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214-023
PTO 21 f- 023 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Thursday, January 30, 2020 10:03 AM To: Well Integrity Compliance Specialist CPF1 & 2 Cc: Regg, James B (CED) Subject: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) OA SCP Dusty, Approval is granted for an increase of OA not to exceed pressure to 1800 psi for the purpose of evaluating the nature of pressurization for an undefined period. Once the evaluation is complete, an update will be sent to the AOGCC addressing mitigation or further evaluation. Please ensure that an internal waiver has been posted at the well. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppio)alaskagov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loeoosalasko.aov From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Wednesday, January 29, 2020 4:23 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL]RE: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) Victoria - Due to the slow nature of the pressure build up, CPAI is anticipating a longer-term pressure build up period to reach stabilization than the approved 2 -week period. Currently 2L-314 and 2L -320s OAs are in the following conditions; 2L-314 • OA pressure is currently 822 psi. OA fluid level was 1020' as of 10 Jan 20 • Pumped 100 bbls of diesel into OA on 17 December 2019. Average buildup rate of approximately 4 psi/day since July of 2019. • With the current OA pressure and build up rate the OA will not reach the DNE of 1000 psi for at least 44 days. 2L-320 OA pressure is currently 855 psi OA fluid level was 1368' on 27 Jan 20 Pumped 100 bbls of diesel into OA on 2 Jan 2019. • Average buildup rate of approximately 1 psi/day since August of 2019. • With the current OA pressure and build up rate the OA will not reach the DNE of 1000 psi for at least 145 days. To fully understand the capability of the charging source, CPAI would like to request an undefined time period to allow pressure stabilization up to 1800 psi. The request for the undefined pressure stabilization time period is based on the fact that CPAI does not have the data to estimate the stabilization point, nor the time it will take to reach. Once stabilization is established CPAI will allow the OA pressure to remain at the stabilization point for no more than 2 weeks for data collection purposes. At that point in time the AOGCC will be notified with the plan for mitigation or further evaluation. Please feel free to call to discuss if you need further details of the plans. Thank you. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 •V WELLS TEAM cm-- M -e From: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Sent: Tuesday, January 28, 2020 2:04 PM To: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Cc: Regg, James B (CED) <iim.reeg@alaska.gov> Subject: [EXTERNAL]RE: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) Dusty, Approval is granted for an increase of OA not to exceed pressure to 1800 psi for the purpose of evaluating the nature of pressurization for a period of two weeks. Once the evaluation is complete, an update will be sent to the AOGCC addressing mitigation or further evaluation. Tha nx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(Malaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoric.Loelpr)@olaska.gov From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, January 25, 2020 5:23 PM To: Regg, James B (CED) <iim.regg@alaska.eov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Subject: Tarn gas lifted producers 2L-314 (PTD #214-023) and 21--320 (PTD #210-166) Jim & Victoria, Tarn gas lifted producers 21--314 (PTD #214-023) and 21--320 (PTD #210-166) are exhibiting an increase in OA pressure and fluid level fall out. CPA] has managed these wells by occasionally loading the OA with liquids to maintain the OA pressure within Conservation Order 494 Rule 3(b). The initial OA gas sampling does not indicate the presence of lift gas or injection gases. However, a more extensive gas sample evaluation is in progress on 2L-314. CPA] is seeking permission to allow the outer annuli to exceed the Conservation Order 494 Rule 3(b) of 1000 psi to identify the stabilization point up to 1800 psi and better understand the nature of pressurization. Both wells are equipped with 10 W 45.5 Ib L-80 surface casing which has a burst rating of 5210 psi. Once the evaluation of the re -pressurization has been completed, an update will be sent to inform the AOGCC of CPAI's next step toward mitigation or further evaluation. Attached are copies of the current 90 -day TIO trends and well bore schematics. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Caioao`Pha�tps ATJ7 ;> 14-- 0 2 3 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, January 28, 2020 2:04 PM To: Well Integrity Compliance Specialist CPF1 & 2 Cc: Regg, James B (CED) Subject: RE: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) Follow Up Flag: Follow up Flag Status: Flagged Dusty, Approval is granted for an increase of OA not to exceed pressure to 1800 psi for the purpose of evaluating the nature of pressurization for a period of two weeks. Once the evaluation is complete, an update will be sent to the AOGCC addressing mitigation or further evaluation. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoePPCa)alas ka.Qov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp of (907)7931247 or Victono.Loeoo@oiaska.gov From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, January 25, 2020 5:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Subject: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) Jim & Victoria, Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) are exhibiting an increase in OA pressure and fluid level fall out. CPAI has managed these wells by occasionally loading the OA with liquids to maintain the OA pressure within Conservation Order 494 Rule 3(b). The initial OA gas sampling does not indicate the presence of lift gas or injection gases. However, a more extensive gas sample evaluation is in progress on 2L-314. CPAI is seeking permission to allow the outer annuli to exceed the Conservation Order 494 Rule 3(b) of 1000 psi to identify the stabilization point up to 1800 psi and better understand the nature of pressurization. Both wells are equipped with 10 %" 45.5 Ib L-80 surface casing which has a burst rating of 5210 psi. Once the evaluation of the re -pressurization has been completed, an update will be sent to inform the AOGCC of CPAI's next step toward mitigation or further evaluation. Attached are copies of the current 90 -day TIO trends and well bore schematics. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM • • Kait 2L- -314 Regg, James B (DOA) P Z140130 From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, August 11, 2017 4:00 PM To: Bixby, Brian D (DOA) , - eii4 (ow I Cc: Regg, James B (DOA) Subject: 170701 KRU 2L-Pad Deficiency Report Attachments: 2L AOGCC Deficiency Report - Completed File - 08-11-2017.pdf Brian, Please see the completed deficiency report for 2L. The paperwork, photo and lab reports have all been combined into a single file for simplicity. If you prefer separate files or need anything additional from us please let me know. Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist ConocoPhillips Alaska Ph:907.659.7535 Pg:924 Mail: NSK 69 sc ED aJ r: `` 5" Original Message From: NSK Prod Engr Specialist Sent: Sunday,July 02, 2017 9:22 AM To: Bixby, Brian D (DOA) <brian.bixby@alaska.gov> Subject: RE: [EXTERNAL] Emailing: 170701 KRU 2L-Pad Deficiency Report.pdf Brian-enclosed is a signed copy of the AOGCC Deficiency Report for your records. We will follow up on this and send you documentation of the corrective actions taken when completed. Thanks, Darrell Humphrey 907-659-7535 Original Message From: Bixby, Brian D (DOA) [mailto:brian.bixby@alaska.gov] Sent: Sunday,July 02, 2017 7:20 AM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL] Emailing: 170701 KRU 2L-Pad Deficiency Report.pdf Darrell, Please print this, sign it and send it back to me. Thanks, 1 • • Brian Brian Bixby Petroleum Inspector Cell 509-998-3683 brian.bixby@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at (907) 279-1433 or brian.bixby@alaska.gov. 2 • • S J.-ee_tol dI 7 State of Alaska Oil and Gas Conservation Commission / Deficiency Report Location: Kg() 2{.,,' 314 ✓ Date: uty r '20)7. PTD: Z Ii.1 "dz 3 Operator: CpNOCb /-I ILA.it}S C� - Type inspection:¶ /5 t..t ✓, OperatorRep:‘—PpAJXeLL 1-1uNn4WInspectof gi,j i. s/ Position: j 0 6161,4660— l Al 5 - 1 Op.Phone: q /59„ 1s [c Correct by(date): 'Epi )Sr Z017- Op. nl7Op.Email: n I3Q&a()NOC° LL1 Follow Up Req'd: Detailed Description of Deficiencies Date Corrected u Z L -3)'-( A 4 t/J S4n.i :rem.Let 57 �/ l / Kgt. it L - 3ZJ z.‘,z zv, C.bc.� . -1-14Eiz6 is gdy-Zuautdcrt up 1,0 66“Ase Ar.0A A/17—/117. 1 ✓ ALrSo UP "r -[itv THE FLures v.} 1n1�u.5/j.'�4 Ash 1 e/VEsrltS&TE Tel .�/a air ` /� g A s Fosrsi.• ) _ 44 0 ,4PIb '144146ARE IT 15 �%VC�T" c� ��� mow— -/1-16 i&-LS o e- 1-..11c7 644 Attachments: ltIo1D OF Installed 'ii S'i n(ZL^3l�1�; LAB r'epor+5 -545 Analysis s\-) Operator Rep 7, 2,1 i Signatures TilA+•r os�/ AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. 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Ilii: t to+_J »MZ = _x ki .'e H pµ , _ -71:41, !/./11110:1---'''':4/11•11-i//:..!!'"9-//'.:-4111/gliMilliN1-31110/TY: .-47'....,.•i-':,..;"'' •,--di!';I:rtiRritak.-1.4- •'`..7...1.!1./M-j0.,.q.111-0.11-:,11111..iii111241. k J 7.:!......59-10:- ...., ' ....... pA ._kit cp. 0 ca 1.- U p O CO +.., mm a = :"••• o 0 04r. O = N 3 O = ++ U = O h p O N N i a) a) ++ '37:' . 4O- .t2 CL O O tri. 411 •KEt4 2L-314- Z14oz3v Regg, James B (DOA) From: Bixby, Brian D (DOA) LS1ToSent: Sunday,July 2, 2017 1:18 PM Filet- To: : Regg,James B (DOA) Subject: Emailing:170701 KRU 2L Pad Deficiency Report.xlsx, 2L AOGCC DEFICIENCY RPT 07-01-17.pdf Attachments: 170701 KRU 2L Pad Deficiency Report.xlsx; 2L AOGCC DEFICIENCY RPT 07-01-17.pdf Jim, I talked this over with Darrell and he stated that they had a similar issue on another pad a few years back with gas and it was what they called swap gas I guess but it was tested and was not formation gas or lift gas. I asked if they had done any testing on 2L-Pad and he said no so that is why I asked them to do the testing. If you need anything else please let `v me know. Thanks, Brian Brian BixbyAU Petroleum Inspector S`ANNE® X01; Cell 509-998-3683 brian.bixby@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at(907) 279-1433 or brian.bixby@alaska.gov. • S State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Kv 2 • 314 Date: �UI1 172.1 ,iZo) PTD: Operator: CCat.i0C.:-PO4 AWKSZA-- Type Inspection:SVS ESTI"J�"i Operator Rep: pRF ELL Ilumpo Rey Inspector'• I,..T€Ayl'fay Position: ap 6461tJag... T-c,AI.SS•r- Op.Phone: q 03., G59.. Correct by(date): Sar ) s ZoI? Op.Email: n j 13ciae VCoP/4t1.L%4,5 v0+4"- Follow Up Req'd: Detailed Description of Deficiencies Date Corrected 11 .14u Z L -3)4 ga 41A161.LSktue4srextieb g,1.-3v , 3a( , 3Z , c At ; .�. -114ERE is gor-Zu13sf..1.►fn up I N I414.14L2 r /041- c) UP `TI-LR.) -P-06 Fi. E .t.r0 es "., t e- ..S . Ac.e` /d var+C-,4Te T( ' Ic.j..4P, .j..4Ouri.:a s GC�,N►Pos�i� 441) A44 6 SERE ,r ,S NOT" C�r►r�wa fn ow- ~04 tAkLLS o 2 LIFT e aS Attachments: signatures: • '/ Operator Rep 7: Z.17 RIAS I�p3�/ AOGCC Inspector *After signing,a copy of this form is to be leh with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 . 0 IPPVOCT 232015 ConocoPhillip Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 28, 2015 ��P{ Commissioner Cathy Foerster Alaska Oil& Gas Commission rr�� Ili" 333 West 7th Avenue, Suite 100 c�,�- Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/28/2015 2N&2L PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-316 50103203420000 2000900 13" N/A 13" N/A 5.95 9/25/2015 2N-333 50103205250000 2060250 19" N/A 19" N/A 5.1 9/25/2015 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 9/25/2015 2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 ( 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25• 9/25/2015 2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 Pit-/_o2,3 SchiumbergerTransmittal#: iVED Drilling & Measurements �7 E DATA LOGGED MWD/LWD Log Product Delivery +1 re4,2015 K.BENDER MAR 3 1 2015 Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana BlGCC Well No: 2L-314 PB1 **REV-1** Date Dispatched: 31-Mar-15 Job#: 14AKA0128 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A VISION*Service 2" MD _ x VISION*Service 2"TVD x VISION*Service 2'TVDSS x VISION*Service 5"MD VISION*Service 5'TVD x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 **REVISED APIN** x x As-Built Survey 1 Contents on CD N/A Nad83 **REVISED APIN** x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/td **REVISED APIN** x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenter(a slb.com Catherine Roso _ Attn:Stephanie Pacillo 907-265-6189 ATO 1707 ✓�v Received By: Sat4D t*p APR 2 9 2015 N 6 "OmmO M N m on N�mQ N md OnQ Mnd ON O�oN�M am m om m m oM m V m eM�ma�No mr a n,-m O m a_ mo.- 84me,-ocnmno mQoa nmo2 cq Oa N8dmr 712ma818028: 88..228;oMd'8m;Nem ommo..4Y ` rn dmmmmmmmmm mmmQd;dMmm aNmmM0 mmmdNmnmNmra OOOOWW c\VV J 0000000000000000000000000000000,0000000000 NupO <Or0 hmarNNNma^D 80.,.Rg22222gNNNgggvfpgg2p,,ggggRRRRNgpm a ' ' a""mm;;5=O,7MOOmNmNOamONaNmO aVNO mmmNmMmN d NaNN d mmmmN am m mNmmNmmm<m <9 . .n nn • • .nnn .. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by directinspection of the file. cL - O i:Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: olor Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: MSS Date: Li. go /6--- /s/ 01 P Project Proofing 1 BY: Maria Date: IA b 5 /s/ al P Scanning Preparation 5 x 30 = 160 + aq = TOTAL PAGES / 79 (Count does not include cover sheet) BY: an Date: Li/clops. /s/ Production Scanning Stage 1 Page Count from Scanned File: I TO (Count does include cover eet) Page Count Matches Number in Scannin Preparation: YES NO BY: CM Date: LE cad/S. /s/ ni f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 0 NO TOTAL PAGES: 1t3 Digital version appended by: Meredith Michal Date: 4/1, (cg /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 3 Scanning is complete at this point unless rescanning is required. 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BENUcR Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2L-314 Date Dispatched: 13-Nov-14 Job#: 14AKA0128 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A TOC Top of Cement x x LAS Digital Data N/A Contents on CD N/A x EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: PDF x Please sign and email a copy to: Please sign and email/fax a copy to: catherine.Roso(a�Conocophilips.com AlaskaPTSPrintCenter0,slb.com Cathaerine Roso Attn: Nathan Green Received By: mxtiza-ouk... 6 Fax: 90 561-8317 2A- o2 Conoco111i s DATA LOGGED 10/1l/201 M.K.BENDER TRANSMITTAL / „, , CONFIDFNT_IAL DATA OCT 082014 FROM: Sandra D. Lemke,ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC AC P.Q. Box 100360 333 W.7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: 2L-314/2L-314PB1 DATE: 10/06/2014 Transmitted: Kuparuk River Unit, Alaska .. ,2L-314 and 2L-314PB1 2-2-(`)SS 1 hardcopy report and 1 CD CANRIG Final well report mud logging data for 2L-314 and 2L-314PB1; 8/22/2014; table of contents, mud logging H equipment; general well details, geologic data, pressure/formation strength, drilling data, show reports, daily reports and formation logs;logs; color log presentations, one set each for wellbore Formation log MD&TVD II Gas ratio MD&TVD Combo log MD&TVD Drilling dynamics MD&TVD li ll fl � 1 CD contains daily reports, DML data, final well report, LAS files, Log PDF files, remarks, TIFF files, show report Please promptly sign, scan and return electronically to 5andra.D.Lemke000P.com d , CC: 2L-314 transmittal folder, production well files, eSearch Recei _,/� ' "✓..E:itt -(Date: \ol,‘(1,z-t 615-Technical Data Management I ConocoPhil/ips I Anchorage, Alaska I Ph: 907.165.6947 RECEIVED STATE OF ALASKA t is C 0 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS A GCC - t.Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other r After Casing r Pull Tubing r Stimulate-Frac j Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (;r Exploratory r 214-023-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service "' 50-103-20686-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL 380051,380052 2L-314 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 11622 feet Plugs(measured) none true vertical 5369 feet Junk(measured) none Effective Depth measured 11610' feet Packer(measured) 8854, 8904 true vertical 5368' feet (true vertical) 5180, 5199' Casing Length Size MD ND Burst Collapse Conductor 80' 16" 134' 134' Surface 2499' 10.75" 2527' 2397' Intermediate 9082' 7 625" 9110' 5265' Production 2706' 4 5" 11610' 5368' Perforation depth. Measured depth: none True Vertical Depth none Tubing(size,grade,MD,and ND) 3.5, L-80,8918 MD, 5204 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 8854 MD and 5180 TVD PACKER-BAKER HRD-E ZXP @ 8904 MD and 5199 ND NIPPLE-CAMCO DS NIPPLE @ 504 MD and 504 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9648-11277' Treatment descriptions including volumes used and final pressure 6 stages-see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation not on-line yet Subsequent to operation 1665 3314 673 -- 609 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development i Service r Stratigraphic r 16.Well Status after work: Oil I✓ Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt: 314-499 Contact Adam Klem @ 263-4529 Email Adam.Klemconocophillips.com Printed Name A Klem Title Sr. Completions Engineer Signature Phone:263-4529 Date vi- /6/3/2 /'4 R$CMS OCT - 2 20<, r. Form 10-404 Revised 10/2012 A 04 Submit Original Only 2L-314 WELL WORK SUMMARY DATE SUMMARY 8/21/2014 SET BAITED PULLING TOOL ON BALL& ROD @ 8882' RKB; PULLED SOV& SET DV @ 8803' RKB; MITT (PASS). MIT-IA(PASS); PULLED CATCHER/BALL& ROD @ 8882' RKB; PULLED 2.75" RHC PLUG @ SAME. READY FOR FRAC. 9/7/2014 Performed first 3 stages of the Bermuda fracture treatment, placing 381,000#'s of 16/20 frac sand into formation (100% of design). Well freeze protected w/diesel. Will return to pump remaining 3 stages once we have reloaded seawater and sand. 9/10/2014 Performed last 3 stages of frac treatment of the Bermuda to completion thru Packers Plus frac ports placing 449,511#of 16/20 carbolite (100% of design); frac was RA traced per proposal. Well left with —4 bbls diesel freeze protect. 9/12/2014 DRIFTED TBG TO 5800' SLM. MEASURED BHP @ 3700'SLM: 1693 PSI. COMPLETE. 9/14/2014 B&C CTU #1: MILL THROUGH UPPER 3 OF 5 PACKERS PLUS FRAC SLEEVES WITH OLGOONIC MOTOR AND MILL. PETROTECHNICS MONITORING RETURNS FOR TRACER- NONE DETECTED. IN PROGRESS. 9/15/2014 B&C CTU#1: PERFORM CLEANOUT TRIP FROM TOP FOR 4TH FRAC SLEEVE AT 10767'TO SURFACE WITH OLGOONIK MOTOR AND MILL. HUNG UP IN MULTIPLE AREAS WHILE POOH, APPEARS TO BE FILL AROUND RESTRICTIONS. PLAN TO RETURN IN THE MORNING AND PERFOM FCO WITH JET SWIRL NOZZLE PRIOR TO FINISHING MILLING. PETROTECHNICS MONITORING RETURNS FOR TRACER- NONE DETECTED. 9/16/2014 B&C CTU#1: PERFORM CLEANOUT TRIP FROM TOP FOR 4TH FRAC SLEEVE AT 10767'TO SURFACE WITH JET SWIRL NOZZLE. PETROTECHNICS MONITORING RETURNS FOR TRACER- NONE DETECTED. START RIH TO MILL LAST 2 OF 5 FRAC SLEEVES, IN PROGRESS. 9/17/2014 B&C CTU#1: MILL OUT THE LAST 2 OF 5 PACKERS PLUS FRAC SEATS AT 10,768' & 11,110' RKB. CLEAN OUT DOWN TO 11,550'CTMD. LOG 2 PASSES WITH PROTECHNICS MEMORY SPECTRASCAN GAMMA RAY LOG FROM 8800'TO 11550'. READY FOR SLICKLINE. 9/18/2014 TAGGED @ 9409 SLM; SET CAT SV @ 8982' RKB; PULLED DV& SET"OV @ 8803' RKB. JOB IN PROGRESS 9/20/2014 PULL DV&SET GLV @ 2817' RKB; (GOOD PT ON TBG) PULLED 2.75"CAT STANDING VALVE @ 8882' RKB & MEASURE BHP @ 8875' RKB (2424 PSI), JOB COMPLETE. `, _p KUP PRODUCER 2L-314 ConocoPhillip5 well attributes (ate anile&�1D TD � A'or Wellbore APW WI Field Name Wellbore StatusUnci('I MD(ftKB) Act Btm(ftKB) Alaska Ir>c 'v 50103206860000 TARN PARTICIPATING AREA PRODUCER 91.67 10,076.07 11,622.0 (ixv >Ifi rn Y ... Comment 112S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-2L-314,9/2720149:01.4r4 AM SSSV:NIPPLE 28.47 8/12/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER.24.9- Last Tag:SLM 9,409.0 9/18/2014 Rev Reason: FRAC,MILLING,TAG;GLV C/O hipshkf 9/27/2014 ' Casing Strings Li ,. Casing Description 00(in) ID(in) Top((KB) Set Depth(ftKB) Set Depth((VD)...Wt/Len(I...Grade Top Thread Conductor 16 14.688 28.0 134.0 134.0 109.00 H-40 Welded Casing Description 012(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..Grade Top Thread SURFACE 103/4 9.950 27.9 2,526.6 2,397.9 45.50 L-80 TSH 563 )(0 REDUCING,58.9 III Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) set Depth(TVD)...Wt/Len 0...Grade Top Thread .AhM.condvotor;28.0-134.0' , INTERMEDIATE 75/8 6.875 25.7 9,110.0 5,266.5 29.70 L-80 Hydril563 1111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Mt LINER 41/2 3.958 8,903.7 11,609.8 5,368.6 12.60 C110 Hyd 521 NIPPLE 504.2 - - III Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 8,903.7 5,198.6 68.77 PACKER BAKER HRD-E ZXP W/HD's 4.820 SURFACE,27.9.2.5266 8,923.4 5,205.7 69,02 NIPPLE CAMCO RS NIPPLE 4.250 8,925.7 5,206.5 69.05 HANGER BAKER FLEX-LOCK 4.800 GAS LIFT,2.817.3 8,9353 5,209.9 69.17 XO REDUCING XO 17#HYDRIC 563 BOX x 12.68 HYDRIC 521 PIN 3.920 IM GAS LIFT;6,055.2 9,462.2 5,332.1 84.65 SWELL TAM SWELL PACKER "F" 3.958 ili PACKER III 9,648.1 5,340.6 89.43 FRAC PORT PP FRAC PORT 2.000"SEAT #5 (Milled Out 2.700 it 9-14-2014) GAS LIFT;6,660.8 illk 9,848.6 5,339.7 90.86 SWELL TAM SWELL PACKER "6" 3.958 illi PACKER GAS LIFT,7,922.1 la 10,024.5 5,336.1 91.46 FRAC PORT PP FRAC PORT 1.875"SEAT #4(Milled Out 9 2.700 14-2014) 10,190.5 5,333.0 90.25 SWELL TAM SWELL PACKER "D" 3.958 PACKER 10,396.9 5,333.5 8931 FRAC PORT PP FRAC PORT 1.750"SEAT #3 (Milled Out 2.700 GAS LIFT;8,803.0111 9-17-2014) 10,562.8 5,335.5 89.56 SWELL TAM SWELL PACKER "C" 3.958 SLIDING SLEEVE;8,830.4 PACKER 10,767.8 5,337.3 8933 FRAC PORT PP FRAC PORT 1.625"SEAT #2(Milled Out 9 2.700 -17-2014) PACKER;8,854.0 XO THREADS;8,8620 :,E, 10,935.1 5,339.9 89,18 SWELL TAM SWELL PACKER "B" 3.958 MI PACKER NIPPLE,8.ee2.1 - - 11 109.8 5,343.8 87.97 FRAC PORT PP FRAC PORT 1.500"SEAT #1 (Milled Out 9 2.700 LOCATOR;8,899.811 -1 -17-2014) LOCATOR.8.900.e 11,277.2 5,351.7 86.92 SWELL TAM SWELL PACKER "A" 1958 pi PACKER SHOE;8,91.5 Tubing Strings Tubing Description String Ma,..ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(IbIft) Grade Top Connection I UPPER COMPLETION 31/2 2.992 24.9 8,918.5 5,203.9 9.30 L-80 EUE Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Moly) Item Des Com (in) 24.9 24.9 0.19 HANGER CAMERON 4 1/2"TUBING HANGER 3.958 INTERMEDIATE,25.7-9,110.0 58.9 58.9 0.45 XO X-O IBT-M BOX x 3-1/2"EUE PIN 3.000 REDUCING 504.2 504.0 3.18 NIPPLE CAMCO DS NIPPLE 2.875 8,830.4 5,171.6 68.10 SLIDING Baker CMU SLIDING SLEEVE W/DS PROFILE IN 2.810 SLEEVE CLOSED POSITION 8,854.0 5,180,4 68.29 PACKER BAKER PREMIER PACKER 2.930 8,882.1 5,190.7 68.51 NIPPLE CAMCO D NIPPLE 2.750 © 0 ' 8,899.8 5,197.2 68,72 LOCATOR FLUTED LOCATOR 3.000 8,900.8 5,197.5 68.74 LOCATOR LOCATOR W/SHEAR SCREWS 3.000 8,917.5 5,203,6 68.94 SHOE FLUTED MULE SHOE WLEG 3.000 iiiiir Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) ❑ ❑ (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,767.8 11,277.0 5,337.3 5,351.7 Frac Stages 1-3 9/7/2014 Stages 1-3 of Bermuda frac treatment placing 381,000'of 16/20 frac sand liar 9,648.1 10,767.8 5,340.6 5,337.3 Frac Stages 4-6 9/10/2014 Stages 4-6 of Bermuda frac treatment placing Frac Stages 4-6;9.648.1 449,511'of 16/20 frac sand Mandrel Inserts ❑ ❑ st ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type lin) (psi) Run Date Corn liar 1 2,817.3 2,602.5 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,609,0 9/20/2014 2 5,055.2 3,603.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0,000 0.0 8/10/2014 I 3 6,660.8 4,301.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 8/10/2014 ❑ O 1 4 7,922.1 4,799.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 8/102014 5 8,803.0 5,161.3 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 9/18/2014 liar Frac Stages 1-3,10,7678 ❑ ❑ �I El LINER;8,903.7-11,609.8 RECEIVED -2--\24,- D/LS SEP 24 `r..:;i AOGCC Schiumberger Drilling & Measurements Transmittal #: 23SEP14-NG01 DATA t,o� c3GE MWD/LWD LogProduct Delivery �W2oi M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2L-314 Date Dispatched: 23-Sep-14 Job#: 14AKA0128 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 6 Contents on CD N/A VISION* Resistivil 2" MD x x VISION* Resistivil 2"TVD x x VISION* Resistivil 5"TVD VISION* Resistivil 5" MD x x MicroScope Resis 5" MD x x MicroScope Resis 5" MD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Please sign and email a copy to: Please sign and email/fax a copy to: iifesie@slb.com spacillo(a�slb.com Stephanie Pacillo Ifeanyi Ifesie Fax: 907-561-8317 907-265-651 ATO 1525 N fi).,tiza.4z04) Received By: o_eiteeft tea -- c..1 p M d^010100 N000,y000f 010000.00 mpmm MMM M0 V w QO tm•1My-W,M 01NONO.mN0010NO O �.0_,.,..0_,....mV Mm ,.......„0.0_„..„,..m NV Eomm 1 N N Ippttpp Ipp n A A p a p m M O�p i o rn n O m O g m m m r p. m 0.0.0101010.0O+N O.00n n mmm QOQ ON MMN0NNN NNCOp IC V NOOOOQIa 010010 p mNN QaQQQQaQQQQaQaQQQ xjO 0Om 0400 OI J M M M M M M M M M M M M o M M M M I M M M 1•I•J m M M M M M M M M np 1 p M M p M M o M M t M l0•]M M 1p�l M M m .10010010010010D100HNIOOMNN1001•O!INN.•O(I.NN N..NNN.Nh1(1N NN NNNN h NNNN1(1 NN10(1 ca __ ,tj any 0. p y �} 1a�1 app Q a �p .y V m O �� "^..�yT yr .`V(tVy O N N N N O Mp N m m ��0Ny1 M N 00 0 0 010 0 A o rNO N n M N w N Y N N W N,-,p1 OI N b O.or-m«000, N ,_ M M M M m m m m m m M Q Q m e l m m•1 M M N M M M M M v a a v a s a 0 0 v o v O v v v loo.m ul.YN1 N N ('ti MM M 000000 MMM Iii MEM G )OCCO6 )COO6660000C00JJ NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNYANNNNNN p UU n n r r r n r n n n A n n n n r r n r n n n n r A n r r n n r A r n A n A A n n A r r n n A n r n N C4 0O N c_iIf O Npp0Vm0mmN�OM 00MNNppAmONNpO. 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'-. oNNON0( 0 COW m it. rr 0 a, 2 CO .O Co07. m 0 m• mgiWO)4OOmV. 2NAINm1mr% U O N mm Z 1- 4ppppp0N( nN0mag O N Q N 0www0WOmoWNNtnN0tow e 0' VNO,-, O LLI if ENpO 0Fn a a Or V N N 0NZ m C o m C O -11: m A W LL U U• nn WMNmMW WrnO WrnrnV 010)rn 2 r r rr r rr MpJ C ,..N.7.,--00...0-0000N.1-00,0 O A O LL pppprnoi ai ai ot»rnmnW161dr ow a OI rn rn W W W m W W W W m m W W W m W W y JN ,. 4 m N LL, 00 m 3 6LL U n 1p p 1p r Ip 1p O N .. gtnit40 V 1O1ppNO110n10MO1�V 21pON00 um n r 0100 Vp 1 toO 1v1p O men N N q.-.-o V N N t m 0000000000 O r N M V W b W CO I C 0 $ ic m E y o - rn • t Waym E v.g r Tmo C E tn'Q 0 m I 0 va N lm J 6 "i EIS,: I 2.`4- 02_3 SEP 2 4 ?1i1 SchlumbergerDrilling & Measurements Transmittal #: 23SEP14-NG01 DATA LOGGED MWD/LWD Log Product Delivery 9 P-W2o14 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2L-314 PB1 Date Dispatched: 23-Sep-14 Job#: 14AKA0128 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION* Resistivi 2" MD x x VISION* Resistivil 2"TVD x x VISION* Resistivil 5"MD x x VISION* Resistivil 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: PDF x Survey: PDF, xls, txt x x N/A Please sign and email a copy to: Please sign and email/fax a copy to: iifesie(a),slb.com spacillo(a)slb.corn Stephanie Pacillo Ifeanyi Ifesie Fax: 907-561-8317 907-265-651 ATO 1525 N (,),),,La_lio„, 6Received By: cJ 4., . ® 8 - ppOCRO A nmm O7- " "V""pp mNMCNmpMO -N-gM NppmM N mmm n8CNNOSO--01-00 O C0000'0dVOOO 70Q OOumON0000YVO C) CC) V m r 7 )7 -,,-,- ,-.-666 j tMtMMTmMMMMMChMmmmmmMeM0MMM O OOOOOOOOOOOOOOOOOOOOOONpONNNNNON0NNNNN mmNNNmmmfmNn8808V 888 0® ill O 6 -4 � �mmOOMAm2mM9`000NONOMNmm mmgs 8qa8 N o. 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U W L 0l 0 0) Q� d o yj o U ri 0. f0 N 0 J O RECEIVED STATE OF ALASKA SEP 12 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANIAIMCC 1a.Well Status: Oil E• Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ , Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: August 12,2014 ' 214-023/314-381 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 July 11,2014• 50-103-20686-00 s 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 181'FNL,704'FEL,Sec.22,T1ON, R7E, UM August 6,2014 • Ki2,U, 2L-314 • Top of Productive Horizon: 8. KB(ft above MSL): 143'RKB 15.Field/Pool(s): 2611'FNL, 1058'FEL, Sec. 14,T1ON, R7E, UM GL(ft above MSL): 115'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 527'FSL,226'FEL,Sec. 14,T1ON, R7E, UM 11622'MD/5369'TVD Tarn Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-460947 y- 5927665 Zone-4 , 11622'MD/5369'TVD ADL 380052,380051 • TPI: x-465883 y- 5930491 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-466707 y- 5928345 Zone-4 nipple @ 504'MD/504'TVD 4602 18.Directional Survey: Yes ❑• No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1391'MD/1378'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res/Neutron/Density, Periscope,Stethoscope,Sonic 9123'MD/5270'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 109# H-40 28' 134' 28' 134' 20" pre-installed ), C> 10.75" 45.5# L-80 28' 2527' 28' 2397' 13.5" 1133 sx Class G,736 sx Class G 7.625" 29.7# L-80 26' 9110' 26' 5265' 9.875" 159 bbls GasBLOK 4.5" 12.6# C-110 8904' 9445' 5199' 5327' 6.5" uncemented liner 4.5" 12.6# L-80 9445' 11610' 5327' 5368' 6.5" uncemented liner 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 8919' 8904'MD/5199'TVD no perfs a7" d'j 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. pi� Was hydraulic fracturing used during completion? Yes❑ No❑ Off. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 8960' 208 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on post-rig well work Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired'? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ 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. NONE Form 10-407 Revised 10/2012 CONTINUED ON REVERSE " - 1 ��. Submit original onl Vit- 3////i 5- die ///���- RBEMS SEP 2 6 Lt, 6 29. GEOLOGIC MARKERS(List all formations and ma ncountered) 30 FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1391' 1378' needed,and submit detailed test information per 20 AAC 25 071 Top Bermuda 9303' 5326' Heel Target 9596' 5362' Toe Target 10605' 5413' 2L-314 Pilot Hole total depth 9573' 5443' N/A Formation at total depth: Bermuda 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,directional survey,cement detail reports 32 I hereby certify that the foregoing is true and correct to the best of my knowledge , S /- "DP) Contact: Dan Bearden @ 263-4864 Email J Daniel Bearden@conocophillips.com Printed Name G.L.Alvordd� Title Alaska Drilling Manager Signature • .. Oak Phone 265-6120 Date '1(L24 (4— INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection, Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 C PAI_2 L-314 Common Well Name * Name MD (feet) TVD (feet) TVDSS (feet) 2L-314PB1 PFROST 1390 1378 -1235 2L-314PB1 CSG 10 34 Surf 2530 2400 -2257 2L-314PB1 0-80 2639 2478 -2335 2L-314PB1 CAMP_SST 2715 2532 -2388 2L-314PB1 0-50 5366 3739 -3596 2L-314PB1 0-40 6233 4117 -3974 2L-314PB1 0-37 6887 4386 -4243 2L-314PB1 T-7 7910 4795 -4652 2L-314PB1 T-6 8185 4909 -4765 2L-314PB1 T-5 8525 5051 -4908 2L-314PB1 T-4.1 8558 5064 -4921 2L-314PB1 T-4 8746 5139 -4996 2L-314PB1 T-3.1 8921 5205 -5061 2L-314PB1 T-3 9004 5233 -5090 2L-314 TOP_BERM 9168 5282 -5138 2L-314 TOP BERM SEIS 9199 5289 -5146 CPAI_2L-314PB1 Common Well Name * Name MD (feet) TVD (feet) TVDSS (feet) 2L-314PB1 PFROST 1390 1378 -1235 2L-314PB1 CSG 10 34 Surf 2530 2400 -2257 2L-314PB1 0-80 2639 2478 -2335 2L-314PB1 CAMP_SST 2715 2532 -2388 2L-314PB1 0-50 5366 3739 -3596 2L-314PB1 0-40 6233 4117 -3974 2L-314PB1 0-37 6887 4386 -4243 2L-314PB1 T-7 7910 4795 -4652 2L-314PB1 1-6 8185 4909 -4765 2L-314PB1 1-5 8525 5051 -4908 2L-314PB1 1-4.1 8558 5064 -4921 2L-314PB1 T-4 8746 5139 -4996 2L-314PB1 1-3.1 8921 5205 -5061 2L-314PB1 T-3 9004 5233 -5090 2L-314PB1 TOP_BERM 9171 5284 -5141 2L-314PB1 TOP BERM SEIS 9191 5290 -5147 2L-314PB1 T-2 9327 5336 -5193 2L-314PB1 BASE_BERM 9365 5351 -5207 2L-314PB1 0-35 9400 5365 -5221 2L-314PB1 K-3 9505 5410 -5267 KUP Completed 2L-314 Conoc F'hiIIips ; 'Well Attributes 'Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status nel(°) MD(ftKB) Act Bhp(ftKB) rc.rr4,..„n 50103206860000 TARN PARTICIPATING AREA Completed 91.67 10,016.07 11,622.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(RI Rig Release Date HORIZONTAL-2L-314,827201411,05;15 AM 28.47 8/12/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Rev Reason:Pull Plug BodyAttii ,GLV C/O hipshkf 8/27/2014 .................................Hanger 249 _ I: ; Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Conductor 16 14.688 28.0 134.0 134.0 109.00 9-40 Casing Description OD(in) ID(in) •Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Surface 103/4 9.950 27.9 2,526.6 2,397.9 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(1...Grade Top Thread xo Reducing(Tubing):58.9 Intermediate 7 5/8 6.875 25.7 9,110.0 5,266.5 29.70 L-80 Hydril563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread _a0A"Conductor,28.0-134.Od1'pj;_ `', Liner 41/2 3.958 8.903.7 11,609.8 5,368.6 1260 C110 Hyd 521 Nipple-DB,XN,DS,D;504.2 Liner Details •-• "• Nominal ID t' 1:: Top(ftKB) Top(TVD)(ftKB) Top Ind(*) Item Des Com (in) ffS 8,903.7 5,198.6 68.77 PACKER Baker HRD-E ZXP W/HD's 5 1/2"X 7 5/8"MYS 125 4.820 • Surface;27.9-2.526.6-1. _ for 39#cag 5 1/2"17#hydril 563 pin do 8,923.4 5,205.7 69.02 Nipple(RS) RS Nipple 7.63"P110 5.5"17#HYD 563 4.250 Mandrel;2.8173 • 8,925.7 5,206.5 69.05 HANGER Baker Flex-Lock 5 1/4"X 75/8"MYS 110 for 39#csg 4.800 Mandrel,5.055.2 5 1/2 17#Hydril563 pin x pin 8,935.3 5,209.9 69.17 XO REDUCING XO 55"17#Hydril 563 box X 45"12.6#Hydril 521 3.920 Mandrel;6,660.8 pin Mandrel;7,922.1 9,462.2 5,332.1 84.65 Swell Packer TAM swell packer "F" 3.958 9,648.1 5,340.6 89.43 FRAC PORT PP Frac Port 2.000"Seat #5 2.000 9,848.6 5,339.7 90.86 Swell Packer TAM swell packer "E" 3.958 Mandrel,6.903.0 10,024.5 5,336.1 91.46 FRAC PORT PP Frac Port 1.875"Seat #4 1.875 iv ' 10,190.5 5,333.0 90.25 Swell Packer TAM swell packer "D" 3.958 Sliding Sleeve:8.830.4 ;• 1 1 10,396.9 5,333.5 89.31 FRAC PORT PP Frac Port 1.750"Seat #3 1.750 ;;. 10,562.8 5,335.5 89.56 Swell Packer -TAM swell packer "C" 3.958 10,767.8 5,337.3 89.33 FRAC PORT PP Frac Port 1.625"Seat #2 1.625 Packer(Tubing):8.854.0 l';':« • XO Threads;8,862.0 10,935.1 5,339.9 89.18 Swell Packer TAM swell packer "B" 3.958 11,109.8 5,343.8 87.97 FRAC PORT PP Frac Port 1.500"Seat #1 1.500 Nipple-DB,CN,DS,D;8,882.1 11,277.2 5,351.7 86.92 Swell Packer TAM swell packer "A" 3.958 Locator;8,899.8 i''4 •'.• --_---- Tubing Strings Locator,8,900.8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth It..Set Depth(TVD)(...Wt)lblft) Grade Top Connection • Upper Completion 31/2 2.992 24.9 8,918.5 5203.9 9.30 L-80 EUE Shoe:8,917.5 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Corn (in) 24.9 24.9 0.19 Hanger Cameron 4 1/2"Tubing hanger 3.958 • 504.2 504.0 3.18 Nipple-DB, Camco 2.875"DS Nipple 2.875 XN,DS,D 8,830.4 5,171.6 68.10 Sliding Sleeve Baker CMU sliding sleeve w/2.813"DS profile in closed 2.810 • • position 8,882.1 5,190.7 68.51 Nipple-DB, Camco 2.75"D nipple 2.750 Intermediate;25.7-9.110.0 XN,DS,D 8,899.8 5,197.2 68.72 Locator 'Fluted Locator 3.000 8,900.8 5,197.5 68.74 Locator Fluted Mule Shoe WLEG 3.000 8,917.5 5,203.6 68.94 Shoe #REF! 3.000 Mandrel Inserts st I - ati C on Top(ND) Valve Latch Port Sae TRO Run o No Top(ftKB) (ftKB) Make Model OD(in) Ser., _ Type (in) (psi) Run Date m 1 2,817.3 2,602.5 CAMCO SER#21 1 Dumm BK-5 8/10/2014 2AE03 y PN:1001 78207 2 5,055.2 3,603.5 CAMCO SER#21 1 Dumm BK-5 8/10/2014 3AE03 y PN:1001 78207 3 6,660.8 4,301.2 CAMCO SER#24 1 Dumm BK-5 8/10/2014 1AEO3 y PN:1001 78207 - 4 7,922.1 4,799.4 CAMCO SER#21 1' Denim BK-5 8/10/2014 8AE03 y PN:1001 78207 • 5 8,803.0 5,161.3 CAMCO SER#21 1 UMY BK 0.000 0.0.8/21/2014 1AE03 •• PN:1001 78207 SV- SER#A1 4G-5317 Liner:8,903.7-11.609.8 • Conoco hiIIips Time Log & Summary We//view Web Reporting Report Well Name: 2L-314 Rig Name: NABORS 9ES Job Type: DRILLING ORIGINAL Rig Accept: 7/10/2014 12:00:00 AM Rig Release: 8/12/2014 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/09/2014 24 hr Summary Clean&clear cellar&rig floor f/rig move, remove berming around pits complex, hook up peak sow pull pits away f/sub,Jack up sub pull mats out f/under sub pull sub off well, pull mats f/around 2L-318 spot on 2L-314, Lay herculite f/pits&sub, N/D diverter assy due t/newe spool arriving, N/U diverter line&new tee spool, N/U annular 06:00 08:00 2.00 0 0 MIRU MOVE MOB P Clean cellar&rig floor prep f/rig move, remove berming from around pits and cuttings box, raise wind walls in cellar. 08:00 12:00 4.00 0 0 MIRU MOVE MOB P Jack up pits hook up peak truck, pull pits away f/sub, pull herculite f/pits complex and spot cellar mats f/ 2L-314,jack up sub,pull rig mats f/ under sub. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Pull sub off well, hang new tree in cellar, lay herculite f/sub base on 2L-314, pull mats f/2L-318, make up diverter line t/knife valve. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Remove diverter line knife valve& annular and tee spool f/2L-314, new tee spool t/change diverter alignment arrived,clear cellar area of equipment, install diverter line in cellar,put wellhead equipment in cellar,make up new tee spool on diverter, N/U annular on tee spool 07/10/2014 Rig Accepted @ 0000 hrs,spot sub and pits, Nipple up Diverter Assy,berm rig spot cuttings tank and berm, Hook up interconnects,take on mud to the pits test mud lines U 2900 psi, load pipe shed w/5"DP,function test bag&knife valve,function test gas alarms and pvt system, state inspector john crisp witnessed function test. 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Continue M/U surface annular on diverter tee, hammer up flange bolts _ on diverter Rig Accepted @ 0000 hrs 03:00 06:00 3.00 0 0 MIRU MOVE MOB P Spot sub over well, set rig mats in position under sub,spot pits complex, lay mats under pit complex. instal berming around pit complex, lay herculite for cuttings box and spot cuttings tank, install berming around cuttings box. 06:00 08:00 2.00 0 0 MIRU MOVE RURD P Install knife valve on diverter line, install diverter sections, install riser and turn buckles. 08:00 12:00 4.00 0 0 MIRU MOVE RURD P Hook up interconnects air steam and water,electrician working on electrical lines Page 1 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 0 0 MIRU MOVE RURD P Take on water to brine tanks, continue installing diverter line blocking up and tightening bolts, finish berming around rig, rig up cuttings tank chute, change out saver sub,adjust rollers on draworks, function test bag and knife valve,test gas alarms, state inspector john crisp witnessed function test 18:00 21:00 3.00 0 0 MIRU MOVE RURD P Take on spud mud to pits,test mud lines t/2900 psi, load shed w/5" DP, load off drillerside w/10 3/4"casing, install 4"vavles on conductor. 21:00 00:00 3.00 0 0 MIRU MOVE RURD P Function test PVT system,finish loading 5" DP in shed strap and tally, prep rig floor t/P/U 5"DP and stand back via mouse hole. 07/11/2014 P/U 5" DP&5" HWDP via mouse hole stand back in derrick, P/U clean out BHA, Pre Spud Safety Meeting, Clean out conductor t/257', POOH L/D Clean Out BHA, M/U Drilling BHA t/154' 00:00 08:00 8.00 0 0 MIRU DRILL PULD P Pick up 5" Dp via mouse hole stand back in derrick 40 stands 08:00 11:00 3.00 0 0 MIRU DRILL PULD P P/U 5" HWDP via mouse hole stand back in the derrick. 11:00 12:00 1.00 0 0 MIRU DRILL PULD P P/U clean out BHA components t/rig floor, load shed w/drilling BHA. 12:00 13:30 1.50 0 0 SURFA( DRILL SFTY P Pre spud safety meeting 13:30 15:00 1.50 0 134 SURFA( DRILL PULD P P/U Clean out BHA bit, motor, stab, HWDP 15:00 21:00 6.00 134 257 SURFA( DRILL DRLG P Clean out conductor t/134' Drill f/ 134't/257'400 GPM 270 psi 40 RPM 50 PUW 48 SOW 50 ROT ADT 1.25 21:00 22:00 1.00 257 0 SURFA( DRILL PULD P POOH f/257'breaking down clean out BHA 22:00 00:00 2.00 0 154 SURFA( DRILL PULD P M/U Drilling BHA, orient motor t/ gyro&MWD, M/U ARC,Telescope, Stab, 7" NMFC t/154' 07/12/2014 P/U BHA shallow pulse test MWD&Gyro tools, Continue P/U BHA t/257'Drill Ahead f/257 t/1899'600 gpm 1200 psi 80 rpm 4k tq Footage-1642' 00:00 01:30 1.50 154 154 SURFA( DRILL DHEQ P Shallow Pulse test MWD tools,450 GPM 350 psi, gyro survey test. 01:30 02:00 0.50 154 257 SURFA( DRILL PULD P Continue P/U BHA f/154't/257' 02:00 12:00 10.00 257 957 SURFA( DRILL DDRL P Drill f/257't/957'550-GPM 940- PSI 60-RPM TQ ON-3.5K PUW-78K SOW-75K ROT-75K ART-2.93 AST-2.16 TOTAL BIT HRS 5.09 12:00 00:00 12.00 957 1,899 SURFA( DRILL DDRL P Drill f/957't/1899'600-GPM 1210- PSI 80-RPM TQ ON-4K OFF-2.5K PUW- 108K SOW-96K ROT-94K Page 2 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/13/2014 24 hr Summary Wait on cuttings tank to be emptied, Drill ahead f/1899'U TD @ 2534'Circ and condition hole standing back stank every bottoms up, OWFF well static,Attempt U pull on elevators tight hole and swabbing pull 35k over @ 1624', BROOH f/1658'U 756'550 gpm 900 psi 60 rpm 00:00 02:00 2.00 1,899 1,899 SURFA( DRILL CIRC T Wait on super suckers U empty cuttings tank, lack of super sucker availability between ASRC/PEAK/CH2MHILL 02:00 12:00 10.00 1,899 2,534 SURFA( DRILL DDRL P Drill f/1899'U 2534'650-GPM 1400 -PSI 90-RPM 5.5K-TQ ON 3K-OFF PUW- 108 SOW-95K ROT-103K AST- 1.51 ART-6.55 FOOTAGE-635 12:00 18:15 6.25 2,534 1,658 SURFA( CASING REAM P Pump Hi Vis Sweep BROOH f/2534' U 1658'594-gpm 1025 psi 80 rpm 18:15 18:45 0.50 1,658 1,658 SURFA( CASING OWFF P Observe well f/flow,well static 18:45 19:30 0.75 1,658 1,658 SURFA( CASING TRIP P Attempt U pull on elevators swabbing and tight hole observed @ 1624'work string 35k over pull observed unable to work through. 19:30 00:00 4.50 1,658 756 SURFA( CASING REAM P BROOH f/1658'U 756'550 gpm 900 psi 60 rpm. 07/14/2014 BROOH f/756'U 219', L/D BHA as per DD/MWD, Clean&Clear Floor, R/U U run 10 3/4"Casing w/Tesco CRT, RIH w/10 3/4"casing check floats on jt#4,floats good, RIH U 1539'Circ&Cond Mud stage pumps U 6 BPM, RIH w/casing U 2495'. 00:00 03:00 3.00 756 219 SURFA( CASING REAM P Continue BROOH f/756'U 219'500 gpm 630 psi 60 rpm 2k tq PUW-75 SOW-75 k 03:00 06:30 3.50 219 0 SURFA( CASING PULD P L/D BHA as per MWD/DD 06:30 09:00 2.50 0 0 SURFA( CASING RURD P Clean&Clear floor L/D BHA components. 09:00 10:00 1.00 0 0 SURFA( CASING RURD P M/U 10 3/4"casing hanger U landing jt, make dummy run confirm depth 28.51', pull and L/D in shed 10:00 15:30 5.50 0 0 SURFA( CASING RURD P R/U U run 10 3/4"casing, L/D short bails R/U long bails and CRT tool, spiders and rig tongs. 15:30 21:00 5.50 0 1,539 SURFA( CASING RNCS P Run 10 3/4" Hyd 563 Casing as per detail,test floats on 4th jt, floats good, RIH U 1539'filling every 5 jts. 21:00 21:30 0.50 1,539 1,539 SURFA( CASING CIRC P Circulate and condition mud stage pumps U 6 bpm 120 psi PUW- 112k SOW-75k 21:30 00:00 2.50 1,539 2,495 ,SURFA( CASING RNCS P Continue RIH w/10 3/4" HYD 563 casing f/1539'U 2495'filling every 5 jts PUW-150k SOW-94k 37/15/2014 M/U Hanger Land Casing on hanger @ 2526'Circ&Cond mud, R/D Casing Equipment, R/U Cement Equipment, Circ&Cond f/cement job Perform Cement job as per detail, Bump plug 2635 stks, check floats, floats held, R/D cementing equipment, suck out landing jt,flush riser, N/U riser and diverter line, remove starting head, N/U wellhead. 00:00 00:30 0.50 2,495 2,495 SURFA( CASING CIRC P Circulate and condition mud 4 BPM 100 psi PUW- 150k SOW-95k 00:30 01:00 0.50 2,495 2,526 SURFA( CASING HOSO P M/U Hanger land 10 3/4" Casing on Hanger @ 2526' LPage 3 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 2,526 2,526 SURFA( CASING CIRC P Circulate and condition mud stage pumps f/2 bpm t/4 bpm 310 psi, PJSM f/R/D tesco&csaing running equipment. 02:00 03:00 1.00 2,526 2,526 SURFA( CEMEN-RURD P R/D Tesco CRT and Casing Running Equipment, R/U Cement head and circulating lines. 03:00 04:30 1.50 2,526 2,526 SURFA( CEMEN CIRC P Stage pumps up t/8 bpm 450 psi PUW- 150k SOW-105k 04:30 05:00 0.50 2,526 2,526 SURFA( CEMEN-SFTY P Pre Job Safety Meeting on cement job with all paries involved. 05:00 08:30 3.50 2,526 0 SURFA( CEMEN-CMNT P Shut down pumps, Line up t/ cementers, break circ.w/5 bbls mudpush, shut in perform PT t/3000 psi,good test, open up valves come on line w/95 bbls 10.5 ppg mudpush,drop bottom plug, pump 389.6 bbls 11.02 ppg lead cmt 7 bpm 200 psi, pump 58.1 bbls 12.0ppg tail cement 3 bpm 300 psi, drop top plug, kick plug out w/10 bbls water, displace w/225 bbls 9.8 ppg Drillplex mud, bump plug 2635 stks FCP 285 pressure up t/855 psi hold f/5 min, bleed off and check floats floats held. 08:30 11:30 3.00 0 0 SURFA( CEMEN RURD P Blow down lines, R/D Cementing equipment, clean shakers, suck out landing jt., Drain riser flush out riser. 11:30 12:00 0.50 0 0 SURFA( CEMEN'NUND P N/D diverter line, remove f/tee in cellar 12:00 17:30 5.50 0 0 SURFA( CEMEN-RURD P Clean out riser and annular w/stack washing tool, change out long bails install short bails, load 5" DP in shed, clean pits 17:30 22:30 5.00 0 0 SURFA( CEMEN NUND P Nipple down diverter assy in cellar remove riser and turn buckles, remove starting head, Install wellhead test t/5000 psi f/10 min. 22:30 00:00 1.50 0 0 SURFA( CEMEN-NUND P N/U BOP stack 07/16/2014 Continue N/U BOP stack,welder modify riser and install,fill stack and choke manifold w/water, R/U&test BOP's w/5"test jt 250/3500 psi, gas alarms&upper IBOP failed State inspector Lou Grimaldi witnessed test, Rebuild and reinstall valve, change out and retest gas monitor system operational, P/U 5" DP Rack back in derrick. 00:00 04:00 4.00 0 0 SURFA( CEMEN NUND P Continue t/N/U BOP Stack,tighten nuts around flange connection, hook up turn buckles, 04:00 05:30 1.50 0 0 SURFA( CEMEN-SFTY T Evacuate rig due t/high H2S alarm, all personel mustered, driller and floorhand don SCBA's clear the rig w/ H2S monitor, No H2S present faulty sensor. 05:30 09:30 4.00 0 0 SURFA(WHDBO NUND P Nipple Up BOPE stack welder lengthening riser to fit on stack, M/U riser 09:30 10:30 1.00 0 0 SURFA( WHDBO RURD P Fill stack and choke lines, R/U test equipment. Page 4 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 17:00 6.50 0 0 SURFA( WHDBO BOPE P Test BOPE w/5"test jt,test choke valves 1-16, HCR&Man choke& Kill, 2"demco,Auto and man IBOP( upper IBOP valve failed),test upper lower and blind rams,Annular, 2 test spool vavles, TIW&Dart,Test Gas Alarms(Failed),Accumulator test AOGCC Inspector Lou Grimaldi witnessed test. 17:00 20:00 3.00 0 0 SURFA(WHDBO BOPE T Remove IBOP and rebuild and reinstall, Gas alarm control panel changed out. and retested (operational). Prep U P/U 5" DP 20:00 00:00 4.00 0 0 SURFA( CEMEN-TRIPP Transfer HWDP, P/U 5" DP f/shed RIH U rack back in derrick 07/17/2014 P/U 5" DP stand back in derrick,Test upper IBOP valve 250/3500 psi f/5 min, M/U BHA as per MWD/DD P/U 5" DP f/shed single in the hole U 1510'shallow pulse test tools, Continue P/U 5"DP U 2264'R/U&test casing U 3000 psi f/30 min good test,Wash&Ream U top of CMT @ 2433' Drill CMT, FC, FS @ 2526' 00:00 04:45 4.75 0 0 SURFA( CEMEN-PULD P P/U 5" DP rack Back in Derrick 04:45 05:00 0.25 0 0 SURFA( CEMEN-SFTY P Kick while tripping drill&AAR 05:00 06:00 1.00 0 SURFA( CEMEN'RURD P Drain Stack, pull wear ring 06:00 08:00 2.00 0 0 SURFA( WHDBO BOPE T Test Upper IBOP after failure, set test plug fill stack with water,test U 250 3500 psi test assy leaked, repair and retest same good test, R/D test equipment, pull test plug 08:00 09:00 1.00 0 0 SURFA( CEMEN-RURD P Set wear ring blow down lines. 09:00 13:30 4.50 0 756 SURFA( CEMEN'PULD P P/U BHA components and M/U BHA as per MWD&DD U 756' 13:30 14:30 1.00 756 1,510 SURFA( CEMEN PULD P P/U 5" DP f/the shed single in the hole f/756'U 1510' 14:30 15:00 0.50 1,510 1,510 SURFA( CEMEN'DHEQ P Shallow test MWD and Directional tools 500 gpm 1145 psi 15:00 16:00 1.00 1,510 2,264 SURFA( CEMEN PULD P P/U 5" DP f/shed f/1510'U 2264' 16:00 16:30 0.50 2,264 2,433 SURFA( CEMEN-TRIP P RIH f/2264'U TOC @ 2433' 16:30 18:30 2.00 2,264 2,264 SURFA( CEMEN-PRTS P R/U&test casing U 3000 psi f/30 min good test, R/D test equipment, blow down lines. 18:30 00:00 5.50 2,433 2,526 SURFA( CEMEN-DRLG P Drill CMT f/2433'U FC @ 2446' Drill FS @ 2526'400 gpm 1125 psi 70 RPM 5k tq PUW-110k SOW-95k Rot- 102k 07/18/2014 Finish Drilling float shoe and Rat Hole, Drill 20'of new hole U 2554'Circ f/FIT Displace well U 9.6ppg LSND, R/U&Perform FIT U 16.6ppg EMW, RIH Drill Ahead V 2661'Wash Pipe started leaking POOH U Shoe, C/O Wash Pipe, RIH f/2452'U 2661' Drill Ahead as per MWD/DD U 4055'(Directional Tools 90°R Offset Misaligned) 00:00 01:30 1.50 2,526 2,534 SURFA( CEMEN-DRLG P Drill FS&Rat hole U 2534'600 gpm 1500 psi 80 rpm 5k tq 01:30 02:00 0.50 2,534 2,554 SURFA( DRILL DDRL P Drill f/2534'U 2554'600 GPM 80 RPM 5k TQ 5k WOB 02:00 02:30 0.50 2,554 2,554 SURFA( DRILL CIRC P Circulate&Condition f/FIT Displace Spud mud w/9.6ppg LSND Page 5 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 2,554 2,515 SURFA( DRILL TRIP P Stand back DP t/2515' 03:00 03:45 0.75 2,515 2,515 SURFA( DRILL LOT P R/U&Perform FIT U 16.6ppg EMW 875 psi, R/D Test Equip. 03:45 05:30 1.75 2,554 2,661 INTRM1 DRILL DDRL P Make up Stand Wash&Ream U 2554' Drilling ahead U 2661'625 GPM 1520 psi 80 RPM 5k TQ PUW- 105k SOW-100k ROT 100k 05:30 06:00 0.50 2,661 2,452 INTRM1 DRILL TRIP T POOH U change out swivel packing f/2661'U 2452' 06:00 07:00 1.00 2,452 2,452 INTRM1 DRILL RGRP T Change out Swivel Packing on top drive. 07:00 07:30 0.50 2,452 2,661 INTRM1 DRILL TRIP T RIH f/2452'U 2661' 07:30 12:00 4.50 2,661 3,019 INTRM1 DRILL DDRL P Drilling ahead f/2661'U 3019'650 GPM 1750 psi 120 RPM 5k TQ ON 3.5k OFF PUW-110k SOW-95 ROT- 100k ART-3.42 Total Jar Hrs 40.5 12:00 00:00 12.00 3,019 4,055 INTRM1 DRILL DDRL P Drill f/3019'U 4055'650 GPM 1970 PSI 120 RPM TQ ON-9K OFF-5K PUW- 122K SOW-95K ROT- 103K ART-3.36 JAR HRS 43.86 07/19/2014 Drill f/4055'U 4526', Pump Hi-Vis sweep around 15%increase of cuttings on return, BROOH f/4526'U 2452', CBU casing unloaded cuttings, Service rig slip and cut drilling line, RIH f/2452'U 4418' No hole issues,Wash &Ream U 4526' Drill Ahead U 4997' 00:00 05:30 5.50 4,055 4,526 INTRM1 DRILL DDRL P Drill f/4055'U 4526'650 GPM 2200 PSI 120 RPM 10k TQ ON 7.5k OFF PUW- 130K SOW-SOW-95K ROT- 105K ADT-3.05 05:30 06:30 1.00 4,526 4,526 INTRMI DRILL CIRC P Circulate and condition hole, pump hi viss sweep around 15%increase in cuttings on return,650 gpm 2100 psi 06:30 10:00 3.50 4,526 2,452 INTRM1 DRILL REAM P BROOH f/4526'U 2452'600 gpm 1930 psi 60 rpm 6.5k tq 10:00 11:00 1.00 2,452 2,452 INTRMI DRILL CIRC P Cirulate and condition hole600 gpm 1690 psi 50 rpm, hole unloaded circulate until clean. 11:00 11:30 0.50 2,452 2,452 INTRM1 DRILL SVRG P Service rig 11:30 14:30 3.00 2,452 2,452 INTRM1 DRILL SLPC P Slip and cut drilling line 78'service top drirve and draworks 14:30 18:00 3.50 2,452 4,418 INTRM1 DRILL WPRT P RIH f/2452'U 4418'no hole issues observed 18:00 18:30 0.50 4,418 4,526 INTRM1 DRILL REAM P Wash&ream f/4418'U 4526'650 gpm 2115psi 80 rpm 18:30 00:00 5.50 4,526 4,997 INTRM1 DRILL DDRL P Drill f/4526'U 4997'650 GPM 2185 PSI 120 RPM TQ ON 10K OFF 7K PUW-138K SOW-96K ROT- 105K ADT-3.25 Page 6 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 37/20/2014 24 hr Summary Drill f/4997't/5751'packed off, lost returns,work string, establish returns, stage pumps t/full drilling rate w/ 120 RPM ream out t/5469'wash&ream U bottom no issues, Drill f/5751't/6315' No hole trouble 00:00 09:00 9.00 4,997 5,751 INTRM1 DRILL DDRL P Drill f/4997't/5751'650 GPM 2365 PSI 120 RPM TQ ON 10K OFF 8K PUW- 140K SOW-100K ROT- 113K ADT-5.78 HRS 09:00 14:00 5.00 5,751 5,751 INTRM1 DRILL OTHR T Hole Packed off,work string, establish returns stage pumps 36 spm 385 psi,work string slowly stage pumps back U drilling rate, work string slowly, CBU hole unloaded 30%increase in cuttings, BROOH U 5469'full returns and movement,Wash&ream U bottom @ 5751', pump sapp&nut plug pill, 1900 units gas on bottoms up. 14:00 00:00 10.00 5,751 6,315 INTRM1 DRILL DDRL P Drill f/5751'U 6315'650 GPM 2450 PSI 120 RPM 11K TQ ON 9K OFF PUW-151K SOW-110K ROT- 125K ADT-5.68 37/21/2014 Drill f/6315'U 6410'observe slight pack off,work string, BROOH f/6410'U 4500' 100 rpm 650 gpm, Hole unloaded, OWFF RIH f/4500'U 6410'CBU,4200 units of gas on bottoms up, Drill f/6410'U 7100'weight up U 9.8 ppg 00:00 02:00 2.00 6,315 6,410 INTRM1 DRILL DDRL P Drill f/6315'U 6410'650 GPM 2450 PSI 120 RPM 9.5K TQ ON 8K OFF PUW-150K SOW- 105K ROT- 125K ADT-.95 HRS Packing off on back ream. 02:00 08:00 6.00 6,410 4,500 INTRM1 DRILL REAM P BROOH f/6410'U 4500' 100 rpm 650 gpm 2450 psi Hole unloaded multiple times, pull last stand slow until shakers cleaned up. 08:00 08:30 0.50 4,500 4,500 INTRM1 DRILL OWFF P Observe well f/flow well static, service rig while monitoring. 08:30 10:30 2.00 4,500 6,410 INTRM1 DRILL TRIP P RIH f/4500'U 6410' 150k PUW 100k SOW 10:30 12:00 1.50 6,410 6,410 INTRM1 DRILL CIRC P Circulate and condition mud 100 rpm 650 gpm 2620, bottoms up gas observed 4200 units. 12:00 00:00 12.00 6,410 7,100 INTRM1 DRILL DDRL P Dril f/6410'U 7100'650 GPM 2550 PSI 120 RPM 12K TQ ON 9K OFF PUW- 157K SOW- 117K ROT- 117K ADT-7.48 Ice berg formation @ 7030' MD Flow Check static Weight up U 9.8 ppg 6450'MD Page 7 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/22/2014 24 hr Summary Drill Ahead F/7100 T/8479'. Pump sweep and circulate hole clean monitor well and make short trip back reaming to 6500'MD with no issues. 00:00 06:00 6.00 7,100 7,447 INTRM1 DRILL DDRL P Dril f/7100't/7447'650 GPM 2600 PSI 120 RPM 11 - 13K TQ ON 8-9k OFF PUW- 160K SOW- 115K ROT- 130K Weight up t/10.0 ppg 7400' MD 06:00 12:00 6.00 7,447 7,850 INTRM1 DRILL DDRL P Dril f/7447't/7850'640 GPM 2630 PSI 120 RPM 12-14kK TQ ON 9K OFF PUW- 165K SOW-115K ROT- 115K ADT-6.01 Ice berg formation. 12:00 18:00 6.00 7,850 8,197 INTRM1 DRILL DDRL P Dril f/7850't/8197'640 GPM 2650 PSI 120 RPM 12- 14K TQ ON 9K- 11k OFF PUW-173K SOW- 120K ROT- 133K ADT-3.14 Ice berg formation. 18:00 00:00 6.00 8,197 8,479 INTRM1 DRILL DDRL P Drill f/8197't/8479'640 GPM 2650 PSI 120 RPM 12- 15KTQON 11 - 14K OFF PUW- 179K SOW- 125K ROT- 143K ADT-3.05 Ice berg formation. 07/23/2014 CBU. BROOH f/8479't/6410. RIH f/6410't/8385',Wash/ream U 8479'. Drill f/8479'U 9044'. TD called by Geologist at 9044'. CBU.Obtain final survey. POOH f/9044'U 8851. Geologists analized BU sample from TD, decision made to continue drilling. RIH, continue drilling f/9044'U 9120'.TD called by Geologist at 9120'.CBU.Obtain final survey. 00:00 01:00 1.00 8,479 8,479 INTRM1 DRILL CIRC P Circulate and condition CBU. 640 gpm,2715 psi, 120 rpm,13-14k Tq, UP Wt 175k, DN Wt 120, RT Wt 140k. Monnitor 15 minutes-Static. 01:00 06:00 5.00 8,479 6,410 INTRM1 DRILL REAM P BROOH f/8479'U 6410' . 640 gpm 2715 ICP, 2500 FCP,120 rpm, 13- 14k initiak Tq, 10-12k final Tq. Initial UP Wt 175k, Dn Wt 120k, RT Wt 140k, Final UP Wt 160k, Dn Wt 105k, RT Wt 125k. Max ECD 11.11, MW 10.1 ppg. 06:00 06:30 0.50 6,410 6,410 INTRMI DRILL SVRG P Service top drive and wash pipe.Well static. 06:30 08:00 1.50 6,410 8,385 INTRM1 DRILL WPRT P RIH f/6410'U 8385. UP Wt 180k, Dn Wt 110k. 08:00 09:00 1.00 8,385 8,479 INTRM1 DRILL REAM P Wash&ream f/8385'U 8479'.640 gpm, 2800 psi, 120 rpm, 14k Tq, Up Wt 180k, Dn Wt 120k, RT Wt 140k. 09:00 12:00 3.00 8,479 8,668 INTRMI DRILL DDRL P Drill f/8479'U 8668'. 640 gpm, 2870 psi on, 2850 psi off, 120 rpm, 16K Tq On, 14K Off. PUW-185K SOW- 120K ROT-140K ADT-1.94 Ice berg formation. Page 8 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 8,668 9,044 INTRM1 DRILL DDRL P Drill f/8668't/9044'.640 gpm, 2760 psi on, 2725 psi off, 120 rpm, 17- 20K Tq On, 15-17K Off. PUW- 200K,SOW-120K, ROT-145K, 10 - 13k WOB, 10.9-11.0 ECD.ADT- 3.91 Ice berg formation. 18:00 19:30 1.50 9,044 9,044 INTRM1 DRILL CIRC P Circulate and condition BU as/per Geologist call TD 9044.640 gpm, 2375 psi Off, 110 rpm,14-17k Tq Off, PUW-200K,SOW-120K, ROT- 145K, 10-13k WOB, 10.9- 11.0 ECD. 19:30 21:00 1.50 9,044 9,044 INTRM1 DRILL REAM P BROOH f/9044't/8851'. Circulate BU each stand racked back until shakers clean. 630 gpm, 2715 ICP, 2500 FCP,110 rpm, 13- 14k Tq, UP Wt 200k, Dn Wt 125k, RT Wt 145k, ECD 10.9- 10.8, MW 10.1 ppg. *Geologists analized BU sample from TD,decision made to continue drilling.Well engineer notified. Washed back in hole to 9044'.Obtain bottomhole surveys. 21:00 22:00 1.00 9,044 9,120 INTRM1 DRILL DDRL P Drill f/9044't/9120'.630 gpm, 2660 psi on, 2630 psi off, 120 rpm, 15- 17K Tq On, 13-15K Off. PUW- 200K,SOW-120K, ROT-145K, 10 -13k WOB, 10.9-11.0 ECD. 22:00 00:00 2.00 9,120 9,120 INTRM1 CASING CIRC P Circulate and condition BU as/per Geologist, call TD at 9120'.620 gpm, 2650 psi Off, 110 rpm,14-17k Tq Off, PUW-200K,SOW-120K, ROT- 145K. 10.9-11.0 ECD. Obtain bottomhole surveys and new SPR's. 37/24/2014 Continue circulate and condition. NFT-Static. POOH on elevators f/9120't/7338'.Work through and clean up tight spots f/8820'-t/8755'. POOH on elevators f/7716't/4910' . Clean up tight spots f/6360'-t/6320', 5458'-5428', 5170'and 4910'. RIH f/4500't/5500'. BROOH f/5500't/2450' . Circulate and condition. POOH on elevators f/2450't/756'. Ly/Dn BHA#3. 00:00 00:30 0.50 9,120 9,120 INTRM1 CASING CIRC P Continue circulate and condition.615 gpm,2590 psi Off, 105 rpm,14-16k Tq Off, PUW- 190K, SOW- 115K, ROT-145K. 00:30 01:00 0.50 9,120 9,120 INTRM1 CASING OWFF P NFT. RKB to top of fluid level=4.5- static 01:00 06:00 5.00 9,120 7,716 INTRM1 CASING WPRT P POOH on elevators f/9120't/7338'. UP Wt 205k, Dn Wt 118k, 10k hole drag. 15-30k overpull f/8820'- t/8755,work through multiple times to eliminate overpull. Pump dry job at 7716'. BDTD. 06:00 09:30 3.50 7,716 4,910 INTRM1 CASING WPRT P POOH on elevators f/7716't/4910'. UP Wt 175k, Dn Wt 110k, 30k overpull f/6360'-t/6320', 25k overpull at 5458'-5428',work through multiple times.20k overpull at 5170', 25k overpull at 4910',work through multiple times. Page 9 of 24 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 09:30 10:00 0.50 4,910 5,500 INTRM1 CASING WPRT P RIH f/4500't/5500'. 150k PUW, 100k SOW. 10:00 15:30 5.50 5,500 2,450 INTRM1 CASING REAM P BROOH f/5500't/2450'. 640 gpm, 2515 psi,120 rpm, 8-9k Tq, UP Wt 150k, Dn Wt 100k, RT Wt 115k. 15:30 17:00 1.50 2,450 2,450 INTRM1 CASING CIRC P Circulate and condition. Pump 40 bbl sweep to surface. 605 gpm, 1950 psi, 110 rpm, 3-4k Tq, PUW- 105K, SOW-94K, ROT-97K. Monitor well. Pump 30 bbl slug. BDTD, Remove blower hose, prep for ly/dn BHA. 17:00 18:00 1.00 2,450 756 INTRM1 CASING TRIP P POOH on elevators f/2450't/756' . UP Wt 75k, Dn Wt 70k. Monitor well at BHA. 18:00 21:00 3.00 756 0 INTRM1 CASING PULD P PJSM. Ly/Dn BHA#3. 17 jnts HWDP, Jars, 3 NMFC. PJSM on unloading of source, remove source. Continue ly/dn BHA as/per DD/ SLB. 21:00 00:00 3.00 0 0 INTRM1 CASING PULD P PJSM.Ly/Dn BHA. Clean/clear rig floor of all subs and equiptment. 07/25/2014 Flush BOPE. Dry install casing hanger in wellhead. Change upper rams to 7 5/8". PT upper rams/annular. RU casing tools. MU and RIH with 7 5/8", 39#shoetrack. RIH with 7 5/8",29.7#casing to 4943'. 00:00 01:00 1.00 0 0 INTRM1 CASING WWWH P MU wash assy. Flush and wash BOPE clean. 01:00 02:30 1.50 0 0 INTRM1 CASING SEQP P Remove wear bushing. Conduct dry install with LD jnt and casing hanger in wellhead-good 02:30 04:30 2.00 0 0 INTRM1 CASING BOPE P Change upper rams from 3 1/2"x 5 1/2"VBR's to 7 5/8"solid body. 04:30 05:30 1.00 0 0 INTRM1 CASING BOPE P RU/Test jnt and plug.set plug. RU equipment to test. 05:30 06:30 1.00 0 0 INTRM1 CASING BOPE P Test BOPE 7 5/8"rams annular from 250 low/3500 high. Charted. 06:30 07:00 0.50 0 0 INTRM1 CASING BOPE P Pull testjnt/plug. R/Dn test tools and equipment. 07:00 10:30 3.50 0 0 INTRM1 CASING RURD P R/Up tools and equipment to run 7 5/8"casing. Remove 5" elevators,short bales. Install long bales,safety valves for casing. MU Tesco equipment with service loop. Stage casing spiders and blower hose. 10:30 11:00 0.50 0 0 INTRM1 CASING SFTY P PJSM with Crew and third party venders. 11:00 12:00 1.00 0 387 INTRM1 CASING RNCS P MU shoetrack: 7 5/8",39#. Baker lock,shoe,float collar connections. Circulate and check floats-good. RIH to 387'with 39#7 5/8"casing. Page 10 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 348 4,943 INTRMI CASING RNCS P RIH with 7 5/8", 29.7#casing f/348' t/4943'. Fill every 10 jnts, break circulation every 2000'after shoe depth. Circulate at 6 bpm,295 psi, UP Wt 135k, Dn Wt 105k. 600 gas units. Install bow spring centrazers on jnts 1#,#2 and free floating Hydroforms on each joint from jnt#3 to#74. 07/26/2014 Cont. RIH with 7 5/8",29.7#casing f/4943' t/9080'.Attempt to MU casing hanger. Circulate and condition. MU re-dressed casing hanger. Circulate Mud to dilute for cement job. R/Dn Tesco tools,equipment. Circulate and reciprocate pipe. Cement 7 5/8"casing at set depth of 9110'MD as/per procedure. TOC at 6482'. Good returns during entire job. Bumped plug at 20:54 hrs, checked floats, not holding.Apply pressure to floats.WOC. 00:00 12:00 12.00 4,943 9,080 INTRM1 CASING RNCS P Continue RIH with 7 5/8",29.7# casing f/4943' t19080'. Fill every 10 jnts, break circulation every 2000' after shoe depth. Circulate at 6 bpm, 430 psi, UP Wt 175k, Dn Wt 105k. Install free floating Hydroforms on each joint from jnt#162 to#212. 12:00 13:00 1.00 9,080 9,080 INTRM1 CASING RNCS T Attempt to make up casing hanger and landing joint. Galled threads, lay down hanger/landing joint. Layed down landing joint,would not make up to hanger. 13:00 14:00 1.00 9,080 9,080 INTRM1 CASING CIRC T Circulate and condition.f/9080' t/9040',4.5 bpm,465 psi. UP Wt 250k, Dn Wt 115k. (While repairing threads on hanger with Cameron hand assisting.) 14:00 14:30 0.50 9,080 9,100 INTRMI CASING RNCS T MU casing hanger with landing joint, using single elevators,guide Tesco tool into landing joint. SO hanger above casing head to 9100'. 14:30 16:00 1.50 9,100 9,100 INTRM1 CEMEN-CIRCP Circulate and condition. Dilute mud for cement job. Stage pumps up to 6 bpm, 522 ICP,485 FCP, UP Wt 225k, Dn Wt 115k. CBU 2x. 16:00 17:00 1.00 9,100 9,100 INTRM1 CEMEN-RURD P PJSM. R/D Tesco tools. MU side door elevators to bales, cementing head, hose, lines,valves and plugs. 17:00 18:00 1.00 9,100 9,100 INTRMI CEMEN-CIRC P PJSM. Circulate and condition. 6 bpm, 650 psi, UP Wt 225k, Dn Wt 115k. Page 11 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:00 3.00 9,100 9,110 INTRM1 CEMEN-CMNT P Turn over to SLB cementers. Pump 5 bbls chemical wash to press test lines to 1700 psi low to 3500 psi high, good test. Pump 35 bbls of CW at 5 bpm, 885 psi. Pump 40 bbls, 12.5#, Mudpush,4.5 bpm,764 psi. Drop bottomplug. Pump 159 bbls, 15.8#gas block cement, 5 bpm, 1135 psi. Drop top plug. Displace with rig pumps at 6 bpm while reciprocating,1085 ICP,to 5300 strokes. Slow to 3 bpm, 745 FCP. Land casing on hanger, set depth of 9110',continue pumping to bump plug at 5729 strokes. Increase to 1400 psi and hold 5 minutes. Cement in place at 20:54 hrs. Bleed off pressure and check floats. Floats did not hold receieved back 5.9 bbls. **Obtained good returns through out entire circulating/cement job while reciprocating pipe. 21:00 00:00 3.00 9,110 9,110 INTRM1 CEMEN-WOC T Wait on cement. Pressure casing back up to 500 over FCP, bled back to 1000 psi.Shut in and hold for 6.45 hours to obtain 100 psi compressive strength. Prep 4"drill pipe in pipe shed. Clear and clean rig. 07/27/2014 WOC. Bled press, check floats-2 bbls back. Install pack-off in well head, PT. Install wear ring. Freeze protect OA with water followed by diesel. POOH w/5"drill pipe sideways to 5177'. 00:00 04:00 4.00 9,110 9,110 INTRM1 CEMEN-WOC T WOC. Maintain 1000 psi on casing for 100 psi compressivity. Load 4" drill pipe in pipe shed. 04:00 06:00 2.00 9,110 9,110 INTRM1 CEMEN-RURD P Bleed pressure off to check floats- good. Recieved 2 bbls back. R/Dn cement head, Ly/Dn landing joint, bales ,Tesco equipment. Drain stack. 06:00 08:30 2.50 9,110 9,110 INTRM1 CEMEN-WWSP P PJSM. RU and install 7 5/8"x 10 3/4' pack-off as/per Cameron rep. PT to 5000 psi, 10 min-Good test. Install wear ring. ID=9 3/4", OD= 10 3/4". 1.08' length. R/Dn running tools.* Hot oil freeze protected 7 5/8"x 10 3/4"OA with 112 bbls water followed by 102 bbls diesel. 08:30 00:00 15.50 9,110 9,110 INTRM1 CEMEN PULD P PJSM. POOH sideways,on elevators, laying down 5"drillpipe. I Total of 55 stands=5177'. UP Wt 50k, Dn Wt 38k. 37/28/2014 P/U 4" DP and rack back 23 stands in the derrick. Install VBR rams in UPR cavity.Test BOPE as/per AOGCC. Page 12 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 10:00 10.00 8,476 0 INTRM1 CEMEN-PULDP PJSM.POOH sideways, on elevators, laying down singles of 5" drillpipe to surface'.Total of 90 stands=8476'. UP Wt 50k, Dn Wt 38k. 10:00 15:30 5.50 0 0 INTRM1 CEMEN-PULDP PJSM. PU singles of 4"drill pipe from pipeshed. Rack back in derrick. Total of 23 stands. UP Wt 66k, Dn Wt 60k. 15:30 16:00 0.50 0 0 INTRMI CEMEN'SFTY P Simulate Man Down drill in mud pits -successful)drill. 16:00 17:00 1.00 0 0 INTRM1 CEMEN-SEQP P PJSM. Remove wear bushing. Pump out stack. Set test plug. Close blinds. 17:00 19:00 2.00 0 0 INTRM1 CEMEN-SEQP P Remove 7 5/8"solid body rams and install 3.5"x 6"VBR's. 19:00 19:30 0.50 0 0 INTRM1 CEMEN-SEQP P PU test tools/hoses and equipment. Fill stack and lines with fluid. 19:30 20:00 0.50 0 0 INTRM1 WHDBO RURD P PJSM to test BOPE. 20:00 00:00 4.00 0 0 INTRMI WHDBO BOPE P Test BOPES. Bob Noble has waived witness of this test via e-mail on 7/26/2014 @ 17:17 hours. Test choke manifold, HCR kill, HCR Choke, manual valves, IBOP valves, safety valve and dart valve to 3500 psi.Test VBR's and annular preventer with 4.5",4"and 3.5"test joints to 250/3500 psi. 07/29/2014 Finish BOP test, P/U 6 1/2" Pilot Hole BHA#4, P/U 4"DP singles and run in the hole. Cement Log F/6200' T/7600'. 00:00 03:30 3.50 0 0 INTRMI WHDBO BOPE P Continue testing BOP's,test VBR's and annular preventer with 4.5",4" and 3.5"test joints, 250/3500 psi. Test accumulator to AOGCC specs and perform a CPAI accumulator draw down. Both tests were good. 03:30 04:30 1.00 0 0 INTRM1 WHDBO SEQP P Remove wear bushing,drain stack, pull test plug,set ware ring, B/D all test equipment, line up choke manifold. 04:30 07:30 3.00 0 180 INTRM1 CEMEN'PULD P P/U 6 1/2"Pilot Hole BHA#4 per DD. 07:30 10:00 2.50 180 531 INTRM1 CEMEN-PULD P P/U Source and install as per SLB. 10:00 12:00 2.00 531 1,540 INTRM1 CEMEN-PULD P P/U and run 4"DP singles in the hole 12:00 12:30 0.50 1,540 1,000 INTRM1 CEMEN-TRIPP Pull 6 stands of 4"DP and stand it back into the derrick. 12:30 20:30 8.00 1,000 6,200 INTRM1 CEMEN'PULD P Continue to P/U 4"DP singles and run in the hole. 20:30 00:00 3.50 6,200 7,600 INTRM1 CEMEN DLOG P Cement log from 6200'to 7600', 850' to 900'/hr max as per MWD. Fill pipe at 7500'and check MWD batterie. GPM 220, PSI 1900, Calculated hole fill=40.6 bbls, Actual=45.5 bbls. Page 13 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/30/2014 24 hr Summary Single into the hole with 4"DP and perform casing cement logs at the same time. Pressure test casing to 3000 psi. Drill cement plugs, FC, Shoe track, Rat hole, and 20'of new hole. Pull back into casing and swap out 10.3 ppg LSND mud to 10.5 LSND mud. Perform LOT, Decision to use mud pump LOT and called LOT 12.4 EMW w/525 psi 10.5 ppg mw and TVD of 7-5/8"shoe @ 5266'. 00:00 05:00 5.00 7,600 8,900 INTRM1 CEMENT PULD P P/U and single in the hole with 4" DP. Run cement logs while running in the hole. PUW 155K, SOW 60K. Max running speed 850'to 900'/hr. 05:00 06:00 1.00 8,900 8,900 INTRM1 CEMENT SLPC P Slip and cut drilling line. 06:00 07:30 1.50 8,900 8,900 INTRM1 CEMEN-CIRCP Circulate and condition 10.3 ppg mud until even all the way around. PUW 160K, SOW 76k. 07:30 08:30 1.00 8,900 8,900 INTRM1 CEMENT PRTS P Pressure test 7 5/8"casing to 3000 psi, hold for 30 minutes. Test was good. 08:30 12:00 3.50 8,900 9,019 INTRM1 CEMENT COCF P Drill cement to cement plugs and FC.Tag and drill cement at 8983' to the cement plug at 9019'. PUW 160K, SOW 76K, RTW 108K, GPM 220, PSI 2017,TQ ON 12K,WOB 12K, RPM 60. 12:00 15:30 3.50 9,019 9,120 INTRM1 CEMEN"COCF P Drill out cement plugs, FC, Shoe track and rat hole to 9120'. GPM 220, RPM 80,TQ 12K, PSI 2060, WOB 5-10K, PUW 178K, SOW 78K, RWT 108K. 15:30 16:30 1.00 9,120 9,140 INTRM1 CEMENT DDRL P Drill new hole from 9,120'to 9,140' MD,TVD 5362'. ECD 11.4 PPG, ART.44 HRS,ADT.44 HRS, PUW 178K, SOW 78K, RWT 108K, RPM 80-90, GPM 240, PSI ON 2068, PSI OFF 2060,TQ ON 12-14K, TQ OFF 12-13K, BIT HRS 33.84, BIT FOR TOUR.44. 16:30 19:00 2.50 9,140 9,090 INTRM1 CEMEN'CIRC P Pull back into the 7 5/8"casing for LOT and change out mud, 10.3 ppg LSND to 10.5 ppg LSND. Circulate and condition mud until even all the way around for LOT. GPM 220, psi 2150. SPR taken at 1830 hrs, 9090' MD, 5260'TVD. Pump#1 at 2 bpm=480 psi, 3 bpm =760 psi. Pump#2 at 2bpm=500 psi, 3 bpm =780 psi. Page 14 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 22:30 3.50 9,090 9,090 INTRM1 CEMEN-LOT P Perform Leak off test with mud pump, pumped 36 stks, 2.5 bbls, leak off pressure 605 psi, EMW 12.7 ppg. Bled back 1.6 bbls. Retest with test pump, pumped 28.5 minutes, Equal to 94 stks mud pump volume(6.6 bbls). Bled back 2.1 bbls, Leak off pressure 395 psi, EMW 11.9 ppg. Final decision to use mud pump LOT: and called LOT 12.4 EMW w/ 525 psi 10.5 ppg mw and TVD of 7-5/8"shoe @ 5266'. 22:30 23:30 1.00 9,090 9,090 INTRM1 CEMEN-SVRG P Service rig while evaluating the LOT. 23:30 00:00 0.50 9,090 9,090 PROD1 DRILL RURD P R/D test equipment and prepare to drill ahead. 07/31/2014 Drill 6 1/2"pilot hole F/9120'T/9572'TD. Back ream F/9572'T/9355'. Open hole logs at 9355', 3 samples taken. Continue back reaming from 9355'to 8600'. Monitor well, pump dry job and POOH to P/U cement string. 00:00 11:00 11.00 9,140 9,572 PROD1 DRILL PHOL P Drill pilot hole from 9158'to 9572'TD. GPM 237, PSI ON 2261, PSI OFF 1815, RPM 100,TQ ON 12K,TQ OFF 11K, PUW 167K, SOW 92K, ROW 108K,ART 3.36 HRS,ADT 3.36 HRS, BIT 41.38 HRS,JARS 160.78 HRS. SPR taken at 11:20 HRS, 9572'MD, 5553'TVD. Pump#1 at 2 bbls=460 psi, 3 bbls =740 psi Pump#2 at 2 bbls=470 psi, 3 bbls =710 psi 10.5 ppg MW. 11:00 12:00 1.00 9,572 9,572 PROD1 DRILL CIRC P Circulate B/U to condition mud. PUW15K, SOW 105K, ROT 110K, MUD 10.5 ppg. 12:00 13:00 1.00 9,572 9,355 PROD1 DRILL REAM P Back ream F/9572'T/9355'. Monitor well for 10 minutes(static). GPM 230, PSI OFF 2115, RPM 70, TQ OFF 10-11K, RWT 110K, PUW 155K, SOW 88K. 13:00 15:00 2.00 0 9,355 PROD1 DRILL DLOG P Open hole logs with stethoscope tool at 9356'bit depth, sample depth 9295'. Sample#1 formation pressure 2864.45 psi, 10.3+ EMW. Sample#2 formation pressure 2851 psi, 10.3 EMW. Sample#3 formation pressure 2879 psi, 10.4 EMW. 15:00 16:30 1.50 9,355 8,600 PROD1 PLUG REAM P Back ream F/9355'T/8600', pump out to top of 39#casing to insure of no swabbing, GPM 220, PSI 1980. Monitor well for 15 minutes. 16:30 17:30 1.00 8,600 8,100 PROD1 PLUG TRIP P POOH F/8600'T/8100', PUW 165K, SOW 89K. Pump dry job and Line up on trip tank to monitor returns. Page 15 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 22:30 5.00 8,100 531 PROD1 PLUG TRIP P POOH F/8100'T/531', PUW 50K, SOW 50K. Monitor well a BHA, calculated hole fill 51 bbls, actual 54.6. 22:30 23:00 0.50 531 531 PROD1 PLUG SFTY P Pre job safety, laying down BHA and removing source. 23:00 00:00 1.00 531 261 PROD1 PLUG PULD P UD BHA,3 stands of HWDP W/Jars. 08/01/2014 L/D 6 1/2"BHA, run in the hole with 3 1/2"cement string,set cement kick off plug to P&A pilot hole.POOH to P/U 6 1/2"rotary steerable BHA. 00:00 03:30 3.50 261 0 PROD1 PLUG PULD P L/D BHA as per DD and clear floor. 03:30 04:00 0.50 0 0 PROD1 PLUG RURD P R/U GBR to run 3 1/2"tubing cement string. 04:00 07:30 3.50 0 949 PROD1 PLUG PULD P P/U tubing cement string 949'. Mule Shoe, 30 Jts of 3 1/2"tubinb, 2- XO's and a 4" DP pup JT. 07:30 12:00 4.50 949 6,371 PROD1 PLUG TRIP P TIH W/91 STDS of 4"DP. PUW 105K, SOW 74K, MW 10.5 ppg. 12:00 13:00 1.00 6,371 9,036 PROD1 PLUG TRIP P TIH F/6371'T/9036'. PUW 148K, SOW 77K, 13:00 13:30 0.50 9,036 9,036 PROD1 PLUG SVRG P Service Rig. 13:30 14:00 0.50 9,036 9,572 PROD1 PLUG TRIP P TIH F/9,036'T/9572'. 14:00 14:30 0.50 9,572 9,572 PROD1 PLUG CIRC P Circulate B/U, PSI 1130, GPM 230, SPM 78, FLOW 35%, PUW 161K, SOW 83K. 14:30 15:00 0.50 9,572 9,572 PROD1 PLUG SFTY P Pre job safety meeting for cement job. 15:00 16:00 1.00 9,572 9,572 PROD1 PLUG RURD P R/U cement equipment Page 16 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 19:30 3.50 9,572 8,960 PROD1 PLUG CMNT P Continue to circulate a total of 588 bbls 10.5 ppg mud prior to start of cement job while having PJSM and batching MP and cement(Max gas 94 units). Dowell pump 13.5 ppg MP to floor with centrifugal pump(Vol f/ unit to the floor=1.2 bbls).Test cmt equipment and lines to 500/3500 psi-good. Dowell pumped 15 bbls of 13.5 ppg MP II, then 1 bbl of H2O to get MP to the floor. Close bag and choke to load foam ball. Open choke and bag after loading the foam ball. Dowell pumped 37 bbls of 17#cmt (208 sx,yield 1 cuft/sx)@ 5 bpm, Dowell followed with 3.5 bbls of 13.5 ppg MudPush II and chased w/1 bbl water to get to the floor. Switch to rig pumps. Rig displaced w/81 bbls of 10.5 ppg mud, pumping 5 bpm until last 6 bbls, slowed to 2 bpm. Shut down, checked to see if balanced, -good. Break off circulating head, P/U single and POOH 7 stands of DP slowly (20'/min)to 8960', (150'above Shoe @ 9110'). Load foam ball and circulate out MP and excess cmt. MP returned to pits at 3,338 STKS, B/U 3 bbls of cmt returned. Full returns while pumping. 19:30 21:30 2.00 8,960 8,846 PROD1 PLUG CIRC P Pull 1 STD 8846', and continue circulating 3 B/U, GPM 443, SPM 150, FLOW 62%, 21:30 22:00 0.50 8,846 8,846 PROD1 PLUG OWFF P Observe well for 30 minutes for flow- static 22:00 00:00 2.00 8,846 6,465 PROD1 PLUG TRIP P POOH F/8,846'T/6,465', PUW 136K, SOW 76K. 08/02/2014 POOH and lay down the 3 1/2"cement string, P/U 6 1/2"rotary steerable BHA#5,TIH with 4"DP T/6,787'. Nabors IBOP on the Top Drive started leaking. In the process of repairing or replacing the IBOP. 00:00 03:30 3.50 6,465 949 PROD1 PLUG TRIP P POOH F/6465'T/949', PUW 40K, SOW 40K, MW 10.5 PPG, small amount of cement at 1708'on DP. Calculated fill 45.4 bbls,Actual fill 52.6 bbls. 03:30 08:00 4.50 949 0 PROD1 PLUG PULD P L/D 3 1/2"tubing,4"DP pup,2-XO, and mule shoe. Calculated fill 3.3 bbls,Actula fill 3.2 bbls. Clear and clean the floor, remove tubing from the pipe shed and bring in the 6 1/2" BHA. 08:00 08:30 0.50 0 0 PROD1 PLUG SFTY P Pre job safety meeting, P/U 6 1/2" rotary steerable BHA#5. 08:30 11:30 3.00 0 544 PROD1 PLUG PULD P P/U 6 1/2"rotary steerable BHA#5, make-up all tools as per SLB DD. Page 17 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 544 1,020 PROD1 PLUG TRIP P TIH with 4"DP F/544'T/1020', PUW 51K, SOW 48K, MW 10.5 ppg. 12:00 13:00 1.00 1,020 1,496 PROD1 PLUG TRIP P TIH F/1208'T/1496', Shollowtest SLB/MWD tools, PUW 65K, SOW 60K. 13:00 13:30 0.50 1,496 1,496 PROD1 PLUG DHEA P Circulate and shallow test SLB/MWD tools. GPM 230, PSI 1638, RPM 30, TQ OFF 787, SPM 78, FLOW 30%. 13:30 17:30 4.00 1,496 6,787 PROD1 PLUG TRIP P TIH F/1496'T/6787', PUW 123K SOW 73K, Fill every 20 stds. 17:30 18:00 0.50 6,787 6,787 PROD1 PLUG SVRG P Service rig, clear and clean floor. 18:00 00:00 6.00 6,787 6,787 PROD1 PLUG RGRP T Troubleshoot IBOP valve on TD, replaced actuator valve,would not test, In the process of replacing the stem packing or replacing the IBOP valve. 38/03/2014 Repair IBOP on Top Drive, TIH,tag cement at 8,960'. Drill cement,tight hole at 9,123',worked pipe free. POOH to 9,108',circulate and condition mud. Directionally drill T/9,204', back ream out of the hole T/9,012'. Swap out LSND mud to KLASHIELD, directionally drill T/9,490'. 00:00 03:30 3.50 6,787 6,787 PROD1 PLUG RGRP T Repair IBOP valve, replace valve key and valve. 03:30 06:00 2.50 6,787 8,964 PROD1 PLUG TRIP P TIH F/6787'T/8904',tag cement at 8964', Shoe @ 9110'. PUW 140K, SOW 99K. Calculated hole fill 10.8 bbls,Actual 6.5 bbls. 06:00 08:00 2.00 8,964 9,123 PROD1 PLUG KOST P Drill out cement F/8964'T/9123', PUW 14K,SOW 99K, RWT 102, WOB 5-10K, SPM 88, GPM 242, PSI ON 2727, RPM 60. 08:00 09:00 1.00 9,123 9,105 PROD1 PLUG OTHR T Pick up off bottom at 9123'tight hole. worked pipe,Jars went off at 247K, worked pipe free, recipricating 20 to 25'. P/U to 9105'circulate and _ condition mud. _ 09:00 10:30 1.50 9,105 9,105 PROD2 DRILL CIRC P Circulate and condition mud, rack back std#91 and circulate on std #90,9,108'while recipricating pipe. PSI OFF 2637, PUW 140K, SOW 99K, RWT 102K, RPM 60. 10:30 12:00 1.50 9,105 9,148 PROD2 DRILL KOST P Directional drill Sidetrack F/9123'to 9148', PSI ON 2470,TQ ON 14K, GPM 246,WOB 5-10, PUW 135K, SOW 100K, RWT 102K,ADT 1.0 HRS, BIT 1.0 HRS, JARS 161.78 HRS, MW 10.5 PPG. 12:00 14:00 2.00 9,148 9,204 PROD2 DRILL DDRL P Directional drill Sidetrack F/9148' T/9204', GPM 242, PSI ON 2616, PSI OFF 2488, RPM 60,TQ ON 12.5K,TQ OFF 10K, PUW 195K, SOW 70K, RWT 110K, MW 10.5, MD 9204', TVD 5290'. 14:00 15:00 1.00 9,204 9,012 PROD2 DRILL REAM P Back ream F/9204'T/9012', GPM 240, PSI OFF 2400, RPM 60,TQ OFF 10K, PUW 210, SOW 73K, RWT 110K. LPage 18 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 17:00 2.00 9,012 9,012 PROD2'1 DRILL CIRC P Build volume, monitor well,take on new mud(KLASHIELD)in pits and dump old mud, prep for displacement. 17:00 18:00 1.00 9,012 9,012 PROD2 DRILL CIRC P Displace LSND mud with 50 bbl Vis sweep followed by KLASHIELD mud. Pump surface to surface until clean and mud is even 10.5 ppg. PSI OFF 2400, GPM 234, SPM 78,TQ OFF 11K, RWT 102K, RPM 60. 18:00 19:00 1.00 9,012 9,204 PROD2 ,DRILL TRIP P TIH F/9110'T/9204', PUW 140K, SOW 85K, GPM 230, PSI OFF 1800, SPR#1 Pump at 2 bpm=400 psi, 3 bpm =630 psi SPR#2 Pump at 2 bpm=390 psi, 3 bpm=620 psi SPR taken at 19:00 hrs, MD 9204', TVD 5259' 19:00 00:00 5.00 9,204 9,490 PROD2 DRILL DDRL P Directional drill F/9204'to 9490', GPM 236, PSI ON 1950, PSI OFF 1850, RPM 120, TQ ON 10K, TQ OFF 9K, PUW 145K, SOW 90K, RWT 110K, ROP 92.7 ft/hr,WOB 5.8k, ECD 11.5, GAS 603 units, MAX GAS 1035 units. X8/04/2014 Directional drill F/9,490'T/10,537' 00:00 12:00 12.00 9,490 9,998 PROD2 DRILL DDRL P Directional drill F/9490'T/9998', GPM 240, PSI ON 2142, PSI OFF 2044, RPM 130, TQ ON 8K, TQ OFF 8K, PUW 145K, SOW 92K, RWT 105K, . ART 7.67 hrs,ADT 7.67 hrs, BIT 14.22 hrs, JARS 175 hrs, SPR#1 Pump at 2 bpm =480 psi, 3 bpm=740 psi. SPR#2 Pump at 2 bpm =470 psi, 3 bpm=730 psi. SPR's taken at 11:30 hrs, 9992'MD, 5337'TVD, MW 10.5 ppg. 12:00 18:00 6.00 9,998 10,251 PROD2 DRILL DDRL P Directional drill F/9998' T/10251',GPM 239, PSI ON 2160, PSI OFF 2050, RPM 130 TQ ON 7.5K,TQ OFF 7K, PUW 143K, SOW 91K, RWT 105K, MW 10.5 ppg, Crew painting, cleaning and general housekeeping. Page 19 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 110,251 10,537 PROD2 DRILL DDRL P I Directional drill F/10251'T/10537', GPM 236, PSI ON 2180, PSI OFF 2050, RPM 130, TQ ON 8K, TQ OFF 7K, PUW 143K, SOW 90K, RWT 105K, ART 9.16 hrs,ADT 9.16 hrs, BIT 23.38 hrs,JAR's 184 hrs, SPR#1 Pump at 2 bpm=510 psi, 3 bpm=790 psi. 1 SPR#2 Pump at 2 bpm=510 psi, 3 bpm=800 psi. SPR's taken at 23:30 hrs, 10442' MD, 5332'TVD, MW 10.5 ppg. 08/05/2014 Drilling f/10537'U 11588' 145K PUW 85K SOW 105K ROT 130 ROM 8K TQ FOOTAGE 1051' 00:00 12:00 12.00 10,537 11,015 PROD2 DRILL DDRL P Drill f/10537'U 11015'236 GPM 2150 PSI 130-RPM 8K-TQ ON 7K-OFF PUW- 149K SOW-92K ROT-108K ADT-7.51 FOOTAGE-478' 12:00 00:00 12.00 11,015 11,588 PROD2 DRILL DDRL P Drill f/11015'U 11588'238 GPM 2300 PSI 130-RPM 8.5K-TQ ON 6K-OFF PUW-145K SOW-85K ROT-105K ADT-7..79 FOOTAGE-573' 08/06/2014 Drill f/11588'U 11622'Circulate hole clean @ 130 rpm 239 gpm standing back stand every 30 min U 11090' BROOH f/11090'U 9014',drop 1.75"opening ball for well commander, CBU @ 522 gpm 2750 psi pump hi vis sweep around, drop 1.75"closing ball f/well commander, pump out of hole U 8633', POOH on elevators f/ 8633'U 545' L/D BHA, HWDP, Collars&Unload Sources. 00:00 01:00 1.00 11,588 11,622 PROD2 DRILL DDRL P Continue Drilling f/11588't/11622' TD 239 GPM 2290 PSI 130 RPM 8K TQ ON 7K OFF PUW-145K SOW-85K ROT- 105K ADT- 1 Total Bit Hrs 40.24 01:00 04:30 3.50 11,622 11,090 PROD2 CASING CIRC P Circulate&Condition hole 239 GPM 1990 PSI 130 RPM standing back _stand eveery 30 min.U 11090' 04:30 09:30 5.00 11,090 9,014 PROD2 CASING REAM P BROOH f/11090'U 9014'w/230 GPM 2040 psi 130 rpm, no hole _issues observed. 09:30 10:00 0.50 9,014 9,014 PROD2 CASING DHEA P Drop 1.75"opening ball f/well commander, stage pressure up U 1920 psi to open well commander. 10:00 12:00 2.00 9,014 9,014 PROD2 CASING CIRC P Circulate and condition hole 120 rpm 522 gpm 2777 psi, pump 35 bbls Hi Vis sweep,circulate until hole cleaned up 40%increase in cuttings on sweep return. 12:00 12:30 0.50 9,014 9,014 PROD2 CASING DHEQ P Drop 1.75"closing ball f/well commander, stage pressure up U 1480 psi U close well commander 12:30 14:00 1.50 9,014 8,633 PROD2 CASING TRIP P POOH w/pumps 238 gpm 2077 psi f/9014'U 8633' Page 20 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:30 0.50 8,633 8,633 PROD2 CASING OWFF P Observe well for flow well static 14:30 15:00 0.50 8,633 8,156 PROD2 CASING TRIP P POOH f/8633't/8156' 15:00 16:00 1.00 8,156 8,156 PROD2 CASING CIRC P Pump dry job, B/D top drive, remove blower hose. 16:00 21:00 5.00 8,156 545 PROD2 CASING TRIP P POOH f/8156't/545' 21:00 00:00 3.00 545 182 PROD2 CASING PULD P L/D BHA as per DD/MWD, HWDP, collars, Unload sources 38/07/2014 Continue L/D BHA, R/U t/run 4.5" Liner w/GBR, RIH w/4.5"Liner as per detail t/2720'M/U ZXP Liner Hanger and cross overs, RIH w/4.5"Liner on 4"DP t/7280' 00:00 03:00 3.00 182 0 PROD2 CASING PULD P Continue L/D BHA as per DD/MWD 03:00 05:00 2.00 0 0 COMPZ CASING RURD P P/U Liner Components and R/U V Run Liner, R/U GBR equipment. 05:00 14:30 9.50 0 2,720 COMPZ CASING RNCS P RIH w/4.5" Liner as per detail t/ 2720' 14:30 15:00 0.50 2,720 2,720 COMPZ CASING RNCS P Change elevators&M/U ZXP Liner Top Packer PUW-65k SOW-60k 15:00 15:30 0.50 2,720 2,720 COMPZ CASING RNCS P Mix and allow Pal mix t/set up. 15:30 16:00 0.50 2,720 2,720 COMPZ CASING CIRC P Circulate and establish parameters 217 gpm 275 psi 16:00 00:00 8.00 2,720 7,280 COMPZ CASING RUNL P RIH w/4.5" Liner on 4" DP f/2720't/ 7280' 08/08/2014 RIH w/4.5"Iiiner on 4" DP t/11613', CBU 3 bpm 735 psi, Set liner 2'off bottom, Set and release ZXP Liner hanger/Packer as per Baker, Displace well t/10.5 ppg brine, OWFF well static 30 min, pull seals above liner hanger CBU 420 gpm, Cut and Slip Drill line 00:00 04:00 4.00 7,280 9,077 COMPZ CASING RUNL P Continue RIH w/4.5"Liner on 4"DP f/7280't/9077' PUW-127k SOW-88k 04:00 06:00 2.00 9,077 9,077 COMPZ CASING CIRC P Circulate and condition hole 50 spm 128 gpm 525 psi 06:00 13:00 7.00 9,077 11,613 COMPZ CASING RUNL P RIH w/4.5" Liner on 4" DP f/9077't/ 11613'tag bottom 13:00 14:00 1.00 11,613 11,613 COMPZ CASING CIRC P Circulate drill string volume 3 bpm 735 psi. 14:00 16:30 2.50 11,613 8,850 COMPZ CASING PACK P Drop 1.5"baker ball,space out liner to set depth 2'off bottom, pressure up t/2200 psi set packer as per Baker, Pressure up t/2800 psi ball sheared out, drop 1.75"baker ball pressure up t/2200 psi slack off, pressure up t/3200 w/mud pumps, isolate pumps pressure up t/4300 psi w/test pump, release hanger, P/U release dog sub, Slack off put 50k on liner w/rotation 16:30 18:30 2.00 8,850 8,850 COMPZ CASING PRTS P R/U&test casing t/2000 psi f/30 min lost 60 psi in 30 min, hold an additional 30 min lost 20 psi. 18:30 21:00 2.50 8,850 8,850 COMPZ RPCOM DISP P Displace well t/10.5ppg brine 420 gpm 2040 psi 21:00 21:30 0.50 8,850 8,850 COMPZ RPCOM OWFF P Observe well for flow well static f/30 min. 21:30 23:30 2.00 8,850 8,768 COMPZ RPCOM CIRC P Stand one stand back, Circulate and condition hole 420 gpm 1740 psi Page 21 of 24 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 8,768 8,768 COMPZ RPCOM SFTY P PJSM f/slip and cut drill line, 08/09/2014 Continue to Slip and Cut Drilling line, servie top drive,adjust brakes on draworks, POOH w/4" DP t/2575' RIH w/remaining 4"DP in Derrick t/4937' POOH L/D all 4" DP L/D Running tool confirm dog sub sheared and Balls recovered. R/U and run 3.5" Upper Completion as per detail w/GBR Casing Services. 00:00 02:00 2.00 8,768 8,768 COMPZ RPCOM SLPC P Slip and cut drilling line adjust brakes on draworks and service top drive and crown sheave,check crown o matic 02:00 08:00 6.00 8,768 2,575 COMPZ RPCOM PULD P POOH L/D 4" DP f/8768't/2575' 08:00 09:30 1.50 2,575 4,937 COMPZ RPCOM TRIP P RIH with remaining DP in Derrick f/ 2575't/4937' 09:30 16:45 7.25 4,937 0 COMPZ RPCOM PULD P POOH L/D 4" DP f/4937't/running tool, L/D Baker running tool, dog sub sheared&balls recovered. 16:45 19:00 2.25 0 0 COMPZ RPCOM RURD P Pull Wear ring, rig up t/run upper completion as per detail, R/U GBR casing service, M/U crossovers f/ well control, load shed w/remaining jewelry bring pup joints t/rig floor. 19:00 00:00 5.00 0 2,585 COMPZ RPCOM PUTB P RIH w/3.5" L-80 9.3#EUE Upper completion t/2585' 08/10/2014 Run 3.5"tubing completion t/8921', locate and shear WLEG w/20k, R/U and circulate corrosion inhibited pill, L/D jts. M/U space out jts, cross over and hanger, R/U and test tubing t/3500 psi f/30 min good test, bleed tubing U 1700 psi, pressure test annulus t/3500 psi f/30 min good test, bleed tubing off and shear DCK,set BPV and test in direction of flow U 1500 psi, clean under rig floor, clean&clear rig floor. 00:00 09:00 9.00 2,585 8,895 COMPZ RPCOM PUTB P Continue RIH w/3.5"Upper completion f/2585'U 8895 09:00 09:30 0.50 8,895 8,921 COMPZ RPCOM HOSO P M/U jt#275 RIH 8921'locate Liner top shear Baker WLEG pins w/20k slack off weight,verify space out. 09:30 11:00 1.50 8,921 8,921 COMPZ RPCOM RURD P Change out bails on top drive install long bails, R/U U circulate,test ports on hanger U 5000 psi f/15 min 11:00 12:30 1.50 8,921 8,921 COMPZ RPCOM CIRC P Circulate and spot corrosion inhibted pill 25 bbls chase w/74 bbls of 10.5 ppg brine 3 bpm 300 psi. 12:30 16:00 3.50 8,921 8,921 COMPZ RPCOM HOSO P L/D 6 jts of tubing, RIH w/4 jts of tubing and cross over and jt of 4.5" IBTM pup and hanger. 16:00 19:30 3.50 8,921 0 COMPZ RPCOM PRTS P R/U and pressure test tubing U 3500 f/30 min good test, bleed tubing U 1700 psi, pressure up on the annulus U 3500 f/30 min good test,bleed tubing and shear DCK valve, 19:30 20:30 1.00 0 0 COMPZ RPCOM MPSP P Set BPV test U 1500 psi in direction offlow U15min 20:30 00:00 3.50 0 0 COMPZ RPCOM RURD P Clean mud system, B/D lines clean pits,clean under rotarty table,clean out mouse hole, clean and clear floor. 08/11/2014 Nipple down BOP stack prep U nipple up adaptor flange and tree,wrong size seals,wait on seals, M/U adaptor and tree, Test failed leaking inspect adaptor flange scared sealing face,Wait on new adaptor flange, N/U&retest same leaking trouble shoot wellhead,test 250/5000 psi f/10 min good test, R/U lubricator&pull BPV, R/U U freeze protect well. Page 22 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 0 0 COMPZ WHDBO NUND P Nipple down riser&BOP stack stand back on stand, change out kill line, C/O Bails, Prep adaptor flange and set TWC plug in BPV. 04:30 07:00 2.50 0 0 COMPZ WHDBO NUND T Wait on cameron to get correct SRL seals from deadhorse, Prep f/Rig move and freeze protecting. 07:00 09:00 2.00 0 0 COMPZ WHDBO NUND T Nipple up adaptor flange and tree, test void on adaptor flange test failed, Inspect adaptor flange scaring around sealing face. 09:00 10:30 1.50 0 0 COMPZ WHDBO NUND T Wait on new adaptor flange, continue V prep f/rig move. 10:30 14:30 4.00 0 0 COMPZ WHDBO NUND T Nipple up wellhead and tree,function all vavles fill tree w/diesel,test tree V 250/5000 psi test failed leaking through bleed port,tighten studs on flange evenly. 14:30 21:45 7.25 0 0 COMPZ WHDBO PRTS T Retest same leaking through observation port,trouble shoot leak retest bleeding off on high pressure test 250 psi test good, change out bleed off valve, retest still leaking out observation port, leak stopped and high test was performed V 5000 psi f/ 5 min,discuss w/town, decide to retest 250/5000 psi f/10 min, retest 250/low f/10 min good test,test 5000 high f/10 min observation port leaked out about 1/8 cup while pressuring up and stopped high test good. 21:45 23:15 1.50 0 0 COMPZ WHDBO MPSP P R/U lubricator test t/1500 psi f/5 min, pull BPV/TWC, RD 23:15 00:00 0.75 0 0 COMPZ WHDBO RURD P R/U t/Freeze protect well w/LRS X8/12/2014 R/U Lubicator,test same and set"H"BPV, R/D lubricator, Clean cellar and cuttings tank out, Finish taking off fluids from pits, continue taking down berming around rig,and contiue rigging down floor to lay derrick over. Rig released @ 12:00 hours, 8/12/2014. 00:00 06:00 6.00 0 0 COMPZ WHDBO FRZP P R/U Little Red lines and hold PJSM with all involveded, Pressure test lines to 2500 psi, Pumped 87 bbls of diesel @ 1.5 bpm with 700 psi, stage up to 2 bpm with 1300 psi max, Line up to U-tube, shut in and blow down lines, Final TBG pressure=400 psi, IA=290 psi. 06:00 08:00 2.00 0 0 COMPZ WHDBO OTHR P M/U lubricator test to 1500 psi for 5 min. Set Type"H" BPV as per Cameron hand, R/D lubricator, all valves shut in on tree. Page 23 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code ` Subcode T Comment 08:00 12:00 4.00 0 0 DEMOB MOVE RURD P Clean out cuttings box while cleasning and clearing cellar of all equipment, Off load remaining fluids in pits, Continue taking down berming around rig,disconnect mud lines and riggiong down rig floor. Release Rig at 12:00 hours, 8/12/2014. Page 24 of 24 M d E 0 0 0 M N N M oM r WN m Oi M ONON WN m 2 WM NM N MM.M O N O 0 0 C n N ON Np ,- O0 oO . 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CO d - (0 co N O }(OI '' a Q W�(.i M M M,-W Oi d` r rr co co nN A m m CO I,-(0 O N.06,-0 0 N E O O O r V C V 0 m Q. M0i000n W coOb O) d m0, (000(O OD OO OO N 0 Q C(no NO Z $ C J O 0N0 o me N C Z 0(n fn 0) V nj O tpa� W ' 3Oav > mc " ms 0 nU mo>r w n-o co(n v d Co 0o N o •..E. CG U YWr W n-r v n,- N Caua U N Nr-:0 V D 000 0 U)` co co co co o Wa MO(0On0)O� � ,-� Oi b •+ T Oo0ry 00 L)0(D D000 (D Q 0 m V o Z Fo D _ ...1.- O. _ R d " C N m j C m 3 m OC fi- O > a 27) 0001) aOE.Nbc° oa> y C c c c c c ynrCDro U O.> N0N.00WNV LL % ' '` Cement Detail Report 0,!'"i ',, 2L-314 ConcoP ohiltips String: Surface Casing Cement Job: DRILLING ORIGINAL, 7/9/2014 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 7/15/2014 05:15 7/15/2014 08:37 2L-314 Comment Shut down pumps, Line up t/cementers, break circ.w/5 bbls mudpush,shut in perform PT t/3000 psi,good test,open up valves come on line w/95 bbls 10.5 ppg mudpush,drop bottom plug, pump 389.6 bbls 11.02 ppg lead cmt 7 bpm 200 psi,pump 58.1 bbls 12.Oppg tail cement 3 bpm 300 psi,drop top plug, kick plug out w/10 bbls water,displace w/225 bbls 9.8 ppg Drillplex mud,bump plug 2635 stks FCP 285 pressure up U 855 psi hold f/5 min, bleed off and check floats floats held. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement Surface Casing 28.0 2,534.0 Yes 230.0 Yes Yes Q Pump Mit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 1 5 285.0 855.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,433.0 Drill Bit 2,534.0 9 7/8 Comment Shut down pumps, Line up U cementers, break circ.w/5 bbls mudpush,shut in perform PT U 3000 psi,good test,open up valves come on line w/95 bbls 10.5 ppg mudpush,drop bottom plug,pump 389.6 bbls 11.02 ppg lead cmt 7 bpm 200 psi,pump 58.1 bbls 12.0ppg tail cement 3 bpm 300 psi,drop top plug,kick plug out w/10 bbls water,displace w/225 bbls 9.8 ppg Drillplex mud,bump plug 2635 stks FCP 285 pressure up U 855 psi hold f/5 min, bleed off and check floats floats held. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush 0.0 0.0 87.6 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead 0.0 2,056.0 1,133 G 389.6 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.93 6.49 11.02 0.00 Additives Additive Type Concentration Conc Unit label Salt D044 10.0 %BWOB Additive Type Concentration Conc Unit label Antifoam D046 0.3 %BWOB Additive Type Concentration Conc Unit label Dispersant D065 0.9 %BWOB Additive Type Concentration Conc Unit label Dispersant D145A 0.05 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail 2,056.0 2,534.0 200 G 58.1 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.63 5.46 12.00 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Page 1/1 Report Printed: 9/10/2014 Cement Detail Report 2L-314 o Conco P01hiHips Lnka String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 7/9/2014 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 7/26/2014 18:09 7/26/2014 20:59 2L-314 Comment Line up hoses to cement trucks.Pump with SLB cementers,5 bbls chemical wash to press test lines to 1700 psi low to 3500 psi high,good test.Pump 35 bbls of CW at 5 bpm,885 psi. Pump 40 bbls, 12.5#, Mudpush,4.5 bpm,764 psi. Drop bottomplug. Pump 159 bbls, 15.8#gas block cement, 5 bpm, 1135 psi. Drop top plug. Displace with rig pumps at 6 bpm while reciprocating,1085 ICP,to 5300 strokes.Slow to 3 bpm,745 FCP.Land casing on hanger, set depth of 9110', continue pumping to bump plug at 5729 strokes. Increase to 1400 psi and hold 5 minutes.Cement in place at 20:54 hrs. Bleed off pressure and check floats. Recieved back 5.6 bbls. Floats failed"Obtained good returns through out entire circulating/cement job. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 4,919.0 9,110.0 No Yes Yes Cement Q Pump Init(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1,085 1 4 745.0 745.0 Yes No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up hoses to cement trucks. Pump with SLB cementers,5 bbls chemical wash to press test lines to 1700 psi low to 3500 psi high,good test. Pump 35 bbls of CW at 5 bpm, 885 psi. Pump 40 bbls, 12.5#, Mudpush,4.5 bpm, 764 psi. Drop bottomplug. Pump 159 bbls, 15.8#gas block cement, 5 bpm, 1135 psi. Drop top plug. Displace with rig pumps at 6 bpm while reciprocating,1085 ICP,to 5300 strokes.Slow to 3 bpm,745 FCP. Land casing on hanger,set depth of 9110', continue pumping to bump plug at 5729 strokes. Increase to 1400 psi and hold 5 minutes. Cement in place at 20:54 hrs. Bleed off pressure and check floats. Receieved back 5.6 bbls. Floats failed*Obtained good returns through out entire circulating/cement job. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 6,322.0 9,110.0 G 159.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 2.91 15.80 6.00 Additives Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) gal/sx Additive Type Concentration Conc Unit label Antifoam gal/sx Additive Type Concentration Conc Unit label Dispersant %BWOC Additive Type Concentration Conc Unit label Gas Block gal/sx Page 1/1 Report Printed: 9/10/2014 • Orzl ti Cement Detail Report 2L-314 Conoa>Phillips String: KOP for lateral Job: DRILLING ORIGINAL, 7/9/2014 06:00 Cement Details Description Cementing Start Date 'Cementing End Date Wellbore Name KOP for lateral 8/1/2014 17:00 8/1/2014 18:06 2L-314PB Comment Circulate 588 bbls 10.5 ppg mud prior to start of cement job while having PJSM and batching MP and cement(Max gas 94 units). Dowell pump 13.5 ppg MP to floor with centrifugal pump(Vol f/unit to the floor=1.2 bbls).Test cmt equipment and lines to 500/3500 psi-good. Dowell pumped 15 bbls of 13.5 ppg MP II, then 1 bbl of H2O to get MP to the floor.Close bag and choke to load foam ball. Open choke and bag after loading the foam ball. Dowell pumped 37 bbls of 17#cmt(208 sx,yield 1 cuft/sx)@ 5 bpm, Dowell followed with 3.5 bbls of 13.5 ppg MudPush II and chased w/1 bbl water to get to the floor. Switch to rig pumps. Rig displaced w/81 bbls of 10.5 ppg mud,pumping 5 bpm until last 6 bbls,slowed to 2 bpm. Shut down,checked to see if balanced,-good. Break off circulating head,P/U single and POOH 7 stands of DP slowly(20'/min)to 8960', (150'above Shoe @ 9110'). Load foam ball and circulate out MP and excess cmt.MP returned to pits at 3,338 STKS,B/U 3 bbls of cmt returned. Full returns while pumping. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) 'Full Return? Vol Cement... Top Plug? Btm Plug? KOP for lateral Set kickoff plug 8,960.0 9,572.0 No No No Q Pump Mit(bbllm...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 3 4 50.0 Yes No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 8,964.0 Drill Bit 9,125.0 6 1/2 Comment Circulate 588 bbls 10.5 ppg mud prior to start of cement job while having PJSM and batching MP and cement(Max gas 94 units). Dowell pump 13.5 ppg MP to floor with centrifugal pump(Vol f/unit to the floor=1.2 bbls).Test cmt equipment and lines to 500/3500 psi-good. Dowell pumped 15 bbls of 13.5 ppg MP II, then 1 bbl of H2O to get MP to the floor.Close bag and choke to load foam ball. Open choke and bag after loading the foam ball. Dowell pumped 37 bbls of 17#cmt(208 sx,yield 1 cufUsx)@ 5 bpm, Dowell followed with 3.5 bbls of 13.5 ppg MudPush II and chased w/1 bbl water to get to the floor. Switch to rig pumps. Rig displaced w/81 bbls of 10.5 ppg mud,pumping 5 bpm until last 6 bbls,slowed to 2 bpm.Shut down,checked to see if balanced,-good. Break off circulating head, P/U single and POOH 7 stands of DP slowly(20'/min)to 8960', (150'above Shoe @ 9110'). Load foam ball and circulate out MP and excess cmt.MP returned to pits at 3,338 STKS, B/U 3 bbls of cmt returned. Full returns while pumping. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 8,490.0 8,857.0 15.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 13.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) 17 ppf KOP cement 8,857.0 9,573.0 208 37.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.00 3.97 17.00 5.75 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 8,490.0 8,857.0 3.5 Yield(ft'/sack) Mix 1-120 Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 13.50 Additives Additive Type Concentration Conc Unit label D047 Antifoam 0.2 gal/sx Additive Type Concentration Conc Unit label D065 Dispersant 1.0 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.2 %BWOC Additive Type Concentration Conc Unit label D177 Retarder 0.005 gal/sx Page 1/1 Report Printed: 9/10/2014 �w �\\I%%%sem THE STATE h^ (� l ��aG s a 01 a E f � ter ,� � o A 1 \ f �� //�, l� i� C .4 ,/; 1 r �l,i' 1'r ��C Cr'1 333 West Seventh Avenue ',` GOVERNOR SEAN PARNEI.1, Anchorage, Alaska 99501-3572 Main 907 279 1 433 4LAS5- E,_-> 90/ 27/ 1542 Adam Klem Sr. Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2L-314 Sundry Number: 314-499 Dear Mr. Klem: 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, Cathy P Foerster Chair DATED this day of September, 2014. Encl. R EC El V t1) STATE OF ALASKA ! ' AL,_AA OIL AND GAS CONSERVATION COMM-—ON SEP 0 3 2014 ION APPLICATION FOR SUNDRY APPROVALS OG�� 20 AAC 25.280 1.Type of Request: Abandon E Aug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r" Re-enter Susp.Well r StimulateAlter casing• r Other: I- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc • Exploratory r Development r. 214-023-0 • 3.AddressStratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20686-00 r 7.If perforating, 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r NoI� k ._2L-314 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380051,380052 - Kuparuk River Field/Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft). Plugs(measured): Junk(measured): 11622 • 5369 ' 11610' • 5368'- 8960' none Casing Length Size MD ND Burst Collapse Conductor 80' 16" 134' 134' Surface 2499' 10.75" 2527' 2397' Intermediate 9082' 7.626" 9110' 5265' Production 2706' 4.5" 11610' 5368' Perforation Depth MD(ft). Perforation Depth TVD(ft). Tubing Size. Tubing Grade: Tubing MD(ft): none none 3.5 L-80 8918 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer NIPPLE-CAMCO DS NIPPLE MD=504' TVD=504' 12 Attachments: Description Summary of Proposal r , 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch I- 14 Exploratory r- Stratigraphic rDevelopment r Service r 14 Estimated Date for Commencing Operations: — 15. Well Status after proposed work: 9/2'//'/ Oil r� - Gas r WDSPL r Suspended r- 16. 16.Verbal Approval: Date. WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Adam Klem @ 263-4529 Email: Adam Klem@conocophillips.com Printed NameKlem Title: Sr. Completions Engineer Signature --- Phone:263-4529 Date �ja//y Commission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness `i.4__ L 'S Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. Spacing Exception Required? Yes ❑ No [f Subsequent Form Required: /0 — `f 0 4 APPROVED BY Approved by:ate)‘' P /COMMISSIONER THE COMMISSION Date: 9- y ' Rpproved application is valid tor 12 months r m the date of approval. I Form 10-403(Revise 10/2012) f' i13/ y Submit Form and Attachments in Duplicate //7"-F 'tia ii IGINAL r/iki RBCMS SEP - 5 20.14. 2L-314 Sundry Application 2L-314 was drilled and the production liner casing was landed on 8/9/14. (A schematic of the completion is attached). The well will has an approximately 2,400' horizontal placed in the Bermuda sand completed with a 4.5" liner with a perforated pup at the toe and 5 ball actuated sliding sleeves and swellable packers between each sleeve. We will drop a ball (progressively getting larger) after each stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. We expect the production to be 1000 bpd in 2014 if a successful stimulation is achieved. Radioactive tracers will be pumped during each stage. We will come back and log the well to confirm we have good isolation between the stages and that the entire interval was effectively stimulated. Additional documentation discussing the radioactive tracers is attached. Proposed Procedure: Schlumberger Pumping Services: (Bermuda sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 18 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 8400 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 119bbl DataFrac stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7000 psi. Stage 1 • 400 bbls YF125ST Pad • 140 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 150 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 180 bbls YF125ST w/4 ppa 16/20 Carbolite AK • 180 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 260 bbls YF125ST w/6 ppa 16/20 Carbolite • Ir-192 ZW (RA tracer) • Drop ball 1 Stage 2 • 400 bbls YF125ST Pad • 140 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 150 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 180 bbls YF125ST w/4 ppa 16/20 Carbolite • 180 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 260 bbls YF125ST w/6 ppa 16/20 Carbolite • Sc-46 ZW (RA tracer) • Drop ball 2 Stage 3 • 400 bbls YF125ST Pad • 140 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 150 bbls YF125ST w/2 ppa 16/20 Carbolite • 180 bbls YF125ST w/4 ppa 16/20 Carbolite • 180 bbls YF125ST w/5 ppa 16/20 Carbolite • 260 bbls YF125ST w/ 6 ppa 16/20 Carbolite • Sb-124 ZW (RA tracer) • Drop ball 3 Stage 4 • 410 bbls YF125ST Pad • 90 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 90 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 100 bbls YF125ST w/4 ppa 16/20 Carbolite • 110 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF125ST w/ 6 ppa 16/20 Carbolite • 140 bbls YF125ST w/ 7 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 8 ppa 16/20 Carbolite • Ir-192 ZW (RA tracer) • Drop ball 4 Stage 5 • 410 bbls YF125ST Pad • 90 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 90 bbls YF125ST w/2 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 100 bbls YF125ST w/4 ppa 16/20 Carbolite • 110 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF125ST w/ 6 ppa 16/20 Carbolite • 140 bbls YF125ST w/ 7 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 8 ppa 16/20 Carbolite AK • Sc-46 ZW (RA tracer) • Drop ball 5 Stage 6 • 410 bbls YF125ST Pad • 90 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 90 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 100 bbls YF125ST w/4 ppa 16/20 Carbolite • 110 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF125ST w/6 ppa 16/20 Carbolite • 140 bbls YF125ST w/ 7 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 8 ppa 16/20 Carbolite • Sb-124 ZW (RA tracer) • Flush with 89 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 830,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) 16. All radioactive material will be disposed of according to ConocoPhillips and regulatory standards. (see attachment for handling guidelines). Cement Evaluation of 2L-314 and wells within 1/4 mile of 2L-314 2L-314: 7 5/8" Casing cement job was pumped on 7/26/2014 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg mud. The plug was bumped @ 1400 psi; the floats did not hold, and it flowed back 5.9bbls. Good returns were observed during the job. Logs show good cement 17 bond to 6060' MD. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect any nearby wells. AK Stimulation Surface Rig-Up \ - Bleed/Tattle Tale Tankk + 0 Tal a >/ wL— mb° 11 - • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95%of max 11101 OC: 1 treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and To ; 000041 set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. ` ••� 'xe F� N N C ~ Y > /T.1►• �a. Hcrul dwnd U Pop-Off Tark N J O LTJ Pump Truck Pop-Off Tank rnry Z> dcd [\' F J ff v J K 5,iD Frac Pump C i PP.] Fra'.Pump Frac Pump Nal i/ N 1101.1 Frac Pump Frac Pump NAI ii 14111 ` -, Fra-Pump AK Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) fl FRAC IRON CONNECTION ,.... • . r • : ,:, / • • H ..,...,.,.. /REMOTE OPERATED „� . o MASTER VALVE •1$ MANUAL OPERATED MEM Stinger I I TAMS III , ; 2 VENT „!®I.111--VALVE II —I I— •`� OPEN r ....,) • !ØI \ FLOW TEE AND �I , ' ■�•• VENT VALVE WELLHEAD .. I i�lll VALVES ..... %'i%r.,. // OPEN EMUy N4k W • Il m -b WELLHEAD C; '\ ; VALVES .J ' '% WT LL CLOSED .....:.-. %\, *' /.t, • ti S ' QUAD PACKOFF e.... ice C. ASSEMBLY IN PLACE IN TUBING I•, I, .I�•", _ •• TUBING , i t • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75"down 3 '/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm AK GUIDELINES FOR USE OF RADIOACTIVE TRACERS DURING WELL STIMULATIONS ALASKA OPERATIONS 1. Only licensed personnel providing radioactive (R/A) tracing services are allowed to handle R/A material to, from, or at any location or facility. 2. The licensed R/A service company representative must maintain their company's license and carry MSDS sheets on location for all R/A isotopes present or in use. 3. The following equipment and paperwork shall be present prior to beginning any tracer operation: TLD Badge - for monitoring exposure Survey Meter - currently calibrated-capable of detecting beta and gamma radiation Warning Signs - Posted at the proper restricted area ( 2mr/hr) Rubber Gloves - For protecting hands while handling radiation Trash Bags - For collecting R/A waste Sponges - For cleaning in case of spill Rad Wash (or similar surfactant) - For decontamination Current License - Contains important information and documents MSDS Sheets - Identifies safety and health concerns Operating/Emergency Manual - Contains important procedures 4. The following procedures should be followed on each job involving R/A tracers: a. Radio contact between the R/A service personnel and frac personnel must be maintained. b. Restricted area must be identified and marked with signs. Access to this area must be restricted to authorized personnel. c. Any leaks in the frac line need to be checked for radiation before being repaired. d. Bleed off lines or lines used for treesaver safety should be laid to the flow-back tank. e. Surveys to check radiation levels should be made on the following areas before the job and documented: pumps, frac line, restricted area, wellhead, flowback tank. 5 After the job, the same areas should be checked again for radiation levels to insure that no significant amounts of radiation remain in the equipment or on the location. 6. The following injection procedures should be observed: a. Multiple injection points for back-up contingency. b. Ability to isolate with a valve the radioactive injection pump if malfunction develops. c. Loading in injector not more than 30 mCi at any one time, to reduce restricted area exposure and reduce spill potential. d. Do not inject directly into blender and/or manifold. Rather, isolate pump entry points. 7. The following procedures should be utilized during flowback of a well when R/A material has been used: a. People in charge of the flowback should be made aware that the R/A material has been used. b. All people contacting flowback fluids or proppants should wash the contacted areas with soap and water. c. Hands should be cleansed thoroughly before eating, drinking or smoking. d. Fluids and proppants should not be handled unnecessarily. e. Flow any returns to holding tank. EMERGENCY PROCEDURES 1. Uncontrolled Sandout or Fluid Reversal - In the event of an uncontrolled sandout or fluid reversal, the following steps shall be taken to prevent personnel and environmental contamination. a. Remove all unnecessary personnel from the area and perform a survey prior to each exit unless other hazards require immediate personnel removal. b. Establish and secure a restricted area with ropes and the proper warning signs to indicate the nature of the hazard. c. Divert all flowback to the holding tank. d. After the flowback has ceased, initiate a complete survey of the area, equipment, vehicles and personnel. Indicate, on a sketch of the area, the magnitude of the contamination and inform all personnel of the nature and extent of the contamination. All items free of contamination shall be removed from the area in a manner to prevent the spread of contamination. e. Proceed to clean contaminated items until survey results are at ambient levels. Retain all decontamination fluid, towels, etc. for later disposal. f. Obtain samples of fluids, soil, and any other media. Assay samples on a portable survey instrument (using both the end window and gamma scintillation probes). Note on the sketch of the area the degree of contamination. Remove the top six inches of soil and contain in the tank. Also divert any standing fluid to the tank. Resurvey the locations where the contamination was removed. If the survey instrument does not record any reading over ambient levels, collect samples and submit to the Houston facility for analysis. g. If the sample results indicate the release was below the prescribed limits, then no subsequent action is necessary. h. If the sample results are above the prescribed limits, the area in question will be decontaminated until the limits are met. i. The material in the tank shall be disposed class II disposal well or held for decay. 2. Routine Sandout or Fluid Reversal - Routine sandout or fluid reversal shall be handled in accordance with the following procedures. a. If the fluid is diverted to a holding tank, sample the well fluid contained in the holding tank. If the instrument readings are above unrestricted area levels, post the tank with caution signs and erect a temporary personnel barrier. Notify the Radiation Safety Officer of the situation. ProTechnics must maintain control of the tank until release can be accomplished. Submit the samples for analysis. The sample analysis will indicate which of the following is the preferred disposal method for the contents of the tank: b. Dispose into a class II disposal well 11. Sandout/Fluid Reversal Limit - Every effort shall be made to keep releases of tracer material As Low As Reasonably Achievable (ALARA). The following limits apply only to our Zero Wash® products. The activity limit for disposal in a class II disposal well will be 1,000 pCi/gm (0.001 uCi/gm) of each Zero Wash® isotope. (Sc-46, Ir-192, & Sb-124). cu 0) co 1-1." -.. , —5 2 -TS co o -o 2U L 5 LLca d" N- CO M J C\1 a V 0 ,- hi v Ln co 0 0 0 0 0 0 N N N N N _C CD (9 CO CO N ,-- .-- .- .- r N a) a) a) a) a) C 3Ti :_71 Ti 'D IC 0 0 0 0 O omit% as as cts ai as (1) o m U U U 0 U a) 0) o a CL H CM CZ (1) o) } �� (^/) '�/� 0 o o CV O N CV CV O O N O O Cl)vS.L LC) a.) 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Intermediate Hole 9.6 PPG 3 i"x 1"KBMG o u J �" Tubing: Keep up with 'CV 1 3-1/2"9.3#L-80 EUE8RD Dilution D(#0 4-1/2" 12.6#L-80 IBTM top joint to surface Estimated top of cement @+/-6,322'MD (500'above C37) u J Iceberg Top 7,017'MD(4.433'rvD) Baker CMU Sliding Sleeve CLOSED w/2.812"Camco'DS'Profile ll 10'above Packer 5 I III3.5"x 7-5/8",Baker Premier Packer+/- 'MD 3'/:"Camco D Nipple 2.75"nogo E•. T 7-5/8"x 4-W Baker Flex Lock Liner hanger ZXP liner top packer /� w/RS Nipple,© Rect, Intermediate Casing ToDset with Bonzai: 7-5/8"29.7#L-80&bottom 300'TN1l0SS 39#-all Hydril 563 connections 6-1/2" Production Hole Top of Bermuda 9,149'MD 5,277'TVD 9,110' MD/5,265'TVD @ 74° t alrte�: $*o..Ackers 0.a.,kecs...u ..roc pqu pTReo} ...:.......... Base Bermuda 9,365'MD 5,349'TVD Production Liner @ 90°: 4-1/2" 12.6#IBTM 11,610' MD/5,368'TVD P7-0 2/ ¢ -623 Ferguson, Victoria L (DOA) From: Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Monday,August 04, 2014 1:56 PM To: Ferguson,Victoria L(DOA) Cc: Shultz, Steve (Orbis Engineering,Inc.); Brunswick, Scott A;Jolley, Liz C Subject: 2L-314 (PTD 214-023) (Sundry: 314-381) Attachments: AOGCC 2L-314 TOC 7.625.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Per the requirements on Tarn well 2L-314 (approved PTD 214-023 and approved Sundry 314-381 to eliminate the Bonzai cement job), please find attached the top of cement log. The C37 (top of Tarn Oil Pool)top came in at 6,818' MD (4,360'TVD). The Sonic log showed TOC from the 7-5/8" intermediate casing at 6,060' MD (4,044'ND)for a total of 758' MD (316'ND)above the top of the Pool. The Bermuda reservoir in the production lateral came in at 9,149' MD (5,277'ND). Therefore,there exists a total of 3,089' MD (1,233'ND)of cement above the Bermuda producing reservoir. Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formatii Top/Marker MD-prognosis TVD-prog TJDSS-prog Comment MD actual TVD actual TvDS 13-112" 2L-314 Surface Section (prognosed depths per wp10) 10 34" Casing Shoe 2 556' 2 423 -2 280 2 526 2.399' -2 25 9-718" 2L-314 Intermediate Section (prognosed depths per wp09) C-80 2 618 2 460 -2 318 2 643 2 480' -2.62 Campanian Sand 2.702 2 516 -2 374 2.715 2 531 -2 67 C-50 5.271' 3 711 -3 568' 5.378' 3 744 -3.88 C-40 6.263' 4 158' -4 015' 6 325' 4 158' 3.01 C-37 6.821' 4 391' 4 248' 6 818 4 360' -4.21 Iceberg 6 956' 4 438' 4 295 7 017 4433 -4 29 T-7 8 073' 4 890' -3 747 7 899 4 790 -4 64 T-4 1 8 557 5.088 4 945 8.466' 5 020' 4 88 7-5:88" Casing Shoe 9 148' 5 286' -5 143 9 110 5 266' -5 12 6-1/2" 2L-314 Pilot Hole Section (prognosed depths ?er wp10) Pilot Hole Top Berm 9.280 5.326 -6 183 9 149 5 277 -5.13 Pilot Top Seis Berm 9 363 5 357 -5 214 9 232 5 302' -5 15 Pilot Hole Base Berm 9 453' 5.395 -5 252 9.365' 5 349 -5.20 Pilot Hole C-35 9 572' 5 453 -5 310 9 403' 5 363 -5.22 Pilot Hole TD 9 785 5 582 -5 439' 9 673' 5 442 -5 22 6-1/2" 2L-314 Production Lateral Section (prognosed depths per wp10) Top Berm Target 9.303 5 326' -5 183 9 149 5 277 -5 13 Top Seis Berm 9.538 5.359 -5 217 9 250 6 301 -5 15 TDToe Target 11 605 5 413' -5 270' Thanks, Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 1 Ferguson, Victoria L (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Thursday,July 10, 2014 10:38 AM To: Schwartz, Guy L(DOA); Ferguson,Victoria L(DOA) Subject: RE:75' Diverter distance calculation question Follow Up Flag: Follow up Flag Status: Flagged Thank you for the confirmation Guy, We just wanted to check. But just to be safe, we have asked Granville to just add another 5'to his diverter line. Thank you, Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, July 10, 2014 10:02 AM To: Bearden, J Daniel Cc: Shultz, Steve (Orbis Engineering, Inc.); Jolley, Liz C; Nabors 9ES Co man; Herbert, Frederick 0; Brunswick, Scott A; Ferguson, Victoria L(DOA) Subject: [EXTERNAL]RE: 75' Diverter distance calculation question Daniel, This is splitting hairs ... never had this come up before. A literal interpretation of the regulation would seem to indicate that the actual distance (using hypontenuse) can be used. So yes this is acceptable as long as the vent line meets the other requirements of 20 AAC 25.035 ( ie such as 50ft from the substructure). 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(Guy schwartz@alaska.gov). From: Bearden, J Daniel [mailto:J.Daniel.Bearden©conocophillips.com] Sent: Thursday,July 10, 2014 9:05 AM To: Schwartz, Guy L(DOA) 1 Cc: Shultz, Steve (Orbis Engineering, 1I.,,.); Jolley, Liz C; Nabors 9ES Co man; Herb. Frederick 0; Brunswick, Scott A Subject: 75' Diverter distance calculation question Hi Guy, Nabors 9ES has rigged up on our next Tarn well,2L-314. We had a question on the calculation of the minimum 75' diverter distance from nearest ignition source: Can the Hypotenuse distance be utilized to calculate the distance,or does it have to be a ground level distance? Thanks, B o,'.er Motc r potential ign on source .1,'_ . ellil w .._.. -0 .�. HYPOtenu %lipse MI I ' Ill r Duna *a I! n 0 -- itill it 4'1'.i184-\\4:. ilitie illig"111 k J d'\\ trnt-_ , _ 11i. a 11'1111 a :r I .YV .s. . . Min 70' from sou ,.,NAllili I NABORS ALASKA RIG 9ES CONOCO PHILLIPS WELL HOUSE LAYOUT AOGCC REGS: 20 AAC 25.035.Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements (a)This section applies to drilling and completion operations other than those covered by 20 AAC 25.036 or 20 AAC 25.037.These operations are also subject to the requirements of 20 AAC 25.527. (b)The operator shall submit the following information with the application for a Permit to Drill(Form 10-401)or refer in the application to that information if that information is already on file with the commission: (1)a diagram of the blowout preventer(BOP)stack or diverter and related equipment for each proposed casing installation; 2 (2')a list of the blowout prevention equipn..,.it(BOPE)and if applicable,diverter equipmeri. ..Ith specifications. (c)Except as provided in(d)and(h)of this section,a high capacity flow diverter system must be installed to provide safety for personnel and equipment before rotary rig drilling is performed below a well's structural or conductor casing,unless the casing is equipped with BOPE conforming with(e)of this section.The following provisions apply to a diverter system: (1)the diverter system must consist of a remotelyoperated annularpack-off device,a full-opening vent line valve,and a diverter vent Y P P g line with a diameter (A)of at least 16 inches,unless a smaller diameter is approved by the commission to account for smaller hole size,geological conditions,rig layout,or surface facility constraints;and (B)at least as large as the diameter of the hole to be drilled,unless a pilot hole with a diameter no larger than that of the vent line is drilled first;the commission will waive the requirement of this paragraph if the operator demonstrates,based on drilling experience in the near vicinity,that drilling a pilot hole would not be necessary for safety; (2)the diverter system must be assembled as follows: (A)the diverter vent line outlet must be located below the annular pack-off,either as an integral part of the annular pack-off device or as a vent-line outlet spool immediately below it; (B)the actuating mechanism for the vent line valve must be integrated with the actuating mechanism for the annular pack-off device in a fail-safe manner so that the vent line valve automatically opens before full closure of the annular pack-off; (C)the vent line must extend to a point at least 75 feet (i)away from a potential source of ignition;and (ii)beyond the drill rig substructure,or to a point within the reserve pit and at least 50 feet beyond the drill rig substructure; (D)the vent line must be as straight as possible,secured to prevent movement,and designed to avoid freeze-up; (E)the vent line may be secured to the rig and with portable cradle supports,but may not be attached to flowlines,cable trays,or other processing equipment; (F)all turns with a bend radius less than 20 times the inside diameter of the vent line must be targeted; (G)all valves must be full-opening; (3)a clearly marked"warning zone"must be established on each side and ahead of the vent line tip,and the following restrictions must be in effect within the warning zone,beginning with the function test of the diverter system immediately before drilling operations begin and ending with diverter system rig-down: (A)a prohibition on vehicle parking; (B)a prohibition on ignition sources or running equipment; (C)a prohibition on staged equipment or materials; (D)the restriction of traffic to essential foot or vehicle traffic only; (4)the commission will,in its discretion,inspect the diverter system for compliance with the requirements of this subsection and require the operator to test the system to ensure proper operation. 3 Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell 4 ,,i,�\\I%% TI STATE -_i e-� �' -: =e_;� s 4=--------,k 333 Vve i Scvenih ,Avenue Ji= _ 1 �°op wilts 110', (JOVI;I:tiOR SEAN PARN�Li.I• Anchorage, Alaska 99501-3572 '� an 907 279 1433 Daniel Bearden Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2L-314 Sundry Number: 314-381 Dear Mr. Bearden: 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, ,% V-r --- Cathy P. Foerster Chair DATED this Z� day of June, 2014. Encl. • RE STATE OF ALASKA JUN 1 8 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION C/2?// 4- 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 0 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 5 Permit to Drill Number ConocoPhillips Alaska,Inc Exploratory ❑ Development Q • 214-023 • 3 Address Stratigraphic ❑ Service El6 API Number P O Box 100360 Anchorage,AK 995510-0360 50-103-20686-00-00 • 7 If perforating 8 Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? KRU 2L-314 ' Will planned perforations require a spacing exception? Yes ❑ No ❑ 9 Property Designation(Lease Number) 10 Field/Pool(s) ADL 380051, 380052 , Kuparuk River Field Tarn Oil Pool • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft) Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth ND(ft) Plugs(measured) Junk(measured) 11500' 5413' 11500' 5413' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 92' 16" 120' 120' Surface 2788' 10-3/4" 2816' 2418' 5210 2480 Intermediate 9016' 7-5/8" 9044' 5286' 9180 8810 Production Liner 2606' 4-1/2" 11500' 5413' 11590 9200 Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) N/A N/A 3-1/2" L-80 8894' Packers and SSSV Type Packers and SSSV MD(ft)and ND(ft) Baker Premier Packer 8844'/5220' • 12 Attachments Description Summary of Proposal Q 13 Well Class after proposed work Detailed Operations Program E BOP Sketch ❑ Exploratory E Stratigraphic E Development 7 • Service ❑ 14 Estimated Date for 7/1/2014 15 Well Status after proposed work: Commencing Operations Oil Q- Gas ❑ WDSPL ❑ Suspended ❑ 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 Daniel Bearden Email j.daniel.bearden a(�.conocophillips.com Printed Name niel Bearden 263-4864 Title Drilling Engineer Signature Phone Date ___.; COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number 3V-{-33 \ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other , J 1 I C C 1.2/1t 12 f 2°(7.G / 1 D r—e- L 1 r-t"GI f0 r- 5/G _ p.U V r 'Ci 71-C' /' ?C(-- !/ D Spacing Exception Required? Yes ❑ No ii Subsequent Form Required `v — 4 G 7 APPROVED BY Approved by ? -a COMMISSIONER THE COMMISSION Date G -22 _/51 AS `'l!GI t y Submit Form and Form 10-403(Revised 10/2012) Approv"p a eI Aoths from the f proval. Attachments in Duplicate d1460//ft YRBGMSJU N 27 20 4G zG /9_ Post Office Box 100360 ConocoPhillips Anchorage,Alaska 99510-0360 Chip Alvord Phone(907)265-6120 Email: Chip.Alvord(a conocophillips.com RECEIVED V D June 17,2014 JUN 1 8 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 AOGCC Anchorage,Alaska 99501 Re: Application for Sundry Approval to Change Approved Program for 2L-314(PTD 214-023) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for Sundry Approval to Change the Approved drilling program for 2L-314 (PTD 214-023). As outlined in our meeting dated April 8th,2014, ConocoPhillips believes we will meet the intent of the AOGCC regulations 20 ACC 25.030(d)(5)by placing cement up to a height of at least 500'above the upper-most hydrocarbon bearing zone in the Tarn Pool(the C-37/Iceberg formation). / We have updated the topset casing depth to be closer to the Bermuda reservoir to within 50'TVD(seismic resolution is+/-30'TVD and we want to refrain from accidently penetrating the Bermuda with the weaker upper zones un- cased). Upon top-setting the Bermuda within 50'TVD with our 7-5/8"casing string,we will pump 133 bbls(639 sx)of Class G cement to achieve a cement height of 2,418' MD(-1140'TVD)above the shoe which will cover at least 500' above the C-37/Iceberg. ConocoPhillips believes this cement coverage satisfies the AOGCC's intent of zonal isolation, and therefore,the Bonzai cement procedure is not needed. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1 Form 10-403 APPLICATION FOR Sundry Approval to Change Approved Program 2. A Un-cemented horizontal liner proposal 3 Proposed Completion Diagram&Cement program Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and (b). 2. A description of the drilling fluids handling system 3. Diagram of riser set up. If you have any questions or require further information, please contact Dan Bearden at 263-4864. Sincerely, • Chip Alvord CPAI Drilling Manager • T, L-314 Tarawa(wp09) IV Grass Roots Topset PIRA.Hole Horizontal Multi-Stage Frac'd Producer ConocoPhillips Proposed Wellbore Schematic Q'CAME O J /4-%"tree,top joint is 4-M"12.6#IBTM,crossed over(for frac equipment) Bearden 6/16/2014 L New Existing Conductor: 16"62.6#HW @ 106' DrillPlex Spud Mud 9.6-10 PPG 3 W'Camco D5 Nipple 2.875" MI 500'MD 13-1/2"Surface Hole 3 K"Camco MMG Surface Casing: 10-3/4"45.5#L-80 Hydril 563 2,816' MD/2,418'TVD @ 63° 3 W'Camco MMG amP0,11 i1 Top. 0 2'MQ(2,534'y! LSND 9-7/8" Intermediate hole 9.6—10.0 PPG 3'/"Camco MMG111 Tubing: Keep up with 3-1/z" 9.3#L-80 EUE8RD Dilution 4-1/2" 12.6#L-80 IBTM top joint to surface Estimated top of cement @+/-6,626'MD (500'above C37) 3 14"Camco MMG Iceberg Top 7,229'MD(4,447'TVD) HIIBaker CMU Sliding Sleeve CLOSED w/2.812"Camco'DS'Profile 10'above Packer 3.5"x 7-5/8",Baker Premier Packer+/-8,844'MD 3'A"Camco D Nipple 2.75"nogo 7-5/8"x 4-W Baker Flex Lock Liner hanger ZXP liner top packer w/RS Nipple,©x/-8,894' • Intermediate Casing TODset with Bonzai: 7-5/8"29.7#L-80&bottom 300'TN110SS 39#-all Hydril 563 connections --Top of Bermuda 9,176'MD 5,334'TVD - 9,044' MD/5,286'TVD @ 74° 6-1/2" Production Hole :Linde ::+1:'l:".:3well Pa kei Packers plus Frac E ui• inent [ ( KLASHIELD. I I hl 1Q5PPG 4.11 O O O O O Barrliuda fore Pressure : Expect dQcrefistng . pre 000towortl tli ;t.9p 3•ppO :1:: T:..:.: . t P Base Bermuda 9,349'MD 5,395'TVD PI WIV&P-Sleeve d@ Production Liner 88.5°: to 9,679' MD 4-1/2" 12.6#IBTM 8,894' MD/5,175'TVD TO 11,500' MD/5,413'TVD 2L-314 7-5/8" Intermediate Cement Design Cement 7-5/8"casing from shoe @ 9,044 MD to 6,626'MD(minimum of 500'above the top of the C37 with 15.8 PPG Class G w/GasBLOK.Assume 40%excess in the open-hole volume. Slurry: (9,044'-6,626') x 0.215 ft3/ftx1.40 (40%excess)=727 ft3 in open hole 80' shoetrackx 0.258 ft3/ftx1.0(0%excess)=20.6ft3 Total volume=727 ft3+20.6 ft3=748 ft3=>639 Sx @ 1.17 ft3/sk System: 639 Sx Class G 15.8 PPG o a) c a--+ . a) Q a-, -o - = Cu N C 0 C E c� s— a) a) o U i Q) C - • E a) -a O co a) C oo U U u co O O c6 —I (Tu— 0 = E TD-' c < -a = a) Li) N O 03 C _aN o co N O2 }, }, -1-j co co O C U O O c3cu � +-+ � O 0 S- v U 2 v No — �--+ a--+ U Uco 0 .— a) cCD" 0 ism n CO .0 ca Ocu E U a, >. N a) o o a) a) O mN L!') a) -a 0 • (11) Om ,a) 40') O OA C > C C v i U 4A (i.) ' -am .o cu O �-c cu °o m az > a) 20 U E O w _. > 1- Q :1-2 v 0 � N U N aj ca O •E 0 �v) 2 n 4.) cti c° i co cu E -' }' . > 0 0 -o(E3 0 a) (D az Cu o 73 _c 0 — 0 m O D C i .cn C +- a) }, 00 O cu +� �_ o ago + . = > o a • o a) ODCL2 _00 "n E E .4s 1-2, 11 Ti,:j L- U , co w _. o_ cu O o o N 4-1 immmiC .- On CIA N .. Ln U = I- o- ..c vs'i U a� C 12 aA a u, 4 aJ co a) o Uca = a--, C N i a) •i - o O a) z -o U • • • +, H Q . C O - N co O . V) a) o v) ED Cl E L Q) c6 W a) O +v-+ m V v u v a) C c v > v 0 au °' .CO O 2 ..D 4- > U caJ O O c� con 0 � o co S. c6 O 4--, +J +� ULn D zn C G.) C o --_-• _c) +� +-, O O _c v U co 0_ >- y- i +� CO N a3 --+ _C 0 -I--) a) ' +J L- O anz O N ra Ni a, 0 o 0- 2 N a) -o c:' o ^I -7-; cu cmvsa) CD > 4-) -.F., cu .' Ln v O a) cur-' E u C' N _0 ° o Q _ i E CO a) -. a) L (6 L C DO . a) _ o O .0 co C o O C +6 - Ln o f— U Q U AZA co Q • \ Q) (J) v) al }'N cn C6 >. Q. a) N n C cu •Uj to ccn UU a .)co a) cu au CO O O QC Q z U Z 0 O a, O `^ a� +) E N -0 C an (13a) C L- H. o > > > ° m oF 7,57 �w ���% � THE STATE\ %% eC ;i i.,,i ci - ,s V ____ _ 333 wcsi SevenTh Avenue 4.4. Ci ov 11lt �i 01: S I:.4 \I P A 12 N i.1.1. Anchorage, Alaska 9950.-3572 -, r" Wm) 907 ;,79 1433 Liz C. Jolley Supervising Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L-314 ConocoPhillips Alaska, Inc. Permit No: 214-023 Surface Location: 181.03' FNL, 704.29' FEL, SEC. 22, T10N, R7E, UM Bottomhole Location: 4766.01' FNL, 230.9' FEL, SEC. 14, T10N, R7E, UM Dear Ms. Jolley: Enclosed is the approved application for permit to drill the above referenced development well. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name KRU 2L-314 PH and API number 50-103-20686-70-00 from records, data and logs acquired for well KRU 2L-314. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, I Daniel T. Seamount,Jr. Commissioner DATED this l day of March, 2014. RECEIVED I STATE OF ALASKA AL 4 OIL AND GAS CONSERVATION COMM )N AN 0 6 H14 PERMIT TO DRILL 20 AAC 25 005 AOGCC la Type of Work. lb.Proposed Well Class: Development-Oil ❑Q . Service- Winj ❑ Single Zone Q • 1c Specify if well is proposed for: Drill E Lateral 0 Stratigraphic Test ❑ Development-Gas 0 Service-Supply 0 Multiple Zone ❑ Coalbed Gas❑ Gas Hydrates 0 Redril❑ Reentry 0 Exploratory ❑ Service- WAG 0 Service-Disp 0 Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q , Single Well❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No 59-52-180 2L-314 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD. 11602 • TVD: - 5413 Kuparuk River Field 4a Location of Well(Governmental Section): 7.Property Designation(Lease Number): ?Ikb Tarn Oil Pool Surface' 181.03'FNL,704.29'FEL,SEC.22,T10N,R7E,UM • 3Sp05'` (ADL)380064;376074 330(262_ Top of Productive Horizon: 8.Land Use Petfiit: 13.Approximate Spud Date' 2657.4'FNL,1010.67'FEL,SEC.14,T10N,R7E,UM , 4602 5/1/2014 Total Depth 4766.01'FNL, 230.9'FEL.Sec 14,T10N. R7E,UM . 9 Acres in Property: 14.Distance to Nearest Property: 5120• 1945'to ADL 375108 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I •142.9 feet 15.Distance to Nearest Well Open Surface: x- 460947 y- 5927664.75 Zone- , 4 GL Elevation above I • 114.9 feet to Same Pool: 2L-313 SF=1.563 16 Deviated wells: Kickoff depth. 400 feet - 17 Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle. 89 degrees • Downhole• 2,800' Surface: 2,259 • 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) 20" 16" welded 92' 28' 28' 120' 120' Existing 13-1/2" 10-3/4" 40# L-80 Hyd563 2591' 28' 28' 2619' 2236' 853 sx 10.7.7ppg lead,271 sx 15.8tail .1 8t/‘ 7-5/8" 29.7# L-80 Hyd563 8413' 28' 28' 8441' 4928' 5-19 ,5a�5 Class G 15.8 ppg 41'48 7-5/8" 39# TN110SS Hyd563 500' 8441' 4928' 8941' 5220' 6-1/2" 4-1/2" 12.6# L-80 IBTM 2811' 8791' 5175' 11602' 5413' V )sx 15.8 ppg Class G \� 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) vi-F 2/28 I1 i- \,'1 Total Depth MD(ft). Total Depth TVD(ft)• Plugs(measured): Effect.Depth MD(ft): Effect Depth TVD(ft): Junk(measured)• c Perforation Depth MD(ft). Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21 Verbal Approval: Commission Representative: Date 1/3/2014 22. I hereby certify that the foregoing is true and correct. Daniel Bearden 263-4864 Contact j.daniel.bearden( COP.com Email Printed Name Liz C.Jolley Title Supervising Drilling Engineer Signature 4---- Phone 265-6247 Date //3 /Pk Commission Use Only Permit to Drill /API Number: Permit Approval See cover letter for other Number ,0 I 90-, 2 3 50-!OS- 20(a '�o - 00 -00 Date' t I requirements. �-�(/ Conditions of approval. If box is checked,well may not be used to explore for,test,or produce coat met ,gas hydrates,or gas contained in les:I IJ Other. � /J y Samples req'd. Yesr-�'' Nco Mud log req'd:Yes No❑ - e= T J J rOO 5 , HZS measures. YesL❑� N Li Directional svy req'd:Ycs, , NoLy Spacing exception req'd. Yes No Inclination-only svy req'd:Yes No /// 1 f'�� APPROVED BY 7 1 / 4 ' 1 Approved b�� _r j ' ' R C4 S I THE COMMISSION Date:30I1f T\ . qua a1i( '► Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the ate o approval(20 AAC 25.005 g)) Attachments in Duplicate Post Office Box 100360 OfOCOPh1II1 Anchorage,Alaska 99510-0360 Phone(907)263-4864 RECEIVED Email: i.daniel.bearden(&conocophillips.com JAN 0 6 2014 January 3,2014 AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill 2L-314 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well slot 2L-314 from the Tarn 2L drilling pad. This well is intended to be a producing well from the Bermuda horizon. The intended spud date for this well is May 151,2014 using Nabors 9ES When the Nabors 9ES rig moves onto 2L-314,the proposed plan is to nipple up and test the diverter system utilizing the existing 16"conductor,spud the well with a 13-1/2"bit,drill to the surface casing point,then run and cement the 10-3/4"45.5#L-80 Hydril 563 surface casing in place. A 9-7/8"bit will be made up and the surface casing drilled out The well will then be drilled down to the intermediate casing point(topsetting the Bermuda)where a string of 7-5/8"29.7#L-80 Hydril 563 casing will be run and cemented in place. A 6-1/2" planned pilot hole into the Bermuda will be drilled for reservoir navigation and data collection. This pilot hole will be plugged back with a cement kickoff plug and a 6-1/2"bit will be run to drill the horizontal lateral portion of the well to TD. Finally, a 4-1/2"production liner with swell packers and frac sleeves will be slid in position for future frac operations. The upper portion of the 4-1/2"liner will be cemented in place with a Bonzai completion Please find attached the information required by 20 ACC 25.005(a)and(c)for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005(a). 2 A proposed drilling program 3 A drilling fluids program summary. 4 Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6 Directional drilling/collision avoidance information as required by 20 ACC 25 050(b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25 035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Dan Bearden at 263- 4864 SEerely, Daniel Bearden Drilling Engineer Attachments ORIGINAL Appii,,ation for Permit to Drill,Well 2L-314 Saved:3-Jan-14 2L-314 Application for Permit to Drill Document 0. ',-).L„:1.i.,., �n ConocoPhillfps Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (0) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 6 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 (Requirements of 20 AAC 25.005 (c)(14)) 8 2L-314 APD Page 1 of 14 Printed:3-Jan-14 ORIGINAL Appm dtion for Permit to Drill,Well 2L-314 Saved:3-Jan-14 15. Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Proposed Well Schematic 8 2L-314 APD Page 2 of 14 Printed:3-Jan-14 _, tai ,) i' t-..r App.,,ation for Permit to Drill,Well 2L-314 Saved:3-Jan-14 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as 2L-314. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a horizontal producer to improve Bermuda oil recovery and pattern sweep efficiency at Tarn. The rig will drill a 13-1/2" surface hole and case with 10-3/4" L-80 with premium connections. The 9-7/8" intermediate section will be drilled to +/- 150' MD above the Bermuda sand, and 7-5/8"top-set casing will be run. A 6-1/2" planned pilot hole into the Bermuda will be drilled for reservoir navigation and data collection. This pilot hole will be plugged back with a cement kickoff plug and a 6- 1/2" bit will be run to drill the horizontal lateral portion of the well. A 4-1/2" production liner, equipped with swell packers and frac sleeves will be run into the open hole for the lower completion, with the upper portion being cemented in place using the Bonzai procedure. Finally, a 3-1/2" gaslifted tubing assembly will be run for the upper completion. Location at Surface 181.03' FNL, 704.29' FEL, Sec 22, T1ON, R7E, UM NAD 1927 RKB Elevation 142.9'AMSL Northings: 5,927,664.75 Eastings: 460,946.60 Pad Elevation 114.9'AMSL Location at 7 5/8" Intermediate Csg Pt. 2,335.2' FNL, 1236' FEL, Sec 14, T1ON, R7E, UM Nad 1927 Measured Depth, RKB: 8,941' Northings: 5,930,767.17 Eastings:465,705.83 Total Vertical Depth, RKB: 5,220' Total Vertical Depth, SS: 5,077' Location at Total Depth on 2,777.5' FNL, 938.5' FEL, Sec 14, T1ON, R7E, UM Pilot Hole Nad 1927 Measured Depth, RKB: 9,542' Northings: 5,930,323.52 Eastings:466,001.74 Total Vertical Depth, RKB: 5,490' Total Vertical Depth, SS: 5,347' Location at Top of Productive 2,657.4' FNL, 1010.67' FEL, Sec 14, T1ON, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 9,348' Northings: 5,930,444 Eastings:465,930 Total Vertical Depth, RKB: 5,325' Total Vertical Depth, SS: 5,182' Location at Total Depth 4,766.01' FNL, 230.9' FEL, Sec 14, T1ON, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 11,602' Northings: 5,928,332.11 Eastings: 466,701.87 Total Vertical Depth, RKB: 5,413' Total Vertical Depth, SS: 5,270' 2L-314 APD Page 3 of 14 Rx Printed:3-Jan-14 Application for Permit to Drill,Well 2L-314 Saved:3-Jan-14 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Nabors 9ES. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP (in) MD/TVD(ft) (lbs. /gal) (psi) Drilling (psi) 16 120/ 120 10.9 55 68 10-3/4 2,619/2,236 14.5 1,040 1,462 7-5/8 8,941 /5,220 15 2,427 2,259 _ 4-1/2 11,602/5,413 15 2,800 2,259 • NOTE: The Nabors 9ES 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A)ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052= Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(16") ASP = [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1]x 120' =68 psi OR ASP = FPP—(0.1 x D) =1,040—(0.1 x 2,236') = 816 psi 2L-314 APD Page 4 of 14 Printed 3-Jan-14 UR I G 1 N A L Application for Permit to Drill,Well 2L-314 Saved:3-Jan-14 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1] x 2,236' = 1,462 psi OR ASP = FPP—(0.1 x D) =2,427—(0.1 x 5,220') = 1,905 psi 3. Drilling below intermediate casing (7-5/8") ASP = [(FG x 0.052)—0.1] D = [(15 x 0.052)—0.1] x 5,220' = 3,550 psi OR ASP = FPP—(0.1 x D) =2,800—(0.1 x 5,413') = 2,259 psi - (B)Data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C)Data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; The most recent SBHPs from offset wells producing wells are: 2L-312: 2,356 psig; 2L-307: 2,650 psig; 2L-306: 1,156 psig; 2L-311: 1,864 psig; The most recent SBHPs for the offset injection wells are: 2L-310: 1,534 psig; and 2L-305: 4,314 psig. Prior to drilling well 2L-314, further offset well pressure surveillance will occur and offset injectors may be shut-in to manage pattern pressures. The Tarn reservoir model predicts the 2L-314 will find reservoir pressure at or near original reservoir pressure of 2,000 to 2,400 psig at the heel of the well with the potential for higher or lower pressure as it is drilled closer to the higher pressured offset injectors and depleted producers. The upper limit of reservoir pressure is estimated at 2,800 psig, but continued pressure monitoring will occur prior to spudding well 2L-314. 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from surface casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 164.8 B-35 Welded 92' Surf 120'/120' Driven Hydril Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,591' Surf 2,619/2,236' 853 sx ASLite Lead 10.7 271 sx Tail Slurry 15.8 ppg 7-5/8 9-7/8 29.7 L-80 Hydril 8,413' Surf 8,441'/4,928' 563 Cement Top planned @ 6,800'MD/ TN- 4,181'TVD. Cemented w/ 7-5/8 9-7/8 39 110S Hydril 500' 8,441'/4,928' 8,941'/5,220' sx GasBLOK Class"G"15.8 ppg S 563 s73 Cement from cementing valve to top of 4 4 1/2 6 1/2 12.6 L-80 IBTM 2,811' 8,791'/5,175' 11,602'/5,413' //"liner,cemented with 104s q GacBLOK Class"G"15.8 ppg 2L-314 APD Page 5 of 14 Printed:3-Jan-14 ORIGINAL Appiwation for Permit to Drill,Well 2L-314 Saved:3-Jan-14 Casing / Liner Design: The 85%collapse and burst ratings are listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7-5/8" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 4.5" 12.6 L-80 3 IBTM 7,500 psi 6,375 psi 8,440 psi 7,174 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Nabors 9ES. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: Surface Intermediate Production 13-1/2" hole 9-7/8" hole 6-1/2" hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Density 9.5 - 10 ppg 9.6—10.0 ppg 10.0- 11.0 ppg YP 60-80 18-28 18-28 Funnel Viscosity(sec) 75—250 40-55 45-55 PV 20-60 20-25 20-25 Initial Gels 10-35 4—8 5-9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Chlorides <1000 9.0— 10 Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water/ gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.5 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight above 9.5 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be important in maintaining wellbore stability. Production Hole Section: LSND/KLASHIELD water-based mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight of at least 10.0 ppg and be 2L-314 APD Page 6 of 14 Printed:3-Jan-14 ORIGINAL Appil.ation for Permit to Drill,Well 2L-314 Saved:3-Jan-14 prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Nabors 9ES Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Nabors 9ES on 2L-314 existing 16"conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor to get 13-1/2" BHA below ground level. 5. Spud and directionally drill 13-1/2" hole to the 10-3/4" surface casing point(2,619' MD/2,236'TVD) according to the directional plan. Run MWD/LWD logging tools in drill string (GR/RES/PWD/Gyro / while drilling) and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 10-3/4"45.5#L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. 8. Shut in BOP's and pressure test surface casing to 3,000 psi per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 10. Directionally drill 9-7/8" intermediate hole to 8,941' MD/5,220'TVD. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD)with on-site mud logging and field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenaris110SS with Hydril 563 connections on the intermediate casing to 8,941' MD/5,220'TVD and cement in place with a minimum of 500' of cement above the Iceberg formation. 13. MU 6-1/2" bit and RIH on 4" drill pipe. 2L-314 APD Page 7 of 14 Printed:3-Jan-14 ORIGINAL App .ration for Permit to Drill,Well 2L-314 Saved:3-Jan-14 14. Directionally drill a 6-1/2" pilot hole to 9,543' MD/5,490'TVD. Run MWD/LWD logging tools in drill string (GR/RES/Neut/DENS/PWD/Periscope/Stethoscope)for navigational monitoring and formation / data gathering. POOH 15. Run back in with OEDP to 9,543' MD and lay a cement kickoff plug back to the shoe of the 7-5/8" casing shoe. 16. Pick up same directional BHA(used to drill pilot hole)with 4" drill pipe, RIH,jump plug below the 7- 5/8" shoe, and drill a 6-1/2" production hole to 11,602' MD/5,413' TVD as per directional program. 17. POOH, and RU casing crew and cementers. 18. MU and run a 4-1/2" liner with Bonzai completion as follows: a. 4-1/2" shoe b. 4-1/2", 12.6#, L-80, BTCM liner(+/-2500')with swell packers and frac sleeves c. ECP (External Casing Packer) d. HMCV(Hydro-Mechanical Cementing Valve) e. 4-1/2", 12.6#,TN110SS,Hydril 563 liner(+/-450') f. Liner hanger 19. Once on bottom, circulate, then drop plug in drill pipe, land plug and pressure up, shear out inner plug. 20. Pressure up and set liner hanger, continue to pressure up and release liner hanger from running tool 21. Place cup tool across the ECP and inflate same with mud, PU cup tool across the cementing valve and increase pressure to shear out valve 22. Perform cementing operations through cementing valve, displace with mud and then pick up on cup tool assembly equipped with a collet to close the cementing valve 23. Once the cementing valve is closed, slack off drill string to set the ZXP liner top packer on top of the liner hanger. 24. Pull cup tool above liner top packer and reverse out any excess cement, run bottom cup on cup tool back into the liner top and perform a pressure test on the liner top packer, POOH and LD 4" drill pipe 25. Run 3-1/2" completion tubing with premier packer and seals and set packer at+/-8,600' MD/5,107' TVD. 26. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1 B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic 2L-314 APD Page 8 of 14 Printed:3-Jan-14 ORIGINAL App ,.,tion for Permit to Drill,Well 2L-314 Saved:3-Jan-14 Attachment 1 —Directional Plan 2L-314 APD Page 9 of 14 Printed:3-Jan-14 OKkJINF\ L Application for Permit to Drill,Well 2L-314 Saved:3-Jan-14 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2L-314 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low I Monitor cellar continuously during interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures,Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips (use of trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/2" Hole /4-1/2" Horizontal Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Plan to top set the 7-5/8" intermediate casing above the Bermuda placing the entire intermediate section behind pipe prior to drilling the Bermuda Mud weight will be used for offsetting formation pressure Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 2L-314 APD Page 10 of 14 Printed:3-Jan-14 AN....—(ion for Permit to Drill,Well 2L-314 Saved:3-Jan-14 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. A separation factor(or proximity ratio) using the ratio of center-to-center distance divided by the combined ellipses of uncertainty between two wellpaths is used to determine wellbore collision risk. A ratio of greater than 1.0 indicates two different well path ellipses of uncertainty do not touch. The traveling cylinder plot is used on the rig to keep track of the wellpath position relative to close approaches to offset existing wellbores. In the event that the wellpath falls behind the curve, drilling is stopped and the motor bend can be increased or the survey frequency can be increased. In general, no significant clearance issues exist with the 2L-314 well plan. Anti-collision analysis indicates the following separation factors between the planned 2L-314 well plan and the following existing wellbores. 2L-313 (Separation Factor= 1.563, 15.15' center to center at a depth of 597' MD) 2L-315 (Separation Factor=2.450, 19.90' center to center at a depth of 497' MD) 2L-03 (Separation Factor= 1.799, 202.60' center to center at a depth of 4,006' MD) Drilling Area Risks: Reservoir Pressure: Offset injection conduits have the potential to increase reservoir pressure over predicted, although this is unlikely, the rig will be prepared to weight up if required. Due to the greater degree of reservoir pressure uncertainty in the Bermuda targeted interval, the Bermuda will first be topset to keep the shallower unstable shale behind pipe prior to penetrating the Bermuda. Mandatory flow checks will be performed upon penetration and when tripping out of suspected gas or overpressured zones such as the Campanian, Iceberg, and Bermuda intervals. Lower Shale Stability: Unstable shale and ash in the intermediate will require higher mud weights to stabilize. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of surging or swabbing the formation. 2L-314 APD Page 11 of 14 Printed:3-Jan-14 ORIGINAL - !L-314 Tarawa Grass Roots TODset Pilot Hole Bonsai Horizontal Multi-Stage Frac'd Producer ConocoPhillips Proposed Wellbore Schematic _ CAMERON 4-W tree,top joint is 4-'A"12.6#IBTM,crossed over(for frac equipment) Bearden 1/20/2014 Fresh WateI l J New Existing Conductor: Spud Mud 16"62.6#H-40 Permafrost 9.6 PPG 3 W'Camco DS Nipple 2.875" ) 500'MD 13-1/2"Surface Hole Fresh Water Spud Mud 9.8-10 PPG J 3'A"Camco MMG ,,, Surface Casing: s1 10-3/4"45.5#L-80 Hydril 563 — .>:- 2,619' MD/2,236'TVD @ 62° I - 3%"Camco MMG «w 10i 1000.4�T00 3g07.:MQ(2 546'.TV' .-. ..... .SND )-7/8"Intermediate Hole 3.6—10.0 PPG 3%"Camco MMG - Tubing: <eep up with 3-1/2"9.3#L-80 EUE8RD Dilution 4-1/2" 12.6#L-80 IBTM top joint to surface Estimated top of cement©+/-6,800'MD (500'above Iceberg) 3 X"Camco MMG aw J Iceberg Top:1;284 ktl'3 t+aa5 hro? ;: .. 11 Baker CMU Sliding Sleeve CLOSED w/2.812"Camco'DS'Profile 10'above Packer 11111 3.5"x 7-5/8",Baker Premier Packer+/-8,800'MD 3%"Camco D Nipple 2.75"nogo Fa E3 7 7-5/8"x 4-W Baker Flex Lock Liner hanger Z%P liner top packer w/RS Nipple,Op+/-8,791' Intermediate Casing ToDset with Bonzai: 7-5/8"29"7#L-80&bottom V TN 110SS 39#-all Hydril 563 connections Top of Bermuda 9,244'MD 5,328'TVD . 8,941'MD!5,220'TVD @ 74° 6-1/2"Production Hole "12:. tint :•::::. ii sikoCii k .._ O O O O O :: :: ikr: ilof� 9erm::. •i III IIII MI III IIII i : ::::° i " r8e ite # ` €E eC`d#ce*s ni . t ::::: ..:: :. . 4s: I 'OWi 'i ::; : :::: Production Liner @ 88.5°: Perforated Pup 4-1/2" 12.6#IBTM 8,791'MD/5,175'TVD TO 11,602' MD/5,413'TVD Appii„ation for Permit to Drill,Well 2L-314 Saved:3-Jan-14 Attachment 3–Proposed Well Schematic Tarn 2L-314 Tarawa(wp08) Grass Roots Tonset Pilot Hole Bonsai Horizontal Multi-Stage Frac'd Producer ConocoPhillips Proposed Wellbore Schematic CAMERON 4-S" tree,top jar:is 4-W 12.6A IBTM.crossed over(for frac equipment) Bearden 12'30L2013 sh Water New Existing Conductor: :i,d Mud 16"62.61/H-40 -t mafrost ;PPG 3 x^canto oe Nipple 2.17r •= 505753 13-112"Surface Hole s'h Water Id Mud 10 PPG 3g"Como MUG A.,_i Surface Casing: 10-3/4"45.5#L-80 Hydril 563 — 2.619'MD/2,236'TVD @ 62v 3L:"Corm*MMG Campanian Top 3,29W.0/10 OAP': .. LSND _ 9-7/8"Intermediate Hole 9.6-10.0 PPG 36"amcoMUC, ,w J TUbinq: Keep up with 3-'/2"9.3#L-80 EUE8RD tiSks Dilution 4-W 12.6#L-80 IBTM top joint to surface I -43 Estimated top of cement +;-6,800'MU (500'above Iceberg) \ , 3',•caa,�e mut .e J N,pq \. Iceberg Top 7.315'MD 0.45aIVOr Baker CMU Sliding Sleeve CLOSED kr?2.111r Camco'05'Pronto , stor IC'a[nnw Pa,Y,nr '1e.;) all1. 3.5'1 r-5.8•,Bakst Premier Pocker 8.615-ND -' �`' /1k� 3',"Camco 0 Nipple 275'nogo � `! V 7 7 7-55'x 4-',5'Baker Flex Lock Lncr hanger '.1.,1 �/,1�,, B54rex Pe rMksr l •7-/iN�e#.r-8791' Intermediate Casino Tooset with Bonzai: ' ` 7-518"29-7#L-80 8 bottom 500'TN110SS 394-ally' D o Hydril 563 connections 6-112"Production Hole ., Top W Bermuda A.244'k1 D 5.328'TVD I d 8,941'MDI 5,220'TVD @ 74e ,.#9nsa1 ldr>gG # x`:128#::::: ►0 0 liDlllll .Tf4.1M . ::P�pltir ....... ..s....>#....d..a..P$.o .:.. ens...•...:.t...... .d.....e.....:.-. s....l•g...•-......€.. ............. . . ... nasi:. :.. d.h$toa<..... . .... . ... ... . . . * .. • i:togR ::::::: : : . ... -• .. : .... ,. . ;;;; �:90��2: X3^.:34w� � ;;; ::: ;; ;. .................................. Production Liner ft 88.5: Perforated Pup 4-1/2"12.6#IBTM 8,791'MD I 5.175'TVD TO SUPERSEDE 11,602'MD/5,413 TVD 2L-314 APD ..-... - ,– Page 12 of 14 -"""" - -' . ..- Printed:3-Jan-14 ORIGINAL Apr.._,.tion for Permit to Drill,Well 2L-314 Saved:27-Feb-14 Attachment 4—Cement Summary 10-3/4" Surface Casing Cement Job Cement 10-3/4" casing from shoe @ 2,619' MD to 2,119' MD(500' of fill)with Class G + Adds @ 15.8 PPG, and from 2,119' to surface with 10.7 PPG Arctic Set Lite. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(Base Perm is 1,385' MD), zero excess in 16" conductor. Lead Slurry: (120')x 0.638 ft3/ft x 1.0 (0% excess) =77 ft3 (1,385'— 120') x 0.364 ft3/ft x 3.5(250%excess) = 1612 ft3 above permafrost (2,119'— 1,385)x 0.364 ft3/ft x 1.5 (50% excess) =401 ft3 below permafrost Total volume=77 ft3+ 1612 ft3+401 ft3= 2090 ft3=> 853 Sx @ 2.45 ft3/sk Lead: 853 Sx Arctic Set Lite @ 10.7 PPG Tail Slurry: (2,619'—2,119') x 0.364 ft3/ft x 1.5 (50% excess) =273 ft3 annular volume 80' x 0.54 ft3/ft=43.2 ft3 shoe track volume Total volume=273 ft3 +43.2 ft3= 316.2 ft3=>271 Sx @ 1.17 ft3/sk Tail: 271 Sx Class G @ 15.8 PPG 7-5/8" Intermediate Casing Cement Job Cement 7-5/8" casing from shoe @ 8,941' MD to 6,800' MD (minimum of 500' above the top of the Iceberg - if present) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the open hole volume. Lead Slurry: (8,941'—6,800')x 0.215 ft3/ft x 1.40(40% excess) =644 ft3 in open hole 80' shoe track x 0.258 ft3/ft x 1.0(0% excess) = 20.6 ft3 Total volume =644 ft3 +20.6 ft3=664.6 ft3=> 573 Sx @ 1.16 ft3/sk Total: 573 Sx Class G @ 15.8 PPG 4-1/2" Liner Bonzai Cement Job Cement 4-1/2" liner from Banzai ECP @ 9,350' MD up to 8,791' MD (150' inside the 7-5/8" 39# casing) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the annular volume, and inside casing for a cap to be circulated out. Lead Slurry: (9,350'—8,941') x 0.12 ft3/ft x 1.40 (40% excess) = 68.7 ft3 in open hole (8,941'—8,791') x 0.129 ft3/ft x 1.40 (40% excess for cap) = 19.4 ft3 in cased hole 3 bbls of under displacement(16.9 ft ) Total volume=68.7 ft3+ 19.4 ft3+ 16.9 ft3=> 105 ft3=> 91 Sx @ 1.16 ft3/sk Total: 91 Sx Class G @ 15.8 PPG + additives to be batch mixed 2L-314 APD Page 13 of 14 Printed:27-Feb-14 App,.,.ation for Permit to Drill,Well 2L-314 Saved:3-Jan-14 Attachment 4-Cement Summary 10-3/4" Surface Casing Cement Job Cement 10-3/4" casing from shoe @ 2,619' MD to 2,119' MD (500' of fill)with Class G + Adds @ 15.8 PPG, and from 2,119' to surface with 10.7 PPG Arctic Set Lite. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(Base Perm is 1,385' MD), zero excess in 16" conductor. Lead Slurry: (120')x 0.638 ft3/ft x 1.0 (0% excess) =77 ft3 (1,385'- 120') x 0.364 ft3/ft x 3.5 (250% excess) = 1612 ft3 above permafrost (2,119'- 1,385)x 0.364 ft3/ft x 1.5 (50% excess) =401 ft3 below permafrost Total volume= 77 ft3+ 1612 ft3+401 ft3= 2090 ft3=> 853 Sx @ 2.45 ft3/sk Lead: 853 Sx Arctic Set Lite @ 10.7 PPG Tail Slurry: (2,619'-2,119')x 0.364 ft3/ft x 1.5(50% excess) =273 ft3 annular volume 80' x 0.54 ft3/ft=43.2 ft3 shoe track volume Total volume=273 ft3+43.2 ft3= 316.2 ft3=>271 Sx @ 1.17 ft3/sk Tail: 271 Sx Class G @ 15.8 PPG 7-5/8" Intermediate Casing Cement Job Cement 7-5/8" casing from shoe @ 8,941' MD to 6,800' MD (minimum of 500' above the top of the Iceberg - if present) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the open hole volume. 2iq--( o � � l� Lead Slurry: (8,941'-6,800')x 0.215 ft3/ft x 1.40 (40% excess) =644 ft3 in open hole 80' shoe track x 0.258 ft3/ft x 1.0 (0% excess) =20.6 ft3 7L.r: 2q)(s Total volume>644 ft3+20.6 ft3=632 ft3=> 545 Sx @ 1.16 ft3/sk Total: 545 Sx Class G @ 15.8 PPG At 4-1/2" Liner Bonzai Cement Job 1,`6"a / 7 Cement 4-1/2" liner from Banzai ECP 10,700' MD to 852' MD (200' inside the 7-5/8" 39# casing) with Class G + Adds @ 15.8 PPG. Assume 40 ess in the annular volume, 0% excess inside casing. 1000 1005'' /0q Lead Slurry: (9,500'-841')x 0.12 ft3/ft x 1.40(40%excess) = 94/ft3 in open hole 200' inside 7-5/8" 39#casing x 0.129 ft3/ft x 1.00(0% excess) =25.8 ft3 80' shoe track x 0.0854 ft3/ft x 1.0 (0% excess) =6.83 ft3 Total volume= 94 ft3+25.8 ft3+6.83 ft3=> 126.6 ft3=> 109 Sx @ 1.16 ft3/sk Total: 109 Sx Class G @ 15.8 PPG 2L-314 APD Page 13 of 14 Printed:3-Jan-14 ORIGINAL REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 5 10/24/13 JFC MEH Add 314 Per K130111ACS 4 11/17/10 NRB - I PER K100117ACS q°° o 0 Q__--1 0 ' °' DS 2A1 Q C� � AI 4 a^ D .6 31 9 v A 0Ef ArtliD 6 NOTES: — mil q'��, TION G 0 ° S 1, IA r': 1) Basis of location and elevation is Drill Site 2L ;gyp �( `f.- 1 °� �j,,-" ~�' n `� t S. monumentation per Lounsbury & Associates. 0' ® � So 2) Coordinates shown are Alaska State Plane '�� `° '� 'e o • Coordinates, Zone 4, N.A.D. 27. 9S THIS N.a N. °'`�1�po 3) Elevations are B.P.M.S.L.. IP d�., ,, • IS 14 j 4) All wells are located within protracted Section 22, —DS 2L w- :b°°li i till Township10 North, Range 7 East, Umiat �:�7 " " Meridian. 9 -Pe �� V 1 E4 V / O '� 6 VO o 5) Drill Site 2-L Grid North is rotated 13' West r —.. from A.S.P. Grid North. 27 • 6 EG ,o z5 'op ti 0A 3G CrWCe Sy 1\ °\ t 41)3 % %jQ % TtoN -- [\'S 2N 0 1 -�— T9N LEGEND VICINITY MAP (Not To Scale) • EXISTING CONDUCTOR LOCATION • FUTURE CONDUCTOR LOCATION ® AS-BUILT CONDUCTOR LOCATION (This Survey) Section Corner T10N, R7E 15+14 22 23 wwwo � LA S' LA W j J �•••• WL':."1 W •••••!•w o W W j O J04:1:::: • w O N CA1z2:).1...4 N 1,..) ••••' j OCA �. wW N N O W U4 N N N O O c pR1L SCALE: 1"=200' LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS Refer to Sheet 2 for Notes and Location Information. 1"40 `.i AREA:2L MODULE:XXXX UNIT: D2 ConocoPhillips DS2L WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK6212D44 9/17/08 CEA—D2LX-6212D44 I 1 OF 2I 5 I -C1biN PL. REV DATE BY CK APP JESCRIPTION REV DATE BY I PP DESCRIPTION 5 10/24/13 JFC MEH Add 314 Per K130111ACS 4 11/17/10 NRB - I PER K100117ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 22, T1ON, R7E WELL SECTION ELEVATIONS OFFSETS NO. 'Y' 'X' LATITUDE LONGITUDE F.N.L. F.E.L O.G. PAD 301 5,927,708.71 461,136.31 70' 12' 48.409" 150' 18' 48.355" 136' 515' 108.6 115.0 303 5,927,701.73 461,107.21 70' 12' 48.339" 150' 18' 49.199" 143' 544' 108.6 117.1 304 5,927,698.48 461,092.72 70° 12' 48.306" 150' 18' 49.619" 147' 558' 108.6 114.9 305 5,927,695.13 461,077.91 70' 12' 48.272" 150' 18' 50.048" 150' 573' 108.6 117.1 306 5,927,691.60 461,063.16 70' 12' 48.237" 150' 18' 50.476" 154' 588' 108.6 114.8 307 5,927,688.53 461,048.89 70' 12' 48.206" 150' 18' 50.890" 157' 602' 108.6 117.1 309 5,927,681.46 461,019.47 70' 12' 48.135" 150' 18' 51.743" 164' 631' 108.6 117.1 310 5,927,678.28 461,005.00 70' 12' 48.103" 150' 18' 52.163" 167' 646' 108.7 114.9 311 5,927,674.97 460,990.28 70' 12' 48.069" 150' 18' 52.589" 171' 661' 108.8 115.3 312 5,927,671.64 460,976.08 70' 12' 48.036" 150' 18' 53.001" 174' 675' 108.7 114.8 313 5,927,668.15 460,961.26 70' 12' 48.001" 150' 18' 53.431" 178' 690' 108.6 117.1 315 5,927,661.35 460,931.78 70' 12' 47.932" 150' 18' 54.286" 185' 719' 108.8 117.1 317 5,927,654.49 460,902.70 70' 12' 47.863" 150' 18' 55.129" 192' 748' 108.9 117.1 318 5,927,651.29 460,888.09 70' 12' 47.831" 150' 18' 55.553" 195' 763' 109.1 114.8 319 5,927,647.91 460,873.38 70' 12' 47.797" 150' 18' 55.979" 199' 777' 109.7 115.3 320 5,927,644.53 460,858.89 70' 12' 47.763" 150' 18' 56.399" 202' 792' 109.1 114.9 321 5,927,641.08 460,844.20 70' 12' 47.729" 150' 18' 56.825" 206' 807' 108.6 115.3 322 5,927,637.77 460,829.38 70' 12' 47.695" 150' 18' 57.255" 209' 821' 109.0 114.8 323 5,927,634.29 460,815.00 70' 12' 47.660" 150' 18' 57.672" 212' 836' 109.5 117.1 325 5,927,627.55 460,785.75 70' 12' 47.593" 150' 18' 58.520" 219' 865' 109.7 117.1 326 5,927,624.35 460,771.05 70' 12' 47.560" 150' 18' 58.947" 223' 880' 109.4 115.4 327 5,927,620.79 460,756.44 70' 12' 47.525" 150' 18' 59.370" 226' 894' 110.1 117.1 328 5,927,617.58 460,741.94 70' 12' 47.492" 150' 18' 59.791" 230' 909' 109.9 115.4 329 5,927,614.08 460,727.42 70' 12' 47.457" 150' 19' 00.212" 233' 923' 110.3 117.1 330 5,927,610.80 460,712.60 70' 12' 47.424" 150' 19' 00.642" 237' 938' 110.4 115.4 ** 314 5,927,664.75 460,946.60 70' 12' 47.967" 150' 18' 53.856" 181' 704' 108.7 114.9 ** INDICATES CONDUCTOR ASBUILT THIS SURVEY. .•!�E OF ,7•• SURVEYOR'S CERTIFICATE "< .,, '95• � I HEREBY CERTIFY THAT l AM PROPERLY •°� • �I� . z#♦�� REGISTERED AND LICENSED 70 PRACTICE 49th 1\ ND SURVEYING IN THE STATE OF ' ALASKA AND 77IAT THIS PLAT REPRESENTS 0 A SURVEY DONE BY ME OR UNDER MY •VIBRIAN G. MANGO D ,o� DIRECT SUPERVISION AND THAT ALL v# am S-8626 v,p ,••.l 4-417 CORRECT AS DIMENSIONSA OND F OCTOBER 23,I LS 2013.E LOUNSBURY �� RpFESSIONA��P•�• & ASSOCIATES, INC. , ' SURVEYORS ENGINEERS PLANNERS ti,"".. y.� AREA:2L MODULE:XXXX UNIT: D2 ConocoPhilli s DS2L WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO.LK6212D44 9/17/08 DRAWING N0' REV: CEA-D2LX-6212D44 PART: 2 OF 2 5 I ' r t U1 \ i '01 \1I�1L 7-Di 2L-3l4PBlwpO8 6.404 Plan Summary SURVEY PROGRAM 1610 . ------ Depth From Depth To Survey/Plan Tool 28.00 1150.00 2L-314PB1wp08(Plan:2L-314PB1) GYD-GC-SS 1150.00 2619.11 2L-314PB1wp08(Plan:2L-314P®NyD+IFR-AK-CAZ-SC 2619.11 8940.91 2L-314PB1wp08(Plan:2L-314P®'VyD+IFR-AK-CAZ-SC 100 �,- /' 8940.91 9542.57 2L-314PB1wp08(Plan:2L-314P®'VyD+IFR-AK-CAZ-SC 0 �/� CASING DETAILS �� ���� TVD MD Name 10 3 ® i� 2235.80 2619.11 10-3/4" x 13-1/2" 10-3/4 5219.90 8940.91 7-5/8" X 9-7/8" 7-5/8 /� /14/41/4 - C-37 T-4. . 0 0° 10-3/4"x 13-1/2" PFROST C-40 / C-35 0 •5- - � ',5 /`• :0.,000 0 . o �� 00O. 0 7-5/8"X 9-7/8" - \ N O� y00 00 1 CO 1 a° - C-90 CAMP SST T-7 BASEERM co 00 0 0 _ - \\ C-80 C-50 ._.._7-5/8"X 9-7/8" '. - o o0o a o ° ci _5555.. - `... 1 , oIIIIIIIIIII _ N O 00 yb ®_� 0 0 I I r I 4‘ l ' I I I I I I I 1 I I 0 0 2500', 5000 7500 10000 0 950 1900 2850 3800 4750 5700 6650 10-3/4"x 13-1/2"Measured Depth Horizontal Departure a Ilil �� �� 2L-317 330 30 = = r y• 60 IIIIgII14 t' I °' t 1 'r ? 2L-308wp04 ass II p '. -' 300 . i 760 see lee see +,se dil gill LI ,\ • `.2L-31 B 5 555 -.. _. 5555 5 5 5 5. ,�„ - a CO l > 5555 __ 5555 __ 2L-314wp08 _ , \ \.`.� 2L, 2L-308PB1wp0e �3,o°B2298 III l 1 iiI�L!I , , _ 9. m I/l` ., -31Rwp1S 270 90 O 30 FIll II 1 2L-313 (((f - 3. y0 - , s ' '' , , 2LJOBVBt ED_ I / t t - umlvll / 5555 '2L-317A2L 311A.(wp01) _ 5555 240' •.i, �-4 120 = .98 'Rd «se .we /1 5398 ma 9e see,, U -. 5555. 55.55_ 5555... 5555. _.. 0 ��3 .3.9 sass - s,ea 0 I I I 1 I I 1 I I 1 I I 1 I I I I I e'. � I 6998 = 74. 210 6" X50 0 1500 3000 4500 6000 7500 9000 1 9)N - 8. 1 1 60 - .88 SECTION DETAILS 8.:,.. - Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target - 1 28.00 0.00 0.00 28.00 -114.90 0.00 0.00 5927413.97 1600980.34 0.00 0.00 0.00 2 353.00 0.00 0.00 353.00 210.10 0.00 0.00 5927413.97 1600980.34 0.00 0.00 0.00 3 653.00 4.50 7.00 652.69 509.79 11.69 1.44 5927425.65 1600981.84 1.50 7.00 -10.58 4 853.00 9.20 22.33 851.22 708.32 34.27 8.47 5927448.19 1600988.99 2.50 29.00 -29.65 -1368.8 5 1000.00 12.10 45.70 995.74 852.84 55.91 23.97 5927469.75 1601004.60 3.50 68.00 -45.06 6 1200.00 12.10 45.70 1191.30 1048.40 85.18 53.96 5927498.86 1601034.75 0.00 0.00 -62.97 7 2456.99 62.35 41.94 2160.56 2017.66 626.42 552.77 5928037.43 1601536.32 4.00 -4.33 -412.33 PFROST 8 6577.83 62.35 41.94 4073.13 3930.23 3341.37 2992.52 5930739.33 1603989.98 0.00 0.00 -2185.06 9 8940.91 74.00 146.00 5219.90 5077.00 3127.31 4743.58 5930516.15 1605739.73 4.00 110.71 -1412.57 Plan:2L-314 7 5/8"CSG 10 8970.91 74.00 146.00 5228.17 5085.27 3103.40 4759.71 5930492.16 1605755.73 0.00 0.00-1384.71 -2222.9 11 9542.57 51.13 146.00 5489.80 5346.90 2685.55 5041.55 5930072.88 1606035.36 4.00 180.00 -897.87 2-90 =MAP CAMP_SST -3747.9 CC-�-50 -43'0 0 C-37 -4857.9 T-7 -5103.9 T-4.1 MiEgiRK4SEIS C-35 Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM 2013 T M Depth Reference: Plan:114.9+28 @ 142.90ft(Nabors 9ES) Magnetic Model Date: 21-Oct-13 System(SS)Reference: Mean Sea Level Magnetic Declination: 19.54° 41. North /Y: 5927413.97 To convert a Magnetic Direction to a True Direction,Add 19.54°East Ground Level/Mud Line: 114.90 East/X: 1600980.34 Rig: Nabors 9ES ORICNOA 100/1000 of reference N 0. I v a o • c as3 E m m E O > a � � O RN cM c'�) C) /^ N V♦ c i L N N N C O co = C v 0 co -O V Y Y a a a 0 N 07,' : . _ CO a Z z 3 N n Q m rn o o 0", O o m CO w CO• v •"' •v o O O) Q N EN m „ co ,-0) O• O ` o Q b o3 coso so O ,n r Q Z z n CL 3 00 .a o 0 co• O O 0 CL csi I- .,- ccsi ,- coay U N ��11�pN > O V' c © 7 a N 0 O r M N N d >(0 O as ,e-- , E - a- ro 0>0 co O O y a .- c- 7 Q CO> m d v J C c 0) m 0 a 3 c 3''' C.3 CD • Y d d I- 2 LW 2 D D = C O d > J J 0 °I 0 0 O ii a c 0 r' 0U 0) m .c - c .- ct Yo co 2 J J ' cC O C ce C C N O ro E N V d C = 3 a • c a y C d O .) 0 0 o ,°.r. y cu 0 C)0 Ti °) LL 0 c U 4fw Ce >, R E w "= = o o o Q-' / Z o .O °f s L O W �c b.10 c:1 J ~ 2 Z fn O CO V I- •7 co 0 r. O co W L a)O M co I co d L — v_ O) w t` O a s to a) 1 Q L,w E I o r E p a = U) o C c c = ca o O o 0 t) Ti: H > +' `r o 3i d a N c .,m a arC N t N a) o as _p C C c O a 115 Z W U) o R —y C c U) Z W 3 0 a 8 Z o m + O cz D Y d Vl N M Q y O Q R N O 0 N CI d 8 N p_ O CLI_C CV t Y CO 3 N $ 00 Li C O (fl LL N C co ~ O O O m O O. fi > c O O 0J o ro o)p N O co coN N y 00 ro O d 0 C C _ 2 N N CO V nD mHmo CO (° 0 °7 0 C c Z CO CL pa oI oz) ro a > .... v 3 = (DEN = n n. a a c,a N L Q' N c.,7)- M m <Q ro ca N 3 0 Q. Y Y J J d U)•C Y 2 _ 2 ` N N V' cn O 03Z W 'I o m m =z Q c + + c co a U Y Y d a N c h dC °> C N O C O C d 0 M c . L. 0 0 C •Ul c 73 7 .o c d 0 O N r a) O C T ro 0 O O i O O O d C Z CO �° p fl 0 _ .fl 0) d N D N a - : w .fl c G1 ` v N O O r d d y O ro o R r w O 0 d N NO d o 0 7 0 0 0a. w 3o a 202 in inu. a 3 3 a 3 2 o a > > o (mr! ti1 � 01 0 LO LO LO LO LO LO CO CO CO CO LO LO CO CO N CO o .a C) T T ,- ,- T T r T T T T T T T T .z m w ^ W W ate) 0 0) O J 0 N Cn O LO O V N Cr) CO CO CO N CO 6 M O) 10 V CO N 0 O 0 N CO V V CO N M 0) 0 N CO LU CO Q Z Z i O O O O O O O O O 0 .-- a. N= =O` Q mrnrn W U Lo 4 4 c0 I- 2 j i6 p�pp�, J . GG = p CN J N N Z a O O O O O 0 0 0 0 O M CO 0 v O O t + V Y O O O O O 0 0 0 O O ,- 0 O N O O N CO 0 O O O O O N O O O o) M CO 6 CA O O CO e- E co N N CO LO a - ' 7 Q tail E Co s. N co CO2 C 0 H n. d H W c) 0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 u v 0 0 0 0 0 LO LO LO LO LO LO LO Ln LO 0 0 C 0 O O O O O ,- .- .- N N N M M O O 2 .c N dCA v KJ 0 (U C ❑ O y . O E U CU C CO N a C c m o ' a 7 V V CO o 0 V 0) 0) 0) LO O N LO 9 d 0 @ = UUU CO CO M CO CO CO N CO 0) LO O co LO Cfl CO F-- 0 0 w d o 0 dj N U U U O O 6 0 0 Co - - 0 O N V CA a V 0 a T 2 N U) CO CA CO CO CO 0O CO C0 C0 C0 CO CO CO CO o) O M GI >s 0) 0) 0) o) W 01 01 0) 0) 0) 0) CO 0) 0 0 0 � � � cQQQ 5 0 0 0 0 0 0 0 0 0 0 0 0 0 o p o (a N 0 0 0 N w cocoa 0 0 0 0 0 0 0 0 0 0 0 J F- . Z CO p o ) Y Y W "' CO CO CO c0 O c0 O O co.. O CO CO CO CO CO CO C >.< < < O ma' a' 2 LO. Y3 U_ LL LL d - t t t N N N N N LO N C) LU 0) CO CO N LO O CO U o a 0 0 0) 0) 0) 0) 0) N N 00 CO (O M ,- .- N M CO L OCS d 3 M M M M M V O Cc) 0) O M U) 0) V c0 • � I.0 CO p U V V 'R 'C V '1' V a <1' V' V V' < �' E t 3 N N�. N N N N N N N N N N N N N N E .= N N N N N N N N N N N N N N N N CI? (!) CO p `� CO 0) CO m O) 0) 0) 0) O) 0) 0) 0) o) 0) 0) 0) D N Z LO 6 LO LO LO LO LO LO CO 6 LO LO LO LO 6 LO SCO UUU O a Cl) CO Q Q Q rn rn o_ _O _O _O co co m I o) CN') CO. 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(.1 a) O _O co O 80dMI L£-1ZI II MIMI0111 V A` o V♦ rn c o 000 0 I o 0c,.1o rn OD 0 o 0 0 C/ 0 O cr,p 6) 0 4 co pp 80, S6, T T , c C7 pp p-) O x pti 0006 Ca) p co �p0 7/7 To o .} 1 O ppp DD —co > ca Cooo 0• X r CI n o0 in 0 T —r-- CON 0 III o 0 T —o CO M J CV 0 _i, I I I I I I o o o O o 0 0 0 0 0 0 0 0 0) co N co in (u!/14 006) u1�49 IW! 9�anal NI- in N 0 0 O 0 -e co 0 L0) f 0 O O _ r r N r 1 r \ O T O ` N CO 1 Ln O _ 0 O N T co o co "Po' V`.; C XNI" BYO~• N 0888 *co= .6w O M C `QQCD 4- co co + 000 al CD O W O -CO N In a) 00 (oO 0 Ln _o T 0 �OOo aO _o co T OO TM ('P CO N J T 4 - N ") ° oo x g 4 M (:00 1- toga -O O O OI O I I I O O O O in O in O Ln CD co N (uiill 099) - 11 -)ulneS co URiGNAL ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-314 (Tarawa) Plan: 2L-314PB1 2L-314PB1wp08 Anticollision Report 29 October, 2013 Sr MD Inc Az: TVD +N/-S +E/-W DLeg TFace rc Target 18.00 0.00 0.00 28.00 0.00 0.00 coo 0.00 M 28 351 2L-314PB1wp08 3 653.00 0.00. 0.007. 353.00 11.69 0.00. 0.00. 0.007. -10.58 4 853.00 9.20 22.33 851.22 34.27 8.47 2.50 29.00 -29.65 351 598 28.00 TO 9542.57 5 1000.00. 12.10 45.704 1191.30 55.918 23.97 3.50 68.00. -62.97-6 598 798 7 2456.99 62.35 41.94 2160.56 626.42 552.77 4.00 -4.33 -412.33 __ 8 6577.83 62.35 41.94 4073.13 3341.37 2992.52 0.00 0.00 -2185.06 798 998 16:01,October 29 2013 9 8940.91 74.00 146.00 5219.90 3127.31 4743.58 4.00 110.71 -1412.57 Plan:2L-314 75/8"CSG 10 8970.91 74.00 146.00 5228.17 3103.40 4759.71 0.00 0.00 -1384.71 998 1198 11 9542.57 51.13 146.00 5489.80 2685.55 5041.55 4.00 180.00 -897.87 C LOBAL FILTER APPLIED: A 1198 1398 1398 1598 Depth From Depth TO Survey/Plen Tool 2809 1159.00 21.-3141,e1wp08Plan:21.014Per0'6GC-SS 1598 1798 1150.90 2619.11 2,314P61wp08(Pan(2,310Pa192/0•I913-012CAZSC 2819.11 8940.91 21.314P511WPp8(Pan:2,3142 +IFA-ANCAZSC 1798 2298 CASING DETAILS TVD MD Name Size 2298 2698 2235.80 2619.11 10.9/4"x 13-1/2" 10-3/4 2698 W 3198 5219.90 8940.91 7.5/8"X 9-7/8" 7-5/8 3198 3598 3598 4098 4098 - 4498 4498 - 4998 0/360 4998 5398 ,- 5398 - 5898 ���\V '% `0 �� 4. _1 1 5898 6398 -30/330 \ ."C °, 7Ir! i iz: 30 E 6998• • • • iv' 7498_,i Ati.. ..,1-'8:!.1:.1:#'.-,?;-2 1 f.;..1.:-,..:.; : 7::1 .! j7 7998 7998 8498 :I:7.. ��, , ,- :-'...'.._„„....____,...„'_.„..11....,.:,„:*'- :(:---:ft-.....:i��j �% 8498 8998 ::: .i.�/.,o�I:147,,...; 8998 9542 „i -60/300 -- ::: _ �s i 60 j 1 ;. 60 ( 4.4.5.11„,:1; . ., .,.....,...".'"--?..----- #041143:4,14,4,,,,,,,iir ..4, „,),,,,,,,,I,..,.. IN n. 11.06• /if/..'''''..-7-f".4''1.44)..!‘0. .Qt.:."°...4-Vtiki -90/270 i� h8�\JAO"1`, r'° ,le , o • .1811% a®..�v.%;Tiff: :E a� O p /r ►��c. � c 49 Po ii �� ur ��4 I mil! �l� I l II �I�,:. !( ff{/f°��� �.a� oto + ,■1/�bi�,ol�,l� aY": %�1t 1 �'1 ,.1�� , 'I�` r'' d" r .1rlea�i:v ��: ����it /i;• 1\ _ Y v IOC C• *):'Ip.6:,,®�/r�I ms, ' ,1^1,1 w 4lr■ ea,4,_'� 1'44,1 lZ• • ��V„\ .f/ ,f-- .V N$'4%4®WA; ..•'9'/lf,,'.4�. i.� s off ne: - 0 i/01 r v ( �`� '�k1- ♦ t�. r.1 err. •� 1 ,,fai lI '2,14 S •' J,.��14 ;.�711.*1.4, Iqw l i.► .f: it3 : . '1�1ytiA4�y '�I/4R�� I 1%4} :I/ \: `. -, �;� rte. � t�.,, ,'--�,� ,�. .,IL ,,�� _• �,.,, .�t�► � �\r®� ►, . ,,,y:;s.*41��.®�►1®\ 1�3=•..a,I.", E0�4,��L ����i�V�,.ialgr-4:to.izirC -120/240 11 k ..,.2+ A °�1 r®�® , '1I I40,.,ye..A ..t �`l�'�1j ��.. I 120 w.:),t4r . �Vic?. 1 �1I7��` SII f'/ t� at �'■t•et,' rai li ,-• ,1F',�f= .iil,[��/i ' Atito,.,Il. \! ''',t-,1:1 � .' �fls r \i �•.i Yrszt..w 4 . *.Ar ,t,le 10.;`:,r�:,., -:%��.{T,�,; ,,4 ``i, + este, ®►�',1�s got wop- .� _moi �� s>`44y�`.4uv.'t;a3��!l /#:r 1, _►�4 .r.<w:r►' yfl� ::/L 0 .ice -150/210 ���!ec� ;j�`ps�iir....! r�•...gr����t:.'�4".. 10 o_ 7.' w ,11M • /. . i'x =11'41,1401w•-.-7,1.1611P49 iagrAr• -1:0/180 ax Pl :2La14.2L M.P.. 44- x 701.x.30701 VO 'b' asxp.ao,.aa12,2.12VO "$ xa20,20320PB,aaxP50 v0 ♦ x 1,24 xo20V2 ♦ P 3201O.1n1.2L308Pe1. 2290 4 x aa142wu.2.19. -r- a 9 a $ n a02(Langley),a 300. a02r -� 24 01 VO � .0,142.315.x.010 V2 -d- x�1a0701.2Lm,2L 32200 $ x ,a3a-03300 ve "4 P 20211ero2D.2L-0mL 000 $ 24 L.306 Moor Vs $ x -X- x022114111.Pan:x222.,.2La22nrn12vo ♦ x 3306T1,x330521wp02 v2 $ xa14v91xnoe xa0120302P61,x302281 V6 $ X -0- x $ Pan 00-001.00.01.Flan 20 MO VV 01.2 30fi VO -} 20 .x316 2.10 VO $ .03,421,10.21,9V0Vfi } x Vo n aoeMarha).nen20 300261,a 308291004 V0 1,00281 v0 $ x x -I- .020 3M $ 101.4 x.213 20-310.,06 v0 010 $ 20 MI Pan 20 311axa11Mm01)v0 $ x32020020261 x 320081 VO '''..Sa ( r-N P.32i,x In x 327 Ve "94- Pen 21.920 Bang.21,242.20(,020/O ) r - , Northing (2500 ft/in) I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 I 1 1 I I I 1 1 i i i i 1 i i i 1 1 i 1 1 1111111111 1 1 1 1 'F'I I ! l 1 1 1 1 1 1 I I I , F I I — o _ a - - J _ 3 0 MO — N J d - _ M N - I J - CO N m Q 0 d - - M c? z O N _ coa M N O M N J M — J N Z N N O M O — CO v N a — O - J Q V. - N - - M J M MO M ( n a _ mo ... 3 _ - co Oi N ON J co - M MM N d CO - J O M -11 — - N C) N ' N J J V. M N - - N J - N - N- iI — cr,t a - El N J M m _ M d M (D - O J d N C _ N M N 3 M C — N N N — O - M` M O N ppl� N - M N - NC 1,111/11/ Iiii: N N C W - 3 3 r J O Q - =/ M Q = y C? r r N N - Yo - - = o (KS C:................„......„....„....................----_- _ Q N CO — Y MM - `Z p, iN - 411w N H In ��0 M - Z OCOC.4 U. N Aa _ 3O M Q V M 1 cv pi I1IF111FFF11111i1iiiiir [ 111111iIIIIIIIiiitF li iiiii111111111111111 IIII1F iti (Oil 5 )�I�;SNA L ConocoPhillips 2L-31 4P B 1 wp08 Schlumberger Alaska a $$m c 0 gn Cl Cl oc MJ - C! M N th J JJ JJ JJ J N N cv ''ms_ l ' ' , 1111.:= .4 I / i ' 4441 ' sill 10, _ iro4i iliAmik" A‘ L , gid, viA ci) q h.I®i��/is ., F 30 00 if ,1 Ii I /1 ------N , 1 � Ii/ �I / 2 --1 11M1111..‘ii 111I r 111111111ililhllII '��s1 I 0 I i i I I I I I IIII I I I I IIII I 1 I i 1 1 0 400 800 1200 1600 2000 2400 Displayed Interval could be less than entire range: Measured Depth 28.00 To 9842.57 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 9542.57 Results Limited By: Centre Distance: 1151.46 GLOBAL FILTER APPLIED:All welipaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1150.00 2L-314PB1wp08(Plan:2L-314PB1) GYD-GC-SS 1150.00 2619.11 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC 2619.11 8940.91 2L-314PB1 wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC 8940.91 9542.57 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2235.80 2619.11 10-3/4" x 13-1/2" 10-3/4 5219.90 8940.91 7-5/8" X 9-7/8" 7-5/8 LEGEND -0- Plan:2L-314(Tarawa),Plan:2L-314,2L-314wp08 VO -8- 2L-311,Plan 2L-311A,2L-311A(wp01)VO -I- 2L-326,2L-326,2L-326 VO - 2L-03,2L-03,2L-03 V2 -A- 2L-312(Cassidy),2L-312,2L-312 VO -X- 2L-327,2L-327,2L-327 V2 -9- 2L-301,2L-301,2L-301 VO -A- 2L-313,2L-313,2L-313 V2 _0- 2L-329,2L-329,2L-329 V2 -e- 2L-304,2L-304,2L-304 VO -X- 2L-315,2L-315,2L-315 V2 -e- 2L-329,2L-329A,2L-329A V2 2L-305,2L-305,2L-305 V2 -B- 2L-317,2L-317,2L-317 V2 -e- 2L-330,2L-330,2L-330 VB -X- 2L-306(Stella),2L-306,2L-306 VO -e- 2L-317,2L-317A,2L-317A V6 -0- 2L-330,Prelim:2L-330ST1,2L-330ST1wp02 V2 - 2L-306(Stella),2L-306PB1,2L-306PB1 VO -9-- 2L-319,2L-319,2L-319 V4 --9- Plan:2L-308(Bertha),Plan:2L-308,2L-308wp04 VO -0- 2L-307,2L-307,2L-307 V2 --I-- 2L-320,2L-320,2L-320 VO - Plan:2L-308(Bertha),Plan:2L-308PB1,2L-308PB1 wp04 VO --X- 2L-307,2L-307L1,2L-307L1 VO -s-- 2L-320,2L-320PB1,2L-320PB1 VO -e- Plan:2L-318(Libra),2L-318,2L-318wp05 VO - 2L-307,2L-307L2,2L-307L2 VO -9- 2L-320,2L-320PB2,2L-32UPB2 VO - Plan:2L-328(Sierra),2L-328,2L-328(wp03)VO 2L-307,2L-307L2-01,2L-307L2-01 VO 2L-321,2L-321,2L-321 V2 -e- Plan:2L-328(Sierra),2L-328PB1,2L-32PB1(wp03)VO -e- 2L-309,2L-309,2L-309 V5 -A- 2L-322(North),2L-322,2L-322 VO -9- Prelim:2L-302(Langley),2L-302,2L-302(wp01)VO -X- 2L-309,2L-309PB1,2L-309PB1 V6 -)-- 2L-322(North),Plan:2L-322A,2L-322Awp12 VO -I- Prelim:2L-302(Langley),2L-302L1,2L-302L1(wp01)VO - 2L-310,2L-310,2L-310 VO -A- 2L-323,2L-323,2L-323 V2 $ 2L-314PB1wp08 - 2L-311,2L-311,2L-311 VO - 2L-325,2L-325,2L-325 V2 tS o l. ._..,. Schlumberger Anticollision Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314PB1 Database: EDM Alaska Prod v16 Reference Design: 2L-314PB1wp08 Offset TVD Reference: Offset Datum Reference 2L-314PB1wp08 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 100.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,151.46ft Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma Survey Tool Program Date 10/29/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 28.00 1,150.00 2L-314PBlwp08(Plan:2L-314PB1) GYD-GC-SS Gyrodata gyro single shots 1,150.00 2,619.11 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,619.11 8,940.91 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,940.91 9,542.57 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 4:28:34PM Page 2 of 49 COMPASS 2003.16 Build 69 Schlumberger Anticollision Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan:114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan:114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314PB1 Database: EDM Alaska Prod v16 Reference Design: 2L-314PB1wp08 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2L Pad 2L-03-2L-03-2L-03 2,812.38 2,600.00 150.54 103.62 3.208 CC 2L-03-2L-03-2L-03 4,005.96 3,800.00 202.60 89.95 1.799 No Errors,ES,SF 2L-301 -2L-301 -2L-301 299.83 300.00 193.43 187.28 31.488 CC 2L-301 -2L-301 -2L-301 500.68 500.00 194.30 184.18 19.199 ES,SF 2L-304-2L-304-2L-304 28.00 27.28 149.97 148.96 148.352 CC 2L-304-2L-304-2L-304 200.72 200.00 150.04 146.36 40.717 ES,SF 2L-305-2L-305-2L-305 142.90 146.10 134.79 132.47 57.994 CC 2L-305-2L-305-2L-305 1,120.61 1,100.00 138.99 119.87 7.271 ES,SF 2L-306(Stella)-2L-306-2L-306 187.75 200.00 119.07 115.50 33.374 CC 2L-306(Stella)-2L-306-2L-306 287.74 300.00 119.53 114.31 22.890 ES,SF 2L-306(Stella)-2L-306PB1 -2L-306PB1 187.75 200.00 119.07 115.50 33.374 CC 2L-306(Stella)-2L-306PB1 -2L-306PB1 287.74 300.00 119.53 114.31 22.890 ES,SF 2L-307-2L-307-2L-307 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307-2L-307 290.84 300.00 106.27 101.42 21.940 ES,SF 2L-307-2L-307L1 -2L-307L1 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307L1 -2L-307L1 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-307-2L-307L2-2L-307L2 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307L2-2L-307L2 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-307-2L-307L2-01 -2L-307L2-01 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307L2-01 -2L-307L2-01 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-309-2L-309-2L-309 28.00 33.98 74.77 73.81 77.557 CC 2L-309-2L-309-2L-309 293.58 300.00 77.05 71.25 13.285 ES,SF 2L-309-2L-309PB1-2L-309PB1 28.00 33.98 74.77 73.76 73.961 CC 2L-309-2L-309PB1-2L-309PB1 293.58 300.00 77.05 71.20 13.178 ES,SF 2L-310-2L-310-2L-310 201.00 200.00 59.34 55.62 15.933 CC 2L-310-2L-310-2L-310 300.98 300.00 60.81 55.48 11.405 ES,SF 2L-311 -2L-311 -2L-311 199.60 200.00 44.67 41.23 13.003 CC 2L-311 -2L-311 -2L-311 299.59 300.00 45.91 40.84 9.050 ES,SF 2L-311 -Plan 2L-311A-2L-311A(wp01) 199.60 200.00 44.67 41.23 13.003 CC 2L-311 -Plan 2L-311A-2L-311A(wp01) 299.59 300.00 45.91 40.84 9.050 ES,SF 2L-312(Cassidy)-2L-312-2L-312 28.10 40.10 30.27 29.26 29.912 CC 2L-312(Cassidy)-2L-312-2L-312 488.34 500.00 31.79 22.28 3.342 ES,SF 2L-313-2L-313-2L-313 496.96 500.00 14.77 6.72 1.834 No Errors,CC 2L-313-2L-313-2L-313 596.83 600.00 15.15 5.45 1.563 No Errors,ES,SF 2L-315-2L-315-2L-315 142.90 146.10 15.21 12.88 6.543 CC 2L-315-2L-315-2L-315 496.48 500.00 19.90 11.78 2.450 No Errors,ES,SF 2L-317-2L-317-2L-317 488.39 500.00 35.49 27.08 4.221 CC,ES,SF 2L-317-2L-317A-2L-317A 488.39 500.00 35.49 27.08 4.221 CC,ES,SF 2L-319-2L-319-2L-319 984.71 1,000.00 38.26 20.21 2.120 No Errors,CC,ES,SF 2L-320-2L-320-2L-320 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320-2L-320 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-320-2L-320PB1 -2L-320PB1 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320PB1 -2L-320PB1 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-320-2L-320PB2-2L-320PB2 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320PB2-2L-320PB2 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-321 -2L-321 -2L-321 396.36 400.00 103.89 97.46 16.145 CC 2L-321 -2L-321 -2L-321 593.91 600.00 106.10 96.39 10.926 ES,SF 2L-322(North)-2L-322-2L-322 288.09 300.00 119.46 113.66 20.613 CC 2L-322(North)-2L-322-2L-322 486.02 500.00 121.16 111.46 12.496 ES,SF 2L-322(North)-Plan:2L-322A-2L-322Awp12 300.08 300.00 119.43 113.40 19.804 CC 2L-322(North)-Plan:2L-322A-2L-322Awp12 497.80 500.00 121.45 111.52 12.232 ES,SF 2L-323-2L-323-2L-323 396.27 400.00 134.55 127.95 20.383 CC 2L-323-2L-323-2L-323 495.03 500.00 135.27 127.04 16.439 ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 4:28:34PM Page 3 of 49 COMPASS 2003.16 Build 69 OIGINAL Schlumberger Anticollision Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan:114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan:114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314PB1 Database: EDM Alaska Prod v16 Reference Design: 2L-314PB1wp08 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2L Pad 2L-325-2L-325-2L-325 142.90 146.20 165.11 162.66 67.270 CC 2L-325-2L-325-2L-325 196.70 200.00 165.45 162.17 50.517 ES,SF 2L-326-2L-326-2L-326 28.00 34.30 180.16 179.14 178.208 CC 2L-326-2L-326-2L-326 392.26 400.00 182.26 174.42 23.224 ES,SF 2L-327-2L-327-2L-327 395.05 400.00 193.76 185.88 24.566 CC 2L-327-2L-327-2L-327 591.07 600.00 195.29 183.53 16.615 ES,SF 2L-329-2L-329-2L-329 395.92 400.00 223.38 216.75 33.736 CC, ES,SF 2L-329-2L-329A-2L-329A 395.92 400.00 223.38 216.75 33.736 CC, ES,SF 2L-330-2L-330-2L-330 492.84 500.00 237.49 228.35 26.007 CC 2L-330-2L-330-2L-330 588.97 600.00 238.27 227.70 22.555 ES,SF 2L-330-Prelim:2L-330ST1 -2L-330ST1wp02 493.47 500.00 237.48 228.39 26.114 CC 2L-330-Prelim:2L-330ST1 -2L-330ST1wp02 589.59 600.00 238.28 227.75 22.636 ES,SF Plan:2L-308(Bertha)-Plan:2L-308-2L-308wp04 1,730.67 1,700.00 65.01 38.56 2.458 No Errors,CC,ES,SF Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1wp 1,730.67 1,700.00 65.01 38.56 2.458 No Errors,CC,ES,SF Plan:2L-314(Tarawa)-Plan:2L-314-2L-314wp08 8,999.99 9,000.00 0.44 -0.52 0.455 No Errors,CC,ES,SF Plan:2L-318(Libra)-2L-318-2L-318wp05 597.79 600.00 53.97 43.61 5.208 CC Plan:2L-318(Libra)-2L-318-2L-318wp05 695.10 700.00 54.22 42.16 4.496 ES,SF Plan:2L-328(Sierra)-2L-328-2L-328(wp03) 579.07 600.00 207.92 196.34 17.952 CC Plan:2L-328(Sierra)-2L-328-2L-328(wp03) 672.42 700.00 209.74 196.21 15.508 ES,SF Plan:2L-328(Sierra)-2L-328PB1 -2L-32PB1 (wp03) 581.27 600.00 207.93 196.30 17.884 CC Plan:2L-328(Sierra)-2L-328PB1 -2L-32PB1 (wp03) 674.45 700.00 209.83 196.26 15.464 ES,SF Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 285.80 300.00 179.84 174.64 34.580 CC Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 386.31 400.00 181.36 174.53 26.550 ES,SF Prelim:2L-302(Langley)-2L-302L1 -2L-302L1 (wp01) 285.80 300.00 179.84 174.64 34.580 CC Prelim:2L-302(Langley)-2L-302L1 -2L-302L1 (wp01) 386.31 400.00 181.36 174.53 26.550 ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 4:28:34PM Page 4 of 49 COMPASS 2003.16 Build 69 Schlumberger Anticollision Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan:114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314PB1 Database: EDM Alaska Prod v16 Reference Design: 2L-314PB1wp08 Offset TVD Reference: Offset Datum Reference Depths are relative to Plan: 114.9+28 @ 142.90ft(Nabors 9 Coordinates are relative to:Plan:2L-314(Tarawa) Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1983,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.30° Ladder Plot I I I I 1 1200 I I I I I I 1 111 I I I I I 1 , • i 1 I I 1 1 'i I ' 1 :.I I I I l !' I I I 1 1 I 114. I 1 C 900 I I ,b I 1 I I I 0 1 I I I I I i,r! •I ,�f. - a1 • 0 II !I Ilrr �1 IIIIIIIIIII 'IIIIIIIIII1 i. mai▪ 600 + ff ' U I + ' 0 1 II ; ;i (S J IIIIIIIIIIIIII J1IIIIIIIIIIIII 2 _ _ C I j • S 0.3▪,U i til 1 300 1it/ Op .:.. I I I I w r 1 J J J J / I I I I �W I I I I 'w 1 I 0 .. I I I 0 2000 4000 L E G44PD 8000 10000 12000 M easured Depth 14 alawa),Plan:2L-314,2L-314wp08V0 -F 2L-311,PIan2L-311A,2L-311A(wp01)V0 -e- 2L-326,2L-326,2L326V0 )32L-03 V2 � 2L-312(Cassidy),2L-312,2L-31210 -8- 2L-327,2L-327,2L327V2 -3 1,2L-301 VO -9- 2L-313,2L-313,2L-313V2 �- 2L-329.2L-329,2L329V2 -3 4,2L-304V0 $• 2L-315,2L-315,2L-315 V1 -A- 2L329.2L-329A,2L-329AV2 -3 5,2 L-305 V2 -3 - 2 L-317,2L-317,2L-317 V3 �- 2L-330.2 L-330.2L330 V8 :ell ),2L-306,2L-306W -� 2 L-317,2 L-317A,2 L-317AV6 —3— 2L-330,Prefm:2L-330ST1,2L-330ST1wp)i ell ),2L-306P81,2L-306PB1 VO -X- 2L-319,2L-319,2L-3191A1 44- Pbn:2L-308(Berha),PIan:2L-308,2L-308u -3 7,2L-307 V2 2L-320,2L-320,2L-320 NA -0- PIan:2L-308(Bertha),Plan:2L-308PB1,2--3 -3 7L1,2 L-307 L1 VO -A- 2L-320,2L320P81,2L-320PB1 VO � Pbn:2L-318(Libra),2L-318.2L-318wp05 VI -3 7L2,2L-307 L2 VO -34- 2L-320.2L320PB2,2L-320PB2V0 -9- Plan:2L-328(Sierra),2L-328,2L-328(wp)3 -3 7L2-01,2L-307L2-01 VO -a- 2L-321,2L-321,2L-321 V2 �- Plan:2L-328(Siena),2L-328PB1.2L-32P8 -3 ,.t-sirs-vb -0- 2L-322(North),2L-322,2L-322bO Prellm:2L-302' Q leLan y),L L-3U L,LL-3 UL Ul CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/2912013 4:28:32PM Page 49 of 49 COMPASS 2003.16 Build 69 0 co es, IX 44 p V as E 03 ttS II i i N N N C v 0 a a cas o C� a_ a_ a a U I J b\ . . . . . . . . _ . . _ . . . . . . / c0R CO \ d ( i/ CO N e // ■ •+ § ; I / \ fri• 2 (N ) ] —▪ f ) \ Cl) co � § - i /i § Ct ] \k « ocsi \ e \ - \e ) \ E "I( \ / } § � /} j CO 0 { 0 } � - � f ){ \ ) R NINIIIP o { 2 c22 0 U § § eC Fees ] )) ) k ■ / k 6 > Rj § °• e -0 o .- 0� 7 k ) \ j 0� t G J % § C 0) 0 \ E . � � ) coo = _ _ o § ` ) T . k } X• w s w o E - o _ . - o _ w to o . _ » \ / § } jk / \ \ ° \� 6 - / . \ \ B CD °CM Ka 2k � � \ :g j 3 § $ ` 1 CI s / 0 0- 0 C 0_ > + , 2 . o a c 'Es Laa �k { 3FW CC) . c > O CO o = F 2 tO z � m } wk 2C 0 § 2 r « i , / I / § / \\ ^ § . + o v . °z k © oo (N Ci k /§ -o I . \ V = V _ - § z coC = 1 Isr 8 s n C / / 7 L /0 -J e ; I ) o 0 0 C , � o co \ 0Z0 . z 0 m Cl- G 0 ¥§ _, � v- co 2 .a Co « _ ; E Q a03 § 11 11 ca 75«02 co $ # 2 o m k .. .. / co 2 ] z i �z < & + + ƒ } ƒ/) ) \ C 7 .. § 0 0 % § c / » § k ƒ k \ \ } q o .. n /« � k ) ±oma 0- - ) a. £ C. $ f $ ) ® � � % = \ • ( S ( a a § � 2 § § o ■ • t % 30- 38 / o Q 202 Cl) 0LLa a k a / E 0 < >CD > § O R | G | A L 0 _o ^� N N WI II WWIx N To I MM W ,- 0 O 'N.. 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Datum: INAD27 J Region: (alaska J Datum: INAD27 A Region: alaska C Latitude/Longitude 'Decimal Degrees J C Latitude/Longitude 'Decimal Degrees _.:J C UTM Zone: I f- South C UTM Zone: True r South ( State Plane Zone:[4 j Units: Ius-ft .E C State Plane Zone:ITrue A Units: I-us-ft j C Legal Description(NAD27 e,r,,, a Legal Description(NAD27 only) -Starting Coordinates: Legal Description — X: 1460946.60 Township: 010 IN A Range: 1007 IE .i Y: 15927664.75 Meridian: lu J Section:122 (FNL181.03392 1FEL .I704.29873 Transform Quit l Help I v 2L-314wp08 Intermediate Casing I 1 3. CPA'Coordinate Converter - J 3' 1S From: — -To: Datum: INAD27 • Region: (alaska .' Datum: 1NAD27 A Region: alaska .1 I C LatitudelLongitude Decimal Degrees C Latitude/Longitude 1Decimal Degrees A (- UTM Zone:I j South C UTM Zone:IT rue I- South t: State Plane Zone:14 , Units: Ius-ft _I C State Plane Zone: ITrue_J Units: Ius ft C Legal Description INAD27 orb,; ( Legal Description(NAD27 only) Starting Coordxwtes:— Legal Description X: 1465705.83 Township: lull) 11 71 Range: X007 rE .' Y: 15930767.17 Meridian: IU J section.114 IFNL .) 2335.2002 'FEL . 11236.0485 Transform Quit 1 Help ORIGI \ AL 2L-314wp08 TD rf CPA'Coordinate Converter l h£3 From: -To: — Datum: (NAD27 . Region: 'alaska A Datum: NAD27 Region: lalaska J r Latitude/Longitude 'Decimal Degrees A C Latitude/Longitude 'Decimal Degrees J C' UTM Zone:I E South C' UTM Zone:ITrue E South ri' State Plane Zone:jq Units: jus-ft . C' State Plane Zone:IT rue J Units: Ius-ft .� C' Legal Description(NAD27 enlvl r Legal Description(NAD27 only) Starting Coordinates: — Legal Description X: 1466701.87 Township: 1010 I'ri Range: irs007 IE A Y: 15928332.11 Meridian: IU _I Section:114 fNL J 14766.0115 1FEL A 230.95469 Transform Quk ( Help I L O1GINiL ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-314 (Tarawa) Plan: 2L-314 2L-314wp08 Anticollision Summary Report 29 October, 2013 Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314 Database: EDM Alaska Prod v16 Reference Design: 2L-314wp08 Offset TVD Reference: Offset Datum Reference 2L-314wp08 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 100.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,357.40ft Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma Survey Tool Program Date 10/29/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 28.00 1,150.00 2L-314PB1wp08(Plan:2L-314PB1) GYD-GC-SS Gyrodata gyro single shots 1,150.00 2,619.11 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,619.11 8,940.91 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,940.91 8,970.91 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,970.91 11,602.00 2L-314wp08(Plan:2L-314) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 5:30:50PM Page 2 COMPASS 2003.16 Build 69 r` 1 Schlurnberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.005 Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314 Database: EDM Alaska Prod v16 Reference Design: 2L-314wp08 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning Kuparuk 2L Pad 2L-03-2L-03-2L-03 2,812.38 2,600.00 150.54 103.62 3.208 CC 2L-03-2L-03-2L-03 4,005.96 3,800.00 202.60 89.95 1.799 No Errors,ES,SF 2L-301 -2L-301 -2L-301 299.83 300.00 193.43 187.28 31.488 CC 2L-301 -2L-301 -2L-301 500.68 500.00 194.30 184.18 19.199 ES,SF 2L-304-2L-304-2L-304 28.00 27.28 149.97 148.96 148.352 CC 2L-304-2L-304-2L-304 200.72 200.00 150.04 146.36 40.717 ES,SF 2L-305-2L-305-2L-305 142.90 146.10 134.79 132.47 57.994 CC 2L-305-2L-305-2L-305 1,120.61 1,100.00 138.99 119.87 7.271 ES,SF 2L-306(Stella)-2L-306-2L-306 187.75 200.00 119.07 115.50 33.374 CC 2L-306(Stella)-2L-306-2L-306 287.74 300.00 119.53 114.31 22.890 ES,SF 2L-306(Stella)-2L-306PB1 -2L-306PB1 187.75 200.00 119.07 115.50 33.374 CC 2L-306(Stella)-2L-306PB1 -2L-306PB1 287.74 300.00 119.53 114.31 22.890 ES,SF 2L-307-2L-307-2L-307 142.90 152.05 105.03 102.57 42.791CC 2L-307-2L-307-2L-307 290.84 300.00 106.27 101.42 21.940 ES,SF 2L-307-2L-307L1 -2L-307L1 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307L1 -2L-307L1 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-307-2L-307L2-2L-307L2 142.90 152.05 105.03 102.57 42.791CC 2L-307-2L-307L2-2L-307L2 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-307-2L-307L2-01 -2L-307L2-01 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307L2-01 -2L-307L2-01 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-309-2L-309-2L-309 28.00 33.98 74.77 73.81 77.557 CC 2L-309-2L-309-2L-309 293.58 300.00 77.05 71.25 13.285 ES,SF 2L-309-2L-309PB1-2L-309PB1 28.00 33.98 74.77 73.76 73.961 CC 2L-309-2L-309PB1-2L-309PB1 293.58 300.00 77.05 71.20 13.178 ES,SF 2L-310-2L-310-2L-310 201.00 200.00 59.34 55.62 15.933 CC 2L-310-2L-310-2L-310 300.98 300.00 60.81 55.48 11.405 ES,SF 2L-311 -2L-311 -2L-311 199.60 200.00 44.67 41.23 13.003 CC 2L-311 -2L-311 -2L-311 299.59 300.00 45.91 40.84 9.050 ES,SF 2L-311 -Plan 2L-311A-2L-311A(wp01) 199.60 200.00 44.67 41.23 13.003 CC 2L-311 -Plan 2L-311A-2L-311A(wp01) 299.59 300.00 45.91 40.84 9.050 ES,SF 2L-312(Cassidy)-2L-312-2L-312 28.10 40.10 30.27 29.26 29.912 CC 2L-312(Cassidy)-2L-312-2L-312 488.34 500.00 31.79 22.28 3.342 ES,SF 2L-313-2L-313-2L-313 496.96 500.00 14.77 6.72 1.834 No Errors,CC 2L-313-2L-313-2L-313 596.83 600.00 15.15 5.45 1.563 No Errors,ES,SF 2L-315-2L-315-2L-315 142.90 146.10 15.21 12.88 6.543 CC 2L-315-2L-315-2L-315 496.48 500.00 19.90 11.78 2.450 No Errors,ES,SF 2L-317-2L-317-2L-317 488.39 500.00 35.49 27.08 4.221CC,ES,SF 2L-317-2L-317A-2L-317A 488.39 500.00 35.49 27.08 4.221CC,ES,SF 2L-319-2L-319-2L-319 984.71 1,000.00 38.26 20.21 2.120 No Errors,CC,ES,SF 2L-320-2L-320-2L-320 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320-2L-320 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-320-2L-320PB1 -2L-320PB1 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320PB1 -2L-320PB1 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-320-2L-320PB2-2L-320PB2 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320PB2-2L-320PB2 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-321 -2L-321-2L-321 396.36 400.00 103.89 97.46 16.145 CC 2L-321 -2L-321-2L-321 593.91 600.00 106.10 96.39 10.926 ES,SF 2L-322(North)-2L-322-2L-322 288.09 300.00 119.46 113.66 20.613 CC 2L-322(North)-2L-322-2L-322 486.02 500.00 121.16 111.46 12.496 ES,SF 2L-322(North)-Plan:2L-322A-2L-322Awp12 300.08 300.00 119.43 113.40 19.804 CC 2L-322(North)-Plan:2L-322A-2L-322Awp12 497.80 500.00 121.45 111.52 12.232 ES,SF 2L-323-2L-323-2L-323 396.27 400.00 134.55 127.95 20.383 CC 2L-323-2L-323-2L-323 495.03 500.00 135.27 127.04 16.439 ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 5:30:50PM Page 27 COMPASS 2003.16 Build 69 OIGINAI Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314 Database: EDM Alaska Prod v16 Reference Design: 2L-314wp08 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning Kuparuk 2L Pad 2L-325-2L-325-2L-325 142.90 146.20 165.11 162.66 67.270 CC 2L-325-2L-325-2L-325 196.70 200.00 165.45 162.17 50.517 ES,SF 2L-326-2L-326-2L-326 28.00 34.30 180.16 179.14 178.208 CC 2L-326-2L-326-2L-326 392.26 400.00 182.26 174.42 23.224 ES,SF 2L-327-2L-327-2L-327 395.05 400.00 193.76 185.88 24.566 CC 2L-327-2L-327-2L-327 591.07 600.00 195.29 183.53 16.615 ES,SF 2L-329-2L-329-2L-329 395.92 400.00 223.38 216.75 33.736 CC, ES,SF 2L-329-2L-329A-2L-329A 395.92 400.00 223.38 216.75 33.736 CC, ES,SF 2L-330-2L-330-2L-330 492.84 500.00 237.49 228.35 26.007 CC 2L-330-2L-330-2L-330 588.97 600.00 238.27 227.70 22.555 ES,SF 2L-330-Prelim:2L-330ST1 -2L-330ST1wp02 493.47 500.00 237.48 228.39 26.114 CC 2L-330-Prelim:2L-330ST1 -2L-330ST1wp02 589.59 600.00 238.28 227.75 22.636 ES,SF Plan:2L-308(Bertha)-Plan:2L-308-2L-308wp04 1,730.67 1,700.00 65.01 38.56 2.458 No Errors,CC,ES,SF Plan:2L-308(Bertha)-Plan:2L-308PB1 -2L-308PB1wp 1,730.67 1,700.00 65.01 38.56 2.458 No Errors,CC,ES,SF Plan:2L-314(Tarawa)-Plan:2L-314PB1-2L-314PB1w 8,999.99 9,000.00 0.44 -0.52 0.458 No Errors,CC,ES,SF Plan:2L-318(Libra)-2L-318-2L-318wp05 597.79 600.00 53.97 43.61 5.208 CC Plan:2L-318(Libra)-2L-318-2L-318wp05 695.10 700.00 54.22 42.16 4.496 ES,SF Plan:2L-328(Sierra)-2L-328-2L-328(wp03) 579.07 600.00 207.92 196.34 17.952 CC Plan:2L-328(Sierra)-2L-328-2L-328(wp03) 672.42 700.00 209.74 196.21 15.508 ES,SF Plan:2L-328(Sierra)-2L-328PB1 -2L-32PB1 (wp03) 581.27 600.00 207.93 196.30 17.884 CC Plan:2L-328(Sierra)-2L-328PB1 -2L-32PB1 (wp03) 674.45 700.00 209.83 196.26 15.464 ES,SF Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 285.80 300.00 179.84 174.64 34.580 CC Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 386.31 400.00 181.36 174.53 26.550 ES,SF Prelim:2L-302(Langley)-2L-302L1 -2L-302L1 (wp01) 285.80 300.00 179.84 174.64 34.580 CC Prelim:2L-302(Langley)-2L-302L1 -2L-302L1 (wp01) 386.31 400.00 181.36 174.53 26.550 ES,SF Nanuk Nanuk 1 -Nanuk 1 -Nanuk 1 Out of range Nanuk 2-Nanuk 2-Nanuk 2 Out of range Plan:CD5 Alpine West Pad(southwest) Plan:CD5-01-Plan:CD5-01-CD5-01wp07 Out of range Plan:CD5-02-Plan:CD5-02-CD5-02wp07 Out of range Plan:CD5-03-Plan CD5-03-CD5-03wp07 Out of range Plan:CD5-04-Plan:CD5-04-CD5-04wp07 Out of range Plan:CD5-05-Plan CD5-05-CD5-05wp07 Out of range Plan:CD5-06-Plan:CD5-06-CD5-06wp07 Out of range Plan:CD5-07-Plan:CD5-07-CD5-07wp07 Out of range Plan:CD5-08-Plan:CD5-08-CD5-08wp07 Out of range Plan:CD5-09-Plan:CD5-09-CD5-09wp07 Out of range Plan:CD5-10-Plan:CD5-10-CD5-1 Owp07 Out of range Plan:CD5-11 -Plan:CD5-11 -CD5-11wp07 Out of range Plan:CD5-12-Plan:CD5-12-CD5-12wp07 Out of range Plan:CD5-13-Plan:CD5-13-CD5-13wp07 Out of range Plan:CD5-314-Plan:CD5-314-CD5-314wp08 Out of range Plan:CD5-315-Plan:CD5-315-CD5-315wp07 Out of range Prelim:AW-10A-Prelim:AW-10A-AW-10Awp06 Out of range Prelim:AW-10B-Prelim:AW-10B-AW-10Bwp06 Out of range Prelim:AW-9A-Prelim:AW-9A-AW-9Awp06 Out of range Prelim:AW-9B-Prelim:AW-9B-AW-9Bwp06 Out of range Prelim:AW-9C-Prelim:AW-9C-AW-9Cwp06 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1029/2013 5:30:50PM 0 COMPASS 2003.16 Build 69 Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314 Database: EDM Alaska Prod v16 Reference Design: 2L-314wp08 Offset TVD Reference: Offset Datum Reference Depths are relative to Plan:114.9+28 @ 142.90ft(Nabors 9 Coordinates are relative to:Plan:2L-314(Tarawa) Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1983,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.30° Ladder Plot I 1 I I I I 1400 1 I I I I I 1 R I I I I I i j�,, I 1 1 1 HT. 0 IS I / I I I I 1050 SSSr 0 c 1 .1 ;' I I 1 I I g I I 7 11 1 ru I I I 1 Ir,� r QCO _JI_ _ 1 ,�, _JI __ _ J _I J J __ d I I { I I I I a) 1 /+ .. I I I I � I 1 1 I I I i I I I I I a) 700 I�' I ' I � I I IF/ I I U 1 it i I 1 I I o I IJ An I I I I Iv _--_J i`'+ J J J c I rr I I I I Iv I �:f e•• I I I I I U I r rr I I I I I 350 I /J. 1 rJ I r . I 1 I 1 I % I .- I I I /S�lit 1 I I I I .., �•,�f�l . I y - 1 I --- I - - J_ J J _J J /y I I LI I II illf 1I I 0 0 2000 4000 L E GWEgP D 8000 10000 12000 M easured Depth 02(Lang leya.2L-302.2L-302(wp01)V0 -9- 2L-311.2L-311,2L-311%A -A- 2L-325.2L-325,2L-325 V2 02(Langle ),2L-302L1,2L-302 L1(wp01)VO 2L-311,PIan2L-311A,2L-311A(wp01)VO 2L-326.2L-326,2L-326V0 3.:L-03 V2 -X- 2 L-312(Cassidy),2 L-312.2 L-312 VO _ — 2L-327.2L-327.2L-327 V2 30',2L-301 VO -X- 2 L-313,2L313.2 L-313 V2 -9- 2L-329.2L-329,2L-329 V2 30,.2L-304Ve -e-- 2L-316.2L315.2L-315 V2 - - 2L-329,2L-320A,2L-320AV2 304,2L-305 V2 2 L-317.2L317.2 L-317 V2 -8- 2L-330,2L-330.2L-330 V8 I142L-306,2L-306 VO -8- 2L-317.2L-317A2L-317A'6 -9- 2L-330,Prelim:2L-330ST1,2L-330ST1wF0: Ia;,2L-306PB1,2L-306P131VD —4-2L-319.2L310,2L-319 V4 -e- Plan:2L-314(falawa),PIan:2L-314PB1. L 10-,2L-307 V2 -Ar- 2L-320,2L320,2L-320 V0 -8- Plan:2L-318(Lbra),2L-318.2L-318wp05V :07 L1,2L-307L144 -8- 2L-320.2L-320P81,2L-320P81 VD -e- Plan:2L-328(Sierra),2L-328,2L-328(wp0: :07 L2,2L-307L2 40 T 2L-320.2L-320P82,2L-320P82V0 -9- Plan:2L-328(Sierra),2L-328PB1.2L-32FB 307 LLIJ I.LL-sur LL-uI vu X- LL-32 1,2L-sz1.LL-SL I VL f-19an.LL-.5u I,tlerna),r um.2 L-SUR.2 L-SL 81 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 5:30:50PM (...‘ Page 29 COMPASS 2003.16 Build 69 Mull\ AL Northing (2500 ft/in) i I l l t I I l I f I I l I I I I 1111111111 ! , I I I I i , i , I i i i i i j i I i i �.I 11 1 , I I I I I , 1 1 1 1 1 1 1 0 a 3 a J — M o N J d M N N - _ a CO N m — 3 a OM d ii rn CO M _IIN O _II Q O N M CC J M D — cpn n 3 m co J .. d _ O N , O M CO O NM N m M M co. d J J O M N - N Ch N N 11 J CO N� -/' N N ii O • M�' O a //, M a C73 • iij 'T N O M _ d J M m _ co V / M CO d C c? N 3 M C N Z N N M O p _ N O _ M cin N I M N N (11 M CD C— N Z C • = N w w 3 W. oQ JM M- 3NN N N C7 C // N ^ JM CL , N / Z _ M N - co _YM i Z — N co __ co M M Z - N _ ffl — N CO J - N CO - co N - Q ry ti - M co O N id. I It I I 1 1 1 1 1 1 1 1 i 1 1 I I1 1 1 1 1 1 1 1 1I i 1i 1 1 I 1 1 i 1 1 1 1 1 i I II 1 l i1 1 i 1 1 1 1 1 1 1 ifi i 1 761 2L-314w 08 344 Plan Summary SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1150.00 2L-314PB1wp08 (Plan:2L-314PB1) GYD-GC-SS 1150.00 2619.11 2L-314PB1 wp08(Plan:2L-314P®'VyD+IFR-AK-CAZ-SC 2619.11 8940.91 2L-314PB1wp08(Plan:2L-314PEIV)'D+IFR-AK-CAZ-SC i41i \ 8940.91 8970.91 2L-314PB1wp08(Plan:2L-314P®WyD+IFR-AK-CAZ-SC 8970.91 11602.00 2L-314wp08(Plan:2L-314) MWD+IFR-AK-CAZ-SC CASING DETAILS v/A11 5812 "(AlLila O 7-5/8"X 9-7/8" o° 10-3/4"x 13-1/2" '-5 Top Bermuda -5 /'''-' '00 `m 1 S `� o-00 ti o0 7-5/8"X 9-7/8" cO LoN m e;o 00 0 / 4-1/2"x 6-1/2" agi - 10-3/4"x 13-1/2" - oo _ 00 O OI N To, '_000 /0 ° O ° O 1 O o i - I / I I 1 I 1 1 1 L. I I I I 1 0 t� ---� 11111 - 0 3000 6000 9000 12000 0 1500 3000 4500 6000 7500 9000 Measured Depth Horizontal Departure 0 0 8070 C - 330 .a+wenwo:. 30 8070 - 0088 o .00 - as60 Ss - o. _ 300 :0,.,;.,.... 60 - m „.., - m 2L-C 14PB1 wp08 • 8878 - 0888 kU 30 270 '_ nsst 90 - .. _ • MM - lase m m 240 120 U - Ione .498 - 0 IIIIIII 1 1 1 1 1 1 1 1 1 1 1 I I I I 210 150 0 1500 3000 4500 6000 7500 9000 180 SECTION DETAILS ',... - nfi0, Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Fasting DLeg TFace Vsec Target 1 8970.91 74.00 146.00 5228.17 5085.27 3103.40 4759.71 5930492.16 1605755.73 0.00 0.00-1384.71 2 9031.25 74.10 143.33 5244.76 5101.86 3056.07 4793.26 5930444.66 1605789.03 4.25 -88.23 -1329.04 3 9178.38 74.10 143.33 5285.08 5142.18 2942.57 4877.76 5930330.73 1605872.92 0.00 0.00-1194.21 4 9702.00 88.54 160.51 5364.49 5221.59 2488.15 5118.46 5929875.11 1606111.23 4.25 51.21 -686.19 5 11602.00 88.54 160.51 5412.90 5270.00 697.60 5752.18 5928081.45 1606735.52 0.00 0.00 1213.13 2L-314(wp06)Toe Top Bermuda Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM 2013 TM Depth Reference: Plan:114.9+28 @ 142.90ft(Nabors 9ES) Magnetic Model Date: 21-Oct-13 System(SS) Reference: Mean Sea Level Magnetic Declination: a True Td North /Y: 5927413.97 To convert a Magnetic Direction to a True Direction,Add 19.54°East Ground Level/Mud Line: 114.90 East/X: 1600980.34 Rig: Nabors 9ES t GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference N a. I C) (13 Q c Es a jai- 3 ON M M V♦ CNIi pimC i N N N O 0a 0 R3 o V a. a_ a 0 °' N 0) .23 z Z 3 N r = m co co 0m 0 0 ifi - 0 coo 0)w w N. � M ,ri v c'o W O O N °) — co V) V) N r N O O O o C:, 10 co a) a) ZZ g O O O O NC) C) O r, • U H co ai 0 N V V© O -0 Oo _ O N JN N oo co Z a >w a) U N W 0) 0co J a N .. C V 7 N CD T.) 0 j a O ;Q a) (n> y •• a J — C C a) 1 C 0) 0) 0 a) 3 a a a H ww 2 0 0 a) ..,Ty C O d > J J 0 d 4> 7 O o t - C . N N O C a) 2 J J to � C O C a) e F U t6 •C V N C E 'a O C co 11 R 0 o 2. 12 0 �a1 U d LL O C — a � m a E w = 1 0) 0 o la a- 'Ct., a7 N CO (�O O co- a v — o0 1`_ r co 0 W N O cj 0 0 L C) CO 00 00 dL6 V m 0 LA N O CD 0 -0 E is r E on p a 7 0 N 0 = 00 0 > o C1 d ib ri ' --- 0 Cl) 7 a) d N C 01(0 'WO 0) N t C C a 15 C a d a) N O 0 est C t O m Z W N t N N C...- a Z W .a a o a) 0 Z o E . z 0ni a Ca c0 M Q iS a AS N O 0 N o .0 (a 7 Z m a a ^ o Y - 3 V cd C C) of LL N C a3 H O O O G. 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T CO O Ico J co N O 0 -In I I I I I 0 0 0 0 0 0 co CD in (un 006) 1-11aea l °! e nal �r s S GU \Mt (0 co (0 co n n n aO a0 a) O N V V n 0 M M M CO M M M M M M V V V VV a 0) O) 6) 6) O) 6) 6) 6) 6) 6) a) 6) O) 6) 0) O CO W = W W d v O 6) 6) > N V) N o co SO] Nn co co N (0 co a) CO n O O CO Q (6 CO co co n n co CO 00 a) co O V a) O CO (O Z Z m D) O O Q) ai a) 6 m O O O r r L5 O • m m W - 0 ' a)V Hr { > J ✓ VV co co N p M N N a O M n O O N C) (O n (O 00 O o J + + = CO O N CO 0 0 N O N N LO O n (O O O N O O 0 Y O W n O O o W 6 a) W W O O C ,- ,- E co W a(7 6 co (O V V V V V '.. 7 Q a) Et"▪ C C a) •, 2 co:.� d a H W O (O (O O C) (O (O (O (O (O (O (O (O O O (O) .i O N N O O N N N N N N N N O O C 0 O V V O O V V V V V V V V O O d L N d OO e J O C 0 a) O CO d ;a C p () R U O Z1'_ p ac) w cc .0 U U U U n (O O N Cco 01 D O N (O O V O LU N V N p a) OV y (O a) o N O 6 O W V O iii O M (O O o QN a !) n n U (O 00 N n W CO N- M M N- r V N.- 1:t QQQNC) n n n W a0 00 a) 6) a) o O a- f° W > c Q a i U (ci ri ri 1. r 6 o ri o (o o 7 c1 O 0V '(n U U U U N 0 0 O O O O O O O O O O O O` O (0 0 CO. CO CO (0 () 0 CO. CO (0 (6 CO J Z O o Y Y Y Y C T Q < < < W r r 1- r r r r r r r L C. a) LL L.L. LL LL .- a7 + + + + (0 n to M co a) a) V co CV O) a) 1- a) a) U a 0> 0> 0> > 0 (O V n CO M 6) CO N01 (O V 03 d T» » N 6) V O M M N aO O M n N o0 0 m O V a) CO CO (O n n CO E C V V V CO CO M N O a) CO ao n (O 1E — O O O O O O O o O O a) O N 6) 6) E M CO M CO M CO M M M M N N N N 0 0 0 0 r .- 0 6) C) 63 rn 0) 0) C) 0) 0) a) a) C3) 0')3 (n CO (n (n Z 0 (n (O (ri (n 0 1.6 116 (ti (n 0 0 a) (n LU C.) Q. UUUU Cn Y Y Y Y n co co o ao a) (n o a) n 1' V 0) 0) M U Q Q Q Q N (Na)• n .- 6 a) r N- 1"-: 0 V V (O (n O M r) O u) a. Q'. a'. W'. (O M O N n N (0 (O• (O V C0 N LL W LL LL co a) O V Q) O N N N N a) 0 (I) O O N N N N N N cc Z (3 +T �+ �+ +T co $ L( n (n 1.6 6 6 6 (ri 6 (O (O (n (n u (n a p F 072222 N.- a0 (O O M a) (O O a) n V V a) a) M (-- n CO C) CO O (O (O CO M V V 61 (O W 0 V M (O O (O a) V 6) a1 V V (O 6) N co V (O CO 0) N CO V (O M (O (O CO 0] m m m N N N N N N M M M M M M M M M CL a d d 0 (n (n LU (n (ri (n (n (n (n 6 (n (r, ui 6 ) ✓ v V V M CO CO CO J J J J V N N N N M C C C C J @ Np aW N O r CO M M CO a) a) N- CO O (O ‘-- a-. _ da a n. n. C o n co co co O v a0 n O N v (O (O (O N O V M M M V n aO V n O O O O a V . V V' .- ,- ,- O O M 7 OOO O - .- .- Ym 3 3 m y C a O m m m m O c o CLCL V m O p 2 N N N i co M co co M E 0 c6 C J J J J J O V O_ O O O n n V CO CO CO V O - V Q 'C U) N N N N N0 M O N r (O CO M r O O V (O Cj co (O ) O r o V N V V V V N V n O O N (O ao W O a0 M d= (0 H . 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Ca CO (0 l0 TN Q O O O O O O O O O O C ., Q C N 2 r r r r r r r r r i_ CJ N DflI } o C) ao 'a 3 co COm 0) 0) ri w▪ w N M 0 0) 0) •a) c-0 (O co `p `o C/3 41 Lo Lc) zz Cl.. 3 �rn z z 0 o m v v m N- c 1- N > 'a) vi CO CO CO id O • N N d • r N + + = co J O O N CO CA m E _m Q 6 <- c- = Q E N C"1 2 c aN s LU ,- E- 5.7 t- wco N- o 0) c o 0 o 'c 1 o t coto c o m - • r m t w m 2 Ce d C N NCO O CO c d 0 ( V in CO M CT C U Gl C (O ,- O 'a C C d o co co _O.i:+ r+ p'• d G) w m d C o a) ad. v m U _ ai U y m a $ rn CO o CC U e r Z l0 O LU L N V Cb O p 0 0 7 03 Z (C) Ln O J 2ZUJc V o r� o. 6 ;o a 0 L g C QDO f) O LCC CtO CO E 0 CV N CO N• x- (Si N CO cd M N P 01 _ a, CA Cb O - CA N- LT Q O O m = (n + O H m F- O C O LO O .0 O C6 t NI _C0 O O CO Csj O_ O N LO -I 4 0 0 m VI co 9m co• C J Co r J O O Z & on Z E d r T r C O m m m m L + Z U) U YY CA 0) U) I- CCL L a O Q W 7 (fl CO (O CO r N N V LO m O N '' 6 O N- W LCV C) N N Q 7 I� C` CO 1- N • (fl 0 V co_? 0 W V V Lo L0 Ln ix) l0 + (A C n m v M N l6 o Z O U o o (O 6) m d' O Ln CO 0 Ts O O 1C X X U M (fl N 6 I- O .0 V (0 CA a_ O6-- N V co E J o O V co CAN ".' (h Ln U Z$M CO- N N Y 0.••••'° 1 CO (.6v o N- n + O � o U CA O O O F C _ CA co CA Cl) N M CA (O N CO CO CO O Cl) O O V V N N ( • m N O V' o) N ..- 3 o O O LC) LC) N 6 O O. N U t W 4 «) V N Cp t-' d) Z' L ' N V Cn CO Q Cy N N N CO V N m M C v > ; a Ln Ln Ln LO Ln n> a V V co O. N O = K N C') M ca, 0 ON O O CO O ` 3 N N C 0 co O 0)) d L O CA N C7 O O U U (U e- N C 7 r " ..L, O • C d n C c M 0 C) c- N O.V CO 7 a I� C`) N O O Sc m m m co d N C) O o r CO a 0YYQCN a) o2) a)m a)to CD C 20 Cb of of rn - N F- m 2N O d N CO o)) co Ci) A CO COal E '� m � E" C C -o `� C in 03• ; aCI) Z £ CI.m coC•O Cl)•O - r C Y ay .. .0 ✓s d 0 Eto V ad ao < N co E --w •y 0) CO , CO CO C 0 o O y 'y U d co F- F- N N u. a 0 O ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-314 (Tarawa) Plan: 2L-314 2L-314wp08 Anticollision Summary Report 29 October, 2013 flozymg OPJGINAL Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314 Database: EDM Alaska Prod v16 Reference Design: 2L-314wp08 Offset ND Reference: Offset Datum Reference 2L-314wp08 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 100.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,357.40ft Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma Survey Tool Program Date 10/29/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 28.00 1,150.00 2L-314PB1wp08(Plan:2L-314PB1) GYD-GC-SS Gyrodata gyro single shots 1,150.00 2,619.11 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,619.11 8,940.91 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,940.91 8,970.91 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,970.91 11,602.00 2L-314wp08(Plan:2L-314) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 5:30:50PM Page 2 COMPASS 2003.16 Build 69 f (. t 1 N L Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit ND Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314 Database: EDM Alaska Prod v16 Reference Design: 2L-314wp08 Offset ND Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning Kuparuk 2L Pad 2L-03-2L-03-2L-03 2,812.38 2,600.00 150.54 103.62 3.208 CC 2L-03-2L-03-2L-03 4,005.96 3,800.00 202.60 89.95 1.799 No Errors,ES,SF 2L-301 -2L-301 -2L-301 299.83 300.00 193.43 187.28 31.488 CC 2L-301 -2L-301 -2L-301 500.68 500.00 194.30 184.18 19.199 ES,SF 2L-304-2L-304-2L-304 28.00 27.28 149.97 148.96 148.352 CC 2L-304-2L-304-2L-304 200.72 200.00 150.04 146.36 40.717 ES,SF 2L-305-2L-305-2L-305 142.90 146.10 134.79 132.47 57.994 CC 2L-305-2L-305-2L-305 1,120.61 1,100.00 138.99 119.87 7.271 ES,SF 2L-306(Stella)-2L-306-2L-306 187.75 200.00 119.07 115.50 33.374 CC 2L-306(Stella)-2L-306-2L-306 287.74 300.00 119.53 114.31 22.890 ES,SF 2L-306(Stella)-2L-306PB1-2L-306PB1 187.75 200.00 119.07 115.50 33.374 CC 2L-306(Stella)-2L-306PB1-2L-306PB1 287.74 300.00 119.53 114.31 22.890 ES,SF 2L-307-2L-307-2L-307 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307-2L-307 290.84 300.00 106.27 101.42 21.940 ES,SF 2L-307-2L-307L1 -2L-307L1 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307L1 -2L-307L1 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-307-2L-307L2-2L-307L2 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307L2-2L-307L2 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-307-2L-307L2-01 -2L-307L2-01 142.90 152.05 105.03 102.57 42.791 CC 2L-307-2L-307L2-01 -2L-307L2-01 290.84 300.00 106.27 101.42 21.939 ES,SF 2L-309-2L-309-2L-309 28.00 33.98 74.77 73.81 77.557 CC 2L-309-2L-309-2L-309 293.58 300.00 77.05 71.25 13.285 ES,SF 2L-309-2L-309PB1 -2L-309PB1 28.00 33.98 74.77 73.76 73.961 CC 2L-309-2L-309PB1-2L-309PB1 293.58 300.00 77.05 71.20 13.178 ES,SF 2L-310-2L-310-2L-310 201.00 200.00 59.34 55.62 15.933 CC 2L-310-2L-310-2L-310 300.98 300.00 60.81 55.48 11.405 ES,SF 2L-311 -2L-311-2L-311 199.60 200.00 44.67 41.23 13.003 CC 2L-311 -2L-311-2L-311 299.59 300.00 45.91 40.84 9.050 ES,SF 2L-311 -Plan 2L-311A-2L-311A(wp01) 199.60 200.00 44.67 41.23 13.003 CC 2L-311 -Plan 2L-311A-2L-311A(wp01) 299.59 300.00 45.91 40.84 9.050 ES,SF 2L-312(Cassidy)-2L-312-2L-312 28.10 40.10 30.27 29.26 29.912 CC 2L-312(Cassidy)-2L-312-2L-312 488.34 500.00 31.79 22.28 3.342 ES,SF 2L-313-2L-313-2L-313 496.96 500.00 14.77 6.72 1.834 No Errors,CC 2L-313-2L-313-2L-313 596.83 600.00 15.15 5.45 1.563 No Errors,ES,SF 2L-315-2L-315-2L-315 142.90 146.10 15.21 12.88 6.543 CC 2L-315-2L-315-2L-315 496.48 500.00 19.90 11.78 2.450 No Errors,ES,SF 2L-317-2L-317-2L-317 488.39 500.00 35.49 27.08 4.221CC, ES,SF 2L-317-2L-317A-2L-317A 488.39 500.00 35.49 27.08 4.221CC, ES,SF 2L-319-2L-319-2L-319 984.71 1,000.00 38.26 20.21 2.120 No Errors,CC,ES,SF 2L-320-2L-320-2L-320 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320-2L-320 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-320-2L-320PB1 -2L-320PB1 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320PB1 -2L-320PB1 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-320-2L-320PB2-2L-320PB2 584.34 600.00 81.69 70.06 7.023 CC 2L-320-2L-320PB2-2L-320PB2 681.90 700.00 82.79 69.22 6.100 ES,SF 2L-321 -2L-321 -2L-321 396.36 400.00 103.89 97.46 16.145 CC 2L-321 -2L-321 -2L-321 593.91 600.00 106.10 96.39 10.926 ES,SF 2L-322(North)-2L-322-2L-322 288.09 300.00 119.46 113.66 20.613 CC 2L-322(North)-2L-322-2L-322 486.02 500.00 121.16 111.46 12.496 ES,SF 2L-322(North)-Plan:2L-322A-2L-322Awp12 300.08 300.00 119.43 113.40 19.804 CC 2L-322(North)-Plan:2L-322A-2L-322Awp12 497.80 500.00 121.45 111.52 12.232 ES,SF 2L-323-2L-323-2L-323 396.27 400.00 134.55 127.95 20.383 CC 2L-323-2L-323-2L-323 495.03 500.00 135.27 127.04 16.439 ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 5:30:50PM Page 27 COMPASS 2003.16 Build 69 ORIGINAL Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314 Database: EDM Alaska Prod v16 Reference Design: 2L-314wp08 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning Kuparuk 2L Pad 2L-325-2L-325-2L-325 142.90 146.20 165.11 162.66 67.270 CC 2L-325-2L-325-2L-325 196.70 200.00 165.45 162.17 50.517 ES,SF 2L-326-2L-326-2L-326 28.00 34.30 180.16 179.14 178.208 CC 2L-326-2L-326-2L-326 392.26 400.00 182.26 174.42 23.224 ES,SF 2L-327-2L-327-2L-327 395.05 400.00 193.76 185.88 24.566 CC 2L-327-2L-327-2L-327 591.07 600.00 195.29 183.53 16.615 ES,SF 2L-329-2L-329-2L-329 395.92 400.00 223.38 216.75 33.736 CC, ES,SF 2L-329-2L-329A-2L-329A 395.92 400.00 223.38 216.75 33.736 CC,ES,SF 2L-330-2L-330-2L-330 492.84 500.00 237.49 228.35 26.007 CC 2L-330-2L-330-2L-330 588.97 600.00 238.27 227.70 22.555 ES,SF 2L-330-Prelim:2L-330ST1 -2L-330ST1wp02 493.47 500.00 237.48 228.39 26.114 CC 2L-330-Prelim:2L-330ST1 -2L-330ST1wp02 589.59 600.00 238.28 227.75 22.636 ES,SF Plan:2L-308(Bertha)-Plan:2L-308-2L-308wp04 1,730.67 1,700.00 65.01 38.56 2.458 No Errors,CC, ES,SF Plan:2L-308(Bertha)-Plan:2L-308PB1 -2L-308PB1wp 1,730.67 1,700.00 65.01 38.56 2.458 No Errors,CC, ES,SF Plan:2L-314(Tarawa)-Plan:2L-314PB1 -2L-314PB1w 8,999.99 9,000.00 0.44 -0.52 0.458 No Errors,CC,ES,SF Plan:2L-318(Libra)-2L-318-2L-318wp05 597.79 600.00 53.97 43.61 5.208 CC Plan:2L-318(Libra)-2L-318-2L-318wp05 695.10 700.00 54.22 42.16 4.496 ES,SF Plan:2L-328(Sierra)-2L-328-2L-328(wp03) 579.07 600.00 207.92 196.34 17.952 CC Plan:2L-328(Sierra)-2L-328-2L-328(wp03) 672.42 700.00 209.74 196.21 15.508 ES,SF Plan:2L-328(Sierra)-2L-328PB1 -2L-32PB1 (wp03) 581.27 600.00 207.93 196.30 17.884 CC Plan:2L-328(Sierra)-2L-328PB1 -2L-32PB1 (wp03) 674.45 700.00 209.83 196.26 15.464 ES,SF Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 285.80 300.00 179.84 174.64 34.580 CC Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 386.31 400.00 181.36 174.53 26.550 ES,SF Prelim:2L-302(Langley)-2L-302L1 -2L-302L1 (wp01) 285.80 300.00 179.84 174.64 34.580 CC Prelim:2L-302(Langley)-2L-302L1 -2L-302L1 (wp01) 386.31 400.00 181.36 174.53 26.550 ES,SF Nanuk Nanuk 1-Nanuk 1 -Nanuk 1 Out of range Nanuk 2-Nanuk 2-Nanuk 2 Out of range Plan:CD5 Alpine West Pad(southwest) Plan:CD5-01 -Plan:CD5-01 -CD5-01wp07 Out of range Plan:CD5-02-Plan:CD5-02-CD5-02wp07 Out of range Plan:CD5-03-Plan CD5-03-CD5-03wp07 Out of range Plan:CD5-04-Plan:CD5-04-CD5-04wp07 Out of range Plan:CD5-05-Plan CD5-05-CD5-05wp07 Out of range Plan:CD5-06-Plan:CD5-06-CD5-06wp07 Out of range Plan:CD5-07-Plan:CD5-07-CD5-07wp07 Out of range Plan:CD5-08-Plan:CD5-08-CD5-08wp07 Out of range Plan:CD5-09-Plan:CD5-09-CD5-09wp07 Out of range Plan:CD5-10-Plan:CD5-10-CD5-10wp07 Out of range Plan:CD5-11 -Plan:CD5-11 -CD5-11wp07 Out of range Plan:CD5-12-Plan:CD5-12-CD5-12wp07 Out of range Plan:CD5-13-Plan:CD5-13-CD5-13wp07 Out of range Plan:CD5-314-Plan:CD5-314-CD5-314wp08 Out of range Plan:CD5-315-Plan:CD5-315-CD5-315wp07 Out of range Prelim:AW-10A-Prelim:AW-10A-AW-10Awp06 Out of range Prelim:AW-10B-Prelim:AW-10B-AW-10Bwp06 Out of range Prelim:AW-9A-Prelim:AW-9A-AW-9Awp06 Out of range Prelim:AW-9B-Prelim:AW-9B-AW-9Bwp06 Out of range Prelim:AW-9C-Prelim:AW-9C-AW-9Cwp06 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 5:30:50PM Page 28 COMPASS 2003.16 Build 69 _yi Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-314(Tarawa) Project: Kuparuk River Unit TVD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Reference Site: Kuparuk 2L Pad MD Reference: Plan: 114.9+28 @ 142.90ft(Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan:2L-314(Tarawa) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:2L-314 Database: EDM Alaska Prod v16 Reference Design: 2L-314wp08 Offset TVD Reference: Offset Datum Reference Depths are relative to Plan: 114.9+28 @ 142.90ft(Nabors 9 Coordinates are relative to:Plan:2L-314(Tarawa) Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1983,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.30° Ladder Plot 1400 I I I I I I fr 1 I I I i /� j I H".;.- I I I . 1 I 111 I i I ,r I I I II f • c 1 050 I k;I ;1 . I I I I 1 o I l if ff� I I I I 1 I I r'r• I I I I I _ _ __J__ I _J __ _ J ____J_ ___ J _I __ a) 1 I I I I 00 1 r I I 1 I ii I I , I I I I m 700 ' ;Irl 1 I Irk 1 I � ifr �fl I I I I 0 1 ,y 1 1 ,( i' I I I a I.f 1 I I I � I � - '' f� I I I I I 350 I �. jI ii I_ J J J �,'.%,1#1,1 I I I LI I I I I 0 0 2000 4000 L E GEIQWD 8000 10000 12000 M easurBd Depth 02(La rig ley),2L-302.2L-302(wp01)VD $ 2L-311,2L-311.2L-311 +I -6- 2L-325.2L-325.2L-325 V2 02(Langle0,2L-3D2L1,2L-302 L1(wp01)V0 -2- 2L-311,PIan2L-311A,2L-311A(wp01)VD -2k- 2L-326.2L-326.2L-326 VO 3,5 L-03 V2 . 2 L-312(Cassid ),2 L-312.2 L-312 VO -- 2L-327.2L-327.2L-327 V2 30'.2L-301 VD 44- 2 L-313.21,313.2 L-313 V2 -9- 2L-320.2L-329.2L-329 V2 30,,2L-3D4VD .-- 2L-315,2L315.2L-315 V2 -9- 2L-329.2L-329A,2L-329AV2 30±.2L-305 V2 - 2L-317.2L317.2L-317 V2 -8- 2L-330.2L-330,2L-330 V8 I11,2L-306,2L-306VT1 $ 2L-317.2L-317A2L-317AV5 -9- 2L-33D.Prelim:2L-330ST1,2L-330ST1wF0: I3;,2L-3D6PB1,2L-306PB1E,O -a- 2L-319.2L319.2L-319 V4 -@- Plan:2L-314(Tarawa),Plan:2L-314PB1.?L 30'.2L-307 V2 -A- 2L-320.2L320.2L-320 VB -9- Plan:2L-318(Lb ra),2L-318.2L-318wp05V :01 Ll.2L-307L1 A) -9- 2L-320.2L-320PB1,2L-32DPB1 VO -40- Plan:2L-328(Sierra),2L-328.2L-328(wp0: :01L2,2L-307L2VD -4- 2L-320,2L-320PB2,2L-320PB2V0 -0- Pia n:2L-328(Sien-a),2L-328PB1,2L-32FB 30,LL-LI I.EL-suLL-LI r VU X- 2u-62I,LL321.2L-sir tit -4-- Plern.2u-.08IBert,a),Pbn.2L-3u8.2L-3C 8. CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/29/2013 5:30:50PM Page 29 COMPASS 2003.16 Build 69 ORIGINAL Amir MD Inc Azi TVD +N/-S +E/-W DLeg TFac Sec Target 970.91 74.00 146.00 5228.17 3103.40 4759.71 0.00 0.0 .71 0 8970 2L-314wp084031.25 74.10 143.33 5244.76 3056.07 4793.26 4.25 -88.2 9.04 3 9178.38 74.10 143.33 5285.08 2942.57 4877.76 0.00 0.00 - 94.21 8970 9098 4 9702.00 88.54 160.51 5364.49 2488.15 5118.46 4.25 51.21 -686.19 8970.91 To 11602.00 5 11602.00 88.54 160.51 5412.90 697.60 5752.18 0.00 0.00 1213.13 2L-314(wp06)Toe 9098 9198 17:15,October 29 2013 I 9198 9298 9298 -- 9398 ,CABAL FILTER APPLIED: A 9398 - 9598 9598 - 9698 25.00 11.50 212-314261,05 Tian..,t-3;wa 115.0 2619.11 212-210PB1,05 9698 9798 esw.s1 32.51 8 '1,,-a,1261,11 8.0.91 21,1412131w50.5132.212-31.12511 Gros „50,.00 ,31.50an:,:; .tea,225K,G. 9798 9898 CASING DETAILS 9898 - 9998 TVD MD Name Size 2235.80 2619.11 10-3/4"x 13-1/2" 10-3/4 9998 10098 5219.90 8940.91 7-5/8"X 9-7/8" 7-5/8 5412.90 11602.00 4-1/2"x 6-1/2" 4-1/2 10098 10298 10298 10398 10398 10498 L-314PB1wp08 10498 10598 10598 10698 0/360 10698 10798 150 10798 10898 30/330 140 30 10898 10998 Ø130 10998 11198 �i�''- 11198 11298 // �'� 120 :// ��- 01 110 11298 11398 //: � 100 11398 11498 ���90 11498 - 11601 60/300 iii/(j6o 80 `A \ 60illi ���50 •• 40 90/270 lie90 Mr" 50 /7/ 60 / ' /i// 70j`x%/ 80 Aiii//- -120/240 r 120 100 110 -------,..-25-:2 /, zi</j; 120 . > � �ji 130 ./ -150/210 140 150 150 -180/180 JGftLAL Conoco hillips 2L-31 4wp08 Schlumberger Alaska O 60 _ Q N - U _ N _ /30 - Jr N Ar � / 0 I i if I I I I I I I I I I I I 1 I I I I I I I I 8000 8250 8500 8750 9000 9250 9500 Displayed interval could be less than entire raffintured Depth 8970.91 To 11602.00 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 8970.91 To 11602.00 Results Limited By: Centre Distance: 1357.40 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1150.00 2L-314PB1 wp08(Plan:2L-314PB1) GYD-GC-SS 1150.00 2619.11 2L-314PB1wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC 2619.11 8940.91 2L-314PB1 wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC 8940.91 8970.91 2L-314PB1 wp08(Plan:2L-314PB1) MWD+IFR-AK-CAZ-SC 8970.91 11602.00 2L-314wp08(Plan:2L-314) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2235.80 2619.11 10-3/4" x 13-1/2" 10-3/4 5219.90 8940.91 7-5/8"X 9-7/8" 7-5/8 5412.90 11602.00 4-1/2"x 6-1/2" 4-1/2 LEGEND —X- Plan:2L-314(Tarawa),Plan:2L-314PB1,2L-314PB1wp08 VO C IGINAL Northing (2500 ft/in) I I l l 1 1 1 1 1 1 1 1 1 1 1 I ' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I II I 1 1 1 1 1 1 1 1 I ..-I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 _ o — 0. 0 - a J - — 3 M Mo — - N -J a - - OOD N - N J a M N 3 a -63' a — 3 a o - m co M V co 3 Z - a o coO J M N N CO N J M — J N Z N N O QomO . — MN 0 _ O J Q N MCND - O O CO ( a 3 — m c..oJ ..• M 3 - CO i N J W - N N _ co0MM N co - JO m N N M II1I M _ aJ M CO _ CO //'' M CO a C - J M N 3 pNj - C N N N — O _ CON _ 00 CO'0 i / c N M N N - N... 01 I 111//// M+C+— NNN — Cw _ 3 wtif, o Q M `� gTN 3 N/r; j< N M Vii. N J O (Z CS) Z - N N CO - J /- - N - coM i Z N co Cti Q M M - O) i N N H M Z N O N — N 4- CO J N - N M - N — Cn Q N - ;--0 N _ 00O t-, _ N/ O - 1 1 1 1 1 1 1 I 1 1 1 1 i 1 1 1 I I I I 1 I I 1 1 1 I I I 1 1 I I 1 I 1 1 1 I 1 1 I I 1 1 1 1 I 1 1 1 1 1 1 i I I 1 I I 1 1 1 I 1 1 1 1 1 1 1 T URIMNAL/4 ) �� T Ferguson, Victoria L (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Thursday, February 27, 2014 11:36 AM To: Ferguson,Victoria L(DOA) Subject: RE:2L-314 (PTD 214-023) Attachments: 2L-314 Permit to Drill Addendum.pdf Hi Victoria, Thank you for pointing this out. Please find attached our Addendum for the 2L-314 PTD to rectify these issues. Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell milt :victoria.fer uson alaska. ov From: Ferguson, Victoria L(DOA) [ a o g @ g ] Sent: Thursday, February 27, 2014 10:02 AM To: Bearden,3 Daniel Subject: [EXTERNAL]2L-314(PTD 214023) Daniel, Please review cementing calculations for the 7-5/8" Intermediate Casing cement job. Also, insure depths for the Bonzai cement job agree with the wellbore schematic. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria fergusone,alaska.gov 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. 17RANISIVii i TAL LE C TER CHECK LS7 WELL NAME: '< J�,� L -31V !)e\elopment ScrN ice -- E.\ploratoory Siraitigraphic I est -- Non-Con\cntional V � FIELD: '.& 4< l\VE.4j- POOL: I� f 1 Jar1 wrn 0 1' Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. . API No. 50- - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) / In accordance with 20 AAC 25.005(1), all records. data and logs / acquired for the pilot hole must be clearly differentiated in both well V Pilot Hole name ( PH) and API number (50-103 - a0(8(Q - ?-0 - 00 ) from records, data and logs acquired for well c K«t& aj 3iy 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. 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E O ac) C 0 0 0_ -U0 c to O O r a 0_, o 0 0 .@ s lb-. " n o n > > 3 m 6 ami m w w Y Y r ° E a) of Y0 0 a) ai .a o a) a) V 0. 0a a`) a) m 0 3 m 0 . H H m -00 0 a a O O .c ° °. aa)) aa) m co m a) o 0 0 c Z a -J D (n 0 0 a a 0 Q a (..) (n 0 0 0 0 Q ¢ 6 m m 0 o g a a co (n 0 W E N- 0 N CO V l0 c0 CO 0) O N CO C )° (0 r CO 0) O N CO V (0 (0 I- 00 O) E N CO V (O (O r CO 0) �- N N N N N N N N N N CO CO CO CO CO CO CO CO CO CO V V V V 1.- N C p c - (N - N -CZ ( U O C W V N N N .7) E d N 0 T E N ' J c a) co W O E Q m co a -I 0 0. a 5 a < a w a 0 a 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. FINAL WELL REPORT MUDLOGGING DATA 2L-314 Provided by: Approved by: Kelly Umlauf Compiled by: Allen Odegaard James Foradas B r i t t e n A d a m s Distribution: 8/22/2014 T.D. Date: 8/6/2014 2L-314 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA...........................................................................................................................12 3.1 Lithostratigraphy ...........................................................................................................................12 3.2 Mudlog Summary..........................................................................................................................13 3.2.1 C-80.......................................................................................................................................13 3.2.2 Campanian Sand...................................................................................................................13 3.2.3 C-50.......................................................................................................................................17 3.2.4 C-40.......................................................................................................................................19 3.2.5 C-37.......................................................................................................................................20 3.2.6 Iceberg...................................................................................................................................21 3.2.7 T-7 .........................................................................................................................................22 3.2.8 T-4.1 ......................................................................................................................................24 3.2.9 Bermuda Sand.......................................................................................................................25 3.2.10 C-35 to TD.............................................................................................................................29 3.3 Isotube Summary..........................................................................................................................31 3.4 Sampling Program / Sample Dispatch..........................................................................................36 4 PRESSURE / FORMATION STRENGTH DATA.................................................................................37 4.1 Pore Pressure Evaluation.............................................................................................................37 4.2 Pore Pressure Plot........................................................................................................................38 4.3 Quantitative Methods....................................................................................................................39 5 DRILLING DATA..................................................................................................................................40 5.1 Survey Data Surface to Production Hole TD ................................................................................40 5.2 Survey Data. Pilot Hole Plugback.................................................................................................43 5.3 Bit Record.....................................................................................................................................44 5.4 Mud Record ..................................................................................................................................45 6 SHOW REPORTS ...............................................................................................................................47 7 DAILY REPORTS ................................................................................................................................50 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Data CD 2L-314 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 2.0 hrs. inundated by moving mud Effective Circulating Density (ECD) From Schlumberger 2750’ to 6517’ 0 hrs. — Hook Load / Weight on bit From Schlumberger & Encoder from (Canrig Drilling Technology LTD.) 0 hrs. — Mud Flow In Derived from Strokes/Minute and Pump Output 0 hrs. — Mud Flow Out Nabors 9ES 0 hrs. — Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 hrs. — Mudlogging Unit DAC box In-unit data collection/distribution center 0 hrs. — Pit Volumes, Pit Gain/Loss Canrig Drilling Technology LTD pit sensors 0 hrs. — Pump Pressure Nabors 9ES 0 hrs. — Pump stroke counters Nabors 9ES (Stroke counter #1 & #2) 0 hrs. — Rate of Penetration Nabors 9ES 0 hrs. — RPM Nabors 9ES 0 hrs. — Torque Nabors 9ES 0 hrs. — 1.2 Crew Unit Type : Steel Arctic Unit Number : ML059 Mudloggers Years *1 Days *2 Sample Catchers Years Days *2 Technician Days Allen Odegaard 17 10 Larry Turner 15 20 Travis Smith 1 Britten Adams 3 21 Dickey Hudgins 7 8 Howard Lamp 1 James Foradas 7 23 Eli Callan 1 28 John Farrell 2 5 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 2L-314 3 2 WELL DETAILS 2.1 Well Summary Well: 2L-314 ‘Tarawa’ API Index #: 50-103-20686-00-00 Field: Kuparuk River Field Surface Co- Ordinates: 181' FNL, 704' FEL, Sec 22,T10N,R7E,UM(NAD2 7) Borough: North Slope Primary Target Depth: 9,149’ MD State: Alaska TD Depth: 5,326’ TVD Rig Name / Type: Nabors 9ES, Arctic Triple Suspension Date: N/A Primary Target: Tarn Bermuda Permit to Drill Number: 214023 Spud Date: 7/11/2014 Ground Elevation: Pad 114.9' MSL Completion Date: 8/10/2014 RT Elevation: RKB 142.9' MSL Completion Status: Secondary Target: Depth: None Classification: Grassroots producer TD Date: 8/7/14 TD Formation: Bermuda Days Testing: N/A Days Drilling: 27 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD ft TVDSS ft TD Formation Mud Weight ppg Dev. oinc Coring Casing/ Liner MD ft TVDSS ft FIT / LOT ppg 13.5” 2534’ -2256’ — 9.5+ 41.15o none 10.75” 2534’ -2256’ 15.7 9.875” 9120’ -5125’ T-4.1 9.8 72.02o none 7.625” 9110’ -5123’ 12.3 6.50” 11622’ -5225’ Bermuda 10.5 87.99o none 4.5” 11622’ -5225’ — 2L-314 4 2.3 Daily Activity Summary 7/10/2014 Rig accepted at 00:00 hrs 7/10/2014. Spot rig over well. Nipple up diverter. Function test bag & knife valve. Test gas alarms. Take on 9.6 ppg Drilplex fluid. Test mud lines & surface equipment. Load 5" drill pipe into pipe shed. 7/11/2014 Finished P/U 5" Drill Pipe. Spud at 5:30 pm, Drilled pilot hole with dumb iron to 257 feet. Trip out of hole and pick up surface. 7/12/2014 Directional shallow test, establish good survey with gyro. Continue to pick up BHA. Drill to 957’ MD. Drill from 957’ MD to 1899’ MD. Prep 10 ¾ casing, stage 66 centralizers to the rig floor. Clear cuttings box at time of report. 7/13/2014 Circulate and condition hole until cuttings box was cleaned and continue drilling to 2534’ MD. Back reaming pump sweep. Trip out of hole from 1805’ MD to 1710’ MD, monitor well for 15 minutes, observed minimal swabbing, worked tight areas, back ream out of hole. 7/14/2014 Finished BROOH with no issues. Laid down BHA. Made Dummy Run. Rigged up Tesco and started running CSG. at 3:30 PM. Called out trucks for cement job and created plan forward. Running 10.875" Casing at report time. 7/15/2014 Condition hole for the cement job for third party. Cement the casing to 2534’ MD. Rig down cement equipment. R/D the diverter and R/U new diverter. Begin R/U new BOP stack. 7/16/2014 Install and put together new BOP. Test Bops valves, rams, and fix gas alarms on rig. Pick up drill pipe (51 joints) and rack them back into the derrick. 7/17/2014 6.b trip out of hole pooh f/ 2150' t/ 579'' racking back 17 stds in the derrick. Drills-bop etc kick while tripping drill. Pick up drill pipe pjsm w/ crew. P/u 51 jts of 5" dp 1571' rabbiting each jt off the skate. Trip out of hole pooh f/ 2160' t/ surface racking back 17 stds dp in derrick and 6 std of hwdp. Up wt 90k dn wt 78k. Test bops m/u test assembly t/ test upper ibop. Test 250 psi low / 3500 psi high f/ 5 min each and chart. Test assembly failed, drain stack-pull wr-set test plug and retest. Test was good. Install/remove wear bushing install wr and run in lock downs. Cont' to r/d test equipment, b/d kill line and line up stack for normal ops. Pick up 3rd party tools p/u bit, bit breaker, lift subs and prep floor f/ m/u bha. Pick up bha pjsm w/ all involved personal in p/u bha. P/u bha as per slb dd. Pick up bha #3, pjsm, uwt 75k, dwt 70k, pick up drill pipe pu 24 jts f/ 755.92', t/1510', then shallow test mwd, uwt 83, dwt 75k circulate and condition shallow test mwd,@ 1510', Gpm 500, psi 1145, flow 68%, spm 168, uwt 83k, dwt 75k pick up drill pipe finish pu dp f/1510', t/2264.69', uwt 102k, dwt 92k, pressure test csg/shoe r/u for casing test, test casingt/3000 psi for 30 min, mw 9.7ppg,test is good, rd equip, bd lines trip in hole pjsm rih f/2264, t/ fc @ 2446', tag cement @ 2433', washdown, uwt 110k, dwt 95k, psi 500, tq 3k, gpm 300, flow 45, spm 102k, drilling cement drill f/ 2446 t/ 2534 gpm- 120, psi on-761, psi off- 520. Rpm-15-70 tq on-4-5k, tq off 3-3.5k. Pu wt- 110k, sow-95k, rot-102k, mw- 9.7 ppg, loading 7 5/8 casing in the shed. 7/18/2014 Rotary drilling f/ 2452' t/ 2526' @ 350 gpm w/ 700 psi on btm 600 psi off btm 60 rpm w/ 4k tq on btm 3k tq off btm up wt 110k dn wt 95k rt wt 100k. Once out of shoe, drill @ 600 gpm w/ 1500 psi on btm 1500 psi 2L-314 5 off @ 80 rpm w/ 4.5k tq on btm 4k tq off, 5k wob - t/ 2554'. Change out mud system displace mud t/ 9.6ppg lsnd @ 600 gpm w/ 1420 psi @ 30 rpm w/ 2k tq. Trip out of hole f/ 2554' t/ 2415' up wt 105k dn wt 95k. R/u t/ perform lot pumping dn dp and dn kill line at the same time. Pressure test csg/shoe perform lot. Pressure up t/ 850 psi and shut in. 16.2ppg emw rotary drilling tih f/ 2415' t/ 2554' up wt 105k dn wt 95k. Drill f/ 2554' t/ 2661' @ 625 gpm w/ 1520 psi on btm 1500 psi off, @ 80 rpm w/ 5k tq on btm 3.5k tq off, 5k wob, up wt 105k dn wt 100k rt wt 100k. Spr @ 2542' md/2409'tvd- #1mp @ 2bbl/min-110 psi @ 3bbl/min- 140 psi. #2mp @ 2bbl/min-100 psi, @ 3bbl/min 160 psi, w/ 9.6 ppg lsnd mud. Trip out of hole swivel packing on td washed out. Pooh f/ 2661' t/ 2452' up inside the shoe to c/o. Change out swivel packing b/d td and c/o swivel packing. Trip in hole f/ 2452' t/ 2661' up wt 110k dn wt 95k. Rotary drilling drill f/ 2661’ t/3019’, gpm- 650, psi on-1750, psi off- 1730. Rpm-120 tq on-5k, tq off 3.5k. Pu wt- 110k, sow-95k, rot- 100k, art-3.42hrs, adt-3.42hrs, total bit hrs-3.42 total jar hours-40.5sprs taken at 1100hrs, 3014' md, 2734 tvd, pump #1 at 2 bpm= 90 psi, at 3 bpm=130 psi. Pump #2 at 2 bpm=90 psi, at 3 bpm= 130 psi mw- 9.6 ppg, rotary drilling -f/ 3019 md t/3538 md, tvd=2938 md, ecds= 10.4-10.5 ppg, art= 3.84 hr, ast=0 hr, adt= 3.84 hrs, puw= 121k, sow= 100k, rot=105k, rpm= 120, gpm= 650, psi on= 1890, psi off=1870, tq on= 6-8k ft/lbs, tq off= 5k ft/lbs. Pump 40bbls sweep @ 3200' 10-15% increase, ream full std's,sprs taken at 17:00hrs, 3490 md, 2915 tvd, pump #1 at 2 bpm= 100 psi, at 3 bpm=140 psi. Pump #2 at 2 bpm=100 3bpm=130 rotary drilling -f/ 3538 md t/4055 md,tvd=3158 md,ecds=10.4-10.7ppg, art= 3.36 hr, ast=0hr, adt=3.36hrs,puw=122k,sow=95k,rot=103k,rpm=120,gpm=650,psi on=1970,psi off=1930,tq on=7-9k ft/lbs,tq off=4-5k ft/lbs. 40 bbls sweep@ 3700' 10-15% increase,ream full std's, 30' surveys as per dd t/ 3800'sprs taken at 2345hrs, 4055'md, 3158 tvd, pump #1 at 2 bpm=100psi,3 bpm=130psi. Pump #2 bpm=100psi, 3 bpm 150psi. 7/19/2014 Rotary drilling f/4055' t/ 4526' @ 120 rpm w/ 8-10k tq on btm, 7.5k tq off btm @ 650 gpm w/ 2200 psi on btm, 2170 psi off btm, w/ 10k wob. Up wt 130k dn wt 95k rt wt 105k. Spr @ 4526' md 3374' tvd- #1mp @ 2bbl/min-150 psi, @ 3bbl/min- 200 psi. #2mp @ 2bbl/min-150 psi @ 3bbl/min- 200 psi. 3.05 hrs adt. Jar hrs-54.2 bit hrs-13.72 circulate and condition @ 4526' circ sweep around @ 650 gpm w/ 2130 psi @ 50 rpm w/ 6k tq. Shut dn pumps and monitor well to varify well is static. Back reaming f/ 4526' t/ 2452' @ 600gpm w/ 1930 psi @ 60 rpm w/ 6.5k tq. Up wt 135k dn wt 100k rt wt 130k. Pump surveys as needed per slb dd. Circulate and condition cbu @ 2526' to clean out csg @ 600 gpm w/ 1690 psi @ 50 rpm w/ 3k tq. Up wt 105k dn wt 90k rt wt 100k. Monitor the well for 30 Min to varify static. Service rig b/d top drive, and service the rig. Pre job safety - for cut and slip, spool out line on roof, prep floor for cut and slip, get all tools together cut drilling line - cut 12 wraps, 78' drilling line, inspection of draw works brakes. Inspect dead man brass and welds on dead man bracket, clean out inside of dw and lay down new absorb, check brake bands, service rig - serivce crown section, p/u tools f/ cut and slip, prep f/ rih trip in hole rih f/ 2450' t/4418' uwt=140k dwt=100k, hole fill = 16.7cal fill=17, fill pipe @ 3380' 70-spm 360 psi, no tight spots observed during trip change out mud system rot/ricp f/ 4431' t/ 4515' gpm= 650, psi off= 2115, torq off= 6k, rot wt= 108k, dump/deliute mud w/ 290 bbls new 9.6 lsnd rotary drilling f/ 4526’ md t/ 4997 md,tvd=3576md,ecds=10.5-10.7ppg,art=3.36hr, adt=3.36 hrs, puw=133k, sow=103k, rot=113k, rpm=120, gpm=650, psi on=2180, psi off=2135, tq on=8-10k ft/lbs,tq off=6-7k ft/lbs. Ream 90' sweep @ 4800' 15- 20%,sprs at 2315 hrs, 4900'md, 3534tvd, pump #1 at 2 bpm=150psi, at 3 bpm=200psi. Pump #2 at 2 bpm=140psi, at 3 bpm= 200psi mw-9.7ppg. 7/20/2014 Rotary drilling drill f/4997 t/5500, gpm- 650, psi on-2240, psi off-2200 . Rpm-120 tq on-9.7k, tq off 8k. Pu wt- 140k, sow-100k, rot-113k, sprs taken at 0430hrs, 5374' md, 3741’tvd, pump #1 at 2 bpm= 180 psi, at 3 bpm=230 psi. Pump #2 at 2 bpm=180 psi, at 3 bpm= 230 psi mw- 9.6 ppg. Rotary drilling drilled f/ 5500’ t/5751, gpm- 650, psi on-2365, psi off- 2350. Rpm-120 tq on-10k, tq off 8k. Pu wt- 145k, sow-100k, rot- 110kadt- 5.78hrs, total bit hrs-22.79 total jar hours-63.32 - sprs taken at 0430hrs, 5374' md, 3741tvd, pump #1 at 2 bpm= 180 psi, at 3 bpm=230 psi. Pump #2 at 2 bpm=180 psi, at 3 bpm= 230 psi mw- 9.6 ppg. Working stuck pipe 5652' packed off. 17k tq, 3000 psi on the up stroke, shut dn pumps and break over dn. Up wt 150k dn wt 100k, 25k over pull. Work pipe up t/ 5464' establish return flow @ 36spm w/ 385 psi. 13k tq w/ 125 rpm. Working stuck pipe -rot/ricp f/ 5563' t/5469', walk pump back up to drilling rate, gpm=650, psi Off=2300, torq on=8-9k, ecd when mwd back signal=11.17 dropped to 10.68, b/u gas max 1390 units. Rwt=115k, pump 30bbls nutplug/drill zone pill, hole unloaded 30% cuttings increase working pipe/tight spot - rih f/ 5563' t/5751', gpm-650, psi-2340, rpm-120, torq- 7-9k, uwt-155k,dwt-105k rwt-118k, 2L-314 6 no tight spots observed 14:00 18:00 4.00 2.a rotary drilling drilled f/ 5751’ md t/ 5968’ md, tvd = 4097’ md,ecds=10.6-10.7ppg, art= 2.39hr, adt=2.39hrs, puw=151k,sow=107k,rot=125k, rpm= 120, gpm= 650, psi on=2415, psi off=2350, tq on=9-12ft/lbs, tq off= 8-9ft/lbs.sprs at1530hrs, 5845md,3946’ tvd, pump #1 at 2 bpm=200psi, at 3 Bpm=250psi. Pump #2 at 2 bpm=200psi, at 3 bpm=250psi mw- 9.7 ppg, br 95' b4 conn. Rotary drilling drilled f/ 5751’ md t/ 6315’ md, tvd=4152’ md, ecds=10.6-10.8ppg, art= 3.29 hr, adt=3.29 hrs, puw=151k, sow=110k,rot=125k, rpm= 120, gpm= 650, psi on=2450, psi off=2400, tq on=9- 11kft/lbs, tq off= 7-9kft/lbs. Sprs At 1530hrs, 5845md, 3946’ tvd, pump #1 at 2 bpm=200psi, at 3 bpm=250psi. Pump #2 at 2 bpm=200psi, at 3 bpm=250psi mw- 9.7 ppg, circ sweep @ 6120- 20% increase, br 95', conn gas 1200-1400 units 7/21/2014 Rotary drilling f/ 6315' t/ 6410' @ 120 rpm w/9.5k on 8k tq off @ 650 gpm w/ 2450 psi on 2435 psi off, up wt 150k dn wt 105k rt wt 125k, 10k wob. Showing signs of pack off on back ream, informed coman and decide to brooh f/ 6410' t/4500'. Adt- .95 hrs, jar hrs-69.95, ttl bit hrs - 29.42 back reaming f/ 6410' t/ 4500' @ 100 rpm w/ 8-9k tq on 7-8k tq off @ 650 gpm w/ 2450 psi. Up wt 150k dn wt 105k rt wt 125k. Adjust pulling speed w/ ecd's. Service rig @ 4500' monitor the well t/ varify well is static, and service the rig. Trip in hole f/ 4500' t/ 6410' up wt 150k dn wt 100k. Circulate and condition cbu @ 100 rpm w/ 9k tq, @ 650 gpm w/ 2620 psi. Circ until trip gas disipated and back to normal peramiters w/ 2440 psi. Up wt 150k dn wt 100k rt wt 128k. Spr @ 6410' md 4193' tvd w/ 9.8 ppg mw - mp #1 @ 2bbl/min - 190 psi @ 3bbl/min- 260 psi, mp#2 @ 2bbl/min - 190 psi @ 3bbl/min - 260 psi. Rotary drilling -f/ 6410’ md t/ 6785’ md, ecds=10.5- 10.6 ppg, art= 3.61 hr, adt= 3.61 hrs, puw= 157k, sow= 112k, rot= 112k, rpm= 120, gpm= 650, psi on= 2450, psi off= 2420, tq on= 10-12 ft/lbs, tq off= 8-9 ft/lbs. Wob-8-12. 40 bbl hi-vis sweep @ 6425' 10 % increase. Rotary drilling -f/ 6785’ md t/7100’ md,tvd=4454’ md,ecds=10.6-10.7ppg,art=3.87hr,adt= 3.87hrs,bithrs-35.87puw=157k,sow=117k,rot=132k,rpm=120,gpm= 650,psi on= 2550, psi off=2500,tq on=10-12k ft/lbs,tq off=8-9kft/lbs.sprs taken at 2000hrs,6880 md,4385’ tvd,pump#1 at 2 bpm=150psi,at 3 bpm=210psi. Pump#2 at 2bpm=150 psi, at 3bpm=210, Psi mw- 9.8,sweep@ 6790' 10% increase. Iceburg @ 7030' md, mont. Well con. 7/22/2014 Rotary drilling drill f/ 7100 t/ 7447, gpm-650, psi on-2600, psi off- 2550 . Rpm-120 tq on-11-13k, tq off 8-9k. Pu wt- 160k, sow-115k, rot-130k, sprs taken at 0220 hrs, 7259' md, 4499 tvd, pump #1 at 2 bpm= 160 psi, at 3 bpm=230 psi. Pump #2 at 2 bpm=160 psi, at 3 bpm= 225 psi mw-10.0 ppg, rotary drilling drill f/ 7447’ t/7850, gpm- 640, psi on-2630, psi off- 2595. Rpm-120 tq on-12-14k, tq off 9k. Pu wt- 165k, sow-115k, rot-115k, adt-6.01hrs, total bit hrs-41.88 total jar hours-82.41 sprs taken at 1020hrs, 7730' md, 4685 tvd, pump #1 at 2 bpm= 180 psi, at 3 bpm=240 psi. Pump #2 at 2 bpm=180 psi, at 3 bpm= 240 psi mw-10.0 ppg. Rotary drilling drill f/7850 t/8197, gpm- 640, psi on-2650, psi off- 2600, rpm-120 tq on-12- 14k, tq off 9-11k. Pu wt- 173k, sow-120k, rot-133k, wob- 10-13k, ecd 10.9-11.1, art-3.14hrs, adt-3.14hrs, bit hrs-4.14, sprs taken at 1800hrs, 8197 md, 4912 tvd, pump #1 at 2 bpm=210 psi, at 3 bpm=270 psi. Pump #2 at 2 bpm=210 psi, at 3 bpm=270 psi mw- 10 ppg, sweep @ 8000' 10% increase. Rotary drilling drill f/8197 t/8479, gpm- 640, psi on-2650, psi off- 2620 .rpm-120 tq on-12-15k, tqoff 11-14k. Pu wt- 179k, sow-125k, rot-143k, wob-10-13k, ecd-10.9-11.1, art-3.05hrs, adt-3.05hrs, total bit hrs-48.07 total jar hours 88.6sprs taken @ 2300hrs, 8497 md, 5029 tvd, pump #1 at 2 bpm= 190 psi, at 3 bpm=250psi. Pump #2 at 2 bpm=190psi, at 3 bpm=250psi mw-10.1ppg, sweep @ 8440' 10% increase. 7/23/2014 Circulate and condition cbu @ 8479' @ 640 gpm w/2715 psi @ 120 rpm w/ 13-14k tq. Up wt 175k dn wt 120k rt wt 140k. Monitor the well f/ 15 min t/ varify static. Back reaming f/ 8479' t/ 6410' @ 640 gpm w/ 2715 icp, 2500 fcp @ 120 rpm w/ 13-14k initial tq, 10-12k final tq. Inital up wt 175k dn wt 120k rt wt 140k, final up wt 160k dn wt 105k rt wt 125k. Adjust pulling speed w/ ecd's, max ecd encountered - 11.11, mw- 10.1 ppg. Service top drive monitor the well to varify static. Service wash pipe. Trip in hole f/ 6410' t/8385' up wt 1180k dn wt 110k. Circulate and condition wash dn and cbu f/ 8385' t/ 8479' @ 640 gpm w/ 2800 psi @ 120 rpm w/ 14k tq. Up wt 180k dn wt 120k rt wt 140k .rotary drilling drill f/ 8479 t/8668, gpm- 640, psi on-2780, psi off- 2750. Rpm-120 tq on-16k, tq off 14k. Pu wt- 185k, sow-120k, rot-140k, adt-1.94hrs, total bit hrs-50.01 total jar hours-90.54 sprs taken at 0001 hrs, 8475 md, 5030 tvd, pump #1 at 2 bpm= 190 psi, at 3 bpm=250 psi pump #2 at 2 bpm=190 psi, at 3 bpm= 250 psi mw- 10.1 ppg, rotary drilling -f/7850 t/9044,tvd 5246' gpm- 640, psi on-2760, psi off- 2725, rpm-120 tq on-17-20k,tq off 15-17k. Pu wt- 200k, 2L-314 7 sow-120k, rot-145k, wob-10-13k, ecd 10.9-11.1,sprs taken at 1700hrs, 8950 md, 5214 tvd, pump #1 at 2 bpm=210 psi, at 3 bpm=280 psi. Pump #2 at 2 bpm=210 psi, at 3 bpm= 280 psi mw- 10.2ppg, sweep @ 8950' 40% increase, art-3.91, adt-3.91, circulate and condition circ bu as per geo. Called 9044' td, take survey/new spr's, f/9044 t/8950, gpm- 640, psi off- 2375, rpm-110,tq off 14-17.5k. Pu wt- 200k, sow-120k, rot-145k, ecd 10.9-11.1,sprs taken at 1920 hrs, 9042 md, 5255 tvd, pump #1 at 2 bpm=210 psi, at 3 bpm=270 psi. Pump #2 at 2 bpm=210 psi, at 3 bpm= 270 psi mw- 10.2 ppg, back reaming - f/ 9044' t/8851' circ bu every std racked back, gpm=630, rpm=110, torq off-13-15k, uwt-200k, dwt-125k, rwt-145k, ecd's- 10.9-10.8, co-man/geo decieded to drill t/ 9120', wash back down to 9044' - Rotary drilling -f/9044 t/9120, tvd 5269' gpm- 630, psi on-2660, psi off- 2630, rpm-120 tq on-15-17k,tq off 13-15k. Pu wt- 200k, sow- 120k, rot-145k, wob-10-13k, ecd 10.9-11.1,sprs taken at 1700hrs, 8950 md, 5214 tvd, pump #1 at 2 bpm=210 psi, at 3 bpm=280 psi. Pump #2 at 2 bpm=210 psi, at 3 bpm= 280 psi mw- 10.2ppg, art-79 , adt- .79, total bha/bit hrs- 54.63 jar total-95.16 circulate and condition -circ bu as per geo. Called 9120' td, take survey/new spr's, f/9120 t/9040, gpm- 620, psi off- 2650, rpm-110, and tq off 14-17k. Pu wt- 200k, sow- 120k, rot-145k, ecd 10.9-11,sprs taken at 2200 hrs, 9120 md, 5269 tvd, pump #1 at 2 bpm=210 psi, at 3 bpm=270 psi. Pump #2 at 2 bpm=210 psi, at 3 bpm= 270 psi mw-10.2 ppg, circ 45 bbls wt sweep, 11.0 ppg high vis @ 23:30 hrs 7/24/14 Circulate and condition cont' cbu @ 9120' @ 615 gpm, w/ 2590 psi @ 105 rpm w/ 14-16k tq, Up wt 190k dn wt 115k rt wt 145k. Monitor the well 30' off btm f/ 30 min to varify well is static. Messure fluid level f/ rkb and observe no flow or losses. Trip out of hole f/9120' t/ 7338' up wt 205k dn wt 118k, 10k drag. @ 8820' t/ 8755' 15-30k over pull, work string until free up wt. @ 8636' 35k over pull, work string until free up wt. Pump d/j @ 7716', b/d td. Trip out of hole f/ 7338' t/ 4910', up wt 175k up wt 110k dn wt @ 6360' t/ 6320' over pull 30k, whip back through once till free p/u wt. @ 5458' 25k over pull t/ 5428', 5170' 20k over pull, 4910' 25k over pull. Trip in hole f/ 4910' t/ 5500' t/ brooh. Up wt 150k dn wt 100k. Back reaming f/ 5500' t/ 5150' @ 640 gpm w/ 2515 psi @ 120 rpm w/ 8-9k tq. Up wt 150k dn wt 100k rt wt 115k. Back reaming f/ 5150' t/ 2450' @ 640 gpm w/ 2515 psi @ 120 rpm w/ 8-9k Tq. Up wt 150k dn wt 100k rt wt 115k. Cal dis = 16.5 act fill=11.5, ran h20 to clean shakers/h20 for wt. Circulate and condition - pump 40 bbl sweep t/ surface, hole undloads cuttings, gpm-605, psi-1950, rpm-110, torq- 2.8-3.3, rwt-97k, uwt-xxk dwt-94k, mont. Well, pump 30 bbl slug, remove blower hose, b/d td, line up on tt for pooh, prep floor for l/d bha trip out of hole -f/2450' t/756', uwt-75kdwt-70k, mont. Well at bha, pjsm for l/d bha, cal hole fill= 9.9bbls act fill=15bbls lay down bha -l/d 17 jnts hwdp, jars, 3 nmfc, bring source box up, pjm for pulling source, remove source, send source box back out, cont. L/d bha as per DD, cal fill= 20bbls, act fill= 23bbls lay down bha pjsm w/ all involved personal, l/d BHA as per slb dd and clear all lift subs/equipment off rig floor. 7/25/14 Circulate and condition m/u assembly t/ flush and clean stack. Install/remove wear bushing pull wr w/ cameron rep and conduct a dry run w/ ld jt and hanger. Change rams set test plug, close blinds and c/o top set of rams t/ 7 5/8. Pu test tools - m/u test plug t/ 7 5/8 test jnt, run in well head, m/u tiw on test jnt, test bops - test 7 5/8 top rams/ bag to 250 low/3500 high, record on chart ld test tool - pull test jnt, remove test plug, r/d test hose/ equipment, l/d tools rig up/down to run casing remove 5" elevators, remove short bails, r/u long bails, m/u safety valves for csg, r/u tesco, p/u spiders, r/u service loop for tesco, m/u blower hose, pre job safety run 7 5/8 csg m/u shoe track - m/u 7 5/8 39.7 # float track/ float collar, baker lock connections, check floats, all good run casing - run 7 5/8 29.7# csg, m/u torq-10,300 ft/pounds for 29.7- 19,300 ft/pounds for 39.7#, c/o tesco dies t/ 29.7#, f/ 248' t/9120', uwt-113k, dwt-99k, fill every jnt on the fly,circ b/u every 2000' in oh, bpm- 6,spm-85, psi-330, cal hole fill= 36 act hole fill=38.7. 7/26/14 Waiting on cement cont/t hold 1000 psi untill 4am, while cmt sets up. Clean around rig, prep 4" dp in pipe shed for next hole section waiting on cement bleed back 2bbls t/trip tank,b/d cmt lines and l/d all cmt equipment,c/o long bails t/short bails,r/d tesco equipment off t/d,l/d 7 5/8 landing jt,drain stack pick up 3rd party tools pjsm w/cameron rep on installing packoff,p/u 5'' single m/u packoff running tool and set as per cameron rep, cameron to pressure test packoff t/5000psi f/10min ''good''. Witnessed by nabors drilling,rig down packoff running tool,set w/r as per cameron,w/r ''id'' = 9 3/4 ''od'' = 10 3/4 length = 1.08 lay down drill pipe pjsm,tih 9 stds of 5'' dp out of derrick and l/d t/pipe shed,hot oil t/freeze protect ''oa'' 7 5/8 x 10 3/4 102 bbl of diesel 112 bbl of sea h2o lay down drill pipe - m/u mule shoe w/ dart valve on btm (2.2' od- 2L-314 8 6.5od), rih w/ 9 stds, l/d 18jnt's, cont. Rih and l/d 5" dp, total jnts 5". L/d=165, 55 stds, uwt=50k, dwt=38k, cal hole fill=132 bbls act fill 132 bbls. 7/27/14 Waiting on cement cont/t hold 1000 psi untill 4am, while cmt sets up. Clean around rig, prep 4" dp in pipe shed for next hole section waiting on cement bleed back 2bbls t/trip tank,b/d cmt lines and l/d all cmt equipment,c/o long bails t/short bails,r/d tesco equipment off t/d,l/d 7 5/8 landing jt,drain stack pick up 3rd party tools pjsm w/cameron rep on installing packoff,p/u 5'' single m/u packoff running tool and set as per cameron rep, cameron to pressure test packoff t/5000psi f/10min ''good'' Witnessed by nabors drilling,rig down packoff running tool,set w/r as per cameron,w/r ''id'' = 9 3/4 ''od'' = 10 3/4 length = 1.08 lay down drill pipe pjsm,tih 9 stds of 5'' dp out of derrick and l/d t/pipe shed,hot oil t/freeze protect ''oa'' 7 5/8 x 10 3/4 102 bbl of diesel 112 bbl of sea h2o lay down drill pipe - m/u mule shoe w/ dart valve on btm (2.2' od- 6.5od), rih w/ 9 stds, l/d 18jnt's, cont. Rih and l/d 5" dp, total jnts 5" l/d=165, 55 stds, uwt=50k, dwt=38k, cal hole fill=132 bbls act fill 132 bbls. 7/28/14 Test bops cont/test b o p's f/4''test jnt bag,3.5 test jnt top rams ,outter test spool vlv,lower rams inner test spool vlv,bag,250 psi low 3500psi high, koomie test, acc/psi 2900,after function 1700psi,200 charge = 31sec,full charge = 146sec,6 bottel average = 2050 install/remove wear bushing drain stack, pull test plug, set w/r,b/d all test equipment, choke manifold, line up choke manifold and man choke and kill f/normal opps pick up bha pjsm w/slb dd and crew on picking up bha,pick up bha as per slb pick up bha pjsm w/slb picking up nuke source, pick up nuke source and install cont/pu bha as per slb pick up drill pipe single in hole w/4'' ht 40 dp f/531.29'md t/1540'md,up wt 67k dn wt 62k trip out of hole f/1500' t/1000' rack back 6 stds, uwt-62 dwt-60 pick up drill pipe - cont p/u 4" dp f/ 1000' t/ 6200', uwt-108k, dwt-75k, fill pipe every 2000', 2.25 drift used on dp cased hole logs - cmt log f/ 6200' t/7600' 850-900'hr/max as per mwd uwt-115, dwt-80, fill pipe @ 7500' and check mwd battery, gpm-220, psi-1900, cal hole fill= 40.6 act fill= 45.5 7/29/14 Test bops cont/test b o p's f/4''test jnt bag,3.5 test jnt top rams ,outter test spool vlv,lower rams inner test spool vlv,bag,250 psi low 3500psi high, koomie test, acc/psi 2900,after function 1700psi,200 charge = 31sec,full charge = 146sec,6 bottel average = 2050 install/remove wear bushing drain stack,pull test plug, set w/r,b/d all test equipment, choke manifold, line up choke manifold and man choke and kill f/normal opps pick up bha pjsm w/slb dd and crew on picking up bha, pick up bha as per slb pick up bha pjsm w/slb picking up nuke source, pick up nuke source and install cont/pu bha as per slb pick up drill pipe single in hole w/4'' ht 40 dp f/531.29'md t/1540'md,up wt 67k dn wt 62k trip out of hole f/1500' t/1000' rack back 6 stds, uwt-62 dwt-60 pick up drill pipe - cont p/u 4" dp f/ 1000' t/ 6200', uwt-108k, dwt-75k, fill pipe every 2000', 2.25 drift used on dp cased hole logs - cmt log f/ 6200' t/7600' 850-900'hr/max as per mwd uwt-115, dwt-80, fill pipe @ 7500' and check mwd battery, gpm-220, psi-1900, cal hole fill= 40.6 act fill= 45.5. 7/30/14 Cased hole logs - f/7600 t/8900' uwt=155k dwt=60k, 850-900ft/hr max cut drilling line - cut 104' drilling line, 16 wraps circulate and condition cond/mud to 10.3ppg all way around up wt 160 dn wt 76k test bops test 7 5/8 csg t/3000psi hold f/30 min (good) b/d kill line drilling cement tag on cmt 8983md, drill out cement,tag on cement plug 9019'md,up wt 160k dn wt 76k, rot wt 108k,gal/min 220,pmp psi 2017,torque on 12k, wob 12k,td rpm 60 drilling cement - drill plugs/shoe @ 9113', gpm-220, rpm- 80 - 90, torq- 12,000-13,000, psi- 2060, wob-5-10k, uwt- 178k, dwt-78k, rwt-108k, drill rat hole t/ 9120' rotary drilling drilled f/ 9120’ md t/ 9140’ md, tvd= 5362’ md, ecds= 11.4 ppg, art= .44 hr, adt=.44 hrs, puw= 178k, sow= 78k, rot= 108k, rpm= 80-90, gpm= 240, psi on= 2060, psi off= 2060, tq on= 12-14 ft/lbs, tq off= 12-13 ft/lbs. Total bit hours= 33.84 bit for tour=.44. change out mud system - swap mud system f/ 10.3 ppg lsnd t/ 10.5 lsnd, circ s/s insure good wt's in and out for lot, gpm- 220, psi-2150, sprs taken at 1830hrs, 9090' md, 5260’ tvd, pump #1 at 2 bpm= 480 psi, at 3 bpm=760 psi. Pump #2 at 2 bpm=500 psi, at 3 bpm= 780 psi mw- 10.5 ppg, formation integrity test (fit) - ru head pin on cmt hose, r/u chart on test spool, fill lines pump down dp and kill lines to insure no air in system, close top rams, 36 stks pumped, 2.5 bbls, broke over at 570 psi, bleed 2L-314 9 back 1.6 bbls, call town to discuss drilling ahead, r/u test pump, attempt another test, pump 28.5 minutes, 6.6 bbls, bleed back 2.1 bbls service rig - full service on top drive, serivce drawworks, serivce crown, ez- torqs, clean up around rig while talked to town formation integrity test (fit) - r/d head pin and cmt hose, blow down kill line cmt line, all good to drill ahead w/ 12.7 emw f/ town. 7/31/14 Rotary drilling cont/drill f/9158'md t/9572'md td, gpm- 237, psi on-2261, psi off- 1815. Rpm-100 tq on-12k, tq off 11k. Pu wt- 167k, sow-92k, rot-108k, art-3.36hrs, adt-3.36hrs, total bit hrs-41.38 total jar hours- 160.78sprs taken at 1120hrs, 9572 md, 9553’ tvd, pump #1 at 2 bpm= 460 psi, at 3 bpm=740 psi. Pump #2 at 2 bpm=470 psi, at 3 bpm= 710 psi mw- 10.5 ppg, circulate and condition circ/bu, up wt 125k,dn wt 105k, rot wt 110k, 10.5 ppg mud back reaming - f/ 9572' t/9355', monitor well 10min, (static), gpm-230, psi off- 2115, rpm- 70, torq off- 10,000-11,000k, rot-110k, uwt- 155k, dwt- 88 open hole logs - take simple's with stethoscope tool @ 9355.9 bit depth, sample depth 9294.9', take one with pumps on and one with pumps off as per stethoscope tool hand back reaming - cont. Pooh f/ 9355' t/ 8600', gpm-220, psi 1980, pump out to top of 39# csg to insure no swabbing, mont. Well 15 min, static, trip out of hole - f/ 8600' t/8100', uwt- 165k dwt- 89k, line up on tt to insure proper hole fill, hole fill correct, line up to pump slug, b/d top drive, line back up on tt, install rubber's and air slips cont. To pooh trip out of hole - f/8100' t/ 531', uwt- 50 dwt-50, mont. Well at bha, cal hole fill=51 act fill=54.6 d pre job safety - l/d bha, remove source lay down bha - r/d 3 stds hwdp w/ jars, l/d well commander, r/b fc, cal hole fill=4.2 act fill 4.3 8/1/14 Lay down bha pjsm w/slb f/removing source, remove source, l/d bha as per dd,clean and clear rig floor pick up 3rd party tools pjsm w/gbr, bring ip tools t/rig floor and r/u trip in hole rih w/3.5 tubing stinger 30 jts,949' mule shoe 'od' 3.5, 'id' 2 7/8, length 3.90, fn 4.5, xo ht 40 x 3.5 eue 'od' 5'', 'id' 2 9/16, length 1.58,3.5 x ht 40 xo length 1.35,pup jt length 14.94 trip in hole r/d gbr c/o 3.5 elevators t/4''elevators, tih w/4'' ht 40 d f/949'mdt/6371' md, up wt 105k dn wt 74k mud wt 10.5ppg12:00 13:30 1.50 6.a trip in hole f/6371', t/9036', uwt 148, dwt 77k, @ shoe service top drive , grease td/wash pipe and drawworks trip in hole f/9036', t/9573', circ bu, psi 1130, gpm 230, spm 78, flow 35%, uwt 161k, dwt 83k, Cement plugs pjsm, pump 5 bbl mud push, test lines t/3500 psi, test was good, pump total 15 bbls, 750 psi 1 bbl h2o, shut bag/choke, drop ball, open bag/choke, pump 17# cement37 bbl, 3.5 bbl mud psuh, 1 bbl h2o, switch to rig to displace, 1000 stk @ 5 bpm, 140 stks @ 2bpm trip out of hole f/9573', t/8900', uwt 163, dwt 83k, pull 20'/pmin circulate and condition psi 2760, gp, 443, spm 150, flow 62%, rack back 1 std and continue to circ hole clean, shut down, monitor well 30 min, pump dry job, bd td, trip out of hole pooh f/8900', t/6465', uwt 136k, dwt 76k. 8/2/14 Trip out of hole cont/pooh f/6465'md t/949'md up wt 40k dn wt 40k 10.5 ppg,cmt/seen @ 1708'md t/surface on 4''dp/3.5 tubbing,4'' displacement calc = 45.4bbls act = 52.6bbls, displacement f/3.5 tubbing cal = 3.3bbls act = 3.2bbls trip out of hole pjsm w/gbr, ru gbr tools, l/d 3.5 tubbing t/pipe shed and xo's/mule shoe,l/d gbr tools, clean clear rig floor, 3.5 tubbing out of pipe shed, load pipe shed w/new bha pick up bha pjsm, bring tools t/rig floor f/bha, pjsm w/slb dd t/mu bha, mu bha as per slb dd, pjsm on p/u nuke source w/slb,install nuke source as per slb trip in hole pjsm,tih w/4'' ht40 dp f/544'md T/1208'md, up wt 51k dn wt 48k, 10.5 ppg mud trip in hole clean and clear floor, install airslips, rih f/1020', t/ 1496', uwt 65k, dwt 60k circulate and condition shallow test @1496',gpm 230, psi 1638, rpm 30, tq off 787, spm 78, flow 30%, b/d td, trip in hole, f/1496, uwt 65k, dwt 60k, t/6787', fill every 20 stds, uwt 123k, dwt 73k, service top drive service td, drawworks, clean and clear floor downtime-top drive rebuild ibop valve, test vavle, test fail, remove and c/o valve key and valve plug packing. 8/3/14 Downtime-top drive -rebuild ibop valve, test-rebuild ibop valve, test vavle, test fail, remove and c/o valve key and valve trip in hole cont/tih f/6787'md t/8964'md, tag cmt @ 8964' md,w/pmps on set wob 15k testcmt, displacement f/tih calc = 10.8bbls act = 6.5bbls rotary drilling drill out cmt f/8964'md t/9123'md, up wt 140, dn wt 99, rot wt 102,wob 5-10k,spm 88, gpm 242,pressure on 2727psi,rpm 60 circulate and condition work stuck pipe,@ 9123'md set jars off @ 247k,rotate and recip/pipe 20'-25', maintain 2L-314 10 circulation,p/u to 9105',pmp psi 2616psi circulate and condition circ/condition mud,stand back stnd #91 9204' md rotate and recip/pipe on stnd #90 9108'md, pump psi 2637,up wt 140k dn wt 99k rot wt 102k rpm rotary drilling make connection stnd #91@9108'md', t/9148'md, cont/drilling pump psi 2470, torque 14k,gpm 246,wob 5-10k,up wt161.78,10.5 ppg mud rotary drilling drill f/ 9148 t/9204, gpm- 242, psi on- 2616, psi off- 2488.rpm-60tq on-12.5k, tq off 10k. Pu wt- 195k, sow-70k, rot-110k, md, 9205 tvd 5290', mw- 10.5ppg, back reaming drill f/ 9204 t/9012â, gpm- 240,psi off- 2400. Rpm-60, tq off 10k. Pu wt- 210k, sow-73k, rot-110k, build volume - weight monitor well, take on new mud in pits and dump old mud, prep for displacement displace to water base pump 50bbl high vis, chase with kla-shield all the way aound till clean, psi 2400, gpm 234, spm 78, tq 11k, rot 102k, rpm 60 trip in hole rih f/9110', t/9204', dwt 85k, uwt 140k, gpm 230, psi 1800, spr #1 @ 30 spm=400 psi, @45 spm=630 psi, #2 @ 30spm=390psi, @45 spm=620psi @ 19:00hr, md 9204' tvd 5259' rotary drilling drill f/ 9204 t/9490, gpm- 236, psi on-1950, psi off- 1850 . Rpm-120tq on-10k, tq off 9k. Pu wt- 145k, sow-90k, rot-110k, art-5.54hrs, adt-5.54hrs, total bit hrs-6.54total jar hours-168.32sprs taken at 2345hrs, 9490md, 5342â tvd, pump #1 at 2 bpm= 390 psi, at 3 bpm=660 psi. Pump #2 at 2 bpm=400 psi, at 3 bpm= 670 psi mw- 10.5ppg, 135k dn wt 100k, rot wt 102k, adt = 1.0, bit = 1.0. 8/4/14 Rotary drilling drill f/ 9490 t/9998, gpm- 240, psi on 2142, psi off-2044. Rpm-130 tq on 8k, tq off 8k. Pu wt- 145k, sow-92k, rot-105k, art-7.67hrs, adt-7.67hrs, total bit hrs-14.22 total jar hours-175.00, sprs taken at 1130hrs, 9992 md, 5337 tvd, pump #1 at 2 bpm= 480 psi, at 3 bpm=740 psi. Pump #2 at 2 bpm=470 psi, at 3 bpm= 730 psi mw- 10.5 ppg rotary drilling drill f/ 9998 t/10251, gpm- 239, psi on-2160, psi off- 2050 . Rpm-130tq on-7.5k, tq off 7k. Pu wt- 143k, sow-91k, rot-105k, mw- 10.5 ppg, housekeeping, painting, cleaning rotary drilling drill f/ 10251t/10537, gpm-236, psi on-2180, psi off- 2050. Rpm-130 tq on-8k, tq off 7k. Pu wt- 143k, sow-90k, rot-105k, art-9.16hrs, adt-9.16hrs, total bit hrs 23.38total jar hours-184.16sprs taken at 2330hrs, 10442 md, 5332 tvd, pump #1 at 2 bpm= 510 psi, at 3 bpm=790 psi. Pump #2 at 2 bpm=510 psi, at 3 bpm= 800 psi mw- 10.5 ppg. 8/5/14 Rotary drilling drill f/ 10537 t/10824, gpm- 240, psi on-2243, psi off-2210. Rpm-130 tq on-8k, tq off 7k. Pu wt- 147k, sow-90k mw- 10.5 ppg, housekeeping, painting, cleaning. Rotary drilling f/ 10824 t/11015, gpm- 236, psi on-2144, psi off-1965. Rpm-130 tq On-8k, tq off 7k. Pu wt- 149k, sow-92k, rot-108k, art-7.51hrs, adt-7.51hrs, total bit hrs-30.91 total jar hours-191.70sprs taken at 1000hrs, 10921 md, 5338 tvd, pump #1 at 2 bpm= 490 psi, at 3 bpm=740 psi. Pump #2 at 2 bpm=470 psi, at 3 bpm= 730 psi mw- 10.5 ppg, rotary drilling drill f/ 11015 t/11301, gpm-235, psi on-2217, psi off- 218 . Rpm-130 tq on-8.5k, tq off 8k. Pu wt- 145k, sow-87k, rot-100k, sprs taken at 1930hrs, 11396md, 5337 tvd, pump #1 at 2 bpm= 530 psi, at 3 bpm=800 psi. Pump #2 at 2 bpm=530 psi, at 3 bpm= 810 psi mw-10.5 ppg rotary drilling drill f/ 11301 t/11588, gpm- 238, psi on-2300, psi off- 2210. Rpm-130 tq on-8.6k, tq off 6.2k. Pu wt- 145k, sow-85k, rot- 105k, art-7.79hrs, adt-7.79hrs, total bit hrs-39.7 total jar hours-199.49sprs mw- 10.5 ppg. 8/6/14 Rotary drilling drill f/11588 t/11622, gpm-239, psi on-2290, psi off- 2130. Rpm-130 tq on-8k, tq off 7k. Pu wt- 145k, sow-85k, rot-105k, art-1 hrs, adt-1hrs, total bit hrs-40.24 total jar hours-201.02sprs taken at 0030hrs, 11622 md, 5369 tvd, pump #1 at 2 bpm= 540 psi, at 3 bpm=800 psi. Pump #2 at 2 bpm=500 psi, at 3 bpm= 790 psi mw-10.5 ppg, trip out of hole brooh f/11622'md t/9014'md,pmp psi 2040, up wt 137k dn wt 92k,rotate wt 105k,tq 6k, rpm 120 circulate and condition drop ball pump @ 85 spm418psi, pressure up @ 1300psi held f/42 sec, increase t/1800psi held f/30sec tool open at 1920psi circulate and condition circ/cond mud, rotate @ 120rpm,up wt 103k dn wt 102k,rot wt 102k,gal/min 522, pmp psi 2777,pump 35 bbl high vis sweep circulate and condition pump ball to close well comander, 28 spm, 83 gpm, 273 psi, closed at 1480 psi, 590 stks; reaming/washing pooh while pumping f/ 9009', t/8633', 81 spm, 238 gpm, 2077 psi, flow 40%, uwt. Continue to pooh unitl the bha. 8/7/14 Lay down bha cont/ld nuks and bha #4 as per slb, clean clear rig floor pick up 3rd party tools pjsm w/gbr, bring tools to rig floor and r/u as per gbr trip in hole pjsm w/gbr conoco rep and crew f/liner run, tih w/4.5 liner t/2720.59'md,up wt 56k dn wt 54k, mud wt 10.5,cal disp 11.2bbls, act disp 10bbls completion-liner- running pjsm, start w/hydril 521, f/2216.93, t/2713.12' uwt 65k, dwt 60k, mu zxp packer, spot pal mix, 30 2L-314 11 min wait, cont run 4'dp circulate and condition verify flow and paramaters, cir @ 5 bpm, 217 gpm, 275 psi, 31% flow, pvt 101bbls, 73 spm, @ 2808.83' trip in hole f/2808', t/7280'md, uwt 87k, dwt 76k,displacement calc 22bbls act 25bbls. 8/8/14 Trip in hole cont/tih w/liner, f/7280'md t/9077'md up wt 127k,dn wt 88k circulate and condition circ/2 bu w/o exceeding 1200 psi, pump psi 525, 148 gal/min, 50 spm , 3.5 bpm. No losses due to well bore. Trip in hole -rih, uwt 136k, dwt 87k, @ 10038', cont. Rih t/11371'. Trip in hole f/11371', t/ 11622', uwt 148k, dwt 90k, tagged @ 11613.9' trip in hole tag bottom at 11613', 18k dwn, 70k wt, pu to break over wt. + 2' sd 11605.85', circ dp vol 1282 stks, drop 1.5 ball, so/pu to sd in tension, psi up t/2200k, set packer, so to block wt, psi up t/2803, shear out early, attempt to release tool, fail, drop 1.75 ball, pump down, psi up 2200k, so, psi 3200, release tool, psi 4300, p/u break over 133k, p/u 6' release dogs, so, pu, rpm 15 so t/block wt, e pressure test csg/shoe purge kill line, open 4" for tattle, psi t/ 2100, hold 30 min, loss 60 psi, held additional 30 min 20 psi loss displace to water base pjsm, fill dirty trucks, start displacement, @19:40, spm 142, gpm 420, psi 8/9/14 Cut drilling line finish cutting drill line; adjust brakes on draw works and service td, crown and dw's. Check com to varify proper function after cut. Lay down drill pipe l/d 125 jts of 4" dp f/ 8768' t/ 4789' up wt 120k dn wt 90k. Trip out of hole f/ 4789' t/ 2575' l/d 70 jts of 4" dp, up wt 85k dn wt 75k. Trip in hole run remaining 25 stds f/ the derrick in the hole f/ 2575' t/ 4937' up wt 90k dn wt 75k. Lay down drill pipe f/ 4937' t/ 2566' up wt 70k dn wt 70k. Inspecting each jt for wash outs and inspecting hard band. Lay down drill pipe start jt 268-351, f/2566', t/surface, uwt 70k, dwt 70k. Inspecting each jt for wash outs and inspecting hard band. Install/remove wear bushing remove wear bushing, drain stack completion-pu, ld, makeup tools, bha clean clear floor, pu equip for running tbg completion-trip tubing/dp run 3.5 9.3 ppf l-80 eue upper competion, uwt 53k, dwt 52k, @2585'. 2L-314 12 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to provisional picks by the wellsite geologist. PROGNOSED LWD PICK FORMATION MD (ft) TVD (ft) MD (ft) TVD (ft) C-80 2618’ 2460’ 2642’ 2480’ Campanian Sand 2702’ 2516’ 2715’ 2531’ C-50 5271’ 3711’ 5379’ 3744’ C-40 6263’ 4158’ 6325’ 4158’ C-37 6821’ 4391’ 6818’ 4361’ Iceberg 6956’ 4438’ 7019’ 4434’ T-7 8073’ 4890’ 7899’ 4790’ T-4.1 8557’ 5088’ 8565’ 5067’ Top Bermuda (Pilot Hole) 9280’ 5326’ 9149’ 5277’ Seismic Bermuda (Pilot Hole) 9363’ 5357’ 9232’ 5302’ Base Bermuda (Pilot Hole) 9453’ 5395’ 9365’ 5349’ C-35 9572’ 5453’ 9403 5363’ Pilot Hole TD 9785’ 5582’ 9573’ 5442’ Top Bermuda Target (Production Hole) 9303’ 5326’ 9149’ 5277’ Top Seismic Bermuda (Production Hole) 9538’ 5359’ 9250’ 5301’ TD/Toe Target (Production Hole) 11605’ 5413’ 11622’ 5368’ 2L-314 13 3.2 Mudlog Summary 3.2.1 C-80 2642’ to 2715' MD (-2623' to -2674' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 211.3 41.4 148.4 49 2 27.7 Claystone (2535' - 2700') = medium dark gray to medium light gray; lumpy to clumpy consistency; pulverulent to malleable tenacity; irregular to earthy fracture; massive to nodular cuttings habit; dull to earthy to slight greasy luster; smooth to slightly gritty texture; massive to thick structure; intergrading to similarly colored siltstone with dense to crunchy tenacity and blocky fracture along with tabular cuttings habit; trace dark fines; non-calcareous; no fluorescence or other hydrocarbon indicators. Claystone (2700' - 2750') = medium dark gray to medium light gray; lumpy to curdy consistency; pulverulent to malleable tenacity; irregular to earthy fracture; massive to nodular cuttings habit; dull to earthy to slight greasy luster; smooth to very fine gritty texture; massive to thick structure; intergrading to similarly colored siltstone with dense to crunchy tenacity and blocky fracture along with tabular cuttings habit; trace dark fines; trace lower very fine to lower medium white to medium gray colored quartz sand occurring in thin stringers in the finer rocks; non-calcareous; no fluorescence or other hydrocarbon indicators. 3.2.2 Campanian Sand 2715’ to 5379' MD (-2674' to -3887' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 377.5 0.2 155 60 3 29.8 Claystone (2750' - 2850') = medium dark gray to light gray with white hues; lumpy to curdy; pulverulent to malleable tenacity; irregular to earthy fracture; massive to nodular cuttings habit; dull to earthy to slight waxy luster; silty to gritty; massive to thick structure; grading to gritty siltstone of similar color with dense to crumbly tenacity, and blocky fracture; cuttings habit becoming more tabular with depth; increasingly common sand and some silty matrix supported sandstone composed of white to dark gray quartz, dark lithics, trace biotite; occurring in thin beds in finer rocks; trace to slight calcareous; no fluorescence or other hydrocarbon indicators. Claystone (2750' - 2850') = medium dark gray to light gray with white hues; lumpy to curdy; pulverulent to malleable tenacity; irregular to earthy fracture; massive to nodular cuttings habit; dull to earthy luster; silty to gritty texture; massive to thick structure; grading to very gritty siltstone of similar color with dense to crumbly tenacity, blocky fracture and common dark fines; some stringers of grain and matrix supported sandstone composed of white to dark gray quartz; calcareous; no fluorescence or other hydrocarbon indicators. Claystone (2850' - 3000') = light to medium gray with dark gray hues; lumpy to curdy; pulverulent to malleable tenacity; irregular to earthy fracture; massive to tabular cuttings habit; dull to earthy luster; very gritty texture; massive to thick structure; intergrading to siltstone and sandstone with tough to crumbly tenacity, blocky fracture, tabular cuttings habit, and gritty texture with similar luster and color to claystone, and composed of clear to dark gray quartz grains and dark lithics mostly occurring as thin stringers in claystone. Claystone (3000' - 3100') = light to medium gray with dark gray hues; clumpy to curdy; pulverulent to 2L-314 14 malleable tenacity; irregular to earthy fracture; massive to tabular cuttings habit; dull to earthy luster; very gritty texture; massive to thick structure; intergrading to siltstone with tough to crumbly tenacity, irregular blocky fracture, tabular cuttings habit, fine gritty to smooth texture, dull luster and gray color; sand composed of clear to dark gray quartz grains and dark lithics commonly occurs in thin stringers in claystone; non-calcareous; no fluorescence or other hydrocarbon indicators. Claystone (3100' - 3200') = medium to dark gray with lighter hues; adhesive; clumpy to curdy; pulverulent to malleable tenacity; irregular to earthy fracture; massive to tabular cuttings habit; dull to earthy luster; very gritty texture; massive to thick structure; intergrading to siltstone with tough to crumbly tenacity, irregular blocky fracture, tabular cuttings habit, fine gritty to smooth texture, dull luster and gray color; sand composed of clear to dark gray quartz grains and dark lithics commonly occurs in thin stringers in claystone; non-to trace calcareous; no fluorescence or other hydrocarbon indicators. Claystone (3200' - 3300') = medium to dark gray with lighter hues; adhesive; clumpy to curdy; pulverulent to malleable tenacity; irregular to earthy fracture; massive to tabular cuttings habit; dull to earthy luster; very gritty texture; massive to thick structure; intergrading to siltstone with tough to crumbly tenacity, irregular blocky fracture, tabular cuttings habit, fine gritty to smooth texture, dull luster and gray color; sands composed of clear to dark gray quartz grains and dark lithics commonly occur in thin stringers in claystone; non-to trace calcareous; these can grade to sandstone also occurring in very thin stringers or beds; some sandstone cuttings exhibit pale yellow fluorescence; no other hydrocarbon indicators. Claystone (3200' - 3300') = medium to dark gray with lighter hues; adhesive; very clumpy to curdy; pulverulent to malleable tenacity; irregular to earthy fracture; massive to tabular cuttings habit; dull to earthy luster; very gritty texture; massive to thick structure; intergrading to siltstone with tough to crumbly tenacity, irregular blocky fracture, tabular cuttings habit, fine gritty to smooth texture, dull luster and gray color; sands composed of clear to dark gray quartz grains and dark lithics commonly occur in thin stringers in claystone; non-calcareous; cuttings of sandstone as above also common in this interval but do not exhibit fluorescence or other hydrocarbon indicators. Claystone (3300' - 3400') = medium to dark gray with lighter hues; adhesive; very clumpy to curdy; pulverulent to malleable tenacity; irregular to earthy fracture; massive to tabular cuttings habit; dull to earthy luster; very gritty texture; massive to thick structure; intergrading to siltstone with tough to crumbly tenacity, irregular blocky fracture, tabular cuttings habit, fine gritty to smooth texture, dull luster and gray color; sands composed of clear to dark gray quartz grains and dark lithics commonly occur in thin stringers in claystone; non-calcareous; cuttings of sandstone as above also common in this interval but do not exhibit fluorescence or other hydrocarbon indicators. Siltstone (3510' - 3555') = dark gray to grayish black colors firm friable to moderate hard hardness; crunchy to stiff tenacity; slight splintery to hackly fracture; wedgelike to platy and elongated cuttings habit; frosted when wet and earthy to dull when dry luster; silty to matte texture; thin bedding structure; no visual fluorescence; no hydrocarbon indicators; no HCl reaction. Claystone (3565 - 3620') = olive gray to medium gray and slight dark gray colors; cohesive to colloidal clay properties; clotted to lumpy consistency; malleable to pulverulent tenacity; earthy to irregular fracture; massive to nodular cuttings habit; earthy to slight waxy luster; smooth to clayey texture; massive to thick bedding structure; no HCl reaction in bulk sample; no hydrocarbon indicators in bulk sample. Sandstone (3630' - 3700') = medium dark gray to dark gray with translucent to clear minerals, black lithics, light olive hues, and very pale yellowish orange mineral colors; quartz dominant with occasional lithics framework; lower fine to lower medium grain size; moderate to well sorting; subangular to angular angularity; low to very low sphericity; easily friable to firm friable hardness; grain enlargement cement; matrix grain support; thin bedding structure; very weak HCl in sandstone; no hydrocarbon indicators in sample. Claystone (3710' - 3775') = olive gray to light olive gray with medium dark gray hues colors; cohesive to 2L-314 15 expansive clay properties; clotted to pasty consistency; pulverulent to malleable tenacity; earthy to irregular fracture; nodular to massive cuttings habit; earthy to waxy when wet luster; smooth to clayey and slight silty texture; massive to soft sediment deformation bedding structure; moderate HCl reaction in bulk sample; traces of yellowish green color in visual fluorescence color; no other oil indicators. Sandstone (3785' - 3850') = olive gray to brownish black with white to clear minerals, black lithic interbedded, and brownish slight reddish minerals colors; quartz dominant with black lithics; upper fine to lower medium grain size; well to fair sorting; subangular to subrounded angularity; moderate sphericity; friable to hard hardness; grain enlargement cement; matrix grain support; thin bedding structure; weak HCl reaction in bulk sample; traces orange yellowish visual fluorescence; no other hydrocarbon indicators in bulk sample. Claystone (3860' - 3930') = olive gray to light olive gray with medium dark gray hues, and dark gray hues colors; cohesive to expansive clay properties; clotted to mushy consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cuttings habit; earthy to waxy luster; clayey to smooth with slight grains in texture; thick to soft sediment deformation bedding structure; weak HCl reaction in bulk sample; traces of yellowish visual fluorescence; no other hydrocarbon indicators; very weak HCl reaction in bulk sample. Siltstone (3940' - 3980') = dark gray to medium dark gray with olive gray hues crunchy to stiff tenacity; hackly to blocky fracture; tabular to platy cuttings habit; dull to earthy luster; matte to silty texture; thin bedding structure; no hydrocarbon indicators in bulk sample; moderate HCl reaction in bulk sample. Claystone (4015' - 4075') = olive gray to light olive gray with grayish black hues, and medium dark gray hues colors; cohesive to colloidal clay properties; mushy to pasty and stiff when dry consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to nodular cuttings habit; waxy to earthy luster; clayey to smooth with occasional gritty to silty texture; thick to soft sediment deformation bedding structure; weak HCl reaction in bulk sample; no hydrocarbon indicators in bulk sample. Siltstone (4085' - 4125') = dark gray medium gray with medium gray hues colors; crumbly to brittle tenacity; earthy to slight hackly fracture; elongated to bladed wedgelike cuttings habit; earthy to dull luster; very thin lenticular bedding structure; no HCl reaction on siltstone; no hydrocarbon indicators in bulk sample. Sandstone (4135' - 4205') = grayish black to dark gray with light greenish gray hues, light olive gray hues, black lithics, very pale orange hues, and clear to translucent minerals color; quartz dominant with lithics and calc framework; very fine to fine grain size; fair to well sorting; angular to subangular angularity; low to moderate sphericity; consolidated to friable hardness; grain enlargement to overgrowths cement; matrix to cement grain support; thin bedding structure; very weak HCl reaction on sandstone; no hydrocarbon indicators in bulk sample. Claystone (4215' - 4280') = olive gray to light olive gray with dark gray to medium dark gray hues color; cohesive to expansive clay properties; lumpy to mushy and clotted consistency; malleable tenacity; irregular to earthy fracture; massive to rounded and curl cuttings habit; waxy to earthy when wet and earthy to slight dull when dry luster; smooth to clayey and occasional silty texture; thick to increasing bedding structure; no HCl reaction on claystone no hydrocarbon indicators in sample. Sandstone (4290 - 4360') = grayish black to dark gray with light greenish gray hues, yellowish gray hues, black lithics, very pale orange hues, and white to translucent minerals color; quartz dominant with lithics and calc framework; very fine to fine grain size; fair to well sorting; angular to subangular angularity; low to moderate sphericity; consolidated to friable hardness; grain enlargement to overgrowths cement; matrix to cement grain support; thin bedding structure; weak HCl reaction on sandstone; no hydrocarbon indicators in bulk sample. Claystone (4370' - 4430') = olive gray to light olive gray with medium gray hue to medium gray hues 2L-314 16 colors; cohesive to colloidal clay properties; clotted to mushy consistency; malleable tenacity; earthy to irregular fracture; massive to rounded cuttings habit; waxy to earthy when wet luster; colloidal to clayey with smooth texture; massive to thick bedding structure; trace tuff sediments; no visual fluorescence colors; no hydrocarbon indicators; weak HCl reaction in bulk sample. Sandstone (4440' - 4500') = brownish black to olive black with grayish black hues, and brownish gray hues colors; quartz dominant with traces of black lithics framework; very fine to medium grain size; poor to fair sorting; angular to subrounded angularity; low to moderate sphericity; consolidated sands to easily friable hardness; grain enlargement cement; matrix grain support; increasing in size bedding structure; no hydrocarbon indicators; very weak HCl reaction in bulk sample. Claystone (4535' - 4595') = medium dark to dark gray and slight grayish black hues colors; expansive to cohesive clay properties; clotted to clumpy consistency; malleable to pulverulent tenacity; irregular to earthy fracture; nodular to massive cuttings habit; earthy to waxy when wet luster; smooth to clayey with gritty and silty occasional texture; thick to soft sediment deformation bedding structure; no hydrocarbon indicators; very weak HCl reaction. Sandstone (4605' - 4690') = olive gray to dark gray with light olive gray hues, translucent to smoky minerals; black lithics, yellowish gray hues, and moderate brown hues colors; quartz dominant occasional calcareous mineral and lithics framework; very fine and fine grain size; well to fair sorting; angular to subrounded angularity; moderate to high sphericity; consolidated to friable hardness; slight grain enlargement to dolomite cement; matrix and cement grain support; thick bedding structure; one yellowish green part of sediment in visual fluorescence in bulk sample; no other hydrocarbon indicators; very weak HCl reaction in bulk sample. Sand (4700' - 4755') = translucent to clear with smoky, pale greenish yellow, light brown, black, and grayish black colors; quartz dominant with lithics; very fine to medium and occasional coarse; fair to poor sorting; rounded to subangular angularity; high to low sphericity; unconsolidated sands; thin to rip up bedding structure; no HCl reaction in bulk sample; no hydrocarbon indicators in bulk sample. Sandstone (4760' - 4830') = olive black to brownish black with black lithics, translucent to clear minerals, light olive gray hues, and pale yellowish orange hues colors; quartz dominant with black lithic and calcareous minerals framework; fine to very fine grain size; well to fair sorting; angular to subangular angularity; moderate to low sphericity; consolidated to easily friable hardness; matrix and cement grain support; overgrowths cement; thick to massive bedding structure; no hydrocarbon indicators; very weak HCl reaction in bulk sample. Sandstone (4840' - 4920') = dark gray to grayish black with translucent to white and clear minerals, black lithics, greenish gray hues, olive gray and light olive gray hues colors; quartz dominant with calcareous and lithics interbedded framework; very fine to lower medium grain size; fair to poor sorting; round to subangular angularity; high to moderate sphericity; consolidated to friable hardness; grain enlargement and overgrowth cement; matrix and cement grain support; massive to thick bedding structure; few yellowish green visual fluorescence colors; no other hydrocarbon indicators; weak HCl reaction in bulk sample. Sandstone (4950' - 5020') = dark gray to medium dark gray with occasional olive gray hues, light olive gray hues, green gray hue, black lithics, and clear to translucent minerals; quartz dominant with lithics framework; lower fine to upper medium grain size; poor to fair sorting; subangular to rounded angularity; moderate to high sphericity; consolidated to firm friable hardness; grain enlargement cement; cement and matrix grain support; massive to thick bedding structure; no hydrocarbon indicators; weak HCl reaction in bulk sample. Siltstone (5030' - 5070') = olive black to grayish black with dark gray hues colors; stiff to dense tenacity; earthy to mottled fracture; tabular to platy cuttings habit; dull to earthy luster; matte to silty with sucrosic texture; thin bedding structure; no hydrocarbon indicators in bulk sample; weak HCl reaction in bulk sample. 2L-314 17 Sandstone (5080' - 5155') = olive black to grayish black with translucent to clear minerals, black lithic, olive gray to greenish gray hues, and smoky white colors; quartz dominant with black lithics, and calcareous minerals framework; very fine to fine grain size; well to fair sorting; subrounded to subangular angularity; high to low sphericity; consolidated sands to firm friable; grain enlargement to overgrowths cement; matrix and cement grain support; massive to thick bedding structure; no HCl reaction in bulk sample; no hydrocarbon indicators in bulk sample. Sand (5165' - 5220') = clear to translucent with black lithics, smoky to white minerals; reddish orange minerals colors; quartz dominant framework with lithic and tuff; very fine grain to medium grain size; fair to poor sorting; angular to subrounded angularity; moderate to low sphericity; unconsolidated sands; thin to contorted bedding structure; moderate HCl reaction in bulk sample; no hydrocarbon indicators in bulk sample. Claystone (5230' - 5285') = olive gray to light olive gray with dark gray hues colors; cohesive to expansive; clotted to mushy consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded tabular cuttings habit; earthy to waxy luster; silty to clayey and colloidal texture; thin to lenticular bedding structure; weak HCl reaction in bulk sample; no hydrocarbon indictor in sample. Sandstone (5295' - 5365') = dark gray to medium dark gray with occasional olive gray hues, light olive gray hues, blue gray hue, black lithics, and clear to translucent minerals; quartz dominant with lithics framework; lower fine to upper fine grain size; poor to fair sorting; subangular to rounded angularity; moderate to high sphericity; consolidated to firm friable hardness; grain enlargement cement; cement and matrix grain support; massive to thick bedding structure; three pieces of yellowish green visual fluorescence colors; no other hydrocarbon indicators in bulk sample; weak HCl reaction in bulk sample. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 2811’ 26.000 5198 0 0 0 0 0 0 3352’ 37.914 6890 111 127 50 0 0 0 3906’ 18.621 4718 77 137 0 0 0 0 4000’ 33.259 5986 90 71 0 0 0 0 4004’ 32.224 5803 86 68 0 0 0 0 4332’ 42.155 9447 98 69 0 0 0 0 4417’ 32.017 6895 174 134 0 0 0 0 4504’ 37.345 7943 180 66 0 0 0 0 3.2.3 C-50 5379’ to 6325' MD (-3887' to -4015' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 248.1 0.2 122.1 972 18 143.1 Claystone (5385' - 5450') = dark gray to olive gray with light olive gray hues colors; cohesive clay properties; mushy to pasty consistency; malleable tenacity; irregular fracture; massive to wedgelike cuttings habit; dull earthy luster; smooth to gritty texture; thin to thick structure; common dark fines; intergrading to siltstone of similar color with crunchy tenacity, blocky fracture, wedgelike cuttings habit, gritty texture and thin laminar structure; interbedded with thin beds of sandstone and sand in places. Claystone (5450' - 5600') = dark gray to medium olive gray with olive gray hues; adhesive; plastic; 2L-314 18 colloidal; clumpy to pasty and curdy; malleable; irregular blocky fracture; massive cuttings habit; earthy to greasy luster; smooth to gritty texture; thick structure; intergrading to dark olive gray siltstone with medium gray and darker hues; brittle to pulverulent; irregular blocky fracture; fine tabular to wedgelike cuttings habit; dull earthy to sparkling luster at high magnifications; gritty to granular texture; thin structure; common dark fines and sand grains; intergrading to softer claystone and gray sandstone with medium gray and darker hues; lower very fine to lower fine grained with some coarser grains; fair to well sorted; subangular to rounded; moderate low to high sphericity; hard to friable; possible cement in harder cuttings; grain supported; composed of clear to gray quartz, with common dark lithics occurring as thin beds in thicker claystones and siltstone; all three types of rock can contain dark possibly carbonaceous fines; thin pale white to pale brown ash also occurs in trace amounts in samples from this interval, and exhibits moderate reaction to HCl; overall sample is non to slightly calcareous; no hydrocarbon indicators. Claystone (5600' - 5650') = medium olive gray to dark gray; slightly adhesive; colloidal; clumpy to pasty; malleable to pulverulent; irregular blocky fracture; massive to fine nodular cuttings habit; dull earthy to waxy luster; silty to smooth texture; thick to thin laminar structure; intergrading to siltstone and shale in places; trace to no ash in samples; non- to slightly calcareous; no hydrocarbon indicators. Claystone (5650' - 5750') = medium olive gray to dark gray; slightly adhesive; colloidal; clumpy to pasty; malleable to pulverulent; irregular blocky fracture; massive to fine nodular cuttings habit; dull earthy to waxy luster; silty to smooth texture; thick to thin structure; intergrading to siltstone and shale; trace ash; no hydrocarbon indicators. Claystone (5650' - 5800') = medium olive gray to dark gray; slightly adhesive; colloidal; curdy to mushy; malleable to pulverulent; blocky to earthy fracture; massive to fine nodular cuttings habit; dull earthy to greasy luster; silty to gritty texture; thick structure; intergrading to gray siltstone and shale; trace ash; no hydrocarbon indicators. Claystone (5800' - 5850') = medium olive gray to dark gray; moderately adhesive; colloidal; curdy to mushy; malleable to pulverulent; blocky to earthy fracture; massive to fine nodular cuttings habit; dull earthy to greasy luster; silty to gritty texture; thick structure; intergrading to siltstone and shale; trace sand, ash; no hydrocarbon indicators; some nutplug LCM additive in sample. Claystone (5850' - 5950') = medium olive gray to dark gray; strongly adhesive; colloidal; clumpy to mushy; malleable to pulverulent; blocky to earthy fracture; massive to nodular cuttings habit; dull earthy to greasy luster; silty to gritty texture; thick structure; intergrading to siltstone and shale; trace sand, ash; no hydrocarbon indicators; no additive in sample; siltstone and shale in this zone have dark olive hue, are brittle to crunchy, planar to splintery fracture; have elongated to platy cuttings habit, dull earthy luster; smooth to gritty texture, and thin laminar to fissile structure; very weak HCl reaction in sample; no hydrocarbon indicators in bulk sample. Siltstone (5960' - 6005') = dark gray to grayish black with olive gray hues colors; brittle to crumbly tenacity; earthy to slight hackly fracture; platy to wedgelike and bladed edges cuttings habit; dull to earthy luster; matte to silty texture; thin to lenticular bedding structure; weak HCl reaction in bulk sample; no hydrocarbon indicators in bulk sample. Claystone (6015' - 6065') = medium dark gray to dark gray colors; cohesive to colloidal clay properties; pasty to mush consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cuttings habit; clayey to silty and occasional gritty texture; massive to thick bedding structure; traces of yellowish orange in visual fluorescence colors; no reaction in HCl bulk sample. Siltstone (6075' - 6120) = olive black to dark gray with grayish black hues; brittle to crumbly tenacity; earthy to slight hackly and mottled fracture; elongated to wedgelike and bladed edges cuttings habit; dull to earthy when dry luster; thin to lenticular bedding structure; very weak HCl reaction in bulk sample; no hydrocarbon indicators in bulk sample. Claystone (6130' - 6190') = olive gray to light gray with dark gray hues, and medium dark gray hues colors; 2L-314 19 cohesive to expansive clay properties; gelatinous to clotted consistency; malleable to pulverulent tenacity; earthy to irregular when dry fracture; nodular to rounded cuttings habit; waxy to earthy when wet luster; thin bedding structure; traces of tuff with yellowish orange visual fluorescence colors; no other hydrocarbon indicators; moderate HCl reaction in bulk sample. Siltstone (6220' - 6275') = grayish black to black and dark gray hues; brittle to crumbly; earthy to slight hackly fracture; platy to elongated with bladed edges cuttings habit; frosted to earthy when wet luster; matte to silty texture; thick bedding structure; traces of yellowish orange color in visual fluorescence color; very weak HCl reaction in bulk sample; no other hydrocarbon indicators in the bulk sample. Siltstone (6285' - 6330') = dark gray to grayish black with olive gray hues; brittle to crumbly tenacity; earthy to slight hackly fracture; platy to wedgelike and bladed edges cuttings habit; dull to earthy luster; matte to silty texture; thin to lenticular bedding structure; strong HCl reaction in bulk sample; traces of yellowish green and orange colors in visual fluorescence; no other hydrocarbon indicators in sample. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 5684’ 225 33905 2290 1176 449 910 233 242 5800’ 155 22296 1483 876 304 647 225 171 6073’ 147 22710 1519 809 282 657 174 166 6219’ 219 31551 2131 1114 535 1094 290 342 3.2.4 C-40 6325’ to 6818' MD (-4015' to -4218' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 183.2 15.2 115.9 376 52 208 Siltstone (6340' - 6395) = olive black to dark gray with grayish black hues colors; brittle to crumbly tenacity; earthy to slight hackly and mottled fracture; elongated to wedgelike and bladed edges cuttings habit; dull to earthy when dry luster; thin to lenticular bedding structure; strong HCl reaction in bulk sample; traces of yellowish green colors in visual fluorescence in bulk sample; no other hydrocarbon indicators. Siltstone (6400' - 6500') = dark olive gray to dark gray; malleable to crumbly tenacity; earthy to irregular blocky fracture; massive to elongated tabular cuttings habit; dull to earthy luster; clayey to gritty granular texture; thin to fissile structure; intergrading to claystone that can be adhesive and shale; traces of nutplug in sample; interbedded with thin stringers of sand; sample moderately calcareous; no hydrocarbon indicators. Siltstone (6500' - 6550') = dark olive gray to dark gray; crunchy to crumbly tenacity; irregular blocky fracture; fine nodular to tabular and planar cuttings habit; dull to earthy luster; colloidal to gritty granular texture; thin to fissile structure; increasingly arenaceous, intergrades to claystone and shale; traces of ash in sample; sand is very fine to medium grain quartz and dark lithics and likely occurs as thin beds; sample moderately calcareous; no hydrocarbon indicators. Siltstone (6550' - 6650') = dark olive gray to dark gray; crunchy to crumbly tenacity; irregular blocky fracture; fine nodular to tabular and planar cuttings habit; dull to earthy luster; colloidal to gritty granular texture; thin to fissile structure; increasingly arenaceous, intergrades to claystone, shale some of which is carbonaceous shale; traces of ash and pyrite; sand is very fine to fine grain quartz with dark lithics grading to sandstone in places, and occurs in thin stringers or beds; sample is moderately calcareous; no 2L-314 20 hydrocarbon indicators; there is LCM in sample including nut plug additive. Claystone (6660' - 6735') = dark gray to olive gray with medium dark gray hues; cohesive to colloidal clay properties; clotted to lumpy consistency; malleable to pulverulent tenacity; earthy to irregular fracture; nodular cuttings habit; waxy to earthy when wet luster; clayey to smooth and slight silty texture; thin soft sediment deformation bedding structure; traces of yellowish white colors in visual fluorescence; no other oil indicators in bulk sample; weak to moderate HCl reaction in bulk sample. Siltstone (6735' - 6785') = dark gray to grayish black colors; friable to easily friable hardness; crumbly to brittle tenacity; earthy to slightly hackly fracture; platy to wedgelike with elongated bladed edges cuttings habit; earthy to dull luster; matte to silty texture; thick and slightly banded bedding structure; traces of yellowish green colors in visual fluorescence; weak HCl reaction in bulk sample; no other hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6651’ 211 30205 2005 1067 485 958 306 322 6687’ 206 29127 2020 1027 438 936 295 236 3.2.5 C-37 6818’ to 7019' MD (-4218' to -4291’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 204.1 126.7 142.8 292 107 202 Sandstone (6800' - 6880') = clear to translucent with smoky hues, white hues, and light gray hues colors; quartz dominant framework; very fine to fine grain size; well to fair sorting; angular to subangular angularity; low to moderate sphericity; consolidated to firm friable hardness; overgrowths and grain enlargement cement; cement and slight matrix grain support; thin to lenticular bedding structure; weak to moderate HCl reaction in bulk sample; few yellowish green visual fluorescence in bulk sample; no hydrocarbon odor in sample; no fluorescence cut color; no cut fluorescence color; no streamer; no other hydrocarbon indicators. Siltstone (6890' - 6960') = dark gray to medium dark gray with grayish black hue colors; firm friable to moderate hard hardness; dense to stiff tenacity; splintery to hackly fracture; wedgelike to platy and tabular cuttings habit; matte to silty and slight sucrosic texture; massive to thick bedding with occasional laminae bedding structure; traces of yellowish orange color in visual fluorescence; no hydrocarbon odor or odor near shakers; no cut colors in bulk sample; no other oil indicators in bulk sample; moderate HCl reaction in bulk sample. Sand (6970' - 7055') = clear to translucent dominant with light greenish gray hues, very light gray hues, black lithics, light bluish gray hues, pale olive hues, pale yellowish orange hues, and slight white colors; unconsolidated sands; quartz dominant with lithics and calcareous minerals framework; lower fine to lower medium grain size; well to fair sorting; angular to subrounded angularity; low to moderate sphericity; thick bedding structure; slight hydrocarbon odor in sample; yellowish green color in visual fluorescence color; no visual cut color; no fluorescence cut colors; no residue in white light; no residue fluorescence cut color; moderate HCl reaction in sample. 2L-314 21 Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6882’ 158 21802 1696 1047 420 879 277 294 6960’ 285 43216 3040 1678 606 1268 366 359 3.2.6 Iceberg 7019’ to 7899' MD (-4291' to -4647' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 211.6 0.3 125.76 1158 21 238.9 Sand (7085' - 7170') = clear to translucent with light gray hues, medium gray hues, yellowish gray hues, cream to white hues, and black lithics colors; unconsolidated sands; quartz dominant with lithic and calcareous minerals frameworks; lower fine to lower medium grain size; well to very well sorting; angular to subrounded angularity; low to very low sphericity; thick to thin bedding structure; slight hydrocarbon odor; no stains; yellowish green patchy visual fluorescence; no cut color in white light; no cut fluorescence color; no visual residue; no fluorescence residue colors; no other hydrocarbon indicators; moderate HCl reaction in bulk sample. Sand (7180' - 7265') = clear to translucent dominant with light greenish gray hues, very light gray hues, black lithics, light bluish green hues, pale olive hues, pale yellowish gray hues, and slight white colors; unconsolidated sands; quartz dominant with lithics and calcareous minerals framework; lower fine to lower medium grain size; well to fair sorting; angular to subrounded angularity; low to very low sphericity; thin to thick bedding structure; slight hydrocarbon odor in sample; yellowish green color in visual fluorescence color; no visual cut color; no fluorescence cut colors; no residue in white light; no residue fluorescence cut color; moderate HCl reaction in sample. Siltstone (7275' - 7350') = dark gray to grayish black colors; friable to firm friable hardness; crumbly to brittle tenacity; earthy to slightly hackly fracture; platy to wedgelike worth elongated bladed edges cuttings habit; earthy to dull luster; matte to silty texture; thick and slightly banded bedding structure; traces of yellowish green colors in visual fluorescence; no visual cut colors; no stains; no hydrocarbon odor; no residue in white light; no residue color in under fluorescence light; no other hydrocarbon indicators; moderate to strong HCl reaction in bulk sample. Siltstone (7350' - 7450') = dark gray with medium gray and black hues; dense to pulverulent; irregular blocky fracture; tabular to nodular cuttings habit; dull earthy luster; clayey to granular texture; thin somewhat fissile structure; intergrading with sandstone, claystone and shale; interbedded with thin very fine to fine sand in places; non- to slightly calcareous; trace sample fluorescence from mud additives; no hydrocarbon indicators. Siltstone (7450' - 7500') = dark gray with medium gray and black hues; dense to pulverulent; irregular blocky fracture; tabular to nodular cuttings habit; dull earthy luster; clayey to granular texture; thin structure; intergrading with thin sandstone, and some claystone; increasingly arenaceous with depth; common dark fines non- to slightly calcareous; trace sample fluorescence from additives; no hydrocarbon indicators. Sandstone (7500' - 7560') = light gray to pale brown with darker olive and black hues, "salt & pepper" appearance; lower very fine to upper medium with some coarser grains; fair sorted; subangular to 2L-314 22 rounded; low mod sphericity; frosting and other signs of mechanical abrasion on grain surfaces; soft to easily friable; grain supported; no to trace cement; moderately calcareous; thin stringers intergrade with siltstone with thick bed appearing at 7545'md; tight; gassy; trace yellow fluorescence; no cut or other hydrocarbon indicators. Sandstone (7560' - 7650') = light gray to pale brown with darker gray and black hues, "salt & pepper" appearance; lower fine to lower medium mostly; fair to moderately well sorted; subangular to rounded; low mod sphericity; frosting and other signs of mechanical abrasion on grain surfaces; friable to soft; grain supported; composition equal parts clear to dark gray quartz and dark gray black lithics; trace ash; some silt matrix; slightly calcareous; massive structure, intergrades with siltstone in places; trace yellow fluorescence; no cut or other hydrocarbon indicators. Sandstone (7650' - 7750') = medium gray to pale brown with brownish gray and black hues, "salt & pepper" appearance; lower fine to lower medium grained; fair to moderately well sorted; subangular to rounded; low mod sphericity; frosting and other signs of mechanical abrasion on grain surfaces; firm friable grain supported; composition equal parts quartz and dark lithics as above; trace ash; some firm cuttings; some silt matrix; moderately calcareous; thin to thick structure; intergrades to siltstone in places; firmer cuttings exhibit dull yellowish brown fluorescence; sample fluorescence <10%; bright residual cut fluorescence in a few firm cuttings but no other hydrocarbon indicators. Sandstone (7750' - 7850') = medium gray to medium brownish gray with light and black hues, "pepper- like" appearance; lower fine to lower medium grained; fair to moderately well sorted; angular to rounded; low to moderate sphericity; signs of mechanical abrasion on grain surfaces; unconsolidated to friable; grain supported; composition quartz and dark lithics; trace ash; common silt matrix; somewhat calcareous; massive to thin structure; intergrades to siltstone; some firmer cuttings exhibit dull yellowish brown fluorescence, and brighter yellow cut fluorescence; sample fluorescence <20%; no residual cut or other hydrocarbon indicators. Traces of LCM in sample; several coarse shale cavings also detected in samples ranging between 10-40mm in length; oil based additives may also be contributing overall sample fluorescence. Sandstone (7850' - 7900') = medium gray to dark brownish gray with light gray and dark gray hues; lower very fine to lower medium grained; fair to moderately well sorted; angular to rounded; mod to high sphericity; soft to easily friable; grain supported with common silt matrix; moderately calcareous; thick to thin structure; intergrading to siltstone; trace ash; <5% dull yellow sample fluorescence; no other hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 7100’ 984 234695 10683 3924 844 2037 471 480 7356’ 142 18043 1408 974 380 668 188 262 7565’ 161 21204 1592 1037 401 747 307 399 3.2.7 T-7 7899’ to 8565’ MD (-4647' to -4887' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 201.5 5.1 68.7 694 20 76.2 Siltstone (7900' - 7950') = medium gray to dark brownish gray with black fines; crunchy to pulverulent; irregular blocky fracture; tabular wedgelike cuttings habit; dull earthy luster; clayey to gritty texture; thin structure; intergrading with sandstone as above; trace ash and lcm in sample; several lamellar gray shale cavings also detected in shakers ranging between 10-30mm in length; no hydrocarbon indicators in nearly 2L-314 23 all sandstone cuttings, few as above. Siltstone (7950' - 8000') = medium gray to dark brownish gray with black fines; crunchy to pulverulent; irregular blocky fracture; tabular wedgelike cuttings habit; dull earthy luster; clayey to gritty texture; thin structure; intergrading with sandstone as above; trace ash in sample; several lamellar gray shale cavings detected at shakers ranging between 20-70mm in length. Siltstone (8000' - 8100') = medium gray to dark brownish gray with black fines; crunchy to pulverulent; irregular blocky fracture; tabular wedgelike cuttings habit; dull earthy luster; clayey to gritty texture; thin structure; intergrading with sandstone as above; trace ash; trace pyrite in sample; trace lower very fine to lower fine metal flakes; several large gray siltstone cavings were detected at the shakers between 8050' and 8065'; these have blocky shape and measure up to 4-5cm in length, 3-4cm in width and 1-2cm in thickness. Sandstone (8115' - 8205') = clear to translucent with light olive gray hues, olive gray hues, medium gray hues, black lithic interbedded, yellowish gray hues, and white hues colors; quartz dominant with lithic and calcareous minerals framework; very fine to fine grain size; well to very well sorting; subrounded to angular angularity; low to moderate sphericity; consolidated to moderate hard hardness; grain enlargement to overgrowths cement; matrix to cement grain support; thin bedding structure with traces of pyrite; traces of yellowish green color in visual fluorescence light; no cut visual cut color; no fluorescence cut colors in bulk sample; no residue colors; moderate HCl reaction in bulk sample. Siltstone (8220' - 8285') = dark gray to medium dark gray with black hues colors; crunchy to slight dense tenacity; drusy to earthy fracture; tabular to elongated and wedgelike cuttings habit; dull to earthy; matte to slight sucrosic and silty texture; laminated to thick with occasional fissile bedding structure; patchy of yellowish green color in visual fluorescence; no stains in bulk sample; blooming white bluish fluorescence cut color with white streamers; yellowish dull residue fluorescence; moderate to strong HCl reaction in bulk sample. Sandstone (8295' - 8385') translucent to clear with black lithics, white to light gray hues, pale yellowish orange hues, grayish orange hues, and yellow gray hues colors; quartz dominant with lithics and calcareous minerals framework; fine to very fine grain size; very well to well sorting; angular to very sub angular angularity; very low to low sphericity; consolidated to firm friable hardness; grain enlargement cement; matrix and cement grain support; thick bedding structure; patchy yellowish green color in visual fluorescence bulk sample; no stains; no hydrocarbon odor; no fluorescence cut color; no residue cut color; no residue color in white light; weak HCl reaction in bulk sample. Siltstone (8395' - 8445') = dark gray to medium dark colors; crumbly to stiff tenacity; slight hackly to earthy fracture; tabular to wedgelike cuttings habit; dull to earthy luster when dry; matte to silty texture; lenticular to thick bedding structure; patchy yellowish green visual fluorescence color; no cut fluorescence colors; no visual cut colors; no residue colors; weak HCl reaction in bulk sample. Siltstone (8479' - 8550') = medium gray to dark gray with brownish gray hues; dense to crumbly; irregular blocky fracture; fine wedgelike to tabular cuttings habit; dull earthy to slightly sparkling luster; gritty texture; thin sometimes laminar structure; intergrades to similar color and pale brown color lower very fine to lower fine grained moderately well sorted, subangular to angular, low to high sphericity, firm to soft sandstone composed of quartz, dark lithics; common black fines; trace pyrite; dull yellow sample fluorescence; no cut or other hydrocarbon indicators. Siltstone (8550' - 8600') = medium gray to dark gray with light brownish hues; dense to crunchy; blocky to planar fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; clayey to gritty texture; massive to fissile laminar structure; intergrades to similar color claystone and some lower very fine to lower fine grained sandstone as described above; common black fines; no hydrocarbon indicators. Siltstone (8600' - 8700') = medium gray to dark gray with brownish gray hues; dense to crumbly; irregular blocky to planar fracture; wedgelike to tabular cuttings habit; dull earthy to slightly sparkling luster; gritty 2L-314 24 texture; thin banded to laminar structure; intergrades to similar color and pale brown to white lower very fine to lower medium grained fair to well sorted, subangular to rounded, mod to high sphericity, firm to soft sandstone; composed of quartz, dark lithics, and black fines; trace pyrite; dull yellow brown fluorescence in sandstone. No other hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 8143’ 49 8062 472 409 95 162 72 108 3.2.8 T-4.1 8565’to 9149' MD (-4887' to -5134' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 212.9 2.6 109.8 705 16 129.6 Siltstone (8600' - 8700') = medium gray to dark gray with brownish gray hues; dense to crumbly; irregular blocky to planar fracture; wedgelike to tabular cuttings habit; dull earthy to slightly sparkling luster; gritty texture; thin banded to laminar structure; intergrades to similar color and pale brown to white lower very fine to lower medium grained fair to well sorted, subangular to rounded, mod to high sphericity, firm to soft sandstone; composed of quartz, dark lithics, and black fines; trace pyrite; dull yellow brown fluorescence in sandstone. No other hydrocarbon indicators. Sandstone (8700' - 8800') = light olive gray to medium gray with brownish hues; lower very fine to lower medium; fair to well sorted; subangular to round; low to very high sphericity; some polish on grain surfaces; firm to soft; grain supported; slight to moderately calcareous; trace cement; common silty matrix; intergrading to siltstone similar to that described above; composed of quartz with common dark lithics and black carbonaceous fines; trace ash in sample; trace pyrite; some firmer grains exhibit dull yellow brown fluorescence; slight residual bright yellow cut rare; sample fluorescence <5%; no other hydrocarbon indicators observed. Sandstone (8800' - 8800') = light olive gray to medium gray with brownish hues; lower very fine to upper fine; fair to well sorted; subrounded to round; high to very high sphericity; some polish on grain surfaces; firm to soft; grain supported; slightly calcareous; common silty matrix; some cement; intergrading to gritty siltstone as described above and medium gray shale in places; quartz and dark lithic composition similar to overlying sandstone; trace pyrite; trace ash; some fine banding evident; some firmer cuttings fluoresce dull yellow to golden brown; sample fluorescence is <1-3%; rocks fining down; no other hydrocarbon indicators. Sandstone (8900' - 8950') = light gray to medium gray with brownish and white hue; two varieties both lower very fine to lower fine grained, fair to well sorted; subangular to rounded; low to high sphericity; hard to easily friable; lighter color varieties have more cement while darker varieties appear to be an intergrade with the siltstone occuring in this interval; some banding seen in both color varieties of sandstone; the light color variety exhibits yellow fluorescence in approx 50% of the sample below 8950' MD. Siltstone (8975' - 9055') = grayish black to dark gray with slight olive black hues colors; brittle to slight crunchy tenacity; splintery to slight hackly fracture; platy to elongated wedgelike cuttings habit; dull to earthy luster when dry; matte to silty texture; thick bedding structure; no stain in sample; faint odor on shaker and in bulk sample; patchy yellowish green visual fluorescence color; faint white fluorescence cut color; no residue color in white light; faint yellowish color in residue fluorescence bulk sample; weak HCl reaction in bulk sample. No other hydrocarbon indicators. 2L-314 25 Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 9000 204.31 27672 2154 1418 282 604 199 194 3.2.9 Bermuda Sand 3.2.9.1 Bermuda Sand in Pilot Hole Plugback 9149’ to 9365' MD (-5134' to -5207' TVDSS) Note: Seismic Bermuda Top: 9232’ MD, -5159’ TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 131 1 60.3 471 20 215.2 Sandstone (9165' - 9265') = translucent to clear with black lithics, pale green yellowish color hue, smoky hues, and slight pale green hues colors; quartz dominated with lithic interbedded framework; fine to very fine grain size; well to very well sorting; subrounded to angular angularity; moderate to very low sphericity; consolidated sands to moderate hard hardness; grain enlargement cement; cement and matrix grain support; thick bedding structure; slight odor in sample; no odor in shaker room; no stains; 85% bright even yellowish green visual fluorescence in sample; white blue with white streamers fluorescence cut color; no visual cut color in white light; no visual residue color; bright bluish white residue fluorescence cut color; very weak HCl reaction in bulk sample. Sandstone/sand = (9275' - 9390') = light gray with pale yellow brown to dark gray to smoky gray hues; lower very fine to upper fine grained; well to very well sorted; subrounded to rounded angularity; moderate to low sphericity; some surface features including polish possible etching; unconsolidated to hard; grain enlargement cement; grain supported; common cement, silt matrix; composition predominantly clear to translucent quartz with lesser pale brown and gray varieties; common dark lithics; no sheen or odor at shakers; slight odor at shakers; no stain; pale yellow sample fluorescence particularly below 9310' sample; instantaneous milk cut generally bright; trace bright yellow cut fluorescence; residual milk ring cut; residual yellow cut fluorescence; best developed between 9310' - 9350' and 9370' to 9390'; trace metal shavings in samples; bright yellow fluorescence is 5-10% in samples between 9370'-9390'. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 9180’ 23.793 5622 452 335 119 157 39 39 9210’ 246.724 43997 2903 1182 151 337 169 134 Note: The Pilot Hole TD penetrated the underlying C-35 which is described below. 3.2.9.2 Bermuda Sand in Production Hole 9149’ to 11622' MD (-5134' to -5225' TVDSS), TD Production Hole Note: Seismic Bermuda Top: 9250’ MD, -5158’ TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 164.5 6.1 69.9 1035 2 334.2 2L-314 26 PRODUCTION HOLE LITHOLOGY Siltstone (9195' - 9270') = dark gray to medium dark gray colors; brittle to crumbly with slight crunchy tenacity; earthy fracture; wedgelike to tabular cutting habits; dull to earthy luster; silty to slight matte texture; thin with laminar feature bedding structures; slight odor in bulk sample; no stains; 98% even bright yellowish green color; fast and bright bluish white fluorescence cut color with white streamers; no visual white light cut color; pale straw color in residue visual color; bright orange white with slight yellowish hue residue fluorescence colors; weak HCl reaction in bulk sample. Sandstone (9280' - 9385') = medium dark gray with dusky yellowish brown lamination hues, very pale orange hues, dark yellowish brown hues, clear to translucent minerals; and black lithic interbedded; quartz dominate with lithic and calcareous framework; very fine to fine grain size; well to fair sorting; subangular to subrounded angularity; moderate to low sphericity; consolidated with friable hardness; overgrowth cement; matrix and cement grain support; massive to thick bedding structure; weak odor in sample; patchy yellowish green fluorescence colors; slow bright bluish white color with no streamers fluorescence cut; no visual cut color; no visual residue color; bright yellowish orange color in residue fluorescence; weak HCl reaction in bulk sample; no other hydrocarbon indicators. Sandstone (9415' - 9525') = very pale brown to very pale orange with dusky yellowish brown hues, black lithics, translucent to clear minerals, smoky to medium light gray colors; quartz dominant with lithic and calcareous minerals framework; fine to coarse grain size; very poor to poor sorting; angular to subangular angularity; very low to low sphericity; consolidated to friable and occasional easily friable hardness; grain enlargement and overgrowth cement; cement and matrix grain support; massive to thick bedding structure; faint odor in bulk sample; no stain in sample; 90% yellowish green color in fluorescence light; fast dull to bright bluish white with white streamers in fluorescence cut color; no visual cut color; no residue visual color; dull residue fluorescence cut color; weak HCl reaction in bulk sample; no other hydrocarbon indicators. Sandstone (9535' - 9645') = moderate yellowish brown to very pale orange with creamy white hues, black minerals, light medium gray hues, dusky yellowish brown laminar layers, and translucent to clear minerals color; quartz dominant with calcareous and lithic framework; very coarse to very fine grain size; very poor to poor sorting; angular to subrounded angularity; very low to low sphericity; consolidated to friable hardness; grain enlargement cement; matrix to cement grain support; thick to massive bedding structure; fair odor in bulky sample; no stains; 95% yellowish green fluorescence color; fast bright bluish white with white streamers fluorescence cut color; no visual residue color; light straw cut color; bright to slight dull yellowish orange residue fluorescence cut color; weak HCl reaction in bulk sample; no other oil indicators. Sandstone (9655' - 9720') =dark yellowish brown to olive gray with light olive hues, medium gray hues, dusky yellowish brown hues, clear to translucent minerals, black lithics colors; quartz dominant with lithic and calcareous minerals framework; very fine to medium grain size; poor to fair sorting; subangular to rounded; very low to very high sphericity; common polish on grain surfaces; soft to friable; some grain enlargement cement; grain supported; 90% dull yellow sample fluorescence; faint odor; slight yellow brown stain; instantaneous bright milk cut; no cut fluorescence; pale straw visible cut; yellowish residual ring; weak HCl reaction in bulk sample. Sandstone (9740' - 9820') = pale brown to medium olive with light olive hues; lower very fine to lower medium grain size; fair to well sorted; subangular to rounded; low to very high sphericity; common polish on grain surfaces; soft to firm friable; some grain enlargement cement; grain supported; composed of quartz with some brown and black lithics with the latter sometimes forming bands; 90% dull yellow gold sample fluorescence with faint odor and slight yellow brown stain common; mod instantaneous milk cut; pale yellow white cut fluorescence; yellowish gold ring; no visible cut; no residual cut; weak reaction to HCl in bulk sample; cuttings coarsen down. Sandstone (9820' - 9920') = pale brown to medium olive with light olive hues; lower very fine to upper fine grained; well to very well sorted; subrounded to rounded; high to very high sphericity and common polish; grain supported; some grain enlargement cement; trace silt matrix; composed of clear to translucent and 2L-314 27 light gray quartz and dark lithics; some black possibly carbonaceous fines; trace odor; common stain; intergrading to thinly bedded olive gray siltstone in a few places lower in sample interval; 90% dull golden brown to yellow sample fluorescence; instantaneous pale milk cut; some cut yellow fluorescence; very faint residual yellow ring; residual pale straw visible cut; slight to no HCl reaction in this sample interval. Sandstone (9940' - 10,040') = pale brown to medium olive with light olive hues; lower very fine to lower medium grained; fair to very well sorted; subangular to rounded, rounder with fining grain size; low to high sphericity; common polish; grain supported with some silt matrix; common grain enlargement cement; hard to easily friable and sometimes soft; intergrading to siltstone in places; common banding; somewhat fissile; very thin structure; composed of translucent to clear to light gray quartz and dark lithics; moderate odor; common stain; dull gold to pale yellow fluorescence; instantaneous bright to weak milk cut; no cut fluorescence in samples; dull residual yellow brown ring cut; dark black globs appear to be mud additive; pale straw visible cut; slight to no HCl reaction in bulk sample. Sandstone (10040' - 10140') = light to medium olive with dark brownish hues; lower very fine to upper medium grained; moderate to well sorted; subangular to rounded, rounder with fining grain size; low to high sphericity; common polish; grain supported with some silt matrix; some grain enlargement cement; hard to easily friable and unconsolidated; intergrading to siltstone in places; common banding; somewhat fissile; very thin structure; composed of translucent to clear to gray quartz and dark gray lithics; moderate odor; common stain; dull gold to pale yellow fluorescence; instantaneous bright milk cut; bright yellow cut fluorescence below 10100'; residual yellow brown ring cut; dark black globs appear to be mud additive; pale straw visible cut; moderate HCl reaction in bulk sample. Sandstone (10140' - 10240') = light to medium olive with dark brownish hues; lower very fine to lower medium grained; moderate to well sorted; subangular to rounded, rounder with fining grain size; low to high sphericity; common polish; grain supported with some silt matrix; some grain enlargement cement; hard to easily friable and unconsolidated; intergrading to siltstone in places; common banding; somewhat fissile; very thin structure; composed of translucent to clear to gray quartz and dark gray lithics; moderate odor; common stain; fine black globs continue appearing; dull gold fluorescence 60%, bright pale yellow 30% in sample; instant milk cut brighter in upper part of interval while fluorescence improves downward. Sandstone (10260' - 10375') = light olive gray to olive gray with black lithics, dusky yellowish brown hues, pale yellowish orange, and slight moderate orange pink hues, clear to white and translucent minerals colors; quartz dominant with lithic and calcareous framework; very fine to coarse grain size; poor to fair sorting; subrounded to angular angularity; low sphericity to moderate sphericity; consolidated to easily friable and occasional firm friable hardness; grain enlargement cement; matrix and cement grain support; massive to thick bedding structure; faint to slight hydrocarbon odor; no stains; 97% even yellowish green color visual fluorescence; fast bluish white with no streamer fluorescence cut color; no cut color; no white light residue colors; dull yellowish orange fluorescence residue color; weak HCl reaction in bulk sample; no other hydrocarbon indicators in sample. Sandstone (10260' - 10375') = dark olive gray to olive gray with black lithics, dusky yellowish brown hues, pale yellowish orange, and light moderate orange pink hues, clear to white and translucent minerals colors; quartz dominant with lithic and calcareous framework; very fine to medium grain size; poor to fair sorting; subrounded to angular angularity; low sphericity to moderate sphericity; consolidated to easily friable and occasional moderate friable hardness; grain enlargement cement; matrix and cement grain support; massive to thick bedding structure; faint to slight hydrocarbon odor; no stains; 99% even yellowish green color visual fluorescence; fast bluish white with streamer fluorescence cut color; no cut color; no white light residue colors; dull yellowish orange fluorescence residue color; weak HCl reaction in bulk sample. Sandstone (10505' - 10630') = light olive gray to olive gray with dusky yellowish brown laminae, very pale orange hues, grayish orange hues, pale brown hues, and translucent to clear minerals color; quartz dominant with lithics and calcareous framework interbedded; lower medium to very fine grain size; poor to fair sorting; subrounded to angular angularity; moderate to low sphericity; consolidated to moderate friable; grain enlargement cement; cement and matrix grain support; massive the thick bedding structure; faint 2L-314 28 odor in sample; no stain or free oil in sample; 98% even yellowish green fluorescence color; no visual cut color; bluish white fluorescence cut with white streamers bright white; bright yellowish orange residue color; no white light residue color in sample; weak to moderate HCl reaction. Sandstone (10640' - 10755') = light olive gray to olive gray with black lithics, dusky yellowish brown hues, pale yellowish orange, and slight moderate orange pink hues, clear to white and translucent minerals colors; quartz dominant with lithic and calcareous framework; very fine to medium grain size; poor to fair sorting; subrounded to angular angularity; low sphericity to moderate sphericity; consolidated to easily friable with occasional firm friable hardness; grain enlargement cement; matrix and cement grain support; massive to thick bedding structure; faint to slight hydrocarbon odor; no stains; 98% even yellowish green color visual fluorescence; fast bluish white with one streamer fluorescence no white light residue; bright yellowish orange residue fluorescence color; very weak to weak HCl reaction in bulk sample; no other hydrocarbon indicators. Sandstone (10765' - 10825') = light gray to medium gray with olive hues; lower very fine to upper fine grained; fair to well sorted; subangular to rounded; low to moderate sphericity; some polish; firm friable to unconsolidated; some grain enlargement cement; grain supported; common silt matrix; some gray banding; thin structure, intergrading to siltstone; slight odor; common stain; yellow fluorescence, 20% bright; instant bright milk cut; no cut fluorescence; pale straw cut; residual yellow ring. Sandstone (10825' - 10920') = light gray to medium gray with olive hues; lower very fine to lower fine grained; fair to well sorted; subangular to rounded; low to moderate sphericity; some polish; composed of quartz 90% and dark lithics; easily friable to unconsolidated; less grain enlargement cement; grain supported; some silt matrix; some gray banding; thin structure, intergrading to siltstone giving gray banded appearance in places; faint odor; some stain; dull yellow fluorescence, 10% bright; instant pale milk cut with some residual white streamers and residual milk cut; yellow white cut fluorescence (30-50%); slight pale straw visible cut with brown hues becomes slightly stronger over time. Sandstone (10920' - 11020') = light gray to medium gray; light olive hue; lower very fine to lower fine grained; fair to well sorted; subrounded to rounded; moderate to high sphericity; polish is present on some grain surfaces; rock composed of quartz 90% and dark lithics; firm friable to easily friable; common grain enlargement cement; grain supported; common silt matrix and dark gray banding; thin structure, intergrading to siltstone in higher percentages with depth in interval to 25% of sample; dull gold to yellow sample fluorescence; delayed pale milk cut; yellow-white cut fluorescence in 60% of sample; no odor; no visible cut or residual cut; some stain; little to no reaction to HCl in bulk sample. Sandstone (11020' - 11120') = light gray to medium gray; light olive hue; lower very fine to lower fine grained; fair to well sorted; subrounded to rounded; moderate to high sphericity; polish is present on some grain surfaces; rock composed of quartz 90% and dark lithics; firm friable to easily friable; common grain enlargement cement; grain supported; common silt matrix; some gray banding; thin structure, intergrading to siltstone in lower percentages with depth in interval to 20% of sample; dull gold to yellow white fluorescence, 60-80% of sample; instant to delayed bright to pale milk cut, with some streaming; no cut fluorescence; light brownish to straw cut; thin yellow gold residual ring; show best developed above 11080'. Sandstone (11120' - 11220') = light gray to medium gray with olive hues; lower very fine to upper fine grained; fair to well sorted; subrounded to rounded; moderate to high sphericity; polish is present on some grain surfaces; rock composed of quartz 90% and dark lithics; firm friable to easily friable; common grain enlargement cement; grain supported; common silt matrix and gray banding; thin structure, intergrading to siltstone in places; dull gold to bright yellowish white sample fluorescence (60-80%); instant moderate bright milk cut; yellow white cut fluorescence seen in some duller fluorescing cuttings; dull gold residual ring; very pale light brownish straw visible cut. Sandstone (11225' - 11340') = olive gray to light olive gray with pale yellowish orange hue, grayish orange hues, white smoky hues, clear to translucent minerals, black lithic mineral colors; quartz dominant with trace lithic and calcareous mineral framework; very fine to lower medium grain size; poorly to moderate 2L-314 29 sorting; very angular to subrounded angularity; very low to low sphericity; consolidated to firm friable hardness; overgrowths cement; matrix and cement grain support; massive bedding structure; slight hydrocarbon odor in bulk sample; no free oil in sample; 95% even bright yellowish green colors; straw cut color in visual white light; bluish white color with white streamer in fluorescence cut colors; bright yellowish orange residue color in fluorescence light; very weak HCl reaction in bulk sample; no odor hydrocarbon indicators in bulk sample. Sandstone (11350' - 11455') = light olive gray to olive gray with traces of black lithics, pale orange hue; orange grayish hue; clear to translucent minerals, and yellowish gray hues color; quartz dominant with calcareous minerals framework; very fine to medium grain sorting; poorly to poor sorting; very angular to subrounded angularity; low to moderate sphericity; consolidated to friable hardness; massive to thick bedding structure; slight hydrocarbon odor in bulk sample; no staining in sample; yellowish green fluorescence cut with white and 99% even; slight straw color in visual cut; bright bluish white in with white streamer; no visual cut colors; bright yellowish slight orange residue fluorescence; very light straw visual residue colors; no other hydrocarbon indicators; weak HCl reaction in bulk sample. Sandstone (11465' - 11580') = olive gray to light olive gray with pale yellowish orange hue, grayish orange hues, white smoky hues, clear to translucent minerals, black lithic mineral colors; quartz dominant with trace lithic and calcareous mineral framework; very fine to lower medium grain size; poorly to moderate sorting; very angular to subrounded angularity; very low to low sphericity; consolidated to easily friable hardness; overgrowths cement; matrix and cement grain support; massive bedding structure; slight hydrocarbon odor in bulk sample; no free oil in sample; 95% even bright yellowish green colors; straw cut color in visual white light; bluish white color with white streamer in fluorescence cut colors; bright yellowish orange residue color in fluorescence light; very weak HCl reaction in bulk sample; no other hydrocarbon indicators in bulk sample. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 9230’ 222 43137 2726 811 77 182 73 62 9280’ 530 96034 9057 3766 493 1203 337 389 9310’ 463 89919 6907 2787 274 757 72 87 9410’ 753 149931 13164 5637 655 1685 358 407 9440’ 407 69307 6869 3153 391 927 215 209 9470’ 458 73988 7068 3294 442 1023 240 255 10100’ 711 102998 10259 5571 775 2050 451 543 10190’ 680 102996 10695 6007 911 2364 619 700 10370’ 338 48711 4672 2843 520 1273 357 447 10400’ 385 32016 2780 1749 358 800 230 315 10490’ 850 45703 5280 3774 510 1629 543 693 10520’ 431 63494 5830 3326 520 1303 396 442 10610’ 494 69713 6884 3941 609 1612 436 489 10670’ 511 80925 7175 3798 566 1439 398 456 11059’ 469 74670 7230 3803 608 1415 389 443 11270’ 916 178894 15143 6719 831 2120 487 558 11370’ 460 69419 7507 4205 604 1525 374 435 11460’ 571 90236 9386 5002 710 1796 482 522 11580’ 378 58212 5239 2741 366 1049 262 322 3.2.10 C-35 to TD 3.2.10.1 C-35 to TD in Pilot Hole Plugback 2L-314 30 9403' to 9573' MD (-5220' to -5229' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 116.9 11.8 60.3 221 54 107.4 Sandstone (9400' - 9530') = light gray to brownish gray with darker hues; upper very fine to upper fine grained; moderate to very well sorted; subrounded to rounded; moderate to high sphericity; some mechanical abrasion features on grain surfaces; hard to easily friable; grain supported with some grain enlargement cement; composed of quartz in translucent, clear, and gray varieties; common dark lithics; no sheen; slight odor; common brown stain; dull yellow sample fluorescence up to 50% bright yellow; strong instantaneous milk cut; no cut fluorescence; visible straw cut; no residual cut fluorescence; thin beds of dark grayish brown siltstone and interbedded with dark brownish black carbonaceous shale increasingly common below 9450'. Siltstone/shale (9470' - 9572') = dark gray to dark brownish gray with black hues; crumbly to crunchy tenacity; blocky to planar fracture; flaky to tabular cuttings habit; dull earthy to resinous luster; gritty to smooth texture; laminar to fissile structure; interbedded and intergrading with laminar to thin beds of sandstone as described above and thicker beds of carbonaceous shale; sandstone cuttings in this zone fluoresce as above but the overall sample fluorescence is only 1-4% of sample, decreasing with depth. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 9331’ 285 38017 3857 2341 388 860 238 245 9552’ 65 9474 972 769 181 311 96 130 Note: The Production Hole TD was above the top of the C-35 2L-314 31 3.3 Isotube Summary Isotube Depth Box Sample MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 1 1 500 499 0 0 0 0 0 0 0 0 1 2 1000 994 0 0 0 0 0 0 0 0 1 3 1500 1143 314 83184 0 0 0 0 0 0 1 4 2000 1965 237 60974 0 0 0 0 0 0 1 5 2500 2378 73 17711 84 49 0 0 0 0 1 6 3003 2715 33 0 73 0 0 0 0 0 1 7 3500 2923 28 5596 93 170 0 0 0 0 1 8 4000 3181 27 5986 90 71 0 0 0 0 1 9 4500 3362 37 7943 180 66 0 0 0 0 1 10 5000 3578 17 2981 91 145 0 0 0 0 1 11 5507 3799 112 19004 971 423 106 220 102 87 1 12 5563 3824 961 269712 15432 6354 1878 3990 627 604 1 13 6005 4016 130 20278 1329 774 239 525 176 152 1 14 6500 4234 324 31608 2426 1578 714 1625 396 449 1 15 7000 4428 25820 25820 1812 1053 394 818 230 230 1 16 7041 4443 73611 73611 4336 2193 731 1557 423 425 1 17 7445 4605 108913 108913 7123 3276 1092 2287 515 563 1 18 7500 4628 21229 21229 1652 1013 367 846 294 315 1 19 8000 4832 8228 8228 604 531 150 324 133 164 1 20 8500 5041 10034 10034 1065 889 281 672 286 266 1 21 8970 5224 113450 113450 10925 7247 1443 3028 859 168 1 22 9000 5234 204 27672 2154 1418 282 604 199 194 1 23 9150 5279 25 4303 297 245 86 51 36 50 1 24 9180 5288 25 5578 276 234 132 37 48 40 1 25 9000 5234 23 5622 452 335 119 157 39 145 2L-314 32 Isotube Depth Box Sample MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 2 1 9210 5297 247 43997 2903 1182 151 337 169 134 2 2 9240 5306 191 32513 2504 1266 171 343 178 88 2 3 9270 9270 118 18924 1739 1011 137 337 98 105 2 4 9300 5327 245 35167 3838 2467 336 924 170 314 2 5 9330 5338 277 38017 3857 2341 388 860 238 245 2 6 9359 5349 450 66751 7047 4566 738 1692 405 447 2 7 9390 5362 151 19503 1895 1394 229 546 251 221 2 8 9420 5374 142 18105 2033 1544 272 661 156 265 2 9 9450 5386 117 16978 1719 1131 198 396 81 103 2 10 9480 5400 78 10468 1204 978 133 388 133 166 2 11 9510 5413 78 11257 1275 913 133 297 272 101 2 12 9540 5427 69 10099 1045 821 176 395 99 183 2 13 9570 5427 75 10673 1240 888 55 199 413 123 2 14 9140 5276 18 2875 192 175 66 39 37 52 2 15 9170 5285 33 672 3028 604 37 157 0 0 2 16 9200 5293 46 7973 629 318 65 70 0 0 2 17 9230 5303 222 43137 2726 811 77 182 73 62 2 18 9260 5313 70 12940 1030 459 116 38 50 0 2 19 9280 5320 530 96034 9057 3766 493 1203 337 389 2 20 9310 5331 463 89919 6907 2787 274 757 72 87 2 21 9360 5350 38 8057 703 405 99 117 46 48 2 22 9380 5358 98 16159 1175 582 56 139 99 56 2 23 9410 5370 768 149931 13164 5637 655 1685 358 407 2 24 9440 5382 410 69307 6869 3153 391 927 215 209 2 25 9470 5395 445 73988 7068 3294 442 1023 240 255 2L-314 33 Isotube Depth Box Sample MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 3 1 9500 5409 175 27861 2668 1313 176 424 120 111 3 2 9530 5423 337 51584 4954 2568 345 860 279 236 3 3 9560 5432 173 9688 1109 743 300 285 126 182 3 4 9590 5440 390 55778 6022 3573 557 1381 350 443 3 5 9620 5443 176 19291 2729 1978 316 846 224 260 3 6 9650 5443 425 58955 6338 3732 574 1457 330 428 3 7 9680 5443 474 65230 7170 4224 674 1620 367 463 3 8 9711 5444 333 43784 4778 2862 436 1066 276 288 3 9 9740 5444 326 43344 4550 2708 417 1031 307 294 3 10 9770 5444 265 30795 3310 2196 381 970 306 309 3 11 9800 5443 459 64552 6277 3562 559 1402 333 424 3 12 9830 5443 297 38647 4265 2814 485 1267 292 415 3 13 9860 5442 346 39754 4456 2848 457 1201 337 345 3 14 9890 5441 446 56156 5861 3581 584 1578 392 524 3 15 9920 5441 183 19676 2315 1801 340 914 312 350 3 16 9950 5440 172 21522 2023 1456 242 616 192 211 3 17 9980 5440 550 86788 7685 3874 562 1432 365 417 3 18 10010 5439 408 58784 5617 3158 479 1224 338 412 3 19 10040 5438 347 47384 4583 2711 444 1100 311 350 3 20 10070 5438 277 42947 4105 2423 377 1013 311 309 3 21 10100 5437 711 102998 10259 5571 775 2050 451 543 3 22 10130 5436 481 71498 7415 4117 610 1565 346 425 3 23 10160 5436 480 71489 7068 3786 559 1425 343 417 3 24 10190 5436 680 102996 10695 6007 911 2364 619 700 3 25 10220 5436 124 19352 1781 1067 164 371 100 81 2L-314 34 Isotube Depth Box Sample MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 4 1 10250 5436 60 6680 752 553 85 207 120 97 4 2 10286 5436 341 42223 4939 3356 549 1546 424 510 4 3 10310 5436 283 32028 3807 2875 594 1443 388 526 4 4 10340 5436 328 43743 4430 2872 526 1357 440 472 4 5 10370 5436 338 48711 4672 2843 520 1273 357 447 4 6 10400 5436 383 32016 2780 1749 358 800 230 315 4 7 10430 5436 224 32016 2780 1749 358 800 230 315 4 8 10463 5437 294 15235 1761 1259 171 544 182 232 4 9 10490 5437 850 45703 5280 3774 510 1629 543 693 4 10 10520 5437 431 63494 5830 3326 520 1303 396 442 4 11 10580 5438 545 81773 7726 4240 609 1598 397 492 4 12 10610 5438 494 69713 6884 3941 609 1612 436 489 4 13 10640 5438 410 62766 5498 3090 471 1253 385 410 4 14 10670 5439 511 80925 7175 3798 566 1439 398 456 4 15 10700 5439 399 62463 5398 3017 499 1208 1707 288 4 16 10730 5439 345 51342 4794 2759 439 1073 303 333 4 17 10760 5440 343 54313 5049 2909 505 1210 284 421 4 18 10790 5440 205 31133 2718 1748 340 738 178 275 4 19 10820 5440 329 56580 4423 2308 341 863 211 286 4 20 10850 5441 315 52739 4374 2161 321 763 150 225 4 21 10880 5441 260 43516 3334 1681 254 615 221 191 4 22 10910 5442 289 47784 3928 1971 278 689 187 188 4 23 10941 5443 318 54790 4255 1976 246 631 179 188 4 24 10970 5443 236 34436 3048 1785 267 784 227 255 4 25 11000 5444 184 26179 2168 1393 220 596 210 202 2L-314 35 Isotube Depth Box Sample MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 5 1 11038 5445 277 38945 3294 1879 287 770 189 240 5 2 11059 5445 469 74670 7230 3803 608 1415 389 443 5 3 11093 5446 258 42139 3498 1911 269 689 201 197 5 4 11120 5446 183 29997 2037 1134 195 480 178 183 5 5 11154 5448 279 46772 3544 1802 247 608 180 190 5 6 11180 5449 248 39274 3283 1734 245 628 168 204 5 7 11210 5451 128 20095 1638 880 116 293 118 97 5 8 11240 5453 375 60292 5624 2816 339 912 243 238 5 9 11257 5453 903 176101 14747 6546 831 2072 423 530 5 10 11270 5454 916 178894 15143 6719 831 2120 487 558 5 11 11301 5456 97 13939 933 568 77 215 90 59 5 12 11333 5458 325 55631 4191 1998 304 751 154 211 5 13 11370 5460 460 69419 7507 4205 604 1525 374 435 5 14 11401 5462 127 27201 2685 1393 203 501 114 144 5 15 11430 5464 492 80930 7553 3709 550 1326 283 384 5 16 11460 5465 571 90236 9386 5002 710 1796 482 522 5 17 11490 5467 529 76562 8877 5175 826 2013 494 661 5 18 11520 5468 180 20734 2358 1720 311 810 282 324 5 19 11550 5469 224 29975 2742 1869 351 909 241 299 5 20 11580 5469 378 58212 5239 2741 366 1049 262 322 5 21 11620 5470 18 3030 287 192 41 69 80 55 2L-314 36 3.4 Sampling Program / Sample Dispatch Set Type / Purpose Well Section Sampling Frequency Sampling Interval* Dispatched to A Washed, screened & dried Reference Samples Set owner: CPAI Surf. & Int. Plugback Prodn. Hole 50’ 20’ 30’ 10’/20’* 150’ – 9,120’ 9,120’ – 9,672’ 9,110’ – 9,120’ 9,110’–11,620’ Alaska Archives 1300 W. 56th Avenue Unit 14 Anchorage, AK 99518 Attn: D. Przywojski 265-6340 B Washed, screened & dried Reference Samples Set owner: CPAI Surf. & Int. Plugback Prodn. Hole 50’ 20’ 30’ 10’/20’* 150’ – 9120’ 9,120’ – 9672’ 9,110’ – 9120’ 9,110’–11,620’ Alaska Archives 1300 W. 56th Avenue Unit 14 Anchorage, AK 99518 Attn: D. Przywojski 265-6340 C IsoTube® Natural Gas Samples Set owner: CPAI Surf. & Int. Plugback Prodn. Hole 500’ 30’ 30’ 500’ – 9,120’ 9,120’ – 9,670’ 9,110’ – 11,620’ Isotech Laboratories 1308 Parkland Court Champaign, IL 61821 (217) 398-3490 *Sample frequency was locally altered according to drill rate constraints and zones of interest. Well section abbreviations: Surf. & Int. = Surface and Intermediate Hole interval; Plugback = Pilot Hole Plugback interval; Prodn. Hole = Production Hole interval. 2L - 3 1 4 37 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Th e w e l l w a s d r i l l e d s l i g h t l y o v e r b a l a n c e d a s w a s i n d i c a t ed b y n o c o n n e c t i o n g a s s e s a n d l o w t r i p a n d w i p e r g a s s e s . 4. 1 P o r e P r e s s u r e E v a l u a t i o n In t e r v a l T o p s P o r e P r e s s u r e ( M W ) Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) MD (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Trend Indicators C- 8 0 C L Y S T 7 0 % SD 1 0 % SL T S T 2 0 % 26 4 2 ’ 2 4 8 0 ’ 8 . 6 1 0 . 8 I n c r e a s e B G , C G , M W Ca m p a n i a n S a n d C L Y S T 8 0 % CL Y S T 1 0 % SL T S T 1 0 % 27 1 5 ’ 2 5 3 1 ’ 9 . 1 9 . 4 Sl i g h t In c r e a s e BG,CG, MW C- 5 0 C L S T 5 0 % SD 3 0 SL T S T 2 0 % 53 7 9 ’ 3 7 4 4 ’ 9 . 3 1 0 . 1 I n c r e a s e B G , C G , M W C- 4 0 C L Y S T 5 0 % SH 1 0 % SS T 4 0 % 63 2 5 ’ 4 1 5 8 ’ 9 . 5 1 0 . 6 I n c r e a s e B G , C G , M W C- 3 7 S L T 8 0 % SS T 1 0 % SD 5 % SH 5 % 68 1 8 ’ 4 3 6 1 ’ 9 . 4 1 0 I n c r e a s e B G , C G , M W Ic e b e r g S D 8 0 % SS T 5 % CL Y S T 1 5 % 70 1 9 ’ 4 4 3 4 ’ 9 . 4 9 . 7 Sl i g h t In c r e a s e BG,CG, MW T- 7 S S T 6 0 % CL Y S T 2 0 % SL T S T 2 0 % 78 9 9 ’ 4 7 9 0 ’ 9 . 6 1 1 I n c r e a s e B G , C G , M W T- 4 . 1 S L T S T 5 0 % SS T 3 5 % SD 1 5 % 85 6 5 ’ 5 0 6 7 ’ 9 . 7 1 0 . 5 I n c r e a s e B G , C G , M W To p B e r m u d a S L T S T 6 0 % S S T 4 0 % 9 1 4 9 ’ 5 2 7 7 ’ 1 0 1 0 . 7 I n c r e a s e B G , C G , M W Ba s e B e r m u d a S S T 7 0 % SD 2 5 % SL T S T 5 % 93 6 5 ’ ( P B # 1 ) 5 3 4 9 ’ - - - B G , C G , M W Be r m u d a T o e ( T D ) S S T 8 5 % SD 2 0 % SL T 5 % 11 6 2 2 ’ (H o r i z o n t a l ) 53 6 8 ’ 1 0 . 6 1 1 . 7 I n c r e a s e B G , C G , M W C- 3 5 S S T 5 0 % SD 2 5 % SL T S T 2 5 % 94 0 3 ’ 5 3 6 3 ’ - - - B G , C G , M W NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , S l t s t = S i l t s t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F a l l T u f f , C S l t s t = C a r b o n a c eous Siltstone 2L-314 38 4.2 Pore Pressure Plot Pore Pressure Gradient C-80Campanian Sand C-50 C-40 C-37Iceberg T-7 T-4.1 Top Bermuda Base Bermuda Bermuda Toe C-35 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 8 8.5 9 9.5 10 10.5 11 11.5 12 Pore Pressue (ppg) Me a s u r e d D e p t h ( f t ) PPG C-80 Campanian Sand C-50 C-40 C-37 Iceberg T-7 T-4.1 Top Bermuda Base Bermuda C-35 Bermuda Toe 2L-314 39 4.3 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). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD, and then modified using the indicators described above, 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 differentiated 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. 2L-314 40 5 DRILLING DATA 5.1 Survey Data Surface to Production Hole TD Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 86.11 0.67 213.57 86.11 -0.42 -0.28 0.30 0.78 134.09 0.47 240.36 134.08 -0.75 -0.60 0.50 0.69 175.34 0.49 225.21 175.33 -0.96 -0.88 0.60 0.31 262.36 0.57 230.58 262.35 -1.50 -1.47 0.90 0.11 353.60 1.12 359.54 353.59 -0.90 -1.83 0.22 1.69 445.92 2.79 10.80 445.85 2.21 -1.42 -2.56 1.85 538.19 3.42 14.86 537.98 7.07 -0.30 -6.74 0.72 630.64 5.27 19.15 630.16 13.75 1.81 -12.30 2.04 722.37 6.58 27.52 721.40 22.39 5.62 -19.12 1.71 815.74 9.22 31.28 813.88 33.53 11.98 -27.42 2.87 911.00 9.42 32.35 907.88 46.64 20.11 -36.95 0.28 1004.17 9.94 30.86 999.73 59.99 28.32 -46.69 0.62 1063.04 10.06 34.35 1057.70 68.60 33.82 -52.89 1.05 1157.36 10.34 36.83 1150.53 82.18 43.55 -62.33 0.55 1250.90 12.40 38.47 1242.23 96.76 54.83 -72.17 2.23 1344.39 13.09 38.88 1333.41 112.86 67.72 -82.89 0.74 1439.30 13.20 38.72 1425.84 129.68 81.24 -94.07 0.12 1532.73 12.93 43.06 1516.85 145.64 95.05 -104.35 1.09 1628.24 12.59 44.08 1610.00 160.93 109.59 -113.74 0.43 1721.72 14.26 46.49 1700.93 176.17 125.03 -122.79 1.88 1816.26 16.19 44.90 1792.14 193.53 142.78 -133.02 2.09 1910.22 20.13 44.19 1881.41 214.41 163.30 -145.63 4.20 2003.92 24.53 45.12 1968.06 239.71 188.34 -160.84 4.71 2098.39 28.09 44.38 2052.73 269.45 217.80 -178.71 3.78 2192.35 32.10 43.57 2134.01 303.36 250.49 -199.39 4.29 2286.67 35.08 43.37 2212.57 341.23 286.38 -222.70 3.16 2380.92 37.89 43.52 2288.34 381.91 324.92 -247.75 2.98 2453.92 41.15 43.85 2344.64 415.50 357.00 -268.34 4.47 2501.09 43.74 43.31 2379.45 438.56 378.94 -282.51 5.54 2575.00 45.17 45.75 2432.21 475.44 415.25 -304.75 3.01 2620.78 45.13 50.07 2464.50 497.19 439.32 -316.95 6.69 2669.16 45.02 53.92 2498.67 518.27 466.30 -327.53 5.64 2717.38 45.15 57.18 2532.72 537.58 494.45 -336.05 4.79 2763.66 45.68 60.34 2565.22 554.67 522.63 -342.47 5.00 2810.60 46.36 63.55 2597.82 570.55 552.43 -347.20 5.13 2857.49 47.80 66.63 2629.75 585.00 583.57 -350.12 5.71 2907.99 51.56 69.01 2662.42 599.51 619.22 -351.57 8.27 2951.75 54.71 70.62 2688.67 611.58 652.08 -351.67 7.78 2L-314 41 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 2996.97 58.01 72.30 2713.72 623.53 687.77 -350.70 7.93 3047.55 61.04 70.24 2739.37 637.54 729.04 -349.75 6.94 3096.14 63.66 66.83 2761.93 653.30 769.08 -350.86 8.23 3140.64 66.17 63.09 2780.80 670.37 805.58 -354.41 9.47 3184.72 67.52 60.08 2798.13 689.65 841.22 -360.35 6.99 3234.46 68.32 57.39 2816.83 713.57 880.61 -369.36 5.26 3278.66 67.81 54.50 2833.35 736.53 914.57 -379.31 6.17 3328.95 67.03 51.90 2852.66 764.34 951.75 -392.73 5.02 3372.60 65.94 49.37 2870.08 789.72 982.69 -405.99 5.87 3422.83 65.39 48.41 2890.78 819.81 1017.18 -422.48 2.06 3517.42 64.35 45.87 2930.95 878.05 1079.95 -455.73 2.67 3564.27 64.70 43.59 2951.10 908.09 1109.71 -473.79 4.46 3585.29 64.88 42.63 2960.06 921.98 1122.71 -482.39 4.22 3612.17 65.03 42.26 2971.44 939.95 1139.14 -493.65 1.37 3647.92 65.25 40.93 2986.47 964.21 1160.67 -509.08 3.43 3707.05 65.39 38.05 3011.16 1005.67 1194.84 -536.36 4.43 3741.85 65.47 36.62 3025.63 1030.83 1214.03 -553.44 3.74 3800.56 65.71 35.04 3049.89 1074.17 1245.33 -583.47 2.48 3896.39 64.71 34.22 3090.08 1145.76 1294.77 -633.82 1.30 3990.86 62.70 34.62 3131.92 1215.62 1342.63 -683.10 2.16 4083.27 62.44 36.33 3174.50 1282.41 1390.23 -729.59 1.67 4177.41 62.27 38.41 3218.18 1348.68 1440.84 -774.55 1.97 4271.62 62.31 40.43 3261.99 1413.11 1493.80 -816.98 1.90 4365.47 63.74 40.76 3304.56 1476.62 1548.23 -858.04 1.56 4461.21 64.89 39.73 3346.06 1542.47 1603.96 -900.86 1.54 4554.58 64.56 39.18 3385.92 1607.66 1657.62 -943.77 0.64 4649.64 64.32 37.61 3426.94 1674.87 1710.88 -988.71 1.51 4744.37 64.64 36.53 3467.75 1743.08 1762.41 -1035.18 1.08 4837.72 64.18 35.06 3508.07 1811.37 1811.65 -1082.51 1.50 4931.36 63.99 34.26 3549.00 1880.64 1859.55 -1131.22 0.79 5026.28 63.99 34.41 3590.62 1951.09 1907.66 -1180.96 0.14 5120.04 64.02 34.42 3631.72 2020.61 1955.29 -1230.00 0.03 5214.56 64.08 36.46 3673.08 2089.85 2004.57 -1278.21 1.94 5309.27 64.56 37.47 3714.12 2158.04 2055.90 -1324.74 1.09 5403.67 64.99 38.67 3754.36 2225.27 2108.56 -1369.90 1.24 5497.44 63.91 38.93 3794.80 2291.20 2161.57 -1413.73 1.18 5591.43 63.11 37.91 3836.72 2357.11 2213.84 -1457.78 1.29 5685.86 64.29 37.38 3878.56 2424.14 2265.54 -1503.08 1.35 5779.83 64.91 38.99 3918.87 2490.86 2318.02 -1547.83 1.68 5874.21 64.48 41.74 3959.22 2555.86 2373.27 -1590.02 2.67 5967.58 63.37 43.78 4000.26 2617.44 2430.20 -1628.41 2.29 6062.04 63.92 40.95 4042.20 2679.97 2487.22 -1667.67 2.75 6156.35 64.34 40.11 4083.35 2744.47 2542.37 -1709.41 0.92 2L-314 42 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 6250.25 64.10 41.49 4124.19 2808.47 2597.62 -1750.66 1.35 6343.78 63.64 42.64 4165.39 2870.81 2653.87 -1790.00 1.21 6438.82 63.80 43.67 4207.47 2932.97 2712.16 -1828.48 0.99 6533.72 64.52 44.71 4248.83 2994.21 2771.69 -1865.67 1.24 6627.79 66.46 46.58 4287.86 3054.04 2832.89 -1900.95 2.74 6722.50 67.76 48.06 4324.70 3113.18 2897.04 -1934.59 1.99 6816.92 68.34 49.37 4359.99 3170.96 2962.84 -1966.37 1.43 6910.20 68.51 50.30 4394.29 3226.91 3029.13 -1996.28 0.94 7002.85 68.55 52.74 4428.21 3280.55 3096.62 -2023.60 2.45 7097.45 67.65 56.71 4463.50 3331.24 3168.25 -2046.73 4.01 7191.66 66.07 61.24 4500.07 3375.99 3242.63 -2063.34 4.54 7286.04 65.75 64.35 4538.12 3415.47 3319.43 -2074.18 3.18 7379.45 65.01 68.25 4577.05 3449.60 3397.16 -2079.67 3.88 7473.22 65.14 72.05 4616.58 3478.47 3477.13 -2079.44 3.68 7568.47 65.00 77.54 4656.75 3501.11 3560.44 -2072.23 5.23 7613.10 65.24 80.72 4675.53 3508.75 3600.19 -2065.81 6.49 7661.69 65.82 84.16 4695.66 3514.56 3644.02 -2056.28 6.55 7755.84 66.72 89.00 4733.57 3519.69 3730.03 -2031.68 4.80 7850.68 66.97 93.11 4770.88 3518.08 3817.19 -2000.36 3.99 7944.07 66.30 96.14 4807.92 3511.17 3902.63 -1964.65 3.06 8038.15 65.30 99.43 4846.50 3499.56 3987.63 -1924.66 3.36 8131.79 64.84 102.25 4885.97 3483.60 4071.02 -1881.14 2.77 8225.74 65.19 105.36 4925.66 3463.28 4153.70 -1833.77 3.02 8320.80 65.39 108.71 4965.41 3437.98 4236.25 -1781.76 3.21 8412.85 65.34 112.25 5003.79 3408.71 4314.62 -1727.46 3.50 8508.72 65.30 117.09 5043.84 3372.37 4393.75 -1666.24 4.59 8602.75 66.05 121.50 5082.59 3330.45 4468.45 -1601.30 4.35 8695.95 66.85 126.12 5119.84 3282.92 4539.40 -1532.37 4.62 8790.48 67.78 130.77 5156.32 3228.70 4607.68 -1458.07 4.64 8883.97 68.53 134.97 5191.12 3169.67 4671.25 -1380.86 4.25 8978.41 69.71 138.90 5224.79 3105.22 4731.48 -1299.69 4.08 9056.15 72.04 142.05 5250.26 3048.57 4778.20 -1230.47 4.86 9123.32 73.99 140.78 5269.88 2998.36 4818.27 -1169.59 3.42 9218.27 76.79 144.11 5293.84 2925.53 4874.24 -1082.01 4.50 9313.83 80.53 145.53 5312.62 2848.96 4928.21 -991.60 4.18 9410.71 83.17 146.54 5326.36 2769.42 4981.78 -898.54 2.91 9503.90 85.85 148.98 5335.27 2690.98 5031.25 -807.90 3.88 9503.90 85.85 148.98 5335.27 2690.98 5031.25 -807.90 3.88 9539.42 86.89 149.09 5337.52 2660.58 5049.49 -773.10 2.94 9600.33 88.97 151.79 5339.72 2607.64 5079.51 -713.08 5.59 9693.35 89.87 153.65 5340.67 2524.97 5122.14 -620.82 2.22 9789.63 90.63 159.44 5340.24 2436.69 5160.45 -524.76 6.07 9885.33 91.00 162.72 5338.88 2346.18 5191.47 -429.10 3.45 2L-314 43 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 9981.71 91.28 164.42 5336.97 2253.76 5218.73 -332.93 1.79 10076.07 91.67 166.99 5334.54 2162.36 5242.02 -239.08 2.75 10170.92 90.27 166.60 5332.93 2070.03 5263.68 -144.91 1.53 10265.55 90.15 166.61 5332.58 1977.98 5285.60 -50.91 0.13 10360.48 89.43 164.92 5332.93 1885.97 5308.94 43.54 1.94 10456.02 89.12 160.66 5334.14 1794.73 5337.20 138.94 4.47 10550.58 89.56 160.09 5335.23 1705.67 5368.96 233.49 0.76 10645.96 89.53 162.45 5335.99 1615.35 5399.58 328.83 2.47 10742.60 89.46 162.31 5336.84 1523.25 5428.84 425.39 0.16 10837.71 88.98 157.43 5338.13 1433.98 5461.56 520.46 5.16 10931.66 89.19 151.47 5339.64 1349.27 5502.05 613.91 6.35 11029.31 88.84 152.67 5341.32 1263.01 5547.78 710.61 1.28 11124.47 87.81 155.50 5344.10 1177.46 5589.35 805.22 3.16 11219.77 86.96 157.25 5348.45 1090.25 5627.50 900.22 2.04 11315.43 86.89 158.84 5353.58 1001.66 5663.21 995.68 1.66 11410.66 86.29 159.84 5359.24 912.71 5696.75 1090.74 1.22 11506.56 87.44 163.24 5364.49 821.89 5727.07 1186.44 3.74 11541.23 87.99 164.39 5365.87 788.63 5736.72 1221.01 3.67 5.2 Survey Data. Pilot Hole Plugback Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section* (ft) Dogleg Rate (o/100ft) 9151.52 74.41 141.77 5277.79 2976.71 4834.53 5440.22 2.50 9246.49 70.09 144.28 5306.74 2904.49 4888.93 5474.08 5.20 9342.83 67.73 145.28 5341.40 2831.06 4940.77 5505.15 2.63 9438.43 65.05 145.62 5379.69 2758.92 4990.45 5534.46 2.82 9536.88 60.52 146.61 5424.70 2686.27 5039.26 5562.81 4.69 9572.89 60.52 146.61 5442.42 2660.10 5056.51 5572.70 0.00 *Note: Apparent discrepancies in the vertical section between the plugback and the production hole reflect changes in the vertical section azimuth from 75°for the Pilot Hole Plugback to 160° for the production hole. 2L - 3 1 4 44 5. 3 B i t R e c o r d Bi t S i z e M a k e T y p e / S N # J e t s / T F A De p t h I n MD To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) Av g . WO B (K l b s ) Av g . RP M Av g . PP (p s i ) Wear BHA 1 1 3 . 5 ” Ba k e r Hu g h e s VM - 3 52 3 9 8 0 5 4x 1 8 , 0 . 9 9 4 13 4 ’ 1 2 3 ’ 1 . 3 9 8 . 4 2 4 0 23 0 0-0-A-NO-E-1-X0-BHA 1 RR # 1 13 . 5 ” Ba k e r Hu g h e s VM - 3 52 3 9 8 0 5 4x 1 8 , 0 . 9 9 4 12 3 ’ 2 2 7 7 ’ 1 9 . 9 3 1 1 4 . 2 1 5 9 0 13 8 0 0-0-A-NO-E-1-X0-BHA 2 2 9 . 8 7 5 ” H a l i b u r t o n FX 6 5 P D C 11 7 8 5 5 2 2x 1 4 , 4 x 1 5 0. 9 9 1 25 3 4 ’ 6 5 7 5 ’ 5 4 . 6 1 2 0 . 6 1 2 12 0 2 7 0 0 0-1-WT-G-X-I-NO-TD 3,4 3 6 . 5 ” H y c a l o g SK H 5 1 3 M - A I C A1 9 7 6 5 0 5x 1 0 , 0 . 3 8 3 91 0 7 ’ 2 5 1 5 ’ 3 1 . 4 4 6 9 . 5 6 . 4 1 2 2 21 2 3 5 2L - 3 1 4 45 5. 4 M u d R e c o r d Co n t r a c t o r : M I S W A C O Mu d T y p e : D R I L L P L E X t o 2 , 5 3 4 , W B M - O t h e r t o T D Da t e D e p t h MW (p p g ) Te m p VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 7/ 1 0 / 1 4 0 9 . 6 7 2 - 3 1 6 5 1 6 / 1 6 / - - - / - 7 . 0 0 - / 9 3 - 1 0 . 8 - - 7/ 1 1 / 1 4 2 5 7 9 . 5 6 1 3 0 0 1 0 5 4 28 / 3 1 / 3 2 - - 6 . 7 5 - / 9 3 0 . 2 5 9 . 7 2 8 0 0 6 0 7/ 1 2 / 1 4 1 5 4 2 9 . 7 7 5 3 0 0 3 5 8 5 9 / 6 0 / 8 5 - - 1 0 . 0 0 1 / 8 9 - 1 0 . 9 1 3 0 0 6 0 7/ 1 3 / 1 4 2 5 5 0 9 . 8 7 6 3 0 0 8 2 1 6 0 / 1 2 0 / 1 8 8 - - 9 . 0 0 1 9 0 T r 1 0 . 8 6 0 0 6 0 7/ 1 4 / 1 4 2 5 3 4 9 . 7 6 8 5 9 1 3 2 2 3 4 / 6 9 / 1 1 0 - - 9 . 0 0 1 / 9 0 T r 1 0 . 7 6 0 0 6 0 7/ 1 5 / 1 4 2 5 3 4 9 . 8 6 7 3 5 1 6 1 6 1 4 / 1 5 / 1 6 - - 9 . 0 0 1 / 9 0 T r 1 0 . 5 3 0 0 6 0 7/ 1 6 / 1 4 2 5 3 4 9 . 6 7 0 4 5 1 7 3 0 8 / 9 / 1 0 6 . 0 2 / - 4 . 5 0 2 / 9 4 T r 1 0 . 0 6 0 0 6 0 7/ 1 7 / 1 4 2 5 3 4 9 . 6 7 0 4 5 1 7 3 0 8 / 9 / 1 0 6 . 0 2 / - 7 . 0 0 2 / 9 1 T r 1 0 . 0 6 0 0 6 0 7/ 1 8 / 1 4 3 8 0 3 9 . 6 8 7 4 2 1 2 2 1 8 / 9 / 1 0 6 . 0 1 / - 6 . 0 0 2 / 9 2 T r 9 . 8 6 0 0 4 0 7/ 1 9 / 1 4 4 7 1 2 9 . 8 8 5 5 3 1 5 2 8 1 1 / 1 4 / 1 6 4 . 8 1 / - 6 . 7 5 2 / 9 1 T r 9 . 9 8 0 0 4 0 7/ 2 0 / 1 4 6 0 3 2 9 . 6 1 0 0 5 1 1 5 3 0 1 2 / 1 4 / 1 5 4 . 0 1 / - 8 . 0 0 2 / 9 0 T r 9 . 8 7 0 0 6 0 7/ 2 1 / 1 4 6 9 5 8 9 . 8 1 0 0 5 0 1 4 2 4 1 1 / 1 2 / 1 3 3 . 7 1 / - 8 . 0 0 2 / 9 0 T r 9 . 5 6 0 0 6 0 7/ 2 2 / 1 4 7 4 5 2 1 0 1 2 7 4 8 1 8 2 5 1 0 / 1 2 / 1 3 3 . 0 1 / 1 9 . 0 0 2 / 8 9 T r 9 . 3 6 0 0 6 0 7/ 2 3 / 1 4 9 1 2 1 1 0 . 1 1 2 7 4 7 1 7 2 6 8 / 1 2 / 1 5 2 . 7 1 / - 1 0 . 0 0 3 / 8 7 - 9 . 1 8 0 0 6 0 7/ 2 4 / 1 4 9 1 2 1 1 0 . 2 - 5 0 1 8 2 3 9 / 1 4 / 1 6 3 . 2 1 / - 1 0 . 5 0 3 / 8 7 - 9 . 1 8 0 0 6 0 7/ 2 5 / 1 4 9 1 2 1 1 0 . 3 - 5 0 2 0 2 7 9 / 1 4 / 1 5 3 . 5 1 / - 1 0 . 5 0 3 / 8 7 - 9 . 1 8 0 0 6 0 7/ 2 6 / 1 4 9 1 2 1 1 0 . 3 - 4 8 2 0 2 7 5 / 6 / 7 4 1 / - 1 1 . 0 0 3 / 8 6 - 8 . 9 6 0 0 6 0 7/ 2 7 / 1 4 9 1 2 1 1 0 . 5 - 5 1 1 6 2 4 1 2 / 1 4 / 1 5 3 1 / - 1 0 . 0 0 3 / 8 7 - 9 . 0 9 0 0 6 0 7/ 2 8 / 1 4 9 1 2 1 1 0 . 5 - 5 1 1 6 2 4 1 2 / 1 4 / 1 5 3 1 / - 1 0 . 0 0 3 / 8 7 - 9 . 0 9 0 0 6 0 7/ 2 9 / 1 4 9 1 2 1 1 0 . 5 - 5 1 1 6 2 4 1 2 / 1 4 / 1 5 3 1 / - 1 0 . 0 0 3 / 8 7 - 9 . 0 9 0 0 6 0 7/ 3 0 / 1 4 9 1 4 0 1 0 . 5 - 5 1 1 5 1 9 8 / 9 / 1 0 3 1 / - 1 0 . 0 0 3 / 8 7 - 1 0 . 1 8 0 0 6 0 8/ 1 / 1 4 9 5 7 2 1 0 . 5 - 4 9 1 3 1 8 6 / 8 / 1 0 3 . 5 1 / - 1 0 . 0 0 3 / 8 7 - 1 0 . 4 8 0 0 6 0 8/ 2 / 1 4 9 5 7 2 1 0 . 5 - 1 1 1 1 8 1 6 9 / 1 1 / 1 5 4 1 / - 1 0 . 0 0 3 / 8 7 - 1 0 . 5 8 0 0 6 0 8/ 3 / 1 4 9 3 1 6 1 0 . 5 8 6 4 5 1 2 1 7 6 / 6 / 7 2 . 1 1 / - 1 2 . 0 0 3 / 8 5 - 2 . 5 1 1 2 0 0 0 8 0 8/ 4 / 1 4 1 0 4 2 4 1 0 . 5 9 8 4 5 1 2 2 2 6 / 7 / 8 2 . 3 1 / - 1 3 . 0 0 3 / 8 4 - 9 . 9 1 2 4 0 0 0 8 0 8/ 5 / 1 4 1 1 4 4 8 1 0 . 5 1 0 0 4 3 1 2 2 0 6 / 7 / 8 2 . 4 1 / - 1 3 . 0 0 3 / 8 4 - 9 . 7 1 2 4 0 0 0 8 0 8/ 6 / 1 4 1 1 6 2 2 1 0 . 5 - 4 5 1 2 1 9 6 / 8 / 8 2 . 4 1 / - 1 3 . 0 0 3 / 8 4 - 9 . 7 1 2 3 0 0 0 8 0 8/ 7 / 1 4 1 1 6 2 2 1 0 . 5 - 4 4 1 2 2 0 6 / 7 / 8 2 . 5 1 / - 1 3 . 0 0 3 / 8 4 - 9 . 7 1 2 3 0 0 0 8 0 8/ 8 / 1 4 1 1 6 2 2 1 0 . 5 - 2 7 - - - - - - - - - - - 8/ 9 / 1 4 1 1 6 2 2 1 0 . 5 - 2 7 - - - - - - - - - - - 2L - 3 1 4 46 Ab b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o n t e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y FL = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t p H = p H ( a t T e m p ) T e m p = F l o w l i n e T e m p e r a t u r e 47 6 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:9050'MD 9572'MD Country:5250 TVD 5443'TVD Averages Before During After Maximum ROP (fph)107 59 55 213 WOB 13 5 10 35 RPM 117 1,063 103 122 Mud Weight 9.8 10.0 10.0 10.0 Chloride 60 60 60 60 Total Gas 146 75 471 C1 (ppm)8,623 22,493 10,675 72,253 C2 (ppm)711 2,103 1,240 7,318 C3 (ppm)522 1,367 888 4,778 C4 (ppm)386 766 253 2,570 C5 (ppm)144 351 536 1,296 Lithology Cuttings Analysis Odor Slight Fluorescence Cut Fluorescence Residual Cut Stain none Amount 85%Type fast Amount Amount Distribution even Intensity bright Color Color Intensity bright Color blue white Residual Fluorescence Cut none Color white to yellow Intesity Color Color Show Ratin 2.5 Free Oil in Mud Comments Report by: SANDSTONE = TRANSLUCENT TO CLEAR WITH BLACK LITHICS, PALE GREEN YELLOWISH COLOR HUE, SMOKEY HUES, AND SLIGHT PALE GREEN HUES COLORS; QUARTZ DOMINATED WITH LITHIC INTERBEDDED FRAMEWORK; FINE TO VERY FINE GRAIN SIZE; WELL TO VERY WELL SORTING; SUBROUNDED TO ANGULAR ANGULARITY; MODERATE TO VERY LOW SPHE- RICITY; CONSOLIDATED SANDS TO MODERATE HARD HARDNESS; GRAIN ENALRGE- MENT CEMENT; CEMENT AND MATRIX GARIN SUPPORT; THICK BEDDING STRUCTURE; SLIGHT ODOR IN SAMPLE; NO ODOR IN SHAKER ROOM; NO STAINS; 85% BRIGHT EVEN YELLOWIH GREEN VISUAL FLUORESCENCE IN SAMPLE; WHITE BLUE WITH WHITE STREAMERS FLUOR-ESCENCE CUT COLOR; NO VISAUL CUT COLOR IN WHITE LIGHT; NO VISUAL RESIDUE COLOR; BRIGHT BLUISHEISH WHITE RESIDUE FLUORESCENCE CUT COLOR. none North Slope Borough Alaska United States ConocoPhillips : 50-103-20686-00-002L-314 Tarn Oil Pool Nabors 9ES July 22-31, 2014 10:00 pm - 11:45 pm bright James Foradas / Britten Adams NONEFROM OIL SHOW SUMMARY yellow white 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 64 Hydrocarbon Show Report #2 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:9200 MD 111621 MD Country:5293 TVD 5471 TVD Averages Before During After Maximum ROP (fph)44 59 77 10,211 WOB 7 4 4 15 RPM 61 122 122 133 Mud Weight 10.5 10.5 10.5 10.5 Chloride 123,000 123,000 123,000 123,000 Total Gas 45 332 19 1,035 C1 (ppm)7,973 49,273 3,030 204,116 C2 (ppm)629 4,632 287 18,217 C3 (ppm)318 2,565 191 7,880 C4 (ppm)135 1,367 110 3,552 C5 (ppm)1 573 134 1,443 Lithology Cuttings Analysis Odor Slight Fluorescence Cut Fluorescence Residual Cut Stain none Amount 60%-80%Type fast Amount Amount Distribution pachy Intensity bright Color Color Intensity bright Color blue white Residual Fluorescence Cut pale Color white to yellow Intesity Color straw Color Show Ratin 2.7 Free Oil in Mud Comments Report by: SANDSTONE = LIGHT GRAY TO MEDIUM GRAY WITH OLIVE HUES; LOWER VERY FINE TO UPPER FINE GRAINED; FAIR TO WELL SORTED; SUBROUNDED TO ROUNDED; MODERATE TO HIGH SPHERICITY; POLISH IS PRESENT ON SOME GRAIN SURFACES; ROCK COMPOSED OF QUARTZ 90% AND DARK LITHICS;FIRM FRIABLE TO EASILY FRIABLE; COMMON GRAIN ENLARGEMENT CEMENT; GRAIN SUPPORTED; COMMON SILT MATRIX AND GRAY BANDING; THIN STRUCTURE, INTERGRADING TO SILTSTONE IN PLACES; DULL GOLD TO BRIGHT YELLOWISH WHITE SAMPLE FLUORESCENCE (60-80%); INSTANT MODERATE BRIGHT MILK CUT; YELLOW WHITE CUT FLUORESCENCE SEEN IN SOME DULLER FLUORESCING CUT- TINGS; DULL GOLD RESIDUAL RING; VERY PALE LIGHT BROWNISH STRAW VISIBLE CUT. slight golden North Slope Borough Alaska United States ConocoPhillips : 50-103-20686-00-002L-314 Tarn Oil Pool Nabors 9ES August 3-6, 2014 5:00 pm - 1:00 am strong James Foradas / Britten Adams NONEFROM OIL SHOW SUMMARY yellow white 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 50 7 DAILY REPORTS ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rizek J. Riley Date: 7/10/14 Time: 23:59 Current Depth (MD): 0’ Current Depth (TVD): 0’ Current Operations: 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: - Max: - Mud Properties @ 0’ MW: 9.6 FV: - PV: 31 YP: 65 FL: - Gels: 16/16/- Sol: 7 pH: 10.8 Cl -: - Ca ++: - MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - Operational Summary: Rig accepted at 00:00 hrs 7/10/2014. Spot rig over well. Nipple up diverter. Function test bag & knife valve. Test gas alarms. Take on 9.6 ppg Drilplex fluid. Test mud lines & surface equipment. Load 5" drill pipe into pipe shed. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rizek J. Riley Date: 7/11/14 Time: 23:59 Current Depth (MD): 258’ Current Depth (TVD): 258’ Current Operations: Picking up BHA 24 hr Footage (MD): 123’ Drilling Parameters ROP: Current: - Max: 378 Torque: Current: - Max: 1620 WOB: Current - Max: 14 RPM: Current: - Max: 45 PP: Current: - Max: 307 Lag: Strokes: 486 Time: 3:50 Surf-Surf: Strokes: 520 Time: 4:00 ECD: Current: - Max: - Mud Properties @ 257’ MW: 9.6 FV: 300 PV: 10 YP: 54 FL: - Gels: 28/31/32 Sol: 6.75 pH: 9.7 Cl -: 2800 Ca ++: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 0 0 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 200 0 Lithologies: - Operational Summary: Finished P/U 5" Drill Pipe. Spud at 5:30 pm, Drilled pilot hole with dumb iron to 257 feet. Trip out of hole and pick up surface. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rizek J. Riley Date: 7/12/14 Time: 23:59 Current Depth (MD): 1903’ Current Depth (TVD): 1875’ Current Operations: Clearing Cuttings Box 24 hr Footage (MD): 1645’ Drilling Parameters ROP: Current: - Max: 416 Torque: Current: - Max: 7706 WOB: Current - Max: 33 RPM: Current: - Max: 83 PP: Current: - Max: 1359 Lag: Strokes: 3412 Time: 23:25 Surf-Surf: Strokes: 3736 Time: 25:38 ECD: Current: - Max: - Mud Properties @ N/A MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: 1450’ MD From: 9.6 To: 9.9 Reason: Keep back methane hydrates Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 1357’ / 1351’ 36 8933 2 1723’ / 1702’ 100 24153 3 1800’ /1776’ 108 26699 4 1859’ /1833’ 133 33468 Lithologies: Clay / Sand / Silt Operational Summary: Directional shallow test, establish good survey with gyro. Continue to pick up BHA. Drill to 957’ MD. Drill from 957’ MD to 1899’ MD. Prep 10 ¾ casing, stage 66 centralizers to the rig floor. Clear cuttings box at time of report. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rizek J. Riley Date: 7/13/14 Time: 23:59 Current Depth (MD): 2534’ Current Depth (TVD): 2404’ Current Operations: POOH 24 hr Footage (MD): 631’ Drilling Parameters ROP: Current: - Max: 270 Torque: Current: - Max: 6782 WOB: Current - Max: 41 RPM: Current: - Max: 94 PP: Current: - Max: 1514 Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: - Max: - Mud Properties @ 2534’ MW: 10.8 FV: N/A PV: 8 YP: 21 FL: N/A Gels: 60/120/188 Sol: 4.3 pH: 10.8 Cl -: 600 Ca ++: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases none Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 1903 112.914 28662.9 0 0 0 0 0 0 2 2025 229.086 58844.36 0 0 0 0 0 0 3 2345 185.845 45707.61 382.77 0 0 0 0 0 4 2509 91.655 21983.07 100.494 0 0 0 0 0 Lithologies: Clay Operational Summary: Circulate and condition hole until cuttings box was cleaned and continue drilling to 2534’ MD. Back reaming pump sweep. Trip out of hole from 1805’ MD to 1710’ MD, monitor well for 15 minutes, observed minimal swabbing, worked tight areas, back ream out of hole. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rizek J. Riley Date: 7/14/14 Time: 23:59 Current Depth (MD): 2534’ Current Depth (TVD): 2404’ Current Operations: RIH with casing. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: - Max: - Mud Properties @ 2534’ MW: 9.7 FV: 59 PV: 13 YP: 22 FL: N/A Gels: 34/69/110 Sol: 9 pH: 10.7 Cl -: 600 Ca ++: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases none Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: Finished BROOH with no issues. Laid down BHA. Made Dummy Run. Rigged up Tesco and started running CSG. at 3:30 PM. Called out trucks for cement job and created plan forward. Running 10.875" Casing at report time . Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rizek J. Riley Date: 7/15/14 Time: 23:59 Current Depth (MD): 2534’ Current Depth (TVD): 2404’ Current Operations: Nipple up BOPs. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: - Max: - Mud Properties @ 2534’ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases none Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: Condition hole for the cement job for third party. Cement the casing to 2534’ MD. Rig down cement equipment. R/D the diverter and R/U new diverter. Begin R/U new BOP stack. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rizek J. Riley Date: 7/15/14 Time: 23:59 Current Depth (MD): 2534’ Current Depth (TVD): 2404’ Current Operations: Racking drill pipe. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: - Max: - Mud Properties @ 2534’ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases none Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: Install and put together new BOP. Test Bops valves, rams, and fix gas alarms on rig. Pick up drill pipe (51 joints) and rack them back into the derrick. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/17/14 Time: 23:59 Current Depth (MD): 2534’ Current Depth (TVD): 2404’ Current Operations: Drilling out Cement. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: - Max: - Mud Properties @ 2534’ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases none Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: 6.B TRIP OUT OF HOLE POOH F/ 2150' T/ 579'' RACKING BACK 17 STDS IN THE DERRICK. DRILLS-BOP ETC KICK WHILE TRIPPING DRILL. PICK UP DRILL PIPE PJSM W/ CREW. P/U 51 JTS OF 5" DP 1571' RABBITING EACH JT OFF THE SKATE. TRIP OUT OF HOLE POOH F/ 2160' T/ SURFACE RACKING BACK 17 STDS DP IN DERRICK AND 6 STD OF HWDP. UP WT 90K DN WT 78K. TEST BOPS M/U TEST ASSEMBLY T/ TEST UPPER IBOP. TEST 250 PSI LOW / 3500 PSI HIGH F/ 5 MIN EACH AND CHART. TEST ASSEMBLY FAILED, DRAIN STACK-PULL WR-SET TEST PLUG AND RETEST. TEST WAS GOOD. INSTALL/REMOVE WEAR BUSHING INSTALL WR AND RUN IN LOCK DOWNS. CONT' TO R/D TEST EQUIPMENT, B/D KILL LINE AND LINE UP STACK FOR NORMAL OPS. PICK UP 3RD PARTY TOOLS P/U BIT, BIT BREAKER, LIFT SUBS AND PREP FLOOR F/ M/U BHA. PICK UP BHA PJSM W/ ALL INVOLVED PERSONAL IN P/U BHA. P/U BHA AS PER SLB DD. PICK UP BHA #3, PJSM, UWT 75K, DWT 70K, PICK UP DRILL PIPE PU 24 JTS F/ 755.92', T/1510', THEN SHALLOW TEST MWD, UWT 83, DWT 75K CIRCULATE AND CONDITION SHALLOW TEST MWD,@ 1510', GPM 500, PSI 1145, FLOW 68%, SPM 168, UWT 83K, DWT 75K PICK UP DRILL PIPE FINISH PU DP F/1510', T/2264.69', UWT 102K, DWT 92K, PRESSURE TEST CSG/SHOE R/U FOR CASING TEST, TEST CASINGT/3000 PSI FOR 30 MIN, MW 9.7PPG,TEST IS GOOD, RD EQUIP, BD LINES TRIP IN HOLE PJSM RIH F/2264, T/ FC @ 2446', TAG CEMENT @ 2433', WASHDOWN, UWT 110K, DWT 95K, PSI 500, TQ 3K, GPM 300, FLOW 45, SPM 102K, DRILLING CEMENT DRILL F/ 2446 T/ 2534 GPM- 120, PSI ON-761, PSI OFF- 520. RPM-15-70 TQ ON-4-5K, TQ OFF 3-3.5K. PU WT- 110K, SOW-95K, ROT-102K, MW- 9.7 PPG, LOADING 7 5/8 CASING IN THE SHED. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/18/14 Time: 23:59 Current Depth (MD): 4053’ Current Depth (TVD): 3155’ Current Operations: Drilling 24 hr Footage (MD): 1519’ Drilling Parameters ROP: Current: 113.8 Max: 263 Torque: Current: 7682 Max: 10264 WOB: Current 8.2 Max: 33 RPM: Current: 114.5 Max: 121 PP: Current: 2012 Max: 2033 Lag: Strokes: 956 Time: 00:04:22 Surf-Surf: Strokes: 5100 Time: 00:23:15 ECD: Current: 10.77 Max: 10.77 Mud Properties @ 4053’ MW: Gels: MW Change: Depth: 3900’ From: 9.6 To: 9.7 Reason: N/A Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 20 Max: 103 Depth (MD/TVD): 2534’/2403’ Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas none Connection Gases 3959’/3115’ 24u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 2811/2597 26.000 5198.000 3352/2862 37.914 6889.730 111.405 126.516 49.878 3906/3093 18.621 4717.803 76.913 136.940 4000/3132 33.259 5985.910 89.600 70.602 Lithologies: 50% Claystone, 10% Sand, 40% Sandstone. Operational Summary: ROTARY DRILLING F/ 2452' T/ 2526' @ 350 GPM W/ 700 PSI ON BTM 600 PSI OFF BTM 60 RPM W/ 4K TQ ON BTM 3K TQ OFF BTM UP WT 110K DN WT 95K RT WT 100K. ONCE OUT OF SHOE, DRILL @ 600 GPM W/ 1500 PSI ON BTM 1500 PSI OFF @ 80 RPM W/ 4.5K TQ ON BTM 4K TQ OFF, 5K WOB - T/ 2554'. CHANGE OUT MUD SYSTEM DISPLACE MUD T/ 9.6PPG LSND @ 600 GPM W/ 1420 PSI @ 30 RPM W/ 2K TQ. TRIP OUT OF HOLE F/ 2554' T/ 2415' UP WT 105K DN WT 95K. R/U T/ PERFORM LOT PUMPING DN DP AND DN KILL LINE AT THE SAME TIME. PRESSURE TEST CSG/SHOE PERFORM LOT. PRESSURE UP T/ 850 PSI AND SHUT IN. 16.2PPG EMW ROTARY DRILLING TIH F/ 2415' T/ 2554' UP WT 105K DN WT 95K. DRILL F/ 2554' T/ 2661' @ 625 GPM W/ 1520 PSI ON BTM 1500 PSI OFF, @ 80 RPM W/ 5K TQ ON BTM 3.5K TQ OFF, 5K WOB, UP WT 105K DN WT 100K RT WT 100K. SPR @ 2542' MD/2409'TVD- #1MP @ 2BBL/MIN-110 PSI @ 3BBL/MIN-140 PSI. #2MP @ 2BBL/MIN-100 PSI, @ 3BBL/MIN 160 PSI, W/ 9.6 PPG LSND MUD. TRIP OUT OF HOLE SWIVEL PACKING ON TD WASHED OUT. POOH F/ 2661' T/ 2452' UP INSIDE THE SHOE TO C/O. CHANGE OUT SWIVEL PACKING B/D TD AND C/O SWIVEL PACKING. TRIP IN HOLE F/ 2452' T/ 2661' UP WT 110K DN WT 95K. ROTARY DRILLING DRILL F/ 2661’ T/3019’, GPM- 650, PSI ON-1750, PSI OFF- 1730. RPM-120 TQ ON-5K, TQ OFF 3.5K. PU WT- 110K, SOW-95K, ROT-100K, ART-3.42HRS, ADT- 3.42HRS, TOTAL BIT HRS-3.42 TOTAL JAR HOURS-40.5SPRS TAKEN AT 1100HRS, 3014' MD, 2734 TVD, PUMP #1 AT 2 BPM= 90 PSI, AT 3 BPM=130 PSI. PUMP #2 AT 2 BPM=90 PSI, AT 3 BPM= 130 PSI MW- 9.6 PPG, ROTARY DRILLING -F/ 3019 MD T/3538 MD, TVD=2938 MD, ECDS= 10.4-10.5 PPG, ART= 3.84 HR, AST=0 HR, ADT= 3.84 HRS, PUW= 121K, SOW= 100K, ROT=105K, RPM= 120, GPM= 650, PSI ON= 1890, PSI OFF=1870, TQ ON= 6-8K FT/LBS, TQ OFF= 5K FT/LBS. PUMP 40BBLS SWEEP @ 3200' 10-15% INCREASE, REAM FULL STD'S,SPRS TAKEN AT 17:00HRS, 3490 MD, 2915 TVD, PUMP #1 AT 2 BPM= 100 PSI, AT 3 BPM=140 PSI. PUMP #2 AT 2 BPM=100 3BPM=130 ROTARY DRILLING -F/ 3538 MD T/4055 MD,TVD=3158 MD,ECDS=10.4-10.7PPG, ART= 3.36 HR, AST=0HR, ADT=3.36HRS,PUW=122K,SOW=95K,ROT=103K,RPM=120,GPM= 650,PSI ON=1970,PSI OFF=1930,TQ ON=7-9K FT/LBS,TQ OFF=4-5K FT/LBS. 40 BBLS SWEEP@ 3700' 10- 15% INCREASE,REAM FULL STD'S, 30' SURVEYS AS PER DD T/ 3800'SPRS TAKEN AT 2345HRS, 4055'MD, 3158 TVD, PUMP #1 AT 2 BPM=100PSI,3 BPM=130PSI. PUMP #2 BPM=100PSI, 3 BPM 150PSI. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/19/14 Time: 23:59 Current Depth (MD): 4950’ Current Depth (TVD): N/A Current Operations: Drilling 24 hr Footage (MD): 897’ Drilling Parameters ROP: Current: 171 Max: 377.5 Torque: Current: 8651 Max: 10922 WOB: Current 9 Max: 18 RPM: Current: 171 Max: 377.5 PP: Current: 2162 Max: 2264 Lag: Strokes: 4995 Time: 00:22:51 Surf-Surf: Strokes: 6165 Time: 00:28:11 ECD: Current: 10.6 Max: 10.7 Mud Properties @ 4950’ MW: Gels: MW Change: Depth: 4875’ From: 9.8 To: 9.7 Reason: N/A Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 24 Max: 55 Depth (MD/TVD): 4242’ MD Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 4523’/3313 2u Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 4004’ MD 32.224 5802.679 86.123 67.704 4332‘ MD 42.155 9446.644 97.529 69.181 4417’ MD 32.017 6895.250 174.442 134.097 4504’ MD 37.345 7943.267 180.060 65.871 Lithologies: 10% Claystone, 30% Sand, 50% Sandstone, 10% Siltstone. Operational Summary: ROTARY DRILLING F/4055' T/ 4526' @ 120 RPM W/ 8-10K TQ ON BTM, 7.5K TQ OFF BTM @ 650 GPM W/ 2200 PSI ON BTM, 2170 PSI OFF BTM, W/ 10K WOB. UP W T 130K DN WT 95K RT WT 105K. SPR @ 4526' MD 3374' TVD- #1MP @ 2BBL/MIN-150 PSI, @ 3BBL/MIN- 200 PSI. #2MP @ 2BBL/MIN-150 PSI @ 3BBL/MIN- 200 PSI. 3.05 HRS ADT. JAR HRS-54.2 BIT HRS-13.72 CIRCULATE AND CONDITION @ 4526' CIRC SWEEP AROUND @ 650 GPM W/ 2130 PSI @ 50 RPM W/ 6K TQ. SHUT DN PUMPS AND MONITOR WELL TO VARIFY WELL IS STATIC. BACK REAMING F/ 4526' T/ 2452' @ 600GPM W/ 1930 PSI @ 60 RPM W/ 6.5K TQ. UP WT 135K DN WT 100K RT WT 130K. PUMP SURVEYS AS NEEDED PER SLB DD. CIRCULATE AND CONDITION CBU @ 2526' TO CLEAN OUT CSG @ 600 GPM W/ 1690 PSI @ 50 RPM W/ 3K TQ. UP WT 105K DN WT 90K RT WT 100K. MONITOR THE WELL FOR 30 MIN TO VARIFY STATIC. SERVICE RIG B/D TOP DRIVE, AND SERVICE THE RIG. PRE JOB SAFETY - FOR CUT AND SLIP, SPOOL OUT LINE ON ROOF, PREP FLOOR FOR CUT AND SLIP, GET ALL TOOLS TOGETHER CUT DRILLING LINE - CUT 12 WRAPS, 78' DRILLING LINE, INSPECTION OF DRAW WORKS BRAKES. INSPECT DEAD MAN BRASS AND WELDS ON DEAD MAN BRACKET, CLEAN OUT INSIDE OF DW AND LAY DOWN NEW ABSORB, CHECK BRAKE BANDS, SERVICE RIG - SERIVCE CROWN SECTION, P/U TOOLS F/ CUT AND SLIP, PREP F/ RIH TRIP IN HOLE RIH F/ 2450' T/4418' UWT=140K DWT=100K, HOLE FILL = 16.7CAL FILL=17, FILL PIPE @ 3380' 70-SPM 360 PSI, NO TIGHT SPOTS OBSERVED DURING TRIP CHANGE OUT MUD SYSTEM ROT/RICP F/ 4431' T/ 4515' GPM= 650, PSI OFF= 2115, TORQ OFF= 6K, ROT WT= 108K, DUMP/DELIUTE MUD W/ 290 BBLS NEW 9.6 LSND ROTARY DRILLING F/ 4526’ MD T/ 4997 MD,TVD=3576MD,ECDS=10.5-10.7PPG,ART=3.36HR, ADT=3.36 HRS, PUW=133K, SOW=103K, ROT=113K, RPM=120, GPM=650, PSI ON=2180, PSI OFF=2135, TQ ON=8-10K FT/LBS,TQ OFF=6-7K FT/LBS. REAM 90' SWEEP @ 4800' 15-20%,SPRS AT 2315 HRS, 4900'MD, 3534TVD, PUMP #1 AT 2 BPM=150PSI, AT 3 BPM=200PSI. PUMP #2 AT 2 BPM=140PSI, AT 3 BPM= 200PSI MW-9.7PPG Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/20/14 Time: 23:59 Current Depth (MD): 6317’ Current Depth (TVD): 4153’ Current Operations: Drilling 24 hr Footage (MD): 1367’ Drilling Parameters ROP: Current: 59.58 Max: 248.1 Torque: Current: 10455.53 Max: 11949 WOB: Current 8.86 Max: 17 RPM: Current: 118.03 Max: 124 PP: Current: 2474.65 Max: 2547 Lag: Strokes: 6302.79 Time: 00:28:55 Surf-Surf: Strokes: 7807.50 Time: 00:35:45 ECD: Current: 10.7 Max: 10.7 Mud Properties @ 6317’ MW: Gels: MW Change: Depth: 5850’ From: 9.7 To: 9.6 Reason: N/A Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 274 Max: 972 Depth (MD/TVD): 5939’/3987’ Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases 6317’/4153’ 1020u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 5684’/3877’ 225 33905.426 2290.106 1176.093 448.683 909.790 233.271 242.444 5800’/3927’ 155 22295.711 1483.470 876.124 303.500 646.726 225.309 170.855 6073’/4046’ 147 22709.963 1518.871 809.104 281.770 656.917 173.958 166.057 6219’/4110’ 219 31551.366 2130.802 1114.477 534.885 1094.296 289.996 342.447 Lithologies: 10% Sand, 90% Siltstone. Operational Summary: ROTARY DRILLING DRILL F/4997 T/5500, GPM- 650, PSI ON-2240, PSI OFF-2200 . RPM-120 TQ ON-9.7K, TQ OFF 8K. PU WT- 140K, SOW-100K, ROT-113K, SPRS TAKEN AT 0430HRS, 5374' MD, 3741’TVD, PUMP #1 AT 2 BPM= 180 PSI, AT 3 BPM=230 PSI. PUMP #2 AT 2 BPM=180 PSI, AT 3 BPM= 230 PSI MW- 9.6 PPG. ROTARY DRILLING DRILLED F/ 5500’ T/5751, GPM- 650, PSI ON-2365, PSI OFF- 2350. RPM-120 TQ ON-10K, TQ OFF 8K. PU WT- 145K, SOW-100K, ROT-110KADT- 5.78HRS, TOTAL BIT HRS-22.79 TOTAL JAR HOURS-63.32 - SPRS TAKEN AT 0430HRS, 5374' MD, 3741TVD, PUMP #1 AT 2 BPM= 180 PSI, AT 3 BPM=230 PSI. PUMP #2 AT 2 BPM=180 PSI, AT 3 BPM= 230 PSI MW- 9.6 PPG. WORKING STUCK PIPE 5652' PACKED OFF. 17K TQ, 3000 PSI ON THE UP STROKE, SHUT DN PUMPS AND BREAK OVER DN. UP WT 150K DN WT 100K, 25K OVER PULL. WORK PIPE UP T/ 5464' ESTABLISH RETURN FLOW @ 36SPM W/ 385 PSI. 13K TQ W/ 125 RPM. WORKING STUCK PIPE -ROT/RICP F/ 5563' T/5469', WALK PUMP BACK UP TO DRILLING RATE, GPM=650, PSI OFF=2300, TORQ ON=8-9K, ECD WHEN MWD BACK SIGNAL=11.17 DROPPED TO 10.68, B/U GAS MAX 1390 UNITS. RWT=115K, PUMP 30BBLS NUTPLUG/DRILL ZONE PILL, HOLE UNLOADED 30% CUTTINGS INCREASE WORKING PIPE/TIGHT SPOT - RIH F/ 5563' T/5751', GPM-650, PSI-2340, RPM-120, TORQ- 7-9K, UWT- 155K,DWT-105K RWT-118K, NO TIGHT SPOTS OBSERVED 14:00 18:00 4.00 2.A ROTARY DRILLING DRILLED F/ 5751’ MD T/ 5968’ MD, TVD = 4097’ MD,ECDS=10.6- 10.7PPG, ART= 2.39HR, ADT=2.39HRS, PUW=151K,SOW=107K,ROT=125K, RPM= 120, GPM= 650, PSI ON=2415, PSI OFF=2350, TQ ON=9-12FT/LBS, TQ OFF= 8-9FT/LBS.SPRS AT1530HRS, 5845MD,3946’ TVD, PUMP #1 AT 2 BPM=200PSI, AT 3 BPM=250PSI. PUMP #2 AT 2 BPM=200PSI, AT 3 BPM=250PSI MW- 9.7 PPG, BR 95' B4 CONN. ROTARY DRILLING DRILLED F/ 5751’ MD T/ 6315’ MD, TVD=4152’ MD, ECDS=10.6-10.8PPG, ART= 3.29 HR, ADT=3.29 HRS, PUW=151K, SOW=110K,ROT=125K, RPM= 120, GPM= 650, PSI ON=2450, PSI OFF=2400, TQ ON=9-11KFT/LBS, TQ OFF= 7-9KFT/LBS. SPRS AT1530HRS, 5845MD, 3946’ TVD, PUMP #1 AT 2 BPM=200PSI, AT 3 BPM=250PSI. PUMP #2 AT 2 BPM=200PSI, AT 3 BPM=250PSI MW- 9.7 PPG, CIRC SWEEP @ 6120- 20% INCREASE, BR 95', CONN GAS 1200-1400 UNITS Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/21/14 Time: 23:59 Current Depth (MD): 6713’ Current Depth (TVD): 4321’ Current Operations: Drilling 24 hr Footage (MD): 796’ Drilling Parameters ROP: Current: 151 Max: 204 Torque: Current: 11195 Max: 13888 WOB: Current 6 Max: 14 RPM: Current: 151 Max: 204 PP: Current: 2522 Max: 2634 Lag: Strokes: 7089 Time: 00:32:33 Surf-Surf: Strokes: 8790 Time: 00:44:20 ECD: Current: 107 Max: 10.7 Mud Properties @ 7113’ MW: Gels: MW Change: Depth: 6900’ From: 9.7 To: 9.8 Reason: N/A Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 161 Max: 1158 Depth (MD/TVD): 7082’MD Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases 6882/4384 1955u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 6651/4297 211 30204.869 2005.213 1066.915 484.740 957.987 306.118 322.336 6687/4311 206 29126.961 2020.385 1026.919 437.938 936.330 294.574 236.170 6882/4384 158 21801.877 1695.876 1047.457 420.028 878.792 277.059 294.290 7100/4465 984 234694.727 10683.089 3924.452 844.116 2036.863 470.722 480.459 Lithologies: 100% Sand. Operational Summary: ROTARY DRILLING F/ 6315' T/ 6410' @ 120 RPM W/9.5K ON 8K TQ OFF @ 650 GPM W/ 2450 PSI ON 2435 PSI OFF, UP WT 150K DN WT 105K RT WT 125K, 10K WOB. SHOWING SIGNS OF PACK OFF ON BACK REAM, INFORMED COMAN AND DECIDE TO BROOH F/ 6410' T/4500'. ADT- .95 HRS, JAR HRS-69.95, TTL BIT HRS - 29.42 BACK REAMING F/ 6410' T/ 4500' @ 100 RPM W/ 8-9K TQ ON 7-8K TQ OFF @ 650 GPM W/ 2450 PSI. UP WT 150K DN WT 105K RT WT 125K. ADJUST PULLING SPEED W/ ECD'S. SERVICE RIG @ 4500' MONITOR THE WELL T/ VARIFY WELL IS STATIC, AND SERVICE THE RIG. TRIP IN HOLE F/ 4500' T/ 6410' UP WT 150K DN WT 100K. CIRCULATE AND CONDITION CBU @ 100 RPM W/ 9K TQ, @ 650 GPM W/ 2620 PSI. CIRC UNTIL TRIP GAS DISIPATED AND BACK TO NORMAL PERAMITERS W/ 2440 PSI. UP WT 150K DN WT 100K RT WT 128K. SPR @ 6410' MD 4193' TVD W/ 9.8 PPG MW - MP #1 @ 2BBL/MIN - 190 PSI @ 3BBL/MIN- 260 PSI, MP#2 @ 2BBL/MIN - 190 PSI @ 3BBL/MIN - 260 PSI. ROTARY DRILLING -F/ 6410’ MD T/ 6785’ MD, ECDS=10.5-10.6 PPG, ART= 3.61 HR, ADT= 3.61 HRS, PUW= 157K, SOW= 112K, ROT= 112K, RPM= 120, GPM= 650, PSI ON= 2450, PSI OFF= 2420, TQ ON= 10-12 FT/LBS, TQ OFF= 8-9 FT/LBS. WOB-8-12. 40 BBL HI-VIS SWEEP @ 6425' 10 % INCREASE ROTARY DRILLING -F/ 6785’ MD T/7100’ MD,TVD=4454’ MD,ECDS=10.6-10.7PPG,ART=3.87HR,ADT= 3.87HRS,BITHRS-35.87PUW=157K,SOW=117K,ROT=132K,RPM=120,GPM= 650,PSI ON= 2550, PSI OFF=2500,TQ ON=10-12K FT/LBS,TQ OFF=8-9KFT/LBS.SPRS TAKEN AT 2000HRS,6880 MD,4385’ TVD,PUMP#1 AT 2 BPM=150PSI,AT 3 BPM=210PSI. PUMP#2 AT 2BPM=150 PSI, AT 3BPM=210 PSI MW- 9.8,SWEEP@ 6790' 10% INCREASE. ICEBURG @ 7030' MD, MONT. WELL CON. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/22/14 Time: 23:59 Current Depth (MD): 8474’ Current Depth (TVD): N/A’ Current Operations: Drilling 24 hr Footage (MD): 1761’ Drilling Parameters ROP: Current: 64.8 Max: 211.6 Torque: Current: 15594 Max: 15786 WOB: Current 4.63 Max: 17 RPM: Current: 113.6 Max: 125 PP: Current: 2669 Max: 2695 Lag: Strokes: 8394 Time: 00:42:41 Surf-Surf: Strokes: 1045 Time: 00:51:34 ECD: Current: 11 Max: 11.1 Mud Properties @ MW: Gels: MW Change: Depth: 7100’ MD From: 9.9 To: 10.0 Reason: N/A Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 25 Max: 1158 Depth (MD/TVD): 7082’ MD Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases 7260’ MD 884u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 6960’ MD 285 43215.782 3040.374 1677.954 605.736 1268.280 366.315 358.967 7356’ MD 142 18043.055 1407.611 973.952 380.151 668.383 188.289 262.370 7565’ MD 161 21203.592 1592.201 1037.188 400.687 747.366 307.313 398.538 8143’ MD 49 8062.390 471.587 409.004 94.758 161.539 71.976 108.021 Lithologies: 10% Sand, 60% Siltstone, 30% Sandstone. Operational Summary: ROTARY DRILLING DRILL F/ 7100 T/ 7447, GPM-650, PSI ON-2600, PSI OFF- 2550 . RPM-120 TQ ON-11- 13K, TQ OFF 8-9K. PU WT- 160K, SOW-115K, ROT-130K, SPRS TAKEN AT 0220 HRS, 7259' MD, 4499 TVD, PUMP #1 AT 2 BPM= 160 PSI, AT 3 BPM=230 PSI. PUMP #2 AT 2 BPM=160 PSI, AT 3 BPM= 225 PSI MW- 10.0 PPG, ROTARY DRILLING DRILL F/ 7447’ T/7850, GPM- 640, PSI ON-2630, PSI OFF- 2595. RPM- 120 TQ ON-12-14K, TQ OFF 9K. PU WT- 165K, SOW-115K, ROT-115K, ADT-6.01HRS, TOTAL BIT HRS- 41.88 TOTAL JAR HOURS-82.41 SPRS TAKEN AT 1020HRS, 7730' MD, 4685 TVD, PUMP #1 AT 2 BPM= 180 PSI, AT 3 BPM=240 PSI. PUMP #2 AT 2 BPM=180 PSI, AT 3 BPM= 240 PSI MW-10.0 PPG. ROTARY DRILLING DRILL F/7850 T/8197, GPM- 640, PSI ON-2650, PSI OFF- 2600, RPM-120 TQ ON-12-14K, TQ OFF 9-11K. PU WT- 173K, SOW-120K, ROT-133K, WOB- 10-13K, ECD 10.9-11.1, ART- 3.14HRS, ADT-3.14HRS, BIT HRS-4.14, SPRS TAKEN AT 1800HRS, 8197 MD, 4912 TVD, PUMP #1 AT 2 BPM=210 PSI, AT 3 BPM=270 PSI. PUMP #2 AT 2 BPM=210 PSI, AT 3 BPM=270 PSI MW- 10 PPG, SWEEP @ 8000' 10% INCREASE ROTARY DRILLING DRILL F/8197 T/8479, GPM- 640, PSI ON-2650, PSI OFF- 2620 .RPM-120 TQ ON-12- 15K, TQOFF 11-14K. PU WT- 179K, SOW-125K, ROT-143K, WOB-10-13K, ECD-10.9-11.1, ART-3.05HRS, ADT-3.05HRS, TOTAL BIT HRS-48.07 TOTAL JAR HOURS 88.6SPRS TAKEN @ 2300HRS, 8497 MD, 5029 TVD, PUMP #1 AT 2 BPM= 190 PSI, AT 3 BPM=250PSI. PUMP #2 AT 2 BPM=190PSI, AT 3 BPM=250PSI MW-10.1PPG, SWEEP @ 8440' 10% INCREASE Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/23/14 Time: 23:59 Current Depth (MD): 9120’ Current Depth (TVD): N/A’ Current Operations: Reaming Hole. 24 hr Footage (MD): 8474’ Drilling Parameters ROP: Current: 212 Max: 195 Torque: Current: 19997 Max: 17205 WOB: Current 19 Max: 12.3 RPM: Current: 124 Max: 116.4 PP: Current: 2822 Max: 2677 Lag: Strokes: 9029 Time: 00:43:43 Surf-Surf: Strokes: 11221 Time: 00:54:22 ECD: Current: 11.1 Max: 11.1 Mud Properties @ MW: Gels: MW Change: Depth: 8600’MD From: 10.0 To: 10.2 Reason: N/A Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 130 Max: 705 Depth (MD/TVD): 8970’MD Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases 8947’MD 553u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 8918’MD 113 16990.017 1196.469 700.467 95.038 276.016 108.769 38.236 8933’MD 127 17915.156 1386.960 817.752 241.176 485.151 160.822 149.083 8970’MD 705 113450.339 10925.417 7246.806 1443.236 3027.892 859.042 167.902 9001’MD 204 28435.594 2208.347 1461.468 292.277 619.974 204.610 205.357 Lithologies: 50% Siltstone, 50% Sandstone. Operational Summary: CIRCULATE AND CONDITION CBU @ 8479' @ 640 GPM W/2715 PSI @ 120 RPM W/ 13-14K TQ. UP WT 175K DN WT 120K RT WT 140K. MONITOR THE WELL F/ 15 MIN T/ VARIFY STATIC. BACK REAMING F/ 8479' T/ 6410' @ 640 GPM W/ 2715 ICP, 2500 FCP @ 120 RPM W/ 13-14K INITIAL TQ, 10-12K FINAL TQ. INITAL UP WT 175K DN WT 120K RT WT 140K, FINAL UP W T 160K DN WT 105K RT WT 125K. ADJUST PULLING SPEED W/ ECD'S, MAX ECD ENCOUNTERED - 11.11, MW- 10.1 PPG. SERVICE TOP DRIVE MONITOR THE WELL TO VARIFY STATIC. SERVICE WASH PIPE. TRIP IN HOLE F/ 6410' T/8385' UP WT 1180K DN WT 110K. CIRCULATE AND CONDITION WASH DN AND CBU F/ 8385' T/ 8479' @ 640 GPM W/ 2800 PSI @ 120 RPM W/ 14K TQ. UP WT 180K DN WT 120K RT WT 140K .ROTARY DRILLING DRILL F/ 8479 T/8668, GPM- 640, PSI ON-2780, PSI OFF- 2750. RPM-120 TQ ON-16K, TQ OFF 14K. PU WT- 185K, SOW-120K, ROT-140K, ADT-1.94HRS, TOTAL BIT HRS-50.01 TOTAL JAR HOURS-90.54 SPRS TAKEN AT 0001 HRS, 8475 MD, 5030 TVD, PUMP #1 AT 2 BPM= 190 PSI, AT 3 BPM=250 PSI PUMP #2 AT 2 BPM=190 PSI, AT 3 BPM= 250 PSI MW- 10.1 PPG, ROTARY DRILLING -F/7850 T/9044,TVD 5246' GPM- 640, PSI ON- 2760, PSI OFF- 2725, RPM-120 TQ ON-17-20K,TQ OFF 15-17K. PU WT- 200K, SOW-120K, ROT-145K, WOB-10-13K, ECD 10.9-11.1,SPRS TAKEN AT 1700HRS, 8950 MD, 5214 TVD, PUMP #1 AT 2 BPM=210 PSI, AT 3 BPM=280 PSI. PUMP #2 AT 2 BPM=210 PSI, AT 3 BPM= 280 PSI MW- 10.2PPG, SWEEP @ 8950' 40% INCREASE, ART-3.91, ADT-3.91, CIRCULATE AND CONDITION CIRC BU AS PER GEO. CALLED 9044' TD, TAKE SURVEY/NEW SPR'S, F/9044 T/8950, GPM- 640, PSI OFF- 2375, RPM- 110,TQ OFF 14-17.5K. PU WT- 200K, SOW-120K, ROT-145K, ECD 10.9-11.1,SPRS TAKEN AT 1920 HRS, 9042 MD, 5255 TVD, PUMP #1 AT 2 BPM=210 PSI, AT 3 BPM=270 PSI. PUMP #2 AT 2 BPM=210 PSI, AT 3 BPM= 270 PSI MW- 10.2 PPG, BACK REAMING - F/ 9044' T/8851' CIRC BU EVERY STD RACKED BACK, GPM=630, RPM=110, TORQ OFF-13-15K, UWT-200K, DWT-125K, RWT-145K, ECD'S-10.9-10.8, CO- MAN/GEO DECIEDED TO DRILL T/ 9120', WASH BACK DOWN TO 9044' 21:00 22:00 1.00 2.A ROTARY DRILLING -F/9044 T/9120, TVD 5269' GPM- 630, PSI ON-2660, PSI OFF- 2630, RPM-120 TQ ON-15-17K,TQ OFF 13-15K. PU WT- 200K, SOW-120K, ROT-145K, WOB-10-13K, ECD 10.9-11.1,SPRS TAKEN AT 1700HRS, 8950 MD, 5214 TVD, PUMP #1 AT 2 BPM=210 PSI, AT 3 BPM=280 PSI. PUMP #2 AT 2 BPM=210 PSI, AT 3 BPM= 280 PSI MW - 10.2PPG, ART-79 , ADT-.79, TOTAL BHA/BIT HRS- 54.63 JAR TOTAL-95.16 CIRCULATE AND CONDITION -CIRC BU AS PER GEO. CALLED 9120' TD, TAKE SURVEY/NEW SPR'S, F/9120 T/9040, GPM- 620, PSI OFF- 2650, RPM-110, and TQ OFF 14-17K. PU WT- 200K, SOW-120K, ROT-145K, ECD 10.9-11,SPRS TAKEN AT 2200 HRS, 9120 MD, 5269 TVD, PUMP #1 AT 2 BPM=210 PSI, AT 3 BPM=270 PSI. PUMP #2 AT 2 BPM=210 PSI, AT 3 BPM= 270 PSI MW-10.2 PPG, CIRC 45 BBLS WT SWEEP, 11.0 PPG HIGH VIS @ 23:30 HRS Report Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/24/14 Time: 23:59 Current Depth (MD): 9120’ Current Depth (TVD): 5271’ Current Operations: L/D BHA. 24 hr Footage (MD): 00’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 5404’/3753’ 3344 Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: CIRCULATE AND CONDITION CONT' CBU @ 9120' @ 615 GPM, W/ 2590 PSI @ 105 RPM W/ 14-16K TQ, UP WT 190K DN WT 115K RT WT 145K. MONITOR THE WELL 30' OFF BTM F/ 30 MIN TO VARIFY WELL IS STATIC. MESSURE FLUID LEVEL F/ RKB AND OBSERVE NO FLOW OR LOSSES. TRIP OUT OF HOLE F/9120' T/ 7338' UP WT 205K DN WT 118K, 10K DRAG. @ 8820' T/ 8755' 15-30K OVER PULL, WORK STRING UNTIL FREE UP WT. @ 8636' 35K OVER PULL, WORK STRING UNTIL FREE UP WT. PUMP D/J @ 7716', B/D TD. TRIP OUT OF HOLE F/ 7338' T/ 4910', UP WT 175K UP WT 110K DN WT @ 6360' T/ 6320' OVER PULL 30K, WHIP BACK THROUGH ONCE TILL FREE P/U WT. @ 5458' 25K OVER PULL T/ 5428', 5170' 20K OVER PULL, 4910' 25K OVER PULL. TRIP IN HOLE F/ 4910' T/ 5500' T/ BROOH. UP WT 150K DN WT 100K. BACK REAMING F/ 5500' T/ 5150' @ 640 GPM W / 2515 PSI @ 120 RPM W/ 8-9K TQ. UP WT 150K DN WT 100K RT WT 115K. BACK REAMING F/ 5150' T/ 2450' @ 640 GPM W/ 2515 PSI @ 120 RPM W/ 8-9K TQ. UP WT 150K DN WT 100K RT WT 115K. CAL DIS = 16.5 ACT FILL=11.5, RAN H20 TO CLEAN SHAKERS/H20 FOR WT. CIRCULATE AND CONDITION - PUMP 40 BBL SWEEP T/ SURFACE, HOLE UNDLOADS CUTTINGS, GPM-605, PSI-1950, RPM-110, TORQ- 2.8-3.3, RWT-97K, UWT-XXK DWT-94K, MONT. WELL, PUMP 30 BBL SLUG, REMOVE BLOWER HOSE, B/D TD, LINE UP ON TT FOR POOH, PREP FLOOR FOR L/D BHA TRIP OUT OF HOLE - F/2450' T/756', UWT-75KDWT-70K, MONT. WELL AT BHA, PJSM FOR L/D BHA, CAL HOLE FILL= 9.9BBLS ACT FILL=15BBLS LAY DOWN BHA -L/D 17 JNTS HWDP, JARS, 3 NMFC, BRING SOURCE BOX UP, PJM FOR PULLING SOURCE, REMOVE SOURCE, SEND SOURCE BOX BACK OUT, CONT. L/D BHA AS PER DD, CAL FILL= 20BBLS, ACT FILL= 23BBLS LAY DOWN BHA PJSM W/ ALL INVOLVED PERSONAL, L/D BHA AS PER SLB DD AND CLEAR ALL LIFT SUBS/EQUIPMENT OFF RIG FLOOR. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/25/14 Time: 23:59 Current Depth (MD): 9120’ Current Depth (TVD): 5271’ Current Operations: RIH with casing. 24 hr Footage (MD): 00’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: CIRCULATE AND CONDITION M/U ASSEMBLY T/ FLUSH AND CLEAN STACK. INSTALL/REMOVE WEAR BUSHING PULL WR W/ CAMERON REP AND CONDUCT A DRY RUN W/ LD JT AND HANGER. CHANGE RAMS SET TEST PLUG, CLOSE BLINDS AND C/O TOP SET OF RAMS T/ 7 5/8. PU TEST TOOLS - M/U TEST PLUG T/ 7 5/8 TEST JNT, RUN IN WELL HEAD, M/U TIW ON TEST JNT, TEST BOPS - TEST 7 5/8 TOP RAMS/ BAG TO 250 LOW/3500 HIGH, RECORD ON CHART LD TEST TOOL - PULL TEST JNT, REMOVE TEST PLUG, R/D TEST HOSE/ EQUIPMENT, L/D TOOLS RIG UP/DOWN TO RUN CASING REMOVE 5" ELEVATORS, REMOVE SHORT BAILS, R/U LONG BAILS, M/U SAFETY VALVES FOR CSG, R/U TESCO, P/U SPIDERS, R/U SERVICE LOOP FOR TESCO, M/U BLOWER HOSE, PRE JOB SAFETY RUN 7 5/8 CSG M/U SHOE TRACK - M/U 7 5/8 39.7 # FLOAT TRACK/ FLOAT COLLAR, BAKER LOCK CONNECTIONS, CHECK FLOATS, ALL GOOD RUN CASING - RUN 7 5/8 29.7# CSG, M/U TORQ-10,300 FT/POUNDS FOR 29.7- 19,300 FT/POUNDS FOR 39.7#, C/O TESCO DIES T/ 29.7#, F/ 248' T/9120', UWT- 113K, DWT-99K, FILL EVERY JNT ON THE FLY,CIRC B/U EVERY 2000' IN OH, BPM- 6,SPM-85, PSI-330, CAL HOLE FILL= 36 ACT HOLE FILL=38.7. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/26/14 Time: 23:59 Current Depth (MD): 9120’ Current Depth (TVD): 5271’ Current Operations: Cementing casing. 24 hr Footage (MD): 00’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: RUN CASING CONT/- RUN 7 5/8 29.7# CSG, M/U TORQ-10,300 FT/POUNDS FOR 29.7- 19,300 FT/POUNDS FOR 39.7#, C/O TESCO DIES T/ 29.7#, F/ 4536' T/9039', UWT- 205K, DWT-100K, FILL EVERY JNT ON THE FLY,CIRC B/U EVERY 2000' IN OH, BPM- 6,SPM-85, PSI-330, CAL HOLE FILL= 58.5BBLS ACT HOLE FILL=61BBLS RUN CASING - M/U CSG HANGER, P/U LANDING JNT, THREADS ON HANGER WERE GAULED TRIED TO ADDRESS WITH FILE, NO GOOD, L/D LANDING JNT, BRAKE OUT HANGER, CAMERON HAND TO DRESS THREADS. CIRCULATE AND CONDITION - M/U TESCO TOOL BACK TO STRING, CIRC/RICP F/9080' T/9040', BROKE OVER @ 250K UWT, 115K DWT, CIRC @ 4.5 BBL/MIN, 465 PSI RUN CASING - M/ CSG HANGER, P/U LANDING JNT WITH SINGLE ELEVATORS, POSITION MAN ON STABBING BOARD TO CENTER JNT, M/U TESCO TOOL CIRCULATE AND CONDITION - CIRC/RICP AS PER MUB MAN TO THIN BACK MUD FOR CMT JOB, STAGE PUMPS TO 6 BBL/MIN, ICP=552 PSI, FCP-485 PSI, UWT-225K DWT-115K, CIRC 2 B/U RIG UP/DOWN TO RUN CASING - R/D TESCO TOOL, INSTALL SIDE DOOR ELEVATORS ON PIPE, M/U BAILS, INSTALL CMT HEAD X-O, M/U CMT HOSE, M/U CMT HEAD, INSTALL CMT LINE W/ SWING,VALVE,PLUG CIRCULATE AND CONDITION -RICP/CIRC W/ CMT HOSE/CMT HEAD, BPM-6, PSI- 650 PSI, UWT-225K DWT-115K, HOLD PJSM W/ ALL CREWS INVOLVED IN CEMENT JOB, PRIMARY CEMENTING -LINE UP TO CMT, PUMP 5 BBLS CHEM H20, S/D PT LINES TO 3500 PSI. PUMP 35 BBLS CHEM H20 @ 5BPM 885PSI, PUMP 40 BBLS 12.5 MP @ 4.5BPM, PSI-764, DROP BMT PLUG, PUMP 155 BBLS 15.8 GAS BLOCK CMT @ 5 BPM, PSI-1135, DROP TOP PLUG, TURN ON TO DIS W/ RIG PUMPS, BUMP PLUG @ 5729STKS, SLOW DOWN PUMP @ 5300, S/D CHECK FLOATS, CIP @ 20:54, BLEED BACK 5 BBLS, ICP-745PSI. LAND CSG, 9110' WAITING ON CEMENT - BLEED BACK 5 BBLS, PUMP 87STKS (6.07 BBLS) TO PRESSURE BACK UP T/ 500 PSI OVER FCP, SHUT IN HOSE AND HOLD 1000 PSI UNTILL 4AM, WHILE CMT SETS UP. CLEAN AROUND RIG, PREP 4" DP IN PIPE SHED FOR NEXT HOLE SECTION. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/27/14 Time: 23:59 Current Depth (MD): 9120’ Current Depth (TVD): 5271’ Current Operations: Making pipe up. 24 hr Footage (MD): 00’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: WAITING ON CEMENT CONT/T HOLD 1000 PSI UNTILL 4AM, WHILE CMT SETS UP. CLEAN AROUND RIG, PREP 4" DP IN PIPE SHED FOR NEXT HOLE SECTION WAITING ON CEMENT BLEED BACK 2BBLS T/TRIP TANK,B/D CMT LINES AND L/D ALL CMT EQUIPMENT,C/O LONG BAILS T/SHORT BAILS,R/D TESCO EQUIPMENT OFF T/D,L/D 7 5/8 LANDING JT,DRAIN STACK PICK UP 3RD PARTY TOOLS PJSM W/CAMERON REP ON INSTALLING PACKOFF,P/U 5'' SINGLE M/U PACKOFF RUNNING TOOL AND SET AS PER CAMERON REP, CAMERON TO PRESSURE TEST PACKOFF T/5000PSI F/10MIN ''GOOD'' WITNESSED BY NABORS DRILLING,RIG DOWN PACKOFF RUNNING TOOL,SET W/R AS PER CAMERON,W/R ''ID'' = 9 3/4 ''OD'' = 10 3/4 LENGTH = 1.08 LAY DOWN DRILL PIPE PJSM,TIH 9 STDS OF 5'' DP OUT OF DERRICK AND L/D T/PIPE SHED,HOT OIL T/FREEZE PROTECT ''OA'' 7 5/8 X 10 3/4 102 BBL OF DIESEL 112 BBL OF SEA H2O LAY DOWN DRILL PIPE - M/U MULE SHOE W/ DART VALVE ON BTM (2.2' OD- 6.5OD), RIH W/ 9 STDS, L/D 18JNT'S, CONT. RIH AND L/D 5" DP, TOTAL JNTS 5" L/D=165, 55 STDS, UWT=50K, DWT=38K, CAL HOLE FILL=132 BBLS ACT FILL 132 BBLS. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/28/14 Time: 23:59 Current Depth (MD): 9120’ Current Depth (TVD): 5271’ Current Operations: Making pipe up. 24 hr Footage (MD): 00’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: WAITING ON CEMENT CONT/T HOLD 1000 PSI UNTILL 4AM, WHILE CMT SETS UP. CLEAN AROUND RIG, PREP 4" DP IN PIPE SHED FOR NEXT HOLE SECTION WAITING ON CEMENT BLEED BACK 2BBLS T/TRIP TANK, B/D CMT LINES AND L/D ALL CMT EQUIPMENT,C/O LONG BAILS T/SHORT BAILS,R/D TESCO EQUIPMENT OFF T/D, L/D 7 5/8 LANDING JT,DRAIN STACK PICK UP 3RD PARTY TOOLS PJSM W/CAMERON REP ON INSTALLING PACKOFF,P/U 5'' SINGLE M/U PACKOFF RUNNING TOOL AND SET AS PER CAMERON REP,CAMERON TO PRESSURE TEST PACKOFF T/5000PSI F/10MIN ''GOOD'' WITNESSED BY NABORS DRILLING, RIG DOWN PACKOFF RUNNING TOOL, SET W/R AS PER CAMERON,W/R ''ID'' = 9 3/4 ''OD'' = 10 3/4 LENGTH = 1.08 LAY DOWN DRILL PIPE PJSM,TIH 9 STDS OF 5'' DP OUT OF DERRICK AND L/D T/PIPE SHED,HOT OIL T/FREEZE PROTECT ''OA'' 7 5/8 X 10 3/4 102 BBL OF DIESEL 112 BBL OF SEA H2O LAY DOWN DRILL PIPE - M/U MULE SHOE W/ DART VALVE ON BTM (2.2' OD- 6.5OD), RIH W/ 9 STDS, L/D 18JNT'S, CONT. RIH AND L/D 5" DP, TOTAL JNTS 5"L/D=165, 55 STDS ,UWT=50K, DWT=38K, CAL HOLE FILL=132 BBLS ACT FILL 132 BBLS. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/29/14 Time: 23:59 Current Depth (MD): 9120’ Current Depth (TVD): 5271’ Current Operations: RIH. 24 hr Footage (MD): 00’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: TEST BOPS CONT/TEST B O P'S F/4''TEST JNT BAG,3.5 TEST JNT TOP RAMS ,OUTTER TEST SPOOL VLV,LOWER RAMS INNER TEST SPOOL VLV,BAG,250 PSI LOW 3500PSI HIGH,KOOMIE TEST,ACC/PSI 2900,AFTER FUNCTION 1700PSI,200 CHARGE = 31SEC,FULL CHARGE = 146SEC,6 BOTTEL AVERAGE = 2050 INSTALL/REMOVE WEAR BUSHING DRAIN STACK,PULL TEST PLUG,SET W/R,B/D ALL TEST EQUIPMENT,CHOKE MANIFOLD,LINE UP CHOKE MANIFOLD AND MAN CHOKE AND KILL F/NORMAL OPPS PICK UP BHA PJSM W/SLB DD AND CREW ON PICKING UP BHA,PICK UP BHA AS PER SLB PICK UP BHA PJSM W/SLB PICKING UP NUKE SOURCE,PICK UP NUKE SOURCE AND INSTALL CONT/PU BHA AS PER SLB PICK UP DRILL PIPE SINGLE IN HOLE W/4'' HT 40 DP F/531.29'MD T/1540'MD,UP WT 67K DN WT 62K TRIP OUT OF HOLE F/1500' T/1000' RACK BACK 6 STDS, UWT-62 DWT-60 PICK UP DRILL PIPE - CONT P/U 4" DP F/ 1000' T/ 6200', UWT-108K, DWT-75K, FILL PIPE EVERY 2000', 2.25 DRIFT USED ON DP CASED HOLE LOGS - CMT LOG F/ 6200' T/7600' 850-900'HR/MAX AS PER MWD UWT-115, DWT-80, FILL PIPE @ 7500' AND CHECK MWD BATTERY, GPM-220, PSI-1900, CAL HOLE FILL= 40.6 ACT FILL= 45.5. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/30/14 Time: 23:59 Current Depth (MD): 9120’ Current Depth (TVD): 5271’ Current Operations: Preparing to drill. 24 hr Footage (MD): 00’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: CASED HOLE LOGS - F/7600 T/8900' UWT=155K DWT=60K, 850-900FT/HR MAX CUT DRILLING LINE - CUT 104' DRILLING LINE, 16 WRAPS CIRCULATE AND CONDITION COND/MUD TO 10.3PPG ALL WAY AROUND UP WT 160 DN WT 76K TEST BOPS TEST 7 5/8 CSG T/3000PSI HOLD F/30 MIN (GOOD) B/D KILL LINE DRILLING CEMENT TAG ON CMT 8983MD, DRILL OUT CEMENT,TAG ON CEMENT PLUG 9019'MD,UP WT 160K DN WT 76K, ROT WT 108K,GAL/MIN 220,PMP PSI 2017,TORQUE ON 12K, WOB 12K,TD RPM 60 DRILLING CEMENT - DRILL PLUGS/SHOE @ 9113', GPM-220, RPM- 80 - 90, TORQ- 12,000-13,000, PSI-2060, WOB-5-10K, UWT- 178K, DWT-78K, RWT-108K, DRILL RAT HOLE T/ 9120' ROTARY DRILLING DRILLED F/ 9120’ MD T/ 9140’ MD, TVD= 5362’ MD, ECDS= 11.4 PPG, ART= .44 HR, ADT=.44 HRS, PUW= 178K, SOW= 78K, ROT= 108K, RPM= 80-90, GPM= 240, PSI ON= 2060, PSI OFF= 2060, TQ ON= 12-14 FT/LBS, TQ OFF= 12-13 FT/LBS. TOTAL BIT HOURS= 33.84 BIT FOR TOUR=.44 CHANGE OUT MUD SYSTEM - SWAP MUD SYSTEM F/ 10.3 PPG LSND T/ 10.5 LSND, CIRC S/S INSURE GOOD WT'S IN AND OUT FOR LOT, GPM- 220, PSI-2150, SPRS TAKEN AT 1830HRS, 9090' MD, 5260’ TVD, PUMP #1 AT 2 BPM= 480 PSI, AT 3 BPM=760 PSI. PUMP #2 AT 2 BPM=500 PSI, AT 3 BPM= 780 PSI MW- 10.5 PPG, FORMATION INTEGRITY TEST (FIT) - RU HEAD PIN ON CMT HOSE, R/U CHART ON TEST SPOOL, FILL LINES PUMP DOWN DP AND KILL LINES TO INSURE NO AIR IN SYSTEM, CLOSE TOP RAMS, 36 STKS PUMPED, 2.5 BBLS, BROKE OVER AT 570 PSI, BLEED BACK 1.6 BBLS, CALL TOWN TO DISCUSS DRILLING AHEAD, R/U TEST PUMP, ATTEMPT ANOTHER TEST, PUMP 28.5 MINUTES, 6.6 BBLS, BLEED BACK 2.1 BBLS SERVICE RIG - FULL SERVICE ON TOP DRIVE, SERIVCE DRAWWORKS, SERIVCE CROWN, EZ- TORQS, CLEAN UP AROUND RIG WHILE TALKED TO TOWN FORMATION INTEGRITY TEST (FIT) - R/D HEAD PIN AND CMT HOSE, BLOW DOWN KILL LINE CMT LINE, ALL GOOD TO DRILL AHEAD W/ 12.7 EMW F/ TOWN. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: L. Martin J. Riley Date: 7/31/14 Time: 23:59 Current Depth (MD): 9572’ Current Depth (TVD): 5443’ Current Operations: POOH. 24 hr Footage (MD): 452’ Drilling Parameters ROP: Current: 58.8 Max: 195 Torque: Current: 11444.9 Max: 17931 WOB: Current 7.2 Max: 35 RPM: Current: 95.2 Max: 117 PP: Current: 2259.1 Max: 2693 Lag: Strokes: 4040 Time: 01:06:31 Surf-Surf: Strokes: 4993.97 Time: 01:22:14 ECD: Current: 11 Max: 11 Mud Properties @ MW: Gels: MW Change: Depth: 9120’ From: 10.5 To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 471 Depth (MD/TVD): 9359’/5349’ Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 8713’/5134’ 24u Connection Gases 9475’/5397’ 101u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 9180’/5288’ 23.793 5621.553 451.860 334.587 118.813 156.516 39.487 39.487 9210’/5297’ 246.724 43996.829 2902.727 1182.339 150.744 337.265 168.586 133.893 9331’/5338’ 285.000 38017.174 3857.131 2341.277 387.875 859.726 238.149 244.844 9552’/5433’ 65.690 9474.211 972.444 768.632 181.190 311.253 95.955 129.756 Lithologies: 40% Shale, 10% Sand, 20% Sandstone, 30% Siltstone. Operational Summary: ROTARY DRILLING CONT/DRILL F/9158'MD T/9572'MD TD, GPM- 237, PSI ON-2261, PSI OFF- 1815. RPM- 100 TQ ON-12K, TQ OFF 11K. PU WT- 167K, SOW-92K, ROT-108K, ART-3.36HRS, ADT-3.36HRS, TOTAL BIT HRS-41.38 TOTAL JAR HOURS-160.78SPRS TAKEN AT 1120HRS, 9572 MD, 9553’ TVD, PUMP #1 AT 2 BPM= 460 PSI, AT 3 BPM=740 PSI. PUMP #2 AT 2 BPM=470 PSI, AT 3 BPM= 710 PSI MW- 10.5 PPG, CIRCULATE AND CONDITION CIRC/BU, UP WT 125K,DN WT 105K, ROT WT 110K, 10.5 PPG MUD BACK REAMING - F/ 9572' T/9355', MONT. WELL 10MIN, (STATIC), GPM-230, PSI OFF- 2115, RPM- 70, TORQ OFF- 10,000-11,000K, ROT-110K, UWT- 155K, DWT- 88 OPEN HOLE LOGS - TAKE SIMPLE'S WITH STETHOSCOPE TOOL @ 9355.9 BIT DEPTH, SAMPLE DEPTH 9294.9', TAKE ONE WITH PUMPS ON AND ONE WITH PUMPS OFF AS PER STETHOSCOPE TOOL HAND BACK REAMING - CONT. POOH F/ 9355' T/ 8600', GPM-220, PSI 1980, PUMP OUT TO TOP OF 39# CSG TO INSURE NO SWABBING, MONT. WELL 15 MIN, STACTIC, TRIP OUT OF HOLE - F/ 8600' T/8100', UWT- 165K DWT- 89K, LINE UP ON TT TO INSURE PROPER HOLE FILL, HOLE FILL CORRECT, LINE UP TO PUMP SLUG, B/D TOP DRIVE, LINE BACK UP ON TT, INSTALL RUBBER'S AND AIR SLIPS CONT. TO POOH TRIP OUT OF HOLE - F/8100' T/ 531', UWT-50 DWT-50, MONT. WELL AT BHA, CAL HOLE FILL=51 ACT FILL=54.6 D PRE JOB SAFETY - L/D BHA, REMOVE SOURCELAY DOWN BHA - R/D 3 STDS HWDP W/ JARS, L/D WELL COMMANDER, R/B FC, CAL HOLE FILL=4.2 ACT FILL 4.3 Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek J. Riley Date: 8/1/14 Time: 23:59 Current Depth (MD): 9572’ Current Depth (TVD): 5443’ Current Operations: POOH cemented. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: 10.5 To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: LAY DOWN BHA PJSM W/SLB F/REMOVING SOURCE, REMOVE SOURCE, L/D BHA AS PER DD,CLEAN AND CLEAR RIG FLOOR PICK UP 3RD PARTY TOOLS PJSM W/GBR,BRING IP TOOLS T/RIG FLOOR AND R/U TRIP IN HOLE RIH W/3.5 TUBING STINGER 30 JTS,949' MULE SHOE 'OD' 3.5, 'ID' 2 7/8, LENGTH 3.90, FN 4.5, XO HT 40 X 3.5 EUE 'OD' 5'', 'ID' 2 9/16, LENGTH 1.58,3.5 X HT 40 XO LENGTH 1.35,PUP JT LENGTH 14.94 TRIP IN HOLE R/D GBR C/O 3.5 ELEVATORS T/4''ELEVATORS, TIH W/4'' HT 40 D F/949'MD T/6371' MD, UP WT 105K DN WT 74K MUD WT 10.5PPG12:00 13:30 1.50 6.A TRIP IN HOLE F/6371', T/9036', UWT 148, DWT 77K, @ SHOE SERVICE TOP DRIVE , GREASE TD/WASHPIPE AND DRAWWORKS TRIP IN HOLE F/9036', T/9573', CIRC BU, PSI 1130, GPM 230, SPM 78, FLOW 35%, UWT 161K, DWT 83K CEMENT PLUGS PJSM, PUMP 5 BBL MUD PUSH, TEST LINES T/3500 PSI, TEST WAS GOOD, PUMP TOTAL 15 BBLS, 750 PSI 1 BBL H2O, SHUT BAG/CHOKE, DROP BALL, OPEN BAG/CHOKE, PUMP 17# CEMENT37 BBL, 3.5 BBL MUD PSUH, 1 BBL H2O, SWITCH TO RIG TO DISPLACE, 1000 STK @ 5 BPM, 140 STKS @ 2BPM TRIP OUT OF HOLE F/9573', T/8900', UWT 163, DWT 83K, PULL 20'/PMIN CIRCULATE AND CONDITION PSI 2760, GP, 443, SPM 150, FLOW 62%, RACK BACK 1 STD AND CONTINUE TO CIRC HOLE CLEAN, SHUT DOWN, MONITOR WELL 30 MIN, PUMP DRY JOB, BD TD, TRIP OUT OF HOLE POOH F/8900', T/6465', UWT 136K, DWT 76K. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek J. Riley Date: 8/2/14 Time: 23:59 Current Depth (MD): 9572’ Current Depth (TVD): 5443’ Current Operations: Repair IBOP. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: 10.5 To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: TRIP OUT OF HOLE CONT/POOH F/6465'MD T/949'MD UP WT 40K DN WT 40K 10.5 PPG,CMT/SEEN @ 1708'MD T/SURFACE ON 4''DP/3.5 TUBBING,4'' DISPLACEMENT CALC = 45.4BBLS ACT = 52.6BBLS, DISPLACEMENT F/3.5 TUBBING CAL = 3.3BBLS ACT = 3.2BBLS TRIP OUT OF HOLE PJSM W/GBR,RU GBR TOOLS,L/D 3.5 TUBBING T/PIPE SHED AND XO'S/MULE SHOE,L/D GBR TOOLS, CLEAN CLEAR RIG FLOOR, 3.5 TUBBING OUT OF PIPE SHED, LOAD PIPE SHED W/NEW BHA PICK UP BHA PJSM,BRING TOOLS T/RIG FLOORF/BHA, PJSM W/SLB DD T/MU BHA,MU BHA AS PER SLB DD, PJSM ON P/U NUKE SOURCE W/SLB,INSTALL NUKE SOURCE AS PER SLB TRIP IN HOLE PJSM,TIH W/4'' HT40 DP F/544'MD T/1208'MD, UP WT 51K DN WT 48K,10.5 PPG MUD TRIP IN HOLE CLEAN AND CLEAR FLOOR, INSTALL AIRSLIPS, RIH F/1020', T/ 1496', UWT 65K, DWT 60K CIRCULATE AND CONDITION SHALLOW TEST @1496',GPM 230, PSI 1638, RPM 30, TQ OFF 787, SPM 78, FLOW 30%, B/D TD, TRIP IN HOLE, F/1496, UWT 65K, DWT 60K, T/6787', FILL EVERY 20 STDS, UWT 123K, DWT 73K, SERVICE TOP DRIVE SERVICE TD, DRAWWORKS, CLEAN AND CLEAR FLOOR DOWNTIME-TOP DRIVE REBUILD IBOP VALVE, TEST VAVLE, TEST FAIL, REMOVE AND C/O VALVE KEY AND VALVE PLUG PACKING. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek J. Riley Date: 8/3/14 Time: 23:59 Current Depth (MD): 9493’ Current Depth (TVD): N/A’ Current Operations: Drilling Ahead. 24 hr Footage (MD): 380’ Drilling Parameters ROP: Current: 92.7 Max: 205.8 Torque: Current: 9290 Max: 17507 WOB: Current 5.8 Max: 35 RPM: Current: 120.5 Max: 124 PP: Current: 1996 Max: 2738 Lag: Strokes: 4033.84 Time: 00:51:29 Surf-Surf: Strokes: 5383.76 Time: 01:07:29 ECD: Current: 11.5 Max: 11.5 Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 603 Max: 1035 Depth (MD/TVD): 9414’ MD Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas - - Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 9380’ MD 98 16159.080 1174.717 581.508 55.659 139.188 98.842 55.535 9410’ MD 753 149931.274 13163.626 5636.875 655.180 1685.288 358.388 406.515 9440’ MD 407 69306.546 6868.823 3152.997 391.123 927.275 214.964 208.811 9470’ MD 458 73987.695 7067.708 3294.216 442.252 1023.280 240.192 254.508 Lithologies: 10% Siltstone, 30% Sand, 60% Sandstone. Operational Summary: DOWNTIME-TOP DRIVE -REBUILD IBOP VALVE, TEST-REBUILD IBOP VALVE, TEST VAVLE, TEST FAIL, REMOVE AND C/O VALVE KEY AND VALVE TRIP IN HOLE CONT/TIH F/6787'MD T/8964'MD, TAG CMT @ 8964' MD,W/PMPS ON SET WOB 15K TESTCMT, DISPLACEMENT F/TIH CALC = 10.8BBLS ACT = 6.5BBLS ROTARY DRILLING DRILL OUT CMT F/8964'MD T/9123'MD, UP WT 140, DN WT 99, ROT WT 102,WOB 5- 10K,SPM 88, GPM 242,PRESSURE ON 2727PSI,RPM 60 CIRCULATE AND CONDITION WORK STUCK PIPE,@ 9123'MD SET JARS OFF @ 247K,ROTATE AND RECIP/PIPE 20'-25', MAINTAIN CIRCULATION,P/U TO 9105',PMP PSI 2616PSI CIRCULATE AND CONDITION CIRC/CONDITION MUD,STAND BACK STND #91 9204' MD ROTATE AND RECIP/PIPE ON STND #90 9108'MD, PUMP PSI 2637,UP WT 140K DN WT 99K ROT WT 102K RPM ROTARY DRILLING MAKE CONNECTION STND #91@9108'MD', T/9148'MD, CONT/DRILLING PUMP PSI 2470, TORQUE 14K,GPM 246,WOB 5-10K,UP WT161.78,10.5 PPG MUD ROTARY DRILLING DRILL F/ 9148 T/9204, GPM- 242, PSI ON-2616, PSI OFF- 2488.RPM-60TQ ON-12.5K, TQ OFF 10K. PU WT- 195K, SOW-70K, ROT-110K, MD, 9205 TVD 5290', MW- 10.5PPG, BACK REAMING DRILL F/ 9204 T/9012â, GPM- 240,PSI OFF- 2400. RPM-60,TQ OFF 10K. PU WT- 210K, SOW-73K, ROT- 110K, BUILD VOLUME - WEIGHT MONITOR WELL, TAKE ON NEW MUD IN PITS AND DUMP OLD MUD, PREP FOR DISPLACEMENT DISPLACE TO WATER BASE PUMP 50BBL HIGH VIS, CHASE WITH KLA- SHIELD ALL THE WAY AOUND TILL CLEAN, PSI 2400, GPM 234, SPM 78, TQ 11K, ROT 102K, RPM 60 TRIP IN HOLE RIH F/9110', T/9204', DWT 85K, UWT 140K, GPM 230, PSI 1800, SPR #1 @ 30 SPM=400 PSI, @45 SPM=630 PSI, #2 @ 30SPM=390PSI, @45 SPM=620PSI @ 19:00HR, MD 9204' TVD 5259' ROTARY DRILLING DRILL F/ 9204 T/9490, GPM- 236, PSI ON-1950, PSI OFF- 1850 . RPM-120TQ ON-10K, TQ OFF 9K. PU WT- 145K, SOW-90K, ROT-110K, ART-5.54HRS, ADT-5.54HRS, TOTAL BIT HRS-6.54TOTAL JAR HOURS-168.32SPRS TAKEN AT 2345HRS, 9490MD, 5342â TVD, PUMP #1 AT 2 BPM= 390 PSI, AT 3 BPM=660 PSI. PUMP #2 AT 2 BPM=400 PSI, AT 3 BPM= 670 PSI MW- 10.5PPG, 135K DN WT 100K, ROT WT 102K, ADT = 1.0,BIT = 1.0. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek J. Riley Date: 8/4/14 Time: 23:59 Current Depth (MD): 10500’ Current Depth (TVD): N/A’ Current Operations: Drilling Ahead. 24 hr Footage (MD): 1000’ Drilling Parameters ROP: Current: 46.6 Max: 179.8 Torque: Current: 7778.3 Max: 9387 WOB: Current 3.8 Max: 13 RPM: Current: 127.6 Max: 131 PP: Current: 2182.3 Max: 2266 Lag: Strokes: 4425 Time: 00:55:54 Surf-Surf: Strokes: 5931 Time: 01:14:56 ECD: Current: 11.7 Max: 11.7 Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 400 Max: 958 Depth (MD/TVD): 10490’MD Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas - - Connection Gases 10347’ MD 299u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 10370’MD 338 48710.717 4672.190 2842.760 519.916 1272.545 357.178 446.500 10400’MD 385 32016.414 2780.353 1748.990 358.116 800.232 230.170 315.121 10462’MD 292 15234.729 1760.863 1258.816 170.645 543.834 181.786 231.818 10520’MD 431 63493.510 5829.929 3325.736 519.916 1303.004 396.404 442.057 Lithologies: 20% Siltstone, 80% Sandstone. Operational Summary: ROTARY DRILLING DRILL F/ 9490 T/9998, GPM- 240, PSI ON 2142, PSI OFF- 2044 . RPM-130 TQ ON-8K, TQ OFF 8K. PU WT- 145K, SOW-92K, ROT-105K, ART-7.67HRS, ADT-7.67HRS, TOTAL BIT HRS-14.22 TOTAL JAR HOURS-175.00, SPRS TAKEN AT 1130HRS, 9992 MD, 5337 TVD, PUMP #1 AT 2 BPM= 480 PSI, AT 3 BPM=740 PSI. PUMP #2 AT 2 BPM=470 PSI, AT 3 BPM= 730 PSI MW- 10.5 PPG ROTARY DRILLING DRILL F/ 9998 T/10251, GPM- 239, PSI ON-2160, PSI OFF- 2050 . RPM-130TQ ON-7.5K, TQ OFF 7K. PU WT- 143K, SOW-91K, ROT-105K, MW- 10.5 PPG, HOUSEKEEPING, PAINTING, CLEANING ROTARY DRILLING DRILL F/ 10251T/10537, GPM-236, PSI ON-2180, PSI OFF- 2050. RPM-130 TQ ON-8K, TQ OFF 7K. PU WT- 143K, SOW-90K, ROT-105K, ART-9.16HRS, ADT-9.16HRS, TOTAL BIT HRS 23.38TOTAL JAR HOURS-184.16SPRS TAKEN AT 2330HRS, 10442 MD, 5332 TVD, PUMP #1 AT 2 BPM= 510 PSI, AT 3 BPM=790 PSI. PUMP #2 AT 2 BPM=510 PSI, AT 3 BPM= 800 PSI MW- 10.5 PPG, Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek J. Riley Date: 8/5/14 Time: 23:59 Current Depth (MD): 11622’ Current Depth (TVD): N/A’ Current Operations: TD well. 24 hr Footage (MD): 1121’ Drilling Parameters ROP: Current: 59.3 Max: 122.5 Torque: Current: 9045.43 Max: 9678 WOB: Current 4.11 Max: 13 RPM: Current: 126.8 Max: 133 PP: Current: 2295.87 Max: 2357 Lag: Strokes: 4781’ Time: 00:59:36 Surf-Surf: Strokes: 6430 Time: 01:20:03 ECD: Current: 11.6 Max: 11.7 Mud Properties @ MW: Gels: MW Change: Depth: 11,575’ From: 10.5 To: 10.55 Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 1023 Depth (MD/TVD): 11268’MD Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas - - Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 11520’MD 181 20734.414 2358.328 1719.952 310.655 810.064 282.010 323.689 11550’MD 225 29974.513 2741.546 1868.617 351.213 909.154 241.229 298.936 11580’MD 385 58212.283 5238.932 2740.506 365.883 1049.498 262.484 321.785 11621’MD 19 3030.425 287.009 191.602 40.989 69.401 79.834 54.583 Lithologies: 10% Siltstone, 90% Sandstone. Operational Summary: ROTARY DRILLING DRILL F/ 10537 T/10824, GPM- 240, PSI ON-2243, PSI OFF-2210. RPM-130 TQ ON-8K, TQ OFF 7K. PU WT- 147K, SOW-90K MW- 10.5 PPG, HOUSEKEEPING, PAINTING, CLEANING ROTARY DRILLING DRILL F/ 10824 T/11015, GPM-236, PSI ON-2144, PSI OFF-1965. RPM-130 TQ ON-8K, TQ OFF 7K. PU WT- 149K, SOW-92K, ROT-108K, ART-7.51HRS, ADT-7.51HRS, TOTAL BIT HRS- 30.91 TOTAL JAR HOURS-191.70SPRS TAKEN AT 1000HRS, 10921 MD, 5338 TVD, PUMP #1 AT 2 BPM= 490 PSI, AT 3 BPM=740 PSI. PUMP #2 AT 2 BPM=470 PSI, AT 3 BPM= 730 PSI MW- 10.5 PPG, ROTARY DRILLING DRILL F/ 11015 T/11301, GPM-235, PSI ON-2217, PSI OFF- 218 . RPM-130 TQ ON-8.5K, TQ OFF 8K. PU WT- 145K, SOW-87K, ROT-100K, SPRS TAKEN AT 1930HRS, 11396MD, 5337 TVD, PUMP #1 AT 2 BPM= 530 PSI, AT 3 BPM=800 PSI. PUMP #2 AT 2 BPM=530 PSI, AT 3 BPM= 810 PSI MW-10.5 PPG ROTARY DRILLING DRILL F/ 11301 T/11588, GPM- 238, PSI ON-2300, PSI OFF- 2210. RPM-130 TQ ON- 8.6K, TQ OFF 6.2K. PU WT- 145K, SOW-85K, ROT-105K, ART-7.79HRS, ADT-7.79HRS, TOTAL BIT HRS- 39.7 TOTAL JAR HOURS-199.49SPRS MW- 10.5 PPG. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek, L. Martin J. Riley. Date: 8/6/14 Time: 23:59 Current Depth (MD): 11622’ Current Depth (TVD): 5174’ Current Operations: R/D BHA. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 10246’/5436’ 20u Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: ROTARY DRILLING DRILL F/11588 T/11622, GPM-239, PSI ON-2290, PSI OFF- 2130. RPM-130 TQ ON-8K, TQ OFF 7K. PU WT- 145K, SOW-85K, ROT-105K, ART-1 HRS, ADT-1HRS, TOTAL BIT HRS-40.24 TOTAL JAR HOURS-201.02SPRS TAKEN AT 0030HRS, 11622 MD, 5369 TVD, PUMP #1 AT 2 BPM= 540 PSI, AT 3 BPM=800 PSI. PUMP #2 AT 2 BPM=500 PSI, AT 3 BPM= 790 PSI MW-10.5 PPG, TRIP OUT OF HOLE BROOH F/11622'MD T/9014'MD,PMP PSI 2040, UP WT 137K DN WT 92K,ROTATE WT 105K,TQ 6K, RPM 120 CIRCULATE AND CONDITION DROP BALL PUMP @ 85 SPM418PSI, PRESSURE UP @ 1300PSI HELD F/42 SEC, INCREASE T/1800PSI HELD F/30SEC TOOL OPEN AT 1920PSI CIRCULATE AND CONDITION CIRC/COND MUD,ROTATE @ 120RPM,UP WT 103K DN WT 102K,ROT WT 102K,GAL/MIN 522, PMP PSI 2777,PUMP 35 BBL HIGH VIS SWEEP CIRCULATE AND CONDITION PUMP BALL TO CLOSE WELLCOMANDER, 28 SPM, 83 GPM, 273 PSI, CLOSED AT 1480 PSI, 590 STKS; REAMING/WASHING POOH WHILE PUMPING F/ 9009', T/8633', 81 SPM, 238 GPM, 2077 PSI, FLOW 40%, UWT. CONTINUE TO POOH UNITL THE BHA. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek, L. Martin J. Riley. Date: 8/7/14 Time: 23:59 Current Depth (MD): 11622’ Current Depth (TVD): 5174’ Current Operations: Running in liner. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: LAY DOWN BHA CONT/LD NUKS AND BHA #4 AS PER SLB, CLEAN CLEAR RIG FLOOR PICK UP 3RD PARTY TOOLS PJSM W/GBR, BRING TOOLS TO RIG FLOOR AND R/U AS PER GBR TRIP IN HOLE PJSM W/GBR CONOCO REP AND CREW F/LINER RUN,TIH W/4.5 LINER T/2720.59'MD,UP WT 56K DN WT 54K, MUD WT 10.5,CAL DISP 11.2BBLS, ACT DISP 10BBLS COMPLETION-LINER-RUNNING PJSM, START W/HYDRIL 521, F/2216.93, T/2713.12' UWT 65K, DWT 60K, MU ZXP PACKER, SPOT PAL MIX, 30 MIN WAIT, CONT RUN 4'DP CIRCULATE AND CONDITION VERIFY FLOW AND PARAMATERS, CIR @ 5 BPM, 217 GPM, 275 PSI, 31% FLOW, PVT 101BBLS, 73 SPM, @ 2808.83' TRIP IN HOLE F/2808', T/7280'MD, UWT 87K, DWT 76K,DISPLACEMENT CALC 22BBLS ACT 25BBLS. Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek, L. Martin J. Riley. Date: 8/8/14 Time: 23:59 Current Depth (MD): 11622’ Current Depth (TVD): 5174’ Current Operations: Running in liner. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max 157U Depth (MD/TVD): Liner landing. Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: TRIP IN HOLE CONT/TIH W/LINER, F/7280'MD T/9077'MD UP WT 127K,DN WT 88K CIRCULATE AND CONDITION CIRC/2 BU W/O EXCEEDING 1200 PSI, PUMP PSI 525, 148 GAL/MIN, 50 SPM , 3.5 BPM. NO LOSSES DUE TO WELL BORE. TRIP IN HOLE -RIH, UWT 136K, DWT 87K, @ 10038', CONT. RIH T/11371' TRIP IN HOLE F/11371', T/ 11622', UWT 148K, DWT 90K, TAGGED @ 11613.9' TRIP IN HOLE TAG BOTTOM AT 11613', 18K DWN, 70K WT, PU TO BREAK OVER WT. + 2' SD 11605.85', CIRC DP VOL 1282 STKS, DROP 1.5 BALL, SO/PU TO SD IN TENSION, PSI UP T/2200K, SET PACKER, SO TO BLOCK WT, PSI UP T/2803, SHEAR OUT EARLY, ATTEMPT TO RELEASE TOOL, FAIL, DROP 1.75 BALL, PUMP DOWN, PSI UP 2200K, SO, PSI 3200, RELEASE TOOL, PSI 4300, P/U BREAK OVER 133K, P/U 6' RELEASE DOGS, SO, PU, RPM 15 SO T/BLOCK WT, E PRESSURE TEST CSG/SHOE PURGE KILL LINE, OPEN 4" FOR TATTLE, PSI T/ 2100, HOLD 30 MIN, LOSS 60 PSI, HELD ADDITIONAL 30 MIN 20 PSILOSS DISPLACE TO WATER BASE PJSM, FILL DIRTY TRUCKS, START DISPLACEMENT, @19:40, SPM 142, GPM 420, PSI Failures: None ConocoPhillips Alaska, Inc. 2L-314 Daily Geologic Report Report for: G. Rezek, L. Martin J. Riley. Date: 8/9/14 Time: 23:59 Current Depth (MD): 11622’ Current Depth (TVD): 5174’ Current Operations: Running Tubing. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max 157U Depth (MD/TVD): Liner landing. Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: CUT DRILLING LINE FINISH CUTTING DRILL LINE; ADJUST BRAKES ON DRAW WORKS AND SERVICE TD, CROWN AND DW'S. CHECK COM TO VARIFY PROPER FUNCTION AFTER CUT. LAY DOWN DRILL PIPE L/D 125 JTS OF 4" DP F/ 8768' T/ 4789' UP WT 120K DN WT 90K. TRIP OUT OF HOLE F/ 4789' T/ 2575' L/D 70 JTS OF 4" DP, UP WT 85K DN WT 75K. TRIP IN HOLE RUN REMAINING 25 STDS F/ THE DERRICK IN THE HOLE F/ 2575' T/ 4937' UP WT 90K DN WT 75K. LAY DOWN DRILL PIPE F/ 4937' T/ 2566' UP WT 70K DN WT 70K. INSPECTING EACH JT FOR WASH OUTS AND INSPECTING HARD BAND. LAY DOWN DRILL PIPE START JT 268-351, F/2566', T/SURFACE, UWT 70K, DWT 70K. INSPECTING EACH JT FOR WASH OUTS AND INSPECTING HARD BAND. INSTALL/REMOVE WEAR BUSHING REMOVE WEAR BUSHING, DRAIN STACK COMPLETION-PU,LD,MAKEUP TOOLS,BHA CLEAN CLEAR FLOOR, PU EQUIP FOR RUNNING TBG COMPLETION-TRIP TUBING/DP RUN 3.5 9.3 PPF L-80 EUE UPPER COMPETION, UWT 53K, DWT 52K, @2585'. Failures: None
