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N 7 N t6 Om M U m 0 W 0. 0 IL 0 f6 ce LLL E I O co I W • N co rn a VCL < E ill m Z < wTO co o rn co -I n c 7 UaO U 2 ; 0 CD o 6 I O N n a0 E ¢ N V U d o J (DI c ENIP N ICC O O a co a G N iri cu CO N 0 N E Q v o 1— E 4Y >. c �M Y CO N o) N N I v/ D Lt m c> a) cCI 11 O 0 c t. g ICC z C7 g cv 0 a� ca a C n m O 1 Z Eo ;12 E U 0 2 g coZ d v co I 3 0o Z I v v r �0 N N c) O co co co ✓ 2 F- % N -C c F CO N E = 6 I > aa) ° W c I I OC ` cr) CC H m C) 0 ou c d O c Z c m o r c) 0• 00 o g I < o 0 c c c U J .5 N ` CU7 a o I a n m n E ._• O 0 o d d o m �+ d 2 O d 0 CO) O x G Co) 0 ) • • Release of Confidential Data Coversheet Well Name: QUGRUK 5A PTD: 214-032 E-Set:T24515,T24516,T24517,T24518,T24519,T24520,T24521,T24522,T24523,T25241,T27264 ✓ Physical data labeled with PTD, E-Set# Conf. entry: various ✓ Import CD data to RBDMS ✓ Confidential (incomplete)entry in Well Data List notes Import to DigLogs via E-Set tab i//Scan labeled data Apply OCR text recognition re/Save to Well Log Header Scans V New"complete" entry in Well Data List notes Logged by: Meredith Guhl Fully logged: 6/28/2016 ,2(L-1-032 • -1 21 Repsol REPJOL 2455 Technology Forest Boulevard The Woodlands,TX,77381 06/28/2016 To: AOGCC(Alaska Oil and Gas Conservation Commission) Meredith Guhl,Petroleum Geology Assistant 333 West 7th Avenue,Suite 100,Anchorage,Alaska 99501 EC E I E Meredith.guhl@alaska.gov v Direct:907-793-1235 .;uH 2 8 2016 RE: Repsol Caryn Sodden AOGCC caryn.sodden@repsol.com, 2455 Technology Forest Boulevard The Woodlands,TX,77381 Dear Meredith, In the data listed below, Repsol is hereby submitting the requested technical information for the well Qugruk-5A following the instructions of the regulation 20 AAC 25071 of the Alaska Oil and Gas Conservation Commission (AOGCC): Qugruk-5A(PTD 214-032) - Final Well Test Report 2014_Q5A Please acknowledge receipt by signing and returning a copy of the transmittal letter(by postal mail,email or fax) to the attention of Caryn Sodden,2455 Technology Forest Boulevard,The Woodlands,TX,77381. (2_,a7i s„.__ Date Signed: • • Guhl, Meredith D (DOA) From: MARTIN VICENTE, ALEJANDRO <alejandro.martin@repsol.com> Sent: Tuesday, June 28, 2016 9:06 AM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5, PTD 213-192, Data Required Attachments: Missing Data Q5 AOGCC June 2016 -Transmittal.pdf Meredith, Find the transmittal letter attached. Regards, Alejandro Martin Vicente Operations Geologist :' Geological Ops Americas "" 2455 Technology Forest Boulevard REPT©L The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin@repsol.com From: MARTIN VICENTE, ALEJANDRO Sent: Tuesday, June 28, 2016 11:40 AM To: 'Guhl, Meredith D (DOA)' Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5, PTD 213-192, Data Required Meredith, The requested file is attached in this email, please confirm this is the requested one. Regards, Alejandro Martin Vicente /Operations Geologist Geological Ops Americas VIIV 2455 Technology Forest Boulevard REP1OL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, June 28, 2016 11:23 AM To: MARTIN VICENTE, ALEJANDRO Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5, PTD 213-192, Data Required 1 • Hello Alejandro, • Thank you for that clarification. You are still sending a CD with the LAS files for the Sonic Scanner Run 1E, correct? Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@repsol.com] Sent: Tuesday, June 28, 2016 6:03 AM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5, PTD 213-192, Data Required Hello Meredith, Sorry,for the confusion, but as you can see in the table below there not DLIS files available for run lb as RTScanner (ZAIT) was not included in that run. Best regards, Alejandro Martin Vicente Operations Geologist Geological Ops Americas " 2455 Technology Forest Boulevard REPIO1 The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: aleiandro.martinlP repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Monday, June 27, 2016 6:09 PM To: MARTIN VICENTE, ALEJANDRO Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5, PTD 213-192, Data Required Hello Alejandro, 2 So you are saying there are no DIA, available for the RTScanner Run 1b? OnAS files, along with the PDF image files and the PDF report? Or, as you said in your first email,you are sending the DLIS files? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@repsol.com] Sent: Thursday, June 16, 2016 2:10 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5, PTD 213-192, Data Required Hello Meredith, Just a clarification regarding the data requested in point 1: 1. DLIS file for the RtScanner Run lb.As with Qugruk 5A, the DLIS file on the CD had already been supplied. I also checked data types in the DLIS file against data type sin the LAS files for the RTScanner run and not all data types are in the DLIS file. Please supply the specific DLIS file(s)associated with the RTScanner log. There is no.dlis file for the run la because the toolstrinq got stuck so we could not loq RtScanner(ZAIT)in that run, please see below: 3 uugruk 5 Hole Size Dun Jtipl�ll Max MIT pun Tool Suite Tap(ft MO) ease(ft MD) Date Mirage! Hale (deg c) as. open Hole 1A ZAIT-PEX-1111415-ECS-CMR-GR ti/a 0bigC}hg 2713.0 02/26-27.2014 8hrs 8.5" Open role 15 FMI-GPIT-PPC-M5IP-PPC-GR NA 2298,9 3376,0 21212414 !ibis 85' open Hole lA HF-G PIT-PPC-MSIP-PPC-GR li/A 2298)3 3378.0 .2'28,2014 25 hs as, open Hole 1D HF-PPC-MSIP-PPC-GP rr-IiNGS-GR H/A 2298.0 3378A 212812014 25 his as. open Haie lE HF-HNGG,S--PPC-MSIP-PPC-GR 162 2298.0 7163c 3122014 Chrs 85' open Hole 1F ZAIT-GPIT-PE<-ECS-HNGS-CMR-GR 114 2298.0 48530 3132014 S5 his Please call me if you need anything else. Regards, Alejandro Martin Vicente / ' . Operations Geologist Geological Ops Americas r IIIIIPPPr- 2455 Technology Forest Boulevard REPJOL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alelandro.martin@repsol.com From: MARTIN VICENTE, ALEJANDRO Sent: Thursday, June 16, 2016 2:42 PM To: 'Guhl, Meredith D (DOA)' Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5, PTD 213-192, Data Required Meredith, Regarding your comments: 1. DLIS file for the RtScanner Run lb.As with Qugruk 5A, the DLIS file on the CD had already been supplied. I also checked data types in the DLIS file against data type sin the LAS files for the RTScanner run and not all data types are in the DLIS file. Please supply the specific DLIS file(s) associated with the RTScanner log. We will send you the requested file in a new delivery today 2. LAS files for SonicScanner Run 1E. The LAS file on the CD had already been supplied. I checked data types from the DLIS file against the LAS file supplied and not all data types in the DLIS file are present in the LAS file. Please supply the specific DLIS file(s) associated with the Sonic Scanner log. We will send you the requested file in a new delivery today 3,—Log image files(PDF)for processed Sonic Scanner RunlE. (MAST GR logs have already been supplied). 4.—Paper logs of processed SonicScanner RunlE, i.e. BestDT SonicScanncr. (MAST GR logs have already been supplied). 4 • • 5. Any reports associated with the SonicScanner Run 1E, i.e. SonicScanner Advisor Report.Just confirming that a report wasn't generated, since one was supplied with the Qugruk 5A Sonic Scanner log. 1 confirm that there is no SonicScanner Advisor report for this well Best regards, Alejandro Martin Vicente / f. Operations Geologist ,, , : Geological Ops Americas 2455 Technology Forest Boulevard REPIM The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: aleiandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhk alaska.gov] Sent: Thursday, June 16, 2016 2:15 PM To: MARTIN VICENTE, ALEJANDRO Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: Qugruk 5, PTD 213-192, Data Required Hello Alejandro and Caryn, I've completed the review of Qugruk 5 also.Thank you for the paper log and the PDF images of the CMR and ECS logs. However, RTScanner data and Sonic Scanner data is still not completely supplied. 1. DLIS file for the RtScanner Run lb.As with Qugruk 5A, the DLIS file on the CD had already been supplied. I also checked data types in the DLIS file against data type sin the LAS files for the RTScanner run and not all data types are in the DLIS file. Please supply the specific DLIS file(s)associated with the RTScanner log. 2. LAS files for SonicScanner Run 1E. The LAS file on the CD had already been supplied. I checked data types from the DLIS file against the LAS file supplied and not all data types in the DLIS file are present in the LAS file. Please supply the specific DLIS file(s)associated with the Sonic Scanner log. Log image files(PDF)for processed Sonic Scanner RunlE. (MAST GR logs have already been supplied). 4. Paper logs of processed SonicScanner RunlE, i.e. BestDT SonicScanner. (MAST GR logs have already been supplied). 5. Any reports associated with the SonicScanner Run 1E, i.e. SonicScanner Advisor Report.Just confirming that a report wasn't generated, since one was supplied with the Qugruk 5A Sonic Scanner log. Please supply the data requested above by June 30, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov 5 • Direct: (907) 793-1235 • CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhlPalaska.gov. From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@repsol.com] Sent: Monday, June 06, 2016 2:00 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY Subject: Tuttu 1 and Tuttu PB1, Qugruk 5 and Qugruk 5A, Data Required Importance: High Good afternoon Meredith, We submitted today to the AOGCC the requested information from the Repsol wells drilled in 2014. Find attached the transmittal letter with all the files included in the delivery. Please let us know when the information is received and if you need anything else. Best regards, Alejandro Martin Vicente Operations Geologist ¢. / RFFl4L Geological Ops Americas 2455 Technology Forest Boulevard The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl alaska.gov] Sent: Tuesday, May 31, 2016 1:51 PM To: SODDEN, CARYN JOY Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Tuttu 1 and Tuttu PB1, PTD 213-186, Data Required Importance: High Hello Caryn, Tuttu 1 and Tuttu PB1, PTD 213-186, completed 4/23/2014, was released from confidentiality on 5/24/2016. I am preparing the data and well file for inclusion in the AOGCC archive and several items need to be supplied for the well to be in compliance. 1. Tuttu 1 PB1 Conventional Core Analysis, as noted in the 10-407 packet,for core 1 (3541' to 3550' MD)and core 2 (3556'to 3573' MD). An extension was requested on June 3, 2014 that mentioned both conventional and sidewall core analyses. The sidewall core analyses were received in June and October 2015,the first submission was mislabeled as Tuttu 1. 2. Isotube analysis for Tuttu 1 and Tuttu 1 PB 1, extensions were requested on June 3, 2014 with an estimated submission date of April 2015. No isotube analyses have been received at this time. 6 3. MDT Fluid Samples laborat analyses by Weatherford for both Tuttu nd Tuttu 1 PB1.The extension requests (see attached) estimated a submission date of December 2015. No MDT analyses have been received at this time. Please supply the information listed above by June 17, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informaciOn,por favor,elimine el mensaje.La distribution o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propOsitos de informacion y no deberia ser considerada como una declaraciOn oficial de Repsol.La transmision del correo electrOnico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informaciOn sea complete o precise.Toda informaciOn este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informaciOn,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propositos de informacion y no deberia ser considerada como una declaracion oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea complete o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propositos de informaciOn y no deberia ser considerada como una declaracion oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea complete o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. 7 AVISO LEGAL: • Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propOsitos de informacion y no deberia ser considerada como una declaracion oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea complete o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. 8 • Guhl, Meredith D (DOA) From: MARTIN VICENTE, ALEJANDRO <alejandro.martin@repsol.com> Sent: Tuesday,June 28, 2016 8:37 AM To: Guhl, Meredith D (DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Attachments: Final Well Test Report 2014_Q5A.pdf Meredith, I submitted the Final Well Test Report (Test. No2) from Expro (attached in this email) in the last delivery . Please confirm that you received it. Regards, Alejandro Martin Vicente /Operations Geologist ti„„. Geological Ops Americas 2455 Technology Forest Boulevard REP,OL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, June 28, 2016 11:24 AM To: MARTIN VICENTE, ALEJANDRO Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Hello Alejandro, Thank you for the clarification. You are still sending a CD with the Expro Test 2 report, correct? Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 • • From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@repsol.com] Sent: Tuesday, June 28, 2016 6:08 AM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY; Bettis, Patricia K(DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Good morning Meredith, The DLIS file for the run 1A that we submitted is the only one that we have for that run. Schlumberger provided to a us a single DLIS file for all the logs acquired in the same run (1a). Feel free to give me a call today if you have any questions about the DLIS file provided, I can help you out. Best regards, Alejandro Martin Vicente / .i,,,, Operations Geologist Geological Ops Americas INV 2455 Technology Forest Boulevard REPJOL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Monday, June 27, 2016 6:12 PM To: MARTIN VICENTE, ALEJANDRO Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Hello Alejandro, I'm sorry if I was too specific in request 4. Please send the specific DLIS file(s) for RTScanner Run 1A for Qugruk 5A, not the DLIS file that includes all data collected in Run 1A. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 • • From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@repsol.com] Sent: Thursday, June 16, 2016 1:40 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Hello Meredith, Regarding your comments: 1. A digital copy of the Expro Qugruk 5A report, labeled Test 2 (paper copy supplied with the 10-407 form). I've scanned the first two pages from the paper report in the well history file to help you locate it. The report supplied on June 8 was already submitted. We will send you the requested file in a new delivery today along with the Q5 files 2.—Isotubes analysis that was due to be submitted December 2015 (sec attached extension request) 3. Surface DST Fluid Samples laboratory analysis, due to be submitted January 2015 (see attached extension request). I've scanned the two extension requests received for Qugruk 5A:DST and Surface DST fluid samples. The dead oil report received June 8 was already submitted. Because of the two extension requests in the well history file, it appears that there are two sets of samples for this well. If that is not the case, please provide an explanation. The reason for the differences in the extension requests for Qugruk 5A: DST and Surface DST fluid samples is because they were prepared for different people but they refer to the same, the final dead oil report. 4. Please supply the DLIS file of the RTScanner Run 1A for Qugruk 5A by June 24, 2016. The DLIS file on the CD had already been supplied. I just checked data types in the DLIS file against data types in the LAS files for the RTScanner run and not all data types are in the DLIS file,for example "TLFamily_DQF ZDB", "TLFamily_DPAA_ZDB", "TLFamily_RH72_1DF'; and "TRIFO139". Please supply the specific DLIS file(s)associated with the RTScanner run. There is no any DLIS file with the data types that you are mentioning. Please confirm when you receive the DVD with the requested information. Regards, Alejandro Martin Vicente / ,t Operations Geologist Geological Ops Americas VW 2455 Technology Forest Boulevard REPIOt The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin©repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, June 16, 2016 1:48 PM To: MARTIN VICENTE, ALEJANDRO 3 • Cc: SODDEN, CARYN JOY; Bettis, facia K (DOA) Subject: Qugruk 5A, PTD 214-032, Data Required Hello Alejandro and Caryn, I've completed the review of the recently arrived data submitted for Qugruk 5A. However all data sent last week had already been submitted and received and thus does not fulfill the requests I made. 1. A digital copy of the Expro Qugruk 5A report, labeled Test 2 (paper copy supplied with the 10-407 form). I've scanned the first two pages from the paper report in the well history file to help you locate it. The report supplied on June 8 was already submitted. 2 —Isotubes analysis that was due to be submitted December 2015 (sec attached extension request) 3. Surface DST Fluid Samples laboratory analysis, due to be submitted January 2015 (see attached extension request). I've scanned the two extension requests received for Qugruk 5A:DST and Surface DST fluid samples. The dead oil report received June 8 was already submitted. Because of the two extension requests in the well history file, it appears that there are two sets of samples for this well. If that is not the case, please provide an explanation. 4. Please supply the DLIS file of the RTScanner Run 1A for Qugruk 5A by June 24, 2016. The DLIS file on the CD had already been supplied. I just checked data types in the DLIS file against data types in the LAS files for the RTScanner run and not all data types are in the DLIS file,for example "TLFamily_DQF ZDB", "TLFamily_DPAA_ZDB", "TLFamily_RH72_1DF'; and "TRIFO139". Please supply the specific DLIS file(s)associated with the RTScanner run. Please supply the data requested above by June 30, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl(a)alaska.gov. From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@ repsol.com] Sent: Monday, June 06, 2016 2:00 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY Subject: Tuttu 1 and Tuttu PB1, Qugruk 5 and Qugruk 5A, Data Required Importance: High Good afternoon Meredith, 4 • • We submitted today to the AOGCC the requested information from the Repsol wells drilled in 2014. Find attached the transmittal letter with all the files included in the delivery. Please let us know when the information is received and if you need anything else. Best regards, Alejandro Martin Vicente Operations Geologist ij / Geological Ops Americas 2455 Technology Forest Boulevard REPJOL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, May 31, 2016 1:51 PM To: SODDEN, CARYN JOY Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Tuttu 1 and Tuttu PB1, PTD 213-186, Data Required Importance: High Hello Caryn, Tuttu 1 and Tuttu PB1, PTD 213-186, completed 4/23/2014, was released from confidentiality on 5/24/2016. I am preparing the data and well file for inclusion in the AOGCC archive and several items need to be supplied for the well to be in compliance. 1. Tuttu 1 PB1 Conventional Core Analysis, as noted in the 10-407 packet,for core 1 (3541'to 3550' MD) and core 2 (3556'to 3573' MD).An extension was requested on June 3, 2014 that mentioned both conventional and sidewall core analyses.The sidewall core analyses were received in June and October 2015, the first submission was mislabeled as Tuttu 1. 2. Isotube analysis for Tuttu 1 and Tuttu 1 PB 1, extensions were requested on June 3, 2014 with an estimated submission date of April 2015. No isotube analyses have been received at this time. 3. MDT Fluid Samples laboratory analyses by Weatherford for both Tuttu 1 and Tuttu 1 PB1.The extension requests(see attached) estimated a submission date of December 2015. No MDT analyses have been received at this time. Please supply the information listed above by June 17, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov 5 • Direct: (907)793-1235 • CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida Unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propositos de informaciOn y no deberia ser considerada como una declaration oficial de Repsol.La transmisiOn del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea completa o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propositos de informacion y no deberia ser considerada como una declaration oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este fibre de error.Por consiguiente,no manifestamos que esta informacion sea completa o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicaciOn es solo para propositos de informacion y no deberia ser considerada como una declaration oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informaciOn sea completa o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only. If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informaciOn,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicaciOn es solo para propositos de informacion y no deberia ser considerada como una declaration oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea completa o precise.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. 6 • • Guhl, Meredith D (DOA) From: MARTIN VICENTE, ALEJANDRO <alejandro.martin@repsol.com> Sent: Tuesday, June 28, 2016 6:08 AM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Good morning Meredith, The DLIS file for the run 1A that we submitted is the only one that we have for that run. Schlumberger provided to a us a single DLIS file for all the logs acquired in the same run (1a). Feel free to give me a call today if you have any questions about the DLIS file provided, I can help you out. Best regards, Alejandro Martin Vicente /Operations Geologist Geological Ops Americas VIIIV 2455 Technology Forest Boulevard REPJOL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl©alaska.gov] Sent: Monday, June 27, 2016 6:12 PM To: MARTIN VICENTE, ALEJANDRO Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Hello Alejandro, I'm sorry if I was too specific in request 4. Please send the specific DLIS file(s) for RTScanner Run 1A for Qugruk 5A, not the DLIS file that includes all data collected in Run 1A. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, 1 please delete it,without first saving or foring it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martirarepsol.com] Sent: Thursday, June 16, 2016 1:40 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Hello Meredith, Regarding your comments: 1. A digital copy of the Expro Qugruk 5A report, labeled Test 2 (paper copy supplied with the 10-407 form). I've scanned the first two pages from the paper report in the well history file to help you locate it. The report supplied on June 8 was already submitted. We will send you the requested file in a new delivery today along with the Q5 files 2 Isotubes analysis that was due to be submitted December 2015 (see attached extension request) 3. Surface DST Fluid Samples laboratory analysis, due to be submitted January 2015 (see attached extension request). I've scanned the two extension requests received for Qugruk 5A: DST and Surface DST fluid samples. The dead oil report received June 8 was already submitted. Because of the two extension requests in the well history file, it appears that there are two sets of samples for this well. If that is not the case, please provide an explanation. The reason for the differences in the extension requests for Qugruk 5A: DST and Surface DST fluid samples is because they were prepared for different people but they refer to the same, the final dead oil report. 4. Please supply the DLIS file of the RTScanner Run 1A for Qugruk 5A by June 24, 2016. The DLIS file on the CD had already been supplied. I just checked data types in the DLIS file against data types in the LAS files for the RTScanner run and not all data types are in the DLIS file,for example "TLFamily_DQF ZDB", "TLFamily_DPAA_ZDB", "TLFamily_RH72_1DF', and "TRIFO139". Please supply the specific DLIS file(s)associated with the RTScanner run. There is no any DLIS file with the data types that you are mentioning. Please confirm when you receive the DVD with the requested information. Regards, Alejandro Martin Vicente /Operations Geologist : , Q Geological Ops Americas Mir 2455 Technology Forest Boulevard Ri EPlOL The Woodlands, TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: aleiandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, June 16, 2016 1:48 PM To: MARTIN VICENTE, ALEJANDRO 2 • Cc: SODDEN, CARYN JOY; Bettis, Pita K (DOA) Subject: Qugruk 5A, PTD 214-032, Data Required Hello Alejandro and Caryn, I've completed the review of the recently arrived data submitted for Qugruk 5A. However all data sent last week had already been submitted and received and thus does not fulfill the requests I made. 1. A digital copy of the Expro Qugruk 5A report, labeled Test 2 (paper copy supplied with the 10-407 form). I've scanned the first two pages from the paper report in the well history file to help you locate it. The report supplied on June 8 was already submitted. —Isotubes analysis that was due to be submitted December 2015(see attached extension request) 3. Surface DST Fluid Samples laboratory analysis, due to be submitted January 2015 (see attached extension request). I've scanned the two extension requests received for Qugruk 5A: DST and Surface DST fluid samples. The dead oil report received June 8 was already submitted. Because of the two extension requests in the well history file, it appears that there are two sets of samples for this well. If that is not the case, please provide an explanation. 4. Please supply the DLIS file of the RTScanner Run 1A for Qugruk 5A by June 24, 2016. The DLIS file on the CD had already been supplied. I just checked data types in the DLIS file against data types in the LAS files for the RTScanner run and not all data types are in the DLIS file,for example "TLFamily_DQF ZDB", "TLFamily_DPAA_ZDB", "TLFamily_RH72_1DF", and "TRIFO139". Please supply the specific DLIS file(s) associated with the RTScanner run. Please supply the data requested above by June 30, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@repsol.com] Sent: Monday, June 06, 2016 2:00 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY Subject: Tuttu 1 and Tuttu PB1, Qugruk 5 and Qugruk 5A, Data Required Importance: High Good afternoon Meredith, 3 • We submitted today to the AOGCC the requested information from the Repsol wells drilled in 2014. Find attached the transmittal letter with all the files included in the delivery. Please let us know when the information is received and if you need anything else. Best regards, Alejandro Martin Vicente Operations Geologist Geological Ops Americas 1111W- 2455 Technology Forest Boulevard REPJOL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin@repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, May 31, 2016 1:51 PM To: SODDEN, CARYN JOY Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Tuttu 1 and Tuttu PB1, PTD 213-186, Data Required Importance: High Hello Caryn, Tuttu 1 and Tuttu PB1, PTD 213-186, completed 4/23/2014, was released from confidentiality on 5/24/2016. I am preparing the data and well file for inclusion in the AOGCC archive and several items need to be supplied for the well to be in compliance. 1. Tuttu 1 PB1 Conventional Core Analysis, as noted in the 10-407 packet, for core 1 (3541' to 3550' MD) and core 2 (3556'to 3573' MD). An extension was requested on June 3, 2014 that mentioned both conventional and sidewall core analyses.The sidewall core analyses were received in June and October 2015,the first submission was mislabeled as Tuttu 1. 2. Isotube analysis for Tuttu 1 and Tuttu 1 PB 1, extensions were requested on June 3, 2014 with an estimated submission date of April 2015. No isotube analyses have been received at this time. 3. MDT Fluid Samples laboratory analyses by Weatherford for both Tuttu 1 and Tuttu 1 PB1.The extension requests(see attached) estimated a submission date of December 2015. No MDT analyses have been received at this time. Please supply the information listed above by June 17, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov 4 Direct: (907)793-1235 • • CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. AVISO LEGAL Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informaciOn,por favor,elimine el mensaje.La distribuciOn o copia de este mensaje este estrictamente prohibida.Esta comunicaciOn es solo para propOsitos de informacion y no deberia ser considerada como una declaraci6n oficial de Repsol.La transmisi6n del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea complete o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informaciOn es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribuciOn o copia de este mensaje este estrictamente prohibida.Esta comunicaci6n es solo para propositos de informacion y no deberia ser considerada como una declaraci6n oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea completa o precise.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informaciOn,por favor,elimine el mensaje.La distribuciOn o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propositos de informacion y no deberia ser considerada como una declaraciOn oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informaciOn sea complete o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. 5 • • Guhl, Meredith D (DOA) From: MARTIN VICENTE, ALEJANDRO <alejandro.martin@repsol.com> Sent: Thursday,June 16, 2016 1:40 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY; Bettis, Patricia K (DOA) Subject: RE: Qugruk 5A, PTD 214-032, Data Required Hello Meredith, Regarding your comments: 1. A digital copy of the Expro Qugruk 5A report, labeled Test 2 (paper copy supplied with the 10-407 form). I've scanned the first two pages from the paper report in the well history file to help you locate it. The report supplied on June 8 was already submitted. We will send you the requested file in a new delivery today along with the Q5 files 2, Isotubes analysis that was due to be submitted December 2015 (see attached extension request) 3. Surface DST Fluid Samples laboratory analysis, due to be submitted January 2015 (see attached extension request). I've scanned the two extension requests received for Qugruk 5A:DST and Surface DST fluid samples. The dead oil report received June 8 was already submitted. Because of the two extension requests in the well history file, it appears that there are two sets of samples for this well. If that is not the case, please provide an explanation. The reason for the differences in the extension requests for Quqruk 5A: DST and Surface DST fluid samples is because they were prepared for different people but they refer to the same, the final dead oil report. 4. Please supply the DLIS file of the RTScanner Run 1A for Qugruk 5A by June 24, 2016. The DLIS file on the CD had already been supplied. I just checked data types in the DLIS file against data types in the LAS files for the RTScanner run and not all data types are in the DLIS file,for example "TLFamily_DQF ZDB", "TLFamily_DPAA_ZDB", "TLFamily_RH72_1DF", and "TRIF0139". Please supply the specific DLIS file(s)associated with the RTScanner run. There is no any DLIS file with the data types that you are mentioning. Please confirm when you receive the DVD with the requested information. Regards, Alejandro Martin Vicente Operations Geologist / ,- , Geological Ops Americas IIIIPIr- 2455 Technology Forest Boulevard REPJOL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martin©repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, June 16, 2016 1:48 PM To: MARTIN VICENTE, ALEJANDRO 1 Cc: SODDEN, CARYN JOY; Bettis, Alia K (DOA) • Subject: Qugruk 5A, PTD 214-032, Data Required Hello Alejandro and Caryn, I've completed the review of the recently arrived data submitted for Qugruk 5A. However all data sent last week had already been submitted and received and thus does not fulfill the requests I made. 1. A digital copy of the Expro Qugruk 5A report, labeled Test 2 (paper copy supplied with the 10-407 form). I've scanned the first two pages from the paper report in the well history file to help you locate it. The report supplied on June 8 was already submitted. 2,—Isotubes analysis that was due to be submitted December 2015 (see attached extension request) 3. Surface DST Fluid Samples laboratory analysis, due to be submitted January 2015 (see attached extension request). I've scanned the two extension requests received for Qugruk 5A: DST and Surface DST fluid samples. The dead oil report received June 8 was already submitted. Because of the two extension requests in the well history file, it appears that there are two sets of samples for this well. If that is not the case, please provide an explanation. 4. Please supply the DLIS file of the RTScanner Run 1A for Qugruk 5A by June 24, 2016. The DLIS file on the CD had already been supplied. I just checked data types in the DLIS file against data types in the LAS files for the RTScanner run and not all data types are in the DLIS file,for example "TLFamily_DQF ZDB", "TLFamily_DPAA_ZDB", "TLFamily_RH72_1DF", and "TRIFO139". Please supply the specific DLIS file(s)associated with the RTScanner run. Please supply the data requested above by June 30, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl(talaska.gov. From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@repsol.com] Sent: Monday, June 06, 2016 2:00 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY Subject: Tuttu 1 and Tuttu PB1, Qugruk 5 and Qugruk 5A, Data Required Importance: High Good afternoon Meredith, 2 • • We submitted today to the AOGCC the requested information from the Repsol wells drilled in 2014. Find attached the transmittal letter with all the files included in the delivery. Please let us know when the information is received and if you need anything else. Best regards, Alejandro Martin Vicente /Operations Geologist .. Geological Ops Americas 1 MIPPV 2455 Technology Forest Boulevard REPAVE. The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: alejandro.martint repsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, May 31, 2016 1:51 PM To: SODDEN, CARYN JOY Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Tuttu 1 and Tuttu PB1, PTD 213-186, Data Required Importance: High Hello Caryn, Tuttu 1 and Tuttu PB1, PTD 213-186, completed 4/23/2014,was released from confidentiality on 5/24/2016. I am preparing the data and well file for inclusion in the AOGCC archive and several items need to be supplied for the well to be in compliance. 1. Tuttu 1 PB1 Conventional Core Analysis, as noted in the 10-407 packet, for core 1 (3541' to 3550' MD) and core 2 (3556'to 3573' MD). An extension was requested on June 3, 2014 that mentioned both conventional and sidewall core analyses. The sidewall core analyses were received in June and October 2015,the first submission was mislabeled as Tuttu 1. 2. Isotube analysis for Tuttu 1 and Tuttu 1 PB 1, extensions were requested on June 3, 2014 with an estimated submission date of April 2015. No isotube analyses have been received at this time. 3. MDT Fluid Samples laboratory analyses by Weatherford for both Tuttu 1 and Tuttu 1 PB1.The extension requests (see attached) estimated a submission date of December 2015. No MDT analyses have been received at this time. Please supply the information listed above by June 17, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov 3 Direct: (907)793-1235 • • CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida iunicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informaciOn,por favor,elimine el mensaje.La distribuci6n o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propositos de informacion y no deberia ser considerada como una declaraciOn oficial de Repsol.La transmisi6n del correo electrOnico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea complete o precisa.Toda informaciOn este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribuciOn o copia de este mensaje este estrictamente prohibida.Esta comunicaciOn es solo para prop6sitos de informaciOn y no deberia ser considerada como una declaraciOn oficial de Repsol.La transmisi6n del correo electrOnico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea complete o precisa.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All iriformation is subject to change without notice. 4 • • Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Thursday, June 16, 2016 10:48 AM To: 'MARTIN VICENTE, ALEJANDRO' Cc: SODDEN, CARYN JOY; Bettis, Patricia K(DOA) Subject: Qugruk 5A, PTD 214-032, Data Required Attachments: Repsol_Transmittal.pdf; 2140320 Qugruk 5A.pdf Hello Alejandro and Caryn, I've completed the review of the recently arrived data submitted for Qugruk 5A. However all data sent last week had already been submitted and received and thus does not fulfill the requests I made. 1. A digital copy of the Expro Qugruk 5A report, labeled Test 2 (paper copy supplied with the 10-407 form). I've scanned the first two pages from the paper report in the well history file to help you locate it. The report supplied on June 8 was already submitted. 3. Surface DST Fluid Samples laboratory analysis, due to be submitted January 2015 (see attached extension request). I've scanned the two extension requests received for Qugruk SA: DST and Surface DST fluid samples. The dead oil report received June 8 was already submitted. Because of the two extension requests in the well history file, it appears that there are two sets of samples for this well. If that is not the case, please provide an explanation. 4. Please supply the DLIS file of the RTScanner Run 1A for Qugruk 5A by June 24, 2016. The DLIS file on the CD had already been supplied. I just checked data types in the DLIS file against data types in the LAS files for the RTScanner run and not all data types are in the DLIS file,for example "TLFamily_DQF ZDB", "TLFamily_DPAA_ZDB", "TLFamily_RH72_1DF'; and "TRIF0139". Please supply the specific DLIS file(s)associated with the RTScanner run. Please supply the data requested above by June 30, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 110 • From: MARTIN VICENTE, ALEJANDRO [mailto:alejandro.martin@repsol.com] Sent: Monday, June 06, 2016 2:00 PM To: Guhl, Meredith D (DOA) Cc: SODDEN, CARYN JOY Subject: Tuttu 1 and Tuttu PB1, Qugruk 5 and Qugruk 5A, Data Required Importance: High Good afternoon Meredith, We submitted today to the AOGCC the requested information from the Repsol wells drilled in 2014. Find attached the transmittal letter with all the files included in the delivery. Please let us know when the information is received and if you need anything else. Best regards, Alejandro Martin Vicente / , Operations Geologist Geological Ops Americas J Iiir 2455 Technology Forest Boulevard REP,OL The Woodlands,TX 77381 Tel: 832 442 1478 I Mobile: 832 381 8898 email: aleiandro.martin@irepsol.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, May 31, 2016 1:51 PM To: SODDEN, CARYN JOY Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Tuttu 1 and Tuttu PB1, PTD 213-186, Data Required Importance: High Hello Caryn, Tuttu 1 and Tuttu PB1, PTD 213-186, completed 4/23/2014, was released from confidentiality on 5/24/2016. I am preparing the data and well file for inclusion in the AOGCC archive and several items need to be supplied for the well to be in compliance. 1. Tuttu 1 PB1 Conventional Core Analysis, as noted in the 10-407 packet, for core 1 (3541'to 3550' MD)and core 2 (3556'to 3573' MD).An extension was requested on June 3, 2014 that mentioned both conventional and sidewall core analyses.The sidewall core analyses were received in June and October 2015,the first submission was mislabeled as Tuttu 1. 2. Isotube analysis for Tuttu 1 and Tuttu 1 PB 1, extensions were requested on June 3, 2014 with an estimated submission date of April 2015. No isotube analyses have been received at this time. 3. MDT Fluid Samples laboratory analyses by Weatherford for both Tuttu 1 and Tuttu 1 PB1.The extension requests (see attached) estimated a submission date of December 2015. No MDT analyses have been received at this time. Please supply the information listed above by June 17, 2016. If you have any questions, please contact me. Thank you, 2 4110 Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. AVISO LEGAL: Esta informaciOn es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicaciOn es solo para propOsitos de informaciOn y no deberia ser considerada como una declaration oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea complete o precisa.Toda informaciOn este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. 3 1110 Repsol E&P USA Inc. 2455 Technology Forest Boulevard The Woodlands,Texas,77381 REPJOL Cancellation of Data Submittal Meredith Guhl AOGCC(Alaska Oil and Gas Conservation Commission) RECEIVED 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 JUN 8 2016 907-793-1225 AOGCC REFERENCE: Qugruk-5A(API: 50-103-20682-01-00; PTD: 214-032) Information: Isotubes Analysis In April 2015, Repsol formally submitted a Data Submittal Extension Request until December 2015 for the following Qugruk-5A Isotubes Analysis: • Isotopic/Compositional • Carbon isotope • Hydrogen isotope The laboratory work itemized in Repsol's Data Submittal Extension Request for Qugruk-5A Isotubes Analysis has not been done, and the work is no longer scheduled to be performed. Please confirm acknowledgment of cancellation of the aforementioned laboratory analysis by signing in the space provided below and returning one (1) copy of this letter to the undersigned. Sincerely yours, Caryn J Sodden caryn.sodden@repsol.com 832-442-1628 Cancellation of the aforementioned work is acknowledged this v day of \M(lQ_, 2016. A&11° By AOGCC • 'M • r Repsol REPJOL 2455 Technology Forest Boulevard The Woodlands,TX,77381 06/06/2016 To: AOGCC(Alaska Oil and Gas Conservation Commission) Meredith Guhl,Petroleum Geology Assistant 333 West 7`h Avenue,Suite 100,Anchorage,Alaska 99501 Meredith.guhl@alaska.gov Direct:907-793-1235 RE: Repsol '. CEIVED Caryn Sodden caryn.sodden@repsol.com 2455 Technology Forest Boulevard JUN 0 8 2016 The Woodlands,TX,77381 Dear Meredith, AOGCC In the data listed below, Repsol is hereby submitting the requested technical information for the wells Qugruk 5, Qugruk-5A,Tuttu-1 and Tuttu-1 PB01 following the instructions of the regulation 20 AAC 25071 of the Alaska Oil and Gas Conservation Commission (AOGCC). Qugruk-5 2-13- 1°12- 1 CD: - Cancellation_AOGCC_Isotube_Analysis_Q-5-.docx-i 2 7-2(o Run 1B Resistivity Scanner ZAIT - Qugruk5_Run1b_Rtscanner_1D_Inv_54in_2300ft_4810ft_Print825- .pdf.---- txtreAIrrtcgily-cd -T 2-`1`14-4- - Qugruk5_Run1b_Rtscanner_1D_Inv_2300ft_4810ft_1ft_Zerod_Dip_Output Jas a_.'J rGexie T q1441- - Qugruk5_Run1b_Rtscanner_1D_Inv_2300ft_4810ft_6in_Output-.las -aar rt w\ 9(T244'4* - Qugruk5_Run1b_Rtscanner_1D_Inv_2300ft_4810ft_10ft_54in_Dip_Output-.las-atre.ad,lyccuvea( 1-2441-4/- - Qugruk5_Run1b_Rtscanner_1d_VFD_2300ft_4810ft_Output-Jas-a1l.vukal, recuve4 TZW44 + - Qugruk5_Run1b_Rtscanner_1d_VFD_2300ft_4810ft_Printl4-.pdf—al, reazlvecl T 24441- - Qugruk5_Run1B_PPC_GPIT_CALIPER_MD-.dlis- aJ - ytGt-veal T24v48 Run 1E Sonic Scanner MAST - Qugruk5_Mech_Earth_Model_PTS_Processed-.las -olve.. ,44.i rcatm-A 124441- - Qugruk5_Mech_Earth_Model_PTS_Processed-.pdf - 0..4re_..4..0 y J(V-o-ot T 24"41- - Qugruk5_Run1E_HNGS_GPIT_SONIC_CALIPER_MD-.las-al7rCAal r4.ceb-cat` Z11448 - Qugruk5_Run1E_HNGS_GPIT_SONIC_CALIPER_TVD-.las-et/Jr—WI 1 c-w' ,( 1-2-14448 �' l a�Q,r{_w4aw rcC4 4 T24441 -1-c-"a v‘44( ud ''f 2:4-23 - Qugruk5_Run1E-SonicScanner-PTS-Processed-.dlis- � - Qugruk5_Run1E_SonicScanner_PTS_Processed- .pdf'[Z1 2_ Run 1F CMR-ECS-GR - Qugruk5_Run1F_CMR_2inMD-.pdf \ - Qugruk5_Run1F_CMR_2inTVD-.pdf Zy LILA 5_ oszko - Qugruk5_Run1F_CMR_5inMD-.pdf - Qugruk5-Run1F_CMR_5inTVD-.pdf/ - Qugruk5_Run1F_ECS_2inMD-.pdf Repsol REP$OL 2455 Technology Forest Boulevard The Woodlands,TX,77381 - Qugruk5_Run1F_ECS_2inTVD-.pdf\r - Qugruk5_Run1F_ECS_5inMD-.pdf /�[. Zqu 'S _ - Qugruk5_Run1F_ECS_5inTVD-.pdf Paper Copies: - Qugruk5_Run1E_SonicScanner_PTS_Processed- 27Z(o3 lECEIVED Queruk-5A,Tutu-1 and Tuttu-1 PB1 JUN "�+�� 1CD: O '± C Qugruk-5A 2-1'1-0 2_ - Ca ncellation_AOGCC_Data_Submittal_Isotube_Analysis_Q-5A-.docx T2-1-2-(&1 - Qugruk5A_Run1A_ZAIT_MSIP_PEX_MAIN_MD-.14) , dltS- G`A fe ve..4 TZ�{519 - Composition of Dead Oil Qugruk-5A-.pdf-a0xte.ai) rcc.e,��v T 2 5 l-11 - Repsol Q-Sa_Daily Flowback Report_Q-5A(DST Final Report from EXPRO)-pdf -samtodi v-c c eAM-A 2L1 5 5 Tuttu-1 Z I - 1 g(� - Cancellation_AOGCC_Data_Submittal_lsotube_Analysis_Tuttu-1-.docx 127 2(05 - Tuttu-1 Single Stage-.pdf - Tuttu-1 Oil Viscosity- .xlsx 2-G5- Water Compositions Tuttu-1- .xlsx Z� - 500292350600_Tuttu-1_CoreDescription_c1-3_11x17-.pdf - 500292350600_Tuttu-1_CoreDescription_c4-5_11x17-.pdf �� T 25�� - 500292350600_Tuttu-1_Petrographic Report_Conventional Core Plugs-.pdf GV� J Y 2GQ� - 500292350600_Tuttu-1_Routine_Core_Analysis_10-Oct-2014-.xlsx - 500292350600_Tuttu-1_Spectral_Gamma_23-Apr-2014-.xlsx Tuttu-1 PB1 23-\ S(0 - Cancellation_AOGCC_Data_Submittal_Isotube_Analysis_Tuttu-1 PB1 - Tuttu-1 and Tuttu-1PB Oil Viscosity-.xlsx Z Zoo - Tuttu-1PB Oil Viscosity Update-.xlsx - Tuttu-1PB Single Stage Fluid Analysis-.pdf - 500292350670_Tuttu-1_PB1_CoreDescription-.pdf - 500292350670_Tuttu-1_PB1_CoreDescription_11x17-.pdf Please acknowledge receipt by signing and returning a copy of the transmittal letter(by postal mail,email or fax) to the attention of Caryn Sodden, 2455 Technology Forest Boulevard,The Woodlands,TX, 77381. Date U M 0 2-0\ Signed: • i Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Thursday,June 02, 2016 10:55 AM To: 'SODDEN, CARYN JOY' Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Qugruk 5A, PTD 214-032, Data missing Attachments: Qugruk 5A T24516.pdf Importance: High Caryn, Along with the issue noted in Qugruk 5 data, a similar issue was noted with the Sonic Scanner/RT Scanner data for Qugruk 5A. All paper logs and images are complete, along with LAS files, however a DLIS file for the RTScanner was not supplied. See attached inventory supplied by Repsol. Please supply the DLIS file of the RTScanner Run 1A for Qugruk 5A by June 24, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl(c@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 ` v • 'a E c° u o . 0 U o° W CO Lfl 0 m a o vi o •,. c m o Q L 3a^ V W ■V .° azLL CU z E 3 ° c W E r0 N 33 -oTs o i — o0 m & 3 3 888 u 2 Z Z LT_ ti 0 z 0 0 0 Fj E o 0 0 ag$4 • 4111 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Friday, May 27, 2016 2:46 PM To: 'SODDEN, CARYN JOY' Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Qugruk 5A, PTD 214-032, Data Required Attachments: Qugruk 5A.pdf Importance: High Hello Caryn, Qugruk 5A, PTD 214-032, completed 4/24/2014,was released from confidentiality on 5/25/2016. I am preparing the data and well file for inclusion in the AOGCC archive and several items need to be supplied for the well to be in compliance. 1. A digital copy of the Expro Qugruk 5A report, labeled Test 2 (paper copy supplied with the 10-407 form). 2. Isotubes analysis that was due to be submitted December 2015 (see attached extension request) 3. Surface DST Fluid Samples laboratory analysis, due to be submitted January 2015 (see attached extension request). Please supply the information above by June 15, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhlPalaska.gov. 1 • • 21 1 -032. Guhl, Meredith D (DOA) From: Decker, Paul L(DNR) Sent: Wednesday, May 18, 2016 4:24 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: RE: Qugruk 5 and Qugruk 5A, Extended Confidentiatity? Hello Meredith, For the record, DNR received two identical letters dated May 9, 2016 from Mr. Ed Kerr representing two LLC's (Armstrong Energy, LLC and 70 & 148, LLC) to extend the confidentiality period for a number of the Qugruk wells, including Qugruk 5 and 5A. After a telephone discussion with Mr. Kerr regarding that initial request, DNR received a new letter dated May 13, 2016 from Mr. Kerr(Armstrong Energy, LLC) clearly stating it "shall serve as a replacement letter for that certain letter sent on May 9th, 2016". The replacement request drops all wells other than Qugruk 7 from consideration for extended confidentiality at this time. There is no longer any active request to extend confidentiality of the Qugruk 5 or 5A wells. Thank you, -Paul Paul L. Decker,Petroleum Geologist Resource Evaluation Manager Alaska Division of Oil&Gas 550 W.7th Ave,Ste. 1100 Anchorage,AK 99501 (907)269-8791 paul.decker@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Department of Natural Resources(DNR),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 DNR is aware of the mistake in sending it to you,contact Paul Decker at(907) 269-8791 or paul.decker@alaska.Rov. From: Guhl, Meredith D (DOA) Sent:Wednesday, May 18, 2016 3:59 PM To: Decker, Paul L(DNR)<paul.decker@alaska.gov> Cc: Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: Qugruk 5 and Qugruk 5A, Extended Confidentiatity? Hello Paul, Has extended confidentiality been requested for Qugruk 5 (PTD 213-192) and Qugruk 5A(PTD 214-032), due for release after 5/24/2016? It is the AOGCC's policy to hold the mainbore confidential until the sidetrack is released, hence the longer than 25 months confidential period for Qugruk 5. Thank you, Meredith 1 S • Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 • I REPJOL Data Submittal Extension Request Repsol Services Company 2455 Technology Forest Boulevard The Woodlands,Texas,77381 As at April 2015,the following information from Qugruk 5A well is not ready for submission: Isotubes analysis. Repsol thereby requests an official Extension for submission. The laboratory to make the isotubes analysis is not defined yet. However, we are planing to perform the following: • Isotopic/Compositional analysis • Carbon isotope analysis • Hydrogen isotope analysis The estimated time for the submission of these data will be: December 2015 The following person will be responsible for update status of the mentioned studies: Lorenzo Villalobos Alaska Exploration Manager LVILLALOBOSV@repsolsinopec.com (832)442 1189 P)N \V a52y1 REPJ OL ✓AN X22415 Data Submittal Repsol Services Company 2455 Technology Forest Boulevard The Woodlands,Texas,77380 As of December 2014,the following information for Qugruk-5A is ready for submission: DST fluid samples laboratory analysis. The following analysis/studies were performed in the Weatherford laboratory, Houston,TX. • Compositional Analysis of Dead Oil You may contact the following person to request further information of the mentioned analysis/studies: Jansen Oliveira Reservoir engineer jansen.dantas@repsol.com 832-442-1412 • • Repsol Weatherford 'CONFIDENTIAL PER AS 38.05.180(8)(C)' Qugruk-5A t.A f3 c;i:?, Composition Oil Composition Qugruk-5A Estimated Mud Contamination:52.86 wt% I? Residual Component ' Component Liquid Properties ✓q Wt Mol MW Density N r� gm/mol gm/cm' Al�'�/d <Os C1 Methane 0.001 0.008 16.0 0.3562 /�0 C2 Ethane 0.003 0.017 30.1 0.3562 C3 Propane 0.017 0.082 44.1 0.5070 iC4 iso-Butane 0.010 0.037 58.1 0.5629 nC4 n-Butane 0.018 0.062 58.1 0.5840 iC5 iso-Pentane 0.026 0.073 72.2 0.6244 nC5 n-Pentane 0.032 0.090 72.2 0.6311 C6 Hexanes 0.131 0.323 84.0 0.6850 C7 Heptanes 0.730 1.571 96.0 0.7220 C6 Octanes 1.497 2.889 107 0.7450 C9 Nonanes 1.595 2.722 121 0.7640 C10 Decanes 1.873 2.887 134 0.7780 C11 Undecanes 1.857 2.609 147 0.7890 C12 Dodecanes 6.446 8.268 161 0.8000 C13 Tridecanes 17.851 21.063 175 0.8110 C14 Tetradecanes 20.448 22.223 190 0.8220 C15 Pentadecanes 15.172 15.208 206 0.8320 C16 Hexadecanes 5.626 5.233 222 0.8390 C17 Heptadecanes 2.370 2.064 237 0.8470 C18 Octadecanes 1.627 1.339 251 0.8520 C19 Nonadecanes 1.299 1.020 263 0.8570 C29 Eicosanes 1.090 0.818 275 0.8620 C21 Henicosanes 1.063 0.755 291 0.8670 C22 Docosanes 0.966 0.654 305 0.8720 C23 Tricosanes 0.936 0.608 318 0.8770 C24 Tetracosanes 0.886 0.553 331 0.8810 C26 Pentacosanes 0.851 0.509 345 0.8850 C26 Hexacosanes 0.844 0.486 359 0.8890 C27 Heptacosanes 0.832 0.459 374 0.8930 C29 Octacosanes 0.785 0.418 388 0.8960 C29 Nonacosanes 0.761 0.391 402 0.8990 C30 Triacontanes 0.689 0.342 416 0.9020 C31 Hentriacontanes 0.705 0.339 430 0.9060 C32 Dotriacontanes 0.646 0.301 444 0.9090 C33 Tritriacontanes 0.656 0.296 458 0.9120 Cu Tetratriacontanes 0.508 0.222 472 0.9140 C35 Pentatriacontanes 0.552 0.234 486 0.9170 C36+ Hexatriacontanes plus 8.600 2.828 628 0.9338 Total 100.000 100.000 Molecular Weight gm/mol 212.49 Density gm/cc 0.8408 HH-69462 Page 1 of 3 • • IV Repsol WeathalKil `CONFIDENTIAL PER AS 38.05.180(8)(C)' Qugruk-6A L ABCRAT ORI€S Composition Plus Fraction Properties Qugruk-5A Estimated Mud Contamination:52.86 wt% Hydrocarbon Plus(C„,)Properties(1) Component Total Fluid Molecular Liquid Fraction Wt Mol Wt Density % % gm/mol gm/cm3 C6, Hexanes plus 99.894 199.524 207 0.8215 Heptanes plus 99.763 199.070 207 0.8236 C10, Decanes plus 95.940 188.066 215 0.8260 C11. Undecanes plus 94.067 183.306 218 0.8551 C15, Pentadecanes plus 47.465 82.541 279 0.8995 Cp, Eicosanes plus 21.371 31.584 432 0.9137 C25, Pentacosanes plus 16.430 23.255 497 0.9245 C3o, Triacontanes plus 12.356 16.918 559 0.9325 C36, Hexatriacontanes plus 8.600 2.828 628 0.9338 (1)Calculated by summation of all compositional data. HH-69462 Page 2 of 3 • o N ,0 C ° a x E M 4Y 7 N 7 G p c� o a U O m 090 690 8900' L90 990 99 o N 1 • `liJ j ..i i A ° ., rL 0 Le ca sZ H Z� 0 U £Z� c ZZO ll0 ° a oZ0 ro E U E 6l0 1- 2 840 0 00 t L40 � i U 9l0 W 00 co r-i co ID u1 0 O _tr40 0 Z10 '. _ N N 0 Q 0 443 cc 0 Lu c 04� auazua9Wl Q 0 60 a etic p. Z \ � 3— W .§ 0 80 Z ea' o 90A3W L 0auepo-osi UU oa auexayogik A 0 N3dA331(1. c Q 5 I= l) o < L . t10 i. 9 — C L.L. -- 0 E i m 8 8 o 0 ° N Nall Z < < CC 0 (V 030.1 me d YJ a yd`asuodsea = • •(jrLLkcA Regg, James B (DOA) From: Hill, Johnnie W (DOA) Sent: Thursday, September 04, 2014 7:14 PM I��G I C1(19/(4 To: Regg, James B (DOA) l Subject: Qugruk 5 Pics _ ‘../(--t ttj,\ Attachments: DSC05048.JPG; DSC05049.JPG; DSC05050.JPG; DSC05051.JPG; DSC05052.JPG Dicks ,fie Johnnie Hill Petroleum Inspector AOGCC 907-659-2714 907-715-7574 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 Johnnie Hill at 907-659-2714 or johnnie.hill@alaska.gov i • su 00. fr {4 r a .,`�'*k�'a ,..?`h1; = e �Q x •P • tg,,'41;. 'yF. p..C.1', f'-,',..'`Cl...- X" ':'*.i;;;01'.• .•1,4 k ,o,',-*-,,,;;;, .aux 7'" tt `" 1 }.4311*--, 4 }'"` f §. r a "` '" } t�€- x•" a s, §k �.:Y%a #*H4', ° + . !..-.;'-'.. : '''''-,-,-'''' .- '''1:'''''1; ) V.t44',::-..,;:;1-4tor,-.,. , 4 A*,;;;...1,,,,,t -,14-!'k Att.. P,,,,:4,,, ::::„.1-4,...,:7::"....N,,,,, �p�,,�� s ,"--"!..-..,'-'..-.. 1.,,,,i � ��! ,� �� ¢ �,.� ±ems ^'{ 4''yy S 4y� $ nY - �. 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O 2` }Y 1 a4 3 4 $ W, x } d u x, z 4 - m ' 4 ' 4 ,, kJ., , , , , : ,, 1 i'l -- - '''',,,', ,,,,,,,,,:110: #,i':,,,,t2 1: pp k � %' t x ff 111' 5 t ' { ; / < holl . IIII 4 \ f . ! \ ‘ \ . f \ - , . i < * ( „ $ , r I , / \. \� 1, f ° % . ! } . %, . . *y : z \ � . » .y\ . : / . » � � ,, 4 • a Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday,June 05, 2014 2:10 PM To: flynn, tim (ext) (tim.flynn@servexternos.repsol.com) Subject: RE: Q-5A (PTD 214-032) Could you also send a vendor frac report summary too. NG Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Thursday, June 05, 2014 1:53 PM To: flynn, tim (ext) (tim.flynn@servexternos.repsol.com) Subject: Q-5A (PTD 214-032) Tim, I could not find the cementing report for the 7" casing in the 10-407 report. Also the surface casing report has the wrong casing listed in the upper section .. shows talley for the 7" casing. Can you resend me those two spreadsheets.... Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or( ). 1 • • REPlOL REcevittlis Data Submittal Extension Request JUN Q 3 2014 A06§§ Repsol Services Company 2001 Timberloch Place,Suite 3000 The Woodlands,Texas,77380 As of May 2014,the following information,for Qugruk-5A well, is not ready for submission: DST Fluid Samples laboratory analysis. Repsol thereby requests an official Extension for submission. The following analysis/studies are planned to be performed in the Weatherford labrotary, Houston,TX: • Bulk properties and composition The estimated time for the submission of these data will be: September/2014. You may contact the following person to request a status update of the mentioned analysis/studies: Yan Dong Reservoir engineer ydong@repsol.com Q 832-442-1756 1 P_f-e,,o.L J` I// / ol r 1-262-1I • ,2114-032- a REPlOL 4ECEIIED Data Submittal Extension Request JUN 0 3 2014 r for Repsol Services Company 2001 Timberloch Place,Suite 3000 The Woodlands,Texas,77380 As at May 2014,the following information from Qugruk 5A well is not ready for submission: Isotubes analysis. Repsol thereby requests an official Extension for submission. The laboratory to make the isotubes analysis is not defined yet. However,we are planing to perform the following: • Isotopic/Compositional analysis • Carbon isotope analysis • Hydrogen isotope analysis The estimated time for the submission of these data will be: April 2015 The following person will be responsible for update status of the mentioned studies: Lorenzo Villalobos Alaska Exploration Manager LVILLALOBOSV@Irepsolsinopec.com (832)442 1189 02/y-o 3 2 • s RECEIVED REPlOL AUG 2 9 2014 AOGCC Data Submittal Extension Request Repsol Services Company 2001 Timberloch Place,Suite 3000 The Woodlands,Texas,77380 As of August 2014,the following information,for Qugruk-5A, is not ready for submission: Surface DST Fluid Samples laboratory analysis. Repsol thereby requests an official Extension for submission. The following analysis/studies are planned to be performed in the Weatherford labrotary, Houston,TX: • Single-stage flash The estimated time for the submission of these data will be:January/2015. You may contact the following person to request a status update of the mentioned analysis/studies: Jansen Oliveira Reservoir engineer c07/ 6jansen.dantas@repsol.com „ ,/, G�� 832-442-1412 1)ST r bo- tAi\ eit'70,tv-ta 041 ,06,11/` I&kV -fr) • Repsol Services Company REPSOL 2001 Timberloch Place,Suite 3000 The Woodlands,Texas,77380 RECEWED JUN 0 3 2014 06/03/2014 To: AOGCC(Alaska Oil and Gas Conservation Commission) AOGCC Makana Bender,Natural Resources Technician 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: REPSOL Lorenzo Villalobos/Juan Aluja jaluiav@repsol.com FAX 287- -17' 773 2001 Timberloch Place,Suite 3000 The Woodlands,TX,77380 Dear Makana, In the data listed below, Repsol Alaska is hereby resubmitting the technical information for the well Qugruk 5A following the instructions of the regulation 20 AAC 25071 of the Alaska Oil and Gas Conservation Commission(AOGCC). 9 CDs: 2A523 - CD#1 MUDLOGGING:containing Canrig's Mudlogging final deliveries 2AS22 - CD#2 LOGGING WHILE DRILLING:containing Schlumberger's LWD final deliveries - CDs#3-#7 WIRELINE LOGGING:containing Schlumberger's Wireline Logging final deliveries 2-452k,2-t52.0,2?.(50,'2-`t5‘%,2-45v-T ZcJ�6 - CD#8 PROCESSED WIRELINE LOGGING DATA:Advanced Analysis �.e1v5�5 - CD#9 MISCELLANEOUS:containing Well Data Required by AOGCC Paper Copies: - Mudlogging final plots - LWD final plots in 2"and 5"scales,in TVD and in MD. - Wireline Logging final plots Extension Requests for following analysis/studies: - Isotubes analysis - DST fluid samples laboratory analysis See attachment for complete inventory of deliverables. 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' - - ---- • co 0 _ d 2 a v o g Cr)m � 0 o my x rnN t C- 0 J^ D e 3x —.8 Q lc o Q RM M W Q Q ` O> d 8 2 =x`O Q Fo m L o 0 Zyo 2 m J w 0 J 7 � d N x C f W K� Z W H N E z N w Q LL N ?W C Q Q m A N LL O m r m Q F- 'S d J c m O N c O To ca J N a) U_ 0 d m E � E U ❑ • • Schlumberger -2-LA 5z2 e Drilling&Measurements 2525 Gambell Street.Suite 400 Anchorage AK 99503 Tel(907)273-1700 R EPi OL Fax(907)561-8317 çî\ tt1M. Date: 21-Mar-2014 `" (4. ;-.I,1 Well Name: Qugruk 5A JUN 0 3 2014 Company: Repsol E&P USA Inc. API Number: 50-103-20682-01-00 MaititV AFE Number: NS-13-001 Field: North Slope Rig: Nabors 105AC Schlumberger mar REPJOL Date: 7-Mar-2014 Well Name: Qugruk 5A Company: Repsol E&P US Inc. API Number: 50-103-20682-01-00 AFE Number: NS-13-001 Location: N 5987456 ft US, E 438058 ft US Field: North Slope Rig: Nabors 105AC Drilling and Measurements Field Support: Operations Manager, Ankur Prakash Field Service Manager, Carolina Pena Drilling and Measurements Field Crew: Cell Manager, Kyle Antonini Cell Engineer, Caitlin Schnitzer Panpim Lohachala Nicholas Ramkissoon "CONFIDENTIAL DATA TRANSMITTAL PER AS 38.05.180(8)(C)." SERVICES PROVIDED Services Services Dates Depth Intervals Directional Survey Service 11-Mar-14 to 21-Mar-14 2,325 ft to 8,015 ft VISION*Resistivity(Resistivity, Gamma Ray) 11-Mar-14 to 21-Mar-14 2,255 ft to 7,977 ft VISION*Service(Density, Porosity, Caliper) 15-Mar-14 to 21-Mar-14 2,361 ft to 7,977 ft OPERATING STATISTICS Total MWD Pumping Time: 106.69 hours Total LWD Pumping Time: 106.69 hours Total MWD Time Below Rotary: 245.75 hours Total LWD Time Below Rotary: 245.75 hours Total MWD Depth Interval: 5,690 ft Total LWD Depth Interval: 5,722 feet Total MWD Runs: 2 Total LWD Runs: 2 JOB PERFORMANCE Directional The final MWD survey point of Qugruk 5A was located at 7,946.89 feet with an inclination of 36.50 degrees and an azimuth of 355.79 degrees. This direction and inclination was projected from the final survey point to TD, which resulted in the following bottom hole coordinates. Measured Depth: 8,015 ft True Vertical Depth: 7009.78 ft Displacement at Azimuth: 3,104.86 ft at 354.749 deg Formation Evaluation The well Qugruk 5A was sidetracked from the original wellbore, Qugruk 5. It was successfully drilled in two runs. It began from 20 feet below the casing shoe at 2,325 ft MD and kicked off from the original wellbore at approximately 2,330 ft MD, building to a tangent and holding to Total Depth.The kick-off direction was set initially to north with a Gyro Schlumberger low REPJO[ tool and then time-drilled while sliding. The well was logged while drilling with the VISION*Service, providing Gamma Ray, Resistivity, Density, Porosity, Caliper,and Drilling Mechanics measurements, in Real Time and Recorded Mode. 12-1/4 inch Section: The Surface Hole Section was completed in the previous wellbore, Qugruk 5, and its information is included in this report as a reference. It was drilled out of the 20 inch conductor casing from 316 ft MD to the planned casing point at 2,325 ft MD. It was completed in one run. Directional Measurements, Gamma Ray, and Resistivity were provided in Real Time and Recorded Mode.The BHA was composed of a Motor, arcVISION*825, and PowerPulse*825.A milled tooth bit was used in this run.The formation was evaluated while drilling,with arcVISION*measuring Gamma Ray and Resistivity, in Real Time and Recorded Mode. Directional measurements were provided by PowerPulse*, while the Motor performed steering operations. This run reached the 9 5/8 inch casing point and the decision was made to POOH to run casing. 8-1/2 inch Sidetrack Section: The Sidetrack was drilled in two LWD runs from a depth of 2,325 ft MD to 8,015 ft MD. Directional Measurements, Gamma Ray,Resistivity, ECD, Density, Porosity, and Caliper were provided in Real Time and Recorded Mode. The BHA of the first run, ST001,was composed of a Motor,arcVISION*675,and TeleScope*675.A milled tooth bit was used in this run.The formation was drilled from 2,325 ft MD to 2,430 ft MD, kicking off from the main wellbore at 2,330 ft MD.The formation was evaluated while drilling,with arcVISION*measuring Gamma Ray, Resistivity,and ECD,in Real Time and Recorded Mode. Directional Measurements were provided by the TeleScope*,while the Motor performed steering operations.The decision was made to POOH to change out the BHA to a full VISION*Service with a Rotary Steerable System. The BHA of the second run, ST002,was composed of a PowerDrive*675,arcVISION*675,TeleScope*675,and adnVISION*675.A PDC bit was used in this run.The formation was drilled from 2,430 ft MD to 8,015 ft MD.The formation was evaluated while drilling,with arcVISION*measuring Gamma Ray, Resistivity,and ECD, and adnVISION*measuring Density, Porosity, and Caliper, in Real Time and Recorded Mode. Directional Measurements were provided by the TeleScope*,while the PowerDrive performed steering operations.This run reached the Well Total Depth of 8,015 ft MD. Innovation The Schlumberger MWD team was successfully able to demodulate real-time data at a rate of 6 bits per second during all sections of the well, up to and including the point of TD at 8,015 ft MD, despite having only one working SPT and a gradually decreasing maximum flow rate as we drilled deeper. To guarantee good data density with lower data rates, we would like to encourage the use of Orion*compression in real time. It is especially useful and recommended if ever Real-Time images are to be provided. Schlumberger Oilfield Services—Drilling&Measurements appreciates the opportunity to provide Repsol E&P USA Inc. with MWD and LWD services. Sincerely, Kyle Antonini MWD/LWD Engineer Schlumberger Drilling&Measurements Ni° ► • • erl ef) W C > � 8 1 N So 11) W CS c� W p CC o 0v z 2 z 2 z o a u F , r e s t ,. n a r u v _ c E n C G G E E v - c E ry 7 g 4. 2 r r $ g g A Fo$ Z L E E E E E i 24 3a� oE.° It _ • re' a E _• E _ 3 3 ; 3 -g ..� g c 3 e f g.2 > -kept& _ 1Ory _ Eg EL o ni t m - - _ g y_ - -o g w0 i oa ; 2 4.5,, ti ,%li *, E , E15 v0 F 3Z' 3 ; ; 1osEE % 31 Lo iliVE - -1 a ..2 .7:6- « t- ° caa c; w a n.-a o = E g E mE O •CEE w - aaE 8£ i .u uno 3yy $lo -5 4 _ _ nl !.,,2 s a t$Wa s asa .¢ aL¢-aaaaU,' a,x) 4 aa $ $ $NO ,E b a asa e RnR "r1 a n C . Q b V M . a nA Ln a 3 ° L t 1 - LL V Y OUi $ J in 'a S '°+ m Z W m a A m m m '�^ r5 i 8 m C7 -- R tels R s 8 2 J e r r ? r 0 d 3 a ; K $ - e c c c p d - - 0 3 3 5 0 > ; & i Q Q a o 5 ,` u f f a W W v - � ¢' ¢' a' a � a a a' a' LL "o a a a a g "o * * 6 a a E ilr d a a r z a a o � w T. 2O �' a 5 O 0 m - , O a a a a aa Cr' Cr' a a 3 OD a o> 0 • Recov MAY 21 2014 AOGGG v.. REPlOL May 19,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage, AK 99501 RE: 10-407 Well Completion Report: Repsol Qugruk 5A PTD 214-032 Dear Commissioner: Repsol hereby submits the 10-407 Well Completion Report for the permanent abandonment of Qugruk 5A,permit to drill 214-032. Qugruk 5, permit to drill 213-192 was spudded 2/01/2014, with a total depth of 7430'MD was reached on 3/08/2013 of the pilot hole. The well was sidetracked on 2/25/2014 at a depth of 2550' MD of the pilot hole and the sidetrack reached TD of 8015'MD on 3!20/2014. Final surface abandonment was completed on 4/24/2014. Pertinent information attached to this report includes the following: 1. Form 10407 Well Completion Report 2. Final Wellbore Schematic 3. Daily Operations Summary 4. Photos of abandonment plate/mound 5. Final Directional Survey Report 6. Wireline +LWD Details 7. Casing and Cementing Report 8. As-built Additional Geological information will be submitted separately. The AOGCC is requested to treat as confidential all information included. If you have any questions or require additional information, please contact myself at 28I- 863-1618,or Tim Flynn at 907-375-6934. .41.41 Bob Jones Drilling Manager Repsol USA ' STATE OF ALASKA ALASI )IL AND GAS CONSERVATION COMMI; )N WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil t ] Gas [o SPLUG L Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 1 20AAC 25 110 Development 111] Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: I Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: Repsol USA (Aba ` /20'1`4 ,;_• 214-032 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Dr Ste 400 Anchorage,AK 99503 :212 13/!3//1 50-103-20682-01-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 2138'FWL, 1381'FSL,Sec.24,T12N, R6E, UM 3/20/2014 Qugruk 5A Top of Productive Horizon: 8. KB(ft above MSL): 35 15. Field/Pool(s): 1873'FWL. 1046 FNL. Sec.24,T12N.R6E,UM GL(ft above MSL): 15 Total Depth: 9.Plug Back Depth(MD+TVD): Wildcat 1855'FWL, 807 FNL,Sec.24,T12N,R6E, UM 0'MD,0'TVD 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 438058 y- 5987456 Zone- 4 8015'MD,7010'TVD 391452 TPI: x- 437815 y- 5990311 Zone- 4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 437799 y- 5990549 Zone- 4 NA LAS 28269 18. Directional Survey: Yes C No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) 1390' 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.1ie;d lateral Top Window MD/TVD: See attached sheet documenting all logs run in Qugruk 5A .1V,V; ' 3`f 2- ' 5/T-- I d,e 23. CASING, LINER AND CEMENTING RECORD /. G-S-r-1 WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 20 131# J-55 0 80' 0 81' 26" 38 sx Permafrost Type L 9 5/8" 47# L-80 0 2305' 0 2305' 12 1/4" 600 sx Perm,220 sx tail 7" 26# L-80 0 7992 0 6996 8 1/2" 250 sx cis G, 169 sx cls G 24.Open to production or injection? Yes ❑ No '❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 1 L I-- 3.5" 7586' 7479'/6572' 5 J t'-' s-I"' 26. ACID, FRACTURE,CEMENT SQUEEZE. ETC. * A R ECEIVED Was hydraulic fracturing used during completion? Yes❑ No ❑ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED / AT MAY 28 2014 7682'-7687' 82728 Gals of 25 ppt linear guar gel `t yf `'-`- - s-/ f 640 Gals LVT-200 VERIFIED AOGCC 201,600 Lbs of 20-40 Carbolite 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/14/2014 Assisted N2 Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 4/13/2014 89.25 Test Period �.. 5.99 0.96 857(Frac) 10-60/64" N/R Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. I 245 2186 24-Hour Rate 1.61 0.25 230.5 37.1 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No El , Sidewall Cores Acquired? Yes ❑ No❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. ** Full Geologic description to follow with separate documentation upon completion of analysis s 1J C MA 171/2-1 Form 10-407 Revised 10/2012 P (p.,1z, 17 CONTINUED ON REVERSESubmit original only • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top 0 0 needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1390 1390 On April 3d at 04:30 the Nuiqsut 200 reservoir was perforated in the Q-5A Schrader Bluff 1390 1390 wellbore from 7,682'-7,687'MD with 4-5/8"deep penetrating charges at 5 spf MCU/Lower Schrader Bluff 2268 2268 and 120°phasing. Immediately following the perforating euan+a-DFIT was- performed by injecting 15.23 Bbls of completion brine into the formation at 10 Tuluvak 2645 2642 BPM. Following the shut down the pressure was monitored for+/- 12 hours Nanushuk 4118 3888 during which the DFIT analysis was performed and the single stage frac HRZ Shale 6877 6096 design was optimized.At 21:17 on the 3d the single stage frac commenced_ Base HRZ/Pebble Shale 6877 6096 during which 201,000 lbs of 20-40 carbolite was successfully place in tha Kup C 7088 6265 formation with 82,728 Gals of 25 ppt linear guar gel at an avg. rate of 24.4 BPM and an avg.STP of 3,531 psi.At 07:30 on the 4th after test cycling the LCU/Kingak Shale 7099 6274 DH test valves the well was open to the choke manifold in an attempt to flow Alpine 7512 6606 the well but the test was aborted due to the fact the OMNI test valve would Nuiqsut 7637 6706 not open.After numerous attempts to cycle the valve open,the decision was made to begin the laborius task of pulling the completion and recompleting the well.At 12:35 on the 13th of April following the 9 days required to kill the well,pull the completion and re-complete,the well was opened to the choke manifold. For the next 3.4 days coiled tubing was used to perform a series of nitrogen lifts,proppant cleanouts and an acid wash during which the well produced a total of 5.99 Bbls of 37°crude,0.95 MMscf of 0.68 gravity gas and 857 Bbls of recovered frac fluid. On the 16th of April,E-line was rigged up and at 23:30 the well was perforated from 7,650'-7,690'MD using 2" through tubing guns as a last attempt to get the well to produce.Following Formation at total depth: Nuiqsut 8015 7010 the second perforating event the well was open to the seperator on and off for an additional+/-36 hours with no fluid returns and a total of 4.65 Mscf of gas. The well test was terminated at 10:30 on the 18th of April. 31. List of Attachments: Well Surveys,Well Schematic, Daily Operations Reports,Halliburton Post Frac Report,Expro Flowback Report,As-Built,Cement Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Flynn 907-375-6934 Email: Tim.flynn@servexternos.repsol.com Printed Name: Bill Hardham Title: Project Manager Signature: IA Phone: 907-375-6917 Date: 5/19/2014 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 10/2012 • lECEIVES STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION , Y `\ 2014 1a.wellstaWEQ oCOMPLETION GasP ❑OORer ❑ RECOMPLETION Abandoned Suspended❑ TREPORT AND LOG lb.Well Class. 'Li 2OMC 25.105 2OMC 25110 Development ❑ Exploratory GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions Service ❑ Stratigraphic Test ❑ 2.Operator Name 5.Date Comp.,Susp.,or 12.Permit to Dnil Number. Repsol USA Aband- 4/24/2014 214-032 3.Address 6.Date Spudded 13.API Number. 3800 Centerpoint Dr Ste 400 Anchorage_AK 98503 2/25/2014 50-103-20682-01-00 4a.Location of Well(Governmental Section). 7.Date TD Reached 14.Well Name and Number Surface 2138'FWL, 1381'FSL,Sec.24,T12N,R6E,UM 3/20/2014 Qugruk 5A - Top of Productive Horizon: 8.KB(ft above MSL) 35 15.Field/Pool(s). 1873'FWL, 1046 FNL,Sec.24,T12N,R6E,UM GL(fl above MSL) 15 Total Depth: 9.Plug Back Depth(MD-TVD). Wildcat 1855'FWL,807 FNL,Sec 24,T12N,R6E,UM 0'MD,0'TVD 4b.Location of Well(State Base Plane Coordinates,NAD 27). 10.Total Depth(MD+TVD). 16.Property Designation. Surface: x- 438058 y- 5987458 Zone- 4 8015'MD,7010'TVD 301452 TPI- x- 437815 y- 5990311 Zone- 4 11.SSSV Depth(MD+TVD) 17.Land Use Permit Total Depth x- 437799 y- 5990549 Zone- 4 NA LAS 28269 18.Directional Survey. Yes ❑ No ❑ 19.Water Depth,if Offshore 20.Thickness of Permafrost MD/TVD. (Submit electronic and printed information per 20 MC 25 050) NA (ft MSL) 1390' 21.Logs Obtained(List all logs here and submit electronic and pnnted information per 20AAC25.071). 22.Re-drilVLateral Top Window MD/TVD: See atta:hod sheet documenting all logs run in Qugruk 5A N/A 23. CASING,LINER AND CEMENTING RECORD WT,PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING �. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 131# J-55 0 80' 0 81' 26" 38 sx Permafrost Type L 9 5/6" 47# L-80 0 2305' 0 2305' 12 1/4" 600 sx Perm.220 sx tai' 7" 26# L-80 0 7992 0 6996 8 12" 250 sx cls G,169 sx cls G X24.Open to production or injection? Yes ❑ No ❑ 25 TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number) 3.5" 7586' 7479'18572' 1 on PI.ETi6N .l 26. ACID,FRACTURE CEMENT SQUEEZE ETC. i Was hydraulic fracturing used dunng completion? Yes❑ No ❑ F'~IJ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ...:3 i , 7682'-7687' 82728 Gals of 25 ppt linear guar gel 640 Gals LVT-200 201.600 Lbs of 20-40 Carbolate 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/14/2014 Assisted N2 Lift Date of Test. Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio; 4/13/2014 89.25 Test Period ...a` 5.99 0.96 857(Frac) 10.60/64" N/R Flow Tubing Casing Press: Calculated Oil-Bbl: Gas.MCF. Water-Bbl: Oil Gravity-API(con): Press. 1 245 2186 24-Hour Rate �•► 1.61 0.25 230.5 37.1 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑ Sidewall Cores Acquired? Yes[.,.J No❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of of.gas or water (submit separate sheets with this form,If needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 MC 25.071. **Full Geologic description to follow with separate documentation upon completion of analysis ARCMS MAY 2 2 2 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only • • 29. GEOLOGiC MARKERS (List at formations and markers encountered) 30. FORMATION TESTS NAME MD TVD Wet tested? [ Yes [] No If yes,list intervals and formations tested, briefly summarizing lest results.Attach separate sheets to this form,if Permafrost-Top 0' 0 needed,and submit detailed test Information per 20 AAC 25.071. Permafrost-Base 1390 1390 Schrader Bluff 1390 1390 MCU/Lower Schrader Bluff 2268 2268 Tuluvak 2660 2659 Nanushuk 3947 3880 HRZ Shale ; 6171 5967 Base HRZ/Pebble Shale 6298 6089 Kup C 6475 6258 _,--- LCU/Kingak Shale 6485 6267 ,, Alpine 6852 6615 Nuigsut 6970 6727 _ 0\'\ -Cf.-C-- , Nechelik 7308 7047 '01 ( . . , Ve5) . \\._c's ' )3-\ °1C k 0 r" , Format on at total depth:Nuigsut 743Q 184c)....„9.9\ , 31. List of Attachments. Vell Surveys,Well Schematic,Daily i =:ent -=port.V, ne/LWD summary repo As-Built Survey 32. I hereby certify that the foregoing is true and correct • the best of my knowledge. Contact: Tim F;, „!7-375-6934 Email: Tim.flynn@servextemos.repsol.com Printed Name B..jc Title: Drilling Manager Si nature Phone' 281-863-1618 Data- 5/19/2013 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells. Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing fool. Item 24: If this well is completed for separate product on 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,Submersble,Water Iniection,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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 10/2012 • CONFI•TIAL Qugruk 5A P&A Schematic - Finallig , REP'JOL 1 : , ; ., ;1-t- 26"Hole 1 S ; 9 518"x 7"Annulus cemented to surface I , :: ! :: :1 :1 20"131#J-55 Conductor @ +/-101'MD/TVD i ; • +, S:il r�, •,']: I 7"Bridge plug set at 280'MD Rig 105 RKB: 20' r ; ; ','•• I : I 10.0 bbls/69 sks class C to surface I Q 5 Elevation w/ Pad Thickness: 15' S •• I�12-1/4"Hole KB to MSL: 35' , r I i i ; : I I ' TOC @+/-2015'MD I I -:; S, I r : % 1 ' S : :-; ,. 4 9-6/8"47#L-80 BTC Casing @ 2305'MD 1 .:'11111111'';c7.4— 7"Bridge plug set at 2405'MD i . 16 bbls/85 sks 17.0 ppg class G F I: %\ \ ',.'s: C: is ::c: \\' %;;\ \:::::::::::\\ • ';, \::::::: :\ \�, '•,,\ %•\ DV Collar @+/-2800' MD \ \ \,, \ \ \;, ';\ \ \ `,% °%\ \ \ \%. %,\ 7"26#L-80 BTC Casing \ \ \ \ \ • �`'•; •,\ \ \ \ \ \ \ \ \ \ 'e\ \ \ \''• '%\ \ \ \ \\ \"' `",\ Q5A Inclination 36.9° \ \% Pilot Hole Inclination through Pay 19.8° \ \ \ '• \ \ \ \% ^,, \ TOC Stage 1 +/-6600'MD \ \.:;: : i:\ \' '•„.\ Kup C @ 7088'MD \: : : :i] :1 \ %,\ (Non Reservior) \: : 1 \ \\\ TOC @+/-7250'MD \: : := : �'r; (Pressure Tested to 2000 psi for 30 min) \ :H:::i .^, : : :'\\ 7"Cement Retainer \:: ::::: ::1 \''',..:: :::::\-\ @ 7500'MD 6597"TVD 1: : :::::::\ \.p,._: :.. '•.%\�— \:i: :H —\-4 8'1/4"open hole ' : ,0 16 bbls/90 sks below retainer \ .••• - \ 10 bbls/56 sks above retainer 1i:: :i ]:':� Perforations @: '' '—Nuiqsut 200 @ 7637'MD, \., ;.;.;.;\ 7650'to 7690'MD \'�' '''=''," \ Baffle Plate @ 7852'MD \ `; _-''.,..,N TD @ 7430'MD �: i \,r, . . . _\Casing Depth TD @ 7992'MD Hole Depth TD @ 8015'MD Revised D. Ross t t — _5 () _ 5A 5-9-2014 Y � ! • \\.; --.Alm"- x n� Ms�, g , � �. y� �i ill N LL 'w'n'2113'NZLl ,..9/41.411, g A 1+ ¢ p ;NM'39)4'NZLl p �' "' NIli V c...---1,\ 1 N.oi� .� c0 i• Z o 0 I a N Y IZ IZ \c-, �0 4 N IG�.O N Vin. t- 3 3 Le''' 3 >Wy6 Zorn (7 • t►•j 'D^ ` � zo z^ IJ zap 66¢ PJ! In L Q=Ei F a� •,- Q,.. ui• bM g.--N �ZW Z( ZC//�� .-I. JOF-_1J W 7�U O Zt4_ \ ONrb M' 5 E aOOi" Q 7 r-N �W6,'1�. VL.Ii ai. ill Y) p� .j V .I� iIN NN II P� 111�h Q!N 4 OO W ^p WH0 m J 4 Y- \\\\ p u af-z II II rz n n ¢t-z 8 11 U(Jwn ap p o c�e/ u �Ca; O ZJOJ>X Z�sYX ZJ9YX 40J tW/I�N yl-FO- ZzO LL� O� D W 0 N x gi a Q n • V . ^m W T 0 V cl.et�. No � U' Op ivo el g a .� Z3 DR SZ�� S 141- ts$ 0 rCZ z3 O µG M et Pk X 1 lo 3 00 0 ‘, To CO ss \ ---- 11% o� o � a� / &M 2 Q I E Rg§ g QF /WW� UL \ / / N N ¢ 2 1 1 1 1 8 e0 / y G� B `y O T + ' 1. z3 .� gz 1 e1 i ` o C �s / / F I t offs 4fesZz - o L e,y~aU o� 0 0 / 5 U ZN / / w0 Z T / o 3 / �Z "IX I I L K222 e �.,s'!"`!,lll,l 110 0 .�.a 'i. ,:P 4 804j161111 Q a=y cn 0 _ -a-1, aaQ ��. V- II . flU i : a8 , i . tip „._Co >t_ 8 o JIIII S..4.(. .\'`..----� z z G'w lllttlt `` H =y O 8 • • Qugruk #5A Daily Operations Summary REPfOL API: 50-103-20682-01-00Permit #: 214-032 Rig: Nabors 105AC CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity MOVE TO ST OPS ON QUGRUK-5A WELLBORE 09:30hrs 11 March 2014 TD: 2130'; Mud Weight: 10.6;Viscosity: 74 Transfer mud to vertical tanks. 0' Clean mud pits. PU KO BHA#1 to 2070' while continue to clean mud pits. 12 March 2014 TD: 2130'; Mud Weight: 10.6;Viscosity: 74; Cont to clean mud pits with vac 0' trucks&super suckers. 13 March 2014 TD: 2130'; Mud Weight: 10.4;Viscosity: 90; Cont to clean mud pits with vac 0' � ��{ trucks&super suckers. M&P Baraclean to flush all mud lines.Take on 805 bbls �'‘s-S'. MOBM. Build berms around MOBM cutting tanks.TIH&tag cmt @ 2130'. Displace out KCL mud. RU base fluid system. Shallow test MWD tools 14 March 2014 TD: 2369'; Mud Weight: 10.4;Viscosity: 77; TIH w/1 std f/derrick to 2120'. 27' Drlg cmt plug 2130'-2329'. Circ BU. RU WL& RIH w/gyro&orient tool face. Slide/DrIg 2329'—2369' (KOP= 2342'). /15 March 2014 TD: 2430'; Mud Weight: 10.4; Viscosity: 78; DrIg 2369'-2430'. POOH LD mud •v 0' motor. MU bit& rotary steerable/ LWD BHA. RIH to 2181'. Shallow test LWD— ti OK.Test BOPE 250/3500 psi—5 min—OK.Attempt to test upper rams— �k pressure up to 3800 psi—ram failed. Pull & rebuild rams w/new rubbers. j f"`- NOTE: All tests witnessed by AOGCC Rep,Jeff Turkington. 16 March 2014 TD: 2720'; Mud Weight: 10.45; Viscosity: 86; Retest upper rams to 250/5000 290' psi.Test BOPE 250/5000 psi. Attempt to test lower rams—pressure up to 1800 psi—ram failed. NOTE: Lower pipe ram test waived witness by AOGCC Rep, Jeff Turkington. Chg out lower pipe ram rubber seals & bonnet seals. Retest lower pip rams 250/5000 psi.Test good. RIH. Drlg 2430'—2720'. 17 March 2014 TD:4018'; Mud Weight: 10.4;Viscosity: 86; DrIg 2720'—3825'. Clean screen 1298' on mud pump#1. Circ. Drlg 3825'—3874'. Circ. DrIg 3874'—4018'.Take survey. Circ BU. Chk f/flow. POOH to 2285' for short trip. 18 March 2014 TD: 5655'; Mud Weight: 10.4; Viscosity: 78; TIH 2285'—4018',stage pump up 1637' &circ BU. Drlg 4018'—5655'. Service top drive. 19 March 2014 TD: 7329'; Mud Weight: 10.65; Viscosity: 99; DrIg 5655'-7329'. 1674' • 110 20 March 2014 TD: 8015'; Mud Weight: 10.65;Viscosity: 95; DrIg 7329'-7636' MD. Chg 686' swab in Pump#1. DrI 7636'-8015' MD. Section TD. Circulate and condition hole, Short trip F/8015'to 2283'MD. Cir BU,TIH to TD. 21 March 2014 TD: 8015'; Mud Weight: 10.7;Viscosity: 100; Wash down to 8015'MD. Circ 0' BU. POOH & LD BHA. RU WL&RIH w/WL run#1A(FT-Scanner-Density- Neutron-PPC-MSIP-PPC-GR). 22 March 2014 TD: 8015'; Mud Weight: 10.6; Viscosity: 99; Cont TIH w/WL run #1A. POOH. 0' LD run#1A tools. PU run#1B tools&RIH w/same. Log f/shoe to 8000'. Log 8000'to shoe. LD run#1B tools&RD WL eqpt. NOTE: Notified AOGCC Rep, Lou Grimaldi, of upcoming BOPE test at 08:30hrs. 23 March 2014 TD: 8015'; Mud Weight: 10.5;Viscosity: 103; Finish RD WL eqpt. Clean floor. 0' LD 6" DC&jars. Chg upper rams 4"to 7". NOTE: Permission granted by AOGCC Rep, Lou Grimaldi,to test the annular w/the HCRS&csg rams w/ inside manuals to permitted pressures then run 7"csg prior to a full BOPE test. RU to test BOPE.Test annular, HCR, Manuals&7" rams to 250/3500 psi-5 min-OK. Blow down chk& kill lines. Chg out bails. RU csg tools. RIH w/7" 26# L-80 BTC csg. NOTE:Sent formal BOPE test notification @ 05:00hrs requested by AOGCC Rep, Lou Gramaldi. 24 March 2014 TD:8015'; Mud Weight: 10.4;Viscosity: 98; Cont RIH w/7" 26#L-80 csg to i r- }1-"S't" 0' 7841'. Wash down to 8003'. C&C. Land 7" @ 7992'MD/6992'TVD. I3U cmt eqpt. s Test all lines to 5000 psi. Pump cmt stage#1: 29.4 bbls 11.5 ppg Tuned Spacer; _ 51.2 bbls(250 sx) 15.8 ppg cmt(yld=1.15cuft/sx). Displace cmt w/5 bbls water to flush lines. Pump 296 bbls 10.4 ppg mud&bump plug w/1834 psi (est TOC @ 5900'). Floats held. Pressure up csg to 3160 psi to open DV-tool ports. ' NOTE: 100% returns throughout job. Circ through DV-tool ports-no cmt to surface. 25 March 2014 TD:8015'; Mud Weight: 10.4;Viscosity:95; RU cmt eqpt for stage 2.Test a 0' lines to 3000 psi. Pump cmt stage#2: 30.9 bbls 11.5 ppg Tuned Spacer; 74.6 Z-N° bbls (169 sx) 12.0 ppg cmt (yld=2.48cuft/sx). Displace cmt w/5 bbls wtr to Sty- flush lines. Pump 102 bbls 10.4 ppg mud &bump plug w/450 psi. Pressure up to 1787 psi to close DV-tool. Floats held. NOTE: 100%returns throughout job- ye- 7 bbls of cmt returns. RD cmt eqpt. Back out& LD landing jt. Wash BOP stack w/wash tool. Install pack-off&test same. NOTE: AOGCC Rep,John Crisp, waived witness of BOPE Test @ 18:10hrs. RD csg tools. Chg out bails& rams. clean pits.Test annular 250/3500 psi.Test BOPE 250/5000 psi. Pull test jt& test plug. Install WB& lockdown same. 26 March 2014 TD: 8015'; Mud Weight: 10.4;Viscosity: 95; Chg elev& LD 3%"TC-II stinger. 0' RD csg running eqpt. Chg elev. FINAL REPORT FOR DRILLING PHASE. BEGIN COMPLETION PHASE: MU 6-1/8" cleanout BHA& RIH to 2777'. Drill DV tool 2808'-2811'. Circ hole clean. RIH to 7844&tag cmt. Drill cmt 7844'-7855'. Circ BU-some cmt returns. RU eqpt&test 7" csg to 4000 psi-30 min-OK. RD testing eqpt.Short trip 7855'-7460'. Prep to displace mud to 10.4 ppg completion brine. • • 27 March 2014 TD: 8015'; Brine Weight: 10.4 Brine; Cont short trip 7460'-5961'.TIH 5961'- 0' 7855'. C&C hole. Begin to displace to 10.4 ppg completion brine. Pump 70 bbls of hi vis spacer. Pump 800 bbls of fresh wtr. 28 March 2014 TD: 8015'; Mud Weight: 10.4 Brine; POOH LD scraper assy. RU tbg tongs, RIH 0' w/31/2TC-11 tbg. RIH w/210 jts 31/29.3 ppf TC-II tbg to 6779'. POOH &rack tbg back in derrick. Build Expro Tank Berm. Install rig mats. 29 March 2014 TD: 8015'; Mud Weight: 10.4 Brine; Cont POOH racking back 3%2"tbg in 0' derrick. Chg out 3%" tbg elev to 4" side door elev. PU &test Metrol tools to 500 psi low—5 min—OK&5000 psi hi—15 min—OK. RU WL& RIH w/USIT logging tool to 7845' (TOC above 6500' MD). RD WL. P/U additinional 3 'A"9.3 ppf TC-II tubing. RD tbg tongs. 30 March 2014 TD:8015'; Mud Weight: 10.4 Brine; Slip &cut DL. RD pipe shed for CT 0' placement. Prep to test BOPs.Abandon rig drill. Cont RU BOPS.Test BOPs 250/3500 psi on annular; 250/5000 psi on rest of components. RD test eqpt. Pull test plug&install WB.Cont RU completion eqpt. Build berms. 31 March 2014 TD:8015'; Mud Weight: 10.4; Brine; Cont setting mats&RU completion eqpt. 0' PU & RIH w/DST&TCP assy. PU lower TCP assy. PU 2-7/8"tbg&fill disc assy. MU pkr to jt of 2-7/8"tbg& RIH w/same to 1213'. Cont RIH w/3%Z"tbg f/ derrick to 5140'—fill every std w/10.4 ppg Brine.Test tbg every±1100'to 4000 psi—5 min—on chart. 01 April 2014 TD: 8015'; Mud Weight: 10.4 Brine; Cont RIH w/3%2"tbg f/derrick to 7620'— 0' fill every std w/10.4 pgp Brine. RU SLB a-line set TCP on depth (top @ 7682' & btm @ 7687'). RD SLB e-line. Space out. MU hgr/landing jt. Set pkr&land completion string.Test hgr&seals 250/5000 psi—10 min—OK.Test lines to 4500 psi.Test pkr(7" x 31/2" annulus) w/4000 psi—15 min—OK. Bled off press & RD test eqpt. Back out landing jt& LD same. Install BPV in tbg hgr. RD handling tools&clear f/floor. 02 April 2014 TD: 8015'; Mud Weight: 10.4 Brine; ND BOPE. Disconnect control lines, 0' choke/kill lines. Split BOPE below double ram section. NOTE:Submitted 24hr notice of upcoming CT/BOPE test to AOGCC @ 19:50hrs 04APR2014. NU frac tree. NU swab&master valve assy. Pressure test bonnet to 5000 psi—10 min— OK.Test master&2nd master to 7500 psi—10 min. Install hard lines to tree. Set BOPE f/CT. MU riser f/CT BOPE. Install 6' section of riser on tree. NU BOPE& secure same.Tie in rig HCR Koomey lines to hyd master vlv on tree. Function test same. 03 April 2014 TD: 8015'; Mud Weight: 10.4 Brine; Test HES CT to 6900 psi. Test Expro lines 0' to 3000 psi. Test HES annulus line to 3000 psi. Fire guns. Perform 20 DFIT. Shut in well &wait 12hrs for DFIT test results. Test Frac lines to 6900 psi, Pump 200,000#'s 20/40 carbolite w/linear gel at a max rate of 22 BPM and max STP of 5155 psi.Average STP was 3531 psi. Shut well in and monitor wellhead for 15 min, open well bleed off to 1500 psi. NOTE: AOGCC Rep,Jeff Turkington, waived witness of BOP/CT test @ 20:54hrs 02Apr2014. 0 • 04 April 2014 TD: 8015'; Mud Weight: 10.4 Brine; Test cycle&function LPR-N &OMNI vlv. 0' Cycle OMNI vlv 14 times—vlvs function test properly. Leave OMNI & LPR-N in test position. Test CT BOPE 250/3500 psi. Perform final walk thru of Expro eqpt. SD due to unable to open LPR-N test vlv. Made several attempts to cycle LPR-N vlv w/no success. RIH w/CT to jet LPR-N w/N2.Tag OMNI vlv @ 6791' &found OMNI vlv closed. Continue attempts to cycle OMNI vlv to open position w/no success. Fill CT&31/2"tbg w/LVT. Pressure up 31/2"tbg to 2000 psi to equalize possible pressure trapped between OMNI vlv& LPR-N vlv. Pressure up annulus between 3W'tbg&7"csg to cycle OMNI vlv various times —no success. NOTE: 23:30hrs 04APR2014—sent notification to AOGCC of upcoming BOPE test on 06APR2014 @ 00:00hrs. 05 April 2014 TD: 8015'; Mud Weight: 10.4 Brine; RD up lines f/rig tanks to CT unit. 0' Displace 3W'tbg w/10.4 ppg Brine. RU N2 to CT unit. Blow down CT&mud lines w/N2. POOH w/CT. RD CT, Expro flowlines to WH. RU return lines to mud tanks.Spot& RU HES SL unit. RU SL&fill lubricator w/10.4 ppg Brine. 06 April 2014 TD: 8015'; Mud Weight: 12.4 Brine; Test lubricator to 3500 psi. RU &run 2.8" 0' gauge ring&tag @ 6746'SLM (6679'tally measurement). POOH. Chg out gauge ring to 2.0". RIH to 6873'SLM. POOH (6791'tally measurement). RIH w/Run#1 w/Kinley DH Power Unit w/3/8"tbg punch to 6686'SLM (6620'tally measurement). Wait for timer to activate tool—indication tool activated. Wait for tool to retract. POOH w/tbg punch for Run#2. RIH w/Run#2 tbg punch HES SL to 6685' (6627'tally measurement). Tool set on 80 min autotimer—tool engaged. POOH. RD HES SL unit.Take on 12.4 ppg Brine. Attempt to displace w/12.4 ppg Brine down tbg& up annulus—pressure up to 2000 psi w/minimal returns. RU 2.80" drift f/gauge run on SL. Pressure test lubricator to 3500 psi. RIH w/500 psi on tbg to 6881'. Tag up previous shot. Work SL w/no restriction. POOH. PU single shot. Pressure test lubricator& RIH @ 100 FPM to 6625'—activate punch tool. No psi change after punch time completed. POOH w/SL. RU rig mud pump to csg annulus&cycle OMNI vlv 3 times w/1500, 2500&2600 psi—noticed leakoff @ 2600 psi. Annulus pressure continued to drop&tbg pressure increased to 2450 psi. Bleed pressure off annulus&circ down tbg @ 1 BPM @ 3000 psi. Pressure decreasing. Increase pump rate to 2.5 BPM w/1400 psi. Continue to displace 10.4 ppg Brine to 12.4 ppg Brine w/2.5 BPM 1000 psi. 07 April 2014 TD: 8015'; Mud Weight: 12.4 Brine; Continue to displace to 12.4 ppg Brine— 0' total pumped 270 bbls w/2.5 BPM 1000 psi. Install BPV. Pump down annulus to test BPV to 3000 psi. RD frac tree. NU 13-5/8" BOPE.Test Expro lines to 3000 psi. Install test jt&fill stack. 08 April 2014 TD: 8015'; Mud Weight: 11.5 Brine; Test annular BOPE 250/3500 psi.Test 0' rams, choke manifold, mud lines, IBOP&safety vlv 250/5000 psi. NOTE: AOGCC Rep, Chuck Scheve,waived witness of BOPE test on 06APR2014 @ 10:02hrs. RD BOPE test eqpt. MU landing jt&TIW vlv. Unset tbg hgr. Open ports on pkr. Close annular. Bleed off pressure 125 psi—0 psi (flow back 62 bbls). Circ 11.5 ppg Brine @ 1 BPM w/500 psi.Stage up to 4 BPM w/1400 psi. PU &unseat pkr. Circ BU @ 2 BPM w/430 psi. Break out top drive. Disconnect safety vlv. PU to tbg hgr. Fluid flowing back up tbg. Connect safety vlv&top drive&circ. 09 April 2014 TD:8015'; Mud Weight: 10.7 Brine; Cont to circ until pressure dropped. Chk 0' for flowback in tbg—no flow. LD hgr&pup jt. Blow down top drive.Chk f/flow —well flowing. Monitor flow to chk f/unbalanced mud.Well continued to flow. Install safety vlv&closed annular preventer. Monitor pressure. Open annular to Expro. Re-set pkr. C&C fluid. Cut fluid wt 11.1 ppg to 10.7 ppg. PU & open pkr circ ports. Blow down top drive.Close TIW vlv&close annular preventer. Monitor pressure(0 psi after 30 min). Pkr ports plugged. 10 April 2014 TD: 8015'; Mud Weight: 11.1 Brine; Work pkr several times to unseat. Break 0' out safety vlv. RD Metro register station. Close annular. Attempt to lower string—unable to go down (20' stick up). Install safety vlv. Connect top drive. Close safety vlv&annular preventer&monitor pressure. Bleed pressure 120 psi—0 psi. Set pkr to circ 11.1 ppg brine around. Attempt to displace hole w/ 11.1 ppg Brine—unable to circ down tbg. Blow down top drive. RU head pin to rev circ.Take returns thru tbg back to flowline. Begin to lose fluid when 11.1 ppg Brine entered tbg—indication both OMNI & LPR-N were open—lost±14 bbls. Unset pkr&monitor well for 15 min—static. Pump 20 bbl 13.1 ppg Brine dry job to POOH. POOH &remove metrol relays while POOH. LD OMNI vlv& check press f/gauge. Cont POOH. Stand above LPR-N packed off with sand. 11 April 2014 TD: 8015'; Mud Weight: 11.1 Brine; Clean sand f/std of 3.5"tbg(±15 gal). 0' Cont POOH. LD LPR-N, gauge carriers, flulid sample catchers, pkr&2-7/8"tbg. Monitor well on trip tank. Empty fluid sample catchers&inspect DH gauges. Prep pit to receive 10.4 ppg Brine wtr to test BHA to 3500 psi. RIH w/compl string& RU flowhead&CT. PU &MU compl BHA& RIH w/same to 1050'. RU & test BHA to 3500 psi w/ 10.4 ppg Brine—5 min—OK. NOTE: Send 24hr notice @ 09:O0hrs 11APR2014 to AOGCC for CTU BOPE test est time 09:O0hrs 12APR2014. • • 12 April 2014 TD: 8015'; Mud Weight: 11.1 Brine; RD BHA test eqpt. RIH w/3.5"tbg 1050'- 0' 7611' & Metrol installing relays on proper tbg jts. MU safety vlv& connect top drive. Set pkr @ 7479'w/15K. Line up to press test pkr. Close upper pipe rams. Pump down kill line to 500 psi.After 5 min press incr to 600 psi. Bleed press back to 500 psi. Press incr to 600 psi-bleed off to 0 psi. Open pipe rams. Chk f/flow-well flowing. Flow decr after 10 min. Set 20K on pkr. Close upper pipe rams. Press up to 500 psi. Press incr to 550 psi&stabilized. Held 550 psi- 10 min-good test. Bleed press off to 0 psi. RU install 4-1/16" 10K fig on 3.5" pup jt. Set in slips. RU flow cross tree.Set CTU BOPE on rig fir w/crane. Insert bolts into BOPE flg. Lift BOPE to top of flow tree. NU CT BOPE. RU CT lubr. RU Expro 3" hard lines on rig flr. Pick CT inj over windwalls w/crane&transfer to rig blks.Stab&MU inj to lubr. Install hyd lines to master vlv. Install drain line to inj. Fin RU Expro 3" hard lines on rig floor. RU to test CTU BOPE. NOTE: AOGCC Rep, Bob Noble, waived witnessing of CTU BOPE test on 12APR2014. 13 April 2014 TD: 8015'; Mud Weight: 11.1 Brine Vis:49; Displace CT string& Expro lines 0' w/LVT-200. Attempt to test CTU BOPE-Test CTU BOPE 250/3500 psi. Pressure test tbg string to 3500 psi. Pressure up annulus to 1570 psi to open LPR-N. Open well to Expro. RIH 4000'-7720' pumping N2. Flow well to Expro eqpt. 14 April 2014 TD:8015'; Mud Weight: 11.1 Brine Vis:49; POOH w/CT 7720'-1000' 0' pumping 1.8 BPM. Flow well to Expro eqpt. RIH w/CT 1000'-6500' pumping N2. Flow well to Expro eqpt. POOH w/CT to 5000'.Stop pumping N2. POOH w/CT to surf&bleed down N2 f/tbg. Monitor well for flow thru Expro eqpt. RIH w/CT to 5000'-fill CT w/8.7 ppg sea wtr. Pump 41 bbls to fill coil. Pump 27 bbls of sea wtr dn the well. POOH to surface @ 150 FPM pumping 1.3 BPM. Pump a total of 113 bbls. Allow pressures to stabilize. Perform injectivity test. Pump 8.7 ppg sea wtr @ 2.1 BPM. Pressure incr 700-1840 psi where pressures leveled off. Inject 20 bbls 8.7 ppg @ 2.1 BPM into formation. SD& monitor pressure. Pressure stable @ 1000 psi after injection. Bleed off pressure to 0 psi. Recover 35 bbls 8.7 ppg sea wtr. Blow down CT reel dn to Expro tanks. RIH w/CT to 7733'while pumping 500 SCF of N2.Spot 24 bbls of 7.5%HCL acid &5 bbls fresh wtr spacer 7688'-7713' @ 1.5 BPM & 1000 SCF N2. 15 April 2014 TD: 8015'; Mud Weight: 11.1 Brine Vis:49; POOH w/CT to 4000'. Flow well 0' to Expro eqpt. RIH w/CT 4000'-7616' pumping 500 SCF of N2-unable to get past 7616'. No measureable fluid. 100% N2 returns. POOH w/CT to surface pumping 500 SCF of N2. Flush coil w/14 bbls 11.1 ppg completion brine. Displace w/40,000 SCF of N2. Monitor well for flow thru Expro eqpt. Flow well to Expro. RIH w/CT pumping N2 &tag up @ 7616'. Perform clean out run to 7800' using hi vis sweeps. POOH to 4000'to monitor flow. • • 16 April 2014 TD: 8015'; Mud Weight: 11.1 Brine Vis: 50; RIH to 7749' &tag up. POOH to 0' surface. RD CT eqpt.R/U wireline w/2" perforating guns. Test lubricator to 3000 psi—test good, RIH w/40' of 2" perforating guns and CCL to 7745' MD. Coorelate guns on depth and perforate from 7650' MD to 7690' MD with 2" guns, 6 shots/ft snd 60 deg phasing. All indications guns fired, POOH,stuck at 7360' MD. Pulled 1800 lbs tension work free, POOH. Lost 200 lbs tension at 3000' while POOH. 17 April 2014 TD: 8015'; Mud Weight: 10.8 Brine Vis: 50; R/D lubricator, monitor well for 0' flow through Expro equipment. R/U wireline w/sinker bars,Test lubricator to 3000 psi—test good. RIH to 6882' MD and attempted to push guns downhole. Guns were moved a total of 10'. POOH with wireline.Attempted to cycle LPR- N valve with pressure cycles with no success. Pump 18 bbls of 8.9 ppg sea water down tubing/1400 psi. Circulate brine through gun lines in mud pits to a consistent weight of 10.8 ppg. Prepare to TIH with fishing tools to fish guns. NOTE: Contacted AOGCC on 4/17/2014 @ 09:30hrs for 24hr BOPE Test. 18 April 2014 TD: 8015'; Mud Weight: 10.6 Brine Vis:47; RU HES SL. Load 100 bbls 10.3 0' ppg Brine into mud pits& blend w/existing 10.8 ppg Brine. Final MW=10.6 ppg. Pump 70 bbls 10.6 ppg Brine dn tbg @ 2 BPM w/1350 psi. Fin RU HES SL unit& press test lubr to 3000 psi—10 min—OK. RIH w/2"JDC fishing assy for 1-3/8"fish neck to 7600'—perf guns no longer in tbg string. POOH w/2" fishing assy. RD SL lubr&secure to derrick. ND CT BOPE&hyd lines. RU HES SL. Press test lubr to 3600 psi—5 min. RIH w/2.80" gauge ring to 6750'. POOH w/ SL. PU PX plug body. Press test lubr to 3600 psi—5 min. RIH w/plug body. 19 April 2014 TD: 8015'; Mud Weight: 10.6 Brine Vis:47; Cont RIH w/PX plug body. Set 0' plug in X-nipple @ 6675'. PU PX plug prong. Press test lubr to 3600 psi—5 min. RIH w/prong assy. Set prong in plug body. POOH w/SL. Press test plug @ 6675'to 3000 psi—10 min. RD HES SL. Flush Expro flowlines w/30 bbls of wtr. Blow down w/N2. RD Expro flowlines. RD SL sheave, lubr& BOP. Pump 30 bbls hot wtr thru mud cross on tree to Expro. Bleed dn w/N2. RD Expro w/crane. RD frac tree. Bleed off annulus&verify no trap gas. Open pipe rams.Strip up thru 20" annular. Back out 10K flg. RU &press test SL lubr to 3000 psi—OK. RIH w/SL to 6675'w/2" prong pulling tool. Latch prong&POOH. PU PX plug pulling too. Press test SL lubr to 3000 psi & RIH w/SL to 6675'. Latch onto PX plug& POOH. RD HES SL. RU to pump dn tbg. Press test lines to 3000 psi—5 min. Pump 9 bbls dn tbg to verify LPR-N valve is open @ 2.5 BPM w/1200 psi— LPR-N is open. Line up to pump dn annulus for rev circ. Press up annulus to 2800 psi to rupture RD circ sub. SD pumps.Open annular& unseat Champ pkr. Rev circ 380 bbls thru choke manifold @ 3 BPM w/400 psi (10.7 ppg in 10.7 ppg out). Monitor well for 30 min—static. • • 20 April 2014 TD: 8015'; Mud Weight: 10.4 Brine Vis:45; RD pump-in sub &floor vlv. 0' Instlal 3.5"elev. Stand back 1 std to remove Metrol repeater. PU landing jt & hgr. Land hgr. Install BPV&test dart. Test BOPE:Annular 250/3500 psi; remaining components 250/5000 psi—all tests good. NOTE: Witness waived by AOGCC Rep,Jeff Jones. Perform successful body test to 3500 psi as per AOGCC Rep,Jeff Jones. RD test eqpt& blow down lines. PU landing jt. MU to hgr& pull up to rig floor(up wt 89k). POOH w/31/2"TC11 tbg. LD DH completion tools. NOTE: FINAL COMPLETIONS REPORT—BEGIN P&A OPS. 21 April 2014 NOTE: BEGIN P&A OPS. 0' TD: 8015'; Mud Weight: 10.7 Brine Vis:46; MU HES EZSV cmt ret& RIH w/ same to 7500'—set dn w/ 10K. RU HES lines &test to 4000 psi. Est inj rate blw pkr 2 BPM @ 1340 psi. Cmt Plug#1: M&P 15 bbls 13.0 ppg Tuned Spacer; 26 bbls (147 sx) 17.0 ppg Class G cmt(yield .99 cuft/sk) @ 2 BPM. Displ w/5 bbls 13.0 ppg Tuned Spacer. Displ w/50.2 bbls 10.7 ppg Brine (16 bbls blw EZSV& 10 bbls abv EZSV). POOH. Rev circ 2 BU @ 8 BPM w/1150 psi. RD& blow down lines. Std back 3 stds—pipe pulling wet. RU &circ. Std back 3%2"tbg RU cmt lines f/csg test. Press test cmt lines to 4000 psi.Test csg to 2000 psi—30 min— OK. Blow down cmt lines. POOH 22 April 2014 TD: 8015'; Mud Weight: 10.7 Brine Vis:46; MU HES EZSV bridge plug& RIH 0' w/same.Set bridge plug @ 2405—set dn 10k to verify pkr set. RU HES lines& test to 4000 psi. Cmt Plug#2: M&P 15 bbls Tuned Spacer @ 13.0 ppg; 15 bbls (85 sx) @ 17.0 ppg Class G cmt(yield .96 cuft/sx); 5 bbls spacer. Displ w/ 11 bbls of 10.6 ppg Brine. LD tbg. RIH & set bridge plug @ 280'. Shear off&verify depth. RU HES lines &test to 4000 psi. Cmt Plug#3: M&P 10 bbls Tuned Spacer @ 13.0 ppg; 10.1 bbls (59 sx) Class C Permafrost cmt @ 15.6 ppg (yield .96 cuft/sx); 1 bbl of good cmt returns to surface. LD 6 jts &top off cmt w/3.7 bbls of 15.6 ppg Class C Permafrost cmt. Blow dn cmt lines. RD cmt eqpt. RU stack flushing tool &flush BOPE. RD tool. Flush out mud sys &cmt lines. Flush thru top drive, cmt lines&chk/kill lines w/Baraclean&fresh wtr. NOTE: Notified AOGCC for inspections of csg before welding cap top. 23 April 2014 Cont clean pits&drip pans. ND BOPE. Clean pits. Finish cleaning mud pits & 0' cellar in prep for removal of wellhead. 24 April 2014 Cut off wellhead & remove same. Clear rig floor of misc items. 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C U ow o • • *111, Schlumberger REPlo, Borehole: Well: Field: Structure: Qugruk 5A Plan vs Actual Qugruk 5 Qugruk Qugruk 5 Gravity&Magnetic Parameters Surface Location NAD27 Alaska State Plane,Zone 04,US Feet Miscellaneous Model: BGGM 2013 Dip:80.869' Date: 29-Mar-2014 Lat N 7022 34.54 Northing: 5987456ftUS Grid Cony: -0.4743 Slot 05 TVD Ret Rotary Toble(35ft above MSL) MagDec:19.108° FS: 57597.196nT Gravity FS: 1001.984mgn(9.80665 Based) Lon: W 150 30 12.73 Fasting: 438058ftUS Scale Fact 0.99990436 Plan:Gugruk 5A 0 1000 2000 3000 4000 0 0 1000 1000 2000 2000 95:8- 2305 40 3000 a 3000 0 0 a to m (I) o x 4000 4000 1-- 5000 - . 5000 6000 • 6000 Q5 PH Polygon 7000 7000 _______-Qugruk 5 Qugruk 5A Qugruk 5A(P24)north 0 1000 2000 3000 4000 Vertical Section(ft)Azim=354.70r Scale=1:400(ft)Origin=ON/-S,OE/-W • Schlumberger REPJOL Borehole: Well: Field: Structure: Qugruk 5A Plan vs Actual Qugruk 5 Qugruk Qugruk 5 Gravity&Magnetic Parameters Surface Location NAD27 Alaska State Plane,Zone 04,US Feet Miscellaneous Model: BGGM 2013 Dip:80.869' Date: 29-Mar.2014 Lat N 70 12 34.54 Northing: 59874565US Grid Conv: -0.4743" Slot 05 TVD Rot Rotary Table(35ft above MSL) Magoec:19.108" FS: 57597.196n7 Gravity FS: 1001.984111gn(9.80665 Based) Lon: W 150 30 12.73 tasting: 438058ftUS Scale Fact: 0.99990436 Plan:Qugruk 5A -2000 -1500 -1000 -500 0 500 Qugruk 5A(P24)north Qugruk 5A 3000 3000 2500 .__._ __._ _ __ ..__.... 2500 2000 • 2000 0 0 (V 1500 (t) 1500 (n 4✓ (n Z 11 1000 1000 500 500 0 Qugruk 5 0 9-54r 2306 MD -2000 -1500 -1000 -500 0 500 EW(ft)Scale=1:200(ft) 411 M , § ) | \ - 1 § p . =�;e==� ;m ;)- i (!! !()&lwii k , )R 0 0 IF ! a ] § $ R Is r40) 2 \ 51,1 \ 0 $ ( Co Sp ) § A 8 j EE 0 | 5 = \ , f ) \ _ • • Cased Hole/Open Max BHTDurationHole SivaCasedRun Tool Suite (deg F) Tap(ft MD) Rase(ft MD) Gate (HN:MM) Comments 8.5 Open Hole 18 ZAIT-PEX-PPC-MSIP-PPC-GR 170.72 2215 8024 21-Mar-2014- 13:90 22-Mar-2014 Good Logging Run 8.5 Open Hole IR CMR-ECS-HNGS 178 2232 8024 22-Mar-14 14:01 Good Logging Run 8.5 Cased Hole 2A 0513-GR 129 6500 7855 29-Mar-14 8:30 Good Logging Run 8.5 Cased Hole 3A GR-CCL 174 6453 7032 1-Apr-14 2:32 Good Logging Run 8,5 Cased Hole - ERS-CCL 179 2568 7692 16-Apr-14 5:00 Good Logging Run CONFIDENTIAL in accordance with AS 38.05.035(a)(8)(C) FOLDER R 21:List of Lags • • Repsol Oil company CASING&CEMENTING REPORT Wet No./PTD# Qugruk 5A/214-032 Date 19-May-14 County la Supv. CASING RECORD-Surface casino , TD 8015'MD/7010'TVD Sh epth: 7992 MD/6996'_,...,______,..8e N/A Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe/jt 47# L-80 L> E 418111 01L-80 9.3308Follar/ ir \ 8.01 , 65ffle/)t4te L-8 5.43 7,82288Its42.88 251Se Tool / L-80 .11 -7,772.66 200 jts 9 5/81 L-80 "`� 7,797.77 -7,772.66 -15,570.43 (/X/LY L Hanger 5/81 Vetco/GE\..,, 2.30 -15,570.43 -15,572.73 landing jt 5/8 I81 -15,572.73. -15,595.54 Totals 23,587.54 Csg Wt.9n Hook: 120,000 Type Float Collar: Float No.Hrs to Run: 24.5 Csg Wt.On Slips: 115,000 Type of Shoe: Float Casing Crew: Wfd Fluid Description: 10,3 ppg WBM/Spud Mud/PV=25 YP=22 HTHP=0 Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: centralizers on every joint in shoe track,every third joint to surface' CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer Density(ppg) 10.5 Volume pumped(BBLs) 60 Lead Slurry Type: Extended Type1 Blend Yield(Ft3/sack): 4.33 Density(ppg) 10.7.0 ppg Volume (BBLs/sacks): 462 bbls/600 sacks Mixing/Pumping Rate(bpm): 5 , Tail Slurry Type: Conventional Class G Blend Yield(Ft3/sack): 1.16 u Density(ppg) 15.8 ppg Volume (BBLs/sacks): 45 bbls/220 sacks Mixing/Pumping Rate(bpm): 5.0 bpm 11 Post Flush(Spacer) N Type: Density(ppg) Rate(bpm): Volume: z LL Displacement: Type: Mud Density(ppg) 10.3 ppg Rate(bpm): 8 bpm Volume(actual/calculated): 20/22 FCP(psi): 670 psi Pump used for disp: Rig pumps Plug Bumped? Yes X No Bump press 0 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 80 bbl cmt/60 bbl spacer I/ Cement In Place At: 12:00 Date: 2/5/2014 Estimated TOC: Surface Method Used To Determine TOC: Cement sample taken @ surface Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: Yield(Ft3/sack): w a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 0 6 Type: Density(ppg) Rate(bpm): Volume: ti Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes No Reciprocated? _Yes No %Returns during job Cement returns to surface? _Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: 0 • Repsol Oil company CASING&CEMENTING REPORT Well No./PTD# Ougruk 5A/214-032 Date 19-May-14 County Colville River Delta State Alaska Supv. CASING RECORD-Surface casino TD 8015'MD/7010'TVD Shoe Depth: 7992 MD/6996'TVD PBTD: N/A Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe/jt 7" L-80 BTC Nalco 42.67 7,992.00 7,949.33 1 7" 26# L-80 BTC 41.32 7,949.33 7,908.01 F.Collar/jt 7" 26# BTC Halco 42.58 7,908.01 7,865.43 Baffle/it 7" 26# L-80 BTC Halco 42.55 7,865.43 7,822.88 123 jts 7" 26# L-80 BTC 5,015.86 7,822.88 2,807.02 Stage Tool 7" L-80 BTC Halco 2.70 2,807.02 2,804.32 68 jts 7" 26# L-80 BTC 2,769.54 2,804.32 34.78 Pup jt 7" 26# L-80 BTC 2.28 34.78 32.50 9 5/8 Hanger 9 5/8"x7" L-80 BTC Vetco/GE 4.62 32.50 27.88 landing jt 7" 26# L-80 BTC 27.88 27.88 0.00 Totals 7,992.00 Csg Wt.On Hook: 150,000 Type Float Collar: Float No.Hrs to Run: 24.5 Csg Wt.On Slips: 130.000 Type of Shoe: Float Casing Crew: Wfd Fluid Description: 10.5 ppg MOBM PV=37 YP=25 HTHP=2.0 Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: • Centralizer Placement: Centralizers on every joint in shoe track,every other(7823-2320'),Every third jt(2320'-surface) CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer Density(ppg) 11.5 Volume pumped(BBLs) 29.2 Lead Slurry Type: Class G Blend Yield(Ft3/sack): 1.15 Density(ppg) 15.8 ppg Volume(BBLs/sacks): 51.2 bbls/250 sacks Mixing/Pumping Rate(bpm): 5 bpm Tail Slurry Type: None Yield(Ft3/sack): N/A Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) N Type:Water Density(ppg) 8.8 Rate(bpm): 2 bpm Volume: 5 bbls LL Displacement: / Type: MOBM Density(ppg) 10.4 ppg Rate(bpm): 8 bpm Volume(actual/calculated): 296/296 ✓ FCP(psi): 670 psi Pump used for disp: Rig pumps Plug Bumped? Yes X No Bump press 0 Casing Rotated? Yes X No Reciprocated? _Yes X No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: N/A Cement In Place At: 18:30 Date: 3/24/2014 Estimated TOC: 6500'MD Method Used To Determine TOC: Calculated based on 100%returns and 40%hole washout Preflush(Spacer) Type: Tuned Spacer Density(ppg) 11.5 Volume pumped(BBLs) 30.9 Lead Slurry Type: Standard Type VII Yield(Ft3/sack): 2.48 Density(ppg) 12 Volume(BBLs/sacks): 74.6 bbls/169 sks Mixing/Pumping Rate(bpm): 5 bbm / Tail Slurry / w Type: None Yield(Ft3/sack): NA a� Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) oType: Water Density(ppg) 8.8 Rate(bpm): 2 bpm Volume: 5 bbls L13 Displacement: u, Type: MOBM Density(ppg) 10.4 Rate(bpm): 8 bpm Volume(actual/calculated): 102/87 FCP(psi): 450 psi Pump used for disp: Rig pumps Plug Bumped? X Yes_No Bump press 1787 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100% Cement returns to surface? X Yes_No Spacer retums? X Yes_No Vol to Surf: 7 bbls Cement In Place At: 0:30 Date: 3/25/2014 Estimated TOC: Surface Method Used To Determine TOC: Witnessed and sampled on surface. Visual cement set up after casing cut off Remarks: The casing hanger was a 9 5/8"hanger with a crossover to hang 7"casing below. ,.,..�^ .-..,:',':,'..-.':::A } ,_,'`,:,-,..4-14P-4:,,,, ,,' ,q �• ' -�, g P i ry y r ,� e.: t ,�{ h5p , wy1 � i v� de 1 gx*4tld Y fr y ir 'Y4' • Ei t • YY ,JI $I 4. Kid '. yi �. ^w :,¢4, r vn, fir' x ,u� ',,,,ty. ' : ,',,'-:!.q4j,„' k,,,r,.,, -. ,: . S.4, -A':,,„,/- ;:!, "•,) - , . !'.•:'''''PAI-.-''''': , •' _-_ ,,z,,,04.. . . _-,.-. 44.'. '- • r'+ < \''‘ ''4''' ' , , ,,,; :1r + ry ,.- ' ' 1,-..4.1=4,r,)''',ia , • � ft } d _ r 5 o- 4` r 5 .'SYS i ��` ,,,,,,,,,,„1.,4,,,;„ 1,,,. - f " ') i ) 1). -, Zr ` k"J , 4. 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''''''' t ', acro a T ' 't 0 '' ' i I - .. w*#► 404 ., ' it '''' 4 - . , ... ...,_ „, . 41„,,,,, . 4 ., . „.„,.. 1,„„.0„i .. ,.. , .. ,... ,„, , ti 414, l '.4rill!pi, b.n a • • klOit yip " w a :1"1"1' . • • HALLIBURTONalifes: . a244,50 Repsol Qugruk 5A Interval 1 Nuiqsut 200 Prudhoe County, AK API: 103-20682-00-00 Prepared tor:David Ross April 3, 2014 Stimulation Treatment Post Job Report 25# Linear Prepared By: Johann Baltrusch/Robert Beasley Marcos Adan/Jeff Waltz Black Crew Notice:Although the information contained in this report is based on sound engineering practices,the copyright owner(s)does(do)not accept any responsibility whatsoever,in negligence or otherwise,for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise.The application, therefore,by the user of this report or any part thereof,is solely at the user's own risk. • • HALLISURTON Table of Contents Section Page(s) Executive Summary 3 Interval Summary 4 Actual Design 5 Interval 1 Plots 6-9 Repsol-Qugruk 5A TOC 2 • • Engineering Executive Summary On April 03,2014 a stimulation treatment was performed in the Nuiqsut 200 formation on the Qugruk 5A well in Prudhoe County,AK. The Qugruk 5A was a 1 stage Vertical Plug and Perf Design. The proposed treatment consisted of: 79,926 gallons of 25#Linear 840 gallons of LVT-200 200,000 pounds of 20/40 CarboLite The actual treatment fully completed 1 of 1 stages.0 stages were skipped,and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 82,728 gallons of 25#Linear 640 gallons of LVT-200 201,600 pounds of 20/40 CarboLite A more detailed description of the actual treatment can be found in the attached reports.The following comments were provided to summarize events and changes to the proposed treatment: Extended 3-4 ppg stage in order to get sand concentration up to where it needed to be. Fixed it and continued job. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants,and fluid volumes are measured to assure the highest level of quality control.Tank fluid analysis,crosslink time,and break tests are performed before each job in order to optimize the performance of the treatment fluids. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well.We hope to be your solutions provider for future projects. Thank you, Johann Baltrusch Robert Beasley Senior Technical Professional Technical Professional Halliburton Energy Services Halliburton Energy Services Repsol-Qugruk 5A &L- • • Interval Summary Qugruk 5A Nuiqsut 200-Interval 1 Interval Summary Date: April 3,2014 Start Time: 9:10:00 PM End Time: 10:50:00 PM Initial Rate(Breakdown): 10.4 bpm Initial Pressure(Breakdown): 2997 psi Max Rate: 25.2 bpm Max Pressure: 5155 psi Max Pressure(SLF): 5155 psi Average Rate: 24.4 bpm Average Pressure: 3531 psi Average Visc: 18 cP Average Temp: 75 F Average pH: 6.3 ISIP: 1111 psi Initial Fracture Gradient: 0.520 psi/ft ISDP: 1730 psi Final Fracture Gradient: 0.720 psi/ft 5 min: 1730 psi 10 min: 1576 psi 15 min: 1560 psi Proppant Summary 20/40 CarboLite Pumped 201,600 lbs Calculated Proppant Pumped* : 201,600 lbs Proppant in Formation: 201,600 lbs Fluid Summary(by fluid description) 25#Linear Volume 82,728 gal 1,970 bbls LVT-200 Volume 4,200 gal 100 bbls Fluid Summary(by stage description) LVT-200 Volume: 640 gal 15 bbls Pad Volume: 9,995 gal 238 bbls Proppant Laden Fluid Volume: 70,033 gal 1,667 bbls Flush Volume: 2,700 gal 64 bbls Cleanup Volume: 3,560 gal 85 bbls Total Fluid Volume: 86,928 gal 2,070 bbls Interval Status: Completed Comments: Blender would not ramp from 3-4 ppg;extended stage and increased concentration Engineer: Baltrusch/Beasley manually. Pumped remainder of job to design. Treater: Marcos Adan Supervisor: Jeff Waltz "Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes. Customer Rep: David Ross Repsol-Qugruk 5A &R&LRepsol-Qugruk 5A Mlik • • Ln o y — a0000000o a _ aMoo o � .n m a 0 0 0 0 0 0 0 0 0 .Q° e a `" m o 0 O O 0 0 0 0 0 0 0 0 0 ai 'a a m °� w C 0 0 0 0 0 0 0 0 0 ^'Itri � a M N o N a H m 3 N N N N N N N N N �- N N N N ▪ `o i o2 2 N N o 0 0 0 II: : : : : o Z Jo N 0 Qa E E a m ,,.... SI � o o E �> q o ° a v. J - O O 00 H 00 00 r O J ,F h W - ,,- -T, °.-:'' 't '''' M Z1%' ,4.° 1' v `�° M .1Di o v `v E E E w 2 2 2 > > > > w U ooO C w r NN � NoO N o g 2O NOm L T,, , m m W m 6 - a - " g m J 7 a ' m :7; d N m p o 00 0 p LL LL :: ;: : _ p Z 1NNmQDtr, y t. N 6 lJ p_;::; a FrvNoo , womo E NryNceivm y m r tea &,'� ` c nInto oo eo m .o a uo . n L'.'4 c T. u b I fa to co o 0 0 o N o �000 $ v m N u"i a v N �' a = o > O a C ,Et U U f f - a E.. 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O O O C �� N O U O d 0 m o F 0 O LL O 1- ZOO -,n N O Z o rn o e E N12 ) O I— 1- M N a) ^ 0 LL, O LL 1- O N 5N N U) C N o Y N o L O s- d 0 a °' ,-I CL _ U) E_ 0 _ L Z og c n a) pQmU D N03 .� -L. ^ �a2 D.Q N Q M OU N — 3 0 4 -M U) N C N 0 . W EL O N 0 = U d II ce a+ W CO N N Q C T} Q Z 7 M N J L() u1 _O p (o O O U U U a Q a o w �' m2 0 0) II wo Zmc� 0 C N 0 O F- p U o u .. N A �, �� N I d,A b d A N I `� O 0 0 0 _ Ln Q 0 00U i 0 m 2 0 to = 0 O N 0- a)N cc • ogull11.416- Regg, James B (DOA) ?AA-03z» From: Q5 DSM <q5.dsm@repsol.com> Sent: Thursday, April 24, 2014 5:55 PM • To: DOA AOGCC Prudhoe Bay Cc: quick, michael (ext); flynn, tim (ext); 'Field Superintendent'; ysa, rick (ext) Subject: Q5 Cement and 20" cap. Attachments: Q5 Cmt and 20 inch cap.pdf; IMG_0304.JPG; IMG_0308.JPG Q5 Nabors 105, Qugruk-Repsol Carlos Cretsinger AVESO LEGAL: Esta informacion es privada y confidencial y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este mensaje y por este media pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribucien o copia de este mensaje este estrictamente prohibida. Esta comunicaciOn es solo para propositos de informacion y no deberia ser considerada como una declaracion oficial de Repsol.La transmision del correo electronic°no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que esta informacion sea completa o precise.Toda informacion este.sujeta a alterarse sin previa aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. 1 • ion:at_ 5 Zt4-03zo Regg, James B (DOA) From: Q5 DSM <q5.dsm@repsol.com> / Sent: Tuesday, April 22, 2014 7:09 AM P �( �� To: Jones,Jeffery B (DOA); DOA AOGCC Prudhoe B y Cc: quick, michael (ext);flynn, tim (ext); 'Field Superintendent; ysa, rick (ext) Subject: RE: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A Attachments: Q5 7 inch P&A Casing testjpg ✓ Good morning Jeff, Here is a copy of our 7" P&A casing test. Will keep you posted on our progress of when we will be cutting off our well head. Thanks Carlos Cretsinger 05 685-3210 From: Jones, Jeffery B (DOA) [mailto:jeff.jones@alaska.gov] Sent: Tuesday, April 22, 2014 6:38 AM To: Q5 DSM; DOA AOGCC Prudhoe Bay Cc: flynn, tim (ext); quick, michael (ext); 'Field Superintendent' Subject: RE: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A Thanks for the update, please scan the chart and email it to me. Jeff Jones AOGCC From: Q5 DSM [mailto:g5.dsm@repsol.com] Sent: Tuesday, April 22, 2014 4:04 AM To: Jones, Jeffery B (DOA); DOA AOGCC Prudhoe Bay Cc: flynn, tim (ext); quick, michael (ext); 'Field Superintendent'; Q5 DSM Subject: RE: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A Jeff, Our cement was in place at 15:00 PM today on our first abandonment plug. We completed the casing test to 2,000 psi for 30 minutes. We are currently picking up our second bridge plug and about to RIH with same. Thanks, Justin Whittenberg 685-3210 From: Jones, Jeffery B (DOA) [mailto:jeff.jones@alaska.gov] Sent: Monday, April 21, 2014 12:22 PM To: Q5 DSM; DOA AOGCC Prudhoe Bay Cc: flynn, tim (ext); quick, michael (ext); 'Field Superintendent' Subject: RE: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A 1 �� Thanks for the update. ��' -- �� Jeff Jones AOGCC From: Q5 DSM [mai|hn:q5.dsmPnepsoicom] Sent: Monday, April 21, 2014 12:15 PM To: Jones, Jeffery B (DOA); DOA AOGCC Prudhoe Bay Cc: flynn, tim (ext); quick, michael (ext); 'Field Superintendent' Subject: RE: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A Jeff, We are just now setting our cement retainer and rigging up Halliburton to pump our first plug job. After we pull out of the cement and circ out we will then perform our casing test to 2000 psi and chart for 30 min. I will keep you posted on our progress. Thanks Carlos Cretsinger 85685'321O From: Jones, Jeffery B (DOA) [mai|to:jeffjunas@a|aska.gov] Sent: Monday, April 21, 2014 6:00 AM To: Q5 DSM; DOA AOGCC Prudhoe Bay Subject: RE: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A Thanks for the update. Jeff Jones AOGCC From: Q5 DSM [mai|to:g5.dsm0arepso|.conn] Sent: Sunday, April 20, 2014 10:48 PM To: Jones, Jeffery B (DOA); DOA AOGCC Prudhoe Bay Subject: RE: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A Jeff, We have just finished laying down our completion down hole tools. We are about to PU our first retainer and RIH. Should be squeezing through our retainer around 8:00 AM tomorrow morning. Thanks, Justin Whittenberg (l5-685-3210 From: Jones, Jeffery B (DOA) [nnai|toieffjones@a|aska.gov] Sent: Sunday, April 20, 2014 6:39 AM To: Q5 DSM; DOA AOGCC Prudhoe Bay Subject: RE: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A Message received, Please provide progress updates. Thanks, 2 Jeff Jones • • AOGCC 448-1228 From: CARLOS CRETSINGER [mailto:noreply@formresponse.com] Sent: Sunday, April 20, 2014 6:21 AM To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay Subject: AOGCC1 Test Witness Notification Request: P &A Plug Verification, NABORS 105 QUGRUK 5A Question Answer Type of Test Requested: P & A Plug Verification Requested Time for 04-23-2014 6:00 AM Inspection Location NABORS 105 QUGRUK 5A Name CARLOS CRETSINGER E-mail g5.dsmnrepsol.com Phone Number (907) 685-3210 Company REPSOL Other Information: Submission ID: 263812873475461248 AVISO LEGAL: Esta information es privada y confidential y este dirigida unicamente a su destinatario.Si Listed no es el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion.por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propositos de informacion y no deberia ser considerada tomo una declaration oficial de Repsol. La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente,no manifestamos que este informacion sea complete o precise.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only.If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL: Esta informacion es privada y confidential y este dirigida unicamente a su destinatario.Si usted noes el destinatario original de este mensaje y por este medio pudo acceder a dicha informacion,por favor,elimine el mensaje.La distribucion o copia de este mensaje este estrictamente prohibida.Este comunicacion es solo para propositos de informacion y no deberia ser considerada como una declaration oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error.Por consiguiente.no manifestamos que esta informacion sea complete o precise.Toda informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only. If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be 3 regarded as an official statement from Repsol.Ent-nsmission cannot be guaranteed to be secure or error-Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVIS()LEGAL, Esta information es privada y confidential y este dirigida unicamente a su destinatario.Si usted no es el destinatario original de este rnensaje y per este media pudo seceder a dicha information,por favor,elimine el mensaje.La distribution o copia de este mensaje este estrictamente prohibida.Esta comunicacion es solo para propositos de information y no deberia sec considerada como una declaration oficial de Repeal.La transmision del correo electronico no garantiza que sea seguro o este libre de error.For consiguiente,no manifestamos que esta informacion sea complete o precise.Tode informacion este sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only. If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not he regarded as an official statement from Repsol,Email transmission cannot he guaranteed to be secure or error-free.Therefore.we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. AVISO LEGAL.; Este informacion es privada y confidential y este dirigida unicamente a su destinatario. Si usted no es 01 destinatario original de este rnensaje y par este medio pudo seceder a dicha informacion,por favor.elimine el mensaje.La distribution o copia de este mensaje este estrictarnente prohibida. Esta comunicacion es solo pare propositos de informacion y no deberia ser considerada coma una declaration oficial de Repsol. La transmision del correo electronico no garantiza que sea seguro a este lihre de error.For consiguiente,no manifestarnos que esta informacion sea complete 0 precise.Toda informacion esta sujeta a alterarse sin previo aviso. This information is private and confidential arid intended for the recipient only. If you are riot the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to he secure or error-free.Therefore,we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. 4 • • # < / / \ G •� W / \/ / co •' IN c/ ƒ % /\ \ / E / (N E • & / 0 On 0 \ \ \ A. y > t \ . . . ». . . ?. . . . . / % _v_, a % , f 7 7. : 7® . -. k @ x » ! \ / : / 3 i / \ . 3,1 j . / \/ 1 z 9 ; / i.. '/ ; \ / 1-A ` 2 2 1 < I { \k i #° { m\ Ef- /k w/ � g. . f\� 2 /®| t ! z k } /A H ® } ) k \ . r,', f �} � . k � ] k o 0_ y . �\ $\\ CNI Y { a f` _ } « ` Q it / , � y2 a # b _ ? \ �... ,....� .. @ _ .� . � ® ( ` \ . . \ \ \ 13 1- .. /^ 2 E k [ ! ; = : « . ... . .. �— . . . { ± ; -- . . . . . , rg 7 © ° ` m} ~ £ ! E [ e\ / . � « CN k22 a. czi • • 4, 4 cr d- ' qqs� N U +-+ ':-. '- *,,,it,..n.:-:,,,;: ,,,,,$ _c on jff { it Q O s. s 1 b *• — rp $ . —co co .,--+ $ E IT � t 1 Fq IF Q O O ,.4 a . „r s._ «r' dA C 4 X 0 r t . 73 • Yr I I91 • illQ C N I O s. = N O• N C dA co Ct s d Q1 d- N d- 0 4 TH....., ^,-14 4'. ' } '% ' '18 a u. ," X 4 e s. a Y' p r \ l6 to AL C .' ". .` Y L Q) b.0E a' O or Tk r 4,)* I//77 THESTATE ��b Alaska� and Gas �-.... Al • �7 o f F } 1\ T ,f `�. C Y1'Ser atslia71 COMM '::.1. \.��d. � s 333 West Seventh Avenue Anchorage, Alaska 99501-3572 of �_ GOVERNOR SEAN PARNELL Main: 907 279 1433 ' Fax: 907.276.7542 Bill Hardham I � Operations Manager � 0-3 ._.. REPSOL USA 3800 Centerpoint Drive, Suite 400 Anchorage, AK 99503 Re: Wildcat Field, Wildcat Pool, Qugruk 5A Sundry Number: 314-256 Dear Mr. Hardham: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Ør' Daniel T. Seamount, Jr. Commissioner is �of April,DATED this� y p , 2014. Encl. • 4)' RECEIVED LVED • STATE OF ALASKA / \ APR 1 7 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑✓ • Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: . .Permit to Drill Number: REPSOL USA • Exploratory ❑✓ • Development ❑ 214-032 • 3.Address: Stratigraphic ❑ Service ❑ API Number: 3800 Centerpoint Dr Ste 400 Anchorage,AK 99503 50-103-20682-01-00 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N Qugruk 5A • Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation(Lease Number): 10.Field/Pool(s): 391452 Wildcat - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8015' .. -7010 7864 6887 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 101' 101' 3060 psi 1500 psi Surface 2305' 9-5/8" 2305' 2305' 6870 psi 4760 psi Intermediate Production 7992' 7" 7992' 6989' 7240 psi 5410 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7650-7690'MD • 6724 6750'TVD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑✓ - Stratigraphic❑ Development❑ Service ❑ 14. Estimated Date for 4/18/2014 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 2• Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Flynn 907-317-5504 Email tim.flvnn@servexternos.repsol.com Printed Name Bill Hardham Title Operations Manager Signature / Phone 907-375-6917 Date 4/17/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\`i_Z. la Plug Integrity i BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance � DC4 a,.•,4.e Other: Z-0P-1 �` ! hod / C�K,,....t Cas, c4'4 - oft i L.,...112. rI RBD z& AY 0 7 2014 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /6 — Li 0 7— APPROVED BY 4/[ (J/I L. Approved by: COMMISSIONER THE COMMISSION Date: I ,i ✓ T' Y•/g•/y I'1& )-)I l4 ly Submit Form and Form 10-403(Rev d 10/2012) Approv inn Tsioo2`Months from the date of approval. Attachments in Duplicate Q' V L ,I y7/ "P • • April 17, 2014 AOOCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: 10-403 Sundry for Permanent Abandonment: Repsol Qugruk 5A PTD 214-032 Dear Commissioner: Repsol hereby submits an Application for Sundry Approvals for the permanent abandonment of Qugruk 5A, permit to drill 214-032. Qugruk 5 (PTD 213-192) was spudded 2/1/2014, and a total depth of 6895' was reached on 2/14/2014. The wellbore was plugged back to the surface casing (Sundry 314-129) and the Qugruk 5A sidetrack (PTD 214-032) was drilled to a total depth of 8015' on 3/20/2014. 7" casing was set and cemented, and the 7"casing perforated from 7650' to 7690' MD, the formation stimulated and the well was tested (Sundry 314-199). The abandonment procedure is attached with the form 10-403 sundry application. In the abandonment procedure Repsol plans to follow 20 AAC 25.112 (g)(1) for tagging requirements,by placing weight on the mechanical plug prior to placing cement. Pertinent information attached to this application includes the following: 1. Form 10-403 Application for Sundry Approvals — 2 copies 2. Abandonment Procedure 3. Current Wellbore Schematic 4. Proposed Abandonment Wellbore Schematic 5. Directional Survey The AOGCC is requested to treat as confidential all information included. If you have any questions or require additional information,please contact Bob Jones, Drilling Manager at 281-863-1618, myself at 907-375-6917, or the technical contacts contained in the following pages. Sincerely, Bill Hardham Operations Manager Repsol USA • r REPSOL USA Qugruk 5A P&A Procedure(PTD 214-032) Current Well Status—BOP stack installed and tested, 3-1/2" tubing completion pulled per approved Sundry 314-199. 1. Notify AOGCC 48 hours prior to commencing abandonment operations. 2. Post approved 10-403 Sundry notice on location. 3. Pickup 7" cement retainer on tubing and RIH to+/-7500' MD. Set Retainer. Pull up and sit back down with 10,000 lbs on retainer to verify set. (per 20 AAC 25.112 (c)(1)(D) and (g)(1)) 4. Rig up cementers and test lines to 4000 psi. 5. Sting into retainer and squeeze 16 bbls (425') of 17.0 ppg class G cement below retainer. (per 20 AAC 25.112 (c)(1)(D)) 3 yZ m44,- 6. Un-sting from retainer and spot 10 bbls (250')of 17.0 ppg class G cement on top of retainer. 7. POOH above top of cement and circulate tubing clean. 46 8. Test casing to 2000 psi for 30 min. Chart test. N' .a" sf'`-`4‘7"-- �i4 `� 9. POOH. ftL 10. Pick up 7" bridge plug on tubing and RIH to+/-2405' MD. Set bridge plug. Pull up and sit back down with 10,000 lbs on bridge plug to verify set. (per 20 AAC 25.112 (g)(1)) 11. Spot 15 bbls (390') 17.0 ppg class G cement on top of bridge plug. 12. POOH above top of cement and circulate tubing clean. POOH. 13. Pick up 7" cement bridge plug on drillpipe and RIH to 280'. Set bridge plug. Pull up and sit back down with 10,000 lbs on bridge plug to verify set. (per 20 AAC 25.112 (g) (1)and (d)(1)(A)) 14. Spot 9.6 bbls (250') of Permafrost cement on top of retainer. POOH. 15. Nipple down BOP and Cut off Wellhead. 16. R/D and move off drilling rig. > N6 f.:4? 4 . 17. Cut off all casing strings (20", 9-5/8", and 7") at least 3 feet below original ground level (per 20 AAC 25.170). 18. Weld a 20" cap onto the casing stub with required well identification information (per 20 AAC 25.120). 19. Take photos of the welded 20" cap. 20. Remove cellar and back fill cellar hole. Take photos of mound. • • ' CONFIDENTIAL Qugruk #5A Current Schematic REPJOL I , 1 t- 26"Hole 1 I ; S ; i 20"131#J-55 Conductor © / /: ' +/-101'MDI TVD • ! % j:: ' I I Rig 105 RKB: 20' I s s I 0 5 Elevation w/ Pad Thickness: 15' 1...4_12'/4'Hole KB to MSL: 35' • e , ; s sI S S % I A + f I J S < : I-4 9-5/8"47#L-80 BTC Casing @ +/-2306'MD I l ;;\ t \\ F : .\ C:::: ::i:: ;1 \.;. : \ \ . \ : :::A \: -;\ , DV Collar @+/-2800' MD \ \ \.. .';\ \ \ \• f6 \ \ \`',, °\\ 7"26#L-80 BTC Casing ., o 38Z gBL" r \ \ \ \ \ \ \, \ \ \ \ \\ -,, ''•\ Q5A Inclination 36.9° \ \ \ `' c,\ \ \ \ \ \ `'• \ Pilot Hole Inclination Through Pay 19.8° \ \ \''; , TOC Stage 1+/-6500'MD \ •\ \\'•. \.:::::ii::\ \.'. °-�\ Kup C @+/-7077'MD \ : :44—8'/2"open hole- *\'"., %;\ (Non Reservior) : \ \:::::.::::: \:: : { ; o\ \] : :: :1 ---. s;C Nuigsut200@+/-7616'MD, \:.::::::::\ Perforations @: ---�-, �_ \:::: ::i:\ 7650'to7690'MD \:''•, •%-;.:\;:::::::::\ \.s . Nuiqsut 100 @+/-7816'MD TD @+/-7430'MD ‘,.1.:.....:•••''iiBaffle Plate @+1-7865'MD \'..,_- basin g Depth @+/-8005'MD p TD Hole Depth TD @+1-8015'MD Revised T Flynn - • t` 4-17-2014 I-11 • - CONFIDENTIAL Qugruk #5A Proposed P&A Schematic MIPIr REPIot 1 ; ; . ; , .;1-4- 26"Hole 1 ' ; 5 : 9 618"x 7"Annulus cemented to surface I ' , 51 51 1 : 51 20"131#J-55 Conductor @ +/-101'MD/TVD NM 5 I -9J18''Bridge plug set at 280'MD Rig 105 RKB: 20' s : 1 0 5 Elevation w/ Pad Thickness: 15' 12-/4"Hole : �� — KB to MSL: 35' s 1 y ; •• - 1 1 1 1 • % 1 9-5/8"47#L-80 BTC Casing @ +/-2305'MD 1 :-,14— -8-61&'-Bridge plug set at 2406'MD I f t 1,.N f \\ ;i ,..; _ %\ \:::::::::::\ : '''....\ 4014 \' ' ' \ ,. \i] �i :::]i\ N‘,. \; i :\ \; •;\ vi::-:•- \ \:, • DV Collar @+/-2800' MD \ \ \:. \ \ \., ''s\ \ \ \''• �,\ 7"26#L-80 BTC Casing • 63g` fQt \ \ \ \ \ \ \; \ \ \ \ \\ \' '••; Q6A Inclination 36.9° \ \ \ s •;\ Pilot Hole Inclination Through Pay 19.8° \ \ \-; , \ TOC Stage 1 +/-6600'MD \ \ \ -• \ \.•: ::•:::\ \.;, -�\ Kup C @+/-7077'MD 4: i : 1 \'-. '•.\ (Non Reservior) Z000,p5., le.,4-7C4-.^-4- \:i: : : i\ - %\ W ,i tiy�SS '\ : ...•.:\ \''' :(.:"• "'':;\ .,9-6115"Cement Retainer \ \�' • '• �— @ 7600'MD 6343"TVD \: :i:.i:::;:\"�—8 /2"open hole ) ."••:. ;'s \__: :::: ••••'",; Nuigsut 200 @+/-7616'MD, \i .:i:i) Perforations@: Viix-'s:::: "-r-- 7650'to 7690'MD r, '� i:: i \ a' :'..;\ Nuigsut100@+/-7816'MD is is is i::\ •.•.�.� TD @+1-7430'MD \is::*:• Baffle Plate @+/-7866'MD '• ' teasing Depth TD @+l-8005'MD Hole Depth TD @+/-8016'MD /{yti Revised T. Flynn rj 4-16-2014 S • REPlOL Sdiemberip ''AIN [Qugruk 5A]Actual Survey Survey Geodetic Report (Non-Det Survey) Report Date: March 20,2014-06:54 PM Survey/OLS Computation: Minimum Curvalure/Lu9nski Client: Raped Vertical Section Azimuth: 354.707°(True North) Field: 0ugruk Vertical Section Origin: 0.000 0,0.000 d Structure/Slot: O59/1k 5/05 TVD Reference Datum: Rotary Table Well: Otgruk 5 TVD Reference Elevation: 35.000 d above MSL Borehole: Chgmk55 Seabed/Ground Elevation: 12.0008above MSL UWI/APIA: Unknown/501032068201 Magnetic Declination: 19.135° Survey Name: IDugruk 58)Actual Survey Total Gravity Field Strength: 1001.9844mgn(9.80665 Based) Survey Date: March 11,2014 Gravity Model: GARM Tort/AHO/DOI/ERD Ratio: 74.551°/3141.504 ft15.428/0.448 Total Magnetic Field Strength: 57597.855 nT Coordinate Reference System: NAD27 Alaska Stale Plane,Zane 04,US Feel Magnetic Dip Angle: 80.869° Location Lat/Long: N 70°223454110"W 150°391272789" Declination Date: March 11,2014 Location Grid N/E y0(: N 5087456.000 1185,E 438058.000101S Magnetic Declination Model: BGGM 2013 CRS Grid Convergence Angle: -0.4743° North Reference: True North Grid Scale Factor: 0.99990436 Grid Convergence Used: 0.0000° Version 1 Patch: 2.7.1043.0 Total Corr Meg North->True 191351 Loral: Local Coortl Referenced To: Well Head MD Incl Atlm True TVDSS TVD VSEC AHD Closure NS EW DLS NortNng Easdng Latitude Longitude Comments (N) (°1 (°1 (Ill (ft) (ft) (N) 181 1N/S NI (E/W ft) (7100ftl (ftUSI (NUS) (NIS°'9 (EIW°'1 RTE 090 0.00 0.00 -35.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 N/A 5987456,20 438058.00 N 70 22 34.54 W 15030 12.73 229.00 0.20 204.56 194.00 229.00 -035 0.40 0.40 5036 W 0.17 009 5987455.64 439057.83 N 702234.54 W 1503012.73 31100 0.22 158.17 276.00 311.00 -0.62 0.68 0.66 5004 W 0.17 020 598745536 438057.83 N 702234.53 W 1503012.73 490.00 0.03 250.53 45500 490.00 -0.96 1.04 098 5097 W 098 0.12 5987455.03 438057.91 N 702234.53 W 1503012.73 58290 0.29 35286 547.00 582.00 -0.74 1.27 0.76 30.75 W0.14 0.32 5987455.25 43805786 N 702234.53 W 1503012.73 85890 0.09 19626 823.00 858.00 -024 088 0.39 5027 W 028 0.14 5987456.74 438057.72 N 702234.51 W 1503012.74 94890 0.26 8680 913.00 948.00 -031 2.10 0.34 5032 W 0.10 034 5987455.68 438057.90 N 702234.54 W 150301273 1045.00 0.09 135.72 1010.00 1045.00 -038 2.39 0.40 0037 50.17 022 5987455.63 438058.17 N 702234.54 W 150301272 1141.00 0.37 161.39 1106.00 1141.00 -0.74 2.76 0.78 50.71 5033 030 5987455.28 438058.32 N 702234.53 W 15030 12.72 1334.0D 0.49 180.60 1298.99 1333.99 -2.15 4.21 2.23 0298 5080 0.06 5987453.91 438058.78 N 702234.52 W 150301270 1430.0D 0.56 14834 1394.99 1429.99 -2.97 5.09 3.10 5287 51.18 0.14 5987453.12 438059.16 N 702234.51 W 1503012.80 152790 081 14421 1491.98 1526.98 -398 6.25 424 0383 6183 0.26 5887452.16 43805980 N 702234.50 W 15030 12.67 181790 0.68 140.22 1781.95 1816.95 -7.17 10.02 7.97 3881 54.13 0.05 5987449.15 439362.07 N 702234.47 W 1503012.61 1913.00 0.76 161.02 1877.95 1912.05 -8.25 11.21 9.15 5785 E4.70 028 5987448.11 438062.64 N 702234.46 W 150301259 2009.00 0.70 153.29 197394 200694 942 12.43 5036 58.98 E517 0.12 5987446.98 438063.10 N 702234.45 W 1503012.58 2106.00 0.59 18389 207093 2105.93 -10.46 13.50 1137 010.01 05.41 0.37 5887445.95 430063.32 N 702234.44 W 1503012.57 2202.00 0.72 169.96 2166.93 2201.93 -1155 14.59 12.37 511.09 E5.48 021 5987444.86 438063.38 N 702234.43 W 1503012.57 Tie-in Survey 2252.00 0.64 174.68 2216.92 2251.92 -12.14 15.18 1284 011.68 E5.56 020 5987444.27 438063.46 N 702234.43 W 1503012.57 230790 0.83 175.46 227192 2306.92 -1285 1509 13.60 51238 E582 035 598744357 438063.51 N 702234.42 W 1503012.56 805 2342.00 137 357.28 2306.92 234102 -12.89 1025 13.45 S 12.22 55.62 628 5987443.74 438063.52 N 70 22 30.42 W 150301256 238190 3.82 35684 234587 2380.87 -1082 18.01 1183 51046 E5.52 628 5987445.50 438063.44 N 702234.44 W 1503012.57 241300 3.90 355.77 237780 2412.80 -8.77 20.17 990 08.31 E539 0.34 5987447.65 438063.32 N 702234.46 W 15030 12.57 2510.00 7.11 337.76 247435 2509.35 028 29.40 292 hi0.54 E2.87 3.72 5987456.52 438060.87 N 702234.55 W 1503012.64 2605.00 10.05 392.50 2568.28 2603.28 1358 43.56 13.72 N 13.34 W a18 320 5987469.36 438054.93 N 702234.67 W 1508012.82 2702.00 13.16 331.11 2663.28 2698.28 31.54 63.07 32.95 N3052 W 12.43 3.22 5987486.62 438045.82 N 702234.64 W 1503013.09 2797.00 17.12 33994 2754.98 2789.98 64.98 87.83 5789 N 53.13 W 22.46 481 5987509.31 438035.99 N 702235.06 W 1503013.38 2895.00 21.51 351.14 2847.47 2882.47 8689 120.15 89.69 N84.46 W 80.18 5.84 5987540.70 438028.53 N 702235.37 W 1503013.61 2990.65 2594 356.50 293533 2970.33 124.64 157.91 12889 N 122.01 W 34.12 430 5687578.28 438024.90 N 702235.74 W 1503013.73 3086.61 28.38 0.29 302105 3056.05 167.65 20103 168.82 N 165.10 W 3524 3.91 5987621.37 438024.13 N 702236.16 W 1503013.76 3182.54 31.01 199 3104.37 3139.37 21486 248.54 21535 N21200 W 3427 288 5987668.86 438025.50 N 702236.63 W 1503013.73 3278.73 36.19 358.55 318494 3219.94 267.12 301.05 26729 N 285.10 W 34.11 4.78 5987721.35 438026.09 N 70 2237.15 W 1503013.73 337527 39.50 35682 326188 3296.68 325.58 359.60 32585 N 323.80 W 36.52 4.59 5987779.86 438024.17 N 70 22 37.72 W 15030 13.80 347123 38.21 357.51 3336.40 3371.40 385.73 419.79 385.75 N 383.72 W 39.50 1.42 5987840.00 438021.88 N 70 22 38.31 W 1503013.88 356785 38.83 359.42 3413.04 3448.04 444.44 478.63 444.44 9442.54 W 41.09 187 5987898.82 438020.58 N 702238.69 W 15030 1303 3665.11 3693 123 349084 3525.84 502.52 537.00 50206 950090 W 40.76 1.12 5987957.17 438021.39 N 702239.47 W 15030 13.92 3761.50 36.91 0.63 3567.90 3602.90 560.00 59490 56021 N 558.79 W 3982 037 5988015.05 438022.81 N 702240.04 W 1503013.89 3857.50 38.90 358.71 3644.67 3679.67 617.51 652.55 617.74 N616.43 W 40.15 120 5988072.68 438022.96 N 702240.60 W 150301390 3953.62 36.92 358.54 3721.52 3756.52 675.10 710.27 675.42 N674.14 W 41.53 0.11 5988130.40 438022.05 N 702241.17 W 15030 1394 4050.00 36.85 358.49 379881 3833.61 73282 768.12 73323 N 73097 W 43.03 0.08 5988188.23 43802103 N 702241.74 W 1503013.99 4146.30 36.83 35787 3875.68 3910.68 790.45 825.86 790.85 N 789.68 W 4487 039 5988245.95 438019.67 N 702242.31 W 1503014.04 4242.51 36.89 355.18 3952.66 3987.66 848.12 883.57 84666 N84728 W 4837 1.68 5988303.56 438016.65 N 702242.87 W 15030 14.14 4338.99 36.93 354.74 4029.81 4064.81 906.07 941.51 808.57 N 904.99 W 5346 0.28 5988361.32 438012.04 N 7022 43.44 W 150 3014.29 4434.60 36.96 353.72 410622 4141.22 963.53 998.97 983.99 N962.17 W 59.23 0.64 5988418.53 438006.74 N 702244.00 W 1503014.46 4530.74 37.00 351.72 418302 4218.02 1021.32 105680 1021.70 N 1019.53 W 68.56 125 5988476.94 437999.89 N 702244.57 W 1503014.68 462709 37.04 352.45 425995 4294.95 1079.27 1114.81 1079.56 N 107698 W 74.55 0.48 5088533.46 437992.37 N 70 22 45.13 W 1503014.91 472358 37.00 350.66 433700 4372.00 113727 1172.90 1137.48 N 1134.44 W 83.00 1.12 5988590.98 437984.32 N 702245.70 W 1503015.16 4818.77 37.01 350.57 4413.01 4448.01 1194.42 1230.20 1194.55 N 1190.97 W 92.43 0.05 5988647.58 437975.44 N 70224625 W 150301543 4916.51 37.03 350.23 4491.05 4526.05 1253.10 1289.05 1253.17 N 1248.99 W 102.25 021 5988705.68 437966.10 N 702246.82 W 150301572 5011.00 37.01 35021 4566.56 4601.56 130987 1345.99 130890 N 1305.11 W 11192 092 5988761.86 437956.90 N 702247.38 W 150301600 5106.00 36.98 350.75 464397 4678.97 /nee Z 1404.31 1368.04 N/362.62 W 121.57 034 5983819.45 437947.73 N 702247.94 W 150301629 520426 36.95 352.28 472088 4755.88 1425.82 1462.19 142582 81419.87 W 130.11 0.86 5988876.76 437939.66 N 702248.51 W 150301654 5301.18 3700 353.58 4798.31 4833.31 148498 1520.48 1484.08 N 1477.72 W 13728 091 5988934.66 437932.97 N 702249.07 W 150301675 5398.20 36.92 353.56 487584 4910.84 1542.40 1578.82 154240 N 153568 W 14381 098 598699287 43792692 N 702249.64 W 150301694 5484.31 36.94 353.48 4952.66 4987.66 1600.14 1636.56 1600.14 N 1593.06 W 150.33 0.00 5980050.10 437920.88 N 70 22 50.21 W 1503017.13 5590.41 36.87 354.51 5029.51 5064.51 1657.84 180427 1657.84 N 1650.45 W 156.37 0.65 5980107.53 437915.31 N 702250.77 W 1503017.30 5686.90 36.79 35505 5106.74 5141.74 1715.68 1752.11 1715.68 N 1708.08 W 161.33 0.71 5980165.19 437910.83 N 702251.34 W 1503017.45 5783.39 36.77 35534 5184.02 5219.02 1773.44 1809.88 1773.44 N 1765.67 W 16587 0.19 5988222.81 437906.77 N 702251.91 W 1503017.58 5879.42 36.82 35432 5260.92 5295.92 183096 1867.40 1830.96 N 1822.95 W 171.05 0.64 5889280.13 437902.06 N 702252.47 W 1503017.73 5975.70 36.83 35387 5337.99 6372.99 1888.66 1925.10 1888.66 N 1880.35 W 176.99 0.28 5989337.57 437896.60 N 702253.03 W 1503017.91 6071.85 36.91 35453 541481 5449.91 1946.35 1982.79 194635 91937.75 W 18282 0.42 5989395.00 437891.25 N 702253.80 W 150301808 6168.26 36.75 35325 549208 5627.08 2004.13 2040.58 2004.14 9199621 W 18097 081 5990452.51 437885.57 N 702254.16 W 150301826 6264.70 36.72 353.74 556937 5604.37 206180 209827 206181 N 2052.52 W 195.50 031 5980509.87 437879.51 N 702254.73 W 150301845 636038 36.87 354.56 564599 5680.98 2119.11 2165.57 2119.11 92106.53 W 201.34 004 5989566.92 437874.15 N 702255.29 W 150301862 6457.17 36.81 354.00 572345 5758.45 2177.14 2213.61 2177.15 N2167.27 W 207.12 035 5989624.70 437868.84 N 70225586 W 1503018.79 6554.18 36.56 35384 5801.25 5836.25 223598 2271.56 2235.10 N 2224.90 W 21326 028 5988682.37 437863.18 N 702256.42 W 150301897 6650.39 36.56 354.00 5878.53 5813.53 2292.39 2328.87 2292.40 N 2281.89 W 219.33 0.10 5989739.40 437857.58 N 702256.98 W 1508019.15 8747.26 36.46 35482 5956.39 5991.39 2350.02 2386.50 235094 82339.25 W 224.95 0.51 5989796.80 437852.44 N 702257.55 W 1503019.31 6840.07 36.58 354.95 603097 6965.97 240525 2441.74 240527 N 2394.26 W 229.87 0.15 5989851.84 437847.08 N 70 22 513.09 W 1503019.46 6939.44 36.55 354.94 6110.70 6145.79 2464.45 2500.93 2464.46 N 245323 W 235.09 0.03 5988910.85 437843.25 N 70 22 58.67 W 150 30 1901 7036.31 36.59 353.56 6188.59 8223.58 2522.16 2558.65 2522.18 N 2510.65 W 24087 005 5980968.31 437837.94 N 70 22 50.23 W 1503019.78 713281 36.54 354.29 6266.00 6301.09 2579.64 2616.14 2579.66 9256781 W246.95 0.45 5990025.52 437832.33 N 70 22 59.80 W 1503019.96 7229.10 36.45 36623 6343.51 6378.51 2636.90 2673.40 263602 N 2624.88 W 251.69 120 5990082.62 437828.07 N 70 23 0.36 W 15030 2010 7324.34 36.37 355.84 6420.15 6455.15 2693.42 2729.83 2693.43 9268127 W 25585 026 5990139.04 437824.63 N 7023 0.91 W 1503020.21 7421.53 36.50 355.90 6498.35 6533.35 2751.13 2787.65 2751.14 02738.85 W 259.75 0.14 5990196.63 437820.96 N 7023 1.48 W 1503020.33 7518.25 36.55 35725 6576.07 6611.07 2808.66 2845.22 2808.66 N279631 W 263.19 083 5990254.11 437817.99 N 7023 2.04 W 1503020.43 761421 36.60 356.12 6653.14 6688.14 2865.80 2902.40 2865.81 N 2853.39 W 266.50 0.70 5990311.22 437815.16 N 7023 2.60 W 1503020.53 771090 36.96 35485 6730.58 6765.58 2923.69 2960.29 2923.68 92911.10 W 271.06 0.87 5990368.96 437811.07 N 7023 3.17 W 1503020.66 7806.04 36.52 056.30 6806.82 6841.82 2980.59 3017.20 2980.58 92967.84 W 275.45 1.02 5990425.72 437807.15 N 7023 3.73 W 1503020.79 7903.49 36.50 355.98 6885.15 8020.15 3038.55 3075.18 3038.55 N3025.68 W 27935 020 5990483.60 437803.73 N 7023 4.30 W 1503020.91 7946.88 36.50 355.79 6920.04 6955.04 3064.36 3100.99 3064.36 N 3051.43 W 28121 026 5990509.36 437802.09 N 7023 4.55 W 1503020.96 Projecdm to TD 8015.00 36.50 355.79 6974.79 7009.79 310487 3141.50 3104.87 53091.84 W284.18 090 5990549.78 437799.45 N 7023 4.95 W1503021.05 Survey Type: Non-Def Survey Drilling Office 2.7.1043.0 Qugruk\Qugruk 5\Qugruk 5\Qugruk 5A\[Qugruk 5Aj Actual Survey 4/17/2014 4:01 PM Page 1 of 2 It 111 .a Comments MD Incl Azlm True TVDSS TVD VSEC AHD Closure NS EW DLS Northing EastMg Latitude Longitude (h) (°1 TI (X) (ft) (ft) (ft) (ft) (N/S ft) (ENI ft) (1/10018 (ftUS) (ftUS) Survey Error Model: ISCWSA Rev 0"'3-0 55.000%Confidence 2.7955 signs Survey Program: MD From MD To EOU Freq Hole Size Casing Diameter Description Part Survey Tool Type Borehole/Survey (fl) (ft) (ft) (in) (in) 1 0.000 23.000 Act Sins 12250 0.525 SIB_MW D-STD-Depai Only Qugmk 5/Qugmk 5 1 23.000 2252.000 Act Sins 12.250 5.625 SLB MWD-STD Qugruk5/Qugmk5 1 2252.000 6015.000 Act Sins 30.000 30.000 SLB_MWD-STD Qugruk SA/(Qr ruk SA)05051 Survey Drilling Office 2.7.1043.0 Qugruk\Qugruk 5\Qugruk 5\Qugruk 5A\Qugruk 5A]Actual Survey 4/17/2014 4:01 PM Page 2 of 2 V • • Qugruk #5A Daily Operations Summary REPlOL API: 50-103-20682-01-00 Permit #: 214-032 Rig: Nabors 105AC CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity MOVE TO ST OPS ON QUGRUK-SA WELLBORE 09:30hrs 18 April 2014 TD:8015'; Mud Weight: 10.6 Brine Vis:47; RU HES SL. Load 100 bbls 10.3 0' ppg Brine into mud pits&blend w/existing 10.8 ppg Brine. Final MW= 10.6 ppg. Pump 70 bbls 10.6 ppg Brine dn tbg @ 2 BPM w/1350 psi. Fin RU HES SL unit& press test lubr to 3000 psi—10 min—OK. RIH w/2"JDC fishing assy for 1-3/8"fish neck to 7600'—perf guns no longer in tbg string. POOH w/2" fishing assy. RD SL lubr&secure to derrick. ND CT BOPE& hyd lines. RU HES SL. Press test lubr to 3600 psi—5 min. RIH w/2.80"gauge ring to 6750'. POOH w/ SL. PU PX plug body. Press test lubr to 3600 psi—5 min. RIH w/plug body. 19 April 2014 TD:8015'; Mud Weight: 10.6 Brine Vis:47; Cont RIH w/PX plug body. Set 0' plug in X-nipple @ 6675'. PU PX plug prong.Press test lubr to 3600 psi—5 min. RIH w/prong assy.Set prong in plug body. POOH w/SL. Press test plug @ 6675'to 3000 psi—10 min. RD HES SL. Flush Expro flowlines w/30 bbls of wtr. Blow down w/N2. RD Expro flowlines. RD SL sheave, lubr& BOP. Pump 30 bbls hot wtr thru mud cross on tree to Expro. Bleed dn w/N2. RD Expro w/crane. RD frac tree. Bleed off annulus&verify no trap gas. Open pipe rams.Strip up thru 20" annular. Back out 10K flg. RU & press test SL lubr to 3000 psi—OK. RIH w/SL to 6675'w/2" prong pulling tool. Latch prong&POOH. PU PX plug pulling too. Press test SL lubr to 3000 psi &RIH w/SL to 6675'. Latch onto PX plug& POOH. RD HES SL. RU to pump dn tbg. Press test lines to 3000 psi—5 min. Pump 9 bbls dn tbg to verify LPR-N valve is open @ 2.5 BPM w/ 1200 psi— LPR-N is open. Line up to pump dn annulus for rev circ. Press up annulus to 2800 psi to rupture RD circ sub. SD pumps.Open annular&unseat Champ pkr. Rev circ 380 bbls thru choke manifold @ 3 BPM w/400 psi (10.7 ppg in 10.7 ppg out). Monitor well for 30 min—static. • I - 1. 20 April 2014 TD:8015'; Mud Weight: 10.4 Brine Vis:45; RD pump-in sub&floor vlv. 0' Instlal 3.5"elev. Stand back 1 std to remove Metrol repeater. PU landing jt& hgr. Land hgr. Install BPV&test dart.Test BOPE:Annular 250/3500 psi; remaining components 250/5000 psi–all tests good. NOTE:Witness waived by AOGCC Rep,Jeff Jones. Perform successful body test to 3500 psi as per AOGCC Rep,Jeff Jones. RD test eqpt& blow down lines. PU landing jt. MU to hgr& pull up to rig floor(up wt 89k). POOH w/31/2"TC11 tbg. LD DH completion tools. NOTE: FINAL COMPLETIONS REPORT–BEGIN P&A OPS. 21 April 2014 NOTE: BEGIN P&A OPS. 0' TD: 8015'; Mud Weight: 10.7 Brine Vis:46; MU HES EZSV cmt ret& RIH w/ same to 7500'–set dn w/10K. RU HES lines&test to 4000 psi. Est inj rate blw pkr 2 BPM @ 1340 psi.Cmt Plug#1: M&P 15 bbls 13.0 ppg Tuned Spacer; 26 bbls (147 sx) 17.0 ppg Class G cmt (yield .99 cuft/sk) @ 2 BPM. Displ w/5 bbls 13.0 ppg Tuned Spacer. Displ w/50.2 bbls 10.7 ppg Brine (16 bbls blw EZSV& 10 bbls abv EZSV). POOH. Rev circ 2 BU @ 8 BPM w/1150 psi. RD& blow down lines.Std back 3 stds–pipe pulling wet. RU &circ. Std back 3W'tbg RU cmt lines f/csg test. Press test cmt lines to 4000 psi.Test csg to 200.0 psi–30 min– OK. Blow down cmt lines. POOH 22 April 2014 TD:8015'; Mud Weight: 10.7 Brine Vis:46; MU HES EZSV bridge plug& RIH 0' w/same. Setbridgeplug @ 2405-set dn 10k to verify pkr set. RU HES lines& test to 4000 psi. Cmt Plug#2: M&P 15 bbls Tuned Spacer @ 13.0 ppg; 15 bbls (85 sx) @ 17.0 ppg Class G cmt(yield .96 cuft/sx); 5 bbls spacer. Displ w/11 bbls of 10.6 ppg Brine. LD tbg. RIH &set bridge plug @ 280'. Shear off&verify depth. RU HES lines&test to 4000 psi.Cmt Plug#3: M&P 10 bbls Tuned Spacer @ 13.0 ppg; 10.1 bbls (59 sx) Class C Permafrost cmt @ 15.6 ppg(yield .96 cuft/sx); 1 bbl of good cmt returns to surface. LD 6 jts&top off cmt w/3.7 bbls of 15.6 ppg Class C Permafrost cmt. Blow dn cmt lines. RD cmt eqpt. RU stack flushing tool &flush BOPE. RD tool. Flush out mud sys&cmt lines. Flush thru top drive,cmt lines&chk/kill lines w/Baraclean&fresh wtr. NOTE: Notified AOGCC for inspections of csg before welding cap top. 23 April 2014 Cont clean pits&drip pans. ND BOPE.Clean pits. Finish cleaning mud pits& 0' cellar in prep for removal of wellhead. 24 April 2014 Cut off wellhead & remove same.Clear rig floor of misc items. Make final cuts 0' on csg&dress cmt for inspection before welding of well cap.Weld cap on conductor. Cont RD Nabors 105AC rig. NOTE: At 13:30hrs 4/24/2014-AOGCC Rep,Johnnie Hill,witnessed& APPROVED top of cement&final installation of well abandonment. RIG RELEASED TO DEMOBE @ 14:00HRS 4/24/2014. • • Qugruk #5A Daily Operations Summary REPfOL API: 50-103-20682-01-00 Permit #: 214-032 Rig: Nabors 105AC CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 11 April 2014 TD:8015'; Mud Weight: 11.1 Brine; Clean sand f/std of 3.5"tbg(±15 gal). 0' Cont POOH. LD LPR-N,gauge carriers,flulid sample catchers, pkr&2-7/8"tbg. Monitor well on trip tank. Empty fluid sample catchers& inspect DH gauges. Prep pit to receive 10.4 ppg Brine wtr to test BHA to 3500 psi. RIH w/comp) string&RU flowhead&CT.I U &MU compl BHA& RIH w/same to 1050'. RU& test BHA to 3500 psi IN/10.4 ppg Brine—5 min—OK. NOTE: Send 24hr notice @ 09:00hrs 11APR2014 to AOGCC for CTU BOPE test est time 09:00hrs 12APR2014. 12 April 2014 TD:8015'; Mud Weight: 11.1 Brine; RD BHA test eqpt. RIH w/3.5"tbg 1050'- 0' 7611'&Metrol installing relays on proper tbg jts. MU safety vlv&connect top drive.Set pkr @ 7479'w/15K. Line up to press test pkr. Close upper pipe rams. Pump down kill line to 500 psi.After 5 min press incr to 600 psi. Bleed press back to 500 psi. Press incr to 600 psi—bleed off to 0 psi.Open pipe rams. Chk f/flow—_well flowing. Flow decr after 10 min.Set 20K on pkr. Close upper pipe rams. Press up to 500 psi. Press incr to 550 psi &stabilized. Held 550 psi— 10 min—good test. Bleed press off to 0 psi. RU install 4-1/16" 10K flg on 3.5" pup jt. Set in slips. RU flow cross tree.Set CTU BOPE on rig flr w/crane. Insert bolts into BOPE flg. Lift BOPE to top of flow tree. NU CT BOPE. RU CT lubr. RU Expro 3" hard lines on rig flr. Pick CT inj over windwalls crane&transfer to rig blks.Stab&MU inj to lubr. Install hyd lines to master vlv. Install drain line to inj. Fin RU Expro 3" hard lines on rig floor. RU to test CTU BOPE. NOTE: AOGCC Rep, Bob Noble,waived witnessing of CTU BOPE test on 12APR2014. 13 April 2014 TD:8015'; Mud Weight: 11.1 Brine Vis:49; Displace CT string&Expro lines 0' w/LVT-200. Attempt to test CTU BOPE—Test CTU BOPE 250/3500 psi. Pressure test tbg string to 3500 psi. Pressure up annulus to 1570 psi to open LPR-N. Open well to Expro. RIH 4000'-7720' pumping N2. Flow well to Expro eqpt. 14 April 2014 TD:8015'; Mud Weight: 11.1 Brine Vis:49; POOH w/CT 7720'-1000' 0' pumping 1.8 BPM. Flow well to Expro eqpt. RIH w/CT 1000'-6500' pumping N2. Flow well to Expro eqpt. POOH w/CT to 5000'.Stop pumping N2. POOH w/CT to surf& bleed down N2 f/tbg.Monitor well for flow thru Expro eqpt. RIH w/CT to 5000'—fill CT w/8.7 ppg sea wtr. Pump 41 bbls to fill coil. Pump 27 bbls of sea wtr do the well. POOH to surface @ 150 FPM pumping 1.3 BPM. i • . Pump a total of 113 bbls. Allow pressures to stabilize. Perform injectivitytest. Pump 8.7 ppg sea wtr @ 2.1 BPM. Pressure incr 700-1840 psi where pressures leveled off. Inject 20 bbls 8.7 ppg @ 2.1 BPM into formation.SD& monitor pressure. Pressure stable @ 1000 psi after injection. Bleed off pressure to 0 psi. Recover 35 bbls 8.7 ppg sea wtr. Blow down CT reel do to Expro tanks. RIH w/CT to 7733'while pumping 500 SCF of N2.Spot 24 bbls of 7.5%HCL acid &5 bbls fresh wtr spacer 7688'-7713' @ 1.5 BPM & 1000 SCF N2. 15 April 2014 TD:8015'; Mud Weight: 11.1 Brine Vis:49; POOH w/CT to 4000'. Flow well 0' to Expro eqpt. RIH w/CT 4000'-7616' pumping 500 SCF of N2—unable to get past 7616'. No measureable fluid. 100%N2 returns. POOH w/CT to surface pumping 500 SCF of N2. Flush coil w/14 bbls 11.1 ppg completion brine. Displace w/40,000 SCF of N2. Monitor well for flow thru Expro eqpt. Flow well to Expro. RIH w/CT pumping N2 &tag up @ 7616'. Perform clean out run to 7800' using hi vis sweeps. POOH to 4000'to monitor flow. .4 • • 16 April 2014 TD:8015'; Mud Weight: 11.1 Brine Vis:50; RIH to 7749' &tag up. POOH to 0' surface. RD CT eqpt.R/U wireline w/2" perforating guns. Test lubricator to 3000 psi—test good, RIH w/40'of 2" perforating guns and CCL to 7745' MD. Coorelate guns on depth and perforate from 7650' MD to 7690' MD with guns, 6 shots/ft snd 60 deg phasing.All indications guns fired, POOH, stuck at 7360' MD. Pulled 1800 lbs tension work free, POOH. Lost 200 lbs tension at 3000'while POOH. 17 April 2014 TD: 8015'; Mud Weight: 10.8 Brine Vis: 50; R/D lubricator, monitor well for /\S�k 0' flow through Expro equipment. R/U wireline w/sinker bars,Test lubricator to ' ,,.f 3000 psi—test good. RIH to 6882' MD and attempted to push guns downhole. � Guns were moved a total of 10'. POOH with wireline.Attempted to cycle LPR- N valve with pressure cycles with no success. Pump 18 bbls of 8.9 ppg sea water down tubing/1400 psi. Circulate brine through gun lines in mud pits to a consistent weight of 10.8 ppg. Prepare to TIHwith fishing tools to fish guns._ i 64 ea(--1FSA Pip tt4O;z : Regg, James B (DOA) From: Q5 DSM [g5.dsm@repsol.com] 10711. Sent: Wednesday, April 09, 2014 10:30 AM l To: Regg, James B (DOA); DOA AOGCC Prudhoe 186y; Brooks, Phoebe L (DOA) Cc: ysa, rick (ext); JONES, ROBERT; 'Field Superintendent': quick, michael (ext); ross, david (ext); MAHMUD, MUAAZ Subject: Qugurk 5A-Coil Tubing BOP Test Report Attachments: 10-424-Q5 -4.4.14.xls; Graph - Repsol Q-5.emf; Halliburton - BOP Test Q-5 4-6-14.xlsx; Halliburton - Event Logger.xlsx Good Morning Mr. Regg, We've reviewed your comments and found out the following information: • On the Qugurk 5A Permit To Drill, the PTD number noted down is 214-032. • The inner real valves were not tested. After discussing with Joe Rodriquez, Service Supervisor, Boots and Coots it was found out that there was an error on Halliburton's BOP test form.Their engineer mixed up the data on the BOP form. After finding the mistake, the we've corrected Halliburton's BOP form to reflect the actual BOP test and have attached the updated form. • There is a shear ram on the stack. The shear rams were function tested but not tested to cut pipe. • It took 150 seconds to attain full pressure for the accumulator test because there are four bottles on the unit which gives the needed volume for the Halliburton stack. On the other hand Schlumberger has two bottles on their unit and could pressure up faster.The pressure and times for filling up the bottles: o 2 sec = 200 psi o 35 sec= 2000 psi o 139 sec = 2500 psi o 150 sec= 2950 psi I've attached the updated forms in excel format. Please let me know if you have any more questions or comments! Regards, Carlos Cretsinger Q5 — Drill Site Manager AVIS()LEGAL: Esta information es privada y confidential y esta dirigida irnicamente a su destinatario. Si usted no es el destinatario original de este mensaje y por este medio pudo acceder a dicha information,por favor,elimine el mensaje.La distrihucion o copia de este mensaje esta estrictamente prohibida.Esta comunicacien es solo para propesitos de informacinn y no deberia ser considerada tomo una declaration oficial de Repsol.La transmision del correo electronico no garantiza que sea seguro o este libre de error, For consiguiente,no manifestarnos que esta information sea cornpleta o precisa.Toda information esta sujeta a alterarse sin previo aviso. This information is private and confidential and intended for the recipient only. If you are not the intended recipient of this message you are hereby notified that any review,dissemination,distribution or copying of this message is strictly prohibited.This communication is for information purposes only and should not be regarded as an official statement from Repsol.Email transmission cannot be guaranteed to be secure or error-free.Therefore.we do not represent that this information is complete or accurate and it should not be relied upon as such.All information is subject to change without notice. 1 • • STATE OF ALASKA _f: r OIL AND GAS CONSERVATION COMMISSION AM t, BOPE Test Report Submit to: jim.regq(a�alaska.gov AOGCC.Inspectors(a�alaska.gov phoebe.brooks(a�alaska.gov Contractor: Halliburton Rig No.: CTU DATE: 4/6/14 Rig Rep.: Joe Rodriguez Rig Phone: 907-685-3210 Rig Fax: Operator: Repsol Op. Phone: 907-685-3213 Op. Fax: Rep.: David Ross E-Mail Q5.dsm@repsol.com Well Name: Qugruk-5A PTD# 2140320 Operation: Drlg: Workover: X Explor.: Test: Initial: XWeekly: Bi-Weekly Test Pressure: Rams: 250/3500 - Annular: Valves: MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign NA Upper Kelly 0 NA Housekeeping: P • Drl. Rig NA Lower Kelly 0 NA PTD On Location NA Hazard Sec. NA Ball Type 0 NA Standing Order Posted NA Misc NA Inside BOP 0 NA FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 2 4.06 TOT P Trip Tank NA NA Annular Preventer 0 NA Pit Level Indicators NA NA #1 Rams 1 Blind P - Flow Indicator NA NA #2 Rams 1 Shear P Meth Gas Detector NA NA #3 Rams 1 Slip P _ H2S Gas Detector NA NA #4 Rams 1 Pipe P • MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 0 NA Inside Reel valves 1 NT HCR Valves 0 NA Kill Line Valves 0 NA Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 2950 P CHOKE MANIFOLD: Pressure After Closure 1500 - P Quantity Test Result 200 psi Attained 2 - P No. Valves 0 NA Full Pressure Attained 150 P Manual Chokes 0 NA Blind Switch Covers: All stations Yes Hydraulic Chokes 0 NA Nitgn. Bottles (avg): 1250 CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 3.5 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: This BOP test is for Halliburton's Coil Tubing Unit. Inner real valves were not tested. There is a shear ram on the stack. The shear rams were function tested but not tested to cut pipe. 24 HOUR NOTICE GIVEN YES X NO Waived By Jeff Turkington Date 4/1/14 Time 19:50 Witness Test start 4/4/14 3:00 Finish 4/4/14 6:30 Form 10-424 (Revised 03/2013) 2014-0406_BOP_Halliburton_CTU_Qugruk-5A.xlsx 0 • 114ALLIEjU1R1ON 4u9rIV-CA =oocw. c coac.: BOP Test P115 2t4a31..0 k)k,bo.;- Ic., E CURRENT DATE: 04/06/14 WELL: Qugruk-5,4 LAST TEST DATE. 04/06/14 TEMP: -10 BOP SN: 062-22863R DRAWDOWN TEST Start Pre.- 2950 Final Pressure: 1500 Check accumulator pre-charge pressure before beginning BOP test, this should be between 1200-1350 psi. Prior to starting drawdown test, ensure that BOP system pressure is as close to 3000 psi as possible. Final pressure should be NLT 1500 psi. BOP BACK UP PUMP TEST: 200 PSI 4000 PSI COMMENTS 249 3579 FULL BODY GOOD TEST 241 3530 Fluid pack for full body PT through the coil at low rate, come offline. Bump up coil pressure to start shell test.. SIZE/TYPE FUNCTION TEST PRESSURE TEST L CLOSED OPEN PSI 3500 Psi SECONt` 10 minu et 249 3579 Good test/EQ port 06 BLINDS 15 17 241 3530 good 4.06 SHEARS 30 51 N/A N/A Good draw down test. Push 10K 4.06 SLIPS 19 18 N/A N/A Good Test Pull 10K 349 3609 Good test/pump 4.06 PIPES 19 18 check good / EQ port 319 3559 good A 13 10000 =I 4000 7500MIME I® 5000r____ 3000 2500 0 2000 T------- , 2500 1 -5000 I® 1000 -7500 '-.t' _� .::• 1 • -0 -10000 ERR 01:00 02:00 03:00 04:00 05:00 06:00 U49 nn. COMPANY MAN SIGNATURE SUPERVISOR SIGNATURE Boots Coots Private , • • 0 0 COo 0 0 0 0 0 0 0 0 N O Lf) O U) in O in 0 N N- - I-- in N O Ni ti r I c:..1-O o - k CO CO a i O v z 0 r) v 0 M -CD ii =- L O N acv_� O 012- ., u) U 1 — 76 cn U p O v 0 N O .2- O Oo a) 4; E m P- 0 O O O -) n c'> O W U p O Q o x d: 1 Zi Q o icC-)' °.) a M .�- D O-t cc -0 C3 N co O4 Q 1j O 7r 2 c N c),I. E CD V) ars 0 (.) 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' • �� . ��x 410 Regg, Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, April 08, 2014 3:27 PM To: ross, david (ext); flynn, tim (ext); 'quick, michael (ext) Cc: 'Q5 RIG CLERK' Subject: RE: Qugruk 5 Coil Tbg BOPE TesReport Re submit report in Excel format and address the following: Well is[\ugrukGA(PTD 214032D) - Why were the inside reel valves reported as not tested? Halliburton form indicates inside reel valves got a good test. Which is it? - Why are you showing Shear Rams as NA? Workover regulations require CT stack to include blind-shear capability. Can't tell from approved sundry because there was no info about CT stack. - Did it really take 150 seconds to attain full pressure (Accumulator performance test), and if so, why? Seems very unusual for coil. Jim Regg Supervisor, Inspections AOGCC sa3vv.7th Ave,Suite 100 Anchorage,AK 99501 907'793'1236 From: Q5 RIG CLERK [mai|toq5.rig.derk@napsoicom] Sent: Sunday, April 06, 2014 7:27 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: ross, david (ext) Subject: Qugruk 5 Coil Tbg BOPE Test Report Good morning, We are submitting our Coil tubing BOPE test report. Please let us know if you have any questions. Sincerely, Kevin Doucet Repsol Rig Clerk Q-5 907-685-3213 q5.rig.clerk@repsol.com REP.FOL ,.. $ • Qugruk #5A Daily Operations Summary REPJOL API: 50-103-20682-01-00Permit#: 214-032 Rig: Nabors 105AC CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 04 April 2014 TD:8015'; Mud Weight: 10.4 Brine; Test cycle&function LPR-N &OMNI vlv. 0' Cycle OMNI vlv 14 times—vlvs function test properly. Leave OMNI& LPR-N in test position. Test CT BOPE 250/3500 psi. Perform final walk thru of Expro eqpt.SD due to unable to open LPR-N test vlv. Made several attempts to cycle LPR-N vlv w/no success. RIH w/CT to jet LPR-N w/N2.Tag OMNI vlv @ 6791' &found OMNI vlv closed. Continue attempts to cycle OMNI vlv to open position w/no success. Fill CT&3%:"tbg w/LVT. Pressure up 31/2"tbg to 2000 psi to equalize possible pressure trapped between OMNI vlv&LPR-N vlv. Pressure up annulus between 3%2"tbg&7"csg to cycle OMNI vlv various times —no success. NOTE: 23:30hrs 04APR2014—sent notification to AOGCC of upcoming BOPE test on 06APR2014 @ 00:00hrs. 05 April 2014 TD:8015'; Mud Weight: 10.4 Brine; RD up lines f/rig tanks to CT unit. 0' Displace 31/2"tbg w/10.4 ppg Brine. RU N2 to CT unit. Blow down CT&mud lines w/N2. POOH w/CT.RD CT,Expro flowlines to WH. RU return lines to mud tanks.Spot&RU HES SL unit. RU SL&fill lubricator w/10.4 ppg Brine. 06 April 2014 TD:8015'; Mud Weight: 12.4 Brine; Test lubricator to 3500 psi. RU &run 2.8" 0' gauge ring&tag @ 6746'SLM (6679'tally measurement). POOH.Chg out gauge ring to 2.0". RIH to 6873'SLM. POOH (6791'tally measurement). RIH w/Run#1 w/Kinley DH Power Unit w/3/8"tbg punch to 6686'SLM(6620'tally measurement). Wait for timer to activate tool—indication tool activated. Wait for tool to retract. POOH w/tbg punch for Run#2. RIH w/Run#2 tbg punch HES SL to 6685'(6627'tally measurement). Tool set on 80 min autotimer—tool engaged. POOH. RD HES SL unit.Take on 12.4 ppg Brine. Attempt to displace w/12.4 ppg Brine down tbg&up annulus—pressure up to 2000 psi w/minimal returns. RU 2.80"drift f/gauge run on SL. Pressure test lubricator to 3500 psi. RIH w/500 psi on tbg to 6881'. Tag up previous shot. Work SL w/no restriction. POOH. PU single shot. Pressure test lubricator& RIH @ 100 FPM to 6625'—activate punch tool. No psi change after punch time completed. POOH w/SL. RU rig mud pump to csg annulus&cycle OMNI vlv 3 times w/1500, 2500&2600 psi—noticed leakoff @ 2600 psi. Annulus pressure continued to drop&tbg pressure increased to 2450 psi. Bleed pressure off annulus&circ down tbg @ 1 BPM @ 3000 psi. Pressure decreasing. Increase pump rate to 2.5 BPM w/1400 psi. Continue to displace 10.4 ppg Brine to 12.4 ppg Brine w/2.5 BPM 1000 psi. � r • • 07 April 2014 TD:8015'; Mud Weight: 12.4 Brine; Continue to displace to 12.4 ppg Brine— 0' total pumped 270 bbls w/2.5 BPM 1000 psi. Install BPV. Pump down annulus to test BPV to 3000 psi. RD frac tree. NU 13-5/8" BOPE.Test Expro lines to 3000 psi. Install test jt&fill stack. 08 April 2014 TD:8015'; Mud Weight: 11.5 Brine; Test annular BOPE 250/3500 psi.Test 0' rams,choke manifold, mud lines, IBOP&safety vlv 250/5000 psi. NOTE: AOGCC Rep, Chuck Scheve,waived witness of BOPE test on 06APR2014 @ 10:02hrs. RD BOPE test eqpt. MU landing jt&TIW vlv. Unset tbg hgr. Open ports on pkr.Close annular. Bleed off pressure 125 psi—0 psi(flow back 62 bbls). Circ 11.5 ppg Brine @ 1 BPM w/500 psi.Stage up to 4 BPM w/1400 psi. PU&unseat pkr.Circ BU @ 2 BPM w/430 psi. Break out top drive. Disconnect safety vlv. PU to tbg hgr. Fluid flowing back up tbg. Connect safety vlv&top drive&circ. 09 April 2014 TD:8015'; Mud Weight: 10.7 Brine; Cont to circ until pressure dropped. Chk 0' for flowback in tbg—no flow. LD hgr&pup jt. Blow down top drive. Chk f/flow —well flowing. Monitor flow to chk f/unbalanced mud.Well continued to flow. Install safety vlv&closed annular preventer. Monitor pressure.Open annular to Expro. Re-set pkr.C&C fluid. Cut fluid wt 11.1 ppg to 10.7 ppg. PU& open pkr circ ports. Blow down top drive.Close TIW vlv&close annular preventer. Monitor pressure(0 psi after 30 min). Pkr ports plugged. 10 April 2014 TD:8015'; Mud Weight: 11.1 Brine; Work pkr several times to unseat. Break 0' out safety vlv. RD Metro register station.Close annular.Attempt to lower string—unable to go down(20'stick up). Install safety vlv.Connect top drive. Close safety vlv&annular preventer&monitor pressure. Bleed pressure 120 psi—0 psi.Set pkr to circ 11.1 ppg brine around. Attempt to displace hole w/ 11.1 ppg Brine—unable to circ down tbg. Blow down top drive. RU head pin to rev circ.Take returns thru tbg back to flowline. Begin to lose fluid when 11.1 ppg Brine entered tbg—indication both OMNI&LPR-N were open—lost±14 bbls. Unset pkr&monitor well for 15 min—static. Pump 20 bbl 13.1 ppg Brine dry job to POOH. POOH &remove metrol relays while POOH. LD OMNI vlv& check press f/gauge. Cont POOH.Stand above LPR-N packed off with sand. • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, April 09, 2014 4:05 PM To: 'ross, david (ext)' Cc: JONES, ROBERT;ysa, rick (ext); quick, michael (ext) Subject: RE: Q-5A Compeltion Status P 1 b .2P-1 -6 32-- David, 2_David, I have reviewed the proposal below and agree with your steps. You have approval to modify the flowback procedure as outlined below. If other significant changes are needed call or email me with the new proposals. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: ross, david (ext) [mailto:david.ross@servexternos.repsol.com] Sent: Tuesday, April 08, 2014 9:29 AM To: Schwartz, Guy L(DOA) Cc: JONES, ROBERT; ysa, rick(ext); quick, michael (ext) Subject: RE: Q-5A Compeltion Status Guy, As per our conversation yesterday the following is an update of the Q-5A completion status and our proposed plan forward. At 19:00 on the 2"d of May we landed the completion string in the Q-5A well as per the 10-403 sundry information. After N/D the BOP and N/U the 10K frac tree, a DFIT injection test and Frac treatment were performed on the 3d and 4th of May. We were able to place 201K lbs of 20-40 carbolite with 82,728 of 25 ppt linear guar gel with a maximum proppant concentration of 6.1 ppg The maximum STP encountered during the frac was 5,155 psi with an average pressure of 3,531 psi. Following the frac treatment we continued to rig up the coiled tubing unit on the rig floor above the tree and a BOP test was conducted. NOTE: AOGCC INSPECTOR JEFF TURKINGTON WAIVED WITNESS OF BOPE/CT TEST @ 2054HRS 02APRIL2014. On the morning of the 5th we were preparing to open the well to the surface test equipment when we discovered the downhole LPR-N test valve had failed in the closed position and later found that OMNI circulation valve was also failing to open. After numerous attempts to cycle the valves open the decision was made to begin rigging down in preparation to pull the completion. Due to the charged frac pressure trapped below the packer and the extremely low bleed off it was necessary to punch the tubing above the closed OMNI valve at+/-6620'and circulate 12.4 ppg kill weight brine into the well in preparation to pull the completion. The+/-4,268 psi of hydrostatic pressure resulting from the 12.4 ppg brine above the punch and the 10.4 brine below the punch is slightly underbalanced with the measured BHP of 4,366 psi at the top perf as of 08:00 today. After installing the BPV in the tubinflnger and performing a 3,000 psi pressur•t in the direction of flow we N/D the frac tree and N/U the BOP stack.The successful BOP test was completed at+/-08:00 this morning and we are proceeding to perform a controlled bleed on the well. At this point we have connected to the Expro flow back line to the HCR choke line on the BOP and fluid packed the line to the choke manifold with 12.4 ppg brine. After closing the annular preventer and back out the lock down screws on the tubing hanger we plan to strip up slightly to place the packer in bypass mode and observe the pressure difference on the choke line. If positive pressure is seen we will perform a controlled lube and bleed operation using the Expro choke manifold until the well is balanced. After circulating sufficiently to ensure we have a consistent density in and out of the well we will monitor the well for 30 minutes for a static condition and then proceed to slowly pull the completion to avoid swabbing the well in. After pulling the completion we will lay down the LPR-N and OMNI valves and prepare to run the completion back in the well. After spacing out and setting the packer our plan is to make up a 4-1/16" 10K flange to the 3-1/2" tubing at the rig floor and then N/U the lower master, HCR master,flow cross and swab valve that previously made up the frac tree. We will install the CT BOP on top of the swab valve and proceed to rig up the CT lubricator and injector which will be suspended by the blocks in the derrick. Once we make up the lubricator to the CT BOP we will be able to apply tension with the blocks to effectively relieve the weight load on the rig floor tree assembly. The Expro flow back line will be tied into the 3" side of the flow cross in the same manner it was installed on the Frac Tree. Do to time constraints,we are proposing to use this rig up to test the well which will eliminate the need to N/D the BOP stack and N/U the tree before testing and later having to N/D the tree and N/U the BOPs again to abandon the well. The 3-1/2" pipe rams and annular preventer will provide two mechanical barriers on the annulus in addition to the two master valves for barriers on the tubing. For additional well control we will be able to pump into the 2" side of the flow cross and down the tubing in addition to having the capability of the rig pumping into the annulus via the valves on the casing head. Repsol is seeking your approval for this change to the 10-403 completion sundry previously submitted and approved, in order to make the best use of the remaining time available for this year's exploration season. Based on the fact we will be flow testing through the BOP stack it is our understanding we will be exempt from the 7 day BOP test schedule until such time we resume operations to kill the well and de-complete. I have attached a schematic of the proposed testing rig-up for your review. Thanks you for your time and consideration of this matter and don't hesitate to call me if you have any questions or require additional information. David Ross / Sr.Completion Engineer Repsol E&P USA Inc. 3800 Centerpoint Dr Ste 400 Anchorage,AK 99503 Tel:907-375-6935(x61935)Cell:907-903-9555 david.ross ar7.servexternos.repsol.com REPJOL 2 i..- - • 0 Proposed Well Test Rig-UP Qugruk-5A .. .mix 4 4 .-— -----1—," al i * .............., j ''.e.. -,.• 11.... ----4 Pal \ ("-C- -ITS:7 ' Owl .,. , .. le'1E'!Yti 1 1 t' ,j6,, t I 1,,4( I I irit l' al 5 .N, i • III•— , > To Expro ,. ,IMP _ NI • V.-A If 111. MT— . 11 „• ! ii.y Be V.401 IM' 7•SO I'3"1 ari 4 ki 1 0., 1 MI ' Mt'5.10.4 ..- )14s, lill6i. 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II �, , to , 9•� .— II — LOCATION U`' 'sc'-.�_ 0 p -5 ( ,1 �I,,' I--1 t ! 0 0 Oti �.i. i !I REMARKS AriLit _.4Cs� 0 �, (f (�� t \ o` a5a�as . 6""v. e ," 04/‘ i a o ! r �t ��;/ ;, / 0 0 4 �K o o`' \' p al ' ' k-"k' / 0 0 000 c' ,00_,,,,,,..-__=�' . / / 00 0 '/ G y .' o ilEME copy' / ///,./ (1.:1) - / 4+14,;„,- _. ...; 000 , N �� - 000 A �- 0p8 / . *-, r _. 000 6 ti , T — 000 \ \ �.,% >--�� _ o002V_ �,r 0£ • Qugruk #5A Daily Operations Summary REPl4L API: 50-103-20682-01-00 Permit#: 214-032 Rig: Nabors 105AC CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 28 March 2014 TD:8015'; Mud Weight: 10.4 Brine; POOH LD scraper assy. RU tbg tongs, RIH 0' w/31/2TC-11 tbg. RIH w/210 jts 3Y 9.3 ppf TC-II tbg to 6779'. POOH& rack tbg back in derrick. Build Expro Tank Berm. Install rig mats. 29 March 2014 TD:8015'; Mud Weight: 10.4 Brine; Cont POOH racking back 334"tbg in 0' derrick.Chg out 332"tbg elev to 4" side door elev. PU&test Metrol tools to 500 psi low—S min—OK&5000 psi hi—15 min—OK. RU WL&RIH w/USIT logging tool to 7845' (TOC above 6500' MD). RD WL. P/U additinional 3%2"9.3 ppf TC-II tubing. RD tbg tongs. 30 March 2014 TD: 8015'; Mud Weight: 10.4 Brine; Slip&cut DL. RD pipe shed for CT 0' placement. Prep to test BOPs.Abandon rig drill. Cont RU BOPs.Test BOPs 250/3500 psi on annular; 250/5000 psi on rest of components. RD test eqpt. Pull test plug&install WB.Cont RU completion eqpt.Build berms. 31 March 2014 TD: 8015'; Mud Weight: 10.4; Brine; Cont setting mats&RU completion eqpt. 0' PU& RIH w/DST&TCP assy. PU lower TCP assy. PU 2-7/8"tbg&fill disc assy. MU pkr to jt of 2-7/8"tbg& RIH w/same to 1213'. Cont RIH w/332"tbg f/ derrick to 5140'—fill every std w/ 10.4 ppg Brine.Test tbg every±1100'to 4000 psi—5 min—on chart. 01 April 2014 TD:8015'; Mud Weight: 10.4 Brine; Cont RIH w/332"tbg f/derrick to 7620'— 0' fill every std w/10.4 pgp Brine. RU SIB e-line set TCP on depth (top @ 7682' & btm @ 7687'). RD SLB e-line. Space out. MU hgr/landing jt.Set pkr&land completion string.Test hgr&seals 250/5000 psi—10 min—OK.Test lines to 4500 psi.Test pkr(7"x 31/2"annulus)w/4000 psi—15 min—OK. Bled off press & RD test eqpt. Back out landing jt& LD same. Install BPV in tbg hgr. RD handling tools&clear f/floor. 02 April 2014 TD:8015'; Mud Weight: 10.4 Brine; ND BOPE. Disconnect control lines, 0' choke/kill lines.Split BOPE below double ram section. NOTE:Submitted 24hr notice of upcoming CT/BOPE test to AOGCC @ 19:50hrs 04APR2014. NU frac tree. NU swab& master valve assy. Pressure test bonnet to 5000 psi—10 min— OK.Test master&2nd master to 7500 psi—10 min. Install hard lines to tree.Set BOPE f/CT. MU riser f/CT BOPE. Install 6' section of riser on tree. NU BOPE& secure same.Tie in rig HCR Koomey lines to hyd master vlv on tree. Function test same. 03 April 2014 TD:8015'; Mud Weight: 10.4 Brine; Test HES CT to 6900 psi.Test Expro lines 0' to 3000 psi. Test HES annulus line to 3000 psi. Fire guns. Perform 20 DFIT. Shut in well &wait 12hrs for DFIT test results. Test Frac lines to 6900 psi, Pump 200,000 U's 20/40 carbolite w/linear gel at a max rate of 22 BPM and max STP • • of 5155 psi.Average STP was 3531 psi.Shut well in and monitor wellhead for 15 min,open well bleed off to 1500 psi. NOTE: AOGCC Rep,Jeff Turkington, waived witness of BOP/CT test @ 20:54hrs 02Apr2014. • • PTO 2J4--03Z Ferguson, Victoria L (DOA) From: quick, michael (ext) <michael.quick@servexternos.repsol.com> Sent: Tuesday, April 01, 2014 11:28 AM To: ross, david (ext); Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA); Bettis, Patricia K (DOA);flynn, tim (ext) Subject: RE: Repsol Qugruk 5A, PTD 214-032 Follow Up Flag: Follow up Flag Status: Completed Victoria— Per our discussion,there is an adapter flange between the 10k Frac tree and the 5k well head tubing bonnet that has a VG-42 seal ring, and the adapter flange is rated to 10k, giving the frac tree and 3-1/2"tubing string ID a working pressure rating of 10,000 psi. The burst of the 3-1/2" L80 tubing is 10,160 psi, and we will hold 2500 psi on the tubing by casing annulus during the stimulation. Regards, Mike From: quick, michael (ext) Sent: Tuesday, April 01, 2014 10:04 AM To: ross, david (ext); 'Schwartz, Guy L(DOA)' Cc: 'Ferguson, Victoria L (DOA)'; 'Bettis, Patricia K (DOA)'; flynn, tim (ext) Subject: RE: Repsol Qugruk 5A, PTD 214-032 Victoria— Following up on your phone call,attached is the Frac Tree schematic, and a pad layout showing the Frac equipment. The pressure ratings of the frac equipment hard lines that we will be pumping through is 10,000 psi working pressure, 4", 1002 hard line. The max treating pressure for the stimulation is 6,000 psi,and the pressure relief valves are set at 6,000 psi. Please let me know if you need any additional information. Regards, Mike From: quick, michael (ext) Sent: Tuesday, April 01, 2014 7:54 AM To: ross, david (ext); Schwartz, Guy L(DOA) Cc: Ferguson, Victoria L (DOA); Bettis, Patricia K(DOA); flynn, tim (ext) Subject: RE: Repsol Qugruk 5A, PTD 214-032 Victoria _. 1 r I will be dropping off the copies of t•undry to your office this morning. • Operations are moving ahead per plan, and we request a verbal approval of this Sundry by the close of business today, if the full Sundry approval is not granted by then. Please let us know if you need any additional information as you review the Sundry. We have an oil transfer agreement in place with Savant for all produced oil. The oil will be strapped in the tank before and after loading into the vacuum truck to ensure the correct volumes are transferred to Savant. Custody transfer will take place when delivered to Savant. I will ask to see you when I drop the Sundry off at the front desk this morning. Regards, Mike From: ross, david (ext) Sent: Monday, March 31, 2014 7:33 AM To: Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA); Bettis, Patricia K (DOA); flynn, tim (ext); quick, michael (ext) Subject: RE: Repsol Qugruk 5A, PTD 214-032 Guy, My apology, I forgot to include the well test P&ID's and schematics which are now included in the attached document. Let me know if there is any additional information you require at your earliest convenience. Regards, David Ross Sr.Completion Engineer / Repsol E&P USA Inc. 3800 Centerpoint Dr Ste 400 l Anchorage,AK 99503 j Tel:907-375-6935(x61935)Cell:907-903-9555 david.rosst servexternos.repsol.com REPJOL Original Message From:Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, March 31, 2014 4:02 AM To: quick, michael (ext) Cc: Ferguson,Victoria L(DOA); Bettis, Patricia K(DOA); ross, david (ext);flynn,tim (ext) Subject: Re: Repsol Qugruk 5A, PTD 214-032 Mike, 2 r � Please provide a schematic of the site equipment . Flare location,tanks, pip1and surface safety valve positions etc Guy Sent from my iPhone >On Mar 30, 2014, at 9:16 PM, "quick, michael (ext)"<michael.quick@servexternos.repsol.com>wrote: >Guy/Victoria/Patricia— > Please see the attached document for the Sundry for the well stimulation and well test of the Repsol Qugruk 5A exploration well, PTD 214-032. > Please let us know if there are any questions or deficiencies. >We will likely be ready to start the stimulation operations late on Tuesday,4/1,if operations go as planned. > I will have a paper copy delivered to the AOGCC on Tuesday AM,when your office re-opens. >Thanks in advance, > Mike > From:Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] >Sent:Sunday, March 30, 2014 10:55 AM >To: quick, michael (ext) >Cc: Bettis, Patricia K(DOA); ross,david (ext); flynn,tim (ext) >Subject: Re: Repsol Qugruk 5A, PTD 214-032 >Submit it electronically to myself, Patricia and Victoria . I should >be able to review it online. >Guy >Sent from my iPhone >On Mar 30,2014,at 7:40 AM, "quick, michael (ext)" <michael.quick@servexternos.repsol.com<mailto:michael.quick@servexternos.repsol.com»wrote: >Guy— > >Since you are going to be out of the office this coming week, and the AOGCC office is closed on Monday, 3/31, I am asking for guidance on our operation plans for Qugruk 5A, PTD 214-032. >We have the 7" casing cemented per our approved program,and ran the USIT(cement evaluation)wireline log Saturday, 3/29. >We will have the completed Sundry 10-403 ready to submit on Monday, 3/31,for the well stimulation and well testing operations planned. We will be ready to start the well stimulation work on Wednesday,4/2. 3 > If we submit the Sundry when yoffice opens on Tuesday,4/1,will we be alto expect to start operations as planned on 4/2? Or can we submit the Sundry electronically tomorrow, Monday 3/31,to give the AOGCC more time to review? > Please advise on how to submit this Sundry for well stimulation and testing that best meets the AOGCC review needs. >Regards, > Mike ><image001.gif> > Michael Quick ><image002.gif> ><image003.gif><http://www.repsol.com/> >Alaska D&C Operations Team Lead > Repsol E&P USA, Inc. >3800 Centerpoint Dr.Suite 400 >Anchorage,AK 99503 >Tel.: 907 375 6933 /Cel: 907 317 2969 >michael.quick@servexternos.repsol.com<mailto:michael.quick@servexterno >s.repsol.com> ><image004.gif> ><Qugruk No 5A Completion 10-403 Form & Information.pdf> 4 7'fr= ti OF 77.4, • OP P. \I %y tVTHE STATE Alaska Oil and Gas O `� (� � . �� ,• .` 9 k# t� C ince v,ne ��, .� f G._. 333 West Seventh Avenue t GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 Bill Hardham Operations Manager Q 3 Repsol E&P USA, Inc. 3800 Centerpoint Drive, Suite 400 Anchorage, AK 99503 Re: Wildcat Field, Wildcat Pool, Qugruk No. 5A Sundry Number: 314-199 Dear Mr. Hardham: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner sem" DATED this I day of April, 2014. Encl. . RECEIVED • STATE OF ALASKA i APR 01 20 4 ALASKA OIL AND GAS CONSERVATION COMMISSION p 4,1; i -- APPLICATION FOR SUNDRY APPROVALS AO 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations Perforate Q Pull Tubing❑ Time Extension ❑ vcPflttil- Operations Shutdown❑ Re-enter Susp.Well❑ fi Aetvr timulate 0 Alter Casing❑ Other: Well 7'051" Q 2.Operator Name: '4.Current Well Class: 5.Permit to Drill Number: vcF 4/r/rf REPSOL E&P USA Inc. Exploratory ❑✓ Development ❑ 214-032 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: ,2 3800 Ceneterpoint Dr.Suite 400,Anchorage,AK,99503 50 , 103-20682-01-00 t►u 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Qugruk No. 5A Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation(Lease Number): 10. Field/Pool(s): 391452 Wildcat 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8,015' 7,010' 7,864' 6,887' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 101 101 3,060 1,500 Surface 9-5/8" 2305' 2305' 6,870 4,760 Intermediate Production 7" 7992' 6989' 7,240 5,410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7660'-7,665' 6,724'-6,728' 3-1/2" L-80 7,581' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"Champ IV Service Packer,No SSSV Packer 7,540'MD,6,628'TVD 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑✓ Stratigraphic❑ Development❑ Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 2-Apr-14 Commencing Operations: Oil Q Gas ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael Quick/375-6933 Email michael.quick@servexternos.repsol.com Printed Name ill Hardham Title Operations Manager • Signature Phone Date 907-375-6917 3/31/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity El BOP Test Er Mechanical Integrity Test ElLocation Clearance ❑ Other: 1,6/3 ./--&- 1 ✓�/ to r35DD psi RBDA44 MAY 10 2014 Spacing Exception Required? Yes ❑ No [ ] Subsequent Form Required: �0 - qT C q- pp y4 ,' / APPROVED BY �� A roved b : COMMISSIONER THE COMMISSION Date: �1 �' 111---��,, -114 lei!111/approval. Submit Fomi and Form 10-403(Revised 10/2012) ApproaaRit ori tt fr 1 months from the dat o ppr va nn Attachments in Duplicate 1t/= 3/1/14- R V ivHL c `'7/ (11 7 • RECEIVED March 31, 2014 APR 1 2uv OOGCG Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: 10-403 Sundry for Well Stimulation and Well Testing Operations: Repsol Qugruk 5A PTD 214-032 Dear Commissioner: Repsol hereby submits an Application for Sundry Approvals for the perforation, stimulation and well testing operations in Qugruk 5A, permit to drill 214-032. Qugruk 5A was spudded 2/1/2014, and a total depth of 8,015' was reached on 3/21/2014. The stimulation and testing procedure is attached with the form 10-403 sundry application. Pertinent information attached to this application includes the following: 1. Form 10-403 Application for Sundry Approvals—2 copies 2. Completion, Stimulation and Well Testing Procedure 3. Proposed Completion Schematic 4. Casing and Tubing Design Cases 5. 7" Casing Cementing Details, Pressure Test, and US1T log 6. Completion Fluid Summary 7. Stimulation Design Summary 8. Produced Fluid Plan 9. Well Testing Surface Equipment Layouts The AOGCC is requested to treat as confidential all information included. If you have any questions or require additional information,please contact Bob Jones, Drilling Manager at 281-863-1618, myself at 907-375-6917, or the technical contacts contained in the following pages. Sincerely, Bill Hardham Operations Manager Repsol USA • • Table of Contents 1. Completion Overview 2 2. Completion Summary 2 3. Completion Specifics 3 4. Well Information 4 5. Operations Sequence &Time Estimate 5 6. Proposed Completion Schematic 6 7. WeIICat Design Limit Information 7 8. 7" Production Cement Job Performed 3-24-14 9 9. 7" Casing Test Performed 3-26-14 to 4,000 psi with 10.4 ppg Brine 9 10. USIT Log Performed 3-29-14 10 11. Fluid Summary 13 12. Frac Design Summary 13 13. Produced Oil Plan 14 • 1. Completion Overview The Qugruk-5 was the first operation to begin drilling for Repsol on the North Slope during the 2013-14 Exploration season. Two wellbores were originally planned to be drilled, the Qugruk-5 pilot hole (Q5) and the Qugruk-5 Sidetrack #1 (Q5 ST1). The execution of the Qugruk-5 completion and well testing operation was dependent on the successful discovery of the Nuiqsut 200 reservoir in the 19.8° pilot hole (Q5) and that the minimum pay criteria of 25' had been met. As a result of encountering an unexpected hydrocarbon bearing reservoir directly above the primary Nuiqsut 200 target, the ability to isolate and fracture stimulate the Nuiqsut 200 in the pilot hole was compromised. A management of change was executed to drill the Q-5A sidetrack to the north with and azimuth of 355.9° and a maximum inclination of 36.9° resulting in a 3,186' departure from the original pilot hole. After successfully drilling the Q-5A sidetrack it was determined that the unexpected hydrocarbon bearing reservoir encountered in the pilot hole was not present in the Q-5A sidetrack and as a result the decision was made to proceed with the fracture stimulation and production test of the Nuiqsut 200 in the Q-5A wellbore. Due to the minimal time remaining the tertiary objective of the Q-5 program, to drill a 6-1/8" open hole sidetrack from the Q5 pilot hole in an effort to convey an FMI log for formation evaluation >' purposes has been eliminated from the program. The completion and testing operations were originally allocated 22 days on the drilling schedule which included installing the DST/TCP completion string and a 10K frac tree prior to performing a single stage fracture stimulation treatment, flow testing the well and performing a series of pressure build up tests. The actual time available for these operations is expected to be less than the allocated time and will ultimately be controlled by the operational efficiency achieved and the planned end of testing operations date of April 18, 2013. 2. Completion Summary The Qugruk-5A completion has been designed to minimize the amount of time required to move from rig operations to the stimulation and testing operations. The portion of the 3-1/2" completion string above the 10K psi service packer will be equipped with acoustic controlled downhole surveillance and sampling equipment in addition to a series of annular pressure controlled test valves. Tubing conveyed perforating equipment and guns will be installed below the service packer which will permit landing the completion string and installing a 10K frac tree prior to perforating the well. The frac tree will be installed under the rig floor which will enable the fracturing treatment to be performed without the need to move the rig off the hole in addition to eliminating the need for a tree isolation device. The frac tree design will also allow for the rig up of coiled tubing or wireline on the rig floor without the need to rig down the frac tree and flowback lines. After rigging up the flowback and frac lines to the tree, pressure will be applied to the tubing in order to detonate the guns at which time the spent guns will be dropped in the rat hole and the well will be ready to perform a Diagnostic Fracture Injection Test (DFIT). The pressure decline following the DFIT will be analyzed to determine the formation Closure Stress, Reservoir Pressure and kH. The derived values for these key modeling parameters will then be used to optimize the single stage hydraulic fracture design. The completion test string will permit the pumping of the fracturing treatment through the string while providing surface read out of the bottom hole pressure and temperatures via multiple downhole gauges. Following the fracture treatment the well will be opened to flow directly through the well testing equipment. Once the well has cleaned up sufficiently a flow test will be performed during which the acoustic controlled triggers on the downhole sample tubes can be activated at will, in order to collect downhole fluid samples for future PVT analysis. The test valves incorporated in the string will _ provide downhole shut-in points for shutting in the well at the start of the build-up phase in order to minimize the wellbore storage effect and allow for more precise reservoir analysis. Following the flow test the well will be killed with completion brine and the test valves can be cycled closed to serve as downhole mechanical barriers prior to removing the frac tree and re-installing the rig BOPs. Following a successful BOP test the completion string will be pulled and laid down prior to abandonment and sidetrack operations. 3. Completion Specifics After setting the service packer and landing the tubing hanger the following procedures will be performed; 1. Pressures test the annulus with 10.4 ppg completion brine to 4,000 psi for 10 minutes and chart same. 2. Bleed the annulus pressure to 0 psi. 3. Pressure test the production tubing and casing below the packer to 2,000 psi for 10 minutes/ and chart same. (Time delayed firing head will be pinned to detonate @ 4,000 psi) 4. Bleed the tubing pressure to 0 psi followed by bleeding the annulus to 0 psi. 5. Test the hanger seals to 250 psi for 5 minutes and 5,000 psi for 10 minutes. As per the schematic there will be two sets of surface read out gauges on the completion DST string. There will also be two downhole sample collectors. The gauges and sample carriers have the ability to communicate with the surface via acoustic signals. Acoustic receivers will be strategically placed in the string to boost the acoustic signals. (4) 600 cc sample tubes will be conveyed in the sample carriers which can be triggered to open independently by unique acoustic signals. Down hole samples will be captured during the absolute open flow potential test. An LPR-N test valve will be run in the string to act as a downhole shut-in point to minimize the wellbore storage during the build-up test. 4. Well Information 4.1. Basic Well Data Well Number: Qugruk-5A Well Type: Oil Producer Final Depth: 8,015' MD / 7,010' TVD AFE Number: NS 13 001 WBS Number: SA31.43.E1405 Permit to Drill Number: 213-192 API Number: -103-20682-00-00 7 ' Estimated Completion Start Date: March 25, 2014 Rig Name: Nabors 105 Pad Elevation: 15' Estimated RKB-MSL: 35' Surface Co-ordinates: 1,380.2 FSL, 3,141.4 FEL, SEC 24, T12N, R6E, UM KOP: 2,350' TD Co-ordinates: 4,504 FSL, 3,425 FEL, SEC 24, T12N, R6E, UM TD MD 8,015' TD TVD 7,009' Maximum Inclination 36.9° 4.2. Reservoir Data Reservoir Name: Nuiqsut 200 Estimated Reservoir Pressure: 3,162 - 3,522 psi Reservoir Pressure Gradient: 0.48 - 0.53 psi/ft Estimated Reservoir Temperature: 168°F Estimated PWF: 2,000-3,000 psi Crude API Gravity: 19-26° Estimated Bubble Point Pressure: 2,000 - 2,200 psi H2S Content: 0% CO2 Content: 0.1 Estimated Production Rate: 100-500 BOPD Reservoir Depth: 7,628' MD, 6,700' TVD i • 5. Operations Sequence & Time Estimate P10 P50 P90 Days Days Days 1 Wellbore Cleanout Trip(WBCT) 0.5 0.5 0.6 2 TOH and rack back the DP 0.3 0.3 0.4 3 P/U tubing, make into stands and rack back in the derrick 0.5 0.6 0.7 4 BOP Test 0.5 0.5 0.6 5 P/U and TIH with DST&TCP string 0.7 0.8 0.9 6 R/U E-Line and RIH to correlate TCP depth, R/D E-line 0.7 0.8 0.9 7 Space Out,Set Packer, Land DST string and test casing to 4,000 and tubing to 2,000 psi 0.3 0.3 0.4 8 N/D BOPs and N/U Tree and CT Riser and Test Same 0.6 0.7 0.8 9 R/U Frac and Well Test lines to Tree and P/T same 0.7 0.8 0.9 10 Open well, cycle DST valves, apply tubing pressure and TCP perforate 0.2 0.3 0.3 11 Perform a DFIT test 0.1 0.1 0.1 12 Analyze DFIT and Finalize Frac Design 0.5 0.6 0.7 13 Pump the single stage frac 0.1 0.1 0.1 14 Wait for Frac Fluid to Break 0.5 0.5 0.6 15 (CONTINGENCY) CT Fill Clean Out 1.4 1.5 1.9 16 Test cycle the OMNI & LPR-N Valve to ensure functionality 0.2 0.2 0.2 17 R/U CT to start N2 lift 0.7 0.8 0.9 18 (CONTINGENCY) Rig up Pulsonix tool and RIH to jet the OMNI & LPR-N valves 0.3 0.3 0.4 19 Change nozzle and RIH to+/- 1,500'and start N2 lift 1.8 2.0 2.5 20 (CONTINGENCY) R/U slick-line and RIH to Install DHSIT 0.5 0.5 0.6 21 Flow Test Well 4.5 5.0 6.3 22 Close LPR-N, OMNI or DHSIT and perform BU Test 4.5 5.0 6.3 23 (CONTINGENCY) RIH with slick-line and retrieve DHSIT 0.5 0.5 0.6 24 Perform Absolute Open Flow Test 0.7 0.8 0.9 25 Bullhead completion brine down tubing 0.2 0.3 0.3 26 Flow check the well 0.0 0.0 0.1 27 Close LPR-N and/or OMNI Valve and P/T to 3,000 psi from above 0.1 0.1 0.2 28 (CONTINGENCY) RIH with slick-line and install PX plug 0.5 0.5 0.6 29 Install BPV in tubing hanger 0.1 0.1 0.1 30 N/D the Frac Tree and N/U the BOPs 0.5 0.6 0.7 31 BOP Test 0.5 0.5 0.6 32 (CONTINGENCY) RIH with slick-line and retrieve PX plug, R/D slick-line 0.3 0.3 0.4 33 Cycle open the OMNI Valve to circulating position 0.2 0.2 0.2 34 (CONTINGENCY) RIH with slick-line and punch tubing 0.5 0.5 0.6 35 Pull DST string and L/D jewelry and rack back tubing 0.5 0.6 0.7 Totals w/Contingencies 24 27 34 Totals w/o Contingencies 23 22 33 • • 6. Proposed Completion Schematic 1I1 .: • • J -4--- 26"Hole I11 1 20"131#J•66 Conductor @ 'f +/-101'MD/TVD • 1 Rig 105 RKB: 20' :1 Q 5 Elevation w/ Pad Thickness: 15' /t-12-%s""Hole KB to MSL: 35' I :I :I :I 1 :I 1 1.11iiiiiii:4— 9-6/8"47#L-80 BTC Casing @ +/-2306'MD I I ••••\'.;\ \;: • \ \''; %,r DV Collar @+/-2800' MD \ \'• \ \ \\% ;\ 7"26#L-80 BTC Casing \ \ \.. \ \ \ \ • i .,\ \ \ \: ';\ \ \ \•; %\\ Nanushuk @ \ \ \ .. •;\ \\ \-4— h 1e \\\, / %..\ Q6A Inclination 36.9° Pilot Hole Inclination Through Pay 19.8° \ \ \••, TOC Stage 1+/-6600'MD \ :N \% t\ \. ::\ \^% .\ .\:::::::_\ 3 K"X Profile '• :,\ \ \••. •;.\ (2)SRO Test %, Gauges `•••-'•••:•: Annular Pressure Cycled ' ' \ (4)SRO Test Circulation Valve1 1 Gauges ••• \ Annular Pressure Cycled ,'r' ��; 7"x 3 1/:"Service Packer @+/-7690'MD \:::::: :\ , . \ \:;:;: : ! Test Valve •.� 2 ' Nuiqsut @ DH Sample Carrier(s) \••'" .,\ 200 +/-7628'MD, \•-.:. -•.\ w/(2)600 cc sample tubes \`..° •••\ TD @+/-7430'MD \::::••-'• PBTD 7,864'MD\\,, • .y L 7",26 lb/ft Shoe @ 7,992'MD Hole Depth TD @ 8016'MD • • 7. WellCat Design Limit Information Minimum Safety Factor(Abs)Under Load Conditions 7"Production Casing Casing OD Weight Grade Connection R2 7" 26 lb/ft L-80 BTC-M ID DRIFT ID Burst psi Collapse psi Axial Lbf 6.276 6.151 7240 5410 519000 Min SF Depth MD Load Case Flag Triaxial 1.348 20.7 FSO N Burst 1.234 20.7 ESO Collapse 1.544 7405 EV Axial 2.499 2800 FSO Nomenclature Load Case Description Load Case Details FSO Frac Screen Out 6000 psi casing press w/brine,200 psi annulus EV Evacuation 100%Brine Evaculation,Ann.Mud and Set Cement Gradient Nomenclature Flag Description N Negative Bending Desi n Limits- 7"Production Casin.-Section 1 -OD 7"-Wei ht 26.000• f-Grade L-80 10000 • • Initial Conditions 8000 ..... ...............;...............,...,......;,........_.............. ............ ........_.,...,.._... ...... , ._.............,.. ..............,,..,.... ,_......... 'CasingEvacuation Burst1.100Triaxial 1250 .60 Tension 10•Displacement i,--,' ......_....... ......:..........._.........................._...._....i........................._i._. ....... :....._ 'Ga Kick 6000-........................... .. ,1.....__............-' _ Gas! ':1.`-1- A GreenCementTest =• 4000 ............................._...._......._...._r.................................... ...._......._......................_. ..........,........... ►� . i •PressureTest y ,, .!• A LostReturnsWithWater a, Compression 1.000 - o_ ..a........_.......................... ...._......._i.......... ii; •' ......_�._....,...........,..........' LostReturnswtthMud 2000 ..._.............._... : •s•- a iJ 1 •TubingLeak c i . ^1 •CleanUp i �4.-t-',...-_-. DST I ►Fr > 2000_....................._>........ ._.............;..._.........._..._,...,;............._......_.................., 7. ac I I .r FracSO kg i ►R W -4000 ......................__..... .................;............ ..._._........................._`...,...........,..........! .....,.......... _ ._........... ningln ole Run H i -6000 ..........................Collapse 1:000. ..................f....._..... ............... ._............................._._......_....._.._......._ .............._.........._.... ..._..._._... • 8000 Note:Limits are approximate I I 1 I I I I I 1 -750000 -600000 -450000 -300000 -150000 0 150000 300000 450000 600000 750000 Axial Force(lbf) • 0 Minimum Safety Factor(Abs)Under Load Conditions 3-1/2"Production Tubing Casing OD Weight Grade Connection R2 3-1/2" 9.3 L-80 TC-I I ID DRIFT ID Burst psi Collapse psi Axial Lbf 2.992 2.867 10160 10530 207220 Min SF Depth MD Load Case Flag Triaxial 1.591 7590 FSO N Burst 2.362 7590 FSO Collapse 3.929 7590 CU Axial 1.681 20.7 OP Nomenclature Load Case Description Load Case Details FSO Frac Screenout 6000 psi tbg press,10.88 ppg frac slurry,2500 psi annulus press CU Clean Up Gas Lift from 1500',2000 annulus press,300 psi FTP OP Overpull 70000 lbf with 10.2 ppg brine Nomenclature Flag Description N Negative Bending Desi•n Limits -3-1/2"Production Tu bine -Section -OD 3-1/2"-We ht 9.300 ••f-Grade L-80 12000 • Initial Conditions Connection Burst 1.100axial 1.250 Tension 1.60( • Frac 8625- . • FracSO Qa•Cleanup ..............................................._:.........._.......................... 2 .______•_____,.._, ' • DST T\7,--•7. S—' •PressureTest • 1875 .. . ! • Compression 1.000 �Yg� —••-• ,A—A—♦ Overpull .2 -1500- :•—r"."• O -4875 1- a a> rs -8250-...................... .., W -11625- Collapse 1.000 Note:Limits are approximate -15000 I I I I I I I -250000 -187500 -125000 -62500 0 62500 125000 187500 250000 A>dal Force(lbf) • • 8. 7" Production Cement Job Performed 3-24-14 16:00 18:30 2.50 PR1 04 12A P CMT STAGE 1: PUMP 29.4 BELS 11.5 PPG TUNED SPACER.LOAD TOP AND BTM PLUG. RELEASE BTM PLUG.PUMP 51.2 BELS(250 SX)15.8 PPG CMT(YIELD 1.15 CU FT'SX). RELEASE TOP PLUG.DISPLACE CMT AS FOLLOWS:PUMP 5 BBLS WATER TO FLUSH LINES.RIG PUMP 296 BELS 10.4 PPG MUD&BUMP PLUG WITH 1834 PSI.(EST TOC 5900')BLEED OFF PRESSURE&FLOATS HELD.RIG PRESSURE UP CASING TO 3160 PSI TO OPEN DV-TOOL PORTS. NOTE:100%RETURNS THROUGH OUT JOB. 18:30 0:00 5.50 PR1 04 12A P CIRCULATE THROUGH DV-TOOL PORTS @ 200 GPM&550 PSI.NO CMT TO SURFACE, 0:00 0:30 0.50 PR1 04 12A P PJSM.RU HALLIBURTON CEMENT EQUIPMENT FOR STAGE 2.TEST ALL LINES TO 3.000 PSI. 0:30 3:00 2.50 PR1 04 12A P CMT STAGE 2:LOAD TOP AND ETM PLUG.PUMP 30.9 BELS 11.5 PPG TUNED SPACER. RELEASE BTM PLUG.PUMP 74.6 BELS(169 SX)12.0 PPG CMT(YIELD 2.48 CU FT%SX). RELEASE TOP PLUG.DISPLACE CMT AS FOLLOWS:PUMP 5 BELS WATER TO FLUSH LINES.RIG PUMP 102 BELS 10.4 PPG MUD&BUMP PLUG AT 450 PSI.RIG PRESSURE UP TO 1787 PSI TO CLOSE Dy-TOOL.BLEED OFF PRESSURE&FLOATS HELD. NOTE:100%RETURNS THROUGH OUT JOB.7 EELS OF CEMENT RETURNS. 9. 7" Casing Test Performed 3-26-14 to 4,000 psi with 10.4 ppg Brine G I �0 -- < ! *� pc�_ • X47`P.0 �� I I 8.-----0 0,, re .n ,-.o 9 o 4 I f t k, '_^^, -4.� I ' �.� \ .q 1 '‘ -`"" 0L i-T �4 k SA Gari��t�Sf 4 y __.4000-- / \ y �/_. .. \ .. / IAS'- �. _-- , ,. QUO-_ ,.. • • 10. USIT Log Performed 3-29-14 ERAV IR AV ERAV_RH Fl IRAV_LI If1 IRAV IRA ,--; Data not LHF1 ERA '‘T -. . ... . . selected q (CS) nun IRAV 0 2000 External Radii Extemal Radii ft/ll Average Average (ERAV) (ERAV) Casing USIT-E USIT-E Collar 3.8 in 2.7 2.7 in 3.8 Locator Ultrasonic Internal Internal Acoustic (CCLU) Radius Radius Impedance USIT-E Averaged Averaged Minimum -20 in 20 Value(IRAV) Value(IRAV) (AIMN) USIT-E USIT-E USIT-E Gamma 3.8 in 2.7 2.7 in 3.8 0 Mrayl 10 Ray + + +Internal Internal Acoustic EDTC-B C-B Radius Radius Impedance L B R U 0 150 Maximum Maximum I I Average Orientation:Top of (AIAV)R B L gAPI Value(IRMX) Value(IRMX) U ( ) ! g $ o0 1 USIT-E USIT-E Orientation:Top of USIT-E 8 m In Stuck Tool `I H Bonded Indicator, 3.8 in 2.7 2.7 in 3.8 a9 �e S i, .1 0 Mrayl 10 • "i O r N e, ? N 0 n Total Intern,' tenial • Acoustic 'as Custom Normalization (STIT) Radiu Radius . 111111111111M Impedance 0 ft 50 Minima'' Minimum Custom Normalization Maximum Liquid USIT Acoustic Impedance -,-� .clue(1Rr lalue(IRMN: (AIMX) With Micro debonding Image USIT c USIT-E USIT-Acoustic Impedance USIT-E (Al_MDEBOND_IMG) -CableDra (AIBK)USIT-E Micro-deborr. USIT-E g. . z ''. in '7 in 3,: (Mrayl) n Mriyt 1C din. Mra I 730q' I I 7310 I �S '" b. 7320 5• V 7330 -, - ;-.1 } it 7340 k e 5 . ; f 1 t ` 735b , . Y I 7360 it r 7370 'A7380 7390 s- d .. • • M , i CLU ,,,.. 1Fy,AV RAV `_. AIAV 7430 . - - _....Aim4 E i 540 ' r 7aso -s . «o4-,'' r...,ff + 1 p .�.,, 74.80 I t zoo .r �sr i . '"' .i- fi750 . a I -.51 7530 ,! ; Air", 7540 I .. „" 755, - - y r i::,::.:.. '... ,':' 1;7' t / 5: 1, „......_ . . .., , ,, ' l''' - ' x� 1• j w 7560 r - ,� .. s• W .r^ 4,1:41:: 7570. �, r t i. j TT 7590` -1 ➢f. *? .. ,., . <._ F.77- ,. 7590 .. •A i ..., .::,.......... 7601 [ # it 761• .•.. ' - ',� i. # 1, •. 762 F: 76 0 t. i ..., , +. .1. /•44 114'.':..w.TQC_�, ' >,wi .._ $:�.. c Ali . • • Intended perf interval 7,660'-7,665' MD 7- 1 _ Irtk. I 1 ./''R— R P.1 X R' .: ,;,. .�,,,_, .,., _ _ .4-4' : �....-44,- CCCl .ii ,RAV RA; ' ,....,, il j'4 . . '•�"+.,.� _11.¢yr'-i� t: 9 # f �, #: ir Mil 7.' e Ars _ _ B I rir... / — µye r --- ` - ....i' ma4'1M'a.•—» 10 't,',.-,•._......'...": .„1,..:-..r..1 i i 77 0 ' .:'.'' ',.:::::Y:. tit it - . ,41.. 14 ,...4 L , ' L!/. 1 c 14 144 73U;' t � t t, f �. t 774 . r - 77 M ir` t }///� i 1 77\" .' ,4 7770 t - .- j$�, *x . rj',a'aar' . P',:, ,yu;. ,., a 778 7790 I '•.' I . �` m. a f tr 7810 e.. art ''` :, R'' 7830 '. i' s 4° * 4 ;..a. i s * Y +n » 7840 I - �,va 4` ye - • • 11. Fluid Summary Operation Fluid Components Density Pressure Tests LVT-200 N/A 6.88 ppg DFIT Test Naar/NaCl/KCI 37.1 ppb NaBr+71.7 ppb NaCl+22 ppb KCI 10.4 ppg Brine Frac Fluid Linear Gel Seawater+25.0 ppt WG-36+0.5 gpt Claweb+ 1.0 8.55 ppg gpt LoSurf+4.0 gpt Optiflo-II+3.0 ppt SP Clean Out Fluid Sea Water N/A 8.55 ppg 12. Frac Design Summary Based on the Geomechanical Study generated from the di-pole sonic and density log information in addition to the pore pressure estimates,the following mechanical properties log was created in the zone of interest. - - 1 :.I 1111i I : MIM 111111111111111111111 ■IIII■� I �7;=3, 0;` . I I : III 1111111111` 111111111 111{i- III 1111111111 1111111111 1 I .11111111111111111 -1111 6600 '�� Al , ' 111 . 11 �� 1111111111111-�:1 E , I ..i: =:ai O t �� ' l i i 1 , :.;.I�3....11. 1I11.=rli1 _ . ' I _ lig= ;111, iiiilli iiilli 11 r- ! , i I ' . II 1911i1111111111PEE s,� t� ! =_ , � 1111 � ' i 11�=! a1::111 �1'■11 11 -`- 11111 ,_ -- - i111r iIui 1111111 ,” .111.11...,■.... ...... I ,_1 II 1111411111111111111 h 1 ; ; 1111 i II11110111111111111111 ► ! I t l �� 'R+r,lt'��11 'i�1" 'i�1 1 1 ' -� * !t a cluil - - `-=1111111 111111- I _mob p i 1 ,. I' I I + ; I i 11111111111111 i1 -.I _ l , III 111 ! 111111111111i ll illi I ' ` . 1 111 � 1111111111111111 __= Hill. 1111' ' I_ i � ; ; '_I I `!IIIIIlI 111111_ �) 20.0 8000 ^.JI 4S _ ID 01 as I 050 110 GR gAPI R I ohm m i !.., RHOB g/cm3 S�.`Dec ".0 010 020 ;t-,t.,,,rf;, PHIE Dec • • The final frac design will be based on information obtained from the diagnostic fracture injection test, however, the tentative design will be based on the following schedule Surface Pump Schedule 25 ppt Linear Gel, 200K lbs of 20-40 Carbo-Lite, Perf Depth 7660'-7665' MD Slurry Fluid Proppant Rate Fluid Prop Cum Pump Volume Volume Concentration (PPG) Proppant Time (M-Gal) (M-Gal) Start End (BPM) Type Type (M-Lbs) (min) 8.00 8.00 0.00 0.00 20.00 Linear Gel 20-40 CL 0.0 9.5 12.00 11.49 1.00 1.00 20.00 Linear Gel 20-40 CL 11.5 14.3 15.00 13.78 2.00 2.00 20.00 Linear Gel 20-40 CL 39.0 17.9 16.00 14.12 3.00 3.00 20.00 Linear Gel 20-40 CL 81.4 19.0 16.00 13.59 4.00 4.00 20.00 Linear Gel 20-40 CL 135.8 19.0 16.00 13.10 5.00 5.00 20.00 Linear Gel 20-40 CL 201.3 19.0 0.25 0.25 0.0 0.0 20.00 LVT-200 201.3 0.3 Total Slurry 83.2 Total Fluid 74.3 Total Proppant 201.3 Avg.Conc 2.7 Total Pump Time 99.1 min Pad % 9.6 13. Produced Oil Plan Repsol has executed an agreement with Savant Alaska LLC.To sell all of the produced oil from the Qugruk 2013-2014 exploration program. Oil will be transported to Deadhorse where the custody transfer will take place. • • 0 >' „ oN et cc —) coN >- z z 0 o av .c-- UJ Z Nm LL > V) c < LU > < cc cc JL7 0 Cc L- O I-- CS -._- LL M I L Q c LU 0 ,N Z 0 O d N 00 D a. ` CS c o- w Ir- H F-O= Q \u e•�6 v w w z rn 7 e r. �Ln 3ix0 3 a N O F' a i O O I 7 L i O L Of n r • r`s L' ` z tT. W .,---- tits 1%, r 2.- 0 '),, \1VN 2. [ V`. iR�, in CO z ti Z R O1 N kj cv o F� / tV O�f,Q O, 6 LII 1-- 4 ___r.: y C a \� X60. cc IUUO / Z r Q N M M J CC (V O s -J u- N P] / W O O O O y r' ,z F z z o c� a O z 0 Z lL O OU O O p _,,tc!!.. .... p11 M S Z 0 N J/ Le$ N 1r pW Z O �2 Q U < H O _Iip V m H 41 Q = U OU J OQ U�ePC°A,�fc+ >Q O wwz 0 o� Z (1)O Lai ZO wE v, 8w U Y V) w. 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' -."EE 3,c o o ' Yr � � 130.3• 3.1502 PO• 2.1502 (111.s") ov i43.&) 4-1/1e•10M J 4^k • ~o 0 4-1/18.10M 1 41/16"5M r I 89 �� 13-5/8"511 Is -�e81 1 MN 21/15N 8F1WSNillim 13.5/8 SM IIE1�80 , _ 9-5/8"PACXOFF 11 ■ j 38+ 2aT 1T 1.11 9-5/0"C56 NOR All I 65.9" llEre �I� 9-S/8"XT'RED -e, ' OA {Ol /.2-1/3P5M L13-5/8"SM ! ' 46.6" l 13-3/8'FLUTED MANDREL HANGER 19.5' a.r ill, 133 /6"X 9-S/8"RED 1 lc 'u-) %t 1120"OD C56 9-5/8"OD C5G 7..OD C5G 3-1/2 OD 1130 ALL DIMENSIONS ARE APPROXIMATE This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved in writing, REPSOL-Q5 neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. FRAC ASSEMBLY 20" X 9-5/8" X 7" X 4-1/2" X 3-1/2" 10M Multibowl Assembly, DRAWN CR 30DEC13 AP With MB-242 Tubing Hanger and K Tubing Bonnet FOR R F KN 30DEC13 FOR REFERENCE ONLY DRAWING NO. SDM-4001-1 • • Option t Option 2 Preferred 1.77 1000.3 200' 0 � 800 �� 160' r ton' s 0 0 N70°22'35.97" W150°30'19.07" r oa ► II N70°22'34.25" 00lit W150°30'32.78SlIS ytt‘ a♦ ♦ R*PAD • 01 \IP's4 �l • _....111....r \------- v:: 00\ottolfr.ss•Cs J SN 11 00. \S 1111 1 til AA t 0i0011 S t ca 0. n O N70°22'31.37" W150°30'13.96" 116 x.„---- „ ,,, .,,,,, eio, 561 *It - N70°22.29.65” W150°30'27.66" i • Ferguson, Victoria L (DOA) From: quick, michael (ext) <michael.quick@servexternos.repsol.com> Sent: Tuesday, April 01, 2014 11:28 AM To: ross, david (ext); Schwartz, Guy L(DOA) Cc: Ferguson,Victoria L(DOA); Bettis, Patricia K(DOA);flynn,tim (ext) Subject: RE: Repsol Qugruk 5A, PTD 214-032 Victoria— Per our discussion,there is an adapter flange between the 10k Frac tree and the 5k well head tubing bonnet that has a VG-42 seal ring, and the adapter flange is rated to 10k,giving the frac tree and 3-1/2"tubing string ID a working pressure rating of 10,000 psi. The burst of the 3-1/2" L80 tubing is 10,160 psi, and we will hold 2500 psi on the tubing by casing annulus during the stimulation. Regards, Mike From: quick, michael (ext) Sent: Tuesday, April 01, 2014 10:04 AM To: ross, david (ext); 'Schwartz, Guy L (DOA)' Cc: 'Ferguson, Victoria L (DOA)'; 'Bettis, Patricia K (DOA)'; flynn, tim (ext) Subject: RE: Repsol Qugruk 5A, PTD 214-032 Victoria— Following up on your phone call, attached is the Frac Tree schematic, and a pad layout showing the Frac equipment. The pressure ratings of the frac equipment hard lines that we will be pumping through is 10,000 psi working pressure, 4", 1002 hard line. The max treating pressure for the stimulation is 6,000 psi, and the pressure relief valves are set at 6,000 psi. Please let me know if you need any additional information. Regards, Mike From: quick, michael (ext) Sent: Tuesday, April 01, 2014 7:54 AM To: ross, david (ext); Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA); Bettis, Patricia K (DOA); flynn, tim (ext) Subject: RE: Repsol Qugruk 5A, PTD 214-032 Victoria— I will be dropping off the copies of this Sundry to your office this morning. 1 Operations are moving ahead per plan, and we request a verbal approval of this Sundry by the close of business today, if the full Sundry approval is not granted by then. Please let us know if you need any additional information as you review the Sundry. We have an oil transfer agreement in place with Savant for all produced oil. The oil will be strapped in the tank before and after loading into the vacuum truck to ensure the correct volumes are transferred to Savant. Custody transfer will take place when delivered to Savant. I will ask to see you when I drop the Sundry off at the front desk this morning. Regards, Mike From: ross, david (ext) Sent: Monday, March 31, 2014 7:33 AM To: Schwartz, Guy L(DOA) Cc: Ferguson, Victoria L(DOA); Bettis, Patricia K (DOA); flynn, tim (ext); quick, michael (ext) Subject: RE: Repsol Qugruk 5A, PTD 214-032 Guy, My apology, I forgot to include the well test P&ID's and schematics which are now included in the attached document. Let me know if there is any additional information you require at your earliest convenience. Regards, David Ross Sr.Completion Engineer Repsol E&P USA Inc. 3800 Centerpoint Dr Ste 400 Anchorage,AK 99503 �I Tel:907-375-6935(x61935)Cell:907-903-9555 david.rossaservexternos.repsol.com REPJOL Original Message From:Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, March 31, 2014 4:02 AM To:quick, michael (ext) Cc: Ferguson,Victoria L(DOA); Bettis, Patricia K(DOA); ross, david (ext);flynn,tim (ext) Subject: Re: Repsol Qugruk 5A, PTD 214-032 Mike, Please provide a schematic of the surface equipment . Flare location,tanks, piping and surface safety valve positions etc 2 • • Guy Sent from my iPhone >On Mar 30, 2014, at 9:16 PM, "quick, michael (ext)"<michael.quick@servexternos.repsol.com>wrote: >Guy/Victoria/ Patricia— > Please see the attached document for the Sundry for the well stimulation and well test of the Repsol Qugruk 5A exploration well, PTD 214-032. > Please let us know if there are any questions or deficiencies. >We will likely be ready to start the stimulation operations late on Tuesday,4/1, if operations go as planned. > I will have a paper copy delivered to the AOGCC on Tuesday AM,when your office re-opens. >Thanks in advance, > Mike > From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] >Sent: Sunday, March 30, 2014 10:55 AM >To: quick, michael (ext) >Cc: Bettis, Patricia K(DOA); ross, david (ext);flynn,tim (ext) >Subject: Re: Repsol Qugruk 5A, PTD 214-032 >Submit it electronically to myself, Patricia and Victoria . I should > be able to review it online. >Guy >Sent from my iPhone >On Mar 30, 2014, at 7:40 AM, "quick, michael (ext)" <michael.quick@servexternos.repsol.com<mailto:michael.quick@servexternos.repsol.com>>wrote: >Guy— > >Since you are going to be out of the office this coming week, and the AOGCC office is closed on Monday,3/31, I am asking for guidance on our operation plans for Qugruk 5A, PTD 214-032. >We have the 7" casing cemented per our approved program,and ran the USIT(cement evaluation)wireline log Saturday, 3/29. >We will have the completed Sundry 10-403 ready to submit on Monday, 3/31,for the well stimulation and well testing operations planned. We will be ready to start the well stimulation work on Wednesday,4/2. > If we submit the Sundry when your office opens on Tuesday,4/1,will we be able to expect to start operations as planned on 4/2? Or can we submit the Sundry electronically tomorrow, Monday 3/31,to give the AOGCC more time to review? 3 > Please advise on how to submit this Sundry for well stimulation and testing thatestmeets the AOGCC review needs. >Regards, >Mike ><image001.gif> > Michael Quick ><image002.gif> ><image003.gif><http://www.repsol.com/> >Alaska D&C Operations Team Lead > Repsol E&P USA, Inc. >3800 Centerpoint Dr. Suite 400 >Anchorage,AK 99503 >Tel.: 907 375 6933 /Cel: 907 317 2969 > michael.quick@servexternos.repsol.com<mailto:michael.quick@servexterno >s.repsol.com> ><image004.gif> ><Qugruk No 5A Completion 10-403 Form & Information.pdf> 4 • Qugruk #5A Daily Operations Summary REPlOL API: 50-103-20682-01-00Permit #: 214-032 Rig: Nabors 105AC CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 21 March 2014 TD:8015'; Mud Weight: 10.7;Viscosity: 100; Wash down to 8015'MD. Circ 0' BU. POOH & LD BHA. RU WL& RIH w/WL run#1A(FT-Scanner-Density- N e ut ro n-P P C-M S I P-PPC-G R). 22 March 2014 TD: 8015'; Mud Weight: 10.6; Viscosity: 99; Cont TIH w/WL run#1A. POOH. 0' LD run#1A tools. PU run#1B tools& RIH w/same. Log f/shoe to 8000'. Log 8000'to shoe. LD run#1B tools& RD WL eqpt. NOTE: Notified AOGCC Rep, Lou Grimaldi,of upcoming BOPE test at 08:30hrs. 23 March 2014 TD:8015'; Mud Weight: 10.5;Viscosity: 103; Finish RD WL eqpt. Clean floor. 0' LD 6" DC&jars. Chg upper rams 4"to 7". NOTE: Permission granted by AOGCC Rep, Lou Grimaldi,to test the annular w/the HCRS&csg rams w/ inside manuals to permitted pressures then run 7" csg prior to a full BOPE test. RU to test BOPE.Test annular, HCR, Manuals&7" rams to 250/3500 psi—5 min—OK. Blow down chk& kill lines.Chg out bails. RU csg tools. RIH w/7" 26# L-80 BTC csg. NOTE:Sent formal BOPE test notification @ 05:00hrs requested by AOGCC Rep, Lou Gramaldi. 24 March 2014 TD:8015'; Mud Weight: 10.4;Viscosity: 98; Cont RIH w/7" 26#L-80 csg to 0' 7841'.Wash down to 8003'. C&C. Land 7" @ 7992'MD/6992'TVD. RU cmt eqpt. Test all lines to 5000 psi. Pump cmt stage#1: 29.4 bbls 11.5 ppg Tuned Spacer; 51.2 bbls (250 sx) 15.8 ppg cmt(yld=1.15cuft/sx). Displace cmt w/5 bbls water to flush lines. Pump 296 bbls 10.4 ppg mud & bump plug w/1834 psi (est TOC @ 5900'). Floats held. Pressure up csg to 3160 psi to open DV-tool ports. NOTE: 100% returns throughout job. Circ through DV-tool ports—no cmt to surface. 25 March 2014 TD:8015'; Mud Weight: 10.4;Viscosity: 95; RU cmt eqpt for stage 2.Test all 0' lines to 3000 psi. Pump cmt stage#2: 30.9 bbls 11.5 ppg Tuned Spacer; 74.6 bbls (169 sx) 12.0 ppg cmt (yld=2.48cuft/sx). Displace cmt w/5 bbls wtr to flush lines. Pump 102 bbls 10.4 ppg mud & bump plug w/450 psi. Pressure up to 1787 psi to close DV-tool. Floats held. NOTE: 100% returns throughout job— 7 bbls of cmt returns. RD cmt eqpt. Back out& LD landing jt.Wash BOP stack w/wash tool. Install pack-off&test same. NOTE: AOGCC Rep,John Crisp, waived witness of BOPE Test @ 18:10hrs. RD csg tools. Chg out bails& rams. clean pits.Test annular 250/3500 psi.Test BOPE 250/5000 psi. Pull test jt& test plug. Install WB& lockdown same. 26 March 2014 TD:8015'; Mud Weight: 10.4;Viscosity: 95; Chg elev& LD 3%2"TC-II stinger. 0' RD csg running eqpt. Chg elev. FINAL REPORT FOR DRILLING PHASE. • • BEGIN COMPLETION PHASE: MU 6-1/8"cleanout BHA&RIH to 2777'. Drill DV tool 2808'-2811'.Circ hole clean. RIH to 7844&tag cmt. Drill cmt 7844'-7855'. Circ BU—some cmt returns. RU eqpt&test 7" csg to 4000 psi—30 min—OK. RD testing eqpt. Short trip 7855'-7460'. Prep to displace mud to 10.4 ppg completion brine. i i 27 March 2014 TD:8015'; Brine Weight: 10.4;Viscosity: 27; Cont short trip 7460'-5961'.TIH 0' 5961'-7855'.C&C hole. Begin to displace to 10.4 ppg completion brine. Pump 70 bbls of hi vis spacer. Pump 800 bbls of fresh wtr. Remove 270 bbls of MOBM. • S RECEIVED ANRIG MAR 26 2014 AOGCC Samples from: Qugruk 5A y-cp Z 14_O3 2- Repsol Repsol E&P USA Inc. API No. 50-103-20682-01-00 North Slope Borough,Alaska 4 (0 SAMPLE MANIFEST Set#3: Dried Cuttings Samples 3/21/2014 From: Canrig Drilling Technology 301 E. 92nd Ave. Anchorage AK 99515 To: AOGCC Attn: Howard Oakland (907) 793-1235 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501 Set#3: Shipment consists of 1 box containing 5 sample trays: (50)Dried Cuttings Samples on 30ft intervals, 2320' —3820' (50)Dried Cuttings Samples on 30ft intervals, 3820' —5320' (50)Dried Cuttings Samples on 30ft intervals, 5320' —6820' (50) Dried Cuttings Samples on 30ft and 10ft intervals, 6820' —7560' (25) Dried Cuttings Samples on 30ft and l Oft intervals, 7560' —8015' This has been shipped as 1 box. Total weight: 14 lbs. 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N U (n n) i-? w 0.0E0 x X OZ Q • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, March 21, 2014 11:14 AM To: 'flynn, tim (ext)' Cc: quick, michael (ext); Bettis, Patricia K (DOA) Subject: RE: Qugruk 5A (PTD 214-032) 7" casing cement Tim, Thanks for coming over to go review the OH logs for Q-5A. Based on the OH data the KUP C is not hydrocarbon bearing . You have approval to modify the cementing program for the 7"casing as per the below changes outlined in your email. 1. New TOC will be 6500' and in stage 1 2. Stage collar will be at 2800' and and cement will be brought to surface. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: flynn, tim (ext) [mailto:tim.flynn@servexternos.repsol.com] Sent: Friday, March 21, 2014 8:36 AM To: Schwartz, Guy L (DOA) Cc: quick, michael (ext) Subject: Qugruk 5A (PTD 214-032) 7" casing cement Guy We are currently at TD of Qugruk 5A at 8015' MD. We are planning to run the 7" casing and cement in 2 stages. As per our original permit (214-032)TOC of cement of the first stage was planned to be 5800' MD to cover the KUP C if it had commercial hydrocarbon. Based on the LWD logs,the Kup C is non reservoir. We would like to change the estimated TOC from 5800' MD to 6500' MD. Having TOC at 6500'MD satisfy's the regulation of having at least 500' MD of cement above any planned fracture interval. The planned fracture will occur through perforations at 7700'MD. Also, based on no commercial hydrocarbons being present above 3000' MD in Qugruk 5A, we would like to move the stage collar from 3500' MD up to 2800' MD. This will allow for cement to be pumped to surface on the second stage and alleviate the need to shoot holes in the casing for final abandonment. Stage 1 original planned cement volume w/TOC at 5800'MD: 57.1 bbls 15.8 ppg class G Stage 1 updated planned cement volume w/TOC at 6500' MD: 51 bbls 15.8 ppg class G cement 1 • • • Stage 2 original planned stage tool at 3500' MD/TOC @ 1800`MD):46.2 bbls 12.0 ppg Type 1/2 cement Stage 2 updated planned cement volume w/cement to surface: 75 bbls 12.0 ppg Type 1/2 cement Thank you / Tim Flynn Senior Drilling Engineer Repsol E&P USA, Inc. iiila Tel.:907 375 6934 /Cel:907 317 5504 tim.flynn(@servexternos.repsol.com REPJ OL • 2 • • i CON . _NTIAL Qugruk#5A Proposed Schematic vomilillr P-f • 03 Z REPlOL 1 , 3 1 t-- 26"Hole I • , I , • I 20"131#J-55 Conductor @ 41 +/-101'MD/TVD Rig 105 RKB: 20' Q 5 Elevation w/ Pad Thickness: 15' .4--12-1/4""Hole KB to MSL: 35' I I I I Top of Cement:1800'MD I I I I ® I-4— 9-5/8"47#L-80 BTC Casing @ +/-2305'MD \ • V A v A DV Collar @+/-2800' MD f mac-✓ G,--r-. "t \ \ \'• \ \ \ \ \%, '••„\ 7"26#L-80 BTC Casing \ \ \ \ \ \ \\ \. \\\ \ \ \'"• ''•;\ Nanushuk @ \ \ \\ \\ \\\. ;\\\ \` \ •. \ \\ \''•. ••; Q5A Inclination 36.9° Pilot Hole Inclination Through Pay 19.8° \\ \\ \+. \\ • \ TOC Stage 1+/-6500'MD \ \ \"'•• ' \ Kup C @+/-7077'MD \ \ \ •• •:,\ (Non Reservior) \ \ \ \ \a\ \ \ \; ..\ \ \ \ \ Alpine @+-7505'MD, (Non Reservoir) \ \ \ \•. \ \-4--8'/z"open hole--O .• '' \ \ \ \ '*N\ Nui 200 @+/-7616'MD, \ \ \.\ \ \ \ \ \\ \ Nuiqsut 100 @+/-7815'MD \ \ TD @+/-7430'MD \ \ :Casing Depth TD @+/-8015'MD Hole Depth TD®+/-8015'MD Revised D.Ross 3-5-2014 54 C • • • Qugruk #5A Daily Operations Summary REPrOL API: 50-103-20682-01-00 Permit #: 214-032 Rig: Nabors 105AC CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 15 March 2014 TD:2430'; Mud Weight: 10.4;Viscosity: 78; Drlg 2369'-2430'. POOH LD mud 0' motor. MU bit& rotary steerable/LWD BHA. RIH to 2181'.Shallow test LWD— OK.Test BOPE 250/3500 psi—5 min—OK.Attempt to test upper rams— pressure up to 3800 psi—ram failed. Pull & rebuild rams w/new rubbers. NOTE:All tests witnessed by AOGCC Rep,Jeff Turkington. 16 March 2014 TD: 2720'; Mud Weight: 10.45;Viscosity: 86; Retest upper rams to 250/5000 290' psi.Test BOPE 250/5000 psi. Attempt to test lower rams—pressure up to 1800 psi—ram failed. NOTE: Lower pipe ram test waived witness by AOGCC Rep, Jeff Turkington. Chg out lower pipe ram rubber seals& bonnet seals. Retest lower pip rams 250/5000 psi.Test good. RIH. Drlg 2430'—2720'. 17 March 2014 TD:4018'; Mud Weight: 10.4;Viscosity: 86; Drlg 2720'—3825'.Clean screen 1298' on mud pump#1. Circ. DrIg 3825'—3874'.Circ.Drlg 3874'—4018'.Take survey. Circ BU.Chk f/flow. POOH to 2285'for short trip. 18 March 2014 TD:5655'; Mud Weight: 10.4;Viscosity: 78; TIH 2285'—4018',stage pump up 1637' &circ BU. Drlg 4018'—5655'. Service top drive. 19 March 2014 TD:7329'; Mud Weight: 10.65;Viscosity: 99; Drlg 5655'-7329'. 1674' 20 March 2014 TD:8015'; Mud Weight: 10.65;Viscosity: 95; Drlg 7329'—7636' MD.Chg 686' swab in Pump#1. Drl 7636'—8015' MD.Section TD. Circulate and condition hole,Short trip F/8015'to 2283'MD. Cir BU,TIH to TD. • • Qugruk #5A Daily Operations Summary REPrO! API: 50-103-20682-01-00 Permit #: 214-032 Rig: Nabors 105AC CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity MOVE TO ST OPS ON QUGRUK-5A WELLBORE 09:30hrs 11 March 2014 TD: 2130'; Mud Weight: 10.6;Viscosity:74 Transfer mud to vertical tanks. 0' Clean mud pits. PU KO BHA#1 to 2070' while continue to clean mud pits. 12 March 2014 TD: 2130'; Mud Weight: 10.6;Viscosity: 74; Cont to clean mud pits with vac 0' trucks&super suckers. 13 March 2014 TD: 2130'; Mud Weight: 10.4;Viscosity:90; Cont to clean mud pits with vac 0' trucks& super suckers. M&P Baraclean to flush all mud lines.Take on 805 bbls MOBM. Build berms around MOBM cutting tanks.TIH &tag cmt @ 2130'. Displace out KCL mud. RU base fluid system.Shallow test MWD tools 14 March 2014 TD:2300'; Mud Weight: 10.4;Viscosity: 90; TIH w/1 std f/derrick to 2120'. 170' (CMT PLUG FTG) Drlg cmt plug 2130'-2300'. F_- iik- Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, March 11, 2014 11:47 AM To: 'flynn, tim (ext)'; Regg, James B (DOA) Cc: JONES, ROBERT;ysa, rick(ext); dial, amanda (ext); DUFRENE, AMANDA; quick, michael (ext) Subject: RE: Change to from WBM to OBM on Qugruk 5 PTDG3Z Q_ 5A 2/4_0k9 Tim, As per our phone call please send me the revised Mud program ... I will file this our folder for the well. Change to OBM is approved. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: flynn, tim (ext) [mailto:tim.fly, servexternos.reDsol.cor ] Sent: Tuesday, March 11, 2014 8:36 AM To: Schwartz, Guy L(DOA); Regg, James B (DOA) Cc: JONES, ROBERT; ysa, rick (ext); dial, amanda (ext); DUFRENE, AMANDA; quick, michael (ext) Subject: Change to from WBM to OBM on Qugruk 5 PTD 314-129 Guy,Jim This is to follow up with the message I have left you. We will be planning to swap the mud system on Qugruk 5A(PTD 314-129)from a WBM to a mineral oil base mud system. When I received the revised mud program , I will forward is on. There is no plans to change mud weight that has already been permitted. Thank you Tim Flynn Senior Drilling Engineer Repsol E&P USA, Inc. l MOW , Tel.:907 375 6934 /Cel:907 317 5504 ' tim.fiynnservexternos.repsoi.com REP.1OL 1 i • 032 rrD 02/9" lalh REPJOL HALLIBURTON DRILLING FLUIDS PROGRAM Operator:Repsol USA Well Name: Qugruk-5A MOBM Location:Alaska Version 1.0 Prepared by Mr. Chris Okland Technical Professional Christopher.Okland(d Halliburton.com Office-907-275-2612 Cell-907-350-2847 Author/Owner Approver Approvers Name: Chris Okland Chris MacKinnon Tim Flynn Title: Tech Proff. Operations Lead ODE Date: March 10,2014 March 10,2014 Signature: HALLIBURTON et amicl . • HALLIBURTON Gar'ca mow REPJOL Qugruk-5A ver 1.0 Prudhoe Bay AK/U.S.A. Mud Program Distribution Name Position Document Version Date Tim Flynn Repsol ODE 1.0 3/11/14 Chris Mackinnon Halliburton Ops Leader 1.0 3/10/14 The table above will serve as a record of distribution control for the approved program,both hard copy and electonic copies shall be logged into the abocc table. Program Amendment and MOC Record Version.# Date Author Description MOC Document number The table above will serve as a record of ammendments submitted for the well. The Management of Change(MOC)process must be followed for changes made to the drilling fluids program after the spud date. Well Data provided bvRepsol Data Provided Document Identifier Date Received Used in Preparation of this Halliburton Program Y/N Approver Scope of work Queruk-5A ver 1 3-5-14 Y ('.Okland Scope Change Documentation No Scope Changes to date Well Data Operator Repsol USA Well No. Qugruk-5A Field/Block Colville River Delta PBU Location Alaska/U.S.A Well Type Exploration Max. Well Inclination 37 Maximum Expected Mud Density 10.6 Estimated Days 30 Days Anticipated BHST at Total Depth of well 165°F Baroid Project Support Team Title Name Cell Number Office Number Email address Technical Professional Chris Okland (907)350-2847 (907)275-2612 Christopher.Okland fa,Halliburton.com Operations Leader Chris Mackinnon (907)227-5045 (907)275-2617 chirs.maekinnon(lfHalliburton.com Lead Mud Eng. Lead Mud Eng. Night Mud Eng. Night Mud Eng. Stock point Manager John Jessup/Brent Edmunds (907)943-1028 (907)659-2422 lohn.JessupaHalliburton.com Brent.Edmunds@Halliburton.com 2 • HALLIBURTON vie REPJOL Qugruk-5A ver 1.0 Prudhoe Bay AK/U.S.A. _ Program Briefing Qugruk-5A will be a side track drilled off the original mother bore of Qugruk-5.The original was drilled to a TD of 7430',surface casing was set at 2305'and the rest of the wellbore was P&A'ed.with cement plugs.Qugruk 5-A will be kicking off with a cement plug set at 2350',using a MOBM drilling fluid weighted to 10.4ppg,and weighted up to a 10.6 ppg 500'before the HRZ.Directionally drill hole section to a TD of 8065'.BHA will be tripped in the hole to the top of the cement plug and the mud will be swapped over using the provided spacer train procedure.Condition mud for wireline fonnation evaluation logs.This section will be P&Aed as per the AOGCC regulations. Well Design Summary Hole Size Casing/Tubing Inc.(deg) Feet Drilled Mud Density Interval (in) Size(in) TD(ft) TVD(ft) Maxud System ax (ft) (ppg) Name 12.25" 9 5/8" 2,305 2,305 0 2,305 Bentonite 9.8-10.0 Surface Spud Mud 8.5" NA 8065' 7047' 37 5715' MOBM 10.4-10.6 Production Quj'ruk 5A 8.5"Sidetrack Casing Size (in) End Depth(ft) NA 8065 Drilling Fluid 10.4-10.6MOBM System ppg. LVT 200,INVERMUL NT,EZ MUL NT,GELTONE V,Lime,DURATONE HT,BARABLOK Main Products ,Calcium Chloride,BAROID 41,BARACARB 5 Recommended Shakers:165+mesh screens,screen up as solids loading on screens diminishes Solids Control Mud Cleaner:3/8"cone orifice.Centrifuge:As necessary to balance MW and LGS buildup Mud Engineer will utilize the solids control unit at all times. Bad displacement Maximize pump rate and pipe rotation,use spacers Potential Problems Lost Circulation Solutions Have excess LCM products available on location Sticky Clay Walnut to alleviate bit balling and shaker blinding Interval Objectives Drill 6 1/8""hole to 8065',run wireline formation evaluation logs. Pump abandonment plugs to P&A. Restricted None Products 3 • • HALLIBL,ATON VIIPF REPIOL Qugruk-5A ver 1.0 Prudhoe Bay AK/U.S.A. Ougrul:5A ST.1 Fluid Target Properties Inlcrcii I•luid:A1013\1 Mud MD Weight Viscosity PV YP HTHP WPS ES 2350'-8065' 10.4 50-80 10-25 18 �5 250- 5511 10.6 25 270K Ougruk 5A ST.1 Fluid Formulation Product Concentration LVT 0.662 bbl Water .172 bbl INVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 10.4ppg(as needed) BARABLOK 2 ppb BAROTROL Plus 4 ppb Special Mixing Instructions: • Mix in order as listed Displacement Procedure Recommendation Spacer Formulations: • Pump 50 bbl.of brine treated to a>40 YP with BARAZAN D+,weighted to a 10.4ppg off a Vac truck. • 25 bbl.of the MOBM treated with GELTONE to a YP>40. • Follow with the ENVIROMUL mud system. Displacement procedure: • Monitor pump strokes to obtain correct displacement. • Maintain maximum pump rates. • Have the bit on bottom as the oil mud exits the bit. • Reciprocate the drill string by one joint every 15 minutes • Rotate the pipe as rapidly as allowed during the actual displacement(>60 RPM) • Do not shut down the pumps during the displacement. • Use an E.S. meter at the flow line to determine when the fluid is water free enough to start taking the returns back into the system.An ES of 200-400 should be sufficient to indicate when displacement is complete.A retort should also be run at this time • to confirm fluid quality. • Clean possum belly and any troughs which were used to transport water base fluid. Interval Operations Summary • Drill ahead maintaining all product concentrations while adding dilution fluid. • Add 3-5 ppb Walnut as background LCM/bit scouring method to help prevent bit balling caused by sticky clays.Utilize the Well Commander circ sub to spot LCM • Maximize the usage of all solids control equipment,screen up where possible and run the centrifuge to minimize LGS and maintain correct MW. • Add BAROTROL+for shale stabilization.Weight up to10.6ppg 500'before the HRZ at 5883'TVD.10.6ppg is the minimum MW requirement to TD. • Utilize LVT 200 for rig site dilution if LGS begin to rise above the recommended<6.5%. • Maintain>500 gpm pump rate while drilling ahead. Utilize DFG 5.4 every 12 Hrs.while drilling for real-time modeling of hole cleaning abilities. Adjust fluid rheology,pipe rotation(RPM)and ROP based on the ability to clean the hole. • Should lubricants be required,add 1-2%NXS-Lube.Call town prior to going over 2%. 4 . • • HALLIBURTDN REPJOL Qugruk-5A ver 1.0 Prudhoe Bay AKLJ .SJA,. Well Concerns • Follow all REPSOL Halliburton processes and Procedures • Truck Usage Volumes-Track the truck utilization volumes using the TFM spreadsheet. CH2Mhill trucks are maximized at 90%of their carrying capacity for every load hauled,and less when heavy fluids are hauled. Attempt to load Vac trucks and Super Suckers to their 90%maximum volume,always taking rig time into account while anticipating trucking wait times. Give logistics dispatchers>24 hours advance notice prior to jobs requiring multiple trucks on location. • Hole Cleaning—Run DEG 5.4 every 12 Hrs.while drilling to monitor hole cleaning capabilities using real time ROP,RPM and pump rates.The continual loading of drill solids into the mud system will change the rheological properties of the mud. Utilize all solids control equipment.Be prepared to dilute by means of water or whole mud to diminish the effects of the drill solids.Utilize real-time PWD for hole cleaning and sweep recommendations. • Lost Returns—A full compliment of LCM contingency products will be available on location should losses occur. • Well Control—Rig hands and Mud Engineers both,shall constantly be aware of mud density measurements,trip volumes and pit volumes to ensure good well control practices are followed. ROP/Pump Rates Rhcologs,rotation and pump rate are critical factors in cleaning this deviated wellbore. Consider the following practices if hole cleaning becomes an issue: • Extended periods of circulation(with maximum pump rate and pipe rotation). • Hole cleaning sweeps(change flow regime of base mud by using mud density or rheology for carrying capacity). • Connection practices-employing extended gpm,rpm and back reaming,prior to the connection. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 500 550 600 80-rpm 180 220 25O 100-rpm 220 270 300 120 rpm 250 275 310 Calculated using 3%maximum cuttings load Calculated ECD's*550 GPM and 100 RPM Depth(MD) Mud wt. Clean hole Max ECD(2.5%cuttings ECD load) 2350' 10.4 10.7 11.0 4500' 10.4 10.7 11.0 5500' 10.4 10.7 11.0 5500' 10.6 10.7 11.2 6500' 10.6 10.7 11.2 7405' 10.6 10.7 11.2 5 • • HALLIBURTC3N REPJOL Qugruk-5A ver 1.0 Prudhoe Bay AK I U.S.A. SCE Recommendations Shakers • Multiple,High-G,linear motion shale shakers are recoinmended in order to maximize the system solids control removal efficiency.Run all available solids control equipment to prevent solids build-up. >200 mesh screens should be achievable for this pilot hole section. • All shale shakers should be"screened up"with finer mesh screens whenever possible without the loss of any drilling fluid off the end of the shakers. • The shale shakers should be continuously monitored for the proper distribution of drilling fluid across the screens to fully utilize the entire surface area of the screens. The drilling fluid should cover+3/4 of the entire screen length. • Damaged screens should be promptly changed and noted on the daily mud report screen usage column. • If near size particle blinding occurs,an attempt should be made to"screen-up"to alleviate this problem. If"screening-up"does not solve this situation,then coarser mesh screens must be installed until past this formation. Mud Cleaner • It is recommended to use a mud cleaner to accomplish the maximum removal of drill solids.The oriface should be as small as possible while utilizing the mud cleaner for this purpose.This will maximize the drill solids removal efficiency while maintaining drilling fluid properties within the prescribed parameters specific to this area and interval formation characteristics. • Check to see that the Mud Cleaner cones are cleaned and in good operational spec prior to drilling the hole section. • Ensure head pressure to the mud cleaner cone manifold is>_35 psi. This is the minimum recommended pressure for each cone to acquire the vortex necessary to strip solids from the drilling fluid. Centrifuge • While drilling ahead,maintain LGS content and MW increases through use of the centrifuge. External Solids control • This unit will be utilized at all times,refer to the SCU document. • This rig will be equipped with a solids control unit consisting of a Mud cleaner and centrifuge,Mud engineers will work closely with the operators of this unit to maintain mud properties as directed. • This unit will also have a mix hopper and will be utilized to mix products downstream from the mud cleaner and centrifuge. 6 • • HALLIBURTON Oak Garold REP-101 Qugruk-5A ver 1.0 Prudhoe Bay AK]U.S.A. Estimated Fluid Disposal Volumes Dilution rates fir the 8.5-interval are anticipated at 0.8 bhl/fi. Production P I O P50 I'90 Initial Build 650 500 1 100 Dilution 650 900 1 100 Total 1300 1700 2200 Estimated Drill Solids Disposal Volumes Production P10 050 I'90 Cuttings Volume 400 44(1 480 Wetting Fluid 400 440 480 Total 800 880 960 Total Well Cost P10 P50 P90 Production S 481,000 S 629,000 5 814,000 Appendices • Sidetrack Hole Hydraulics • LCM Decision Trees 7 • i HA,LLIBtJRTON liggai I Baroid _ REPlO[ Qugruk-5A ver 1.0 Prudhoe Bay AK/U.S.A. Production Hole Hydraulics DrillAhead® Enviromul 2.294%Cutting Total Flow Rate=13.0 bpm RCP=180.0 fVhr 2 231%Cutting Eff Density=10.400 ppg Cutting Dia=0.150 In 1.05 h CUT time R=100%@ 180.0 ftihr•120.0 RPM/HC=80.0 RPM-1m iC=5m i U -.-ECD�x Z4 -+-Eco Mai (2 ,� i E akaa, , ail r. 5000 1 a 1145201 . l # _, i , 7500 111 _ .. 0 i 4 F H I: ro 109 9 600 I) 39 60 9*104 II 11.6 •5 0 Cutting Load Transport Eh Average V Hole Angle ECD Welt>ere (%) (%avg) (flimin) (°) (pug) (Inl 8 • • HALILIIBURTON mow REPlOt Qugruk-5A ver 1.0 Prudhoe Bay AK/U.S.A. Losses Lost Circulation Decision Tree fl Payzone Mud Systems V + Partial Seepage 20 60 bbllhr Severe Total 5.20 bbllhr Static Static 60-200 bbllhr Static >200 bbllhr Static i i Treat Active System Treat Active System + + • with 5 sx/hr Baracarb with 10 sx/hr Baracarb 60-150 bbl/hr Static 150-200 bbl/hr Static Drill Across Fault 50/150 150 + Drill Across Fault Drill Across Fault Contact Drilling Engineer or Engineer lynami on call Dynamic too ppb LCMIMud Pill: Contact Drilling Engineer Losses<15 Yes Losses<15 Yes 20 ppb Baroseal f bbllhr or Engineer on call. bbl/hr 20 ppb Baracarb 50 Consider drill ahead wl 30 ppb Barofibre 20 ppb SteelSeal seawater v No Drill Ahead Drill Ahead 10 ppb Baracarb 150 Consider drilling ahead V No without returns Increase Treatment to V 10 sx/hr Baracarb 50/ 50 ppb LCMIMud Pill: Contact Drilling Engineer or 150 Engineer"On Call". i 20 bbls Base mud Consider drill ahead w/ 10 ppb Baracarb 25 seawater 20 ppb Baracarb 50 Dynamic 20 ppb Baracarb 150 Losses<15 Yes bbl/hr Drill Ahead No v 20 ppb LCMIMud Pill: Dynamic Losses<20 Yes 20 bbls base mud bbl/hr 10 ppb Baracarb 50 Drill Ahead 10 ppb Baracarb 150 No V 1)ODE must approve any steps past PARTIAL losses. Contact the Engineer 2)Drill across fault or loss zone 1.5-2.0 times the length of the on call to determine if throw before spotting LCM pills. Dynamic 3)PBL sub should be run in BHA to spot pills if'Partial Loss'cases or Losses<15 Yes additional LCM above are anticipated prior to drilling to allow the spotting of LCM bbl/hr I treatments are to be pills. made 4) LCM pill volume=300'.600'column based upon actual hole Drill Ahead diameter. 5)PRIOR TO ANY LCM PILL,APPROPRIATE DISCUSSIONS AT No THE RIG MUST BE MADE TO MINIMIZE THE POTENTIAL FOR i i PLUGGING THE DRILL STRING. Proceed to'Partial Losses'Pill 1 9 • • I-IALLIBURTC]N Bcid REPJOL Qugruk-5A ver 1.0 Prudhoe Bay AK/U.S.A. "Festinu,at the Wellsite • During normal drilling operations one complete mud check should be run every 6 hours. This is a total of four complete checks made over a 24 hour period. Timing for mud checks and cost cut off should begin at 12:01 am each day. Unusual circumstance's and/or non circulating periods should dictate deviations from this schedule. • All rheological properties(ie.6 speed readings,LSRV and gel strengths,including 30 minute gels)will be taken at the standard 120°F unless otherwise specified. Routine Sampling • Mud samples(1 QT)should be sent in any time the need arises,ie.hole problems or lubricant problems. • Samples of the mud plant built fluids will be tested prior to shipment to the rig site and saved until the well is completed. Samples must be logged on appropriate sample tracking form. • Samples of new mud delivered to the rig site will be checked for weight and rheology at a minimum prior to offloading into the rig pits. HSE at the Wellsite Ilealth • All rig personnel should have access to current/up to date MSDS sheets and PPE required by MSDS sheets for every chilling fluid product on location.An MSDS book must be retained in the rig pits,and Mud Lab. These books will be maintained by the onsite mud engineer.Additionally quick reference PPE charts for specific products will be posted in the rig pits and the mud lab.These charts are by no means an MSDS replacement. Always read and adhere to the MSDS sheet prior to handling any drilling fluid products. • Rig Crew Pretour meetings are a good platform to discuss upcoming product mixes and HSE requirements. f:nvironmcnt • Ensure all sack products stored outside are shielded from the arctic weather with plastic or a box. • Do not store single sacks outside of a box. • Attempt to use all opened,partial sacks. • Proper planning for necessary products in the pits will diminish the"Hurry up"factor. Properly planned events create less opportunity for mishaps. 10 • • HALLIBURTON ,, Baroid REPJOL Qugruk-5A ver 1.0 Prudhoe Bay AK/U.S.A. NFPA Ratings Product Name Health Flammability Reactivity PPE :Vdacide(; 0 respirator,rubber gloves,rubber apron,chemical goggles.face shield °" ill Dust-mist respirator,coveralls,work gloves,safety glasses BXII ABLOCK .I I 0 Baracarb 1 0 coveralls,work gloves,safely glasses Baracor 700 I _ 0 rubber gloves,chemical goggles,coveralls Bara Defort rn HI' I , "" 0 coveralls,rubber plot es,rubber apron,chemical goggles BaraKlean I I 0 respirator,rubber gloves.rubber apron,chemical goggles,face shield BDF-5l5 I 0 i 0 dust mask,coveralls,work gloves,safety glasses Barascas I) 2 r ' 0 dust mask,coveralls,work gloves,safety classes Baraian D+ o i i Ili 0 coveralls,work gloves,safety glasses Barofibre n n 0 coveralls,work gloves,safety glasses Baroid I 0 0 dust mask,coveralls.work gloves,safety glasses Baroseal I o ' 0 coveralls,work gloves,safety glasses Barotrol Ellis I o 0 dust mask,coveralls,work gloves,safety glasses BDP-999 I , 0 rubber gloves,rubber apron,chemical goggles.face shield Bicarbonate of soda 0 0 0 coveralls,work gloves,safety glasses CALCIUM CHLORIDE I 0 dust mist respirator,coveralls,work gloves,dust proof goggles Carbonox 0 I 0 coveralls,work gloves,safety glasses Caustic Soda 4 I I 0 respirator,rubber gloves,rubber apron,chemical goggles,face shield CFS-520 I 0 0 coveralls,rubber gloves,rubber apron,safety goggles 1 Citric Acid Anil)(Irons I 0 0 respirator,rubber gloves,rubber apron,chemical goggles,face shield Dcsco CF I 0 ' 0 coveralls,work gloves,safety glasses Dextrid LT 0 0 0 coveralls,work gloves,safety glasses Drit-N-Slide 0 0 , 0 coveralls,work gloves,safety glasses DURATONE HT ] u - 0 NIOSH certified respirator,coveralls,work gloves,safety glasses F1'Mudlube I I 0 rubber gloves,chemical goggles,coveralls EZ MILL NT _ _ 0 Organic vapor respirator,impervious rubber gloves,rubber apron,chemical goggles,face shield GELTONE\' I o 0 NIOSH certified respirator,gloves,safety glasses,coveralls Geovis XTL I I 0 dust mask,gloves,safety glasses INVERMUL NT 2 _ 0 organic vapor respirator,impervious rubber gloves,rubber apron,chemical goggles,face shield Mica fine I 0 0 coveralls,work gloves,safety glasses LIME I n 0 dust mist respirator(95%),goggles,rubber apron,impervious rubber gloves,chemical goggles L\'T-2110 0 0 organic vapor respirator,coveralls,work gloves,safety glasses N-Dril HT+ 0 0 _ 0 coveralls,work gloves,safety glasses No-Sulf 1 0 0 dust mask,coveralls,work gloves,safety glasses N-Vis 0 0 0 coveralls,work gloves,safety glasses NXS-Lube I I ,I, 0 rubber gloves,safety glasses,coveralls Sodium Bromide 2 0 0 dust mask,coveralls,work gloves,safety glasses Sodium Chloride 0 0 0 dust mask,coveralls,work gloves,safety glasses Steel Seal 1 0 0 coveralls,work gloves,safety glasses Stick-Less 20 0 0 0 dust mask,coveralls,work gloves,safety glasses Wall-Nut M 0 0 0 coveralls,work gloves,safety glasses 11 S Schwartz, Guy L (DOA) From: flynn, tim (ext) <tim.flynn@servexternos.repsol.com> Sent: Friday, March 07, 2014 1:39 PM To: Schwartz, Guy L(DOA) Subject: RE: Q-5A (PTD 214-032) Importance: High Gu', Please see updated cement volumes of 7" casing for Qugruk 5A. Stage Depth Density Yield BBL(40%OH XS) SKS Stage 1 8065'-5800' 15.8# 1.16cuft/sk 74.9 bbl 363 sks Stage 2 3500'-1800' 12.0# 2.48cuftlsk 50.7 bbl 115 sks Thank you /t Tim Flynn Senior Drilling Engineer 1 Repsol E&P USA. Inc. Tel.:907 375 6934 /Cel:907 317 5504 flynn(a�servextEr.,:,; ccs REP,IOL From: Schwartz, Guy L(DOA) [ a ilto:quy.schwartz@alaska.ci ] Sent: Friday, March 07, 2014 1:17 PM To: flynn, tim (ext) Subject: Q-5A (PTD 214-032) Can you double check your cement volumes.... For 7" both stages. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 oF • • •0-147:7:-;34:7,_ 333 Wesi Seventh A\,enue GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 1:1 Main: 907 279 1433 Bill Hardham Operations Manager Repsol USA 3800 Centerpoint Drive, Suite 400 Anchorage, AK 99503 Re: Wildcat Field, Wildcat Pool, Qugruk 5A Repsol USA Permit No: 214-032 Surface Location: 2138' FWL, 1381' FSL, SEC. 24, T12N, R16E, UM Bottomhole Location: 1849.8' FWL, 776.1' FNL, SEC. 24, T12N, R6E, UM Dear Mr. Hardham: Enclosed is the approved application for permit to drill the above referenced exploration well. All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or approvals 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the AOGCC's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P Foerster Chair DATED this 7day of March, 2014. RECEIVED STATE OF ALASKA ALAI,OIL AND GAS CONSERVATION COMMI•N MAR 0 6 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC 11a.Type of Work: 1b. Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone Q• Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑✓ • Reentry ❑ Exploratory D.. Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: Repsol USA Bond No. 22032715 • Qugruk 5A• 3.Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Dr.Suite 400 Anchorage,AK 99503 MD: 8065' TVD: . 7048 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Wildcat, Surface: 2138'FWL, 1381'FSL,Sec.24,T12N, R16E,UM ' 391452 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1875.5'FWL,993.9'FNL,Sec.24,T12N, R6E,UM • LAS 28269 3/9/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1849.8'FWL,776.1'FNL,Sec.24,T12N, R6E,UM • 2560. 3141'FEL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above . 36' feet 15.Distance to Nearest Well Open Surface: x•438058 y- 5987456 Zone- 4. GL Elevation above , 16' feet to Same Pool: NA 16.Deviated wells: Kickoff depth: 2350' • feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: _ 37 degrees Downhole: 3735- Surface: 3031 • 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) 8.5" 7" 26# L-80 BTC-M 8045' 0' 0' 8065' 7047' 1st stg:279 sx Lead/2nd stg:99 sx 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural 80.00 20" 38 sx Permafrost type L cement 101 101 Surface 2,305.00 9-5/8" 600 sx Perm lead,220 sx tail 2305 2305 Intermediate Production Liner Perforation Depth MD(ft): N/A Perforation Depth TVD(ft): N/A 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot ❑✓ Shallow Hazard Analysis Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program O 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Tim Flynn 907-317-5504 Contact tim.flynn @ servexternos.repsol.c Email Printed Name Bill Hardham Title Operations Manager Signature104-1.C.,--- 32.e•-4.-.-- . Phone 907-375-6917 Date 3/6/2014 Commission Use Only Permit to Drill -API API�Nilmber: Permit Approval See cover letter for other Number: cQ1 l 03z 50- /03-.206gZ--O/ -00 Date: ��7�I requirements. Conditions of approval: If box is checked, 2"well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: -W 3500 (S i. Lickd f ` C j( Samples req'd: Yes [ No❑ Mud log req'd:Yes['No❑ L3 p �� c7,12._ H2S measures: Yes [f No❑ Directional svy req'd:Yes 17.No❑ E 6 Spacing exception req'd: Yes ❑ No Lo" [✓ Inclination-only svy req'd:Yes❑ No ' K Sera. "..,.r..., Sak &Y. IAJtXX15 . I-r 6lcw !....141,v,v l yn (I APPROVED BY Approved by: / �`�-.tom COMMISSIONER. r 3-741 THE COMMISSION Date: 3-7- /el 3-7 I1 �ISu 3 I gSubmit Form and Form 10-401(r,-vised 10/2012) Thi p I'v f r t from the date of approval 20 AAC 25.005(g)) Attachments in Duplicate fly • I RECEIVED MAR 0 6 2014 AOGOO 1411.1r- REPrOL REPSOL USA Application for Permit to Drill Qugruk 5A North Slope, AK March 2014 • March 06, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Application for Permit to Drill: Repsol Qugruk 5A Dear Commissioner: Repsol hereby applies for a Permit to Drill a sidetrack, Qugruk 5A. Qugruk 5A will be a sidetrack from an already existing onshore exploratory well on the North Slope. The surface location for Qugruk 5A is located approximately 10 miles East of Conoco Phillips CD1 (Alpine) development in the Colville River Delta. Repsol plans to start drilling the sidetrack Qugruk 5A approximately March 9, 2014. Qugruk 5A sidetrack will be drilled using Nabors 105AC. The ice pad and ice road is complete and the rig is on location to drill Qugruk 5 (API 50-103-20682-00-00 &PTD 213-192) and sidetrack Qugruk 5A. A DST is planned for the sidetrack{At the completion of the drilling and testing program, the drilling rig will be demobilized to Deadhorse. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill— 2 copies 2. Well Prognosis and discussion of operational considerations 3. Location Plat and Drill Pad Layouts 4. Days vs. Depth Drilling Curve 5. Drilling Procedure 6. Wellbore Schematic 7. Directional Plot 8. Pressure information including pore pressure, mud weight and fracture gradient curves, maximum anticipated surface pressure calculations, and casing properties and design factors. 9. Drilling Area Risks 10. Cement Program 11. Drilling Fluid Program Repsol does not anticipate the presence of H2S in any formations to be encountered in / this well. However, H2S monitoring equipment will be functioning on the rig at all times during the drilling and completion operations. • S The AOGCC is requested to treat as confidential all information included in the Application for Permit to Drill as information in these documents is drawn from research and data proprietary to Repsol. If you have any questions or require additional information, please contact Bob Jones, Drilling Manager at 281-863-1618, myself at 907-375-6917. Sincerely, Bill Hardham Operations Manager Repsol USA REPSOL USA Qugruk 5A Overview and Timetable Repsol is conducting an exploration drilling program on leases operated by Repsol during the winter 2013-2014 drilling season. The drilling program will include activities beginning during the summer of 2013 and ending during the summer of 2014 including: • Construction of two rig ice pads and 1 camp pad located in the Colville River Delta in which two exploratory wells will be drilled(Qugruk#5, Qugruk#7). Another rig ice pad and camp is located in the Schrader Bluff area near DS1J pad in the Kuparuk River Unit. To enable the drilling of Tuttu#1,an ice pad will be constructed off of DS1J for staging construction and drilling operations in December or January as permitted by ADNR and the NSB. • Approximately 30 miles of onshore ice roads have been constructed as permitted by ADNR and the NSB for transporting drilling rigs and equipment for drilling operations. • Exploration drilling operations will be conducted between January to April at three separate locations using three separate drilling rigs. The wells are being drilled primarily to assess oil reserves within leases operated by Repsol. • Demobilize all equipment from the ice pad and clean up the sites and ice roads during April to early May. • Conduct summer clean up operations during July to August 2014. Operational Considerations Surface Casing Shoe Depth The 9-5/8"surface casing shoe was set at 2305' TVD while drilling Qugruk 5,located deep enough to isolate the permafrost section, shallow gravels and unconsolidated sediments and provide adequate integrity at the casing shoe to accommodate future mud weights. The first expected hydrocarbon bearing sand is the Tuluvak Sand(Tuluvak_FM) at+/-2529' SSTVD. Lost Circulation and Sloughing Shales Some of the wells in this general region encountered sloughing shales below the HRZ and lost circulation in and near their target horizons. The Qugruk 5A casing and mud programs have been designed to take these potential problems into account. Pressures Anticipated pore pressures are derived primarily from the histories of offsetting wells in conjunction with a pore pressure analysis completed using offset log data. As shown on the attached pore pressure plot and maximum anticipated surface pressure(MASP)calculations for the vertical pilot hole,the highest expected pressure is at 7,048' TVD and is 3,738 psi(0.530 psi/ft= 10.2 ppg EMW) and will result in a maximum theoretical pressure, with a full column of gas, of 3,030 psi. Due to a formation breakdown(expect 14.0 LOT at 9 5/8"casing shoe)the maximum pressure at surface will be 1,447 psi. (see included calculations). A 5,000 psi WP BOP and wellhead system will be used on this well. • Pore Pressure Review The pore pressure prediction section of this application contains an evaluation of the risk of drilling high pressure zones as potentially recognized after seismic processing. The following plot can be used as a reference for the planned mud weights compared to the expected pore pressure and fracture gradients. Q-SPH & Q-5 ST1 PP/FG Prediction Pressure ppg(EMW) 8 9 10 11 12 13 14 15 16 17 18 19 20 0 1000 --• Base Permafrost 2000 Tuluvak —CtS PH MW 31100r-i! C2 5 fracture psi —Max.Pore pressure �QSST1 MW ----Nuysul200 4000 —- --Base Permafrost �HRZSha:e —Tuluvak 5000---a- 6000 \\,s, ♦ HRZShalc -------------- • Nuiysut200 7000 WI') A gas influx on an offset well was experienced at a depth of 2500' TVD on Well Fiord#2. Mud weight was 9.2 ppg when the event occurred,BOP's were in place and the well was killed with a 9.4 ppg fluid. The mud weight was increased to 9.7 ppg and no other problems were encountered. A well control event occurred on Qugruk#2(4 miles to the Northwest) while drilling with 9.2 ppg mud at 2523' MD. The design of this well has the surface casing being set above the Tulavak and mud weight in excess of 10.2 ppg will be used to drill the production section. BOP System and BOPE Testing The BOP system of Nabors Rig 105 is rated at 5,000 psi working pressure and is described in the BOPE section of this application. Since the calculated maximum anticipated surface pressure in this well is 3,030 psi,it is planned to routinely test all BOPE to 3 500 nsi(except the annular • • BOP which will be tested to 50% of its rated working pressure(2,500 psi). BOPE will be tested every 7 days per 20 ACC 25.035. Well Deviation The Qugruk 5A wellbore will be drilled as a low angle sidetrack built to —37 degrees inclination and evaluated by open hole LWD logging. A DST is planned in the Nuiqsut formation through perforation in the 7"casing string. H2S None of the offsetting wells encountered measurable amounts of H2S in the intervals to be drilled, and it is not expect that drilling the Qugruk 5 well will encounter measurable amounts of H2S. However,the drilling rig will be wired with operating sensors,enhanced by additional sensors tied into the mud logging system,to continuously monitor for the presence of H2S. Drilling Waste Handling Waste drilling mud from the well will be temporarily stored within a bermed storage cell in tanks prior to being hauled to G&I; while the drill cuttings will be temporarily stored within a bermed storage area in"shale bin"containers. Cuttings will be hauled to an approved disposal facility for processing and disposal. Diagrams are included with this application that shows the ice pad layouts with the proposed location of the storage cells. Additional Information Additional information on operations such as formation tops,logging,mud logging,etc.can be found on the attached Qugruk 5A Well Prognosis. Certified Location Plat An as-built location plat,certified by a Registered Land Surveyor, will be submitted shortly after construction of the drilling location is completed and the conductor pipe is set. Contacts The contacts within Repsol for information are: Reporting and Technical Information: Tim Flynn 907-317-5504 or Michael Quick 907-375-6933 Geological Data and Logs: Ricard Fernandez 281-297-1058 • I REPSOL USA Qugruk SA Well Prognosis Well Name: Qugruk 5A Surface Location: 2138'FWL, 1381' FSL,Sec. 24,T12N,R6E,UM Target Location: 1875.5'FWL, 993.9'FNL, Sec. 24,T12N,R6E,UM Bottom hole location: 1849.8'FWL,776.1'FSL, Sec. 24,T12N,R6E,UM Elevation: Ground Level 16' AMSL(Includes 1' of ice) Drill Floor(DF) 20' AGL RKB: 36' Planned TD: 8065' MD/7048' TVD Formation Tops: Tops Depth(TVD) MFS 2368' T Tuluvak 2559' Nanushuk 3935' Torok 5671' HRZ 5929' KUP C 6267' Alpine 6655' Nuiqsut 6760' Cores: No core planned for this wellbore. Planned Logs: 8-1/2" Sidetrack: LWD: Gamma Ray/Resistivity,Neutron/Density Wireline: None Mud Logging: Mud Logging will be in operation from the base of the surface casing to well TD. Services will include sample collection; plotting of ROP,lithology, and drilling parameters; show description; gas analysis of cuttings;and gas chromatography!Samples will be collected every 30' from the s base of surface casing to TD, and every 5' in zones of interest. Collect Isotubes from any gas shows.The wellsite Geologist will adjust the interval or sampling rates as required. • Qugruk SA Drilling Procedure I. The Qugruk 5 well will be abandoned to+/-2300' MD/TVD. A 10-403 Sundry will be submitted for the P&A plan. Note: BOPE will remain on the well and will be tested to 250/3500 psi every 7 days. AOGCC will be notified 48 hours prior to test. 2. Make up 8-1/2"drilling BHA and RIH to top of kickoff plug at+/-2300' MD/TVD. 3. Kickoff of plug as per timed drilling sequence and directional plan. 4. Drill an 8-1/2"hole building to 37 degrees. Run and utilize MWD and LWD tools through this hole section to monitor hole angle and to collect logging data. 5. Hole —37 degrees to+/- 8065' MD/7048' TVD. 6. Condition the hole for running 7"casing. 7. Install casing rams and test. 8. Run 7"casing. 9. Pump first stage of cement job. 10. Pressure up to function stage tool for second cement job,pump second stage slurry. A"( eL11. Test 7"casing to 3000 psi for 30 min. Record test. 12. R/U wireline and log with USIT in 7"casing. / 13. Completion plan through the DST will be covered in aaarate work plan. 7 14. P&A well per AOGCC regulations approved 10-403 Sundry. 15. RDMOB • Qugruk 5A Pressure Calculations and Drilling Risks Maximum Anticipated Surface Pressure: Pilot Hole The maximum anticipated surface pressure (MASP) for this well will be the higher of the formation pore pressure(less a full gas column to the surface) at TD or the formation fracture pressure at the last casing shoe(less a full gas column to the surface). The MASP expected in the 8-1/2"hole section is 3,738 psi at a depth of 7,048' TVD (or 0.530 psi/ft less 0.1 psi/ft gas gradient). Predicted fracture gradient data for this area based on offset log data,at 2,305' TVD, the depth of the 9-5/8"casing shoe,is 0.728 psi/ft(14.0 ppg). Complete evacuation of the wellbore,except for a 0.1 psi/ft gas gradient,is assumed. 8-1/2"Hole Section—2,305' to 7048' TVD(Sidetrack) MASP(pore pressure)=(7100 ft)(0.530—0.1)= 3030 psi MASP(form.breakdown)= (2305 ft)(0.728—0.1)= 1,447 psi Therefore,MASP in the 8-1/2"hole section is 3,030 psi and the 5,000 psi BOPE system to be used will be adequate. Well Proximity Risk: The nearest wellbore to the planned wellbore of the Qugruk 5A,Till#1 well located approximately 2 miles to the Northwest. Therefore,there are no nearby wellbore proximity 7 risks. Drilling Area Risks: 8-1/2" Sidetrack Hole—7" Casing Interval EVENT RISK LEVEL Miti ation Shale stability in the Moderate Control with higher mud weight and proper drilling interval below HRZ practices. Lost Circulation Moderate Monitor hole cleaning efficiency. Mitigation by good hole cleaning practices. Reduce mud weight if possible. If losses occur,reduce pump rates and lower mud rheology,use LCM material. Hole Swabbing/Tight hole Moderate Circulate hole clean prior to trip. Proper hole fill on Trips utilizing trip sheets,pumping out of hole as needed. Differential Sticking Low Periodic wiper trips as needed for hole conditions. Do not leave pipe static for extended periods. Abnormal Reservoir Low Follow programmed mud weights, monitor well, Pressure increasing mud weights as needed. Ensure adequate kick tolerance prior to drilling pay interval(s). I BOP Control System The blowout preventer stack is a Shaffer 13 5/8"x 5000 psi annular preventer, a 13 5/8"x 5000 psi double gate ram type preventer fitted with blind rams in the bottom and variable rams in the top and a Shaffer 13 5/8"x 5000 psi single gate ram preventer fitted with a 2 7/8"5"variable ram block. The BOPE control system on Nabors Rig#105 is a 6 station, 165 gallon-220 gallon reservoir. Ten 15 gallon bottles,four nitrogen backup. One manual master control station with six controls located on main unit, one six station remote control panel located on drillers station. Equipped with 1 electric and 2 air pumps with emergency power. All PLC controlled. The choke manifold is rated 3 1/8"x 5000 psi. It will include a remote hydraulic actuated choke and a hand held adjustable choke. Wellhead System An exploration wellhead system has been selected for this well,a 5M rated wellhead assembly will be nippled up on the well for the sidetrack. The 9-5/8" casing is suspended with a fluted 13 3/8"mandrel hanger in a landing ring that is part of the diverter system. If a top cement job is required,wash pipe will be attempted to be run through the ball valve seat at the base of the conductor.Tubing to pass through the ports on the top of the hanger will be available if access through the ball valve is not possible. Once cementing is complete,the diverter system is removed and a 5M wellhead system is installed on the 13 3/8" mandrel hanger. The connection between the wellhead system and the mandrel hanger is pressure tested to 1200psi. The 13 5/8" 5M wellhead system is design to suspend the 7" casing on a 9 5-8" fluted mandrel hanger, and the 13 3/8" x 9 5/8" annulus is secured with a packoff that is installed from the rig floor without the need to remove the BOP stack. This packoff is tested to 5M upon installation. The wellhead system has been designed to be completely removed after the well has been drilled and prepared for abandonment. 0 Ougruk 5 Planned Schematic r • i +— 26"Hole f i - � I 'r t I r ! ii^ I 20"131#J55 Conductor r 4_ +;-101'MD;TVD Rig 105 RKB: 20' 0 5 Elevation wi Pad Thickness: 15' e • L # 12- 7"Hole KB to MSL: 35' ;I ;l F ') - -Top of Cement: 1800'MD ':; -t e , . ! -4-- 9-5118"47#L-80 BTC Casing @ +1-2305'MD .,. DV Collar y +;-3500' MD Nanushuk 14+l-4173'MD,3935'TVD ,:\ ST-1 inclination Through Pay 36.9' ,-, Pilot Hole Inclination Through Pay 19-8` \'' 'c`` TOC Stage 1 +0-5800'MD Kup C +,'-6089'MD,6267'TVD 4 " Alpine @+1-7276'MD,6655'TVD \,: \.t— 8 1-open hole 4. •.,ti Nuigsut 200 ig+.-7706'MD,6760'TVD 4;: t �\ 4 .'I, ' Nuigsut 100 i +.'-7862'MD, 4 1 .\ 6885'TVD ID i'+-7430'MD r, _ TD tsa,++;-8065'MD +,'-70.18'TVD Qugruk 5A Cementing Program 7"Intermediate Casing,8-1/2"hole set at 8065' MD,cemented in 2 stages Spacer: 30 bbl 11.5 ppg Tuned Spacer 1st Stage: Top of slurry: +/-5800' MD/5236' TVD Premium class G cement, 15.8 ppg density a7 40% excess /Z X Yield: 1.15 cu ft/sk Volume: 57.1 bbls(279 sx) including excess &80' Shoe track Spacer: 30 bbl 11.5 ppg Tuned Spacer 211d Stage: Top of slurry: +/- 1800' MD/TVD Type 1/2 cement, 12.0 ppg density 40% excess Yield: 2.48 cu ft/sk Volume: 46.2 bbls(104 sx) • • \ § , § ( & § � 2 ° 7 0 0 0 25 6 \ \ §e 0 20- ~ 4 ) @\ a @ [ ® • 0 c } 3 %.ac 0 \ 0c o Co oto- $a2 C U. §§[/\ CD - E §ECO CO ICJ CO k CO q,W ) § Tizi . cg ® §� 0 u)u- \ R co 0 \§@e ■ E) E CO® = 2 3 = LU5 C : # e * U- 0 E E±f« 3 . } Z�0J \ + / vt ^ 0 40 II = a « _ Ico co a CO �/ k (\�\ CO co 0.030 0 0 e. 0 k a § § F \ o = _ § 2 \ z3 co To _ /TO [ 0 oo \ | M° o /» m e. ) I I 72 E. 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Y 2 ' O L W V Qtill O E 0 Ci 0 o IY a 0.0 1,11 1 C_1 H c Ln cc (13 Tr CI o o t - o QN 2 Tr N M L U S. o dA ¢ a) -0 bA 06O av a n ti v o N W N N Tr Y ,w O 3 `a O ti N ' 3 L C U Z OA • 2 a ,i- ,-.1 O - N GO co N U a \ O N -O - _N CO O] Q 2 L)1 N cr) Arm cn C cC z V O N cn Ni O 0 0 0 0 0 0 0 0 0 • • REP$OL Qugruk 5(P24)north Proposal Geodetic Report Schlumberger (Del Plan) Report Date: March 04,2014-04:31 PM Survey/DL5 Computation: Minimum Curvature/Lubinski Client: Repsol Vertical Section Azimuth: 354.707°(True Nam) Field: Qugmk Vertical Section Origin: 0.0000,0.000 ft Structure/Slot: Ougruk 5/05 TVD Reference Datum: Rotary Table Well: Ougruk 5 TVD Reference Elevation: 36.000 ft above MSL Borehole: Qugruk 5 Pad Elevation: 15.000 ft abate MSL APIB: 501032068200 Magnetic Declination: 19.108° Survey Name: Ougruk 5(P24)north Total Gravity Field Strength: 1002.0040e50t(9.80665 Based) Survey Date: March 04,2014 Gravity Model: DOX Tort/AHD 1 001/ERD Ratio: 41.746°/3167.108 ft/5.180/0.449 Total Magnetic Field Strength: 57597.188 nT Coordinate Reference System: 51AD27 Alaska Stale Plane,Zone 04,US Feet Magnetic Dip Angle: 80.869° Location Lat/Long: N 7011 22'34.54116",W 1501130 12.72789" Declination Date: March 29,2014 Location Grid N/E 7/X: N 5987456.000 BUS,E 438058.0001MUS Magnetic Declination Model: BOOM 2013 CRS Grid Convergence Angle: -04743° North Reference: True Nam Grid Scale Factor: 0.99990436 Total Corr Meg North->True North: 0.0000° Version/Patch: 2.7.998.0 Total Corr Meg,Grid North: 19.108011 Local Coord Referenced To: Wel Head MD net Ads,True NDSS ND VSEC NS EW TF DLS Directional Zoneonal Exclusion Zone tasting Northing Comments (ft) (°I (°) (9) (8) (ft) (ft) (ft) (°) (°/1000) Difficulty Index Alert My�, (806) (ftUS) RTE 0.00 0.00 0.00 3690 0.00 0.00 0.00 0.00 204.56M WA 0.00 9.13 43805890 5987466.00 229.00 0.20 20456 19390 229.00 -0.35 -036 -0.17 158.1794 0.09 0.00 9.33 43805793 598745504 311.00 0.22 158.17 27590 311.00 4.62 -0.84 -0.17 250.5354 0.20 0.00 9.30 43805793 5987455.36 490.00 093 250.53 45490 490.00 -036 -097 -006 3529654 0.12 0.00 0.15 43805791 5987455.03 582.00 0.29 352.86 54690 582.00 -0.74 -0.75 -0.14 196.26M 0.32 0.05 897 438057.86 5987455.25 85600 0.09 19626 82290 85600 .024 -027 -028 86.814 0.14 0.38 9.22 438057.72 598745574 94890 026 8660 91230 948.00 -0.31 -032 -0.10 135.7254 0.34 0.52 9.03 43805790 5987455.68 1045.00 0.00 135.72 1009.00 1045.00 -088 -0.37 0.17 161.39M 0.22 0.63 9.17 438058.17 5987455.63 1141.00 0.37 161.39 110590 1141.00 -0.74 -0.71 0.33 160.654 0.30 0.76 9.43 438058.32 5987455.28 133490 0.49 160.60 129799 1333.98 -2.15 -2.08 090 148.3494 0.06 096 9.52 438058.78 5987453.91 143000 0.56 148.34 139330 1429.99 -297 -297 1.18 14421M 0.14 1.07 9.49 438059.16 5987453.12 1527.00 0.81 14421 149098 152298 -3.98 393 1.83 140.2294 0.26 1.21 9.62 43805380 5987452.16 1817.00 0.68 140.22 178095 1816.95 -7.17 -6.81 4.13 161.02M 0.05 1.43 9.50 43806297 5887449.15 191390 0.76 161.02 187695 1912.95 -825 -7.85 4.70 153.29M 0.28 1.52 9.74 438062.64 5987448.11 2009.00 0.70 15329 1972.94 200694 942 -898 5.17 183.8954 0.12 1.59 9.63 438063.10 5987446.98 2106.00 0.59 18399 2069.93 2105.93 -10.46 -10.01 5,41 169.9694 0.37 1.67 9.70 438063.32 5987445.95 2202.00 0.72 16996 216593 2201.93 -1155 -1199 5.48 174.6894 0.21 1.73 9.77 438063.38 5987444.86 Tie-in Survey 2252.00 094 174.88 221592 2251.92 -12.14 -11.68 556 172.554 0.20 1.76 9.72 438003.46 598744427 2300.00 0.71 172.50 2263.92 2299.92 -12.71 -1224 5,62 172.394 0.16 1.78 9.77 438063.52 5987443.71 9681 2305.00 0.72 172.30 2268.82 2304.92 -12.77 -12.31 5.63 170.6794 816 1.76 8.78 438069.53 5587443.65 KOPCm4/100 2350.00 0.79 170.67 231392 2349.92 -13.37 -1290 5.72 22.86M 0.16 1.81 9.83 438063.61 5987443.06 2400.00 1.28 2296 236391 239991 -1322 -12.72 5.99 16.594 4.00 2.00 725 438063.89 5987443.23 Cie 4/190 2435.00 2.67 18.50 2398.89 2434.89 -12.12 -11.58 6.38 12.5494 4.00 2.12 6.47 43806428 5987444.37 2448.84 3.18 12.54 2412.72 2448.72 -11.45 -1099 6.55 4.9521 4.00 2.17 Enter Alert 5.98 438064.46 5987445.05 2500.00 5.16 4.95 2463.74 2499.74 4.83 -721 7.06 3.9654 4.00 2.35 Alert 4.31 43806530 598744673 2511.83 5.62 3.96 2475.52 2511.52 -6.74 -6.11 7.14 359.7694 4.00 2.38 Enter Fail 3.98 43806598 5987449.4 2600.00 9.11 369.76 256294 259694 4.48 5.19 7.41 671 4.00 2.69 Fad 3.05 438065.45 5987461.13 264828 10.95 358.62 260651 2644.51 12.52 1325 7.29 5.581 4.00 2.83 Exit Fad 398 438065.40 5987469.19 2700.00 13.09 357.70 2861.05 2697.05 2669 24.43 692 4.681 4.00 2.99 Alert 5.66 438065.13 5987480.37 270927 13.46 357.57 2670.07 2706.07 2591 26.56 6.84 4.551. 4.00 3.01 Eel Alert 5.98 438065.05 5987482.50 280030 17.08 356.59 2757.59 2793.59 49.69 50.42 5.59 3.611 490 325 9.31 43806431 5987506.36 2900.00 21.08 355.89 2852.07 2888.07 82.35 83.02 3.43 2.941 4.00 3.47 13.16 438062.12 5987538.98 3000.00 25,07 355.40 2944.06 2980.06 121.53 122.09 0.44 2.51 4.00 3.66 17.08 438059.45 598757607 3100.00 29.07 355.05 3033.08 3069.08 16733 167.43 -3.35 2.181 4.00 3.83 2103 438056.03 5987623.44 320010 33.06 354.77 3118.72 3154.72 218.62 218.82 -794 1.941 4.00 3.98 2530 43805187 598767496 End Cry 3295.64 3699 354.55 3197.07 3233.07 273.43 273.39 -13.05 HS 4.00 4.11 28.80 43804722 5987728.46 3300.00 36.89 354.55 3200.56 3236.56 276.05 276.00 -13.30 HS 0.0D 4.12 2680 43804699 5887732.07 3400.00 36.89 354.55 3280.54 3316.54 336.08 335.75 -10.00 HS 0.00 4.20 28.80 438041.78 5987791.87 3500.00 36.89 354.55 3360.52 3396.52 396.10 395.51 -24.70 HS 0.00 4.26 28.80 438036.58 5887851.66 3600.00 3689 354.65 3440.50 3476.50 456.13 45526 30.40 HS 0.00 4.32 28.80 438031.38 5987911.46 3700.00 36.89 354.55 3520.48 3556.48 516.15 515.02 -36.10 HS 0.00 4.38 2890 438026.17 598797125 3800.00 36.89 354.55 3600.47 3636.47 576.18 574.77 -41.80 HS 0.00 4.42 2890 43802097 5988031.04 3900913 38.89 354.55 368045 3716.45 636.20 634.53 -47.49 HS 0.00 4.47 28.80 438015.76 5988090.84 4000.00 3699 354.55 3760.43 3796.43 69623 69428 -53.19 HS 0.00 4.50 28.80 43801056 5988150.83 4100.00 36.89 354.55 3840.41 3876.41 75625 754.04 -5889 HS 0.00 4.54 2820 438005.36 5988210.42 4200.00 36.89 354.55 3920.39 3956.39 81628 813.79 64.59 HS 0.00 4.57 28.80 438000.15 6988270.22 4300.00 36.89 354.55 4000.37 4036.37 876.31 873.55 -70.29 HS 0.00 4.61 28.80 43799435 5988330.01 4400.00 36.89 354.55 4080.35 411635 936.33 933.30 -75.99 HS 0.00 4.63 28.80 437969.74 5988389.81 4500.00 36.89 354.55 4160.33 4186.33 996.36 993.05 61.69 HS 0.00 4.66 28.80 437984.54 5988449.60 4600.00 36.89 354.55 4240.31 4276.31 1056.38 05291 -87.69 HS 0.00 4.69 28.80 437979.33 5888509.39 4700.00 36.69 354.55 4320.29 4356.29 1116.41 112.56 -93.09 HS 0.00 4.71 28.80 437974.13 6988569.19 4800.00 36.89 354.55 440027 4436.27 1176.43 172.32 -98.79 HS 0.00 4.74 28.80 43796893 5988628.98 490290 36.89 354.55 448025 451625 1236.46 232.07 -104.49 HS 0.00 4.76 28.80 437963.72 5968668.78 5000.00 36.89 354.55 456023 459523 1296.48 291.83 -110.19 HS 0.00 4.78 2880 437958.52 598874857 510090 36.80 354.55 484021 4676.21 1356.51 351.58 .115.89 HS 0.00 4.80 2890 437953.31 5988808.36 5200.00 36.89 354.55 4720.19 4756.19 1416.54 411.34 -121.59 HS 0.00 492 28.80 437948.11 5988868.16 5300.00 36.89 354.55 4800.18 4836.18 1476.56 471.09 -127.29 HS 0.87 4.84 28.80 43794291 5988927,95 5400.00 38.89 354.55 4880.16 4916.16 1536.59 53095 -132.99 HS 0.00 4.86 28.80 437937.70 5988987.75 5500.00 36.89 354.55 4960.14 4096.14 1596.61 590.60 -138.69 HS 0.00 4.87 28.80 437932.50 5089047.54 5600.00 36,89 354.55 5940.12 5076.12 1656.64 850.36 -144.39 HS 0.00 4.89 2680 437927.29 5989107.33 5700.00 3669 354.55 5120.10 5156.10 171666 710.11 -150.09 HS 0.00 4.91 2680 437922.09 5989167.13 5800.00 36.89 354.55 5200.08 6936.08 1776.69 769.88 -155.79 HS 0.00 4.92 28.80 43791698 598922692 590090 36.89 354.55 5280.06 5316.06 1836.71 829.62 -161.49 HS 0.00 4.94 28.80 437911.68 598928671 6000.00 36.89 351.55 5380.04 5386.04 189674 88987 -167.18 HS 0.00 4.05 2890 437906.48 5989348.51 6100.00 36.89 364.55 5440.02 5476.02 1956.77 949.13 -172.88 HS 0.00 4.97 2880 43790127 598940620 620090 36.89 354.55 5520.00 5556.00 2016.79 2008.88 -178.58 HS 0.00 4.98 28.80 437896.07 5089466.10 630030 36.89 354.55 559998 5835.98 2076.82 2068.64 -184.28 HS 0.00 4.99 28.80 437890.86 598952589 640090 3689 354.55 567998 571596 213684 212829 -180.98 HS 0.00 5.01 2880 437885.68 5989585.68 6500.00 36.89 354.55 575924 5795.94 219687 2188.15 -19588 HS 0.00 5,02 2820 437880.46 5989645.48 6870.00 36.89 354.55 583932 5875.92 2256.89 224790 -201.38 HS 0.00 5,03 2880 43787525 598970527 670090 36.89 354.55 5919.90 5955.90 231692 2307.66 -207.08 HS 0.00 5.04 28.80 437870.05 5989765.07 680001 36.89 354.55 5999.88 6035.88 237694 2367.41 -212.78 HS 0.00 505 28.81 43786484 598982486 690030 36.89 354.55 6079.87 6115.87 243697 2427.16 -218.48 HS 0.00 5,07 2681 437869.64 5989884.65 700090 36.89 35455 6159.85 619585 2497.00 248692 -224.18 HS 0.00 508 28.81 437854.43 5989944.45 710030 36.89 35155 623983 627523 255732 2546.67 .22988 HS 0.00 5.09 2881 437849.23 599000424 720030 36.89 354.55 831921 635581 261705 2606.43 -235.688 HS 0.00 5.10 2881 437844.03 599006493 7300.00 38.89 354.55 6399.79 6435.79 2677.07 2666.18 -241.28 HS 0.00 5.11 28.81 43783309 599012383 740090 38.89 354.55 6479.77 6515.77 2737.10 2725.94 -246.98 HS 0.00 5.12 2881 437833.62 5990183.62 7500.00 36.89 35455 6559.75 6595.75 2797.12 2785.69 -252.68 HS 0.00 513 2881 43782641 5990243.42 760000 36.89 354.55 6639.73 6675.73 2857.15 2845.45 -258.38 HS 0.00 5.14 2881 437823.21 599030321 7700.00 36.89 354.55 6719.71 6755.71 2917.17 2905.20 -264.08 HS 0.00 5.15 2881 437818.01 599036330 780030 36.89 354.55 6799.69 6835.69 297720 2964.96 -269.78 HS 0.00 5.18 2881 437812.80 599042280 Q5 Rath Target 781589 36.89 354.55 6812.00 6848.00 2986.44 2974.15 -270.65 HS 0.00 5.16 2881 437812.00 5990432.00 7900.00 38.89 354.55 6879.67 8015.67 3037.23 3024.71 -275.48 HS 0.00 5.17 28.81 437807.60 5990482.58 800390 3689 354.55 6959.65 6995.65 3097.25 3084.47 -281.17 115 0.00 5.17 28.81 437802.39 5990542.39 TO 8065.39 36.89 354.55 701195 7047.95 3136.50 3123.54 -284.90 0.00 5.18 2881 43779899 5990581.48 Survey Error Model: ISCW SA Rev 0°"3-295.000%Confidence 2.7956 sigma Survey Program: Description Part MD From 940 To EOU Prep Hole Size Casing Diameter Survey Tool Type Borehole/Survey / 0.003 2252.000 Act Sins 12250 9.625 SLB_M WO-STD Qugruk 5 PH/Ougruk 5 PH 1 2252.000 2305.000 1/100.000 12250 9.625 SLB_MWD-STD Ougruk5/Qugruk 5(P24)north 1 2305.000 8065.389 11100.000 8.500 8.500 SLB_MWD-STD 0095415/Qrpndl 5(024)north Legal Description: Northing(I) testing(X) Surface:1380.2 FSL 3141.4 FEL B24 712N R6E UM 5987456.000 438058.000 q5 north target 4354 FSL 3411 FEL 24 T12N R6EUM 5990432.000 437812.000 BHL 4504 FSL 3425 FEL 24 T12N R6EUM 5990581.480 437798.990 Drilling Office 2.6.1166.0 Qugruk\Qugruk#5\Qugruk#5(priority 1)\Qugruk#5\Qugruk#5(P5) 3/6/2014 2:57 PM Page 1 of 1 • • i i i i 3i 1 I i i S 1 1 1 1 i 1 i i i i i i 1 I t 1 i i 1 1 1 I i 1 1 1 1 i i 1 i I i i i 1 i 1 1 f Y t i t 1 i Y 1 i ! 1 1 1 1 1 ii 1 1 1 r I I 1 8 i i 1 i 1 i i i N i i A U t N . O- - i 1 i i j i t i i i i I i 1 t I i1 i 1 i 1 i iE i i i i i i 0 i i -4 i i i r, i i i i i 1 i i M t / i V i w i C i i 71,v 1 1 1 1 c o 34z V • . N • ..... §_ . • 0 i e IIIQQQ i HJ ON (10) 1-11J10S • • REPJOL HALLIBURTON DRILLING FLUIDS PROGRAM Operator:Repsol USA Well Name: Qugruk-5 Location:Alaska Version 3.1 Prepared by Mr. Chris Okland Technical Professional Christopher.Okland@Halliburton.com Office-907-275-2612 Cell-907-350-2847 Author/Owner Approver Approvers Name: Chris Okland Chris MacKinnon Tim Flynn Title: Tech Proff. Operations Lead ODE Date: Nov 11,2013 Signature: HALLIBURTON Ceroid i • HALL.LI BURTDNI Etarcaci REPIOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Mud Program Distribution Name Position Document Version Date Tim Flynn Repsol ODE 3.1 3/6/14 Chris Mackinnon Halliburton Ops Leader 3.1 The table above will serve as a record of distribution control for the approved program,both hard copy and electonic copies shall be logged into the above table. Program Amendment and MOC Record Version.# Date Author Description MOC Document number The table above will serve as a record of ammendments submitted for the well. The Management of Change(MOC)process must be followed for changes made to the drilling fluids program after the spud date. Well Data provided bvRepsol Data Provided Document Identifier Date Received Used in Preparation of this Halliburton Program Y/N Approver Scope of work Qugruk-5 ver 1 11-10-12 Y C.Okland Scope Change Documentation No Scope Changes to date Well Data Operator Repsol USA Well No. Qugruk-5 Field/Block Colville River Delta PBU Location Alaska/U.S.A Well Type Exploration Max.Well Inclination 52 Maximum Expected Mud Density 10.4 Estimated Days 92 Days Anticipated BAST at Total Depth of well 165°F Baroid Project Support Team Title Name Cell Number Office Number Email address Technical Professional Chris Okland (907)350-2847 (907)275-2612 Christopher.Okland @Halliburton.com Operations Leader Chris Mackinnon (907)227-5045 (907)275-2617 chirs.mackinnon@Halliburton.com Lead Mud Eng. Lead Mud Eng. Night Mud Eng. Night Mud Eng. Stock-point Manager John Jessup/Brent Edmunds (907)943-1028 (907)659-2422 John.Jessup@Halliburton.com Brent.Edmunds@Halliburton.com 2 i S HALLIBURTDNi E3aroid REPJ'OL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A Program Briefing Qugruk-5 will be drilled from the Colville River Delta.A 20"conductor will be driven/drilled in place to+/-101 ft and cemented. The 12 1/4"surface hole will be drilled from 101 ft through the base of the permafrost to TD using conventional bentonite spud mud weighted to 9.8 ppg.The MW will be allowed to rise to 10.0 ppg by the base of the permafrost(+/-1,272'TVD)with the addition of BARACARB 25-50 or Barite/drill solids.3-5 lb/bbl background LCM consisting of BARACARB 25- 50 will be used through the surface hole section to reduce lost circulation potential.The surface hole will be drilled to TD at 2,264'MD.9 5/8"47#casing will be run and cemented. The 8 1/2"hole will be drilled ahead from the 9 5/8"casing shoe to the expected TD depth of 7,405'using a 6%KCl/PHPA drilling fluid weighted to 10.4 ppg to remain at 10.4 ppg by the top of HRZ. The well will be drilled to the core point,this will be picked by the onsite Geologist 50'above the Nuiqsut. 3-5 lb/bbl of background LCM(Wal-Nut)will be used through this section if bit balling through the heavy clay sections becomes an issue.Discontinue Wal-Nut usage if bit balling is not seen.The mud weight will remain at 10.4 ppg through 5500'TVD.BDF-515 and BAROTROL+(shale stabilization)will be added prior to drilling into the HRZ. The well will be conditioned for multiple wireline logging runs beginning at the first core point and at TD depth of 7405'MD. Pick up and run 7"26#casing to surface,7"casing will be cemented in two stages. Completion for this section will be covered through the DST in a separate work plan.A cement retainer will be set above the perfs in the 7"casing and cement will be pumped though it for the abandonment. The 6 1/8"hole will be drilled ahead from the 9 5/8"casing,kicking off with a cement plug set at 2350',using a 6%KCl/PHPA drilling fluid weighted to 10.4ppg,10.6 ppg by the HRZ.Directionally drillhole section to a TD of 8065'.Condition mud for wireline formation evaluation logs.This section will be P&Aed as per the AOGCC regulations. MW through these sections are based upon polar plot and offset data,actual MW will be based upon dictating wellbore conditions. Well Desien Summary Hole Size Casing/Tubing TD(ft) TVD(ft) Inc.(deg) Feet Drilled Mud System Mud Density Interval (in) Size(in) Max (ft) (ppg) Name 12.25" 9 5/8" 2,264 2,264 0 2,264 Bentonite 9.8.10.0 Surface Spud Mud 8.5" 7" 7405' 7135' 20 5151 KCl/PHPA 10.4 Intermediate 6.125" NA 8065' 7047' 52 5715' KCl/PHPA 10.4-10.6 Production Ougruk-5 Surface Interval Casing Size (in) End Depth(ft) 9 5/8 47# 2264'MD Drilling Fluid System 9.8-10.0 ppg Bentonite Spud Mud Products Required Aquagel,Soda Ash,Dril-N-Slide,Caustic Soda,Baracarb,Barite Shakers:Begin with-80 mesh screens,screen up as flow rates and solids allow. Recommended Solids Control Mud Cleaner:Begin with 3/8-1/2"orifaces on the mud cleaner.Ensure>35 psi head pressure at each cone. Centrifuge:Run as necessary to halanceLGS and necessary MW. Maintain viscosity to carry gravel out of Sloughing Gravel wellbore Potential Problems Solutions Heavy Clay Intervals Utilize CondetlDril-N-Slide to minimize shaker blinding from sticky clay. Interval Objectives Maintain Well Control Run and cement 9 5/8"casing Restricted Products None 3 • H., LL1BURTDIV Ga{-oici REPlOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Formation Tops Estimated Expected Pore Pressure Formation Formation Top (EMW ppg) (TVDSS) BPRF 1,272 9.4 MCU 2,149 8.7 Tuluvak 2,549 10.2 Ougruk-512'/x"Surface Interval Fluid Target Properties Interval Fluid:Sud Mud Mud Weight Funnel Vis API MD(ft) (lb/gal) (see/qt) YP pH (ml) MBT 0-2,264 9.8-10.0 125-275 25-40 >9.0 <14.0 20-25 Oueruk-5 12'/x"Spud Mud Fluid Formulation Product Concentration Cold Lake Water 0.94 bbl SODA ASH 0.15 ppb AQUAGEL 25 ppb X-TEND II 0.1 ppb CAUSTIC SODA 0.1 ppb (9.0-10.0 pH) BARACARB 25-50 3-5 ppb Background BAROID 41 70 ppb (9.8 ppg) PAC-L As needed to reduce API wl DRIL-N-SLIDE/Condet Premix As needed for sticky Clay • Have the rig or Baroid mud plant mix—600 bbl 9.8 ppg Spud Mud and deliver to the wellsite. • Ensure rig pits and lines are clean prior to offloading any new 9.8 ppg mud from trucks. Qugruk-5121/x"Surface Interval Operations Summary • Drill ahead maintaining all product concentrations while adding dilution mud or cold lake water. • Run background BARACARB 25-50 at 3-5 lb/bbl for for bridging to minimize lost circulation events through the unconsolidated formations seen in Prudhoe Bay surface hole sections. • Begin drilling with 9.8 ppg MW and allow drill solids and Baracarb to increase the MW to 10.0 by the base of Permafrost Use Barite if necessary to maintain 10.0 ppg MW. • Maximize the usage of all solids control equipment,screen up when possible and run the centrifuge to reduce LGS and maintain MW. • Utilize cold lake water for rig site dilution fluid. • Maintain>_500 gpm pump rate while drilling ahead. Utilize DFG 5.4 for realtime modeling of hole cleaning abilities. Adjust fluid rheology,pipe rotation (RPM)and ROP based on the ability to clean the hole. • In preparation of running the 9 5/8"casing,ensure native solids(LGS)content is<10%. • Check with cementers to target a YP while circulating the casing on bottom. Use Desco CF to obtain the desired YP. Well Concerns • Follow all REPSOL-Halliburton processes and Procedures • Truck Usage Volumes-Track the truck utilization volumes using the TFM spreadsheet. CH2Mhill trucks are maximized at 90%of their carrying capacity for every load hauled,and less when heavy fluids are hauled. Attempt to load Vac trucks and Super Suckers to their 90%maximum volume,always taking rig time into account while anticipating trucking wait times. Give logistics dispatchers>24 hours advance notice prior to jobs requiring multiple trucks on location. • Hole Cleaning—Run DFG 5.4 every 12 Hrs.while drilling to monitor hole cleaning capabilities using real time ROP,RPM and pump rates.The continual loading of drill solids into the mud system will change the rheological properties of the mud. Utilize all solids control equipment.Be prepared to dilute by means of water or whole mud to diminish the effects of the drill solids. • Lost Returns—Losses are not expected through the surface hole section,although a full compliment of LCM contingency products will be available on location should losses occur. 4 • HRLLIBURTDNJ Baroid REPlOL Qugruk-5 ver. 3.1 Prudhoe Bay AK/U.S.A. • Well Control—Rig hands and Mud Engineers both,shall constantly be aware of mud density measurements,trip volumes and pit volumes to ensure good well control practices are followed. Surface Hole ROP/Pumn Rates Rheology and pump rate are critical factors in cleaning this verticle wellbore. Consider the following practices if hole cleaning becomes an issue: • Hole cleaning sweeps(change flow regime of base mud by using rheology for carrying capacity). • Connection practices-employing extended gpm,rpm and back reaming,prior to the connection. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 550 600 650 80-rpm 175 190 215 100-rpm 175 190 215 120 rpm 175 195 215 Calculated using 4%maximum cuttings load Calculated ECD's @ 575 GPM and 100 RPM Depth(MD) Mud wt. Clean hole Max ECD(3.5%cuttings ECD load) 1200' 10.0 10.2 10.6 2264' 10.0 10.2 10.6 • Shallow Gas Potential— o A gas influx on an offset well was experienced at a depth of 2500'TVD on Well Fiord#2. Mud weight was 9.2 ppg when the event occurred, BOP's were in place and the well was killed with a 9.4 ppg fluid. The mud weight was increased to 9.7 ppg and no other problems were encountered. o A well control event occurred on Qugruk#2 while drilling with 9.2 ppg mud at 2523'MD. The design of this well has the surface casing being set above the Tulavak and mud weight in excess of 10.2 ppg will be used to drill the production section. Qugruk 5 8 1/2"Hole Interval Casing Size (in) End Depth(ft) 7" 7405'MD Drilling Fluid 10.46%KCl/PHPA System ppg. l'otassium Chloride(KCl),BARAZAN D+,PAC-L,EZ Mud DP,Caustic Soda,BAROID 41, Main Products DRIL-N-SLIDE,ALDACIDE G,BARACOR 700,BARASCAV D,BDF-515,BAROTROL PLUS Recommended Shakers:165+mesh screens,screen up as solids loading on screens diminishes Solids Control Mud Cleaner:3/8"cone orifice.Centrifuge:As necessary to balance MW and LGS buildup Mud Engineer will utilize the solids control unit as needed. l3ad displacement Maximize pump rate and pipe rotation Have excess LCM products available on I,ost Circulation location Potential Problems Solutions Use DRIL-N-SLIDE/Condet,for shaker Sticky Clay blinding,background Walnut to alleviate bit balling.Use 3-5 ppb Wal-Nut while drilling through sticky clay sections to help prevent bit balling. Interval Objectives Drill to core depth picked by the onsite Geologist.Core up to 150'and then drill ahead to 7,405'TD depth and run wireline logs.Minimize rig down time due to trips. Restricted None Products 5 • i 1-1,^1-L.1 13 I—WIT Pd Baroid REPJOL Qugruk-5 ver. 3.1 Prudhoe Bay AK/U.S.A. Formation tops Estimated Expected Pore Pressure Formation Formation Top (EMW ppg) (TVDSS) Tuluvak 2,549 10.2 Torok 5,606 9.1 HRZ 5,883 9.3 Nuiqsut 6.650 10.1 Qugruk 5 8-1/2"Hole Fluid Target Properties Interval Fluid:6% KCUPHPA� \ MD d ` astir Yield Point Cl MBT `{Pi pH LGS% HTHP in eight iscosity (nil) Shale(ml) 2,264'—7,405' (10.4 12-24 18-25 30k <12 <5 9.0-10 <6.5% <10.0 Qugruk 5 8-1/2"Hole uid Formulation Product Concentration Water 0.89 bhl BARAZAN D+ 1 ppb KC1 22 ppb PAC L 2 ppb CAUSTIC SODA 0.1 ppb (9.0-10.0 pH) BAROID 41 89 ppb (as needed for 10.4) ALDACIDE G 0.2 ppb CONDET Premix .5% (Mixed at LMP only) EZ MUD DP .75-1.0 ppb(Mud plant mix 0.15 ppb max add remainder at rigsite) BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb DRIL-N-SLIDE 0.5-1.0% (For clays from rigsite) BDF-515 4.0 ppb (added prior to HRZ) BAROTROL PLUS 4.0 ppb (added prior to HRZ) Displacement Procedure Recommendation • Clean the rig pits of the surface fluid and flush all of the surface equipment and lines prior to taking onboard the new 6%KCUPHPA fluid. • After tagging the landing collar and drilling it out,pump a 50 bbl HI-VIS spacer,followed by the 10.4ppg KCUPHPA mud.Watch the shakers for KCUPHPA returns before routing to active system.Plan to pretreat for cement contamination with Citric Acid and bicarb.Do not add Baracor 700 until after finished drilling cement,as the cement will cause the Baracor 700 to precipitate out of the fluid. 8-1/2"Hole Interval Operations Summary • Drill ahead maintaining all product concentrations while adding dilution fluid. • Add 3-5 ppb Walnut as background LCM/bit scouring method to help prevent bit balling caused by sticky clays. Dril-N-Slide/Condet will also help to clean the BHA and shakers of the sticky clays. • Maximize the usage of all solids control equipment,screen up where possible and run the centrifuge to minimize LGS and maintain correct MW. • Add BDF-515 and BAROTROL+for shale stabilization.10.4 ppg is the minimum MW requirement from HRZ to TD. • Utilize fresh water or 6-8%KCI water for rig site dilution if LGS begin to rise above the recommended<6.5%. • Maintain>500 gpm pump rate while drilling ahead. Utilize DFG 5.4 every 12 Hrs.while drilling for real-time modeling of hole cleaning abilities. Adjust fluid rheology,pipe rotation(RPM)and ROP based on the ability to clean the hole. • Lost Returns—A full compliment of LCM contingency products will be available on location should losses occur. 6 • • HALLIBLJRTDI\I Baroid _ REPloa Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. • Corrosion Mitigation Plan—As part of the corrosion mitigation plan,Sodium Sulfite and Baracor 700 will be run in the 6%KCUPHPA fluid system to mitigate corrosion.Daily phosphonate and dissolved 02 checks will be run to monitor this program. Phosphonate levels should be maintained between 250- 850 ppm. Dissolved 02 should be kept at 1 ppm or lower. Record levels of each on the daily mud reports. Well Concerns • Follow all REPSOL-Halliburton processes and Procedures • Truck Usage Volumes-Track the truck utilization volumes using the TFM spreadsheet. CH2Mhi11 trucks are maximized at 90%of their carrying capacity for every load hauled,and less when heavy fluids are hauled. Attempt to load Vac trucks and Super Suckers to their 90%maximum volume,always taking rig time into account while anticipating trucking wait times. Give logistics dispatchers>24 hours advance notice prior to jobs requiring multiple trucks on location. • Hole Cleaning—Run DFG 5.4 every 12 Hrs.while drilling to monitor hole cleaning capabilities using real time ROP,RPM and pump rates.The continual loading of drill solids into the mud system will change the theological properties of the mud. Utilize all solids control equipment.Be prepared to dilute by means of water or whole mud to diminish the effects of the drill solids. • Lost Returns—Losses are not expected through the surface hole section,although a full compliment of LCM contingency products will be available on location should losses occur. • Well Control—Rig hands and Mud Engineers both,shall constantly be aware of mud density measurements,trip volumes and pit volumes to ensure good well control practices are followed. Coring Interval • The core point for this interval will be picked by the onsite Geologist 50'above the Nuiqsut. While coring add 10 sx hr of BARACARB 25 and or BARACARB 50 for bridging during the coring operation. 8-1/2" Hole ROP/Pumn Rates Rheology and pump rate are critical factors in cleaning this verticle wellbore. Consider the following practices if hole cleaning becomes an issue: • Extended periods of circulation(with maximum pump rate). • Hole cleaning sweeps(change flow regime of base mud by using rheology for carrying capacity). • Connection practices-employing extended gpm,rpm and back reaming,prior to the connection. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 500 550 600 80-rpm 180 220 250 100-rpm 220 270 300 120 rpm 250 275 310 Calculated using 3%maximum cuttings load Calculated ECD's @ 550 GPM and 100 RPM Depth(MD) Mud wt. Clean hole Max ECD(2.5%cuttings ECD load) 2300' 10.4 10.7 11.0 4500' 10.4 10.7 11.0 5500' 10.4 10.7 11.0 5500' 10.4 10.7 11.0 6500' 10.4 10.7 11.0 7405' 10.4 10.7 11.0 7 • • HALLIBURTDNS Eitaroici REPJOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Ouxruk 5 6 1/8"Sidetrack Casing Size (in) End Depth(ft) NA 8065 Drilling Fluid 10.4-10.66%KCl/PHPA System ppg. Potassium Chloride(KCl),BARAZAN D+,PAC-L,EZ Mud DP,Caustic Soda,BAROID 41, Main Products DRIL-N-SLIDE,ALDACIDE G,BARACOR 700,BARASCAV D,BDF-515,BAROTROL PLUS,EZ GLIDE Recommended Shakers:165+mesh screens,screen up as solids loading on screens diminishes Solids Control Mud Cleaner:3/8"cone orifice.Centrifuge:As necessary to balance MW and LGS buildup Mud Engineer will utilize the solids control unit as needed. Bad displacement Maximize pump rate and pipe rotation Lost Circulation Have excess LCM products available on Potential Problems Solutions location Sticky Clay Use DRIL-N-SLIDE,background Walnut to alleviate bit balling and shaker blinding Interval Objectives Drill 6 1/8""hole to 8065',run wireline formation evaluation logs. Pump abandonment plugs to P&A. Restricted None Products Qugruk 5 ST.1 Fluid Target Properties Interval Fluid:6% KCI/PHPA MD Mud Plastic Yield Point Cl MBT API pH LGS% HTHP in Weight Viscosity (ml) Shale(ml) 2350'—8065' 10.4-10.6 12-24 18-25 30k <12 <5 9.0-10 <6.5% <10.0 Ou2ruk 5 ST.1 Fluid Formulation Product Concentration Water 0.89 bhl BARAZAN D+ 1 ppb KC1 22 ppb PAC L 2 ppb CAUSTIC SODA 0.1 ppb (9.0-10.0 pH) BAROID 41 119 ppb (as needed for 10.4) ALDACIDE G 0.2 ppb CONDET Premix .5% (Mixed at LMP only) EZ MUD DP .75-1.0 ppb(Mud plant mix 0.15 ppb max add remainder at rigsite) BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb EZ GLIDE or NXS-Lube As necessary DRIL-N-SLIDE 0.5-1.0% (For clays from rigsite) BDF-515 4.0 ppb (added prior to HRZ) BAROTROL PLUS 4.0 ppb (added prior to HRZ) Displacement Procedure Recommendation • Attempt to reuse the previous Hole Interval drilling fluid 6%KCl/PHPA. Use a dilution fluid blended with the reused fluid if the LGS content is high. • Once at the whipstock,blend any dilution fluid with the reused system while attempting to sidetrack. 8 • • HALLIBLIR TDPJ Baroid REPJOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Interval Operations Summary • Drill ahead maintaining all product concentrations while adding dilution fluid. • Add 3-5 ppb Walnut as background LCM/bit scouring method to help prevent bit balling caused by sticky clays. Dril-N-Slide/Condet will also help to clean the BHA and shakers of the sticky clays. Utilize the Well Commander circ sub to spot LCM • Maximize the usage of all solids control equipment,screen up where possible and run the centrifuge to minimize LGS and maintain correct MW. • Add BDF-515 and BAROTROL+for shale stabilization.Weight up to 10.6ppg 500'before the HRZ at 5883'TVD.10.6ppg is the minimum MW requirement to TD. • Utilize water for rig site dilution if LGS begin to rise above the recommended<6.5%. • Maintain>225 gpm pump rate while drilling ahead. Utilize DFG 5.4 every 12 Hrs.while drilling for real-time modeling of hole cleaning abilities. Adjust fluid rheology,pipe rotation(RPM)and ROP based on the ability to clean the hole. • Should lubricants be required,add 1-2%EZ GLIDE or NXS-Lube.Call town prior to going over 2%. Well Concerns • Follow all REPSOL-Halliburton processes and Procedures • Truck Usage Volumes-Track the truck utilization volumes using the TFM spreadsheet. CH2Mhi11 trucks are maximized at 90%of their carrying capacity for every load hauled,and less when heavy fluids are hauled. Attempt to load Vac trucks and Super Suckers to their 90%maximum volume,always taking rig time into account while anticipating trucking wait times. Give logistics dispatchers>24 hours advance notice prior to jobs requiring multiple trucks on location. • Hole Cleaning—Run DFG 5.4 every 12 Hrs.while drilling to monitor hole cleaning capabilities using real time ROP,RPM and pump rates.The continual loading of drill solids into the mud system will change the rheological properties of the mud. Utilize all solids control equipment.Be prepared to dilute by means of water or whole mud to diminish the effects of the drill solids.Utilize real-time PWD for hole cleaning and sweep recommendations. • Lost Returns—A full compliment of LCM contingency products will be available on location should losses occur. • Well Control—Rig hands and Mud Engineers both,shall constantly be aware of mud density measurements,trip volumes and pit volumes to ensure good well control practices are followed. ROP/Pump Rates Rheology,rotation and pump rate are critical factors in cleaning this deviated wellbore. Consider the following practices if hole cleaning becomes an issue: • Extended periods of circulation(with maximum pump rate and pipe rotation). • Hole cleaning sweeps(change flow regime of base mud by using mud density or rheology for carrying capacity). • Connection practices-employing extended gpm,rpm and back reaming,prior to the connection. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 225 250 300 80-rpm 125 150 165 100-rpm 150 175 175 120 rpm 175 190 175 Calculated using 3%maximum cuttings load Calculated ECD's 275 GPM and 90 RPM Depth(MD) Mud wt. Clean hole Max ECD(2.5%cuttings ECD load) 6400' 10.4 11.2 11.5 _14 .,a 10.4 11.2 11.5 9 • • I-lilaLLIBURTON1 Baroid REPJOL Qugruk-5 ver. 3.1 Prudhoe Bav AK/U.S.A. SCE Recommendations Shakers • Multiple,High-G,linear motion shale shakers are recommended in order to maximize the system solids control removal efficiency.Run all available solids control equipment to prevent solids build-up. >200 mesh screens should be achievable for this pilot hole section. • All shale shakers should be"screened up"with finer mesh screens whenever possible without the loss of any drilling fluid off the end of the shakers. • The shale shakers should be continuously monitored for the proper distribution of drilling fluid across the screens to fully utilize the entire surface area of the screens. The drilling fluid should cover+3/4 of the entire screen length. • Damaged screens should be promptly changed and noted on the daily mud report screen usage column. • If near size particle blinding occurs,an attempt should be made to"screen-up"to alleviate this problem. If"screening-up"does not solve this situation,then coarser mesh screens must be installed until past this formation. • Sticky clays and heavy oils are prevalent in Prudhoe Bay surface holes and shallow intermediate hole sections. Use DRIL-N-SLIDE to remedy the screen blinding seen while drilling sticky clay and heavy oil formations. Mud Cleaner • It is recommended to use a mud cleaner to accomplish the maximum removal of drill solids.The oriface should be as small as possible while utilizing the mud cleaner for this purpose.This will maximize the drill solids removal efficiency while maintaining drilling fluid properties within the prescribed parameters specific to this area and interval formation characteristics. • Check to see that the Mud Cleaner cones are cleaned and in good operational spec prior to drilling the hole section. • Ensure head pressure to the mud cleaner cone manifold is>_35 psi. This is the minimum recommended pressure for each cone to acquire the vortex necessary to strip solids from the drilling fluid. Centrifuge • While drilling ahead,maintain LGS content and MW increases through use of the centrifuge. External Solids control • This rig will be equipped with a solids control unit consisting of a Mud cleaner and centrifuge,Mud engineers will work closely with the operators of this unit to maintain mud properties as directed. • This unit will also have a mix hopper and will be utilized to mix products downstream from the mud cleaner and centrifuge. 10 • • HA.LLIBIJ IFITCI NI Bamici REPJ"OL Qugruk-5 ver. 3.1 HI _ Prudhoe Bav AK/U.S.A. Well Cost/Volumes(Cubic/bbls) Estimated Fluid Disposal Volumes Dilution rates for the 12.25"surface interval are anticipated at 1.24 hhl/ft. Surface P 10 P50 P90 Initial Build 550 550 550 Dilution 1200 1750 2750 Total 1750 2300 3300 Estimated Drill Solids Disposal Volumes Surface PLO P50 P90 Cuttings Volume 330 412 453 Wetting Fluid 660 824 906 Total 990 1236 1359 Estimated Fluid Disposal Volumes Dilution rates for the 8.5 interval are anticipated at 0.8 bbl/ft. Intermediate P1 O P50 P90 Initial Build 1077 1577 2577 Dilution 1938 2686 3586 Total 3015 2838 4638 Estimated Drill Solids Disposal Volumes Intermediate P1 O P50 P90 Cuttings Volume 361 415 456 • Wetting Fluid 722 830 912 Total 1083 1245 1368 Estimated Fluid Disposal Volumes Dilution rates for the 6.125"interval are anticipated at 0.5 bbl/ft. Production P 10 P50 l'90 Initial Build 300 QUO 1300 Dilution 300 800 1300 Total 600 1600 2600 Estimated Drill Solids Disposal Volumes Production Pl O P50 P90 Cuttings Volume 46 50 55 Wetting Fluid 92 100 110 Total 138 150 165 II • HALLIBURTICI 1 J Taw Barioici REPlOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Appendices • Surface Hole Hydraulics • Intermediate Hole Hydraulics • Sidetrack Hole Hydraulics • LCM Decision Trees 12 • f • • HA�..L1BURTDPJ fi " Elar©ict _. REPJOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Surface Hole Hydraulics at 2,264'MD DrillAheada Spud mud 3.837%Cutting Flow Rate Total =14.2 bpm ROP=200.0 ftthr 3 838%Cutting Eff Density=10.000 ppg Cutting Dia=0.250 in 0.40 h CUT tome R=100% .+ 200.0 ft/hr-100 0 RPM IHC=80.0 RPM-1m!C=5m i 0 414 u.. :T - ECO HbCxt «a,» 1 11 IS 1 1 y 1 1 1r 2.41 (• 1�C jj 385 '` 1 1 lU: i 6.56 i 4 II 111 -0- C ";:`.. I ' t ' t u ! r I I- 0 2 4 6 0 t0 4 50 100 0 150 300 0 30 50 90 9:8 10.3 10.6 -10 -5 0 5 10 Cutting Load Transport Eff Average V Hole Angle ECD Wellbore (%) (%avg) (ft/mon) (°) (Ppg) (in) 13 1 • 0 HA,LLIBUIMRTDI%A -. tr'larotd REPJOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Intermediate Hole Hydraulics Dri I IAhead® A 2 453%Cutting Total Flow RateHP l 3.0 bpm ROP=220.0 ft/hr 2.411%Cutting Eff Density=10.400 ppg Cutting Dia=0.150 In 0.64 h CUT time R=100% y 220.0 ftihr-80.0 RPM IHC=80.0 RPM-lm/C=5m I ° I ,-CO tNezt ii ■ ■ iii■ 1 2500 [24 BB] 2~ sa IIII 5006 ; �, [48f 8] . a • iits 1MS, t �` r, 0 2 4 6 8 I0 0 50 100 0 300 600 0 30 60 90 10 4 11 11.6 -5 0 5 Cutting Load Transport Eft Average V Hole Angle ECD Wellbore {961 i%avg) (Rimm? (°) (p09) {in) 14 • • HALLIBURTDNI Bair-aid _ REPJOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Sidetrack I Hydraulics DrillAhead'' 6%KCL PHPA 1 788%Cutting tat Flow Rate=70bpm ROP= 175.0ftlhr 170%Cutting Eff Density=10.400 ppg Cutting Dia=0.100 in 0.51 h CUT time R=100%r_, 175.0 ftlhr-100.0 RPM 1HC=80.0 RPM-1m/C=5m/ a k.00.1111"rn -.4.--ECD WOOA ■ +III \ ■ all i, 14 111 V Ili 44 i 2500 . [24761 . } ■la � ■ o› 1 5400 [a7231 go II 9 \\\\\\\i\ 0 2.15 ..,. .. .. r 7500 o t . i t it [69701 0 2 4 5 8 IS 0 50 100 0 750 507 0 30 60 90 104 111 11.8 -5 0 5 Cutting Load Transport E11 Average V Hole Angle ECD Wellbore {%1 (%avg) (Wm) (1 (PPM (in) 15 ! • HAI—LI BIJITDPd Baroid REPJOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Lost Circulation Decision tree Losses Lost Circulation Decision Tree fl Intermediate Hole Sections • + • + Partial Seepage 20 60 bbllhr Severe Total 5.20 bbllhr Static Static 60-200 bbllhr Static >200 bbllhr Static V i Treat Active System Treat Active System + + • with 5 Barofibre with 10 sx/hr 60-150 bbl/hr Static 150-200 bbllhr Static Drill Across Fault sx/hrBAROFIBRE + Drill Across Fault Drill Across Fault Contact Drilling + + Engineer or Engineer �ynami on call Losses<15 Yes Dynamic 100 ppb LCMIMud Pill: bbl/hr Losses<25 Yes 20 ppb Baroseal F Contact Drilling Engineer 1 bbl/hr 20 ppb Baroseal M 30 ppb Barofibre or Engineer on call. Drill Ahead Drill Ahead 20 ppb Wallnut M 0 No 10 ppb Wallnut F V No Increase Treatment to y • POOH,P/U dumb iron BHA 5 sx/hr Barofibre 70 ppb LCM/Mud Pill: Contact Drilling Engineer or 5 sx/hr Baracarb 50 't20 ppb Baroseal F Engineer"On Call". 20ppb Baroseal M Consider spoiling EZ SQUEEZE or GUNK pill. 20 ppb Barofibre lynamic 10 ppb Wallnut M Consider spotting EZ Losses<15 Yes SQUEEZE pill/GUNK Squeeze/ bbllhr cementlplugback contingency Drill Ahead No 40 ppb LCMIMud Pill: Dynamic Losses<15 Yes 10 ppb Baroseal F bbllhr 4, 10 ppb Baroseal M Drill Ahead 10 ppb Barofibre 10 ppb Wallnut M No V Notes: Contact Drilling 1)Drill across fault or loss zone 1.5-2.0 times the length of the throw before spotting LCM pills. Engineer or Engineer 2)Circ Sub should be run in BHA to spot pills if"Partial Loss"cases Dynamic on call to determine if or above are anticipated prior to drilling,to allow the spotting of LCM Losses<15 Yes pills. additional LCM bbllhr 1 treatments are to be . 3)LCM pill volume=300-600'column based upon actual hole T diameter. Drill Ahead made. 4)PRIOR TO ANY LCM PILL,APPROPRIATE DISCUSSIONS AT THE RIG SITE MUST BE MADE TO MINIMIZE THE POTENTIAL No FOR PLUGGING THE DRILL STRING, CONTACT THE MWD V ENGINEER FOR SIZING AND PPB MAXIMUM QUANTITIES Proceed to'Partial ALLOWABLE THROUGH BHA. Losses'Pill / 16 • 0 HALLIEll UFtTOrd Biarold �f♦.. REPJOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Losses Lost Circulation Decision Tree fl Payzone Mud Systems • • + • Partial Seepage 20.60 bblthr Severe Total 5.20 bblthr Static Static 60.200 bblthr Static >200 bblthr Static V V Treat Active System Treat Active System + + • with 5 sx/hr Baracarb with 10 sx/hr Baracarb 60-150 bbl/hr Static 150-200 bbl/hr Static Drill Across Fault 50/150 150 ' j f Drill Across Fault Drill Across Fault Contact Drilling + + Engineer or Engineer eynami on call Dynamic goo ppb LCMIMud Pill: Contact Drilling Engineer Losses<15 Yes Losses<15 Ye 20 ppb Baroseal f bbl/hr or Engineer on call. bbl/hr 20 ppb Baracarb 50 Consider drill ahead w/ 30 ppb Barofibre Drill Ahead Drill Ahead 20 ppb SteelSeal seawater • No 10 ppb Baracarb 150 Consider drilling ahead V No without returns Increase Treatment to V v 10 sx/hr Baracarb 50/ 50 ppb LCM/Mud Pill: 150 Contact Drilling Engineer or 20 bblsBased Engineer"On Call". mud Consider drill ahead wl 10 ppb Baracarb 25 seawater 20 ppb Baracarb 50 Dynamic 20 ppb Baracarb 150 Losses<15 Yes bbl/hr 1 Drill Ahead No V Dynamic 20 ppb LCM/Mud Pill: Losses<20 Yes 20 bbls base mud bblthr 10 ppb Baracarb 50 Drill Ahead 10 ppb Baracarb 150 ( No i 1)ODE must approve any steps past PARTIAL losses. Contact the Engineer 2)Drill across fault or loss zone 1.5-2.0 times the length of the on call to determine if throw before spotting LCM pills. Dynamic ;3)PBL sub should be run in BHA to spot pills if'Partial Loss'cases or Losses<15 Yes additional LCM 'above are anticipated prior to drilling to allow the spotting of LCM bblthr I treatments are to be pills. i made 4) LCM pill volume=300'-600'column based upon actual hole Drill Ahead diameter. 5)PRIOR TO ANY LCM PILL,APPROPRIATE DISCUSSIONS AT No THE RIG MUST BE MADE TO MINIMIZE THE POTENTIAL FOR i PLUGGING THE DRILL STRING. Proceed to'Partial Losses'Pill 17 • • HALLIBURTCDN earnici REPJOL Qugruk-5 ver.3.1 Prudhoe Bay AK/U.S.A. Testing at the Wellsite • During normal drilling operations one complete mud check should be run every 6 hours. This is a total of four complete checks made over a 24 hour period. Timing for mud checks and cost cut off should begin at 12:01 am each day. Unusual circumstances and/or non circulating periods should dictate deviations from this schedule. • All rheological properties(ie.6 speed readings,LSRV and gel strengths,including 30 minute gels)will be taken at the standard 120°F unless otherwise specified. Routine Sampling • Mud samples(1 QT)should be sent in any time the need arises,ie.hole problems or lubricant problems. • Samples of the mud plant built fluids will be tested prior to shipment to the rig site and saved until the well is completed. Samples must be logged on appropriate sample tracking form. • Samples of new mud delivered to the rig site will be checked for weight and rheology at a minimum prior to offloading into the rig pits. HSE at the Wellsite Health • All rig personnel should have access to current/up to date MSDS sheets and PPE required by MSDS sheets for every drilling fluid product on location.An MSDS book must be retained in the rig pits,and Mud Lab. These books will be maintained by the onsite mud engineer.Additionally quick reference PPE charts for specific products will be posted in the rig pits and the mud lab.These charts are by no means an MSDS replacement. Always read and adhere to the MSDS sheet prior to handling any drilling fluid products. • Rig Crew Pretour meetings are a good platform to discuss upcoming product mixes and HSE requirements. Environment • Ensure all sack products stored outside are shielded from the arctic weather with plastic or a box. • Do not store single sacks outside of a box. • Attempt to use all opened,partial sacks. • Proper planning for necessary products in the pits will diminish the"Hurry up"factor. Properly planned events create less opportunity for mishaps. 18 • • HALLIBtJRTDPJ illir ems, o;d REPJOL Qugruk-5 ver. 3.1 Prudhoe Bay AK/U.S.A. NFPA Ratings Product Name Health Flammability Reactivity PPE Aldacide G 3 0 0 respirator,rubber gloves,rubber apron,chemical goggles,face shield Baracarb 1 0 0 coveralls,work gloves,safety glasses Baracor 700 1 2 0 rubber gloves,chemical goggles,coveralls BaraDefoam HP 1 0 0 coveralls,rubber gloves,rubber apron,chemical goggles BaraKlean 1 1 0 respirator,rubber gloves,rubber apron,chemical goggles,face shield BDF-515 1 0 0 dust mask,coveralls,work gloves,safety glasses Barascav D 2 0 0 dust mask,coveralls,work gloves,safety glasses Barazan D+ 0 0 0 coveralls,work gloves,safety glasses Barofibre 0 0 0 coveralls,work gloves,safety glasses Baroid 1 0 0 dust mask,coveralls,work gloves,safety glasses Baroseal 1 0 0 coveralls,work gloves,safety glasses Barotrol Plus 1 0 0 dust mask,coveralls,work gloves,safety glasses BDF-499 1 0 0 rubber gloves,rubber apron,chemical goggles,face shield Bicarbonate of soda 0 0 0 coveralls,work gloves,safety glasses Carbonox 0 1 0 coveralls,work gloves,safety glasses Caustic Soda 4 0 0 respirator,rubber gloves,rubber apron,chemical goggles,face shield CFS-520 1 0 0 coveralls,rubber gloves,rubber apron,safety goggles Citric Acid Anhydrous 1 0 0 respirator,rubber gloves,rubber apron,chemical goggles,face shield Desco CF 1 0 0 coveralls,work gloves,safety glasses Dextrid LT 0 0 0 coveralls,work gloves,safety glasses Dril-N-Slide 0 0 0 coveralls,work gloves,safety glasses EP Mudlube 1 1 0 rubber gloves,chemical goggles,coveralls EZ Glide 1 1 0 rubber gloves,safety glasses,coveralls EZ-Mud DP 1 1 0 dust mask,gloves,safety glasses Geovis XTL 1 1 0 dust mask,gloves,safety glasses Mica fine 1 0 0 coveralls,work gloves,safety glasses N-Dril HT+ 0 0 0 coveralls,work gloves,safety glasses No-Sulf 1 0 0 dust mask,coveralls,work gloves,safety glasses N-Vis 0 0 0 coveralls,work gloves,safety glasses NXS-Lube 1 1 0 rubber gloves,safety glasses,coveralls PAC-L 0 0 0 coveralls,work gloves,safety glasses Potassium Chloride 1 0 0 coveralls,work gloves,safety glasses Potassium Hydroxide(KOH) 3 0 1 respirator,rubber gloves,rubber apron,chemical goggles,face shield SAPP 1 0 0 dust mask,coveralls,work gloves,safety glasses Soda Ash 2 0 0 respirator,rubber gloves,rubber apron,chemical goggles,face shield Sodium Bromide 2 0 0 dust mask,coveralls,work gloves,safety glasses Sodium Chloride 0 0 0 dust mask,coveralls,work gloves,safety glasses Steel Seal 1 0 0 coveralls,work gloves,safety glasses Stick-Less 20 0 0 0 dust mask,coveralls,work gloves,safety glasses Therma Thin 1 0 0 rubber gloves,chemical goggles,coveralls Wall-Nut M 0 0 0 coveralls,work gloves,safety glasses X-Cide 207 3 0 0 rubber gloves,rubber apron,chemical goggles,face shield X-Tend II 1 1 0 rubber gloves,chemical goggles,coveralls 19 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • 71 Y,N Mi- 1, k 1 A3 L l,IR, ._:-- E-. EC K I J ' 1. WELL NAME: - JC S A- . .e z V_C3 - -- t)cvelopmcnt Scry icy.. ✓ I..xhloi-aiory Stimigraphic.i cst Non-(Sonventional FIELD):EL ): 9Y '—y-- hOCyL: Check Box for Appropriae Letter/ Paragraphs to be Includes; in Transmittai 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- - - - (lf last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) - In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. / All dry ditch sample sets submitted to the AOGCC must be in no greater ✓/ Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: / Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 5/2013 - • 46 ❑ ❑ @o co c a) n a) N cn c a) O .a o @ Q a) c Q •c HI 0 L ' ° m. E : cc = w C N N CZ E O ° ' cc d Y 2 0 co c 3. 0 co d c p. N, c; p, U 3 s, g ° o @, 00 � co o o _n o Q 00 3 N, oc$ 45 U) Y. a) a) co (0 0 7= m �: c a) 0. '7) �O : w. . .c . j: J m c 0. 3' O w 0), 4:: 0, a °' w. C co' 3. U o • o 0 a •• a' o c c) tp Q O °? a 0 f6 ° ° o Yo co a @' ° 3' to • m a @ ° m _ v' o O 0) ° u U c < o m' CO O ° m 4 ° 3 0 2 • 0O 0 -0 �. c) .Q Q CO v) 0' U 3 co 0 ON; ° ° aoi co Q 3 ° co a n n a o Mo La X Z O N Ty °) O U' a) 0Hd . , Na X Z CD 0 , crnoam ; Q (DUo o E o w < O w U co Nm Dco c 3M 'imM I w. waOF Y Q• U . c a 15 X p w to n Q < U)) U)) o U)) aa)) U)):. U)) a CO aa)) a aa): < < < < < < aa)): a 0), aa; aa; aa, < a); ay); aa; a); aa; o, < o aa; < < a) . z z > >- z >- >- >- >- >- >- >- >- > z z z z z z } >- >- >- >- > Z > > > >- > ZZ Z > ZZ > >, ° N coa U ---0 O @ U) c E 3 E ° O, U U c a) c 4k, co O 0' 5U N LL T � . Q ^>, c E A C d o 4k p.. C >t 0 -°O 3 E0 3 0: O co w' ° U C' O' o o w N a NN Ny DE o CD a �� o n 71 o - N LL 0 C 0) y' Q IL a) a a '0 0 y: ,� g CC; y 0) 0. CD 0 a 't 0 n • o a'co co aco E NI m dfli C (n @ C > °' N.� 0 o "4o CC ' _: a)V O' us: E a) N. "3 O M -° O 7 co y N O "- O) U' 0 0 c N' co c co -c C' ° 0 O' 1' C C C cn a) d p) .. _ o o S o' 0 °' c a �, c ° CO. p o m ° ;� a' c c O c O s,,i CO E E = 43 c c' E Lo CO a o c c > I' °. o O otS °)' r ° a N' .c n c c @ c o c c ° m c co O o -o :°: o a a) o 0 0 p 0 0) 0 ( .a _ ° a)' 0 uS d °, a 3 0 >' 0. 4' Y a) • o o ° ° S 0 °' a CO Y 2' o o ° as co ° @ '� Q m. �, N o, co p. ° ° cn U n ° r o' o ° c ° m - @ o: c.2 E' E 3 °' a) s m' 3' w ° c 'E Z E m cc o :° cg co o. n °= s. w @ 0 -7o a) co ` c' c ° y' co @ .N co, c o 0 o a 3' -,c, -.a. 0 --- s; c E TD cp ° n c c =o =o 7,' ° f0 3 3 a) E a> .. o f :, 3 2 O o n. ai 0 q co 0 3 ° m a) `o w o > P. v o v' ° ° a s 3' @' o co Z' U d D c 'O O @ .� @ LO ° p N N O @ E O p O O. C. N O o N -O E' N @ E' rn O a) 0- co - C 05 LL O _c a ° "° a. a ° 7 N Q ai. N.. a • V y n O ° ° - @ U ' U -O @ E c 0 . N E CO CO o c 0 N @ @ O O O 3 ci c/) V) O 0- N 2 2 @ 2 1' O) 3 'p cn -° �S, @ U E @ 3 @ @ @ � c o ° o @' w p >. ' � 2 c !D � .N o n ° w m :° c a a ° o x a) a) ° 3 S 'p c O• °r a`), ,. c' @ 3. a _c m o �, o o. ° a) >, - a) 11 _J (6 4 _ O "O "O U " C' co 9. -0 -. -O L a) in "5 a) 0 > .Ot ca. .0 ° N co U' U d� c. @. _ O C E �) w a) @ -. N 0 v V O v) _ > '0 0 (0 C 0. CO° a) C, o. COE 0 °� ' 0 • @ o o �' v o o a) 0 0 U' m ..0 0 "C. U) fl E '3 C .C, `� CO 0', v; �, �� (/) w O - (DC 0 0 0 O .0 . @ @ • • n O N - 3 0 > > 3' c O d O a) c) w, w a) a CO " 0- E ° @ N -f cr c E m °- a) a) a) E <'.) a) ° E c a) 3 a) C .0 H I- 1; "E y c > _ a a, o Y`o' a U•. E co U; o c. m > o ° a) c 7 -0 0- a 'Cr) ° @ o =; 2' 2 2 co -O @ 'CI °, C O; O .0 ° a) @ a) 0 0 0 V cza � D555cn200an. U ¢ a ococioc� U ¢ � Q � ommUsaoCcn0, (0 n = E - N M4 to OI-. 00 O 0 � N� C.) C� � 0�0 0�._) O N C°\14 M NV toN N IV- 0N N O M MN MM V Mo cM nM 003 OM) U O U Iv v v `m C N O CO 0 j 0 O U o ce NO 0 c6 (N 03 N @ N m U CO N- (z) 0) O N CI N- O y "' / d V Y ch r co co a) E J N - N O) E ^ C c ` 0 O �) w o E n co o a J 0 a Y 0 d Q Q w a O W a LL • . 5 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Repsol E&P USA Nabors 105-E Qugruk-5A Final Well Test Report Test No. 2 Sunday 13th April, 2014 12:35 hrs. THRU Wednesday 16 April, 2014 22:00 hrs. PAGE No. Disclaimer 3 Cover Letter 4 Well Information Data Sheet 5 Well Test Report (15 min) 6 Well Head Plot 12 Well Head & Bottom Hole Plot 13 Bottom Hole Plot 14 Separator Plot 15 Production Plot 16 Cumulative Plot 17 Sequence of Events 18 Diagram - P&ID 77 WT Equipment Layout 79 This report is based on sound engineering practices, but because of variable well conditions and other information which must be relied upon, the Expro Group makes no warranty, express or implied, as to the accuracy of the data or any calculations or opinions expressed herein. You agree that the Expro Group shall not be liable for any loss of damage whether due to negligence or otherwise arising out of or in connection with such data, calculations, or opinions. Index Qugruk-5A Final Flowback Report Test No. 2 In no event will Expro be liable for failure to obtain any particular results or for any damages, including but not limited to, indirect, special or consequential damages, whether due to negligence or otherwise arising out of or in connection with such use of data, calculations, recommendations or opinions provided by Expro. Expro Well Testing will use its best efforts to furnish customers with accurate information and interpretations as a part of, and incident to, the services provided. However, Expro cannot and does not warrant the accuracy or correctness of such information or interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any decision regarding drilling, completion, production, financing or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. D I S C L A I M E R These calculations are based on certain data, assumptions and applied mathematical methods. Inaccurate well data, changing well conditions, tolerance variations of mechanical components, mechanical malfunctions and other factors may affect these calculations. Expro Americas, LLC 4141 B Street Suite 302 Anchorage, Alaska 99503 Tel: (907) 751-8700 Fax: (907) 344-5079 www.exprogroup.com Repsol E&P USA Inc. 3800 Centerpoint Dr Ste 400 Anchorage, AK 99503-5826 Cordially, Roland Taylor Expro Supervisor 1 Mobile: 907.980.2560 Email: roland.taylor@exprogroup.com Lonny Tucker Sharon Oyao Operations Supervisor Well Test Engineer 907.335.6601 907.335-6602 Please find enclosed Well Test Report corresponding to the operations performed during Ref: Well Test Qugruk-5A_Test No. 2 Monday, May 05, 2014 13th - 16th of April 2014 on Qugruk-5A Drill Site. The following report is compiled from information collected through manual readings and Expro's computerized Data Acquisition System. The overall operation conducted for the Qugruk - 5A well was a standard Drill Stem Test (DST). The well effluent was diverted through a sand extrusion vessel then to a separator. The well's liquid production was taken to 400 barrel tanks and measured. The gas rate was measured through a gas meter installed on the separator's gas run then diverted to the flare stack and burnt at the flare tip. If there are any questions regarding the contents of this report, please contact Roland Taylor. Client REPSOL E&P USA Field QUGRUK Well No. QUGRUK-5A Test No. NO. 2 Start Date 13-Apr-2014 12:35 Location QUGRUK DRILL SITE Country U.S.A Well Type EXPLORATION / OIL PRODUCER Final Depth 8,015' MD / 7,009 TVD Reservoir Depth 7,628' MD / 6,700 TVD Target Reservoir Nuiqsuit 200 Repsol Completion Engineer David Ross Expro Job No.2530447 Expro Engineer Sharon Oyao Expro Project Manager Roland Taylor Report Approved By (CHS) : Date: Report Approved By (Welltest) : Date: Well Information Expro Confidential 5/6/2014 Page 6 CUSTOMER:TEST No: CUSTOMER REP:START DATE: EXPRO SUPERVISOR:END DATE: WELL NUMBER: Comments Ratio Methanol Time & Date El a p s e d T i m e Ch o k e S i z e M a n u a l Re a d WH P @ t h e We l l h e a d WH T @ S w a b Do wn S t r e a m Ch o k e Di f f P r e s s A c r o s s Ch o k e Bo t t o m H o l e Pr e s s u r e ( L o w e r Ga u g e ) Bo t t o m H o l e Te m p e r a t u r e An n u l u s P r e s s u r e N it r o g e n I n j e c t i o n To t a l F l u i d s Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r M ud & S e d i m e n t Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r T ot a l F l u i d In c r e m e n t Pr e s s u r e @ M e t e r Ru n Ga s T e m p e r a t u r e @ M e t e r R u n Oi l T e m p e r a t u r e @ Oi l L e g Or i f a c e P l a t e S i z e Oi l G r a v i t y M a n u a l Re a d Oi l G r a v i t y M a n u a l Re a d ( C o r r e c t e d ) Wa t e r G r a v i t y Ma n u a l R e a d Wa t e r S a l i n i t y Ma n u a l R e a d Wa t e r p H M a n u a l Re a d BS & W S h a k e o u t s S ol i d s , M u d , Em u l s i o n Wa t e r C u t Ga s G r a v i t y Ra n a r e x M a n u a l Re a d CO 2 D r a g e r M a n u a l Re a d H² S D r a g e r M a n u a l Re a d GO R O il Mu d Ga s @ E X P R O Se p a r a t o r Wa t e r C a l c . f r o m Sa m p l e s To t a l F l u i d S ur f a c e I n j e c t i o n Ma n u a l R e a d (dd-mmm-yy hh:mm)(hours)Initial WHP 2166.1 psig Initial BHP 5347.3 psig (64ths)(psig)(F)(psi)(psig)(psig)(F)(psig)(scf/min)(stb/d)(stb/d)(MMscf/d)(stb/d)stb/d (stb)(MMscf)(stb)(stb)(psig)(F)(F)(inches)(SG60)(API60)(API60)(ppm)(pH)(%)(%)(%)(Air=1)(%)(ppm)(Mscfd/bbls)(stb)(stb)(MMscf)(stb)(stb)(gal/day) 13-Apr-14 12:35 0:00:00 Open well to Expro's choke on 10/64ths adjustable choke 10 2165.60 57 53 1793.14 5347.27 165.58 1548.50 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 46.24 66.02 70.56 0.00 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.000000 0.00 0.00 13-Apr-14 12:45 0:10:00 Increase choke to 12/64ths (12:37 hrs) 12 1927.14 54 55 1869.23 5109.56 165.55 1523.48 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 49.17 66.29 70.73 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.000000 0.00 0.00 13-Apr-14 13:00 0:25:00 Increase choke to 16/64ths (13:10 hrs). Gas SG 0.972 12 1680.49 50 46 1636.78 4862.89 165.52 1513.91 0.00 0.00 0.00 0.312060 0.00 0.00 0.00 0.003251 0.00 0.00 58.93 66.62 69.92 1.25 N/R 100.00 0.00 100.00 0.972 N/R 0.00 0.00 0.003251 0.00 0.00 13-Apr-14 13:15 0:40:00 16 1225.34 45 66 1153.83 4415.68 165.49 1492.88 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 64.79 70.54 68.89 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.003251 0.00 0.00 13-Apr-14 13:30 0:55:00 16 812.67 42 71 731.65 3995.55 165.46 1462.85 0.00 0.00 0.00 0.717650 0.00 0.00 0.00 0.007476 0.00 0.00 76.55 74.45 67.84 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.010726 0.00 0.00 13-Apr-14 13:45 1:10:00 ** Note: Gas rates at separator represents Nitrogen returned 16 540.29 43 45 492.59 3722.22 165.43 1459.79 0.00 0.00 0.00 0.515659 0.00 0.00 0.00 0.005371 0.00 0.00 60.47 74.11 67.63 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.016098 0.00 0.00 13-Apr-14 14:00 1:25:00 16 363.61 45 36 327.47 3540.48 165.42 1514.87 0.00 0.00 0.00 0.346568 0.00 0.00 0.00 0.003610 0.00 0.00 48.02 73.30 67.32 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.019708 0.00 0.00 13-Apr-14 14:15 1:40:00 16 107.42 39 12 91.21 3334.76 165.46 1505.88 0.00 0.00 0.00 0.187888 0.00 0.00 0.00 0.001957 0.00 0.00 33.02 71.05 66.26 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.021665 0.00 0.00 13-Apr-14 14:30 1:55:00 ** Fluid to surface. Increase choke to 60/64ths. wt 9.9 ppg. Salinity 260000 ppm 60 288.30 41 5 293.92 3420.72 166.11 1536.10 0.00 0.00 0.00 0.018605 0.00 0.00 0.00 0.000194 0.00 0.00 10.86 68.45 91.54 1.75 N/R 260000 100.00 0.00 100.00 N/R 0.00 0.00 0.021859 0.00 0.00 13-Apr-14 14:45 2:10:00 N2 online @300 scf/min (14:38 hrs)60 64.07 38 15 39.46 3278.12 166.68 1543.18 300.00 297.60 0.00 0.016862 297.60 0.00 0.00 0.000176 3.10 3.10 14.79 66.99 97.79 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.022034 3.10 3.10 13-Apr-14 15:00 2:25:00 Bypass Separator 60 17.81 40 7 0.54 3253.69 167.52 1571.68 300.00 297.60 0.00 0.016501 297.60 0.00 0.00 0.000172 3.10 3.10 16.44 65.52 96.77 0.00 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.022206 6.20 6.20 13-Apr-14 15:15 2:40:00 N2 offline (15:14 hrs)60 24.92 41 11 0.91 3179.53 168.14 1574.55 0.00 148.80 0.00 0.016791 148.80 0.00 0.00 0.000175 1.55 1.55 15.98 64.69 91.20 0.00 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.022381 7.75 7.75 13-Apr-14 15:30 2:55:00 60 25.99 41 12 3.99 3160.77 168.43 1509.71 0.00 297.60 0.00 0.016673 297.60 0.00 0.00 0.000174 3.10 3.10 16.04 63.74 87.94 0.00 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.022555 10.85 10.85 13-Apr-14 15:45 3:10:00 N2 back online @ 500 scf/min. Decrease choke to 32/64ths (15:53 hrs)60 29.59 41 12 2.20 3136.89 168.52 1521.18 500.00 0.00 0.00 0.016915 0.00 0.00 0.00 0.000176 0.00 0.00 16.14 62.71 85.31 0.00 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.022731 10.85 10.85 13-Apr-14 16:00 3:25:00 Fluid wt 8.6 ppg. Salinity 50000 ppm 32 339.68 38 75 249.14 2975.70 168.64 1459.21 500.00 1190.40 0.00 0.308611 1190.40 0.00 0.00 0.003215 12.40 12.40 50.33 68.79 95.19 1.75 N/R 50000 100.00 0.00 100.00 N/R 0.00 0.00 0.025946 23.25 23.25 13-Apr-14 16:15 3:40:00 32 377.83 40 90 280.35 2816.87 168.97 1518.89 500.00 223.20 0.00 0.499521 223.20 0.00 0.00 0.005203 2.33 2.33 64.47 75.85 118.58 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.031149 25.58 25.58 13-Apr-14 16:30 3:55:00 N2 rate decrease to 300 scf/min (16:40 hrs) 32 113.53 38 40 63.72 2729.38 169.22 1500.91 300.00 148.80 0.00 0.619986 148.80 0.00 0.00 0.006458 1.55 1.55 79.02 79.56 122.15 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.037607 27.13 27.13 13-Apr-14 16:45 4:10:00 32 43.73 42 41 -2.81 2623.51 169.33 1486.37 300.00 74.40 0.00 0.198694 74.40 0.00 0.00 0.002070 0.78 0.78 38.72 78.43 121.88 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.039677 27.90 27.90 13-Apr-14 17:00 4:25:00 N2 rate increase to 500 scf/min 32 1.15 46 0 1.33 2699.95 169.32 1502.44 500.00 148.80 0.00 0.000000 148.80 0.00 0.00 0.000000 1.55 1.55 50.48 74.51 111.10 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.039677 29.45 29.45 13-Apr-14 17:15 4:40:00 32 0.00 49 0 0.00 2899.15 169.14 1504.54 500.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 50.27 71.09 106.28 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.039677 29.45 29.45 13-Apr-14 17:30 4:55:00 Increase choke to 22/64ths (17:34 hrs) 32 331.04 44 59 256.91 2790.01 168.83 1561.35 500.00 818.40 0.00 0.000000 818.40 0.00 0.00 0.000000 8.53 8.53 49.76 69.18 102.42 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.039677 37.98 37.98 13-Apr-14 17:45 5:10:00 22 489.74 48 118 366.04 2585.18 168.97 1476.43 500.00 1041.60 0.00 0.673528 1041.60 0.00 0.00 0.007016 10.85 10.85 110.93 76.96 111.54 1.75 N/R 100.00 0.00 100.00 N/R 0.00 0.00 0.046693 48.83 48.83 13-Apr-14 18:00 5:25:00 BS&W: 99% Brine & 1% Sediment 22 344.57 44 73 261.95 2489.75 169.31 1524.05 500.00 148.80 0.00 0.509290 147.31 1.49 0.00 0.005305 1.53 1.55 84.00 82.31 127.61 1.75 N/R 100.00 1.00 99.00 N/R 0.00 0.03 0.051998 50.36 50.39 13-Apr-14 18:15 5:40:00 Increase choke to 30/64th 30 330.35 46 97 221.48 2432.97 169.45 1536.29 500.00 669.60 0.00 0.549001 662.90 6.70 0.00 0.005719 6.91 6.98 91.98 79.41 104.81 1.75 N/R 100.00 1.00 99.00 N/R 0.00 0.17 0.057717 57.26 57.44 13-Apr-14 18:30 5:55:00 BS&W: 99% Brine & 1% Sediment 30 359.71 45 84 269.09 2305.27 169.55 1476.81 500.00 372.00 0.00 0.481846 368.28 3.72 0.00 0.005019 3.84 3.88 80.48 81.18 124.47 1.75 N/R 100.00 1.00 99.00 N/R 0.00 0.25 0.062736 61.10 61.35 13-Apr-14 18:45 6:10:00 BHP=2306 psi BHT=170 F 30 332.65 44 64 258.87 2298.12 169.62 1537.25 500.00 297.60 0.00 0.336350 294.62 2.98 0.00 0.003504 3.07 3.10 74.23 81.60 131.49 1.75 N/R 100.00 1.00 99.00 N/R 0.00 0.31 0.066240 64.17 64.48 13-Apr-14 19:00 6:25:00 BS&W: 96% Brine & 4% Sediment 30 406.27 48 109 281.31 2170.31 169.63 1473.75 500.00 520.80 0.00 0.646118 499.97 20.83 0.00 0.006730 5.21 5.43 92.63 80.59 110.11 1.75 N/R 100.00 4.00 96.00 N/R 0.00 0.74 0.072970 69.38 70.12 13-Apr-14 19:15 6:40:00 30 352.75 48 121 218.89 1958.08 169.73 1507.99 500.00 297.60 0.00 0.920898 285.70 11.90 0.00 0.009593 2.98 3.10 115.69 81.01 115.59 1.75 N/R 100.00 4.00 96.00 N/R 0.00 0.99 0.082563 72.35 73.35 13-Apr-14 19:30 6:55:00 BS&W: 89% Brine & 11% Sediment 30 300.23 47 102 186.28 1843.16 169.85 1522.14 500.00 595.20 0.00 0.796191 529.73 65.47 0.00 0.008294 5.52 6.20 99.18 83.43 125.12 1.75 N/R 100.00 11.00 89.00 N/R 0.00 2.36 0.090856 77.87 80.23 13-Apr-14 19:45 7:10:00 30 268.20 46 92 169.60 1783.58 169.88 1549.87 500.00 669.60 0.00 0.695878 595.94 73.66 0.00 0.007249 6.21 6.98 87.84 85.59 131.65 1.75 N/R 100.00 11.00 89.00 N/R 0.00 3.89 0.098105 84.08 87.97 13-Apr-14 20:00 7:25:00 BS&W: 96% Brine & 4% Sediment. Sparge separator. Fluid wt 8.75 lb/Gal 30 275.54 45 91 174.24 1750.55 169.90 1566.70 500.00 595.20 0.00 0.615427 571.39 23.81 0.00 0.006411 5.95 6.20 86.76 86.17 137.76 1.75 N/R 48000 100.00 4.00 96.00 N/R 0.00 4.39 0.104516 90.03 94.42 13-Apr-14 20:15 7:40:00 30 260.70 44 93 154.97 1694.44 169.89 1555.42 500.00 148.80 0.00 0.660364 142.85 5.95 0.00 0.006879 1.49 1.55 94.16 85.68 124.03 1.75 N/R 100.00 4.00 96.00 N/R 0.00 4.51 0.111395 91.52 96.03 13-Apr-14 20:30 7:55:00 BS&W: 97%Brine & 3% Sediment. Sparge separator and sandtrap 30 247.55 43 110 136.26 1677.02 169.89 1500.53 500.00 0.00 0.00 0.590542 0.00 0.00 0.00 0.006151 0.00 0.00 94.77 88.18 137.74 1.75 N/R 100.00 3.00 97.00 N/R 0.00 4.51 0.117546 91.52 96.03 13-Apr-14 20:45 8:10:00 30 287.08 42 94 184.52 1640.76 169.84 1550.26 500.00 0.00 0.00 0.622885 0.00 0.00 0.00 0.006488 0.00 0.00 102.59 88.89 140.66 1.75 N/R 100.00 3.00 97.00 N/R 0.00 4.51 0.124034 91.52 96.03 13-Apr-14 21:00 8:25:00 BS&W: 96% Brine & 4% Sediment. N2 pump offline 30 264.07 41 96 164.38 1637.40 169.81 1534.38 0.00 0.00 0.00 0.594530 0.00 0.00 0.00 0.006193 0.00 0.00 97.73 89.08 142.45 1.75 N/R 100.00 4.00 96.00 N/R 0.00 4.51 0.130227 91.52 96.03 13-Apr-14 21:15 8:40:00 Start pumping N2 @ 500 scf/min 30 217.35 43 80 133.52 1558.23 169.77 1513.34 500.00 74.40 0.00 0.542973 71.42 2.98 0.00 0.005656 0.74 0.78 91.15 90.13 133.09 1.75 N/R 100.00 4.00 96.00 N/R 0.00 4.57 0.135883 92.26 96.84 13-Apr-14 21:30 8:55:00 BS&W: 97% Brine & 3% Sediment. Start pumping brine @1.8 bbls/min 30 141.36 41 65 75.14 1578.40 169.77 1513.72 1000.00 0.00 0.00 0.375862 0.00 0.00 0.00 0.003915 0.00 0.00 78.16 89.52 122.71 1.75 N/R 100.00 3.00 97.00 N/R 0.00 4.57 0.139799 92.26 96.84 13-Apr-14 21:45 9:10:00 30 361.01 38 115 236.53 1894.55 169.69 1538.40 1000.00 0.00 0.00 0.315138 0.00 0.00 0.00 0.003283 0.00 0.00 80.59 89.25 140.69 1.75 N/R 100.00 3.00 97.00 N/R 0.00 4.57 0.143081 92.26 96.84 13-Apr-14 22:00 9:25:00 BS&W: 97% Brine & 3% Sediment 30 1039.31 57 234 782.20 2942.89 169.52 1464.76 1000.00 446.40 0.00 1.601971 433.01 13.39 0.00 0.016687 4.51 4.65 135.90 79.48 102.59 1.75 N/R 100.00 3.00 97.00 N/R 0.00 4.85 0.159768 96.77 101.63 13-Apr-14 22:15 9:40:00 30 754.20 63 140 598.54 2958.83 169.18 1487.33 1000.00 595.20 0.00 1.394361 577.34 17.86 0.00 0.014525 6.01 6.20 108.97 79.14 97.70 1.75 N/R 100.00 3.00 97.00 N/R 0.00 5.22 0.174293 102.79 108.01 13-Apr-14 22:30 9:55:00 BS&W: 96%Brine & 4% Sediment. Sparge separator 34 815.03 65 217 567.78 3021.31 168.80 1525.77 1000.00 1636.80 0.00 0.716023 1571.33 65.47 0.00 0.007459 16.37 17.05 107.21 75.90 92.82 1.75 N/R 100.00 4.00 96.00 N/R 0.00 6.59 0.181752 119.16 125.74 13-Apr-14 22:45 10:10:00 34 845.10 68 202 619.93 3037.52 167.09 1562.30 1000.00 1860.00 0.00 1.322503 1785.60 74.40 0.00 0.013776 18.60 19.38 129.17 73.88 90.55 1.75 N/R 100.00 4.00 96.00 N/R 0.00 8.14 0.195528 137.76 145.89 13-Apr-14 23:00 10:25:00 BS&W: 95% Brine & 5% Sediment 42 717.81 70 255 403.67 3490.39 164.60 1486.18 1000.00 2232.00 0.00 1.539938 2120.40 111.60 0.00 0.016041 22.09 23.25 111.60 71.43 85.79 1.75 N/R 100.00 5.00 95.00 N/R 0.00 10.46 0.211569 159.84 170.31 13-Apr-14 23:15 10:40:00 Sparge sand trap and separator. Red sheen on sample surface (23:00 hrs)42 430.28 72 146 247.25 2819.75 160.71 1447.74 1000.00 1636.80 0.00 1.349343 1554.96 81.84 0.00 0.014056 16.20 17.05 117.16 72.71 94.26 1.75 N/R 100.00 5.00 95.00 N/R 0.00 12.17 0.225624 176.04 188.21 13-Apr-14 23:30 10:55:00 BS&W: 93% Brine & 7% Sediment 42 598.07 72 202 347.13 3149.75 158.39 1461.13 1000.00 2048.11 0.00 0.915135 1904.74 143.37 0.00 0.009533 19.84 21.33 109.39 72.75 93.00 1.75 N/R 100.00 7.00 93.00 N/R 0.00 15.15 0.235157 195.88 211.04 13-Apr-14 23:45 11:10:00 44 534.35 72 218 252.04 2903.73 156.82 1451.56 1000.00 2436.96 0.00 1.335563 2266.37 170.59 0.00 0.013912 23.61 25.39 120.54 71.67 92.30 1.75 N/R 100.00 7.00 93.00 N/R 0.00 18.71 0.249069 219.49 238.20 14-Apr-14 00:00 11:25:00 BS&W: 90% Brine & 10% Sediment. H2O: 8.75lb/Gal 44 456.09 73 202 194.24 2508.80 156.01 1461.70 1000.00 1440.29 0.00 1.396534 1296.26 144.03 0.00 0.014547 13.50 15.00 119.89 71.99 94.28 1.75 N/R 48000 100.00 10.00 90.00 N/R 0.00 21.71 0.263616 232.99 254.70 14-Apr-14 00:15 11:40:00 44 398.93 73 181 163.20 2263.60 157.11 1465.14 1000.00 2080.42 0.00 1.326766 1872.37 208.04 0.00 0.013820 19.50 21.67 118.29 71.80 93.61 1.75 N/R 100.00 10.00 90.00 N/R 0.00 26.04 0.277437 252.50 278.54 14-Apr-14 00:30 11:55:00 BS&W: 99% Brine & 1% Sediment. Coil at 1100ft 42 314.91 73 157 116.07 2150.55 158.37 1459.40 1000.00 2960.59 0.00 1.251243 2930.99 29.61 0.00 0.013034 30.53 30.84 111.55 72.38 96.51 1.75 N/R 100.00 1.00 99.00 N/R 0.00 26.66 0.290471 283.03 309.69 14-Apr-14 00:45 12:10:01 Stop pumping brine. Pumped 260 bbls 42 324.92 70 179 119.79 1944.52 159.82 1425.74 1000.00 1920.38 0.00 0.949302 1901.18 19.20 0.00 0.009889 19.80 20.00 110.79 73.36 98.12 1.75 N/R 100.00 1.00 99.00 N/R 0.00 27.06 0.300359 302.83 329.89 14-Apr-14 01:00 12:25:00 BS&W: 99%Brine & 1% Sediment. Sparge sand trap 42 265.37 67 165 76.41 1883.90 161.59 1401.07 300.00 560.11 0.00 1.366424 554.51 5.60 0.00 0.014234 5.78 5.83 126.27 77.98 112.43 1.75 N/R 100.00 1.00 99.00 N/R 0.00 27.18 0.314593 308.61 335.78 14-Apr-14 01:15 12:40:00 42 129.28 64 97 15.30 1736.52 163.25 1481.78 300.00 320.06 0.00 1.358123 316.86 3.20 0.00 0.014147 3.30 3.33 113.38 84.08 111.21 1.75 N/R 100.00 1.00 99.00 N/R 0.00 27.24 0.328740 311.91 339.15 14-Apr-14 01:30 12:55:00 No Fluid Returns 30 132.72 61 86 48.74 1738.54 164.53 1451.94 300.00 160.03 0.00 0.734795 160.03 0.00 0.00 0.007654 1.67 1.67 93.32 85.09 109.38 1.75 N/R 100.00 0.00 100.00 N/R 0.00 27.24 0.336394 313.58 340.82 14-Apr-14 01:45 13:10:00 30 41.59 60 38 3.51 1806.87 165.04 1440.66 300.00 0.00 0.00 0.350669 0.00 0.00 0.00 0.003653 0.00 0.00 68.34 81.73 106.71 1.75 N/R 0.00 N/R 0.00 27.24 0.340047 313.58 340.82 14-Apr-14 02:00 13:25:00 No Fluid Returns 20 50.76 59 46 3.86 1921.87 165.28 1423.25 300.00 0.00 0.00 0.042094 0.00 0.00 0.00 0.000438 0.00 0.00 50.79 77.59 100.10 1.75 N/R 0.00 N/R 0.00 27.24 0.340485 313.58 340.82 14-Apr-14 02:15 13:40:00 20 66.28 57 63 -4.75 2027.50 165.39 1494.21 300.00 0.00 0.00 0.033601 0.00 0.00 0.00 0.000350 0.00 0.00 64.37 73.91 95.83 1.75 N/R 0.00 N/R 0.00 27.24 0.340835 313.58 340.82 14-Apr-14 02:30 13:55:00 Fluid at separator. No cut for BS&W 20 391.90 53 102 286.01 2080.67 165.47 1483.89 300.00 0.00 0.00 0.039653 0.00 0.00 0.00 0.000413 0.00 0.00 81.99 71.95 96.15 1.75 N/R 0.00 N/R 0.00 27.24 0.341248 313.58 340.82 14-Apr-14 02:45 14:10:00 20 293.96 51 95 195.88 2062.47 165.53 1472.60 300.00 0.00 0.00 0.361629 0.00 0.00 0.00 0.003767 0.00 0.00 94.20 78.77 118.90 1.75 N/R 0.00 N/R 0.00 27.24 0.345015 313.58 340.82 14-Apr-14 03:00 14:25:00 No Fluid Returns 20 111.77 56 56 50.25 2000.80 165.79 1514.68 300.00 0.00 0.00 0.299994 0.00 0.00 0.00 0.003125 0.00 0.00 74.08 80.41 115.15 1.75 N/R 0.00 N/R 0.00 27.24 0.348140 313.58 340.82 14-Apr-14 03:15 14:40:00 20 55.81 56 51 0.69 2097.28 166.07 1503.20 300.00 0.00 0.00 0.103984 0.00 0.00 0.00 0.001083 0.00 0.00 56.41 78.22 109.50 1.75 N/R 0.00 N/R 0.00 27.24 0.349223 313.58 340.82 14-Apr-14 03:30 14:55:00 No Fluid Returns 20 33.26 57 32 -3.57 2227.29 166.09 1495.55 300.00 0.00 0.00 0.038941 0.00 0.00 0.00 0.000406 0.00 0.00 49.01 75.15 105.94 1.75 N/R 0.00 N/R 0.00 27.24 0.349629 313.58 340.82 14-Apr-14 03:45 15:10:00 20 31.65 58 30 -3.95 2243.26 166.01 1494.02 300.00 0.00 0.00 0.026494 0.00 0.00 0.00 0.000276 0.00 0.00 36.20 72.12 103.16 1.75 N/R 0.00 N/R 0.00 27.24 0.349905 313.58 340.82 Repsol E&P USA David Ross 2 April 13, 2014 April 16, 2014 Time Rates SeparatorVolumes (15 mins)Choke BS&W Properties 12:35 hrs Casing Roland Taylor Qugruk-5A Cumulatives Well Test Report (15 min) Gas PropertiesFluid Properties 22:00 hrs Expro Confidential 5/6/2014 Page 7 CUSTOMER:TEST No: CUSTOMER REP:START DATE: EXPRO SUPERVISOR:END DATE: WELL NUMBER: Comments Ratio Methanol Time & Date El a p s e d T i m e Ch o k e S i z e M a n u a l Re a d WH P @ t h e We l l h e a d WH T @ S w a b Do wn S t r e a m Ch o k e Di f f P r e s s A c r o s s Ch o k e Bo t t o m H o l e Pr e s s u r e ( L o w e r Ga u g e ) Bo t t o m H o l e Te m p e r a t u r e An n u l u s P r e s s u r e N it r o g e n I n j e c t i o n To t a l F l u i d s Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r M ud & S e d i m e n t Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r T ot a l F l u i d In c r e m e n t Pr e s s u r e @ M e t e r Ru n Ga s T e m p e r a t u r e @ M e t e r R u n Oi l T e m p e r a t u r e @ Oi l L e g Or i f a c e P l a t e S i z e Oi l G r a v i t y M a n u a l Re a d Oi l G r a v i t y M a n u a l Re a d ( C o r r e c t e d ) Wa t e r G r a v i t y Ma n u a l R e a d Wa t e r S a l i n i t y Ma n u a l R e a d Wa t e r p H M a n u a l Re a d BS & W S h a k e o u t s S ol i d s , M u d , Em u l s i o n Wa t e r C u t Ga s G r a v i t y Ra n a r e x M a n u a l Re a d CO 2 D r a g e r M a n u a l Re a d H² S D r a g e r M a n u a l Re a d GO R O il Mu d Ga s @ E X P R O Se p a r a t o r Wa t e r C a l c . f r o m Sa m p l e s To t a l F l u i d S ur f a c e I n j e c t i o n Ma n u a l R e a d (dd-mmm-yy hh:mm)(hours)Initial WHP 2166.1 psig Initial BHP 5347.3 psig (64ths)(psig)(F)(psi)(psig)(psig)(F)(psig)(scf/min)(stb/d)(stb/d)(MMscf/d)(stb/d)stb/d (stb)(MMscf)(stb)(stb)(psig)(F)(F)(inches)(SG60)(API60)(API60)(ppm)(pH)(%)(%)(%)(Air=1)(%)(ppm)(Mscfd/bbls)(stb)(stb)(MMscf)(stb)(stb)(gal/day) Repsol E&P USA David Ross 2 April 13, 2014 April 16, 2014 Time Rates SeparatorVolumes (15 mins)Choke BS&W Properties 12:35 hrs Casing Roland Taylor Qugruk-5A Cumulatives Well Test Report (15 min) Gas PropertiesFluid Properties 22:00 hrs 14-Apr-14 04:00 15:25:00 No Fluid Returns 20 35.24 60 33 2.31 2318.08 166.00 1496.89 300.00 0.00 0.00 0.026212 0.00 0.00 0.00 0.000273 0.00 0.00 38.37 69.85 100.60 1.75 N/R 0.00 N/R 0.00 27.24 0.350178 313.58 340.82 14-Apr-14 04:15 15:40:00 20 42.28 60 43 1.10 2386.36 165.94 1521.37 300.00 0.00 0.00 0.031137 0.00 0.00 0.00 0.000324 0.00 0.00 45.47 68.32 99.43 1.75 N/R 0.00 N/R 0.00 27.24 0.350502 313.58 340.82 14-Apr-14 04:30 15:55:00 Returns at choke and separator 20 50.76 61 45 0.22 2393.53 165.87 1489.82 1000.00 0.00 0.00 0.030195 0.00 0.00 0.00 0.000315 0.00 0.00 49.78 67.06 98.21 1.75 N/R 0.00 N/R 0.00 27.24 0.350817 313.58 340.82 14-Apr-14 04:45 16:10:00 Increase choke to 36/64ths (4:48 hrs)36 511.36 50 125 378.05 2478.11 165.87 1547.77 1000.00 720.14 0.00 0.153150 720.14 0.00 0.00 0.001595 7.50 7.50 67.02 68.14 97.22 1.75 N/R 100.00 0.00 100.00 N/R 0.00 27.24 0.352412 321.08 348.32 14-Apr-14 05:00 16:25:00 BS&W 99.5%H2O. Sparge separator and sand trap 36 407.80 53 147 239.50 1841.95 166.21 1527.30 700.00 1200.24 0.00 1.760124 1194.24 6.00 0.00 0.018335 12.44 12.50 124.27 75.96 85.39 1.75 N/R 100.00 0.50 99.50 N/R 0.00 27.37 0.370747 333.52 360.89 14-Apr-14 05:15 16:40:00 Decrease choke to 24/64ths (5:13 hrs)24 340.67 51 87 246.89 1577.67 167.22 1552.36 700.00 160.03 0.00 0.700514 159.23 0.80 0.00 0.007297 1.66 1.67 88.71 81.00 86.83 1.75 N/R 100.00 0.50 99.50 N/R 0.00 27.38 0.378044 335.18 362.56 14-Apr-14 05:30 16:55:00 BS&W: 80%H2O, 20% proppant 24 350.31 49 92 247.48 1540.14 167.69 1499.00 500.00 0.00 0.00 0.741177 0.00 0.00 0.00 0.007721 0.00 0.00 94.34 77.86 85.15 1.75 N/R 100.00 20.00 80.00 N/R 0.00 27.38 0.385765 335.18 362.56 14-Apr-14 05:45 17:10:00 24 277.60 49 85 187.07 1524.44 167.96 1495.55 500.00 0.00 0.00 0.668415 0.00 0.00 0.00 0.006963 0.00 0.00 90.12 77.28 83.93 1.75 N/R 100.00 20.00 80.00 N/R 0.00 27.38 0.392727 335.18 362.56 14-Apr-14 06:00 17:25:00 No fluid returns 24 342.81 48 95 237.60 1524.71 168.14 1493.83 300.00 0.00 0.00 0.571368 0.00 0.00 0.00 0.005952 0.00 0.00 87.28 79.26 82.89 1.75 N/R 0.00 N/R 0.00 27.38 0.398679 335.18 362.56 14-Apr-14 06:15 17:40:00 24 270.72 49 85 180.64 1483.68 168.31 1467.63 300.00 0.00 0.00 0.573624 0.00 0.00 0.00 0.005975 0.00 0.00 96.91 83.51 109.35 1.75 N/R 0.00 N/R 0.00 27.38 0.404654 335.18 362.56 14-Apr-14 06:30 17:55:00 Fluid wt. 8.7 ppg. Salinity 48000 ppm. Gas SG 0.972 24 184.40 50 77 102.75 1441.14 168.46 1458.26 300.00 0.00 0.00 0.462396 0.00 0.00 0.00 0.004817 0.00 0.00 83.40 84.48 105.94 1.75 N/R 48000 0.00 0.972 N/R 0.00 27.38 0.409471 335.18 362.56 14-Apr-14 06:45 18:10:00 24 159.63 50 68 90.74 1438.00 168.57 1436.64 300.00 0.00 0.00 0.367180 0.00 0.00 0.00 0.003825 0.00 0.00 78.56 83.82 100.71 1.75 N/R 0.00 N/R 0.00 27.38 0.413296 335.18 362.56 14-Apr-14 07:00 18:25:00 No fluid returns 24 134.79 50 72 59.69 1469.88 168.61 1472.03 300.00 0.00 0.00 0.313606 0.00 0.00 0.00 0.003267 0.00 0.00 72.12 83.51 97.20 1.75 N/R 0.00 N/R 0.00 27.38 0.416562 335.18 362.56 14-Apr-14 07:15 18:40:00 24 92.97 50 51 33.21 1544.06 168.62 1452.71 300.00 0.00 0.00 0.260210 0.00 0.00 0.00 0.002711 0.00 0.00 74.90 81.92 93.73 1.75 N/R 0.00 N/R 0.00 27.38 0.419273 335.18 362.56 14-Apr-14 07:30 18:55:00 No fluid returns 24 56.96 51 46 7.66 1631.63 168.47 1452.90 300.00 0.00 0.00 0.159383 0.00 0.00 0.00 0.001660 0.00 0.00 64.78 80.56 91.32 1.75 N/R 0.00 N/R 0.00 27.38 0.420933 335.18 362.56 14-Apr-14 07:45 19:10:00 24 72.71 52 59 9.89 1631.63 168.47 1446.02 300.00 0.00 0.00 0.129258 0.00 0.00 0.00 0.001346 0.00 0.00 63.84 79.11 89.25 1.75 N/R 0.00 N/R 0.00 27.38 0.422280 335.18 362.56 14-Apr-14 08:00 19:25:00 No fluid returns 24 82.87 51 64 15.88 1705.15 168.31 1442.96 300.00 0.00 0.00 0.143649 0.00 0.00 0.00 0.001496 0.00 0.00 63.62 78.21 86.79 1.75 N/R 0.00 N/R 0.00 27.38 0.423776 335.18 362.56 14-Apr-14 08:15 19:40:00 24 121.02 46 81 33.14 1740.38 168.17 1449.27 300.00 0.00 0.00 0.175545 0.00 0.00 0.00 0.001829 0.00 0.00 80.12 77.88 85.13 1.75 N/R 0.00 N/R 0.00 27.38 0.425604 335.18 362.56 14-Apr-14 08:30 19:55:00 No fluid returns 24 218.65 46 97 114.91 1764.70 168.11 1446.78 300.00 0.00 0.00 0.204567 0.00 0.00 0.00 0.002131 0.00 0.00 94.60 78.60 110.72 1.75 N/R 0.00 N/R 0.00 27.38 0.427735 335.18 362.56 14-Apr-14 08:45 20:10:00 Gas SG 0.972 24 296.18 47 85 203.14 1786.55 168.07 1437.41 300.00 0.00 0.00 0.286609 0.00 0.00 0.00 0.002986 0.00 0.00 80.91 81.36 124.50 1.75 N/R 0.00 0.972 N/R 0.00 27.38 0.430721 335.18 362.56 14-Apr-14 09:00 20:25:00 24 299.24 47 85 206.86 1791.81 168.05 1427.85 300.00 0.00 0.00 0.313975 0.00 0.00 0.00 0.003271 0.00 0.00 91.70 82.72 120.63 1.75 N/R 0.00 N/R 0.00 27.38 0.433991 335.18 362.56 14-Apr-14 09:15 20:40:00 N2 offline (09:20 hrs)24 334.86 46 90 238.56 1770.23 168.09 1431.29 300.00 0.00 0.00 0.319004 0.00 0.00 0.00 0.003323 0.00 0.00 90.16 83.76 122.94 1.75 N/R 0.00 N/R 0.00 27.38 0.437314 335.18 362.56 14-Apr-14 09:30 20:55:00 24 319.04 45 88 226.49 1706.77 168.24 1444.68 0.00 0.00 0.00 0.336518 0.00 0.00 0.00 0.003505 0.00 0.00 95.79 84.20 126.20 1.75 N/R 0.00 N/R 0.00 27.38 0.440820 335.18 362.56 14-Apr-14 09:45 21:10:00 Fluids to surface 24 358.49 45 83 263.47 1622.05 168.49 1431.10 0.00 480.10 0.00 0.302584 480.10 0.00 0.00 0.003152 5.00 5.00 85.13 84.42 130.66 1.75 N/R 100.00 0.00 100.00 N/R 0.00 27.38 0.443972 340.18 367.56 14-Apr-14 10:00 21:25:00 **Trace of oil to surface 24 400.69 45 69 320.32 1545.64 168.72 1415.99 0.00 240.05 0.00 0.298358 240.05 0.00 0.00 0.003108 2.50 2.50 84.87 83.96 132.79 1.75 N/R 100.00 0.00 100.00 N/R 0.00 27.38 0.447080 342.68 370.06 14-Apr-14 10:15 21:40:00 24 415.21 47 91 317.92 1499.12 168.88 1405.08 0.00 120.02 0.00 0.281771 120.02 0.00 0.00 0.002935 1.25 1.25 78.83 83.98 132.27 1.75 N/R 100.00 0.00 100.00 N/R 0.00 27.38 0.450015 343.93 371.31 14-Apr-14 10:30 21:55:00 BS&W: 94.5% Brine & 0.5% Sediment. Oil: 5%. Gas SG 0.968 24 318.43 51 79 238.68 1458.08 168.99 1456.53 0.00 80.02 4.00 0.330325 75.62 0.40 0.04 0.003441 0.79 0.83 94.02 83.61 125.60 1.75 N/R 95.00 0.50 94.50 0.968 0.00 0.04 27.39 0.453456 344.72 372.15 14-Apr-14 10:45 22:10:00 24 248.78 53 56 190.82 1425.38 169.05 1445.06 0.00 0.00 0.00 0.267356 0.00 0.00 0.00 0.002785 0.00 0.00 74.49 82.20 117.54 1.75 N/R 95.00 0.50 94.50 N/R 0.04 27.39 0.456241 344.72 372.15 14-Apr-14 11:00 22:25:00 Salinity 68000 ppm. pH 7 24 188.15 54 82 107.52 1412.02 169.09 1452.71 0.00 80.02 0.00 0.191103 80.02 0.00 0.00 0.001991 0.83 0.83 73.05 81.10 112.28 1.75 N/R 68000 7 100.00 0.00 100.00 N/R 0.04 27.39 0.458231 345.55 372.98 14-Apr-14 11:15 22:40:00 24 143.20 56 71 65.62 1404.69 169.13 1437.60 0.00 0.00 0.00 0.100743 0.00 0.00 0.00 0.001049 0.00 0.00 85.70 79.04 108.01 1.25 N/R 0.00 N/R 0.04 27.39 0.459281 345.55 372.98 14-Apr-14 11:30 22:55:00 No fluid returns 24 108.33 57 54 51.47 1403.89 169.14 1442.00 0.00 0.00 0.00 0.122248 0.00 0.00 0.00 0.001273 0.00 0.00 66.69 77.65 103.88 1.25 N/R 0.00 N/R 0.04 27.39 0.460554 345.55 372.98 14-Apr-14 11:45 23:10:00 24 83.18 58 41 34.73 1408.78 169.16 1431.29 0.00 0.00 0.00 0.094419 0.00 0.00 0.00 0.000984 0.00 0.00 50.04 76.25 100.45 1.25 N/R 0.00 N/R 0.04 27.39 0.461538 345.55 372.98 14-Apr-14 12:00 23:25:00 No fluid returns 24 77.37 60 79 -7.69 1431.46 169.16 1424.02 0.00 0.00 0.00 0.015811 0.00 0.00 0.00 0.000165 0.00 0.00 78.04 73.38 97.40 1.25 N/R 0.00 N/R 0.04 27.39 0.461702 345.55 372.98 14-Apr-14 12:15 23:40:00 24 78.59 63 75 0.00 1461.41 169.12 1418.09 0.00 0.00 0.00 0.017777 0.00 0.00 0.00 0.000185 0.00 0.00 84.11 71.01 94.84 1.25 N/R 0.00 N/R 0.04 27.39 0.461887 345.55 372.98 14-Apr-14 12:30 23:55:00 Coil start RIH to 5000 ft. No fluid returns 24 81.42 65 78 0.90 1488.90 169.08 1424.78 0.00 0.00 0.00 0.017025 0.00 0.00 0.00 0.000177 0.00 0.00 84.54 70.37 93.87 1.25 N/R 0.00 N/R 0.04 27.39 0.462065 345.55 372.98 14-Apr-14 12:45 24:10:00 24 78.29 67 79 1.16 1515.94 169.03 1420.58 0.00 0.00 0.00 0.018103 0.00 0.00 0.00 0.000189 0.00 0.00 84.38 69.42 92.07 1.25 N/R 0.00 N/R 0.04 27.39 0.462253 345.55 372.98 14-Apr-14 13:00 24:25:00 No Fluid Returns 24 87.39 69 85 1.03 1546.25 169.00 1419.62 0.00 0.00 0.00 0.018356 0.00 0.00 0.00 0.000191 0.00 0.00 85.29 68.10 90.03 1.25 N/R 0.00 N/R 0.04 27.39 0.462445 345.55 372.98 14-Apr-14 13:15 24:40:00 24 92.74 70 92 -2.11 1575.52 168.96 1446.21 0.00 0.00 0.00 0.018487 0.00 0.00 0.00 0.000193 0.00 0.00 89.72 67.13 88.04 1.25 N/R 0.00 N/R 0.04 27.39 0.462637 345.55 372.98 14-Apr-14 13:30 24:55:00 No Fluid Returns 24 60.78 70 42 16.91 1578.32 168.95 1473.75 0.00 0.00 0.00 0.092972 0.00 0.00 0.00 0.000968 0.00 0.00 95.55 66.29 86.31 1.25 N/R 0.00 N/R 0.04 27.39 0.463606 345.55 372.98 14-Apr-14 13:45 25:10:00 24 34.71 69 31 1.07 1732.53 168.92 1461.70 0.00 0.00 0.00 0.049135 0.00 0.00 0.00 0.000512 0.00 0.00 68.88 68.93 84.46 1.25 N/R 0.00 N/R 0.04 27.39 0.464117 345.55 372.98 14-Apr-14 14:00 25:25:00 24 37.46 71 34 1.59 1899.96 168.54 1443.34 0.00 0.00 0.00 0.011589 0.00 0.00 0.00 0.000121 0.00 0.00 45.56 68.72 83.02 1.25 N/R 0.00 N/R 0.04 27.39 0.464238 345.55 372.98 14-Apr-14 14:15 25:40:00 Coil start pumping fluid 24 35.24 72 35 -1.38 1905.64 168.21 1444.49 0.00 0.00 0.00 0.013001 0.00 0.00 0.00 0.000135 0.00 0.00 44.09 67.07 81.86 1.25 N/R 0.00 N/R 0.04 27.39 0.464374 345.55 372.98 14-Apr-14 14:30 25:55:00 24 32.87 74 37 -4.58 1919.66 168.07 1433.01 0.00 0.00 0.00 0.013518 0.00 0.00 0.00 0.000141 0.00 0.00 44.16 66.13 80.56 0.00 N/R 0.00 N/R 0.04 27.39 0.464514 345.55 372.98 14-Apr-14 14:45 26:10:00 Shut-in at choke manifold (14:51 hrs) 0 880.88 72 39 845.27 3291.38 167.48 1465.52 0.00 0.00 0.00 0.001000 0.00 0.00 0.00 0.000010 0.00 0.00 43.55 65.20 79.32 0.00 N/R 0.00 N/R 0.04 27.39 0.464525 345.55 372.98 14-Apr-14 15:00 26:25:00 0 1364.25 79 62 1309.71 4110.69 160.81 1398.39 0.00 0.00 0.00 0.005000 0.00 0.00 0.00 0.000052 0.00 0.00 46.21 64.40 78.12 0.00 N/R 0.00 N/R 0.04 27.39 0.464577 345.55 372.98 14-Apr-14 15:15 26:40:00 0 1545.96 80 58 1499.01 4395.42 153.39 1435.50 0.00 0.00 0.00 0.002000 0.00 0.00 0.00 0.000021 0.00 0.00 64.35 63.96 77.00 0.00 N/R 0.00 N/R 0.04 27.39 0.464598 345.55 372.98 14-Apr-14 15:30 26:55:00 0 1205.50 80 56 1155.21 4190.81 147.43 1454.81 0.00 0.00 0.00 0.005000 0.00 0.00 0.00 0.000052 0.00 0.00 68.57 63.43 76.21 0.00 N/R 0.00 N/R 0.04 27.39 0.464650 345.55 372.98 14-Apr-14 15:45 27:10:00 Fluid wt 8.7 ppg. Slowly open choke (15:46 hrs). Shut-in at choke (14:56)16 1045.42 79 58 997.78 3981.05 147.10 1458.26 0.00 0.00 0.00 0.012624 0.00 0.00 0.00 0.000132 0.00 0.00 65.94 62.85 75.30 0.00 N/R 0.00 N/R 0.04 27.39 0.464781 345.55 372.98 14-Apr-14 16:00 27:25:00 Coil pumping for injectivity test 0 944.06 77 59 889.84 3853.69 149.17 1459.60 0.00 0.00 0.00 0.013268 0.00 0.00 0.00 0.000138 0.00 0.00 63.10 62.62 74.50 0.00 N/R 0.00 N/R 0.04 27.39 0.464919 345.55 372.98 14-Apr-14 16:15 27:40:00 0 1559.07 77 56 1507.37 4629.61 148.70 1414.46 0.00 0.00 0.00 0.013233 0.00 0.00 0.00 0.000138 0.00 0.00 65.23 62.56 73.88 0.00 N/R 0.00 N/R 0.04 27.39 0.465057 345.55 372.98 14-Apr-14 16:30 27:55:00 Coil pumped 133 bbls total 0 1262.67 77 52 1218.99 4234.61 145.36 1491.15 0.00 0.00 0.00 0.014136 0.00 0.00 0.00 0.000147 0.00 0.00 63.90 62.04 72.89 0.00 N/R 0.00 N/R 0.04 27.39 0.465205 345.55 372.98 14-Apr-14 16:45 28:10:00 Open choke to 24/64ths (16:35)24 785.64 78 67 729.51 3886.16 146.72 1510.66 0.00 0.00 0.00 0.014727 0.00 0.00 0.00 0.000153 0.00 0.00 61.26 61.65 72.24 1.25 N/R 0.00 N/R 0.04 27.39 0.465358 345.55 372.98 14-Apr-14 17:00 28:25:00 24 112.31 64 102 0.01 2935.24 150.74 1531.32 0.00 2157.60 0.00 0.023396 2157.60 0.00 0.00 0.000244 22.48 22.48 76.28 62.30 96.93 0.88 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.465448 368.02 395.46 14-Apr-14 17:15 28:40:00 24 18.35 60 12 -3.01 2808.60 157.05 1519.27 0.00 1041.60 0.00 0.016178 1041.60 0.00 0.00 0.000169 10.85 10.85 87.07 62.29 97.84 0.88 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.465617 378.87 406.31 14-Apr-14 17:30 28:55:00 Decrease choke to 14/64ths 14 8.64 61 6 -0.63 2820.96 159.93 1537.44 0.00 148.80 0.00 0.007653 148.80 0.00 0.00 0.000080 1.55 1.55 72.62 62.13 94.86 0.88 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.465697 380.42 407.86 14-Apr-14 17:45 29:10:00 14 29.97 60 3 18.60 2856.85 161.47 1492.49 0.00 0.00 0.007998 0.00 0.00 0.00 0.000083 0.00 0.00 72.66 61.93 92.54 0.88 N/R 0.00 N/R 0.04 27.39 0.465780 380.42 407.86 14-Apr-14 18:00 29:25:00 14 26.91 60 8 9.77 2882.34 162.31 1499.57 0.00 148.80 0.00 0.007864 148.80 0.00 0.00 0.000082 1.55 1.55 72.48 61.70 89.80 0.88 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.465862 381.97 409.41 14-Apr-14 18:15 29:40:00 14 24.39 60 8 10.91 2894.68 162.79 1498.42 0.00 223.20 0.00 0.007961 223.20 0.00 0.00 0.000083 2.33 2.33 72.32 61.71 87.55 0.88 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.465945 384.30 411.73 14-Apr-14 18:30 29:55:00 Start pumping N2 @ 1000 scf/min 14 219.65 82 12 214.03 3069.76 163.05 1506.65 1000.00 669.60 0.00 0.007561 669.60 0.00 0.00 0.000079 6.98 6.98 71.99 61.46 85.59 0.88 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.466023 391.27 418.71 14-Apr-14 18:45 30:10:00 14 93.96 93 20 75.04 2993.52 163.01 1485.99 1000.00 1934.40 0.00 0.007638 1934.40 0.00 0.00 0.000080 20.15 20.15 71.72 61.17 83.44 0.88 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.466103 411.42 438.86 14-Apr-14 19:00 30:25:00 30 416.44 83 146 259.98 3378.81 162.90 1485.80 350.00 669.60 0.00 0.009126 669.60 0.00 0.00 0.000095 6.98 6.98 109.31 76.00 94.49 0.88 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.466198 418.40 445.83 14-Apr-14 19:15 30:40:00 30 325.08 73 120 194.65 3313.55 162.47 1462.46 0.00 0.00 0.00 0.009378 0.00 0.00 0.00 0.000098 0.00 0.00 113.14 82.25 103.12 0.88 N/R 0.00 N/R 0.04 27.39 0.466296 418.40 445.83 Expro Confidential 5/6/2014 Page 8 CUSTOMER:TEST No: CUSTOMER REP:START DATE: EXPRO SUPERVISOR:END DATE: WELL NUMBER: Comments Ratio Methanol Time & Date El a p s e d T i m e Ch o k e S i z e M a n u a l Re a d WH P @ t h e We l l h e a d WH T @ S w a b Do wn S t r e a m Ch o k e Di f f P r e s s A c r o s s Ch o k e Bo t t o m H o l e Pr e s s u r e ( L o w e r Ga u g e ) Bo t t o m H o l e Te m p e r a t u r e An n u l u s P r e s s u r e N it r o g e n I n j e c t i o n To t a l F l u i d s Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r M ud & S e d i m e n t Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r T ot a l F l u i d In c r e m e n t Pr e s s u r e @ M e t e r Ru n Ga s T e m p e r a t u r e @ M e t e r R u n Oi l T e m p e r a t u r e @ Oi l L e g Or i f a c e P l a t e S i z e Oi l G r a v i t y M a n u a l Re a d Oi l G r a v i t y M a n u a l Re a d ( C o r r e c t e d ) Wa t e r G r a v i t y Ma n u a l R e a d Wa t e r S a l i n i t y Ma n u a l R e a d Wa t e r p H M a n u a l Re a d BS & W S h a k e o u t s S ol i d s , M u d , Em u l s i o n Wa t e r C u t Ga s G r a v i t y Ra n a r e x M a n u a l Re a d CO 2 D r a g e r M a n u a l Re a d H² S D r a g e r M a n u a l Re a d GO R O il Mu d Ga s @ E X P R O Se p a r a t o r Wa t e r C a l c . f r o m Sa m p l e s To t a l F l u i d S ur f a c e I n j e c t i o n Ma n u a l R e a d (dd-mmm-yy hh:mm)(hours)Initial WHP 2166.1 psig Initial BHP 5347.3 psig (64ths)(psig)(F)(psi)(psig)(psig)(F)(psig)(scf/min)(stb/d)(stb/d)(MMscf/d)(stb/d)stb/d (stb)(MMscf)(stb)(stb)(psig)(F)(F)(inches)(SG60)(API60)(API60)(ppm)(pH)(%)(%)(%)(Air=1)(%)(ppm)(Mscfd/bbls)(stb)(stb)(MMscf)(stb)(stb)(gal/day) Repsol E&P USA David Ross 2 April 13, 2014 April 16, 2014 Time Rates SeparatorVolumes (15 mins)Choke BS&W Properties 12:35 hrs Casing Roland Taylor Qugruk-5A Cumulatives Well Test Report (15 min) Gas PropertiesFluid Properties 22:00 hrs 14-Apr-14 19:30 30:55:00 30 179.36 76 48 121.97 3125.76 162.48 1443.53 500.00 0.00 0.00 0.006946 0.00 0.00 0.00 0.000072 0.00 0.00 66.77 78.36 108.45 0.88 N/R 0.00 N/R 0.04 27.39 0.466368 418.40 445.83 14-Apr-14 19:45 31:10:00 Observed API 39.4 @88F. Corrected API 37.1 @60F 30 489.28 57 138 337.22 3343.59 162.63 1432.24 500.00 669.60 0.00 0.006478 669.60 0.00 0.00 0.000067 6.98 6.98 59.22 76.17 119.79 0.88 0.839 37.1 100.00 0.00 100.00 N/R 0.04 27.39 0.466436 425.37 452.81 14-Apr-14 20:00 31:25:00 30 369.57 64 58 308.05 3049.83 162.73 1419.81 500.00 595.20 0.00 0.030050 595.20 0.00 0.00 0.000313 6.20 6.20 81.39 76.18 121.10 1.50 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.466749 431.57 459.01 14-Apr-14 20:15 31:40:00 31 618.77 52 181 421.82 3002.33 163.18 1438.36 500.00 892.80 0.00 0.244583 892.80 0.00 0.00 0.002548 9.30 9.30 68.62 76.33 102.30 1.50 N/R 100.00 0.00 100.00 N/R 0.04 27.39 0.469296 440.87 468.31 14-Apr-14 20:30 31:55:00 BS&W: 89% Brine &1% Sediment. Oil 10%31 276.53 53 130 135.54 2590.40 163.92 1465.33 500.00 372.00 37.20 1.126771 331.08 3.72 0.39 0.011737 3.45 3.88 120.97 78.84 108.38 1.50 N/R 90.00 1.00 89.00 0.00 0.43 27.47 0.481034 444.32 472.22 14-Apr-14 20:45 32:10:00 31 404.82 58 81 316.32 2596.76 164.88 1508.18 500.00 148.80 14.88 0.591161 132.43 1.49 0.16 0.006158 1.38 1.55 90.82 79.93 113.86 1.50 N/R 90.00 1.00 89.00 0.00 0.58 27.50 0.487191 445.70 473.79 14-Apr-14 21:00 32:25:00 BS&W: 98% Brine & 2% Sediment. Trace oil 31 607.28 53 117 476.88 2602.77 164.97 1535.34 500.00 372.00 0.00 0.546056 364.56 7.44 0.00 0.005688 3.80 3.88 91.45 80.44 112.44 1.50 N/R 100.00 2.00 98.00 N/R 0.58 27.66 0.492880 449.50 477.74 14-Apr-14 21:15 32:40:00 31 343.27 54 109 219.65 2574.42 165.03 1480.25 500.00 669.60 0.00 0.974145 656.21 13.39 0.00 0.010147 6.84 6.98 109.28 79.20 116.73 1.50 N/R 100.00 2.00 98.00 N/R 0.58 27.94 0.503027 456.34 484.86 14-Apr-14 21:30 32:55:00 31 309.25 54 106 188.62 2315.50 165.34 1538.40 500.00 297.60 0.00 0.702991 291.65 5.95 0.00 0.007323 3.04 3.10 93.56 78.80 113.32 1.50 N/R 100.00 2.00 98.00 N/R 0.58 28.06 0.510350 459.37 488.02 14-Apr-14 21:45 33:10:00 31 291.51 57 112 166.49 2174.14 165.68 1495.36 500.00 595.20 0.00 0.815406 583.30 11.90 0.00 0.008494 6.08 6.20 108.00 77.89 104.86 1.50 N/R 100.00 2.00 98.00 N/R 0.58 28.31 0.518844 465.45 494.34 14-Apr-14 22:00 33:25:00 BS&W: 90% Brine & 10% Sediment. Trace oil 31 311.70 54 113 183.28 2035.32 165.90 1547.19 500.00 892.80 0.00 0.662995 803.52 89.28 0.00 0.006906 8.37 9.30 97.37 78.48 111.96 1.50 N/R 100.00 10.00 90.00 N/R 0.58 30.17 0.525750 473.82 504.57 14-Apr-14 22:15 33:40:00 31 298.93 55 117 171.87 1934.02 166.05 1530.55 500.00 595.20 0.00 0.900862 535.68 59.52 0.00 0.009384 5.58 6.20 114.32 78.30 109.01 1.50 N/R 100.00 10.00 90.00 N/R 0.58 31.41 0.535134 479.40 511.39 14-Apr-14 22:30 33:55:00 BS&W: 93% Brine & 7% Sediment. Trace oil 31 253.67 53 104 143.34 1736.71 166.22 1531.32 0.00 520.80 0.00 0.882178 484.34 36.46 0.00 0.009189 5.05 5.43 98.47 81.81 118.89 1.50 N/R 100.00 7.00 93.00 N/R 0.58 32.17 0.544323 484.44 517.20 14-Apr-14 22:45 34:10:00 31 174.39 52 89 80.49 1468.13 166.44 1509.13 0.00 3124.80 0.00 0.707617 2906.06 218.74 0.00 0.007371 30.27 32.55 92.97 83.03 124.73 1.50 N/R 100.00 7.00 93.00 N/R 0.58 36.72 0.551694 514.72 552.02 14-Apr-14 23:00 34:25:00 BS&W: 97% Brine & 2% Sediment. Oil 1% 31 68.12 53 61 3.32 1409.07 166.48 1479.49 0.00 148.80 1.49 0.396101 144.34 2.98 0.02 0.004126 1.50 1.55 76.08 82.51 123.64 1.50 N/R 99.00 2.00 97.00 0.00 0.60 36.79 0.555820 516.22 553.61 14-Apr-14 23:15 34:40:00 Start pumping N2 @ 500 scf/min 20 439.07 61 111 321.19 1242.01 166.62 1519.08 500.00 0.00 0.00 0.196363 0.00 0.00 0.00 0.002045 0.00 0.00 80.26 81.24 122.08 1.50 N/R 99.00 2.00 97.00 N/R 0.60 36.79 0.557866 516.22 553.61 14-Apr-14 23:30 34:55:00 BS&W: 93% Brine & 6% Sediment. Oil 1%20 435.93 72 108 324.70 1558.31 166.67 1446.59 750.00 148.80 1.49 0.507063 138.38 8.93 0.02 0.005282 1.44 1.55 92.51 83.00 123.05 1.50 N/R 99.00 6.00 93.00 0.00 0.62 36.97 0.563148 517.66 555.25 14-Apr-14 23:45 35:10:00 10 781.15 69 42 735.42 2107.58 166.54 1389.78 750.00 0.00 0.00 0.276809 0.00 0.00 0.00 0.002883 0.00 0.00 74.82 80.71 119.17 1.50 N/R 99.00 6.00 93.00 N/R 0.62 36.97 0.566031 517.66 555.25 15-Apr-14 00:00 35:25:00 BS&W: 98.5% Brine & 0.5% Sediment. Oil 1%. N2 offline, Begin POOH 10 907.67 67 84 818.62 3064.75 165.65 1437.60 0.00 0.00 0.00 0.038867 0.00 0.00 0.00 0.000405 0.00 0.00 62.09 76.16 112.04 1.50 N/R 99.00 0.50 98.50 N/R 0.62 36.97 0.566436 517.66 555.25 15-Apr-14 00:15 35:40:00 Begin Acid wash operation 10 733.88 65 73 652.23 3205.75 163.87 1385.00 0.00 0.00 0.00 0.109802 0.00 0.00 0.00 0.001144 0.00 0.00 91.28 74.78 106.89 1.50 N/R 99.00 0.50 98.50 N/R 0.62 36.97 0.567580 517.66 555.25 15-Apr-14 00:30 35:55:00 Divert to tank #1 for Acid wash returns 10 748.64 64 55 684.41 3001.62 162.61 1470.50 0.00 0.00 0.00 0.060647 0.00 0.00 0.00 0.000632 0.00 0.00 67.86 73.64 102.48 1.50 N/R 0.00 N/R 0.62 36.97 0.568211 517.66 555.25 15-Apr-14 00:45 36:10:00 Start pumping N2 at 1000 scf/min 10 792.87 64 55 733.36 2868.81 162.81 1462.08 1000.00 0.00 0.00 0.057269 0.00 0.00 0.00 0.000597 0.00 0.00 62.43 72.59 98.80 1.50 N/R 0.00 N/R 0.62 36.97 0.568808 517.66 555.25 15-Apr-14 01:00 36:25:00 No fluid returns 10 1211.37 65 85 1120.93 2879.42 163.21 1450.61 1000.00 0.00 0.00 0.056142 0.00 0.00 0.00 0.000585 0.00 0.00 66.91 71.44 94.84 1.50 N/R 0.00 N/R 0.62 36.97 0.569393 517.66 555.25 15-Apr-14 01:15 36:40:00 10 1748.48 67 84 1658.73 3216.38 163.39 1450.22 1000.00 0.00 0.00 0.096049 0.00 0.00 0.00 0.001001 0.00 0.00 114.70 69.99 91.22 1.50 N/R 0.00 N/R 0.62 36.97 0.570393 517.66 555.25 15-Apr-14 01:30 36:55:00 Reduce N2 rate to 300 scf/min 30 2422.62 70 83 2336.19 3741.37 162.67 1478.72 300.00 0.00 0.00 0.024817 0.00 0.00 0.00 0.000259 0.00 0.00 89.77 67.00 87.85 1.50 N/R 0.00 N/R 0.62 36.97 0.570652 517.66 555.25 15-Apr-14 01:45 37:10:00 30 1254.12 58 195 1028.47 4456.03 161.19 1498.61 300.00 0.00 0.00 1.020538 0.00 0.00 0.00 0.010631 0.00 0.00 115.57 74.55 82.95 1.50 N/R 0.00 N/R 0.62 36.97 0.581282 517.66 555.25 15-Apr-14 02:00 37:25:00 Begin POOH with coil. Fluid returns, pH=2 30 745.22 61 180 545.51 3003.13 161.19 1478.53 0.00 3273.60 0.00 1.603278 3273.60 0.00 0.00 0.016701 34.10 34.10 150.28 79.47 91.36 1.50 N/R 2 100.00 0.00 100.00 N/R 0.62 36.97 0.597983 551.76 589.35 15-Apr-14 02:15 37:40:00 30 355.58 58 127 218.68 1801.17 162.76 1480.83 0.00 0.00 0.00 1.484750 0.00 0.00 0.00 0.015466 0.00 0.00 130.89 80.36 87.39 1.50 N/R 0.00 N/R 0.62 36.97 0.613449 551.76 589.35 15-Apr-14 02:30 37:55:00 No Fluid Returns 30 279.89 56 121 154.72 1391.51 164.94 1490.01 0.00 0.00 0.00 1.230930 0.00 0.00 0.00 0.012822 0.00 0.00 113.53 84.47 92.96 1.50 N/R 0.00 N/R 0.62 36.97 0.626271 551.76 589.35 15-Apr-14 02:45 38:10:00 30 201.61 56 105 84.83 1300.02 165.99 1472.79 0.00 74.40 0.00 1.023036 74.40 0.00 0.00 0.010657 0.77 0.77 107.88 86.02 104.98 1.50 N/R 100.00 0.00 100.00 N/R 0.62 36.97 0.636928 552.54 590.12 15-Apr-14 03:00 38:25:00 No Fluid Returns. Gas S.G. = 0.970 30 85.47 55 72 16.08 1249.49 166.49 1458.07 0.00 0.00 0.00 0.632232 0.00 0.00 0.00 0.006586 0.00 0.00 89.88 85.16 98.56 1.50 N/R 0.00 0.970 N/R 0.62 36.97 0.643514 552.54 590.12 15-Apr-14 03:15 38:40:00 24 47.17 56 44 -0.23 1190.56 166.79 1457.30 1500.00 0.00 0.00 0.211732 0.00 0.00 0.00 0.002206 0.00 0.00 62.81 80.56 96.51 1.50 N/R 0.00 N/R 0.62 36.97 0.645719 552.54 590.12 15-Apr-14 03:30 38:55:00 No Fluid Returns 24 78.59 58 78 1.92 1181.44 166.96 1442.19 1500.00 0.00 0.00 0.064853 0.00 0.00 0.00 0.000676 0.00 0.00 66.28 75.42 90.28 1.50 N/R 0.00 N/R 0.62 36.97 0.646395 552.54 590.12 15-Apr-14 03:45 39:10:00 Trace of fluid at choke. N2 stop pumping 24 400.54 60 141 250.61 1249.61 167.07 1485.61 500.00 0.00 0.00 0.515414 0.00 0.00 0.00 0.005369 0.00 0.00 104.02 78.17 85.50 1.50 N/R 0.00 N/R 0.62 36.97 0.651764 552.54 590.12 15-Apr-14 04:00 39:25:00 Increase choke to 60 /64ths to bleed N2 40 237.46 55 161 59.22 1961.40 166.94 1425.36 0.00 0.00 0.00 1.490593 0.00 0.00 0.00 0.015527 0.00 0.00 135.53 86.40 100.36 1.50 N/R 0.00 N/R 0.62 36.97 0.667291 552.54 590.12 15-Apr-14 04:15 39:40:00 60 85.70 54 81 6.09 1933.47 166.21 1430.14 0.00 148.80 0.00 0.995772 148.80 0.00 0.00 0.010373 1.55 1.55 105.20 84.82 101.85 1.50 N/R 100.00 0.00 100.00 N/R 0.62 36.97 0.677663 554.09 591.67 15-Apr-14 04:30 39:55:00 No Fluid Returns 60 66.36 54 71 -5.61 1746.14 166.14 1488.48 0.00 0.00 0.00 0.373079 0.00 0.00 0.00 0.003886 0.00 0.00 82.92 82.51 94.27 1.50 N/R 0.00 N/R 0.62 36.97 0.681550 554.09 591.67 15-Apr-14 04:45 40:10:00 60 52.75 56 57 -1.88 1771.42 166.30 1487.14 0.00 0.00 0.00 0.207748 0.00 0.00 0.00 0.002164 0.00 0.00 65.90 79.65 89.68 1.50 N/R 0.00 N/R 0.62 36.97 0.683714 554.09 591.67 15-Apr-14 05:00 40:25:00 60 44.88 57 44 -0.05 1785.08 166.37 1475.28 0.00 0.00 0.00 0.118423 0.00 0.00 0.00 0.001234 0.00 0.00 55.93 76.38 87.30 1.50 N/R 0.00 N/R 0.62 36.97 0.684947 554.09 591.67 15-Apr-14 05:15 40:40:00 Decrease choke to 14/64ths 14 2.60 59 1 -0.42 1774.59 166.47 1464.95 0.00 0.00 0.00 0.244024 0.00 0.00 0.00 0.002542 0.00 0.00 19.93 73.69 87.91 1.50 N/R 0.00 N/R 0.62 36.97 0.687489 554.09 591.67 15-Apr-14 05:30 40:55:00 14 3.44 58 0 4.48 1805.41 166.61 1464.38 0.00 0.00 0.00 0.030802 0.00 0.00 0.00 0.000321 0.00 0.00 4.60 69.84 87.86 1.50 N/R 0.00 N/R 0.62 36.97 0.687810 554.09 591.67 15-Apr-14 05:45 41:10:00 14 0.54 58 1 0.26 1829.14 166.69 1467.44 0.00 0.00 0.00 0.031062 0.00 0.00 0.00 0.000324 0.00 0.00 4.51 67.70 84.82 1.50 N/R 0.00 N/R 0.62 36.97 0.688134 554.09 591.67 15-Apr-14 06:00 41:25:00 14 1.91 57 1 -1.45 1849.39 166.72 1465.14 0.00 0.00 0.00 0.033033 0.00 0.00 0.00 0.000344 0.00 0.00 7.39 66.12 84.82 1.50 N/R 0.00 N/R 0.62 36.97 0.688478 554.09 591.67 15-Apr-14 06:15 41:40:00 14 2.83 58 0 0.91 1870.18 166.74 1456.53 0.00 0.00 0.00 0.033174 0.00 0.00 0.00 0.000346 0.00 0.00 8.57 65.43 83.36 1.50 N/R 0.00 N/R 0.62 36.97 0.688823 554.09 591.67 15-Apr-14 06:30 41:55:00 14 4.97 58 0 0.00 1890.41 166.76 1446.21 0.00 0.00 0.00 0.033108 0.00 0.00 0.00 0.000345 0.00 0.00 8.97 64.62 80.96 1.50 N/R 0.00 N/R 0.62 36.97 0.689168 554.09 591.67 15-Apr-14 06:45 42:10:00 14 2.91 59 1 0.87 1909.82 166.77 1439.13 0.00 0.00 0.00 0.033544 0.00 0.00 0.00 0.000349 0.00 0.00 9.23 63.79 78.25 1.50 N/R 0.00 N/R 0.62 36.97 0.689518 554.09 591.67 15-Apr-14 07:00 42:25:00 14 2.06 60 4 -0.66 1928.41 166.79 1434.35 0.00 0.00 0.00 0.033382 0.00 0.00 0.00 0.000348 0.00 0.00 8.96 63.53 76.42 1.50 N/R 0.00 N/R 0.62 36.97 0.689865 554.09 591.67 15-Apr-14 07:15 42:40:00 14 3.67 60 0 4.18 1946.37 166.80 1437.41 0.00 0.00 0.00 0.033710 0.00 0.00 0.00 0.000351 0.00 0.00 9.44 63.08 75.13 1.50 N/R 0.00 N/R 0.62 36.97 0.690216 554.09 591.67 15-Apr-14 07:30 42:55:00 14 0.76 61 2 -1.98 1963.76 166.82 1428.23 0.00 0.00 0.00 0.033711 0.00 0.00 0.00 0.000351 0.00 0.00 9.62 62.40 74.20 1.50 N/R 0.00 N/R 0.62 36.97 0.690568 554.09 591.67 15-Apr-14 07:45 43:10:00 14 1.30 61 1 -0.84 1980.43 166.83 1427.08 0.00 0.00 0.00 0.033323 0.00 0.00 0.00 0.000347 0.00 0.00 9.47 62.25 73.13 1.50 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 08:00 43:25:00 14 2.06 61 4 0.33 1996.65 166.84 1418.09 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.96 61.93 72.15 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 08:15 43:40:00 14 5.35 62 4 -4.12 2012.32 166.85 1413.50 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.64 61.71 71.00 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 08:30 43:55:00 14 0.00 62 0 3.99 2028.03 166.86 1409.29 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.62 61.31 70.44 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 08:45 44:10:00 14 2.06 62 0 0.00 2045.18 166.86 1409.87 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.80 61.00 69.57 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 09:00 44:25:00 14 1.68 62 6 -5.57 2059.07 166.88 1483.69 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.34 60.90 69.15 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 09:15 44:40:00 14 0.76 61 4 -3.66 2070.51 166.89 1478.72 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.70 60.56 68.47 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 09:30 44:55:00 14 1.38 60 0 3.23 2083.69 166.89 1467.05 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.77 60.43 67.83 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 09:45 45:10:00 14 3.75 61 1 -0.61 2096.38 166.89 1471.45 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.32 60.58 67.32 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 10:00 45:25:00 14 1.83 61 4 0.40 2108.79 166.89 1464.95 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 8.94 61.22 67.44 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 10:15 45:40:00 14 5.89 62 6 -4.50 2120.85 166.89 1461.32 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.21 61.79 67.44 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 10:30 45:55:00 14 1.38 62 4 -1.61 2132.67 166.90 1447.16 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.40 62.67 67.97 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 10:45 46:10:00 14 6.50 63 4 -0.32 2145.62 166.90 1443.53 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.89 62.67 68.37 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 Expro Confidential 5/6/2014 Page 9 CUSTOMER:TEST No: CUSTOMER REP:START DATE: EXPRO SUPERVISOR:END DATE: WELL NUMBER: Comments Ratio Methanol Time & Date El a p s e d T i m e Ch o k e S i z e M a n u a l Re a d WH P @ t h e We l l h e a d WH T @ S w a b Do wn S t r e a m Ch o k e Di f f P r e s s A c r o s s Ch o k e Bo t t o m H o l e Pr e s s u r e ( L o w e r Ga u g e ) Bo t t o m H o l e Te m p e r a t u r e An n u l u s P r e s s u r e N it r o g e n I n j e c t i o n To t a l F l u i d s Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r M ud & S e d i m e n t Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r T ot a l F l u i d In c r e m e n t Pr e s s u r e @ M e t e r Ru n Ga s T e m p e r a t u r e @ M e t e r R u n Oi l T e m p e r a t u r e @ Oi l L e g Or i f a c e P l a t e S i z e Oi l G r a v i t y M a n u a l Re a d Oi l G r a v i t y M a n u a l Re a d ( C o r r e c t e d ) Wa t e r G r a v i t y Ma n u a l R e a d Wa t e r S a l i n i t y Ma n u a l R e a d Wa t e r p H M a n u a l Re a d BS & W S h a k e o u t s S ol i d s , M u d , Em u l s i o n Wa t e r C u t Ga s G r a v i t y Ra n a r e x M a n u a l Re a d CO 2 D r a g e r M a n u a l Re a d H² S D r a g e r M a n u a l Re a d GO R O il Mu d Ga s @ E X P R O Se p a r a t o r Wa t e r C a l c . f r o m Sa m p l e s To t a l F l u i d S ur f a c e I n j e c t i o n Ma n u a l R e a d (dd-mmm-yy hh:mm)(hours)Initial WHP 2166.1 psig Initial BHP 5347.3 psig (64ths)(psig)(F)(psi)(psig)(psig)(F)(psig)(scf/min)(stb/d)(stb/d)(MMscf/d)(stb/d)stb/d (stb)(MMscf)(stb)(stb)(psig)(F)(F)(inches)(SG60)(API60)(API60)(ppm)(pH)(%)(%)(%)(Air=1)(%)(ppm)(Mscfd/bbls)(stb)(stb)(MMscf)(stb)(stb)(gal/day) Repsol E&P USA David Ross 2 April 13, 2014 April 16, 2014 Time Rates SeparatorVolumes (15 mins)Choke BS&W Properties 12:35 hrs Casing Roland Taylor Qugruk-5A Cumulatives Well Test Report (15 min) Gas PropertiesFluid Properties 22:00 hrs 15-Apr-14 11:00 46:25:00 14 1.53 63 2 1.82 2155.68 166.90 1441.04 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 10.19 62.42 68.00 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 11:15 46:40:00 14 1.45 63 2 -1.60 2166.35 166.90 1435.50 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 10.13 62.19 67.88 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 11:30 46:55:01 14 5.05 65 4 -4.42 2177.04 166.90 1441.04 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 10.06 61.78 67.36 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 11:45 47:10:01 14 5.73 66 3 -3.13 2187.35 166.90 1470.88 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.74 61.59 67.35 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 12:00 47:25:01 14 24.54 67 0 22.41 2214.01 166.90 1477.57 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.76 61.40 66.80 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 12:15 47:40:01 Start pumping N2 @ 300 scf/min 14 40.83 68 0 36.28 2237.10 166.85 1461.32 300.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.21 61.53 66.95 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 12:30 47:55:01 No Fluid Returns 14 1.15 67 2 -1.15 2442.19 166.78 1461.51 300.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.63 61.58 66.94 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 12:45 48:10:01 14 0.00 67 0 0.00 2773.84 166.46 1479.30 300.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.51 61.25 66.75 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 13:00 48:25:01 Increase N2 rate to 500 scf/min 14 0.00 68 0 0.00 2787.57 165.87 1464.76 500.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.46 61.21 66.29 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 13:15 48:40:01 14 0.00 67 0 0.00 2750.51 165.51 1448.50 500.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.20 61.14 66.09 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 13:30 48:55:01 Increase N2 rate to 1000 scf/min 14 0.00 65 0 0.00 2729.47 165.36 1443.72 1000.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.15 61.42 66.33 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 13:45 49:10:01 Decrease N2 rate to 500 scf/min (13:57)14 0.00 65 0 0.00 2715.63 165.32 1442.76 1000.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.42 61.48 66.12 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 14:00 49:25:01 Increase choke to 22/64ths (14:04); 26/64ths (14:06); 30/64ths (14:08)30 562.36 49 0 571.82 2973.68 165.27 1494.98 500.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 9.08 61.69 66.27 0.00 N/R 0.00 N/R 0.62 36.97 0.690915 554.09 591.67 15-Apr-14 14:15 49:40:01 Dec. N2 rate to 300 scf/min (14:18). Dec. choke to 18/64th (14:13). Fluid wt 10.2ppg 18 1214.96 53 115 1095.54 2731.77 164.84 1510.47 300.00 1264.80 0.00 0.000000 1264.80 0.00 0.00 0.000000 13.18 13.18 26.91 66.16 67.59 0.00 N/R 100.00 0.00 100.00 N/R 0.62 36.97 0.690915 567.26 604.85 15-Apr-14 14:30 49:55:01 Increase choke to 26/64ths. Fluid wt 9.25 ppg 26 903.87 48 140 758.64 2488.62 165.07 1485.80 300.00 0.00 0.00 1.023391 0.00 0.00 0.00 0.010660 0.00 0.00 97.40 80.88 96.51 1.75 N/R 0.00 N/R 0.62 36.97 0.701575 567.26 604.85 15-Apr-14 14:45 50:10:01 Increase N2 rate to 500 scf/min 26 448.47 52 79 357.06 2071.18 166.00 1493.83 500.00 0.00 0.00 1.398192 0.00 0.00 0.00 0.014565 0.00 0.00 98.51 78.95 93.71 1.75 N/R 0.00 N/R 0.62 36.97 0.716140 567.26 604.85 15-Apr-14 15:00 50:25:01 Fluid to surface (14:56 hrs)26 414.30 52 42 363.35 2048.77 166.66 1531.70 500.00 148.80 0.00 0.468714 148.80 0.00 0.00 0.004882 1.55 1.55 62.10 81.05 111.58 1.75 N/R 100.00 0.00 100.00 N/R 0.62 36.97 0.721022 568.81 606.40 15-Apr-14 15:15 50:40:01 Stop pumping N2 26 321.10 47 64 252.98 2066.02 166.91 1489.62 0.00 0.00 0.00 0.329702 0.00 0.00 0.00 0.003434 0.00 0.00 82.57 81.29 122.79 1.75 N/R 100.00 0.00 100.00 N/R 0.62 36.97 0.724456 568.81 606.40 15-Apr-14 15:30 50:55:01 26 381.50 45 111 264.63 2013.60 167.03 1481.21 0.00 297.60 0.00 0.235828 297.60 0.00 0.00 0.002457 3.10 3.10 72.99 80.32 132.20 1.75 N/R 100.00 0.00 100.00 N/R 0.62 36.97 0.726913 571.91 609.50 15-Apr-14 15:45 51:10:01 26 711.04 46 125 573.30 1991.40 167.23 1448.31 0.00 520.80 0.00 0.284279 520.80 0.00 0.00 0.002961 5.43 5.43 112.22 79.07 122.35 1.75 N/R 100.00 0.00 100.00 N/R 0.62 36.97 0.729874 577.34 614.92 15-Apr-14 16:00 51:25:01 BS&W: 69% Brine & 6% Sediment. Oil 25% 26 652.19 45 102 546.61 1800.31 167.39 1440.28 0.00 148.80 37.20 0.731021 102.67 8.93 0.39 0.007615 1.07 1.55 122.15 80.02 119.46 1.75 N/R 125000 6 75.00 6.00 69.00 0.976 0.00 1.00 37.16 0.737489 578.41 616.57 15-Apr-14 16:15 51:40:01 Increase choke to 30/64ths 30 453.27 48 113 328.25 1603.74 167.62 1448.88 0.00 297.60 74.40 0.788930 205.34 17.86 0.78 0.008218 2.14 3.10 125.42 82.66 122.44 1.75 N/R 75.00 6.00 69.00 0.00 1.78 37.53 0.745707 580.54 619.85 15-Apr-14 16:30 51:55:01 BS&W: 98% Brine & 1% Sediment. Oil 1% 30 171.02 48 162 3.06 1363.14 167.89 1466.10 0.00 74.40 0.74 0.682969 72.91 0.74 0.01 0.007114 0.76 0.78 125.00 83.93 122.58 1.75 N/R 6 99.00 1.00 98.00 0.00 1.79 37.55 0.752821 581.30 620.64 15-Apr-14 16:45 52:10:01 30 59.40 50 56 3.67 1338.54 167.99 1442.57 0.00 0.00 0.00 0.146086 0.00 0.00 0.00 0.001522 0.00 0.00 60.07 80.70 115.21 1.75 N/R 99.00 1.00 98.00 N/R 1.79 37.55 0.754343 581.30 620.64 15-Apr-14 17:00 52:25:01 No Fluid Returns 30 117.28 53 111 7.01 1608.61 168.00 1480.44 0.00 0.00 0.00 0.116694 0.00 0.00 0.00 0.001216 0.00 0.00 74.68 77.20 107.05 1.75 N/R 100.00 0.00 100.00 N/R 1.79 37.55 0.755559 581.30 620.64 15-Apr-14 17:15 52:40:01 30 510.90 70 112 392.85 2655.15 167.56 1423.06 0.00 372.00 0.00 0.529257 372.00 0.00 0.00 0.005513 3.88 3.88 117.75 79.78 119.26 1.75 N/R 100.00 0.00 100.00 N/R 1.79 37.55 0.761072 585.18 624.51 15-Apr-14 17:30 52:55:01 BS&W: 99.25% Brine & 0.75% Sediment. Increase choke to 34/64ths 34 572.26 74 88 476.92 3485.11 166.58 1408.91 0.00 669.60 0.00 0.398013 664.58 5.02 0.00 0.004146 6.92 6.98 94.16 79.36 123.47 1.75 N/R 100.00 0.75 99.25 N/R 1.79 37.65 0.765218 592.10 631.54 15-Apr-14 17:45 53:10:01 Fluid wt 8.8 ppg 34 232.80 74 108 127.83 3265.60 164.68 1449.08 0.00 1488.00 0.00 0.107358 1476.84 11.16 0.00 0.001118 15.38 15.50 96.40 75.35 98.71 1.75 N/R 100.00 0.75 99.25 N/R 1.79 37.88 0.766336 607.49 647.15 15-Apr-14 18:00 53:25:01 BS&W: 99% Brine & 1% Sediment, Trace Oil, PH=7, Salinity=40000ppm 34 221.18 73 98 126.69 3214.02 159.86 1444.87 0.00 2083.20 0.00 0.092492 2062.37 20.83 0.00 0.000963 21.48 21.70 111.30 71.94 101.01 1.75 N/R 40000 7 100.00 1.00 99.00 N/R 1.79 38.32 0.767299 628.97 669.07 15-Apr-14 18:15 53:40:01 34 208.94 73 117 96.15 3308.27 158.42 1448.69 0.00 3050.40 0.00 0.093582 3019.90 30.50 0.00 0.000975 31.46 31.78 110.82 69.66 96.32 1.75 N/R 100.00 1.00 99.00 N/R 1.79 38.95 0.768274 660.43 701.16 15-Apr-14 18:30 53:55:01 BS&W: 95% Brine & 0.5% Sediment. Oil 4.5%. Salinity=40000ppm; 8.75 lb/gal H2O 34 10.93 73 17 1.00 2926.21 156.98 1439.89 0.00 223.20 10.04 0.096095 212.04 1.12 0.10 0.001001 2.21 2.33 114.57 67.74 95.86 1.75 N/R 40000 95.50 0.50 95.00 0.00 1.89 38.98 0.769275 662.63 703.50 15-Apr-14 18:45 54:10:01 34 3.82 72 8 -2.01 2907.88 157.41 1424.98 0.00 0.00 0.00 0.093088 0.00 0.00 0.00 0.000970 0.00 0.00 113.57 65.84 91.47 1.75 N/R 95.50 0.50 95.00 N/R 1.89 38.98 0.770245 662.63 703.50 15-Apr-14 19:00 54:25:01 BS&W: 99.75% Brine & 0.25%Sediment. 9.75 lb/gal H2O 34 98.62 68 95 9.73 2992.62 158.32 1434.35 0.00 0.00 0.00 0.092531 0.00 0.00 0.00 0.000964 0.00 0.00 112.50 64.61 87.71 1.75 N/R 100.00 0.25 99.75 N/R 1.89 38.98 0.771209 662.63 703.50 15-Apr-14 19:15 54:40:01 34 295.87 71 125 168.69 3403.63 158.78 1445.63 0.00 1492.22 0.00 0.095765 1488.49 3.73 0.00 0.000998 15.51 15.54 120.51 64.04 95.38 1.75 N/R 100.00 0.25 99.75 N/R 1.89 39.05 0.772206 678.14 719.08 15-Apr-14 19:30 54:55:01 BS&W: 100% Brine with trace oil 34 165.37 73 123 47.47 3449.34 158.06 1455.96 0.00 1618.56 0.00 0.097144 1618.56 0.00 0.00 0.001012 16.86 16.86 121.15 63.11 102.72 1.75 N/R 100.00 0.00 100.00 N/R 1.89 39.05 0.773218 695.00 735.94 15-Apr-14 19:45 55:10:01 34 153.98 73 120 36.61 3350.08 157.27 1445.44 0.00 1280.26 0.00 0.095292 1280.26 0.00 0.00 0.000993 13.34 13.34 124.82 62.17 98.80 1.75 N/R 100.00 0.00 100.00 N/R 1.89 39.05 0.774211 708.34 749.28 15-Apr-14 20:00 55:25:01 **Sand to surface. BS&W: 99.5% Brine & 0.5% Sediment 34 208.72 73 122 85.46 3398.00 156.10 1463.61 0.00 2080.42 0.00 0.094153 2070.01 10.40 0.00 0.000981 21.56 21.67 125.33 61.32 94.67 1.75 N/R 100.00 0.50 99.50 N/R 1.89 39.27 0.775192 729.90 771.06 15-Apr-14 20:15 55:40:01 Increased sand returns 34 51.61 78 50 -0.33 3398.00 156.10 1486.75 500.00 800.16 0.00 0.097455 796.16 4.00 0.00 0.001015 8.29 8.34 122.05 60.43 95.75 1.75 N/R 100.00 0.50 99.50 N/R 1.89 39.35 0.776207 738.19 779.43 15-Apr-14 20:30 55:55:01 BS&W: 99.75% Brine & 0.25% Sediment. Sand returns 34 64.30 76 56 7.40 3398.00 156.10 1520.42 500.00 160.03 0.00 0.096897 159.63 0.40 0.00 0.001009 1.66 1.67 120.43 60.82 109.96 1.75 N/R 100.00 0.25 99.75 N/R 1.89 39.36 0.777216 739.85 781.11 15-Apr-14 20:45 56:10:01 Decrease in sand returns. N2 returns 34 325.99 76 127 195.27 3398.00 156.10 1489.82 500.00 400.08 0.00 0.099005 399.08 1.00 0.00 0.001031 4.16 4.17 123.39 60.89 118.88 1.75 N/R 100.00 0.25 99.75 N/R 1.89 39.38 0.778247 744.01 785.28 15-Apr-14 21:00 56:25:01 BS&W: 99.5%H2O & 0.5% sediment. Sparging every 10min 34 934.70 79 137 769.89 3398.00 156.10 1532.28 500.00 1120.22 0.00 0.378406 1114.62 5.60 0.00 0.003942 11.61 11.67 127.50 67.40 103.42 1.75 N/R 100.00 0.50 99.50 N/R 1.89 39.50 0.782189 755.62 797.01 15-Apr-14 21:15 56:40:01 34 755.65 76 149 529.88 3439.20 152.52 1498.23 500.00 1360.27 0.00 0.500579 1353.47 6.80 0.00 0.005214 14.10 14.17 122.95 71.18 102.98 1.75 N/R 100.00 0.50 99.50 N/R 1.89 39.64 0.787403 769.72 811.25 15-Apr-14 21:30 56:55:01 BS&W: 99.5% Brine & 0.5% Sediment 34 1246.87 76 156 1086.92 3869.18 152.55 1485.42 0.00 400.08 0.00 0.521150 398.08 2.00 0.00 0.005429 4.15 4.17 127.34 72.41 105.68 1.75 N/R 100.00 0.50 99.50 N/R 1.89 39.68 0.792832 773.87 815.44 15-Apr-14 21:45 57:10:01 34 215.21 68 111 93.29 2677.24 153.47 1430.14 0.00 1120.22 0.00 0.629174 1114.62 5.60 0.00 0.006554 11.61 11.67 136.76 74.14 104.67 1.75 N/R 100.00 0.50 99.50 N/R 1.89 39.80 0.799386 785.48 827.17 15-Apr-14 22:00 57:25:01 BS&W: 99.75% Brine & 0.25% Sediment 34 270.57 65 126 142.47 2300.31 157.08 1438.94 0.00 80.02 0.00 0.279533 79.82 0.20 0.00 0.002912 0.83 0.83 121.48 73.56 109.75 1.75 N/R 100.00 0.25 99.75 N/R 1.89 39.80 0.802298 786.31 828.00 15-Apr-14 22:15 57:40:01 34 201.45 63 142 57.54 2340.51 159.90 1436.07 0.00 160.03 0.00 0.177535 159.63 0.40 0.00 0.001849 1.66 1.67 131.98 72.99 121.43 1.75 N/R 100.00 0.25 99.75 N/R 1.89 39.81 0.804147 787.97 829.67 15-Apr-14 22:30 57:55:01 No Fluid Returns 34 153.21 67 116 29.06 2398.68 161.05 1436.07 0.00 0.00 0.00 0.139867 0.00 0.00 0.00 0.001457 0.00 0.00 121.82 71.83 116.14 1.75 N/R 0.00 N/R 1.89 39.81 0.805604 787.97 829.67 15-Apr-14 22:45 58:10:01 N2 online @1000 scf/min 34 144.42 63 141 -3.39 2328.82 161.55 1462.85 1000.00 0.00 0.00 0.101998 0.00 0.00 0.00 0.001062 0.00 0.00 135.55 69.26 114.89 1.75 N/R 0.00 N/R 1.89 39.81 0.806667 787.97 829.67 15-Apr-14 23:00 58:25:01 BS&W: 100% Brine 34 541.58 70 117 416.87 2928.60 161.94 1494.02 1000.00 80.02 0.00 0.132182 80.02 0.00 0.00 0.001377 0.83 0.83 134.46 68.39 119.20 1.75 N/R 100.00 0.00 100.00 N/R 1.89 39.81 0.808043 788.81 830.51 15-Apr-14 23:15 58:40:01 34 511.13 70 102 414.50 3116.26 160.66 1458.45 1000.00 400.08 0.00 0.183108 400.08 0.00 0.00 0.001907 4.17 4.17 127.55 70.29 127.57 1.75 N/R 100.00 0.00 100.00 N/R 1.89 39.81 0.809951 792.97 834.68 15-Apr-14 23:30 58:55:01 BS&W: 95%Brine & trace sediment. Oil 5%. Gas SG = 0.97 34 636.28 64 204 399.33 2703.63 160.12 1469.92 1000.00 2480.50 124.02 0.766999 2356.47 0.00 1.29 0.007990 24.55 25.84 123.85 71.91 83.18 1.75 N/R 95.00 0.00 95.00 0.970 0.00 3.18 39.81 0.817940 817.52 860.51 15-Apr-14 23:45 59:10:01 34 459.36 61 163 276.63 2167.07 161.50 1535.72 1000.00 960.19 48.01 1.782938 912.18 0.00 0.50 0.018572 9.50 10.00 155.27 77.59 105.07 1.75 N/R 95.00 0.00 95.00 0.00 3.68 39.81 0.836513 827.02 870.52 16-Apr-14 00:00 59:25:01 BS&W: 100% Brine, trace sediment, trace Oil 34 464.01 61 193 247.84 1700.65 162.86 1487.52 1000.00 800.16 0.00 1.951692 800.16 0.00 0.00 0.020330 8.33 8.33 163.51 81.10 109.93 1.75 N/R 100.00 0.00 100.00 N/R 3.68 39.81 0.856843 835.36 878.85 16-Apr-14 00:15 59:40:00 34 402.75 60 189 200.60 1561.20 163.88 1467.82 0.00 160.03 0.00 2.045077 160.03 0.00 0.00 0.021303 1.67 1.67 173.12 87.07 114.81 1.75 N/R 100.00 0.00 100.00 N/R 3.68 39.81 0.878146 837.02 880.52 16-Apr-14 00:30 59:55:00 No Fluid Returns 34 131.19 60 108 17.01 1532.09 164.47 1477.19 0.00 160.03 160.03 1.491731 0.00 0.00 1.67 0.015539 0.00 1.67 147.80 84.01 111.60 1.75 N/R 0.00 0.00 5.35 39.81 0.893685 837.02 882.18 16-Apr-14 00:45 60:10:00 34 98.70 59 98 2.12 1548.64 164.89 1496.70 0.00 0.00 0.00 0.359473 0.00 0.00 0.00 0.003745 0.00 0.00 101.66 80.82 105.57 1.75 N/R 0.00 N/R 5.35 39.81 0.897429 837.02 882.18 16-Apr-14 01:00 60:25:00 No Fluid Returns 34 87.23 59 86 0.87 1648.48 165.06 1469.54 500.00 0.00 0.00 0.159844 0.00 0.00 0.00 0.001665 0.00 0.00 120.18 77.82 100.98 1.75 N/R 0.00 N/R 5.35 39.81 0.899094 837.02 882.18 16-Apr-14 01:15 60:40:00 34 171.64 53 132 25.02 1640.10 165.07 1530.94 300.00 0.00 0.00 0.178024 0.00 0.00 0.00 0.001854 0.00 0.00 109.25 77.52 122.13 1.75 N/R 0.00 N/R 5.35 39.81 0.900948 837.02 882.18 16-Apr-14 01:30 60:55:00 BS&W: 97% Brine & trace sediment. Oil 3%34 438.91 56 190 227.68 1511.39 165.29 1506.07 300.00 0.00 0.00 0.303948 0.00 0.00 0.00 0.003166 0.00 0.00 137.65 77.97 107.78 1.75 N/R 97.00 0.00 97.00 N/R 5.35 39.81 0.904115 837.02 882.18 16-Apr-14 01:45 61:10:00 34 310.55 55 174 124.29 1143.44 165.70 1494.21 300.00 1840.37 55.21 1.409619 1785.16 0.00 0.58 0.014684 18.60 19.17 169.61 82.54 117.09 1.75 N/R 97.00 0.00 97.00 0.00 5.92 39.81 0.918798 855.62 901.36 16-Apr-14 02:00 61:25:00 BS&W: 96% Brine, trace sediment. Oil 4%. N2 offline 34 214.45 55 147 63.33 984.48 166.11 1478.91 0.00 160.03 6.40 1.220482 153.63 0.00 0.07 0.012713 1.60 1.67 148.27 85.70 122.96 1.75 N/R 96.00 0.00 96.00 0.00 5.99 39.81 0.931511 857.22 903.02 16-Apr-14 02:15 61:40:00 34 128.59 54 113 13.73 906.44 166.58 1451.37 0.00 0.00 0.00 0.856834 0.00 0.00 0.00 0.008925 0.00 0.00 133.37 87.09 124.65 1.75 N/R 96.00 0.00 96.00 N/R 5.99 39.81 0.940437 857.22 903.02 Expro Confidential 5/6/2014 Page 10 CUSTOMER:TEST No: CUSTOMER REP:START DATE: EXPRO SUPERVISOR:END DATE: WELL NUMBER: Comments Ratio Methanol Time & Date El a p s e d T i m e Ch o k e S i z e M a n u a l Re a d WH P @ t h e We l l h e a d WH T @ S w a b Do wn S t r e a m Ch o k e Di f f P r e s s A c r o s s Ch o k e Bo t t o m H o l e Pr e s s u r e ( L o w e r Ga u g e ) Bo t t o m H o l e Te m p e r a t u r e An n u l u s P r e s s u r e N it r o g e n I n j e c t i o n To t a l F l u i d s Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r M ud & S e d i m e n t Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r T ot a l F l u i d In c r e m e n t Pr e s s u r e @ M e t e r Ru n Ga s T e m p e r a t u r e @ M e t e r R u n Oi l T e m p e r a t u r e @ Oi l L e g Or i f a c e P l a t e S i z e Oi l G r a v i t y M a n u a l Re a d Oi l G r a v i t y M a n u a l Re a d ( C o r r e c t e d ) Wa t e r G r a v i t y Ma n u a l R e a d Wa t e r S a l i n i t y Ma n u a l R e a d Wa t e r p H M a n u a l Re a d BS & W S h a k e o u t s S ol i d s , M u d , Em u l s i o n Wa t e r C u t Ga s G r a v i t y Ra n a r e x M a n u a l Re a d CO 2 D r a g e r M a n u a l Re a d H² S D r a g e r M a n u a l Re a d GO R O il Mu d Ga s @ E X P R O Se p a r a t o r Wa t e r C a l c . f r o m Sa m p l e s To t a l F l u i d S ur f a c e I n j e c t i o n Ma n u a l R e a d (dd-mmm-yy hh:mm)(hours)Initial WHP 2166.1 psig Initial BHP 5347.3 psig (64ths)(psig)(F)(psi)(psig)(psig)(F)(psig)(scf/min)(stb/d)(stb/d)(MMscf/d)(stb/d)stb/d (stb)(MMscf)(stb)(stb)(psig)(F)(F)(inches)(SG60)(API60)(API60)(ppm)(pH)(%)(%)(%)(Air=1)(%)(ppm)(Mscfd/bbls)(stb)(stb)(MMscf)(stb)(stb)(gal/day) Repsol E&P USA David Ross 2 April 13, 2014 April 16, 2014 Time Rates SeparatorVolumes (15 mins)Choke BS&W Properties 12:35 hrs Casing Roland Taylor Qugruk-5A Cumulatives Well Test Report (15 min) Gas PropertiesFluid Properties 22:00 hrs 16-Apr-14 02:30 61:55:00 Swab Valve and Master Hydraulic Closed 34 90.37 53 88 1.36 916.93 166.72 1438.36 0.00 0.00 0.00 0.310796 0.00 0.00 0.00 0.003237 0.00 0.00 107.30 83.66 117.77 1.75 N/R 0.00 N/R 5.99 39.81 0.943674 857.22 903.02 16-Apr-14 02:45 62:10:00 34 1.30 51 0 1.52 980.05 166.80 1490.77 0.00 0.00 0.00 0.261145 0.00 0.00 0.00 0.002720 0.00 0.00 34.26 82.37 108.76 1.75 N/R 0.00 N/R 5.99 39.81 0.946395 857.22 903.02 16-Apr-14 03:00 62:25:00 Decrease choke to 20/64ths 20 0.00 51 0 0.00 1040.42 166.85 1471.07 0.00 0.00 0.00 0.036701 0.00 0.00 0.00 0.000382 0.00 0.00 4.84 77.86 102.47 1.75 N/R 0.00 N/R 5.99 39.81 0.946777 857.22 903.02 16-Apr-14 03:15 62:40:00 20 1.45 52 0 0.00 1084.17 166.82 1442.38 0.00 0.00 0.00 0.037283 0.00 0.00 0.00 0.000388 0.00 0.00 4.66 73.49 97.91 1.75 N/R 0.00 N/R 5.99 39.81 0.947165 857.22 903.02 16-Apr-14 03:30 62:55:00 20 0.00 54 0 0.00 1117.40 166.78 1430.91 0.00 0.00 0.00 0.038332 0.00 0.00 0.00 0.000399 0.00 0.00 4.08 70.91 93.85 1.75 N/R 0.00 N/R 5.99 39.81 0.947565 857.22 903.02 16-Apr-14 03:45 63:10:00 20 0.00 54 0 0.00 1147.49 166.75 1476.81 0.00 0.00 0.00 0.038583 0.00 0.00 0.00 0.000402 0.00 0.00 4.76 68.85 91.01 1.75 N/R 0.00 N/R 5.99 39.81 0.947966 857.22 903.02 16-Apr-14 04:00 63:25:00 Well shut-in at Master Valve 20 0.00 54 0 0.00 1174.59 166.73 1468.20 0.00 0.00 0.00 0.038183 0.00 0.00 0.00 0.000398 0.00 0.00 4.74 67.47 88.40 1.75 N/R 0.00 N/R 5.99 39.81 0.948364 857.22 903.02 16-Apr-14 04:15 63:40:00 20 0.00 54 0 0.00 1199.50 166.71 1443.15 0.00 0.00 0.00 0.036849 0.00 0.00 0.00 0.000384 0.00 0.00 4.42 65.95 85.75 1.75 N/R 0.00 N/R 5.99 39.81 0.948748 857.22 903.02 16-Apr-14 04:30 63:55:00 20 0.00 54 0 0.00 1222.52 166.69 1433.39 0.00 0.00 0.00 0.036856 0.00 0.00 0.00 0.000384 0.00 0.00 4.31 65.18 83.84 1.75 N/R 0.00 N/R 5.99 39.81 0.949132 857.22 903.02 16-Apr-14 04:45 64:10:00 20 0.00 54 0 0.95 1244.39 166.67 1482.55 0.00 0.00 0.00 0.031835 0.00 0.00 0.00 0.000332 0.00 0.00 5.50 64.27 81.89 1.75 N/R 0.00 N/R 5.99 39.81 0.949464 857.22 903.02 16-Apr-14 05:00 64:25:00 20 0.00 54 0 0.00 1264.85 166.67 1473.37 0.00 0.00 0.00 0.036678 0.00 0.00 0.00 0.000382 0.00 0.00 4.21 63.67 80.25 0.75 N/R 0.00 N/R 5.99 39.81 0.949846 857.22 903.02 16-Apr-14 05:15 64:40:00 20 0.00 54 0 0.00 1284.40 166.65 1463.99 0.00 0.00 0.00 0.036556 0.00 0.00 0.00 0.000381 0.00 0.00 4.32 63.44 78.86 0.75 N/R 0.00 N/R 5.99 39.81 0.950226 857.22 903.02 16-Apr-14 05:30 64:55:00 20 0.00 54 0 0.00 1303.22 166.64 1445.44 0.00 0.00 0.00 0.037301 0.00 0.00 0.00 0.000389 0.00 0.00 4.78 62.73 77.62 0.75 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 05:45 65:10:00 20 0.00 54 0 0.57 1321.31 166.64 1433.97 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.65 62.32 76.22 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 06:00 65:25:00 Well shut-in at Master Valve 20 0.00 56 0 0.00 1338.91 166.64 1483.31 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.24 62.02 75.15 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 06:15 65:40:00 20 0.00 55 0 0.00 1355.88 166.63 1467.63 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.55 61.77 74.16 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 06:30 65:55:00 20 0.00 56 0 0.00 1372.41 166.63 1464.76 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.45 61.20 73.14 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 06:45 66:10:00 20 0.00 56 0 0.00 1388.61 166.63 1453.28 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.73 60.95 72.18 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 07:00 66:25:00 Well shut-in at Master Valve 20 0.00 56 0 0.00 1404.48 166.63 1450.03 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.19 60.86 71.69 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 07:15 66:40:00 20 0.00 55 0 0.00 1420.03 166.63 1435.11 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.38 60.77 70.97 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 07:30 66:55:00 20 0.00 55 0 0.00 1435.49 166.63 1433.97 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.07 61.01 70.56 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 07:45 67:10:00 20 0.00 54 0 0.00 1450.80 166.64 1465.14 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.14 61.32 70.21 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 08:00 67:25:00 Shut-in at choke manifold (08:00 hrs) 0 0.00 53 0 0.00 1465.81 166.64 1467.82 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.36 61.97 70.03 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 08:15 67:40:00 Open Master valve on wellhead 0 171.64 53 0 170.77 1470.79 166.65 1458.64 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.58 62.14 70.05 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 08:30 67:55:00 Shut-in at choke manifold. Monitoring wellhead pressure 0 172.32 52 0 170.96 1486.50 166.68 1451.18 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.78 62.22 70.01 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 08:45 68:10:00 0 177.60 51 0 174.19 1501.33 166.69 1442.38 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 5.20 62.02 69.66 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 09:00 68:25:00 Shut-in at choke manifold. Monitoring wellhead pressure 0 180.20 51 0 179.13 1515.76 166.70 1437.79 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 4.57 62.32 69.42 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 09:15 68:40:00 0 180.81 50 0 183.50 1530.07 166.71 1435.69 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 5.01 62.27 69.12 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 09:30 68:55:00 0 183.94 49 0 182.55 1542.90 166.72 1431.29 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 5.53 62.49 69.65 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 09:45 69:10:00 0 189.83 49 0 186.91 1557.39 166.72 1429.95 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.96 62.28 70.34 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 10:00 69:25:00 Shut-in at choke manifold. Monitoring wellhead pressure 0 191.59 48 0 187.10 1571.68 166.73 1419.24 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.98 62.31 70.28 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 10:15 69:40:00 0 191.36 48 0 187.41 1585.85 166.74 1424.78 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.69 62.46 70.02 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 10:30 69:55:00 0 197.78 48 0 190.52 1599.93 166.75 1415.22 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 7.18 62.45 69.68 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 10:45 70:10:00 0 202.37 49 0 193.18 1613.99 166.75 1404.89 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.85 62.35 69.27 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 11:00 70:25:00 Shut-in at choke manifold. Monitoring wellhead pressure 0 200.84 50 0 200.02 1627.89 166.76 1404.13 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.81 62.37 68.86 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 11:15 70:40:00 0 203.21 51 0 202.00 1641.77 166.76 1401.26 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.59 62.69 69.09 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 11:30 70:55:00 0 207.26 51 0 204.77 1655.61 166.78 1482.55 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 7.07 62.61 68.89 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 11:45 71:10:00 0 208.72 51 1 206.74 1669.19 166.79 1478.91 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 7.16 62.25 68.63 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 12:00 71:25:00 Shut-in at choke manifold. Monitoring wellhead pressure 0 214.91 52 0 208.38 1682.68 166.79 1469.73 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.77 62.45 68.60 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 12:15 71:40:00 0 215.06 52 0 210.85 1696.11 166.80 1462.85 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.83 62.45 68.28 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 12:30 71:55:00 0 221.64 52 0 216.17 1709.35 166.80 1459.60 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.92 62.19 68.25 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 12:45 72:10:00 0 219.57 52 1 214.91 1722.50 166.80 1467.05 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.64 62.37 67.91 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 13:00 72:25:00 Shut-in at choke manifold. Monitoring wellhead pressure 0 224.77 51 0 218.64 1735.56 166.81 1451.75 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.78 62.42 67.93 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 13:15 72:40:00 0 224.62 52 0 225.66 1748.44 166.81 1461.13 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.93 62.19 67.89 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 13:30 72:55:00 0 229.82 51 0 226.99 1761.09 166.81 1454.05 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.73 62.18 67.77 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 13:45 73:10:00 0 233.10 51 1 231.51 1773.57 166.81 1445.06 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.75 62.19 67.52 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 14:00 73:25:00 Shut-in at choke manifold. Monitoring wellhead pressure 0 234.71 51 0 234.25 1785.95 166.81 1442.19 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.85 61.91 67.54 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 14:15 73:40:00 0 239.53 49 0 234.02 1798.10 166.81 1441.23 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.86 62.44 67.59 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 14:30 73:55:00 0 239.07 50 0 241.43 1810.05 166.81 1443.15 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.93 62.25 67.35 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 14:45 74:10:00 0 240.29 50 0 238.96 1821.80 166.81 1440.66 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.77 62.30 67.38 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 15:00 74:25:00 Shut-in at choke manifold. Monitoring wellhead pressure 0 242.35 51 0 239.15 1833.54 166.82 1484.84 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.94 62.16 67.35 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 15:15 74:40:00 Open choke to bleed down pressure (15:13)0 94.27 52 0 92.13 1844.80 166.82 1482.55 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 6.49 62.55 67.29 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 15:30 74:55:00 Shut-in well at wing valve to pressure test E-line lubricator 0 0.00 51 0 0.00 1853.24 166.82 1480.63 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.39 62.99 78.00 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 15:45 75:10:01 0 0.00 52 0 0.00 1861.24 166.83 1468.58 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.64 63.31 75.91 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 16:00 75:25:01 0 0.00 52 0 0.38 1872.46 166.83 1466.86 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 20.27 63.03 74.68 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 16:15 75:40:02 0 0.00 52 0 0.00 1883.52 166.83 1465.33 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.99 62.97 73.80 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 16:30 75:55:02 0 0.00 52 0 0.00 1894.27 166.83 1469.35 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.85 62.93 73.24 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 16:45 76:10:03 0 0.00 52 0 0.00 1904.77 166.82 1471.64 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.50 63.39 72.78 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 17:00 76:25:03 0 0.00 52 0 0.00 1915.09 166.82 1463.04 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.79 63.13 72.41 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 17:15 76:40:04 0 0.00 52 0 0.00 1925.23 166.82 1471.07 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.63 63.38 71.88 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 17:30 76:55:04 0 0.00 52 0 0.00 1935.25 166.81 1468.01 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.69 63.27 71.67 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 17:45 77:10:05 0 0.00 53 0 0.00 1945.13 166.81 1460.55 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.73 63.23 71.40 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 Expro Confidential 5/6/2014 Page 11 CUSTOMER:TEST No: CUSTOMER REP:START DATE: EXPRO SUPERVISOR:END DATE: WELL NUMBER: Comments Ratio Methanol Time & Date El a p s e d T i m e Ch o k e S i z e M a n u a l Re a d WH P @ t h e We l l h e a d WH T @ S w a b Do wn S t r e a m Ch o k e Di f f P r e s s A c r o s s Ch o k e Bo t t o m H o l e Pr e s s u r e ( L o w e r Ga u g e ) Bo t t o m H o l e Te m p e r a t u r e An n u l u s P r e s s u r e N it r o g e n I n j e c t i o n To t a l F l u i d s Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r M ud & S e d i m e n t Oi l Ga s @ E x p r o Se p a r a t o r Wa t e r T ot a l F l u i d In c r e m e n t Pr e s s u r e @ M e t e r Ru n Ga s T e m p e r a t u r e @ M e t e r R u n Oi l T e m p e r a t u r e @ Oi l L e g Or i f a c e P l a t e S i z e Oi l G r a v i t y M a n u a l Re a d Oi l G r a v i t y M a n u a l Re a d ( C o r r e c t e d ) Wa t e r G r a v i t y Ma n u a l R e a d Wa t e r S a l i n i t y Ma n u a l R e a d Wa t e r p H M a n u a l Re a d BS & W S h a k e o u t s S ol i d s , M u d , Em u l s i o n Wa t e r C u t Ga s G r a v i t y Ra n a r e x M a n u a l Re a d CO 2 D r a g e r M a n u a l Re a d H² S D r a g e r M a n u a l Re a d GO R O il Mu d Ga s @ E X P R O Se p a r a t o r Wa t e r C a l c . f r o m Sa m p l e s To t a l F l u i d S ur f a c e I n j e c t i o n Ma n u a l R e a d (dd-mmm-yy hh:mm)(hours)Initial WHP 2166.1 psig Initial BHP 5347.3 psig (64ths)(psig)(F)(psi)(psig)(psig)(F)(psig)(scf/min)(stb/d)(stb/d)(MMscf/d)(stb/d)stb/d (stb)(MMscf)(stb)(stb)(psig)(F)(F)(inches)(SG60)(API60)(API60)(ppm)(pH)(%)(%)(%)(Air=1)(%)(ppm)(Mscfd/bbls)(stb)(stb)(MMscf)(stb)(stb)(gal/day) Repsol E&P USA David Ross 2 April 13, 2014 April 16, 2014 Time Rates SeparatorVolumes (15 mins)Choke BS&W Properties 12:35 hrs Casing Roland Taylor Qugruk-5A Cumulatives Well Test Report (15 min) Gas PropertiesFluid Properties 22:00 hrs 16-Apr-14 18:00 77:25:05 0 0.00 54 0 0.00 1954.75 166.81 1461.51 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 20.04 62.59 70.53 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 18:15 77:40:06 0 0.00 55 0 0.00 1964.27 166.81 1454.81 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.89 61.99 69.49 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 18:30 77:55:06 0 0.00 56 0 0.00 1973.68 166.80 1453.67 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.19 61.85 69.02 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 18:45 78:10:07 0 0.00 57 0 0.00 1982.89 166.80 1453.67 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.07 61.90 68.38 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 19:00 78:25:07 0 0.00 56 0 0.00 1992.05 166.80 1448.50 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.96 61.89 67.98 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 19:15 78:40:08 0 0.00 56 0 0.00 2000.93 166.79 1454.24 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.41 61.94 67.43 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 19:30 78:55:08 0 0.00 55 0 0.00 2009.71 166.79 1449.46 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.15 61.68 67.10 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 19:45 79:10:09 0 0.00 54 0 0.00 2018.32 166.79 1456.15 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.45 61.24 66.48 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 20:00 79:25:09 0 0.61 54 0 0.00 2026.87 166.78 1443.72 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.27 60.94 65.80 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 20:15 79:40:10 Open wing valve on tree to bleed off lubricator 0 0.00 54 0 0.00 2035.33 166.78 1451.56 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 19.10 60.39 65.16 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 20:30 79:55:10 Wing valve shut-in at the wellhead 0 0.00 50 0 0.00 1949.17 166.81 1441.23 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.95 60.13 64.42 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 20:45 80:10:11 0 0.00 50 0 0.00 1973.19 166.95 1449.84 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.75 59.80 64.04 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 21:00 80:25:11 0 0.00 50 0 0.00 1988.24 166.95 1444.29 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.72 59.43 63.07 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 21:15 80:40:12 0 0.00 50 0 -0.15 2000.33 166.94 1450.61 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.63 59.10 62.68 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 21:30 80:55:12 0 0.00 49 0 0.00 2010.94 166.94 1443.34 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.49 58.69 61.81 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 21:45 81:10:13 0 0.00 49 0 0.00 2020.83 166.93 1438.94 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.36 58.22 61.36 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 16-Apr-14 22:00 81:25:13 E-line start RIH with perforating guns 0 0.00 48 0 0.00 2025.69 166.92 1440.66 0.00 0.00 0.00 0.000000 0.00 0.00 0.00 0.000000 0.00 0.00 18.23 57.94 60.69 0.00 N/R 0.00 N/R 5.99 39.81 0.950615 857.22 903.02 0 10 20 30 40 50 60 70 80 90 100 0.00 1000.00 2000.00 3000.00 4000.00 5000.00 6000.00 We l l H e a d T e m p e r a t u r e [ F ] a n d C h o k e S i z e [ 6 4 t h s ] Pr e s s u r e [ p s i g ] Date & Time WELL HEAD PLOT Qugruk-5A WHP Annulus Press WHT Choke Size 0 10 20 30 40 50 60 70 0.00 1000.00 2000.00 3000.00 4000.00 5000.00 6000.00 Ch o k e S i z e [ 6 4 t h s ] Pr e s s u r e [ p s i g ] Date & Time WELL HEAD & BOTTOM HOLE PLOT Qugruk-5A Well Head Press Bottom Hole Press Choke Size 140.00 145.00 150.00 155.00 160.00 165.00 170.00 175.00 0.00 1000.00 2000.00 3000.00 4000.00 5000.00 6000.00 Te m p e r a t u r e [ F ] Date & Time BOTTOM HOLE PLOT Qugruk-5A Bottom Hole Pressure Bottom Hole Temperature Pr e s s u r e [ p s i g ] 0.00 10.00 20.00 30.00 40.00 50.00 60.00 70.00 80.00 90.00 100.00 0.00 20.00 40.00 60.00 80.00 100.00 120.00 140.00 160.00 180.00 200.00 Te m p e r a t u r e [ F ] Date & Time SEPARATOR PLOT Qugruk-5A Separator Pressure Separator Temperature 0.000000 0.500000 1.000000 1.500000 2.000000 2.500000 0.00 500.00 1000.00 1500.00 2000.00 2500.00 3000.00 3500.00 Fl o w R a t e s [ M M s c f / d ] Fl o w R a t e [ s t b / d ] Date & Time PRODUCTION PLOT Qugruk-5A Oil Rate Water Rate Total Liquid Rate Mud Rate Gas Rate 0.000000 0.100000 0.200000 0.300000 0.400000 0.500000 0.600000 0.700000 0.800000 0.900000 1.000000 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 Cu m u l a t i v e V o l u m e [ M M s c f ] Cu m u l a t i v e V o l u m e [ B b l s ] Date & Time CUMULATIVE PLOT Qugruk-5A Oil Cumulative Water Cumulative Total Liquid Mud Cummulative Gas Cumulative Page 30 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED 22-Mar-14 14:00 Joe Fisher Vincent Madrid Arrive at Qugruk camp and check in with camp manager 14:30 Shelby Brown Vance Wolford Joe Fisher perform site visit of Q5 and Q7 with David Bray 16:30 Mark Atkinson T. Atkinson, S. Brown, V. Wolford and V. Madrid attend camp orientation 23-Mar-14 7:00 Hold safety meeting and fill out TRAC for building berms 7:30 Crew arrive at Q5 pad and sign in with the rig 8:00 Attend berm building safety meeting with all parties involved in building berms 9:00 Assist Cruz Construction in laying out liner for the frac berm 9:30 Begin nailing down sills on berm 10:30 Roll 1/2 of berm liner back to bring in crane 11:00 Attend Drill site orientation (Joe, Shelby, Travis, Vance and Vince) 12:30 Look over equipment with Crane operators to plan for spotting equipment 1:00 Joe & Vance depart for Deadhorse to pick up rental trucks 14:00 Assist crane operation with laying down rig mats in frac berm 24-Mar-14 6:00 Crew arrive on location 6:15 Safety meeting and TRAC for building berms 6:30 Safety meeting with Crane crew about setting rig mats 6:45 Start setting rig mats 10:00 Move crane over to main Expro berm 12:00 Start setting rig mats in generator berm 12:45 Start setting rig mats in main well test berm 16:30 Finished setting rig mats in main well test berm 25-Mar-14 6:00 Crew arrive on location 6:15 Safety meeting and TRAC for spotting equipment 6:30 Safety meeting with Crane crew about spotting equipment 6:45 Safety meeting and TRAC for loading equipment at camp pad 8:00 Load separator onto winch truck 9:00 Spot separator into berm with winch truck 10:00 Spot doghouse into berm with winch truck 13:00 Move doghouse up to separator with crane Travis Atkinson Shelby Brown Vance Wolford Vince Madrid Joe Fisher Travis Atkinson Vince Madrid Shelby Brown Vance Wolford Vince Madrid Joe Fisher Joe Fisher Travis Atkinson Shelby Brown Vance Wolford Sequence of Events STE CREW ON SITE Page 31 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 25-Mar-14 14:00 Spot vertical separator with bed truck 15:00 Spot line heater into berm with bed truck 16:00 Spot dual compressor with crane 17:00 Spot Dual Generator with crane 26-Mar-14 6:00 Crew arrive on location 6:15 Safety meeting and TRAC for spotting equipment 6:30 Safety meeting with Crane crew about spotting equipment 6:45 Safety meeting and TRAC for loading equipment at camp pad 7:30 Spot Choke with loader 9:00 Spot sand tank with loader 10:00 Place heater on generators 11:00 Rig up to relief tank 12:30 Spot relief tank with crane 13:00 Roland Taylor Chris Tobin R. Taylor, S. Oyao, M. Joiner and C. Tobin checks in flights to Deadhorse 13:00 Sharon Oyao Jordan Mooney A. McCabe, B. Hickey and J. Mooney checks in flight to Deadhorse 13:30 Michael Joiner Brent Hickey Spot sand trap with crane 14:30 Start generator #2 (Gen A2035 8537 hrs, Gen A6363 6363 hrs.) 14:45 Crew flight departs Anchorage for Deadhorse 15:00 Plug in equipment and start powering up 15:15 Load truck with flare stack and related equipment 16:45 Crew arrive Deadhorse. Locate truck and drive to Qugruk location. Obtain Repsol badges 17:00 Install igniter on flare stack 20:20 Crew arrive on location and checks in with camp manager. Receive room assignments 27-Mar-14 6:00 Day crew arrive on Qugruk-5 location 6:30 Hold Safety meeting with the Client and Expro crew at the Rig camp 7:00 Conduct walk around well site area 7:30 Hold Safety Meeting. Discuss current operations and today's tasks 8:00 Create TRAC for rigging up equipment and pipework 8:30 Replace and install data flanges at the inlet and outlet of choke Roland Taylor Joe Fisher Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Andrew McCabe Shelby Brown Joe Fisher Travis Atkinson Vance Wolford Page 32 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 27-Mar-14 10:00 Start testing flare igniter 13:00 Move data acquisition system equipment to choke house 13:15 Start unpacking consumables from the DAS Lab. Clean and organize office supplies 13:35 Hold safety huddle and discuss lifting flare stack 13:45 Start spotting flare anchors into position 14:10 Start installing shackles and guy wires on flare stack 14:30 Q7 crew members arrive on Q5 pad 14:40 Start lifting flare stack into position 14:50 Install turn buckles on flare anchors 15:00 Flare stack lifted into position 15:20 Start adjusting turn buckles to tension guy wires 16:00 Flare stack installation complete 16:00 Clean-up well test area in preparation for crew change 16:15 Day crew departs location. 16:30 Crew attends Repsol Site orientation 17:30 Repsol camp site orientation complete 18:45 Night crew arrive on Q5 pad. Hold shift handover and walk around well test area 19:30 Discuss positioning light plants with David Bray around well test area 20:00 Positioned light plants with forklift around the well test area. 20:15 Review JSA & TRAC card for rigging up well test equipment. 20:30 Load 2" & 3" 1502 pipe from Q-camp pad into truck and depart for Q5. 21:00 Start rigging up flow line from downstream choke to the heat exchanger inlet 21:30 Start rigging up 3" 206 gas flare line to the flarestack from the gas scrubber. 22:30 Start rigging up 3" 602 gas line from the separator to the gas scrubber. 23:30 Start rigging up 2" 1502 sparge line from sand trap to blow down tank. 28-Mar-14 1:30 Start rigging up 3" 602 relief line from the sand trap, separator & gas scrubber to the relief tank. 5:00 Clean up tools & work area in the well test area. 5:30 Day crew arrives on location 5:45 Hold shift handover meeting. Discuss current operation Shelby Brown Andrew McCabe Brent Hickey Vance Madrid Roland Taylor Chris Tobin Travis Atkinson Page 33 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 28-Mar-14 6:00 Nightshift departs on location 6:15 Hold pre-job safety meeting. Discuss today's operation and task 6:30 Continue rigging up oil line 6:35 Continue rigging up sand trap dump line 7:25 Install 4" flange on sand tank 7:40 Contact crane crew to move line heater 8:05 Re-spot data acquisition Lab 8:15 Start rigging up data acquisition system (DAS) 8:40 Complete connecting gas scrubber fluid outlet and separator oil outlet 8:55 Discuss crane operations with Repsol personnel 9:10 Complete rigging up sand trap dump to sand tank 10:00 Continue rigging up separator inlet 10:15 GCI Rep. visits lab and starts working on supplying communications to Expro lab 10:20 Start labeling transducers and installing on equipment 10:25 Crane re-spots line heater 10:45 Re-spot pipe trailer 10:55 Complete connecting downstream choke manifold to line heater inlet 11:20 Start rigging up sand dump from separator to sand tank 11:30 Completed sand dump line from separator to sand tank 11:30 Spotted Transducers 13:20 Start tightening all hammer union connections inside main berm 13:44 Start laying liner material under gas line to flare 15:00 Start connecting ground cables to all equipment 15:20 Start rigging up safety system 15:25 Start installing final berm wall on main berm 16:15 Main STE berm complete 17:00 Conduct well test area clean up 17:40 Night Crew arrive on location 17:40 Hold Shift Handover meeting. Discuss current operation. Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 34 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 28-Mar-14 18:00 Day crew depart location. 18:00 Night Crew hold toolbox talk, complete risk assessment. 18:30 Start installing restraint cables on flow line to choke and all relief lines. 19:00 Start pipe tally on pipe installed by day crew 20:00 Complete pipe tally 20:50 Complete installing restraint cables on inlet of choke manifold to separator inlet 21:00 Continue installing DAS pressure transducers and cables 22:00 Cleaned up pup joints and misc. items around the well test area 23:00 Complete installation of restraint cables on relief lines 29-Mar-14 0:00 Rig up gas scrubber drain into top of sand tank 0:30 Start assisting with laying out liner for tank farm 12:30 Spot portable heaters around well test area 1:15 Hold toolbox talk for spotting rig mats in tank farm berm. 1:30 Start spotting rig mats with crane in tank farm berm. 2:00 Install Hi / Lo pilot manifold on the separator inlet and continued to rig up safety system 4:00 Complete spotting rig mats in tank farm berm 4:15 Start rigging up heater trunk hoses from portable heaters 4:20 Raise stack on line heater and test fire burner. Unit operational 4:30 Start rigging up data acquisition cables to separator and heater transducers 5:30 Day crew arrives on location 5:45 Hold shift handover meeting. Discuss current operations 6:00 Night crew depart location 6:15 Attend daily operations meeting with Repsol completions supervisor 6:30 Hold pre-job safety meeting. Discuss shift activities 6:50 Continue rigging up safety system 6:55 Start rigging up air lines for instrumentation 7:00 Start building enclosure for sand trap 7:30 Continue rigging up data acquisition cables and transducers 7:45 Hold pre-job safety meeting. Write JSA for spotting tanks Jordan Mooney Vance Wolford Roland Taylor Michael Joiner Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Travis Atkinson Sharon Oyo Chris Tobin Page 35 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 29-Mar-14 8:15 Hold pre-task safety meeting with crane crew. Discuss spotting tanks 8:30 Test Igniter on flare. Igniter functional 8:35 Start lifting first 400 bbl. tank 9:12 Start spotting second 400 bbl. tank 9:30 Start lifting first set of tank stairs 9:55 First set of stairs installed on tanks 10:15 Start spotting third 400 bbl. tank 10:25 Spot fourth 400 bbl. tank 10:45 Install second set of stairs on tanks 11:10 Spot diverter manifold 12:15 Data acquisition system establishes communication with the Fardux server 13:45 Hold safety huddle . Discuss rigging up pipe 13:55 Discuss releasing crane with Repsol completions supervisor 14:10 Start rigging up oil line from Tee to tank farm diverter manifold 15:00 Request 90ft and 80ft lengths of liner material for pipe runs from Cruz personnel 15:00 Complete rigging up oil line to diverter manifold 15:30 Start installing valves and fitting on 400bbl tank inlets 16:00 Continue troubleshooting transducers 16:15 Start installing enclosure walls around sand trap 16:30 Cruz personnel delivers liner materials for pipe run 17:00 Crew start cleaning work area and storing tools in preparation for shift change 17:30 Hold shift handover meeting. Discuss current operations 18:00 Night Shift conduct walk around and survey projects to be completed 18:30 Hold shift safety Meeting. Review Risk Assessments and TRAC 21:00 Rig up high pressure Diverter Manifold #1 for vertical tank farm 23:00 Troubleshoot DAS heater temperature transducers and scrubber pressure. 30-Mar-14 0:00 Rigged vertical tank suction manifold (Diverter Manifold #2). 1:00 Install liner material under oil line from Scrubber to Tank Farm. 1:15 Meeting with truck driver at Q-Pad to give instruction on bringing 7 Horizontal Tanks to Q5. Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Chris Tobin Page 36 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 30-Mar-14 1:30 Begin spotting horizontal tanks. Position with Loader after truck spot tank on rig mat 3:00 Horizontal Tanks in position 3:15 Heater temp transducers and scrubber press online. Switch Sep diff transducer 3:30 Position transfer pump between vertical and horizontal tanks 4:15 Rig up transfer pump inlet suction from vertical tank manifold 4:45 Rig up discharge line from transfer pump to horizontal tanks. 5:15 Cleaned up tools and materials around well test area. 5:30 Day crew arrives on location 5:40 Hold Shift Handover meeting. Discuss current operation. 5:50 Night crew departs location 6:00 Hold pre-job safety meeting. Review JSA and TRAC for rigging up well test equipment 6:15 Continue rigging up and testing separator instruments 6:20 Request lumber for building berm for oil line 7:00 Hold Safety meeting huddle. Discuss rigging up tank farm 7:15 Continue building hooch for sand separator 7:45 Start laying out pump cable 7:50 Relocate pump to allow cables to connect 8:00 Truck starts delivering 500 bbl. horizontal tanks 8:55 Test soft start on transfer pump 9:10 Loader starts spotting horizontal tanks 9:40 Switch generators 10:15 Start installing inlet hoses on 500 bbls tanks 10:20 Attend Q5 Rig orientation 11:00 Attend H2S drill for Q5 pad 12:30 Complete enclosure around sand separator 13:00 Replace temperature transducer on downstream choke 14;20 Spot portable heaters inside tank farm berm 15:30 Complete inlet manifold on horizontal tanks 15:40 Start rigging up suction manifold on 500 bbl tanks Jordan Mooney Roland Taylor Sharon Oyao Vance Wolford Travis Atkinson Michael Joiner Page 37 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 30-Mar-14 15:50 Start building enclosure for front of 500 bbl tanks 17:15 Stage suction hoses around 500 bbl tanks 17:30 Night crew arrives location 17:45 Hold Shift Handover meeting. Discuss current operations with night crew 18:00 Day Shift Departs Location. 18:10 Hold pre-shift safety meeting. Review Risk Assessment and TRAC 18:30 Continue rigging up suction and inlet on horizontal Tanks 19:00 Continue with pipe tally 19:15 Insulate separator inlet 19:30 Start laying out plastic under pipe 20:30 Rig up ESD Pull stations at tank farm manifold, Flare Stack and Choke Manifold. 23:00 Pressurize ESD Loop and fixed leaks. 31-Mar-14 0:30 Test all Hi/Lo Pilots with hydraulic pump. All pilots operational 1:30 Test all ESD pull stations 2:00 Continue compiling pipe tally on piping and hoses 2:30 Move SSV close to well test area and tarp in and start to heat up with heater trunk hose 3:00 Adjust heat exchanger ESD pressure switch from 75 psi to 26 psi. Heater ESD operational 3:30 Continue to type in trace numbers for piping and hoses in pipe tally file 3:45 Rig up 2" diaphragm pump and spot Arctic Frost totes with forklift 3:55 Start transferring glycol from totes to heater bath 4:30 Complete pumping Arctic Frost totes into the heat exchanger bath 5:00 Rig down diaphragm pump and clean up around well test area 5:30 Day crew arrives on location 5:40 Hold Shift Handover meeting. Discuss current operation 6:00 Hold pre-shift safety meeting. Review JSA and create TRAC 6:20 Attend Repsol daily morning meeting 6:45 Perform checks on all hatches on tanks in tank farm 7:00 Test fire line heater 7:15 Start building enclosure for tank farm main diverter manifold Roland Taylor Travis Atkinson Sharon Oyao Vance Wolford Michael Joiner Jordan Mooney Vince Madrid Chris Tobin Shelby Brown Andrew McCabe Brent Hickey Page 38 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 31-Mar-14 7:25 Spot Nitrogen racks in main berm with crane 8:30 R. Taylor attends daily operations meeting 9:15 Start rigging up chemical injection system inside choke manifold 9:30 Start installing Mass flow meter inside separator 10:10 Install straps on all camlok connections 10:35 Complete rigging up chemical injection system 10:45 Start gauging all tanks to obtain initial levels 11:05 All tanks completely empty 11:10 Arrange flight to location for boiler technician 11:40 Request loader operator spot 4ea. Barrels of glycol in generator berm 13:10 Obtain stinger from Little Red Services 13:40 Rig up diaphragm pump 13:50 Start transferring glycol from barrels to heater bath 14:20 Complete filling heater bath 14:40 Start installing whip checks on all air hoses 15:00 Whip checks installed on all air hoses 15:30 Start installing whip checks on tank farm hoses 17:05 Conduct walk through well test system with Repsol's company reps 17:15 Conduct well test area clean up 17:30 Night Crew arrive on location 17:40 Hold shift handover meeting. Discuss current operations 18:00 Day crew depart location 18:30 Night Crew Hold pre-shift safety Meeting, complete JSA and risk assessment 19:00 Disconnect scrubber high level alarm from ESD loop and rigged into 50 PSI air supply 20:00 Completed walking lines, distributed radios and begin pressurizing system with air 20:30 Leak found in choke bean seat and sand trap. 20:54 Repaired leaks and start pressuring system with air. 21:10 Shut off air. Suspected ice plug in sand trap dump line 21:25 Start wrapping lines to clear ice plug Chris Tobin Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Page 39 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 31-Mar-14 21:25 Line wrapped. Start applying heat 21:55 Plug cleared from bottom of sand trap 21:56 Began pressuring system with air. 22:15 System pressured to 120 psi. Begin pressure test 22:30 Air pressure Test successful. (Start Time: 22:15 End Time: 22:30) 22:34 Begin bleeding air pressure 22:45 Pressure bleed to 0 psi in entire system 23:30 Little Red Services truck rigged up 1-Apr-14 0:00 Company rep releases Little Red Services (LRS) until 07:00 hrs. Pressure test delayed 1:00 Blow air through tank inlets to clear ice plugs. 3:00 Wrap tank Inlets 4:00 Rig and set separator relief valve with 250 psi Nitrogen pre-charge 4:45 Pneumatic test 90 psi on vertical tank suction manifold and hoses 5:15 Pneumatic test 80 psi transfer pump suction to vertical tank outlet valves 5:30 Day crew arrives on location 5:40 Hold shift handover meeting. Discuss current operation with night crew 5:50 Night crew depart location 6:00 Hold pre-shift safety meeting. Review Risk Assessments and create TRAC 6:30 Start building enclosure around front of horizontal tanks 7:20 Little Red Services arrive on location 7:30 Install valve and fittings to connect pressure test hose to inlet of sand trap 7:35 Little Red Services rig up hose to sand trap inlet 7:40 Little Red Services start heating pressure test fluids 8:00 Start logging data file in Fardux 8:10 Crew synchronize time to Fardux scan time 8:30 R. Taylor attend daily operations meeting 9:45 Hold pre-pressure test safety meeting with Co. Man, LRS, Vac Truck personnel and Expro 10:20 Hand out radios to all personnel involved in the pressure testing operations 10:22 Conduct walk-around well test area prior to pressure testing Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Roland Taylor Page 40 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 1-Apr-14 10:28 LRS start filling surface lines with LVT-220 @ 0.75 bbls/min 10:34 Fluid at choke manifold 10:43 Fluid at separator 10:54 Leak at ball valve in separator. LRS stops pumping 11:00 Start emailing Datacast username and password to client 11:35 LRS resumes filling surface lines at 0.75 bbls/min. 20bbls pumped 11:50 Function test High Level shut down on separator while filling vessel 12:15 Fluid at vertical scrubber 12:33 LRS out of fluids. 62.5 bbls pumped 12:35 LRS rigged down and move to other side of the pad to take on more LVT 14:05 LRS back on location and start rigging up 15:05 Complete building tank farm hooch 15:20 LRS resume filling surface lines and vessels with LVT 15:24 Function test dump valves and controllers on separator while filling vessel 15:26 Function test High Level alarm on scrubber while filling scrubber vessel. Alarm operational 15:33 Flush fluids to each 400bbl tank 15:33 Open line to tank #1 15:34 Open inlet line to tank #2 15:35 Open line to tank #3. Close line to tank #2. 15:36 Open line to tank #4. Close line to tank #3. 15:42 LRS complete pump LVT to fill system. Total fluid = 77 bbls. 15:54 Pressure test tank inlet to 500 psi for 10 minutes 15:57 LRS pumps down. Leak on tank #3 16:02 Bleed off pressure to zero. Gather tools and tighten inlet of tank #3 16:09 Resume pressure testing. LRS pressure system to 500psi 16:10 Pressure test tank inlets to 500 psi for 10 minutes 16:20 Pressure test on tank inlet complete. Good Test, no visible leaks. Bleed off pressure 16:25 Bleed pressure to zero psi 16:34 Start pressure testing downstream lines and vessels. Pressure increase to 250psi Page 41 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 1-Apr-14 16:38 Pressure test entire system to 1000 psi 16:48 Pressure test complete. No visible leaks. Bleed off pressure 16:51 Pressure bleed off completely 16:53 Pressure increase to 500 psi. Monitor for 3 minutes 17:00 Start pressure testing line heater inlet to 3000psi for 10 minutes 17:10 Pressure test on line heater complete. No visible leaks. Bleed off pressure 17:13 Bleed pressure to zero psi 17:18 Pressure increase to 500 psi. Monitor for 3 minutes 17:22 Pressure test downstream valves on choke manifold to 3000psi for 10 minutes 17:32 Pressure test on downstream valves complete. Good Test. Bleed off pressure 17:35 Pressure increase to 500 psi. Monitor for 3 minutes 17:40 Pressure test upstream valves on choke manifold to 3000psi for 10 minutes 17:40 Night Crew arrives on location 17:50 Pressure test on upstream valves complete. No visible leaks. Bleed off pressure 17:52 Pressure bleed off completely 18:00 LRS start rigging down truck 18:00 Hold shift handover meeting. Discuss current operations 18:20 Day crew depart on location 18:30 Night crew hold pre-shift safety meeting, complete JSA, risk assessment 18:40 Inform ACS fluid transfer will be performed 18:45 Rig up Vacuum Truck to transfer LVT fluid 19:15 ACS personnel arrive on site 19:20 Begin LVT fluid transfer to Vac Truck 20:00 Vac Truck suction from Tank Farm diverter manifold 20:15 Tested oil flow meter while transferring fluid from separator 20:35 Vac Truck suction from Vertical Scrubber drain 20:50 Vac Truck suction from Vertical Scrubber gas line 21:10 Vac Truck suction from Separator water drain line 21:30 Vac Truck suction from Sand Trap drain Chris Tobin Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Page 42 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 1-Apr-14 21:45 Complete Vac Truck fluid transfer; 59 bbl of LVT return. Leave fluid level in the separator 22:30 Change flow meter calibration and tested. 23:30 Rig down pressure test caps 2-Apr-14 1:30 Connect SSV to ESD Panel 2:00 Rig up well head ESD pull station 2:30 Start to rig up flow line upstream of sand trap 2:45 Move Nitrogen tanks from well test berm to generator berm to make room for flow line 3:15 Company man witness Hi/Lo pilot ESD test 3:30 Company man witness ESD pull station test and line heater shut down. 4:30 Purge lines with nitrogen. 5:15 Clean up tools and materials around well test area. 5:30 Day crew arrive on site 5:40 Hold shift handover meeting. Discuss current operation with night crew 5:50 Night crew depart location 6:00 Hold pre-shift safety meeting. Discuss rig up equipment Risk Assessment 6:30 Complete sending Datacast username and password to client 6:40 Start wrapping pipe with plastic for heat trace 8:00 Start troubleshooting liquid flow meters 10:15 Conduct walk around the test area with Repsol Reservoir Engineers 14:20 Replace heater bath temperature transducer 14:30 Complete wrapping pipe for heat trace 15:00 Install air supply transducers at the compressor 16:30 Start building containment for inlet line 17:00 Cleaned up tools and materials around well test area 17:30 Night crew arrives on location 17:35 Hold shift handover meeting. Discuss current operation with night crew 18:00 Day crew depart location 18:10 Hold pre-shift safety meeting. Discuss rig up equipment Risk Assessment 18:30 Continue rigging up flow line into SSV and Flow Wing Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Jordan Mooney Vance Wolford Shelby Brown Brent Hickey Vince Madrid Chris Tobin Andrew McCabe Page 43 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 2-Apr-14 22:00 Complete rigging up flow line and SSV into flow wing 23:00 Ran DAS single core well head pressure and annulus pressure cables 23:30 Install well head and annulus pressure transducers 23:40 Install restraint cables on inlet line from flow wing to sand trap 23:45 Attend safety meeting in mechanic shop with Q5 personnel. Discuss pressure testing inlet line 3-Apr-14 0:20 Safety meeting complete, begin valve alignment to bypass separator to Tank #1 1:06 Flushed 7bbls through choke bypass separator into tank 1 1:12 Begin pumping for 3000 psi pressure test 1:16 Pressure dropping begin walking the line. No leaks on Expro pipe 1:21 Pressure test resumed 1:23 Pressure begins dropping at 2100 psi 1:24 Bled pressure to 300 psi 1:26 Resume pumping for 3000 psi pressure test 1:34 Shut in for 10 minute 3000 psi pressure test 1:46 500psi drop in 12 minutes 1:47 Bump pressure to 3000 psi 1:55 Lost 600 psi in 8min 1:56 Bumped pressure to 3000 psi 1:58 Pressure dropped 100 psi to 2900 psi. Leaking cement pump shut in 2:07 No pressure drop after 9 minutes. Pressure bled to 0 psi 2:10 Continue wrapping inlet line with plastic 3:30 Replace annulus pressure transducer and change needle valve 4:15 Attended safety meeting for perforating and performing DFIT. 4:40 Annulus valve open and pressured to 1500 psi with LVT from cementing unit (Step 8) 5:00 Annulus pressure increased to 2500 psi (Step 8) 5:25 Open well and begin pressuring to 4000 psi with LVT from frac pumps to fire guns (Step 9) 5:30 Day crew arrives on location 5:40 Perforating guns fired 5:40 Hold shift handover meeting. Discuss current operation with night crew Roland Taylor Travis Atkinson Michael Joiner Page 44 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 3-Apr-14 6:15 Conduct walk-around well test area 6:45 Hold pre-shift safety meeting. Discuss Risk assessment 8:00 Continue wrapping inlet line with plastic 8:15 Conduct pipe tally inventory from sand trap to wellhead 8:35 Critical crane lift around well test area. Crew asked to vacate well test area 9:00 Perform housekeeping in the separator 10:00 Install sample port at the inlet separator 11:00 Complete building doors on hooch 11:50 Hook up Nitrogen to sand trap 13:00 Print field reading sheets 13:15 Print 500 bbls tank calibration 14:00 Continue troubleshooting liquid flow meters 14:30 Get sampling accessories ready 17:00 Clean up tools & work area in the well test area. 17:00 Complete troubleshooting flow meters. Meters reading in DAS 17:30 Night crew arrives on location 17:40 Hold shift handover meeting. Discuss current operation with night crew 18:00 Day crew departs on location 18:30 Hold pre-shift safety meeting. Discuss the shift's activities. Review JSA and TRAC 19:00 Wrap tank riser with plastic sheeting 19:35 Rigged up low gas flow meter on channel 18 20:00 Moved wellhead pressure transducers to flow wing 20:30 Connect wellhead temperature transducers 23:00 Prepare well test data sheet for flowing 4-Apr-14 1:00 Load 3" 1502 pipe in basket 2:00 Create UT map for pipework 3:00 Spot ESD pull station to close to wellhead 5:00 Clean up tools & work area in the well test area. 5:30 Day crew arrives on location Andrew McCabe Brent Hickey Chris Tobin Sharon Oyao Vance Wolford Jordan Mooney Shelby Brown Vince Madrid Page 45 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 4-Apr-14 5:45 Hold shift handover meeting. Discuss current operation with night crew 6:40 Discuss future operations with Repsol's Company rep 7:00 Obtain initial straps on tanks. Tank #1=24" Tank #2=10" Tank #3=1 Tank #4=1" 7:15 Attend Safety Meeting at Coil Tubing Unit for coil tubing clean-up 7:30 Hold pre-shift safety meeting. Review JSA and create TRAC 8:00 Open well at the wing valve 8:05 Open well at Expro choke bypass separator to tanks 8:05 Open choke to 32/64ths adjustable 8:06 Fluid at tank #1 8:15 Nitrogen online @ 1000 scf/min. 8:15 Start strapping tank every 15 mins. Tank #1= 36" = 55.8 bbls 8:20 Nitrogen and fluids at choke manifold 8:25 Start testing ESD with Repsol's Company reps. 8:30 Tank #1 = 40" = 62 bbls. 8:34 Increase choke to 40/64ths adjustable 8:40 Decrease Nitrogen rate to 750 scf/min 8:45 Decrease Nitrogen rate to 500 scf/min 8:45 Tank #1= 45" = 69.8 bbls. 8:50 Decrease Nitrogen rate to 250 scf/min 9:00 Tank #1 = 50" = 77.5 bbls. 9:12 Decrease choke at 22/64ths adjustable 9:14 N2 offline 9:15 Divert flow from Tank #1 to Tank #2 9:15 Tank #1 = 55" = 85.3 bbls. 9:15 Nitrogen offline @ 250 scf/min 9:27 Increase choke to 128/64ths adjustable 9:40 Coil tubing blow down complete 9:45 Shut-in wing valve 9:45 Re-set ESD at the separator Travis Atkinson Sharon Oyao Michael Joiner Vance Wolford Jordan Mooney Roland Taylor Page 46 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 4-Apr-14 9:54 Choke shut-in. Choke at 0/64ths adj 10:00 Attend safety meeting for opening the well. Discuss flow procedures 10:45 Start fluid transfer from tank #1 to Vac Truck 11:45 Nitrogen online @ 300 scf/min 11:53 Complete fluid transfer from tank #1 11:55 Open well on 13/64ths adjustable choke 11:57 Resume fluid transfer on tank #1 12:00 Constantly rocking choke 12:20 Tank 2 = 6" = 9.30 bbls 12:25 Constantly rocking choke 12:42 Increase back pressure to 1500 psi 12:50 Increase Nitrogen injection rate to 400 scf/min 12:50 Decrease back pressure to 500 psi 13:03 Decrease back pressure to 100 psi 13:24 Nitrogen pump rate at 500 scf/min 13:27 Choke to 42/64ths adjustable 13:30 Increase Nitrogen injection rate to 500 scf/min 14:00 Increase Nitrogen injection rate to 600 scf/min 14:09 Divert flow to separator 14:22 0.875" orifice plate in service 14:25 0.875" orifice plate out of service 14:25 Gas SG = 0.972 14:26 1.250" orifice plate in service 14:30 Divert flow from Tank #2 to Tank #3 14:58 Rock choke 15:17 Rock choke 15:24 Decrease choke to 8/64ths adjustable 15:30 Increase Nitrogen injection rate to 700 scf/min 15:38 Increase choke to 22/64ths. Bleed choke port Page 47 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 4-Apr-14 15:40 Increase Nitrogen injection rate to 1000 scf/min 15:42 Increase choke to 24/64ths. 15:43 1.250" orifice plate out of service 15:48 1.750" orifice plate in service 15:56 Increase choke to 28/64ths. 15:58 Conduct inspection on surface lines 16:00 Nitrogen offline @ 1000 scf/min. Start bleeding down 16:00 Increase choke to 36/64ths adj 16:04 Decrease choke to 16/64ths 16:09 Divert flow to oil meter low 16:15 Load pump for Nitrogen 16:30 Shut-in Choke Manifold. Choke at 0/64ths adj 17:00 Nitrogen pumpers resume pumping Nitrogen @ 1000 scf/min 17:07 Increase choke to 16/64ths. 17:30 Night crew arrives on location 17:35 Increase choke to 18/64ths 17:42 Increase choke to 20/64ths 18:00 Hold handover meeting 18:00 Day crew depart location 18:16 Increase choke to 24/64th 18:20 Decrease choke to 22/64 18:53 Increase choke to 23/64th 19:00 Nitrogen offline @ 1000 scf/min 19:07 Decrease choke to 18/64th 19:10 Decrease choke to 16/64th 19:13 Vac truck pulled 41.08bbls LVT from Tank #1. Tank level 1.5" or 2.33 bbl 19:30 Load pump for Nitrogen 19:30 Gas SG= 0.97 20:00 Increase choke to 62/64 Carter Garrett Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Page 48 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 4-Apr-14 20:30 Tank #3=8.5" or 13.8 bbl 20:37 Fluid at Choke 20:39 Fluid at Separator 20:40 Choke Shut in 21:00 Tank #1 level 2.5" or 3.88 bbl 21:05 C. Garrett attend safety meeting and discuss future operations 21:25 RIH with coil tubing 21:30 Begin cycling Omni valve 21:34 Start bleeding Annulus pressure from 1500 psi 21:36 Annulus pressure bled to 30 psi, begin RIH with coil tubing 21:38 Tagged Omni valve with coil tubing and begin POOH 21:40 Pressure Annulus to 1500 psi to cycle Omni Valve 21:46 Bled Annul Pressure to 0 psi and RIH to tag Omni valve 21:51 Begin pressuring Annulus to cycle Omni Valve 21:53 Annulus pressure at 1500 psi 21:56 Begin bleeding Annulus pressure 21:58 Annulus pressure bled to 10 psi. Began RIH with Coil Tubing 22:04 Omni valve tagged and POOH 22:07 Annulus pressured to 1500 psi to cycle Omni 22:09 Begin bleeding Annulus pressure 22:27 Opened choke to 12/64th 22:30 BS&W: 100% LVT 22:33 Choke increased to 16/64th 22:35 Tank #1=17". Desired flow rate of 1 bbl/min 22:40 Tank #1= 24". 4045.5 bbl/Day or 2.8 bbl/min 22:46 Tank #1=36" or 55.8 bbl. 3.1 bbl/min 22:55 Close Choke 23:00 Begin pressuring annulus to 2500 psi 23:05 Annulus pressure 2500 psi to cycle Omni valve Page 49 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 4-Apr-14 23:06 Begin bleeding Annulus pressure 23:10 Annulus pressure bled. Begin RIH with coil tubing 23:15 Annulus pressured to 1550 psi 23:20 Annulus bled to 50 psi. Begin RIH with coil tubing 23:25 Annulus pressured to 2500 psi 23:30 Annulus bleed to 40 psi 5-Apr-14 0:00 C. Garrett attended meeting at the Rig office 1:00 Open choke 1:03 WHP pressure bled to 20 psi through choke 1:28 Called ACS to request inspection and monitoring during LVT transfer 1:35 Tank #1=58" = 32bbls of LVT recovered 1:39 41bbls of LVT pumped 1:58 Switched from Tank #1 to Tank #3. Tank #1 is LVT. 72bbls LVT pumped 2:00 Tank #1=71" = 70 bbl of LVT returned to Tank 2:10 Start bypassing separator 2:30 Tank #3= 16" (24.8bbl), 0.36 bbl/min. Tank #1=71" (No Shrinkage) 2:30 BS&W: 100% Brine, trace sediment, trace LVT 2:30 1.750" orifice plate out of service 3:00 Tank #3=22" (34.1bbl), 0.31 bbl/min 3:00 Salinity = 280,000 ppm 3:27 Daniels plate lifted. Begin N2 injection 3:30 Tank #3=22". Fluid returns at choke. Choke Decrease to 32/64 3:32 U/S choke and wellhead pressures at 430 psi 3:34 U/S choke pressure stable at 240 psi 3:40 Visually confirm Tank 3 receiving fluid 3:45 ACS arrive on location for fluid transfer (100bbls LVT in tank) from tank 1 to Vac truck 4:00 U/S choke pressure increase to 1300 psi. Choke decrease to 24/64ths 4:02 U/S pressure decreasing from 1360 psi. 4:03 Decrease choke to 16/64ths Page 50 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 5-Apr-14 4:10 WHP and U/S choke pressure at 250 psi. Open choke to 128/64ths 4:13 Blow lines into tank 3 with Expro N2 4:15 Blow lines into tank 1 with Expro N2 4:16 Open into tank 3 4:16 Tank 1 = 1" Vac truck transferred 108 bbls 4:20 Tank 3 = 48"" Vac truck transferred 50 bbls 4:30 Inject Methanol with Nitrogen to clear lines 5:00 Clean up well test area in preparation for change over 5:30 Day crew arrive on location 5:40 Hold shift handover meeting. Discuss current operation with night crew 6:00 Night crew depart location 7:00 Hold pre-shift safety meeting. Discuss the day's activities 7:15 Fill out and discuss JSA and TRAC for rigging down pipe, transducers and cables at inlet 7:30 Remove transfer pump cables to allow crane access 7:40 Rig down temp transducers at the inlet 7:50 Start rigging down inlet line to downstream SSV 8:00 Troubleshoot oil meter low at the oil line separator. Lower magnetic pick-up to get reading 8:30 R. Taylor attends daily operations meeting 8:50 Rig down pressure transducers at the inlet 9:10 Roll and label scan cable at the inlet 9:30 Hold safety meeting and discuss rigging down inlet off of well head 9:45 Start rigging down inlet line 10:30 Inlet line rigged down 10:30 Install flange on drilling choke line 10:45 Crane spotted around well test area 11:00 Crane removes SSV from around well head 11:10 Crane spots SSV around rig choke line 11:20 Start rigging up lines from SSV to inlet line 11:45 Inlet line rigged up to the rig's choke line Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 51 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 5-Apr-14 13:20 Start installing restraint cables on inlet line and SSV 13:40 Restraint cables installed on inlet line 14:05 Hold safety meeting and discuss adjusting flare tip and using man-lift 14:30 Personnel start working on flare tip 14:50 Start cleaning and organizing spares conex 16:30 Complete adjusting and removing ice from flare tip 17:00 Start cleaning up worksite in preparation for shift change 17:30 Night shift arrives on location 17:40 Hold shift handover meeting. Discuss current operation with day crew 18:00 Hold pre-shift safety meeting 20:00 Wrap flow line and SSV 21:00 Drain fluid from scrubber 23:00 Zero adjustable choke 3:00 Perform housekeeping around well test area 5:00 Perform snow removal from containment 6-Apr-14 5:30 Day shift arrives on location 5:35 Hold shift handover meeting. Discuss current operation with night crew 6:00 Hold pre-shift safety meeting. Review JSA and TRAC 6:45 Inspect all heater trunks and confirm they are not producing water puddles 7:00 Conduct housekeeping in choke manifold building 7:30 Switch from compressor #2-1973 to compressor #1-1975 8:00 Review MSDS for LVT. All crew members sign sheet in acknowledgement of review 8:15 Line up flow to bypass separator 8:30 R. Taylor attends daily operations meeting 9:00 Conduct housekeeping in tank farm 10:00 Move man-lift out of well test area 10:45 Remove High pressure pilot from choke inlet 10:50 Start inventorying choke beans 11:00 Discuss fluid transfer with CH2MHILLMHILL truck pusher Carter Garrett Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 52 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 6-Apr-14 11:15 Complete inventory of choke beans 11:18 Call ACS to inspect fluid transfer connections 11:20 Fill out offsite fluid transfer sheet 11:28 Start fluid transfer from tank #3 to Vac Truck 11:30 Put generator #2026 in service. Shut down generator #2305 11:43 Complete fluid transfer from tank 3 to Vac truck. Estimate transferred vol 73.0 bbls 11:45 Reset PSH1 inlet safety pilot from 4500 psi to 3500 psi 12:05 Start fluid transfer from tank #2 to Vac truck 12:15 Complete fluid transfer from tank 2 to Vac truck. Estimate transferred vol 40.3 bbls 14:00 Test safety pilot. Trips at desired pressure 14:25 Test fire igniter. Igniter operational 14:40 Install 16/64ths positive choke bean in positive side of choke manifold 15:00 Start inventorying orifice plates 15:15 Complete orifice plate inventory and input in system for Project File 15:30 Rig down the manual injection pump 16:00 Perform housekeeping in DAS lab 17:00 Clean-up around well test area in preparation for shift change 17:30 Night crew arrive on location 17:45 Night and Day crew conduct meeting in separator house 18:00 Hold shift handover meeting. Discuss current operation with day crew 18:45 Hold pre-shift safety meeting. Review JSA and TRAC 7-Apr-14 2:00 Test fire igniter. Igniter operational 4:00 Perform snow removal from around well test area 4:45 Perform housekeeping in DAS lab 5:00 Clean-up around well test area in preparation for shift change 5:30 Day crew arrive on location 5:45 Hold shift handover meeting. Discuss current operation with night crew 6:00 Hold pre-shift safety meeting. Review JSA and TRAC 7:30 Switch from compressor #1-1975 to compressor #2-1973 Carter Garrett Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Page 53 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 7-Apr-14 8:00 Disconnect SSV supply line and blow tanner gas through line 8:30 R. Taylor attends daily operations meeting 8:40 Start printing Q5 equipment maintenance file 9:30 Switch generator from generator #2305 to generator #2206 13:30 Test fire igniter. Igniter operational 14:00 Replace needle valves with ball valves on upstream data header on inlet line 16:00 Perform general housekeeping in preparation for shifts change 16:15 Search pad for empty glycol totes 17:00 Reconnect transfer pump to suction manifold 17:30 Night crew arrives on location 17:35 Hold shift handover meeting. Discuss current operation with day crew 18:00 Hold pre-shift safety meeting. Review JSA and TRAC 18:30 Review MSDS for Methanol and Glycol 19:00 Rig up well head pressure and temperature transducer on SSV data header 19:30 Blow out sparge lines to sand tank with Nitrogen 20:00 Function tank butterfly valves 20:30 Grease upstream choke valves 20:45 Rig up Little Red pressure test truck to data header upstream of SSV 21:45 Fill flow line with LVT to pressure test 22:55 Pressure test flow line to 3000 psi with LVT 8-Apr-14 1:45 Test fire igniter. Igniter operational 2:00 Test ESD pull stations. All pull stations operational 4:00 Perform snow removal from all containment 5:00 Perform housekeeping around well test area 5:30 Day crew arrives on location 5:35 Hold shift handover meeting. Discuss current operation with night crew 5:45 Night crew depart on location 6:30 Conduct walk around well test area and survey work completed 7:00 Review and sign SDS for glycol and methanol Vance Wolford Jordan Mooney Carter Garrett Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 54 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 8-Apr-14 7:15 Continue printing Q5 equipment maintenance file 8:00 Switch from compressor #2-1973 to compressor #1-1975 8:25 Start removing low level switch from separator 8:40 T. Atkinson and V. Wolford depart Q5 pad to drop level switch to Q7 pad 9:30 Attend Safety Meeting at Nabors Rig floor. Discuss flow procedures 10:00 Align flow bypassing separator to tanks 10:05 Align flow open to tank #1 10:50 Open choke to 16/64ths 10:57 Divert flow from tank#1 to tank #2 11:00 Strap tank #1 = 1" =1.55bbls 11:15 Strap tank #2 = 3" = 4.65bbls 11:18 Increase choke to 22/64ths 11:19 Rock choke 11:30 Strap tank #2 = 4" = 6.2bbls 11:36 Increase choke to 26/64ths 11:46 Increase choke to 28/64ths 12:15 Fluid weight = 11.8 ppg 12:39 BHP = 4038 psi 12:40 Increase choke to 30/64ths 12:45 Divert flow from tank#2 to tank #3 12:46 Align flow from tank #3 to Vac Truck 12:52 Start fluid transfer from tank #2 to Vac Truck 13:00 Shut in at choke manifold 13:00 BHP = 4011 psi 13:05 Start slowly opening choke 13:07 Shut in at choke manifold 13:08 Complete fluid transfer from tank 2 to Vac Truck. Transferred vol = 35.65 bbls 13:09 Open choke to 16/64ths 13:20 Fluid weight = 11.9 ppg Page 55 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 8-Apr-14 13:24 Increase choke to 20/64ths 13:28 BHP = 3983 psi 13:35 Increase choke to 42/64ths 13:37 Fluid weight = 11.9 ppg 13:38 Rock choke 13:44 Increase choke to 46/64ths 13:50 Rock choke 13:53 BHP = 3971 psi 14:08 Divert flow from tank#3 to tank #2 14:10 Company rep decides to start circulating using the rig's pump and pits 14:13 Start fluid transfer from tank #3 to Vac truck 14:28 Complete fluid transfer from tank 3 to Vac truck. Transferred vol = 39.53 bbls 14:30 Start bleeding wellhead pressure 14:31 Slowly open choke to bleed down pressure 14:40 Shut rig manifold valve to Expro's surface lines 15:10 Hold safety meeting and discuss blowing down lines. Write TRAC for operations 15:10 Connect Vac truck to tank manifold and start evacuating surface lines 16:10 Vac truck complete pulling fluids. Shut Vac truck 16:15 Start blowing down sand trap with Nitrogen to sand tank 16:20 Start blowing down surface lines to tanks with Nitrogen 16:30 Align flow lines to tank #2 16:45 Strap tank #2 = 9" =13.95 bbls 16:50 Start fluid transfer from tank #2 to Vac truck 16:55 Complete fluid transfer from tank 2 to Vac truck. Transferred vol = 11.63 bbls 17:00 Conduct walk around and clean up well test area in preparation for shift change 17:05 Shut choke manifold valves 17:30 Night crew arrives on location 17:48 Stop logging data from Fardux 18:00 Hold safety meeting and discuss blowing down lines. Write TRAC for operations Carter Garrett Shelby Brown Andrew McCabe Page 56 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 8-Apr-14 23:00 Blow down lines with Nitrogen 9-Apr-14 1:00 Test ESD pull stations and Hi/Lo pilots 2:00 Test fire igniter. Igniter operational 3:00 Print copies of shift handover, safety minute, TRAC 4:00 Snow removal all containment 5:00 Conduct walk around and clean up well test area in preparation for shift change 5:30 Day crew arrives on location 5:45 Hold shift handover meeting. Discuss current operation with night crew 5:50 Night crew depart location 6:00 Hold pre-shift safety meeting. Review JSA and TRAC 6:30 Create daily report from Tuesday's (04-08) operation 7:40 Switch from compressor #1-1975 to compressor #2-1973 8:20 Attend Safety Meeting at Expro's well test area. Discuss flow procedures 8:30 Start logging data from Fardux 8:40 Start bleeding pressure from rig manifold to Expro's choke manifold 8:42 Align flow bypassing separator to tanks 8:42 Align flow open to tank #1 9:05 Slowly open the rig's manifold 9:30 Showing fluid at Expro's choke manifold 9:31 Rig's manifold fully open 9:44 Open Expro's choke to 16/64ths 9:45 Start bleeding pressure. Increase choke to 18/64ths 9:48 Increase choke to 22/64ths 9:51 Increase choke to 26/64ths 9:52 Increase choke to 30/64ths 10:05 Decrease choke to 18/64ths 10:20 Shut-in at Rig's manifold 10:25 Confirm no fluid return at the tank 11:30 Fill out TRAC for replacing pressure transducers Brent Hickey Vince Madrid Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 57 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 9-Apr-14 11:36 Replace upstream choke pressure transducer 11:40 Input pressure transducer calibration on channel 9: U/S choke Press 12:00 Replace wellhead pressure transducer 12:10 Input pressure transducer calibration on channel 1: WHP 13:40 Conduct safety meeting. Review TRAC for blowing surface lines with Nitrogen 13:45 Start blowing down surface lines with Nitrogen 13:46 Choke to 16/64ths 13:47 Align flow open to tank #2 13:49 Fluid returns to tanks 14:01 Start blowing down sand trap with Nitrogen to sand tank 14:15 Blowing down surface lines to tanks with Nitrogen 14:20 Complete blowing down in all surface lines with Nitrogen 14:24 Shut-in at the choke manifold 14:25 Strap at tank #2 = 4" = 6.2 bbls 14:30 Test fire igniter. Igniter operational 15:00 Continue printing Q5 equipment maintenance file 17:00 Conduct general housekeeping in preparation for shift change 17:15 Stop logging data from Fardux 17:30 Night crew arrives on location 18:00 Hold safety meeting and discuss blowing down lines. Write TRAC for operations 19:00 All shift personnel review solids management WTOS 20:00 Ultrasonic thickness test flow line to separator 23:00 Test ESD pull stations and Hi/Lo pilots 10-Apr-14 0:00 Test fire igniter. Igniter operational 1:00 Assist Alaska State inspector 1:30 Photograph scrubber relief valve for state inspector 4:00 Snow removal all containment 5:00 Conduct walk around and clean up well test area in preparation for shift change 5:30 Day crew arrives on location Carter Garrett Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Page 58 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 10-Apr-14 5:35 Hold shift handover meeting. Discuss current operation with night crew 5:50 Night crew depart location 6:15 Hold pre-shift safety meeting. Review JSA and TRAC 7:46 Switch from compressor #1-1975 to compressor #2-1973 8:00 Crew review Solids Management WTOS 8:30 R. Taylor attends daily operations meeting 9:30 Complete printing Q5 equipment file maintenance 11:38 Switch to generator #1 13:30 R. Taylor and V. Wolford depart Q5 pad to Q7 pad 13:45 Function test all ESD pull stations. ALL ESD pull stations tripped system when activated 13:50 Blow tanner gas through SSV lines 14:01 Test fire igniter. Igniter operational 16:00 D. Bray collect Q5 equipment maintenance file binder 17:00 Conduct general housekeeping in preparation for shift change 17:30 Night crew arrives on location 17:45 Hold shift handover meeting. Discuss current operation with night crew 18:00 Day crew departs on location 21:45 Dip heater bath, 180 deg F 22:00 Brent, Vince and Shelby depart to Q7 to requisite 3" 1502 pipe 22:55 Brent, Vince and Shelby return from Q7 11-Apr-14 2:00 Hammer pipe together for vertical flow line section 3:00 Test fire igniter. Igniter operational 3:55 Packer at surface 4:30 Snow removal all containment 5:00 Conduct walk around and clean up well test area in preparation for shift change 5:30 Day crew arrives on location 5:35 Hold shift handover meeting. Discuss current operation with night crew 5:45 Night crew departs location 6:05 Hold pre-shift safety meeting. Review JSA and TRAC Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Carter Garrett Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Page 59 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 11-Apr-14 7:00 Test heater bath temperature with manual gauge. 7:15 Remove heater bath temp transducers and place on the top hatch for accurate reading 7:50 Switch from compressor #1-1975 to compressor #2-1973 8:30 R. Taylor attends daily operations meeting 10:30 Reset liquid flow meters 11:00 Check inventory and locate radio batteries 13:00 Switch to generator #2 13:45 Blow tanner gas through SSV lines 13:50 Request crane to re-position heaters at tank farm 14:10 Crane operator start re-positioning heaters 14:30 Loader starts scraping back side of berm for fueler driveway 15:00 Heaters re-positioned outside tank farm berm 15:15 Start marking points on hard-line for UT test at critical areas 15:45 V. Wolford and J. Mooney depart Q5 to Q7 to pick up low level switch 16:22 Conduct safety meeting. Discuss rig down inlet line, SSV and instrumentation 16:25 V. Wolford and J. Mooney arrive Q5 pad from Q7 pad 16:30 Rig down WHP & WHT transducers and SSV lines. Transducers place at separator house 16:45 Start rigging down inlet line from rig manifold 16:50 Start installing low level switch in separator 17:10 Start rigging up inlet piping towards well head 17:35 Night crew arrives on location 17:45 Hold shift handover meeting. Discuss current operation with night crew 18:00 Day crew departs on location 18:10 Hold pre-shift safety meeting. Review JSA and TRAC 18:30 Receive 3 DAS cables from Q7 20:00 Conduct ultrasonic thickness test flow line to separator 20:15 Crane arrives on location 20:55 Hold safety meeting with crane operators and discuss operation 21:00 Begin crane lift operations of 3" 1502 Vance Wolford Jordan Mooney Carter Garrett Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Page 60 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 11-Apr-14 21:20 Crane pickup SSV 21:20 Rig up separator Hi/Lo level ESD shut down 21:35 SSV in place 21:45 Test scan cables and transducers (WHT, WHP, Annulus Pressure) 12-Apr-14 1:00 Test fire igniter. Igniter operational 1:45 Function tested all ESD pull stations. Working operationally 2:00 Radio inventory 4:00 Snow removal of containment 5:00 Housekeeping of all areas 5:40 Day crew arrives on location 5:45 Hold shift handover meeting. Discuss current operation with night crew 6:00 Night crew departs location 6:15 Conduct walk around well test area and survey work completed 6:30 Hold pre-shift safety meeting. Review JSA and TRAC 7:00 Inspect all heater trunks and confirm they are not producing water puddles 7:35 Switch from compressor #1-1975 to compressor #2-1973 8:30 R. Taylor attends daily operations meeting 9:00 Install data header on the wellhead 10:10 Install annulus pressure 10:30 Run scan cable and confirm connection and reading 10:42 Start logging data from Fardux 11:30 Conduct safety meeting. Review rig-up well test equipment risk assessment 11:35 Fill out and discuss TRAC for rigging up inlet line and instrumentation 13:00 R.Taylor attend safety meeting on the rig floor. Discuss rigging up well head 13:10 Switch to generator #1 13:15 Test fire igniter. Igniter operational 13:20 Function test all ESD pull stations. ALL ESD pull stations tripped system when activated 14:30 Stop logging data from Fardux 14:45 Lift riser for well head to rig floor Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 61 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 12-Apr-14 15:05 Crew told to suspend rigging up at rig floor and allow coil tubing to rig up 17:00 Conduct general housekeeping in preparation for shift change 17:40 Night crew arrives on location 17:50 Hold shift handover meeting. Discuss current operation with night crew 17:55 Day crew departs on location 18:00 Hold pre-shift safety meeting. Review JSA and TRAC 18:20 Safety meeting on rig floor to discuss flow line rig-up operations 20:00 Change PSH1 from 3500 psi to 4500 psi 21:30 Switch upstream and downstream pressure transducers 22:00 Begin rigging up inlet riser 22:30 Position riser through mouse hole with tugger 23:00 Connect flow line riser to SSV 23:40 Add needle valve to annulus pressure transducer for double isolation 23:30 Connect WHT and WHP transducers and run scan cables 23:45 Pressure test safety meeting on drill floor 13-Apr-14 0:00 Fill flow line with LVT for pressure test 0:23 Pressure flow line to 450 psi 0:58 Increase pressure to 1600 psi 1:00 Bleed pressure to 0 psi and fix leak at autoclave data header fitting 1:20 Pressure flow line to 3500 psi 1:22 Pressure bled to 0 psi 1:45 Pressure flow line to 400 psi 1:47 Pressure bled to 0 psi 2:07 Pressure flow line to 800 psi 2:09 Pressure bled to 0 psi 2:36 Pressure flow line to 1500 psi 2:37 Pressure bled to 0 psi 2:55 Replace autoclave seat on flow wing data header 2:59 Pressure flow line to 3650 psi Carter Garrett Shelby Brown Andrew McCabe Brent Hickey Vince Madrid Page 62 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 13-Apr-14 3:06 Pressure bled to 0 psi. Pressure test successful 3:55 Open choke flow LVT to Tank #1 4:03 No fluid returns to tank #1 4:20 Wrap upstream SSV to cellar door with plastic sheeting 4:40 Shut in choke manifold 4:46 Pressure flowline to 160 psi 4:48 Increase pressure to 280 psi 5:00 Increase pressure to 3680 psi, begin pressure test 5:07 Open choke to bleed pressure to 0 psi 5:08 Returns at tank #1 5:09 Pressure bled to 0 psi 5:10 Choke closed 5:11 Pressure increased to 380 psi 5:13 Pressure drop to 270 psi 5:29 Well head pressure 365 psi 5:31 Increase pressure to 3620 psi. Begin pressure test 5:41 WHP 3470 psi. drop 150 psi in 10 minutes (4%) 5:45 Day crew arrives on location 5:47 Hold shift handover meeting. Discuss current operation with night crew 6:00 Night crew departs location 6:10 Conduct walk around well test area. 6:20 Hold pre-shift safety meeting. Review flowing the well JSA 7:00 Strap sparge tank = 5" = 9.65 bbl. (back portion) 7:00 Confirm alarm settings on Air supply and ESD panel 7:02 Blow tanner gas through SSV lines 7:05 Function test all ESD pull stations. ALL ESD pull stations tripped system when activated 7:20 Test fire igniter. Igniter operational 7:30 Conduct inspection on surface lines 8:04 Coil tubing pressure testing complete. Shut in at choke manifold Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 63 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 13-Apr-14 8:30 R. Taylor attends daily operations meeting 8:54 Tubing and surface line pressured up to 3000 psi 8:58 Open choke to bleed pressure. Choke to 16/64ths 8:58 Returns at tank #1 9:05 Increase choke to 48/64ths to bleed pressure 9:07 Pressure bleed to 0 psi 9:08 Shut-in Choke.16/64ths on positive side 9:10 Strap tank #1 = 3" = 4.65 bbls 9:25 Confirm flow aligned to tank 1 9:25 Confirm line bypass to separator 9:28 Returns at tank #1 9:30 Start blowing down Coil Tubing with Nitrogen at 1000 scf/min 9:40 Strap tank #1 = 10" = 15.5 bbls. 9:50 Strap tank #1 = 19" = 29.45 bbls. Total barrels back = 27.9 bbl 9:54 Nitrogen rate drop to 500 scf/min 9:55 Nitrogen rate 300 scf/min away 10:00 Strap tank #1 = 31" = 48.05 bbls. Total barrels back = 46.5 bbl 10:02 Divert flow to separator 10:03 Choke to 16/64ths 10:06 1.750" orifice plate in service 10:10 1.750" orifice plate out of service 10:11 Shut-in choke manifold 10:11 Start pressuring up to test tubing and inlet line test to 3500 psi 10:14 Nitrogen online @ 1500 scf/min. 10:21 Increase Nitrogen rate to 1600 scf/min 10:37 Nitrogen offline 10:38 Pressure at 3500 psi. Monitor pressure 11:00 Test OK. Pressure holding steady 11:00 Open choke to bleed pressure 2000 psi Page 64 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 13-Apr-14 11:02 Choke to 12/64ths 11:03 Increase choke to 16/64ths. 11:18 Shut-in choke manifold. Pressure @ 2100psi 12:06 Function test all ESD pull stations. ALL ESD pull stations tripped system when activated 12:10 Move ESD pull station to the Rig floor at the well head 12:35 Open well at Expro's choke manifold on 10/64ths adjustable choke 12:37 Increase choke to 12/64ths 12:38 1.750" orifice plate in service 12:43 1.750" orifice plate out of service 12:47 1.250" orifice plate in service 13:00 Gas SG = 0.972 13:10 Increase choke to 16/64ths. 13:12 1.250" orifice plate out of service 13:15 1.750" orifice plate in service 13:25 Contact ACS to witness and check connections on fluid transfer from Tank #1 13:44 Start fluid transfer from tank #1 to Vac truck 13:51 Complete fluid transfer from tank 1 to Vac truck. Transferred vol = 46.5 bbls 14:30 Rock choke 14:31 Increase choke to 60/64ths. 14:32 Fluids to surface 14:38 Nitrogen injection rate @ 300 scf/min. 14:38 Fluid wt. = 9.9 ppg 14:40 Salinity = 260000 ppm 14:42 1.750" orifice plate out of service 14:57 Flow bypass separator 14:58 Nitrogen at choke manifold 15:00 Divert flow from tank#2 to tank #3 15:06 Returns at tank #3 15:15 Divert flow from tank#3 to tank #2 Page 65 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 13-Apr-14 15:21 Nitrogen off line 15:45 Resume injecting Nitrogen @ 500 scf/min. 15:45 Divert flow from tank#2 to tank #3 15:48 Returns at tank #3 15:51 Divert flow to separator 15:52 Nitrogen at choke manifold 15:53 Decrease choke to 32/64ths 15:55 1.750" orifice plate in service 16:00 Divert flow from tank#3 to tank #2 16:00 Fluid wt. = 8.6 ppg 16:00 Nitrogen injection rate decreased to 300 scf/min 16:03 Sparge sand trap. Trace of frac sand 16:09 Salinity = 50000 ppm 16:13 Switch to 1.5" oil low meter 16:15 Divert flow from tank#2 to tank #3 16:30 Divert flow from tank#3 to tank #2 16:32 Sparge sand trap. Trace of frac sand 16:45 Divert flow from tank#2 to tank #3 16:53 Divert flow bypassing separator 16:55 Nitrogen injection rate increased to 500 scf/min 17:00 1.750" orifice plate out of service 17:19 Coil Tubing at 4500 ft. 17:30 Divert flow from tank#3 to tank #2 17:32 Coil Tubing at 5500 ft. 17:34 Divert flow to separator 17:36 1.750" orifice plate in service 17:43 BHP = 2753 psi 17:45 Divert flow from tank#2 to tank #3 17:45 Night crew arrives on location Page 66 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 13-Apr-14 18:00 Shift handover, night shift take over. Divert to tank 2 18:15 Divert to tank 3 18:30 Coil stopped at 6500ft ft. Sparge sand trap. 18:45 64.3 bbl produced 19:00 BS&W: 96% Brine, 4% Sediment 19:05 Sparge Separator 19:30 BS&W: 89%Brine 11%Sediment 20:00 Sparge separator. Fluid wt. =8.75ppg 21:33 N2 at 1000 scf/min 21:47 N2 at 1000 scf/min 22:00 Sparge Sand Trap 22:28 Increase choke to 34/64. Target rate of 1.8 bbl/min 22:30 Sparge separator. BS&W 96%Brine, 4% Sediment 22:33 Increased pump rate to 1.8 bbl/min. Sparge Sand Trap 22:50 Choke shut in. Open to tank #3 22:56 Open Choke 22:58 Increase choke to 44/64ths 22:59 Decrease choke to 42/64ths 23:00 Sparge sand trap 23:00 Red sheen on sample surface. 23:10 Sparge sand trap 23:17 Sparge separator and sand trap 23:30 Sparge sand trap. BS&W: 93% Brine & 7% Sediment 23:35 Coil tubing below perforations. Begin coming above perfs with coil 23:38 Increase choke to 46/64ths 23:45 Tank #2=77" (1.7bbl/min) 23:46 Sparge sand trap 23:57 Sparge sand trap 14-Apr-14 0:00 247.7 bbl total produced Carter Garrett Shelby Brown Andrew McCabe Vince Madrid Brent Hickey Page 67 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 14-Apr-14 0:00 BS&W: 90% Brine &10% Sediment, Salinity=48000 ppm, Fluid wt. = 8.75 lb/gal 0:30 Coil at 1100 ft. BS&W: 99%Brine &1% Sediment 0:53 N2 at 300 scf/min 1:00 Sparge sand trap. Tank #3=106.5" (0.4 bbl/min) 1:00 BS&W: 99% Brine & 1% Sediment 1:18 Decrease choke to 30/64 1:30 Tank #3= 107.5"(0.111 bbl/min). No fluid cut 1:45 Tank #2=104" no returns in 15 min 1:50 Coil stop at 300 ft to circulate 300 scf/min N2 for an hour. Decrease choke to 20/64 2:15 No returns 2:23 Fluid at separator 2:25 Upstream choke pressure increase to 340 psi and rising 2:30 Sparge Sand Trap. No cut 2:38 Increase choke to 24/64ths 3:00 Sand tank=12"/12.75" 3:15 No returns at tank 3:24 Coil at 1600ft 3:25 Decrease choke to 20/64 3:30 No returns at tank 4:00 No returns at tank 4:30 Total produced including 9.61 bbl in sand tank= 340.6bbls. 4:34 Increase N2 to 1000 scf/min 4:36 Fluid at choke and separator 4:48 Increase choke to 36/64. N2 rate decreased to 700 scf/min 5:00 Decrease N2 to 500 scf/min 5:13 Decrease choke to 24/64 5:15 Total produced=362.31bbl (includes sand tank returns) 5:19 Total of 320 bbls produced 5:30 BS&W: 80%Brine & 20% Sediment Page 68 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 14-Apr-14 5:45 Day crew arrives on location 5:55 Nitrogen injection rate at 300 scf/min 5:50 Hold shift handover meeting. Discuss current operation with night crew 6:00 Divert flow from tank#3 to tank #2 6:05 Flowing straight Nitrogen 6:10 Night crew depart location 6:30 Hold pre-shift safety meeting. Review flowing the well JSA 6:30 Fluid wt. 8.7 ppg. Salinity = 48000 ppm. Gas SG = 0.972 7:30 Function test all ESD pull stations. ALL ESD pull stations tripped system when activated 7:35 Blow tanner gas through SSV lines 8:00 Sparge sand trap 8:15 Divert flow from tank#2 to tank #3 8:15 Fluid slugging through choke manifold 8:30 Divert flow from tank#3 to tank #2 8:35 Fluid wt. 8.7 ppg. Salinity = 40000 ppm. Gas SG = 0.972 8:45 Divert flow from tank#2 to tank #3 9:00 Coil Tubing start POOH 9:00 Divert flow from tank#3 to tank #2 9:45 Divert flow from tank#2 to tank #3 10:00 Fluid to surface 10:00 Divert flow from tank#3 to tank #2 10:10 **Trace of oil to surface 10:10 Collect sample from choke inlet 10:15 Divert flow from tank#2 to tank #3 10:30 Divert flow from tank#3 to tank #2 10:30 BS&W: 94% Brine & 0.5% Sediment. Oil 5% 10:30 Gas SG = 0.968 10:45 Divert flow from tank#2 to tank #3 11:00 Divert flow from tank#3 to tank #2 Roland Taylor Travis Atkinson Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 69 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 14-Apr-14 11:04 Switch generators 11:05 Take 1.750" orifice plate out of service 11:10 Put 1.250" orifice plate in service 12:00 Contact ACS to witness and check connections on fluid transfer from Tank to Vac truck 12:31 Start fluid transfer from tank #2 to Vac Truck 12:33 Coil Tubing start running hole to 5000 ft 13:15 Complete fluid transfer from tank #2 to Vac Truck. Transferred vol = 177.3 bbls 13:16 Start fluid transfer from tank #3 to Vac Truck 13:30 Stop fluid transfer from tank #3. Vac truck reach capacity 14:15 Coil tubing starts pumping fluid 14:20 Start performing ultrasonic thickness test on high velocity points on pipe 14:30 1.250" orifice plate out of service 14:34 Shut-in at choke manifold 14:45 Complete ultrasonic thickness test on pipe 14:46 Slowly open choke to bleed down pressure 14:47 Fluid at choke manifold 14:51 Shut-in at choke manifold 15:00 R. Lucier arrive on Q5 pad. Conduct walk around well test area 15:40 Fluid wt 8.7 ppg 15:46 Slowly open choke 15:50 Shut-in at choke manifold 16:00 Sparge sand trap 16:34 Coil tubing pumped 133 bbls total 16:35 Slowly open choke to bleed down pressure 16:40 Returns to tank #1 16:42 1.250" orifice plate in service 16:48 1.250" orifice plate out of service 16:51 0.875" orifice plate in service 17:16 Divert flow from tank#3 to tank #2 Rene Lucier Page 70 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 14-Apr-14 17:30 Divert flow from tank#2 to tank #3 17:30 Choke to 14/64ths adjustable 17:45 Night crew arrives on location. Divert flow from tank#3 to tank #2 18:00 Divert flow from tank#2 to tank #3 18:02 Hold pre-shift safety meeting. Review flowing the well JSA 18:05 Day crew depart 18:15 Divert flow from tank#3 to tank #2 18:19 N2 injection 500 scf/min 18:25 N2 injection 1000 scf/min. Returns at tank 18:30 Tank#2=8.5" 18:45 Tank#2=21.5" 18:47 N2 @ 350 scf/min 18:48 Divert flow through separator 18:51 Drain scrubber 18:57 Increase choke to 30/64 19:00 Tank#2=28". 37.2 bbl produced since 18:15 19:09 Crown valve closed to re-zero coil 19:15 Tank#2=30". 40.3 bbl produced since 18:15 19:23 RIH with coil tubing 75 ft/min, N2 at 500 scf/min 19:23 Returns at tank 19:30 N2 at 500 scf/min 19:45 Oil API 39.4 @ 88F. API gravity at 60F is 37.1 20:00 1.5" orifice dropped. Tank#3=9.5" 20:12 Returns at separator 20:15 Increase choke to 31/64. Tank#3=15.5", 22.5 bbl returned since 19:30hrs 20:30 BS&W: 89% Brine & 1% Sediment. Oil 10% 20:45 Tank#3=16.5" (27.9 bbl since 19:30hrs) 20:51 RIH with coil 21:00 BS&W: 98% Brine & 2% Sediment, trace oil. Tank#2=22" (31.8 bbl since 19:30) Carter Garrett Shelby Brown Andrew McCabe Vince Madrid Brent Hickey Page 71 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 14-Apr-14 21:01 Sparge sand trap 21:15 Tank#3=21", 38.8 bbl return since 1930 21:16 Crane moves from well test area 21:30 BS&W: 92% Brine & 8% Sediment. Tank#2=24" (41.9 bbl since 19:30) 21:45 Begin filling tank #1 with calcium carbonate. Tank#3=25" (48.1 bbl since 19:30) 22:00 BS&W: 90% Brine & 10% Sediment, trace oil. Tank#2=30" (57.4bbl since 19:30) 22:09 Sparge sand trap 22:15 Tank#3=29", 63.6 bbl return since 19:30 22:20 DAS lab internet/phone online 22:25 C. Garrett attends supervisor safety meeting 22:30 BS&W: 93%Brine & 7% Sediment, trace oil 22:45 Tank#3=30" (92.3bbl since 19:30) 22:46 Hold acid operation safety meeting in separator 22:47 Stop pumping N2 23:00 BS&W: 97% Brine & 2% Sediment. Oil 1%. Tank #2=33.5". Begin acid wash operation 23:04 Decrease choke to 20/64 23:15 Tank#3=31" (1.6 bbl since acid wash op) 23:18 N2 at 500 scf/min 23:21 N2 at 1000 scf/min 23:25 N2 at 750 scf/min 23:30 BS&W: 93% Brine & 6% Sediment. Oil 1%. Tank#2=33.5" 23:34 Decrease choke to 10/64 23:45 Tank#3=31" (1.6 bbl since acid wash op) 15-Apr-14 0:00 BS&W: 98.5% Brine & 0.5% Sediment. Oil 1%. Tank#2=33.5" (No returns) 0:03 N2 offline. Begin POOH at 150 ft/min 0:15 Tank#3=31". No returns 0:30 Divert from tank #2 to tank #1. Coil stop at 4000 ft 0:45 Tank #1= 15" no returns. Begin acid return 0:48 N2 online at 1000 scf/min Page 72 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 15-Apr-14 0:50 Expro personnel review and sign calcium carbonate and hydrochloric acid MSDS 1:00 No returns at surface 1:30 Begin slowly increase choke to 30/64. N2 at 300 scf/min. 1:33 Returns at tank 1:38 Choke at 30/64 1:45 Fluid returns at choke, pH=7 1:51 Fluid returns at choke, pH=4 1:55 Fluid returns at choke, pH=2 2:00 Tank#1=37" 34.1 bbls returned 2:11 Coil at 4000 ft 2:30 No returns 2:45 Coil begins pumping calcium carbonate at 2bbl/min. Tank#1=37.5" or 58.13 bbl (initial strap) 2:49 Coil pump 6 bbl 2:51 Coil pump 10 bbl 2:53 Coil pump 13 bbl calcium carbonate 3:00 BHP=1305 psi. No returns for BS&W. Gas gravity=0.970 3:13 N2 online at 1500 scf/min 3:15 Decrease choke to 24/64 3:38 N2 decrease to 500 scf/min. WHP increasing 3:45 Fluid at choke. 3:46 N2 offline 3:57 Increase choke to 36/64 3:59 Increase choke to 40/64 4:13 Blow down separator into Tank #1 with N2 4:15 Tank#1=38.5" (59.68 bbl) 5:00 Divert from tank #1 to tank #2 5:05 Bleed separator pressure and bypass 5:45 Day crew arrives on location 5:50 Hold shift handover meeting. Discuss current operation with night crew Roland Taylor Rene Lucier Page 73 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 15-Apr-14 6:15 Night crew depart location 6:30 Hold pre-shift safety meeting. Review flowing the well JSA and HCl and CaCO3 7:00 Perform pipe tally on inlet line 8:00 Update inlet line pipework tally 10:00 Plot report: WHP and Annulus pressure from 1500 hrs to 1800 hrs. Submit to client 10:15 Plot report: WHP from 4-14 @ 2200 hrs to 4-15_0500 hrs. Submit to client 11:15 Start blowing brine to tank #1from Vac truck 11:33 Complete pumping brine to tank #1. Estimate load of 50 bbls 11:50 Company rep informs crew of start RIH with Coil tubing 12:15 Switch generator 12:16 Switch air compressor 12:18 Start pumping of N2 @ 300 scf/min. WHP = 40 psig 13:00 Increase Nitrogen rate to 500 scf/min 13:30 Increase Nitrogen rate to 1000 scf/min. WHP = 0 psig 13:54 WHP starts increasing 13:56 Fluid to surface 13:57 Decrease Nitrogen rate to 500 scf/min 14:04 Increase choke to 22/64ths 14:06 Increase choke to 26/64ths 14:08 Increase choke to 30/64ths 14:08 Fluid wt 10.2 ppg 14:11 Divert flow to separator 14:13 Decrease choke to 18/64ths 14:15 Strap at tank #2 = 42" = 65.10 bbls. Gain of 13.18 bbls since the coil lift 14:15 Divert flow from tank #2 to tank #3 14:18 Decrease Nitrogen rate to 300 scf/min 14:20 1.750" orifice plate in service 14:23 Straight N2 to surface 14:25 Increase choke to 22/64ths Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 74 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 15-Apr-14 14:27 Increase choke to 26/64ths 14:30 Divert flow from tank #3 to tank #2 14:30 Sparge sand trap 14:34 Fluid wt 9.25 ppg 14:38 Increase Nitrogen rate to 500 scf/min 14:56 Fluid to surface 14:58 Returns to tank #1 15:00 Total of 15 bbls return since starting N2 lift 15:00 Divert flow from tank #2 to tank #3 15:15 Divert flow from tank #3 to tank #2 15:15 Nitrogen injection pump offline 15:30 Divert flow from tank #2 to tank #3 15:45 Divert flow from tank #3 to tank #2 15:50 Sparge sand trap 15:53 Straight N2 to surface 16:00 Divert flow from tank #2 to tank #3 16:00 BS&W=69% Brine and 6% Sediment. Oil 25% 16:00 Salinity = 125,000 ppm; pH = 6; Gas SG 0.976 16:00 Coil start pumping fluid. Pumps down 16:15 Divert flow from tank #3 to tank #2 16:15 Increase choke to 30/64ths 16:30 Divert flow from tank #2 to tank #3 16:30 BS&W=98% Brine and 1% Sediment. Oil 1%. pH = 6 16:45 Divert flow from tank #3 to tank #2 16:52 Coil start pumping fluid with LRS @ rate 1.3 bbls/min 17:00 Divert flow from tank #2 to tank #3 17:01 No fluid returns 17:03 Fluid to surface 17:15 Divert flow from tank #3 to tank #2 Page 75 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 15-Apr-14 17:30 Divert flow from tank #2 to tank #3 17:30 BS&W=99.25% Brine and 0.25% Sediment 17:30 Salinity 42,000 ppm; Fluid wt 8.8 ppg; Gas SG 0.990 17:35 Increase choke to 34/64ths 17:45 Divert flow from tank #3 to tank #2 17:45 Night crew arrives on location 17:50 Hold shift handover meeting. Discuss current operation with night crew 17:55 Hold pre-shift safety meeting. Review flowing the well JSA 18:00 BS&W: 99%Brine,1%Sediment,trace oil, Salinity=40,000, PH=7. 18:00 Divert flow from tank #3 to tank #2 18:15 Divert flow from tank #2 to tank #3. Tank#3=69.5" 18:30 BS&W: 95% Brine & 0.5% Sediment. Oil 4.5%. Salinity=40,000ppm, Fluid wt.=8.75ppg. 18:45 Divert flow from tank #3 to #2 18:50 Coil at 760 ft 18:53 Start pumping brine through coil 19:00 Returns at separator. Sparge sand trap. BS&W: 99.75% Brine, 0.25% Sediment 19:00 Fluid wt= 9.75ppg 19:00 Divert flow from tank #2 to #3 19:02 Brine pump at 1.9 bbl/min 19:15 Tank #3=79" total 15.5 bbl returned. Divert tank #3 to tank #2 19:19 Sparge sand trap 19:30 BS&W: 100% Brine trace oil. Tank #2=77" 32.4 bbl returned 19:30 Divert flow from tank #2 to tank #3 19:45 Tank #3=87"(136.6bbl), 45.7 bbl returned. Divert flow from tank #3 to tank #2 19:50 Increase brine pump to 3 bbl/min 19:58 Sand trap choke open. Solids at sand trap. 20:00 BS&W: 99.5% Brine & 0.5% sed.T#2=90", 67.4 bbl returned 20:00 Divert flow from tank #2 to tank #3 20:05 N2 online at 500 scf/min Carter Garrett Shelby Brown Andrew McCabe Vince Madrid Brent Hickey Page 76 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 15-Apr-14 20:15 Increased sand returns. T3=92"(144.94bbl), 75.7bbl returned 20:15 Divert flow from tank #3 to tank #2 20:30 BS&W: 99.75%Brine & 0.25% Sediment. T#2=91", 77.4bbl return 20:30 Divert flow from tank#2 to #3 20:40 Decrease in sand returns 20:45 Tank #3=91"(143.27bbl), 81.6bbl return. Divert flow from tank #3 to tank #2 20:50 N2 at flare 20:56 Sparge separator 21:00 BS&W: 99.5% Brine & 0.5% Sediment. Divert flow from tank #2 to tank #3 21:05 Sand tank returns: 35.4 bbl sand & 108 bbl fluid returns 21:15 Tank #3=103"(163.3bbl). Divert flow from tank#3 to #2 21:27 N2 offline. Coil at 6600 ft 21:30 BS&W: 99.5% Brine & 0.5% Sediment 21:30 Tank #2=100.5"(159.11bbl) 220bbl returns including sand tank 21:45 Tank #3=110". Sand tank: 15"sand/52"fluid (13.5bbl sediment return) 22:00 Tank #2=101"(159.94") Total fluid returns=276bbl. BS&W: 99.75% Brine & 0.25% Sediment 22:15 Tank #3=111"(176.6bbl) Divert from tank #3 to tank #2 22:30 Tank #2=101"(159.94") Divert from tank #2 to tank #3. No fluid cut 22:45 Tank #3=111"(176.6bbl) Divert from tank #3 to tank #2 23:00 BS&W: 100% Brine. Tank #2=101.5". Divert from tank #2 to tank #3 23:13 Coil at 4000 ft 23:15 Tank #3=113.5" (180.8bbl). Divert from tank #3 to tank #2 23:19 Sparge sand trap 23:30 BS&W: 95% Brine with trace sediment. Oil 5%. Tank #2=117" 23:30 Divert from tank #2 to tank #3 23:45 Tank #3=119.5". Divert from tank #3 to tank #2 16-Apr-14 0:00 BS&W: 100% Brine, trace sediment, trace Oil. Tank #2=122". Divert from T#3 to T#2 0:15 Tank #3=120.5" (192.45). Divert from tank #2 to tank #3 0:30 Tank #2=123" (196.62 bbl). Divert from tank #3 to tank #2 Page 77 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 16-Apr-14 0:45 Tank #3=120.5" (192.45). Divert from tank #2 to tank #3 0:48 N2 offline 0:59 N2 online at 500 scf/min 1:00 Tank #2=123" (196.62 bbl). Divert from tank #3 to tank #2 1:12 N2 at 300 scf/min 1:25 Fluid at choke 1:30 BS&W: 97% Brine & trace sediment. Oil 3% 1:45 Tank #3=132" (211.62 bbl) 2:00 BS&W: 96% Brine with trace sediment. Oil 4%. N2 offline. Tank #3=133" (213.29bbl) 2:15 Vac truck remove 272.7 bbl 2:31 Swab valve closed & master hydraulic valve closed 3:25 Hold safety meeting in DAS lab 3:00 Decrease choke to 20/64ths 3:30 350 bbl total fluids recovered since 4/15 19:00 5:45 Day crew arrives on location 5:50 Hold shift handover meeting. Discuss current operation with night crew 6:10 Night crew depart on location 6:45 Hold pre-shift safety meeting. Review flowing the well JSA 8:00 Shut-in at choke manifold. WHP = 170 psig 8:15 Re-spot downstream SSV heater for rig operation 9:24 Open choke to 12/64ths 9:26 Shut-in at choke manifold 10:00 Switch generator 10:10 Perform Ultrasonic thickness on high velocity points on surface lines 12:15 Contact ACS to witness and check connections on fluid transfer from Sparge Tank 13:00 Start fluid transfer from Sparge Tank to Vac truck 13:15 Switch air compressors 13:30 Complete fluid transfer from Sparge Tank to Vac Truck. Estimated load 239 bbls. 14:00 Move methanol barrels to rig's containment Roland Taylor Rene Lucier Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 78 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 16-Apr-14 14:30 Organize pipe trailer 15:13 Open choke to bleed down pressure from wireline lubricator 15:30 Shut-in at the wing valve for pressure testing at the wellhead 15:30 Strap sand tank = 4.5" 15:35 Stage heater back at downstream SSV 16:00 Change-out N2 tank for blowdown of sparge line on sand trap 16:30 Repair hooch on transfer pumps 17:45 Night crew arrives on location 17:50 Hold shift handover meeting. Discuss current operation with night crew 18:00 Hold pre-shift safety meeting. Review JSA and TRAC 18:30 Lubricator pressure test ongoing 20:16 Wing valve open to bleed pressure through well test package. Open to T#3 20:24 Wing valve closed 20:26 Well head pressure bled to 0 psi 22:00 Begin RIH with wireline perforation guns 22:45 Expro Q7 crew arrive. Transfer rental pipe from Q7 truck to Q5 basket 23:00 Wireline at perforation depth 23:05 Close choke manifold 23:10 Perforating guns fired 23:23 Bottom hole pressure= 2089 psi 23:33 Bottom hole pressure=2091 17-Apr-14 0:08 Wireline stuck in hole at 7315 ft 3:05 Open master valve 3:07 Open wing valve. WHP: 230 psi 3:12 Ignite flare pilot 3:15 Open choke manifold to 16/64" 3:16 **Gas at flare 3:25 0.75" orifice plate dropped 3:30 Gas S.G.=0.704 Carter Garrett Shelby Brown Andrew McCabe Vince Madrid Brent Hickey Page 79 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 17-Apr-14 3:36 Gas rate of 63 scf/min 3:45 Gas rate 23 scf/min 4:00 Gas S.G.=0.688. Gas rate=12 scf/min 4:15 Dip tank 2. 2" of oil at surface 5:45 Day crew arrive on location 5:50 Hold shift handover meeting. Discuss current operation with night crew 6:00 0.70% CO2 and 0 ppm H2S 6:10 Night crew departs on location 6:20 Hold pre-shift safety meeting. Discuss the day's activities and review flowing the well JSA 7:30 Switch compressor 11:40 Contact ACS to witness and check connections on fluid transfer from tanks 12:00 Company shut wing valve and master valve for pressure testing 12:02 Start fluid transfer from tank #3 to Vac truck. 12:12 Well shut-in on the flow cross @ the tree 12:13 Shut-in supply gas to the flare 12:13 0.750" orifice plate out of service 12:30 Complete fluid transfer from tank #3 to Vac truck. Estimated load 110.58 bbls 12:30 Start fluid transfer from tank #2 to Vac truck. 13:04 Complete fluid transfer from tank #2 to Vac truck. Estimated load 121.24 bbls 14:00 Contact ACS to witness and check connections on pumping approx. 100 bbls fluid to tank #1 14:15 Start pumping to tank #1 from Vac truck with a estimate load of 100 bbls 14:32 Shut-in at Expro's choke manifold 14:34 Open at wing valve. Showing WHP @ 5 psi 14:50 Complete pumping to tank #1. 110 bbls added to tank. 15:39 Rig starts bleeding off pressure at the Annulus 15:43 Confirm alignment of flow to tank #3 and separator bypass 15:43 Open Expro's choke manifold to bleed pressure 16:00 Receive 3 totes of glycol from Q7 16:15 Shut-in choke manifold Roland Taylor Rene Lucier Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Page 80 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 17-Apr-14 16:20 Open choke manifold 16:40 Increase Annulus Pressure. Attempt to close LPRN 16:58 Bleed off annulus pressure 17:00 Shut in at flow cross. Shut in at choke 17:45 Night crew arrive on location 17:50 Hold shift handover meeting. Discuss current operation with night crew 18:00 Hold pre-shift safety meeting. Review JSA and TRAC 19:00 Choke closed. Shut in at Flow cross. 20:35 Wing valve open 20:37 Open choke manifold 20:38 Fluid at choke 20:45 Fluid returns at separator 22:00 Blow down lines to vertical tanks with rig air 22:16 Shut off rig air 22:23 Flow wing closed. Shut in at choke 18-Apr-14 5:30 70bbl of 10.2 ppg brine pumped. 1300 psi WHP from rig gauge 5:45 Day crew arrives on location 5:50 Hold shift handover meeting. Discuss current operation with night crew 6:10 Night crew departs location 6:15 Hold pre-shift safety meeting. Review rig down equipment JSA 6:45 R. Lucier departs Q5 drill site. L. Kropf replaces R. Lucier 6:50 L. Kropf conduct walk around well test area 6:55 Wireline start rigging up equipment at the wellhead 7:00 Cap surface safety valve 7:30 Start blowing down separator fluids to tank # 4 7:40 Contact loader operator to re-spot hose conex 7:50 Loader operator spots hose conex around tank farm 7:55 Review TRAC for rigging down horizontal tank manifolds 8:00 Open and close flow cross to confirm zero pressure Carter Garrett Shelby Brown Andrew McCabe Vince Madrid Brent Hickey Roland Taylor Larry Kropf Michael Joiner Sharon Oyao Vance Wolford Jordan Mooney Jamon Sandoval Page 81 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 18-Apr-14 8:04 Blow down fluids from separator to sand tank 8:05 Blow down separator sparge line with N2 8:10 Start blow down separator with N2 8:15 Start packing hoses from horizontal tanks on hose rack 8:28 Start rigging down inlet and outlet manifolds on the horizontal tanks 8:30 R. Taylor attends daily operations meeting 8:30 Complete blowing down lines on the separator 9:15 Rig down low gas flow meter and liquid flow meters 10:20 Company man D. Ross gives notification to start rig down and demob operations 10:30 Start rigging down supply line to SSV 10:30 Email Fardux to end services for Datacast 10:45 Stop logging data from Fardux 11:00 Start rigging down data acquisition cables and safety pilots 11:00 Start rigging down grounding cables and air hose 11:25 Discuss hot water blowdown with truck lead and Company Man 12:30 Rig down all transducers except at the wellhead 13:00 Start removing heat trace plastic sheeting from pipe 18-Apr-14 14:00 Start rigging down sand trap, gas scrubber and separator relief lines 14:30 Complete rigging down data acquisition equipment 15:00 Rig down of relief lines complete 16:00 Create TRAC for laying down flare stack 16:50 Hold safety meeting with crane crew and discuss laying down flare stack 17:05 Start laying down flare stack 17:20 Flare stack lowered to the ground 17:25 Start removing guy cables from flare stack 17:45 Night crew arrives on location 18:00 Hold pre-shift safety meeting. Review rig down equipment JSA 19:00 Remove remaining plastic sheeting on lines 19-Apr-14 2:00 Remove sections of safety system from separator Joseph Fisher Shelby Brown Andrew McCabe Vince Madrid Brent Hickey Page 82 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 19-Apr-14 2:30 Rig down scrubber pressure transducer 3:00 Rig down relief and gas lines 4:00 Lower heater exhaust stack 4:30 Rig down DAS computer 5:00 Connect hose to run from N2 tanks to drill floor 5:45 Day crew arrive on location 5:45 Hold shift handover meeting. Discuss current operation with night crew 6:00 Night depart location 6:00 Conduct walk around at the Rig Floor 6:10 Hold pre-shift Safety Meeting. Fill out TRAC and discuss blowing down surface lines 6:20 Wireline complete rigging down at the wellhead. Inform Expro to start blowing down lines 6:54 Confirm alignment to tank #2 7:05 LRS starts pumping hot water from kill side of tree 7:12 Returns at the choke manifold 7:17 Returns at tank #2 7:40 LRS shut-in. pumped approx. 30 bbls of water 7:41 Start blowing down surface lines with Nitrogen 7:46 Nitrogen returns at choke manifold 7:47 Nitrogen returns at tanks 7:57 Start blow down riser at the tanks 8:00 Stop blowing down tank riser. Replace Nitrogen cylinders 8:20 Attend Safety Meeting at the Rig Floor. Discuss rigging down wellhead 8:30 Resume blowing down tank risers 8:40 Complete blowing down surface lines 9:00 Rig down scan cables and transducers at the wellhead 9:15 Connect Vac truck to tank farm inlet manifold 9:15 Start rigging down inlet lines 9:20 Start removing inlet riser from rig floor with the crane 9:30 Continue rigging down surface line Roland Taylor Larry Kropf Jamon Sandoval Sharon Oyao Vance Wolford Jordan Mooney Page 83 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 19-Apr-14 9:45 Inlet riser removed from rig floor 9:55 R. Taylor discuss equipment de-mob with rig clerk and logistics coordinator 10:55 Start rigging down tank inlet hoses 11:40 Complete rigging down tank inlet hoses 11:55 Remove flange from flow wing side of tree 12:30 Start rigging up Vac truck to start emptying tanks 13:05 Call ACS technician to witness fluid transfer 13:10 Start rigging down nitrogen cylinder manifolds 13:20 Start gathering and placing pipe joints on pipe rack and inside pipe basket 13:33 Start transferring fluids from tank # 2 to vac truck 13:43 Complete emptying tank #2. Start transferring fluids from tank # 1 14:00 Complete rigging down nitrogen manifolds and place in separator 14:05 GCI technician visits lab and identify equipment to be returned 14:07 Complete emptying tank #1. Start transferring fluids from tank #3 14:15 Complete emptying tank #3. Start transferring fluids from tank #4 14:20 Complete emptying tank #4. Approx. 147 bbls vac from 4-tanks. All 4 tanks empty 14:27 Start rigging down sand trap sparge line 14:30 Strap tank #1 to tank #4: Tank #1= 0.5" Tank #2 = 1.5" Tank #3 = 1" Tank #4 = 1" 14:35 Gathered all data cards and field reading inspection sheets 15:00 Complete rig down sand trap sparge line 15:20 Continue stacking pipe joints on pipe trailer 15:35 Cruz personnel starts dismantling tank farm berm 15:40 Start disassembling tank inlet and outlet fittings on vertical tanks 15:55 Start replacing inlet flange on sand tank 16:15 Place all tank outlet hoses on hose rack 16:25 Complete disassembly of inlet and outlet fittings on vertical tanks 16:40 Inlet flange on sand tank replaced 17:15 Conduct general housekeeping in preparation for shift change 17:45 Night crew arrives on location Page 84 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 19-Apr-14 17:50 Hold shift handover meeting. Discuss current operation with night crew 18:00 Hold pre-shift Safety Meeting. Fill out TRAC and discuss rig down and load out 18:30 Finish placing hoses on hose rack 19:00 Demolish tank farm hooch 19:30 Place hose rack into hose conex 19:45 Lynden drops trailer 20:00 Lynden truck hauls off tank A 2715 20:30 Crane lifts tank stairs off of tanks 21:30 Crane lifts diverter manifold out of tank farm 22:00 Bed truck arrives on location 22:20 Bed truck leaves with tank #124 to Mustang pad 22:45 Crane removes remaining three vertical tanks out of tank farm 23:00 ACS completes fluid transfer checklist for glycol from heater bath 23:15 ACS completes fluid transfer checklist for sand tank 23:30 Complete transfer of glycol from heater bath 23:45 Vac truck Completes removing fluids out of sand tank 20-Apr-14 0:45 Winch trucks arrive to load out tanks 1:00 Winch truck leaves with tank # 2716 1:15 Winch truck leaves with tank # 2717 1:45 Bed truck leaves with tank #310 2:00 Crane lifts relief tank out of main berm 2:30 Crane lifts sand trap out of main berm 2:45 Winch truck leaves with tank # 2714 3:00 Winch truck leaves with tank # 2713 3:15 Bed truck leaves with tank # 288 4:00 Prepare conex for transport 4:15 Loader removes nitrogen racks 4:30 Move DAS equipment to lab for transport 4:40 Winch truck leaves with tank # 2712 Joseph Fisher Shelby Brown Andrew McCabe Vince Madrid Brent Hickey Page 85 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 20-Apr-14 4:40 Winch truck leaves with tank # 2711 4:45 Box and inventory radios 4:50 Bed truck leaves with tank # 304 5:00 Remove sand trap relief line 5:15 Load winch truck and trailer with pipe house and hose conex 5:45 Day crew arrive on location 5:50 Hold shift handover meeting. Discuss current operation with night crew 6:05 Night depart location 6:10 Hold pre-shift Safety Meeting. Fill out TRAC and discuss loading & unloading equipment 6:25 Conduct walk around well test area. Check all equipment in preparation for shipping 7:00 Crane crew starts removing rig mats at the tank farm 7:15 Start packing lab supplies in DAS lab 7:20 Start wrapping equipment inlets and outlets 7:30 Cruz personnel start dismantling well test main berm 8:00 DAS lab packed and ready for shipping 8:20 Remove grounding cable and power supply cable from lab 8:30 Re-spot data acquisition Lab 8:35 Lower hand rail at the sand tank 9:10 Truck with flare stack, diverter manifold, SSV and sand Trap departs location 9:30 Return phone, battery backups, Ethernet cords and Ethernet connection to Larry 10:10 Two Lynden trucks with trailers arrive on location 10:35 Lay down vertical separator and load on truck 10:45 Start transferring fuel from line heater fuel tank to rig's portable fuel tank 11:05 Winch truck back up to doghouse and start separating doghouse and separator 11:20 Crane starts lifting compressor building and load onto Lynden trailer 11:40 Close doors on separator and doghouse 12:10 Complete transferring fuel from line heater to Rig's fuel tank 13:00 Winch truck starts loading separator 13:20 Crane start loading generator on Lynden trailer Roland Taylor Larry Kropf Jamon Sandoval Sharon Oyao Vance Wolford Jordan Mooney Page 86 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 20-Apr-14 14:05 Load line heater on trailer 14:30 Load blowdown tank on trailer 15:10 Truck with Separator depart Q5 pad for wash bay 15:15 Trailer arrives on location for final load 15:20 Start loading propane bottles, Relief tank on Lynden trailer 15:20 Spot Glycol and Methanol in rig's berm 16:25 Trailers depart Q5 pad location 17:00 Complete Lynden trailer manifests 17:45 Crew departs location 21-Apr-14 6:30 Obtain review and signature on Job Performance Report from Repsol Co. man. D. Bray 8:40 V. Wolford, J. Sandoval, J. Fisher and R. Taylor depart Q-camp for Deadhorse 10:45 Crew arrives Deadhorse 10:55 Return 3ea. rental trucks to truck rental company 11:05 Crew depart Deadhorse 12:55 Crew arrives Q-camp 13:20 Crew depart Q-camp on Repsol transport bus for charter flight 14:35 Perform survey on Q5 drill site. Search for left behind items and inspect pad condition 15:45 Receive call from logistics. Discuss equipment movement 17:05 Reply to Yan Dong's email. Update on location of oil sample 17:15 Email material movement sheets to logistics 18:00 Call wash bay personnel and discuss equipment cleaning 18:15 Email equipment spreadsheet to wash bay personnel 18:30 Update end of job paperwork 22-Apr-14 6:00 Continue updating end of job paperwork 14:10 Depart Q-camp via Repsol charter 16:30 Arrive Anchorage 23-Apr-14 8:00 Start updating and completing Project file for Repsol Q-5 well 12:35 Project File binders complete 13:40 Start reviewing and finalizing Q5 Well Report Roland Taylor Larry Kropf Jamon Sandoval Sharon Oyao Vance Wolford Jordan Mooney Joseph Fisher Shelby Brown Andrew McCabe Vince Madrid Brent Hickey Roland Taylor Roland Taylor Sharon Oyao Page 87 COMPANY:Repsol E&P USA Inc. FIELD:Qugruk LEASE:Qugruk-5 Drill Site WELL#:Qugruk-5A A.F.E. #:NS_13_001 DATE TIME OPERATIONS PERFORMED Sequence of Events STE CREW ON SITE 23-Apr-14 18:00 Q5 preliminary well Report complete. Submit for review Process & Instrumentation Diagram Process & Instrumentation Diagram Well Test Equipment Layout Well Test Equipment Layout Company:Company: Company:Company: Repsol USARepsol USA Repsol USARepsol USA Well: Well: Well: Well: Qugruk#Qugruk# Qugruk#Qugruk#5A5A 5A5A Field:Field: Field:Field: North SlopeNorth Slope North SlopeNorth Slope State:State: State:State: AlaskaAlaska AlaskaAlaska Country:Country: Country:Country: USAUSA USAUSA Date:Date: Date:Date: 2424 2424-- --MarchMarch MarchMarch-- --20142014 20142014 Interval:Interval: Interval:Interval: 2,215’ to 7,9502,215’ to 7,9502,215’ to 7,9502,215’ to 7,950 ‘‘ ‘‘ MDMD MDMD Section:Section: Section:Section: 8.58.5 8.58.5” (Open Hole)” (Open Hole)” (Open Hole)” (Open Hole) SchlumbergerSchlumbergerSchlumbergerSchlumberger PetroTechnical ServicesPetroTechnical ServicesPetroTechnical ServicesPetroTechnical Services 2525 Gambell Street, Suite 4002525 Gambell Street, Suite 4002525 Gambell Street, Suite 4002525 Gambell Street, Suite 400 99503 99503 99503 99503 -- -- Anchorage, AlaskaAnchorage, AlaskaAnchorage, AlaskaAnchorage, Alaska Sonic Scanner Advisor ReportSonic Scanner Advisor ReportSonic Scanner Advisor ReportSonic Scanner Advisor Report Prepared By: Prepared By: Prepared By: Prepared By: Hatem AbiedaHatem AbiedaHatem AbiedaHatem Abieda CONFIDENTIAL DATA TRANSMITTAL PER AS 38.05.180(8)(C) Standard Disclaimer The use of and reliance upon this recorded-data by the herein named company (and any of its affiliates, partners, representatives, agents, consultants and employees) is subject to the terms and conditions agreed upon between Schlumberger and the Company, including: (a) Restrictions on use of the recorded-data; (b) Disclaimers and waivers of warranties and representations regarding company's use and reliance upon the recorded-data; and (c) Customer's full and sole responsibility for any inference drawn or decision made in connection with the use of this recorded-data. 3 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Table Table Table Table of contents of contents of contents of contents 11 11-- -- EXECUTIVE SUMMARY EXECUTIVE SUMMARY EXECUTIVE SUMMARY EXECUTIVE SUMMARY ................................ ................................ ................................ ................................................................ ................................ ................................ ................................................................ ................................ ................................ ...................................................... ...................... ...................... ...................... 44 44 22 22-- -- WELL PARAMETERS & TO WELL PARAMETERS & TO WELL PARAMETERS & TO WELL PARAMETERS & TOOL CONFIGURATION OL CONFIGURATION OL CONFIGURATION OL CONFIGURATION ................................ ................................ ................................ ................................................................ ................................ ................................ ............................................. ............. ............. ............. 55 55 33 33-- -- SONIC SCANNER DATA A SONIC SCANNER DATA A SONIC SCANNER DATA A SONIC SCANNER DATA ACQUISITION CQUISITION CQUISITION CQUISITION ................................ ................................ ................................ ................................................................ ................................ ................................ ............................................................ ............................ ............................ ............................ 77 77 44 44-- -- DATA QC DATA QC DATA QC DATA QC ................................ ................................ ................................ ................................................................ ................................ ................................ ................................................................ ................................ ................................ ................................................................ ................................ ................................ .............................................. .............. .............. .............. 99 99 55 55-- -- SUMMARY SUMMARY SUMMARY SUMMARY ................................ ................................ ................................ ................................................................ ................................ ................................ ................................................................ ................................ ................................ ................................................................ ................................ ................................ ......................................... ......... ......... ......... 15 15 15 15 66 66-- -- RECOMMENDATIONS RECOMMENDATIONS RECOMMENDATIONS RECOMMENDATIONS ................................ ................................ ................................ ................................................................ ................................ ................................ ................................................................ ................................ ................................ ...................................................... ...................... ...................... ...................... 15 15 15 15 APPENDIX A APPENDIX A APPENDIX A APPENDIX A -- --ADVANCED SONIC SCANN ADVANCED SONIC SCANN ADVANCED SONIC SCANN ADVANCED SONIC SCANNER PROCESSING ER PROCESSING ER PROCESSING ER PROCESSING ................................ ................................ ................................ ............................................................... ............................... ............................... ............................... 16 16 16 16 AA AANISOTROPY NISOTROPY NISOTROPY NISOTROPY AA AANALYSIS NALYSIS NALYSIS NALYSIS ................................ ................................ ................................ ................................................................ ................................ ................................ ................................................................ ................................ ................................ ............................................................. ............................. ............................. ............................. 16 16 16 16 FF FFRACTURE RACTURE RACTURE RACTURE EE EEVALUATION FROM VALUATION FROM VALUATION FROM VALUATION FROM SS SSTONELEY TONELEY TONELEY TONELEY ................................ ................................ ................................ ................................................................ ................................ ................................ ................................................................ ................................ ................................ .................................... .... .... .... 17 17 17 17 4 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope 11 11-- -- Executive Executive Executive Executive Summary Summary Summary Summary • Sonic Scanner data were acquired over the open hole 8.5” section from 2,215’ – 7,950‘ MD in the Qugruk#5A well on March 21, 2014. • Sonic Scanner was run with all data mode and data was processed for high frequency Monopole Far (MF) and Dipole (XD and YD) for Compressional and Shear slowness respectively. • Data reprocessing using optimized parameters was carried out for the entire section for more accurate formation Compressional and Shear slowness estimation. Multishot processing was applied to field data to compute the slowness. The final result of Multishot processing will enhance the vertical resolution. Next pages describe processing workflow, parameters used, and further observations of the advanced interpretation of the Sonic Scanner data if any. 5 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope 22 22-- -- Well Parameters & Tool Configuration Well Parameters & Tool Configuration Well Parameters & Tool Configuration Well Parameters & Tool Configuration 6 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Toolstring Toolstring Toolstring Toolstring 7 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope 33 33-- -- Sonic Scanner data acquisition Sonic Scanner data acquisition Sonic Scanner data acquisition Sonic Scanner data acquisition • During logging, Sonic Scanner sequentially fires six sources: one far monopole high- frequency (used for Compressional and Shear generation), one far monopole low- frequency (used for Stoneley generation), two orthogonally-polarized dipole sources (used to generate the borehole flexural mode), and two monopoles located just above and below the receiver array (commonly used for cement bond evaluation) • Per source firing, the resulting waveforms are recorded at 13 receiver levels. For a given depth, the 13 recorded waveforms compose a “waveform array” • Slownesses are obtained by processing waveform arrays through various techniques, such as “Slowness-Time Coherence”, or STC. Figure 1 shows Sonic Scanner tool configuration and different modes that can be acquired by the tool. 8 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Figure 1 Figure 1 Figure 1 Figure 1: Sonic Scanner tool configuration and different modes that can be acquired by the tool 9 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope 44 44-- -- Data Data Data Data QC QC QC QC • The quality of the raw waveform data from the 13 receivers was checked for consistency and noise. All monopole and dipole waveforms have good consistency indicating that all the receivers worked properly (Figure 2). • For borehole acoustics, whether on wireline or while-drilling, signal strength is affected by mud weight and viscosity. Borehole rugosity will also attenuate and destroy signal strength. Any gas in the mud will severely attenuate the signal as well. • Overall, the raw monopole and dipole waveform quality is good (Figure 3). • The quality of the Compressional and Shear slowness from High Frequency Monopole Far is good quality and the final slowness (DTCO and DTSM) was obtained from Slowness- Time Coherence (STC) processing with the multishot technique. The shear slowness quality deteriorates above 4,100’ MD and then disappear (Figure 4). This could be related to slowness of shear compared to mud slowness (DTmud < DTSM). • The Shear slowness DTSM was obtained from the low-frequency of the dipole-generated borehole flexural wave and showed good quality. The ultimate quality control of the obtained shear slowness occurs in the slowness-frequency domain through dispersion curve analysis (Figure 5 and 6). • Anisotropy was seen in along some intervals from comparison of the X and Y dipole dispersion curves. • A good Stoneley slowness was also observed throughout the entire interval. 10 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Figure 2 Figure 2 Figure 2 Figure 2: consistency check for the 13 receivers indicating that all the receivers worked properly. 11 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Figure Figure Figure Figure 33 33: The Compressional and shear arrival are seen on the VDL. The majority of the logged interval indicates good monopole compressionl and shear and dipole shear. Monopole Waveform X-Dipole Waveform Y-Dipole Waveform 12 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Figure Figure Figure Figure 44 44: Data reprocessing of high frequency monopole showed good compressional and shear slowness. Shear slowness deteriorates and then disappear above 4,100’MD. High frequency monopole shear High frequency monopole compressional 13 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Figure Figure Figure Figure 55 55: Data reprocessing of X-Dipole showed good quality shear slowness. Shear X-Dipole °°°°° Shear X -Dipole °°°°° Shear Y-Dipole 14 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Figure Figure Figure Figure 66 66: Data reprocessing of Y-Dipole showed good quality shear slowness. Shear Y -Dipole °°°°° Shear X -Dipole °°°°° Shear Y-Dipole 15 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope 55 55-- -- Summary Summary Summary Summary • Sonic Scanner data was acquired in the Qugruk#5A well over the 8.5” section in standard mode to include monopole compression and cross dipole data. • Data was reprocessed at PTS – Alaska to obtain more accurate formation slowness. • Compressional and Shear slowness were obtained using optimized processing parameters and Multishot technique to improve vertical resolution. Quality-control was based on slowness-time-coherence (STC), slowness-frequency-analysis (SFA) and dispersion analysis. • Overall the quality of the acquired raw data is good across the entire run and resulted in good quality Monopole compression and shear slowness as well as dipole shear slowness. • DLIS, LAS and graphic files are provided that reflect the processing mentioned above. 66 66-- -- Recommendations Recommendations Recommendations Recommendations • A good Stoneley slowness curve is indicated through the entire well bore. A stoneley fracture analysis may indicate fractured areas within the wellbore. • Anisotropy processing is recommended due to variations in the X and Y shear dipole dispersion curves. 16 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Appendix A Appendix A Appendix A Appendix A -- --Advanced Sonic Scanner Advanced Sonic Scanner Advanced Sonic Scanner Advanced Sonic Scanner Processing Processing Processing Processing Anisotropy Analysis Anisotropy by definition is a variation of a physical property depending on the direction in which it is measured. Anisotropy involves directional variation at one point as opposed to heterogeneity, which involves variation from point to point. Both anisotropy and heterogeneity are matters of scale, and so their usage relates to the wavelengths involved. Transverse isotropic <TI> media are anisotropy in that they exhibit the same property value when measured within a plane but a different value when measured perpendicular to the plane. We can classify TI anisotropy into two categories, Transverse Isotropic Vertical <TIV>, and Transverse Isotropic Horizontal <TIH> (see Fig A). In the presence of anisotropy, the shear wave splits into a fast and a slow shear. Anisotropy as measured by the borehole acoustic tool is in the plane perpendicular to the tool axis. In a vertical well, with sub-horizontal layers, the shear anisotropy indicates differences in the horizontal stresses or the presence of fractures. In a high angle or horizontal well, we will expect to see anisotropy even in the non-fractured intervals or in the absence of horizontal stress differences due to the difference between vertical and horizontal stresses. The natural layering of the earth generally causes TIV anisotropy. Velocities that will vary from those measured vertically to those measured horizontally characterize it. Usually the vertical velocity is slower than the horizontal velocity. While anisotropy is always a matter of scale, for our purposes shales, being more laminar, tend to be high TIV materials whereas sands and carbonates tend to be low TIV materials. TIH anisotropy usually has two possible origins. First, it can be caused by vertical parallel fractures, and second by stress imbalances. Figure A Figure A Figure A Figure A: Formation Anisotropy Classification S min Stress Shales, Bedding - TIV Fractures - TIH V s () V s ()V s (r, ) Intrinsic Stress-Induced Intrinsic S max S min Stress Shales, Bedding - TIV Fractures - TIH V s () V s ()V s (r, ) Intrinsic Stress-Induced Intrinsic S max 17 Sonic Scanner Advisor Report March-24-2014 Qugruk# 5A North Slope Fracture Evaluation from Stoneley Evaluation of permeable fractures is important in oil and gas exploration especially in basement complexes where production is mostly through fractures. Sonic measurements have an advantage of showing open permeable fractures; which are most important for evaluating productivity in basement reservoirs. Stoneley transmission and reflection analyses are standard techniques for sonic fracture evaluation. Borehole effects (hole enlargement and lithology changes) are some limitations to quantitative fracture evaluation. The Stoneley locates open fractures through analysis of energy losses and reflections back into the borehole. Note that Stoneley indicated “fractures” might have many different geological interpretations; the reader is hereby warned that similar conditions exist with other geologic events, such as karstic features, which looks to the Stoneley exactly like a fracture. Thus the term fracture, when used with Stoneley interpretation, will mean any sudden, short interval, of high permeability in a tight formation. In this case the Stoneley wave is affected in two ways. First the Stoneley wave will lose energy by actually moving fluid in the open fracture. Second the fracture will act as a secondary source and generate reflections back into the borehole seen as chevron patterns. It must be emphasized that the energy loss is an actual evidence of flow movement into and out of the formation and is our primary identifier of open fractures or permeable zones. Company: Repsol Well: Qugruk 5A Field North Slope State: Alaska Country: USA Date: March 2014 Schlumberger Data and Consulting Services 2525 Gambell Street Suite 400 Anchorage, Alaska 99503 Geomechanical Study of Qugruk 5A Jason Burt CONFIDENTIAL DATA TRANSMITTAL PER AS A 38.05.180(C)(8) Standard Disclaimer ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION FURNISHED WITH THE SERVICES OR OTHERWISE COMMUNICATED BY SCHLUMBERGER TO CUSTOMER AT ANY TIME IN CONNECTION WITH THE SERVICES ARE OPINIONS BASED ON INFERENCES FROM MEASURMENTS, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS, WHICH INFERENCES, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONSARE NOT INFALLIBLE, AND WITH RESPECT TO WHICH PROFESSIONALS IN THE INDUSTRY MAY DIFFER, ACCORDINGLY, SCHLUMBERGER CANNOT AND DOES NOT WARRANT THE ACCURACY, CORRECTNESS OR COMPLETENESS OF ANYS SUCH INTERPRETATION, RESEARCH ANALYSIS, DATA, RESULTS, ESTIMATES OR RECOMMENDATION. CUSTOMER ACKNOWLEDGES THAT IT IS ACCEPTING THE SERVICES “AS IS”, THAT SCHLUMBERGER MAKES NO REPRESENTATION OR WARRANTY, EXPRE SS OR IMPLIED, OF ANY KIND OR DESCRIPTION IN RESPECT THERETO. SPECIFICALLY, CUSTOMER ACKNOWLEDGES THAT SCHLUMBERGER DOES NOT WARRANT THAT ANY INTERRPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION IS FIT FOR A PARTICULAR PURPOSE, INCLUDING BUT NOT LIMITED TO COMPLIANCE WITH ANY GOVERNMENT REQUEST OR REGULATORY REQUIREMENT. CUSTOMER FURTHER ACKNOWLEDGES THAT SUCH SERVICES ARE DELIVERED WITH THE EXPLICIT UNDERSTANDING AND AGREEMENT THAT ANY ACTION TAKEN BASED ON THE SERVICES RECEIVED SHALL BE AT ITS OWN RISK AND RESPONSIBLILITY AND NO CLAIM SHALL BE MADE AGAINST SCHLUMBERGER AS A CONSEQUENCE THEROF. Qugruk 5A MEM 3 Table of Contents 1. INTRODUCTION......................................................................................................... 5 1.1 SCOPE OF WORK ........................................................................................................ 5 2. DATA CATALOGUE AND DATA PROCESSING ................................................. 6 2.1 AVAILABLE DATA ...................................................................................................... 6 2.2 DATA PROCESSING ..................................................................................................... 6 3. MECHANICAL EARTH MODEL ............................................................................. 8 THE STEPS USED TO GENERATE THE MINIMUM HORIZONTAL STRESS FOR QUGRUK 5A ... 8 3.1 STRATIGRAPHY MODEL ............................................................................................. 8 3.1.1 Methods used in facies discrimination ............................................................... 9 3.2 ELASTIC PROPERTIES MODEL .................................................................................... 9 3.2.1 Dynamic Properties ......................................................................................... 10 3.2.2 Static Young Modulus ...................................................................................... 10 3.2.3 Static Poisson Ratio ......................................................................................... 10 3.2.4 Biot Elastic Constant ....................................................................................... 11 3.2.5 Results View ..................................................................................................... 11 3.3 OVERBURDEN STRESS .............................................................................................. 12 3.3.1 Borehole Information ....................................................................................... 12 3.3.2 Overburden Stress Qugruk 5A ......................................................................... 12 3.3.3 Composite Density ........................................................................................... 12 3.3.4 Results View ..................................................................................................... 13 3.4 PORE PRESSURE ....................................................................................................... 14 3.4.1 Well Qugruk 5A................................................................................................ 14 3.4.2 Results View ..................................................................................................... 14 3.5 HORIZONTAL STRESSES............................................................................................ 15 3.5.1 Results View ..................................................................................................... 16 4. CONCLUSIONS ......................................................................................................... 17 APPENDIX A – STONEFISH MEM OUTPUT DATA .............................................. 18 Qugruk 5A MEM 4 Table of Figures Figure 1: Open hole data for the Qugruk 5A well .......................................................................................... 7 Figure 2: MEM Flow Chart ............................................................................................................................ 8 Figure 3: Mechanical Stratigraphy of the Qugruk 5A .................................................................................... 9 Figure 4: Elastic Property plot for Qugruk 5A ..............................................................................................11 Figure 5: Overburden Plot for Qugruk 5A ....................................................................................................13 Figure 6: Pore Pressure Plot for Qugruk 5A ..................................................................................................14 Figure 7: Minimum Horizontal Stress Results for Qugruk 5A between 7100 -7900 ft MD ...........................16 Qugruk 5A MEM 5 1. Introduction This work was initiated in order to devise mechanical earth model to calculate minimum horizontal stress, Young’s modulus, and Poisson’s ratio for an optimized fracture design. 1.1 Scope of Work This geomechanical analysis included the following steps: 1. Acquire all available open hole, survey, and drilling data from the Qugruk 5A well. 2. Perform QC to insure the data is on depth and looks reasonable for the region and environment where it was acquired. 3. Perform a petrophysical analysis of the Q5A well 4. Preform a geomechanical analysis to generate the necessary rock strength data. 5. Generate report and graphics. This document describes the work outlined above. Qugruk 5A MEM 6 2. Data Catalogue and Data Processing 2.1 Available Data Available data included open hole well logs acquired in the Qugruk 5A well Input Logs: Qugruk 5A Name Measurements Comments GR Gamma Ray Measured Gamma Ray RHOZ Density Measured Bulk Density PHIE Porosity Effective Porosity from CMR PHIT Porosity Total Porosity from CMR DTCO Acoustic Slowness Measured compressional travel time DTSM Acoustic slowness Calculated shear slowness using VPVS and DTCO VSH Standard Volume Ratio Calculated shale volume from ECS 2.2 Data Processing Open hole data from the Qugruk 5A well was examined to identify selected properties including Compressional Slowness, Shear Slowness, density (RHOZ), total porosity (PHIT), effective porosity (PHIE), and shale volume (VSH). Qugruk 5A MEM 7 Figure 1: Open hole data for the Qugruk 5A well Qugruk 5A MEM 8 3. Mechanical Earth Model The steps used to generate the Minimum Horizontal Stress for Qugruk 5A Figure 2: MEM Flow Chart 3.1 Stratigraphy Model The stratigraphy model documents the properties of the formation between the formation tops. It is important to quantify the lithology, porosity, and elastic properties of the different layers. Of particular interest is a description that differentiates between layers of different mechanical properties. The mechanical behavior of rock is often sensitive to whether sedimentary grains or clay minerals constitute the dominant load-bearing-solid Qugruk 5A MEM 9 phase in a given layer. To facilitate modeling over large distances, categorize sediments into grain support and clay support facies. 3.1.1 Methods used in facies discrimination Sand/Shale discrimination was done using the VSH results from the petrophysical analysis. Grain supported rock was identified if the VSH was less than 35% with clay supported rock occurring if VSH was greater than 35%. Figure 3: Mechanical Stratigraphy of the Qugruk 5A 3.2 Elastic Properties Model Elastic properties are a function of acoustic (sonic) and density values of the material . Initially dynamic properties were computed which were then converted to static values. The reason for this conversion is that the elastic properties derived from sonic data is affected by the frequency of the sound waves used to make these measurements (dynamic properties). These dynamic properties are converted to static properties to match those Qugruk 5A MEM 10 obtained in typical laboratory analysis (static properties that are not frequency dependent). The static properties are then used for rock stress and strength calculations. 3.2.1 Dynamic Properties Dynamic elastic properties were calculated using the sonic (compressional and shear) and density well log data. The elastic properties included Young’s Modulus and Poisson’s Ratio. Input Logs Calculation Array Name Comments Dynamic elastic properties1 DTCO Compressional DT DTSM Shear DT RHOZ Density Methodology Calculation Zone Method Dynamic elastic properties All Sonic Model Results Calculation Name Comments Dynamic elastic properties E_dyn Young’s Modulus Pr_dyn Poisson’s ratio 3.2.2 Static Young Modulus The Modified Morales Correlation was used to convert from dynamic Young’s Modulus. Input Logs Calculation Array Name Comments Static Young's modulus E_dyn PHIT_D Total Porosity Methodology Calculation Zone Method Static Young's modulus All Modified Morales Correlation Results Calculation Name Comments Static Young's modulus E_sta 3.2.3 Static Poisson Ratio Static Poisson’s Ratio, was assumed to be the same as the dynamic Poisson’s Ratio. Qugruk 5A MEM 11 3.2.4 Biot Elastic Constant Biot Elastic Constant α was calculated using the Krief Porosity Correlation. Input Logs Calculation Array Name Comments Biot elastic constant1 PHIT Total Porosity Methodology Calculation Zone Method Biot elastic constant1 All Krief Porosity Correlation Results Calculation Name Comments Biot elastic constant1 ALPH 3.2.5 Results View Figure 4: Elastic Property plot for Qugruk 5A Qugruk 5A MEM 12 3.3 Overburden Stress Overburden stress is determined by using the measured bulk density across the logged interval and extrapolating this measurement to surface. 3.3.1 Borehole Information The following parameters were used to account for the overburden stress caused by th e depth of water above the mud line or ground level Name Value Unit Air Gap 35 ft Water Depth 0 ft Water Density 1.03 g/cm3 3.3.2 Overburden Stress Qugruk 5A Input Logs Calculation Array Name Comments Methodology Calculation Method Overburden stress from density Extrapolate Density Results Calculation Name Comments Overburden stress from density RBCP 3.3.3 Composite Density Composite Density Calculation Start(TVD:ft) Stop(TVD:ft) Density Overburden stress from density 35 2220 RBCP 2220 6917 RHOZ Results Calculation Name Comments Overburden stress from density1 OBmw RBCP_Comp SigV Overburden Stress Qugruk 5A MEM 13 3.3.4 Results View Figure 5: Overburden Plot for Qugruk 5A Qugruk 5A MEM 14 3.4 Pore Pressure Pore pressure gradient calculated assuming a water density of 1.03 g/cc and a pore pressure gradient of 0.435 psi/ft. This gradient was used to correlate to the Qugruk #1 well where MDT pressure points were taken. 3.4.1 Well Qugruk 5A Input Logs Calculation Array Name Comments Methodology Calculation Method Log input1 Constant Pressure Gradient Input Results Calculation Name Comments Log input1 PPmw Pore Pressure Gradient PPRS Pore Pressure 3.4.2 Results View Figure 6: Pore Pressure Plot for Qugruk 5A Qugruk 5A MEM 15 3.5 Horizontal Stresses The minimum horizontal stress was calculated using the Poro-Elastic Horizontal Strain Model. Input Logs Calculation Array Name Comments Min. horizontal stress1 ALPH Biot’s elastic constant E_sta Young’s Modulus PPRS Pore Pressure Pr_sta Poisson’s Ratio SigV Overburden Stress Methodology Calculation Zone Method Min. horizontal stress1 All Poro-Elastic Horizontal Strain Model Interval Parameters Calculatio n Zone Facies Start (MD:ft) Stop (MD:ft) Parameter 1 Parameter 2 Min. horizontal stress1 Zone1 Sand_1 Ex (10-3) Ey (10-3) 7100 7900 0.2 0.8 Results Calculation Name Comments Min. horizontal stress1 Sigh Qugruk 5A MEM 16 3.5.1 Results View Figure 7: Minimum Horizontal Stress Results for Qugruk 5A between 7100-7900 ft MD Qugruk 5A MEM 17 4. Conclusions Mechanical earth model was created using sonic compression and shear, porosity, effective porosity, density, and shale volume. The mechanical earth model was built to solve for static Young’s modulus, Static Poisson’s ratio, overburden pressure, and minimum horizontal stress. Minimal errors in were introduced into the equations from the petrophysical calculation due to the use of the porosity and effective porosity from the CMR and the shale volume from the ECS. Qugruk 5A MEM 18 Appendix A – StoneFish MEM output data Name Description E_sta Static Young's Modulus Pr_sta Static Poisson's Ratio SigV Vertical Stress Sigh Total Minimum Horizontal Stress REPSOL EXPLORATION NORTH AMERICA MUDLOGGING DATA FINAL WELL REPORT FOR Qugruk 5A 2013 – 2014 Alaska Campaign North Slope Borough Alaska, USA Provided by: Approved by: Alejandro Martin Compiled by: Greg Hammond James Foradas D y l a n M u l l e r Mike Franco Distribution: 5/16/2014 T.D. Date: 3/20/2014 Qugruk 5A 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ...............................................................................................2 1.1 Equipment Summary....................................................................................................................2 1.2 Mudlogging Crew ........................................................................................................................2 2 WELL DETAILS .................................................................................................................................3 2.1 Well Summary.............................................................................................................................3 2.2 Hole Data ...................................................................................................................................3 2.3 Well Synopsis .............................................................................................................................4 3 GEOLOGICAL DATA .........................................................................................................................4 3.1 Lithostratigraphy .........................................................................................................................4 3.2 Mudlog Summary ........................................................................................................................5 3.3 Formation Gas Peaks Summary .................................................................................................16 3.4 Connection Gases .....................................................................................................................16 3.5 Trip (Wiper) Gases ...................................................................................................................16 3.6 Sampling Program / Sample Dispatch .........................................................................................17 4 PRESSURE / FORMATION STRENGTH DATA ..................................................................................18 4.1 Pore Pressure Gradient Evaluation .............................................................................................18 4.2 Quantitative Methods .................................................................................................................19 5 DRILLING DATA ..............................................................................................................................20 5.1 Daily Activity Summary ..............................................................................................................20 5.2 Survey Data..............................................................................................................................29 5.3 Bit Record ................................................................................................................................32 5.4 Mud Record Contractor: Halliburton/Baroid..................................................................................33 5.5 Isotube Record .........................................................................................................................36 5.6 Ditch Magnet Record .................................................................................................................39 6 DAILY REPORTS ............................................................................................................................40 Enclosures: 2”/100’ Master Log MD/TVD 2”/100’ Engineering Log Depth MD 2”/ 30 min. Engineering Log (time -based) 2”/100’ Gas Log MD 2”/100’ Pressure Log MD/TVD 5”/100’ Show Log MD Final Well Data on CD/ROM Qugruk 5A 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Total Downtime Comments Ditch gas QGM Agitator and Gas Trap (mounted in opossum belly) E-Series Total Gas and Chromatography by flame ionization (FID) 0* Block Height/Bit depth Crown block encoder 0* Hook Load / Weight on bit RigWatch 0* Mud Flow In Derived from Pump Rates and Pump Output 0* Mud Flow Out Fluid level radar sensor on flow line 0* Mudlogging unit computer system HP Compaq Pentium 4 (x3 : DML, Rigwatch, and Sample Catcher station) 0* Pit Volumes, Pit Gain/Loss Fluid level radar sensors atop mud pits 0* Pump Pressure Pressure transducer 0* Pump stroke counters Proximity sensors 0* Rate of penetration Derived from bit depth vs. time 0* RPM Top drive sensor 0* Torque Top drive sensor 0* * RigWatch data lost for less than 5 minutes each day while RigWatch resets 1.2 Mudlogging Crew Crew Unit Type : Arctic Unit Number : ML032 Mudloggers Years *1 Days *2 Sample Catchers Years *1 Days *2 Technicians Days Greg Hammond 4 18 Fred Spiers 1 8 Howard Lamp 1 Jim Foradas 7 3/11 Jim Adams 1 3/11 Jim Adams 1 3/14 Larry Turner 17 9 Mike Franco 7 4 Justin Boutte 4 7 Omar Hinostroza 7 10 Dylan Muller 3 3/20 *1 Years experience as Mudlogger *2 Days at wellsite between sidetrack kick off and rig down Qugruk 5A 3 2 WELL DETAILS 2.1 Well Summary The Qugruk 5A well was drilled as an appraisal well intended to test the Nuiqsut sand s. It was drilled as a sidetrack from the surface casing shoe of the plugged Qugruk 5 wellbore. Well: Qugruk 5A API Index #: 50-103-20682-01-00 Field: North Slope Surface Co-Ordinates: 2,138 FWL, 1,381 FSL SEC. 24, T12N, R6E Borough: North Slope Primary Target Depth: Nuiqsut 200: 7,628’ MD / 6,700’TVD State: Alaska Total Depth: 8,015’MD/ 7,009’TVD Rig Name / Type: Nabors Alaska Drilling 105AC / Arctic Land Rig Suspension Date: 4/23/2014 Primary Target: Nuiqsut 200 License: 214-032 Spud Date: 3/11/2014 Ground Elevation: 11’ AMSL Completion Date: 4/21/2014 Ice Pad Elevation 15’ AMSL Completion Status: (plugged and abandoned) RT Elevation: 35’ AMSL Classification: Appraisal Secondary Target Depth Kuparuk C: 7,074’MD / 6,254’TVD TD Formation: Base Nuiqsut TD Date: 3/20/2014 Days Drilling: 7 Days Testing: 27 2.2 Hole Data Maximum Depth Shoe Dept h Hole Section MD (ft) TVD (ft) TD Formation Mud Weight (ppg) Dev. (oinc) Casing/ Liner MD (ft) TVD (ft) LOT/ FIT (ppg) Conductor 103 103 N/A N/A 0 20” N/A N/A N/A 12.25” 2325 2325 Lower Schrader Bluff 10.3 0.64 9 5/8” 2305 2305 FIT 13.6 8.5” 8015 7009 Base Nuiqsut 10.6 36.5 7” 7992 6991 Qugruk 5A 4 2.3 Well Synopsis The original Qugruk 5 appraisal well was drilled targeting the Nuiqsut 200 and Kuparuk C sands. The well was designed to evaluate reservoir thickness, petrophysical properties, permeability, and fluid properties and to prove continuity with the Qugruk 1 well drilled in 2013. Qugruk 5 was spudded on February 1, 2014. The surface section was drilled to 2,325’ MD on February 3 with casing set at 2305’ MD. Four cores were drilled from 6,895’ MD to 7102’ MD. Total depth of 7,340’ MD/7,164’ TVD was reached on February 25. The well encountered 160’ of gross reservoir thickness at a depth of 6,970’ MD in the Nuiqsut 200 sand. Wireline logs were unable to reach bottom and LWD tools were run on drill pipe for evaluation. The well was plugged back to the surface casing shoe in preparation for the Qugruk 5A sidetrack on March 11. In preparation for the Qugruk 5A sidetrack, the water-based mud was displaced with mineral oil-based mud . Cement was tagged on March 14 at 2136’ and new formation was drilled at 2342’. Total depth of 8,015’ MD/7,009’ TVD was reached on March 20. After wireline logging, 7” casing was set at 7992’ on March 24 in preparation for testing. The well was plugged to surface on April 22, 2014. 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops are field tops that were picked based on cuttings and LWD. Prognosed Depth (ft) Actual Depth (ft) Zone or Horizon MD TVD TVDSS MD TVD TVDSS Base Permafrost / Schrader Bluff 1,390 1,390 -1,355 1,390 1,390 -1,355 Schrader Bluff OA Sand (W Sak – COP) 1,515 1,515 -1,480 1,515 1,515 -1,480 MCU / Lower Schrader Bluff 2,268 2,268 -2,233 2,268 2,268 -2,233 Lower Schrader Bluff MFS 2,446 2,446 -2,411 2,436 2,436 -2,401 Tuluvak 2,644 2,642 -2,607 2,650 2,647 -2,612 Nanushuk 4,173 3,935 -3,900 4,122 3,891 -3,856 Torok 6,344 5,671 -5,636 6,339 5,664 -5,629 HRZ Shale 6,666 5,929 -5,894 6,659 5,920 -5,885 Base HRZ / Pebble Shale 6,913 6,126 -6,091 6,887 6,104 -6,069 Kuparuk C 7,089 6,267 -6,232 7,074 6,254 -6,219 LCU / Kingak Shale 7,102 6,277 -6,242 7,088 6,265 -6,230 Alpine 7,275 6,655 -6,620 7,507 6,602 -6,567 UJU / Kingak Seismic Marker - - - - - - Nuiqsut 200 7,706 6,760 -6,725 7,628 6,700 -6,665 Nuiqsut 100 7,862 6,885 -6,850 7,804 6,840 -6,805 Base Nuiqsut - - - 7,911 6,927 -6,892 Total Depth - - - 8,015 7,010 -6,975 Qugruk 5A 5 3.2 Mudlog Summary Upper Schrader Bluff (Surface 130’ MD to 1,515’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 257.7 1.8 96.2 72 0 7.2 This section is comprised mainly of sandy gravels, and sands, with some sandy siltstones. The base of the Permafrost within this formation was reached at 1,390’ MD. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 1340’ 61 11240 - - - - - - Individual sample descriptions are as follows: Sand/gravel: white, medium to dark gray with fine to medium with coarser fragments 4 to 8 mm. poorly sorted; subangular to angular to rounded; moderate to high sphericity; 75% opaque white quartz, 30% medium to dark gray lithic fragments 5% pale olive to light brown fragments. fining downward. Some pyrite, muscovite biotite and light green grains observed. Sand/gravel: medium to dark gray, white; fine to medium grain with coarse fragments 4 to 8 mm. poorly sorted; subangular to angular to rounded; moderate to high sphericity; 40% opaque white quartz, 50% medium to dark gray lithic fragments 10% pale olive to light brown, light green, and chert grains. At approximately 730' coal and wood fragments from 700' to 760' fines downward. Sand/gravel: medium to dark gray, white; fine to medium grain with coarse fragments 3 to 6 mm. poorly sorted; subangular to angular to rounded; moderate to high sphericity; 40% opaque white quartz, 50% medium to dark gray lithic fragments 10% pale olive to light brown, light green, and chert grains. Sand/gravel: medium to dark gray, white; fine to medium grain with coarse fragments 3 to 9 mm. poorly sorted; subangular to angular to rounded; moderate to high sphericity; 40% opaque white quartz, 50% medium to dark gray lithic fragments 10% light brown, grayish brown, olive brown, pale yellowish orange, grayish pink, and chert grains. Coal pieces at 880'. Sand/gravel: white, medium to dark gray; fine to medium grain with coarse fragments 2 to 6 mm. mod sorted; subangular to rounded. moderate to high sphericity; 60% opaque white quartz, 30% medium to dark gray lithic fragments 10% light brown, olive brown, light green grains , wood fragments at 940'. Sand/gravel: white, medium to dark gray; fine to medium grain with coarse fragments 2to6 mm. mo d sorted; subangular to rounded, moderate to high sphericity; 60% medium dark gray lithic fragments, 30% opaque white quartz. 10% light brown, olive brown, light green grains, wood and vegetation fragments. Sand/gravel: white to dark gray with salt pepper appearance; fine to very coarse grained grading to fine gravels averaging 3 to 5mm in diameter; moderately sorted; subrounded to rounded; low to moderate sphericity; composed of 50% medium to dark gray lithic fragments, 40% opaque white and translucent gray quartz, 10% light green and light brown lithics; trace organic materials; trace pyrite frosting surfaces of dark gray lithic grains; trace chert ironstone and chert in places. Qugruk 5A 6 Schrader Bluff OA Sand (W Sak – COP) (1,515’ MD to 2,268 MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 160.3 8.8 78.2 24 2 14.3 This section is comprised mainly of sands and sandy gravels. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 1515’ 16.5 3040 - - - - - - Individual sample descriptions are as follows: Gravel/sand: medium to dark gray with light gray hues; predominantly fine gravel (2 to15mm) and fine to coarse sand; fair to moderately sorted; subangular to rounded; low to high sphericity; some granules tabular; common grinding and polish on grain surfaces; composition of approximately 60% medium to dark gray lithics, 30% white to light gray quartz; common green lithics; trace to common reddish brown lithics; trace sandstone gravels; trace pyrite grains in sand . Sand/gravel: medium to dark gray with olive hues, salt pepper appearance; lower fine to upper medium grain sand; gravels 2 to12mm in diameter; fair to well sorted; subangular to rounded; low to moderate sphericity; composed of roughly equal parts of medium to dark gray lithic fragments and quartz occurring in opaque white, light gray and clear translucent varieties; traces of greenish and reddish brown lithics, also some sandstone clasts in gravels. Sand/gravel: light to dark gray, opaque white, some olive, brown, light green grains, gravel 2 to 8mm, subangular to well rounded, moderately sorted, some clay, shell fragments 1390' to 2020'. 40% to 50% light gray to dark gray lithics, 40% to 50% opaque white quartz sand very fine to coarse, subangular to well rounded, subangular to well rounded, mod sorted, 50% light to dark gray lithics, 50% opaque white quartz, traces of green and red brown lithics, trace chert, shell fragments, some pyritization on dark gray grains. 60% to 80% gravel. coarsening downward Gravels dropping to less than 10% below 1720' MD. Composition as above. MCU/Lower Schrader Bluff (2,268’ to 2,436’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 135.1 0.9 37.3 15 0 7.4 This formation was found to be primarily composed of clayey and tuffaceous siltstones and sandy gravels in the section drilled with water-based mud as part of the original Qugruk 5 wellbore. The portion drilled below 2325’ with mineral oil-based mud as part of the Qugruk 5A wellbore was found to be shaly, indicating significant gravel/sand caving and clay swelling during the original surface section. Qugruk 5A 7 Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 2268’ 15.9 2733 - - - - - - Individual sample descriptions are as follows: Gravel: light to dark gray, opaque white, some olive, brown, light green clasts, 4 to 7 mm, subangular to rounded moderately sorted, some clay, shell 2230' to 2260'. 80% light gray to dark gray lithics, 10%-20% opaque white quartz, trace sand, some clay, traces of green and olive brown clasts. 2260' and 2290' trace whitish gray tuff, soft to fragile, slightly calcareous, irregular shape, silty to clayey. Shale: medium dark gray; firm; blocky; dull luster; silty to gritty texture; massive structure. Lower Schrader Bluff MFS (2,436’ to 2,650’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 153.5 1.8 84.7 35 9 19.8 The Lower Schrader Bluff Formation from is comprised of shale with some siltstone and tuff. Formation Gas Peaks Depth TG C1 C2 C3 C4i C4n C5i C5n 2620’ 36 5738 20 13 11 11 17 7 Individual sample descriptions are as follows: Shale 80 to 90%: medium to dark gray, non calcareous, sub fissile to sub blocky irregular fracture, moderately firm to firm, silty to gritty texture, dull luster, trace carbonaceous specks, massive to platy structure, tabular to elongated cuttings habit. Tuff 0%-30%: white to off white, irregular to sub blocky, moderately firm, well indurated, massive habit, waxy to dull luster, massive structure. Siltstone 10%: whitish to light gray, moderately to well indurated, siliceous cement, trace carbonaceous specs, trace argillaceous. Shale 90%: medium to dark gray, non calcareous, sub fissile to sub blocky irregular fracture, moderately firm to firm, silty gritty texture, dull luster, trace carbonaceous specks, massive to platy structure, tabular to elongated cuttings habit. Tuff 0%-10%: white to off white, irregular to sub blocky, moderately firm, well indurated, massive habit, waxy to dull luster, massive structure. Siltstone 10%: whitish to light gray, moderately to well indurated, siliceous cement, trace carbonaceous specs, trace argillaceous. Shale 90 to 100%: medium to dark gray, non calcareous, sub fissile to sub blocky, irregular fracture, moderately firm to firm, silty gritty texture, dull luster, trace carbonaceous specks, massive to platy structure, tabular to elongated cuttings habit. Siltstone 0 to 10%: whitish gray to light gray, moderately to well indurated, siliceous cement, trace carbonaceous specks, trace argillaceous. 100%: Shale at 2680'. Tuluvak (2,650’ to 4,122’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 298.8 2.9 138.9 140 2 39.2 Qugruk 5A 8 This interval of the Tuluvak Formation is comprised of siltstone and shale with some tuff. Formation Gas Peaks Depth TG C1 C2 C3 C4i C4n C5i C5n 2877’ 59 9824 68 40 4 9 6 5 3070’ 108 18206 253 59 21 24 14 11 3109’ 140 23808 377 107 31 42 14 8 3368’ 59 8720 184 80 15 15 8 8 Individual sample descriptions are as follows: Shale 60%: medium to light gray, non calcareous, moderately firm to firm, irregular to sub blocky, earthy to dull luster, trace to very silty, grades to argillaceous siltstone. Siltstone 40%: light to medium gray, non to slightly calcareous, slightly to moderately argillaceous throughout. Grades to silty shale. Traces of black specks in micro laminations. Patchy yellow fluorescence with a yellowish white milky cut. Shale 50%: medium to light gray, non-calcareous, moderately firm to firm, irregular to sub blocky, earthy to dull luster, trace to very silty, grades to argillaceous siltstone. Siltstone 50%: light to medium gray, non to slightly calcareous, slightly to moderately argillaceous throughout. Grades to silty Shale. Traces of black specks in micro laminations. Patchy yellow fluorescence with a yellowish white milky cut. Slight mineral grain fluorescence. Siltstone 75%: dark gray, soft to crumbly moderately indurated, silty to gritty texture, dull luster. Shale 25%: medium to dark gray, firm to brittle, blocky fracture, dull luster, silty, moderately argillaceous throughout. Siltstone 80%: light gray to medium gray, firm to brittle, platy cutting habit, sub blocky fracture, smooth to silty texture, non to slightly calcareous, trace of tuff. Shale 20%: medium gray to dark gray, brittle to splintery facture, flaky to platy cutting habit, dull luster, smooth texture, slightly calcareous. Siltstone 75%: light gray to medium gray, soft to crumbly, moderately indurated, irregular cuttings habit, gritty to silty texture, dull luster. Shale 25%: medium gray to dark gray, slightly to moderately argillaceous throughout, irregular to sub blocky, earthly dull luster. Siltstone 80%: light gray to dark gray, soft to crumbly, moderately indurated, massive to platy cutting habit, granular to silty texture, earthy luster. Shale 20%: light gray to medium gray, firm and stiff, poorly indurated, platy cutting habit. Siltstone 80%: olive gray to light gray, soft to friable, no induration, dense to brittle tenacity, earthy to dull luster, trace of tuff. Shale 25%: medium to dark gray, firm to brittle, blocky fracture, dull luster, silty grading to moderately argillaceous throughout. Siltstone 80%: light gray to dark gray, soft to crumbly, moderately indurated, massive to platy cutting habit, granular to silty texture, earthy luster. Shale 20%: light gray to medium gray, firm and stiff, poorly indurated, platy cutting s habit. Shale 20% to 40%: medium to light gray, non-calcareous, moderately firm to firm, irregular to sub blocky, earthy to dull luster, trace to very silty, grades to argillaceous. Siltstone 80% to 50%: light to medium gray, non to slightly calcareous, slightly to moderately argillaceous throughout; grades to silty Shale. Traces of black specks in micro laminations. T uff 10%: at 4060'. White to light gray, non to very slightly calcareous, irregular fracture, soft to moderately indurated, silty in part, waxy. Patchy yellow fluorescence with a milky cut. Qugruk 5A 9 Nanushuk (4,122’ to 6,339’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 289.3 10.3 122.8 200 7 55.8 The interval of the Nanushuk formation is comprised of shale and siltstone with occasional tuff. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 4232’ 201 33581 1275 476 62 130 36 23 4478’ 158 26689 1106 387 45 102 26 23 4596’ 200 32947 1573 526 69 130 30 29 4656’ 151 27957 1364 489 58 120 30 33 5257’ 64 11184 432 263 54 82 43 33 5361’ 73 11457 446 200 32 80 26 17 5446’ 36 5954 231 93 22 33 22 17 5473’ 31 4604 190 81 23 31 7 10 6135’ 61 10069 384 135 17 34 2 10 6148’ 49 7970 301 107 14 28 2 9 Individual sample descriptions as follows: Shale 20% to 40%: medium to light gray, non calcareous, moderately firm to firm, irregular to sub blocky, earthy to dull luster, trace to very silty, grades to argillaceous. Siltstone 80%-50%: light to medium gray, non to slightly calcareous, slightly to moderately argillaceous throughout , grades to silty Shale. Traces of black specks in micro laminations. T uff 10%: at 4060'. White to light gray, non to very slightly calcareous, irregular fracture, soft to moderately indurated, silty in part, waxy. Patchy yellow fluorescence with milky cut. Shale 30%: medium to light gray, non-calcareous, moderately firm to firm, irregular-sub blocky, earthy to dull luster, trace to very silty, grades to argillaceous. siltstone 60%: to 70%: light to medium gray, non to slightly calcareous slightly to moderately argillaceous throughout grades to silty shale. Traces of black specks in micro laminations . Tuff 10%: at 4210'. white to light gray, non to very slightly calcareous, irregular, soft to moderately indurated, silty in part, waxy. Patchy yellow fluorescence with a milky cut. Shale 30%: medium to light gray, non-calcareous, moderately firm to firm, irregular -sub blocky, earthy to dull luster, trace to very silty, grades to argillaceous siltstone 70%: light to medium gray, non to slightly calcareous silty to moderately Argillaceous throughout grades to silty shale. Traces of black specks in micro laminations. Patchy yellow fluorescence with a milky cut. Siltstone 80%: light gray to dark gray, soft to crumbly, moderate indurated, massive platy cutting habit, granular to silty texture, earthy luster. Yellowish fluorescence trace with white. Shale 20%: light gray to medium gray, firm and stiff poor induration, with a platy habit. Siltstone 75%:dark gray, soft to crumbly moderately indurated ir regular, silty to gritty texture, dull luster. Shale 25%: medium to dark gray, firm to brittle, blocky fracture, dull luster silty grade moderately argillaceous throughout. Siltstone 80%: medium gray to dark gray, soft to crumbly hardness, sub-blocky to blocky, dull to earthy luster, non to slightly calcareous, gritty light trace sand, trace of tuff. Shale 20%: light gray to medium gray firm to stiff poor induration; platy. Scattered dull yellowish fluorescence. Qugruk 5A 10 Siltstone 85%: medium gray to dark gray soft to crumbly hardness, sub -blocky to blocky, dull to earthy luster, non to slightly calcareous, gritty light trace of sand, trace of tuff. Shale 15%: light gray to medium gray firm to stiff poor induration platy. Scattered dull yellowish fluorescence. Siltstone 70%: medium to olive gray, firm to crumbly hardness, dull to earthy luster, silty grade moderately argillaceous, smooth texture, thinly bedded with siltstone. Shale 15%: light gray, slightly calcareous, silty to moderately argillaceous throughout, black specks in micro laminations. Patchy yellow fluorescence. Tuff 15%: white to light gray, soft to firm, smooth texture, dull luster, thinly bedded with siltstone. Siltstone 75%: dark gray, soft to crumbly moderately indurated irregular, silty to gritty texture, dull luster. Shale 25%: medium to dark gray, firm to brittle, blocky fracture, dull luster, silty grade moderately argillaceous throughout. Shale 100%: medium to dark gray, non to slightly calcareous, moderately firm to brittle, sub blocky to blocky fracture, slightly to very silty in parts, massive cuttings habit; earthy to dull luster, trace siltstone. Shale 100%: medium to dark gray, non to slightly calcareous, moderately to firm to brittle, sub blocky to blocky fracture, slightly to very silty in parts, massive cuttings habit; earthy to dull luster, trace siltstone; trace sand. Shale 90%: medium to dark gray, non to slightly calcareous, moderately firm to brittle, sub blocky to blocky fracture, slightly to very silty in parts, massive cuttings habit; earthy to dull luster, trace siltstone 90%: at 5470', white to light gray, trace bk. lithic fragments, grades to very fine sand, friable to moderately indurated, non- calcareous; trace tuff. Shale 100%: medium to dark gray, non to slightly calcareous, moderately firm to brittle, sub blocky to blocky fracture, slightly to very silty in parts, massive cuttings habit; earthy to dull luster, trace siltstone. Shale 100%: medium to dark gray, non to slightly calcareous, moderately firm to brittle, sub blocky to blocky fracture, slightly to very silty in parts, massive cuttings habit; earthy to dull luster, trace siltstone; trace pyrite at 5620'. Shale 100%: medium to dark gray, non to slightly calcareous, moderately firm to brittle, sub blocky to blocky fracture, slightly to very silty in parts, massive cuttings habit; earthy to dull luster, trace siltstone. Shale 100%: medium to dark gray, non to slightly calcareous, moderately firm to brittle, sub blocky to blocky fracture, slightly to very silty in parts, massive cuttings habit; earthy to waxy luster, trace siltstone; trace sand. Shale 100%: olive gray to dark gray, moderately firm to brittle, slightly calcareous, slightly to very silty, sub - blocky to earthy fracture, earthy to waxy luster, platy cuttings habit, trace of sand. Shale 100%: olive gray to dark gray, moderately firm to brittle, slightly calcareous, slightly to very silty, sub - blocky to earthy fracture, earthy to waxy luster, platy cuttings habit, trace siltstone. Torok (6,339’ to 6,659’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 185.5 24.6 114.5 37 10 20.5 The interval of the Torok formation is comprised of shale and rare siltstone. Qugruk 5A 11 Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 6354’ 36 5763 193 89 19 24 8 8 Individual sample descriptions are as follows: Shale 100%: olive gray to dark gray, moderately firm to brittle, slightly calcareous, slightly to very silty, sub - blocky to earthy fracture, earthy to waxy luster, platy cuttings habit, trace siltstone; mud additive nut plug. Shale 100%: olive gray to dark gray, moderately firm to brittle, slightly calcareous, slightly to very silty, sub - blocky to earthy fracture, earthy to waxy luster, platy cuttings habit, trace siltstone; Shale 90%: medium to dark gray, non to slightly calcareous, moderately firm-brittle, sub blocky-blocky fracture, slightly to very silty in parts, platy cuttings habit, earthy -dull luster, trace of clean Siltstone 10%: white-light gray, trace black fragments, friable to moderately indurated. Shale 100%: medium to dark gray, moderately firm to brittle, slightly calcareous, slightly to very silty, sub - blocky to earthy fracture, earthy to waxy luster, platy cuttings habit. Shale 100%: medium to dark gray, moderately firm to brittle, slightly calcareous, slightly to very silty, sub - blocky to earthy fracture, earthy to waxy luster, platy cuttings habit; carbonaceous. HRZ Shale (6,659’ to 6,887’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 205.4 32.1 125.3 63 4 40.6 The short interval of the HRZ Shale is comprised of shale. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 6749’ 53 9133 224 62 8 15 18 3 Individual sample descriptions are as follows: Shale 100%: medium to dark gray, moderately firm to brittle, slightly calcareous, slightly to very silty, sub - blocky to earthy fracture, earthy to waxy luster, platy cuttings habit. Shale 100%: light to dark gray, non to slightly calcareous, firm-brittle, well indurated sub fissile to sub blocky fracture; trace to moderately silty in parts, massive cuttings habit; earthy to dull luster. Pebble Shale/Base HRZ (6,887’ to 7,074’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 260.7 4.5 124.7 48 8 27.3 The section of the Pebble shale formation consists shale with trace sandstone. Qugruk 5A 12 Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 - - - - - - - - - Individual sample descript ions are as follows: Shale 100%: light to dark gray, non to slightly calcareous, firm-brittle, well indurated sub fissile to sub blocky fracture; trace to moderately silty in parts, massive cuttings habit; earthy to dull luster. Trace tuff at 6940' MD. Shale 100%: light to dark gray, non to slightly calcareous, firm-brittle, well indurated sub fissile to sub blocky fracture; trace to moderately silty in parts, massive cuttings habit; earthy to dull luster. Trace tuff; trace quartz sand at 7000' MD. Shale 100%: light to dark gray, non to slightly calcareous, firm-brittle, well indurated sub fissile to sub blocky fracture; trace to moderately silty in parts, massive cuttings habit; earthy to dull luster. Trace light brown sandstone with calcareous cement. Kuparuk C (7,074’ to 7,088’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 142.9 57.5 110.0 16 14 16.4 The interval of the Kuparuk C sand formation was the secondary target zone of the original Qugruk 5 well. It was observed as 10% sandstone in a sample that was otherwise shale. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 - - - - - - - - - Individual sample descriptions are as follows: Shale 90%. Sandstone 10%: dark gray-grayish black, non-calcareous, silty to v. fine grained, loose and unconsolidated quartz grains w. trace consolidated friable fragments, rounded-sub rounded, poor visible porosity, patchy dull yellow fluorescence; slow residual milky cut. LCU/Kingak Shale (7,088’ to 7,507’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 190.9 14.1 111.6 28 8 22.3 The interval of the LCU/Kingak shale formation consists of shale with trace sand/sandstone. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 - - - - - - - - - Individual sample descriptions are as follows: Qugruk 5A 13 Shale 90%: light -dark gray, non-calcareous firm-brittle, well indurated, sub fissile to sub blocky, trace- moderately silty, earthy to dull luster. Sandstone 10%: dark gray-grayish black, non-calcareous, silty to v. fine grained, loose and unconsolidated quartz grains w. trace consolidated friable fragments, rounded-sub rounded, poor visible porosity, patchy dull yellow fluorescence; slow residual milky cut. Shale 100%: light to dark gray, non to slightly calcareous, firm-brittle, well indurated sub fissile to sub blocky fracture; trace to moderately silty in parts, massive cuttings habit; earthy to dull luster. Shale 100%: light to dark gray, non to slightly calcareous, firm-brittle, well indurated sub fissile to sub blocky fracture; trace to moderately silty in parts, massive cuttings habit; earthy to dull luster. Trace sand at 7260' MD. Shale 100%: light to dark gray, non to slightly calcareous, firm-brittle, well indurated sub fissile to sub blocky fracture; trace to moderately silty in parts, massive cuttings habit; earthy to dull luster. Shale 100%: medium to dark gray, medium brown, non calcareous, brittle-crumbly; moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. Trace sand at 7300'-7320'. Shale 100%: medium to dark gray, medium brown, non calcareous, brittle-crumbly; moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. Trace sand. Shale 100%: medium to dark gray, medium brown, non calcareous, brittle-crumbly; moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. Trace pyrite. Shale 100%: medium to dark gray, medium brown, non calcareous, brittle-crumbly; moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. Alpine (7,507 to 7,628’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 161.6 15.3 102.6 28 17 21.6 The Alpine formation was primarily shale with trace sand. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 - - - - - - - - - Individual sample descriptions are as follows: Shale 100%: medium to dark gray, medium brown, non calcareous, brittle-crumbly; moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. trace gray sandstone with calcareous cement . Trace pyrite, trace glauconite, trace sand at 7550' MD. Shale 100%: medium to dark gray, medium brown, non calcareous, brittle to crumbly, moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy -dull luster. Trace light brown sandstone w. calcareous cement. Trace pyrite; trace glauconite, trace light brown sandstone 10%: medium to dark gray, quartz fine to very fine, well sorted, round to sub round , high sphericity at 7570' & 7580' MD. Qugruk 5A 14 Nuiqsut 200 (7,628’ to 7,804’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 165.2 40.3 99.1 77 22 41.3 This interval of the Nuiqsut 200 formation is the primary zone of interest in this well. This section is composed of shale, trace sandstone/sand, and trace tuff. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 7677’ 73 13030 324 274 63 76 26 9 Individual sample descriptions are as follows: Shale 100%: medium to dark gray, medium brown non calcareous, brittle to crumbly, moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. Trace light brown sandstone with calcareous cement. Trace pyrite, trace glauconite, trace sand to 7610' MD. Shale 100%: medium to dark gray, medium brown non calcareous, brittle to crumbly, moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. Trace light brown sandstone with calcareous cement. Trace pyrite. Shale 100%: medium to dark gray, medium brown non calcareous, brittle to crumbly, moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. Trace light brown sandstone with calcareous cement. Shale 100%: medium to dark gray, medium brown non calcareous, brittle to crumbly, moderately indurated, sub fissile to sub blocky, moderately silty, massive cuttings habit, earthy to dull luster. Trace light brown sandstone with calcareous cement. Trace pyrite. Trace tuff at 7740' to 7450' MD. Trace sand, trace sandstone. Moderately yellow, milky white cut. Nuiqsut 100 (7,804’ to 7,911’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 179.0 27.6 106.3 34 20 29.0 This interval of the Nuiqsut 100 formation is composed of shale. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 - - - - - - - - - Individual sample descriptions are as follows: Shale 100%: medium brown to dark yellowish brown; scattered light olive gray; dense crumbly to brittle; irregular to blocky fracture; wedgelike to blocky to curved cuttings; common PDC bit cut; dull to earthy luster; matte to sucrosic text ure; massive structure wit h rare yellow ish brown calcareous microlamina; moderately to weakly calcareous; partly disintegrates upon application of HCL; occasional very calcareous tuff fragments; rare silty fragments with fine to very fine glauconite; scattered well indurated dark gray Shale fragments; trace well rounded medium quartz sand; patchy to even dull to moderate whitish yellow fluorescence; moderate milky white cut; faint gold residual fluorescence; faint straw residual cut. Qugruk 5A 15 Base Nuiqsut (7,911’ to 8,015’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 215.1 27.1 99.9 36 12 29.2 This interval of the Base Nuiqsut formation is composed of shale. Formation Gas Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 - - - - - - - - - Individual sample descriptions are as follows: Shale 100%: dark brownish gray to dark yellowish brown; scattered light olive gray; dense crumbly to brittle; irregular to blocky fracture; wedgelike to blocky to curved cuttings; abundant PDC bit cut; dull to earthy luster; matte to sucrosic texture; occasional silty texture; massive structure; rare light olive gray tuff fragments; weakly to non calcareous ; patchy to even dull whitish yellow fluorescence; moderate milky cut; no residual cut. Qugruk 5A 16 3.3 Formation Gas Peaks Summary Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 2620’ 36 5738 20 13 11 11 17 7 2877’ 59 9824 68 40 4 9 6 5 3070’ 108 18206 253 59 21 24 14 11 3109’ 140 23808 377 107 31 42 14 8 3368’ 59 8720 184 80 15 15 8 8 4232’ 201 33581 1275 476 62 130 36 23 4478’ 158 26689 1106 387 45 102 26 23 4596’ 200 32947 1573 526 69 130 30 29 4656’ 151 27957 1364 489 58 120 30 33 5257’ 64 11184 432 263 54 82 43 33 5361’ 73 11457 446 200 32 80 26 17 5446’ 36 5954 231 93 22 33 22 17 5473’ 31 4604 190 81 23 31 7 10 6135’ 61 10069 384 135 17 34 2 10 6148’ 49 7970 301 107 14 28 2 9 6354’ 36 5763 193 89 19 24 8 8 6749’ 53 9133 224 62 8 15 18 3 7677’ 73 13030 324 274 63 76 26 9 3.4 Connection Gases . MD (ft) TVD (ft) Date (YYYY/MM/DD) Time (HH:MM) Connection Gas (units) Average Background Gas (units) 2861 2850 20140317 2:26 13 38 6135 5500 20140319 6:07 11 50 3.5 Trip (Wiper) Gases MD (ft) TVD (ft) Trip to (ft MD) Downtime (hours) Date (YYYY/MM/DD) Time (HH:MM) Max Gas (units) Average Background Gas (units) 4018 3808 4020 3.6 20140318 1:06 42 14 8015 7009 8015 6.5 20140321 7:55 37 20 8015 7009 8003’ 7.0 20140323 20:31 97 12 8015 7009 8003’ 19.01 20140324 9:32 94 27 1 unit = 0.05% Methane Equivalent Qugruk 5A 17 3.6 Sampling Program / Sample Dispatch Washed and spun dried samples are contained within plastic Petrocraft® vials, and wet samples are in plastic Whi rlpak® bags. Set Type / Purpose Frequency Interval Dispatched to 1 Dried and Wet Cuttings Samples Set owner: REPSOL E&P USA Inc. 30’ 10’ 30’ 10’ 30’ 2320’ – 7060’ 7060’ – 7120’ 7120’ – 7240’ 7240’ – 7840’ 7840’ – 8015’ CGG Services US Inc. Attn: Jennifer Koerth (979) 562-2782 3311 South US Hwy 77 PO Box 295 Schulenberg, Texas 78956 2 Wet Cuttings Samples Set owner: REPSOL PALEO N/A PALEO samples taken in surface section as part of original Qugruk 5 well; not taken while drilling Qugruk 5A N/A 3 Dried Cuttings Samples Set owner: AOGCC 30’ 10’ 30’ 10’ 30’ 2320’ – 7060’ 7060’ – 7120’ 7120’ – 7240’ 7240’ – 7840’ 7840’ – 8015’ AOGCC Attn: Howard Okland (907) 793-1235 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 4 Geochemical samples in IsoJars® Set owner: REPSOL E&P USA Inc. 90’ 2320’ – 8015’ CGG Services US Inc. Attn: Jennifer Koerth (979) 562-2782 3311 South US Hwy 77 PO Box 295 Schulenberg, Texas 78956 5 Gas samples in IsoTubes® Set owner: REPSOL E&P USA Inc. 90’ and at selected gas peaks 2320’ – 8015’ CGG Services US Inc. Attn: Jennifer Koerth (979) 562-2782 3311 South US Hwy 77 PO Box 295 Schulenberg, Texas 78956 6 Mud sample in IsoJars® Set owner: REPSOL E&P USA Inc. Section beginning/end and at mud property changes 2320’ – 8015’ CGG Services US Inc. Attn: Jennifer Koerth (979) 562-2782 3311 South US Hwy 77 PO Box 295 Schulenberg, Texas 78956 Qugruk 5A 18 4 PRESSURE / FORMATION STRENGTH DATA 4.1 Pore Pressure Gradient Evaluation Interval Tops Pore Pressure (EMW) Formation Interval Primary Lithology (%) Secondary Lithology (%) MD (ft) TVD (ft) TVDSS (ft) Min (ppg) Max (ppg) Trend Trend Indicators Base Permafrost / Schrader Bluff Cs Sd 1,390 1,390 -1,355 9.8 10.3 - (No ECD data) Schrader Bluff OA Sand (W Sak-COP) Sd Cs 1,515 1,515 -1,480 10.2 10.3 Decreasing (No ECD data before 2154’) MCU / Lower Schrader Bluff Cs Sh 2,268 2,268 -2,233 10.2 10.4 Even ECD Lower Schrader Bluff MFS Sh Sltst 2,436 2,436 -2,401 10.4 10.45 Slight increase ECD, BG Tuluvak Sltst Sh 2,650 2,647 -2,612 10.45 10.45 Even ECD Nanushuk Sh Sltst 4,122 3,891 -3,856 10.35 10.6 Even ECD, BG Torok Sh Sltst 6,339 5,664 -5,629 10.5 10.6 Increase ECD HRZ Shale Sh 6,659 5,920 -5,885 10.5 10.65 Even ECD Base HRZ / Pebble Shale Sh 6,887 6,104 -6,069 10.6 10.65 Even ECD, BG Kuparuk C Sh Sndst 7,074 6,254 -6,219 10.6 10.6 Even ECD, BG LCU / Kingak Shale Sh 7,088 6,265 -6,230 10.6 10.65 Even ECD, BG Alpine Sh 7,507 6,602 -6,567 10.6 10.65 Even ECD, BG Nuiqsut 200 Sh 7,628 6,700 -6,665 10.6 10.6 Even ECD, BG Nuiqsut 100 Sh 7,804 6,840 -6,805 10.6 10.6 Even ECD, BG Base Nuiqsut Sh 7,911 6,927 -6,892 10.6 10.6 Even ECD, BG NOTE: Sd = Sand, Clst = Claystone/Clay, Sltst = Siltstone, Sndst = Sandstone , Sh = Shale, Cs Conglomerat ic Sand, Cg = Conglomerate Qugruk 5A 19 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Predicted pore pressure trends provided by Repsol. As a reference, PPG is calculated initially with a formula provided by Canrig, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD – (0.6-((.001*TLGSU)+(0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiat ed from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when estimating trends, as with DXC data, with data points in shale intervals. Qugruk 5A 20 5 DRILLING DATA 5.1 Daily Activity Summary 3/12/2014 Commence Qugruk 5A at 09:30. Pick up sidetrack directional BHA; trip in to 2067'; cut 100' drill line; continue to clean mud system. Max Gas last 24hrs 0u = 0.00%. Approximately 1.0 ounce of material collected from ditch magnet. 3/13/2014 Continue to clean pits for change over to mineral based mud system. No Max Gas for last 24 hours. No material collected from ditch magnet, due to no flow over shakers last 24 hours. 3/14/2014 Continue to clean out pits; change to mineral based mud system; RIH; tag cement at 2130’; begin drilling cement from 2130’ to 2172’; continue to drill cement. Max Gas last 24hrs 0u = 0.00%. Approximately, 0.0 ounces of material collected from ditch magnet. 3/15/2014 Rotary drilling cement from 2172’ to 2260’ staging up to 20K WOB. L/D single for and P/U 5" PUP for space out. Continue to drill cement to 2329’. CBU at 2329’; B/D top Drive and R/U Wire Line for Gyro Run to orient motor; POOH with wireline; RIH with wireline to verify orientation of toolface; TOOH with wireline; R/D wireline; L/D 5” pup P/U single; Slide/Time Drill at 1.5’/Hr from 2330’ to 2369’; Commenced rotary drilling to 2430’; CBU @ 2430' TOOH B/D top Drive and monitor well; Laying down BHA at time of report. Max Gas last 24hrs 8u = 0.16%. Approximately, 120.0 ounces of material collected from ditch magnet which DD attributed to be likely due to mill bit orientation in relation to casing during rotary drilling of cement above casing shoe at 2305’. 3/16/2014 Continue TOOH; B/D Top Drive and monitor well; POOH L/D BHA stand back both stands of collars and L/D BHA; clean up rig floor and prep for P/U BHA; P/U BHA PJSM for M/U BHA; M/U BHA; P/U bit and X/O to floor and P/U BHA. Test Power Drive; PJSM to load Source; Load Source; P/U BHA; TIH to 2179'; Fill pipe; shallow test of MWD tools; B/D Top Drive; install/remove wear bushing; P/U test tools M/U test plug to string and set plug; Test BOPs change upper pipe ram door seal; test annular to 250 low 3500 high for 5 min. test rig gas alarms: test witnessed by AOGCC Rep. Jeff Turkington; Upper Ram failure; pull/rebuild Rams; Testing BOPs at time of report. Max Gas last 24hrs 0u = 0.00%. Approximately, 18.5 ounces of material collected from ditch magnet, likely due to mill bit orient ation (as yesterday). 3/17/2014 Continued testing BOPs; tests witnessed by AOGGC Representatives Jeff Turkington and Johnnie Hill; bottom pipe rams failed;; conducted Koomey Test; waited on verification for ram rubber; C/O rubbers on lower rams; test lower pipe rams; install/remove wear bushing; remove test joint, P/U single, M/U to test plug, L/D test plug, P/U wear bushing running tool, set wear ring, L/D single/running tool; CBU at 2183'; TIH from 2183' to 2400’; wash down from 2400 to 2430’; set parameters per DD; commence rotary drilling from 2430’; rotary drilling at time of report. Max Gas last 24hrs 51u = 1.02%. Approximately, 10.5 ounces of material collected from ditch magnet. 3/18/2014 Rotary drilling from 2935’ to 3249'; BOP drill, driller simulated flow check and shutting in well; rotary drilling continued to 3874'; downtime -mud pump (MP) install new dresser sleeve rubbers on #1 MP suction line; continued drilling to 4018’ C&C; CBU @ 4005'; send downlink to zero tool; monitor well 10 min., hole static; pump dry job, B/.D top drive; TOOH from 4018' to 2285' on elevators; service rig, C/O valve and seat on # 2 MP; service ST-80; monitor hole on trip tank; TIH on elevators from 2285' to 4018'; commence drilling from 4018'; drilling at time of report. Max Gas last 24hrs 137u = 2.74%. Approximately, 15.9 ounces of material collected from ditch magnet. Qugruk 5A 21 3/19/2014 Continued rotary drilling from 4181' to 5943’; reaming one stand between 5860’ and 5943’ at time of report. Max Gas last 24hrs 201u = 4.02%. Approximately, 5.2 ounces of material collected from ditch magnet. 3/20/2014 CBU at 5943’; Rotary drilling from 5943’ to 6440'; change/replace pump expendables C/O swab and liner on MP #2; circulated at 6440'. SPR after working on mud pump, MP #1; rotary drilling from 6440' to 7390'; Circulated at 7390'. SPR after working on mud pump, MP #1; rotary drilling from 7390' to 7407’; drilling at time of report. Max Gas last 24hrs 63u = 1.26%. Approximately, 3.7 ounces of material collected from dit ch magnet. 3/21/2014 Rotary drilling from 7407’ to 7636’; change/replace pump expendables, C/O 2 swabs on MP #1, Circulate on MP #2; rotary drilling from 7636’ to TD at 8015' MD; CBU; Pump Dry Job; TOOH 8015 to 6563’ on elevators; backreaming from 6563' to 6467'; TOOH from 6467' to 3731’ on elevators; B/D top Drive; TOOH to 2390’; service rig while monitoring well to make sure well is static; CBU at 2380’; TIH from 2380’; TIH at time of report. Max Gas last 24hrs 73u = 1.46%. Approximately, 1.5 ounces of material collected from ditch magnet. 3/22/2014 TIH from 2380’ to 6234’; C&C fill pipe at 6234; B/D top drive, continue TIH to 7970; C&C wash down to 8015’; C&C monitor well and pump dry job; B/D top drive; TOOH to 5271’; TOOH to 2173’ on elevators; mo nitor hole for 15mins., hole static; continue TOOH to 1031’ on elevators; R/B HWDP; PJSM for unloading radioactive sources; L/D sources and BHA; clean and service rig; conduct derrick inspection; monitor hole with trip tank; R/U wireline for Open Hole Log Run 1A, test tools; RIH on Open Hole Log Run 1A at time of report. Max Gas last 24hrs 37u = 0.74%. Approximately, 2.0 ounces of material collected from ditch magnet. 3/23/2014 RIH on Open Hole Log Run 1A to 8000’, log out to shoe, remove nuclear sources; L/D Run 1A tools; P/U Open Hole Log Run 2 tools, load nuclear source; RIH with Open Hole Log Run 2 to 5600’. Make repairs to suction valve pit 5; Continue Open Hole Log Run 1B clean suction manifold on mud pump MP#1, general housekeeping/preventive maint enance; L/D tools and nuclear source from Run 1B. R/D wireline loggers; L/D collars and jars; L/D 2 stands of HWDP into pipe shed and preparing to change our rams at time of report. Max Gas last 24hrs 0u = 0.00%. Approximately, 0.5 ounces of material collected from ditch magnet. 3/24/2014 R/B 5 stands of HWDP. L/D 6 joints collars and float sub; drain stack, function rams, flush stack; close blind rams; PJSM, C/O upper 4" to 7" fixed rams; I/R wear bushing, pull wear ring, set test plug; R/U to test BOPs; test BOPs; R/D testing equipment; B/D choke and kill lines; R/U to run casing, PJSM with GBR; run casing to 2200', CBU, fill pipe every 10 joints; RIH from 2200' to 4241', fill pipe every 20 joints; C&C at 3998', C/O GBR HPU due to mechanical issues; RIH to 4800', CBU, fill pipe; running casing at 5410’ time of report. Max Gas last 24hrs 97u = 1.94%. Approximately, 0.3 ounces of material collected from ditch magnet. 3/25/2014 Run 7" casing to 6550' filling pipe every 20 joints; C&C fill pipe/CBU at 5637'; run 7" casing to 7475', filling every 5 joints; C&C; run casing to 7841', W/D to 8003' C&C; P/U cement head; R/U/D to run casing M/U hangar/landing joint, drain stack, land hangar; break circulation; R/D CRT; install cement lines, M/U cement head, break circulation; PT cement lines; PJSM for cement job; PT cement lines, pump spacer, drop plug; C&C/D; pump tail cement, drop top plug, displace with mud; set plug, open diverter; C&C; L/D casing tools; service rig; load 102 jnts TC2 3.5" tubing in shed, remove thread protectors. P/U M/U Johnny Wacker to X-over; second cementing operation in progress at report time. Max Gas last 24hrs 94u = 1.88%. Shakers cleaned during cementing, no material collected from ditch magnet. 3/26/2014 Complete cementing, bleed pressure; check flowback; R/D cementers L/D landing joint; C/O elevators; clean cellar box; P/U 1 joint DP and wash tool, casing head and clean stack; L/D wash tool; P/U packoff/running tool; set packoff; RILDS; PT pack off; L/D casing equipment Qugruk 5A 22 and stabbing board; change rams, set test plug. C/O top and bottom rams to VBRs. C/O bails; continue processing 3 1/2" tubing; offload 470 bbls of MOBM from pits; begin cleaning pits; R/D MWD sensors; P/U test tools; R/U to test BOP’s; test BOP’s, AOGCC John Crisp waived the right to witness; R/D from BOP tests; L/D test joint; TIH R/U GBR casing tongs/elevators and crummies in preparation to RIH 3.5" cement stinger string. RIH 3.5” cement stinger string at time of report. Max Gas last 24hrs 0u = 0.00%. No material collected from ditch magnet. 3/27/2014 RIH to 1291' TOOH L/D39 joints of 3 1/2 tubing, R/D L/D tubing equipment; clean and clear rig floor and pipe shed; P/U BHA; P/U L/D, M/U tools, BHA, bit and scrapers; RIH with 7 stands HWDP and 21 stands DP to 2777' top of DV tool at 2807' Rotate same on depth according to pipe tally; drill plugs, CBU; rotate/work string mill thru DV collar; W/D and ream to 3064'; B/D top drive; TIH with tubing/DP to 6804' breaking circ at 6414'; B/D top drive and C&C at 6804' B/D top drive, TIH with tubing to 7844'; tag fill, ream W/D to 7855'; C&C L/D top single in stand; CBU at 7845'; cleanout/test R/U test chart, cement hose, valves to test 7" to 4000psi for 30mins on chart; R/D and B/D kill/cement lines; TOOH from 7845' to 7499’; L/D 11 singles from string; TOOH to 5971’; RIH to 7855'; C&C at time of report in prep to displace mud; Max Gas last 24hrs 0u = 0.00%. Approximately 2oz material collected from ditch magnet, derived from polishing. 3/28/2014 Complete C&C; CBU; PJSM on displacement; displace to completion fluid offloading MOBM returns from pit 4, clean out mud system, flow box, pipe rack, shaker beds and flow trough, displace to completion fluid pump 50bbls spacer and 314bbls completion brine at 7851'. B/D top drive, clean out trip tank for swap to completion fluid; get protectors on floor buggy; completion-trip tubing/DP from 7851' to 1589’, continue flushing all lines in pits, offload dirty H2O to vac trucks; clean mud pits 1-6; finish completion trip; L/D completion BHA and cleaning drill floor at time of report. Max Gas last 24hrs 0u = 0.00%. Approximately, 8.3 ounces of material collected from ditch magnets. 3/29/2014 L/D completion BHA; R/U to run 3 ½” tubing; R/U to run casing; waiting on 3rd party tools, GBR tubing torque turn computer; P/U and test torque turn equipment; RIH w/ 12 joints of 3 ½” tubing to 2395’; shut down to inspect pipe skate and C/O hydraulic fittings on casing power unit; load sample carriers in pipe shed; continue to P/U completion tubing from 2395’ to 6782’; POOH with 3 ½” tubing from 6782’ to 2798’; racking back stands in derrick, up WT to 65K / down WT to 60K at 4501’. Max Gas last 24hrs 0u = 0.00%. Approximately, 7.5 ounces of material collected from ditch magnets. 3/30/2014 Comp lete POOH 3 ½” tubing trip; prepare to test sample carrier bbls; BHA ready pipe shed to P/U carriers; C/O elevators; P/U 1st carrier; M/U bull plug and X/Os; P/U single joint DP and M/U X/Os; torque all CXNs to spec; R/U test equipment; completion- formation testing sample carrier to 500psi for 5 minutes, 5000psi, for 15 minutes; P/U, L/D make up tools, BHA open rams; R/D test hose; drain assembly; break out single joint and L/D same; remove testing plug; L/D 1st and P/U 2nd carrier; install test plug; R/U to test equipment; test 2nd sample carrier to same specs; R/U to run wireline; test tools to surface; RIH for cased hole logs with CMT bond log assembly to 7885’; POOH and R/D wireline; P/U 575’ of 3 ½” tubing; torque turn to optimum make up torque of 2500 ft/lbs; C&C pump volume plus annular volume at 575’ W/ 10.4 brine; clean pill pit and trip tank; POOH from 575’ to surface; cut drill line; prepare to remove pipe / tool shed. Max Gas last 24hrs 0u = 0.00%. Approximately, 4.0 ounces of material collected from ditch magnets. 3/31/2014 Demobilize pipe shed sections 3-6 in preparation for coil tubing unit; R/U heaters onto skate section of pipe shed; R/U skate controls and lighting in pipe shed; R/U to test BOPs; test BOPs; LD test tool Koomey test; pull test plug and R/D test equipment; B/D choke manifold and all lines; wait on 3rd party tools; conduct rig service/maintenance; assist Metro w/ working Qugruk 5A 23 on tools in pipe shed. Max Gas last 24hrs 0u = 0.00%. Approximately, 2.5 ounces of material collected from ditch magnets. 4/01/2014 Continue to wait on 3rd party tools (tubing handing equipment); assisting Metrol w/ pipe shed; P/U perforation guns; M/U time delay firing head and bull nose; pull mouse hole in preparation to M/U packer; load pipe shed with handling equipment; install 2 7/8” elevators; RIH w/ 2 7/8” tubing; P/U packer using single of 3 ½” tubing; M/U tools and BHA; TIH with tubing from 1213’ to 4734’ w/ 3 ½” tubing torque turn to 2300 ft/lb; filling tubing on fly w/ 10.4 brine; installing Metrol relays as required; testing tubing to 4000 psi for 5 minutes at 1718’, 2693’, 3762’, and 4734’; WT up 50K, dn WT 50K at 1718’, up WT 54K dn WT 54K at 2693’; continue to RIH w/ tubing and pressure test. Max Gas last 24hrs 0u = 0.00%. Approximately, 3.0 ounces of material collected from ditch magnets. 4/02/2014 Continue to RIH with 2 7/8” tubing from 4734’ to 7620’, while pressure testing tubing to 4000 psi for 5 minutes at 5704’, 6664’, and 7620’; P/U space out joints and RIH to 7683’, up WT 82K, dn WT 75K; R/U to run wire line; RIH w/ wire line to RA sub at 6683’; POOH; R/D wire line; pull tubing to 7678’; R/U wire line; RIH w/ wire line to 6681’; POOH w/ slick line / wire line from 6681’ and R/D; configure tally and spacer out to set packer/tubing hanger; M/U hanger and L/J; set packer; set dn 20K compression on packer at 7560’ / RA sub at 6681’ and land hanger; run in to lock dn screws and test hanger seal to 5000 psi for 10 minutes; liner clean out; R/U to test annulus w/ PT line s to 4500 psi, and test to 1100 psi and hold for 15 minutes; stage up to 4000 psi for 10 minutes; secure well set BPV w/ Vetco rep.; L/D 3rd party tools and tubing handling equipment. Max Gas last 24hrs 0u = 0.00%. Approximately, 1.5 ounces of material collected from ditch magnets. 4/03/2014 Nipple dn BOPs; pull riser, un-chain stack; R/D Koomey hoses; nipple dn choke and kill lines; nipple dn annular and mud cross; prepare cellar and wellhead clean and clear of tools and equipment; NU/ND completion tree; clean tubing hanger; N/U frac tree, swab, and master valve assembly; test bonnet to 5000 psi for 10 minutes; test master and 2nd master to 7500 psi and hold for 10 minutes; Halliburton and XPRO M/U hard lines to cellar; M/U hard line to tree and annulus; M/U riser from goat head to coil tubing on rig floor; H/U HCR kill Koomey lines to hydraulic master valve and function test. Max Gas last 24hrs 0u = 0.00%. Approximately, 1.0 ounces of material collected from ditch magnets. 4/04/2014 Complete function testing Koomey lines to hydraulic master valve; fill lines and PT EXPRO lines to 3000 psi; fill PT cementers lines to annulus valve to 2500 psi; PT all other lines and body test on coil tubing BOPE to 6900 psi; pressure up annulus to 2700 psi to function LPR-N / OMNI valves; pressure up to 2200 psi for 6 minutes, observed guns fire at 0530; testing perform DFIT w/ 15 bbls LVT; C/O charge pump; ready equipment for R/U injector head; P/U coil lubricator and M/U to BOP; nipple up/dn BOPs, well head R/U injector head to lubricator on rig floor; H/U hose to coil tbg BOPs and R/U drain hoses from injector head; fluid pack lines for testing; testing finalize frac model; PJSM on frac job; PT lines and begin frac job; shut in well and moni tor for 15 minutes; B/D and clear lines; open and bleed back; prepare R/U and test BOPs. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/05/2014 Test BOPs (body test) 250 low, 3500 high for 15 minutes; R/D frac line off goats head; R/U cement line to wing valve; cycle OMNI and LPR-N valves; test CT blinds and pipe rams 250 low, 3500 high for 15 minutes; test whiteness waved by AOGCC Rep; CT blow dn coil to EXPRO; walk thru w/ EXPRO on equipment and ESDs; PJSM on open up LPR-N and flow well; attempt to open LPR-N; begin RIH w/ CT; attempt to function LPR-N/OMNI valves down hole; attempt to open OMNI valve while pumping Nitrogen; not successful in functioning valve; displace tubing w/ 10.4 MW brine. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. Qugruk 5A 24 4/06/2014 R/U lines from mud pits to coil tubing unit and continue to displace w/ 10.4 ppg brine; R/U Nitrogen to blow dn coil tubing unit; POOH coil tubing; complete operations on charge pump and discharge line; prepare to R/D coil tubing unit; conduct PJSM on nipple up/dn BOPs, well head to R/D coil tubing; remove injector head; pull lubricator and set back on coil tubing; set CT BOPs safely to side and secure on rig floor; wait on 3rd party personnel prep for wire line, on rig floor and set up to pump dn tubing, take returns from annulus to pits; PJSM on wire line operations; M/U X/O from flange to OTTIS cxn; R/U wire line lubricator; R/U to test lubricat or against master valve and fill lubricator; test/chart lubricator to 3500 psi; RIH 2.8” drift run. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/07/2014 RIH 2.8” drift run, tag up at 6746’; POOH; R/D drift, R/U to 2” drift; RIH and tag up at 6873’; blow dn kill line; R/U one shot slick line tool, RIH; stage tool at 6686’ slickline measurement, 6628’ tubing (TBG) tally measurement; downhole power unit with TBG punch engaged after time delay; POOH and R/D TBG punch; R/U 2nd TBG punch run; R/U one shot slick line tool and RIH; stage tool at 6685’ slickline measurement, 6627’ TBG tally measurement; downhole power unit with TBG punch engaged after time delay; POOH; R/U slickline DPU/TBG punch; C/O mud system, take on 12.4 ppg brine; offload 10.4 ppg brine; clean pits to make room for displacement volume; R/U kill line to mud cross for circulating dn TBG; attempt to circulate 12.4 ppg dn TBG and up annulus; pressure up to 2000 psi w/ minimal returns; R/U wireline TO for 2.80 drift run; PT lubricator to 3500 psi; RIH w/ 500 psi on TBG to 6881’ tagged up on previous shots, work wireline w/ no restrictions, POOH; M/U single shoot, PT lubricator and RIH at 100’/min, hold 1000 psi on TBG at punch point at 6625’ lined up to monitor returns from annulus; no psi drop after punch time; POOH with wireline; R/D wireline; R/U to pump dn annulus and attempt to open OMNI valve; pressure up to 2625 psi and monitor TBG psi; TBG and annulus stabilized at 2450 psi; OMNI valve still closed; R/U to circulate 12.4 ppg TBG and up annulus to pits; start at 1 bbl/min w/ 2900 psi, as psi dropped, work pump up to 2.5 bbl/min w/ 1200 psi; continue to displace 10.4 w/ 12.4 ppg brine; 40 spm at 1150 psi; blow dn lines after displacement; VETCO set BPV, R/U to test BPV from annulus; test/chart back pressure valve for 5 minutes at 300 psi; bown dn pump lines; nipple up/dn BOPs; nipple dn1 riser, tree. Max Gas last 24hrs 0u = 0.00%. Approximately, 0.5 ounces of material collected from ditch magnets. 4/08/2014 N/D frac tree; install BOP cart; R/U hydraulic ram to cart; fold up Herculite from frac job; R/D H.P. lines from annulus; N/U BOPs; install single gate/mud cross; retract cattle chute to allow room for crane pick; set double gate/annular onto BOP trolley; set cattle chute back; safe out cellar area; N/U double gate/annular; N/U BOPs, choke hose/kill hose; M/U Koomey lines; test gas alarms/PVT system; clean out flow box, set riser, PT X-Pro lines from choke manifold to 3000 psi w/ little red; P/U test tools, PJSM w/ Vetco rep for setting test JT; R/U to test BOPs; fill stack and choke manifold w/ water. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/09/2014 Test BOPs annular 250 psi low, 3500 psi high, remaining tests at 250/5000 psi low/high; L/D test tool lines, choke manifold and top drive; retrieve test dart; POOH back pressure valve; R/U landing joint/TIW valve; PJSM for pulling hanger; back out lockdown screws; unseat tbg hanger/string, open ports on packer; shut annular; bleed off downhole pressure to EXPRO through choke manifold; pump 0.5 bbl/min OD, 12.4 ppg w/, R/D tbg and return to EXPRO through choke manifold; circulate 11.5 ppg at 1 bbl/min w/ 500 psi; stage up to 4 bbl/min w/ 1400 psi; up wt 70K; unseat packer; P/U 105K and hold to unseat, verity unseating and continue to circulate b/u at 2 bbl/min w/ 400 psi; B/D top drive and pull hanger, up WT 90K; monitor well. Max Gas last 24hrs 219u = 4.38% @ 16:18. Approximately, 0.5 ounces of material collected from ditch magnets. 4/10/2014 Continue to monitor well, circulate at 31 spm, 490 psi, 85K U/W, 70K D/W; L/D hanger and pup jnt; blow dn top drive; shut annular/choke manifold, well flowing, monitor casing pressure, Qugruk 5A 25 02:30hrs at 140 psi, 03:30, 04:30, and 05:30hrs at 150 psi; 06:30, and 07:30hrs at 160 psi; 08:30hrs at 160 psi; bleed off to EXPRO through choke manifold, open annular; set packer, 85K U/W, 65K D/W; circulate and condition (C&C) 31 spm at 400 psi; circulate 11.1 ppg dn tbg taking returns to mud pits at 2 bbl/min w/ 285 psi; circulate at 2 bbl/min w/ 375 psi, cutting weight back to 10.7 ppg while running centrifuge, w/ 10.7 ppg all around, final circulation 3 bbl/min735 psi; B/D top drive; P/U to open ports on packer; shut in well and monitor psi at choke. Max Gas last 24hrs 163u = 3.26% @ 11:25. Approximately, 0.25 ounces of material collected from ditch magnets. 4/11/2014 Unseat packer; 85K U/W, 62K D/W; L/D acoustic repeater from top single; well flowing, install TIW, shut annular, TIW, and choke manifold, and monitor pressure; monitor SICP, 02:30hrs at 50 psi, 03:30hrs at 80 psi, 04:30hrs at 120 psi, 120 psi final SICP; L/D single, remove TIW, set packer, 82K U/W, 61K D/W; R/U to rev. circ., circulate 35 spm at 450 psi; blow dn top drive; R/U to utube taking returns through tbg; unseat packer, 81K U/W, 60K D/W; R/U headpin, H.P. hose to circulate dn tbg; pump 13 ppg dry job; POOH w/ tbg from 7621’ to 3000’ U/W 84K; remove Metrol relays on the rig floor, 50K U/W at 3000’; continue to TOH w/ tbg from 3000’ to 1136’; U/W 35K; M/U tools, BHA; PJSM for L/D completion BHA; L/D tools, rack back stands in derrick from 1136’ to 773’; continue to L/D tools and BHA. Max Gas last 24hrs 100u = 2.00% @ 08:30. Approximately, 0.50 ounces of material collected from ditch magnets. 4/12/2014 Continue to POOH and L/D makeup tools and BHA; L/D stand that was hole punched; breaking every cxn on stands 1-4, making sure stands no t plugged off; swap elevators for 2 7/8”; L/D BHA; monitor hole w/ trip tanks; prep for RIH while BHA is prepared by 3rd party; conduct rig service from 12:00 to 15:30; PJSM to P/U BHA; M/U tail pipe, sample/gauge carriers, LPR-N and OMNI valves; X-nipple and install Metrol relays as per running order; to 1050’ w/ 3.5” 9.2 lb/ft tbg, torque turn to 2300 ft/lb optimum, run at 60’/min; fill tbg w/ 10.4 non-polymer brine; R/U and PT BHA to 3500 psi for 5 min; continue to RIH w/ tbg. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/13/2014 Continue to RIH w/ 3.5” tbg from 1050’ to 6013’, U/W 53K, D/W 44K; continue to RIH from 6013’ to 7611’, space out to 7578’; R/U to test packer from kill line; test to 500 psi and chart; hook up gauges in cellar; ND/NU crane tree to rig floor; hook up Koomey lines to Koomey unit for frac tree master HCR valve; PJSM on N/U tree and coil BOP; R/U hoses to master valve; function test master; C/O elevators; P/U string to dn WT; break out floor valve; visually monitor tbg for 10 min; M/U dbl pin and 10K flange TQ to spec. SD 17K on packer; shoe at 7585.56’; M/U tree using crane; N/U BOPs; install control lines to BOPs and function test; N/U CT BOPs; M/U CT lubricator; begin R/U EXPRO hard line on tree; PJSM on R/U CT injector; pick CT injector head over windwalls and transfer to TD; secture control lines to windwall; M/U injector head to lubricator; install hyd lines to master valve; install drain line to injector; chain injector head back to derrick; R/U EXPRO lines; R/U to test CT BOP; PJSM on testing CT BOP; begin testing BOPs; fluid packing coil tbg lines, BOP w/ LVT; P/T coil tbg BOPs at 250 psi low/3500 psi high; continue to test BOPs. Max Gas last 24hrs 51u = 1.02%. Approximately, 0.75 ounces of material collected from ditch magnets. 4/14/2014 Continue testing BOPs; C/O API ring under crown valve on frac tree cont, w/ test; P/T coil tbg BOPs w/ LVT 200; flush coil/tree w/ Nitrogen; P/T tbg string to 3500 psi w/ Nitrogen; bleed off to EXPRO; PJSM on flowing well; close rams and annular; pressure up annulus to 1570 psi to open L-PRN; maintaining max 1600 psi; open up and flow to EXPRO; RIH w/ CT to 1500’, 4500’, 5500’, and 6500’, lift w/ N2 to EXPRO, maintaining max 1600 psi on annulus; take on 220 seawater to pits; begin mixing friction reducer; R/U hoses to coil tbg to transfer fluid; continue lifting from 6500’; shut dn flow to EXPRO; continue mixing friction reducer; begin transferring fluid to coil tbg from pits; RIH w/ CT to 7570’; pumping 0.7 to 1.8 bbls/min; tag/jet thru at 1.8 bbls/min up to 4800 psi; maintaining 1500-1600 annulus psi; continue to RIH to 7720’, pump 1.8 bbls/min; POOH to 7585’; take on additional 60 bbls seawater to pits; Qugruk 5A 26 maintaining 1500-1600 annulus psi; POOH from 7585’ to 1000’, pumping 1.8 bbls/min, maintaining 1500-1600 annulus psi; RIH from 1000’ to 4000’, pumping Nitrogen at 300 SCF min. Continue to pump Nitrogen. Max Gas last 24hrs 0u = 0.00%. Approximately, 0.25 ounces of material collected from ditch magnets. 4/15/2014 Continue pumping Nitrogen at 4000’, at 300 SCF min; RIH to 6500’, pump Nitrogen at 300-700 SCB; pull tbg from 6500’ to surface; pull coil above crown valve and monitor well; continue to flow well to EXPRO; maintaining 1500-1600 psi on annulus; RIH to 5000’, continue to flow well to EXPRO; maintaining 1500-1600 psi on annulus; pump out of hole 1.8 bbls/min at 4400 psi, 150’/min; take return flow to EXPRO, maintaining 1500-1600 psi on annulus; CT at surface; continue to flow well to EXPRO; maintaining 1500-1600 psi on annulus; RIH w/ CT to 6500’ lifting w/ Nitrogen to EXPRO; begin pumping acid; RIG to 7710’, spot 25 bbls acid; POOH w/ coil tbg, maintaining 1500-1600 psi on annulus; RIH w/ coil tbg to displace acid pill to EXPRO w/ Ni trogen; displacing acid pill. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/16/2014 RIH w/ coil tbg to 7620’, tag up, and displace acid pill to EXPRO; POOH w/ coil tbg; flush coil w/ calcium Bi-carbonate, purge w/ Nitrogen (N) to EXPRO; bleed off (N) from coil to EXPRO, shut crown valve in, continue monitoring well, taking returns to EXPRO; clean pill pit in preparation for taking on seawater and mixing high vis pill; mix high vis sweep and friction reducer; RIH from surface to 6500’ lifting w/ (N) to EXPRO, maintaining 1500-1600 psi on annulus; pump 166 bbls seawater w/ friction reducer from pits at 1 bbl/min, taking return flow to EXPRO, maintaining 1500-1600 psi on annulus; mix friction reducer into 290 bbl vac truck; swap over to vac truck, pump in hole to 7750’ up to 3 bbls/min of seawater from vac truck, maintaining 1500-1600 psi on annulus; circulate 5 bbl tandem sweeps (33 bbls total) from pits to clean out from 7750’ to 7800’ at up to 3 bbls/min; circulate hole clean w/ seawater; maintaining 1500-1600 psi on annulus; POOH to 2500’ lifting w/ (N) to EXPRO; maintaining 1500-1600 psi on annulus; begin to RIH from 2500’ w/ coil to make sure perforated section is still clear. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/17/2014 Continue to RIH w/ coil tbg to 7738’ to make sure perforated section is still clear, maintaining 1500-1600 psi on annulus (mntng P on annulus); POOH from 7738’ after lifting w/ (N), mntng P on annulus; shut in master/HCR, bleed off coil (N) to EXPRO; shut in crown valve, mntng P on annulus; PJSM on N/U, N/D BOPs, wellhead; remove coil injector unit/lubricator w/ crane, mntng P on annulus; remove flanged X/O for coil lubricator; install wireline (WL) X/O on top of coil BOPs; use crane to R/U WL BOPs/lubricators; R/U WL sheaves, mntng P on annulus; M/U rope socket; R/U lubricator; PJSM on PT lubricator; attempt to fill and PT; R/D and trouble shoot lubricator; R/U and fill lubricator using Glycol; PT lubricator to 3000 psi for 5 min; break below lubricator; M/U WL tools and function test electrical continuity; M/U perforating guns; M/U lubricator and PT break to 3000 psi; RIH w/ WL guns to 7735’; correlate depth; fire guns from 7650’ to 7641.3’ WLM; POOH from 7641.3’ WLM to surface; shut well in; break lubricator; check tools; open up to EXPRO, mntng P on annulus. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/18/2014 Lined up taking returns to EXPRO, monitor well, maintaining 1500-1600 psi on annulus (mntng P on annulus); R/U Schlumberger Eline; M/U rope socket; prep tools for run number (2); P/U lubricator; R/U Little Red to test lubricator w/ LVT; continue to mntng P on annulus, monitor well lined up to EXPRO; PJSM on PT and WL run; R/U fill and PT w/ Little Red to 3000 psi for 5 min; RIH w/ WL and tag at 6868’; POOH w/ WL, monitor tbg and annulus psi; R/U to pump dn tbg; bleed off annulus psi in order to close LPR-N; bleed off tbg psi; PJSM on R/D WL; R/D WL lubricator and stage in pipe shed; R/D WL BOP and fly off rig floor w/ crane; PJSM on R/U CT; off load seawater from pits, cycle LPR-N; line up to pump dn tbg; pump 18 bbls, 8.9 PPG seawater mixture at up to 2 bbls/min, 1400 psi; verify LPR-N open; bleed back to EXPRO; consolidate and blend brine in pits to 10.8 ppg; wait on 3rd party tools, slick line, and Qugruk 5A 27 brine truck; B/dn EXPRO line; remove ice from derrick; receive brine, mix w/ existing pit volume; continue waiting on 3rd party tools. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/19/2014 Receive 113 bbls brine at 10.1 ppg, mix w/ existing pit volume, ending brine at 10.7 ppg; pump 70 bbls dn tbg of 10.7 ppg brine, 31 spm at 1600 psi; B/D cement line after pumping; R/U to pump dn annulus to maintain 1500-1600 psi on annulus; R/U Halliburton slickline (SL) to fish Schlumberger’s guns; R/U lubricator/sheaves and tools, Little Red PT lubricator to 3000 psi w/ LVT; RIH to 7550’, no fish, POOH; R/D lubricator and secure in derrick; HES SL crew timed out; R/D lubricator extensions and WL valve; remove SL X/O off of CT BOP; install CT flange to OTIS X/O; R/D CT hyd lines; remove Schlumberger lubricator from pipe shed; PJSM on N/dn CT BOPs and fly out w/ crane; N/dn BOPs, bring up lubricator extensions for CT from pipe shed; break extensions apart; N/D CT BOPs; R/D CT hyd hoes to cellar; M/U extension piece onto bottom of CT BOP; Fly out BOP and extension pieces using crane onto truck; N/U SL X/O to crown valve and TQ to spec, M/U SL BOP; waiting on 3rd party SL crew; PJSM on R/U SL; R/U SL; PT lubricator w/ LVT from Little Red to 3600 psi, 5 min; RIH w/ SL gauge rung to 6750’; POOH; swap BHA to PX lock plug; PT lubricator w/ LVT from Little Red to 3600 psi, 5 min; RIH w/ PX lock. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/20/2014 RIH w/ PX lock and set at 6675’; POOH; swap SL tools, PT lubricator w/ Little Red to 3600 psi; RIH w/ prong run; set prong; POOH; Little Red test prong to 3000 psi for 10 min; R/D SL sheaves, lubricator, and BOP; Little Red, pump 30 bbls hot water through mud cross on tree to EXPRO; B/D w/ Nitrogen; R/D EXPRO w/ crane; R/D frac tree; Pick w/ crane and L/D on rig mat; install 4.5” elevators; bleed off annulus through super choke; double stack power tongs to rig floor; P/U, L/D M/U tools, BHA verify no trapped psi; open pipe rams; strip up thru annular 20”; break out 10K flange X/O and M/U X/Os to OTIS cxn us ing GBR double stacked tongs; PJSM on R?U and test SL lubricator; M/U WL pump tee, valve, and lubricator; test to 3000 psi using LVT from Little Red; RIH to 6675’ w/ 2” SB prong pulling tool; latch on; POOH; L/D prong pulling tool; P/U PX plug pulling tool; PT to 3000 psi using LVT from Little Red; RIH to 6675’, latch on, POOH; R/D, L/D SL; R/U to pump dn tbg, reverse circulate; fill and PT lines to 3000 psi for 5 min; pump 9 bbls dn tbg to verify LPR-N open; line up/dn kill line and shear RD at 2800 psi; shut don pumps, open annulus and un-seat packer; reverse circ thru choke manifold at up to 3 bbls/min, 400 psi; 1 ½ complete circulations at RD sub; visually monitor well as static; reverse circulating assembly; drain gas buster observed well u-tbg; pump 10 bbls 11.2 ppg brine dn tbg, 50 spm; continue cleaning operations. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/21/2014 POOH; R/B 1 stand; B/D cement line; P/U test tools, B/D kill/choke lines; P/U land ing jnt, set hanger, test dart, install test jnt; R/U to test BOPs; PT test BOPs, annular 250/3500 psi; remaining BOPs and equip 250/5000 psi; L/D test tool; pull test dart; R/D test equip and B/D lines; P/U landing jnt and M/U to hanger; bolds and pull ha nger and 3 ½ tub to rig floor; UpWT 89K; PJSM on tripping tbg; L/D landing jnt and tubing hanger; ready rig floor for tripping; M/U floor valve to X/Os; monitor well (static); stand back 1 stand in derrick; observed stand wet, pump 15 bbl 11.1 ppg dry job; B/D top drive; trip tbg from 7393’ to 983’, removing Metrol relays; PJSM on L/D BHA; TOH w/ BHA to surface; service, break, and L/D tools; open drain valve; standing stands of tbg back in derrick; remove Metrol relays; L/D tbg tail jnts to pipe shed; P/U 3rd party tools, clean/clear rig floor and pipe shed; prep to P/U tools; load shed w/ tbg; P/U, rack back 1 stand; P/U 2 jnts and packer assy; M/U packer assy; begin to RIH w/ packer assy. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. 4/22/2014 RIH w/ packer assy at 90 ft/min to 6500’; UW 70K, DW 64K; TIH to 7500’, RIH w/ 76 stands from derrick; P/U 4 singles from shed; UW 77K, DW 62K; C&C for R/U to reverse circ; install X/O head pin; R/U to take returns to flow box from tbg; pump dn kill line; C&C, reverse circ w/ Qugruk 5A 28 upper pipe rams closed, 125 gpm at 330 psi; B/D kill line reverse circ line; monitor well on trip tank; remove tools from pipe shed; ensure 3” line strung out from pits to cement unit for transferring brine; continue to monitor well on trip tanks; set packer at 7500’, pull 42K over to shear, S/D 14K; PJSM on R/U cementers; pressure test lines to 4000 psi; establish injection rate below packer, 2 bpm at 1340 psi; squeeze cmt pump 15 bbl, 13 ppg spacer, 26 bbl, 17 ppg class G premium, 5 bb, 13 ppg spacer and displace w/ 55 bbl 10.6 ppg brine; R/D cmt, B/D lines; L/D single jnt to pipe shed; stand back 5 stands in derrick; P/U single jnt and R/U to reverse circ; clean out cmt stinger; reverse out at up to 8 bbls/min, 1150 psi, 1.5 tbg volumes; R/D and B/D lines ready to tbg trip; stand back 3 stands in derrick to 6725’, observed pipe pulling wet; C&C, R/U circ head; C&C at 350 gpm, 1375 psi; trip tbg from 6725’ to 5100’, standing back in derrick; R/U circ head; PJSM on csg test; R/U cmt lines, fill and PT cmt lines; pressure test csg/shoe, perform csg test 2000 psi, 30 min; C&C, B/D cmt lines; pump 5 bbls dry job; R/D cmt hose and head pin; L/D single jnt of tbg to pipe shed from 5100’ to 3000’; continue to POOH, L/D tbg in pipe shed from 3000’ to surface. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. Qugruk 5A 29 5.2 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) NS (ft) EW (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 N/A 229.00 0.20 204.56 229.00 S 0.36 W 0.17 -0.35 0.09 311.00 0.22 158.17 311.00 S 0.64 W 0.17 -0.62 0.20 490.00 0.03 250.53 490.00 S 0.97 W 0.08 -0.96 0.12 582.00 0.29 352.86 582.00 S 0.75 W 0.14 -0.74 0.32 858.00 0.09 196.26 858.00 S 0.27 W 0.28 -0.24 0.14 948.00 0.26 86.80 948.00 S 0.32 W 0.10 -0.31 0.34 1045.00 0.09 135.72 1045.00 S 0.37 E 0.17 -0.38 0.22 1141.00 0.37 161.39 1141.00 S 0.71 E 0.33 -0.74 0.30 1334.00 0.49 160.60 1333.99 S 2.08 E 0.80 -2.15 0.06 1430.00 0.56 148.34 1429.99 S 2.87 E 1.18 -2.97 0.14 1527.00 0.81 144.21 1526.98 S 3.83 E 1.83 -3.98 0.26 1817.00 0.68 140.22 1816.95 S 6.81 E 4.13 -7.17 0.05 1913.00 0.76 161.02 1912.95 S 7.85 E 4.70 -8.25 0.28 2009.00 0.70 153.29 2008.94 S 8.98 E 5.17 -9.42 0.12 2106.00 0.59 183.89 2105.93 S 10.01 E 5.41 -10.46 0.37 2202.00 0.72 169.96 2201.93 S 11.09 E 5.48 -11.55 0.21 2252.00 0.64 174.68 2251.92 S 11.68 E 5.56 -12.14 0.20 2307.00 0.83 175.46 2306.92 S 12.38 E 5.62 -12.85 0.35 2342.00 1.37 357.28 2341.92 S 12.22 E 5.62 -12.69 6.28 2381.00 3.82 356.84 2380.87 S 10.46 E 5.52 -10.92 6.28 2413.00 3.90 355.77 2412.80 S 8.31 E 5.39 -8.77 0.34 2510.00 7.11 337.76 2509.35 N 0.54 E 2.87 0.28 3.72 2605.00 10.05 332.50 2603.28 N 13.34 W 3.18 13.58 3.20 2702.00 13.16 331.11 2698.28 N 30.52 W 12.43 31.54 3.22 2797.00 17.12 339.94 2789.98 N 53.13 W 22.46 54.98 4.81 2895.00 21.51 351.14 2882.47 N 84.46 W 30.18 86.89 5.84 2990.65 25.04 356.50 2970.33 N 122.01 W 34.12 124.64 4.30 3086.61 28.38 0.29 3056.05 N 165.10 W 35.24 167.65 3.91 3182.54 31.01 1.99 3139.37 N 212.60 W 34.27 214.86 2.88 3278.73 35.19 358.55 3219.94 N 265.10 W 34.11 267.12 4.76 3375.27 39.50 356.82 3296.68 N 323.60 W 36.52 325.58 4.59 3471.23 38.21 357.51 3371.40 N 383.72 W 39.50 385.73 1.42 3567.85 36.83 359.42 3448.04 N 442.54 W 41.09 444.44 1.87 Qugruk 5A 30 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) NS (ft) EW (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 3665.11 36.93 1.23 3525.84 N 500.90 W 40.76 502.52 1.12 3761.50 36.91 0.63 3602.90 N 558.79 W 39.82 560.08 0.37 3857.50 36.90 358.71 3679.67 N 616.43 W 40.15 617.51 1.20 3953.62 36.92 358.54 3756.52 N 674.14 W 41.53 675.10 0.11 4050.00 36.85 358.49 3833.61 N 731.97 W 43.03 732.82 0.08 4146.30 36.83 357.87 3910.68 N 789.68 W 44.87 790.45 0.39 4242.51 36.89 355.18 3987.66 N 847.28 W 48.37 848.12 1.68 4338.99 36.93 354.74 4064.81 N 904.99 W 53.46 906.07 0.28 4434.60 36.96 353.72 4141.22 N 962.17 W 59.23 963.53 0.64 4530.74 37.00 351.72 4218.02 N 1019.53 W 66.56 1021.32 1.25 4627.09 37.04 352.45 4294.95 N 1076.98 W 74.55 1079.27 0.46 4723.58 37.00 350.65 4372.00 N 1134.44 W 83.09 1137.27 1.12 4818.77 37.01 350.57 4448.01 N 1190.97 W 92.43 1194.42 0.05 4916.51 37.03 350.23 4526.05 N 1248.99 W 102.25 1253.10 0.21 5011.08 37.01 350.21 4601.56 N 1305.11 W 111.92 1309.87 0.02 5108.00 36.98 350.75 4678.97 N 1362.62 W 121.57 1368.03 0.34 5204.26 36.95 352.28 4755.88 N 1419.87 W 130.11 1425.82 0.96 5301.18 37.00 353.58 4833.31 N 1477.72 W 137.28 1484.08 0.81 5398.20 36.92 353.56 4910.84 N 1535.68 W 143.81 1542.40 0.08 5494.31 36.94 353.48 4987.66 N 1593.06 W 150.33 1600.14 0.05 5590.41 36.87 354.51 5064.51 N 1650.45 W 156.37 1657.84 0.65 5686.90 36.79 355.65 5141.74 N 1708.08 W 161.33 1715.68 0.71 5783.39 36.77 355.34 5219.02 N 1765.67 W 165.87 1773.44 0.19 5879.42 36.82 354.32 5295.92 N 1822.95 W 171.05 1830.96 0.64 5975.70 36.83 353.87 5372.99 N 1880.35 W 176.99 1888.66 0.28 6071.85 36.91 354.53 5449.91 N 1937.75 W 182.82 1946.35 0.42 6168.26 36.75 353.25 5527.08 N 1995.21 W 188.97 2004.13 0.81 6264.70 36.72 353.74 5604.37 N 2052.52 W 195.50 2061.80 0.31 6360.38 36.87 354.56 5680.99 N 2109.53 W 201.34 2119.11 0.54 6457.17 36.81 354.00 5758.45 N 2167.27 W 207.12 2177.14 0.35 6554.18 36.56 353.84 5836.25 N 2224.90 W 213.26 2235.09 0.28 6650.39 36.56 354.00 5913.53 N 2281.89 W 219.33 2292.39 0.10 6747.26 36.46 354.82 5991.39 N 2339.25 W 224.95 2350.02 0.51 6840.07 36.58 354.95 6065.97 N 2394.26 W 229.87 2405.25 0.15 Qugruk 5A 31 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) NS (ft) EW (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 6939.44 36.55 354.94 6145.79 N 2453.23 W 235.09 2464.45 0.03 7036.31 36.59 353.56 6223.59 N 2510.65 W 240.87 2522.16 0.85 7132.81 36.54 354.29 6301.09 N 2567.81 W 246.95 2579.64 0.45 7229.10 36.45 356.23 6378.51 N 2624.88 W 251.69 2636.90 1.20 7324.34 36.37 355.84 6455.15 N 2681.27 W 255.60 2693.42 0.26 7421.53 36.50 355.90 6533.35 N 2738.85 W 259.75 2751.13 0.14 7518.25 36.55 357.25 6611.07 N 2796.31 W 263.19 2808.66 0.83 7614.21 36.60 356.12 6688.14 N 2853.39 W 266.50 2865.80 0.70 7710.90 36.96 354.85 6765.58 N 2911.10 W 271.06 2923.69 0.87 7806.04 36.52 356.30 6841.82 N 2967.84 W 275.45 2980.59 1.02 7903.49 36.50 355.98 6920.15 N 3025.68 W 279.35 3038.55 0.20 7946.89 36.50 355.79 6955.04 N 3051.43 W 281.21 3064.36 0.26 8015.00 36.50 355.79 7009.79 N 3091.84 W 284.18 3104.87 0.00 Qugruk 5A 32 5.3 Bit Record BHA # Bit # Size Make Type / Serial # Jets / TFA Depth In MD/TVD Total Footage Bit Hrs Avg. ROP (ft/hr) Avg. WOB (klbs) Avg RPM Avg PP (psi) Wear Q5 BHA #1 1 12.25” Hughes Milltooth VMD-3 / 5229032 3X14, 1X16 / 0.647 103’/103’ 2222’ 28.1 101.1 12.0 94.8 1917 1-2-WT-A-E-1A-FC-TD Q5A BHA #1 2 8.5” Hughes Milltooth VMD-3 / 5201572 3X20, 1X16 / 1.117 2305’/2305’ 105’ 14.1 18.1 6.8 16.0 2006 1-1-NO -A-E-I-NO -BHA BHA #2 3 8.5" NOV PDC / A192482 7x11 / 0.65 2430’/2430’ 5585' 51.92 107.6 6.9 118.8 3331 1-1-WT-N-X-I-NO -TD Qugruk 5A 33 5.4 Mud Record Contractor: Halliburton/Baroid Mud Type: Gel Spud Mud Date Depth /TVD MW VIS PV YP Gels FL FC Sol O/W Sd Alk Cl Ca ECD (at TDs) 1/29/2014 103’/103’ 9.60 65 20 28 15/22/27 9.3 2/0 5.3 0.0/9 4.5 0.10 100 - 1/30/2014 103’/103’ 9.50 70 24 26 8/20/25 9.1 2/0 4.8 0.0/95.0 0.10 100 - 1/31/2014 103’/103’ 9.80 65 27 25 10/22/27 8.6 2/0 5.8 0.0/94.0 0.10 100 - 2/01/2014 316’/316’ 9.95 68 25 25 10/23/28 7.9 2/0 7.2 0.0/92.5 3.00 0.35 800 - 2/02/2014 2200’/2200’ 10.1 70 24 27 12/42/51 9.0 2/0 8.8 1.0/90.0 4.00 0.70 900 20 - 2/03/2014 2325’/2325’ 10.2 65 26 22 9/32/45 8.5 2/0 8.8 1.0/90.0 4.00 0.80 900 20 - 2/04/2014 2325’/2325’ 10.3 71 25 22 10/49/75 8.4 2/0 8.8 1.0/90.0 3.50 0.70 700 20 - 2/05/2014 2305’/2305’ 10.3 71 25 22 10/49/75 8.4 2/0 8.8 1.0/90.0 3.50 0.70 700 - 2/06/2014 2305’/2305’ 10.4 52 18 21 5/8/15 4.2 1/0 6.9 0.0/91.5 0.30 31000 160 - 2/07/2014 2305’/2505’ 10.2 38 24 20 6/33/62 8.4 2/0 8.8 1.0/90.0 3.00 0.70 700 20 - 2/08/2014 2305’/2305’ 10.4 38 26 20 6/32/64 8.2 2/0 8.8 1.0/90.0 3.00 0.70 800 20 - Mud Type: KCl Polymer (From original Qugurk 5 wellbore cementing operations) Date Depth/TVD MW VIS PV YP Gels FL FC Sol O/W Sd Alk Cl Ca ECD (at TDs) 3/11/2014 2130’/2130’ 10.45 65 18 14 5/24/30 6.8 1/2 9.6 2.0/86.1 0.10 0.70 30000 1500 - 3/12/2014 2305’/2305’ 10.45 65 18 14 5/24/30 6.8 1/2 9.6 2.0/86.1 0.10 0.70 30000 1500 - 3/1 3/2014 2305’/2305’ 10.4 90 26 15 7/10/0 - 0/2 12.4 80.0/20.0 - - 1 2 - Mud Type: Mineral Oil Based Mud Date Depth/TVD MW VIS PV YP Gels FL FC Sol O/W THTS HTHP CaCl2 WPS ECD (at TD’s) 3/14/2014 2350’/2330’ 10.4 77 28 14 8/12/15 - 0/2 13.0 80.7/19.3 1.5 4.0 13.06 238,233 10.74 3/1 5/2014 2430’/2430’ 10.4 78 30 12 8/11/14 - 0/2 12.3 80.2/19.8 1.5 4.2 13.06 246,864 10.4 3/1 6/2014 2576’/2576’ 10.45 86 35 14 9/14/17 - 0/2 13.0 80.0/20.0 1.4 3.8 12.09 273,852 10.87 3/17/2014 4018’/4018’ 10.4 86 46 20 9/16/21 - 0/2 13.1 80.0/20.0 1.3 3.6 11.12 261,312 10.85 3/18/2014 5637’/5100’ 10.45 78 41 21 8/18/23 - 0/2 13.1 80.1/19.9 1.5 3.8 13.08 255,349 10.89 3/19/2014 7230’/6379’ 10.65 99 47 24 10/20/25 - 0/2 13.9 81.9/18.1 1.4 4.2 12.09 278.169 11.08 3/20/2014 8015’/7009’ 10.7 100 45 25 12/22/26 - 0/2 15.2 80.7/19.3 1.6 4.0 14.03 271,725 10.50 3/21/2014 8015’/7009’ 10.6 89 43 26 10/20/28 - 0/2 14.7 82.0/18.0 1.4 3.8 12.09 278,790 10.80 Qugruk 5A 34 3/22/2014 8015’/7009’ 10.6 99 42 26 9/19/27 - 0/2 14.7 82.0/18.0 1.4 3.8 12.09 278,790 - 3/23/2014 8015’/7009’ 10.5 103 43 26 10/20/27 - 0/2 14.1 81.5/18.5 1.4 3.8 12.09 277,580 10.6 3/24/2014 8015’/7009’ 10.4 95 37 25 10/20/27 - 0/2 13.2 80.6/19.4 1.5 3.8 13.06 266,158 - 3/25/2014 8015’/7009’ 10.4 95 37 25 10/20/27 - 0/2 13.0 80.3/19.7 1.5 4.0 13.06 276,350 - 3/26/2014 8015’/7009’ 10.4 27 - - - - - - - - - - - 10.4 Mud Type: Brine Date Depth/TVD MW VIS PV YP Gels FL FC Sol O/W THTS HTHP CaCl2 WPS ECD (at TD’s) 3/27/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - 10.4 3/28/2014 7848’/6533’ 10.15 27 - - - - - - - - - - - 10.15 3/29/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - 10.4 3/30/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - - 3/31/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - 10.4 4/01/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - 10.4 4/02/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - 10.4 4/03/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - 10.4 4/04/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - 10.4 4/0 5/2014 7848’/6533’ 10.4 27 - - - - - - - - - - - 0.00 4/06/2014 7848’/6533’ 12.4 - 13 21 9/13/15 - - - - - - - - 10.4 4/07/2014 7848’/6533’ 12.4 - - - - - - - - - - - - 12.4 4/08/2014 7848’/6533’ 11.4 40 - - - - - - - - - - - 11.9 4/09/2014 7848’/6533’ 10.8 47 - - - - - - - - - - - 10.9 4/10/2014 7848’/6533’ 11.10 47 - - - - - - - - - - - 11.10 4/11/2014 7848’/6533’ 11.10 48 - - - - - - - - - - - - 4/12/2014 7848’/6533’ 11.10 48 - - - - - - - - - - - 11.10 4/13/2014 7848’/6533’ 11.10 49 - - - - - - - - - - - 11.10 4/14/2014 7848’/6533’ 11.10 49 - - - - - - - - - - - 0.00 4/15/2014 7848’/6533’ 11.10 50 - - - - - - - - - - - 0.00 Abbreviations MW = Mud Weight Gels = Gel Strength O/W = Oil to Water ratio Ca = Calcium (Hardness) VIS = Funnel Viscosity FL = Filtrate (Fluid) Loss Sd = Sand Content (%) ECD = Effective Circulating Density PV = Plastic Viscosity FC = Filter Cake Alk = Alkalinity YP = Yield Point Sol = Solids (%) Cl = Chlorides Qugruk 5A 35 Mud Type: Brine Date Depth/TVD MW VIS PV YP Gels FL FC Sol O/W THTS HTHP CaCl2 WPS ECD (at TD’s) 4/16/2014 7848’/6533’ 11.10 50 - - - - - - - - - - - 0.00 4/17/2014 7848’/6533’ 11.00 50 - - - - - - - - - - - 11.00 4/18/2014 7848’/6533’ 10.70 47 - - - - - - - - - - - 0.00 4/19/2014 7848’/6533’ 10.70 47 - - - - - - - - - - - 10.70 4/20/2014 7848’/6533’ 10.70 45 - - - - - - - - - - - 0.00 4/21/2014 7848’/6533’ 10.70 46 - - - - - - - - - - - 10.70 Abbreviations MW = Mud Weight Gels = Gel Strength O/W = Oil to Water ratio Ca = Calcium (Hardness) VIS = Funnel Viscosity FL = Filtrate (Fluid) Loss Sd = Sand Content (%) ECD = Effective Circulating Density PV = Plastic Viscosity FC = Filter Cake Alk = Alkalinity YP = Yield Point Sol = Solids (%) Cl = Chlorides Qugruk 5A 36 5.5 Isotube Record Box 5 Num Type of Gas Date Time MD Total Gas (units) C1 (ppm) C2 (ppm) C3 (ppm) iC4 (ppm) nC4 (ppm) iC5 (ppm) nC5 (ppm) 1 Trip Gas (Q5) 20140306 19:37 5192 70 2 Trip Gas (Q5) 20140309 4:15 6090 180 3 Background Gas 20140314 20:45 2350 2 144 0 0 8 2 5 3 4 Background Gas 20140316 19:15 2440 11 1960 6 21 3 0 7 4 5 Background Gas 20140316 20:45 2530 28 5345 26 40 16 31 6 9 6 Background Gas 20140316 22:32 2620 36 5738 20 13 11 11 17 7 7 Background Gas 20140317 0:10 2710 15 2261 9 7 3 0 2 8 8 Background Gas 20140317 1:41 2800 23 3450 10 18 6 9 0 1 9 Background Gas 20140317 4:54 2980 35 3857 32 25 3 3 2 0 10 Background Gas 20140317 3:14 2890 37 5892 42 39 4 6 2 7 11 Formation Gas 20140317 5:05 2998 73 11605 105 34 7 5 3 0 12 Background Gas 20140317 6:11 3070 108 18206 253 59 21 24 14 11 13 Background Gas 20140317 7:38 3160 65 10684 197 67 16 26 5 0 14 Background Gas 20140317 8:35 3250 35 5492 119 47 21 15 5 11 15 Background Gas 20140317 9:25 3340 21 4874 103 48 10 10 4 7 16 Background Gas 20140317 10:30 3430 35 5437 116 41 5 7 10 3 17 Background Gas 20140317 11:18 3520 44 6967 162 53 4 6 7 5 18 Background Gas 20140317 12:27 3610 42 7062 160 42 15 13 2 5 19 Background Gas 20140317 13:23 3700 30 5177 113 56 3 9 9 3 20 Background Gas 20140317 14:26 3790 28 4411 98 49 11 11 4 6 21 Background Gas 20140317 17:06 3880 22 3439 76 32 13 7 9 0 22 Background Gas 20140317 18:11 3970 32 574 146 60 10 10 6 12 23 Background Gas 20140318 2:19 4060 44 6834 167 49 4 12 5 7 24 Background Gas 20140318 3:20 4150 65 11101 269 78 5 14 2 4 25 Formation Gas 20140318 4:09 4232 201 33581 1275 476 62 130 36 23 Qugruk 5A 37 Isotube record (Cont.) Box 6 Num Type of Gas Date Time MD Total Gas (units) C1 (ppm) C2 (ppm) C3 (ppm) iC4 (ppm) nC4 (ppm) iC5 (ppm) nC5 (ppm) 1 Background Gas 20140318 5:05 4330 118 20047 664 238 37 60 14 13 2 Background Gas 20140318 6:40 4420 78 12840 445 160 17 36 20 18 3 Background Gas 20140318 6:24 4474 147 25135 1041 365 42 96 24 21 4 Background Gas 20140318 7:06 4510 102 16574 691 241 25 63 22 17 5 Background Gas 20140318 8:08 4600 152 28240 1358 460 59 114 26 26 6 Background Gas 20140318 9:14 4690 106 21441 1056 393 43 96 26 29 7 Background Gas 20140318 9:50 4786 75 12107 585 211 28 52 13 16 8 Background Gas 20140318 11:09 4870 69 8758 448 184 28 50 15 17 9 Background Gas 20140318 12:10 4960 32 4251 323 135 19 40 15 6 10 Background Gas 20140318 13:54 5050 42 6432 277 139 29 50 32 25 11 Background Gas 20140318 15:07 5140 35 5082 203 98 22 38 11 9 12 Background Gas 20140318 16:35 5230 23 3972 155 108 23 31 20 11 13 Background Gas 20140318 17:49 5320 18 4652 175 70 11 28 6 17 14 Background Gas 20140318 19:02 5411 42 6518 250 113 12 44 16 6 15 Background Gas 20140318 20:51 5500 35 5073 225 98 23 31 30 8 16 Background Gas 20140318 22:11 5590 28 3871 164 76 14 29 9 5 17 Background Gas 20140318 23:55 5680 23 3163 121 89 18 23 19 5 18 Background Gas 20140319 1:05 5770 20 2583 96 55 9 24 0 25 19 Background Gas 20140319 2:17 5860 16 2075 77 39 9 13 0 14 20 Background Gas 20140319 4:10 5950 13 1667 75 54 0 27 6 1 21 Background Gas 20140319 5:11 6040 23 3122 93 39 3 9 3 4 22 Background Gas 20140319 6:25 6130 50 7799 299 105 14 26 1 7 23 Background Gas 20140319 7:30 6220 28 3705 132 52 8 15 2 7 24 Background Gas 20140319 8:35 6310 26 4265 140 61 12 15 5 4 25 Background Gas 20140319 9:36 6400 20 3274 113 56 13 18 6 6 Qugruk 5A 38 Isotube record (Cont.) Box 7 Num Type of Gas Date Time MD Total Gas (units) C1 (ppm) C2 (ppm) C3 (ppm) iC4 (ppm) nC4 (ppm) iC5 (ppm) nC5 (ppm) 1 Background Gas 20140319 12:04 6490 22 3661 117 41 10 17 9 8 2 Background Gas 20140319 13:25 6580 26 4523 136 61 2 10 5 5 3 Background Gas 20140319 14:35 6670 27 4529 125 58 5 14 3 5 4 Background Gas 20140319 16:05 6760 45 7287 178 74 6 11 9 5 5 Background Gas 20140319 17:10 6850 50 8867 194 83 13 20 13 5 6 Background Gas 20140319 18:29 6940 26 1667 75 54 0 27 6 1 7 Background Gas 20140319 20:05 7030 22 3751 84 66 15 16 3 6 8 Background Gas 20140319 21:40 7120 20 3387 67 56 6 12 3 4 9 Background Gas 20140319 23:01 7210 20 3548 62 48 10 6 6 0 10 Background Gas 20140320 0:24 7300 18 2923 53 27 8 10 4 9 11 Background Gas 20140320 1:43 7390 20 3254 58 38 9 5 11 6 12 Background Gas 20140320 2:51 7480 22 3254 72 47 17 13 11 7 13 Background Gas 20140320 5:19 7570 25 4039 79 61 24 20 13 6 14 Background Gas 20140320 6:12 7615 21 3180 55 61 12 10 6 2 15 Background Gas 20140320 7:39 7660 70 12416 309 244 65 73 21 16 16 Background Gas 20140320 9:01 7730 37 6219 153 125 29 35 18 8 17 Background Gas 20140320 9:18 7750 31 5209 127 100 24 29 17 9 18 Background Gas 20140320 10:30 7840 31 4925 144 121 31 40 26 12 19 Background Gas 20140320 12:08 7930 26 4370 124 122 32 31 25 13 20 Background Gas 20140320 13:30 8015 27 4422 115 108 31 37 15 6 21 Trip Gas (Casing) 20140323 20:31 3051 97 20568 58 15 5 5 4 4 22 Bottoms up casing 20140324 12:45 7992 38 8222 90 73 14 14 16 18 Qugruk 5A 39 5.6 Ditch Magnet Record Date lbs oz Remarks 20140312 1 20140313 0.0 20140314 0.0 20140315 7.0 8.0 DD attributes quantity of metal to Millbit orientation while drilling out cement in casing 20140316 18.5 DD attributes quantity of metal to Millbit orientation while drilling out cement in casing 20140317 10.5 DD attributes quantity of metal to Millbit orientation while drilling out cement in casing 20140318 15.9 DD attributes quantity of metal to Millbit orientation while drilling out cement in casing 20140319 5.2 Magnets also caked with approx. 1 lb of non-magnetic cuttings. 20140320 3.7 Magnets also caked with approx. 3oz non-magnetic cuttings. 20140321 1.5 Magnets also caked with traces of non-magnetic cuttings. 20140322 2.0 Magnets also caked with approx. 1oz non-magnetic cuttings. 20140323 0.5 Magnets also caked with traces of non-magnetic cuttings. 20140324 0.3 Magnets also caked with approx. 0.5 oz non-magnetic cuttings 20140325 - Magnets cleaned by rig during cementing run. No sample collected. 20140326 - Magnets cleaned by rig during cementing run. No sample collected. 20140327 2.0 Metal derived from polishing during completion. 20140328 8.5 Metal mixed with mud and cement cuttings, much derived from displacement to completion fluid (brine). 20140329 7.5 Magnets cleaned / collected by Canrig personnel. 20140330 4.0 Magnets cleaned / collected by Canrig personnel. 20140331 2.5 Magnets cleaned / collected by Canrig personnel. 20140401 3.0 Magnets cleaned / collected by Canrig personnel. 20140402 1.5 Magnets cleaned / collected by Canrig personnel. 20140403 1.0 Magnets cleaned / collected by Canrig personnel. 20140404 0.0 No mud flow over shakers, no metal/material collected. 20140405 0.0 No mud flow over shakers, no metal/material collected. 20140406 0.0 No discernable metal/material collected from ditch magnet. 20140407 0.5 Magnets cleaned / collected by Canrig personnel. 20140408 0.0 No discernable metal/material collected from ditch magnet. 20140409 0.5 Magnets cleaned / collected by Canrig personnel. 20140410 ******** 0.25 Magnets cleaned / collected by Canrig personnel. 20140411 0.50 Magnets cleaned / collected by Canrig personnel. 20140412 0.0 No discernable metal/material collected from ditch magnet. 20140413 0.75 Magnets cleaned / collected by Canrig personnel. 20140414 0.25 Magnets cleaned / collected by Canrig personnel. 20140415 0.0 No mud flow over shakers, no metal/material collected. 20140416 0.0 No mud flow over shakers, no metal/material collected. 20140417 0.0 No mud flow over shakers, no metal/material collected. 20140418 0.0 No discernable metal/material collected from ditch magnet. 20140419 0.0 No discernable metal/material collected from ditch magnet. 20140420 0.0 No discernable metal/material collected from ditch magnet. 20140421 0.0 No discernable metal/material collected from ditch magnet. 20140422 0.0 No discernable metal/material collected from ditch magnet. Qugruk 5A 40 6 DAILY REPORTS REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Schroabo, Hayne DATE March 12, 2014 DEPTH 2305' PRESENT OPERATION Cleaning Pits TIME 03:00 YESTERDAY 2305' 24 HOUR FOOTAGE 0' CASING INFORMATION 2" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7430' MW 10.45 VIS 65 PV 18 YP 14 FL 6.8 Gels 5/24/30 CL- 30000 FC 1/2 SOL 9.6 SD 0.10 OIL 2.0/86.1 MBT 13.5 pH 10.0 Ca+ 1500 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u / 0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY Commence Qugruk 5A at 09:30. Pick up sidetrack directional BHA; trip in to 2067'; cut 100' drill line; continue to clean mud system. Max Gas last 24hrs 0u = 0.00%. Approximately 1.0 ounce of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5830 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Schroabo, Hayne DATE March 12, 2014 DEPTH 2305' PRESENT OPERATION Cleaning Pits TIME 03:00 YESTERDAY 2305' 24 HOUR FOOTAGE 0' CASING INFORMATION 2" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7430' MW 10.45 VIS 65 PV 18 YP 14 FL 6.8 Gels 5/24/30 CL- 30000 FC 1/2 SOL 9.6 SD 0.10 OIL 2.0/86.1 MBT 13.5 pH 10.0 Ca+ 1500 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u / 0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY Commence Qugruk 5A at 09:30. Pick up sidetrack directional BHA; trip in to 2067'; cut 100' drill line; continue to clean mud system. Max Gas last 24hrs 0u = 0.00%. Approximately 1.0 ounce of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5830 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Schroabo, Hayne DATE March 13, 2014 DEPTH 2305' PRESENT OPERATION Cleaning Pits TIME 03:00 YESTERDAY 2305' 24 HOUR FOOTAGE 0' CASING INFORMATION 2" @ 103'; 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" Baker VMD-3 5201572 3X20; 1X16 2305' In Hole 0' 00.00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 2305' MW 10.45 VIS 65 PV 18 YP 14 FL 6.8 Gels 5/24/30 CL- 30000 FC 1/2 SOL 9.6 SD 0.10 OIL 2.0/86.1 MBT 13.5 pH 10.0 Ca+ 1500 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u / 0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY Continue to clean pits for change over to mineral based mud system. No Max Gas for last 24 hours. No material collected from ditch magnet, due to no flow over shakers last 24 hours. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Schroabo, Hayne DATE March 14, 2014 DEPTH 2305' PRESENT OPERATION Drilling Cement TIME 03:00 YESTERDAY 2305' 24 HOUR FOOTAGE 0' CASING INFORMATION 2" @ 103'; 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" Baker VMD-3 5201572 3X20; 1X16 2305' In Hole 0' 00.00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 2305' MW 10.4 VIS 90 PV 26 YP 15 FL -- Gels 7/10/0 CL- 1 FC 0/2 SOL 12.4 SD -- OIL 80.0/20.0 MBT -- pH -- Ca+ 2 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u / 0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY Continue to clean out pits; change to mineral based mud system; RIH; tag cement at 2130’; begin drilling cement from 2130’ to 2172’; continue to drill cement. Max Gas last 24hrs 0u = 0.00%. Approximately, 0.0 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Schroabo, Hayne DATE Mar 15, 2014 DEPTH 2430' PRESENT OPERATION Tripping out TIME 03:00 YESTERDAY 2325' 24 HOUR FOOTAGE 105' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2381.00' 3.82 356.84 2380.87' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Baker Milltooth 5201572 3x20, 1x16 2325' 2430' 105' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 60.0 @ 2325 0.9 @ 2333 18.1 27.55 FT/HR SURFACE TORQUE 3279 @ 2328 38 @ 2369 966.6 1747.96 AMPS WEIGHT ON BIT 54 @ 2353 0 @ 2429 6.8 2.59 KLBS ROTARY RPM 36 @ 2326 19 @ 2375 16.0 26.00 RPM PUMP PRESSURE 2067 @ 2372 1338 @ 2346 1821.6 2006.49 PSI DRILLING FLUIDS REPORT DEPTH 2340' MW 10.4 VIS 77 PV 28 YP 14 FL - Gels 8/12/15 CL- - FC 0/2 SOL 13.0 SD - OIL 80.7/19.3 MBT - pH - Ca+ - Alk - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 14 @ 2325 0 @ 2326 4.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 2767 @ 2325 9 @ 2326 477.8 CONNECTION GAS HIGH ETHANE (C-2) 4 @ 2409 0 @ 2385 0.9 AVG PROPANE (C-3) 13 @ 2423 0 @ 2351 2.9 CURRENT BUTANE (C-4) 17 @ 2347 0 @ 2326 6.6 CURRENT BACKGROUND/AVG 2u / 2u PENTANE (C-5) 13 @ 2347 0 @ 2326 3.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Shale; tuff; siltstone PRESENT LITHOLOGY Shale; tuff; siltstone DAILY ACTIVITY SUMMARY Rotary drilling cement from 2172’ to 2260’ staging up to 20K WOB. L/D single for and P/U 5" PUP for space out. Continue to drill cement to 2329’. CBU at 2329’; B/D top Drive and R/U Wire Line for Gyro Run to orient motor; POOH with Wireline; RIH with wireline to verify orientation of toolface; TOOH with wireline; R/D wireline; L/D 5” pup P/U single; Slide/Time Drill at 1.5’/Hr from 2330’ to 2369’; Commenced rotary drilling to 2430’; CBU @ 2430' TOOH B/D top Drive and monitor well; Laying down BHA at time of report. Max Gas last 24hrs 8u = 0.16%. Approximately, 120.0 ounces of material collected from ditch magnet which DD attributed to be likely due to mill bit orientation in relation to casing during rotary drilling of cement above casing shoe at 2305’. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Schroabo, Hayne DATE Mar 16, 2014 DEPTH 2430' PRESENT OPERATION Testing BOPs TIME 03:00 YESTERDAY 2430' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Baker Milltooth 5201572 3x20, 1x16 2325' 2430' 105' 8.35 1-1-NO-A-E-I-NO BHA 3 8.5" NOV PDC bit A192482 7x11 2430' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 2430' MW 10.4 VIS 78 PV 30 YP 12 FL - Gels 8/11/14 CaCl2 13.06 FC 0/2 SOL 12.3 THTS 1.5 OIL 80.2/19.8 MBT - pH - WPS 246,864 HTHP 4.2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue TOOH; B/D Top Drive and monitor well; POOH L/D BHA stand back both stands of collars and L/D BHA; clean up rig floor and prep for P/U BHA; P/U BHA PJSM for M/U BHA; M/U BHA; P/U bit and X/O to floor and P/U BHA. Test Power Drive; PJSM to load Source; Load Source; P/U BHA; TIH to 2179'; Fill pipe; shallow test of MWD tools; B/D Top Drive; install/remove wear bushing; P/U test tools M/U test plug to string and set plug; Test BOPs change upper pipe ram door seal; test annular to 250 low 3500 high for 5 min. test rig gas alarms: test witnessed by AOGCC Rep. Jeff Turkington; Upper Ram failure; pull/rebuild Rams; Testing BOPs at time of report. Max Gas last 24hrs 0u = 0.00%. Approximately, 18.5 ounces of material collected from ditch magnet, likely due to mill bit orientation (as yesterday). CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Schroabo, Hayne DATE Mar 17, 2014 DEPTH 2935' PRESENT OPERATION Drilling TIME 03:00 YESTERDAY 2430' 24 HOUR FOOTAGE 505' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2797.00' 17.12 339.94 2789.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" NOV PDC bit A192482 7x11 2430' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 153.5 @ 2486 1.8 @ 2607 85.9 79.71769 FT/HR SURFACE TORQUE 5751 @ 2492 1325 @ 2431 2714.8 1870.09451 AMPS WEIGHT ON BIT 11 @ 2552 0 @ 2431 3.7 4.15397 KLBS ROTARY RPM 110 @ 2431 26 @ 2430 109.2 110.00000 RPM PUMP PRESSURE 2479 @ 2905 1871 @ 2775 2402.2 2479.73247 PSI DRILLING FLUIDS REPORT DEPTH 2576'/2576' MW 10.45 VIS 86 PV 35 YP 14 FL - Gels 9/14/17 CaCl2 12.09 FC 0/2 SOL 13.0 THTS 1.4 OIL 80.0/20.0 MBT - pH - WPS 273,852 HTHP 3.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 58 @ 2877 2 @ 2431 23.4 TRIP GAS CUTTING GAS 0 @ 2935 0 @ 2935 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9826 @ 2878 449 @ 2431 3273.5 CONNECTION GAS HIGH 51 ETHANE (C-2) 68 @ 2877 1 @ 2431 16.3 AVG 51 PROPANE (C-3) 45 @ 2521 0 @ 2671 18.5 CURRENT 0 BUTANE (C-4) 51 @ 2604 1 @ 2431 13.1 CURRENT BACKGROUND/AVG 36/23 PENTANE (C-5) 36 @ 2733 1 @ 2800 9.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY shale and siltstone, trace to common tuff PRESENT LITHOLOGY shale and siltstone DAILY ACTIVITY SUMMARY Continued testing BOPs; tests witnessed by AOGGC Representatives Jeff Turkington and Johnnie Hill; bottom pipe rams failed;; conducted Koomey Test; waited on verification for ram rubber; C/O rubbers on lower rams; test lower pipe rams; install/remove wear bushing; remove test joint, P/U single, M/U to test plug, L/D test plug, P/U wear bushing running tool, set wear ring, L/D single/running tool; CBU at 2183'; TIH from 2183' to 2400’; wash down from 2400 to 2430’; set parameters per DD; commence rotary drilling from 2430’; rotary drilling at time of report. Max Gas last 24hrs 51u = 1.02%. Approximately, 10.5 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 18, 2014 DEPTH 4181' PRESENT OPERATION Drilling TIME 03:00 YESTERDAY 2935' 24 HOUR FOOTAGE 1246 CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4146.30' 36.83 357.87 3911.08' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" NOV PDC bit A192482 7x11 2430' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 298.8 @ 3787' 2.9 @ 2936' 151.1 153.89945 FT/HR SURFACE TORQUE 7856 @ 3833' 940 @ 4020' 4136.7 5930.64232 AMPS WEIGHT ON BIT 12 @ 3461' 0 @ 4083' 5.5 7.11021 KLBS ROTARY RPM 123 @ 4020' 45 @ 4019' 118.4 118.00000 RPM PUMP PRESSURE 3428 @ 4067' 262 @ 4069' 3036.7 3267.12606 PSI DRILLING FLUIDS REPORT DEPTH 4018'/4018' MW 10.4 VIS 86 PV 46 YP 20 FL - Gels 9/16/21 CaCl2 11.12 FC 0/2 SOL 13.1 THTS 1.3 OIL 80.0/20.0 MBT - pH - WPS 261,312 HTHP 3.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 140 @ 3109' 2 @ 3918' 43.3 TRIP GAS 48 CUTTING GAS 0 @ 4181' 0 @ 4181' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 23808 @ 3109' 423 @ 3918' 6355.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 376 @ 3110' 10 @ 3918' 124.9 AVG 0 PROPANE (C-3) 117 @ 3193' 4 @ 3918' 46.8 CURRENT 0 BUTANE (C-4) 73 @ 3114' 0 @ 3249' 16.8 CURRENT BACKGROUND/AVG 32/43 PENTANE (C-5) 25 @ 3070' 0 @ 3251' 7.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY shale and siltstone, trace to common tuff PRESENT LITHOLOGY shale and siltstone, trace to common tuff DAILY ACTIVITY SUMMARY Rotary drilling from 2935’ to 3249'; BOP drill, driller simulated flow check and shutting in well; rotary drilling continued to 3874'; downtime-mud pump (MP) install new dresser sleeve rubbers on #1 MP suction line; continued drilling to 4018’ C&C; CBU @ 4005'; send downlink to zero tool; monitor well 10 min., hole static; pump dry job, B/.D top drive; TOOH from 4018' to 2285' on elevators; service rig, C/O valve and seat on # 2 MP; service ST-80; monitor hole on trip tank; TIH on elevators from 2285' to 4018'; commence drilling from 4018'; drilling at time of report. Max Gas last 24hrs 137u = 2.74%. Approximately, 15.9 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 19, 2014 DEPTH 5943' PRESENT OPERATION Drilling TIME 03:00 YESTERDAY 4181' 24 HOUR FOOTAGE 1762' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5783.29' 36.77 355.34 5219.02' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" NOV PDC bit A192482 7x11 2430' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 289.3 @ 4352' 10.3 @ 4798' 124.6 100.37401 FT/HR SURFACE TORQUE 13269 @ 5563' 1240 @ 5173' 6370.7 7612.52603 AMPS WEIGHT ON BIT 19 @ 4704' 0 @ 5850' 7.5 9.76128 KLBS ROTARY RPM 144 @ 5359' 113 @ 4702' 120.6 119.00000 RPM PUMP PRESSURE 3681 @ 5563' 288 @ 5102' 3382.1 3465.74787 PSI DRILLING FLUIDS REPORT DEPTH 5637'/5100' MW 10.45 VIS 78 PV 41 YP 21 FL - Gels 8/18/23 CaCl2 13.06 FC 0/2 SOL 13.1 THTS 1.5 OIL 80.1/19.9 MBT - pH - WPS 255,349 HTHP 3.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 201 @ 4232' 0 @ 5943' 62.1 TRIP GAS CUTTING GAS 0 @ 5943' 0 @ 5943' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 34748 @ 4619' 1265 @ 5719' 9975.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 1676 @ 4619' 47 @ 5639' 422.0 AVG 0 PROPANE (C-3) 576 @ 4619' 20 @ 5639' 162.3 CURRENT 0 BUTANE (C-4) 214 @ 4619' 9 @ 5719' 69.9 CURRENT BACKGROUND/AVG 20/62 PENTANE (C-5) 76 @ 5257' 1 @ 5638' 28.6 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY shale and siltstone, trace to common tuff and sandy siltstone PRESENT LITHOLOGY shale and siltstone, trace to common tuff and sandy siltstone DAILY ACTIVITY SUMMARY Continued rotary drilling from 4181' to 5943’; reaming one stand between 5860’ and 5943’ at time of report. Max Gas last 24hrs 201u = 4.02%. Approximately, 5.2 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 20, 2014 DEPTH 7407' PRESENT OPERATION Drilling TIME 03:00:00 YESTERDAY 5943' 24 HOUR FOOTAGE 1464' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7324.34' 36.37 355.84 6420.15' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" NOV PDC bit A192482 7x11 2430' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 260.7 @ 6909' 4.5 @ 7006' 116.0 100.91934 FT/HR SURFACE TORQUE 12301 @ 6175' 1955 @ 5958' 7323.6 7612.52603 AMPS WEIGHT ON BIT 22 @ 7395' 0 @ 6428' 7.6 7.97731 KLBS ROTARY RPM 124 @ 7244' 117 @ 7068' 120.0 119.00000 RPM PUMP PRESSURE 3926 @ 7338' 337 @ 6520' 3679.7 3777.86786 PSI DRILLING FLUIDS REPORT DEPTH 7,230' MW 10.65 VIS 99 PV 47 YP 24 FL - Gels 10/20/25 CaCl2 12.09 FC 0/2 SOL 13.9 THTS 1.4 OIL 81.9/18.1 MBT - pH - WPS 278,169 HTHP 4.2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 63 @ 6804' 4 @ 6874' 25.7 TRIP GAS CUTTING GAS 0 @ 7407' 0 @ 7407' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 10878 @ 6857' 872 @ 6874' 4064.4 CONNECTION GAS HIGH 11 ETHANE (C-2) 384 @ 6136' 22 @ 6874' 111.6 AVG 0 PROPANE (C-3) 168 @ 6899' 12 @ 6874' 56.7 CURRENT 0 BUTANE (C-4) 69 @ 6901' 4 @ 6874' 23.1 CURRENT BACKGROUND/AVG 19/25 PENTANE (C-5) 25 @ 6810' 1 @ 6911' 9.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY shale; traces of siltstone, tuff and sand PRESENT LITHOLOGY shale DAILY ACTIVITY SUMMARY CBU at 5943’; Rotary drilling from 5943’ to 6440'; change/replace pump expendables C/O swab and liner on MP #2; circulated at 6440'. SPR after working on mud pump, MP #1; rotary drilling from 6440' to 7390'; Circulated at 7390'. SPR after working on mud pump, MP #1; rotary drilling from 7390' to 7407’; drilling at time of report. Max Gas last 24hrs 63u = 1.26%. Approximately, 3.7 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 21, 2014 DEPTH 8015' PRESENT OPERATION TIH TIME 3:00 YESTERDAY 7407' 24 HOUR FOOTAGE 608' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8015' 36.50 355.79 6974.79' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" NOV PDC bit A192482 7x11 2430' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 215.1 @ 7971' 15.3 @ 7516' 101.6 40.09081 FT/HR SURFACE TORQUE 11672 @ 7860' 3308 @ 7928' 8086.6 5413.06263 AMPS WEIGHT ON BIT 17 @ 7492' 4 @ 8015' 9.2 4.86847 KLBS ROTARY RPM 121 @ 7449' 117 @ 7967' 119.8 120.00000 RPM PUMP PRESSURE 3824 @ 7456' 3637 @ 7514' 3738.2 3739.35955 PSI DRILLING FLUIDS REPORT DEPTH 8015' MW 10.7 VIS 100 PV 45 YP 25 FL - Gels 12/22/26 CaCl2 14.03 FC 0/2 SOL 15.2 THTS 1.6 OIL 80.7/19.3 MBT - pH - WPS 271,725 HTHP 4.0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 77 @ 7665' 11 @ 7425' 30.1 TRIP GAS 18 CUTTING GAS 0 @ 8015' 0 @ 8015' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 13756 @ 7665' 1935 @ 7425' 4947.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 342 @ 7665' 35 @ 7425' 119.4 AVG 0 PROPANE (C-3) 277 @ 7665' 23 @ 7425' 100.1 CURRENT 0 BUTANE (C-4) 150 @ 7665' 11 @ 7425' 55.4 CURRENT BACKGROUND/AVG 0/26 PENTANE (C-5) 41 @ 7932' 7 @ 7617' 22.6 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY shale; traces of siltstone and sandstone PRESENT LITHOLOGY N/A Tripping DAILY ACTIVITY SUMMARY Rotary drilling from 7407’ to 7636’; change/replace pump expendables, C/O 2 swabs on MP #1, Circulate on MP #2; rotary drilling from 7636’ to TD at 8015' MD; CBU; Pump Dry Job; TOOH 8015 to 6563’ on elevators; backreaming from 6563' to 6467'; TOOH from 6467' to 3731’ on elevators; B/D top Drive; TOOH to 2390’; service rig while monitoring well to make sure well is static; CBU at 2380’; TIH from 2380’; TIH at time of report. Max Gas last 24hrs 73u = 1.46%. Approximately, 1.5 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 22, 2014 DEPTH 8015' PRESENT OPERATION RIH with wireline TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" NOV PDC bit A192482 7X11 2430' 8015' 5585' 51.92 1-1-WT-N-X-I-NO TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 8015' MW 10.6 VIS 89 PV 43 YP 26 FL - Gels 10/20/28 CaCl2 12.09 FC 0/2 SOL 14.7 THTS 1.4 OIL 82.0/18.0 MBT - pH - WPS 278,790 HTHP 3.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 37 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY TIH from 2380’ to 6234’; C&C fill pipe at 6234; B/D top drive, continue TIH to 7970; C&C wash down to 8015’; C&C monitor well and pump dry job; B/D top drive; TOOH to 5271’; TOOH to 2173’ on elevators; monitor hole for 15mins., hole static; continue TOOH to 1031’ on elevators; R/B HWDP; PJSM for unloading radioactive sources; L/D sources and BHA; clean and service rig; conduct derrick inspection; monitor hole with trip tank; R/U wireline for Open Hole Log Run 1A, test tools; RIH on Open Hole Log Run 1A at time of report. Max Gas last 24hrs 37u = 0.74%. Approximately, 2.0 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 23, 2014 DEPTH 8015' PRESENT OPERATION L/D HWDP TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 8,015'/7,010' MW 10.6 VIS 99 PV 42 YP 26 FL - Gels 9/19/27 CaCl2 12.09 FC 0/2 SOL 14.7 THTS 1.4 OIL 82.0/18.0 MBT - pH - WPS 278,790 HTHP 3.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY RIH on Open Hole Log Run 1A to 8000’, log out to shoe, remove nuclear sources; L/D Run 1A tools; P/U Open Hole Log Run 2 tools, load nuclear source; RIH with Open Hole Log Run 2 to 5600’. Make repairs to suction valve pit 5; Continue Open Hole Log Run 1B clean suction manifold on mud pump MP#1, general housekeeping/preventive maintenance; L/D tools and nuclear source from Run 1B. R/D wireline loggers; L/D collars and jars; L/D 2 stands of HWDP into pipe shed and preparing to change our rams at time of report. Max Gas last 24hrs 0u = 0.00%. Approximately, 0.5 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 6 DAILY COST $5800 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 24, 2014 DEPTH 8015' PRESENT OPERATION Running casing TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 8,015'/7,010' MW 10.5 VIS 103 PV 43 YP 26 FL - Gels 10/20/27 CaCl2 12.09 FC SOL THTS 1.4 OIL 81.5/18.5 MBT - pH - WPS 277,580 HTHP 3.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 97 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 12/6 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY R/B 5 stands of HWDP. L/D 6 joints collars and float sub; drain stack, function rams, flush stack; close blind rams; PJSM, C/O upper 4" to 7" fixed rams; I/R wear bushing, pull wear ring, set test plug; R/U to test BOPs; test BOPs; R/D testing equipment; B/D choke and kill lines; R/U to run casing, PJSM with GBR; run casing to 2200', CBU, fill pipe every 10 joints; RIH from 2200' to 4241', fill pipe every 20 joints; C&C at 3998', C/O GBR HPU due to mechanical issues; RIH to 4800', CBU, fill pipe; running casing at 5410’ time of report. Max Gas last 24hrs 97u = 1.94%. Approximately, 0.3 ounces of material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 4 DAILY COST $5800 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 25, 2014 DEPTH 8015' PRESENT OPERATION Cementing TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 8015'/7010' MW 10.4 VIS 95 PV 37 YP 25 FL - Gels 10/20/27 CaCl2 13.06 FC 0/2 SOL 13.2 THTS 1.5 OIL 80.6/19.4 MBT - pH - WPS 266,158 HTHP 3.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 94 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/1 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY Run 7" casing to 6550' filling pipe every 20 joints; C&C fill pipe/CBU at 5637'; run 7" casing to 7475', filling every 5 joints; C&C; run casing to 7841', W/D to 8003' C&C; P/U cement head; R/U/D to run casing M/U hangar/landing joint, drain stack, land hangar; break circulation; R/D CRT; install cement lines, M/U cement head, break circulation; PT cement lines; PJSM for cement job; PT cement lines, pump spacer, drop plug; C&C/D; pump tail cement, drop top plug, displace with mud; set plug, open diverter; C&C; L/D casing tools; service rig; load 102 jnts TC2 3.5" tubing in shed, remove thread protectors. P/U M/U Johnny Wacker to X-over; second cementing operation in progress at report time. Max Gas last 24hrs 94u = 1.88%. Shakers cleaned during cementing, no material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 4 DAILY COST $5710 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 26, 2014 DEPTH 8015' PRESENT OPERATION RIH w/ 3.5" cement stinger TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 8,015/7,010' MW 10.4 VIS 95 PV 37 YP 21 FL - Gels 9/18/25 CaCl2 13.06 FC 0/2 SOL 13.0 THTS 1.5 OIL 80.3/19.7 MBT - pH - WPS 276,350 HTHP 4.0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY Complete cementing, bleed pressure; check flowback; R/D cementers L/D landing joint; C/O elevators; clean cellar box; P/U 1 joint DP and wash tool, casing head and clean stack; L/D wash tool; P/U packoff/running tool; set packoff; RILDS; PT pack off; L/D casing equipment and stabbing board; change rams, set test plug. C/O top and bottom rams to VBRs. C/O bails; continue processing 3 1/2" tubing; offload 470 bbls of MOBM from pits; begin cleaning pits; R/D MWD sensors; P/U test tools; R/U to test BOP’s; test BOP’s, AOGCC John Crisp waived the right to witness; R/D from BOP tests; L/D test joint; TIH R/U GBR casing tongs/elevators and crummies in preparation to RIH 3.5" cement stinger string. RIH 3.5” cement stinger string at time of report. Max Gas last 24hrs 0u = 0.00%. No material collected from ditch magnet. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4870 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 27, 2014 DEPTH 8015' PRESENT OPERATION C&C TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 8015'/7010' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs DAILY ACTIVITY SUMMARY RIH to 1291' TOOH L/D39 joints of 3 1/2 tubing, R/D L/D tubing equipment; clean and clear rig floor and pipe shed; P/U BHA; P/U L/D, M/U tools, BHA, bit and scrapers; RIH with 7 stands HWDP and 21 stands DP to 2777' top of DV tool at 2807' Rotate same on depth according to pipe tally; drill plugs, CBU; rotate/work string mill thru DV collar; W/D and ream to 3064'; B/D top drive; TIH with tubing/DP to 6804' breaking circ at 6414'; B/D top drive and C&C at 6804' B/D top drive, TIH with tubing to 7844'; tag fill, ream W/D to 7855'; C&C L/D top single in stand; CBU at 7845'; cleanout/test R/U test chart, cement hose, valves to test 7" to 4000psi for 30mins on chart; R/D and B/D kill/cement lines; TOOH from 7845' to 7499’; L/D 11 singles from string; TOOH to 5971’; RIH to 7855'; C&C at time of report in prep to displace mud; Max Gas last 24hrs 0u = 0.00%. Approximately 2oz material collected from ditch magnet, derived from polishing. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4870 REPORT BY Foradas REPSOL E+P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 28, 2014 DEPTH 8015' PRESENT OPERATION L/D BHA, Cleaning drill floor TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Complete C&C; CBU; PJSM on displacement; displace to completion fluid offloading MOBM returns from pit 4, clean out mud system, flow box, pipe rack, shaker beds and flow trough, displace to completion fluid pump 50bbls spacer and 314bbls completion brine at 7851'. B/D top drive, clean out trip tank for swap to completion fluid; get protectors on floor buggy; completion-trip tubing/DP from 7851' to 1589’, continue flushing all lines in pits, offload dirty H2O to vac trucks; clean mud pits 1-6; finish completion trip; L/D completion BHA and cleaning drill floor at time of report. Max Gas last 24hrs 0u = 0.00%. Approximately, 8.3 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4795 REPORT BY Foradas REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 29, 2014 DEPTH 8015' PRESENT OPERATION POOH w/ 3.5" Tubing TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.15 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY L/D completion BHA; R/U to run 3 ½” tubing; R/U to run casing; waiting on 3rd party tools, GBR tubing torque turn computer; P/U and test torque turn equipment; RIH w/ 12 joints of 3 ½” tubing to 2395’; shut down to inspect pipe skate and C/O hydraulic fittings on casing power unit; load sample carriers in pipe shed; continue to P/U completion tubing from 2395’ to 6782’; POOH with 3 ½” tubing from 6782’ to 2798’; racking back stands in derrick, up WT to 65K / down WT to 60K at 4501’. Max Gas last 24hrs 0u = 0.00%. Approximately, 7.5 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4795 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 30, 2014 DEPTH 8015' PRESENT OPERATION Prepare to remove pipe/tool shed TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Complete POOH 3 ½” tubing trip; prepare to test sample carrier bbls; BHA ready pipe shed to P/U carriers; C/O elevators; P/U 1st carrier; M/U bull plug and X/Os; P/U single joint DP and M/U X/Os; torque all CXNs to spec; R/U test equipment; completion-formation testing sample carrier to 500psi for 5 minutes, 5000psi, for 15 minutes; P/U, L/D make up tools, BHA open rams; R/D test hose; drain assembly; break out single joint and L/D same; remove testing plug; L/D 1st and P/U 2nd carrier; install test plug; R/U to test equipment; test 2nd sample carrier to same specs; R/U to run wireline; test tools to surface; RIH for cased hole logs with CMT bond log assembly to 7885’; POOH and R/D wireline; P/U 575’ of 3 ½” tubing; torque turn to optimum make up torque of 2500 ft/lbs; C&C pump volume plus annular volume at 575’ W/ 10.4 brine; clean pill pit and trip tank; POOH from 575’ to surface; cut drill line; prepare to remove pipe / tool shed. Max Gas last 24hrs 0u = 0.00%. Approximately, 4.0 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4795 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE Mar 31, 2014 DEPTH 8015' PRESENT OPERATION Working on Tools in Pipe Shed TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Demobilize pipe shed sections 3-6 in preparation for coil tubing unit; R/U heaters onto skate section of pipe shed; R/U skate controls and lighting in pipe shed; R/U to test BOPs; test BOPs; LD test tool Koomey test; pull test plug and R/D test equipment; B/D choke manifold and all lines; wait on 3rd party tools; conduct rig service/maintenance; assist Metro w/ working on tools in pipe shed. Max Gas last 24hrs 0u = 0.00%. Approximately, 2.5 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4015 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 1, 2014 DEPTH 8015' PRESENT OPERATION RIH w/ Tubing and Pressure Test TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue to wait on 3rd party tools (tubing handing equipment); assisting Metrol w/ pipe shed; P/U perforation guns; M/U time delay firing head and bull nose; pull mouse hole in preparation to M/U packer; load pipe shed with handling equipment; install 2 7/8” elevators; RIH w/ 2 7/8” tubing; P/U packer using single of 3 ½” tubing; M/U tools and BHA; TIH with tubing from 1213’ to 4734’ w/ 3 ½” tubing torque turn to 2300 ft/lb; filling tubing on fly w/ 10.4 brine; installing Metrol relays as required; testing tubing to 4000 psi for 5 minutes at 1718’, 2693’, 3762’, and 4734’; WT up 50K, dn WT 50K at 1718’, up WT 54K dn WT 54K at 2693’; continue to RIH w/ tubing and pressure test. Max Gas last 24hrs 0u = 0.00%. Approximately, 3.0 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 2, 2014 DEPTH 8015' PRESENT OPERATION L/D 3rd Party tools and Tubing Handling Equipment TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue to RIH with 2 7/8” tubing from 4734’ to 7620’, while pressure testing tubing to 4000 psi for 5 minutes at 5704’, 6664’, and 7620’; P/U space out joints and RIH to 7683’, up WT 82K, dn WT 75K; R/U to run wire line; RIH w/ wire line to RA sub at 6683’; POOH; R/D wire line; pull tubing to 7678’; R/U wire line; RIH w/ wire line to 6681’; POOH w/ slick line / wire line from 6681’ and R/D; configure tally and spacer out to set packer/tubing hanger; M/U hanger and L/J; set packer; set dn 20K compression on packer at 7560’ / RA sub at 6681’ and land hanger; run in to lock dn screws and test hanger seal to 5000 psi for 10 minutes; liner clean out; R/U to test annulus w/ PT lines to 4500 psi, and test to 1100 psi and hold for 15 minutes; stage up to 4000 psi for 10 minutes; secure well set BPV w/ Vetco rep.; L/D 3rd party tools and tubing handling equipment. Max Gas last 24hrs 0u = 0.00%. Approximately, 1.5 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 3, 2014 DEPTH 8015' PRESENT OPERATION Testing Koomey Lines to Hydraulic Master Valve TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Nipple dn BOPs; pull riser, un-chain stack; R/D Koomey hoses; nipple dn choke and kill lines; nipple dn annular and mud cross; prepare cellar and wellhead clean and clear of tools and equipment; NU/ND completion tree; clean tubing hanger; N/U frac tree, swab, and master valve assembly; test bonnet to 5000 psi for 10 minutes; test master and 2nd master to 7500 psi and hold for 10 minutes; Halliburton and XPRO M/U hard lines to cellar; M/U hard line to tree and annulus; M/U riser from goat head to coil tubing on rig floor; H/U HCR kill Koomey lines to hydraulic master valve and function test. Max Gas last 24hrs 0u = 0.00%. Approximately, 1.0 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 4, 2014 DEPTH 8015' PRESENT OPERATION Prepare R/U and test BOPs TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Complete function testing Koomey lines to hydraulic master valve; fill lines and PT EXPRO lines to 3000 psi; fill PT cementers lines to annulus valve to 2500 psi; PT all other lines and body test on coil tubing BOPE to 6900 psi; pressure up annulus to 2700 psi to function LPR-N / OMNI valves; pressure up to 2200 psi for 6 minutes, observed guns fire at 0530; testing perform DFIT w/ 15 bbls LVT; C/O charge pump; ready equipment for R/U injector head; P/U coil lubricator and M/U to BOP; nipple up/dn BOPs, well head R/U injector head to lubricator on rig floor; H/U hose to coil tbg BOPs and R/U drain hoses from injector head; fluid pack lines for testing; testing finalize frac model; PJSM on frac job; PT lines and begin frac job; shut in well and monitor for 15 minutes; B/D and clear lines; open and bleed back; prepare R/U and test BOPs. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 5, 2014 DEPTH 8015' PRESENT OPERATION Displace Tubing w/ 10.4 MW Brine TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Test BOPs (body test) 250 low, 3500 high for 15 minutes; R/D frac line off goats head; R/U cement line to wing valve; cycle OMNI and LPR-N valves; test CT blinds and pipe rams 250 low, 3500 high for 15 minutes; test whiteness waved by AOGCC Rep; CT blow dn coil to EXPRO; walk thru w/ EXPRO on equipment and ESDs; PJSM on open up LPR-N and flow well; attempt to open LPR-N; begin RIH w/ CT; attempt to function LPR-N/OMNI valves down hole; attempt to open OMNI valve while pumping Nitrogen; not successful in functioning valve; displace tubing w/ 10.4 MW brine. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 6, 2014 DEPTH 8015' PRESENT OPERATION RIH 2.8” Drift Run TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.4 VIS 27 PV YP FL Gels CaCl2 FC SOL THTS OIL MBT pH WPS HTHP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY R/U lines from mud pits to coil tubing unit and continue to displace w/ 10.4 ppg brine; R/U Nitrogen to blow dn coil tubing unit; POOH coil tubing; complete operations on charge pump and discharge line; prepare to R/D coil tubing unit; conduct PJSM on nipple up/dn BOPs, well head to R/D coil tubing; remove injector head; pull lubricator and set back on coil tubing; set CT BOPs safely to side and secure on rig floor; wait on 3rd party personnel prep for wire line, on rig floor and set up to pump dn tubing, take returns from annulus to pits; PJSM on wire line operations; M/U X/O from flange to OTTIS cxn; R/U wire line lubricator; R/U to test lubricator against master valve and fill lubricator; test/chart lubricator to 3500 psi; RIH 2.8” drift run. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 7, 2014 DEPTH 8015' PRESENT OPERATION Nipple Down Riser, Tree TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 12.4 VIS -- PV 13 YP 21 FL -- Gels 9/13/15 CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH 9.1 WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY RIH 2.8” drift run, tag up at 6746’; POOH; R/D drift, R/U to 2” drift; RIH and tag up at 6873’; blow dn kill line; R/U one shot slick line tool, RIH; stage tool at 6686’ slickline measurement, 6628’ tubing (TBG) tally measurement; downhole power unit with TBG punch engaged after time delay; POOH and R/D TBG punch; R/U 2nd TBG punch run; R/U one shot slick line tool and RIH; stage tool at 6685’ slickline measurement, 6627’ TBG tally measurement; downhole power unit with TBG punch engaged after time delay; POOH; R/U slickline DPU/TBG punch; C/O mud system, take on 12.4 ppg brine; offload 10.4 ppg brine; clean pits to make room for displacement volume; R/U kill line to mud cross for circulating dn TBG; attempt to circulate 12.4 ppg dn TBG and up annulus; pressure up to 2000 psi w/ minimal returns; R/U wireline TO for 2.80 drift run; PT lubricator to 3500 psi; RIH w/ 500 psi on TBG to 6881’ tagged up on previous shots, work wireline w/ no restrictions, POOH; M/U single shoot, PT lubricator and RIH at 100’/min, hold 1000 psi on TBG at punch point at 6625’ lined up to monitor returns from annulus; no psi drop after punch time; POOH with wireline; R/D wireline; R/U to pump dn annulus and attempt to open OMNI valve; pressure up to 2625 psi and monitor TBG psi; TBG and annulus stabilized at 2450 psi; OMNI valve still closed; R/U to circulate 12.4 ppg TBG and up annulus to pits; start at 1 bbl/min w/ 2900 psi, as psi dropped, work pump up to 2.5 bbl/min w/ 1200 psi; continue to displace 10.4 w/ 12.4 ppg brine; 40 spm at 1150 psi; blow dn lines after displacement; VETCO set BPV, R/U to test BPV from annulus; test/chart back pressure valve for 5 minutes at 300 psi; bown dn pump lines; nipple up/dn BOPs; nipple dn riser, tree. Max Gas last 24hrs 0u = 0.00%. Approximately, 0.5 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 8, 2014 DEPTH 8015' PRESENT OPERATION R/U to Test BOPs TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 12.4 VIS 40 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY N/D frac tree; install BOP cart; R/U hydraulic ram to cart; fold up Herculite from frac job; R/D H.P. lines from annulus; N/U BOPs; install single gate/mud cross; retract cattle chute to allow room for crane pick; set double gate/annular onto BOP trolley; set cattle chute back; safe out cellar area; N/U double gate/annular; N/U BOPs, choke hose/kill hose; M/U Koomey lines; test gas alarms/PVT system; clean out flow box, set riser, PT X-Pro lines from choke manifold to 3000 psi w/ little red; P/U test tools, PJSM w/ Vetco rep for setting test JT; R/U to test BOPs; fill stack and choke manifold w/ water. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 9, 2014 DEPTH 8015' PRESENT OPERATION Monitoring Well after Pressure Testing TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.4 VIS 40 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/8u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Test BOPs annular 250 psi low, 3500 psi high, remaining tests at 250/5000 psi low/high; L/D test tool lines, choke manifold and top drive; retrieve test dart; POOH back pressure valve; R/U landing joint/TIW valve; PJSM for pulling hanger; back out lockdown screws; unseat tbg hanger/string, open ports on packer; shut annular; bleed off downhole pressure to EXPRO through choke manifold; pump 0.5 bbl/min OD, 12.4 ppg w/, R/D tbg and return to EXPRO through choke manifold; circulate 11.5 ppg at 1 bbl/min w/ 500 psi; stage up to 4 bbl/min w/ 1400 psi; up wt 70K; unseat packer; P/U 105K and hold to unseat, verity unseating and continue to circulate b/u at 2 bbl/min w/ 400 psi; B/D top drive and pull hanger, up WT 90K; monitor well. Max Gas last 24hrs 219u = 4.38% @ 16:18. Approximately, 0.5 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 10, 2014 DEPTH 8015' PRESENT OPERATION Shut In Well / Monitoring PSI at Choke TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.8 VIS 47 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/11u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue to monitor well, circulate at 31 spm, 490 psi, 85K U/W, 70K D/W; L/D hanger and pup jnt; blow dn top drive; shut annular/choke manifold, well flowing, monitor casing pressure, 02:30hrs at 140 psi, 03:30, 04:30, and 05:30hrs at 150 psi; 06:30, and 07:30hrs at 160 psi; 08:30hrs at 160 psi; bleed off to EXPRO through choke manifold, open annular; set packer, 85K U/W, 65K D/W; circulate and condition (C&C) 31 spm at 400 psi; circulate 11.1 ppg dn tbg taking returns to mud pits at 2 bbl/min w/ 285 psi; circulate at 2 bbl/min w/ 375 psi, cutting weight back to 10.7 ppg while running centrifuge, w/ 10.7 ppg all around, final circulation 3 bbl/min735 psi; B/D top drive; P/U to open ports on packer; shut in well and monitor psi at choke. Max Gas last 24hrs 163u = 3.26% @ 11:25. Approximately, 0.25 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 11, 2014 DEPTH 8015' PRESENT OPERATION Continue to L/D tools and BHA TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.1 VIS 47 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/4u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Unseat packer; 85K U/W, 62K D/W; L/D acoustic repeater from top single; well flowing, install TIW, shut annular, TIW, and choke manifold, and monitor pressure; monitor SICP, 02:30hrs at 50 psi, 03:30hrs at 80 psi, 04:30hrs at 120 psi, 120 psi final SICP; L/D single, remove TIW, set packer, 82K U/W, 61K D/W; R/U to rev. circ., circulate 35 spm at 450 psi; blow dn top drive; R/U to utube taking returns through tbg; unseat packer, 81K U/W, 60K D/W; R/U headpin, H.P. hose to circulate dn tbg; pump 13 ppg dry job; POOH w/ tbg from 7621’ to 3000’ U/W 84K; remove Metrol relays on the rig floor, 50K U/W at 3000’; continue to TOH w/ tbg from 3000’ to 1136’; U/W 35K; M/U tools, BHA; PJSM for L/D completion BHA; L/D tools, rack back stands in derrick from 1136’ to 773’; continue to L/D tools and BHA. Max Gas last 24hrs 100u = 2.00% @ 08:30. Approximately, 0.50 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 12, 2014 DEPTH 8015' PRESENT OPERATION RIH w/ Tubing TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.1 VIS 48 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue to POOH and L/D makeup tools and BHA; L/D stand that was hole punched; breaking every cxn on stands 1- 4, making sure stands not plugged off; swap elevators for 2 7/8”; L/D BHA; monitor hole w/ trip tanks; prep for RIH while BHA is prepared by 3rd party; conduct rig service from 12:00 to 15:30; PJSM to P/U BHA; M/U tail pipe, sample/gauge carriers, LPR-N and OMNI valves; X-nipple and install Metrol relays as per running order; to 1050’ w/ 3.5” 9.2 lb/ft tbg, torque turn to 2300 ft/lb optimum, run at 60’/min; fill tbg w/ 10.4 non-polymer brine; R/U and PT BHA to 3500 psi for 5 min; continue to RIH w/ tbg. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 13, 2014 DEPTH 8015' PRESENT OPERATION Testing BOPs TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.1 VIS 48 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/3u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue to RIH w/ 3.5” tbg from 1050’ to 6013’, U/W 53K, D/W 44K; continue to RIH from 6013’ to 7611’, space out to 7578’; R/U to test packer from kill line; test to 500 psi and chart; hook up gauges in cellar; ND/NU crane tree to rig floor; hook up Koomey lines to Koomey unit for frac tree master HCR valve; PJSM on N/U tree and coil BOP; R/U hoses to master valve; function test master; C/O elevators; P/U string to dn WT; break out floor valve; visually monitor tbg for 10 min; M/U dbl pin and 10K flange TQ to spec. SD 17K on packer; shoe at 7585.56’; M/U tree using crane; N/U BOPs; install control lines to BOPs and function test; N/U CT BOPs; M/U CT lubricator; begin R/U EXPRO hard line on tree; PJSM on R/U CT injector; pick CT injector head over windwalls and transfer to TD; secture control lines to windwall; M/U injector head to lubricator; install hyd lines to master valve; install drain line to injector; chain injector head back to derrick; R/U EXPRO lines; R/U to test CT BOP; PJSM on testing CT BOP; begin testing BOPs; fluid packing coil tbg lines, BOP w/ LVT; P/T coil tbg BOPs at 250 psi low/3500 psi high; continue to test BOPs. Max Gas last 24hrs 51u = 1.02%. Approximately, 0.75 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 14, 2014 DEPTH 8015' PRESENT OPERATION Pumping Nitrogen TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.1 VIS 49 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue testing BOPs; C/O API ring under crown valve on frac tree cont, w/ test; P/T coil tbg BOPs w/ LVT 200; flush coil/tree w/ Nitrogen; P/T tbg string to 3500 psi w/ Nitrogen; bleed off to EXPRO; PJSM on flowing well; close rams and annular; pressure up annulus to 1570 psi to open L-PRN; maintaining max 1600 psi; open up and flow to EXPRO; RIH w/ CT to 1500’, 4500’, 5500’, and 6500’, lift w/ N2 to EXPRO, maintaining max 1600 psi on annulus; take on 220 seawater to pits; begin mixing friction reducer; R/U hoses to coil tbg to transfer fluid; continue lifting from 6500’; shut dn flow to EXPRO; continue mixing friction reducer; begin transferring fluid to coil tbg from pits; RIH w/ CT to 7570’; pumping 0.7 to 1.8 bbls/min; tag/jet thru at 1.8 bbls/min up to 4800 psi; maintaining 1500-1600 annulus psi; continue to RIH to 7720’, pump 1.8 bbls/min; POOH to 7585’; take on additional 60 bbls seawater to pits; maintaining 1500-1600 annulus psi; POOH from 7585’ to 1000’, pumping 1.8 bbls/min, maintaining 1500-1600 annulus psi; RIH from 1000’ to 4000’, pumping Nitrogen at 300 SCF min. Continue to pump Nitrogen. Max Gas last 24hrs 0u = 0.00%. Approximately, 0.25 ounces of material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 15, 2014 DEPTH 8015' PRESENT OPERATION Displacing Acid Pill w/ Nitrogen TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.1 VIS 49 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue pumping Nitrogen at 4000’, at 300 SCF min; RIH to 6500’, pump Nitrogen at 300-700 SCB; pull tbg from 6500’ to surface; pull coil above crown valve and monitor well; continue to flow well to EXPRO; maintaining 1500-1600 psi on annulus; RIH to 5000’, continue to flow well to EXPRO; maintaining 1500-1600 psi on annulus; pump out of hole 1.8 bbls/min at 4400 psi, 150’/min; take return flow to EXPRO, maintaining 1500-1600 psi on annulus; CT at surface; continue to flow well to EXPRO; maintaining 1500-1600 psi on annulus; RIH w/ CT to 6500’ lifting w/ Nitrogen to EXPRO; begin pumping acid; RIG to 7710’, spot 25 bbls acid; POOH w/ coil tbg, maintaining 1500-1600 psi on annulus; RIH w/ coil tbg to displace acid pill to EXPRO w/ Nitrogen; displacing acid pill. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 16, 2014 DEPTH 8015' PRESENT OPERATION RIH w/ Coil Tubing TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.1 VIS 50 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY RIH w/ coil tbg to 7620’, tag up, and displace acid pill to EXPRO; POOH w/ coil tbg; flush coil w/ calcium Bi-carbonate, purge w/ Nitrogen (N) to EXPRO; bleed off (N) from coil to EXPRO, shut crown valve in, continue monitoring well, taking returns to EXPRO; clean pill pit in preparation for taking on seawater and mixing high vis pill; mix high vis sweep and friction reducer; RIH from surface to 6500’ lifting w/ (N) to EXPRO, maintaining 1500-1600 psi on annulus; pump 166 bbls seawater w/ friction reducer from pits at 1 bbl/min, taking return flow to EXPRO, maintaining 1500-1600 psi on annulus; mix friction reducer into 290 bbl vac truck; swap over to vac truck, pump in hole to 7750’ up to 3 bbls/min of seawater from vac truck, maintaining 1500-1600 psi on annulus; circulate 5 bbl tandem sweeps (33 bbls total) from pits to clean out from 7750’ to 7800’ at up to 3 bbls/min; circulate hole clean w/ seawater; maintaining 1500-1600 psi on annulus; POOH to 2500’ lifting w/ (N) to EXPRO; maintaining 1500-1600 psi on annulus; begin to RIH from 2500’ w/ coil to make sure perforated section is still clear. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 17, 2014 DEPTH 8015' PRESENT OPERATION Open to EXPRO/ Maintaining Pressure on Annulus TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.1 VIS 50 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Continue to RIH w/ coil tbg to 7738’ to make sure perforated section is still clear, maintaining 1500-1600 psi on annulus (mntng P on annulus); POOH from 7738’ after lifting w/ (N), mntng P on annulus; shut in master/HCR, bleed off coil (N) to EXPRO; shut in crown valve, mntng P on annulus; PJSM on N/U, N/D BOPs, wellhead; remove coil injector unit/lubricator w/ crane, mntng P on annulus; remove flanged X/O for coil lubricator; install wireline (WL) X/O on top of coil BOPs; use crane to R/U WL BOPs/lubricators; R/U WL sheaves, mntng P on annulus; M/U rope socket; R/U lubricator; PJSM on PT lubricator; attempt to fill and PT; R/D and trouble shoot lubricator; R/U and fill lubricator using Glycol; PT lubricator to 3000 psi for 5 min; break below lubricator; M/U WL tools and function test electrical continuity; M/U perforating guns; M/U lubricator and PT break to 3000 psi; RIH w/ WL guns to 7735’; correlate depth; fire guns from 7650’ to 7641.3’ WLM; POOH from 7641.3’ WLM to surface; shut well in; break lubricator; check tools; open up to EXPRO, mntng P on annulus. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 18, 2014 DEPTH 8015' PRESENT OPERATION Waiting on Third Party Tools TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 11.0 VIS 50 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Lined up taking returns to EXPRO, monitor well, maintaining 1500-1600 psi on annulus (mntng P on annulus); R/U Schlumberger Eline; M/U rope socket; prep tools for run number (2); P/U lubricator; R/U Little Red to test lubricator w/ LVT; continue to mntng P on annulus, monitor well lined up to EXPRO; PJSM on PT and WL run; R/U fill and PT w/ Little Red to 3000 psi for 5 min; RIH w/ WL and tag at 6868’; POOH w/ WL, monitor tbg and annulus psi; R/U to pump dn tbg; bleed off annulus psi in order to close LPR-N; bleed off tbg psi; PJSM on R/D WL; R/D WL lubricator and stage in pipe shed; R/D WL BOP and fly off rig floor w/ crane; PJSM on R/U CT; off load seawater from pits, cycle LPR-N; line up to pump dn tbg; pump 18 bbls, 8.9 PPG seawater mixture at up to 2 bbls/min, 1400 psi; verify LPR-N open; bleed back to EXPRO; consolidate and blend brine in pits to 10.8 ppg; wait on 3rd party tools, slick line, and brine truck; B/dn EXPRO line; remove ice from derrick; receive brine, mix w/ existing pit volume; continue waiting on 3rd party tools. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 19, 2014 DEPTH 8015' PRESENT OPERATION RIH W/ PX Lock TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.7 VIS 47 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY Receive 113 bbls brine at 10.1 ppg, mix w/ existing pit volume, ending brine at 10.7 ppg; pump 70 bbls dn tbg of 10.7 ppg brine, 31 spm at 1600 psi; B/D cement line after pumping; R/U to pump dn annulus to maintain 1500-1600 psi on annulus; R/U Halliburton slickline (SL) to fish Schlumberger’s guns; R/U lubricator/sheaves and tools, Little Red PT lubricator to 3000 psi w/ LVT; RIH to 7550’, no fish, POOH; R/D lubricator and secure in derrick; HES SL crew timed out; R/D lubricator extensions and WL valve; remove SL X/O off of CT BOP; install CT flange to OTIS X/O; R/D CT hyd lines; remove Schlumberger lubricator from pipe shed; PJSM on N/dn CT BOPs and fly out w/ crane; N/dn BOPs, bring up lubricator extensions for CT from pipe shed; break extensions apart; N/D CT BOPs; R/D CT hyd hoes to cellar; M/U extension piece onto bottom of CT BOP; Fly out BOP and extension pieces using crane onto truck; N/U SL X/O to crown valve and TQ to spec, M/U SL BOP; waiting on 3rd party SL crew; PJSM on R/U SL; R/U SL; PT lubricator w/ LVT from Little Red to 3600 psi, 5 min; RIH w/ SL gauge rung to 6750’; POOH; swap BHA to PX lock plug; PT lubricator w/ LVT from Little Red to 3600 psi, 5 min; RIH w/ PX lock. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 20, 2014 DEPTH 8015' PRESENT OPERATION Monitoring Well TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.7 VIS 47 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY RIH w/ PX lock and set at 6675’; POOH; swap SL tools, PT lubricator w/ Little Red to 3600 psi; RIH w/ prong run; set prong; POOH; Little Red test prong to 3000 psi for 10 min; R/D SL sheaves, lubricator, and BOP; Little Red, pump 30 bbls hot water through mud cross on tree to EXPRO; B/D w/ Nitrogen; R/D EXPRO w/ crane; R/D frac tree; Pick w/ crane and L/D on rig mat; install 4.5” elevators; bleed off annulus through super choke; double stack power tongs to rig floor; P/U, L/D M/U tools, BHA verify no trapped psi; open pipe rams; strip up thru annular 20”; break out 10K flange X/O and M/U X/Os to OTIS cxn using GBR double stacked tongs; PJSM on R?U and test SL lubricator; M/U WL pump tee, valve, and lubricator; test to 3000 psi using LVT from Little Red; RIH to 6675’ w/ 2” SB prong pulling tool; latch on; POOH; L/D prong pulling tool; P/U PX plug pulling tool; PT to 3000 psi using LVT from Little Red; RIH to 6675’, latch on, POOH; R/D, L/D SL; R/U to pump dn tbg, reverse circulate; fill and PT lines to 3000 psi for 5 min; pump 9 bbls dn tbg to verify LPR-N open; line up/dn kill line and shear RD at 2800 psi; shut don pumps, open annulus and un-seat packer; reverse circ thru choke manifold at up to 3 bbls/min, 400 psi; 1 ½ complete circulations at RD sub; visually monitor well as static; reverse circulating assembly; drain gas buster observed well u-tbg; pump 10 bbls 11.2 ppg brine dn tbg, 50 spm; continue cleaning operations. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 21, 2014 DEPTH 8015' PRESENT OPERATION RIH w/ Packer Assembly TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.7 VIS 45 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY POOH; R/B 1 stand; B/D cement line; P/U test tools, B/D kill/choke lines; P/U landing jnt, set hanger, test dart, install test jnt; R/U to test BOPs; PT test BOPs, annular 250/3500 psi; remaining BOPs and equip 250/5000 psi; L/D test tool; pull test dart; R/D test equip and B/D lines; P/U landing jnt and M/U to hanger; bolds and pull hanger and 3 ½ tub to rig floor; UpWT 89K; PJSM on tripping tbg; L/D landing jnt and tubing hanger; ready rig floor for tripping; M/U floor valve to X/Os; monitor well (static); stand back 1 stand in derrick; observed stand wet, pump 15 bbl 11.1 ppg dry job; B/D top drive; trip tbg from 7393’ to 983’, removing Metrol relays; PJSM on L/D BHA; TOH w/ BHA to surface; service, break, and L/D tools; open drain valve; standing stands of tbg back in derrick; remove Metrol relays; L/D tbg tail jnts to pipe shed; P/U 3rd party tools, clean/clear rig floor and pipe shed; prep to P/U tools; load shed w/ tbg; P/U, rack back 1 stand; P/U 2 jnts and packer assy; M/U packer assy; begin to RIH w/ packer assy. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco REPSOL E&P USA INC. North Slope DAILY WELLSITE REPORT Qugruk 5A REPORT FOR Scarbough, Whittenberg DATE April 22, 2014 DEPTH 8015' PRESENT OPERATION POOH w/ Tubing TIME 3:00 YESTERDAY 8015' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 103', 9.625" @ 2305', 7" @ 7992' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 7848'/6533' MW 10.7 VIS 46 PV -- YP -- FL -- Gels -- CaCl2 -- FC -- SOL -- THTS -- OIL -- MBT -- pH -- WPS -- HTHP -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No formation drilled last 24hrs. DAILY ACTIVITY SUMMARY RIH w/ packer assy at 90 ft/min to 6500’; UW 70K, DW 64K; TIH to 7500’, RIH w/ 76 stands from derrick; P/U 4 singles from shed; UW 77K, DW 62K; C&C for R/U to reverse circ; install X/O head pin; R/U to take returns to flow box from tbg; pump dn kill line; C&C, reverse circ w/ upper pipe rams closed, 125 gpm at 330 psi; B/D kill line reverse circ line; monitor well on trip tank; remove tools from pipe shed; ensure 3” line strung out from pits to cement unit for transferring brine; continue to monitor well on trip tanks; set packer at 7500’, pull 42K over to shear, S/D 14K; PJSM on R/U cementers; pressure test lines to 4000 psi; establish injection rate below packer, 2 bpm at 1340 psi; squeeze cmt pump 15 bbl, 13 ppg spacer, 26 bbl, 17 ppg class G premium, 5 bb, 13 ppg spacer and displace w/ 55 bbl 10.6 ppg brine; R/D cmt, B/D lines; L/D single jnt to pipe shed; stand back 5 stands in derrick; P/U single jnt and R/U to reverse circ; clean out cmt stinger; reverse out at up to 8 bbls/min, 1150 psi, 1.5 tbg volumes; R/D and B/D lines ready to tbg trip; stand back 3 stands in derrick to 6725’, observed pipe pulling wet; C&C, R/U circ head; C&C at 350 gpm, 1375 psi; trip tbg from 6725’ to 5100’, standing back in derrick; R/U circ head; PJSM on csg test; R/U cmt lines, fill and PT cmt lines; pressure test csg/shoe, perform csg test 2000 psi, 30 min; C&C, B/D cmt lines; pump 5 bbls dry job; R/D cmt hose and head pin; L/D single jnt of tbg to pipe shed from 5100’ to 3000’; continue to POOH, L/D tbg in pipe shed from 3000’ to surface. Max Gas last 24hrs 0u = 0.00%. No discernable metal / material collected from ditch magnets. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3240 REPORT BY Mike Franco