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214-026
Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2B-02A 50-029-21154-01 910106459 Kuparuk River Multi Finger Caliper Field & Processed 14-Jun-25 0 12 2B-03B 50-029-21151-02 n/a Kuparuk River Radial Bond Record Field- Final 8-Mar-25 0 13 2F-09 50-029-21090-00 910080198 Kuparuk River Plug Setting Record Field- Final 23-May-25 0 14 2F-09 50-029-21090-00 910010602 Kuparuk River Radial Bond Record Field- Final 2-May-25 0 15 2G-17 50-029-23134-00 910106461 Kuparuk River Plug Setting Record Field- Final 9-Jun-25 0 16 2K-23 50-103-20125-00 910099510 Kuparuk River Multi Finger Caliper Field & Processed 2-Jun-25 0 17 2K-34 50-103-20688-00 910096425 Kuparuk River Multi Finger Caliper Field & Processed 15-Jun-25 0 18 2M-08 50-103-20184-00 910027001 Kuparuk River Multi Finger Caliper Field & Processed 9-May-25 0 19 2M-25 50-103-20152-00 910106929 Kuparuk River Plug Setting Record Field- Final 12-Jun-25 0 110 2M-25 50-103-20152-00 910106929 Kuparuk River Tubing Cut Record Field- Final 13-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:216-087223-080184-036202-243190-014214-026192-101191-021T40589T40590T40591T40591T40592T40593T40594T40595T40596T405966/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:42:29 -08'00'2K-3450-103-20688-00 910096425Kuparuk RiverMulti Finger CaliperField & Processed15-Jun-2501214-026 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q+Lp - oa 1p Well History File Identifier Organizing (done) o-sided ❑ Rescan Needed RE CAN: OVERSIZED: NOTES: Co r Items: ❑ Maps: Grayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: I BY: Maria Date: 3 /s/ Project Proofing BY: agla Date: a, 3 5 /s/ W--- Scanning Preparation le x 30 = ( gd + I =TOTAL PAGES 1 CI (Count does not include cover sheet) BY: WM Date: 3 'i- /s/ Production Scanning Stage 1 Page Count from Scanned File: I 1 1 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: 4:111. Date: 4/z3 I W. /s/ of Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredit Michal / to Date: 2/1-1/ 0 IS— /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES:c2. 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O 4 C m c 0 )I ., V 2 .- p pg p O 7a L �C U .+ OJ cu � N a) G U E a mE ° E E IE ap ) o 7 0 d 0 Q ca U 0 Guhl, Meredith D (DOA) From: Callahan, Mike S [Mike.Callahan©conocophillips.com] Sent: Friday, January 30, 2015 12:06 PM To: Guhl, Meredith D (DOA) Subject: RE: KRU 2K-34, PTD 214-026, Complete list of Formation Tops Meredith, here's the information you need in table form. Top/Marker MD Actual TVD Actual 13-1/2" Intermediate Section Base Permafrost 1,648' 1,604' West Sak Sand 3,386' 2,783' Surface Casing Shoe 3,543' 2,875' 8-1/2" Intermediate Section Fault 6,279' 4,459' K-3 8,156' 5,542' K-2 8,617' 5,786' Top HRZ 8,760' 5,840' Intermediate Casing Shoe 8,257' 5,979' Base HRZ/Top Kalubik 9,355' 6,006' Fault 1 (DTE 18') 9,447' 6,031' K1 Marker 9,618' 6,078' Fault 2 (DTE 27') 9,649' 6,086' Top C 9,800' 6,129' Top A6 Not Observed Top A5 9,858' 6,143' Top A4 9,928' 6,162' TD in A4 10,127' 6,217' Please let me know if you need anything else. Thanks, Mike From: Guhl, Meredith D (DOA) [mailto:meredith.guhl©alaska.gov] Sent: Friday, January 30, 2015 11:51 AM To: Callahan, Mike S Subject: [EXTERNAL]RE: KRU 2K-34, PTD 214-026, Complete list of Formation Tops Mike, Sorry, I just printed what you sent to include it in the well history file and it didn't print clearly. Could you paste the data into an excel table or something? Or include it as a table rather than a picture so that it's legible, please? 1 I really just need the following columrl . Top/Marker, MD actual and TVD actual . Thanks, Meredith From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent: Friday, January 30, 2015 10:09 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2K-34, PTD 214-026, Complete list of Formation Tops Meredith,the attached table has the prognosed and actual markers for each formation encountered on 2K-34. Actual depths are in the columns on the right, with comments indicating where the actual depths came in relative to prognosed. Casing shays.Latino%Wena,labial'NW OtpAa.$ I Mikan,Foiraloa Tops anti IRuskk ptorosidMpissi "Pie) -•;.•'a'am, 1":•C':,ro:i1 :< I X.S0°o7 lc rv*-1 ":r:... I :z:'.-; I :•..$ >:r;,4 ..i.. t3-Ur 2K44 Lotus Sector Sou a6—a"C3: •f? •550 _ t': •44 •f:- -•=d' +i "sec Att'Sk5.r: .•5 .:!f! ::3e :'3: •:44: '! :et: &1x as n;Sve :5:: 2 er"! :: a-1r 2104 kdtimodate*don K,? . • -- a 5L2 5.393 K-2 ="x -f.4-42 Tb-'IC ST•s !33. Ofd' 4„ :,,,: -46_ •C. IEN r"t—a:".Sal C;a :rt , s> baa In ti a.';':•ty.e to LAS WI ;:r !r; •sa f4IT2K,.4 flint trots !ase-FC -.1'..: Please provide the complete list of fo.„.ation tops and geologic markers for KRU 2r-i4, PTD 214-026,completed June 23, 2014. You may provide this list via email, and I will append it to the 10-407 form. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 3 Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday,January 28,2015 4:03 PM To: Loepp,Victoria T(DOA);Allsup-Drake, Sharon K Subject: RE:2K-34(PTD 214-026) 10-407 Cementing Summary Attachments: 2K-34 Cement Detail Report.pdf Follow Up Flag: Follow up Flag Status: Completed Victoria, after looking through the original reports, it looks like the data was entered incorrectly into the report. Our original plan was for 30 bbls of cement to be pumped, and the actual volume pumped was 33 bbls. I'm not sure why the planned volume instead of the actual volume was entered into our WellView report, I will look into this further. 33 bbls works out to 159 sacks, so I believe the 195 sacks entered was a typo on the report. I have attached the corrected report, please let me know if you need any more information on this well. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday,January 28, 2015 2:59 PM To: Allsup-Drake, Sharon K Cc: Callahan, Mike S Subject: [EXTERNAL]RE: 2K-34(PTD 214-026) 10-407 Cementing Summary On the production liner cement,the yield calculation using 30 bbls pumped, 195 sx does not result in the 1.16 yield. Please clarify. Thanx, Victoria From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillios.com] Sent: Wednesday, January 28, 2015 2:43 PM To: Loepp, Victoria T(DOA) Cc: Callahan, Mike S Subject: RE: 2K-34(PTD 214-026) 10-407 Cementing Summary Victoria— Attached are the cement reports for 2K-34. Thanks, Sharon From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, January 28, 2015 2:19 PM 1 0161111 Cement Detail Report 2K-34 ConocoPhillips String: Production Liner Cement Job: Cement Details Description 'Cementing Start Date Cementing End Date Wellbore Name Production Liner Cement 6/20/2014 12:45 6/20/2014 14:30 2K-34 Comment SLB pumped 5 bbl H2O,test lines to 4000 psi. Batch up and pump 30 bbl 13.3 ppg MudPush II,30 bbl 15.8 pptg Tail cement,kick out plug with 10 bbl H2O, displace with rig pump. Dart latched wiper plug @ 915 stks,bumped plug @ 1065 stks,CIP @ 14:20. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Production Liner Cement Cement to top of 8,979.0 10,127.0 No 10.0 Yes No production liner Q Pump/nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 4 4 980.0 2,800.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(In) Comment Cement/contaminate returns to surface when circulating on top of packer. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 8,979.0 10,127.0 159 G 33.0 Yield(W/sack) Mix H2O Ratio(gal/ss... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 77.0 7.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.5 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Page 111 Report Printed: 1/28/2015 Of Cement Detail Report 2K-34 conocoPhillips String: Production Liner Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Liner Cement 6/20/2014 12:45 6/20/2014 14:30 2K-34 Comment SLB pumped 5 bbl H2O,test lines to 4000 psi.Batch up and pump 30 bbl 13.3 ppg MudPush II,30 bbl 15.8 pptg Tail cement,kick out plug with 10 bbl H2O, displace with rig pump.Dart latched wiper plug @ 915 stks,bumped plug @ 1065 stks,CIP @ 14:20. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Production Liner Cement Cement to top of 8,979.0 10,127.0 No 10.0 Yes No production liner Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 4 4 980.0 2,800.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement/contaminate returns to surface when circulating on top of packer. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped Tail Cement 8,979.0 10,127.0 195 G 30.0) Yield(ft!sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi -- 1.16 5.07 15.80 77.0 7.00 Additives Additive ._ Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type .-" Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type `,,, Concentration Conc Unit label Fluid Loss Control D167 ..."" 0.5 %BWOC Additive Type 2 Concentration Conc Unit label Retarder D177 ' 0.01 gal/sx y 10 ' 0. . i 0 le b i 5 ) P. , ...---- ( 6,, I Page 1/1 Report Printed: 7/24/2014 Cement Detail Report 0 ►ti 2K-34 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL,5/24/2014 12:00 Cement Details Description 'Cementing Start Date Cementing End Date 'Weilbore Name Surface Casing Cement 6/2/2014 01:30 6/2/2014 05:00 2K-34 Comment Pump 5 bbl of water to flood lines.Test cement lines 550&3000 psi.Rig pumps 100 bbls of 10.5 ppg MudPush @ 5 bpm=200 psi. Drop bottom plug.SLB pumped 460 bbls 11.02 ppg of ALC @ 6 bpm=250 psi.SLB pumped 57 bbls of 12 ppg tail cement @ 5 bpm=330 psi.Drop top plug&SLB pumped 10 bbls of water to flush lines.Swap to rig&pump 316 bbls of mud @ 7 bpm=600 psi,to bump top plug.Pressure up to 1100 psi for 5 min,bled off to check floats(good). CIP @ 05:00 hrs.178 bbls of cement to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement 10 3/4"surface 28.3 3,543.0 No 178.0 Yes Yes casing 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) 6 5 6 625.0 625.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5 bbl of water to flood lines.Test cement lines 550&3000 psi.Rig pumps 100 bbls of 10.5 ppg MudPush @ 5 bpm=200 psi.Drop bottom plug.SLB pumped 460 bbls 11.02 ppg of ALC @ 6 bpm=250 psi.SLB pumped 57 bbls of 12 ppg tail cement @ 5 bpm=330 psi.Drop top plug&SLB pumped 10 bbls of water to flush lines.Swap to rig&pump 316 bbls of mud @ 7 bpm=600 psi,to bump top plug.Pressure up to 1100 psi for 5 min,bled off to check floats(good). CIP @ 05:00 hrs.178 bbls of cement to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 28.3 2,817.0 1,338 G 460.0 Yield(fN/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr I(psi) 1.93 6.25 11.02 183.6 8.50 Additives Additive Type Concentration Conc Unit label Additive Type Concentration Conc Unit label Salt D044 10.0 %BWOW 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 Cement 2,817.0 3,555.0 198 G 57.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.62 5.36 12.00 167.8 6.50 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Retarder D110 0.02 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.09 gal/sx Page 1l1 Report Printed: 7/24/2014 114 Cement Detail Report 2K-34 ConocoPhilSI Flxke String: Cement Squeeze Job: DRILLING ORIGINAL, 5/24/2014 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Squeeze 6/4/2014 15:30 6/4/2014 16:21 2K-34 Comment Held PreJob.SLB pumped 2 bbls water.Pressure test to 2500 psi.Good.Pump 13.5 bbls 10.5 ppg Mud Push @ 3 bpm 140 psi.Pump 18.6 bbls 15.8 ppg cement @ 3 bpm 330 psi.Pump 3 bbl 10.5 ppg Mud Push.Rig chased with 47 bbls of 9.7 ppg mud.POOH 6 stands and perform squeeze.6 bbls squeezed away with hesitation squeeze in 10 minute intervals,600 psi max pressure. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Squeeze Enhance shoe integrity 3,460.0 3,575.0 No 0.0 No No 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) 3 3 3 330.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 3,460.0 Drill Bit 3,575.0 8 1/2 Comment Held PreJob.SLB pumped 2 bbls water.Pressure test to 2500 psi.Good.Pump 13.5 bbls 10.5 ppg Mud Push @ 3 bpm 140 psi. Pump 18.6 bbls 15.8 ppg cement @ 3 bpm 330 psi.Pump 3 bbl 10.5 ppg Mud Push. Rig chased with 47 bbls of 9.7 ppg mud.POOH 6 stands and perform squeeze.6 bbls squeezed away with hesitation squeeze in 10 minute intervals,600 psi max pressure. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 3,460.0 3,575.0 91 G 18.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.10 15.80 83.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) S002 0.5 %BWOC Page 1/1 Report Printed: 7/24/2014 1 0114 Cement Detail Report 2K-34 ConocoPhiilip String: Intermediate Casing Cement Job: DRILLING ORIGINAL,5/24/2014 12:00 Cement Details Description Cementing Start Date Cementing End Date 'Wellbore Name Intermediate Casing Cement 6/14/2014 14:30 6/14/2014 16:45 2K-34 Comment SLB pumped 60 bbl 12.5 ppg MudPush,60 bbl 15.8 ppg Tail cement,chase with 10 bbl water,displaced with 342 bbl 10.4 ppg mud to bump. Float held.CIP @ 16:30.95%returns throughout job. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Intermediate Casing Cement 7"casing 6,850.0 9,257.0 Yes Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 850.0 1,350.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 6,850.0 9,257.0 289 G 60.0 Yield(fN/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 104.0 4.75 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.005 gal/sx Page 111 Report Printed: 7/24/2014 RECEIVED ► STATE OF ALASKA SEP 19 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND SCC la Well Status: Oil ❑• Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.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: June 23,2014• 214-026/314-370 - 3 Address. 6 Date Spudded 13 API Number P.O. Box 100360,Anchorage,AK 99510-0360 May 26,2014- 50-103-20688-00- 4a Location of Well(Governmental Section) 7 Date TD Reached' 14 Well Name and Number: Surface: 116'FSL,94'FEL,Sec.2,T1ON, R8E, UM June 18,2014 • y`'�,.._- 2K-34 , Top of Productive Horizon 8. KB(ft above MSL): 143'RKB 15 Field/Pool(s): 345 FSL, 1890'FEL,Sec.3,T1ON, R8E, UM GL(ft above MSL). 115.8'AMSL Kuparuk River Field Total Depth 9.Plug Back Depth(MD+TVD) 4930'FNL, 2082'FEL,Sec.3,T1ON, R8E, UM 10117'MD/6215' Kuparuk Oil Pool • 4b Location of Well(State Base Plane Coordinates,NAD 27) 10 Total Depth(MD+TVD) 16.Property Designation. Surface: x-498310 y- 5938420 Zone-4 10127'MD/6217'TVD ADL 25588,25589 • TPI: x-491235 y- 5938654 Zone-4 11 SSSV Depth(MD+TVD) 17.Land Use Permit Total Depth: x-491697 y- 5938647 Zone-4 nipple @ 643'MD/642'TVD 2674,2675 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) 1600'MD/1440'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 none 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 164.8# A-106 28' 104' 28' 104' 42" driven 10.75" 45.5# L-80 28' 3543' 28' 2876' 13.5" 1338 sx ArcticLiteCRETE, 198 sx Class G 7" 26# L-80 26' 9248' 26' 5978' 8.5" 289 sx Class G 4.5" 12.# L-80 8979' 10117' 5906' 6215' 6.125" . / sx Class G /57 Vr7- /0//5— 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" 9025' 8979'MD/5906'TVD 9955'-9960'MD 6170'-6172'TVD 6 spf �OMPLE7lON- //� 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC l�/K1t 4 Was hydraulic fracturing used during completion? Yes No Q VERs r : DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ---^ w 3460'-3575' 91 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) / waiting on facility tie-in 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 Q ' Sidewall Cores Acquired' Yes ❑ No 0 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 ARCM$ OCT — 1 201& Form 10-407 Revised 10/2012 V, //Z y S CONTINUED ON REVERSE 0hU 1 30I&l )� Submit original only 429. GEOLOGIC MARKERS(List all formations and ma. encountered) 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 1600' 1440' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A5 9858' 6144' Top Kuparuk A4 9928' 6162' N/A Formation at total depth: Kuparuk A4 31 LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Mike Callahan @ 263-4180 Email: Mike.Callahan(c�conocophillips.com Printed Name G. L.Alvord Title. Alaska Drilling Manager yrole CCtlP4 4'l� ' 9-/q. Signature r, Phone 265-6120 Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation' Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Guhl, Meredith D (DOA) From: Callahan, Mike S [Mike.Callahan©conocophillips.com] Sent: Friday, January 30, 2015 12:06 PM To: Guhl, Meredith D (DOA) Subject: RE: KRU 2K-34, PTD 214-026, Complete list of Formation Tops Meredith, here's the information you need in table form. Top/Marker MD Actual TVD Actual 13-1/2" Intermediate Section Base Permafrost 1,648' 1,604' West Sak Sand 3,386' 2,783' Surface Casing Shoe 3,543' 2,875' 8-1/2" Intermediate Section Fault 6,279' 4,459' K-3 8,156' 5,542' K-2 8,617' 5,786' Top HRZ 8,760' 5,840' Intermediate Casing Shoe 8,257' 5,979' Base HRZ/Top Kalubik 9,355' 6,006' Fault 1 (DTE 18') 9,447' 6,031' K1 Marker 9,618' 6,078' Fault 2 (DTE 27') 9,649' 6,086' Top C 9,800' 6,129' Top A6 Not Observed Top A5 9,858' 6,143' Top A4 9,928' 6,162' TD in A4 10,127' 6,217' Please let me know if you need anything else. Thanks, Mike From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@aalaska.gov] Sent: Friday, January 30, 2015 11:51 AM To: Callahan, Mike S Subject: [EXTERNAL]RE: KRU 2K-34, PTD 214-026, Complete list of Formation Tops Mike, Sorry, I just printed what you sent to include it in the well history file and it didn't print clearly. Could you paste the data into an excel table or something? Or include it as a table rather than a picture so that it's legible, please? KUP PROD 2K-34 Conor Phillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ft66) Act Btm(ftKB) tr.vrdh„Ihp„ 501032068800 KUPARUK RIVER UNIT PROD 74.58 9212.37 10,127.0 ... Comment HIS(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-34,9/1620148.05-.18 AM SSSV:NIPPLE Last WO. 27.33 6/23/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD LATERAL haggea 9/16/2014 HANGER 23 5- 6.4 •m Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread _._..__. I CONDUCTOR 16 14.000 28.0 104.0 104.0 164.80 A-106 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 28.3 3,543.0 2,875.7 45.50 L-80 Hyd563 ,....Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 6276 25.8 9,247.7 5,977.7 26.00 L-80 TN Blue _....__........__..............._.............._.._.......... -...Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread LINER 41/2 3.958 8,979.2 10,117.0 6,214.8 12.60 L-80 IBTM T Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl("I Item Des Com (in) • 8,979.2 5,906.0 74.43 PACKER BAKER 5"x 7"ZXP PACKER w HRDE profile 10' 5.250 • ,tiM CONDUCTOR;29.0-10.0 8,999.3 5,911.4 74.51 NIPPLE BAKER"RS"NIPPLE TSH-521 Box x Box 4.270 • 9,002.1 5,912.1 74.52 HANGER BAKER FLEX LOCK LINER HANGER 4.350 1. NIPPLE:643.3 9,012.0 5,914.7 74.51 SBE BAKER 80-40 SEAL BORE ESTENSION 4.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB( Set Depth(ft..Set Depth IND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 23.5 9,024.8 5,918.2 9.30 L-80 EUE 8rd Completion Details Nominal ID P'. Top(ftKB) Top(ND)(ftKB) Top Inch) Item Des Com (in) GAS LIFT;3,021.1 23.5 23.5 0.00 HANGER FMC GEN V TUBING HANGER 2.992 643.4 641.7 7.28 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 8,935.7 5,894.3 74.26 NIPPLE CAMCO DS NIPPLE w/2.813"Profile 2.812 8,983.7 5,907.2 74.45 LOCATOR BAKER LOCATOR 3.000 8,984.9 5,907.5 74.45 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSY w/12'of 3.000 seals • SURFACE;28.3.3,843.0 l Perforations&Slots Shot • Dens GAS LIFT;5,097.1 t Top(TVD) Btm(ND) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Can 9,955.0 9,960.0 6,170.3 6,171.7 7/20/2014 0.0 IPERF 6 SPF 60 DEGREE PHASING GAS LIFT;6,589.8 Mandrel Inserts St ati Top(TVD) Valve Latch Port Size TRO Run GAS LIFT;7,705.6 ] N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com i; f' 3,021.1 2,572.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,312.0 9/6/2014 2 5,097.1 3,776.0 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,293.0 9/6/2014 GAS LIFT e,e755 - 3 6,589.8 4,638.7 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,276.0 9/6/2014 4 7,705.6 5,282.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,259.0 9/6/2014 II5 8,875.5 5,877.6 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 9/6/2014 NIPPLE;6935.7 Notes:General&Safety End Date Annotation NOTE: LOCATOR,8.983.6 1 111 I SEAL ASSY;8,984.9 I I _ U, II- at a I l INTERMEDIATE;25.8-9,247.7 L a_ IPERE;9.955.0-9.960.0 a la It LINER;8,979.2.10,117.0 f t SLOTS;9,952.7-12,329.6 _ LINER L7;9,951.9-12,330.0 /II 'i1. o co II •• rnfII ac\iEN ii `)i�Ellll/ : t` _ M NOc m Y (D- rt rt H E m Y N I- CO i- 11 Y o CD II 00 E o `� a) (5) (9 co 0 0 O m II cy U -+ COm m © 11 7 - C a m Y o I I N o a Coto o c IIal o c 4J o E oo m o_Ym I- @ �m o_W a) Y I1 c w N V p)YII G CL I LI _2- 6 c o o o m II Z D C7 C a) — (1, _I rn cn o CO U u) m Q x W m II 0 U Y U -§ XI° m UN II o °? o o NZ cLL � aN II U J UE U O r (n r o N II E * Eti E ca xCC xv Co N CO03 CO M (p U o O O `,4" .c II U rn U ao U o in in in w ° CD Orn II po N N N CO N N a) Y Y Y Y !�1= i i i co i i 0 co (Q co CO Cc) vO Q) ,.N";. CO CO M !— co M Jmmmm N 0 a3 Nip i;-- C CO `( I— ii.. 10,/ cn o Iiiii c EN i 1st o a --- m coo G) '-r, x :::). o O Lo N Q rn IL Y 0Y m (4;3 D J oco o o Q * .&)M o co N 4 © v, o .c co 2K-34 WELL WORK SUMMARY • DATE SUMMARY 7/17/2014 SLB CTU#5: PERFORM BOP SHELL TEST AND PUSH/PULL AFTER MONTHLY REBUILD AND BOPE TEST. CIRCULATE OUT DRILLING MUD WITH JET SWIRL NOZZLE, SLICK DIESEL, AND FLO-VIS GEL TO HARD TAG AT 9988' CTMD (10,003' RKB). DISPLACE WELL TO SLICK SEA WATER WITH CRW-132 CORROSION INHIBITOR AND LAY IN DIESEL FREEZE PROTECT FROM 2000'. READY FOR ELINE. 7/19/2014 DRIFTED TO TD @ 9953' SLM....JOB IN PROGRESS. 7/20/2014 PERFORATE FROM 9,955'-9,960' RKB W/2-1/2" POWER JET GUNS, WAIT 1 HOUR AND LOG SBHPS: 30 MINS PRESSURE STOP @ 9,955' RKB: 3803 PSI & 161 DEGF. 15 MINS GRADIENT STOP @ 9,590' RKB 3758 PSI & 157 DEGF. PRESSURES WERE STILL RISING WHILE LOGGING , LOG GR &CCL FROM SHOT DEPTH TO SBR @ 8,994' RKB, LOG CCL TO SURFACE @ 120 FPM JOB DONE. 7/25/2014 DRIFT TBG W/2.68" CENT&TAG TD @ 10021' SLM; MEASURE BHP @ 9955' RKB: 3832 PSI. JOB COMPLETE 7/26/2014 (PRE-CTD) T POT PASSED, T PPPOT PASSED, IC POT PASSED, IC PPPOT PASSED, SV NEG PASSED, SV POS PASSED, SSV NEG PASSED, SSV POS PASSED, MV NEG PASSED, MV POS PASSED. ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2K-34 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 5/25/2014 10:00:00 AM Rig Release: 6/24/2014 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/24/2014 24 hr Summary Released from rig maintenance @ 12:00 hrs. Rig down, separate modules and begin moving from 2B pad to 2K-34. Made notification to AOGCC of upcoming diverter test. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Release from rig maintenance @ 12:00 hrs,disconnect electrical and steam lines.Trucks arrived at 15:00 hrs. Pull apart rig mods. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Begin moving rig mods to 2K pad, pipe sheds and rock washer. Sub departed 2B pad @ 20:30 hrs. 35/25/2014 Move rig from 2B pad to 2K-34, rig up and accept rig @ 10:00 hrs. R/U diverter, load pipe shed and P/U 5" DP. 00:00 03:30 3.50 0 0 MIRU MOVE MOB P Spot sub base and pit complex over well 2K-34. 03:30 04:30 1.00 0 0 MIRU MOVE MOB P Mobilize pump room, motor room and boiler complex for 2B pad to 2K pad. 04:30 07:30 3.00 0 0 MIRU MOVE MOB P Spot power pack, rock washer and pipe shed. 07:30 08:30 1.00 0 0 MIRU MOVE RURD P Plug in electrical lines, hook up steam,air fuel and water. 08:30 10:00 1.50 0 0 MIRU MOVE RURD P PJSM,Work on rig accetance check list and test gas alarms. Rig Accepted at 10:00 hours. 10:00 12:00 2.00 0 0 MIRU DRILL NUND P PJSM, Nipple up diverter and install 4"valves on conductor. 12:00 14:00 2.00 0 0 MIRU DRILL NUND P PJSM,continue N/U diverter. 109' from well to end of diverter, 90'from cellar wall to end of diverter. 14:00 18:00 4.00 0 0 MIRU DRILL RURD P Take on Drilplex mud, load pipe shed with 103 jts 5"DP, 17 jts HWDP, R/U envirovac, instqall mouse hole, install elevators. 18:00 20:00 2.00 0 0 MIRU DRILL RURD P Strap DP, HWDP and DC in pipe shed, continue on-loading mud, R/U to P/U DP. 20:00 00:00 4.00 0 0 MIRU DRILL PULD P PJSM, P/U 30 stands 5"drill pipe via mouse hole. 35/26/2014 Complete P/U pipe. Perform diverter and accumulator test,witness waived by AOGCC Bob Noble. M/U BHA #1 and clean out to 130'MD. M/U drilling BHA,adjust motor to 1.5°, directional drill to 746'MD taking Gyro surveys. 00:00 01:00 1.00 0 0 MIRU DRILL PULD P PJSM, P/U 4 stands of 5"DP and 6 stands of 5"HWDP. Page 1 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:30 0.50 0 0 MIRU DRILL BOPE P Perform diverter test:system pressure=2900 psi, pressure after closing=1800 psi,200 psi recharge= 42 sec,full pressure after 168 sec. Time to knife valve open= 10 sec, time for annular to close= 18 sec. Witness of test waived by AOGCC rep Bob Noble. 01:30 03:30 2.00 0 0 MIRU DRILL RURD P Load pipe shed with SLB tools and pick up tools from ground via beaver slide. 03:30 05:00 1.50 0 0 SURFA( DRILL PULD P PJSM, M/U BHA#1 as per SLB rep. 05:00 05:45 0.75 0 0 SURFA( DRILL RURD P Flood conductor, R/U and pressure test surface equipment to 5000 psi, good. 05:45 08:15 2.50 0 130 SURFA( DRILL DRLG P Drill out conductor with 0°bent in motor. Drill f/30'MD to 130'MD pump @ 450 gpm,400 psi,86% flow,20-30 rpm's. 08:15 09:00 0.75 130 30 SURFA( DRILL TRIP P PJSM, POOH f/130'MD to 30'MD. 09:00 09:45 0.75 30 30 SURFA( DRILL PULD P Adjust motor bend to 1.5°as per SLB rep. 09:45 11:15 1.50 30 30 SURFA( DRILL PULD T Trouble shoot Gyrodata tools- SIMOPS, P/U 3 joints of drill collars. 11:15 12:15 1.00 30 60 SURFA( DRILL PULD P PJSM, P/U BHA#2 as per SLB rep. 12:15 14:00 1.75 60 130 SURFA( DRILL PULD P PJSM,Continue P/U BHA#2 14:00 14:30 0.50 130 130 SURFA( DRILL SRVY P RIH tag bottom,Take Gyro survey, shallow pulse test @ 450 gpm, 500 psi. 14:30 16:00 1.50 130 243 SURFA( DRILL DRLG P Drill from 130' MD to 243'MD @ 40 rpm, 1k TQ,450 gpm @ 500 psi, 86%Flow out. (SIMOPS on L/D single and rack back stand.) 16:00 16:30 0.50 243 243 SURFA( DRILL PULD P POOH with single, rack back 1 stand. P/U flex collars and saver sub, P/U stand HWDP. Establish parameters. 16:30 00:00 7.50 243 746 SURFA( DRILL DDRL P Directional drill from 243'MD to 746' MD, 746'TVD.ART=2.77, AST=2.76,ADT=5.53,Jar Hrs=29.23, Bit Hrs=5.53, P/U=74k, S/O=74k, ROT=74k,Tq on/off=4/1k ft lbs,WOB=5-25k, ECD=10.76, 56%Flow out, 60 rpm,493 gpm @ 900 psi. Reduced rpm to 60 per Gyrodata for tool. No recordable losses. 05/27/2014 Continued directional drilling 13 1/2" surface hole section from 746-2159'MD,2013'TVD. Page 2 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 746 1,141 SURFA( DRILL DDRL P Directional drill from 746'MD to 1141' MD, 1131'TVD.ART=1.87, AST=2.08,ADT=3.95,Jar Hrs=33.18, Bit Hrs=9.48, P/U=87k, S/0=82k, ROT=85k,Tq on/off=6/3k ft lbs,WOB=15-20k, ECD=10.32, 64%Flow out,60 rpm, 500 gpm @ 1000 psi. No recordable losses. 06:00 12:00 6.00 1,141 1,419 SURFA( DRILL DDRL P Directional drill from 1141'MD to 1419'MD, 1398'TVD.ART=.72, AST=2.97,ADT=3.69,Jar Hrs=36.87, Bit Hrs=13.17, P/U=93k, S/0=83k, ROT=88k,Tq on/off=7/3k ft lbs,WOB=20-25k, ECD=10.65, 84%Flow out, 60 rpm,500 gpm @ 1100 psi. Observing loss—8 bph,total for tour 55 bbls. 12:00 18:00 6.00 1,419 1,753 SURFA( DRILL DDRL P Directional drill from 1419'MD to 1753'MD, 1714'TVD.ART=.95, AST=3.4,ADT=4.35,Jar Hrs=41.22, Bit Hrs=17.52, P/U=97k, S/O=88k, ROT=92k,Tq on/off=4/2k ft lbs, WOB=5-15k, ECD=10.41,71% Flow out,60 rpm,607 gpm @ 1300 psi. 18:00 00:00 6.00 1,753 2,159 SURFA( DRILL DCSG P Directional drill from 1753' MD to 2159'MD,2013'TVD.ART=1.71, AST=2.15,ADT=3.86,Jar Hrs=45.08, Bit Hrs=21.38, P/U=104k, S/0=90k, ROT=95k,Tq on/off=4/2k ft lbs,WOB=5-25k, ECD=10.52,87%Flow out,60 rpm, 604 gpm @ 1400 psi. 35/28/2014 Directional drilled from 2159'-3590'MD,2909 TVD.Circulate surface to surface 2X. OWFF&backream out of hole to 3090' MD. 00:00 06:00 6.00 2,159 2,530 SURFA( DRILL DDRL P Directional drill from 2159' MD to 2530'MD,2285'TVD.ART=1.42, AST=2.10,ADT=3.52, Jar Hrs=48.60, Bit Hrs=24.90, P/U=106k, S/0=91k, ROT=98k, Tq on/off=6/3k ft lbs,WOB=15-20k, ECD=10.32, 59% Flow out,60 rpm, 608 gpm @ 1710 psi. 06:00 12:00 6.00 2,530 2,994 SURFA( DRILL DDRL P Directional drill from 2530'MD to 2994'MD,2562'TVD.ART=2.98, AST=1.13,ADT=4.11,Jar Hrs=52.71, Bit Hrs=29.01, P/U=109k, S/O=88k, ROT=96k, Tq on/off=6/5k ft lbs,WOB=20-25k, ECD=10.72, 66%Flow out, 60 rpm, 650 gpm @ 1850 psi. Page 3 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 2,994 3,455 SURFA( DRILL DDRL P Directional drill from 2994'MD to 3455'MD,2830'TVD.ART=3.35, AST=.32,ADT=3.67,Jar Hrs=56.38, Bit Hrs=32.68, P/U=115k, S/0=91k, ROT=100k,Tq on/off=8/4k ft lbs, WOB=5-25k, ECD=10.85, 84% Flow out, 80 rpm,750 gpm @ 2475 psi. 18:00 21:00 3.00 3,455 3,590 SURFA( DRILL DDRL P Directional drill from 3455'MD to 3590'MD,2908'TVD.ART=1.60, AST=O,ADT=1.6, Jar Hrs=57.98, Bit Hrs=34.28, P/U=120k, S/O=93k, ROT=101 k,Tq on/off=7/4k ft lbs, WOB=5-20k, ECD=10.46,80% Flow out,80 rpm,755 gpm @ 2475 psi. 21:00 22:30 1.50 3,590 3,590 SURFA( CASING CIRC P Circulate surface to surface 2X @ 650 gpm, 1850 psi,60 rpm,5k tq, FO 60%. 22:30 23:00 0.50 3,590 3,590 SURFA( CASING OWFF P Monitor well, losses observed, calculated 18 BPH. 23:00 00:00 1.00 3,590 3,090 SURFA( CASING REAM P BROOH from 3590'-3090' MD,650 gpm, 1750 psi,60 rpm,6k tq, FO 60 %, calcualted 3.75,actual 33 bbls, 30 bbls loss 05/29/2014 BROOH from 3090'-1698'MD. Hole unloaded&exceed surface equipment capacity.Clean up&stage up pumps.Whlie staging up pumps tagged up at 1647' MD. Made several attempts to get back in the hole.Tried to slide back into the original hole with gyro&MWD surveys confirming, not in original wellbore. Decision made to sidetrack and obtain wellbore seperation. Directional drill from 1882'-2380' MD,2161'TVD. 00:00 01:45 1.75 3,090 1,698 SURFA( CASING REAM P BROOH f/3090'MD to 1698' MD. Began BROOH @ 650 gpm, hole taking 30 bbls for 5 stands pulled. Slowed pumps to 450 gpm=1430 psi,hole still taking 16 bbls for 5 stands pulled. Rotate @ 60 rpm's with 5K Tq. 01:45 03:45 2.00 1,698 1,698 SURFA( CASING OTHR T Observed hole unloading cuttings at a high rate, unable to process the large amount of cutting on surface equipment.Shut down, unpack and clean flow line, possum belly. Stage pumps back up to 450 gpm. 03:45 05:00 1.25 1,698 1,647 SURFA( CASING REAM T Pick up f/1698'MD to 1607'MD, work string down.Tagged up @ 1647'MD. Set down 15K two times. P/U and line up tool face high side, pump @ 2 bpm and attempt to slack-off.Attempt to slack-off w/5 rpm's and no pump, no success. Attempt to rotate @ 5 rpm's,pump @ 2 bpm, no success. Increase rotary to 60 rpm's and pump @ 2 bpm, no success. Unable to work past 1647'MD. Page 4 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:45 0.75 1,647 1,662 SURFA( CASING DDRL T Attempt to re-enter wellbore by pumping @ 300 gpm=950 psi,60 rpm's,Tq=4K, 10K WOB.All inductions point that new hole was drilled to 1662'MD. P/U to 1640' MD, had to set down 20K to get past 1647'MD. 05:45 06:45 1.00 1,662 1,662 SURFA( CASING CIRC T P/U and work pipe, pump @ 2 bpm=200 psi, P/U=96K, S/O=90K. Discuss options with town. 06:45 09:30 2.75 1,662 1,793 SURFA( CASING DDRL T Slide 10L f/1662'MD to 1698'MD, pump @ 450 gpm=850 psi,63% flow. Perform Gyro survey, Gyro tool 8'into sidetrack. Data showed we are 1/2°low and 1° R of original wellbore. Slide @ 40L f/1698'MD to 1750'MD to attempt to intersect original wellbore. Shoot Gyro survey @ 1750'MD, Drill ahead f/1750' MD to 1793'MD, pump @ 500 gpm, 1000 psi,63%flow,60 rpm's, 6K Tq. 09:30 11:15 1.75 1,793 1,515 SURFA( CASING REAM T BROOH @ 510 gpm=850=1050 psi, 60 rpm's f/1793'MD to 1603'MD, observed high and erratic torque @ 1647'MD. Shut down rotary and pumps,worked though trouble zone @ 1647'MD multiple times,good. POOH to 1515'MD on elevators. 11:15 11:30 0.25 1,515 1,790 SURFA( CASING TRIP T Trip in to hole f/1515'MD to 1790' MD. No tight hole observed. 11:30 12:00 0.50 1,790 1,790 SURFA( CASING SRVY T Survey hole, Discuss plan forward to re-drill surface hole f/1647'MD to TD 12:00 13:30 1.50 1,790 1,882 SURFA( CASING DDRL T Directional drill from 1790'MD to 1882' MD, 1802'TVD. P/U=100k, S/0=89k, ROT=95k,Tq on/off=6/4k ft lbs,WOB=10-25k, ECD=10.18, 62%Flow out,60 rpm,500 gpm @ 1150 psi. 13:30 15:00 1.50 1,882 1,882 SURFA( CASING SRVY T POOH from 1882'- 1697' MD,taking MWD surveys at 1759', 1744', 1697' MD.Wash back to 1882'MD& consult with town to drill ahead to obttain wellbore seperation. 15:00 18:00 3.00 1,882 2,160 SURFA( CASING DDRL T Directional drill from 1882' MD to 2160'MD, 2025'TVD.ART=1.58, AST=2.11,ADT=3.69,Jar Hrs=61.67, Bit Hrs=37.97, P/U=103k, S/O=89k, ROT=95k,Tq on/off=6/3k ft lbs,WOB=5-30k, ECD=10.35,71%Flow out,60 rpm, 648 gpm @ 1600 psi. Page 5 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:45 3.75 2,160 2,344 SURFA( CASING DDRL T Directional drill from 2160'MD to 2344'MD,2161'TVD.ART=.38, AST=1.41,ADT=1.79, Jar Hrs=63.46, Bit Hrs=39.76, P/U=106k, S/0=90k, ROT=97k,Tq on/off=5/2k ft lbs,W0B=5-30k, ECD=10.21,71%Flow out,60 rpm, 651 gpm @ 1650 psi. 21:45 23:00 1.25 2,344 2,344 SURFA( CASING SFTY T Remove ice build up from derrick. 23:00 00:00 1.00 2,344 2,380 SURFA( CASING DDRL T Directional drill from 2344' MD to 2380'MD, 2161'TVD.ART=0, AST=1,ADT=1,Jar Hrs=64.45, Bit Hrs=40.75, P/U=106k, S/0=90k, ROT=97k,Tq on/off=8/4k ft lbs, WOB=5-25k, ECD=10.28,71% Flow out, 70 rpm,650 gpm @ 1650 ' psi. 35/30/2014 While drilling at 2380' MD,encounter a hard spot.While trying varying parameters to make it drill, noticed indications that we might be hanging up on a stabilizer up the string. Racked back a stand and reamed 2349'-2257'MD.Tagged up at 2305'on second full ream. Made several attempts to re-enter hole without pumps. Lined up tool face directionally and stacked 35k on string,with pumps and slid ahead with no differential psi into well bore. Reamed clean and confirmed position with survey. Drilled to TD, from 2383'-3555' MD,2882 TVD. CBU 3X&OWFF 30 min. 00:00 00:30 0.50 2,380 2,383 SURFA( CASING DDRL T Directional drill from 2380' MD to 2383'MD, 2161'TVD.ART=.5, AST=O,ADT=.5,Jar Hrs=66.10, Bit Hrs=42.40, P/U=106k, 5/0=90k, ROT=97k,Tq on/off=5/4k ft lbs, WOB=5-30k, ECD=10.21, 71% Flow out, 60 rpm,650 gpm @ 1650 psi. 00:30 02:30 2.00 2,383 2,383 SURFA( CASING DDRL T No progress making hole.Try varying parameters 40-70 rpm, 5-35k WOB, 650 gpm, 1650 psi,with no success. Conditions indicated stab was hanging up a stand up the hole. 02:30 03:30 1.00 2,383 2,305 SURFA( CASING REAM T Rack one stand back and ream from 2349'-2257'MD. On second ream down tagged up at 2305'MD. Made several attempts to get back into hole with no pumps on(stacking weight&lining up tool face). Pick up away from tag point and shoot survey to confirm location. 03:30 05:45 2.25 2,305 2,383 SURFA( CASING REAM T Line up tool face for directional and slide from 2305'-2349'MD,stacking 30k WOB,650 gpm, 1500 psi. Observed no differential psi while sliding.Shot survey to confirm correct position. Reamed from 2300'-2383'MD(650 gpm, 1500 psi, 60 rpm, 3-9k tq.)&shot survey to confirm correct position. Page 6 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 12:00 6.25 2,383 2,665 SURFA( CASING DDRL T Directional drill from 2383'MD to 2665'MD,2368'TVD.ART=1.60, AST=2.52,ADT=4.12,Jar Hrs=72.15, Bit Hrs=48.45, P/U=111k, S/0=86k, ROT=96k,Tq on/off=7/4k ft lbs,WOB=15-20k, ECD=10.42,60%Flow out,60 rpm, 650 gpm @ 1680 psi. 12:00 18:00 6.00 2,665 3,238 SURFA( CASING DDRL T Directional drill from 2665'MD to 3238' MD,2696'TVD.ART=2.94, AST=1.33,ADT=4.27,Jar Hrs=76.42, Bit Hrs=52.72, P/U=115k, S/0=91k, ROT=99k,Tq on/off=8/4k ft lbs,WOB=25-30k, ECD=10.64,69%Flow out,80 rpm, 670 gpm @ 1900 psi. 18:00 21:30 3.50 3,238 3,555 SURFA( CASING DDRL T Directional drill from 3238'MD to 3555'MD,2883'TVD.ART=1.98, AST=0,ADT=1.98,Jar Hrs=78.40, Bit Hrs=54.70, P/U=120k, S/0=94k, ROT=100k, Tq on/off=8/5k ft lbs, WOB=15-20k, ECD=10.50,70% Flow out, 80 rpm,700 gpm @ 2200 psi. 21:30 23:30 2.00 3,555 3,555 SURFA( CASING CIRC T CBU 3X with rotation and recipication.720 gpm, 2200 psi,80 rpm, 5-6k Tq, PU 120K, SO 91K, & ROT 101K. 23:30 00:00 0.50 3,555 3,555 SURFA( CASING OWFF T Monitor well, static 05/31/2014 BROOH from 3555'-1886'MD.At 2534'MD a large amount of clay exceeded the capacity of our surface equipment.Shut down to clear. POOH on elevators from 1886-1515 MD. RIH from 1515-3460'MD. CBU 3X& OWFF. POOH to surface laying down BHA. Flushed stack of clay and made a dummy run with the hanger. Rigged up Tesco casing equipment. Made up shoe and float equipment. 00:00 00:30 0.50 3,555 3,365 SURFA( CASING TRIP T PJSM,Attempt to POOH on elevators,pull 2 stands, pulling tight w/30K OP @ 3365' MD. Decision made to BROOH. 00:30 02:15 1.75 3,365 2,534 SURFA( CASING REAM T BROOH f/3365'MD to 2534'MD. Pump @ 650 gpm=1800 psi, rotate ©60 rpm's w/5-6K Tq, 1200 fph string speed. 02:15 05:45 3.50 2,534 2,534 SURFA( CASING OTHR T Cuttings over loaded the flow line and riser, large clay/gravel balls packed off the flow line. Unpack flow line and riser. 05:45 07:30 1.75 2,534 1,886 SURFA( CASING REAM T BROOH f/2534'MD to 2164'MD. Pump @ 650 gpm= 1800 psi, rotate @ 60 rpm's w/5-6K Tq, 1200 fph string speed.Slow back reaming speed to 4.5 fpm @ 2164', CBU x 2 to 1886'MD.Actual displacement= 17 bbls,Calculated displacement= 11.7 bbls. Page 7 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 1,886 1,515 SURFA( CASING WPRT T POOH on elevators f/1886'MD to 1515'MD. No overpull observed. Actual displacement=7.14 bbls, Calculated displacement=3.9 bbls. 08:00 08:15 0.25 1,515 1,880 SURFA( CASING WPRT P RIH from 1515'-1880'MD. 08:15 09:15 1.00 1,880 1,880 SURFA( CASING SFTY P Remove ice from derrick. 09:15 10:00 0.75 1,880 3,460 SURFA( CASING WPRT P RIH from 1880'-3460'MD. Smooth trip no problems. Calculated displacement 19.5,actual displacement 20.86. 10:00 10:15 0.25 3,460 3,555 SURFA( CASING REAM P Wash and ream from 3460'-3555' MD,450 gpm, 1250 psi, 60 rpm,Tq 5-6K, PU 105K, SO 80K. 10:15 12:15 2.00 3,555 3,450 SURFA( CASING CIRC P CBU 3X @ 650 gpm, 1650 psi, FO 74%, 60 rpm,Tq 5-6K. Lay down single and rack back a stand at each BU. 12:15 12:45 0.50 3,450 3,450 SURFA( CASING OWFF P Monitor well, static. 12:45 15:00 2.25 3,450 790 SURFA( CASING TRIP P POOH on elevators from 3450'-790' MD, PU 117K, SO 90K. Calculated displacement 40.86, actual 65.11 bbls. 15:00 16:00 1.00 790 219 SURFA( CASING TRIP P Stand back HWDP. 16:00 18:30 2.50 219 0 SURFA( CASING PULD P Lay down BHA as per SLB DD. 18:30 20:00 1.50 0 0 SURFA( CASING RURD P Clear BHA from floor and clean up. 20:00 21:15 1.25 0 0 SURFA( CASING RURD P Flush&drain stack. Make dummy run with hanger. 21:15 23:00 1.75 0 0 SURFA( CASING RURD P Rig up Tesco casing equipment. 23:00 00:00 1.00 0 123 SURFA( CASING RNCS P PJSM, make up shoe joint and float equipment. 06/01/2014 RIH with 10 3/4"casing from 123'-720'MD. Started losing returns&could not establish circulation. Decision made to lay down casing till circulation could be established. Bowspring centralizers packed with clay. Stage up pumps and RIH washing each joint down from 123'-3505'MD,stopping several time to CBU&de-ice derrick. Make up hanger&landing joint. Land casing @ 3542'MD.After laying down Tesco CRT&making up cement head could not pick up string. Circulate&condition for cement job. 00:00 00:15 0.25 123 123 SURFA( CASING RNCS P Test float equipment,good. 00:15 02:00 1.75 123 720 SURFA( CASING RNCS P RIH with 10.75"casing from 123'-720' MD. Returns lost to hole and could not establish circulation. Decision made to POOH and establish circulation. 02:00 04:15 2.25 720 123 SURFA( CASING RNCS T POOH from 720'-123'MD. Bowspring centralizers packed with clay. 04:15 04:45 0.50 123 123 SURFA( CASING CIRC T Establish circulation staging the pumps up to 4.5 bpm, 100 psi, FO 45%. 04:45 07:00 2.25 123 720 SURFA( CASING RNCS T RIH from 123'-720'MD,4 bpm, 100psi,45%FO. 07:00 08:30 1.50 720 1,040 SURFA( CASING RNCS P RIH from 720'-1040'MD. Reduce pump rate and running speed to 3 bpm,75 psi, FO 35%, 180 fph. Page 8 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:00 0.50 1,040 1,040 SURFA( CASING CIRC P CBU staging up pump rate 3-5 bpm, 75-150 psi, FO 35-54%. 09:00 11:00 2.00 1,040 1,802 SURFA( CASING RNCS P RIH from 1040'-1802'MD, 5 bpm, 150 psi, FO 54%. 11:00 12:00 1.00 1,802 1,802 SURFA( CASING CIRC P CBU @ 5 bpm,210 psi, 54%FO, PU 100K, SO 72K. Losses for tour 295 bbls. 12:00 14:45 2.75 1,802 2,685 SURFA( CASING RNCS P RIH from 1802'-2685'MD, 5 bpm, 200 psi. 14:45 15:45 1.00 2,685 2,685 SURFA( CASING SFTY P Remove ice from derrick. Circulate @ 5 bpm=200 psi. 15:45 16:00 0.25 2,685 2,740 SURFA( CASING RNCS P RIH from 2685'-2740'MD,5 bpm, 200 psi. 16:00 16:45 0.75 2,740 2,740 SURFA( CASING SFTY P Remove ice from derrick, circulate 5 bpm, 250 psi. 16:45 19:15 2.50 2,740 3,505 SURFA( CASING RNCS P RIH form 2740'-3505'MD, 5 bpm, 300 psi. 19:15 21:15 2.00 3,505 3,505 SURFA( CASING CIRC P CBU @ 5 bpm, 300 psi, PU 160K, SO 103K. Pick up cement head& long bales. 21:15 22:45 1.50 3,505 3,542 SURFA( CASING RNCS P Make up hanger&landing joint. Land hanger @ 3542'MD. Lay down Tesco CRT&make up cement head. Calculated displacement 33.05, actual 79.52 bbls. 22:45 00:00 1.25 3,542 3,542 SURFA( CEMEN'CIRC P Circulate&condition mud for cement. Stage up pumps 2-5 bpm, 150-300 psi.Attempt to ricpicate string. Pull 100k over,decision made to leave landed. Losses for tour 127 bbls 06/02/2014 Circulated&conditioned mud for cement job. Cemented 10.75"surface casing as per program, CIP @ 05:00 hrs. Flush stack with retarder pill. Nipple down surface&diverter equipment. Nipple up, orient&test wellhead to 1000 psi for 10 min. Nipple up casing spool&BOPE. Rig up&test BOPE 250/3500 psi, for 5 minutes each. Completed 6 out of 10 tests at 24:00 hrs.Test waived by AOGCC Rep.Jeff Jones. 00:00 01:15 1.25 3,542 3,542 SURFA( CEMEN-CIRC P Circulate&condition mud for cement staging pumps up 6-7 bpm,300-400 psi, FO 49-54%. Slight losses at 7 bpm. 01:15 01:30 0.25 3,542 3,542 SURFA( CEMEN-SFTY P PJSM with all involved parties for cement job. 01:30 05:15 3.75 3,542 3,542 SURFA( CEMEN'CMNT P Pump 5 bbl of water to flood lines. Test cement lines 550&3000 psi. Rig pumps 100 bbls of 10.5 ppg MudPush @ 5 bpm=200 psi. Drop bottom plug. SLB pumped 460 bbls 11.02 ppg of ALC @ 6 bpm=250 psi. SLB pumped 57 bbls of 12 ppg tail cement @ 5 bpm=330 psi. Drop top plug&SLB pumped 10 bbls of water to flush lines. Swap to rig&pump 316 bbls of mud @ 7 bpm=600 psi, to bump top plug. Pressure up to 1100 psi for 5 min, bled off to check floats(good). CIP @ 05:00 hrs. 178 bbls of cement to surface. _ _ Page 9 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 06:15 1.00 3,542 3,542 SURFA( CEMEN-RURD P Flush out stack with cement retarder pill. Rig down cement head&landing joint. 06:15 07:15 1.00 3,542 3,542 SURFA( CEMEN'SFTY P Remove ice from derrick. 07:15 12:00 4.75 3,542 3,542 SURFA( WHDBO NUND P Function and wash out surface annular. Nipple down diverter equipment. Sim-op clear floor of casing running tools. 12:00 13:00 1.00 3,542 3,542 SURFA(WHDBO NUND P Prep&install wellhead as per FMC rep. 13:00 14:30 1.50 3,542 3,542 SURFA( WHDBO NUND P Orient&verify wellhead with pad operator. Torque&test well head to 1000 psi for 10 min. 14:30 17:00 2.50 3,542 3,542 SURFA( WHDBO NUND P Nipple up casing spool&BOPE. 17:00 18:00 1.00 3,542 3,542 SURFA( WHDBO NUND P Change out lines on annular&install riser. 18:00 18:45 0.75 3,542 3,542 SURFA( WHDBO NUND P Clear and clean rig floor&cellar. 18:45 20:00 1.25 3,542 3,542 SURFA( WHDBO RURD P Rig up BOPE test equipment. 20:00 00:00 4.00 3,542 3,542 SURFA( WHDBO BOPE P Test BOPE with 5"joint 250/3500 psi,for 5 min each.#1 top VBR's; CV's 1,12,13,14; Manual Kill Line Valve.#2 Upper IBOP; CV's 9, 11; HCR Kill.#3 Lower IBOP; CV's 5,8,10.#4 Dart valve; CV's 4,6,7.#5 FSV; CV 2.#6 HCR Choke&4"Kill Line Demco Valve. AOGCC Jeff Jones waived on 6-1-14 @ 19:10 hrs. 06/03/2014 Finish testing BOPE&rig down. Pick up and stand back 111 joints of 5"DP. Pick up and make up BHA 3. Single in the hole with BHA 3 to 3404'. CBU&test casing to 3000 psi for 30 min. Drill out float equipment, shoe&20'of new hole to 3575'MD. CBU&rack back one stand. Rig up&perform LOT to a 14.0 ppg EMW. Shut in pressure, bled down to 190 psi. Confer with town and decide to perform second test. LOT to 13.4 ppg EMW. Shut in pressure bled down to 115 psi. Confer with town,decide to POOH to RIH&squeeze cement. Monitor well&POOH from 3401'-1100' MD. 00:00 01:45 1.75 3,542 3,542 SURFA( WHDBO BOPE P Test BOPE with 5"joint 250/3500 psi, for 5 min each.#7 Manual Choke Vavie&HCR Kill.#8 Annular Preventer.#9 Lower VBR's.#10 Blind Rams&CV 3.Accumulator Test: Initial System Psi=2900 psi; After Closure=1650 psi;200 psi Attained=40 sec; Full psi Attained = 188 sec. 5 Nitrogen bottles averaged 2150 psi.Test waived by AOGCC Jeff Jones waived on 6-1-14 @ 19:10 hrs. 01:45 02:45 1.00 3,542 3,542 SURFA(WHDBO RURD P Rig down test equipment,blow down TD&all lines. Install wear ring 10.125". 02:45 03:15 0.50 0 0 SURFA( CEMEN RURD P Mobilize tools to rig floor&install mouse hole. 03:15 06:30 3.25 0 0 SURFA( CEMEN-PULD P Pick up 111 joints(37 stands)&rack back in the derrick. Page 10 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:00 0.50 0 0 SURFA( CEMEN-RURD P Clear&clean rig floor. Mobilize BHA to rig floor. 07:00 09:00 2.00 0 724 SURFA( CEMEN-PULD P Pick up&make up BHA 3, as per SLB DD. 09:00 09:45 0.75 724 724 SURFA( CEMEN DHEQ P Shallow pulse test MWD&Power Drive @ 470 gpm, 975 psi, FO 53%. 09:45 10:15 0.50 724 724 SURFA( CEMEN-SVRG P Service Rig 10:15 12:45 2.50 724 3,404 SURFA( CEMEN-PULD P Single in the hole from 724'-3404', calculated displacement 28.2;actual 22.4 bbls. 12:45 13:45 1.00 3,404 3,404 SURFA( CEMEN CIRC P CBU @ 500 gpm= 1300 psi. 13:45 14:15 0.50 3,404 3,404 SURFA( CEMEN-RURD P Rig up to test casing. 14:15 14:45 0.50 3,404 3,404 SURFA( CEMEN PRTS P Test 10 3/4"surface casing to 3000 psi for 30 min. 14:45 15:15 0.50 3,404 3,455 SURFA( CEMEN-COCF P Wash&ream from 3404'-3455'MD, 475 gpm, 1200 psi, 30 rpm,6-10K Tq, PU 112K, SO 82K, ROT 92K. 15:15 18:00 2.75 3,455 3,462 SURFA( CEMEN-DRLG P Drill out float equipment from 3455'-3462'MD,475 gpm, 1200 psi, 20-50 rpm, 6-10k Tq,WOB 10-20K. 18:00 19:30 1.50 3,462 3,575 SURFA( CEMEN DRLG P Drill cement, shoe, &20'of new hole from 3462'-3575'MD,550 gpm, 1700 psi, 50-60 rpm,Tq 5-8K,WOB 5-12 K. 19:30 20:00 0.50 3,575 3,501 SURFA( CEMEN-CIRCP CBU 550 gpm, 1600 psi, PU 120K, SO 82K, ROT 82K, 80 rpm,5-8k Tq. Rack a stand back. SPR @ 3501'MD 2869'TVD, MW 9.8 ppg,22:15 hrs. #1 @ 30= 130; @ 40=220 #2 @ 30= 140; @ 40=220 20:00 20:15 0.25 3,501 3,501 SURFA( CEMEN-RURD P Rig up test equipment for LOT. 20:15 22:00 1.75 3,501 3,501 SURFA( CEMEN-LOT P Perform LOT to 14.0 ppg EMW.Shut in pressure bled down to 190 psi. Confer with town and decide to perform second test. LOT to 13.4 ppg EMW. Shut in pressure bled down to 115 psi. Confer with town, decide to POOH to RIH&squeeze cement. 22:00 22:30 0.50 3,501 3,501 SURFA( CEMEN-OWFF T Monitor well, static. 22:30 00:00 1.50 3,501 1,100 SURFA( CEMEN-TRIP T POOH from 3501'-1100'MD, PU 60K,SO 59K. Calculated displacement 15, actual 17.68 bbls. X6/04/2014 Finish POOH to surface. Rig up and test with 3.5"test joint. Rig up&pick up-900'of 3.5"tubing. RIH with tubing on 5"DP to 3575'MD. Lay 200'cement plug around casing shoe, POOH to 3000'MD&squeeze. POOH from 3000'-970'MD. Lay down tubing from 970'-538'MD. 00:00 00:15 0.25 1,100 724 SURFA( CEMEN-TRIP T POOH from 1100'-724'MD. Monitor well,static 00:15 01:00 0.75 724 0 SURFA( CEMEN-PULD T Rack back HWDP, DC, BHA 3. Lay down stab&bit. Calculated displacement 23.67,actual 23.46 bbls. Page 11 of 34 Time Logs Date _ From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:15 0.25 0 0 SURFA( CEMEN-RURD T Clear&clean rig floor. 01:15 01:30 0.25 0 0 SURFA( CEMEN-BOPE T Drain stack, pull wear bushing, & R/U to test 3.5"tubing. 01:30 03:30 2.00 0 0 SURFA( CEMEN BOPE T Test 3.5"joint to 250/3500 psi for 5 min each test.Annular, upper& lower VBR's were tested. 03:30 04:00 0.50 0 0 SURFA( CEMEN BOPE T Rig down test equipment,drain stack, install 10.125"wear bushing. 04:00 05:00 1.00 0 0 SURFA( CEMEN RURD T Rig up tubing handling equipment. 05:00 06:30 1.50 0 939 SURFA( CEMEN'PULD T Pick up&RIH 3.5"8rd EUE tubing from surface to 939'MD. 06:30 06:45 0.25 939 939 SURFA( CEMEN RURD T Change out handling equipment to 5". 06:45 08:15 1.50 939 3,531 SURFA( CEMEN-TRIPT RIH from 939'-3531'MD, rig up cement lines. Calculated displacement 25.02, actual 21.7 bbls. 08:15 09:15 1.00 3,531 3,575 SURFA( CEMEN'CIRC T Wash down from 3531'-3575'MD& condition mud for cement @ 7 bpm, 525 psi, FO 40%. 09:15 12:45 3.50 3,575 3,575 SURFA( CEMEN OTHR T Wait on SLB cementers. 12:45 15:30 2.75 3,575 3,575 SURFA( CEMEN-RURD T Rig up cementer&condition mud 300 gpm,400 psi. 15:30 15:45 0.25 3,575 3,575 SURFA( CEMEN"RURD T SLB pump 3 bbls H2O, psi test cement lines 400&2500 psi. 15:45 16:30 0.75 3,575 3,575 SURFA( CEMEN"CMNT T SLB Batch up&pump 13.4 bbls of 10.5 ppg MudPush, 18.7 bbls of 15.8 cement,&3 bbls of 10.5 MudPush to clear lines. Swap to Rig pumps and chase with 47 bbls of 9.7 ppg mud. 16:30 17:15 0.75 3,575 3,000 SURFA( CEMEN-TRIP T POOH from 3575'-3000'MD, running speed 3 min per stand. 17:15 17:30 0.25 3,000 3,000 SURFA( CEMEN-CIRC T Circulate pipe volume at 250 gpm, 130 psi. 17:30 17:45 0.25 3,000 3,000 SURFA( CEMEN-RURD T Rig up head pin,valves,&cement line for squeeze job. 17:45 19:30 1.75 3,000 3,000 SURFA( CEMEN SQEZ T Pressure up well bore to 500 psi& shut in. Bring psi back up from 250 to 500 psi&shut in several times. Confer with town and decide to psi up to 600 psi and shut in for 10 min, pressuring back up every 10 min. This was repeated till cement thickening time reached a 70 Bc.6 bbls of cement squeezed away, 1/2 barrel bled back after pressure release. 19:30 20:30 1.00 3,000 3,000 SURFA( CEMEN-CIRC T CBU @ 500gpm, 500 psi, PU 80K, SO 68K 20:30 20:45 0.25 3,000 3,000 SURFA( CEMEN"OWFF T Monitor well,static. 20:45 22:15 1.50 3,000 970 SURFA( CEMEN-TRIP T POOH from 3000'-970'MD. 22:15 22:45 0.50 970 970 SURFA( CEMEN'RURD T Change out handling equipment from 5"to 3.5". Page 12 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 970 538 SURFA( CEMEN-PULD T Lay down 3.5"tubing from 970'-538' MD 36/05/2014 RIH with BHA 4.Tag TOC @ 3457'MD&cleaned out cement to 3575'MD. Perform FITto EMW 14.7 ppg. Drill 20'of new hole and perform LOT to EMW 14.3 ppg. Drill ahead from 3595-4517'MD. 00:00 00:30 0.50 538 0 SURFA( CEMEN'PULD T Lay down 3.5"tubing from 538'- surface. 00:30 01:30 1.00 0 0 SURFA( CEMEN-RURD T Rig down tubing handling equipment, clear&clean rig floor. 01:30 02:00 0.50 0 0 SURFA( CEMEN'EQRP T Change out SLB psi sensor on gooseneck of standpipe. 02:00 03:00 1.00 0 724 SURFA( CEMEN-PULD T Make up bit&down load MWD. Pick up stab&RIH with remaining BHA, as per SLB Rep. 03:00 03:15 0.25 724 724 SURFA( CEMEN'DHEQ T Shallow pluse test MWD,450 gpm, 925 psi, FO 55%, as per SLB Rep. 03:15 04:00 0.75 724 3,127 SURFA( CEMEN'TRIP T RIH from 724'-3127' MD, fill pipe evey 20 stands. Calculated displacement 37.71, actual 33.6 bbls. 04:00 04:30 0.50 3,127 3,127 SURFA( CEMEN'WOC T Wait on cement to reach 500 psi compressive strength. 04:30 05:15 0.75 3,127 3,457 SURFA( CEMEN-WASH T Wash down from 3127'-3457'MD,2 bpm, 250 psi, FO 36%.Tagged TOC ©3457',set 10k down weight. 05:15 06:30 1.25 3,457 3,457 SURFA( CEMEN-CIRC T CBU,450 gpm, 1350 psi 40 rpm,Tq 6k. Slow pumps to 278 gpm, 550 psi to handle thick cement contaminated mud coming back. 06:30 07:45 1.25 3,457 3,575 SURFA( CEMEN-DRLG T Drill out cement plug from 3457'-3575'MD, 350-400 gpm, 775-975 psi, FO 80-85%,40 rpm,Tq 6K. 07:45 08:15 0.50 3,575 3,501 SURFA( CEMEN"CIRC T Circulate&condition @ 464 gpm, 1200 psi, FO 72%,40 rpm,Tq 6K. Rack back one stand. 08:15 08:30 0.25 3,501 3,501 SURFA( CEMEN'RURD T Rig up test equipment for FIT. 08:30 09:30 1.00 3,501 3,501 SURFA( CEMEN-FIT T Preform FIT to a EMW of 14.7 ppg. R/D test equipment. 09:30 10:00 0.50 3,501 3,595 SURFA( CEMEN DDRL T Make up stand&drill from 3575'-3595'MD, 550 gpm, 1650 psi, FO 77%,60 rpm,Tq 7K, PU 117K, SO 83K, ROT 90K. 10:00 10:30 0.50 3,595 3,595 SURFA( CEMEN CIRC T CBU @ 550 gpm, 1600 psi,40 rpm, Tq 6K. 10:30 11:30 1.00 3,595 3,595 SURFA( CEMEN'LOT T Perform LOT to a EMW of 14.3 ppg. 11:30 12:00 0.50 3,595 3,595 INTRM1 DRILL RURD T Rig down test equipment,blow down lines,&clear rig floor. 12:00 12:45 0.75 3,595 3,595 INTRM1 DRILL CIRC P Displace wellbore to a 9.6 ppg LSND mud system 500 gpm, 1000 psi. 12:45 18:00 5.25 3,595 4,051 INTRM1 DRILL DDRL P Directional drilling from 3595-4051' MD, 3175'TVD,ART=3.49,ADT 3.49,Jars 35.76, Bit 3.49, PU 115K, SO 91 K, ROT 105K,Tq on 6-10K,off 4-5K, ECD no info, FO 69%,WOB 10-12K, 130 rpm, 550 gpm, 129 spm, 1525 psi. Page 13 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 4,051 4,517 INTRM1 DRILL DDRL P Directional drilling from 4051'-4517' MD, 3441'TVD,ART=4.53,ADT 4.53,Jars 40.29, Bit 8.02, PU 117K, SO 93K, ROT 105K, Tq on 6-7K,off 4-5K, ECD 11.2, FO 70%,WOB 10-12K, 130 rpm,575 gpm, 135 spm, 1700 psi. 06/06/2014 Directional drilled from 4517'-6431'MD,4546'TVD. Observed a drilling break @ 6277'MD,4457'TVD,with 35 bbls loss. Shut down to monitor well. Observe well flowing, perform wellbore breathing test.30 bbls returns with flow decreasing to nothing. Observe wellbore breathing on connections, verify flow steadily decreases. 00:00 06:00 6.00 4,517 5,165 INTRM1 DRILL DDRL P Directional drilling from 4517'MD to 5165'MD, 3815'TVD,ART=4.03, ADT 4.03,Jars 44.32, Bit Hrs 12.05, PU 122K, SO 104K, ROT 113K,Tq on 7-8 K,off 2-3 K, ECD 11.73, FO 72%,WOB 10-15K, 140 rpm, 590 gpm, 138 spm, 2020 psi. 06:00 12:00 6.00 5,165 5,592 INTRM1 DRILL DDRL P Directional drilling from 5165'MD to 5592'MD,4061'TVD,ART=3.42, ADT 3.42,Jars 47.74, Bit Hrs 15.47, PU 134K, SO 115K, ROT 118K,Tq on 5-6 K, off 2-3 K, ECD 11.78, FO 70%,WOB 10-15K, 140 rpm, 594 gpm, 138 spm,2125 psi. SPR's 5535' MD,4028'TVD, MW=10.0 ppg, 11:15hrs #1 @ 30=300, @40=370 psi #2 @ 30=300, @40=390 psi 12:00 20:00 8.00 5,592 6,279 INTRM1 DRILL DDRL P Directional drilling from 5592' MD to 6279'MD,4351'TVD,ART=5.54, ADT 5.54,Jars 51.68, Bit Hrs 19.41, PU 135K,SO 114K, ROT 122K,Tq on 5-9 K,off 2-4 K, ECD 11.99, FO 70%,WOB 10-15K, 130 rpm, 595 gpm, 139 spm, 2250 psi. SPR's 5999'MD,4296'TVD, MW 10.0ppg, 17:00hrs #1 @ 30=280, @ 40=370 psi #2@ 30=290, @ 40=350 psi 20:00 21:15 1.25 6,279 6,279 INTRM1 DRILL OWFF T Observed a drilling break @ 6277' MD,4457'TVD,35 bbl loss,&pump psi decrease. Shut down to monitor well. Observe well flowing, perform wellbore breathing test. 30 bbls returns with flow decreasing to nothing. Decision made to drill ahead and monitor gains&losses very closely. 21:15 00:00 2.75 6,279 6,431 INTRM1 DRILL DDRL P Directional drilling from 6279' MD to 6431' MD,4546'TVD,ART=4.8,ADT 4.8,Jars 54.89, Bit Hrs 22.62, PU 131K, SO 112K, ROT 121K,Tq on 6-9 K,off 3-4 K, ECD 11.71, FO 70%,WOB 10-15K, 130 rpm, 590 gpm, 138 spm,2300 psi. Observe wellbore breathing on connections, verify flow steadily decreases. Page 14 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/07/2014 24 hr Summary Directional drilled ahead from 6431'-6833'. Observed increasing trend with losses. Pump LCM pill&continue to drill ahead with reduced pump rate to manage losses from 6833'-7800'MD, 5328'TVD. 00:00 04:45 4.75 6,431 6,833 INTRM1 DRILL DDRL P Directional drilling from 6431'MD, 4546'TVD to 6833'MD,4692 TVD., ART=3.4,ADT 3.4, Jars 58.3, Bit Hrs 26.03, PU 140K, SO 115K, ROT 125K,Tq on 6-8 K,off 5K, ECD 12.01, FO 60%,WOB 10-15K, 130 rpm,590 gpm, 138 spm,2400 psi. 04:45 06:30 1.75 6,833 6,833 INTRMI DRILL CIRC T Circ. Obtain loss rate. 550GPM, 2100PSI, Losses=80 bbl/hr.Mix LCM Pill 06:30 07:45 1.25 6,833 6,833 INTRM1 DRILL CIRC T Pump and spot 67.5 bbl. LCM pill. 5 bpm @ 500 psi. for 1400 stks. Stage up pump to 590 gpm/2500 psi. Loss rate @80 bbl/hr, reduce pump rate to 500gpm/1850 psi.Circ. out LCM pill. 07:45 12:00 4.25 6,833 7,083 INTRM1 DRILL DDRL P Directional drilling from 6833'MD, 4692 TVD to 7083 MD,4923'TVD., ART=3,ADT 3,Jars 61.3, Bit Hrs 29.03, PU 141K, SO 116K, ROT 130K,Tq on 9 K, off 5K, ECD 11.42, FO 49%,WOB 5-10K, 120 rpm, 525 gpm, 122 spm,2000 psi. Average loss rate 14 bbls/hr after LCM pill. SPR@6923'MD,4831'TVD. MW=10.1, 0900 hrs. #1 @ 30 spm=290 psi.40 spm+360 psi #2 @ 30 spm=290 psi.40 spm=390 psi Mud losses for tour=294 bbls 12:00 18:00 6.00 7,083 7,482 INTRMI DRILL DDRL P Directional drilling from 7083' MD to 7482 MD, 5153'ND.,ART=4.29, ADT 4.29,Jars 65.59, Bit Hrs 33.32, PU 151K, SO 124K, ROT 134K,Tq on 7-9 K, off 5-6K, ECD 11.16, FO 65%,WOB 4-9K, 120 rpm,525 gpm, 122 spm,2025 psi. Monitor breathing every 200'on trip tank for 15 min. Strap every 5 min to ensure flow back is decreasing, measured loss rate in 5 min increments 10 bph to 3 bph in 15 minutes. Page 15 of 34 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 7,482 7,800 INTRM1 DRILL DDRL P Directional drilling from 7482'MD to 7800'MD, 5328'TVD.,ADT 3.25, Jars 68.84, Bit Hrs 36.57, PU 153K, SO 127K, ROT 139K,Tq on 9-10 K, off 5-6K, ECD 11.23, FO 65%,WOB 4-7K, 120 rpm, 525 gpm, 122 spm, 2000 psi. Monitor breathing every 200'on trip tank for 15 min. Strap every 5 min to ensure flow back is decreasing, measured loss rate in 5 min increments 14 bph to 2 bph in 15 minutes. SPR's @ 7760'MD, 5313'TVD, MW 10 ppg,23:00hrs #1 @30=310@40=390 psi #2 @ 30=300 @ 40=390 psi 06/08/2014 Directionally drilled from 7800'to the casing drilling point at 9151'MD, 5951'TVD. Observed a increase in connection gas,decision made to increase MW to 10.4 ppg for trip margin. Pumped a sweep&CBU 3X. Sweep returned to surface at calculated strokes indicating gauged hole. 00:00 06:00 6.00 7,800 8,224 INTRM1 DRILL DDRL P Directional drilling from 7800'MD to 8224'md,5581'TVD.,ADT 4.93,Jars 73.57, Bit Hrs 41.3, PU 161K,SO 129K, ROT 144K,Tq on 9-10 K, off 5-6K, ECD 11.35, FO 50%,WOB 5-15K, 120 rpm,525 gpm, 123 spm, 2130 psi. Max gas 102 units 06:00 12:00 6.00 8,224 8,543 INTRM1 DRILL DDRL P Directional drilling from 8224'md to 8543',5756'TVD.,ADT 3.70,Jars 77.27, Bit Hrs 45.0, PU 161K, SO 131K, ROT 145K,Tq on 10-11 K,off 6K, ECD 11.49, FO 52%,WOB 5-10K, 120 rpm, 550 gpm, 129 spm, 2300 psi. Max gas 162 units SPR's @ 8406'MD, 5686'TVD, MW 10.1 ppg,09:30 hrs #1 @ 30=320 @ 40=400 psi #2@30=320@40=390 psi Kick w/Drilling drill @08:00 hrs. CRT=120 sec. 12:00 18:00 6.00 8,543 8,965 INTRM1 DRILL DDRL P Directional drilling from 8543'-8965' MD, 5902'TVD.,ADT 4.6, Jars 81.87, Bit Hrs 49.6, PU 163K, SO 134K, ROT 147K,Tq on 10-11 K, off 6-7K, ECD 11.63, FO 61%,WOB 6-10K, 120 rpm,550 gpm, 129 spm, 2200 psi. Max gas 199 units SPR's @ 8962'MD, 5901'ND, MW 10.1 ppg, 18:00 hrs #1 @30=370@40=470 psi #2@30=370@40=470 psi Page 16 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:15 3.25 8,965 9,151 INTRM1 DRILL DDRL P Directional drilling from 8965'md to 9151',5951'TVD.,ADT 2.15,Jars 84.02, Bit Hrs 51.75, PU 164K,SO 134K, ROT 147K,Tq on 10-13 K,off 6-7K, ECD 11.75, FO 64%,WOB 5-10K, 120 rpm,550 gpm, 129 spm, 2300 psi. Max gas 276 units 21:15 00:00 2.75 9,151 9,151 INTRM1 DRILL CIRC P Weight up mud from 10.1 -10.4 ppg. Pump high vis weighted sweep w/nut plug. Sweep returned on calculated strokes to show hole in guage. CBU 3X @ 550 gpm, 2250 psi, 120 rpm, Tq 7k, FO 51%, PU 164K, SO 135K, ROT 148K. Rack back 1 stand when 10.4 ppg went surface to surface. SPR's @ 9151'MD,5951'TVD, MW 10.4 ppg,23:00 hrs #1 @30=370@40=480 psi #2 @ 30=380 @ 40=480 psi 06/09/2014 BROOH to shoe. Circulate hole clean at the shoe.Slip&cut drill line. POOH on elevators&lay down BHA. Pull wear bushing&function test BOPE. Flush stack, recover large portion of 10.75"top plug. Perform dummy run with 7"hanger. 00:00 01:15 1.25 8,966 8,966 INTRM1 CSGDRI OWFF P Observe well @8966'MD.Well static after total of 3 bbls.flowed back 01:15 01:45 0.50 8,966 8,966 INTRM1 CSGDRI OWFF P Observe well.Static 01:45 04:30 2.75 8,966 8,227 INTRM1 CSGDRI REAM P PJSM-BROOH 8,966'MD to 8227' MD. 525 gpm,2150 psi, 120 rpm, 8K TQ. PU 165K, SO 130K, Rot 147K 04:30 05:30 1.00 8,227 8,227 INTRM1 CSGDRI CIRC P CBU @ 8,227 MD to lower ECD's and background gas. Rotate and reciprocate. 525 gpm,2100psi, 120 rpm, TQ 7K 05:30 10:00 4.50 8,227 5,262 INTRM1 CSGDRI REAM P BROOH 8227'MD to 5262'MD.525 gpm,2150 psi, 120 rpm,7K TQ. ECD @ 5262' MD=11.90 ppg. 10:00 10:45 0.75 5,262 5,262 INTRM1 CSGDRI CIRC P CBU @ 5,262 MD.to lower ECD's.. Rotate and reciprocate. 500 gpm, 1700psi, 100 rpm,TQ 4K. Reduced ECD to 11.66 ppg. 10:45 12:00 1.25 5,262 4,891 INTRM1 CSGDRI REAM P BROOH 5262'MD to 4891 MD. 525 gpm,1700 psi, 120 rpm,4K TQ. ECD =11.65 ppg.Actual disp=74 bbls. Cal.disp=30 bbl's 12:00 14:15 2.25 4,891 3,500 INTRM1 CSGDRI REAM P PJSM. BROOH 4891 MD to 3500' MD. 525 gpm,1700 psi, 120 rpm,4K TQ. . 14:15 15:45 1.50 3,500 3,500 INTRM1 CSGDRI CIRC P Circulate hole clean @ 525 gpm, 1600 psi. Condition mud from 10.7 ppg to 10.4+ppg at shoe. 15:45 16:45 1.00 3,500 3,500 INTRM1 CSGDRI SLPC P Slip&cut 84'drill line.(Monitor well on trip tank, 1.75 bbl increase in 5 min, .25 bbl increase in 45 minutes. Well static after 1 hr. 16:45 17:15 0.50 3,500 3,500 INTRM1 CSGDRI SVRG P Service top drive. Page 17 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 19:30 2.25 3,500 724 INTRM1 CSGDRI TRIP P POOH on elevators from 3500'-724' MD,calculated displacement 38.19, actual 56 bbls. Kick w/Tripping CRT=67sec @ 19:00 hrs 19:30 19:45 0.25 724 724 INTRM1 CSGDRI OWFF P Monitor well, flowed back.25 bbls, static after 5 min. 19:45 20:15 0.50 724 170 INTRM1 CSGDRI TRIP P Rack back HWDP. 20:15 22:00 1.75 170 0 INTRM1 CSGDRI PULD P Lay down BHA 4, as per SLB DD. 22:00 22:15 0.25 0 0 INTRM1 CSGDRI RURD P Clean and clear rig floor. 22:15 22:30 0.25 0 0 INTRM1 CSGDRI BOPE P Function test rams&annular. Pull wear bushing. 22:30 23:30 1.00 0 0 INTRM1 CSGDRI RURD P Rig up, flush stack, &rig down. 23:30 00:00 0.50 0 0 INTRM1 CSGDRI RURD P Rig up landing joint and hanger. Perform dummy run with 7" intermediate hanger. 36/10/2014 Change upper rams to 7",test upper rams and annular. R/U Tesco CDS and calibrate. P/U Bit,float equipment and 7"26#L-80 TN Blue casing drilling string, RIH to 5091'MD. 00:00 02:00 2.00 0 0 INTRM1 CASING NUND P PJSM-Change upper pipe rams to 7" 02:00 04:45 2.75 0 0 INTRMI CASING BOPE P PJSM-R/U and test upper pipe rams, 250/3500 psi.Test annular to 250/2500 psi.. Chart test. Sim-ops Tesco Rep rig up torque turn equip. Rig down test equip. 04:45 08:30 3.75 0 0 INTRM1 CASING RURD P PJSM-Rig up Tesco CDS. 08:30 09:00 0.50 0 0 INTRM1 CASING PUTB P Calibrate torque turn, M/U bit and wearsox centralizer joint. 09:00 10:30 1.50 0 48 INTRMI CASING RNCS T Torque turn graph showed indication of improper makeup.Recalibrate torque turn. Galled collar on bit jt. and pin on wearsox jt. 10:30 12:00 1.50 48 90 INTRM1 CASING RNCS T Lay dn.wearsox jt. Change out collar on bit joint. Used the good box from joint#2 to replace the bad box on joint#1. Picked up a new single wearsox joint#2 and made it up to the original 3 wearsox joint#1. 12:00 14:00 2.00 90 1,718 INTRM1 CASING RNCS P PJSM, M/U shoe track joints, RIH with 7"26#L-80 TN Blue casing to jt 40 @1718'MD. 14:00 16:45 2.75 1,718 1,718 INTRM1 CASING CIRC P Circulate surface to surface volume 150 bbl @ 200 gpm, 300 psi. P/U=69k, S/0=68k,flow out 40%no losses. 16:45 20:30 3.75 1,718 3,500 INTRM1 CASING RNCS P Continue RIH with 26#TN Blue casing from 1718'MD to 3500'MD. Ran total 48 Hydroform centralizers on joints#3-50. 20:30 22:30 2.00 3,500 3,500 INTRM1 CASING CIRC P Circulate surface to surface volume 300 bbl, ICP @ 3 bpm=200 psi, staged up to 300 gpm,550 psi Flow out=41%. P/U=91 k, S/0=84k.. Page 18 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 3,500 5,091 INTRM1 CASING RNCS P Continue RIH from 3500'MD to 5091' MD. P/U=120k, S/0=100k. Fill pipe every joint,top off every 10 joints. Calc Disp=47.76 bbl,Actual Disp=46.44 bbl. 06/11/2014 RIH with 7"26#TN Blue/Hydril 563 string to 9151'MD. Displace to new 11.0 ppg mud and perform LOT to 12.0 ppg(Well breathing).Begin casing drilling from 9151'MD to 9187'MD, losses @ 20 bph. 00:00 01:15 1.25 5,091 5,175 INTRM1 CASING CIRC P Continue RIH from 5091'MD to 5175'.MD Brk. circ. Stage pump up to 300 gpm. Circ.surface to surface.Lost 20 bbl's w/circ. Gain back 20 bbl.s after shutting down pump. 01:15 04:45 3.50 5,175 6,839 INTRMI CASING RNCS P Continue RIH w/7"csg.from 5175' MD to 6839' MD. 04:45 07:15 2.50 6,839 6,839 INTRM1 CASING CIRC P Brk.circ. Stage pump up to 300 gpm. Circ.surface to surface.Lost 38 bbl's w/circ. Gain back 10 bbl.s after shutting down pump. 07:15 10:45 3.50 6,839 8,358 INTRM1 CASING RNCS P Continue RIH w/7"csg. from 6839' MD to 8358'MD. 200 jt's in hole. P/U=185K, S/0=120K.Actual Disp.=66 bbls. Calculated Disp=79 bbls. 10:45 13:30 2.75 8,358 8,358 INTRM1 CASING CIRC P Establish circulation, stage pump up to 300 gpm. 1000 psi. Circ.surface to surface. P/U=170K. S/0=120K. Total losses for tour=25 bbls. 13:30 13:45 0.25 8,358 8,490 INTRMI CASING RNCS P Continue to RIH with 7"casing from 8358'MD to 8490' MD. Hit tight spot. 13:45 14:45 1.00 8,490 8,520 INTRM1 CASING REAM T Work thru tight spot @ 8490' MD, took 15k down wt.Worked pipe several times, Rotate 15 rpm,pump 2 bpm,stage up to 3.5 bpm,work pipe down to 8520", regained good circulation. 14:45 17:30 2.75 8,520 9,151 INTRM1 CASING RNCS P Continue RIH from 8520'MD,wash down last jt to 9151'MD pumping 2 bpm,tagged bottom and set down 5k. P/U=195k, S/O=129k. 17:30 18:45 1.25 9,151 9,151 INTRM1 CSGDRI CIRC P Establish circulation @ 2 bpm,425 psi.Stage up to 7 bpm, 300 gpm=1250 psi. Circulate 1 bottoms up, initial condition for mud displacement. 18:45 20:45 2.00 9,151 9,151 INTRM1 CSGDRI CIRC P PJSM,displace well to 11.0 ppg P-vis mud with Torque seal additive for casing drilling. Displace @ 300 gpm, 1250 psi ICP, FCP=1000 psi. Rotate 20 rpm, reciprocate 20'after new mud reached 6200'MD in annulus. Optain SPR's @ 20:40, 11.0 ppg,9148'MD, 5951'TVD. #1-10 spm=140 psi,20 spm=220 psi #2-10 spm=160 psi,20 spm=260 psi Page 19 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:00 1.25 9,151 9,151 INTRM1 CSGDRI LOT P PJSM, lay down jt 219, R/U and perform LOT. Pumped total 15 bbl, pressured up to 175 psi and flatlined. Monitored SIP, bled down to 120 psi and flatlined. Bled back 8.7 bbl. Calculated 12.0 ppg EMW LOT. Discuss results with drilling engineer. 22:00 22:15 0.25 9,151 9,151 INTRM1 CSGDRI RURD P R/D test equipment. 22:15 00:00 1.75 9,151 9,187 INTRM1 CSGDRI DCSG P Casing drill from 9151'MD to 9187' MD,5960'TVD. Bit hrs=1.75, P/U=185k, 5/O=127k, ROT=152k, Tq on/off=15/13k, 37% Flow out, 5-20 WOB,80 rpm, 300 gpm @ 700 psi, Max gas=27. Losses stable at 20 bph,total losses for tour 32.5 bbl. 36/12/2014 Casing drill to 9257'MD,5980'TVD.Stop drilling due to complete lost circulation while weighting up to 12.5 ppg.Wait on mud, build LCM pills and pump 120 bbl LCM pill,followed by active with 15 ppb. Losses temporarily improved. Re-building pills. 00:00 03:30 3.50 9,187 9,257 INTRM1 CSGDRI DCSG P Casing drill from 9187'MD,5960' TVD to 9257'MD, 5980'TVD.. Bit hrs=2.86, P/U=185k, S/0=130k, ROT=185k,Tq on/off=12-15/14k, 34%Flow out, 8-18 WOB,80 rpm, 300 gpm @ 500 psi, Max gas=78 units. 03:30 12:00 8.50 9,257 9,241 INTRM1 CSGDRI COND T Stop drilling due to total loss of returns to surface while weighting up mud to 12.5 ppg. Pull off bottom and reduce pump rate to.5 bpm, 100 psi. Stop rotating. P/U=185K 5/O=125K. Loss rate at 50-60 bph. Shut down mud pump and fill hole with trip tank. Losses at 40 bph. UD 1 jt.7"casing to 9,241 MD.Work string at 100 FPH w/5 RPM,TQ=13K Ordered mud from mud plant while building mud in pits. ROT P/U 156K, ROT S/O 150K. Losses decreasing to 20bph with no pump. Total losses for tour=940 bbls. 12:00 16:00 4.00 9,241 9,241 INTRM1 CSGDRI COND T PJSM, Building 100 bbl mud volume in pit 6, Mixing LCM, monitor losses via trip tank to keep annulus full. Reciprocate pipe @ 100 fph, rotate @ 10 rpm.Tq=12-13k, P/U=156k, S/O=149k, ROT=154k. Static losses @ 18 bph. 16:00 19:15 3.25 9,241 9,241 INTRM1 CSGDRI COND T Offload 12.5 ppg mud into pits,dilute back to 11.5 ppg.Top off pits, build 20 ppb Torque seal pill in pill pit. Build 100 ppb Mixed LCM(100 ppb total)pill in pit 5.Add treatment of 5 ppb Torque Seal,5 ppb G-Seal and 3 ppb SafeCarb to pit 6 for chase fluid. Page 20 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 22:00 2.75 9,241 9,241 INTRM1 CSGDRI CIRC T Pump 20 bbl LCM pill from pill pit, followed by 100 bbl 100 ppb pill from pit 5, chase with pit 6 11.5 ppg mud. Pump pills down at 1 bpm, 125 psi 65%loss, stage up to 2.5 bpm 70% loss, 3 bpm 95%loss, reduce rate to 2.5 bpm to place pills. 22:00 23:00 1.00 9,241 9,241 INTRM1 CSGDRI CIRC T Pump pills to bit and up to 4000 stks at 2.5 bpm,65%losses while pumping.At 4000 stks, increase rotation to 80 rpm,flow rate to 200 gpm. Initially 95%losses, pumped to 5700 strokes then backed off rate to 3 bpm. Losses at 65%or 120 bph at 3 bpm,slightly improved from 95% losses pre LCM and reducing mud weight to 11.5 ppg. Mud weight in/out 11.5 ppg. Could not notice any remarkable increase in flow out while pumping. 23:00 23:30 0.50 9,241 9,198 INTRM1 CSGDRI CIRC T Confer with enginner, Shut down pumps and lay down joint#221 to move circulation point. 23:30 00:00 0.50 9,198 9,198 INTRM1 CSGDRICIRC T Continue circulation 1 bpm-100 psi while mixing more LCM.Total losses for today=1233 bbl 06/13/2014 Keep casing moving while building high concentration 120 ppb LCM pill, adding 40 ppb LCM to all surface volume. Cut mud weight on surface volume from 11.5 ppg to 10.5 ppg. Begin pumping LCM down hole @ 1 bpm. 00:00 02:00 2.00 9,198 9,198 INTRM1 CSGDRICIRC T Continue circulation @ 1 bpm-100 psi w/no returns at surface. Mixing 50 ppb LCM into active pits. Losses a 02:00 06:00 4.00 9,198 9,198 INTRM1 CSGDRI COND T Shut down pump, reduce rotary to 5 RPM,work string. Fill hole with trip tank, losses at 24 bph. Reduce mud weight in active pit to 11.2 ppg. 06:00 07:30 1.50 9,198 9,198 INTRM1 CSGDRI CIRC T Continue to reduce mud weight to 11.0 ppg. Reciprocate pipe at 9,198 MD. P/U=165K, S/0=150K.Attempt to regain circulation twice pumping at 2 bpm, 150 psi. No returns to surface, Keep hole full with trip tank. 20 bph losses. 07:30 10:30 3.00 9,198 9,198 INTRM1 CSGDRI CIRC T Attempt to break circulation @ 1bpm.No returns to surface. Pumped total of 30bbls. P/U=160K, 5/O=145K. Shut down pump. 10:30 12:00 1.50 9,198 9,198 INTRM1 CASING COND T Decision made to reduce mud weight to 10.5 ppg and establish circulation for cement job. Page 21 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 22:00 10.00 9,198 9,198 INTRM1 CASING COND T PJSM,continue to reduce all mud in pits and vacuum trucks to 10.4-10.5 ppg.Adjust additives in Mega Pill-120 ppb, 100 bbl in pit 5. Pit 6 has 400 bbl at 45 ppb total LCM and 10.4+ppg.(SIMOPS unload pipeshed of 7"casing, bring cement head to rig floor) 22:00 00:00 2.00 9,198 9,198 INTRM1 CASING CIRC T Pump 110 bbl Mega Pill 100 ppb LCM from pit 5 @ 1 bpm, 110 psi ICP. FCP @ midnite 210 psi, 5 rpm 14k Tq,80%losses @ 1 bpm. (SIMOPS load pipe shed with 4"drill pipe) Total losses for the day 540 bbl 36/14/2014 Circulate 10.4 ppg LCM laden mud to regain circulation. Reduce mud weight to 10.4 ppg and regain circulation.Cement 7"casing @ 9247.72'MD. Set and test 7"packoff. Rig down casing equip, R/U to lay down drill pipe. 00:00 07:00 7.00 9,198 9,198 INTRM1 CASING CIRC T PJSM-Chase Mega Pill w/10.5 ppg, mud. Remove trip tank from active system and take returns to pit#5. Monitor returns and increase pump rate to 1.5 bpm,290 psi, 15 rpm, 13-14K tq.Slight returns observed at surface.90%losses @ 1.5 bpm. Stage pump rate to 2 bpm,490 psi. Losses at 76%. Increase pump rate to 2.5 bpm. 300 psi. Losses steadily reduced to<10%as 10.4 ppg mud made it around. LCM had little effect. 07:00 08:30 1.50 9,198 9,198 INTRM1 CASING CIRC T Continue to circ.and cond. mud @9,198 MD.2.5 bpm,300 psi, 15 rpm, 12-14K tq. Could not heal losses,decision to cement 7"casing @ 9274'MD. 08:30 09:15 0.75 9,198 9,247 INTRM1 CEMEN-CIRCP PJSM-M/U 20'pup jt„ hanger and landing jt. Break circ.Wash down to 9,247 MD. Monitor well while making up hanger. Gained 1 bbl. 09:15 10:30 1.25 9,247 9,247 INTRM1 CEMEN-CIRCP Continue to circulate @ 2.5 bbls,300 psi.Stage up to 4.5 bpm w/full returns.,375 psi. Rig down Tesco bails. 10:30 12:15 1.75 9,247 9,247 INTRM1 CEMEN-RURD P PJSM-Rig down Tesco CDS. R/U long bails, 350T elevators. Ran total of 171 jts. Tenaris Blue,49 jts Hydril 563., lx 20'Hydril 563 pup jt., and hanger. 12:15 14:30 2.25 9,247 9,247 INTRM1 CEMEN-CIRCP Establish circulation @ 1 bpm,stage up to 4.5 bpm 200-450 psi, 36% Flow out @ 4.5 bpm. Obtain SPR's, SIMOPS PJSM on cementing 7" casing. Page 22 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:45 2.25 9,247 0 INTRM1 CEMEN-CMNT P Pump cement job per program, SLB pumped 60 bbl 12.5 ppg MudPushll, 60 bbl 15.8 ppg Class G Tail Cement,followed by 10 bbl water, displace with 342 bbl 10.4 ppg mud with rig. Bump plugs @ 3378 stks, CIP @ 16:28 hrs. FCP=850 psi, held 1350 psi on floats for 5 min and released,floats held. Minimal flow from annulus after shut down, monitor with trip tank until stopped. Lost 22 bbl mud during cement job. Float shoe @ 9247.72'MD,5976.97' TVD. Double valve float collar @ 9154.8'MD. 16:45 18:15 1.50 0 0 INTRM1 CEMEN-RURDP Rig down cementing equipment, rig down long bails and elevators, remove from floor. 18:15 19:00 0.75 0 0 INTRM1 CEMEN"WWSP P R/U packoff running tool,set packoff, RILDS,torque and remove running tools. 19:00 19:30 0.50 0 0 INTRM1 CEMEN-PRTS P Test packoff to 250/5000 psi, 10 minutes each witnessed by Co Rep. 19:30 21:45 2.25 0 0 INTRMI CEMEN-RURD P PJSM,C/O 4'/2 IF"saver sub to 4" XT39,space out grabbers, C/O grabber dies and bell guide. 21:45 23:15 1.50 0 0 INTRM1 CEMEN-RURD P PJSM,change out upper 7"rams to 3'/z'X 6"VBR's. 23:15 00:00 0.75 0 0 INTRM1 CEMEN'RURD P R/U Short bails and 5"elevators, get tools and equipment ready to L/D 5" DP. SIMOPS-R/U OA for annular flush and FP. 06/15/2014 Perform annular flush and Isotherm freeze protection on 10%"x 7"annulus. Lay down 5"DP.Test BOPE with 3%",4"and 4'/2'test jts to 250/3500 psi.Annular to 250/2500. P/U 4"drill pipe and stand back 15 stands. 00:00 00:45 0.75 0 0 INTRM1 CEMEN-PULD P PJSM-L/D 5" DP, 6 stands of 5" HWDP 00:45 03:00 2.25 0 0 INTRM1 CEMEN-FRZP P PJSM-R/U and flush 10 %"x7"annulus w/190 bbls H2O. Initial injection rate 1/2 bpm=100 psi. Stage pump up to 4 bpm. Final injection pressure=830 psi. Shut in pressure=600 psi. R/D lines. 03:00 06:00 3.00 0 0 INTRM1 CEMEN-PULD P L/D 5' DP 06:00 06:45 0.75 0 0 INTRMI CEMEN-PULD P Unload pipeshed 06:45 10:30 3.75 0 0 INTRM1 CEMEN PULD P Continue to L/D drill pipe. Sim-Ops, PJSM. Spot Little Red,test lines to 2500 psi. Pump 121 bbls of Isotherm NT down OA. Initial rate-1 bpm=500 psi. Final injection rate= 1.5 bpm @ 905 psi. SIP=690 psi. L/D mouse hole, Clear rig floor. 10:30 12:00 1.50 0 0 INTRM1 CEMEN-OTHR P Level rig due to pad settling. 12:00 13:45 1.75 0 0 INTRM1 WHDBO RURD P PJSM-Bring tools to rig floor and rig up to test BOPE Page 23 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 17:45 4.00 0 0 INTRM1 WHDBO BOPE P PJSM-Test BOPE w/4"test jt.Test #1 Upper VBR's,valves 1,12,13,14, manual kill valve,Test#2 upper IBOP, HCR kill,valves 9,11.Test#3 Lower IBOP,valves 5,8,10.Test#4 Dart valve,valves 4,6,7.Test#5 Floor valve,and valve#2.Test#6 HCR choke,4"Demco kill line valve. Test #7 Manual choke, HCR kill.Test#8 annular preventer.Test#9 Lower VBR's. 17:45 19:45 2.00 0 0 INTRM1 WHDBO BOPE P Change testjt. out to 4 1/2". Test #10 Upper VBR's,Test#11 Lower VBR's.Test#12 Annular preventer. Change testjt.to 3 1/2". Test#13 Upper VBR'sa.Test#14 Lower VBR's.Test#16 Annular preventer. Test#16 Blind rams.All tests 250 psi low, 3500 psi high,test annular to 2500 psi high for 5 min's each 19:45 20:15 0.50 0 0 INTRM1 WHDBO BOPE P Accumulator test.System Pressure=2900 psi. Pressure after closed=1600 psi.200 psi attained=48 sec. Full Pressure attained=209 sec. Nitrogen bottles avg=2025 psi.Test witness waived by Johnnie Hill w/AOGCC on 6/15/14 @ 07:44 hrs. 20:15 21:00 0.75 0 0 INTRMI WHDBO BOPE P Rig down test equipment, blow down choke, kill and choke lines.set 6.938"wear bushing. 21:00 00:00 3.00 0 0 INTRM1 WHDBO RURD P PJSM, load 8 jts HWDP and jars in pipe shed,strap and process same. P/U BHA components from beaverslide. P/U and rack back 15 stds 4"DP. L/D mouse hole. Prep for P/U BHA. 06/16/2014 P/U BHA#6, P/U 4"DP and single in hole,perform casing test to 3000 psi 30 min. Drill out float equipment, cement, EZ case bit, rathole and 10'formation to 9267'MD. 00:00 01:15 1.25 0 106 INTRMI CEMEN'PULD P PJSM-M/U BHA to 106'MD 01:15 02:15 1.00 106 106 INTRMI CEMEN-PULD P PJSM-Load nuclear sources 02:15 02:45 0.50 106 200 INTRMI CEMEN-PULD P PJSM-Continue to make up BHA to 200'MD 02:45 03:45 1.00 200 200 INTRM1 CEMEN-SVRG P Service drawworks,top drive and iron roughneck. 03:45 04:30 0.75 200 478 INTRM1 CEMEN PULD P Continue to make up BHA to 478' MD 04:30 05:30 1.00 478 1,543 INTRM1 CEMEN-PULD P TIH. Picking up singles from pipe shed to 1543'MD 05:30 06:30 1.00 1,543 1,543 INTRM1 CEMEN-DHEQ P Perform shallow pulse test. @ 1543' MD.250 gpm,60 spm, 1500 psi. 06:30 12:00 5.50 1,543 7,288 INTRMI CEMEN"PULD P Continue TIH, picking up singles from pipe shed to 7288'MD. Fill pipe every 20 stands. OA pressure=250 psi Page 24 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 7,288 9,087 INTRM1 CEMEN-PULD P PJSM, Continue single in hole from 7822'MD to 9087'MD.Calc Disp=58.74 bbl,Actual Disp=60.95 bbl. P/U=140k, S/0=88k. 13:30 14:00 0.50 9,087 9,150 INTRM1 CEMEN'WASH P Wash and ream from 9087'MD to 9150'MD @ 200 gpm, 1800 psi,40 rpm, 5K Tq,34%Flow out.Cement at shakers. 14:00 16:00 2.00 9,150 9,150 INTRM1 CEMEN CIRC P Circulate and condition mud to even mud weight 10.4 ppg, 200 gpm, 1450 psi,50 rpm, 7k Tq,36%Flow out. 16:00 17:30 1.50 9,150 9,150 INTRM1 CEMEN PRTS P R/U and test casing to 3000 psi for 30 minutes charted,good test. Rig down test equipment. SPR's @ 19:00 hrs, 10.4 ppg 9146' MD/5950'TVD #1-20 spm=480 psi, 30 spm=670 psi #2-20 spm=500 psi, 30 spm=730 psi 17:30 00:00 6.50 9,150 9,267 INTRM1 CEMEN'DRLG P Drill cement and float equipment from 9150'MD to 9257'MD,formation to 9267'MD/5950'TVD.ART=.52, P/U=137k, S/0=87k, ROT=114k,Tq on/off=9/7k, Flow out=33%, WOB=10k 60 rpm,207 gpm @ 1700 psi. 36/17/2014 Drill to 9277'MD, 5986'TVD and perform 16.0 ppg FIT. Displace to 12.5 ppg LSND Mud, condition and commence drilling 6-1/8"tangent to 9662'MD @ 20-30 fph. Pyrite and siderite streaks. SIMOPS-Pull rig boilers for replacement and prep boiler room for new install. 00:00 01:00 1.00 9,267 9,277 INTRM1 CEMEN DRLG P Continue drilling 20' new formation to 9277'MD, 5986'TVD,230 gpm, 1900 psi, P/U=148k, S/0=90k, ROT=112k,Tq on/off=10/7k, ADT=.89, Bit Hrs=1.41,Jar Hrs=146.82. Noted slow ROP 10-20 fph when drilling formation. 01:00 02:00 1.00 9,277 9,274 INTRM1 CEMEN"CIRC P CBU @ 9274'MD to clean hole and get even mud weight 10.4 ppg in/out. 230 gpm 1900 psi, Rotate 30 rpm, Tq=9k. 02:00 03:30 1.50 9,274 9,240 INTRM1 CEMEN"FIT P PJSM, R/U test equipment and circulate additional pipe volume @ 230 gpm 1900 psi. Perform FIT to 16.0 ppg, 15 sec SIP 1625 psi. Held flat at 1600 psi after five minutes. 03:30 05:15 1.75 9,240 9,277 PROD1 DRILL CIRC P PJSM,displace well over to 12.5 ppg treated LSND @ 5 bpm, ICP 1900 psi, FCP 2600 psi. 05:15 09:00 3.75 9,277 9,277 PROD1 DRILL CIRC T Circulate and condition mud. Shakers screening out LCM and weight material after displacement. Changed shaker screens to 1 ea-84 'mesh on each shaker to keep Barite in the system. Circulate @ 4 bpm, 1700 psi, adding barite to obtain 12.5 ppg in/out prior to drilling ahead. Page 25 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 9,277 9,374 PROD1 DRILL DDRL P Drill from 9277'MD to 9347'MD, 6004'TVD.ADT=2.54, Bit Hrs=3.95, Jar Hrs=149.36, P/U=148k, S/0=90k, ROT=112k,Tq on/off=7/6k, ECD=14.55 ppg EMW, Flow out=38%,W0B=6-8, RPM=100,230 gpm @ 2700 psi. SPR's @ 9272'MD, 5984'TVD, 12.5 ppg,08:45 hrs. #1-20 spm=830 psi, 30 spm=1200 psi #2-20 spm=750 psi,30 spm= 1110 psi 12:00 18:00 6.00 9,374 9,556 PROD1 DRILL DDRL P Directional drill from 9347'MD to 9556'MD,6042'TVD.ART=5.04, Bit Hrs=8.99,Jar Hrs=154.4, P/U=127k, S/0=94k, ROT=105k,Tq on/off=7/5k, ECD=14.34 ppg EMW, Flow out=36%,W0B=8-15k, RPM=100,222 gpm @2650 psi, Max Gas=90 units. lntermittant hard streaks of pyrite and siderite slowing ROP. 18:00 00:00 6.00 9,556 9,662 PROD1 DRILL DDRL P Directional drill from 9347' MD to 9662' MD, 6092'TVD.ART=3.54, Bit Hrs=12.53,Jar Hrs=157.54, P/U=130k, S/O=94k, ROT=108k,Tq on/off=7/5k, ECD=14.43 ppg EMW, Flow out=37%,WOB=10-12k, RPM=100,225 gpm @2675 psi, Max Gas=452 units at botoms up after connection. Noted increased flow and gas at BU strokes. Flow check on connection-slight but steady flow. Begin slow weight up to 12.7 ppg. SPR's @ 9613'MD,6076'TVD, 12.5 ppg,21:00 hrs. #1-20 spm=640 psi,30 spm=970 psi #2-20 spm=630 psi, 30 spm=980 psi. 06/18/2014 Drill from 9662'MD to TD @ 10127'MD,6217'TVD.Weight up to 13.1 ppg trip margin. CBU x 2, OWFF. Pump out to shoe @ 2 bpm,2500 fpm. CBU @ shoe. Continue pump out of hole @ 2 bpm,2500 fph. Page 26 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 9,662 9,910 PROD1 DRILL DDRL P Directional drill from 9662' MD to 9910'MD, 6159'TVD.ART=10.59, Bit Hrs=23.12,Jar Hrs=168.53, P/U=128k, S/0=80k, ROT=106k,Tq on/off=8/6k, ECD=14.96 ppg EMW, Flow out=36%,WOB=6-13k, RPM=100-120,225 gpm @2900 psi, Max Gas=281 units at bottoms up after connection. SPR's @ 9727'MD,6110'TVD, 12.7 ppg,02:30 hrs. #1-20 spm=780 psi,30 spm=1040 psi #2-20 spm=740 psi,30 spm=1070 psi. SPR's @ 9830'MD,6137'TVD, 12.8 ppg,08:45 hrs. #1-20 spm=780 psi,30 spm=1080 psi #2-20 spm=740 psi,30 spm=1110 psi. 12:00 17:30 5.50 9,910 10,127 PROD1 DRILL DDRL P Directional drill from 9910'MD to 10127'MD,6217'TVD.ART=4.59, Bit Hrs=27.71,Jar Hrs=173.12, P/U=152k, S/0=93k, ROT=110k,Tq on/off=8/6k, ECD=15.37 ppg EMW, Flow out=37%,WOB=8-12k, RPM=100, 225 gpm @ 2800 psi, Max Gas=380 units at bottoms up after connection. SIMOPS-Weight up mud sytem to 13.1 ppg for trip margin. 17:30 17:45 0.25 10,127 10,127 PROD1 CASING SRVY P Obtain SPR's, Survey on bottom. SPR's @ 10127'MD,6217'TVD, 17:30hrs, 13.1 ppg. #1-20 spm=710 psi, 30 spm=1090 psi #2-20 spm=780 psi, 30 spm=1100 psi. 17:45 19:00 1.25 10,127 10,127 PROD1 CASING CIRC P Circulate hole clean @ drilling rate. 19:00 19:45 0.75 10,127 10,127 PROD1 CASING OWFF P Motitor well for flow. Slight trickle to static after 7 min, 30 min static. (SIMOPS-PJSM on pumping out of hole.) 19:45 21:30 1.75 10,127 9,182 PROD1 CASING TRIP P Pump out @ 2 bpm 700 psi, pulling 2500 fph to 9182'MD. Ream x 2 on stand#95, 9467'-9372'due 15k overpull and slight pressure increase. No problems after reaming 3.5 bpm 50 rpm. Calc Fi11=5.6 bbl,Actual Fill=11.16 bbl. 21:30 22:15 0.75 9,182 9,182 PROD1 CASING CIRC P CBU @ 9182'MD,225 gpm 2850 psi, 100 rpm, 6k Tq, 37%Flow out. 157 units gas on bottom up strokes. Page 27 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:45 0.50 9,182 9,182 PROD1 CASING OWFF P Monitor well @ shoe,static. 22:45 00:00 1.25 9,182 8,519 PROD1 CASING TRIP P Continue pumping out of hole from 9182'MD to 8519'MD @ 2500 fph,2 bpm 650 psi. Drop 2.25"hollow rabbit with 100'wire on stand#90. (8514' DP length). P/U=130k, S/0=93k, Calc Fill=2.8 bbl,Actual Fill=4.54 bbl. 06/19/2014 Pump out to 2500'MD, POOH with BHA#6 and L/D. Pick up 4'/2'liner sting and RIH to 9300'MD.Circulating as needed to even out mud weight due to barite sag. 13.1 ppg in/12.6 ppg out. 00:00 09:00 9.00 8,519 2,560 PROD1 CASING TRIP P Continue pumping out of the hole f/ 8519'MD to 2560' MD. Increased pump rate f/2 bpm=600 psi to 4 bpm= 1300 psi due to dynamic barite sag.Actual displacement= 46.3 bbls, Calculated displacement= 39.2 bbls. 09:00 09:15 0.25 2,560 2,560 PROD1 CASING OWFF P OWFF,static. 09:15 11:15 2.00 2,560 478 PROD1 CASING TRIP P POOH on elevators @ 2500 fph to 478'MD.Actual displacement=11.9 bbls, Calculated displacement= 11.8 bbls. 11:15 12:00 0.75 478 478 PROD1 CASING PULD P OWFF, P/U SLB tools to rig floor, prep to L/D Nuke tools. 12:00 13:45 1.75 478 0 PROD1 CASING PULD P PJSM, rack back 3 stds HWDP, LID 3 jts flex collars, unload nuclear sources. Break bit, L/D remaining BHA. 13:45 14:45 1.00 0 0 PROD1 CASING RURD P Clean and clear rig floor, L/D tools, P/U casing equipment. 14:45 15:30 0.75 0 0 COMPZ CASING RURD P PJSM, Rig up casing equipment. SIMOPS-install hydroform centralizers with bottom stop collar per running detail in the pipe shed. 15:30 16:00 0.50 0 0 COMPZ CASING SVRG P Lubricate top drive and rig. 16:00 20:00 4.00 0 1,135 COMPZ CASING RNCS P Pick up liner string per detail. M/U EZ Ream liner shoe, double float collar, landing collar, SBE. Flex lock liner hanger, RS Nipple,ZXP packer w/HRDE. Mix Pal Mix, pour and let set for 30 minutes. P/U=44k, 5/0=43k. Calc Disp=4.97 bbl,Actual Disp=5.02 bbl. 20:00 21:30 1.50 1,135 3,041 COMPZ CASING RUNL P Break circulation on first stand, continue RIH,filling pipe every 10 stands to 3000' MD. 21:30 22:00 0.50 3,041 3,041 COMPZ CASING CIRC P Establish circulation @ 4 bpm, circulate surface to surface to break gels and even mud weight. P/U=64k, S/0=61k. 22:00 23:30 1.50 3,041 5,873 COMPZ CASING RUNL P Continue RIH from 3041'MD to 5873' MD filling pipe every 10 stands. Calc Disp=31.85 bbl,Actual Disp=35.7 bbl. P/U=89k, S/0=73k. Page 28 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 5,873 5,873 COMPZ CASING CIRC P Cirulate and condition mud @ 5873' MD,5 bpm 900 psi,40%Flow out. Noted barite sag, 12.6 ppg mud weight coming out. Circulate until even @ 12.9 ppg. 06/20/2014 Run liner to bottom,washing down from 9740'MD to tag @ 10127'no fill. C&C then pump 30 bbl cement per program. Set liner hanger and ZXP packer but saw no verification.Test ZXP to 1500 psi 10 minutes-good. POOH, rotating dog sub not sheared out. 00:00 01:00 1.00 5,873 5,873 COMPZ CASING CIRC P PJSM, continue circulate and condition mud @ 5873'MD, 5 bpm 900 psi. P/U=95k,S/0=75k. 01:00 02:45 1.75 5,873 9,187 COMPZ CASING RUNL P Continue RIH t/9187' MD filling pipe every 10 stands. Calc Disp=51.4 bbl, Actual Disp=85.5 bbl. 02:45 05:45 3.00 9,187 9,187 COMPZ CASING CIRC P Circulate and condition mud @ 9187' MD.3.5 bpm 900 psi. Pumped 3 BU to even out mud weight due barite sag, 12.5 ppg out, 12.9 ppg in. Obtain P/U=130k,S/0=90k and rotating torque 5k @ 10 rpm values. 05:45 06:15 0.50 9,187 9,740 COMPZ CASING RUNL P Continue RIH from 9187'MD to 9740' MD, lost 15k slack off weight. 06:15 08:00 1.75 9,740 9,740 COMPZ CASING CIRC P M/U top drive,establish circulation, reciprocate pipe 30'. Stage pump up to 3 bpm,975 psi. Mud weight on BU _13.7 ppg. 08:00 09:00 1.00 9,740 10,117 COMPZ CASING RUNL P Wash down from 9740'MD to 10127' MD @ 2.7 bpm 800 psi,tag bottom _no fill. 09:00 10:15 1.25 10,117 10,117 COMPZ CEMENT RURD P Make up cement head and XO's with pup joint to space out liner string. M/U to top drive. 10:15 12:45 2.50 10,117 10,117 COMPZ CEMEN-CIRCP Circulate and condition mud for cement job, reduce mud weight to 12.8 ppg.2.5 bpm, 1200 psi, P/U=135k, S/0=85k. Noted some minor packing off while circulating, decide to pump cement. 12:45 14:30 1.75 10,117 10,117 COMPZ CEMENT CMNT P Cement liner per program, pump 5 bbl H2O,test lines to 4000 psi. Batch up and pump 30 bbl 13.3 ppg 1 1 MudPush II,30 bbl 15.8 pptg Tail J cement,kick out plug with 10 bbl 411 H2O,displace with rig pump. Dart latched wiper plug @ 915 stks, bumped plug @ 1065 stks,CIP @ 14:20. 14:30 15:30 1.00 10,117 8,979 COMPZ CEMENT PACK P Set hanger and ZXP pack assy per Baker rep.Pressure up to 3500 with rig pumps to set liner hanger, no set. Line up SLB to pump up to 4200 psi to set liner hanger and HRDE. P/U 7' and set down 40k to set ZXP packer. No indication of shear, repeat with rotation, no indication of shear out. Page 29 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 8,979 8,959 COMPZ CEMENT RURD P Rig down cement head pup jts and XO's, L/D single while picking up to clear the RS packoff. 16:00 18:30 2.50 8,959 8,959 COMPZ CEMENT CIRC P Circulate excess cement out from liner top,condition mud per Mud rep. 6 bpm, 1750 psi,39% Flow out. 18:30 18:45 0.25 8,959 8,959 COMPZ CEMEN-PRTS P Test ZXP packer to 1500 psi 10 minutes(Good) 18:45 19:15 0.50 8,959 8,959 COMPZ CEMEN-CIRC P Pump and spot 40 bbl High Vis 12.8 ppg pill on top of packer. 19:15 20:00 0.75 8,959 8,959 COMPZ CEMEN-SFTY P Conduct Safety Stand down with rig crew concerning Ladder Safety and ladder inspection. Review recent incident,discuss equipment inspection. Inspect all ladders on rig, take 2 out of service. SIMOPS- Observe well for flow-Static. 20:00 20:15 0.25 8,959 8,956 COMPZ CEMEN RURD P PJSM, rack back stand, blow down top drive, P/U instring single. 20:15 23:45 3.50 8,956 0 COMPZ CEMEN'TRIP P Continue POOH on elevators to surface, lay down running tool. Calc Fill=52.63 bbl,Actual Fill=56.95 bbl. L/D running tools, inspect rotating dog sub, not sheared out. 23:45 00:00 0.25 0 0 COMPZ CEMEN-RURD T Clean and clear rig floor, prepare new packoff and rotating dog sub for RIH to verify ZXP packer is set fully. SIMOPS-Held Safety Stand down with oncoming crew-Ladder Safety and ladder inspection. 06/21/2014 M/U Baker rotating dog sub assy. RIH on 4"DP to verify packer set. Set down X 3 @ 40k observed shear out,. POOH.Test ZXP to 3500 psi-Good. M/U and RIH with 3'/z'upper GL completion, locate and space out. Begin displacement from 12.8 ppg mud to 8.5 seawater. 00:00 00:30 0.50 0 0 COMPZ CEMEN SFTY P Conduct Safety Stand down with rig crew concerning Ladder Safety and ladder inspection. Review recent incident, discuss equipment inspection. Inspect all ladders on rig 00:30 01:00 0.50 0 0 COMPZ CEMEN'PULD T PJSM,break XO and pups off cement head, lay down. 01:00 01:45 0.75 0 0 COMPZ CEMEN PULD T PJSM P/U Baker Pack-off dog sub and M/U as per Baker rep. 01:45 02:00 0.25 0 1,140 COMPZ CEMEN'TRIP T PJSM, RIH w/7 stands of 4"DP f/ derrick, P/U 6 joints of 4"HWDP and RIH w/2 stands of 4"HWDP f/ derrick. 02:00 05:15 3.25 1,140 8,979 COMPZ CEMEN TRIP T RIH w/4"DP f/derrick f/1140'MD to 8979'MD.Actual displacement= 56.44 bbls,Calculated displacement=52.60 bbls. Page 30 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 05:45 0.50 8,979 8,979 COMPZ CEMEN-PACK T Set down on ZXP liner top packer, observed a bobble on weight inductor @ 26K, cont.to S/O to 40K. P/U and set down 45K on ZXP. P/U, rotate @ 15 rpm's,4-6K tq. S/0 setting 40K down on ZXP. P/U to neutral. P/U= 142K, S/O=85K. Baker rep confirmed w/town ZXP is set. 05:45 08:45 3.00 8,979 0 COMPZ CEMEN TRIP T OWFF, POOH f/8974'MD to surface. Dog sub was sheared on Baker tool. Actual displacement= 57.4, Calculated displacement= 52.60 bbls. 08:45 09:00 0.25 0 0 COMPZ CEMEN PULD P Clean and clear rig floor. 09:00 10:00 1.00 0 0 COMPZ CEMEN PRTS P PJSM, R/U and test ZXP packer to 3500 psi f/30 minutes on chart,good test. 10:00 11:15 1.25 0 0 COMPZ RPCOM RURD P Wash stack and pull wear bushing. Blow down kill line and top drive. 11:15 12:00 0.75 0 0 COMPZ RPCOM RURD P PJSM, mobilize casing equipment to rig floor and R/U cazsing handling tools. 12:00 19:30 7.50 0 8,970 COMPZ RPCOM RCST P P/U and RIH with 3%"GL completion string. P/U locator seal assembly, DS Nipple 2.813", 1 GLM w/SOV,4 GLM w/DMY, DS nipple 2.875"and 233 jts 3%2'tubing. 19:30 21:15 1.75 8,970 9,008 COMPZ RPCOM HOSO P P/U jt 234 and M/U circulating hose, establish circulation and RIH to locate top of seal bore @ 9011'MD .5 bpm,400 psi. Continue in and fully locate @ 9029'MD. Lay down 3 jts, P/U 4.21', 10.11'and 10.20'pup, jt 232, hanger and landing joint. R/U circulating hoses for brine displacement. 21:15 00:00 2.75 9,008 9,008 COMPZ RPCOM DISP P PJSM,displace well from 12.8 ppg Mud to 8.5 ppg Seawater. Pump 200 bbl Seawater @ 3 bpm, ICP=800 psi, 37%Flow out, max pressure 1650 psi @ 3 bpm. Pump 100 bbl HV spacer,followed by 35 bbl Soap spacer,followed by seawater©3 bpm,750 psi. 06/22/2014 Complete brine displacement. Land hanger and RILDS.Attempt to test tubng string with IA open, bled down with flow out IA. R/U SLB slickline,set CAT-SV plug in DS @ 8934'.Test tubing fail. Pull SOV from GLM @ 8875,appeared good. R/D SLB and R/U HES slickline. 00:00 02:00 2.00 9,008 9,008 COMPZ RPCOM DISP P Cont to displace well to 8.5 ppg sea water,staging pumps up f/3 bpm=600 psi to 7.5 bpm=1290 psi, 36%flow. Pumped 690 bbls of seawater. 02:00 02:15 0.25 9,008 9,008 COMPZ RPCOM THGR P FMC rep inspect tbg hanger to confirm TWC will fit in hanger profile. Page 31 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 02:45 0.50 9,008 9,008 COMPZ RPCOM CRIH P Pump 20 bbls of inhibited sea water @ 3 bpm=225 psi,chase w/73 bbls of sea water to spot inhibited sea water from seal assy to SOV on GLM. 02:45 03:15 0.50 9,008 0 COMPZ RPCOM THGR P Drain stack, land hanger and run in lock downs on tbg hanger. 03:15 03:30 0.25 0 0 COMPZ RPCOM PRTS T Attempt to pressure test 3-1/2"tbg to 3500 psi,observed pressure bleeding off via IA at a fast rate. 03:30 03:45 0.25 0 0 COMPZ RPCOM OTHR T Discuss options with town engineer. Decision made to R/U Slickline to replace SOV in GLM#5, run leak detection tools. 03:45 04:00 0.25 0 0 COMPZ RPCOM CIRC T Pump down IA to determine if leak is two-way., observed fluid coming out 3-1/2"tbg. 04:00 07:00 3.00 0 0 COMPZ RPCOM SLKL T Mobilize SLB digital slickline to rig. SIMOPS-Clean rig pits,clean and paint boiler room, prep for hopper installation it pits. 07:00 08:30 1.50 0 0 COMPZ RPCOM SLKL T Load digital slickline tools in pipe shed,spot trucks. SIMOPS,pull landing joint, replace with 3-pups in order to get stump closer to rig floor to rig up slickline pressure control and lubricator. 08:30 10:30 2.00 0 0 COMPZ RPCOM SLKL T PSJM-P/U and R/U SLB Slickline tools. 10:30 11:15 0.75 0 0 COMPZ RPCOM SLKL T Test lubricator and grease head to 500 psi. 11:15 13:00 1.75 0 8,925 COMPZ RPCOM SLKL T RIH with D-CAT SV standing valve and catcher on Slickline,set in 2.812"DS nipple @ 8935.73'. Pick up 10'with line. 13:00 13:15 0.25 8,925 8,935 COMPZ RPCOM PRTS T R/U circulating lines, pressure test to 1500 psi, presure bleeding off. Pressure up to 3500 psi, bled off fast and flowing out the IA. 13:15 14:00 0.75 8,935 0 COMPZ RPCOM SLKL T POOH w/Slickline, C/O plug running tool to kick over tool. 14:00 18:30 4.50 0 0 COMPZ RPCOM SLKL T RIH w/Kickover tool attempt to pull SOV GLM#5, un-successful. Re-dress tool and re-attempt, un-successful.. 18:30 20:00 1.50 0 0 COMPZ RPCOM SLKL T Attempt pressure test on tubing again due D-CAT SV setting uncertainty.Again tubing failed. Re-dress kickover tool with roller stem, RIH and pull SOV. Successfull, no sign of shear on SOV. 20:00 21:00 1.00 0 0 COMPZ RPCOM SLKL T PJSM, R/D SLB digital slickline due crew timed out. Clear SLB tools from rig floor. 21:00 00:00 3.00 0 0 COMPZ RPCOM SLKL T PJSM-R/U HES slickline. MOB tools to rig floor,spot trucks, load lubricator in the pipe shed. Page 32 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/23/2014 24 hr Summary R/U HES Slickline and set SOV in GLM#5.Test tubing to 3500, annulus to 3000 psi 30 min ea charted. Shear out SOV, set TWC and test to 3200 psi. N/D BOPE, install tubing adapter and test 5k good. Install tree test 5k good. Pump inhibited brine and diesel FP. Lay down drill pipe. Secure well and release rig @ 00:00. 00:00 00:45 0.75 0 0 COMPZ RPCOM SLKL T Cont to R/U HES Slick line unit. 00:45 02:15 1.50 0 8,875 COMPZ RPCOM SLKL T RIH w/new SOV on HES slick line. Attempt to set SOV in GLM#5 @ 8875'MD 02:15 02:30 0.25 8,875 0 COMPZ RPCOM SLKL T Inspect slick line running tool on surface.SOV did not set in GLM#5. 02:30 04:00 1.50 0 0 COMPZ RPCOM SLKL T RIH w/new SOV on slick line. Set SOV in GLM#5@ 8875'MD. 04:00 04:15 0.25 0 0 COMPZ RPCOM PRTS T Pressure test 3-1/2"tbg to 3500 psi for 5 minutes,good test. 04:15 05:00 0.75 0 0 COMPZ RPCOM SLKL T Rig down HES slick line unit. 05:00 06:30 1.50 0 0 COMPZ RPCOM PRTS P Pressure test 3-1/2"tbg to 3500 psi f/30 minutes good test. Bleed down tbg to 2000 psi, pressure up IA to 3000 psi and test for 30 minutes, good test. Bleed off IA and tbg. Ramp up on IA, SOV sheared @ 2700 psi.All tests recorded on chart recorder. 06:30 06:45 0.25 0 0 COMPZ WHDBO RURD P R/D testing equipment and LID landing joint. 06:45 07:15 0.50 0 0 COMPZ WHDBO MPSP P Set TWC as per FMC rep,test TWC to 3200 psi f/5 minutes in the direction of flow. 07:15 07:30 0.25 0 0 COMPZ WHDBO RURD P Blow down choke line, kill line and cellar lines. 07:30 08:30 1.00 0 0 COMPZ WHDBO NUND P PJSM, Nipple down BOPE. 08:30 10:15 1.75 0 0 COMPZ WHDBO NUND P Install SBMS seals and adapter flange,test void to 5000 psi f/10 minutes.Test witnessed by CPAI rig supervisor, good test. 10:15 11:30 1.25 0 0 COMPZ WHDBO NUND P N/U tree as per FMC.Test to to 5000 psi,good. 11:30 12:15 0.75 0 0 COMPZ WHDBO MPSP P PJSM, Pull TWC, SIMOPS-R/U freeze protect&U-tube hoses and equipment. 12:15 14:30 2.25 0 0 COMPZ WHDBO FRZP P PJSM, Pressure test lines to 2500 psi. Pump 190 bbl inhibited brine, followed by 65 bbl diesel freeze protection @ 2.25 bpm 900 psi with Litte Red. Shut down pump,static pressure 160 psi. Line up to U-tube well. SIMOPS-Cut and slip drilling line. 14:30 16:00 1.50 0 0 COMPZ WHDBO FRZP P U-Tube well. SIMOPS R/U to lay down 4"drill pipe and HWDP from derrick. 16:00 17:00 1.00 0 0 COMPZ WHDBO MPSP P PJSM, R/U Lubricator and set 3" Type H BPV. 17:00 17:45 0.75 0 0 COMPZ MOVE RURD P Rig down hoses,secure wellhead, clean cellar area for rig move. Page 33 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 00:00 6.25 0 0 COMPZ MOVE PULD P Lay down 4"drill pipe. Page 34 of 34 Schlumberger ConocoPhiilips 2K-34 ASP Final Survey Report (Dei Survey) Report Data June 25.2014-0224 PM Survey I DLS Computation: Minimum CurvaNe/Lubinsld Client: ConocoPhilkps(Alaska)Inc.-Kup2 Vertical Section Azimuth: 271.605'(True North) Field: Kuparuk River Unit2 Vertical Section Origin: aunt 0.0008 Structure l Slot: Kuparuk 2K Pad/2K-34 ND Reference Datum: RKB Well: 2K-34 ND Reference Elevation: 143.130 ft above Mean Sea Level Borehole: 20-34 Seabed/Ground Elevation: 115.800 ft above Mean Sea Level UWI 1 API#: 50-103-20688-00.00 Magnetic Declination: 19.194° Survey Name: 2K-34 Final Total Gravity Field Strength: 1601.9933mgn(9.80665 Based) Survey Date: June 19,2014 Gravity Model: DOX Tort I AHD I DDI I ERD Ratio: 109.462°/7274.274 0/6.113/1.170 Total Magnetic Field Strength: 57592.016 nT Coordinate Reference System: NAD27 Alaska State Plane,Zone 04,US Feel Magnetic Dip Angle: 80.828' Location Lat I Long: N 70°14'34.74680",W 150°0'49.14257' Declination Date: June 01,2014 Location Grid N/E Y/X: N 593E419.9808US,E 498309.810 SUS Magnetic Declination Model: BGGM 2013 CRS Grid Convergence Angle: -0.0128" North Reference: True North Grid Scale Factor: 0.9999 Grid Convergence Used: 0.0000' Version 1 Patch: 2.7.1013.0 Total Corr Mag North->True 191939° North: Local Coord Referenced To: Well Head CommentsMD Ind Azlm True TVDSS ND VSEC AHD Closure NS EW DLS Northing Easting L,attude Longitude 101 (1 rt 181 181 181 101 MI 101 1111 rno001 (1tU51 IBUSI Pl ti Tie-In 0.00 0.00 0.00 -143.13 0.00 0.00 0.00 0.00 0.00 0.00 N/A 5938419.98 498309.81 70.24298572 -150.01365071 Ground Level 27.33 0.00 0.00 -115.80 27.33 0.00 0.00 0.00 0.00 0.00 0.00 5938419.98 498309.81 70.24298522 -150.01385071 96.40 0.04 154.21 -4673 9640 -0.01 0.02 0.02 -0.02 0.01 0.06 5938419.96 49830982 70.24298516 -150.01365063 147.63 0.08 11362 4.50 147.63 -0.05 0.08 0.07 -0.05 0.05 0.11 5938419.93 498309.86 70.24298508 -150.01365030 176.34 0.70 27272 33.21 17634 0.10 0.24 0.12 -0.05 -0.11 2.70 5938419.93 498309.70 70.24298508 -150.01365157 262.57 2.33 275.51 119.41 262.54 2.38 2.52 238 014 -2.38 1.89 5938420.12 498307.43 7024298561 -16.01366991 356.32 2.72 272.96 213.07 356.20 6.50 66.5 651 044 -6.50 0.43 5938420.42 498303.32 7024298642 -150.01370317 448.77 563 269.07 305.26 448.39 13.23 13.37 13.23 048 -13.22 3.18 5938420.46 498296.59 70.24298653 -150.01375749 541.70 6.53 268.37 397.67 54080 23.06 23.22 23.06 025 -23.06 0.97 5938420.24 498286.75 70.24298592 -150.01383695 633.30 7.30 269.27 48860 631.73 34.07 34.24 34.09 0.03 -34.09 0.85 5938420.02 498275.73 70.24298531 -150.01392599 724.78 7.08 270.33 57936 722.49 45.52 45.69 45.54 -0.01 -45.54 0.28 5938419.98 498264.28 70.24298520 -150.01401845 817.40 9.60 272.43 67099 814.12 58.95 59.13 58.96 0.35 58.96 2.74 5938420.34 498250.85 70.24298618 -150.01412687 910.40 9.49 272.49 76271 905.84 74.37 74.55 74.38 1.01 -74.37 0.12 5938421.01 498235.45 70.24298799 -150.01425130 1005.21 10.77 272.35 85604 999.17 91.04 91.22 91.05 1.72 -91.03 1.35 5938421.72 49821879 70.24298991 -150.01438584 1095.60 1206 274.32 944.64 1087.77 108.92 10911 108.92 277 -108.89 149 5938422.78 498200.94 7024299280 -150.01453003 1190.03 15.36 273.03 103636 1179.49 131.28 131.49 131.28 4.18 -131.22 3.51 5938424.19 498178.61 70.24299663 -150.01471037 1229.40 16.15 274.50 107425 1217.38 141.96 142.18 141.97 4.88 -141.88 2.25 5938424.89 498167.94 70.24299856 -150.01479651 1320.60 17.03 273.69 1161.66 1304.79 167.98 168.21 167.99 6.74 -167.86 1.00 593842675 498141.97 70.24300362 -150.01500625 1413.59 21.53 271.35 1249.41 1392.54 198.67 198.91 198.68 8.02 -198.52 4.91 5938428.04 498111.31 70.24300712 -150.01525388 Tie-In 2K-34P81 1504.57 26.20 26926 133259 1475.72 235.45 235.70 235.45 8.15 -235.31 5.22 5938428.18 498074.52 70.24300748 -150.01555101 1600.32 26.78 26992 1418.29 1581.42 278.13 27841 278.13 7.85 .278.02 0.88 5938427.89 498031.82 70.24300665 -150.01589589 1647.05 27.30 270.23 1459.91 1603.04 299.37 299.65 299.37 7.88 -299.26 1.15 5938427.92 498010.58 70.24300672 -150.01606745 1662.09 28.40 269.89 1473.21 1616.34 306.39 306.68 306.39 7.88 -306.29 7.39 5938427.93 498003.55 7024300674 -150.01612418 1692.16 3063 269.30 1499.37 1642.50 321.19 321.49 321.20 • 7.78 -321.10 7.48 5938427.83 497988.74 70.24300645 -150.01624380 1783.78 3247 268.77 1577.45 1720.58 369.08 369.43 36910 6.96 -369.03 2.03 5938427.02 49794082 70.24300422 -150.01663087 1876.84 34.65 270.23 1654.99 1798.12 420.49 420.87 420.52 6.53 -420.47 2.50 5938426.61 49788939 70.24300304 -150.01704625 1969.70 34.82 275.50 1731.32 1874.45 473.34 473.75 473.36 9.18 -473.27 3.24 5938429.27 497836.59 7024301026 -150.01747264 2062.78 35.97 276.06 1807.20 1950.33 527.11 527.67 527.11 14.61 -526.90 1.28 5938434.71 497782.96 70.24302509 -150.01790580 2154.21 38.42 277.44 1880.02 2023.15 582.15 582.93 582.17 21.13 -581.78 2.83 5938441.24 497728.09 70.24304288 -150.01831899 2245.90 44.31 27885 1948.81 2091.94 642.31 643.50 642.42 29.75 -641.73 6.50 593844987 497668.15 70.24306643 -150.01883310 2297.10 44.48 278.82 1985.39 2128.52 677.85 679.32 678.04 35.25 -677.12 0.33 5938455.38 49763276 70.24308145 -150.01911894 2338.81 46.26 278.14 2014.77 2157.90 707.39 709.07 707.66 6.64 -706.55 4.41 593845977 497603.34 70.24309342 -150.01935659 2432.36 47.39 274.75 2078.72 2221.85 775.27 777.21 775.70 47.27 -774.25 2.91 593846742 497535.65 70.24311424 -150.01990333 2524.90 49.91 27464 2139.85 2282.98 844.64 846.67 845.14 52.95 -843.48 2.72 5938473.11 497466.42 70.24312975 -150.02046241 2618.35 53.13 274.44 2197.99 2341.12 917.6 919.82 918.28 58.74 -916.40 3.45 593847892 497393.52 70.24314554 -150.02105127 2710.93 5422 274.50 2252.83 2395.96 992.18 994.41 992.86 64.55 -990.76 1.18 5938484.75 49731916 7024316139 -150.02165179 2801.67 5440 273.97 2305.77 2448.90 106.80 1068.10 1066.56 69.99 -1064.26 0.51 5938490.20 497245.68 7024317623 -150.02224532 2894.93 6.6 272.44 2359.07 2502.20 1142.29 114463 1143.08 74.26 -1140.66 209 978441.49 49716.28 7024318787 -150.02286234 2987.57 5603 272.19 2410.92 2554.05 1219.05 1221.39 1219.82 77.36 -1217.36 0.27 5938497.61 497092.59 7024319630 -150.02348178 3080.56 55.73 272.39 2463.08 2606.21 1296.03 1298.38 1296.78 93.44 -1294.29 0.37 5938500.70 497015.67 70.2432467 -150.02410298 3172.69 5530 272.15 2515.25 2658.38 1371.97 137432 1372.71 83.45 -1370.17 0.51 5938503.73 496939.80 7024321285 -150.02471577 326.6 53.70 269.68 256.35 2712.48 1447.80 1450.16 1448.47 84.67 -1446.00 2.78 5938504.97 496863.98 7024321617 -150.02532814 3357.80 53.94 270.03 2623.63 2766.76 1521.98 1524.37 1522.55 84.49 -1520.21 0.40 5938504.80 49678978 7024321562 -150.02592745 3450.6 53.98 269.74 2678.26 2821.39 1597.03 1599.46 1597.52 84.34 -1595.29 ' 0.26 5938504.67 496714.70 70.24321516 -150.02653382 3457.65 53.91 269.56 262.38 2825.51 1602.68 1605.11 1603.16 84.30 -1600.94 2.31 5938504.63 496709.05 70.24321506 -150.02657946 10-3/4"CSG 354299 54.03 269.19 273258 2675.71 1671.64 1674.12 1672.04 83.55 -169.95 0.37 5938503.90 496640.05 7024321297 -150.02713675 3590.39 54.09 268.99 2760.40 2903.53 1709.98 1712.50 1710.34 8294 -1708.32 0.37 5938503.30 496601.68 70.24321129 -150.02744662 3626.34 5421 26.6 2781.46 2924.59 1739.08 1741.64 173941 82.33 -1737.46 0.94 5938502.69 496572.55 70.2432(959 -150.02768189 3719.64 5425 26.84 2835.99 2979.12 1814.69 1817.34 1814.93 80.64 -1813.14 021 5938501.02 496496.88 70.24320493 -150.02829307 3813.71 54.23 268.73 2890.97 3034.10 1890.93 1893.68 1891.11 7902 -1889.46 0.10 5938499.42 496420.56 70.24320045 -150.02890939 3903.51 54.29 26.03 2943.42 3088.55 1963.73 1966.56 1963.6 77.60 -1962.33 0.28 5938498.01 496347.70 70.24319651 -150.02949790 3996.27 54.24 26974 2997.59 3140.72 2038.97 2041.86 2039.07 76.79 -2037.62 0.62 5938497.22 496272.41 70.24319425 -150.03010592 4090.6 54.44 27040 3052.63 3195.76 2115.65 2118.57 2115.72 76.88 -2114.33 0.61 5938497.33 496195.72 70.24319445 -150.03072538 4182.73 54.60 271.34 310606 3249.19 2190.60 2193.52 2190.67 78.02 -2189.28 0.85 5938498.48 496120.78 7024319750 -150.03133064 4275.37 54.64 271.45 316.70 3302.83 2266.13 2269.06 2266.19 79.86 -2264.79 0.11 5938500.34 496045.27 70.24320246 -150.03194043 4368.50 5526 271.11 3213.18 3356.31 2342.37 2345.30 2342.43 81.56 -2341.01 0.73 5938502.06 495969.06 70.24320705 -150.03255598 4462.46 5521 270.70 326.76 3409.89 2419.55 2422.48 2419.60 82.78 -2418.18 0.36 5938503.29 495891.89 70.24321031 -150.03317925 4555.82 55.13 271.30 3320.08 346321 2496.18 2499.12 2496.22 84.12 -2494.81 0.53 5938504.65 49581528 7024321390 -16.03379803 4648.41 54.60 271.17 337337 3516.50 2571.90 2574.84 2571.94 85.75 -2570.51 0.58 638506.30 49573958 70.24321829 -150.03440938 4740.64 54.61 270.73 3426.79 3569.92 2647.08 2650.02 2647.11 87.00 -2645.68 0.39 5938507.56 495664.42 70.24322182 -150.03501646 4834.03 54.75 270.93 3480.78 3623.91 2723.27 2726.22 2723.30 88.10 -2721.87 0.23 5938508.68 495588.23 70.24322456 -150.03563177 4925.75 54.68 271.33 3533.76 3676.89 2798.14 2801.09 2798.16 6.58 -2796.73 0.36 593851017 495513.39 70.2432262 -150.03623629 501886 54.71 27204 3587.58 3730.71 2874.13 2877.08 2874.15 91.81 -2872.68 0.62 593851243 495437.44 70.24323455 -150.0368496 511124 54.61 272.35 3641.01 3784.14 2949.48 2952.43 2949.50 94.70 -2947.98 0.29 5938515.33 495.387.15 70.24324235 -150.03745779 520330 54.71 272.30 3694.26 3837.39 3024.57 3027.53 3024.60 97.74 -3023.02 0.12 5938518.39 495287.12 70.24325060 -150.03806376 5296.41 54.70 272.47 3748.06 3891.19 3100.56 3103.53 3100.59 100.91 3098.95 0.15 5938521.57 495211.20 7024325915 -150.03867695 5387.98 54.70 272.61 3800.97 3944.10 3175.28 3178.26 3175.32 104.22 3173.61 0.12 5938524.90 49513655 70.24326811 -150.03927990 5481.75 5471 272.32 386.15 3998.28 3251.81 325479 3251.85 107.51 3250.07 0.25 63852821 495060.09 70.24327702 -16.03989740 5574.11 5469 272.08 3908.52 4051.65 3327.18 3330.17 3327.23 110.40 3325.39 0.21 63853112 49498478 70.24328483 -16.04050570 5666.27 5473 271.79 3961.77 410490 3402.40 3405.40 3402.45 11294 3400.6 0.26 593853367 494909.61 7024329168 -16.04111285 5758.92 54.68 271.85 4015.30 4158.43 3478.02 3481.02 347807 115.35 -3476.16 0.08 5938536.09 494834.03 70.24329815 -150.04172324 5852.16 5468 271.59 406.20 4212.33 355410 355709 3554.15 117.63 -3552.20 0.23 5938538.39 494758.00 70.24330429 -150.04233736 5944.82 54.71 271.55 412275 4265.88 3629.72 3632.71 3629.76 119.70 -3627.79 0.05 5938540.48 499682.42 70.24330985 -150.04294781 6038.19 54.70 271.61 4176.70 4319.83 3705.93 37013.92 3705.97 121.80 -3703.97 0.05 5938542.60 49960625 70.24331549 -150.04356302 612969 5467 271.70 4229.60 4372.73 3780.59 3783.58 3780.63 123.96 -3778.60 0.09 638544.77 494531.62 70.24332128 -16.04416573 622185 54.73 27232 4282.85 4425.98 3855.6 3858.80 3855.85 126.6 386.77 0.55 5938547.43 494456.46 70.24332838 -150.04477278 631181 54.65 27250 4336.00 4479.13 3930.84 3933.84 3930.89 129.75 -3928.75 0.18 5938550.60 494381.49 70.24333690 -150.04537829 6406.86 5468 272.72 438982 4532.95 4006.74 4009.75 4006.79 13321 -4004.58 0.21 5938554.07 494305.67 70.24334623 -150.04599068 6498.02 54.68 273.34 444252 456.65 4081.09 4084.13 4081.16 137.14 -4078.85 0.55 5938558.02 494231.41 70.24335686 -150.04859054 691.99 54.61 273.54 449690 4640.03 4157.69 416.77 4157.77 141.74 -4155.35 0.19 5938562.64 494154.91 70.2433631 -150.04720837 6684.16 54.60 273.67 4550.28 4693.41 423278 4235.91 4232.87 146.46 -4230.34 0.12 5938567.38 494079.93 70.24338211 -150.04781396 6775.35 54.76 272.88 4603.01 4746.14 4307.15 4310.31 4307.26 15071 .4304.62 0.73 5938571.64 494005.66 70.24339360 -150.04841387 6868.6 54.85 273.30 465690 4800.03 4383.54 4386.73 4383.6 154.83 -4380.93 0.38 5938575.78 493929.36 7024340474 -150.04903011 696206 54.75 272.37 4710.63 4853.76 4459.68 446288 4459.81 158.60 -4456.99 0.82 -5938579.56 493853.31 70.24341491 .150.04964440 705545 54.79 271.61 4764.50 4907.63 4535.97 4539.17 4536.10 161.25 -4533.23 0.67 5938582.23 493777.08 70.24342202 -150.0626009 7148.14 54.80 271.95 4817.94 4961.07 4611.70 4614.90 4611.83 163.60 -4608.93 0.30 5938584.60 493701.39 70.24342832 -150.05087144 7240.55 54.78 272.42 4871.22 5014.35 467.20 4690.41 4687.33 16.48 -4684.38 0.42 5938587.49 493625.95 70.24343606 -150.05148075 7334.01 54.82 272.55 4925.09 5068.22 4783.6 4766.78 4763.70 16.79 -4760.67 0.12 593859082 493549.66 70.24344497 -16.05209694 7426.06 54.78 272.80 4978.15 512128 4838.77 4842.00 4838.91 173.30 -4835.81 0.23 5938594.35 493474.53 7024345443 -150.05270374 7519.58 54.67 272.76 5032.16 5175.29 4915.10 4918.34 4915.26 177.00 -4912.07 0.12 5938598.07 493398.28 70.24348441 -150.05331961 7612.57 5480 27281 5085.85 5228.98 4991.01 4994.27 4991.18 180.69 -4987.91 0.15 5938601.77 49332245 70.24347436 .150.05393207 7704.87 5477 273.30 5139.07 5282.20 5066.39 5069.6 5066.57 184.71 5063.21 0.43 5938605.81 493247.16 70.24348520 -150.05454020 7797.31 5486 273.03 5192.34 5335.47 5141.92 5145.23 5142.11 188.88 5138.64 0.26 5938610.00 49317173 70.24349645 -150.05514943 7888.85 54.68 27247 5245.14 5388.27 5216.67 5220.00 5216.88 192.47 5213.33 0.54 593613.60 493097.06 70.24350612 -150.05575261 7982.50 5478 272.11 5299.22 5442.35 5293.13 5296.46 5293.34 195.53 -5289.73 0.33 5938616.67 493020.67 70.24351432 -150.05836961 8074.41 54.75 272.07 5352.25 5495.38 5368.20 5371.53 536.41 198.26 -5364.75 0.05 5938619.43 492945.65 70.2435216 -150.05697548 8169.03 54.6 271.07 5406.90 5550.03 5445.43 5448.77 5445.64 200.38 5441.96 0.87 5938621.56 492868.45 70.24352728 -16.05759900 8259.55 54.71 271.10 5459.22 560235 5519.30 5522.64 5519.50 201.78 5515.81 0.04 5938622.98 49279460 70.24353096 -16.05819548 8352.11 55.27 270.57 551232 5655.45 5595.11 5598.45 5595.30 20188 -5591.62 0.77 638624.10 492718.81 7024353382 -16.0588076 8445.17 58.66 269.57 5563.05 5706.18 5673.08 5676.46 5673.25 202.96 566.62 3.75 5938624.20 492640.81 70.24353188 -150.0643759 8538.65 62.43 269.86 566.01 5752.14 5754.12 5757.84 5754.57 202.56 5751.00 4.04 5938623.81 49255944 70.24353262 -16.08009481 8632.37 65.42 270.61 5650.21 5793.33 5838.56 58422.01 5838.70 202.92 5835.17 3.27 5938624.18 492475.28 70.24353341 -150.06077455 • • • • Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2K Pad\2K-34\2K-34\2K-34 Final 7/11/2014 3:08 PM Page 1 of 2 S. Comments IM Ind Adm True TVDSS 7VD VSEC AHD Closure NS EW DLS Northing Eas8ng Latitude Longitude MI ri in 1111 Illi MI 181 MI ISI ISI 7110081 MUSI 1898) rl In 8722.36 68.50 271.13 568541 5828.54 5921.36 5924.81 5921.48 204.18 -591796 346 5938625.46 492392.50 70.24353668 -150.06144317 8816.61 72.20 272.51 571710 586023 6010.10 601356 601023 207.01 5006.66 416 5938628.31 492303.81 7024354422 -150.06215950 8909.85 74.16 272.91 5744.08 588721 6099.33 610280 6099.47 211.23 -6095.81 2.14 5938632.55 492214.67 70.24355555 -150.06287946 9001.88 74.52 272.49 5768.92 5912.05 6187.93 6191.42 6188.07 215.40 518/.32 0.59 5938636.75 492126.17 70.24356676 -150.06359432 9096.77 74.46 271.93 5794.30 5937.43 6279.36 6282.85 627951 218.93 -6275.69 0.57 5938640.29 492034.81 70.24357619 -150.06433221 9212.37 74.58 271.38 5825.15 5968.28 6390.76 6394.26 6390.91 222.15 -6387.05 0.47 5938643.54 491923.46 70.24358472 -150.06523155 7"CSG 9257.00 74.50 271.09 5837.05 5980.18 643378 6437.27 6433.92 223.07 -6430.05 0.85 5938644.47 491880.46 70.24358715 -150.06557886 9307.92 74.41 270.76 5850.69 5993.82 6482.83 6486.33 6482.97 223.87 -6479.10 0.65 5938645.28 491831.42 70.24358920 -150.06597499 9402.88 74.12 270.58 5876.45 601958 6574.22 6577.73 6574.35 224.94 -6570.50 0.36 5938646.37 491740.03 70.24359191 -150.06671309 9496.84 74.05 270.44 590221 6045.34 6664.56 6668.09 6664.68 22574 -6660.85 0.16 5938647.19 491649.69 70.24359389 -150.06744279 9592.71 74.01 270.65 5928.59 6071.72 8756.72 6760.26 6756.82 228.82 5753.02 0.21 5938648.09 491557.53 70.24359606 -150.06818711 9684.17 74.40 271.07 5953.48 6096.61 6844.72 6848.27 6844.81 227.94 -8841.02 0.61 5936649.43 491469.54 70.24359945 -150.06889777 9779.60 74.34 271.72 5979.19 6122.32 6936.62 6940.17 6936.71 230.17 5932.89 0.66 5938651.69 491377.68 70.24360534 -150.06963974 9875.71 74.01 270.98 6005.40 6148.53 7029.08 703264 7029.17 232.35 -7025.33 0.82 5938653.89 491285.25 70.24361105 -150.07038629 9970.31 74.12 271.46 603138 6174.51 7120.04 7123.60 7120.13 234.29 -711827 0.50 5938655.84 491194.31 70.24361611 -150.07112076 10065.33 74.06 271.16 6057.43 6200.56 7211.42 7214.98 7211.50 236.38 -7207.83 0.31 5938657.95 491102.97 70.24362158 -150.07185853 4-12"1.mer 10117.00 74.05 271.16 6071.63 6214.76 7261.10 7264.66 7261.18 237.39 -7257.30 0.00 5938658.97 491053.31 70.24362420 -150.07225948 Prajec0on to TD 10127.00 74.05 271.16 6074.38 6217.51 7270.71 7274.27 7270.79 237.58 -7266.91 010 593865917 491043.69 70.24362471 -150.07233731 Survey Type: Def Survey Survey Error Model: ISCW SA Rev 0'...3-D 95.000%Confidence 2.7955 sigma Survey Program: Description pan MD From MD To EOU Freq Hole Size Casing Diameter Survey Tool Type Borehole)Survey (8) (8) (8) (In) On) 1 0.000 1190.030 Act Stns 13.500 10.750 GYD-GC-SS 20-34 PB1/2K-34PB1-Final 1 1190.030 1504.570 Act Stns 13.500 10.750 MWD+IFR-AK-CAZ-SC 20-34 PB1120-34P91-Final 1 1504.570 3542.990 Act Stns 13.500 10.750 MWD+IFR-AK-CAZ-SC 2K-34/2K-34 Final 1 3542.990 9096.780 Act Stns 8.500 7.000 MWD+IFR-AK-CAZSC 2K-34/2K-34 Final 1 9096.780 9212370 Act Sins 8.500 7.000 INC+TREND 2K-3412K-34 Final 1 9212.370 10065.330 Act Stns 6.125 4.500 MWD+IFR-AK-CAZSC 2K-34/2K-34 Final 1 10065.330 10127.000 Act Stns 6.125 4.500 BLIND 2K-3412K34 Final Legal Description: Norley l'/) lasting8(1)2 Surface:115.9 FSL94.6 FEL 52T10N ROE UM 5938419.980 498309.810 BBL:350 FSL 2081 FEL 3 T10N RBEUM 593806/170 491043.690 Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. O Yes D No I have checked to the beat of my ability that the following data is correct: 55 Surface Coordinates (9 Declination&Convergence la GRS Survey Corrections ® Survey Tool Codes SLB DE: Client Representative: Date: Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2K Pad\2K-34\2K-34\2K-34 Final 7/11/2014 3:08 PM Page 2 of 2 Z \ '---( - 02.< . . RECEIVED ConocoPhillips AUG 19 2014 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 14, 2014 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7ti,Avenue, Suite 100 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. Cement was pumped July 25, 2014 &July 27, 2014. The corrosion inhibitor/sealant was pumped July 29, 2014 &August 5, 2014. 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, 7,(bM a2 1 -------- Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 8/14/2014 2K,2L&2X 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 2K-29 50103206870000 2140250 9'9" 1 00 31" 7/27/2014 8 5 7/29/2014 2K-34PB1 50103206880000 2140260 6'5" 100 20" 7/27/2014 5.1 7/29/2014 2L-318 50103206810000 2131830 4'2" 15 gal. 25" 7/25/2014 1.7 7/29/2014 2X-12A 50029211890100 1951760 SF na 24" na 17 8/5/2014 EC IV GV STATE OF ALASKA JUL1 6 Z014 ALA,. OIL AND GAS CONSERVATION COMM, .ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Performed. Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdow n Fr. 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 214-026-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20688-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25588,25589 2K-34 9.Logs(List logs and submit electronic and printed data per 20AAC25 071): 10.Field/Pool(s): GR/Res Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10127 feet Plugs(measured) none true vertical 6217 feet Junk(measured) none Effective Depth measured 10117 feet Packer(measured) 8979 true vertical 6215 feet (true vertical) 5906 Casing Length Size MD ND Burst Collapse CONDUCTOR 76 16 104 104 SURFACE 3515 10.75 3543 2876 INTERMEDIATE 9222 7 9248 5978 LINER 1138 4.5 10117 6215 Perforation depth: Measured depth: none True Vertical Depth: none Tubing(size,grade,MD,and TVD) 3.5, L-80,9025 MD, 5918 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER ZXP PACKER @ 8979 MD and 5906 TVD NIPPLE-CAMCO DS NIPPLE W/2.875"PROFILE @ 643 MD and 642 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development IP Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP P SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt 314-370 Contact Mike Callahan Cad 263-4180 Email Mike.Callahan@conocophillips.com Printed Name Mike Callahan Title Drilling Engineer Signature �-JC_G„_ Phone:263-4180 Date 7//5/ 1J /0/3 °//l� R$DMS JUL 16 20 4 doodv/ 5� Form 10-404 Revised 10/2012 Submit Original Only �ager �� KUP PROD 2K-34 Conor PhiIIips ,r Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ORB) u�,,,,r„ ,501032068800 KUPARUK RIVER UNIT PROD ' 74.58 9,212.37 10,127.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(ft) •Rig Release Date 2K-34,7/8/20147.05:53 AM SSSV:NIPPLE Last WO: 27.33 6/23/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL,GLV C/O,PULL CAT haggea 7/8/2014 SV HANGER.23.5- 16■111r Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MKB) Set Depth(ND)... WtlLen(I...Grade Top Thread CONDUCTOR 16 14.000 28.0 104.0 104.0 164.80 A-106 Welded "-""'--Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 10 3/4 9.950 28.3 3,543.0 2,875.7 45.50 L-80 Hyd563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread INTERMEDIATE 7 6.276 25.8 9,247.7 5,977.7 26.00 L-80 TN Blue Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread _.......... ._II. ...............LINER 41/2 3.958 8,979.2 10,117.0 6,214.8 12.60 L-80 IBTM Liner Details IIf Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (In) 8,979.2 5,906.0 74.43 PACKER BAKER 5"x 7"ZXP PACKER w HRDE profile 10' 5.250 8,999.3 5,911.4 74.51 NIPPLE BAKER"RS"NIPPLE TSH-521 Box x Box 4.270 9,002.1 5,912.1 74.52 HANGER BAKER FLEX LOCK LINER HANGER 4.350 ,n,ti,CONDUCTOR,28 o-104.0 r 9,012.01 5,914.71 74.51 ISBE I BAKER 80-40 SEAL BORE ESTENSION I 4.000 Tubing Strings NIPPLE;643.3 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection TUBING 3 1/2 2.992 23.5 9,024.8 5,918.2 9.30 L-80 EUE 8rd Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 1°) Item Des Com (in) 23.5 23.5 0.00 HANGER FMC GEN V TUBING HANGER 2.992 643.4 641.7 7.28 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 GAS LIFT;3,021.1 a 8,935.7 5,894.3 74.26 NIPPLE CAMCO DS NIPPLE w/2.813"Profile 2.812 I 8,983.7 5,907.2 74.45 LOCATOR BAKER LOCATOR 3.000 8,984.9 5,907.5 74.45 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSY w/12'of 3.000 seals Mandrel Inserts St ai BANKER (TVD) Valve Latch Port Size TRO Run SURFACE;2813,5430-• Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3,021.1 2,572.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/21/2014 2 5,097.1 3,776.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/21/2014 GAS LIFT;5.0971II 3 6,589.8 4,638.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/2/2014 4 7,705.6 5,282.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/21/2014 5 8,875.5 5,877.6 CAMCO MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 7/6/2014 GAS LIFT;6.5898 Notes:General&Safety End Date Annotation NOTE: GAS LIFT,7,705.6 11 GAS LIFT,8,875.5 11 11 NIPPLE;8,935.7 1 LOCATOR;8,983.6 a i SEAL ASSY,8.9849 I f i# 111 I INTERMEDIATE.25.8-9.247 7 l LINER.8,9792-10,1170 l 0 e MOAN o M W MAO1MA'-ML .N00'Mt0O)Oa,'0MMN N000. 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Death E. Death Phase Code Subcode T Comment 05/24/2014 24 hr Summary Released from rig maintenance© 12:00 hrs. Rig down,separate modules and begin moving from 2B pad to 2K-34. Made notification to AOGCC of upcoming diverter test. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Release from rig maintenance @ 12:00 hrs, disconnect electrical and steam lines.Trucks arrived at 15:00 hrs. Pull apart rig mods. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Begin moving rig mods to 2K pad, pipe sheds and rock washer. Sub departed 2B pad @ 20:30 hrs. 35/25/2014 Move rig from 2B pad to 2K-34, rig up and accept rig @ 10:00 hrs. R/U diverter, load pipe shed and P/U 5" DP. 00:00 03:30 3.50 0 0 MIRU MOVE MOB P Spot sub base and pit complex over well 2K-34. 03:30 04:30 1.00 0 0 MIRU MOVE MOB P Mobilize pump room, motor room and boiler complex for 2B pad to 2K pad. 04:30 07:30 3.00 0 0 MIRU MOVE MOB P Spot power pack, rock washer and pipe shed. 07:30 08:30 1.00 0 0 MIRU MOVE RURD P Plug in electrical lines, hook up steam, air fuel and water. 08:30 10:00 1.50 0 0 MIRU MOVE RURD P PJSM,Work on rig accetance check list and test gas alarms. Rig Accepted at 10:00 hours. 10:00 12:00 2.00 0 0 MIRU DRILL NUND P PJSM, Nipple up diverter and install 4"valves on conductor. 12:00 14:00 2.00 0 0 MIRU DRILL NUND P PJSM,continue N/U diverter. 109' from well to end of diverter, 90'from cellar wall to end of diverter. 14:00 18:00 4.00 0 0 MIRU DRILL RURD P Take on Drilplex mud, load pipe shed with 103 jts 5"DP, 17 jts HWDP, R/U envirovac, instqall mouse hole, install elevators. 18:00 20:00 2.00 0 0 MIRU DRILL RURD P Strap DP, HWDP and DC in pipe shed, continue on-loading mud, R/U to P/U DP. 20:00 00:00 4.00 0 0 MIRU DRILL PULD P PJSM, P/U 30 stands 5"drill pipe via mouse hole. 05/26/2014 Complete P/U pipe. Perform diverter and accumulator test,witness waived by AOGCC Bob Noble. M/U BHA #1 and clean out to 130'MD. M/U drilling BHA, adjust motor to 1.5°,directional drill to 746'MD taking Gyro surveys. 00:00 01:00 1.00 0 0 MIRU DRILL PULD P PJSM, P/U 4 stands of 5"DP and 6 stands of 5"HWDP. Page 1 of 34 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T " Comment 01:00 01:30 0.50 0 0 MIRU DRILL BOPE P Perform diverter test:system pressure=2900 psi, pressure after closing= 1800 psi,200 psi recharge= 42 sec, full pressure after 168 sec. Time to knife valve open= 10 sec, time for annular to close= 18 sec. Witness of test waived by AOGCC rep Bob Noble. 01:30 03:30 2.00 0 0 MIRU DRILL RURD P Load pipe shed with SLB tools and pick up tools from ground via beaver slide. 03:30 05:00 1.50 0 0 SURFA( DRILL PULD P PJSM, M/U BHA#1 as per SLB rep. 05:00 05:45 0.75 0 0 SURFA( DRILL RURD P Flood conductor, R/U and pressure test surface equipment to 5000 psi, good. 05:45 08:15 2.50 0 130 SURFA( DRILL DRLG P Drill out conductor with 0°bent in motor. Drill f/30'MD to 130'MD pump @ 450 gpm,400 psi, 86% flow, 20-30 rpm's. 08:15 09:00 0.75 130 30 SURFA( DRILL TRIP P PJSM, POOH f/130'MD to 30' MD. 09:00 09:45 0.75 30 30 SURFA( DRILL PULD P Adjust motor bend to 1.5°as per SLB rep. 09:45 11:15 1.50 30 30 SURFA( DRILL PULD T Trouble shoot Gyrodata tools- SIMOPS, P/U 3 joints of drill collars. 11:15 12:15 1.00 30 60 SURFA( DRILL PULD P PJSM, P/U BHA#2 as per SLB rep. 12:15 14:00 1.75 60 130 SURFA( DRILL PULD P PJSM, Continue P/U BHA#2 14:00 14:30 0.50 130 130 SURFA( DRILL SRVY P RIH tag bottom,Take Gyro survey, shallow pulse test @ 450 gpm, 500 psi. 14:30 16:00 1.50 130 243 SURFA( DRILL DRLG P Drill from 130'MD to 243'MD @ 40 rpm, 1k TQ,450 gpm @ 500 psi, 86%Flow out. (SIMOPS on L/D _ single and rack back stand.) 16:00 16:30 0.50 243 243 SURFA( DRILL PULD P POOH with single, rack back 1 stand. P/U flex collars and saver sub, P/U stand HWDP. Establish _ parameters. 16:30 00:15 7.75 243 746 SURFA( DRILL DDRL P Directional drill from 243' MD to 746' MD, 746'TVD.ART=2.77, AST=2.76,ADT=5.53, Jar Hrs=29.23, Bit Hrs=5.53, P/U=74k, S/O=74k, ROT=74k, Tq on/off=4/1k ft lbs,WOB=5-25k, ECD=10.76, 56%Flow out,60 rpm,493 gpm @ 900 psi. Reduced rpm to 60 per Gyrodata for tool. No recordable losses. 05/27/2014 Continued directional drilling 13 1/2" surface hole section from 746-2159'MD,2013'TVD. �� Page 2 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 746 1,141 SURFA( DRILL DDRL P Directional drill from 746' MD to 1141' MD, 1131'TVD.ART=1.87, AST=2.08,ADT=3.95, Jar Hrs=33.18, Bit Hrs=9.48, P/U=87k, S/0=82k, ROT=85k, Tq on/off=6/3k ft lbs, WOB=15-20k, ECD=10.32, 64% Flow out, 60 rpm, 500 gpm @ 1000 psi. No recordable losses. 06:00 12:00 6.00 1,141 1,419 SURFA( DRILL DDRL P Directional drill from 1141' MD to 1419' MD, 1398'TVD.ART=.72, AST=2.97, ADT=3.69, Jar Hrs=36.87, Bit Hrs=13.17, P/U=93k, S/0=83k, ROT=88k, Tq on/off=7/3k ft lbs,WOB=20-25k, ECD=10.65, 84% Flow out, 60 rpm, 500 gpm @ 1100 psi. Observing loss—8 bph,total for tour 55 bbls. 12:00 18:00 6.00 1,419 1,753 SURFA( DRILL DDRL P Directional drill from 1419' MD to 1753' MD, 1714'TVD.ART=.95, AST=3.4,ADT=4.35, Jar Hrs=41.22, Bit Hrs=17.52, P/U=97k, S/O=88k, ROT=92k,Tq on/off=4/2k ft lbs, WOB=5-15k, ECD=10.41, 71% Flow out, 60 rpm, 607 gpm @ 1300 psi. 18:00 00:00 6.00 1,753 2,159 SURFA( DRILL DCSG P Directional drill from 1753' MD to 2159' MD, 2013'TVD.ART=1.71, AST=2.15,ADT=3.86, Jar Hrs=45.08, Bit Hrs=21.38, P/U=104k, S/0=90k, ROT=95k, Tq on/off=4/2k ft lbs, WOB=5-25k, ECD=10.52, 87% Flow out, 60 rpm, 604 gpm @ 1400 psi. 05/28/2014 Directional drilled from 2159'-3590' MD, 2909 TVD.Circulate surface to surface 2X. OWFF&backream out of hole to 3090' MD. 00:00 06:00 6.00 2,159 2,530 SURFA( DRILL DDRL P Directional drill from 2159' MD to 2530' MD, 2285'TVD.ART=1.42, AST=2.10,ADT=3.52, Jar Hrs=48.60, Bit Hrs=24.90, P/U=106k, S/0=91k, ROT=98k, Tq on/off=6/3k ft lbs,WOB=15-20k, ECD=10.32, 59% Flow out, 60 rpm, 608 gpm @ 1710 psi. 06:00 12:00 6.00 2,530 2,994 SURFA( DRILL DDRL P Directional drill from 2530' MD to 2994'MD, 2562'TVD.ART=2.98, AST=1.13,ADT=4.11, Jar Hrs=52.71, Bit Hrs=29.01, P/U=109k, S/O=88k, ROT=96k, Tq on/off=6/5k ft lbs,WOB=20-25k, ECD=10.72, 66% Flow out, 60 rpm, 650 gpm @ 1850 psi. Page 3 of 34 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 2,994 3,455 SURFA( DRILL DDRL P Directional drill from 2994'MD to 3455'MD,2830'TVD.ART=3.35, AST=.32,ADT=3.67,Jar Hrs=56.38, Bit Hrs=32.68, P/U=115k, S/0=91k, ROT=100k,Tq on/off=8/4k ft lbs, WOB=5-25k, ECD=10.85, 84% Flow out, 80 rpm, 750 gpm @ 2475 psi. 18:00 21:00 3.00 3,455 3,590 SURFA( DRILL DDRL P Directional drill from 3455'MD to 3590'MD, 2908'TVD.ART=1.60, AST=0,ADT=1.6,Jar Hrs=57.98, Bit Hrs=34.28, P/U=120k, 5/0=93k, ROT=101 k, Tq on/off=7/4k ft lbs, WOB=5-20k, ECD=10.46, 80% Flow out, 80 rpm, 755 gpm @ 2475 psi. 21:00 22:30 1.50 3,590 3,590 SURFA( CASING CIRC P Circulate surface to surface 2X @ 650 gpm, 1850 psi,60 rpm, 5k tq, FO 60%. 22:30 23:00 0.50 3,590 3,590 SURFA( CASING OWFF P Monitor well, losses observed, calculated 18 BPH. 23:00 00:00 1.00 3,590 3,090 SURFA( CASING REAM P BROOH from 3590'-3090'MD, 650 gpm, 1750 psi,60 rpm,6k tq, FO 60 %, calcualted 3.75,actual 33 bbls, 30 bbls loss X5/29/2014 BROOH from 3090'-1698' MD. Hole unloaded&exceed surface equipment capacity. Clean up&stage up pumps.Whlie staging up pumps tagged up at 1647' MD. Made several attempts to get back in the hole.Tried to slide back into the original hole with gyro&MWD surveys confirming, not in original wellbore. Decision made to sidetrack and obtain wellbore seperation. Directional drill from 1882'-2380'MD, 2161'TVD. 00:00 01:45 1.75 3,090 1,698 SURFA( CASING REAM P BROOH f/3090'MD to 1698'MD. Began BROOH @ 650 gpm, hole taking 30 bbls for 5 stands pulled. Slowed pumps to 450 gpm= 1430 psi, hole still taking 16 bbls for 5 stands pulled. Rotate @ 60 rpm's with 5K Tq. 01:45 03:45 2.00 1,698 1,698 SURFA( CASING OTHR T Observed hole unloading cuttings at a high rate, unable to process the large amount of cutting on surface equipment. Shut down, unpack and clean flow line, possum belly. Stage pumps back up to 450 gpm. 03:45 05:00 1.25 1,698 1,647 SURFA( CASING REAM T Pick up f/1698' MD to 1607' MD, work string down.Tagged up @ 1647' MD. Set down 15K two times. P/U and line up tool face high side, pump @ 2 bpm and attempt to slack-off.Attempt to slack-off w/5 rpm's and no pump, no success. Attempt to rotate @ 5 rpm's, pump @ 2 bpm, no success. Increase rotary to 60 rpm's and pump @ 2 bpm, no success. Unable to work past 1647'MD. Page 4 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:45 0.75 1,647 1,662 SURFA( CASING DDRL T Attempt to re-enter wellbore by pumping @ 300 gpm=950 psi, 60 rpm's,Tq=4K, 10K WOB.All inductions point that new hole was drilled to 1662'MD. P/U to 1640'MD, had to set down 20K to get past 1647'MD. 05:45 06:45 1.00 1,662 1,662 SURFA( CASING CIRC T P/U and work pipe, pump @ 2 bpm=200 psi, P/U=96K, S/O=90K. Discuss options with town. 06:45 09:30 2.75 1,662 1,793 SURFA( CASING DDRL T Slide 10L f/1662'MD to 1698'MD, pump @ 450 gpm=850 psi,63% flow. Perform Gyro survey, Gyro tool 8'into sidetrack. Data showed we are 1/2° low and 1° R of original wellbore. Slide @ 40L f/1698' MD to 1750' MD to attempt to intersect original wellbore. Shoot Gyro survey @ 1750'MD, Drill ahead f/1750'MD to 1793'MD, pump @ 500 gpm, 1000 psi,63%flow,60 rpm's,6K _ _ Tq. 09:30 11:15 1.75 1,793 1,515 SURFA( CASING REAM T BROOH @ 510 gpm=850=1050 psi, 60 rpm's f/1793'MD to 1603'MD, observed high and erratic torque @ 1647' MD. Shut down rotary and pumps,worked though trouble zone @ 1647' MD multiple times,good. POOH to 1515' MD on elevators. 11:15 11:30 0.25 1,515 1,790 SURFA( CASING TRIP T Trip in to hole f/1515' MD to 1790' _ MD. No tight hole observed. 11:30 12:00 0.50 1,790 1,790 SURFA( CASING SRVY T Survey hole, Discuss plan forward to re-drill surface hole f/1647' MD to TD 12:00 13:30 1.50 1,790 1,882 SURFA( CASING DDRL T Directional drill from 1790' MD to 1882'MD, 1802'TVD. P/U=100k, S/0=89k, ROT=95k,Tq on/off=6/4k ft lbs,WOB=10-25k, ECD=10.18, 62%Flow out, 60 rpm, 500 gpm @ 1150 psi. 13:30 15:00 1.50 1,882 1,882 SURFA( CASING SRVY T POOH from 1882'- 1697' MD,taking MWD surveys at 1759', 1744', 1697' MD.Wash back to 1882'MD& consult with town to drill ahead to obttain wellbore seperation. 15:00 18:00 3.00 1,882 2,160 SURFA( CASING DDRL T Directional drill from 1882'MD to 2160' MD,2025'TVD.ART=1.58, AST=2.11,ADT=3.69,Jar Hrs=61.67, Bit Hrs=37.97, P/U=103k, S/O=89k, ROT=95k, Tq on/off=6/3k ft lbs,WOB=5-30k, ECD=10.35, 71% Flow out, 60 rpm, 648 gpm @ 1600 psi. Page 5of34 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:45 3.75 2,160 2,344 SURFA( CASING DDRL T Directional drill from 2160' MD to 2344' MD, 2161'TVD.ART=.38, AST=1.41,ADT=1.79, Jar Hrs=63.46, Bit Hrs=39.76, P/U=106k, S/0=90k, ROT=97k,Tq on/off=5/2k ft lbs,WOB=5-30k, ECD=10.21,71%Flow out, 60 rpm, 651 gpm @ 1650 psi. 21:45 23:00 1.25 2,344 2,344 SURFA( CASING SFTY T Remove ice build up from derrick. 23:00 00:00 1.00 2,344 2,380 SURFA( CASING DDRL T Directional drill from 2344' MD to 2380'MD, 2161'TVD.ART=O, AST=1,ADT=1, Jar Hrs=64.45, Bit Hrs=40.75, P/U=106k, 5/0=90k, ROT=97k, Tq on/off=8/4k ft lbs, WOB=5-25k, ECD=10.28, 71% Flow out, 70 rpm,650 gpm @ 1650 psi. 05/30/2014 While drilling at 2380'MD,encounter a hard spot.While trying varying parameters to make it drill, noticed indications that we might be hanging up on a stabilizer up the string. Racked back a stand and reamed 2349'-2257'MD.Tagged up at 2305'on second full ream. Made several attempts to re-enter hole without pumps. Lined up tool face directionally and stacked 35k on string,with pumps and slid ahead with no differential psi into well bore. Reamed clean and confirmed position with survey. Drilled to TD, from 2383'-3555' MD,2882 TVD. CBU 3X&OWFF 30 min. 00:00 00:30 0.50 2,380 2,383 SURFA( CASING DDRL T Directional drill from 2380' MD to 2383'MD, 2161'TVD.ART=.5, AST=0,ADT=.5,Jar Hrs=66.10, Bit Hrs=42.40, P/U=106k, 5/0=90k, ROT=97k,Tq on/off=5/4k ft lbs, WOB=5-30k, ECD=10.21, 71% Flow out,60 rpm,650 gpm @ 1650 00:30 02:30 2.00 2,383 2,383 SURFA( CASING DDRL T No progress making hole.Try varying parameters 40-70 rpm, 5-35k WOB, 650 gpm, 1650 psi,with no success. Conditions indicated stab was hanging up a stand up the hole. 02:30 03:30 1.00 2,383 2,305 SURFA( CASING REAM T Rack one stand back and ream from 2349'-2257' MD. On second ream down tagged up at 2305'MD. Made several attempts to get back into hole with no pumps on(stacking weight&lining up tool face). Pick up away from tag point and shoot survey to confirm location. 03:30 05:45 2.25 2,305 2,383 SURFA( CASING REAM T Line up tool face for directional and slide from 2305-2349'MD, stacking 30k WOB,650 gpm, 1500 psi. Observed no differential psi while sliding. Shot survey to confirm correct position. Reamed from 2300'-2383' MD(650 gpm, 1500 psi, 60 rpm, 3-9k tq.)&shot survey to confirm correct position. Page 6 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 12:00 6.25 2,383 2,665 SURFA( CASING DDRL T Directional drill from 2383'MD to 2665' MD,2368'TVD.ART=1.60, AST=2.52,ADT=4.12,Jar Hrs=72.15, Bit Hrs=48.45, P/U=111 k, 5/0=86k, ROT=96k, Tq on/off=7/4k ft lbs,WOB=15-20k, ECD=10.42,60% Flow out, 60 rpm, _ 650 gpm @ 1680 psi. 12:00 18:00 6.00 2,665 3,238 SURFA( CASING DDRL T Directional drill from 2665'MD to 3238' MD,2696'TVD.ART=2.94, AST=1.33,ADT=4.27,Jar Hrs=76.42, Bit Hrs=52.72, P/U=115k, 5/0=91k, ROT=99k, Tq on/off=8/4k ft lbs,WOB=25-30k, ECD=10.64,69% Flow out, 80 rpm, 670 gpm @ 1900 psi. 18:00 21:30 3.50 3,238 3,555 SURFA( CASING DDRL T Directional drill from 3238'MD to 3555' MD,2883'TVD.ART=1.98, AST=0,ADT=1.98,Jar Hrs=78.40, Bit Hrs=54.70, P/U=120k, S/0=94k, ROT=100k,Tq on/off=8/5k ft lbs, WOB=15-20k, ECD=10.50, 70% Flow out, 80 rpm,700 gpm @ 2200 psi. 21:30 23:30 2.00 3,555 3,555 SURFA( CASING CIRC T CBU 3X with rotation and recipication. 720 gpm,2200 psi, 80 rpm, 5-6k Tq, PU 120K, SO 91K, & ROT 101K. 23:30 00:00 0.50 3,555 3,555 SURFA( CASING OWFF T Monitor well,static 05/31/2014 BROOH from 3555-1886' MD.At 2534'MD a large amount of clay exceeded the capacity of our surface equipment. Shut down to clear. POOH on elevators from 1886'-1515 MD. RIH from 1515'-3460'MD. CBU 3X& OWFF. POOH to surface laying down BHA. Flushed stack of clay and made a dummy run with the hanger. Rigged up Tesco casing equipment. Made up shoe and float equipment. 00:00 00:30 0.50 3,555 3,365 SURFA( CASING TRIP T PJSM,Attempt to POOH on elevators, pull 2 stands, pulling tight w/30K OP @ 3365'MD. Decision made to BROOH. 00:30 02:15 1.75 3,365 2,534 SURFA( CASING REAM T BROOH f/3365'MD to 2534'MD. Pump @ 650 gpm= 1800 psi, rotate @ 60 rpm's w/5-6K Tq, 1200 fph string speed. 02:15 05:45 3.50 2,534 2,534 SURFA( CASING OTHR T Cuttings over loaded the flow line and riser, large clay/gravel balls packed off the flow line. Unpack flow line and riser. 05:45 07:30 1.75 2,534 1,886 SURFA( CASING REAM T BROOH f/2534'MD to 2164'MD. Pump @ 650 gpm= 1800 psi, rotate @ 60 rpm's w/5-6K Tq, 1200 fph string speed. Slow back reaming speed to 4.5 fpm @ 2164', CBU x 2 to 1886'MD.Actual displacement= 17 bbls, Calculated displacement= 11.7 bbls. Page 7 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 1,886 1,515 SURFA( CASING WPRT T POOH on elevators f/1886' MD to 1515 MD. No overpull observed. Actual displacement=7.14 bbls, Calculated displacement=3.9 bbls. 08:00 08:15 0.25 1,515 1,880 SURFA( CASING WPRT P RIH from 1515'-1880'MD. 08:15 09:15 1.00 1,880 1,880 SURFA( CASING SFTY P Remove ice from derrick. 09:15 10:00 0.75 1,880 3,460 SURFA( CASING WPRT P RIH from 1880'-3460' MD. Smooth trip no problems. Calculated displacement 19.5,actual displacement 20.86. 10:00 10:15 0.25 3,460 3,555 SURFA( CASING REAM P Wash and ream from 3460'-3555' MD,450 gpm, 1250 psi,60 rpm,Tq 5-6K, PU 105K, SO 80K. 10:15 12:15 2.00 3,555 3,450 SURFA( CASING CIRC P CBU 3X @ 650 gpm, 1650 psi, FO 74%, 60 rpm, Tq 5-6K. Lay down single and rack back a stand at each BU. 12:15 12:45 0.50 3,450 3,450 SURFA( CASING OWFF P Monitor well, static. 12:45 15:00 2.25 3,450 790 SURFA( CASING TRIP P POOH on elevators from 3450'-790' MD, PU 117K, SO 90K. Calculated displacement 40.86, actual 65.11 bbls. 15:00 16:00 1.00 790 219 SURFA( CASING TRIP P Stand back HWDP. 16:00 18:30 2.50 219 0 SURFA( CASING PULD P Lay down BHA as per SLB DD. 18:30 20:00 1.50 0 0 SURFA( CASING RURD P Clear BHA from floor and clean up. 20:00 21:15 1.25 0 0 SURFA( CASING RURD P Flush&drain stack. Make dummy run with hanger. 21:15 23:00 1.75 0 0 SURFA( CASING RURD P Rig up Tesco casing equipment. 23:00 00:00 1.00 0 123 SURFA( CASING RNCS P PJSM, make up shoe joint and float equipment. 06/01/2014 RIH with 10 3/4"casing from 123'-720' MD. Started losing returns&could not establish circulation. Decision made to lay down casing till circulation could be established. Bowspring centralizers packed with clay. Stage up pumps and RIH washing each joint down from 123'-3505'MD,stopping several time to CBU&de-ice derrick. Make up hanger&landing joint. Land casing @ 3542'MD.After laying down Tesco CRT&making up cement head could not pick up string. Circulate&condition for cement job. 00:00 00:15 0.25 123 123 SURFA( CASING RNCS P Test float equipment,good. 00:15 02:00 1.75 123 720 SURFA( CASING RNCS P RIH with 10.75"casing from 123'-720' MD. Returns lost to hole and could not establish circulation. Decision made to POOH and establish circulation. 02:00 04:15 2.25 720 123 SURFA( CASING RNCS T POOH from 720'-123'MD. Bowspring centralizers packed with clay. 04:15 04:45 0.50 123 123 SURFA( CASING CIRC T Establish circulation staging the pumps up to 4.5 bpm, 100 psi, FO 45%. 04:45 07:00 2.25 123 720 SURFA( CASING RNCS T RIH from 123'-720' MD,4 bpm, 100psi,45%FO. 07:00 08:30 1.50 720 1,040 SURFA( CASING RNCS P RIH from 720'-1040' MD. Reduce pump rate and running speed to 3 bpm, 75 psi, FO 35%, 180 fph. Page 8 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:00 0.50 1,040 1,040 SURFA( CASING CIRC P CBU staging up pump rate 3-5 bpm, 75-150 psi, FO 35-54%. 09:00 11:00 2.00 1,040 1,802 SURFA( CASING RNCS P RIH from 1040'-1802'MD, 5 bpm, 150 psi, FO 54%. 11:00 12:00 1.00 1,802 1,802 SURFA( CASING CIRC P CBU @ 5 bpm,210 psi, 54%FO, PU 100K, SO 72K. Losses for tour 295 bbls. 12:00 14:45 2.75 1,802 2,685 SURFA( CASING RNCS P RIH from 1802'-2685'MD,5 bpm, 200 psi. 14:45 15:45 1.00 2,685 2,685 SURFA( CASING SFTY P Remove ice from derrick. Circulate @ 5 bpm =200 psi. 15:45 16:00 0.25 2,685 2,740 SURFA( CASING RNCS P RIH from 2685'-2740'MD, 5 bpm, 200 psi. 16:00 16:45 0.75 2,740 2,740 SURFA( CASING SFTY P Remove ice from derrick, circulate 5 bpm, 250 psi. 16:45 19:15 2.50 2,740 3,505 SURFA( CASING RNCS P RIH form 2740'-3505'MD, 5 bpm, 300 psi. 19:15 21:15 2.00 3,505 3,505 SURFA( CASING CIRC P CBU @ 5 bpm, 300 psi, PU 160K, SO 103K. Pick up cement head& long bales. 21:15 22:45 1.50 3,505 3,542 SURFA( CASING RNCS P Make up hanger&landing joint. Land hanger @ 3542'MD. Lay down Tesco CRT&make up cement head. Calculated displacement 33.05, actual 79.52 bbls. 22:45 00:00 1.25 3,542 3,542 SURFA( CEMEN-CIRCP Circulate&condition mud for cement. Stage up pumps 2-5 bpm, 150-300 psi.Attempt to ricpicate string. Pull 100k over,decision made to leave landed. Losses for tour 127 bbls 06/02/2014 Circulated&conditioned mud for cement job. Cemented 10.75"surface casing as per program, CIP @ 05:00 hrs. Flush stack with retarder pill. Nipple down surface&diverter equipment. Nipple up, orient&test wellhead to 1000 psi for 10 min. Nipple up casing spool&BOPE. Rig up&test BOPE 250/3500 psi, for 5 minutes each. Completed 6 out of 10 tests at 24:00 hrs.Test waived by AOGCC Rep.Jeff Jones. 00:00 01:15 1.25 3,542 3,542 SURFA( CEMEN-CIRC P Circulate&condition mud for cement staging pumps up 6-7 bpm, 300-400 psi, FO 49-54%. Slight losses at 7 bpm. 01:15 01:30 0.25 3,542 3,542 SURFA( CEMEN-SFTYP PJSM with all involved parties for cement job. 01:30 05:15 3.75 3,542 3,542 SURFA( CEMEN-CMNT P Pump 5 bbl of water to flood lines. Test cement lines 550&3000 psi. Rig pumps 100 bbls of 10.5 ppg MudPush @ 5 bpm=200 psi. Drop bottom plug. SLB pumped 460 bbls 11.02 ppg of ALC @ 6 bpm=250 psi. SLB pumped 57 bbls of 12 ppg tail cement @ 5 bpm=330 psi. Drop top plug&SLB pumped 10 bbls of water to flush lines. Swap to rig&pump 316 bbls of mud @ 7 bpm=600 psi, to bump top plug. Pressure up to 1100 psi for 5 min, bled off to check floats(good). CIP @ 05:00 hrs. 178 bbls of cement to surface. Page 9 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 06:15 1.00 3,542 3,542 SURFA( CEMEN'RURD P Flush out stack with cement retarder pill. Rig down cement head&landing joint. 06:15 07:15 1.00 3,542 3,542 SURFA( CEMEN"SFTY P Remove ice from derrick. 07:15 12:00 4.75 3,542 3,542 SURFA(WHDBO NUND P Function and wash out surface annular. Nipple down diverter equipment. Sim-op clear floor of casing running tools. 12:00 13:00 1.00 3,542 3,542 SURFA( WHDBO NUND P Prep&install wellhead as per FMC rep. 13:00 14:30 1.50 3,542 3,542 SURFA( WHDBO NUND P Orient&verify wellhead with pad operator. Torque&test well head to 1000 psi for 10 min. 14:30 17:00 2.50 3,542 3,542 SURFA( WHDBO NUND P Nipple up casing spool& BOPE. 17:00 18:00 1.00 3,542 3,542 SURFA(WHDBO NUND P Change out lines on annular&install riser. 18:00 18:45 0.75 3,542 3,542 SURFA(WHDBO NUND P Clear and clean rig floor&cellar. 18:45 20:00 1.25 3,542 3,542 SURFA(WHDBO RURD P Rig up BOPE test equipment. 20:00 00:00 4.00 3,542 3,542 SURFA(WHDBO BOPE P Test BOPE with 5"joint 250/3500 psi,for 5 min each.#1 top VBR's; CV's 1,12,13,14; Manual Kill Line Valve.#2 Upper IBOP; CVs 9, 11; HCR Kill.#3 Lower IBOP; CV's 5,8,10.#4 Dart valve; CV's 4,6,7.#5 FSV; CV 2.#6 HCR Choke&4"Kill Line Demco Valve. AOGCC Jeff Jones waived on 6-1-14 @ 19:10 hrs. 06/03/2014 Finish testing BOPE&rig down. Pick up and stand back 111 joints of 5"DP. Pick up and make up BHA 3. Single in the hole with BHA 3 to 3404'. CBU&test casing to 3000 psi for 30 min. Drill out float equipment, shoe&20'of new hole to 3575'MD. CBU&rack back one stand. Rig up&perform LOT to a 14.0 ppg EMW. Shut in pressure, bled down to 190 psi. Confer with town and decide to perform second test. LOT to 13.4 ppg EMW. Shut in pressure bled down to 115 psi. Confer with town,decide to POOH to RIH&squeeze cement. Monitor well& POOH from 3401'-1100'MD. 00:00 01:45 1.75 3,542 3,542 SURFA(WHDBO BOPE P Test BOPE with 5"joint 250/3500 psi,for 5 min each.#7 Manual Choke Vavle&HCR Kill.#8 Annular Preventer.#9 Lower VBR's.#10 Blind Rams&CV 3.Accumulator Test: Initial System Psi=2900 psi; After Closure= 1650 psi;200 psi Attained=40 sec; Full psi Attained = 188 sec. 5 Nitrogen bottles averaged 2150 psi.Test waived by AOGCC Jeff Jones waived on 6-1-14 @ 19:10 hrs. 01:45 02:45 1.00 3,542 3,542 SURFA(WHDBO RURD P Rig down test equipment, blow down TD&all lines. Install wear ring 10.125". 02:45 03:15 0.50 0 0 SURFA( CEMEN-RURD P Mobilize tools to rig floor&install mouse hole. 03:15 06:30 3.25 0 0 SURFA( CEMEN'PULD P Pick up 111 joints(37 stands)&rack back in the derrick. Page 10 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:00 0.50 0 0 SURFA( CEMEN'RURD P Clear&clean rig floor. Mobilize BHA to rig floor. 07:00 09:00 2.00 0 724 SURFA( CEMEN'PULD P Pick up&make up BHA 3, as per SLB DD. 09:00 09:45 0.75 724 724 SURFA( CEMEN-DHEQ P Shallow pulse test MWD&Power Drive @ 470 gpm, 975 psi, FO 53%. 09:45 10:15 0.50 724 724 SURFA( CEMEN-SVRG P Service Rig 10:15 12:45 2.50 724 3,404 SURFA( CEMEN PULD P Single in the hole from 724'-3404', calculated displacement 28.2; actual 22.4 bbls. 12:45 13:45 1.00 3,404 3,404 SURFA( CEMEN CIRC P CBU @ 500 gpm = 1300 psi. 13:45 14:15 0.50 3,404 3,404 SURFA( CEMEN'RURD P Rig up to test casing. 14:15 14:45 0.50 3,404 3,404 SURFA( CEMEN-PRTS P Test 10 3/4"surface casing to 3000 psi for 30 min. 14:45 15:15 0.50 3,404 3,455 SURFA( CEMEN COCF P Wash&ream from 3404'-3455' MD, 475 gpm, 1200 psi, 30 rpm, 6-10K Tq, PU 112K, SO 82K, ROT 92K. 15:15 18:00 2.75 3,455 3,462 SURFA( CEMEN DRLG P Drill out float equipment from 3455-3462' MD,475 gpm, 1200 psi, 20-50 rpm,6-10k Tq,WOB 10-20K. 18:00 19:30 1.50 3,462 3,575 SURFA( CEMEN DRLG P Drill cement, shoe, &20'of new hole from 3462'-3575'MD, 550 gpm, 1700 psi, 50-60 rpm,Tq 5-8K,WOB 5-12 K. 19:30 20:00 0.50 3,575 3,501 SURFA( CEMEN CIRC P CBU 550 gpm, 1600 psi, PU 120K, SO 82K, ROT 82K,80 rpm,5-8k Tq. Rack a stand back. SPR @ 3501'MD 2869'TVD, MW 9.8 ppg, 22:15 hrs. #1 @30= 130; @ 40=220 #2 @ 30= 140; @ 40=220 20:00 20:15 0.25 3,501 3,501 SURFA( CEMEN-RURD P Rig up test equipment for LOT. 20:15 22:00 1.75 3,501 3,501 SURFA( CEMEN'LOT P Perform LOT to 14.0 ppg EMW. Shut in pressure bled down to 190 psi. Confer with town and decide to perform second test. LOT to 13.4 ppg EMW. Shut in pressure bled down to 115 psi. Confer with town, decide to POOH to RIH&squeeze cement. 22:00 22:30 0.50 3,501 3,501 SURFA( CEMEN OWFF T Monitor well, static. 22:30 00:00 1.50 3,501 1,100 SURFA( CEMEN-TRIPT POOH from 3501'-1100' MD, PU 60K, SO 59K. Calculated displacement 15, actual 17.68 bbls. 36/04/2014 Finish POOH to surface. Rig up and test with 3.5"test joint. Rig up&pick up-900'of 3.5"tubing. RIH with tubing on 5"DP to 3575'MD. Lay 200'cement plug around casing shoe, POOH to 3000'MD&squeeze. POOH from 3000'-970'MD. Lay down tubing from 970'-538'MD. 00:00 00:15 0.25 1,100 724 SURFA( CEMEN-TRIPT POOH from 1100'-724'MD. Monitor well, static 00:15 01:00 0.75 724 0 SURFA( CEMEN PULD T Rack back HWDP, DC, BHA 3. Lay down stab&bit. Calculated displacement 23.67, actual 23.46 bbls. Page 11 of 34 Time''Logs Date `- From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:15 0.25 0 0 SURFA( CEMEN-RURD T Clear&clean rig floor. 01:15 01:30 0.25 0 0 SURFA( CEMEN-BOPE T Drain stack, pull wear bushing, & R/U to test 3.5"tubing. 01:30 03:30 2.00 0 0 SURFA( CEMEN-BOPE T Test 3.5"joint to 250/3500 psi for 5 min each test.Annular, upper& lower VBR's were tested. 03:30 04:00 0.50 0 0 SURFA( CEMEN'BOPE T Rig down test equipment,drain stack, install 10.125"wear bushing. 04:00 05:00 1.00 0 0 SURFA( CEMEN"RURD T Rig up tubing handling equipment. 05:00 06:30 1.50 0 939 SURFA( CEMEN-PULD T Pick up&RIH 3.5"8rd EUE tubing from surface to 939'MD. 06:30 06:45 0.25 939 939 SURFA( CEMEN'RURD T Change out handling equipment to 5". 06:45 08:15 1.50 939 3,531 SURFA( CEMEN-TRIP T RIH from 939'-3531' MD, rig up cement lines. Calculated displacement 25.02, actual 21.7 bbls. 08:15 09:15 1.00 3,531 3,575 SURFA( CEMEN CIRC T Wash down from 3531'-3575'MD& condition mud for cement @ 7 bpm, 525 psi, FO 40%. 09:15 12:45 3.50 3,575 3,575 SURFA( CEMEN'OTHR T Wait on SLB cementers. 12:45 15:30 2.75 3,575 3,575 SURFA( CEMEN-RURD T Rig up cementer&condition mud 300 gpm,400 psi. 15:30 15:45 0.25 3,575 3,575 SURFA( CEMEN-RURD T SLB pump 3 bbls H2O, psi test cement lines 400&2500 psi. 15:45 16:30 0.75 3,575 3,575 SURFA( CEMEN'CMNT T SLB Batch up&pump 13.4 bbls of 10.5 ppg MudPush, 18.7 bbls of 15.8 cement, &3 bbls of 10.5 MudPush to clear lines. Swap to Rig pumps and chase with 47 bbls of 9.7 ppg mud. 16:30 17:15 0.75 3,575 3,000 SURFA( CEMEN-TRIPT POOH from 3575-3000'MD, running speed 3 min per stand. 17:15 17:30 0.25 3,000 3,000 SURFA( CEMEN-CIRCT Circulate pipe volume at 250 gpm, 130 psi. 17:30 17:45 0.25 3,000 3,000 SURFA( CEMEN-RURD T Rig up head pin,valves, &cement _ line for squeeze job. 17:45 19:30 1.75 3,000 3,000 SURFA( CEMEN'SQEZ T Pressure up well bore to 500 psi& shut in. Bring psi back up from 250 to 500 psi&shut in several times. Confer with town and decide to psi up to 600 psi and shut in for 10 min, pressuring back up every 10 min. This was repeated till cement thickening time reached a 70 Bc.6 bbls of cement squeezed away, 1/2 barrel bled back after pressure release. 19:30 20:30 1.00 3,000 3,000 SURFA( CEMEN-CIRCT CBU @ 500gpm, 500 psi, PU 80K, SO 68K 20:30 20:45 0.25 3,000 3,000 SURFA( CEMEN-OWFF T Monitor well, static. 20:45 22:15 1.50 3,000 970 SURFA( CEMEN-TRIPT POOH from 3000'-970'MD. 22:15 22:45 0.50 970 970 SURFA( CEMEN-RURD T Change out handling equipment from 5"to 3.5". Page 12 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 970 538 SURFA( CEMEN-PULD T Lay down 3.5"tubing from 970'-538' MD 06/05/2014 RIH with BHA 4. Tag TOC©3457' MD&cleaned out cement to 3575'MD. Perform FITto EMW 14.7 ppg. Drill 20'of new hole and perform LOT to EMW 14.3 ppg. Drill ahead from 3595'-4517'MD. 00:00 00:30 0.50 538 0 SURFA( CEMEN-PULD T Lay down 3.5"tubing from 538'- surface. 00:30 01:30 1.00 0 0 SURFA( CEMEN"RURD T Rig down tubing handling equipment, clear&clean rig floor. 01:30 02:00 0.50 0 0 SURFA( CEMEN-EQRP T Change out SLB psi sensor on gooseneck of standpipe. 02:00 03:00 1.00 0 724 SURFA( CEMEN'PULD T Make up bit&down load MWD. Pick up stab& RIH with remaining BHA, as per SLB Rep. 03:00 03:15 0.25 724 724 SURFA( CEMEN DHEQ T Shallow pluse test MWD,450 gpm, 925 psi, FO 55%, as per SLB Rep. 03:15 04:00 0.75 724 3,127 SURFA( CEMEN-TRIPT RIH from 724'-3127'MD, fill pipe evey 20 stands. Calculated displacement 37.71, actual 33.6 bbls. 04:00 04:30 0.50 3,127 3,127 SURFA( CEMEN WOC T Wait on cement to reach 500 psi compressive strength. 04:30 05:15 0.75 3,127 3,457 SURFA( CEMEN-WASH T Wash down from 3127'-3457'MD, 2 bpm,250 psi, FO 36%.Tagged TOC @ 3457', set 10k down weight. 05:15 06:30 1.25 3,457 3,457 SURFA( CEMEN CIRC T CBU,450 gpm, 1350 psi 40 rpm,Tq 6k. Slow pumps to 278 gpm, 550 psi to handle thick cement contaminated mud coming back. 06:30 07:45 1.25 3,457 3,575 SURFA( CEMEN'DRLG T Drill out cement plug from 3457'-3575'MD, 350-400 gpm, 775-975 psi, FO 80-85%,40 rpm, Tq 6K. 07:45 08:15 0.50 3,575 3,501 SURFA( CEMEN CIRC T Circulate&condition @ 464 gpm, 1200 psi, FO 72%,40 rpm,Tq 6K. Rack back one stand. 08:15 08:30 0.25 3,501 3,501 SURFA( CEMEN RURD T Rig up test equipment for FIT. 08:30 09:30 1.00 3,501 3,501 SURFA( CEMEN'FIT T Preform FIT to a EMW of 14.7 ppg. R/D test equipment. 09:30 10:00 0.50 3,501 3,595 SURFA( CEMEN'DDRL T Make up stand&drill from 3575-3595'MD, 550 gpm, 1650 psi, FO 77%, 60 rpm,Tq 7K, PU 117K, SO 83K, ROT 90K. 10:00 10:30 0.50 3,595 3,595 SURFA( CEMEN-CIRC T CBU @ 550 gpm, 1600 psi,40 rpm, Tq 6K. 10:30 11:30 1.00 3,595 3,595 SURFA( CEMEN LOT T Perform LOT to a EMW of 14.3 ppg. 11:30 12:00 0.50 3,595 3,595 INTRM1 DRILL RURD T Rig down test equipment, blow down lines, &clear rig floor. 12:00 12:45 0.75 3,595 3,595 INTRM1 DRILL CIRC P Displace wellbore to a 9.6 ppg LSND mud system 500 gpm, 1000 psi. 12:45 18:00 5.25 3,595 4,051 INTRM1 DRILL DDRL P Directional drilling from 3595'-4051' MD, 3175'TVD,ART=3.49,ADT 3.49,Jars 35.76, Bit 3.49, PU 115K, SO 91 K, ROT 105K, Tq on 6-10K, off 4-5K, ECD no info, FO 69%,WOB 10-12K, 130 rpm, 550 gpm, 129 spm, 1525 psi. Page 13 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 4,051 4,517 INTRM1 DRILL DDRL P Directional drilling from 4051'-4517' MD, 3441'TVD,ART=4.53,ADT 4.53, Jars 40.29, Bit 8.02, PU 117K, SO 93K, ROT 105K,Tq on 6-7K,off 4-5K, ECD 11.2, FO 70%,WOB 10-12K, 130 rpm, 575 gpm, 135 spm, 1700 psi. 06/06/2014 Directional drilled from 4517'-6431'MD,4546'TVD. Observed a drilling break @ 6277'MD,4457'TVD,with 35 bbls loss. Shut down to monitor well. Observe well flowing, perform wellbore breathing test. 30 bbls returns with flow decreasing to nothing. Observe wellbore breathing on connections,verify flow steadily decreases. 00:00 06:00 6.00 4,517 5,165 INTRM1 DRILL DDRL P Directional drilling from 4517' MD to 5165 MD, 3815'TVD,ART=4.03, ADT 4.03,Jars 44.32, Bit Hrs 12.05, PU 122K, SO 104K, ROT 113K,Tq on 7-8 K, off 2-3 K, ECD 11.73, FO 72%,WOB 10-15K, 140 rpm, 590 gpm, 138 spm, 2020 psi. 06:00 12:00 6.00 5,165 5,592 INTRM1 DRILL DDRL P Directional drilling from 5165 MD to 5592' MD,4061'TVD,ART=3.42, ADT 3.42, Jars 47.74, Bit Hrs 15.47, PU 134K, SO 115K, ROT 118K, Tq on 5-6 K, off 2-3 K, ECD 11.78, FO 70%,WOB 10-15K, 140 rpm, 594 gpm, 138 spm,2125 psi. SPR's 5535' MD,4028'TVD, MW=10.0 ppg, 11:15hrs #1 @ 30=300, @40=370 psi #2 @ 30=300, @40=390 psi 12:00 20:00 8.00 5,592 6,279 INTRM1 DRILL DDRL P Directional drilling from 5592' MD to 6279'MD,4351'TVD,ART=5.54, ADT 5.54,Jars 51.68, Bit Hrs 19.41, PU 135K, SO 114K, ROT 122K, Tq on 5-9 K, off 2-4 K, ECD 11.99, FO 70%,WOB 10-15K, 130 rpm, 595 gpm, 139 spm, 2250 psi. SPR's 5999'MD,4296'TVD, MW 10.0ppg, 17:00hrs #1 @ 30=280, @ 40=370 psi #2@ 30=290, @ 40=350 psi 20:00 21:15 1.25 6,279 6,279 INTRM1 DRILL OWFF T Observed a drilling break @ 6277' MD,4457'TVD, 35 bbl loss, &pump psi decrease. Shut down to monitor well. Observe well flowing, perform wellbore breathing test. 30 bbls returns with flow decreasing to nothing. Decision made to drill ahead and monitor gains&losses very closely. 21:15 00:00 2.75 6,279 6,431 INTRM1 DRILL DDRL P Directional drilling from 6279' MD to 6431'MD,4546'TVD,ART=4.8,ADT 4.8,Jars 54.89, Bit Hrs 22.62, PU 131K, SO 112K, ROT 121K, Tq on 6-9 K, off 3-4 K, ECD 11.71, FO 70%,WOB 10-15K, 130 rpm, 590 gpm, 138 spm,2300 psi. Observe wellbore breathing on connections, verify flow steadily decreases. Page 14 of 34 Time Logs Date From To Dur S. Depth rE Depth Phase Code Subcode T Comment 06/07/2014 24 hr Summary Directional drilled ahead from 6431'-6833'. Observed increasing trend with losses. Pump LCM pill&continue to drill ahead with reduced pump rate to manage losses from 6833'-7800'MD, 5328'TVD. 00:00 04:45 4.75 6,431 6,833 INTRM1 DRILL DDRL P Directional drilling from 6431' MD, 4546'TVD to 6833'MD, 4692 TVD., ART=3.4,ADT 3.4, Jars 58.3, Bit Hrs 26.03, PU 140K, SO 115K, ROT 125K,Tq on 6-8 K,off 5K, ECD 12.01;FO 60%,WOB 10-15K, 130 rpm, 590 gpm, 138 spm, 2400 psi. 04:45 06:30 1.75 6,833 6,833 INTRM1 DRILL CIRC T Circ. Obtain loss rate. 550GPM, 2100PSI, Losses=80 bbl/hr. Mix LCM Pill 06:30 07:45 1.25 6,833 6,833 INTRM1 DRILL CIRC T Pump and spot 67.5 bbl. LCM pill. 5 bpm @ 500 psi. for 1400 stks. Stage up pump to 590 gpm/2500 psi. Loss rate @80 bbl/hr, reduce pump rate to 500gpm/1850 psi. Circ. out LCM pill. 07:45 12:00 4.25 6,833 7,083 INTRM1 DRILL DDRL P Directional drilling from 6833'MD, 4692 TVD to 7083 MD,4923'TVD., ART=3,ADT 3,Jars 61.3, Bit Hrs 29.03, PU 141K, SO 116K, ROT 130K, Tq on 9 K, off 5K, ECD 11.42, FO 49%,WOB 5-10K, 120 rpm, 525 gpm, 122 spm,2000 psi. Average loss rate 14 bbls/hr after LCM pill. SPR@6923'MD,4831'TVD. MW=10.1, 0900 hrs. #1 @ 30 spm=290 psi.40 spm+360 psi #2 @ 30 spm=290 psi.40 spm=390 psi Mud losses for tour=294 bbls 12:00 18:00 6.00 7,083 7,482 INTRM1 DRILL DDRL P Directional drilling from 7083' MD to 7482 MD, 5153'TVD.,ART=4.29, ADT 4.29, Jars 65.59, Bit Hrs 33.32, PU 151K, SO 124K, ROT 134K, Tq on 7-9 K, off 5-6K, ECD 11.16, FO 65%,WOB 4-9K, 120 rpm, 525 gpm, 122 spm, 2025 psi. Monitor breathing every 200'on trip tank for 15 min. Strap every 5 min to ensure flow back is decreasing, measured loss rate in 5 min increments 10 bph to 3 bph in 15 minutes. I _. Page 15of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 7,482 7,800 INTRM1'DRILL DDRL P Directional drilling from 7482' MD to 7800' MD, 5328'TVD.,ADT 3.25, Jars 68.84, Bit Hrs 36.57, PU 153K, SO 127K, ROT 139K, Tq on 9-10 K, off 5-6K, ECD 11.23, FO 65%,WOB 4-7K, 120 rpm, 525 gpm, 122 spm, 2000 psi. Monitor breathing every 200'on trip tank for 15 min. Strap every 5 min to ensure flow back is decreasing, measured loss rate in 5 min increments 14 bph to 2 bph in 15 minutes. SPR's @ 7760' MD, 5313'TVD, MW 10 ppg, 23:00hrs #1 @30=310@40=390 psi #2@30=300@40=390 psi 06/08/2014 Directionally drilled from 7800'to the casing drilling point at 9151' MD, 5951'TVD. Observed a increase in connection gas, decision made to increase MW to 10.4 ppg for trip margin. Pumped a sweep&CBU 3X. Sweep returned to surface at calculated strokes indicating gauged hole. 00:00 06:00 6.00 7,800 8,224 INTRM1 DRILL DDRL P Directional drilling from 7800' MD to 8224'md, 5581'TVD.,ADT 4.93, Jars 73.57, Bit Hrs 41.3, PU 161K, SO 129K, ROT 144K, Tq on 9-10 K, off 5-6K, ECD 11.35, FO 50%,WOB 5-15K, 120 rpm, 525 gpm, 123 spm, 2130 psi. Max gas 102 units 06:00 12:00 6.00 8,224 8,543 INTRM1 DRILL DDRL P Directional drilling from 8224'md to 8543', 5756'TVD., ADT 3.70,Jars 77.27, Bit Hrs 45.0, PU 161K, SO 131K, ROT 145K, Tq on 10-11 K, off 6K, ECD 11.49, FO 52%,WOB 5-10K, 120 rpm, 550 gpm, 129 spm, 2300 psi. Max gas 162 units SPR's @ 8406' MD, 5686'TVD, MW 10.1 ppg, 09:30 hrs #1 @ 30=320 @ 40=400 psi #2 @ 30=320 @ 40=390 psi Kick w/Drilling drill @08:00 hrs. CRT=120 sec. 12:00 18:00 6.00 8,543 8,965 INTRM1 DRILL DDRL P Directional drilling from 8543'-8965' MD, 5902'TVD., ADT 4.6, Jars 81.87, Bit Hrs 49.6, PU 163K, SO 134K, ROT 147K, Tq on 10-11 K, off 6-7K, ECD 11.63, FO 61%,WOB 6-10K, 120 rpm, 550 gpm, 129 spm, 2200 psi. Max gas 199 units SPR's @ 8962'MD, 5901'TVD, MW 10.1 ppg, 18:00 hrs #1 @ 30=370 @ 40=470 psi #2 @ 30=370 @ 40=470 psi Page 16 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:15 3.25 8,965 9,151 INTRM1 DRILL DDRL P Directional drilling from 8965'md to 9151', 5951'TVD.,ADT 2.15,Jars 84.02, Bit Hrs 51.75, PU 164K, SO 134K, ROT 147K, Tq on 10-13 K,off 6-7K, ECD 11.75, FO 64%,WOB 5-10K, 120 rpm, 550 gpm, 129 spm, 2300 psi. Max gas 276 units 21:15 00:00 2.75 9,151 9,151 INTRM1 DRILL CIRC P Weight up mud from 10.1 -10.4 ppg. Pump high vis weighted sweep w/nut plug. Sweep returned on calculated strokes to show hole in guage. CBU 3X @ 550 gpm,2250 psi, 120 rpm, Tq 7k, FO 51%, PU 164K, SO 135K, ROT 148K. Rack back 1 stand when 10.4 ppg went surface to surface. SPR's @ 9151'MD, 5951'TVD, MW 10.4 ppg,23:00 hrs #1 @ 30=370 @ 40=480 psi #2 @ 30=380 @ 40=480 psi 06/09/2014 BROOH to shoe. Circulate hole clean at the shoe. Slip&cut drill line. POOH on elevators&lay down BHA. Pull wear bushing&function test BOPE. Flush stack, recover large portion of 10.75"top plug. Perform dummy run with 7"hanger. 00:00 01:15 1.25 8,966 8,966 INTRM1 CSGDRI OWFF P Observe well @8966' MD.Well static after total of 3 bbls.flowed back 01:15 01:45 0.50 8,966 8,966 INTRM1 CSGDRIOWFF P Observe well. Static 01:45 04:30 2.75 8,966 8,227 INTRM1 CSGDRI REAM P PJSM-BROOH 8,966'MD to 8227' MD. 525 gpm,2150 psi, 120 rpm,8K TQ. PU 165K, SO 130K, Rot 147K 04:30 05:30 1.00 8,227 8,227 INTRM1 CSGDRI CIRC P CBU @ 8,227 MD to lower ECD's and background gas. Rotate and reciprocate. 525 gpm, 2100psi, 120 rpm, TQ 7K 05:30 10:00 4.50 8,227 5,262 INTRM1 CSGDRI REAM P BROOH 8227' MD to 5262' MD. 525 gpm,2150 psi, 120 rpm, 7K TQ. ECD @ 5262' MD=11.90 ppg. 10:00 10:45 0.75 5,262 5,262 INTRM1 CSGDRI CIRC P CBU @ 5,262 MD.to lower ECD's.. Rotate and reciprocate. 500 gpm, 1700psi, 100 rpm,TQ 4K. Reduced ECD to 11.66 ppg. 10:45 12:00 1.25 5,262 4,891 INTRM1 CSGDRI REAM P BROOH 5262'MD to 4891 MD. 525 gpm,1700 psi, 120 rpm, 4K TQ. ECD =11.65 ppg.Actual disp=74 bbls. _Cal. disp=30 bbl's 12:00 14:15 2.25 4,891 3,500 INTRM1 CSGDRI REAM P PJSM. BROOH 4891 MD to 3500' MD. 525 gpm,1700 psi, 120 rpm,4K TQ. . 14:15 15:45 1.50 3,500 3,500 INTRM1 CSGDRI CIRC P Circulate hole clean @ 525 gpm, 1600 psi. Condition mud from 10.7 ppg to 10.4+ppg at shoe. 15:45 16:45 1.00 3,500 3,500 INTRM1 CSGDRISLPC P Slip&cut 84'drill line. (Monitor well on trip tank, 1.75 bbl increase in 5 min, .25 bbl increase in 45 minutes. Well static after 1 hr. 16:45 17:15 0.50 3,500 3,500 INTRM1 CSGDRI SVRG P Service top drive. Page 17 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 19:30 2.25 3,500 724 INTRM1 CSGDRI TRIP P POOH on elevators from 3500'-724' MD, calculated displacement 38.19, actual 56 bbls. Kick w/Tripping CRT=67sec @ 19:00 hrs 19:30 19:45 0.25 724 724 INTRM1 CSGDRI OWFF P Monitor well,flowed back.25 bbls, static after 5 min. 19:45 20:15 0.50 724 170 INTRM1 CSGDRI TRIP P Rack back HWDP. 20:15 22:00 1.75 170 0 INTRMI CSGDRI PULD P Lay down BHA 4, as per SLB DD. 22:00 22:15 0.25 0 0 INTRM1 CSGDRI RURD P Clean and clear rig floor. 22:15 22:30 0.25 0 0 INTRM1 CSGDRI BOPE P Function test rams&annular. Pull wear bushing. 22:30 23:30 1.00 0 0 INTRM1 CSGDRI RURD P Rig up, flush stack, &rig down. 23:30 00:00 0.50 0 0 INTRM1 CSGDRI RURD P Rig up landing joint and hanger. Perform dummy run with 7" intermediate hanger. 36/10/2014 Change upper rams to 7",test upper rams and annular. R/U Tesco CDS and calibrate. P/U Bit,float equipment and 7"26#L-80 TN Blue casing drilling string, RIH to 5091' MD. 00:00 02:00 2.00 0 0 INTRM1 CASING NUND P PJSM-Change upper pipe rams to 7" 02:00 04:45 2.75 0 0 INTRM1 CASING BOPE P PJSM-R/U and test upper pipe rams, 250/3500 psi.Test annular to 250/2500 psi.. Chart test. Sim-ops Tesco Rep rig up torque turn equip. Rig down test equip. 04:45 08:30 3.75 0 0 INTRM1 CASING RURD P PJSM-Rig up Tesco CDS. 08:30 09:00 0.50 0 0 INTRM1 CASING PUTB P Calibrate torque turn, M/U bit and wearsox centralizer joint. 09:00 10:30 1.50 0 48 INTRM1 CASING RNCS T Torque turn graph showed indication of improper makeup.Recalibrate torque turn. Galled collar on bit jt. and pin on wearsox jt. 10:30 12:00 1.50 48 90 INTRM1 CASING RNCS T Lay dn.wearsox jt. Change out collar on bit joint. Used the good box from joint#2 to replace the bad box on joint#1. Picked up a new single wearsox joint#2 and made it up to the original 3 wearsox joint#1. 12:00 14:00 2.00 90 1,718 INTRM1 CASING RNCS P PJSM, M/U shoe track joints, RIH with 7"26#L-80 TN Blue casing to jt 40@1718'MD. 14:00 16:45 2.75 1,718 1,718 INTRM1 CASING CIRC P Circulate surface to surface volume 150 bbl @ 200 gpm,300 psi. P/U=69k, S/0=68k,flow out 40%no losses. 16:45 20:30 3.75 1,718 3,500 INTRM1 CASING RNCS P Continue RIH with 26#TN Blue casing from 1718'MD to 3500' MD. Ran total 48 Hydroform centralizers on joints#3-50. 20:30 22:30 2.00 3,500 3,500 INTRMI CASING CIRC P Circulate surface to surface volume 300 bbl, ICP @ 3 bpm=200 psi, staged up to 300 gpm, 550 psi Flow out=41%. P/U=91k, S/O=84k.. Page 18 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 3,500 5,091 INTRM1 CASING RNCS P Continue RIH from 3500'MD to 5091' MD. P/U=120k, 5/0=100k. Fill pipe every joint,top off every 10 joints. Calc Disp=47.76 bbl,Actual _ Disp=46.44 bbl. 36/11/2014 RIH with 7"26#TN Blue/Hydril 563 string to 9151'MD. Displace to new 11.0 ppg mud and perform LOT to 12.0 ppg(Well breathing). Begin casing drilling from 9151' MD to 9187'MD, losses @ 20 bph. 00:00 01:15 1.25 5,091 5,175 INTRMI CASING CIRC P Continue RIH from 5091'MD to 5175'.MD Brk. circ. Stage pump up to 300 gpm. Circ. surface to surface.Lost 20 bbl's w/circ. Gain back 20 bbl.s after shutting down pump. 01:15 0445 3.50 5,175 6,839 INTRM1 CASING RNCS P Continue RIH w/7"csg.from 5175' MD to 6839'MD. 04:45 07:15 2.50 6,839 6,839 INTRMI CASING CIRC P Brk. circ. Stage pump up to 300 gpm. Circ. surface to surface.Lost 38 bbl's w/circ. Gain back 10 bbl.s after shutting down pump. 07:15 10:45 3.50 6,839 8,358 INTRM1 CASING RNCS P Continue RIH w/7"csg.from 6839' MD to 8358'MD.200 jt's in hole. P/U=185K, S/0=120K.Actual Disp.=66 bbls. Calculated Disp=79 bbls. 10:45 13:30 2.75 8,358 8,358 INTRM1 CASING CIRC P Establish circulation, stage pump up to 300 gpm. 1000 psi. Circ. surface to surface. P/U=170K. S/0=120K. Total losses for tour=25 bbls. 13:30 13:45 0.25 8,358 8,490 INTRM1 CASING RNCS P Continue to RIH with 7"casing from 8358' MD to 8490'MD. Hit tight spot. 13:45 14:45 1.00 8,490 8,520 INTRM1 CASING REAM T Work thru tight spot @ 8490' MD, took 15k down wt.Worked pipe several times, Rotate 15 rpm, pump 2 bpm, stage up to 3.5 bpm,work pipe down to 8520", regained good circulation. 14:45 17:30 2.75 8,520 9,151 INTRMI CASING RNCS P Continue RIH from 8520'MD,wash down last jt to 9151'MD pumping 2 bpm,tagged bottom and set down 5k. P/U=195k, S/O=129k. 17:30 18:45 1.25 9,151 9,151 INTRMI CSGDRI CIRC P Establish circulation @ 2 bpm,425 psi. Stage up to 7 bpm, 300 gpm=1250 psi. Circulate 1 bottoms up, initial condition for mud displacement. 18:45 20:45 2.00 9,151 9,151 INTRM1 CSGDRI CIRC P PJSM, displace well to 11.0 ppg P-vis mud with Torque seal additive for casing drilling. Displace @ 300 gpm, 1250 psi ICP, FCP=1000 psi. Rotate 20 rpm, reciprocate 20'after new mud reached 6200'MD in annulus. Optain SPR's @ 20:40, 11.0 ppg, 9148'MD, 5951'TVD. #1-10 spm=140 psi,20 spm=220 psi #2-10 spm=160 psi,20 spm=260 psi Page 19 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:00 1.25 9,151 9,151 INTRMI CSGDRI LOT P PJSM, lay down jt 219, R/U and perform LOT. Pumped total 15 bbl, pressured up to 175 psi and flatlined. Monitored SIP, bled down to 120 psi and flatlined. Bled back 8.7 bbl. Calculated 12.0 ppg EMW LOT. Discuss results with drilling engineer. 22:00 22:15 0.25 9,151 9,151 INTRM1 CSGDRI RURD P R/D test equipment. 22:15 00:00 1.75 9,151 9,187 INTRM1 CSGDRI DCSG P Casing drill from 9151'MD to 9187' MD, 5960'TVD. Bit hrs=1.75, P/U=185k, S/O=127k, ROT=152k, Tq on/off=15/13k, 37% Flow out, 5-20 WOB,80 rpm, 300 gpm @ 700 psi, Max gas=27. Losses stable at 20 bph,total losses for tour 32.5 bbl. 06/12/2014 Casing drill to 9257'MD, 5980'TVD. Stop drilling due to complete lost circulation while weighting up to 12.5 ppg.Wait on mud,build LCM pills and pump 120 bbl LCM pill, followed by active with 15 ppb. Losses temporarily improved. Re-building pills. 00:00 03:30 3.50 9,187 9,257 INTRMI CSGDRI DCSG P Casing drill from 9187'MD, 5960' TVD to 9257'MD, 5980'TVD.. Bit hrs=2.86, P/U=185k, 5/0=130k, ROT=185k, Tq on/off=12-15/14k, 34%Flow out, 8-18 WOB, 80 rpm, 300 gpm @ 500 psi, Max gas=78 units. 03:30 12:00 8.50 9,257 9,241 INTRM1 CSGDRI COND T Stop drilling due to total loss of returns to surface while weighting up mud to 12.5 ppg. Pull off bottom and reduce pump rate to.5 bpm, 100 psi. Stop rotating. P/U=185K S/O=125K. Loss rate at 50-60 bph. Shut down mud pump and fill hole with trip tank. Losses at 40 bph. L/D 1 jt.7"casing to 9,241 MD.Work string at 100 FPH w/5 RPM,TQ=13K Ordered mud from mud plant while building mud in pits. ROT P/U 156K, ROT S/O 150K. Losses decreasing to 20bph with no pump.Total losses for tour=940 bbls. 12:00 16:00 4.00 9,241 9,241 INTRMI CSGDRI COND T PJSM, Building 100 bbl mud volume in pit 6, Mixing LCM, monitor losses via trip tank to keep annulus full. Reciprocate pipe @ 100 fph, rotate © 10 rpm.Tq=12-13k, P/U=156k, S/O=149k, ROT=154k. Static losses @ 18 bph. 16:00 19:15 3.25 9,241 9,241 INTRM1 CSGDRI COND T Offload 12.5 ppg mud into pits, dilute back to 11.5 ppg. Top off pits, build 20 ppb Torque seal pill in pill pit. Build 100 ppb Mixed LCM(100 ppb total)pill in pit 5.Add treatment of 5 ppb Torque Seal, 5 ppb G-Seal and 3 ppb SafeCarb to pit 6 for chase fluid. Page 20 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 22:00 2.75 9,241 9,241 INTRM1 CSGDRI CIRC T Pump 20 bbl LCM pill from pill pit, followed by 100 bbl 100 ppb pill from pit 5, chase with pit 6 11.5 ppg mud. Pump pills down at 1 bpm, 125 psi 65%loss, stage up to 2.5 bpm 70% loss, 3 bpm 95% loss, reduce rate to 2.5 bpm to place pills. 22:00 23:00 1.00 9,241 9,241 INTRM1 CSGDRI CIRC T Pump pills to bit and up to 4000 stks at 2.5 bpm,65%losses while pumping.At 4000 stks, increase rotation to 80 rpm,flow rate to 200 gpm. Initially 95%losses, pumped to 5700 strokes then backed off rate to 3 bpm. Losses at 65%or 120 bph at 3 bpm, slightly improved from 95% losses pre LCM and reducing mud weight to 11.5 ppg. Mud weight in/out 11.5 ppg. Could not notice any remarkable increase in flow out while pumping. 23:00 23:30 0.50 9,241 9,198 INTRM1 CSGDRI CIRC T Confer with enginner, Shut down pumps and lay down joint#221 to move circulation point. 23:30 00:00 0.50 9,198 9,198 INTRM1 CSGDRICIRC T Continue circulation @ 1 bpm-100 psi while mixing more LCM.Total losses for today=1233 bbl 36/13/2014 Keep casing moving while building high concentration 120 ppb LCM pill, adding 40 ppb LCM to all surface volume. Cut mud weight on surface volume from 11.5 ppg to 10.5 ppg. Begin pumping LCM down hole @ 1 bpm. 00:00 02:00 2.00 9,198 9,198 INTRM1 CSGDRICIRC T Continue circulation @ 1 bpm-100 psi w/no returns at surface. Mixing 50 ppb LCM into active pits. Losses a 02:00 06:00 4.00 9,198 9,198 INTRM1 CSGDRI COND T Shut down pump, reduce rotary to 5 RPM,work string. Fill hole with trip tank, losses at 24 bph. Reduce mud weight in active pit to 11.2 ppg. 06:00 07:30 1.50 9,198 9,198 INTRM1 CSGDRI CIRC T Continue to reduce mud weight to 11.0 ppg. Reciprocate pipe at 9,198 MD. P/U=165K, 5/0=150K.Attempt to regain circulation twice pumping at 2 bpm, 150 psi. No returns to surface, Keep hole full with trip tank. 20 bph losses. 07:30 10:30 3.00 9,198 9,198 INTRM1 CSGDRICIRC T Attempt to break circulation @ 1bpm.No returns to surface. Pumped total of 30bbls. P/U=160K, S/O=145K.Shut down pump. 10:30 12:00 1.50 9,198 9,198 INTRM1 CASING COND T Decision made to reduce mud weight to 10.5 ppg and establish circulation for cement job. Page 21 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 22:00 10.00 9,198 9,198 INTRM1 CASING COND T PJSM, continue to reduce all mud in pits and vacuum trucks to 10.4-10.5 ppg.Adjust additives in Mega Pill-120 ppb, 100 bbl in pit 5. Pit 6 has 400 bbl at 45 ppb total LCM and 10.4+ppg.(SIMOPS unload pipeshed of 7"casing, bring cement head to rig floor) 22:00 00:00 2.00 9,198 9,198 INTRM1 CASING CIRC T Pump 110 bbl Mega Pill 100 ppb LCM from pit 5 @ 1 bpm, 110 psi ICP. FCP @ midnite 210 psi, 5 rpm 14k Tq, 80%losses @ 1 bpm. (SIMOPS load pipe shed with 4"drill pipe) Total losses for the day 540 bbl 36/14/2014 Circulate 10.4 ppg LCM laden mud to regain circulation. Reduce mud weight to 10.4 ppg and regain circulation. Cement 7"casing @ 9247.72' MD. Set and test 7"packoff. Rig down casing equip, R/U to lay down drill pipe. 00:00 07:00 7.00 9,198 9,198 INTRM1 CASING CIRC T PJSM-Chase Mega Pill w/10.5 ppg, mud. Remove trip tank from active system and take returns to pit#5. Monitor returns and increase pump rate to 1.5 bpm,290 psi, 15 rpm, 13-14K tq. Slight returns observed at surface. 90%losses @ 1.5 bpm. Stage pump rate to 2 bpm,490 psi. Losses at 76%. Increase pump rate to 2.5 bpm.300 psi. Losses steadily reduced to<10%as 10.4 ppg mud made it around. LCM had little effect. 07:00 08:30 1.50 9,198 9,198 INTRM1 CASING CIRC T Continue to circ. and cond. mud @9,198 MD.2.5 bpm, 300 psi, 15 rpm, 12-14K tq. Could not heal losses,decision to cement 7"casing @ 9274'MD. 08:30 09:15 0.75 9,198 9,247 INTRM1 CEMEN-CIRC P PJSM-M/U 20'pup jt„ hanger and landing jt. Break circ.Wash down to 9,247 MD. Monitor well while making up hanger. Gained 1 bbl. 09:15 10:30 1.25 9,247 9,247 INTRM1 CEMEN-CIRCP Continue to circulate @ 2.5 bbls,300 psi. Stage up to 4.5 bpm w/full returns., 375 psi. Rig down Tesco bails. 10:30 12:15 1.75 9,247 9,247 INTRM1 CEMEN-RURD P PJSM-Rig down Tesco CDS. R/U long bails, 350T elevators. Ran total of 171 jts.Tenaris Blue,49 jts Hydril 563., lx 20' Hydril 563 pup jt., and hanger. 12:15 14:30 2.25 9,247 9,247 INTRM1 CEMEN-CIRCP Establish circulation @ 1 bpm,stage up to 4.5 bpm 200-450 psi, 36% Flow out @ 4.5 bpm. Obtain SPR's, SIMOPS PJSM on cementing 7" casing. Page 22 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:45 2.25 9,247 0 INTRM1 CEMEN"CMNT P Pump cement job per program, SLB pumped 60 bbl 12.5 ppg MudPushll, 60 bbl 15.8 ppg Class G Tail Cement,followed by 10 bbl water, displace with 342 bbl 10.4 ppg mud with rig. Bump plugs @ 3378 stks, CIP @ 16:28 hrs. FCP=850 psi, held 1350 psi on floats for 5 min and released, floats held. Minimal flow from annulus after shut down, monitor with trip tank until stopped. Lost 22 bbl mud during cement job. Float shoe @ 9247.72' MD, 5976.97' TVD. Double valve float collar @ 9154.8'MD. 16:45 18:15 1.50 0 0 INTRM1 CEMEN-RURD P Rig down cementing equipment, rig down long bails and elevators, remove from floor. 18:15 19:00 0.75 0 0 INTRM1 CEMEN-WWSP P R/U packoff running tool, set packoff, RILDS,torque and remove running tools. 19:00 19:30 0.50 0 0 INTRM1 CEMEN-PRTS P Test packoff to 250/5000 psi, 10 minutes each witnessed by Co Rep. 19:30 21:45 2.25 0 0 INTRM1 CEMEN-RURD P PJSM, C/O 4'%IF"saver sub to 4" XT39, space out grabbers, C/O grabber dies and bell guide. 21:45 23:15 1.50 0 0 INTRM1 CEMEN RURD P PJSM, change out upper 7"rams to 3'/z'X 6"VBR's. 23:15 00:00 0.75 0 0 INTRM1 CEMEN RURD P R/U Short bails and 5"elevators, get tools and equipment ready to L/D 5" DP. SIMOPS-R/U OA for annular flush and FP. 06/15/2014 Perform annular flush and Isotherm freeze protection on 10%"x 7"annulus. Lay down 5"DP. Test BOPE with 3%",4"and 4%"test jts to 250/3500 psi.Annular to 250/2500. P/U 4"drill pipe and stand back 15 stands. 00:00 00:45 0.75 0 0 INTRM1 CEMEN-PULD P PJSM-L/D 5" DP,6 stands of 5" HWDP 00:45 03:00 2.25 0 0 INTRM1 CEMEN FRZP P PJSM-R/U and flush 10 3/4'x7"annulus w/190 bbls H2O. Initial injection rate 1/2 bpm=100 psi. Stage pump up to 4 bpm. Final injection pressure=830 psi. Shut in pressure=600 psi. R/D lines. 03:00 06:00 3.00 0 0 INTRM1 CEMEN-PULD P L/D 5'DP 06:00 06:45 0.75 0 0 INTRM1 CEMEN-PULD P Unload pipeshed 06:45 10:30 3.75 0 0 INTRM1 CEMEN-PULD P Continue to L/D drill pipe. Sim-Ops, PJSM. Spot Little Red,test lines to 2500 psi. Pump 121 bbls of Isotherm NT down OA. Initial rate-1 bpm=500 psi. Final injection rate= 1.5 bpm @ 905 psi. SIP=690 psi. L/D mouse hole, Clear rig floor. 10:30 12:00 1.50 0 0 INTRM1 CEMEN-OTHR P ,Level rig due to pad settling. 12:00 13:45 1.75 0 0 INTRM1 WHDBO RURD P PJSM-Bring tools to rig floor and rig up to test BOPE LPage 23 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 17:45 4.00 0 0 INTRM1 WHDBO BOPE P PJSM-Test BOPE w/4"test jt.Test #1 Upper VBR's, valves 1,12,13,14, manual kill valve,Test#2 upper IBOP, HCR kill,valves 9,11. Test#3 Lower IBOP,valves 5,8,10.Test#4 Dart valve,valves 4,6,7.Test#5 Floor valve,and valve#2.Test#6 HCR choke,4"Demco kill line valve. Test #7 Manual choke, HCR kill.Test#8 annular preventer.Test#9 Lower VBR's. 17:45 19:45 2.00 0 0 INTRM1 WHDBO BOPE P Change test jt. out to 4 1/2".Test #10 Upper VBR's,Test#11 Lower VBR's. Test#12 Annular preventer. Change test jt.to 3 1/2". Test#13 Upper VBR'sa. Test#14 Lower VBR's. Test#16 Annular preventer. Test#16 Blind rams.All tests 250 psi low, 3500 psi high,test annular to 2500 psi high for 5 min's each 19:45 20:15 0.50 0 0 INTRM1 WHDBO BOPE P Accumulator test. System Pressure=2900 psi. Pressure after closed=1600 psi. 200 psi attained=48 sec. Full Pressure attained=209 sec. Nitrogen bottles avg=2025 psi.Test witness waived by Johnnie Hill w/AOGCC on 6/15/14 @ 07:44 hrs. 20:15 21:00 0.75 0 0 INTRM1 WHDBO BOPE P Rig down test equipment, blow down choke, kill and choke lines. set 6.938"wear bushing. 21:00 00:00 3.00 0 0 INTRM1 WHDBO RURD P PJSM, load 8 jts HWDP and jars in pipe shed, strap and process same. P/U BHA components from beaverslide. P/U and rack back 15 stds 4"DP. UD mouse hole. Prep for P/U BHA. 36/16/2014 P/U BHA#6, P/U 4"DP and single in hole, perform casing test to 3000 psi 30 min. Drill out float equipment, cement, EZ case bit, rathole and 10'formation to 9267' MD. 00:00 01:15 1.25 0 106 INTRM1 CEMEN'PULD P PJSM-M/U BHA to 106'MD 01:15 02:15 1.00 106 106 INTRM1 CEMEN-PULD P PJSM-Load nuclear sources 02:15 02:45 0.50 106 200 INTRM1 CEMEN-PULD P PJSM-Continue to make up BHA to 200'MD 02:45 03:45 1.00 200 200 INTRM1 CEMEN-SVRG P Service drawworks,top drive and iron roughneck. 03:45 04:30 0.75 200 478 INTRM1 CEMEN-PULD P Continue to make up BHA to 478' MD 04:30 05:30 1.00 478 1,543 INTRM1 CEMEN-PULD P TIH. Picking up singles from pipe shed to 1543' MD 05:30 06:30 1.00 1,543 1,543 INTRM1 CEMEN-DHEQ P Perform shallow pulse test. @ 1543' MD. 250 gpm, 60 spm, 1500 psi. 06:30 12:00 5.50 1,543 7,288 INTRM1 CEMEN-PULD P Continue TIH, picking up singles from pipe shed to 7288'MD. Fill pipe every 20 stands. OA pressure=250 psi I- Page 24 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 7,288 9,087 INTRM1 CEMEN-PULD P PJSM, Continue single in hole from 7822'MD to 9087'MD. Calc Disp=58.74 bbl,Actual Disp=60.95 bbl. P/U=140k, S/O=88k. 13:30 14:00 0.50 9,087 9,150 INTRM1 CEMEN-WASH P Wash and ream from 9087' MD to 9150'MD @ 200 gpm, 1800 psi,40 rpm, 5K Tq, 34%Flow out. Cement at shakers. 14:00 16:00 2.00 9,150 9,150 INTRM1 CEMEN-CIRC P Circulate and condition mud to even mud weight 10.4 ppg, 200 gpm, 1450 psi, 50 rpm, 7k Tq, 36% Flow out. 16:00 17:30 1.50 9,150 9,150 INTRM1 CEMEN'PRTS P R/U and test casing to 3000 psi for 30 minutes charted, good test. Rig down test equipment. SPR's @ 19:00 hrs, 10.4 ppg 9146' MD/5950'TVD #1-20 spm=480 psi, 30 spm=670 psi #2-20 spm=500 psi, 30 spm=730 psi 17:30 00:00 6.50 9,150 9,267 INTRMI CEMEN DRLG P Drill cement and float equipment from 9150'MD to 9257'MD, formation to 9267'MD/5950'TVD.ART=.52, P/U=137k, S/0=87k, ROT=114k,Tq on/off=9/7k, Flow out=33%, WOB=10k 60 rpm,207 gpm @ 1700 psi. 06/17/2014 Drill to 9277'MD, 5986'TVD and perform 16.0 ppg FIT. Displace to 12.5 ppg LSND Mud, condition and commence drilling 6-1/8"tangent to 9662'MD @ 20-30 fph. Pyrite and siderite streaks. SIMOPS-Pull rig boilers for replacement and prep boiler room for new install. 00:00 01:00 1.00 9,267 9,277 INTRM1 CEMEN-DRLG P Continue drilling 20' new formation to 9277'MD, 5986'TVD,230 gpm, 1900 psi, P/U=148k, S/O=90k, ROT=112k, Tq on/off=10/7k, ADT=.89, Bit Hrs=1.41,Jar Hrs=146.82. Noted slow ROP 10-20 fph when drilling formation. 01:00 02:00 1.00 9,277 9,274 INTRM1 CEMEN-CIRC P CBU @ 9274' MD to clean hole and get even mud weight 10.4 ppg in/out. 230 gpm 1900 psi, Rotate 30 rpm, Tq=9k. 02:00 03:30 1.50 9,274 9,240 INTRM1 CEMEN-FIT P PJSM, R/U test equipment and circulate additional pipe volume @ 230 gpm 1900 psi. Perform FIT to 16.0 ppg, 15 sec SIP 1625 psi. Held flat at 1600 psi after five minutes. 03:30 05:15 1.75 9,240 9,277 PROD1 DRILL CIRC P PJSM,displace well over to 12.5 ppg treated LSND @ 5 bpm, ICP 1900 psi, FCP 2600 psi. 05:15 09:00 3.75 9.277 9,277 PROD1 DRILL CIRC T Circulate and condition mud. Shakers screening out LCM and weight material after displacement. Changed shaker screens to 1 ea-84 mesh on each shaker to keep Barite in the system. Circulate @ 4 bpm, 1700 psi,adding barite to obtain 12.5 ppg in/out prior to drilling ahead. Page 25 of 34 Time Logs Date From To Dur. S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 9,277 9,374 PROD1 DRILL DDRL P Drill from 9277' MD to 9347'MD, 6004'TVD.ADT=2.54, Bit Hrs=3.95, Jar Hrs=149.36, P/U=148k, S/O=90k, ROT=112k, Tq on/off=7/6k, ECD=14.55 ppg EMW, Flow out=38%,WOB=6-8, RPM=100, 230 gpm @ 2700 psi. SPR's @ 9272'MD, 5984'TVD, 12.5 ppg, 08:45 hrs. #1-20 spm=830 psi, 30 spm=1200 psi #2-20 spm=750 psi, 30 spm= 1110 psi 12:00 18:00 6.00 9,374 9,556 PROD1 DRILL DDRL P Directional drill from 9347' MD to 9556' MD, 6042'TVD.ART=5.04, Bit Hrs=8.99, Jar Hrs=154.4, P/U=127k, S/0=94k, ROT=105k, Tq on/off=7/5k, ECD=14.34 ppg EMW, Flow out=36%,WOB=8-15k, RPM=100, 222 gpm @2650 psi, Max Gas=90 units. Intermittant hard streaks of pyrite and siderite slowing ROP. 18:00 00:00 6.00 9,556 9,662 PROD1 DRILL DDRL P Directional drill from 9347'MD to 9662' MD, 6092'TVD.ART=3.54, Bit Hrs=12.53, Jar Hrs=157.54, P/U=130k, 5/O=94k, ROT=108k,Tq on/off=7/5k, ECD=14.43 ppg EMW, Flow out=37%, WOB=10-12k, RPM=100, 225 gpm @2675 psi, Max Gas=452 units at botoms up after connection. Noted increased flow and gas at BU strokes. Flow check on connection-slight but steady flow. Begin slow weight up to 12.7 ppg. SPR's @ 9613' MD, 6076'TVD, 12.5 ppg, 21:00 hrs. #1-20 spm=640 psi, 30 spm=970 psi #2-20 spm=630 psi, 30 spm=980 psi. 36/18/2014 Drill from 9662' MD to TD @ 10127' MD, 6217'TVD. Weight up to 13.1 ppg trip margin. CBU x 2, OWFF. Pump out to shoe @ 2 bpm, 2500 fpm. CBU @ shoe. Continue pump out of hole @ 2 bpm, 2500 fph. Page 26 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 9,662 9,910 PROD1 DRILL DDRL P Directional drill from 9662'MD to 9910'MD, 6159'TVD.ART=10.59, Bit Hrs=23.12,Jar Hrs=168.53, P/U=128k, S/O=80k, ROT=106k,Tq on/off=8/6k, ECD=14.96 ppg EMW, Flow out=36%,WOB=6-13k, RPM=100-120,225 gpm @2900 psi, Max Gas=281 units at bottoms up after connection. SPR's @ 9727'MD,6110'TVD, 12.7 ppg, 02:30 hrs. #1-20 spm=780 psi, 30 spm=1040 psi #2-20 spm=740 psi, 30 spm=1070 psi. SPR's @ 9830'MD, 6137'TVD, 12.8 ppg,08:45 hrs. #1-20 spm=780 psi, 30 spm=1080 psi #2-20 spm=740 psi, 30 spm=1110 psi. 12:00 17:30 5.50 9,910 10,127 PROD1 DRILL DDRL P Directional drill from 9910' MD to 10127' MD, 6217'TVD.ART=4.59, Bit Hrs=27.71, Jar Hrs=173.12, P/U=152k, S/0=93k, ROT=110k,Tq on/off=8/6k, ECD=15.37 ppg EMW, Flow out=37%,WOB=8-12k, RPM=100,225 gpm @ 2800 psi, Max Gas=380 units at bottoms up after connection. SIMOPS-Weight up mud sytem to 13.1 ppg for trip margin. 17:30 17:45 0.25 10,127 10,127 PROD1 CASING SRVY P Obtain SPR's, Survey on bottom. SPR's @ 10127'MD,6217'TVD, 17:30hrs, 13.1 ppg. #1-20 spm=710 psi, 30 spm=1090 psi #2-20 spm=780 psi, 30 spm=1100 psi. 17:45 19:00 1.25 10,127 10,127 PROD1 CASING CIRC P Circulate hole clean @ drilling rate. 19:00 19:45 0.75 10,127 10,127 PROD1 CASING OWFF P Motitor well for flow. Slight trickle to static after 7 min, 30 min static. (SIMOPS-PJSM on pumping out of hole.) 19:45 21:30 1.75 10,127 9,182 PROD1 CASING TRIP P Pump out @ 2 bpm 700 psi, pulling 2500 fph to 9182'MD. Ream x 2 on stand#95, 9467'-9372'due 15k overpull and slight pressure increase. No problems after reaming 3.5 bpm 50 rpm. Calc Fill=5.6 bbl,Actual Fill=11.16 bbl. 21:30 22:15 0.75 9,182 9,182 PROD1 CASING CIRC P CBU @ 9182'MD, 225 gpm 2850 psi, 100 rpm,6k Tq, 37%Flow out. 157 units gas on bottom up strokes. Page 27 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:45 0.50 9,182 9,182 PROD1 CASING OWFF P Monitor well @ shoe, static. 22:45 00:00 1.25 9,182 8,519 PROD1 CASING TRIP P Continue pumping out of hole from 9182' MD to 8519' MD @ 2500 fph,2 bpm 650 psi. Drop 2.25"hollow rabbit with 100'wire on stand#90. (8514' DP length). P/U=130k, 5/0=93k, Calc Fill=2.8 bbl,Actual Fill=4.54 bbl. 36/19/2014 Pump out to 2500'MD, POOH with BHA#6 and L/D. Pick up 4'/z'liner sting and RIH to 9300'MD.Circulating as needed to even out mud weight due to barite sag. 13.1 ppg in/12.6 ppg out. 00:00 09:00 9.00 8,519 2,560 PROD1 CASING TRIP P Continue pumping out of the hole f/ 8519'MD to 2560' MD. Increased pump rate f/2 bpm=600 psi to 4 bpm= 1300 psi due to dynamic barite sag.Actual displacement= 46.3 bbls, Calculated displacement= 39.2 bbls. 09:00 09:15 0.25 2,560 2,560 PROD1 CASING OWFF P OWFF, static. 09:15 11:15 2.00 2,560 478 PROD1 CASING TRIP P POOH on elevators @ 2500 fph to 478'MD.Actual displacement= 11.9 bbls, Calculated displacement= 11.8 bbls. 11:15 12:00 0.75 478 478 PROD1 CASING PULD P OWFF, P/U SLB tools to rig floor, prep to L/D Nuke tools. 12:00 13:45 1.75 478 0 PROD1 CASING PULD P PJSM, rack back 3 stds HWDP, L/D 3 jts flex collars, unload nuclear sources. Break bit, L/D remaining BHA. 13:45 14:45 1.00 0 0 PROD1 CASING RURD P Clean and clear rig floor, L/D tools, P/U casing equipment. 14:45 15:30 0.75 0 0 COMPZ CASING RURD P PJSM, Rig up casing equipment. SIMOPS-install hydroform centralizers with bottom stop collar per running detail in the pipe shed. 15:30 16:00 0.50 0 0 COMPZ CASING SVRG P Lubricate top drive and rig. 16:00 20:00 4.00 0 1,135 COMPZ CASING RNCS P Pick up liner string per detail. M/U EZ Ream liner shoe,double float collar, landing collar, SBE. Flex lock liner hanger, RS Nipple,ZXP packer w/HRDE. Mix Pal Mix, pour and let set for 30 minutes. P/U=44k, 5/0=43k. Calc Disp=4.97 bbl,Actual Disp=5.02 bbl. 20:00 21:30 1.50 1,135 3,041 COMPZ CASING RUNL P Break circulation on first stand, continue RIH,filling pipe every 10 stands to 3000'MD. 21:30 22:00 0.50 3,041 3,041 COMPZ CASING CIRC P Establish circulation @ 4 bpm, circulate surface to surface to break gels and even mud weight. P/U=64k, S/0=61k. 22:00 23:30 1.50 3,041 5,873 COMPZ CASING RUNL P Continue RIH from 3041'MD to 5873' MD filling pipe every 10 stands. Calc Disp=31.85 bbl,Actual Disp=35.7 bbl. P/U=89k, S/0=73k. Page 28 of 34 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:30 00:00 0.50 5,873 5,873 COMPZ CASING CIRC P Cirulate and condition mud @ 5873' MD, 5 bpm 900 psi,40%Flow out. Noted barite sag, 12.6 ppg mud weight coming out. Circulate until even @ 12.9 ppg. 06/20/2014 Run liner to bottom,washing down from 9740'MD to tag @ 10127'no fill. C&C then pump 30 bbl cement per program. Set liner hanger and ZXP packer but saw no verification. Test ZXP to 1500 psi 10 minutes-good. POOH, rotating dog sub not sheared out. 00:00 01:00 1.00 5,873 5,873 COMPZ CASING CIRC P PJSM, continue circulate and condition mud @ 5873'MD, 5 bpm 900 psi. P/U=95k, S/O=75k. 01:00 02:45 1.75 5,873 9,187 COMPZ CASING RUNL P Continue RIH t/9187'MD filling pipe every 10 stands. Calc Disp=51.4 bbl, Actual Disp=85.5 bbl. 02:45 05:45 3.00 9,187 9,187 COMPZ CASING CIRC P Circulate and condition mud @ 9187' MD. 3.5 bpm 900 psi. Pumped 3 BU to even out mud weight due barite sag, 12.5 ppg out, 12.9 ppg in. Obtain P/U=130k, S/O=90k and rotating torque 5k @ 10 rpm values. 05:45 06:15 0.50 9,187 9,740 COMPZ CASING RUNL P Continue RIH from 9187'MD to 9740' MD, lost 15k slack off weight. 06:15 08:00 1.75 9,740 9,740 COMPZ CASING CIRC P M/U top drive, establish circulation, reciprocate pipe 30'. Stage pump up to 3 bpm, 975 psi. Mud weight on BU 13.7 ppg. 08:00 09:00 1.00 9,740 10,117 COMPZ CASING RUNL P Wash down from 9740'MD to 10127' MD©2.7 bpm 800 psi,tag bottom no fill. 09:00 10:15 1.25 10,117 10,117 COMPZ CEMEN-RURD P Make up cement head and XO's with pup joint to space out liner string. M/U to top drive. 10:15 12:45 2.50 10,117 10,117 COMPZ CEMEN-CIRCP Circulate and condition mud for cement job, reduce mud weight to 12.8 ppg. 2.5 bpm, 1200 psi, P/U=135k, S/O=85k. Noted some minor packing off while circulating, decide to pump cement. 12:45 14:30 1.75 10,117 10,117 COMPZ CEMEN CMNT P Cement liner per program, pump 5 bbl H2O,test lines to 4000 psi. Batch up and pump 30 bbl 13.3 ppg MudPush II, 30 bbl 15.8 pptg Tail cement, kick out plug with 10 bbl H2O, displace with rig pump. Dart latched wiper plug @ 915 stks, bumped plug @ 1065 stks, CIP @ 14:20. 14:30 15:30 1.00 10,117 8,979 COMPZ CEMEN"PACK P Set hanger and ZXP pack assy per Baker rep.Pressure up to 3500 with rig pumps to set liner hanger, no set. Line up SLB to pump up to 4200 psi to set liner hanger and HRDE. P/U 7' and set down 40k to set ZXP packer. No indication of shear, repeat with rotation, no indication of shear out. Page 29 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 8,979 8,959 COMPZ CEMEN-RURD P Rig down cement head pup jts and XO's, L/D single while picking up to clear the RS packoff. 16:00 18:30 2.50 8,959 8,959 COMPZ CEMEN'CIRC P Circulate excess cement out from liner top,condition mud per Mud rep. 6 bpm, 1750 psi, 39% Flow out. 18:30 18:45 0.25 8,959 8,959 COMPZ CEMEN"PRTS P Test ZXP packer to 1500 psi 10 minutes(Good) 18:45 19:15 0.50 8,959 8,959 COMPZ CEMEN-CIRC P Pump and spot 40 bbl High Vis 12.8 _ ppg pill on top of packer. 19:15 20:00 0.75 8,959 8,959 COMPZ CEMEN"SFTY P Conduct Safety Stand down with rig crew concerning Ladder Safety and ladder inspection. Review recent incident, discuss equipment inspection. Inspect all ladders on rig, take 2 out of service. SIMOPS- Observe well for flow-Static. 20:00 20:15 0.25 8,959 8,956 COMPZ CEMEN RURD P PJSM, rack back stand, blow down top drive, P/U instring single. 20:15 23:45 3.50 8,956 0 COMPZ CEMEN TRIP P Continue POOH on elevators to surface, lay down running tool. Calc Fill=52.63 bbl,Actual Fill=56.95 bbl. L/D running tools, inspect rotating dog sub, not sheared out. 23:45 00:00 0.25 0 0 COMPZ CEMEN-RURD T Clean and clear rig floor, prepare new packoff and rotating dog sub for RIH to verify ZXP packer is set fully. SIMOPS-Held Safety Stand down with oncoming crew-Ladder Safety and ladder inspection. 06/21/2014 M/U Baker rotating dog sub assy. RIH on 4"DP to verify packer set. Set down X 3 @ 40k observed shear out,. POOH.Test ZXP to 3500 psi-Good. M/U and RIH with 3'/2'upper GL completion, locate and space out. Begin displacement from 12.8 ppg mud to 8.5 seawater. 00:00 00:30 0.50 0 0 COMPZ CEMEN"SFTY P Conduct Safety Stand down with rig crew concerning Ladder Safety and ladder inspection. Review recent incident, discuss equipment inspection. Inspect all ladders on rig 00:30 01:00 0.50 0 0 COMPZ CEMEN-PULD T PJSM, break XO and pups off cement head, lay down. 01:00 01:45 0.75 0 0 COMPZ CEMEN-PULD T PJSM P/U Baker Pack-off dog sub and M/U as per Baker rep. 01:45 02:00 0.25 0 1,140 COMPZ CEMEN-TRIP T PJSM, RIH w/7 stands of 4" DP f/ derrick, P/U 6 joints of 4"HWDP and RIH w/2 stands of 4"HWDP f/ derrick. 02:00 05:15 3.25 1,140 8,979 COMPZ CEMEN TRIP T RIH w/4"DP f/derrick f/1140' MD to 8979'MD.Actual displacement= 56.44 bbls, Calculated displacement=52.60 bbls. Page 30 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 05:45 0.50 8,979 8,979 COMPZ CEMEN-PACK T Set down on ZXP liner top packer, observed a bobble on weight inductor @ 26K, cont.to S/O to 40K. P/U and set down 45K on ZXP. P/U, rotate @ 15 rpm's,4-6K tq. S/O setting 40K down on ZXP. P/U to neutral. P/U= 142K, S/0=85K. Baker rep confirmed w/town ZXP is set. 05:45 08:45 3.00 8,979 0 COMPZ CEMEN-TRIPT OWFF, POOH f/8974'MD to surface. Dog sub was sheared on Baker tool. Actual displacement= 57.4, Calculated displacement= 52.60 bbls. 08:45 09:00 0.25 0 0 COMPZ CEMEN-PULD P Clean and clear rig floor. 09:00 10:00 1.00 0 0 COMPZ CEMEN-PRTS P PJSM, R/U and test ZXP packer to 3500 psi f/30 minutes on chart,good test. 10:00 11:15 1.25 0 0 COMPZ RPCOM RURD P Wash stack and pull wear bushing. Blow down kill line and top drive. 11:15 12:00 0.75 0 0 COMPZ RPCOM RURD P PJSM, mobilize casing equipment to rig floor and R/U cazsing handling tools. 12:00 19:30 7.50 0 8,970 COMPZ RPCOM RCST P P/U and RIH with 3'/z'GL completion string. P/U locator seal assembly, DS Nipple 2.813", 1 GLM w/SOV,4 GLM w/DMY, DS nipple 2.875"and 233 jts 3'/z"tubing. 19:30 21:15 1.75 8,970 9,008 COMPZ RPCOM HOSO P P/U jt 234 and M/U circulating hose, establish circulation and RIH to locate top of seal bore @ 9011' MD .5 bpm,400 psi. Continue in and fully locate @ 9029'MD. Lay down 3 jts, P/U 4.21', 10.11'and 10.20'pup, jt 232, hanger and landing joint. R/U circulating hoses for brine displacement. 21:15 00:00 2.75 9,008 9,008 COMPZ RPCOM DISP P PJSM,displace well from 12.8 ppg Mud to 8.5 ppg Seawater. Pump 200 bbl Seawater @ 3 bpm, ICP=800 psi, 37%Flow out, max pressure 1650 psi @ 3 bpm. Pump 100 bbl HV spacer,followed by 35 bbl Soap spacer,followed by seawater @ 3 bpm, 750 psi. 36/22/2014 Complete brine displacement. Land hanger and RILDS.Attempt to test tubng string with IA open, bled down with flow out IA. R/U SLB slickline, set CAT-SV plug in DS @ 8934'. Test tubing fail. Pull SOV from GLM @ 8875, appeared good. R/D SLB and R/U HES slickline. 00:00 02:00 2.00 9,008 9,008 COMPZ RPCOM DISP P Cont to displace well to 8.5 ppg sea water, staging pumps up f/3 bpm=600 psi to 7.5 bpm=1290 psi, 36%flow. Pumped 690 bbls of seawater. 02:00 02:15 0.25 9,008 9,008 COMPZ RPCOM THGR P FMC rep inspect tbg hanger to confirm TWC will fit in hanger profile. Page 31 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 02:45 0.50 9,008 9,008 COMPZ RPCOM CRIH P Pump 20 bbls of inhibited sea water @ 3 bpm=225 psi, chase w/73 bbls of sea water to spot inhibited sea water from seal assy to SOV on GLM. 02:45 03:15 0.50 9,008 0 COMPZ RPCOM THGR P Drain stack, land hanger and run in lock downs on tbg hanger. 03:15 03:30 0.25 0 0 COMPZ RPCOM PRTS T Attempt to pressure test 3-1/2"tbg to 3500 psi, observed pressure bleeding off via IA at a fast rate. 03:30 03:45 0.25 0 0 COMPZ RPCOM OTHR T Discuss options with town engineer. Decision made to R/U Slickline to replace SOV in GLM#5, run leak detection tools. 03:45 04:00 0.25 0 0 COMPZ RPCOM CIRC T Pump down IA to determine if leak is two-way., observed fluid coming out 3-1/2"tbg. 04:00 07:00 3.00 0 0 COMPZ RPCOM SLKL T Mobilize SLB digital slickline to rig. SIMOPS-Clean rig pits, clean and paint boiler room, prep for hopper installation it pits. 07:00 08:30 1.50 0 0 COMPZ RPCOM SLKL T Load digital slickline tools in pipe shed, spot trucks. SIMOPS, pull landing joint, replace with 3-pups in order to get stump closer to rig floor to rig up slickline pressure control and lubricator. 08:30 10:30 2.00 0 0 COMPZ RPCOM SLKL T PSJM-P/U and R/U SLB Slickline tools. 10:30 11:15 0.75 0 0 COMPZ RPCOM SLKL T Test lubricator and grease head to 500 psi. 11:15 13:00 1.75 0 8,925 COMPZ RPCOM SLKL T RIH with D-CAT SV standing valve and catcher on Slickline,set in 2.812"DS nipple @ 8935.73'. Pick up 10'with line. 13:00 13:15 0.25 8,925 8,935 COMPZ RPCOM PRTS T R/U circulating lines, pressure test to 1500 psi, presure bleeding off. Pressure up to 3500 psi, bled off fast and flowing out the IA. 13:15 14:00 0.75 8,935 0 COMPZ RPCOM SLKL T POOH w/Slickline, C/O plug running tool to kick over tool. 14:00 18:30 4.50 0 0 COMPZ RPCOM SLKL T RIH w/Kickover tool attempt to pull SOV GLM#5, un-successful. Re-dress tool and re-attempt, un-successful.. 18:30 20:00 1.50 0 0 COMPZ RPCOM SLKL T Attempt pressure test on tubing again due D-CAT SV setting uncertainty.Again tubing failed. Re-dress kickover tool with roller stem, RIH and pull SOV. Successfull, no sign of shear on SOV. 20:00 21:00 1.00 0 0 COMPZ RPCOM SLKL T PJSM, R/D SLB digital slickline due crew timed out. Clear SLB tools from rig floor. 21:00 00:00 3.00 0 0 COMPZ RPCOM SLKL T PJSM-R/U HES slickline. MOB tools to rig floor, spot trucks, load lubricator in the pipe shed. Page 32 of 34 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06/23/2014 24 hr Summary R/U HES Slickline and set SOV in GLM#5. Test tubing to 3500, annulus to 3000 psi 30 min ea charted. Shear out SOV,set TWC and test to 3200 psi. N/D BOPE, install tubing adapter and test 5k good. Install tree test 5k good. Pump inhibited brine and diesel FP. Lay down drill pipe. Secure well and release rig @ 00:00. 00:00 00:45 0.75 0 0 COMPZ RPCOM SLKL T Cont to R/U HES Slick line unit. 00:45 02:15 1.50 0 8,875 COMPZ RPCOM SLKL T RIH w/new SOV on HES slick line. Attempt to set SOV in GLM#5 @ 8875'MD 02:15 02:30 0.25 8,875 0 COMPZ RPCOM SLKL T Inspect slick line running tool on surface. SOV did not set in GLM#5. 02:30 04:00 1.50 0 0 COMPZ RPCOM SLKL T RIH w/new SOV on slick line. Set SOV in GLM#5 @8875'MD. 04:00 04:15 0.25 0 0 COMPZ RPCOM PRTS T Pressure test 3-1/2"tbg to 3500 psi for 5 minutes, good test. 04:15 05:00 0.75 0 0 COMPZ RPCOM SLKL T Rig down HES slick line unit. 05:00 06:30 1.50 0 0 COMPZ RPCOM PRTS P Pressure test 3-1/2"tbg to 3500 psi f/30 minutes good test. Bleed down tbg to 2000 psi, pressure up IA to 3000 psi and test for 30 minutes, good test. Bleed off IA and tbg. Ramp up on IA, SOV sheared @ 2700 psi.All tests recorded on chart recorder. 06:30 06:45 0.25 0 0 COMPZ WHDBO RURD P R/D testing equipment and L/D landing joint. 06:45 07:15 0.50 0 0 COMPZ WHDBO MPSP P Set TWC as per FMC rep,test TWC to 3200 psi f/5 minutes in the direction of flow. 07:15 07:30 0.25 0 0 COMPZ WHDBO RURD P Blow down choke line, kill line and cellar lines. 07:30 08:30 1.00 0 0 COMPZ WHDBO NUND P PJSM, Nipple down BOPE. 08:30 10:15 1.75 0 0 COMPZ WHDBO NUND P Install SBMS seals and adapter flange,test void to 5000 psi f/10 minutes.Test witnessed by CPAI rig supervisor, good test. 10:15 11:30 1.25 0 0 COMPZ WHDBO NUND P N/U tree as per FMC. Test to to 5000 psi,good. 11:30 12:15 0.75 0 0 COMPZ WHDBO MPSP P PJSM, Pull TWC, SIMOPS-R/U freeze protect&U-tube hoses and equipment. 12:15 14:30 2.25 0 0 COMPZ WHDBO FRZP P PJSM, Pressure test lines to 2500 psi. Pump 190 bbl inhibited brine, followed by 65 bbl diesel freeze protection @ 2.25 bpm 900 psi with Litte Red. Shut down pump, static pressure 160 psi. Line up to U-tube well. SIMOPS-Cut and slip drilling line. 14:30 16:00 1.50 0 0 COMPZ WHDBO FRZP P U-Tube well. SIMOPS R/U to lay down 4"drill pipe and HWDP from derrick. 16:00 17:00 1.00 0 0 COMPZ WHDBO MPSP P PJSM, R/U Lubricator and set 3" Type H BPV. 17:00 17:45 0.75 0 0 COMPZ MOVE RURD P Rig down hoses,secure wellhead, clean cellar area for rig move. Page 33 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 00:00 6.25 0 0 COMPZ MOVE PULD P Lay down 4"drill pipe. 2K-34 WELL WORK SUMMARY DATE SUMMARY 7/6/2014 PULLED SOV& SET WITH DV @ 8876' RKB (MIT-T TO 2500 PSI PASSED); PULLED 2.81" CAT SV @ 8936' RKB; DRIFT TBG. WITH 2.71" CENT& 2.5" BAILER DOWN TO 9122' SLM (SLOWED TO A STOP BY 74 DEGREE DEVIATION & 12.8 MUD IN LINER). IN PROGRESS. 7/7/2014 DRIFTED TBG WITH 29'-3"x 2.125" STEM (TRACTOR) & 6'-8"x 2.74" DUMMY PERF GUN STALLED OUT @ 9192' SLM HEAVY MUD/DEVIATION. READY FOR CTU. • Cement Detail Report 2K-34 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 5/24/2014 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 6/2/2014 01:30 6/2/2014 05:00 2K-34 Comment Pump 5 bbl of water to flood lines.Test cement lines 550&3000 psi. Rig pumps 100 bbls of 10.5 ppg MudPush @ 5 bpm=200 psi.Drop bottom plug.SLB pumped 460 bbls 11.02 ppg of ALC @ 6 bpm=250 psi.SLB pumped 57 bbls of 12 ppg tail cement @ 5 bpm=330 psi. Drop top plug&SLB pumped 10 bbls of water to flush lines.Swap to rig&pump 316 bbls of mud @ 7 bpm=600 psi,to bump top plug. Pressure up to 1100 psi for 5 min,bled off to check floats(good). CIP @ 05:00 hrs. 178 bbls of cement to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement 10 3/4"surface 28.3 3,543.0 No 178.0 Yes Yes casing Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 5 6 625.0 625.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5 bbl of water to flood lines.Test cement lines 550&3000 psi. Rig pumps 100 bbls of 10.5 ppg MudPush @ 5 bpm=200 psi.Drop bottom plug.SLB pumped 460 bbls 11.02 ppg of ALC @ 6 bpm=250 psi.SLB pumped 57 bbls of 12 ppg tail cement @ 5 bpm=330 psi. Drop top plug&SLB pumped 10 bbls of water to flush lines.Swap to rig&pump 316 bbls of mud @ 7 bpm=600 psi,to bump top plug. Pressure up to 1100 psi for 5 min,bled off to check floats(good). CIP @ 05:00 hrs. 178 bbls of cement to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 28.3 2,817.0 1,338 G 460.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.93 6.25 11.02 183.6 8.50 Additives Additive Type Concentration Conc Unit label Additive Type Concentration Conc Unit label Salt D044 10.0 %BWOW 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 Cement 2,817.0 3,555.0 198 G 57.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1 (psi) 1.62 5.36 12.00 167.8 6.50 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Retarder D110 0.02 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.09 gal/sx Page 1/1 Report Printed: 7/15/2014 • • ,1111114 Cement Detail Report 0 114 2K-34 ConocoPhillips String: Cement Squeeze Job: DRILLING ORIGINAL, 5/24/2014 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Squeeze 6/4/2014 15:30 6/4/2014 16:21 2K-34 Comment Held PreJob.SLB pumped 2 bbls water. Pressure test to 2500 psi.Good. Pump 13.5 bbls 10.5 ppg Mud Push @ 3 bpm 140 psi. Pump 18.6 bbls 15.8 ppg cement @ 3 bpm 330 psi. Pump 3 bbl 10.5 ppg Mud Push. Rig chased with 47 bbls of 9.7 ppg mud. POOH 6 stands and perform squeeze.6 bbls squeezed away with hesitation squeeze in 10 minute intervals,600 psi max pressure. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Cement Squeeze Enhance shoe integrity 3,460.0 3,575.0 No 0.0 No No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 330.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 3,460.0 Drill Bit 3,575.0 8 1/2 Comment Held PreJob.SLB pumped 2 bbls water. Pressure test to 2500 psi.Good. Pump 13.5 bbls 10.5 ppg Mud Push @ 3 bpm 140 psi. Pump 18.6 bbls 15.8 ppg cement @ 3 bpm 330 psi.Pump 3 bbl 10.5 ppg Mud Push. Rig chased with 47 bbls of 9.7 ppg mud. POOH 6 stands and perform squeeze.6 bbls squeezed away with hesitation squeeze in 10 minute intervals,600 psi max pressure. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 3,460.0 3,575.0 91 G 18.6 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.10 15.80 83.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) S002 0.5 %BWOC Page 1/1 Report.Printed: 7/15/2014 Cement Detail Report 2K-34 Conoco`Phillips hl.xka String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 5/24/2014 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 6/14/2014 14:30 6/14/2014 16:45 2K-34 Comment SLB pumped 60 bbl 12.5 ppg MudPush,60 bbl 15.8 ppg Tail cement,chase with 10 bbl water,displaced with 342 bbl 10.4 ppg mud to bump. Float held.CIP @ 16:30.95%returns throughout job. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...'Top Plug? Btm Plug? Intermediate Casing Cement 7"casing 6,850.0 9,257.0 Yes Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 850.0 1,350.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 6,850.0 9,257.0 289 G 60.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 104.0 4.75 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.005 gal/sx Page 1/1 Report Printed: 7/15/2014 Cement Detail Report 0 2K-34 ConocoPhillips String: Production Liner Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Liner Cement 6/20/2014 12:45 6/20/2014 14:30 2K-34 Comment SLB pumped 5 bbl H2O,test lines to 4000 psi. Batch up and pump 30 bbl 13.3 ppg MudPush II,30 bbl 15.8 pptg Tail cement,kick out plug with 10 bbl H2O, displace with rig pump.Dart latched wiper plug @ 915 stks,bumped plug @ 1065 stks,CIP @ 14:20. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Production Liner Cement Cement to top of 8,979.0 10,127.0 No 10.0 Yes No production liner Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 4 4 980.0 2,800.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement/contaminate returns to surface when circulating on top of packer. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 8,979.0 10,127.0 195 G 30.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 77.0 7.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.5 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Page 1/1 Report Printed: 7/15/2014 2y4-02(.0 -off RECEIVF'' 2_4(5�C.,0 JUL 1 1 20'14 SchluScblumberer AentsOGCC Transmittal#: 10JUL14-SPO1 mberger Drilling & MeasuremDATA LOGGED MWD/LWD Log Product Delivery --//A /20141 M.K BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2K-34 Date Dispatched: 10-Jul-14 Job#: 13AKA0122 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2"MD x x VISION*Service 2"TVD x x VISION*Service __5"MD x x VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 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 Please sign and email a copy to: Please sign and email/fax a copy to: iifesie(c slb.com spacillo a(�slb.com Stephanie Pacillo Ifeanyi Ifesie Fax:907-561-8317 907-265-6519 ATO 1525 N Received By: AVaga,fruk..., - / 3/, CO �p p C0p pp W ° 0 7 0000.O M A CO O m m tl O 92 0 CID CND<I0 O Nr V CID O CNO tV Q.<9 aoa M m�y8p�MN r IN i �� - O) O CO CO COD CIO CO Ps A O O O e-N M N r n O N O OINNCOOd NMm,-CO V Om CVCO03 C M M M CO CO CO M CO CO CO Q Q d d Q Q Q 10 1 D N O I I C D r r r CO CO CO W N N N N N CO CO ® J O O O O O O O O O 0 0 o o o o 0 0 0 o 0 00000000000000 100 100 100 C00 C00 100 to 100 100 C00 100 100 COC100 100 100 100 100 100 100 t00 N 10C)100 100 100 100 10 10 100 100 10 10 10 10 100 1p0 100 d N o t3 1 et fC^N N CO COW COI CDNMN V)OI COW COco Lo CO 10 d CO n ONONOm0 et 4CVV r-oCO CO CO CO CO N C"ir 9�NN,0 OO CD d 10 W 10 CD CD CO 10 NCD COW COW CO �`y-=`) CO CO CO CO CO CO CO CO CO OD OD CO CO CO O O O 000000000000 0 o ^N Q O r 0 ,- ei 1r 0 N CD WWW coW CO ')M M M M M M M M M M M M 0 0 M M 0 o W N N N N N N N N N N N N N N N N N COM M J d d Q Q Q Q d d d d d d d d d d d d d d d d d d d d d d d d d d d Q Q d d d N IlriL N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N O O O O O C O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0) r r N. a.a-r r r r r r r r r rppr r r r r r r r r r r r r r r r r r r r r r a-r•••• ��WI C—co coO OD rs CO CONOA NN CID<oW CD030)CO INO, W IID hA CNDctp 03 W CD CD�<Cpp INOomN T. 0W 0 Of A0 ooc0 CO,c01001I 0N00- r M.-00000DCO ONDNCIO04 MOMCD OM)W 000 :.2 0 0 0 0 W I r CC`MM MMN N NNNNNN.-.-.-•.7 O 000 W W ICDr r CO O CO 10d Mtn N,- W CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO I CO CO CO CO r r r r r r r r r r r r r r r W W W W W W W W W CO W W W W W W W W W CO W W W CO W W W W W W W W W W W W W W 0000000000000000000 d 0000000,10000000000 W"'CO CO CO CO CO N N CO Q NIy NOD W W LO et CO W N MMN,-r�Q r CO r N,-N 100 W CSW W CO W 0.-0 0 N O 0 CO 0 h r,-CO r O 0 CO W W CO O CO N prp N CO Mr Q 00rN d {=W W W W W N N N N N F2 N N N N N N CIV N N N N N CA N N N M 0 0 I[)U)trO N 8 r OO)0)) Z co M co M co co M co co co co M co co co co co M co co co co co co M co co co co co M CO CO W CO W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W M M IO 10 O 010 M 10 O0ON LO 10100M N 10 N N 1010 O O O O O o 10 CD 10 OM MN OJ"'000. 0 W M CD I..tO CO el'01 o W 1-100.— N 000000,4.03M.M.-1-N1003,-CD COCOOD N CD,-CO dOONNIIMQ W r Q.-100 tn O 0 0 0 0 N.0 M0 0 0 N0. 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N 0 E ') $ 0 m m o c E M ^ 2 2 2 O k d 0. y r1,r1, _. 0 21-1-02`10 DATA LOGGED 244 52 1/9/2014 ConocoPhillips .M K^EIVED BENDER TRANSMITTAL JUL 09 2014 AOGCC FROM: Sandra D. Lemke,ATO3-0340 TO; Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: 2K-34 DATE: 07/08/2014 Transmitted: Kuparuk River Unit, Alaska 2K-34 1 hardcopy report with digital data on CD Canrig Final well report mud logging data for 2K-34; 6/18i2014; table of contents, mud logging equipment; general well details, geologic data, pressure/formation strength, drilling data,show reports,daily reports and formation logs; color log presentations; Formation log MD Gas ratio MD Combo log MD Drilling dynamics MD 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 Sandra.D.Lemkec&COP,com CC: 2K-34 transmittal folder, production well files, eSearch Receipt: fIrl Date: i h 1 g+ 111111111111� - GIS-Technical Data Management I ConocoPhllbps I Anchorage, Alaska I Ph:907265.6947 'A, _,'"\\ Ii/-7-Ass;\ TI-TE STATE S. ' _ � --- I ------ :,33 v/c5I Sc.,r, 1i A,-.iii,� ( O\'i'.RN(}fZ �;I;AN i AR: Eli /\,ncl-orac;e, Alaska 995(;1 3522 a�;_-L . � 07 ;7U IA3? Mike Callahan Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-34 Sundry Number: 314-370 Dear Mr. Callahan: 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, ,-4(..e.44,4-- Cathy P Foerster Chair DATED this 17 g^-' of June, 2014. Encl. • RECEIVED JUN 1 7' 2014 STATE OF ALASKA D.7.g L i l 4 r / ALASKA OIL AND GAS CONSERVATION COMMISSION �"1O�V APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 Type of Request Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown Q' Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name 4 Current Well Class: 5.Permit to Drill Number: ConocoPhiliips Exploratory ❑ Development Q 214-026 3.AddressStratigraphic ❑ Service ❑ 6.API Number 700 G St. 50-103-20688-00-00 7 If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing In this pool? A)/- A2t,-- Will planned perforations require a spacing exception? Yes ❑ No ❑ 2K-34 9 PropertynDesignation(Lease Number): /ii.b 10.Field/Pool(s): n -,7 /t�� 9-S`S-W t _5'S O emH Kuparuk River nir F1 EId 1 K c i l/ CA I 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): 9257 5980 9257 5981 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 104' 104' Surface 3527' 10-3/4" 3555' 2882' 5210 psi 2470 psi Intermediate 9219' 7" 9247' 5978' 7240 psi 5410 psi Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft): • Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12 Attachments Description Summary of Proposal O 13.Well Class after proposed work: • Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Service ❑ 14.Estimated Date for 6/14/2014 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑✓ 16.Verbal Approval: Date 6/13/2014 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Victoria Ferguson GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Mike Callahan Email mike.callahanaconocophillips.com Printed Name Mike Callahan Title Drilling Engineer Signature Phone to il COMMISSION USE ONLY • Conditions of approval. Notify Commission so that a representative may witness Sundry Number \/, -2 .-1 Plug Integrity ❑ BOP Test© Mechanical Integrity Test ❑ Location Clearance ❑ Other. 3C13f'l5t F.5-0L),125 - • I CI- /v - -) - wIt)-,/v, 5-U 4Gt 5 5 G, l d c, v !' ' !ff—C wt l ( ✓l�a✓d` f��., A ✓II Cl. / V H G,vc ://,; 57,d C'a p o f q l 1 107 _5 a L it ri-c 25-, G - Z �b.) . Spacing Exception Required? Yes ❑ NoSubsequent Form Required: / L -4 U 4 APPROVED BY / Approved by: a67P.941.4.74.--. COMMISSIONER THE COMMISSION Date: `-/9 [T _/ -?/,21 (D I?J/y Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the ate of approval. Attachments in Duplicate V1 6'/1 ORIGINAL � r�� RBCMS JUN 202 • 2K-34 Change in Scope and Plan Forward Summary While casing drilling with 7" intermediate casing at 9257' MD,we were attempting to increase mud weight from 11.0 ppg to 12.5 ppg in anticipation of potential high pressure in the Kuparuk reservoir and a large fault that could potentially communicate with the reservoir. The expected MD of the fault is 9370', with ±100'of uncertainty,so we did not feel comfortable drilling any further until we had sufficient mud weight. While weighting up,we lost full returns, most likely in a fault that was crossed at approximately 6200' MD where we saw minor losses while drilling. Repeated attempts at regaining circulation through decreased mud weight, reduced flow rates to decrease ECD,and addition of LCM to the entire mud system as well as large concentration LCM pills have been unsuccessful in regaining full circulation. Currently we have about 65% returns with a 10.4 ppg mud weight circulating at 2.5 bbls/min and we are preparing to cement the casing in place. Because the loss zone is at 6200' MD and our planned TOC is at 7500' MD,we are confident that even with some losses it will not affect the quality of cement, as the losses will occur above the TOC. Because we were not able to reach our planned TD with the 7" intermediate casing(plan was to land in the top of the Kuparuk"C" Sand to isolate the Kalubik shale above),we are altering our plan to complete this well as a rotary horizontal. Instead,we intend to drill a 6-1/8" slant hole, maintaining the current well trajectory,to the base of the A4 sand and cement a 4-1/2" liner in place. We will run 3-1/2"tubing and leave the well in the condition originally planned. We will return to the well at a later date with Nabors-CDR2 to drill a coiled tubing sidetrack out of the 4-1/2" liner in the A4 Sand. A separate permit for that work will be submitted once it has been planned and scheduled. Our plan forward from this point is as follows: 1. Cement 7" intermediate casing in place at 9247' MD,with planned top of cement to be 7500' MD. 2. Flush 10.75"x 7" annulus with water,followed by Isotherm NT(diesel base)to freeze protect annulus down to base permafrost. 3. PU 6-1/8" PDC Bit and 4.5" drilling assembly,with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 4. Drill out cement and 20'of new hole. Perform LOT(or FIT to maximum of 16.0 ppg EMW), recording results. 5. Directionally drill 6-1/8" hole to TD at+/- 10,145' MD/6,223'TVD as per directional plan. If tight hole is seen while tripping to the shoe, perform wiper trip to TD. POOH and lay down BHA. 6. PU and run 4-1/2" liner to TD and set liner hanger @ +/-9100' MD/5938'TVD (^'150'of liner lap inside 7" intermediate casing). 7. Cement 4-1/2" liner, bringing cement above top of liner. 8. Set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. 9. PU 3.5"tubing and RIH. Displace well to brine and land tubing. Set two-way check valve in tubing. 10. Nipple down BOPE, nipple up tree and test. Pull two-way check valve. 11. Freeze protect well with diesel by pumping into 3.5" x 7" annulus,taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows,the Wells Group will freeze protect the well post rig). 12. Set BPV and move rig off. zo 34(wp10) ConocoPhillips Grass RootsHorizontal A-Sand Producer Proposed Wellbore Schematic 2!%"Tree L C16'on1&4.8#ductor{drivenA-106 ): Freshwater Spud.Mud 104'MD 1104'TVD Permafrost 9X PPG 3 I-Carol,' Ntvt:2.V' M UTMrAu:r: Fresh Water i 111`:"&47..11 HES crrr..rxr 551:!t,0:1'. Spud Mud - 13-112" Surface Hole 0 9.8.10 PPG b- 3' rt-r,'Gnao —ti d 0:' NYU:VoRYr Surface Casing: Below West Sak 10-3./4"45.5#L-8O Hdril 563 3.572' MD 2 897'TVD 3 Y... [ani. i0°` RIMC Modred ,"IBM-LSND +.6–10-0 PPG 5.6.1-4'Om. we J innP up with MNGWa tlrc Tubing: -:ruipAluti� 3-/Z 9 3#L-80 EUE8RD 8-112"Intermediate Hole Es mated kr at cement i-«.A COY PAD 1.4-.1,-,..7:,', xixJ (650.aba re C sard 1.1103 Mo•Yt! b"S+l%-Gar., Ft–--1 blwc Yr-6a1 w: I"' 504 3 5'.'Cum.DY Np{1.2 tl'3 >,... !Y> w9 -tsttt) Intermediate Casino: 12.5 P PG %xr i r.-Tr,.a:,.->s-.:rr a- 7' 26 L-A.: &trii:l TN Blue Cornett rS Torque Seal added r:as: slrr•I.xLe�3 Lrn -r- Torque 9.247'MD:5.980 TVD 1 74` ,�•rtsNa�.ss:o wt: Ail ihh. t'f -i.i-:- •:.;•Yi•)• i':' ':r i ►4.F►r E E 1 1 E E f E E E 1 E i , : . •�; :' :::::::::: ::::: : 4-1f2?"•14:b :EB'TIVI:: ::::::::: • : :: :::: : : Ef}144':Ad[3 6x223'T • Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Tuesday,June 17, 2014 8:11 AM To: 'Callahan, Mike S' Subject: RE:2K-34 (PTD#214-026) Updated PTD Please send over paper copy to the AOGCC and include a wellbore schematic- Original Message From: Callahan, Mike S[mailto:Mike.Callahan@conocophillips.com] Sent:Saturday,June 14, 2014 8:45 AM To: Ferguson,Victoria L(DOA) Subject: RE: 2K-34(PTD#214-026) Updated PTD Victoria, here is the 10-403 for the Operational Shutdown, including a summary of what led to the changes and the plan forward. Please let me know if this is what you are looking for or if you would like any more information. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907)263-4180 Cell: (907)231-2176 Original Message From: Ferguson,Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Friday,June 13,2014 7:12 PM To:Callahan, Mike S Subject [EXTERNAL]Re:2K-34(PTD#214-026)Updated PTD Please submit this as an Operational Shutdown on a 10-403 for this PTD. Thanx, Victoria Sent from my iPhone >On Jun 13,2014,at 6:23 PM, "Callahan, Mike S"<Mike.Callahan@conocophillips.com>wrote: >Victoria, please see the attached updated PTD for 2K-34. Changes made to the PTD are: >Section 6: Updated current casing and cement information, plus new plan for cemented 4-1/2"slant liner >Section 13: Updated procedure to reflect new plan forward,starting at step 11. >Attachments: Updated directional plan,cement plan for intermediate,and well schematic. > .>Let me know if you have any quest,..on anything. Will this be given a new P1. ,or will it remain the same PTD just updated? If there is anything else I need to do to submit this please let me know,and I will get it sent in as soon as possible on Monday morning. >Thanks, > Mike Callahan >Drilling Engineer >ConocoPhillips Alaska >ATO 15-1564 >Office: (907) 263-4180 >Cell: (907)231-2176 ><2K-34 PTD_Updated.pdf> 2 • • Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Friday,June 13, 2014 12:40 PM To: 'Callahan, Mike S' Subject: RE:2K-34(PTD#214-026) Update/Plan Forward Mike, An Operations Shutdown is covered in 20 AAC 25.072. In short you need to file a 10-403 providing a full justification for the shutdown,a description of the proposed condition of the well bore upon shutdown,the approximate date when drilling/completion will resume and a proposed program for securing the well during the period of shutdown. If you decide to do this you can request a verbal approval and follow up immediately with a 10-403. If you decide to drill ahead and the BHL is greater than 500'from the approved PTD,then a new PTD will need to be submitted. Again,you may request a verbal and follow up with the new PTD. If the BHL will not change by more than 500',then a change of approved program should be submitted and can outline only the changes from the approved PTD. Again,you may obtain a verbal and follow up immediately with the 10-403. Hope this is helpful. Let me know your plan when you have formulated one. 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.ferguson@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793- 1247 or Victoria.Ferguson@alaska.gov Original Message---- From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent: Friday,June 13,2014 11:09 AM To: Ferguson,Victoria L(DOA) Subject: RE: 2K-34(PTD#214-026) Update/Plan Forward Victoria, 1 • ,We pumped around our first LCM pili _ .,h 11.5 ppg mud last night and got about. .0 returns back as the pill was crossing the loss zone, but it quickly dropped back to full losses. We are a few hours away from getting the next pill started around,with 10.4 ppg mud. We weighted up from 10.0 to 10.4 ppg during the conventional drilling portion because we were getting increased connection gas, so 10.4 ppg is as low as we will go. After this next LCM pill gets around,whether we get returns back or not,our plan is to go ahead and cement the casing in place. If we are unable to get returns,our loss zone is above where the top of cement will be anyways(losing at 6200' MD, planned TOC at 7500' MD), so we should not have a problem getting cement in place. The cement is loaded and ready to go,so we should be able to get into cementing pretty quick after this next circulation, most likely tonight or early tomorrow morning sometime. The two options we are left with moving forward after we are cemented are: 1) Drill a conventional 6-1/8"slant hole through the reservoir and run and cement 4-1/2" liner to set up for a CTD sidetrack or 2)Suspend the well and move the rig off to come back at a later date, potentially with some sort of drilling liner or other as of yet un-thought of option (not sure on the viability of this,would take a lot of research/planning/lead time). I will keep you up to date on the progress and our plan forward. If you have any questions or concerns please let me know. I am not overly familiar with the regulations on a change to the well plan like this. Could you please advise if there is any sort of sundry that needs to be done regarding the change in scope? Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907)263-4180 Cell: (907)231-2176 Original Message From: Ferguson,Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Friday,June 13,2014 9:07 AM To:Callahan, Mike S Subject: [EXTERNAL]RE: 2K-34(PTD#214-026) Update/Plan Forward Mike, Thanx for the update- Keep me posted. Victoria Original Message From: Callahan, Mike S[mailto:Mike.Callahan@conocophillips.com] Sent:Thursday,June 12, 2014 4:57 PM To: Ferguson,Victoria L(DOA) Subject:2K-34(PTD#214-026) Update/Plan Forward Victoria, I just wanted to provide you with an update on the status and plan forward on 2K-34: We conventionally drilled our 8-1/2" intermediate hole to the casing drilling depth of 9151'MD. During drilling we crossed a prognosed fault at 6200',where we encountered dynamic losses at 40-60 bph (10.0 ppg MW,550 gpm). Two LCM pills healed those losses down to 5-10 bph,which stayed roughly constant for the remainder of the hole section. 2 • .We ran our 7" casing drilling assembly ,_LCase bit,WearSox centralizers on bottok._ _No joints,Tenaris Blue x Hydril 563 tapered string)to bottom with minimal issues. At that point we swapped over to 11.0 ppg mud, losing"'20 bph at 300 gpm. Our LOT at the surface shoe (after the cement squeeze)was 14.3 ppg, so we are pretty confident the losses are occurring in the zone around 6200'. We casing drilled from 9151'to our current depth of 9257' MD with stable dynamic losses around 20 bph (11.0 ppg MW, 300 gpm). At this depth we are approximately 100' MD from a prognosed fault(50'throw)that has a reasonable likelihood of being in communication with the Kuparuk reservoir. The nearest offset injector(2K-13) has an EMW of 12.1 ppg, which is what we based the drill-in mud weight(12.5 ppg)on. The pore pressure estimate for the Kuparuk reservoir at our location has a range from 10.9-13.9 ppg(most likely on the low side of the estimate,the production engineer believes the pressure to be closer to the 10.9 ppg number, but there is of course some uncertainty). We weighted the mud up to 12.5 ppg at 9257' MD in anticipation of drilling across the fault. The 12.5 ppg mud made it around the bit and to approximately 4800' MD,at which point we lost full returns. We staged the pumps back all the way down to 1 bpm and were still on full losses. Statically we are losing 10-20 bbls/hour at this time. We are currently on the trip tank, keeping the hole full while mixing mud to begin circulating LCM. The plan forward,once we have the mud necessary, is to circulate around 11.5 ppg mud, with a 100 bbl LCM pill to attempt to heal the loss zone. If we can re-establish circulation at 11.5 ppg,we will attempt to slowly bring the weight up while maintaining our Torque Seal wellbore strengthening LCM at^'5 ppb. If we can get back near 12.5 ppg and handle the necessary ECD,we will drill ahead at that point. In the scenario that we can't get what we need,we would be looking at potentially cementing the casing in place. From there we would have to discuss our options for completing the well. I will keep you updated on our progress. If you have any questions or concerns, please let me know. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907)263-4180 Cell: (907)231-2176 3 • Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent Thursday,June 05, 2014 12:39 PM To: 'Callahan, Mike S' Subject: RE:2K-34 (PTD 214-026) Updated LOT Attachments: Cement Report.xlsx Mike, Please refer to 20 MC 25.030(d)(4)and AOGCC Industry Guidance Bulletin 13-001 on our website concerning inadequate surface casing cement jobs. In the future,the AOGCC should be notified when the LOT indicates insufficient integrity of the casing shoe before taking remedial steps. In addition,the AOGCC would like the attached casing& cementing report completed. How much cement was placed and what was the excess? You have approval to proceed to drill ahead. 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.ferguson@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793- 1247 or Victoria.Ferguson@alaska.gov Original Message From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent:Thursday,June 05,2014 11:18 AM To: Ferguson,Victoria L(DOA) Subject: 2K-34(PTD 214-026) Updated LOT Victoria,we just completed our second LOT with 20'of new formation open(attached). We got a 14.3 ppg leak off and saw a much better signature on our shut-in, indicating the issue with outlet original LOT was resolved by the cement squeeze. I have the rig standing by,we will wait for your OK before proceeding to drill ahead. Please let me know if you would like any more information. Thanks, 1 • Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Tuesday,June 17, 2014 8:11 AM To: 'Callahan, Mike S' Subject: RE: 2K-34 (PTD#214-026) Updated PTD Please send over paper copy to the AOGCC and include a wellbore schematic- Original Message From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent: Saturday,June 14,2014 8:45 AM To: Ferguson,Victoria L(DOA) Subject: RE: 2K-34(PTD#214-026) Updated PTD Victoria, here is the 10-403 for the Operational Shutdown, including a summary of what led to the changes and the plan forward. Please let me know if this is what you are looking for or if you would like any more information. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office:(907)263-4180 Cell: (907)231-2176 Original Message From: Ferguson,Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Friday,June 13,2014 7:12 PM To:Callahan, Mike S Subject: [EXTERNAL]Re: 2K-34(PTD#214-026) Updated PTD Please submit this as an Operational Shutdown on a 10-403 for this PTD. Thanx, Victoria Sent from my iPhone >On Jun 13, 2014,at 6:23 PM, "Callahan, Mike 5"<Mike.Callahan@conocophillips.com>wrote: >Victoria, please see the attached updated PTD for 2K-34. Changes made to the PTD are: >Section 6: Updated current casing and cement information, plus new plan for cemented 4-1/2" slant liner >Section 13: Updated procedure to reflect new plan forward,starting at step 11. >Attachments: Updated directional plan,cement plan for intermediate,and well schematic. 1 .> Let me know if you have any questk,...,on anything. Will this be given a new PTL ,or will it remain the same PTD just updated? If there is anything else I need to do to submit this please let me know, and I will get it sent in as soon as possible on Monday morning. >Thanks, > Mike Callahan > Drilling Engineer >ConocoPhillips Alaska >ATO 15-1564 >Office: (907)263-4180 >Cell: (907)231-2176 ><2K-34 PTD_Updated.pdf> 2 PTO 21 'f— a zc Ferguson, Victoria L (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday,June 05,2014 11:18 AM To: Ferguson,Victoria L(DOA) Subject: 2K-34(PTD 214-026) Updated LOT Attachments: 2K-34 Surface casing test. Post Sq.20feet new hole FIT V.4 .xlsx;ATT00001.txt Follow Up Flag: Follow up Flag Status: Flagged Victoria,we just completed our second LOT with 20'of new formation open(attached). We got a 14.3 ppg leak off and saw a much better signature on our shut-in, indicating the issue with outlet original LOT was resolved by the cement squeeze. I have the rig standing by,we will wait for your OK before proceeding to drill ahead. 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Please see AOGCC Industry Guidance Bulletin 13-001 before proceeding- From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent:Thursday,June 05, 2014 9:50 AM To: Ferguson, Victoria L(DOA) Subject: RE: 2K-34 (PTD # 214-026) Surface Cement Squeeze Results Victoria, I have attached the simulation for the surface job we pumped. The cement job went well, with 176 bbls of cement back to surface. We were unable to reciprocate during the job,which may have contributed to the unsuccessful LOT. I've also attached the simulation and the pumping schedule we followed for the squeeze job. We were able to pump away 6 bbls of cement, with 0.5 bbls bleeding back after the squeeze. Let me know if this is what you are looking for or if you would like more information. Thanks, Mike From: Ferguson, Victoria L(DOA) [mailto:victoria.fergusonCa)alaska.gov] Sent: Thursday,June 05, 2014 9:38 AM To: Callahan, Mike S Subject: [EXTERNAL]RE: 2K-34 (PTD # 214-026) Surface Cement Squeeze Results Please send details of the surface casing cement job as well as the hesitation squeeze. Thanx, Victoria From: Callahan, Mike S [mailto:Mike.Callahan©conocophillips.com] Sent:Thursday, June 05, 2014 9:33 AM To: Ferguson, Victoria L(DOA) Subject: 2K-34(PTD # 214-026) Surface Cement Squeeze Results Victoria,as discussed on the phone,we just completed a cement squeeze below our surface casing shoe on 2K-34 on Doyon 141. After our initial drill out,our LOT showed a very slow pressure build-up,followed by a rapid pressure drop after shut-in. We performed two LOT's with the same result(both attached),which we believe may indicate some sort of small cement channel at the shoe. We performed a hesitation squeeze, pumping away 5.5 bbls of cement,to remedy this. After drilling out the cement from the squeeze,we completed another LOT(actually an FIT,stopping at 14.7 ppg) that looks much better and does not have the same pressure drop after shut-in(labeled 2K-34 Surface casing test FIT V.3), indicating we have a good shoe at this point. If you would like any more information or have any more questions, please let me know. i Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907)263-4180 Cell: (907)231-2176 2 2K-34 Surface Cement Squeeze 6-4-14 Time Strokes Rate bpm Pressure Time Strokes Rate Pressure 17:53 0 1 150 19:00 47 O/U 400 17:55 12 1 500 19:01 50 .5 550 17:55 16 S/I 500 19:02 52 S/I 600 18:02 16 O/U 250 19:12 52 O/U 425 18:03 16 .5 250 19:12 54 .5 525 18:04 18 .5 400 19:13 56 S/I 600 18:05 21 .5 500 19:21 56 O/U 450 18:05 23 S/I 550 19:22 58 .5 525 18:15 23 O/U 300 19:22 60 S/I 600 18:16 24 .5 400 19:30 60 O/U 450 18:16 26 .5 475 19:30 Bled back.5 bbls. 18:17 28 .5 500 18:17 31 S/I 600 18:27 31 O/U 300 18:27 32 .5 425 18:28 37 S/I 600 18:38 37 O/U 400 18:38 40 .5 500 18:39 43 S/I 600 18:49 43 O/U 400 18:49 45 .5 500 18:50 47 S/I 600 PlugAdvisor Summary Report 4 t tgy„„t„. Company: CPAI Well Name: 2K-34 Field Name: Kuparuk State: Alaska Date: 6/3/2014 Well Location: Kuparuk API/UWI Number: Proposal Number: v1 Contact: Jenna Houston (reviewed by Stephen Lauper) Objective: Pump a 200' long 15.8ppg Class G + S002 plug from 3575” to 3375” and then squeeze into formation. Objective is to potentially improve chances of obtaining a higher FIT. Disclaimer Notice This informatim is presented in goad faith but no warranty is given fry andSchlumbeger assumes no liability fw advice or recommendations made careening Schlumberger the use of any product or mince.The results grvei are en mates based on calculations pratxed by a computer model India]ng varians assumptiars on the well,reservoir and treatment.The resins depend on nput data prov ided by the Customer and estimates as to unknown data and can be no more accurate than the male!,the assumptions and such input data.The mfamation presented is Schlumberger's hest estimate of the results that may be achieved and should be used for comparison purposes rather anon absolute values.The quality of input data,and hence results,may be improred throw die use of certain tests and procedures which Schlumberger can assist in selecting.Freedom from iMnmymem of patents of ScNmrdeger or others s not to be inferred nor we aro such rights granted unless expressly agreed to in wrinng. 3 � WELL DATA Well Data Job Type: Abandonment Plug Rig Type: Land Total Depth(Measured): 3575 ft True Vertical Depth(TVD): 2898.6 ft TOC in pipe before POOH: 3229.9 ft TOC in annulus before POOH: 3382.4 ft O.en Hole Bottom Depth Mean Calliper Mean Excess Mean Equiv. Diameter Diameter ft 3575ft 8.5 in 12% 8.915 in Drill Pi.e Bottom Measured OD ID Weight Depth 2655 ft 5 in 4.276 in 19.5 Ibm/ft 3575 ft 3.5 in 2.992 in 9.5 Ibm/ft • Bottom Measured OD ID Weight Depth 28ft 3545 ft 10.75 in 9.95 in 45.5 Ibm/ft ft ft ft Schlumberger .. b FLUIDS DATA Fluids Data Name Type Density, Model Consistency, Power Ty, Gel Ibm/gal Ibf.s^n/100ft Index Ibf/100ft2 Strength, 2 Ibf/100ft2 Mud MUD 9.6 Herschel-B. 0.12555 0.83 1.44 4.27 MUDPUSH II SPACER 10.5 Herschel-B. 3.29418I 0.42 6.11 29.67 Shoe SLURRY 15.8 Herschel B. 0.93207 0.84 0.06 8.31 Squeeze Slurry Shoe Squeeze Slurry DESIGN Fluid No:4 Density : 15.80 lb/gal Rheo.Model : HERSCHEL_B. k :9.32E-3 Ibf.s^n/ft2 At temp. :71 degF n :0.843 Ty :0.06 lbf/100ft2 Gel Strength :8.31 Ibf/100ft2 DESIGN BLEND SLURRY Name :G Mix Fluid :5.095 gal/sk Job volume : 18.7 bbl Dry Density : 199.77 lb/ft3 Yield : 1.17 ft3/sk Quantity :89.76 sk Sack Weight :94 lb Solid Fraction :41.7% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.095 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.300%BWOB Dispersant D167 0.550%BWOB Fluid loss D153 0.150%BWOB Antisettling S002 0.500%BWOB Accelerator Schlumberger t ---, 1 PLACEMENT VOLUMES Placement Summary Volume Optimization Plug Length 200 ft Plug top MD after POOH 3375 ft Plug Volume 18.67 bbl Original Fluid Mud Underdisplacement Volume 2.4 bbl Drill Pipe Volume 55.16 bbl Fluid Se.uence Name Balanced Volume, Annular Top MD,ft Density, Length,ft bbl Length,ft Ibm/gal Mud 238.7 3223.1 0 9.6 3223.1 MUDPUSH II ? 13.4 159.3 3223.1 10.5 159.3 Shoe Squeeze ? 15.7 192.6 3382.4 15.8 192.6 Slurry Shoe Squeeze 2 3 0 3229.9 15.8 345.1 Slurry MUDPUSH II 3.1 0 2870.7 10.5 359.3 Mud 47.8 0 67.7 9.6 2803 Schlumberger Y.: 70. STATIC PULL OUT OF HOLE (POOH) POOH Summa Final drill pipe shoe depth after POOH: 3002.94 ft Length of uncontaminated cement after POOH: 199.88 ft Length of contaminated cement after POOH: 0 ft Top MD of uncontaminated cement after POOH: 3375.12 ft POOH Simulation Results Interfaces in annulus 0 596 "" 1192 _ JI' 1786 , 2383 • 2979 3 3.I 3 ft 3575 -3-1.Eft 3575 3575 3432 3289 3146 3X+3 3_!5 ft 3575 3432 3289 3146 3003 Shoe Depth MD,ft I-. Shoe Depth MD,ft Schlumberger qy PLACEMENT Pumping Schedule Fluid Name Flow Rate, Volume,bbl Time,min Backpressure, Cumulative bbl/min psi Time,min MUDPUSH II 5 13.42 2.68 0 2.68 FtN4 Shoe Squeeze Slurry 5 18.67 3.73 0 6.42 MUDPUSH II 5 3.12 0.62 0 7.04 Mud 5 47.83 9.57 0 16.61 Well Security Pressure.psi 0 226 452 979 9:3 1129 1355 1581 1807 2033 0.00 200.00 • 400.00 • 600.00 800.00 1000.00 1200.00 1400.00 1600.00 -PorePressure.psiinAr 1800.00 Frac Pressure,psi in An O , ....Min Pressure.psi in Ant 2000.00 "Max Pressure.psi inAn 2200,00 m Min Static Pressure.psi Max Static Pressure,ps 2400.00 t 2600.00 2800.00 3000.00 \\ 3200.00 3400.00 3600.00 3800.00 gamic Well Fe Min annular pore security 17.6%(220.3psi)at MD=3575ft. ecurity rac Min annular frac security 19.8%(372psi)at MD=3575ft. Pore Min annular static pore security 15.7%(195.1psi)at MD= Static Well Security 3558.6ft. Frac Min annular static frac security 21.1%(396.5psi)at MD= 3575ft. Schlumberger FLUID MIXING BEFORE POOH Fluid Mixing at the end of placement Annulus Mixing Slurry in ArmulL_ Pipe'.'.zing Slurry in Pipe Legend Zones Contamination Ris, : Ys Contamination Risk 0 0 .- ,J. Slurry Contaminat 0 No Sirrry Hips Catttarni 0 Medium Conte Ili Low Contamin '00• '4:: _: Z•_. 2100• kids Mud O Mud - MUOPUSH II 0 CW100 0 Slue Squeeze 0 =-ash Water ALC Lead Cassie 1 9.62'. • Piot Slurr Contamination Risk Pipe High:647 ft Medium:259 ft Low:151 ft Annulus Ry ``'='-- High:143 ft Medium:18 ft Low:152 ft Schlumberger Schlumberger C e m CA D E* well cementing recommendation for 10 3/4" Surface Operator : CPAI Well : 2K-34 Country : USA Field : Kuparuk State : Alaska Prepared for : Mike Callahan Location : Kuparuk Proposal No. : v3 Service Point : Prudhoe Bay Date Prepared : 6.1.14 Business Phone : (907)659-2434 Prepared by : Jenna Houston Phone : (907)223-8916 E-Mail Address : jhouston2@slb.com n LIRE Disclaimer Notice: Schlumberger submits the dwnsnent with the benefit of its judgment.experience.and Dowd aafield practices. This information is provided in accordance with generally accepted industry practice,retying an facts or information provided by others,limitations,computer models,measurements.assumptions and inferences that are not infallible. Calculations are estimates based on provided information,M proposals,recounendations,or prerfntions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE.OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of alp intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights aro granted hereby. Mark of Schlumberger Page 1 2K-34 cement v1.cfw;06-01-2014; LoadCase Surface w/crete:Version wcs-cem473_O8 Client : CPAI Well : 2K-34 Schlumberger String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/Crete Max. Deviation Angle : 55 deg Max. DLS : 2.500 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.8 271.8 0.750 400.0 400.0 2.3 271.8 1.500 500.0 499.8 3.8 271.8 1.500 600.0 599.5 5.3 271.8 1.500 700.0 698.9 7.3 271.8 2.000 800.0 797.9 9.3 271.8 2.000 900.0 896.4 10.2 271.8 0.980 1000.0 994.6 11.5 271.8 1.230 1100.0 1092.2 14.0 271.8 2.500 1200.0 1188.7 16.5 271.8 2.500 1300.0 1283.9 19.0 271.8 2.500 1400.0 1377.8 21.5 271.8 2.500 1500.0 1470.0 24.0 271.8 2.500 1600.0 1560.5 26.5 271.8 2.500 1700.0 1649.0 29.0 271.8 2.500 1800.0 1735.4 31.5 271.8 2.500 1900.0 1819.5 34.0 271.8 2.500 2000.0 1901.2 36.5 271.8 2.500 2100.0 1980.3 39.0 271.8 2.500 2200.0 2056.7 41.5 271.8 2.500 2300.0 2130.2 44.0 271.8 2.500 2400.0 2200.6 46.5 271.8 2.500 2500.0 2267.9 49.0 271.8 2.500 2600.0 2331.9 51.5 271.8 2.500 2700.0 2392.5 54.0 271.8 2.500 2800.0 2450.8 54.7 271.8 0.740 2900.0 2508.6 54.7 271.8 0.000 3000.0 2566.4 54.7 271.8 0.000 3100.0 2624.1 54.7 271.8 0.000 3200.0 2681.9 54.7 271.8 0.000 3300.0 2739.7 54.7 271.8 0.000 3400.0 2797.5 54.7 271.8 0.000 3500.0 2855.3 54.7 271.8 0.000 3555.0 2887.1 54.7 271.8 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1529.0 12.50 8.30 Base permafrost Sandstone 3555.0 12.50 8.30 TD Sandstone Page 3 2K-34 cement v1.ciw:06-01-2014, LoadCase Surface wI crete,Version wcs-cem473 08 Client : CPAI Well : 2K-34 Schlum holler String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crate Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (deg F) (degF/100ft) 0.0 0.0 20 0.0 1529.0 1496.4 32 0.8 3555.0 2887.1 81 2.1 Page 4 2K-34 cement vl.cfw;06-01-2014; LoadCase Surface w/Crete;Version wcs-cern473 08 Client : CPAI Well : 2K-34 Schlumberger String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/trete Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :3535.0 ft Casing Shoe :3555.0 ft NB of Cent. Used :50 NB of Floating Cent. :18 Centralizer Placement Bottom MD Nbr. Cent./ Cent.Name Code Min.STO @ Depth (ft) Joint (%) (ft) 3035.0 37 1/2 S1104610-10 3/4-6-46 2.6 2895.0 (3/16")B 3555.0 13 1/1 S1104610-103/4-6-46 67.7 3555.0 (3/16")B Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) S1104610-10 3/4-6- 10 3/4 15.874 11.874 No Houma 13.500 708.15 1450.02 46(3/16")13 ft Jro 0 20 0 60 80 100 - - Betoeen Cent. -i At Cent. Ns ' 1 J ti — Pipe Standoff Page 5 2K-34 cement vi.ciw.06-01-2014; loadCase Surface w/trete:Version wcs-cem473 08 Client : CPAI Well : 2K-34 Sclanderner String : 10 3/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Section 3: fluid description Mud DESIGN Fluid No: 1 Density :9.80 lb/gal Rheo.Model :HERSCHEL_B. k :1.26E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.835 Ty : 1.44 lbf/100ft2 Gel Strength :4.27 Ibf/100ft2 MUD Mud Type :WBM Job volume :324.2 bbl Water Type :Fresh VOLUME FRACTION Solids :9.0% Oil : 1.0% Water :90.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model :HERSCHEL_B. k :3.29E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.417 Ty :6.11 lbf/100ft2 Gel Strength :29.67 Ibf/100ft2 Job volume :90.0 bbl Surface Tall DeepCRETE Slurry DESIGN Fluid No:4 Density : 12.00 lb/gal Rheo.Model :BINGHAM Pv : 167.753 cP At temp. :71 degF Ty : 14.32 Ibf/100ft2 Gel Strength :20.19 lbf/100ft2 DESIGN BLEND SLURRY Name : 12.0(0.80) Mix Fluid :5.482 gaUsk Job volume : 56.3 bbl Dry Density : 112.29 lb/ft3 Yield : 1.63 ft3/sk Quantity : 194.40 sk Sack Weight : 100 lb Solid Fraction :54.9% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.392 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D185 0.060 gal/sk blend Dispers. LT D186 0.030 gal/sk blend Accelerator Page 6 2K-34 cement v1 cfw,06-01-2014. Loadfase Surface w/trete,Version wcs-cem473 08 Client : CPAI Well : 2K-34 SclimMcr String : 10 3/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Fresh Water DESIGN Fluid No:5 Density :8.32 lb/gal Rheo.Model :NEWTONIAN At temp. :(degF) Viscosity :5.000 cP Gel Strength :(Ib1/100ft2) Job volume : 10.0 bbl ALC Lead DESIGN Fluid No:6 Density : 11.02 lb/gal Rheo. Model :HERSCHEL_B. k :6.45E-3 Ibf.s^n/ft2 At temp. :71 degF n :0.907 Ty :2.70 lbf/100ft2 Gel Strength :17.81 Ibf/100ft2 DESIGN BLEND SLURRY Name :ALC B439 Mix Fluid :6.496 gal/sk Job volume :455.0 bbl Dry Density :95.42 lb/ft3 Yield :1.93 ft3/sk Quantity : 1323.71 sk Sack Weight : 100 lb Solid Fraction :55.0% BASE FLUID Type :Fresh water Density :8.35 lb/gal Base Fluid :6.296 gal/sk Additives Code Conc. Function D046 0.300%BWOB Antifoam D065 0.900%BWOB Dispersant D044 10.000%BWOW Salt Page 7 214-34 cement vt clw,06-01-2014, LoadCase Surface w/crele,Version wcs-cem473_08 • Client : CPAI Well : 2K-34 Schlumhcrgcr String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/Crete Section 4: fluid sequence Original fluid Mud 9.80 lb/gal k: 1.26E-3 Ibf.s^n/ft2 n :0.835 Tv: 1.44 lbf/100ft2 Displacement Volume 334.2 bbl Total Volume 935.4 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann.Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 90.0 0.0 10.50 k:3.29E-2 Ibf.s^n/ft2 n:0.417 Ty:6.11 Ibf/100ft2 ALC Lead 455.0 3055.0 11.02 k:6.45E-3 lbf.s^n/ft2 n:0.907 Ty:2.70 Ibf/100ft2 Surface Tail 56.3 500.0 3055.0 12.00 Pv:167.753 cP Ty:14.32 lbf/100ft2 DeepCRETE Slurry Fresh Water 10.0 3371.0 8.32 viscosity:5.000 cP Mud 324.2 0.0 9.80 k:1.26E-3lbf.s^n/ft2 n:0.835 Ty:1.44lbf/100ft2 Static Security Checks: Frac 8 psi at 110.0 ft Pore 16 psi at 110.0 ft Collapse 1786 psi at 3475.0 ft Burst 3580 psi at 0.0 ft Csg.Pump out 47 ton Check Valve Diff Press 197 psi Page 8 2K-34 cement vl.ctw;08-01-2014; LoadCase Surface w/Crete;Version wcs-cem473_08 Client : CPAI Well : 2K-34 SekInkrier String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surfacew/crete Section 5: pumping schedule Jon objective: bring cement to surface. nate nas oeen slowed to 5 bpm in case a higher rate cannot be achieved without losses/packing off. Spacer and cement rates up to 7 bpm and displacement rates up to 8 bpm are acceptable. Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 90.0 18.0 90.0 80 Pump MUDPUSH II Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug ALC Lead 5.0 455.0 91.0 455.0 80 Pump lead slurry Surface Tail 5.0 56.3 11.3 56.3 80 Pump tail slurry DeepCRETE Slurry Pause 0.0 0.0 5.0 0.0 80 Drop top plug Fresh Water 5.0 10.0 2.0 10.0 80 Kick out plug Pause 0.0 0.0 5.0 0.0 80 Swap to rig Mud 5.0 314.2 62.8 314.2 80 Displacement Mud 3.0 10.0 3.3 324.2 80 Slow to bump plug Total 03:23 935.4 bbl hr:mn Dynamic Security Checks: Frac 8 psi at 110.0 ft Pore 9 psi at 110.0 ft Collapse 1786 psi at 3475.0 ft Burst 3347 psi at 0.0 ft Temperature Results BHCT 80 degF Simulated Max HCT 73 degF Simulated BHCT 73 degF Max HCT Depth 3337.3 ft CT at TOC 71 degF Max HCT Time 03:23:25 hr:mn:sc Static temperatures : At Time 1 (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole (degF) (degF) 81 degF Page 9 2K 34 cement vl.cfw,06-01-2014, LoadCase Surface w/Crete:Version wcs-cem4f3 08 Client : CPAI Well : 2K-34 Schlumberger String : 10 3/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/trete ft (x 1000) psi 0 1 2 J L — Hydrostatic N --Calc.Pump Press. Nin.Hydrostatic Calc.CemHP Ntax.Dynamic .� Acquired Pressure -- Mn.Dynamic a — Frac — Pore 6 rn a_ 0 250 o Time (min) 8— N Depth= 3555 ft 0 CO Ari.lar Velocity E V Z^ 5 O >N-. C C O Q O ?- O 0 250 Fluid Sequence Dynamic Wel Security Time(min) Page 10 2K-34 cement v1 cfw:06-01-2014, LoadCase Surface w/crete,Version wcs-cem473_08 Client : CPAI Well : 2K-34 Sekluothrger String : 10 3/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Depth= 3555 ft W z to ^N 0 0_ I 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Fluids at 3555 ft Acq�u `"h �i�r Ac q !lh h �— QDu • Eet - Q NTzi I N- LL 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Page 11 2K-34 cement v1.cfw:06.01-2014; LoadCase Surface w/crete;Version wcs-cem473 06 Client : CPAI Well : 2K-34 Schlumberger String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Section 6: WELLCLEAN II Simulator ft 0 25 50 75 100 0 25 50 75 100+ -Std Betw.Cent. `-- Mud Contarrination -Cement Coverage -Uncontaninated Slurry §- 4.....r.........arrrx_r_f--r-j---) N ...r-rj •-] , 1- Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° s 1 0 I -9 5007- -500 S00- 506 1000- -1000 1000- 1000 = 1500- -moil E g 1590- 1500 E. $ 2090- 2090 $ $ 2090- 2000 2500- -2500 2500- 2500 3006 30.00. 3000- 3000 3506 11.11111 3504 3500 3500 30 3 3 0 3 i 2 ill I Mud I I High L I Low Fresh Water I I Medium I I None MI Surface Tail DeepCRETE Slurry I I ALC Lead I I MUDPUSH II Page 12 2K-34 cement vt.crw;06-01-2014: LoadCase Surface w/crete;Version wcs-cem473_08 Client : CPAI Well : 2K-34 SchluWbcrgcr String : 10 3/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Tolerances - Spacer Max Rate is 7 BPM - Cement rate 5-7 BPM (remain within +/-0.2ppg Density Range,to be checked periodically with a mud balance, if rate is reduced ensure TT requirements are still met) - Max displacement Rate is 8 BPM, must slow to 3 BPM as indicated - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be conditioned prior to cementing - Maintain returns during cement job if possible Contingencies In the event that a problem occurs during mixing, pumping, or displacement, contingency plans should be systematically followed. If a shutdown occurs during the job, make note in the CemCAT report of when the stoppage occurred and how much time is available to remedy an issue before the thickening time becomes a problem. 1) If losses are encountered prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Slow rate until full circulation is regained c) Determine max rate with full circulation and pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at minimum rate b) Attempt to remedy issue c) If issue with mixing system—switch to back-up mixing system d) If issue with triplex pump—continue with secondary triplex on unit 3) Mud Pump failure during displacement a) Discuss rig up in the event of cement unit displacement in PJSM b) Attempt to continue displacement with secondary rig pump c) Attempt to remedy issue d) Note displacement volume pumped by mud pumps: verify with well site leader e) Subtract pumped volume from total volume, which will be the volume pumped by the cement unit f) Rig up hoses to get mud to Cement Unit and begin displacement with cement unit (verify volume with well site leader) Page 13 2K-34 cement vt.cfw;06-01-2014; LoadCase Surface w/crete;Version wcs-cem473 06 PTD Z / -OZ� Ferguson, Victoria L (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday,June 05, 2014 9:50 AM To: Ferguson,Victoria L(DOA) Subject: RE:2K-34 (PTD#214-026) Surface Cement Squeeze Results Attachments: 2K-34 10.75in Surface CADE v3 6.1.14.pdf;2K-34 Surface Cement Squeeze Schedule.docx; 2K-34 Shoe Squeeze Plugadvisor v16.3.14.pdf Victoria, I have attached the simulation for the surface job we pumped. The cement job went well, with 176 bbls of cement back to surface. We were unable to reciprocate during the job,which may have contributed to the unsuccessful LOT. I've also attached the simulation and the pumping schedule we followed for the squeeze job. We were able to pump away 6 bbls of cement, with 0.5 bbls bleeding back after the squeeze. Let me know if this is what you are looking for or if you would like more information. Vo Thanks, Mike From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent:Thursday, June 05, 2014 9:38 AM To: Callahan, Mike S Subject: [EXTERNAL]RE: 2K-34 (PTD # 214-026) Surface Cement Squeeze Results Please send details of the surface casing cement job as well as the hesitation squeeze. Thanx, Victoria From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent: Thursday, June 05, 2014 9:33 AM To: Ferguson, Victoria L(DOA) Subject: 2K-34 (PTD # 214-026) Surface Cement Squeeze Results Victoria,as discussed on the phone,we just completed a cement squeeze below our surface casing shoe on 2K-34 on Doyon 141. After our initial drill out,our LOT showed a very slow pressure build-up,followed by a rapid pressure drop after shut-in. We performed two LOT's with the same result(both attached),which we believe may indicate some sort of small cement channel at the shoe. We performed a hesitation squeeze, pumping away 5.5 bbls of cement,to remedy this. After drilling out the cement from the squeeze,we completed another LOT(actually an FIT,stopping at 14.7 ppg) that looks much better and does not have the same pressure drop after shut-in (labeled 2K-34 Surface casing test FIT V.3), indicating we have a good shoe at this point. 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(71(0 oa 03 -403 O , tDOCDOOO OO CAOOCn OOCTO O 01001 0000 0000 Client : CPAI Well : 2K-34 Scbi Nrgcr String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/creta Section 3: fluid description Mud DESIGN Fluid No: 1 Density :9.80 lb/gal Rheo.Model :HERSCHEL_B. k : 1.26E-3 lbf.sAn/ft2 At temp. :80 degF n :0.835 Ty : 1.44 lbf/100ft2 Gel Strength :4.27 Ibf/100ft2 MUD Mud Type :WBM Job volume :324.2 bbl Water Type : Fresh VOLUME FRACTION Solids :9.0 Oil : 1.0% Water :90.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo.Model :HERSCHEL_B. k :3.29E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.417 Ty :6.11 Ibf/100ft2 Gel Strength :29.67 Ibf/100ft2 Job volume . 90.0 bbl Surface Tail DeepCRETE Slurry DESIGN Fluid No:4 Density . 12.00 lb/gal Rheo. Model :BINGHAM Pv :167.753 cP At temp. :71 degF Ty :14.32 Ibf/100ft2 Gel Strength :20.19 lbf/100ft2 DESIGN BLEND SLURRY Name : 12.0(0.80) Mix Fluid :5.482 gal/sk Job volume :56.3 bbl Dry Density : 112.29 lb/ft3 Yield :1.63 ft3/sk Quantity : 194.40 sk Sack Weight : 100 lb Solid Fraction :54.9% BASE FLUID Type :Fresh water Density :8.32 lb/gal Base Fluid :5.392 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D185 0.060 gal/sk blend Dispers.LT D186 0.030 gal/sk blend Accelerator Page 6 2K-34 cement v1 cfw,06-01-2014, LoadCase Surface w/trete,Version wcs-cem473_08 Client : CPAI Well : 2K-34 WIWI" String : 10 3/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/Crete Fresh Water DESIGN Fluid No:5 Density :8.32 lb/gal Rheo.Model :NEWTONIAN At temp. :(degF) Viscosity :5.000 cP Gel Strength :(Ibf/100ft2) Job volume : 10.0 bbl ALC Lead DESIGN Fluid No:6 Density : 11.02 lb/gal Rheo. Model :HERSCHEL_B. k :6.45E-3 Ibf.s^n/ft2 At temp. :71 degF n :0.907 Ty :2.70 lbf/100ft2 Gel Strength : 17.81 Ibf/100ft2 DESIGN BLEND SLURRY Name :ALC B439 Mix Fluid :6.496 gal/sk Job volume :455.0 bbl Dry Density :95.42 Ib/ft3 Yield : 1.93 ft3/sk Quantity : 1323.71 sk Sack Weight : 100 lb Solid Fraction :55.0% BASE FLUID Type : Fresh water Density :8.35 lb/gal Base Fluid :6.296 gal/sk Additives Code Conc. Function D046 0.300%BWOB Antifoam D065 0.900%BWOB Dispersant D044 10.000%BWOW Salt Page 7 2K-34 cement v1 cfw,O8-01-2014, LoadCase Surface W/crete,Version wcs-cem473_08 . Client : CPAI Well : 2K-34 Schlumbargcr String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Section 5: pumping schedule Job objective: bring cement to surface. Rate has been slowed to 5 bpm in case a higher rate cannot be achieved without losses/packing off. Spacer and cement rates up to 7 bpm and displacement rates up to 8 bpm are acceptable. Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 90.0 18.0 90.0 80 Pump MUDPUSH II Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug ALC Lead 5.0 455.0 91.0 455.0 80 Pump lead slurry Surface Tail 5.0 56.3 11.3 56.3 80 Pump tail slurry DeepCRETE Slurry Pause 0.0 0.0 5.0 0.0 80 Drop top plug Fresh Water 5.0 10.0 2.0 10.0 80 Kick out plug Pause 0.0 0.0 5.0 0.0 80 Swap to rig Mud 5.0 314.2 62.8 314.2 80 Displacement Mud 3.0 10.0 3.3 324.2 80 Slow to bump plug Total 03:23 935.4 bbl hr:mn Dynamic Security Checks: Frac 8 psi at 110.0 ft Pore 9 psi at 110.0 ft Collapse 1786 psi at 3475.0 ft Burst 3347 psi at 0.0 ft Temperature Results BHCT 80 degF Simulated Max HCT 73 degF Simulated BHCT 73 degF Max HCT Depth 3337.3 ft CT at TOC 71 degF Max HCT Time 03:23:25 hr:mn:sc Static temperatures: At Time I (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole (degF) (degF) 81 degF Page 9 2K-34 cement v1.cfw;06-01-2014; LoadCase Surface w/crete:Version wcs-cem473_08 CIF 'rye, STATE _=1 33 W,=,st Sc"/ l ili A nliuc 1-I\AC,I: PAiZN1'[ 1 Anchorage AlUsl945;,1-3572 1433 G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-34 ConocoPhillips Alaska, Inc. Permit No: 214-026 Surface Location: 4983' FNL, 34' FEL, SEC. 2, T10N, T8E, UM Bottomhole Location: 4730' FNL, 4318' FEL, SEC. 3, T10N, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. Foerster Chair DATED this day of February, 2014. ' RECEIVED ` STATE OF ALASKA FEB 13 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a Type of Work 1 b Proposed Well Class Development-Oil Q• Service-Winj ❑ Single Zone D. 1c Specify if well is proposed for: Drill Q• Lateral E Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redd ❑ Reentry[ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name' 5. Bond U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2K-34 r 3.Address 6.Proposed Depth 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 12387', TVD: 6217' • Kuparuk River Field 4a Location of Well(Governmental Section) 7 Property Designation(Lease Number) Surface:4983'FNL,94'FEL,Sec.2,T1ON,T8E, UM • ADL 25588,25589 Kuparuk Oil Pool - Top of Productive Horizon: 8.Land Use Permit 13.Approximate Spud Date 4951'FNL, 1604'FEL,Sec.3,T1ON,R8E,UM ` 2674,2675 4/20/2014 Total Depth. 9.Acres in Property. 14.Distance to 4730'FNL,4318'FEL,Sec.3,T1ON,R8E, UM S(a0 -2580 9,1bNearest Property >1 mile 4b Location of Well(State Base Plane Coordinates-NAD 27): 10 KB Elevation above MSL. /VG„,S 44-8 feet 15 Distance to Nearest Well Open Surface:x- 498310 y- 5938600 Zone- 4 , GL Elevation above MSL.ll$•. -228•feet to Same Pool: 2K-13A,1750 16.Deviated wells Kickoff depth. . 300 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle- , 92° deg Downhole:846e psig 3750 ? Surface:3305 psig r 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) 42" 16" 62.5# H-40 Welded 87' 28' 28' 115' 115' driven 13.5" 10.75" 45.5# L-80 Hydril 563 3600' 28' 28' 3600' 2818' 120 sx Arctic LiteCRETE,200 sx DeepCRET 8.5" 7" 26# L-80 Hydril 563 9652' 28' 28' 9652' 6126' 280 sx Class G 6.125" 4.5" 12 6# L-80 IBTM 2886' 9500' 6081' 12387' 6217' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20 Attachments: Property Plat❑ BOP Sketch❑ Drilling Prograrr ❑✓ Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25 050 requirements Q 21.Verbal Approval Commission Representative Date. //2/?O/L/ fif. �-- 22. I hereby certify that the foregoing is true and correct Contact Mike Callahan @ 263-4180 LI% JOI,.GeG ! Fbi2 Email Mike Callahanaconocophillips.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signaturef9,-rbh/1Phone:265-6120 Date a2//.1h04r Commission Use Only Permit to Drill API Number 1 Permit Approval 1 See cover letter Number. Rill 01� 50- )03— �0b�' -00 — 00 Date: t�� �'+✓]I 1 Ifor other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m`a ane,gas hydrates,or gas contained in shales Er- Other:, 30 P 1--e if -/-0 3 SD U p 5 I . Samples req'd. Yes ❑ o Mud log req'd: Yes❑ No Er W a v c r q r-a r-, 1 z cl un ca c r 2 o,44 6%25- 5142S measures: Yes [No ❑ Directional svy req'd: Yes Er No❑ ;t d 11 o w C 4,5?h y d I''1) 'N Spacing exception req'd: Yes ElNo [ Inclination-only svy req'd: Yes❑ No 2---- LA,-11-11 0:4 ----Lv11-11avf c, dirt cril a1 6vrvtr, _ APPROVED BY THE Approved by C ivOif rGin /� t o date N Date al iZI t 't'Form 10-401 (R vised 10/2012) This permi i li f r h fr`I/M►,tJJLLdate of approval(20 AAC 25.005(g)) '�I(3 if t_F 212///f Conoco$hillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Mike Callahan Phone (907) 263-4180 February 12, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk"A"Sand Producer, 2K-34 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore producer well, a horizontal well in the Kuparuk"A"sand. The expected spud date for 2K-34 is April 20th, 2014, using the Doyon 141 drilling rig. The rig will drill a 13-1/2"surface hole and run 10-3/4"casing to "3600'. An 8-1/2"intermediate section will be conventionally drilled to 9150', building to 72°. 7"intermediate casing with an 8-1/2"casing while drilling bit will then be run. The well will be casing drilled to a depth of 9,652' MD, holding a constant angle for the duration of the casing drilled section, at which point the 7"casing will be cemented in place. No MWD or directional tools will be part of the casing drilling assembly, preventing the ability to take directional surveys while drilling. A request for a waiver of the requirement to survey every 500'of a tangent section in a directional well is attached in this application. A 6-1/8"production lateral of approximately 2,700'will then be drilled to a TD of 12,387'. The well will be completed with a 4-1/2" production liner with perforated pup joints, set at "9,500', and 3-1/2" production tubing run to surface. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 2K-34. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 2500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also, a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for this well. Sincerely, Mike Callahan Kuparuk Drilling Engineer lication for Permit to Drill,Well 2K-34 Revision No.0 Saved: 12-Feb-14 Permit It — Kuparuk Well 2K-34 ass . Application for Permit to Drill Document R"-4. M zxirnize Well %/414e Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(t) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 10.Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 11.Seabed Condition Analysis 5 Requirements of 20 AAC 25.005 (c)(11) 5 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 2K-34 PTD.doc Page 1 of 7 ORIGINAL Printed: 12-Feb-14 'ication for Permit to Drill,Well 2K-34 Revision No.0 Saved. 12-Feb-14 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005 (c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Loads and CemCADE Summary 7 Attachment 4 Well Schematic 7 Attachment 5 Request for Waiver of 20 AAC 25.050 7 1. Well Name Requirements of 20 AAC 25.005(i) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2K-34. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4983' FNL 94' FEL Sec. 2 Twn 10N Rng 8E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 146.5'AMSL Northings 5,938,600.18 Eastings: 498,310.14 Pad Elevation 118.5'AMSL Location at Top of Productive Interval 4951' FNL 1604' FEL Sec. 3 Twn 10N Rng 8E UM (Kuparuk"A4"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9772' Northings: 5,938,641.40 Eastings:491,404.25 Total Vertical Depth, RKB: 6157' Total Vertical Depth, 55: 6010' Location at Total Depth 4730' FNL 4318' FEL Sec. 3 Twn lON Rng 8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12387' Northings: 5,938,862.09 Eastings: 488,806.97 Total Vertical Depth, RKB: 6217' Total Vertical Depth, 5S: 6070' and (D)other information required by 20 AAC 25.050(6); 2K-34 PTD.doc Page 2 of 7 Printed' 12-Feb-14 �� ; ! lN IAL lication for Permit to Drill,Well 2K-34 Revision No.0 Saved: 12-Feb-14 Requirements of 20 AA C 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 2K-34 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 25.035,20 MC 25.036, or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 2K-34. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on dolling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum expected reservoir pressure in the Kuparuk C and A Sands at the location of 2K-34 is / 0.650 psi/ft, or 12.5 ppg EMW (equivalent mud weight). This pressure is predicted based on the maximum pressures measured in our nearest offset wells 2K-13 (12.2 ppg) and 2K-06 (11.. ppg). The nearest well to the north is 2M-14, with a pressure of 13.7 ppg, but that well is believe to be isolated by faults so that pressure should not be seen at the 2K-34 location. Note that these pressures have been monitored on a monthly basis and have stabilized near these values. All nearby injection is shut-in and will remain shut-in until after the drilling of 2K-34, so these should represent the absolute maximum possible pressure seen in 2K-34. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the formations is 3,305 psi, calculated thusly: MPSP = (6,120 ft TVD)(0.650 - 0.11 psi/ft) = 3,305 psi (B)data on potential gas zones; The wellbore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 2K-34 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: 2K-34 PTD doc Page 3 of 7 ci n I I iL Printed: 12-Feb-14 cation for Permit to Drill,Well 2K-34 Revision No.0 Saved: 12-Feb-14 (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(0; Leak off and/or formation integrity tests will be performed roughly 20 feet below both the surface and intermediate casing shoes in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 42 62.5 H-40 Welded 87' Surf 115'/115' Planned: Driven Planned: Cement top planned to surface - 11.0 10-3/4" 13-1/2" 45.5 L-80 Hyd563 3,600' Surf 3,600'/2,818' ppg Arctic LiteCRETE lead and 12.0 ppg DeepCRETE tail Planned: Cement Top 7" 8-1/2" 26 L-80 Hyd563 / 9,652' Surf 9,652'/6,126' planned @ 8,000' TN-BlueMD/5455'TVD - 15.8 ppg Class G 4-1/2" 6-1/8" 12.6 L-80 IBTM 2,886' 9500/6,081' 12,387'/6,217' N/A 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 2K-34 surface hole. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 2K-34 PTD.doc Page 4 of 7 ORIGINAL Printed: 12-Feb-14 cation for Permit to Drill,Well 2K-34 Revision No.0 Saved: 12-Feb-14 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Casing Surface Intermediate Drilling Production 13-1/2" Hole 8-1/2" Hole 8-1/2" Hole 6-1/8" Hole 10-3/4" Casing 7" Casing 4-1/2" Liner Mud System DRILPLEX LSND LSND FLO-THRU Density 8.8-9.5 9.6- 10.0 10.0- 12.5 12.5 PV 10-20 10-20 10-20 10-20 YP 40-80 20-28 16-24 16-24 LSYP 30-50 7-9 6-8 5-7 Initial Gel 30-50 8- 12 6- 12 5- 10 10 minute Gel 30-50 8- 18 6- 16 6- 12 API Filtrate NC < 6 <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 < 10 pH 10.5- 11.5 9.5- 10.0 9.0- 10.0 9.5- 10.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. 2K-34 PTD.doc Page 5 of 7 ORIGINAL Printed: 12-Feb-14 cation for Permit to Drill,Well 2K-34 Revision No.0 Saved: 12-Feb-14 12.Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16"conductor to +/- 120' RKB. Install landing ring on conductor. 2. Move in/ rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 13-1/2"hole to casing point at +/- 3600' MD / 2818'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install wellhead and test to 5000 psi. Nipple up BOPE and test 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 8.5" bit and 6.75"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30 minutes. 7. Drill out cement and 20'of new hole. Perform leak off test (or FIT to maximum of 16.0ppg EMW), recording results. 8. Directionally drill to 8-1/2"casing drilling point at "9150' MD/ 5977'TVD. Pull out of hole on elevators to the surface casing shoe. 9. If tight hole is observed while pulling out on elevators, perform wiper trip prior to running casing. 10. Run 7", 26# L80, Tenaris Blue casing with 8-1/2" Baker EZCase bit to TD. Perform open hole LOT prior to beginning casing drilling and record results. 11. Casing drill to 9450' MD (roughly 200' MD above top of C-Sand) while weighting up mud to 12.5 ppg and adding Torque Seal LCM, perform a second open hole LOT and record results. Proceed drilling to TD of 9652' MD/ 6126'TVD. 11.1. Note that this will be —500'of new hole drilled without the ability to take surveys. Please see attachment 5, requesting a waiver of 20 MC 25.050 (c)(1) to allow for drilling greater than 500' without taking a directional survey. 12. Cement 7" intermediate casing in place, with planned top of cement to be 8000' MD, roughly 650'TVD above the top of the C-Sand. 13. Flush 10.75"x 7"annulus with water, followed by diesel to freeze protect annulus down to base permafrost. 14. Perform gyro run on E-line to confirm well position following casing drilling section. 15. PU 6-1/8" PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools, including Schlumberger's Stethoscope (formation pressure). RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 2K-34 PTD.doc Page 6 of 7 Printed: 12-Feb-14 ORIGINAL cation for Permit to Drill,Well 2K-34 Revision No.0 Saved: 12-Feb-14 16. Drill out cement and 20'of new hole. Perform LOT(or FIT to maximum of 16.0 ppg EMW), recording results. 17. Directionally drill 6-1/8" hole to TD at +/- 12387' MD/ 6217'TVD as per directional plan, taking pressure points with Stethoscope every —500'. POOH to 7"shoe. If tight hole is seen while tripping to the shoe, perform wiper trip to TD. POOH and lay down BHA. 18. PU and run 4-1/2"liner with perforated pup joints to TD and set liner hanger @ +/- 9500'MD/6081'ND. 19. Set liner top packer and POOH. 20. PU 3.5"tubing and RIH. Displace well to brine and land tubing. Set two-way check valve in tubing. 21. Nipple down BOPE, nipple up tree and test. Pull two-way check valve. 22. Freeze protect well with diesel by pumping into 3.5"x 7"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 23. Set BPV and move rig off. 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 2K Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 2K Pad, 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Request for waiver of 20 AAC 25.050(c)(1) 2K-34 PTD doc Page 7 of 7 OR I D q L Printed: 12-Feb-14 - DDl 2K-34wp05 6 . 323 Plan Summary SURVEY PROGRAM 12 23.Fehruay 07 27 j ,.„„p Depth From Depth To Survey/Plan Tool "'- 11 :00 3571.92 2K-34wp05(2K-34) MWD+IFR-AK-CAZ-SC - ' 3571.92 9275.00 2K-34wp05(2K-34) MWD+IFR-AK-CAZ-SC _ ------ /• / 9275.00 9668.58 2K-34wp05(2K-34) MWD+IFR-AK-CAZ-SC k 9668.5812386.41 2K-34wp05(2K-34) MWD+IFR-AK-CAZ-SC CASING DETAILS \\ TVD MD Name Size 2896.50 3571.92 10-3/4" x 13-1/2" 10-3/4 6014.44 9275.00 7"x 8-1/2" 7 6125.50 9851t.6?J/2"Casing Drilling 7 6213.7012328.48 4 1/2"x 6 1/8" 4-1/2 I I _ �6, 0 00 i.i 10-3 4"x 13-1/2" 5 a- -5 0 L,_' 0i' 00 7"50 8-1/2" 41/2"x 61/8" 0 00 `m Ln b 0 / 0 hi) o co o ® � 7"50 8 1/2"Casing Drilling I h o Op ` 1 rn o p o gbh <o 10-3/4"x 13-1/2" - 0 0000°�A °D 03 riG N CD , ' r 1111111111 0 ` I y, ' 0 0 1500 3000 4500 600075006 9000 0 3000 6000 9000 12000 Horizontal Departure Measured Depth 0 0 60 - ii : III Il28 250 i. :_ I <p11 • n, 50 330 ',�. 596 ze0 - "0 O �� ',: ,1K-06• 03 550 550 650 550 m � 1ri 300 ........<4. r 60 - 850 •2 III t<t ',.. 1050 - 250 4VI�, ,zeo ,aeo • - l.. '-... `144. 2K 2 '60 � illli 11 I I 2N 29wpt 0 30 I Ir 270 �`�ai 0,66 III III '' may, 5,50 1 it 13. 6,6" - "60 2 mlllb "54 4130 y - ,,.. ' .,:". "0' 4,60 - U 240 1:ff t!-.," 120 MO - 5150 �/Jof m.m. - 0 i i + 1 1 1 I I I I I I I I I I I I I I I I I I 1''11 ''• p 210• :50 9150 7150 8150 8150 0 1500 3000 4500 6000 7500 9000 10500 12000 9150 ' .1e0 10150 - 12150 12150 - 14150 SECTION DETAILS 14150 - 16150 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 -118.50 0.00 0.00 5938170.36 1638342.94 0.00 0.00 0.00 -5836.5 2 250.00 0.00 0.00 250.00 103.50 0.00 0.00 5938170.36 1638342.94 0.00 0.00 0.00 3 600.49 5.26 271.82 600.00 453.50 0.51 -16.06 5938170.87 1638326.88 1.50 271.82 16.07 4 849.34 10.23 271.82 846.50 700.00 1.58 -49.57 5938171.95 1638293.37 2.00 0.00 49.59 5 950.96 10.23 271.82 946.50 800.00 2.15 -67.62 5938172.53 1638275.33 0.00 0.00 67.65 6 2729.58 54.70 271.82 2409.75 2263.25 31.72 -998.16 5938202.35 1637344.89 2.50 0.00 998.57 7 8336.93 54.70 271.82 5650.00 5503.50 177.06 -5572.22 5938348.94 1632771.32 0.00 0.00 5574.50 8 8941.93 72.85 271.82 5916.23 5769.73 194.23-6112.41 5938366.25 1632231.19 3.00 0.00 6114.91 9 9668.58 72.85 271.82 6130.50 5984.00 216.28 -6806.39 5938388.49 1631537.29 0.00 0.00 6809.17 1010008.21 90.00 272.05 6180.95 6034.45 227.59 -7140.79 5938399.89 1631202.93 5.05 0.78 7143.74 2K-34 JC 27Aug13 Heel Top HRZ 11 10121.74 91.70 270.55 6179.27 6032.77 230.16 -7254.27 5938402.50 1631089.46 2.00 -41.52 7257.22 12 10704.09 91.70 270.55 6161.99 6015.49 235.70 -7836.33 5938408.20 1630507.46 0.00 0.00 7838.93 13 11073.85 90.00 277.74 6156.50 6010.00 262.41 -8204.83 5938435.00 1630139.00 2.00 103.22 8208.26 2K-34 JC 27Aug13 Crest 14 11212.14 87.23 277.74 6159.84 6013.34 281.04-8341.81 5938453.66 1630002.04 2.00 180.00 8345.94 15 12386.41 87.23 277.74 6216.50 6070.00 439.07-9504.01 5938612.00 1628840.00 0.00 0.00 9514.15 2K-34 JC 27Aug13 Toe ' - -6000.5 • A°"- Top Kalubik/Base HR -6041.5 K-1 -6120.5 Top C =MirgA-6 Top A-5 -61fid`A-4 Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2012 T M Depth Reference: Plan:118.5+28©146.50ft(Doyon 141) Magnetic Madel Date: 04-Sep-13 System(SS)Reference: Mean Sea Level Magnetic Declination: 19.65° -1Sti- North/Y: 5938170.36 Ground Level/Mud Line: 118.50 To convert a Magnetic Direction to a True Direction,Add 19.65°East East/X: 1638342.94 Rig: Doyon orucINAL GLOBAL FILTER:Using user defined selection&filtering criteria 0 .� V C ■ li = C L m a o C) FNM M CCSi i N C%1 C p0. 0- CMCZ LL V Y Y a N a 0 o ORIGINAL • I a Z � Z OM C p o O a N U O C) O Pco 4 r 0- C_ �■,J� (n (n 2 o .� OU 2 e_- 3 c a) ©@ 0 O` a) U M 0o 0o f6 a a)..O- Ut 'ICI' Y + + 7 (p > a) . 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C State Plane Zone:(True .1 Units: us-ft • C Legal Description(NAD 27 only) G Legal Description[NAD27 only) -Starting Coordinates: -Legal Description — — 1498310.14 Township: 010 N . Range:For JE A Y: 15938600.18 Meridian: (U J Section: IFNL4983.3232 )FEL J 194.202187 Transform I Quit I Help 2K-34wp05 Intermediate Casing I ■ 'CAA(Coordinate '' — 0 X From: -- — — —To:— Datum: INAD27 J Region: )alaska A Datum: INAD27 =..f Region: (alaska j C Latitude/Longitude 'Decimal Degrees J C Latitude/Longitude IDecimal Degrees J 9 C UTM Zone: r South C UTM Zone: True r South r State Plane Zone:14 2:1 Units:Ius-ft J C State Plane Zone:(True A Units: Ius-ft j C Legal Description(NAD27 only) a Legal Description[NAD27 only) —Starting Coordinates: —Legal Description X: 1491880.32 Township: 010 F.-, Range: 008 F- . Y: 15938626.05 Meridian IU A Section:-- IFNL _I 4961.6373 FEL 1244.6531 Transform I Quit I Help I ORIGINAL 2K-34wp05 Intermediate Casing II in CPA!Coordinate Convert (taliiiilaellV From:. -- - ---- -To: Datum: (NAD27 _".I Region. ialaska =..1 Datum: 1NAD27 J Region: ialaska .i r' Latitude/Longitude (Decimal Degrees .d C Latitude/Longitude 'Decimal Degrees I r-' UTM Zone:I r South C UTM Zone-I True I South r. State Plane Zone:14 j Units: Jus-ft 2:_1 C State Plane Zone.'True . Units: lus-ft L 1 C Legal Descrintinn 1N.AD27 onl•,.j C Legal Description(NAD 27 only) 1 Starting Coordinates: Description X. 1491520.67 Township: 010 JN_I Range: 008 'E - Y: 15938637.56 Meridian: Ju J Section:13 1FNL 14950.5222 1FEL .j 11604.3293 Transform Quit I Help J 2K-34wp05 Well TD - r CPAI Coordinate Converte O X From: __.- - -To: Datum: 1NAD27 2:1 Region: ialaska J Datum: INAD27 .1 Region: ialaska -1 r Latitude/Longitude 'Decimal Degrees 2j, C Latitude/Longitude [Decimal Degrees J r` UTM Zone:1 r South C UTM Zone.!True I South State Plane Zone:14 J Units: 'us-ft _i C State Plane Zone:'True j Units: 1„-ft C Legal Descnption INAD27 only) C Legal Description(NAD 27 only) Starting Coordinates: — -Legal Description -- X: 1488806.97 Township: WIT IN j Range: 008 iE Y: 15938862.09 Meridian: lu -I Section:13 IFNL . 14729.5171 }FEL J 14318.1923 Transform.................. Quit I Help I 1. J ORIGINAL ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-34 2K-34 2K-34wp05 Anticollision Summary Report 10 February, 2014 atiefl 41 0, TCR Required. Minor Risk should be applied for well 2K-08 ICR required ORIGINAL Se MD Inc Azi TVD +N/-S +FJ-W DLeg TFace pec Target Z8 250 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 00 2K-34wn05 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 x.00 250 350 r 3 600.49 5.26 271.82 600.00 0.51 -16.06 1.50 271.82 16.07 4 849.34 10.23 271.82 846.50 1.58 -49.57 2.00 0.00 49.59 28.00 To 12386.41 2 0.00 0.00 67.65 6 2729.58 54.70 271.82 2409.75 31.72 998.5 950.96 10.23 271.82 946.50 2.15 66 2.50 0.00 998.57 350 450 7 8336.93 54.70 271.82 5650.00 177.06 -5572.22 0.00 0.00 5574.50 450 550 8 8941.93 72.85 271.82 5916.23 194.23 -6112.41 3.00 0.00 6114.91 10:14,February 10 2014 al 9 9668.58 72.85 271.82 6130.50 216.28 -6806.39 0.00 0.00 6809.17 550 650 10 10008.21 90.00 272.05 6180.95 227.59 -7140.79 5.05 0.78 7143.74 2K-34 JC 27Aug13 Heel 11 10121.74 91.70 270.55 6179.27 230.16 -7254.27 2.00 -41.52 7257.22 650 850 12 10704.09 91.70 270.55 6161.99 235.70 -7836.33 0.00 0.00 7638.93 LOBAL FILTER APPLIED: A 14 11212.13 64 85 7.23 277.74 6159.84 281.04 -83.00 277.74 6156.50 262.41 41.81 2.00 180.00 8345.94 2K-34 JC 27Aug13 Crest 850 1050 15 12386.41 87.23 277.74 6216.50 439.07 -9504.01 0.00 0.00 9514.15 2K-34 JC 27Aug13 Toe D n From Depth To Survey/Mon Tool 1050 1250 25.00 1150.00 TK-Mwp051TK-Tp GYD-GC 15700 3571.92 2K-14wp05(2KJ0) NWD.IFA-AK-CIIZSC 71.92 9275.00 2K-Jawp0512K-34) MWD.IFA-ac-CIU1250 1450 ]5.00 %5&50 TK•OOwppS(2(44) .IWD.IFlI-AK-CKSC CASING DETAILS 1450 1650 TVD MD Name Size 1650 2150 2896.50 3571.92 10-3/4"x 13-1/2" 10-3/4 6014.44 9275.00 7"x 8-1/2" 7 2150 2650 6125.50 985A 82/2"Casing Drilling 7 6913 70 19398 e8 A 1Y2"o A l m" A 1)9 2650 3150 3150 3650 3650 4150 4150 4650 0/360 4650 5150 •.,'.,''ti 1- ;O4- " "�.�i'..s 5150 6150 1922 ;1'��417--:`' e�,r. 1 .--lid 4•��a1►s e> ^a t -;; s. 6150 7150 0/330 �0, .��� 1 �!®� 30 'K-08BPB x,1,0,0 I/801, n .4 AMPAr ♦ t t / 4,„4..4140.4,..../71.T.1. /� 1/ a WtTrd ...:‘,.:.-.'!:'-$441.---1 �rorail7150 8150 i1 ,T1/,r / ,f 1. 11��,rIs--/.el t••, .y `�` 8150 9150 I/ 1111♦ • • 1973" 1 { ,,ik /,�{l`I/ /fillsl. ,�����tv.'I�Ii"� ` , ''rif•11�. 1.k i. A�%������/�//i1�1/f�l�let.l. 1ar����orfi°i��`��� �►"� 9150 10150 ‘,..4.41:V0,104041//A • 1,,41ll/it. i lir d1°tY.r. 11�. , ...2-y%/ 10150 12150 fi .' flr Ot p • ` ,lhr_e, °:moi► `2!►� 1' --,-A-.,1.•.,-.,4,1,440/,0,1,. i :i,�,yr/ ' ,„i//,. l ►,.., e.4,/ 12150 14150 .ttle;e i///,''/ Jif,0u rri�� / i ws`�� 14/� \' 01 fl/�/l��j i/‘,,,,,-.11,;,,-,7. i ° .ate III 4t ��' �4, ..4,4,,iy 4, lil .: �:0-'• kRii�-`1r'Wp0,; 14150 16150 -60/300 , ��j/'� °'o '' ',}�i,iii ,`�.`r`is ita%Ot 1ifr;. 60 fly / h r< t .%::Aliglifftifi.,'•,:,.,:,'il'''!:.:;,,i, .;,;:z.!,,•:e4:74.,:;fil:10\ , ••••:...:tleite•!,'---714,:YrtiViri \ \ -.m.r.o. ' -."-, ') 1 \ k • III ���� ���I / Il. 7: /' Y7 _1I. '. i t II `r __� � I I i -90/270 T-1----' - 90 ' I �I�I Ilil VIII \ \Ir ;� 1 . i"�' � •e A „ { 1 / 1 � y � '�• I,��v�r�1'Ppiletll f, 1��11 t ®►�e "°`as` __ d�{ °!!0. 1 4 1,4,4t-a, * I it tot ss x`71/,I,,,,I fI•r�,���� �4AirAtapP � K-29w 11titi '120!240 �..��� .�� �;i.-:4V-vti.70:11::;. 42 D--�1 rizisilio 4PII \\Iiiimm. d�.�i� ♦f j t K-12 �`ti1= l:i4.ii.4N. - - 150/210 / J,-. 7,.;1:-i,-W.44' 150 " L-Ll " kIf�l1, ryJ!` ,0=-- -----PK-28AL1 PO =I$0/18 ih K-28AP8 [2K-28eL1r FK-28AL1PO 1 t 2 9 2 -E� 2 1B3 VO "Sr 2 t 2 $ 20 28 20 280101.20 2601e1 70 t 20 9 2. -8- 2K -X- 2H °0 $ 2.28,2K 26,20 28 70 -NI. 110n 20 28.1181 20 22.20 20.,1 70 -8- 20 -9E 20 013 20 080101,20 080151 70 9 2010, -9- 20 -8- 20 28,2K 28,40 28 75 "g .. -8- 2 -A 9 2 -jE -➢4(...4(... 2 $ 2034,05 ®24 00.2400V1 -!- 20 -8- 21 -X- 2112 "- 20 14 20 14,1,20 14001 70 -A- 21 20.20 2801.1,20.0001 70 $ 20 -A- 20 4 20 9 20 15 2K 15.20 15 70 -e- 20 28,20 28001101,2K 28,1151 00 $ 2107.20 07.20 07 70 F. 2Ke.,20085102.2008510270 $ 2110.25100.20130VO 9 2K 16,2015.201570 "- 21-2L21725001102,20-280111020018 ORIGINAL • Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-34 Project: Kuparuk River Unit TVD Reference: Plan: 118.5+28 @ 146.50ft(Doyon 141) Reference Site: Kuparuk 2K Pad MD Reference: Plan: 118.5+28 @ 146.50ft(Doyon 141) Site Error: 0.00ft North Reference: True Reference Well: Plan:2K-34 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-34 Database: EDM Alaska Prod v16 Reference Design: 2K-34wp05 Offset TVD Reference: Offset Datum Reference 2K-34wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,435.84ft Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma Survey Tool Program Date 2/7/2014 From To (ft) (ft) Survey(Wellbore) Tool Name Description 28.00 1,150.00 2K-34wp05(2K-34) GYD-GC-SS Gyrodata gyro single shots 1,150.00 3,571.92 2K-34wp05(2K-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,571.92 9,275.00 2K-34wp05(2K-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,275.00 9,668.58 2K-34wp05(2K-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,668.58 12,386.41 2K-34wp05(2K-34) 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 2/10/2014 10:00:54AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-34 Project: Kuparuk River Unit TVD Reference: Plan: 118.5+28 @ 146.50ft(Doyon 141) Reference Site: Kuparuk 2K Pad MD Reference: Plan: 118.5+28 @ 146.50ft(Doyon 141) Site Error: 0.00ft North Reference: True Reference Well: Plan:2K-34 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-34 Database: EDM Alaska Prod v16 Reference Design: 2K-34wp05 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 2K Pad 2K-01 -2K-01 -2K-01 146.50 154.00 179.90 177.40 71.850 CC 2K-01-2K-01 -2K-01 317.57 325.00 181.64 175.98 32.078 ES,SF 2K-02-2K-02-2K-02 146.50 154.00 154.86 152.36 61.848 CC 2K-02-2K-02-2K-02 392.60 400.00 157.26 150.21 22.293 ES,SF 2K-03-2K-03-2K-03 146.50 154.00 130.02 127.51 51.927 CC 2K-03-2K-03-2K-03 442.48 450.00 132.26 124.26 16.528 ES,SF 2K-04-2K-04-2K-04 417.41 425.00 103.67 96.14 13.774 CC 2K-04-2K-04-2K-04 616.35 625.00 104.78 93.41 9.219 ES,SF 2K-05-2K-05-2K-05 567.03 575.00 77.23 66.83 7.425 CC 2K-05-2K-05-2K-05 666.15 675.00 78.05 65.71 6.325 ES,SF 2K-06-2K-06-2K-06 146.50 154.00 54.85 52.34 21.906 CC 2K-06-2K-06-2K-06 616.71 625.00 56.01 44.65 4.927 ES,SF 2K-07-2K-07-2K-07 567.11 575.00 24.74 14.34 2.379 No Errors,CC 2K-07-2K-07-2K-07 616.80 625.00 25.38 14.01 2.233 No Errors,ES,SF 2K-08-2K-08-2K-08 67.49 75.00 4.81 3.20 2.995 No Errors,CC 2K-08-2K-08-2K-08 342.42 350.00 6.49 0.37 1.060 No Errors,ES,SF 2K-08-2K-08A-2K-08A 75.16 75.00 4.82 3.15 2.879 No Errors,CC 2K-08-2K-08A-2K-08A 325.11 325.00 6.22 0.42 1.072 No Errors,ES,SF 2K-08-2K-08APB1 -2K-08APB1 75.16 75.00 4.82 3.15 2.879 No Errors,CC 2K-08-2K-08APB1 -2K-08APB1 325.11 325.00 6.22 0.42 1.072 No Errors,ES,SF 2K-08-2K-08APB2-2K-08APB2 75.16 75.00 4.82 3.10 2.800 No Errors,CC 2K-08-2K-08APB2-2K-08APB2 325.11 325.00 6.22 0.37 1.064 No Errors,ES,SF 2K-08-2K-08APB3-2K-08APB3 75.16 75.00 4.82 3.10 2.800 No Errors,CC 2K-08-2K-08APB3-2K-08APB3 325.11 325.00 6.22 0.37 1.064 No Errors,ES,SF 2K-08-2K-08BPB1 -2K-08BPB1 75.16 75.00 4.82 3.15 2.879 No Errors,CC 2K-08-2K-08BPB1 -2K-08BPB1 325.11 325.00 6.22 0.42 1.072 No Errors,ES,SF 2K-08-2K-08BPB2-2K-08BPB2 75.16 75.00 4.82 3.15 2.879 No Errors,CC 2K-08-2K-08BPB2-2K-08BPB2 325.11 325.00 6.22 0.42 1.072 No Errors, ES,SF 2K-08-2K-08BPB3-2K-08BPB3 75.16 75.00 4.82 3.15 2.879 No Errors,CC 2K-08-2K-08BPB3-2K-08BPB3 325.11 325.00 6.22 0.42 1.072 No Errors,ES,SF 2K-09-2K-09-2K-09 146.50 154.00 20.00 17.5 } 7.988 CC 2K-09-2K-09-2K-09 417.34 425.00 22.05 15. 3.197 ES,SF 2K-10-2K-10-2K-10 146.50 154.00 45.11 42.61 18.018 CC 2K-10-2K-10-2K-10 541.74 550.00 47.99 35.95 3.987 ES,SF 2K-11-2K-11-2K-11 392.38 400.00 69.74 62.68 9.889 CC 2K-11-2K-11-2K-11 566.74 575.00 70.98 60.58 6.827 ES,SF 2K-12-2K-12-2K-12 146.50 154.00 95.11 92.61 37.985 CC 2K-12-2K-12-2K-12 566.59 575.00 97.84 87.44 9.412 ES,SF 2K-13-2K-13-2K-13 292.44 300.00 184.40 179.13 35.029 CC 2K-13-2K-13-2K-13 867.28 875.00 187.01 171.75 12.251 ES,SF 2K-13-2K-13A-2K-13A 292.44 300.00 184.40 179.13 35.029 CC 2K-13-2K-13A-2K-13A 867.28 875.00 187.01 171.75 12.251 ES,SF 2K-13-2K-13AL1 -2K-13AL1 292.44 300.00 184.40 179.18 35.343 CC 2K-13-2K-13AL1 -2K-13AL1 867.28 875.00 187.01 171.79 12.289 ES,SF 2K-13-2K-13AL2-2K-13AL2 292.44 300.00 184.40 179.18 35.343 CC 2K-13-2K-13Al2-2K-13AL2 867.28 875.00 187.01 171.79 12.289 ES,SF 2K-14-2K-14-2K-14 267.47 275.00 209.73 204.86 43.115 CC 2K-14-2K-14-2K-14 763.53 775.00 212.42 199.30 16.186 ES,SF 2K-14-2K-14A-2K-14A 267.47 275.00 209.73 204.86 43.115 CC 2K-14-2K-14A-2K-14A 763.53 775.00 212.42 199.30 16.185 ES,SF 2K-14-2K-14AL1 -2K-14AL1 267.47 275.00 209.73 204.86 43.115 CC 2K-14-2K-14AL1 -2K-14AL1 763.53 775.00 212.42 199.30 16.185 ES,SF 2K-15-2K-15-2K-15 466.90 475.00 234.60 224.43 23.072 CC CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/102014 10.00:54AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-34 Project: Kuparuk River Unit ND Reference: Plan:118.5+28 @ 146.50ft(Doyon 141) Reference Site: Kuparuk 2K Pad MD Reference: Plan: 118.5+28 @ 146.50ft(Doyon 141) Site Error: 0.00ft North Reference: True Reference Well: Plan:2K-34 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-34 Database: EDM Alaska Prod v16 Reference Design: 2K-34wp05 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 2K Pad 2K-15-2K-15-2K-15 787.61 800.00 237.58 219.27 12.979 ES,SF 2K-16-2K-16-2K-16 146.50 154.00 260.22 257.72 103.927 CC 2K-16-2K-16-2K-16 689.23 700.00 263.61 247.86 16.740 ES,SF 2K-17-2K-17-2K-17 117.50 125.00 284.92 282.60 122.590 CC 2K-17-2K-17-2K-17 763.30 775.00 288.59 275.61 22.220 ES,SF 2K-26-2K-26-2K-26 28.00 35.50 204.87 203.90 212.505 CC 2K-26-2K-26-2K-26 713.91 725.00 210.52 198.31 17.237 ES,SF 2K-28-2K-28-2K-28 347.69 350.00 117.66 110.90 17.409 CC 2K-28-2K-28-2K-28 572.34 575.00 120.84 109.79 10.932 ES,SF 2K-28-2K-28A-2K-28A 347.69 350.00 117.66 110.90 17.409 CC 2K-28-2K-28A-2K-28A 572.34 575.00 120.84 109.79 10.932 ES,SF 2K-28-2K-28AL1-2K-28AL1 347.69 350.00 117.66 110.95 17.530 CC 2K-28-2K-28AL1-2K-28AL1 572.34 575.00 120.84 109.83 10.979 ES,SF 2K-28-2K-28AL1 PB1 -2K-28AL1 PB1 347.69 350.00 117.66 110.90 17.409 CC 2K-28-2K-28AL1PB1-2K-28AL1PB1 572.34 575.00 120.84 109.79 10.932 ES,SF 2K-28-2K-28AL1 PB2-2K-28AL1 PB2 347.69 350.00 117.66 110.90 17.409 CC 2K-28-2K-28AL1PB2-2K-28AL1PB2 572.34 575.00 120.84 109.79 10.932 ES,SF 2K-28-2K-28APB1-2K-28APB1 347.69 350.00 117.66 110.90 17.409 CC 2K-28-2K-28APB1 -2K-28APB1 572.34 575.00 120.84 109.79 10.932 ES,SF Plan:2K-29-Plan:2K-29-2K-29wp11 2,106.89 2,125.00 59.15 24.84 1.724 No Errors,CC,ES,SF Kuparuk 2M Pad 2M-09-2M-09-2M-09 11,717.51 12,177.00 757.42 464.21 2.583 No Errors,CC,ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/10/2014 10.00:54AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL - Schlumberger Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-34 Project: Kuparuk River Unit TVD Reference: Plan: 118.5+28 @ 146.50ft(Doyon 141) Reference Site: Kuparuk 2K Pad MD Reference: Plan: 118.5+28 @ 146.50ft(Doyon 141) Site Error: 0.00ft North Reference: True Reference Well: Plan:2K-34 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-34 Database: EDM Alaska Prod v16 Reference Design: 2K-34wp05 Offset TVD Reference: Offset Datum Reference Depths are relative to Plan: 118.5+28 @ 146.50ft(Doyon 14Coordinates are relative to:Plan:2K-34 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:-0.02° Ladder Plot 1400 n l ri vt` :�. I • r ii• I 41 ..... I I 1 III 1 fp :'t (I I I 7...I 1 r "'' ii I :-1050 �� �' rrl ., t► C I i IC ►1� f Ife. I I I 1 r I I I I (a I 1, f'1 4 1 J. 1 I �� Q _ ___J- ! r�' _ __as J J r_ J 1 lailiP. g? r� f« co i 'T I Ar •: a) I f :r ,r r Sao 31 ■. 1 • : I I i1 ' e•. `+. I I f f� ..va s�•.� 0 I 1', �11 x ^.rte I - .:� 2 _J "� J J J J — C — — — I ii' .• '' FJ f•� ::< I 1 I U I Fiq 'r�� I •.d I I 1 • 350 ,1;r,� 'r ...K' _... . 3raIG•# .4 : ra ' 1 I 1 .r ;�I1 I I I I I .. . J J J J J _ _ :.,.i.:.,....7.....„:„.7,.....„ 1 i _ I I I I I r I I I I I , I I I I I I I I I I I I I 0 2000 4000 6000 8000 1 00 00 12000 LIIEI slWIDepth - 2K-01,2K-01.2K-01 VO 2K-08.2K-08 BPB2,2K-08BPB2L0 -0- 2K-15.2K-15,2K-15\•0 2K-02.2K-02.2K-02V1 43- 2K-08.2K-08BP83.2K-089PB3'O 2K-16.2K-16,2K-113W -B- 2K-03.2K-03,2K-03 V1 -A- 2K-09.2K-09,2K-09 V4 2K-17,2K-17,2K-1740 - - 2K-04,2K-04,2K-04V2 -6- 2K-10,2K-10,2K-1D V2 -5- 2K-26.2K-26.2K-26 VD 2K-05.2K-05,2K-05 V1 -0- 2K-11,2K-11.2K-11 V1 -A- 2K-28,2K-28,2K-281 -9- 2 K-06.2 K-06.2 K-06 V1 -3(- 2K-12,2K-12.2K-121/5 -}I- 2 K-28.2 K-28A•2 K-28 AVO -9- 2K-07.2K-07.2K-07' --a-2K-13,2K-13,2K-13V0 $ 2K-28.2K-28AL1.2K-28 AL1'O -a- 2 K-08.2K-08.2 K-08 VO -a- 2K-13.2K-13A•2K13AV0 -13- 2K-28.2K-28AL1PB1,2K-28AL1P131 VO -e- 2K-08.2K-08A,2K-08AV0 -A-2K-13.2K-13AL1,2K-13AL1 VD -4- 2K-28,2K-28AL1P92,2K-28AL1PB2V0 -F2K-08.2K-08APB1.2K-O8APB1VU - 2K-13.2K-13AL2,2K-13AL2VD -- 2K-28.2K-28APB1,2K-28APB1VO -0- cR-08.2K-08APB2.2K-08APB2 VO -A- rR-14,ER-14,ER-14 v0 -X- PIan:28.-29,Pbn:2K-29.28,-E0wpI1 VO CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/10/2014 10:00:54AM Page 5 COMPASS 2003.16 Build 69 ORGNAL 2K-34 Drilling Hazards Summary Surface — 13-1/2" Hole, 10-3/4" Casing RISK RISK LEVEL MITIGATION STRATEGY/ CONTINGENCY Directional plan optimized to steer away from Proximity to existing 2K-08 2K-08 wellbore as soon as possible. wellbore near surface Moderate Consequence of colliding with 2K-08 is minimal because 2K-08 will be cemented to surface. Minimize directional work in this interval due Weak/unstable formation to likely difficulty steering in soft formation. around 700' Moderate Surface mud will be Drilplex as opposed to standard spud mud to better clean hole. Drilplex mud to help with hole stability. Pump Hole washout/ instability Moderate substantial excess cement to compensate for washout and increase likelihood of cement to surface. Adequate mud weight (8.5-9.2 ppg) to control Shallow gas / gas hydrates Low formations. If substantial gas observed, control drill and add MI's lecithin to mud Intermediate— 8-1/2" Hole, 7" Casing RISK RISK LEVEL MITIGATION STRATEGY/ CONTINGENCY Importance of LOT communicated to all parties, all parties familiar with LOT procedure. If sufficient LOT is not achieved, pump squeeze cement job Insufficient or Low prior to proceeding with intermediate drilling. undetermined LOT Casing drilling bottom portion of intermediate will potentially increase LOT achieved through wellbore strengthening (open hole LOT will be performed prior to entering C-Sand). Condition mud & clean hole prior to trips. Monitor High ECD /tight hole on ECDs with PWD tool and adjust parameters trips / surge and swab Moderate accordingly. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets). Keep hole clean — use PWD to monitor hole cleaning. If losses occur— reduce pump rates and Lost circulation Moderate mud rheology, use LCM. Casing drilling will help prevent/reduce this in bottom portion of intermediate. Instability in Casing drilling through shale sections will HRZ/Kalubik Moderate substantially reduce this risk through wellbore strengthening and minimizing exposure time (casing will already be on bottom at conclusion of drilling). Due to tight clearance while casing drilling (7" Well control during casing in 8-1/2" hole), well control practices will casing drilling section Moderate be critical. Shut-in at any sign of flow and monitor pressure, do not wait to flow check. Mud loggers to perform connection flow monitoring. Mud will be weighted up to 11.5 ppg prior to drilling into C-Sand (based on pressures from Overpressure in Moderate offset wells that will be monitored leading up to Reservoir drilling of 2K-34). Casing drilling to strengthen shallow formations to minimize risk of shallow losses while high pressure reservoir is open. Production — 6-1/8" Hole, 4-1/2" Liner RISK RISK LEVEL MITIGATION STRATEGY/ CONTINGENCY Importance of LOT communicated to all parties, Insufficient or Low all parties familiar with LOT procedure. If sufficient undetermined LOT LOT is not achieved, pump squeeze cement job prior to proceeding with lateral drilling. Condition mud & clean hole prior to trips. Monitor High ECD /tight hole on ECDs with PWD tool and adjust parameters trips/surge and swab Moderate accordingly. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets). Keep hole clean — use PWD to monitor hole cleaning. If losses occur— reduce pump rates and Lost circulation Moderate mud rheology, use LCM. Stethoscope tool will be used to measure reservoir pressure and determine adequate mud weight to avoid being too far overbalanced. Sufficient mud weight to handle pressures. Overpressured reservoir Moderate Stethoscope tool to get accurate measurement of reservoir pressure. Diligence monitoring well on connections and during tripping. ORIGINAL 2K-34 Schlumberger CemCADE Preliminary Job Design 7" Intermediate Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Location: Kuparuk Client:CPAI Volume Calculations and Cement Systems Revision Date: February 10,2014 Volumes are based on 40%excess. The top of the tail slurry is designed to be Prepared by:Jenna Houston at 8000' MD. Location:Anchorage,AK Phone: (907)263-4207 Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -210 min. (pump time plus 120 min.) 15.8 ppg Class G +adds - 1.16 ft3/sk I0.1268 ft3/ft x (9667'-8000') x 1.40 (40%excess) = 296 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 18 ft3 296 ft3+ 18 ft3 = 314 ft3 314 ft3/ 1.16 ft3/sk= 271 sks Round up to 280 sks Previous Csg. < 10-3/4",45.5.#casing BHST= 149°F, Estimated BHCT= 106°F. at 3572'MD (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 6.0 60.0 10.0 10.0 Pause 0.0 0.0 5.0 15.0 Tail Slurry 6.0 55.8 9.3 24.3 Pause 0.0 0.0 5.0 29.3 Fresh Water 6.0 10.0 1.7 31.0 Pause 0.0 0.0 5.0 36.0 Mud 6.0 346.8 57.8 93.8 Mud 3.0 10.0 3.3 97.1 < Top of Cement at MUD REMOVAL -8000'MD Expected Mud Properties: -11.5 ppg, Pv<20, Yield Point<25. Spacer Properties:12.5 ppg MudPUSH* II, Pv=20 -24, Yield Point=37-41 Centralizers: As per program < 7",26#casing in 8-1/2"OH TD at-9667'MD (6131'TVD) * Mark of Schlumberger ORIGINAL 2K-34 Schlumberger CemCADE Preliminary Job Design 10 3/4" Surface Casino (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 3072' MD. Client:CPAI Revision Date: February 10,2014 Prepared by:Jenna Houston Location:Anchorage,AK Lead Slurry Minimum pump time: -250 min. (pump time plus 120 min.) Phone: (907)263-4207 ALC @ 11.02 ppg- 1.93 ft3/100 lb sk Mobile: (907)223-8916 email:jhouston2@slb.com 0.6382 ft3/ft x 110 x 1.0 (0%excess) = 71 ft3 0.3637 ft3/ft x (1529-110) x 3.50 (250%excess) = 1807 ft3 < TOC at Surface 0.3637 ft3/ft x (3072-1529) x 1.50 (50%excess) = 842 ft3 1807 ft3+71 ft3+842 ft3= 2720 ft3 2720 ft3/ 1.93 ft3/sk= 1410 sks(1420 sks) Have additional ALC on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -180 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.3637 ft3/ft x (3572-3072) x 1.50 (50%excess) = 273 ft3 0.54000 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3 +44 ft3 = 317 ft3 317 ft3/ 1.63 ft3/sk = 195 sks Round up to 200 sks BHST= 81°F, Estimated BHCT=71°F. (Based on 2.1 °F/100 ft. from surface) PUMP SCHEDULE < Base of Permafrost at l 1,529'MD(-1,350'SS Pump Rate Stage Stage Time Cumulative TVD) Stage b m m Time (bpm) Volume (bbl) (min) (min) CW 100 7.0 50.0 7.1 7.1 MUDPUSH II 7.0 50.0 7.1 14.2 Pause 0.0 0.0 5.0 19.2 < Top of Tail at ALC Lead 7.0 484.2 69.2 88.4 3072'MD Surface Tail 7.0 56.3 8.0 96.4 DeepCRETE Slurry Pause 0.0 0.0 5.0 101.4 Fresh Water 7.0 10.0 1.4 102.8 Pause 0.0 0.0 5.0 107.8 Mud 8.0 315.8 39.5 147.3 Mud 3.0 10.0 3.3 150.6 < 10 3/4",45.5#casing MUD REMOVAL in 13.5"OH Expected Mud Properties:9.8 ppg, Pv<20, Ty<20 Spacer Properties:10.5 ppg MudPUSH* ll pv= 17-21, Ty 20-25 TD at 3572'MD (2897'TVD) Centralizers: As per CPAi program. • Mark of Schlumberger ORIGINAL 2K-34 r Grass Roots Horizontal A-Sand Producer ConocoPhillips Proposed Wellbore Schematic :1!, 1,-' Callahan 211014 Preen were; Conductor To Be Installed: Spud Mud 16626H40 Pcrmatdrnzt 9.6 PPG 314:carrr,7:5 Ntpg2.!T5• 11 UTMfi,Yl7D.' Fresh 4Vate+ Ir-''=B $ij NESCrrrtnnxr 1,00,T. Spud Mud13-112"Surface Hale 9 6.10 PPG 0 - cans,ItaR x. Surface Casing: Below West Sak 10-14"45.5#L-BD Hydril 5.53 — 3,600'MD 2 818'TVD 8 Y.Canes KER.:-•R N fiBM-LSND 3.6—10.0 PPG r.,.a aye Koop up withTubing:nop 3-%;9 3#l-80 EUE8F el ft Hutton b-lit'" Intermediate hole iiEs,marod t9 d ecmcnr 1g-+4.A 091Y r.1a (550'above Csam; IP 3.'Caney k Mop o 2 tr ce:a:.7a w Intermediate Casino:Satin C Sand t 2' ''' ` --7%R i,rn•Tn;Oseanr p Y.n Ml 7.26#L-80&with TN Blue Connections Torque Seal 'led -`°" Sra,•'ck Lack L"u-"-g" 9,652'MD 16.126'TVD©73` eo RS N o':le.9a:U YD ::::::::::::::::::::•••••:::::::::::: : : ,a ":F6,od ustfon Hole...• • 3A[ t=fiu7iiia(: : : :: : : ::: :.4.$P$±tf �,� •:•••••••:•:••••••::•:::•::::::•:•:•:•:•:•:•:•:•:•:•:•. -""••••. . . .............. ......r ore\To 1\ Production Liner: Perforated Pups 4-112" 12,64 IBTM 12,387'MD 6217'TVD ORIGINAL Request for Waiver of 20 AAC 25.050(c)(1) 20 AAC 25.050 states that: (c)A well that is intentionally deviated must be (1) directionally surveyed at intervals not more than 500 feet apart on straight or tangent sections of the well during the normal course of drilling, and at intervals not exceeding 100 feet in all portions of the hole where intentional angle changes are performed; / We request a waiver of this requirement for the tangent portion (planned 502' section) of the 8-1/2" intermediate section of this well,which will be drilled with casing. The casing drilling assembly does not utilize a BHA(simply a bit on the end of the 7" casing string), and thus cannot incorporate MWD to take surveys while drilling. The bottom 100 feet of the casing will use full gauge WearSox spray-on metal centralizers designed to help the casing hold a constant angle. These centralizers will be placed at the bit, as well as 10', 20',45', and 85' back from the bit. Experience drilling in south Texas, Colorado, and Alaska with this arrangement has shown to consistently hold angle while drilling (<1°/1000' maximum drop in angle). As shown in the Directional Plan (Attachment 1),there are no nearby anti-collision risks during this section of drilling. Upon completion of the casing drilling section, a gyro will be run on E-line to survey the interval. f UGN L Bettis, Patricia K (DOA) From: Callahan, Mike S [Mike.Callahan@conocophillips.com] Sent: Wednesday, February 19, 2014 12:32 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2K-34: Permit to Drill Patricia, sorry for the discrepancy. The correct number should be 3950 psi, which corresponds to the pressure gradient of 0.65 psi/ft at 6120 psi. Not sure where the 3700 number came from,that was an oversight on my part. Please let me know if you have any more questions. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Bettis, Patricia K(DOA) [mailto:Datricia.bettis@alaska.gov] Sent: Wednesday, February 19, 2014 12:09 PM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2K-34: Permit to Drill Good morning Mike, On the Form 10-401, Box 17. Maximum Anticipated Pressures, would you please verify that the maximum anticipated downhole pressure is 3700 psig? On page 3 of the Application for Permit to Drill Document,the TVD is listed as 6,120 feet and the pressure gradient is listed as.650 psi/ft. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, February 19, 2014 12:09 PM To: 'Callahan, Mike S' Subject: KRU 2K-34: Permit to Drill Good morning Mike, On the Form 10-401, Box 17. Maximum Anticipated Pressures, would you please verify that the maximum anticipated downhole pressure is 3700 psig? On page 3 of the Application for Permit to Drill Document,the ND is listed as 6,120 feet and the pressure gradient is listed as.650 psi/ft. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) /(2(ti 021 -3 / W'0 AI q-0 (c, From: Callahan, Mike S [Mike.Callahan@conocophillips.com] Sent: Tuesday, February 18, 2014 9:47 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2K-29: Permit to Drill Application Patricia,the logging program for 2K-29 is as follows: Surface: Gamma Ray, Resistivity, Annular Pressure While Drilling (APWD), Equivalent Static Density(ESD),Temperature Intermediate: Gamma Ray, Resistivity,APWD, ESD, Downhole Weight on Bit and Torque Production: Gamma Ray, Resistivity, Density, Porosity,APWD, ESD,Temperature, Formation Pressure While Drilling (Schlumberger's Stethoscope tool),Well Placement(Schlumberger's Periscope tool—deep resistivity) Here is a snapshot with the specific tools we plan to run: A11 these services have spec, is charges as per BAAC1 Standard BNA will be used whereever aess,L • Gamma Ray(Real Time and Recorded Mode Data) Resistivity i trom arcVISlON tool•Includes alt 20 Curves in Recorded Mode and 34 curves in Real time) Resistivity I from ImPulse tool-Includes all 10 Curves in Recorded Mode and 3-4 curves in Real time) Density I Includes Real time and Recorded Mode Average.atimuthet and Image) (Please comment which curves are needed in real time) Porosity(Real time end recorded mode.Average) Aamil. Pressure walk Drilling•APWD(rea I time and recorded Mode) Egrhrakst Static Density•ESD I Reel Time) Temperature( RealTime and Recorded Mode) ROOB I Downhole Weight On flit and Torque•Real time and Recorded woe) MWD Condnuous radon(Real Time Toylike RPM(Real time and Recorded Mode) Formation Pressure"Mile DrIMe-StethoScape MiaeScope•ll to 14•Description on Attached sheet GNOMON•(Oil Eased Mud Resistivity Li to 14 I Description on Attached Sheet SouicScepe 415-ti to 13- I Monopole and Quadrupole Sonic tool)Description on Attached Sheet SoaicScape 1325(Monopole and Quadrupole Sonic tool)Description on Attached Sheet SoaicVlSlON(Monopole tool)LI or 12-Description on Attached Sheet Periscope(WeliPlacement tool)li to l3-Description on Attached Sheet EcoScape 67S-Multifunctional IWO Service-Description on Attached Sheet EcoScape 67S.Sigma EcoScope 676•SpectroScopy Top o1 Cement Service Additionally, I recently submitted the PTD for 2K-34,which will be drilled after this well with Doyon 141. I imagine the same question will arise, and the logging program for that well will be identical to this one. / Please let me know if you have any more questions. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907)231-2176 1 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, February 18, 2014 9:33 AM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2K-29: Permit to Drill Application Good morning Mike, Please provide what logs will be run for each interval of the wellbore. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 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. i l�!L1\�i_L l��_>� �'i 1 L�_ I� L�I� WELL NAME: KR ,2I4 -3 f?-1:1_i `pt(1l,llc'1IC,11,1111'11,' • C%,1 `. 111 'i` _ Illcll'�II FL1?111: Xyc,„rui< POC H Ki �_ / cJ 2'J1!_ Check i3ox for Appropriate Letter / Paragraphs to he Included in Transmittai Letter CIiEC;:K OPTION TEXT FOR APPROVAL LETTER MULTI The permit Is for a new wellbore segment of existing \\cll Permit LATERAI 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 abo\c. between 60-69) In accordance with 20 AAC 25.005(f). all records. data and logs - acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging in also required for this well: Requirements /Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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N 0 U) c0 O C L, 2 U) p ° E G) O O 0) a) O• y, y ma •� 0) G) Ia ca; Fa c° O 0S >) -0(.) 2 •° f0 O O: d a) a c) m `0 c .- a o. C w > f) 0: a) 0 3 c: :0 0 c cr 'c, y: c c m a' '9p a w @ 0 0 0. 0 .-n >. w 6 fa _a _ •0 •0 -0 0 . C N a. O O -0, .--E a) ) N a): N. > .� (6. L: 0, co .- V: V: a: C (a, C E USt O > ° o 3 '' '' '' @ - 0 z C m E m 3: c o c.) ° °: c0r aN) ti a) P 0 y, m o: c: �, co N' 0 8', c F' Z C O O U C O O 0 O O 0 'O' 0: = a E' : coE I O a)' U N c _. 0 0 0 0 m m a) ° o 3 o o: >: 3 0) co: .' 3: D 0) vi 0 3 co' m w a . ate)' 0 _,1 O c E m v a� a� a� aa)) a`> o E E c m 3 , c ,t F H H, . aa) ate) a >' c c. d 0 y`o a 0 E a5 0); m e m , 0 t 0 c 0 v a a `0 a� m 0 3, M' 2 2 a), v 0, v 'a O, O. .c 0 ' a), 0, a), 0, O, i 0 rJ U c Z a _iD S 5 co w O O a a U 5 Q a U co U U U U Q w Q w 0 m, m, U, D 2' I d 0, 0 0 0 W ` ) E r .- N M V to O W 0) NMV )nO O0) O N N M N IN (N0 t:,- N N O NM M M Mn cMD h M M ce O C .0. NO w N 'O" ON ° 0 AS rn 0) p N p m p N W O� N C N N E J N N 0 a) O o J u c a m c a ° p m 0 Lu 0 E J o F- s a s W Q > 0 Q 0 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. 5 FINAL WELL REPORT MUDLOGGING DATA 2K-34 Provided by: Approved by: Jennifer Crews Compiled by: Greg Hammond John Farrell T y l e r H a r r i s Frank Thrailkill Distribution: 6/30/2014 T.D. Date: 6/18/2014 2K-34 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................3 1.1 Equipment Summary ......................................................................................................................3 1.2 Crew................................................................................................................................................3 2 WELL DETAILS .....................................................................................................................................4 2.1 Well Summary.................................................................................................................................4 2.2 Hole Data........................................................................................................................................4 2.3 Daily Activity Summary...................................................................................................................6 3 GEOLOGICAL DATA.............................................................................................................................8 3.1 Lithostratigraphy .............................................................................................................................8 3.2 Mudlog Summary............................................................................................................................9 3.3 Connection & Trip Gases..............................................................................................................18 3.4 Trip (Wiper) Gases........................................................................................................................18 3.5 Sampling Program........................................................................................................................19 4 DRILLING DATA..................................................................................................................................20 4.1 Survey Data..................................................................................................................................20 4.2 Bit Record.....................................................................................................................................23 4.3 Mud Record ..................................................................................................................................24 5 SHOW REPORT..................................................................................................................................25 6 DAILY REPORTS ................................................................................................................................26 Enclosures: 2”/100’ Formation Log (MD) 2”/100’ Gas Ratio Log (MD) 2”/100’ LWD Combo Log (MD) 2”/100’ Drilling Dynamics Log (MD) Final Data CD 2K-34 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Ditch gas QGM Agitator (In possum belly) Flame ionization total gas & chromatography. 0 Hook Load / Weight on bit Totco WITS Feed 0 Mud Flow In Totco WITS Feed 0 Mud Flow Out Totco WITS Feed 0 Mudlogging unit computer system Intel(R)Core(TM)2 Duo CPU 0 Mudlogging unit DAC box In-unit data collection/distribution center 0 Pit Volumes, Pit Gain/Loss Totco WITS Feed 0 Pump Pressure Totco WITS Feed 0 Pump stroke counters Totco WITS Feed 0 Totco Well Monitoring Components Totco computer networked in Mudlogging Unit 0 Rate of penetration Totco WITS Feed 0 RPM Totco WITS Feed 0 Torque Totco WITS Feed 0 1.2 Crew Unit Type: Arctic Steel Unit Number: ML032 Mudloggers Years1 Days2 Technician Days Greg Hammond 4 16 Travis Smith 1 John Farrell 1 18 Tyler Harris 1 18 Frank Thrailkill 2 16 1 Years experience as Mudlogger 2 Days at wellsite between Canrig rig-up and rig-down 2K-34 4 2 WELL DETAILS 2.1 Well Summary Well: 2K-34 API Index #: 50-103-20688-00-00 Field: Kuparuk River Unit Surface Coordinates: X: 491,404.25’ Y: 5,938,641.40’ Borough: North Slope Primary Target Depth: 9928’ MD / 6163’ TVD State: Alaska TD Depth: 10,127’ MD / 6217’ TVD Rig Name / Type: Doyon 141, Arctic Triple License: 214-026 Primary Target: Kuparuk A Ground Elevation: 118.5’ AMSL Spud Date: May 26, 2014 KB: 146.5’ AMSL TD Date: June 18, 2014 TD Formation: A4 Days Drilling: 24 Completion Date: June 20, 2014 Classification: Production Completion Status: Liner in slant hole section 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVDSS (ft) TD Formation Mud Weight (ppg) Dev. (oinc) Casing/ Liner MD (ft) TVDSS (ft) FIT (ppg) 13.5” 3555 -2738 West Sac 9.6 53.9 10.75” 3543 -2732 14.7 8.5” 9151 -5807 HRZ 10.0 74.5 7” 9151 -5808 14.3 8.5” 9257 -5836 HRZ 11.0 74.6 7” 9257 -5836 16.0 6.125” 10127 -6074 Kuparuk A4 13.1 74.0 4.5” 10117 -6070 2K-34 5 Project Overview The project goal was to safely drill and complete the Kuparuk River Unit 2K-34 production well. The surface and upper intermediate sections were to be rotary drilled and the lower intermediate to be drilled with casing set below the Kalubik shale. The production section was planned to be rotary drilled to reach a prognosed depth of 12,387’ MD / 6,217’TVD in the Kuparuk A4 sand. The following objectives were taken from the 2K-34 Drilling and Completions Program: No Accidents, Incidents or Spills. Complete well within time and cost. Recover resources in the Kuparuk A sand to replace/increase production from abandoned 2K-08. Utilize casing drilling to successfully drill bottom portion of intermediate hole. Build off of learnings from 2K-29 to help prove feasibility of the technology for future use at Kuparuk. The 13.5” surface section was drilled prior to Canrig rig up. Mudlogging commenced at 7000’ MD during the drilling of the 8.5” upper intermediate section. The 8.5” rotary assembly was pulled out at 9151' MD / 5952' TVD for the drilling of the lower intermediate casing drilling section. TD for the 8.5” casing drilling section was called at 9257' MD / 5980' TVD due to losses. The casing was set in the HRZ shale above the Kalubik shale. Due to shallower than planned intermediate TD, the 6.125” section was drilled as a slant hole in preparation for coil tubing drilling of a production hole at a later date. The slant hole was drilled to 10127' MD/ 6217' TVD, encountering the target A4 sand at 9928’ MD / 6162’ TVD. The well was completed with a 4.5” perforated liner set at 10117’ MD / 6214’ TVD. 2K-34 6 2.3 Daily Activity Summary 6/6/2014: Canrig began rigging up. 6/7/2014: Canrig began full logging operations at 7000' MD. Drill from 7000' to 7843' MD. 6/8/2014: Drilled from 7,843' to 9,151' MD. Weighted up mud from 10ppg to 10.4ppg in response to higher connection gases. Monitored well and begin pulling out of hole. 6/9/2014: Monitor well @ 8966' MD; flowed back 3 BBL then stopped, static for 30 minutes; BROOH, CBU @ 8227’ MD; Cont. BROOH to10.4 ppg; monitor well for 15 minutes. Rack back HWPD, L/D collars and BHA. R/U and pull wear bushings, test all rams. R/U and flush stack, drain stack P/U landing JT and hanger and make dummy run. 6/10/2014: Change out top pipe rams to 7", test. Rig up Tesco. Trouble shoot torque valve. Rig up to run in hole with casing. Running in hole to 5155', fill every 10 joints. 6/11/2014: Cont. RIH T/5175’ MD, circulate SS stage pump up T/300 GPM, 700 PSI, lost 20 BBLS while pumping and gained back 20 after shutting down pump. Cont. RIH W/ 7” CSG F/5175’ MD T/6839’ MD. Circulate SS 6839’ MD, stage up pump T/300 GPM, lost 38 BBLS while pumping and gained back 10 BBLS. Cont. RIH F/6839’ MD T/8358’ MD. Circ. SS @ 8358’ MD. PJSM continue to CBU @ 8358’ MD @ 280 GPM – 1000 PSI. Continue to RIH F/8358’ MD T/8490’ MD. Tight spot at 8490’ MD, worked pipe and regained circulation. Continue to RIH F/8520’ MD wash down T/9151’ MD.CBU @ 2 BPM. PJSM, displaced well @ 7 BPM = 1250 PSI. PJSM, R/U to perform leak off test, pump 13.3 BBLS pressured up T/175 PSI = 12 PPG EMW. R/D test equipment. DRLG F/9151’ MD T/9187’ MD. 6/12/2014: Stopped drilling due to losses and returns of 50-60 barrels per hour. Losses subsided to about 20 bph with pumps off. Mixed 100 bbls of LCM and diluted mud to 11.5 ppg. Pumped and circulated LCM at 1 barrel per minute. 6/13/2014: CONT CIRC @ 1 BPM with no returns. Shut down pump, reduce ROT T/5 RPM, work string, keep hole full W/TT reduce MW T/11.0 ppg. CONT working CSG, attempt to regain CIRC twice, pumping 2BPM and 1 BPM, no returns. Reduce MW T/10.5 ppg and ESTB CIRC F/CMT job. Circ LCM pill. 6/14/2014: Chased mega pill with 10.5 ppg mud with slight returns at 1.5 bpm increased at 2.5. Continued to circulate and condition at 2.5 bpm. Observed 108 units of downtime gas once the pumps were turned on. Monitored well while making up hanger and landing and rigged up cementing equipment. Cemented and pressured up for 5 minutes and bled pressure. Prepared for laying down 5" pipe and rigged up O-A for flush and freeze product. Picking up hanger and landing and rigged up cementing equipment. Cemented and pressured up. Prepared for laying down 5" drill pipe and rigged up O-A for flush and freeze protect. 6/15/2014: LD 5” DP, 5 STNDS HWDP. Flush ANN W/190bbl H2O. Unload pipe shed, CONT LD DP. Spot up Little Red, test lines T/2500 psi, pump 121 bbl Isotherm NT down OA. R/U and successfully test BOP. R/D test equip blow down choke, kill and choke lines. P.U and rack back 4” DP. 6/16/2014: Make up the BHA and perform rig service. Running in hole to 1,543', SP CONT. single in hole with 4" DP to 7,288'. Wash and ream to 9,150' Circulate and condition. Test casing to 3000 psi for 30 minutes. Begin drilling cement/float equipment, rat hole, and 20' new formation. 6/17/2014: Continue drilling 20’ new hole to 9277’ MD. CBU @ 9274’ MD R/U CIRC equip, successful 2K-34 7 FIT to 16 ppg. Blow down kill and circ lines. Displace well to 12.5 ppg LSND. Circulate and condition, change out shaker screens. Drill to 9663’ MD. 6/18/2014: DRLG T/9919 SPRs @9727’MD and 9830’ MD. DRLG to 10127’MD. SPRs, SVY on BTM. CBU until clean. Monitor well. Pump OOF to 9182’MD, ream x2 from 9467’MD. CBU at 9182’MD. Monitor well at shoe, static. CONT pump OOH to 8519’MD. 6/19/2014: CONT POOH T/8519'MD. Increase pump rate T/4BPM to reduce barite settling. CONT POOH T/478'MD. SLB unload nukes. Clean & clear rig floor. L/D tools, P/U CSG equip. Install centralizers. Lube rig & top drive. Run liner per detail. RIH T/ 3041'MD, filling pipe every 10 STDS. CBU cont Circ until MW evens out. 6/20/2014: CIRC & COND mud. M/U TD, break CIRC, recip pipe 30’ stage up pump T/ 3 BPM. Wash F/9740’ MD T/10127’MD. M/U CMT head. CIRC and COND mud and dilute to 12.8ppg IN/OUT. CMT liner per SLB. Dart latched @ 915 STKS. CIRC out excess CMT. Test ZXP packer. Pump and spot Hi Vis pill @ 8956’ MD. OWF, static. CONT POOH. 2K-34 8 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops provided by wellsite geologist. PROGNOSED ACTUAL FORMATION / MARKER MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) 13-1/2" Surface Section Base Permafrost 1,600' 1,556' -1,412' 1,648' 1,604' -1,461' Base West Sak Sand 3,340' 2,709' -2,565' 3,386' 2,783' -2,640' 8-1/2" Intermediate Section Fault +/-6,200' - - 6,279' 4,459' -4,315' K-3 - - - 8,156' 5,542' -5,398' K-2 - - - 8,617' 5,786' -5,642' Top HRZ 8,714' 5,834' -5,687' 8,760' 5,840' -5,697' 6-1/8" Slant Hole Base HRZ/ Top Kalubik 9,279' 5,987' -5,843' 9,355' 6,006' -5,863' Fault 1 (DTE 18') 9,370' 6,011' -5,868' 9,447' 6,031' -5,888' K1 Marker 9,410' 6,022' -5,879' 9,618' 6,078' -5,935' Fault 2 (DTE 27') - - - 9,649' 6,086' 5,943' Top C 9,745' 6,114' -5,974' 9,800' 6,129' -5,985' Top A6 9,813' 6,132' -5,989' - - - Top A5 9,820' 6,134' -5,991' 9,858' 6,143' -6,000' Top A4 9,878' 6,150' -6,007' 9,928' 6,162' -6,019' Fault 3 10,033' 6,193' -6,049' - - - TD in A4 10,145' 6,223' -6,080' 10,127' 6,217' -6,074' 2K-34 9 3.2 Mudlog Summary Schrader Bluff – 7000’ MD1 / 4875’ TVD to 8760’ MD / 5840’ TVD (-4732’ to -5697’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 268.1 7.3 94.9 267 10 56.8 1Depth Canrig commenced logging operations The Schrader bluff was comprised of beds of siltstone, carbonaceous siltstone, and sandstone. The siltstone was predominantly medium dark gray to dark gray and contained micro laminated carbonaceous material in the lower portion. The siltstone was often crumbly with poor to moderate induration. The sand was mainly olive gray to medium dark gray, composed dominantly of quartz with secondary dark lithics. The sand often contained rare volcanic material and microcrystalline pyrite. This zone contained no oil shows. Individual sample descriptions are as follows: Siltstone (7000' - 7070') = dark gray to medium dark gray; soft crumbly to dense brittle; moderate to poor induration; irregular to earthy planar fracture; massive to tabular to elongate cuttings habit; dull to earthy luster; silty to smooth to sucrosic texture; massive structure with common subtle bedding, trace linear biotite intergrowths, very rare carbonaceous micro lamina; occasional medium gray smooth claystone; trace to scattered fine to medium grained angular sands; abundant Safecarb mud additive contamination. Siltstone (7070' - 7140') = dark gray to medium dark gray; firm friable to dense brittle and soft crumbly; moderate in- duration; irregular to earthy fracture; massive to tabular to elongate bladed cuttings; earthy luster; massive structure; silty to sucrosic texture with occasional subtle bedding; occasional to common silty to smooth medium gray claystone; trace fine to medium sands and very fine grained sandstone fragments; scattered biotite; abundant Safecarb and nut plug mud additives. Siltstone (7140' - 7195') = medium dark gray to grayish black; firm to dense; moderate to poor induration; irregular to blocky fracture; massive to wedgelike cuttings; silty to sucrosic to smooth texture; massive structure; occasional dark gray claystone; scattered medium to fine grained sands; trace biotite; rare pyrite; abundant Safecarb. Sand (7195' - 7260') = medium dark gray to olive black; secondary grayish black; lower medium to upper very fine; moderately sorted; subangular to very angular; discoidal to prismoidal and sub spheroidal; 70% transparent to opaque colorless quartz; 25% medium to dark gray lithics; trace biotite; rare micro- crystalline pyrite; rare moderate orangish brown volcanics; very rare jasper; scattered very fine grained sandstone fragments; interbedded with siltstones as above; abundant Safecarb. Sand (7260' - 7350') = medium dark gray to olive black; secondary olive gray and grayish black; lower fine to lower medium predominant with common very fine; moderately to well sorted; subangular to angular with scattered very angular; discoidal to sub spheroidal and prismoidal; 70% transparent to translucent quartz; 25% medium to dark gray lithics; trace biotite; rare microcrystalline pyrite; very rare moderate orangish brown volcanics; scattered very fine to fine grained crunchy sandstone fragments with yellowish to light brownish gray tuff/clay matrix support; interbedded with siltstones as above; abundant Safecarb. Sand (7350' - 7440') = medium dark gray to dark gray with olive black secondary hues; upper fine to lower medium, occasional lower fine; subangular to angular; discoidal to sub spheroidal; well to moderately sorted; unconsolidated; 70% transparent to translucent quartz, 30% medium dark gray to grayish black lithics; trace moderate orange brown volcanics; scattered light olive gray to yellowish gray sandstone fragments, tuff/clay matrix supported; abundant Safecarb; patchy dull orng yel sample fluor, imm dull yel wh cut fluor, clear cut, no residue, dull yel resid fluor. 2K-34 10 Sand (7440' - 7520') = medium gray to medium dark gray with light olive gray secondary hues; upper fine to lower medium; sub prismoidal to sub discoidal; well to moderately sorted; predominantly unconsolidated; 70% transparent to translucent quartz, 30% medium dark gray to grayish black lithics; scattered mix of grain supported and clay/tuff matrix supported sandstone fragments; common olive gray to medium gray siltstone, poorly indurated, earthy fracture, tabular cuttings habit, dull to earthy luster, silty texture massive structure; trace sample fluorescence. Sand (7520' - 7600') = medium dark gray to olive gray; upper fine to lower medium; low sphericity; subangular to subrounded; subprismoidal to subdiscoidal; well to moderately sorted; partially unconsolidated, common tuff/clay matrix supported sandstone; 60% transparent to translucent quartz, 40% medium dark gray to grayish black lithic fragments; siltstone, olive gray to medium dark gray, poor to moderate induration, tabular to nodular, dull earthy luster, massive structure; common clay nodules, brownish gray, well hydrated, poorly indurated, massive structure; scattered sample fluor. Sand (7600' - 7670') = olive gray to medium dark gray; upper fine to lower medium, occasional lower fine; low to sub moderate sphericity; angular to sub rounded; moderately to well sorted; predominantly unconsolidated, occasional tuff/clay matrix supported sandstone; 70% clear to transparent quartz; 30% medium dark gray to grayish black lithics; common medium dark gray to olive gray siltstone, well to poorly indurated, tabular to nodular, trace micro laminations of carbonaceous material; scattered sample fluor. Sand (7670' - 7750') = olive gray to medium dark gray; upper fine to lower medium, scattered upper medium; moderate to low sphericity; sub discoidal; well to moderately sorted; predominantly unconsolidated, intermittent tuff/clay matrix supported sandstone fragments; 70% translucent to transparent quartz, 30% dark gray to grayish black lithic fragments; common medium dark gray to dark gray siltstone, poor to moderate induration, dull earthy luster, massive structure; scattered sample fluor. Siltstone (7750' - 7835') = medium gray to medium dark gray with strong olive gray secondary hues; poor to moderate induration; crumbly to tough tenacity; earthy fracture; massive to tabular cuttings habit; dull to earthy luster; silty texture; massive structure, trace micro laminations of carbonaceous material; common sandstone fragments, quartz framework, grain supported to tuff/clay matrix supported; common grayish black to black lithic fragments. Siltstone (7835' - 7915') = dark gray to medium dark gray; poor to well induration; tough to crumbly tenacity; tabular to massive cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; occasional silt grades into lower very fine sand; common medium dark gray sandstone, upper fine to lower medium, low to moderate sphericity, moderately sorted, grain supported, quartz framework, strong reaction to HCL; common dark gray to grayish black lithic fragments; trace tuffaceous material; abundant Safecarb and nut plug mud additive contamination. Siltstone (7915' - 7975') = olive gray to medium dark gray; poorly indurated; crumbly tenacity; earthy fracture; tabular cuttings habit; earthy to dull luster; silty texture; massive structure; scattered sand, upper fine to lower medium, predominantly translucent to transparent quartz; common nodules of well hydrated clay and grayish black to black lithic fragments; abundant Safecarb and nut plug mud additive contamination. Siltstone (7975' - 8055') = medium gray to medium dark gray; poor to moderately indurated; crumbly tenacity; earthy to open fracture; tabular to occasionally elongated cuttings habit; dull to earthy luster; silty to occasionally gritty texture; massive to thinly laminated structure; common light gray to medium light gray sandstone, upper fine, low to moderate sphericity, well to moderately sorted, grain supported, quartz framework; common fragments of carbonaceous material; abundant Safecarb and nut plug mud additive contamination. Siltstone (8055' - 8100') = medium gray to medium dark gray with olive gray secondary hues; poor to moderately indurated; crumbly tenacity; elongated to tabular cuttings habit; silty texture; dull to earthy luster; common nodules of mushy brownish gray clay, well hydrated; trace grayish blue green moderately indurated claystone; abundant Safecarb and nut plug. 2K-34 11 Siltstone (8100' - 8190') = medium dark gray to olive black; secondary olive gray to medium gray; soft crumbly to dense; irregular to earthy planar fracture; massive to irregular flaky to elongated cuttings; silty to sucrosic predominant; occasionally smooth; massive to subtly laminated structure with rare slightly carbonaceous micro lamina and very rare fine biotite lineations; scattered fine to very fine quartz and dark gray lithic sands; trace very fine grained sandstone fragments with yellowish gray tuff/clay matrix support; trace microcrystalline pyrite; abundant Safecarb mud additive. Siltstone (8190' - 8270') = medium dark gray to olive black; secondary olive gray to medium gray; soft crumbly to firm to dense friable; irregular to earthy planar to blocky fracture; massive to irregular flaky to elongated and wedgelike cuttings; silty to sucrosic texture; massive to subtly laminated structure; scattered carbonaceous micro lamina; trace very fine tuff and biotite grains in siltstones; trace to rare very fine grained sandstone fragments with yellowish gray tuff/clay matrix; trace microcrystalline pyrite; abundant Safecarb and nut plug additives. Carbonaceous siltstone/siltstone (8270' - 8340') = blackish gray; easily friable to friable; poor to moderate induration; crumbly tenacity; planar fracture; platy to tabular cuttings habit; slightly vitreous to earthy luster; gritty texture; microlaminae to fissile structures; interbedded siltstone as described above; secondary upper to lower fine grained sand; abundant Safecarb and mud additives. Carbonaceous siltstone/siltstone (8340' - 8400') = dark gray to grayish black; easily friable to friable; poor induration; crumbly to pulverulent tenacity; planar to irregular earth fracture; vitreous to earthy luster; silty to gritty texture; microlaminae structures composed of carbonaceous material and siltstone; secondary tuffaceous material; abundant Safecarb and mud additives. Carbonaceous siltstone/siltstone (8400 - 8450') = dark gray to grayish black with secondary olive black hues; friable to soft; poorly indurated; dense to crumbly tenacity; irregular to planar fracture; platy to elongated tabular cuttings habit; vitreous to dull earthy luster; silty to gritty and slightly clayey texture; subtle microlaminae of carbonaceous material; traces of biotite within lamination; secondary tuff/clay and coal fines; abundant Safecarb and nut plug mud additives. Siltstone/carbonaceous siltstone (8450' - 8520') = dark gray to grayish black and greenish black in part; easily friable to soft; crumbly to pulverulent tenacity; planar to irregular fracture; platy to wedgelike cuttings habit; silty to sucrosic texture; fissile structures with subtle microlaminae of carbonaceous; material; secondary tuff/clay and coal fines; abundant Safecarb and nut plug mud additives. Siltstone (8520' - 8580') = medium dark gray to grayish black with secondary olive black; soft to easily friable; crumbly to pulverulent tenacity; irregular to planar fracture; platy to tabular wedge like cuttings habit; silty to gritty texture; mainly massive with micro laminated structures in part; secondary carbonaceous material; trace smooth yellowish gray devitrified ash tuff; very rare prismatic calcite vein filling deposit fragments. Siltstone (8580' - 8680') = dark gray to olive black; secondary olive gray; soft crumbly to firm friable; irregular to earthy planar fracture; massive to irregular flaky to elongate splintery cuttings to wedgelike cuttings; silty to gritty to occasionally smooth texture; laminated to massive structure; common to abundant carbonaceous micro lamina; scattered carbonaceous material; trace soft smooth yellowish gray tuff fragments; rare very fine tuff grains in siltstones; rare very fine grained sandstone fragments with calcareous cement; very rare moderate orangish brown volcanic lithics; very rare yellowish prismatic calcite vein filling deposit fragments; abundant nut plug and Safecarb additives. Carbonaceous siltstone (8680' - 8740') = olive black to dark gray; scattered medium gray to olive gray fragments; soft crumbly to firm friable; occasionally flexible carbonaceous layers; irregular to earthy planar fracture; massive to laminated with abundant carbonaceous micro lamina; trace increasing tuff fragments; rare very fine sandstone fragments and sands; rare microcrystalline pyrite. 2K-34 12 Selected Gas Peaks Depth TG C1 C2 C3 C4i C4n C5i C5n 7215’ 268 45089 2903 1147 147 263 65 59 7522’ 82 12884 983 429 52 119 32 25 8058’ 66 10880 685 312 41 86 33 42 8311’ 132 21248 1531 459 46 102 32 19 8437’ 182 30481 1791 565 57 131 28 29 8494’ 165 28304 1637 549 53 125 23 27 8710’ 184 30521 1945 680 75 180 44 44 2K-34 13 HRZ – 8760’ MD / 5840’ TVD to 9355’ MD / 6006’ TVD (-5697’ to -5863’ TVDSS) 8.5” conventional section (8760’ – 9151’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 150.0 27.4 93.5 336 7 152.5 8.5” casing while drilling section (9151’ – 9257’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 202.8 0.3 36.9 95 0 39.7 6.125” slant hole section (9257’ – 9355’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 69.5 1.6 30.7 62 3 29.5 The HRZ was comprised of carbonaceous siltstone. The carbonaceous siltstone often ranged in color from greenish black to olive black. The carbonaceous material was present within the microlaminae of the siltstone. The carbonaceous siltstone ranged from well to very poorly indurated. Traces of tuffaceous material were found throughout this interval. This zone contained now oil shows. Individual sample descriptions are as follows: Carbonaceous Siltstone (8740' - 8860') = olive black to grayish black; scattered medium dark gray; soft crumbly to firm friable; occasional dense to moderately hard; irregular to earthy planar to blocky fracture; massive to irregular flaky to elongate splintery to wedgelike cuttings; silty to gritty to occasionally smooth texture; laminated to massive structure; abundant carbonaceous micro lamina; common subtle silt micro bedding; scattered firm flexible carbonaceous material; trace to scattered soft yellowish gray devitrified ash tuff; rare very fine crumbly to moderately hard calcareous olive gray sandstone fragments; rare microcrystalline pyrite; rare moderate orangish brown volcanics; very rare mottled translucent to transparent jasper; very rare well rounded coarse sand grains; abundant Safecarb and nut plug additives. Carbonaceous siltstone (8860' - 8970') = greenish black to dark greenish gray, scattered medium dark gray; soft and easily friable to firmly friable; mostly moderately indurated with some poor to very poor induration; mostly crumbly with some dense to brittle sections; primarily massive with some platy to wedgelike cuttings habit; silty texture with varying amounts gritty to occasionally clayey; laminar to massive structure; micro laminations of carbonaceous material; trace amounts of pyrite and very soft yellowish gray devitrified tuff; trace amounts of olive gray sandstone which disappear in later samples; higher amounts of an extremely adhesive clay material appear in later samples; small amounts of rounded upper coarse to lower very coarse quartz sand grains scattered throughout sample. Siltstone/carbonaceous siltstone (8970' - 9030') = greenish black to olive black; scattered dark greenish gray; soft and easily friable to firmly friable; very poor to poor induration with some moderately well indurated; pulverulent to crumbly with some tough and dense; platy to massive cuttings habits; silty to gritty texture; laminated to massive structure; trace amounts of soft very light gray devitrified tuff. Siltstone/carbonaceous siltstone (9030' - 9150') = greenish black to olive black; firmly to easily friable grades into easily to firmly friable; moderately well induration grades into poor to very poor induration; dense to brittle grading into pulverulent to crumbly; platy and tabular cuttings habits grade into primarily massive; gritty silty texture grades into one displaying a more clayey property; luster is greasy to dull; a laminated structure grading into a massive one; micro laminated carbonaceous shale is abundant in early samples, mostly grades out; micro beds of carbonaceous material is seen in the silt in later samples; scattered amounts of devitrified tuff is seen ranging from milky white to medium bluish gray. 2K-34 14 Carbonaceous Siltstone (9150' - 9240') = greenish black to olive black; crumbly to crunchy; moderate to poor induration; scaly to elongated; dull to earthy luster; silty to gritty texture; massive to thinly laminated structure; scattered tuff; abundant nut plug mud additive. Carbonaceous Siltstone (9270' - 9300') = dark gray to grayish black; poor to moderate induration; firm to friable; crumbly to dense tenacity; irregular to planar fracture; tabular to wedgelike cuttings habit; clayey to gritty texture; occasional microlaminae structures; secondary medium dark gray, massive siltstone; trace fine grained sand. Selected Gas Peaks Depth TG C1 C2 C3 C4i C4n C5i C5n 8771’ 125 19945 1402 564 62 162 38 39 8819’ 143 23300 1716 702 73 198 43 46 8920’ 199 34246 2475 901 85 239 65 72 8978’ 288 54538 3962 1544 107 454 82 86 9009’ 336 56962 4351 1538 197 401 69 73 9146’ 117 18109 1338 495 36 126 37 31 2K-34 15 Kalubik – 9355’ MD / 6006’ TVD to 9800’ MD / 6129’ TVD (-5863’ to -5985’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 125.0 0.4 41.9 224 3 35.5 The Kalubik interval was comprised of carbonaceous siltstone. The carbonaceous siltstone was predominantly dark gray to grayish black. The samples had moderate to poor degree of induration, with a crumbly tenacity. Secondary quartz sand was found in several samples throughout the Kalubic. Trace glauconite, siderite and pyrite were found in the lower portions of the interval. One sample yielded oil indicators. Individual sample descriptions are as follows: Carbonaceous Siltstone (9300' - 9420') = medium dark gray to grayish black; poor to moderate induration; crumbly tenacity; planar to occasionally irregular fracture; elongated to tabular cuttings habit; silty to gritty texture; microlaminae and massive structures; carbonaceous material interbedded with medium dark gray to grayish black silt; secondary fine grained sand with rare transparent grayish green to slightly green silicate grains; siltstone in 9330' sample is lighter in color than the siltstone in 9360' and 9390' sample; abundant Safecarb mud additive. Carbonaceous Siltstone (9420' - 9490') = dark gray to grayish black; poor to moderate induration; crumbly to brittle tenacity; planar to irregular fracture; elongated to platy cuttings habit; clayey to gritty texture; occasional microlaminae structures; trace pyrite; Safecarb mud additive present; no odor; scattered brownish black fragments; orange to dull orange fluor; light milky yellow cut fluor; no visible cut; pale straw residue; dark milky yellow residue fluor. Carbonaceous Siltstone (9490' - 9535') = dark gray to grayish black; poor induration; crumbly tenacity; planar to irregular fracture; elongated to tabular cuttings habit; silty to gritty texture; occasional microlaminae structure; trace very fine grained sand; abundant Safecarb mud additive. Carbonaceous Siltstone (9535' - 9605') = dark gray to grayish black with olive black secondary hues; moderate to sub moderate induration; tough to crumbly to brittle tenacity; open to earthy fracture; elongated to tabular, occasionally flaky; silty to matte texture; massive to thinly laminated structure; common course translucent to frosted quartz grains; common pyrite and black carbonaceous lithics; abundant siderite fragments in 9605' sample. Carbonaceous Siltstone (9605' - 9695') = grayish black to dark gray; moderate to poor induration; crumbly to brittle to tough tenacity; earthy fracture; elongated to tabular cuttings habit; dull earthy to slightly frosted luster; silty to matte texture; massive to thinly laminated structure; common carbonaceous lithic fragments and translucent to frosted upper coarse to lower medium quartz grains; scattered pyrite; trace siderite fragments; trace glauconite. Carbonaceous Siltstone (9695' - 9800') = grayish black to dark gray; moderate to poor induration; crumbly to tough tenacity; earthy to open fracture; tabular to elongated cuttings habit; earthy to frosted luster due to common pyrite coating; silty to matte texture; massive to thinly laminated structure; common upper coarse to upper medium, translucent to frosted quartz grains, often pyritized; common siderite fragments; trace siderite coating on rounded quartz grains; trace glauconite, trace microcrystalline pyrite, very rare greenish gray modeled with dark greenish gray translucent grains. Selected Gas Peaks Depth TG C1 C2 C3 C4i C4n C5i C5n 9600’ 224 50695 2415 625 61 122 35 20 9650’ 72 15744 953 316 41 93 12 3 2K-34 16 Kuparuk C – 9800’ MD / 6129’ TVD to 9858’ MD / 6143’ TVD (-5985’ to -6000’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 83.6 1.3 29.9 65 4 31.9 This Kuparuk C interval was comprised of medium light gray to grayish black sand. The sand was lower coarse to upper medium in size. The grains had moderate sorting and ranged form angular to round. The grains were often poorly consolidated and occasionally had weak carbonate cement. Traces of glauconite and pyrite were found in this interval. Oil shows were of poor quality in this interval. Samples generally had no free oil, stain, or odor. Sample fluorescence was scattered to even dull gold. The cut was not visible in white light, but under the fluoroscope appeared milky white. The residue fluorescence was a dark milky yellow, but not visible under white light. Individual sample description is as follows: Sand (9800' - 9870') = medium light gray to grayish black with secondary light olive gray; lower coarse to upper medium grained; moderate sorting; angular to round; high to moderate sphericity; impact surface features; poorly consolidated; minor carbonate cement; occasional silty matrix material; low textural maturity; low compositional maturity; common upper fine, well rounded, black lithic inclusions found within grains; trace glauconite; trace microcrystalline pyrite; no odor; no stain; scattered to even dull gold fluor; milky yellow cut fluor; milky yellow cut fluor; no visible cut; dark milky yellow residual cut fluor; no visible residual cut. Selected Gas Peaks Depth TG C1 C2 C3 C4i C4n C5i C5n 9811’ 58 9180 635 233 39 77 15 16 9834’ 65 11024 799 310 61 75 32 39 Kuparuk A5 – 9858’ MD / 6143’ TVD to 9928’ MD / 6162’ TVD (-6000’ to -6019’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 74.0 4.4 43.7 235 26 107.0 The Kuparuk A5 interval was comprised of sand and sandstone. Samples varied from brownish black to olive gray. Grain size varied from lower very fine to lower coarse grained. The sand ranged from subrounded to subangular and had a moderate to high degree of sphericity. The secondary sandstone was well rounded and well sorted with lower very fine grains. Oil indicators were found in the sandstone and yielded a show report. The oil show was of fair quality in this interval. The sandstone contained oil staining and odor. Samples contained a scattered to even dull gold fluorescence. The cut fluorescence was milky yellow and appeared with streamers. This cut was not visible in white light. The residual cut was also not visible in white light, but left a dull yellow fluorescence. Individual sample description is as follows: Sandstone/Sand (9870' - 9945') = brownish black to olive gray; lower very fine to lower coarse grained; moderate sorting; subangular to well rounded; moderate to high degree of sphericity; occasional impact 2K-34 17 surface features; unconsolidated to poorly consolidated; occasional silty matrix; secondary siltstone; sandstone is lower very fine grained; well rounded; well sorted; contains oil staining; contains oil odor; scattered to even dull gold fluor; light milky yellow cut fluor with streamers; no visible cut; dull yellow residual fluor; no visible residual cut. Selected Gas Peak Depth TG C1 C2 C3 C4i C4n C5i C5n 9875’ 236 31645 2977 1204 121 260 58 57 Kuparuk A4 – 9928’ MD / 6162’ TVD to 10127’ MD / 6127’ TVD (-6019’ to -6074’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 95.4 4.5 50.9 380 49 170.0 The Kuparuk A4 was comprised of a sandstone that was brownish black to brownish gray. The grains ranged from lower fine to upper medium with poor to moderate sorting. The sandstone grains were moderate to highly spherical and had weak silicate cement. Traces of microcrystalline pyrite were found throughout this interval. Free oil was found throughout this interval. Show evaluations indicated high quality oil. Samples often had a moderate to strong oil smell. Samples had scattered to even light orange sample fluorescence. The cut was bright milky yellow in fluorescent light and brown in white light. The residual florescence was pale peach to yellow and in one instance was brown in visible light. Individual sample descriptions are as follows: Sandstone (9945' - 10040') = brownish black to brownish gray; lower fine to upper medium grained; poor sorting; subangular to subrounded; moderate degree of sphericity; occasional impact surface features; unconsolidated to poorly consolidated; silicate cement; secondary siltstone and loose coarse grained sand; rare micro crystalline pyrite; contains free oil pinpoints in mud; light brown stain; moderate scattered to even orange sample fluor; bright milky yellow cut fluor; brown visible cut; pale yellow to pale peach residual fluor; brown residual cut. Sandstone (10040' - 10127') = brownish black to brownish gray; upper fine to upper medium; moderate sorting; subrounded to subangular; high degree of sphericity; trace impact surface features; poor consolidation; occasional silty matrix; grain supported; moderate to high textural maturity; secondary siltstone; trace microcrystalline pyrite; contains free oil pinpoints; light brown staining; moderate to scattered light orange fluor and scattered light yellow fluor; bright milky white cut; pale yellow to orange residual fluor; no residual cut. Selected Gas Peaks Depth TG C1 C2 C3 C4i C4n C5i C5n 9975’ 380 50704 5251 2083 212 444 96 93 10009’ 294 29418 2651 1030 106 235 97 79 2K-34 18 3.3 Connection & Trip Gases 1unit = 0.05% Methane Equivalent Depth MD (ft) TVD (ft) Gas over background (units) 7020 4887 65 7115 4942 80 7300 5049 60 7380 5095 30 7480 5152 40 7575 5207 30 7665 5259 20 7760 5314 34 7945 5421 40 8040 5475 35 8135 5530 66 8230 5585 36 8320 5637 38 8410 5687 50 8515 5741 30 8595 5777 70 8690 5816 116 8780 5849 80 8870 5876 60 8960 5901 136 9060 5928 50 9660 6090 418 9745 6113 340 9840 6139 260 9935 6165 110 3.4 Trip (Wiper) Gases 1unit = 0.05% Methane Equivalent Depth (ft) Trip to (ft) Gas (units) Downtime (hrs) 9151 0 121 67.8 9760 0 118 32.0 2K-29 19 3.5 Sampling Program Interval and spot cuttings samples were collected for analysis by the mudlogger and wellsite geologist based on ROP and zones of interest, generally every 30’. Washed and dried reference samples were not collected. 2K-34 20 4 DRILLING DATA 4.1 Survey Data 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 0 0 0 0 0 0 0 96.4 0.04 154.21 96.4 -0.03 0.01 -0.02 0.04 147.63 0.08 113.62 147.63 -0.06 0.06 -0.06 0.11 176.34 0.7 272.72 176.34 -0.06 -0.1 0.1 2.7 262.57 2.33 275.51 262.54 0.13 -2.37 2.37 1.89 356.32 2.72 272.96 356.2 0.43 -6.49 6.5 0.43 448.77 5.63 269.07 448.39 0.47 -13.22 13.22 3.16 541.7 6.53 268.37 540.8 0.25 -23.06 23.06 0.97 633.3 7.3 269.27 631.73 0.02 -34.08 34.08 0.85 724.75 7.08 270.33 722.46 -0.02 -45.53 45.52 0.28 819.1 9.6 272.43 815.81 0.35 -59.21 59.2 2.69 910.43 9.49 272.17 905.87 0.96 -74.34 74.34 0.13 1005.21 10.77 272.35 999.17 1.62 -90.99 91.01 1.35 1095.6 12.06 274.32 1087.77 2.67 -108.85 108.88 1.49 1190.03 15.36 273.03 1179.5 4.08 -131.18 131.23 3.51 1229.4 16.12 274.48 1217.39 4.78 -141.84 141.9 2.17 1320.6 17.32 273.99 1304.74 6.71 -168 168.1 1.32 1413.59 21.55 271.48 1392.41 8.12 -198.9 199.01 4.64 1504.57 26.11 269.45 1475.61 8.36 -235.64 235.75 5.09 1600.32 26.78 269.92 1561.34 8.13 -278.28 278.38 0.73 1647.05 27.3 270.23 1602.96 8.16 -299.53 299.62 1.15 1662.09 28.4 269.89 1616.26 8.16 -306.55 306.65 7.39 1692.16 30.63 269.3 1642.43 8.05 -321.36 321.46 7.48 1783.78 32.47 268.77 1720.5 7.24 -369.29 369.36 2.03 1876.84 34.65 270.23 1798.05 6.81 -420.73 420.78 2.5 1969.7 34.82 275.5 1874.38 9.46 -473.53 473.62 3.24 2062.78 35.97 276.06 1950.25 14.89 -527.17 527.35 1.28 2154.21 38.42 277.44 2023.08 21.41 -582.05 582.33 2.83 2245.9 44.31 278.85 2091.86 30.03 -641.99 642.42 6.5 2297.1 44.48 278.82 2128.45 35.53 -677.39 677.9 0.33 2338.91 46.26 278.14 2157.82 39.92 -706.82 707.4 4.41 2432.36 47.39 274.75 2221.77 47.55 -774.52 775.23 2.91 2524.9 49.91 274.64 2282.9 53.23 -843.75 844.55 2.72 2618.35 53.13 274.44 2341.04 59.02 -916.66 917.55 3.45 2710.93 54.22 274.5 2395.88 64.83 -991.02 992 1.18 2801.67 54.4 273.97 2448.82 70.27 -1064.52 1065.58 0.51 2894.93 55.89 272.44 2502.12 74.54 -1140.92 1142.05 2.09 2K-34 21 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 ) 2987.57 56.03 272.19 2553.98 77.64 -1217.63 1218.8 0.27 3080.56 55.73 272.39 2606.14 80.72 -1294.55 1295.76 0.37 3172.69 55.3 272.15 2658.3 83.73 -1370.43 1371.68 0.51 3265.86 53.7 269.68 2712.41 84.95 -1446.26 1447.52 2.76 3357.8 53.94 270.03 2766.68 84.77 -1520.47 1521.72 0.4 3450.66 53.98 269.74 2821.32 84.62 -1595.56 1596.79 0.26 3457.65 53.91 269.56 2825.43 84.58 -1601.21 1602.44 2.31 3590.39 54.09 268.99 2903.45 83.22 -1708.59 1709.78 0.37 3626.34 54.21 268.6 2924.51 82.61 -1737.72 1738.9 0.94 3719.64 54.25 268.84 2979.05 80.92 -1813.4 1814.54 0.21 3813.71 54.23 268.73 3034.02 79.3 -1889.72 1890.81 0.1 3903.51 54.29 269.03 3086.47 77.87 -1962.59 1963.65 0.28 3996.27 54.24 269.74 3140.65 77.07 -2037.88 2038.92 0.62 4090.68 54.44 270.4 3195.69 77.16 -2114.59 2115.61 0.61 4182.73 54.6 271.34 3249.12 78.3 -2189.54 2190.57 0.85 4275.37 54.64 271.45 3302.75 80.14 -2265.05 2266.1 0.11 4368.5 55.26 271.11 3356.24 81.84 -2341.27 2342.34 0.73 4462.46 55.21 270.7 3409.82 83.06 -2418.45 2419.53 0.36 4555.82 55.13 271.3 3463.14 84.4 -2495.07 2496.16 0.53 4648.41 54.6 271.17 3516.42 86.03 -2570.77 2571.88 0.58 4740.64 54.61 270.73 3569.84 87.28 -2645.94 2647.06 0.39 4834.03 54.75 270.93 3623.84 88.38 -2722.14 2723.26 0.23 4925.75 54.68 271.33 3676.82 89.86 -2796.99 2798.13 0.36 5018.86 54.71 272.04 3730.63 92.09 -2872.94 2874.11 0.62 5111.24 54.61 272.35 3784.06 94.98 -2948.25 2949.45 0.29 5203.3 54.71 272.3 3837.32 98.02 -3023.28 3024.53 0.12 5296.41 54.7 272.47 3891.11 101.18 -3099.21 3100.5 0.15 5387.98 54.7 272.61 3944.03 104.5 -3173.87 3175.21 0.12 5481.75 54.71 272.32 3998.21 107.79 -3250.33 3251.72 0.25 5574.11 54.69 272.08 4051.58 110.68 -3325.66 3327.08 0.21 5666.27 54.73 271.79 4104.82 113.22 -3400.84 3402.3 0.26 5758.92 54.68 271.85 4158.35 115.62 -3476.42 3477.91 0.08 5852.16 54.68 271.59 4212.26 117.91 -3552.46 3553.98 0.23 5944.82 54.71 271.55 4265.81 119.98 -3628.05 3629.59 0.05 6038.19 54.7 271.61 4319.76 122.08 -3704.23 3705.8 0.05 6129.69 54.67 271.7 4372.65 124.24 -3778.86 3780.46 0.09 6221.85 54.73 272.32 4425.91 126.87 -3854.03 3855.66 0.55 6313.81 54.65 272.5 4479.06 130.03 -3929.01 3930.68 0.18 6406.86 54.68 272.72 4532.87 133.49 -4004.84 4006.56 0.2 6498.02 54.68 273.34 4585.58 137.42 -4079.11 4080.89 0.55 6591.99 54.61 273.54 4639.95 142.02 -4155.62 4157.46 0.19 2K-34 22 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) 6684.16 54.6 273.67 4693.34 146.74 -4230.6 4232.52 0.12 6775.35 54.76 272.88 4746.06 150.99 -4304.89 4306.86 0.73 6868.86 54.85 273.3 4799.96 155.11 -4381.19 4383.23 0.38 6962.06 54.75 272.37 4853.68 158.88 -4457.25 4459.35 0.82 7055.45 54.79 271.61 4907.55 161.53 -4533.49 4535.62 0.67 7148.14 54.8 271.95 4960.99 163.88 -4609.19 4611.35 0.3 7240.55 54.78 272.42 5014.27 166.76 -4684.64 4686.84 0.42 7334.01 54.82 272.55 5068.14 170.07 -4760.94 4763.18 0.12 7426.06 54.78 272.8 5121.21 173.58 -4836.07 4838.37 0.23 7519.58 54.67 272.76 5175.21 177.28 -4912.33 4914.68 0.12 7612.57 54.8 272.81 5228.9 180.97 -4988.17 4990.57 0.15 7704.87 54.77 273.3 5282.13 184.99 -5063.47 5065.93 0.43 7797.31 54.86 273.03 5335.39 189.16 -5138.9 5141.42 0.26 7888.85 54.68 272.47 5388.2 192.75 -5213.59 5216.16 0.54 7982.5 54.78 272.11 5442.27 195.8 -5289.99 5292.6 0.33 8074.41 54.75 272.07 5495.3 198.54 -5365.01 5367.66 0.05 8169.03 54.68 271.07 5549.96 200.66 -5442.22 5444.89 0.87 8259.55 54.71 271.1 5602.27 202.06 -5516.08 5518.76 0.04 8352.11 55.27 270.57 5655.38 203.16 -5591.88 5594.57 0.77 8445.17 58.66 269.57 5706.1 203.24 -5669.88 5672.57 3.75 8538.65 62.43 269.86 5752.06 202.84 -5751.26 5753.93 4.04 8632.37 65.42 270.61 5793.25 203.19 -5835.43 5838.09 3.27 8722.36 68.5 271.13 5828.47 204.46 -5918.23 5920.89 3.46 8816.61 72.2 272.51 5860.16 207.29 -6006.92 6009.63 4.16 8909.85 74.16 272.91 5887.14 211.51 -6096.07 6098.83 2.14 9001.88 74.52 272.49 5911.98 215.68 -6184.59 6187.41 0.59 9096.77 74.46 271.93 5937.35 219.21 -6275.95 6278.82 0.57 9212.37 74.58 271.38 5968.21 222.43 -6387.31 6390.22 0.47 9307.92 74.41 270.76 5993.75 224.15 -6479.37 6482.29 0.65 9402.88 74.12 270.58 6019.5 225.21 -6570.76 6573.69 0.36 9496.84 74.05 270.44 6045.27 226.02 -6661.12 6664.05 0.16 9592.71 74.01 270.65 6071.64 226.9 -6753.28 6756.21 0.21 9684.17 74.4 271.07 6096.54 228.22 -6841.28 6844.22 0.61 9779.6 74.34 271.72 6122.25 230.45 -6933.15 6936.12 0.66 9875.71 74.01 270.98 6148.46 232.63 -7025.59 7028.58 0.82 9970.31 74.12 271.46 6174.43 234.57 -7116.54 7119.55 0.5 10065.33 74.05 271.16 6200.49 236.66 -7207.89 7210.92 0.31 2K - 3 4 23 4. 2 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 in M D To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) WO B (K l b s ) RP M PP (p s i ) Wear 1 1 3 . 5 ” B a k e r MX L - 1 X M T / 52 3 8 1 1 9 4x 1 6 / 0 . 7 8 5 1 0 4 ’ 2 6 ’ 0 . 3 5 7 4 . 3 1 1 1 (see 1RR2) 1R R 1 1 3 . 5 ” B a k e r MX L - 1 X M T / 52 3 8 1 1 9 4x 1 6 / 0 . 7 8 5 1 3 0 ’ 3 4 6 0 ’ 3 4 . 2 8 1 0 0 . 9 1 1 1 (see 1RR2) 1R R 2 1 3 . 5 ” B a k e r MX L - 1 X M T / 52 3 8 1 1 9 4x 1 6 / 0 . 7 8 5 1 6 4 7 ’ 1 9 0 8 ’ 2 0 . 7 3 9 2 . 0 1 1 1 1-2-WT-A-E-1/8-NO-TD 2 8 . 5 ” S e c u r i t y MM 6 5 M P D C / 12 3 5 4 2 8 4 6x 1 3 / 0 . 7 7 8 3 5 5 5 ’ 2 0 ’ 0 . 3 2 6 2 . 5 1 1 1 No wear 2R R 1 8 . 5 ” S e c u r i t y MM 6 5 M P D C / 12 3 5 4 2 8 4 6x 1 3 / 0 . 7 7 8 3 5 7 5 ’ 5 5 7 6 ’ 5 1 . 7 5 1 0 7 . 7 8 . 4 2 1 1 8 . 2 2 1 9 6 7 2 1-1-WT-A-X-I-CT-TD 3 8 . 5 ” B a k e r EZ C a s e B i t Ty p e / E Z C 5 0 6 6x 1 0 / 0 . 4 6 0 9 1 5 1 ’ 1 0 6 ’ 4 . 1 3 6 . 9 9 . 7 7 5 . 7 5 2 4 ( c e m e n t e d i n h o l e ) 4 6 . 1 2 5 ” S m i t h MD i 5 1 3 P D C / JJ 0 0 6 9 3x 1 3 / 0 . 3 8 9 9 2 5 7 ’ 2 2 7 2 ’ 2 7 . 7 4 1 . 9 1 0 . 4 1 0 1 . 2 2 6 0 5 0 - 4 - S - B T - X - I - N O - T D 1 Dr i l l e d p r i o r t o C a n r i g a r r i v a l 2 A v e r a g e s f r o m 7 0 0 0 ’ w h e n l o g g i n g c o m m e n c e d 2K - 3 4 24 4. 3 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 : L S N D Da t e De p t h (f t ) MW (p p g ) MB T (l b / b b l ) 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) 6/ 7 / 1 4 7 6 5 6 1 0 . 0 1 8 . 5 4 6 1 3 2 0 8 / 8 / 9 4 . 3 1 / - 1 0 3 / 8 7 0 . 7 5 9 . 5 8 5 0 4 8 6/ 8 / 1 4 9 1 5 1 1 0 . 3 1 8 . 7 5 5 6 1 6 2 6 1 1 / 1 1 / 1 1 2 . 6 1 / - 1 2 4 / 8 4 0 . 5 9 . 5 7 0 0 6 0 6/ 9 / 1 4 9 1 5 1 1 0 . 4 1 8 . 7 5 5 1 1 1 2 0 6 / 7 / 9 3 . 8 1 / - 1 1 4/ 8 5 t r 9 . 8 6 0 0 6 0 6/ 1 0 / 1 4 9 1 5 1 1 0 . 5 1 8 . 7 5 5 2 1 7 3 1 1 2 / 1 3 / 1 4 3 . 6 1 / - 1 1 . 5 4 / 8 5 t r 9 . 8 5 0 0 4 0 6/ 1 1 / 1 4 9 1 8 9 1 0 . 9 5 4 7 1 0 1 6 7 / 7 / 7 3 . 6 1 / - 1 1 3 / 8 6 t r 9 . 8 5 0 0 1 0 0 6/ 1 2 / 1 4 9 2 5 8 1 1 . 6 - 4 7 1 0 1 4 7 / 8 / - - - / - - - / - - 9 . 3 - - 6/ 1 3 / 1 4 9 2 5 8 1 0 . 5 - 4 2 5 1 6 9 / 1 1 / 1 2 4 1 / - 9 1 / 9 0 - 9 . 3 5 0 0 8 0 6/ 1 4 / 1 4 9 2 5 8 1 0 . 6 1 . 8 7 5 4 2 1 0 1 4 8 / 9 / 9 5 . 5 1 / - 9 1 / 9 0 - 8 . 8 5 0 0 8 0 6/ 1 5 / 1 4 9 2 5 8 1 0 . 5 1 . 5 4 4 8 1 6 9 / 1 0 / 1 2 5 1 / - 9 1 / 9 0 - 8 . 6 5 0 0 8 0 6/ 1 6 / 1 4 9 2 5 8 1 0 . 5 3 4 1 8 2 1 9 / 1 0 / 1 1 5 . 4 1 / - 1 0 1 / 8 9 - 1 0 . 4 5 0 0 1 0 0 6/ 1 7 / 1 4 9 6 1 4 1 2 . 5 4 . 4 5 1 1 8 2 2 6 / 8 / 1 1 2 . 7 1 / - 1 7 . 5 2 / 8 1 1 9 . 7 5 0 0 1 4 0 6/ 1 8 / 1 4 1 0 1 2 7 1 3 . 1 7 5 1 2 7 2 2 6 / 8 / 1 0 6 . 2 1 / - 2 1 1 / 7 8 t r 9 . 3 5 0 0 1 1 2 Mu d T y p e : P O W E R - V I S L S N D 6/ 1 1 / 1 4 9 1 8 9 1 0 . 9 5 4 7 1 0 1 6 7 / 7 / 7 3 . 6 1 / - 1 1 3 / 8 6 t r 9 . 8 5 0 0 1 0 0 6/ 1 2 / 1 4 9 2 5 8 1 1 . 6 - 4 7 1 0 1 4 7 / 8 / - - - / - - - / - - 9 . 3 - - 6/ 1 3 / 1 4 9 2 5 8 1 0 . 5 - 4 2 5 1 6 9 / 1 1 / 1 2 4 1 / - 9 1 / 9 0 - 9 . 3 5 0 0 8 0 6/ 1 4 / 1 4 9 2 5 8 1 0 . 6 1 . 8 7 5 4 2 1 0 1 4 8 / 9 / 9 5 . 5 1 / - 9 1 / 9 0 - 8 . 8 5 0 0 8 0 Mu d T y p e : L S N D Da t e De p t h (f t ) MW (p p g ) MB T (l b / b b l ) 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) 6/ 1 5 / 1 4 9 2 5 8 1 0 . 5 1 . 5 4 4 8 1 6 9 / 1 0 / 1 2 5 1 / - 9 1 / 9 0 - 8 . 6 5 0 0 8 0 6/ 1 6 / 1 4 9 2 5 8 1 0 . 5 3 4 1 8 2 1 9 / 1 0 / 1 1 5 . 4 1 / - 1 0 1 / 8 9 - 1 0 . 4 5 0 0 1 0 0 6/ 1 7 / 1 4 9 6 1 4 1 2 . 5 4 . 4 5 1 1 8 2 2 6 / 8 / 1 1 2 . 7 1 / - 1 7 . 5 2 / 8 1 1 9 . 7 5 0 0 1 4 0 6/ 1 8 / 1 4 1 0 0 7 2 1 3 . 1 6 5 3 2 4 2 2 7 / 9 / 1 1 - 1 / - 2 0 . 5 1 / 7 9 t r 9 . 5 5 0 0 6 0 6/ 1 9 / 1 4 1 0 1 2 7 1 3 . 1 6 5 3 2 6 2 2 6 / 7 / 7 3 1 / - 2 1 1 / 7 8 t r 9 . 6 5 0 0 6 8 6/ 2 0 / 1 4 1 0 1 2 7 1 2 . 8 6 6 3 2 4 2 5 7 / 1 1 / 1 1 3 . 2 1 / - 2 0 1 / 7 9 t r 9 . 9 5 0 0 7 2 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 WL = 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 2K-34 25 5 SHOW REPORT Hydrocarbon Show Report # 1 Operator: Conoco Phillips Alaska Well: API Number: Field: Date: Rig: Start Time: 7:47 End Time: 11:07 County: Depth Start End State: 9800'MD 9858'MD Country: 6127'TVD 6144'TVD Averages Before During After Maximum ROP (fph) 20 30 43 74 WOB 12 9 10 12 RPM 99 113 119 120 Mud Weight 12.80 12.80 12.80 12.80 Chloride 500 500 500 500 Total Gas 10 31 109 66 C1 (ppm) 1,582 5,005 14,886 11,024 C2 (ppm) 106 377 1,275 799 C3 (ppm) 53 151 535 312 C4 (ppm) 34 57 179 136 C5 (ppm) 10 26 55 71 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain None Amount 50% Type Streaming Amount Amount Distribution Patchy-Even Intensity Dull-Brt Color Color Intensity Dulll Color Milky Residual Fluorescence Cut None Color Gold Yellow Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: 50-103-20688-00-00 2K-34 Kuparuk River Unit North Slope Borough Alaska USA Doyon 141 6/18/2014 None Dark-Yellow Harris / Thrailkill None Poor Dull-Bright Sand = medium light gray to grayish black with secondary light olive gray; lower coarse to upper medium grained; moderate sorting; angular to round; high to moderate sphericity; impact surface features; poorly consolidated; minor carbonate cement; occasional silty matrix material; low textural maturity; low compositional maturity; common upper fine, well rounded, black lithic inclusions found within grains; trace glauconite; trace microcrystalline pyrite; no odor; no stain; scattered to even dull gold fluor; milky yellow cut fluor; milky yellow cut fluor; no visible cut; dark milky yellow residual cut fluor; no visible residual cut. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 2 Operator: Conoco Phillips Alaska Well: API Number: Field: Date: Rig: Start Time: 11:07 End Time: 12:51 County: Depth Start End State: 9858'MD 9928'MD Country: 6144'TVD 6163'TVD Averages Before During After Maximum ROP (fph) 30 43 51 95 WOB 9 10 9 13 RPM 113 119 103 120 Mud Weight 12.80 12.80 12.80 12.80 Chloride 500 500 500 500 Total Gas 31 109 170 236 C1 (ppm) 5,005 14,886 21,314 31,651 C2 (ppm) 377 1,275 2,028 3,028 C3 (ppm) 151 535 858 1,226 C4 (ppm) 57 179 294 384 C5 (ppm) 26 55 117 115 Lithology Cuttings Analysis Odor Faint-Mod Fluorescence Cut Fluorescence Residual Cut Stain Amount 75% Type Streaming Amount Amount 50% Distribution Even Intensity Bright Color Color Lt-Brn Intensity Dull Color Light Residual Fluorescence Cut Color Gold Milky Intesity Color None Yellow Color Oil Show Rating Free Oil in Mud Comments Report by: 50-103-20688-00-00 2K-34 Kuparuk River Unit North Slope Borough Alaska USA Doyon 141 6/18/2014 None Yellow Harris / Thrailkill None Fair Dull Sandstone/sand = brownish black to olive gray; lower very fine to lower coarse grained; moderate sorting; subangular to well rounded; moderate to high degree of sphericity; occasional impact surface features; unconsolidated to poorly consolidated; occasional silty matrix; secondary siltstone; sandstone is lower very fine grained; well rounded; well sorted; contains oil staining; contains oil odor; scattered to even dull gold fluor; light milky yellow cut fluor with streamers; no visible cut; dull yellow residual fluor; no visible residual cut. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 3 Operator: Conoco Phillips Alaska Well: API Number: Field: Date: Rig: Start Time: 12:53:16 End Time: 18:00:59 County: Depth Start End State: 9928 MD 10127'MD Country: 6163'TVD 6217'TVD Averages Before During After Maximum ROP (fph) 43 51 95 WOB 10 9 14 RPM 119 103 120 Mud Weight 12.80 12.80 13.10 13.10 Chloride 500 500 500 500 Total Gas 108 170 380 C1 (ppm) 14,727 21,314 50,704 C2 (ppm) 1,261 2,028 5,251 C3 (ppm) 529 858 2,083 C4 (ppm) 177 294 656 C5 (ppm) 54 117 247 Lithology Cuttings Analysis Odor Mod-Strong Fluorescence Cut Fluorescence Residual Cut Stain Amount 80% Type Streaming Amount Amount 70% Distribution Even Intensity Bright Color Color Light-Brown Intensity Dull Color Milky Residual Fluorescence Cut Moderate Color Orange Yellow Intesity Color Brown Color Oil Show Rating Free Oil in Mud Comments Report by: Pale Yel/Peach Harris / Thrailkill Trace Good Moderate Sandstone = Brownish black to brownish gray; lower fine to upper medium grained; poor sorting; subangular to subrounded; moderate degree of sphericity; occasional impact surface features; unconsolidated to poorly consolidated; silicate cement; secondary siltstone and loose coarse grained sand; rare micro crystalline pyrite; contains free oil pinpoints in mud; light brown stain; moderate scattered to even orange sample fluor; bright milky yellow cut fluor; brown visible cut; pale yellow to pale peach residual fluor; brown residual cut. Medium Brown 50-103-20688-00-00 2K-34 Kuparuk River Unit North Slope Borough Alaska USA Doyon 141 6/18/2014 Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 2K-34 26 6 DAILY REPORTS Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Lundale DATE June 7, 2014 DEPTH 7843' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 7000' 24 HOUR FOOTAGE 843' CASING INFORMATION 16" @ 108', 10.75" @ 3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7797.31' 54.88 272.60 5334.69' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Security MM65M PDC 12354284 6x13 3554' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 268.1 @ 7760 7.3 @ 7083 98.0 92.7 FT/HR SURFACE TORQUE 12718 @ 7234 7417 @ 7490 8428.7 8567.0 AMPS WEIGHT ON BIT 16 @ 7234 0 @ 7412 7.0 9.7 KLBS ROTARY RPM 120 @ 7005 118 @ 7839 118.5 119.0 RPM PUMP PRESSURE 1925 @ 7269 1413 @ 7020 1851.6 1845 PSI DRILLING MUD REPORT DEPTH 7656' MW 10.0 VIS 46 PV 13 YP 20 FL 4.3 Gels 8/8/9 CL- 850 FC 1/NA SOL 10 SD 0.75 OIL 3/87 MBT 18.5 pH 9.5 Ca+ 48 Alk 0.15 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 267 @ 7215 10 @ 7447.00000 46.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 45088 @ 7215 1625 @ 7447 7487.9 CONNECTION GAS HIGH 80 ETHANE (C-2) 2902 @ 7215 91 @ 7447 476.2 AVG 45 PROPANE (C-3) 1146 @ 7216 35 @ 7761 219.3 CURRENT 40 BUTANE (C-4) 410 @ 7215 26 @ 7765 99.8 CURRENT BACKGROUND/AVG 27 PENTANE (C-5) 124 @ 7246 0 @ 7001 38.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Schrader Bluff PRESENT LITHOLOGY Siltstone, sand DAILY ACTIVITY SUMMARY Canrig began full logging operations at 7000' MD. Drill from 7000' to 7843' MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2935.00 REPORT BY Hammond Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Lundale DATE June 8, 2014 DEPTH 9151' PRESENT OPERATION Pulling out of hole TIME 24:00 YESTERDAY 7843' 24 HOUR FOOTAGE 1308' CASING INFORMATION 16" @ 108', 10.75" @ 3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9096.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Security MM65M PDC 12354284 6x13 3554' 9151' 5597' 51.13 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 311.8 @ 9148 15.7 @ 9062 92.2 65.79 FT/HR SURFACE TORQUE 13672 @ 9088 7788 @ 8962 9487.8 9757 AMPS WEIGHT ON BIT 114 @ 9054 0 @ 8039 9.4 7.9 KLBS ROTARY RPM 120 @ 8225 117 @ 8874 118.1 118 RPM PUMP PRESSURE 2341 @ 8370 1433 @ 7953 2042.3 2166 PSI DRILLING FLUIDS REPORT DEPTH 9151' MW 10.3 VIS 56 PV 16 YP 26 FL 2.6 Gels 11/11/11 CL- 700 FC 1/- SOL 12 SD 0.5 OIL 4/84 MBT 18.75 pH 9.5 Ca+ 60 Alk 0.12 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 336 @ 9009 7 @ 9110 92.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 56962 @ 9009 1166 @ 9110 15172.4 CONNECTION GAS HIGH 143 ETHANE (C-2) 4351 @ 9009 102 @ 9110 1088.4 AVG 60.5 PROPANE (C-3) 1544 @ 8978 41 @ 9110 413.6 CURRENT 50 BUTANE (C-4) 598 @ 9009 16 @ 9110 161.1 CURRENT BACKGROUND/AVG PENTANE (C-5) 173 @ 8954 6 @ 9110 55.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY HRZ PRESENT LITHOLOGY Siltstone, carbonaceous siltstone DAILY ACTIVITY SUMMARY Drilled from 7,841' to 9,151' MD. Weighted up mud from 10ppg to 10.4ppg in response to higher connection gases. Monitered well and begin pulling out of hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2935.00 REPORT BY Thrailkill Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Lundale DATE June 9, 2014 DEPTH 9151' PRESENT OPERATION Dummy Run TIME 24:00 YESTERDAY 9151' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 108', 10.75" @ 3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9096.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" Security MM65M PDC 12354284 6x13 3575' 9151' 5575' 51.75 1-1-WT-A-X-I-CT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9151' MW 10.4 VIS 51 PV 11 YP 20 FL 3.8 Gels 6/7/9 CL- 600 FC 1/- SOL 11 SD tr OIL 4/85 MBT 18.75 pH 9.8 Ca+ 60 Alk 0.18 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Monitor well @ 8966' MD; flowed back 3 BBL then stopped, static for 30 minutes; BROOH, CBU @ 8227’ MD; Cont. BROOH to10.4 ppg; monitor well for 15 minutes. Rack back HWPD, L/D collars and BHA. R/U and pull wear bushings, test all rams. R/U and flush stack, drain stack P/U landing JT and hanger and make dummy run. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY John Farrell Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Lundale DATE June 10, 2014 DEPTH 9151' PRESENT OPERATION Running in hole TIME 24:00 YESTERDAY 9151' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @108', 10.75" @3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9096.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Baker Hughes EZ Case Bit Type EZC506 7040005 6x10 9151' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9151' MW 10.5 VIS 52 PV 17 YP 31 FL 3.6 Gels 12/13/14 CL- 500 FC 1/- SOL 11.5 SD TR OIL 4/85 MBT 18.75 pH 9.8 Ca+ 40 Alk 0.2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Change out top pipe rams to 7", test. Rig up Tesco. Trouble shoot torque valve. Rig up to run in hole with casing. Running in hole to 5155', fill every 10 joints. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY Trey Thrailkill Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Lundale DATE June 11, 2014 DEPTH 9190' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9151' 24 HOUR FOOTAGE 39' CASING INFORMATION 16" @ 108', 10.75" @ 3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9096.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Baker Hughes EZ Case Bit Type EZC506 7040005 6x10 9151' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 202.8 @ 9154' 2.0 @ 9155' 48.0 12.4 FT/HR SURFACE TORQUE 16503 @ 9158' 9849 @ 9151' 13484.1 13729.0 AMPS WEIGHT ON BIT 122 @ 9159' 6 @ 9163' 15.5 20.4 KLBS ROTARY RPM 118 @ 9151' 77 @ 9190' 74.2 77.0 RPM PUMP PRESSURE 2171 @ 9151' 346 @ 9152' 667.3 609.0 PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 95 @ 9151' 22 @ 9162' 42.4 TRIP GAS 122 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 13520 @ 9151' 3671 @ 9162' 7478.7 CONNECTION GAS HIGH ETHANE (C-2) 929 @ 9151' 244 @ 9162' 511.0 AVG PROPANE (C-3) 332 @ 9151' 74 @ 9162' 165.0 CURRENT 25 BUTANE (C-4) 94 @ 9189' 8 @ 9160' 37.3 CURRENT BACKGROUND/AVG 30 PENTANE (C-5) 38 @ 9151' 3 @ 9163' 9.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY HRZ PRESENT LITHOLOGY Siltstone, carbonaceous siltstone DAILY ACTIVITY SUMMARY Cont. RIH T/5175’ MD, circulate SS stage pump up T/300 GPM, 700 PSI, lost 20 BBLS while pumping and gained back 20 after shutting down pump. Cont. RIH W/ 7” CSG F/5175’ MD T/6839’ MD. Circulate SS 6839’ MD, stage up pump T/300 GPM, lost 38 BBLS while pumping and gained back 10 BBLS. Cont. RIH F/6839’ MD T/8358’ MD. Circ. SS @ 8358’ MD. PJSM continue to CBU @ 8358’ MD @ 280 GPM – 1000 PSI. Continue to RIH F/8358’ MD T/8490’ MD. Tight spot at 8490’ MD, worked pipe and regained circulation. Continue to RIH F/8520’ MD wash down T/9151’ MD.CBU @ 2 BPM. PJSM, displaced well @ 7 BPM = 1250 PSI. PJSM, R/U to perform leak off test, pump 13.3 BBLS pressured up T/175 PSI = 12 PPG EMW. R/D test equipment. DRLG F/9151’ MD T/9187’ MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY John Farrell Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Lundale DATE June 12, 2014 DEPTH 9257' PRESENT OPERATION Circulating LCM TIME 24:00 YESTERDAY 9190' 24 HOUR FOOTAGE 67' CASING INFORMATION 16" @ 108', 10.75" @3543 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9096.00' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Baker Hughes EZ Case Bit Type EZC506 7040005 6 x10 9151' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 59.1 @ 9237 0.3 @ 9224 29.8 46.48 FT/HR SURFACE TORQUE 15194 @ 9234 12512 @ 9196 14023.4 13502 AMPS WEIGHT ON BIT 128 @ 9199 2 @ 9237 13.4 122.7 KLBS ROTARY RPM 78 @ 9242 76 @ 9240 77.8 78 RPM PUMP PRESSURE 612 @ 9193 267 @ 9234 495.4 336 PSI DRILLING FLUIDS REPORT DEPTH 9515' MW 11.6 VIS 47 PV 10 YP 14 FL - Gels 7/8/- CL- - FC -/- SOL - SD - OIL -/- MBT - pH 9.3 Ca+ - Alk - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 71 @ 9224 30 @ 9238 45.6 TRIP GAS CUTTING GAS 0 @ 9242 0 @ 9242 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 12117 @ 9224 5130 @ 9238 7180.3 CONNECTION GAS HIGH ETHANE (C-2) 898 @ 9224 363 @ 9201 521.8 AVG PROPANE (C-3) 311 @ 9224 137 @ 9193 189.4 CURRENT BUTANE (C-4) 92 @ 9224 42 @ 9193 58.3 CURRENT BACKGROUND/AVG PENTANE (C-5) 34 @ 9240 13 @ 9193 21.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Stopped drilling due to losses and returns of 50-60 barrels per hour. Losses subsided to about 20 bph with pumps off. Mixed 100 bbls of LCM and diluted mud to 11.5 ppg. Pumped and circulated LCM at 1 barrel per minute. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY Trey Thrailkill Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Reinhardt DATE Jun 13, 2014 DEPTH 9257' PRESENT OPERATION Circulate LCM pill TIME 24:00 YESTERDAY 9257' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 108', 10.75" @ 3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9096.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Baker Hughes EZ Case Bit Type EZC506 7040005 6x10 9151' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9257' MW 10.5 VIS 42 PV 5 YP 16 FL 4 Gels 9/11/12 CL- 500 FC 1/- SOL 9 SD - OIL 1/90 MBT - pH 9.3 Ca+ 80 Alk 0.18 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY CONT CIRC @ 1 BPM with no returns. Shut down pump, reduce ROT T/5 RPM, work string, keep hole full W/TT reduce MW T/11.0 ppg. CONT working CSG, attempt to regain CIRC twice, pumping 2BPM and 1 BPM, no returns. Reduce MW T/10.5 ppg and ESTB CIRC F/CMT job. Circ LCM pill. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY John Farrell Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Reinhardt DATE June 14, 2014 DEPTH 9257' PRESENT OPERATION Laying down 5" drill pipe TIME 2400 YESTERDAY 9257' 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @108' 10.75" @ 3543 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 996.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Baker Hughes EZ Case Bit Type EZC506 7040005 6x10 9151' 9257' 106' 4.1 Cemented in hole TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9257 MW 10.6 VIS 42 PV 10 YP 14 FL 5.5 Gels 8/9/9 CL- 500 FC 1/- SOL 9 SD n/a OIL 1/90 MBT 1.875 pH 8.8 Ca+ 80 Alk 0.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS 108u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Chased mega pill with 10.5 ppg mud with slight returns at 1.5 bpm increased at 2.5. Continued to circulate and condition at 2.5 bpm. Observed 108 units of downtime gas once the pumps were turned on. Monitored well while making up hanger and landing and rigged up cementing equipment. Cemented and pressured up for 5 minutes and bled pressure. Prepared for laying down 5" pipe and rigged up O-A for flush and freeze product.king up hanger and landing and rigged up cementing equipment. Cemented and pressured up. Prepared for laying down 5" drill pipe and rigged up O-A for flush and freeze product. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY Trey Thrailkill Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Reinhardt DATE Jun 15, 2014 DEPTH 9257' PRESENT OPERATION P/U and rack back 4" DP TIME 24:00 YESTERDAY 9257' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 108', 19.75" @ 3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 996.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.13" Smith MDi 513 PDC JJ0069 3x13 9257' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9257' MW 10.5 VIS 44 PV 8 YP 16 FL 5 Gels 9/10/12 CL- 500 FC 1/- SOL 9 SD - OIL 1/90 MBT 1.5 pH 8.6 Ca+ 80 Alk 0.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY LD 5” DP, 5 STNDS HWDP. Flush ANN W/190bbl H2O. Unload pipe shed, CONT LD DP. Spot up Little Red, test lines T/2500 psi, pump 121 bbl Isotherm NT down OA. R/U and successfully test BOP. R/D test equip blow down choke, kill and choke lines. P.U and rack back 4” DP. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY John Farrell Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Reinhardt DATE June 15, 2014 DEPTH 9277' PRESENT OPERATION Drilling Cement TIME 2400 YESTERDAY 9257' 24 HOUR FOOTAGE 20' CASING INFORMATION 16" @108' 10.75" @ 3543' 7" @9248' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9096.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" Smith MDi 513 PDC JJ0069 3x13 9257' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 62.5 @ 9258 1.6 @ 9266 18.9 19.09 FT/HR SURFACE TORQUE 14212 @ 9257 8993 @ 9258 10450.8 9846 AMPS WEIGHT ON BIT 13 @ 9267 3 @ 9258 10.4 8.5 KLBS ROTARY RPM 89 @ 9272 61 @ 9267 77.3 87 RPM PUMP PRESSURE 1974 @ 9272 284 @ 9257 1742.1 1831 PSI DRILLING FLUIDS REPORT DEPTH 9258' MW 10.5 VIS 41 PV 8 YP 21 FL 5.4 Gels 9/10/11 CL- 500 FC 1/- SOL 10 SD N/A OIL 1/89 MBT 3 pH 10.4 Ca+ 100 Alk 0.5 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 62 @ 9267 14 @ 9263 29.4 TRIP GAS CUTTING GAS 0 @ 9277 0 @ 9277 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6343 @ 9265 2641 @ 9261 1746.7 CONNECTION GAS HIGH ETHANE (C-2) 371 @ 9265 159 @ 9263 105.4 AVG PROPANE (C-3) 116 @ 9265 50 @ 9263 33.6 CURRENT 24 BUTANE (C-4) 21 @ 9265 10 @ 9263 6.8 CURRENT BACKGROUND/AVG 12 PENTANE (C-5) 6 @ 9258 1 @ 9265 1.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Make up the BHA and perform rig service. Running in hole to 1,543', SP CONT. single in hole with 4" DP to 7,288'. Wash and ream to 9,150' Circulate and condition. Test casing to 3000 psi for 30 minutes. Begin drilling cement/float equipment and rathole to 9257'. Drilling ahead. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY Trey Thrailkill Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Wall, Reinhardt DATE June 15, 2014 DEPTH 9277' PRESENT OPERATION Drilling Cement TIME 24:00 YESTERDAY 9257' 24 HOUR FOOTAGE 20' CASING INFORMATION 16" @ 108', 10.75" @ 3543' 7" @9248' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9096.77' 74.46 271.93 5937.35' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" Smith MDi 513 PDC JJ0069 3x13 9257' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 62.5 @ 9258 1.6 @ 9266 18.9 19.09 FT/HR SURFACE TORQUE 14212 @ 9257 8993 @ 9258 10450.8 9846 AMPS WEIGHT ON BIT 13 @ 9267 3 @ 9258 10.4 8.5 KLBS ROTARY RPM 89 @ 9272 61 @ 9267 77.3 87 RPM PUMP PRESSURE 1974 @ 9272 284 @ 9257 1742.1 1831 PSI DRILLING FLUIDS REPORT DEPTH 9258' MW 10.5 VIS 41 PV 8 YP 21 FL 5.4 Gels 9/10/11 CL- 500 FC 1/- SOL 10 SD N/A OIL 1/89 MBT 3 pH 10.4 Ca+ 100 Alk 0.5 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 62 @ 9267 14 @ 9263 29.4 TRIP GAS CUTTING GAS 0 @ 9277 0 @ 9277 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6343 @ 9265 2641 @ 9261 1746.7 CONNECTION GAS HIGH ETHANE (C-2) 371 @ 9265 159 @ 9263 105.4 AVG PROPANE (C-3) 116 @ 9265 50 @ 9263 33.6 CURRENT BUTANE (C-4) 21 @ 9265 10 @ 9263 6.8 CURRENT BACKGROUND/AVG 12 PENTANE (C-5) 6 @ 9258 1 @ 9265 1.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Make up the BHA and perform rig service. Running in hole to 1,543', SP CONT. single in hole with 4" DP to 7,288'. Wash and ream to 9,150' Circulate and condition. Test casing to 3000 psi for 30 minutes. Begin drilling cement/float equipment, rathole, and 20' new formation. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY Trey Thrailkill Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Coates, Reinhardt DATE Jun 17, 2014 DEPTH 9663' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9277' 24 HOUR FOOTAGE 386' CASING INFORMATION 16" @ 108', 10.75" @ 23543', 7" @ 9248' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9592.71' 74.01 270.73 6072.8' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" Smith MDi 513 PDC JJ0069 3x13 9257' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 125.0 @ 9568 0.4 @ 9555 45.4 3.36114 FT/HR SURFACE TORQUE 9846 @ 9277 6114 @ 9278 7137.6 7768 AMPS WEIGHT ON BIT 73 @ 9560 3 @ 9349 11.2 12.2 KLBS ROTARY RPM 119 @ 9294 57 @ 9284 97.6 100 RPM PUMP PRESSURE 2674 @ 9358 1831 @ 9277 2484.2 2502 PSI DRILLING FLUIDS REPORT DEPTH 9614' MW 12.5 VIS 51 PV 18 YP 22 FL 2.7 Gels 6/8/11 CL- 500 FC 1/- SOL 17.5 SD 1 OIL 2/81 MBT 4.4 pH 9.7 Ca+ 140 Alk 0.52 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 224 @ 9600 3 @ 9279 40.8 TRIP GAS CUTTING GAS 0 @ 9663 0 @ 9663 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 50694 @ 9600 745 @ 9278 7184.4 CONNECTION GAS HIGH 418 ETHANE (C-2) 2414 @ 9600 35 @ 9278 429.2 AVG 418 PROPANE (C-3) 628 @ 9601 18 @ 9278 138.2 CURRENT 418 BUTANE (C-4) 187 @ 9601 0 @ 9278 48.6 CURRENT BACKGROUND/AVG 25 PENTANE (C-5) 54 @ 9600 0 @ 9293 14.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Kalubik PRESENT LITHOLOGY Carbonaceous siltstone DAILY ACTIVITY SUMMARY Continue drilling 20’ new hole to 9277’ MD. CBU @ 9274’ MD R/U CIRC equip, successful FIT to 16 ppg. Blow down kill and circ lines. Displace well to 12.5 ppg LSND. Circulate and condition, change out shaker screens. Drill to 9663’ MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3235.00 REPORT BY John Farrell Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Coates, Reinhardt DATE June 18, 2014 DEPTH 10127' PRESENT OPERATION Monitor well at shoe TIME 24:00 YESTERDAY 9663' 24 HOUR FOOTAGE 464' CASING INFORMATION 16" @ 108', 10.75" @ 3543', 7" @ 9248' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9592.71' 74.01 270.73 6072.80' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" Smith MDi 513 PDC JJ0069 3x13 9257' 10127' 870' 27.71 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 95.4 @ 10000 1.1 @ 9709 40.0 44.85 FT/HR SURFACE TORQUE 10426 @ 9694 6773 @ 9668 7896.3 8642.0 AMPS WEIGHT ON BIT 14 @ 9796 2 @ 9844 9.8 11.10 KLBS ROTARY RPM 120 @ 9853 96 @ 9746 105.6 102.0 RPM PUMP PRESSURE 2881 @ 10094 2487 @ 9670 2751.3 2849.0 PSI DRILLING FLUIDS REPORT DEPTH 10072' MW 13.1 VIS 53 PV 24 YP 22 FL 2.2 Gels 7/9/11 CL- 500 FC 1/- SOL 20.5 SD tr OIL 1/79 MBT 6 pH 9.5 Ca+ 60 Alk 0.4 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 380 @ 9977 3 @ 9797 98.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 50704 @ 9975 518 @ 9797 12885.7 CONNECTION GAS HIGH 418 ETHANE (C-2) 5251 @ 9975 36 @ 9797 1167.4 AVG 282 PROPANE (C-3) 2083 @ 9975 17 @ 9798 491.4 CURRENT 110 BUTANE (C-4) 656 @ 9975 12 @ 9798 172.1 CURRENT BACKGROUND/AVG PENTANE (C-5) 247 @ 10032 0 @ 9729 63.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9800'-9860'; 9860'-9928'; 9928'-10127' Kuparuk C; Kuparuk A5; Kuparuk A4 58u; 236u; 380u See Show Report #1; See Show Report #2; See Show Report #3 LITHOLOGY PRESENT LITHOLOGY Sand/Sandstone DAILY ACTIVITY SUMMARY Drill to 9910’ SPRs at 9727’ MD & 9830’ MD. Drilling to 10127’ MD. SPRs, SVY on BTM. CBU until clean. Monitor well. Pump OOH to 9182’ MD, ream twice from 9467’ MD to 9372’ MD. CBU at 9182’ MD. Monitor well at shoe, static. Continue to pump OOH to 8519’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3320.00 REPORT BY John Farrell Kuparuk A4 Conoco Phillips Alaska, Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2K-34 REPORT FOR Coates, Reinhardt DATE Jun 19, 2014 DEPTH 10127' PRESENT OPERATION Circulate and Condition Mud TIME 24:00 YESTERDAY 10127' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 108', 10.75" @ 3543', 7" @ 9248' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10065.30' 74.05 271.16 6200.49' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" Smith MDi 513 PDC JJ0069 6x13 9257' 10127' 870' 27.71 0-4-S-BT-X-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10127' MW 13.1 VIS 53 PV 26 YP 22 FL 3 Gels 6/7/7 CL- 500 FC 1/- SOL 21 SD tr OIL 1/78 MBT 6 pH 9.6 Ca+ 68 Alk 0.38 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY CONT POOH T/8519'MD. Increase pump rate T/4BPM to reduce barite settling. CONT POOH T/478'MD. SLB unload nukes. Clean & clear rig floor. L/D tools, P/U CSG equip. Install centralizers. Lube rig & top drive. Run liner per detail. RIH T/ 3041'MD, filling pipe every 10 STDS. CBU cont Circ until MW evens out. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3320.00 REPORT BY John Farrell
