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210-181
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-08A KUPARUK RIV UNIT 1E-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2024 1E-08A 50-029-20496-01-00 210-181-0 N SPT 6193 2101810 1548 500 2500 2430 2420 30 30 30 30 REQVAR P Sully Sullivan 6/3/2024 MIT-T per AIO 2B.065 to show tubing integrity 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-08A Inspection Date: Tubing OA Packer Depth 235 242 243 243IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240604100923 BBL Pumped:0.5 BBL Returned:0.5 Monday, July 22, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 MIT-T AIO 2B.065 James B. Regg Digitally signed by James B. Regg Date: 2024.07.22 15:00:42 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-08A KUPARUK RIV UNIT 1E-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2024 1E-08A 50-029-20496-01-00 210-181-0 N SPT 6193 2101810 1548 540 825 850 850 30 30 30 30 REQVAR P Sully Sullivan 6/3/2024 MIT-IA Test per AIO 2B.065 to show casing integrity 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-08A Inspection Date: Tubing OA Packer Depth 230 2505 2420 2410IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240604101509 BBL Pumped:3.1 BBL Returned:2 Monday, July 22, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 99 9 9 9 AIO 2B.065 James B. Regg Digitally signed by James B. Regg Date: 2024.07.22 14:58:07 -08'00' Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1 2 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1 3 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1 4 1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1 5 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1 6 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1 7 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1 8 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1 9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1 10 1G-04 50-029-20835-00 909359162 Kuparuk River Patch Setting Record Field- Final 11-Jun-24 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39146 T39147 T39148 T39149 T39150 T38151 T39152 T39153 T39153 T39154 181-173 181-065 201-248 223-038 197-184 214-138 210-181 196-096 182-161 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:03:51 -08'00' 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1 210-181 T39152 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-08A KUPARUK RIV UNIT 1E-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-08A 50-029-20496-01-00 210-181-0 N SPT 6193 2101810 1548 30 350 355 355 20 20 20 20 REQVAR P Austin McLeod 6/4/2022 AIO 2B.065. MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-08A Inspection Date: Tubing OA Packer Depth 40 2020 1940 1930IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605184103 BBL Pumped:3.6 BBL Returned:1.5 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:21:59 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-08A KUPARUK RIV UNIT 1E-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-08A 50-029-20496-01-00 210-181-0 N SPT 6193 2101810 1548 30 2040 1970 1960 20 20 20 20 REQVAR P Austin McLeod 6/4/2022 AIO 2B.065. MITT. Plug at 7257'. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-08A Inspection Date: Tubing OA Packer Depth 20 45 45 45IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605183842 BBL Pumped:0.7 BBL Returned:0.7 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 MITT. James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:23:58 -08'00' MEMORANDUM State of Alaska Permit Number: 210-181-0 Alaska Oil and Gas Conservation Commission To: Jim Regg /�/� / �/ P.I. Supervisor ( g ` 411I i5tw DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests Rel Insp Num: ConocoPhilkps Alaska, Inc. Packer Depth Pretest Initial IE -08A FROM: Austin McLeod KUPAR[JK RIV UNIT IE -08A Petroleum Inspector N ' TVD Sre: Inspector Tubing Reviewed By: 2500 ' P.I. Supr z NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IE -08A API Well Number 50-029-20496-01,00 Inspector Name: Austin McLeod Permit Number: 210-181-0 Inspection Date: 6/7/2020 Insp Num: mitSAM200607203435 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ]E-0sA Type Inj N ' TVD 6193 - Tubing 70 2500 ' 2400 2380 PTD 2101810 Type Test SPT Test psi 1548 IA 160 175 175- 175 BBL Pumped: 0.6 'BBL Returned: 0.6 ' OA 15 15 15 - 15 - Interval REQVAR p/F P Notes: 2 year MIT -T as per AIO 2B.065. Monday, June 8, 2020 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor '\� FROM: Austin McLeod Petroleum Inspector NON-CONFIDENTLIL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. LE -08A KUPARUK RIV UNIT 1E -08A Src: Inspector Reviewed By: P.I. Supry :P3L Comm Well Name KUPARUK RIV UNIT 1E -08A API Well Number 50.029-20496-01-00 Inspector Name: Austin McLeod Permit Number: 210-181-0 Inspection Date: 617/2020 , Insp Num: mitSAM200607203712 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IE-08A'Yelnj N�TpD 6193 Tubing 70 425,E2425 - 47F5, PTD ype Test sPr Test psi 1548 IA 140 2500 - BBL Pum,BBL Returned: 2 OA 15 - 1s 15 - 1s IntervalVAR P/F P Notes: 2 year MIT -IA as per AIO 2B.065. Monday, June 8, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 13,2018 TO: Jim Regg s P.I.Supervisor o'y q G1416 SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA,INC. 1E-08A FROM: Adam Earl KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By:�r� P.I.Supry 7W— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-08A API Well Number 50-029-20496-01-00 Inspector Name: Adam Earl Permit Number: 210-181-0 Inspection Date: 6/9/2018 Insp Num: mitAGE180611090529 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-08A Type Inj N TVD [ 6193 Tubing, 1010 ' 1260 ' 1310 - 1310 PTD 2101810 1Type Test SPT Test psi 1548 ' IA 500 2490 ' 2400 - 2385 - BBL Pumped: 2.5 BBL Returned: 1.5 OA 20 _ 30 - 20 • 25 Interval REQVAR P/F P Notes: MIT-IA tested as per AIO 2B.065 to line up Anniversary date ` SCANNED JUN 2 2 Lll1 u Wednesday,June 13,2018 Page 1 of 1 �' MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,June 13,2018 P.I.Supervisor �y 051.6 SUBJECT: Mechanical Integrity Tests ( ( CONOCOPHILLIPS ALASKA,INC. 1E-08A FROM: Adam Earl KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JB- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IE-08A API Well Number 50-029-20496-01-00 Inspector Name: Adam Earl Permit Number: 210-181-0 Inspection Date: 6/9/2018 Insp Num: mitAGE180611085901 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ' 1E-08A -TType Inj N `TVD 6193 Tubing 1380 - 2495 ' 2440 2425 PTD 2101810 Type Test SPTjTest psi 1548 IA 510 510 - 505 505 • BBL Pumped: L 03 ' BBL Returned: 0.3 - OA 20 - 20 - 20 ' 20 - Interval REQVAR P/F 1 P Notes: MIT-T tested as per AIO 2B.065 to line up Anniversary date SCANNED JUN 2 z 1-1)I Wednesday,June 13,2018 Page 1 of 1 V OF Tit • • 4).' (y/,..sa THE STATE Alaska Oil and Gas a ���s ®f® Ll® clv Conservation Commission __ 1 l ✓Vz 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OASY,Pd Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Staff Wells Engineer A7. ConocoPhillips Alaska, Inc. t�N1dED �� � ' PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-08A Permit to Drill Number: 210-181 Sundry Number: 317-520 Dear Mr. Burke: 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, Hollis S. French �l Chair DATED this l day of November, 2017. RBDMS 'NOV 1 3 2017 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 NOV 0 3 2017 1.Type of Request: Abandon LJ Plug Perforations LJ Fracture Stimulate LI Repair Well Li MA S ///t* a i6 shutdown LJ Suspend El El Other Stimulate DPull Tubing ❑ A o ed Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other DAD Acid TrtmnL 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 210-181-0 ' 3.Address: Stratigraphic 6.API Number: ❑ Service ❑✓ . P. O. Box 100360,Anchorage,Alaska 99510 50-029-20496-01 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A r Will planned perforations require a spacing exception? Yes CINo D/ KRU 1E-08A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,AB1-2646 I'M Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,860' • 6,571' ' 7714' 6483' . 3353 Casing Length Size MD TVD Burst Collapse Structural Conductor 48' 16" 80' 80' Surface 2,864' 10-3/4" 2,896' 2705' Intermediate Production 7,537' 7" 7,568' 6395' LinerA 2368' 5-1/2" 7860' 6571' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7645'-7655' - 6441'-6447' 3.500" L-80 7,299' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER ZXP LINER TOP PACKER MD=5492 TVD=4921 PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 MD=6272 TVD=5596 , PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 MD=7058 TVD=6095 • PACKER-BAKER FAB PACKER 45-FA-36 MD=7227 TVD=6193 , SSSV-CAMCO Nipple MD=546 TVD=546 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Q. 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/1/2017 OIL ❑ WINJ ❑ WDSPL LI Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ , GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com Authorized Signature: �./� Date: COMM SSION USE ONLY Contact Phone: (907)265-6097 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31i . 5Jd Plug Integrity ❑ BOP Test LI Mechanical Integrity Test ❑ Location Clearance ❑ Other: ❑ �� [,':)'i 1 R;:i�7 Post Initial Injection MIT Req'd? Yes No R�i;��i�� f , Y .7 �l)I� Spacing Exception Required? Yes ❑ No �' Subsequent Form Required: /0 .4-6 V d22-7 APPROVED BY Approved by: / COMMISSIONE I I Date: ( t \C-1 1 V / `i i ` RJroGhio 'l" Submit Form and 41k 10-403 Revised 4/2017 AeQQQ ap lication is valid for 1 dtltt proval. [n I'M 1'///0- �y �//i7 Attachments in Duplicate \ T �2 ,EGA j� ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska 1E-08 Acid Treatment (10404365) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars, perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to increase injectivity ✓ • Coiled Tubing: Spot 100 bbl of DAD into formation 1. MIRU CT, MU 5 port wash nozzle BHA 2. Begin RIH, enter slotted liner completion at 7262' MD. 3. Continue RIH until end of first liner section at 8325' MD is reached or until CT locks up 4. When CT has reached ultimate depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH at a rate that will allow treatment to be spotted from final depth to 7262' MD (At 8325' MD 100 bbl/1 BPM=100 min & 1063 ft / 100 min=10.5 fpm). Chase the DAD treatment out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 5. After an additional 5 bbl of fluid has been injected behind the treatment POOH 6. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HCl H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal October 3, 2017 1E-08 Well Work Procedure Page 1 of 1 ' n1. - KUP INJ • 1E-08A ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act Btm(ftKB) r, v trap 500292049601 KUPARUK RIVER UNIT INJ 8,422.0 ••• Comment 142S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date DEVIATED-1E-08A,8/31/2015 9:30:20 AM SSSV:NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,260.0 8/28/2014 Rev Reason:PULL PLUG hipshkf 8/31/2015 ' HANGER;24.3 i"�f Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED I rCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)... WULen(I...Grade Top Thread may,SURFACE 10 3/4 9.950 31.8 2395.6 2,704.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(...Wt/Len(I...Grade Top Thread WINDOW A 8 6.000 5,712.0 5,722.0 5,120.5 26.00 L-80 .l�M CONDUCTOR;32.0.110.0 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 30.9 7,568.0 6,394.5 26.00 K-55 BTC NIPPLE;545.8 Casing Description OD(in) ID(in) Top(ftKB( Set Depth(ftKB) Set Depth)T/D(...Wt/Len(I...Grade Top Thread LINER A 51/2 4.950 5,491.6 7,860.0 6,570.8 15.50 L-80 HD-L Liner Details GAS LIFT;2,336.5 inNominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,491.6 4,921.4 28.84 PACKER BAKER ZXP LINER TOP PACKER"ZXPN"w/ 5.500 5.5"Hyd 563 box down,5.50"ID 10'PBR 5,508.1 4,935.7 29.15 HANGER BAKER LINER HANGER"HMC"Liner Hanger 4.890 SURFACE;3r.7-2,895.6--. ' Tubing Strings Tubing Description !String Ma...I ID(in) I Top(ftKB) I Set Depth(ft..1 Set Depth(ND)(...I Wt(INtt) I Grade 'Top Connection GAS LIFT;3,479.7 TUBING 3 1/2 2.992 24.3 7,299.91 6,236.5 9.30 L-80 EUEm8RD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Teel(°) Item Des Com (in) GAS LIFT;4.532.224.3 24.3 0.00 HANGER FMC Gen III TUBING HANGER 3.500 545.8 545.8 0.65 NIPPLE CAMCO 3-1/2""X"NIPPLE w/2.813" 2.813 6,253.5 5,581.2 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3.000 GAS LIFT,5,396.7 i' E 6,256.7 5,583.7 36.20 PBR 80-40 PBR w/special trim OD,3-1/2"EUE box 3.000 6,2703 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 6,271.9 5,595.6 38.90 PACKER 3-1/2"x 5-1/2"BAKER FAB PACKER 45-FA-36 3.000 7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RD4 2.960 - 7,057.8 6,094.7 54.88 PACKER 3-1/2"x 5-1/2"Baker FAB Packer 45-FA-36 3.000 7,070.1 6,101.8 54.90 NIPPLE CAMCO 3-1/2"X-NIPPLE,2.813"EUE 8 Rnd 2.813 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 WINDOW A;5,712.05,722.0 7,226.6 6,192.9 53.35 PACKER BAKER FAB PACKER 45-FA-36 3.000 • 7,266.1.- 6,216.4 53.50 NIPPLE -CAMCO X-NIPPLE w/2.813"profile EUE 8rd pin x pin 2.813 GAS LIFT; W 6,199.8 It: 7,299.0 6,236.0 53.61 SHOE 3-1/2" WIRELINE ENTRY GUIDE 2.960 a Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD( Top Incl SEAL ASSY;6253.5 • Top(ftKB( (ftKB) C) Des Com Run Date ID(in) 7,563.0 6,391.5 52.96 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR 4/4/2011 0.000 PBR;6,256.7 ing WESTERN LATERALS 1E-08AL2&1E-08AL2-01 ANCHOR;6,270.3 7,645.0 6,441.1 52.57 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 PACKER;6.271.9 LATERALS • 7,698.0 6,473.4 52.51 CMT Retainer CMT RETAINER SET IN'A'FOR LATERAL 2/17/2011 0.000 111..1 SIDETRACKS Perforations&Slots Shot Dens • Top(ND) Btm(ND) (shots/f ANCHOR;7,056.1 ;I t Top(ftKB( Btm(ftKB) (ftKB( (ftKB) Zone Date t) Type Com PACKER;7.067.8 -- 7,517.0 7,537.0 6,363.9 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES: illi: 2.5'HSD 2506 PF HMX, • 60 Deg.Phase NIPPLE;7,070.1 7,564.0 7,574.0 6,392.1 6,398.1 2/17/2011 6.0 APERF TUBING PUNCHES: 60 Deg. ha2.5"HSD s6e PF HMX, 11 7,645.0 7,655.0 6,441.1 6,447.2 2/17/2011 6.0 APERF TUBING PUNCHES: MI 2.5"HSD 2506 PF HMX, ANCHOR;7,224.9 1 i 60 Deg.Phase PACKER;7.226.6 a. Cement Squeezes Top(ND) Btm(ND) Top(ftKB( Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 7,047.0 7,645.0 6,088.5 6,441.1 CMT PLUG 2/20/2011 NIPPLE,7,266.1 I. Mandrel Inserts St a I ni on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com SHOE:7,299.0 r 1' 2,336.5 2,231.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 2 3,479.7 3,199.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 APERF;7,517.0-7,537.0-- 3 4,532.2 4,090.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 PRODUCTION;30.9-7.588.0 4 5,396.7 4,838.1 CAMCO -KBMG - 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 APERF;7.564.0.7,574.0 5 6,199.8 5,538.2 CAMCO KGB2-9 1 GAS LIFT DMY BK 0.000 0.0 10/8/2014 WHIPSTOCK;7,563.0 AL2-01 Slotted Lbw; 261.7- ' - Notes:General&Safety 9,570.0 End Date Annotation 8/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 iii SLOTS;7,642.CK86.769.1 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 - WHIPSTOCK;7,645.0 AL1-01 blotted 7.641.08 1/18/2012 NOTE:WAIVERED WELL-PACKER SET TOO HIGH 10.350.0 APERF;7,645.0-7.655.0 CMT Retainer;7,698.0 ,_. LINER A,5,491.6-7,860G . • . §§ / 22;! NI \ \ a II II // Hii §liv 1 ) � \ kli ` 2 { : \ k : j ; ! § . § § )| / [10 IIIni H ! ; I 1 q1 | '7 ;22 71IH I | ( \ \ { / \ Ui \ l \ i / § &/| y \ ` - " ! ,! 2! ll \| !! ` § / \ II ;> 11 ( . . • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission y TO: j Regg ,-)-7 'l DATE: Monday,May 22,2017 P.I.Supervisor � ' —I ZZ`ef 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-08A FROM: Lou Laubenstein KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry lei-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-08A API Well Number 50-029-20496-01-00 Inspector Name: Lou Laubenstein Permit Number: 210-181-0 Inspection Date: 5/14/2017 Insp Num: mitLOL170514141717 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IE-osA Type Inj N .TVD � 6193 - Tubing 1 800 880 - 880 - 880 .' PTD 1 _ 2101810 " Type Test SPT Test psi 1 1548 ' IA 1 1050 2000- 1960_ 1950 1 BBL Pumped: 0.7 - BBL Returned: 0.8 OA % 30 30 ' 30. 30 . Interval REQVAR 1P/F P '�-_—. Notes: MITIA_per AIO 2B.065. SCANNED .:ti 1 1 tri; Monday,May 22,2017 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: _ DATE: Friday,May 19,2017 Jim Regg P.I.Supervisor 1 g l a 4 1 7 ] SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA INC 1E-08A FROM: Lou Laubenstein KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprae— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-08A API Well Number 50-029-20496-01-00 Inspector Name: Lou Laubenstein Permit Number: 210-181-0 Inspection Date: 5/14/2017 Insp Num: mitLOL170514140018 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IE-08A - Type Inj N• TVD 6193 Tubing 770 2030 - 1940 • 1920 - PTD 2101810 ' Type Test SPT Test psi 1548 IA 570 660 675 - 675 - BBL Pumped: 0.3 - BBL Returned: 0.5 - OA 30 30 - 30 - 30 Intervale REQVAR P/F P Notes: MITT per AIO 2B.065 There was a plug set into the tubing at 7261 ft for this test ✓ SCANNED . i_i , 2 p i{' Friday,May 19,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,September 02,2015 P.I.Supervisor e 9/4.II SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-08A FROM: Bob Noble KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, J '/ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-08A API Well Number 50-029-20496-01-00 Inspector Name: Bob Noble Permit Number: 210-181-0 Inspection Date: 8/27/2015 Insp Num: mitRCN150827162653 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-08A , Type Inj N TVD 6193 " Tubing I 650 H 1930 • I 1830 - 1815 - 2loisio TypeSPT psi1548 PTD _ TestTest - IA 263 308 - 315 - 315 - Interval REQVAR P/F P OA 20 20 - 20li 20 - Notes: MIT-T per AIO 2B.065.No required test pressure on AA. Wednesday,September 02,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg lq DATE: Wednesday,September 02,2015 P.I.Supervisor �t7 l -f is SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-08A FROM: Bob Noble KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1.--- ---- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-08A API Well Number 50-029-20496-01-00 Inspector Name: Bob Noble Permit Number: 210-181-0 Inspection Date: 8/27/2015 Insp Num: mitRCN150827163300 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E 08A Type Inj N-TVD 6193 - Tubing 425 - I 640 T 640 - 640 - 2101810 yp Testi SPT psi �. _ __PTD T e Testi Test � 1548 - IA 264 19401875- 1860 - IntervalIREQVAR ,./-' — - P - -- /F P OA 20 20 20 20 - Notes: MIT-IA per AIO 2B.065.No required test pressure on AA. t- SCANNED Wednesday,September 02,2015 Page 1 of 1 O •c F- - SILL U ..- \ co a Ua�a ce cr- ... ���mLL p p U 0) m co 0 F O Z w w co aIll ao w a pa U m F J cCWCC0 0 0 _ =�w�2 �� WZ N a CO _ w 0 -0 N U m O ti C •C U J N 0_u-X p p Cn O Z =LL U L -j fn 0: J _JO o N O a0 ^o (�a.n.p0 to, dp dp o W LLa_z,_ N up Cn-- m c0 u_ in' ELL U N 0 d U U O N U W W U U LL to CO E aa) CD♦- N ~ �0-� t 0< 0_Q F- cn�W m l-0 LU C �y -H Z Z U LL a Z IZFL m Z pZ Z S2Zu)O co u_ 0_ p� v v w c 2 c or Co O0u.�F-00 2U FE-0 Cl") oCZcCcCdd 2W H0 CC al FL � c Q m o m 0 0 > V- V' V 2 G_ a'O 0 O O 0 o N. 0 0 0 0 0 0 Z rn N N N N N N N N N N N N N 0 0 r-ir N 0 0 0 0 0 N N N N CV CV N N Z > J '\-- N N N N N N N N N M M Z E 1 co 4.- '-- a) O a) C c c c c c c c _ i u) Co co a) a) G) a) m N a) a) Co Co �/ Q in C 0 U CO CO �° n a n n 0. 0. n n m m 0 0 0 0 0 0 0 0 0 0 0 0 0 -- Q c «° C4 n N co 10 0 0 co O O O O O N CO Od- o CO CC) 0 CO CO O CO a O O M O ++ I� N- CO CO CO CO CO CO CO 00 CO CO a J 0 Ti co N- N- N- � 1,- N- N- N- N- N- N- N- N J Wa .- _ ,-- _ d C t; O V V N N V V N N O LO Ce 1O M ',7 CSO CSD N- N- (D (D N- LO n N O 0 U) CC) Cf) LO LO tO U) C)) CA Cf) CO tO h N- UJ W Zd i UD Z 8 c p 7 O Q W Z r) 3 J c.0 m '° CL5 15 15 aN C z°I c 0 0 0 0 75 75 1 0 0 s Na) u) a) O N E J CO Cf) ul 1.0 N N III LO N N Cf) E CO U 0 QGcoJ 1— ,- p Z N d COIIJ Ce a > Y 0 a) W a 0 z I O. w Q Y Y .15 Icc n Q 6 z >, . w ww d U p m c _N .� . c ..N NN E J 'O O Co yNO Co (7 N -o a as Z 7 Co c O V Ix CC CC U d' CC CC O O _ m a) O v= C C C r= C C c m m !V a) O f0 C 4 O O O 'rz O• O O C C o^ 6 ca a) 't E > > > > > > > > E E Lo 0:' Z 0 a) a) U c c c U c c c a) a) w U d o 0 0 cn 0 0 Z O Nd N CO co r > O J y y ja C) C) N C[) N O O .Co W O Z IN N N N N Z 0 Q `0 E E. 1 E E ' Z . 2 V ' r N Co w c rn 0 O y w • ms 2. co J J J co O 00N-co W u. a) D a) F J .KY 1 a) 0 I O I- a y �2 a 0 0 o n a o o Ti 0 o 0 o p 0. 2 10 I 3 J 0 W W J W J J R w J J J W o r o + m a T e= '0 m O JI O a3 a) y U N a) m . a �2 0 m m o ce} E m _U a) m ...— CI N O a p L a3 6 • _ ..., E Eu_c" ..-E.-c4a-c) _2 c Or:IL Ocn cn•.C_ y F- O U a5 E /C� C p) V) a) + J N 7�VL. T > >. N Cp t EL L a a) w N E + H m 0 I y c a a0 Eli eco y aco H-O> oU j I' Q N HH U v v v v 2 ZT c a) o iii m Cl) m a) m co E Eco JU U 0 0 0 0 E Cl et Q c P. Cl' o 0 oOVa N- cN- co 0 Z a"' a Om JJ U r r N � y ; a in N. O V o O M co M N Z U N to Cl) W Z CI_ d > V0 coa) 0 Z o Q � Sc a CL N c U U a)O m o 5 r o 0 GG 0 I .-s1 p_ O � E in N U ti U O J Q < CO 11 L 9 L T o. O ' ■ ~ u C o A G Z N CO • CO0 2 W ct T c CO • a) t v+ ce Q 0 I N 1 Q Y of a> Q Z o p U TWO CO 112 o 3 f w of o. E o I E 1 I I"- 0) E CO E L 0 co a a a H H a z E O CO O _1 _�03 0) w Q m r. c 'C o N N N 2 >- 3 N I N 0 a! N- N N E Z U) t/) �pas J a) a' •0 O I J co J N z Q P• '0 U C 7) Z ami U cam• c U 0 U to- c O o i y ami IO 10 O ` , U Q U a T.� E i a Zit' \ O O a7 o L C N 0 0 a 2 ,w � w w J Q 0 ¢a 0 U Os- 02 Ni 47L4,9) ( ___ __ti,e___ iii r 9. '—kk14- T ct_ c__ ,L4 ,� . Ik 0.1 11;11 l .-14.1 :, it7e1( .476, . /--1--) a) �2V11€ 4/ // 'V S Syi waggs p e - i$e<8 ii H ti s h3 N C y T '0 tli R P,5 f0 PO) ® e O °s o Lu VI a 1 a 3a e e° N F "r gi r xe<i III \:' es W...J II S il Ali - tl`t I i_ _0sAL ( g , . L i _ i l - '� Ail - 0) 3 iF —a — 1 ; \..6N LI i \\:\ talr..\\ kg ; o0 m® R »'n o e 23 ti. 3g ( n An "d ` u 8. gym° N uw 4 N v a n Ym- __m n rv_a il 11 S nyb } iry w bib bffb m m$So o7i N �n7k3 11M ommw wP il 11 il X60, ti) g:it.ic ti II 'YnC 11 u :::: mm L f f:14. . ,.lc-J O-T r r "� d ci; till 1 ins< Q 444 4 s ' U aaaaaa !MI V J4wwwww 'bP gw� u, ®fiPE _ iged MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,September 16,2013 TO: Jim Regg r" ) P.I.Supervisor I‹. 7(z-7/13 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-08A FROM: Jeff Turkington KUPARUK RIV UNIT IE-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, t(,2_. NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-08A API Well Number 50-029-20496-01-00 Inspector Name: Jeff Turkington Permit Number: 210-181-0 Inspection Date: 9/8/2013 Insp Num: mitJAT130908171637 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IL 08A Type In;j I N TVD 6193 ' i IA 1496 1563 ' 1575 - r 1575 - Type . !- PTD 2101810 Test,SPT Test; psi 3000 " OA 7 7 7 - 7 Interval REQVAR P/F P i Tubing i 1300 3410 3240 _ '-- 3220 . _ - Notes: MIT-T per AIO 2B.065.0.6 bbl diesel to fill. Monday,September 16,2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,September 16,2013 Jim Regg 607113 P.I.Supervisor I SUBJECT: Mechanical Integrity Tests ( � CONOCOPHILLIPS ALASKA INC 1E-08A FROM: Jeff Turkington KUPARUK RIV UNIT 1E-08A Petroleum Inspector Sre: Inspector Reviewed By': P.I.Supry J6/z— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-08A API Well Number 50-029-20496-01-00 Inspector Name: Jeff Turkington Permit Number: 210-181-0 Inspection Date: 9/8/2013 Insp Num: mitJAT130908171237 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IE-08A , Type Inj N"I TVD 6193 IA i 1520 1 3380 ' 1 3310 -I 3275 -il TyP p 3000 • 6 7 II � 7 f OA RE VAR I _ PTD 2101810 1 e Test SPT Test st' Interval Q P/F P Tubing 1310 1450 1450 1450 ---------------- Notes: MIT-IA per AIO 2B.065. 1.1 bbl diesel to fill. s Monday,September 16,2013 Page 1 of 1 Brooks, Phoebe L (DOA) rib it 210/8/0 From: NSK Problem Well Supv[n1617@conocophillips.com] Sent: Friday, September 13, 2013 11:40 AM To: Brooks, Phoebe L (DOA) Subject: RE: KRU witnessed MIT's performed 09-08-13 Attachments: 1E-08A schematic.pdf; MIT KRU 1E-08A 09-08-13 Revised.xls Attached is the revised MIT form for 1E-08A. I've also included the schematic for reference. Thanks Kelly From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Friday, September 13, 2013 10:52 AM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: KRU witnessed MIT's performed 09-08-13 Kelly, Will you please send me the schematic for 1E-08A(we have a differing packer tvd)? Thanks, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Thursday, September 12, 2013 10:03 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: KRU witnessed MIT's performed 09-08-13 Attached are the MIT forms for the witnessed tests performed on 09/08/13. 1E-08A is waiver compliance 2F-14 had been overdue for its 4 yr because it was shut in at the time of pad testing. It was recently returned to injection on 08/30/13. 3N-13 is an initial test post RWO Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 1 40.4 KUP INJ 1E-08A Cc>nocoPhillips :, Weil Attributes Max Angle&MD TD A ( Wellbore API/UWI Field Name Wellbore Statue Incl("l MD(RKB) Act Btm(ftKB) 500292049601 KUPARUK RIVER UNIT INJ 8,422.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date --' Well Confo:DEVIATED-1E-0eA9/3r10134.26:29PM SSSV:NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 Schematic-Adual Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,712.0 2/9/2011 Rev Reason:SET WRP hipshkf 9/3/2013 HANGER,24 "-"."--"-1' Casing Strings 1 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD).. String Wt...String.. String Top Thrd ICIliCONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED t. Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd :'a SURFACE 103/4 9.950 31.8 2,895.6 2,704.5 45.50 K-55 BTC CONDUCTOR, !° Casing Description String 0... String ID...Top(BBB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 32-80 WINDOW A 8 6.000 5,712.0 5,722.0 5,120.5 26.00 L-80 NIPPLE,546 l Cuing Deeeription Strip 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String g...String Top Thrd PRODUCTION 7 6.276 30.9 7,568.0 6,394.5 26.00 K-55 BTC GAS L , Cuing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 2'IFTa LINER A 51/2 4.950 5,491.6 7,860.0 6,570.8 15.50 L-80 HD-L Liner Details Top Depth (TVD) Top Incl Nomi... S U3R2F 2,8% _ Top(RKB) IR(B) (") Item Description Comment ID(in) IL 5,491.6 4,921.3 28.84 PACKER BAKER ZXP LINER TOP PACKER"ZXPN"w/5.5"Hyd 563 box down, 5.500 GAS LIFT, 5.50"ID 10'PBR 3,d60 inirl IN ar 5,508.1 4,935.7 29.31 HANGER BAKER LINER HANGER"HMC"Liner Hanger 4.890 GAS UFT, Tubing Strings 4532 Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD).,.String Wt...String...String Top Thrd alld6 TUBING 31/2 2.992 24.3 7,299.9 6,236.5 9.30 L-80 EUEmSRD GAS LIFT, Completion Details 5,397 alczTop Depth ler (TVD) Top Incl Nomi... ilLTop(RKB) (6KB) (") Item Description Comment ID(in) 24.3 24.3 0.00 HANGER FMC Gen III TUBING HANGER 3.500 _ 545.8 545.8 0.65 NIPPLE CAMCO 3-12""X"NIPPLE w/2.813" 2.813 6,253.5 5,581.0 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3.000 6,256.7 5,583.6 38.20 PBR 80-40 PBR w/special trim OD,3-112"EUE box 3.000 WINDOW A, 6,270.3 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 5,7125,722 6,271.9 5,595.6 38.90 PACKER 3-1/2"x 5-1/2"BAKER FAB PACKER 45-FA-36 3.000 GAS LIFT, AIL7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RDL 2.960 MIL 7,057.8 6,094.7 54.88 PACKER 3-12"x 5-12"Baker FAB Packer 45-FA-36 3.000 SEAL ASSY, 7,070.1 6,101.8 54.90 NIPPLE CAMCO 3-1/2"X-NIPPLE,2.813"EUE 8 Rnd 2.813 6,253 FOR.6257 1 11 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 ANCHOR,- OWE.6,270 7,226.6 6,192.9 53.35 PACKER BAKER FAB PACKER 45-FA-36 3.000 : PACKER.6,2727,266.1 6,216.4 53.50 NIPPLE CAMCO X-NIPPLE w/2.813"profile EUE 8rd pin x pin 2.813 AIL- 7,299.0 6,236.0 53.61 SHOE 3-1/2"WWIRELINE ENTRY GUIDE 2.960 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth r " (TVD) Top tool , Top(RKB) (RKB) (") Description Comment Run Date ID(In) ANCHOR - 7,271.0 6,219.3 53.51 PLUG 2.69"WEATHERFORD WRP 9/1/2013 0.000 056 PACKER.7. _--' 7,563.0 6,391.5 52.96 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR WESTERN 4/4/2011 0.000 LATERALS 1E-08AL2 8 1E-08AL2-01 NIPPLE 7,070--- - 7,645.0 6,441.2 52.57 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 LATERALS '.,, -, 7,698.0 6,473.4 52.51 CMT Retainer CMT RETAINER SET IN'A'FOR LATERAL SIDETRACKS 2/17/2011 0.000 ANCHOR, Perforations&Slots 225- Shot PACKER,7227 Top(TVD) Btm)TVD) Dens illr.;A Top IRKS)Btm(BBB) (MB) (RKB) Zone Date (oh.-- TYPe Comment ,� NIPPLE.7,268 7,517.0 7,537.0 6,363.9 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"1-180 2506 "`• PF HMX,60 Deg.Phase 7,564.0 7,574.0 6,392.1 6,398.2 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PLUG.7.271PF HMX,60 Deg.Phase 7,645.0 7,655.0 6,441.2 6,447.3 2/172011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 q �,r, PF HMX,60 Deg.Phase • SHOE.7.299 6"•' APERF. L.,. Notes:General&Safety. 7E17-7.537 `�,; PRODUCTION, \� �e- End Date Annotation 1-75F % . 8/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 APER7,564'7.574 w ,`"\A 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 WHIPSTOCK, 7E63 1/18/2012 NOTE:WAIVERED WELL-PACKER SET TOO HIGH CMT PLUG, 7,047 S. WHIPSTOCK, 7,645 APERF, .-.--y, 7,645-7,655 CMT Retainer, �t6 7,696 --- SLOT LL SLOTS, 7.6437,943 - LINER A, j'"' 5,492-7,660 TDryE-06A). "'�' Mandrel Details 7,860 ^gy„ Top Depth Top Port SLOTS, 7,6438,7 __,,R 5... (TVD) Incl OD Valve Latch Size TRO Run SLOTS, - v ' " N...Top MKS) (RKB) Il Make Model (in) 5ery Type Type (in) (psi) Run Date Com... 8,125-8,326LOTS, 1 2,336.5 2,231,6 31.84 CAMCO KBMG 1 GAS LIFT DMY BK 0,000 0.0 7/15/2011 SLOTS, 8,2219,666 AL1-02sloned _ 2 3,479.7 3,199.0 34.15 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 6,209.6,606 3 4,532.2 4,090.4 30.29 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 SLOTS, 8,326$569• 4 5,396.7 4,838.1 28.89 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 SLOTS,1 9,084-9,148 \ 5 6,199.8 5,538.1 35.54 CAMCO KGB2-9 1 GAS LIFT DMY BTM 0.000 0.0 7/16/2011 AL2-01 Stoned Liner, "--":. rrriiii."-ni- SLOTS, .t1,,,,, 9.150.15,350 AL1-01 Stoned , Liner. 7.642-10.3500 WELL LOG TRANSMIT TAL MAY 2 8 2013 AOGCC To: Alaska Oil and Gas Conservation Comm. May 22, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 2 j c-11 RE: TDML Sigma Log: 1E-08 Run Date: 5/21/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com IE-08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20496-01 MDL Sigma Log gm 1 Color Log 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com 1 Date: lT- 1 iJ Signed: ' � Y ) _/�_� - _ - r r-F WELL LOG TRANSMITTAL MAY 10 2013 GC To: Alaska Oil and Gas Conservation Comm. May 2, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 2A0-\-6\ Anchorage, Alaska 99501 '2-25 d\ RE: Injection Profile: 1E-08A Run Date: 4/21/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1E-08A Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20496-01 Injection Profile Log 1 Color Log 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton • Wireline& Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: +7, ‘3 Signed: Ntik,641,4, 6,4 n STATE OF ALASKA j ALAS.,,OIL AND GAS CONSERVATION COMM, .JN REPORT OF SUNDRY WELL OPERATIONS AO(3C0 1.Operations Performed: Abandon r Repair well r Rug Perforations r Perforate rOther -WINJ to WAG Alter Casing r Pull Tubing r Stimulate Frac rWaiver r Time Extension r Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r j 210-181-0 3.Address: 6.API Number: Stratigraphic r Service 17, P. O. Box 100360,Anchorage,Alaska 99510 ' 50-029-20496-01 —00 7.Property Designation(Lease Number): 8.Well Name and Number: - ADL025651 '' 1E-08A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7860 feet Plugs(measured) None true vertical 6571 feet Junk(measured) None Effective Depth measured 7714 feet Packer(measured) 5492, 7058 true vertical 6483 feet (true vertical) 4921,6095 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80 80 0 0 SURFACE 2864 13 2896 2705 0 0 PRODUCTION 7537 7 7568 6395 0 0 LINER A 5492 5.5 7860 6571 0 0 Perforation depth: Measured depth: 7517-7537; 7564-7574;7645-7655 True Vertical Depth: 6364-6376;6392-6398;6441-6447 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7299 MD,6236 TVD Packers&SSSV(type,MD,and ND) PACKER-5-1/2"X 7"BAKER ZXP LINER TOP PACKER"ZXPN"@ 5492 MD and 4921 TVD PACKER-3-1/2"X 5-1/2" BAKER FAB PACKER 45-FA-36 @ 7058 MD and 6095 TVD SSSV-NIPPLE@ 546 MD and546TVD 7M:1 e` 1 1 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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 Subsequent to operation 3077 1158 3355 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Servicer J' Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations X GSTOR r VVINJ r WAG ", —GIN J r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bob Christensen/Darrell Humphrey Email N1139Ca).conocophillips.com Printed Name be D.Christen :n Title NSK Production Engineering Specialist Signature / on / Phone:659-7535 Date 3/2_4/, 3 1714-': ,C9/2 2 Form 10-404 Revised 12/2043BDMS MAR 2 8 2013 /� //' /�3 Submit Original Only �a it/i7Ifb `� (Dw 11/'/13 1E-08A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/24/11 STATE WITNESSED (JOHN CRISP) MIT-T( PASSED) 03/25/12 RIH WITH TMDL PULSE NEUTRON LOGGING TOOLS AND RECORD BASELINE DATA FROM 7300'TO GAS LIFT MANDREL @ 5397' IN PREPORATION FOR MI INJECTION / RETURN LATER TO CHECK FOR GAS MIGRATION 01/31/13 (AC EVAL) MITIA(PASSED) @ 2500 PSI, OC-POT(PASSED), OC-PPPOT(PASSED) @ 2000 PSI 03/07/13 TAGGED TOP OF LINER @ 7261' RKB. MEASURED BHP ( 3288 psi ) @ 7100' RKB. JOB COMPLETE. 03/20/13 Commenced WAG EOR Injection 4 KUP 1E-08A ConocoPhillips , 1 Well Attributes Max Angle&MD TD Alaska.Inc. F.. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(kKB) v, ,,,,enap., 500292049601 KUPARUK RIVER UNIT INJ 7,860.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... Well conrre:DEVIATED-1E-08A,4/sno721o'4s'.35 AM SSSV:NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 Schematic-Actual ' -,- Annotation Depth(kKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,712.0 2/9/2011 Rev Reason:CSG CORRECTION osborl 4/9/2012 HANGER,24 "'"Iw' Casing Strings i Casing Description String 0...TString ID...Top(kKB) Set Depth(f...Sot Depth(TVD).. String Wt String...String Top Thrd CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED Casing Description String 0... SMng ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd i SURFACE 10 3/4 9.950 31.8 2,895.6 2,704.5 45.50 K-55 BTC II Casing Description String 0... String ID...Top MKS) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd WINDOWA 8 6.000 5,712.0 5,722.0 5,120.5 26.00 L-80 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 30.9 7,568.0 6,394.5 26.00 K-55 BTC CONDUCTOR, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String... String Top Thrd 32-80 LINER A 5 1/2 4.950 5,491.6 7,860.0 6,570.8 15.50 L-80 HD-L NIPPLE,546 --- Liner Details Top Depth GAS LIFT. (TVD) Top Incl Nomi... 2,336 Top(ftKB) (ftKB) (°) Item Description Comment ID(In) 5,491.6 4,921.3 28.84 PACKER BAKER ZXP LINER TOP PACKER"ZXPN"w/5.5"Hyd 563 box down, 5.500 5.50"ID 10'PBR 5,508.1 4,935.7 29.19 HANGER 'BAKER LINER HANGER"HMC"Liner Hanger 4.890 SURFACE. J 4\ r ubing Strings ..., 32-2,896 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt. String...String Top Thrd TUBING 31/2 2.992 j 24.3 7,299.9 6,236.5 9.30 L-80 EUEm8RD GAS LIFT, _ Completion Details Top Depth U iiiiii (TVD)480 Top Inst NontL.. Top(RKB) (ftKB) (°) Item Description Comment ID(In) GAS LIFT 24.3 24.3 -0.04 HANGER FMC Gen III TUBING HANGER 3.500 4,53z 545.8 545.8 0.76 NIPPLE CAMCO 3-1/2""X"NIPPLE w/2.813" 2.813 6,253.5 5,581.0 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3.000 GAS LIFT . 6,256.7 5,583.6 38.20 PBR 80-40 PBR w/special trim OD,3-1/2"EUE box 3.000 5,397 - 6,270.3 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 - 6,271.9 5,595.6 38.90 PACKER 3-1/2"x 5-1/2'BAKER FAB PACKER 45-FA-36 3.000 7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RDL 2.960 7,057.8 6,094.7 54.88 PACKER 3-1/2"x 5-1/2"Baker FAB Packer 45-FA-36 3.000 7,070.1 6,101.8 54.90 NIPPLE CAMCO 3-12"X-NIPPLE,2.813"EUE 8Rnd 2.813 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 meIPsroclt; 7,226.6 6,192.9 53.35 PACKER BAKER FAB PACKER 45-FA-36 3.000 5'712 7,266.1 6,216.4 53.50 NIPPLE CAMCO X-NIPPLE w/2813"profile EUE 8rd pin x pin 2.813 WINDOW A, 5.7125,722 7,299.0 6,236.0 53.61 SHOE 3-1/2"WWIRELINE ENTRY GUIDE 2.960 simit GAS LIFT, iDther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) All 6,200 Top Depth (TVD) Top Incl "� Top(kKB) (ftKB) (°) Description Comment Run Date ID(In) SEAL ASSY, 7,563.0 6,391.5 52.92 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR WESTERN 4/4/2011 0.000 6,253 asammamq LATERALS 1E-08AL2&1E-08AL2-01 7,645.0 6,440.8 51.87 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 PBR,5257 `' LATERALS ANCHOR. 8,270 ( 7,698.0 6,475.3 54.64 CMT Retainer CMT RETAINER SET IN'A'FOR LATERAL SIDETRACKS 2/17/2011 0.000 PACKER.6.272 it I illt Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date CO- Type Comment 7,517.0 7,537.0 6,364.0 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PF HMX,60 Deg.Phase 7,564.0 7,574.0 6,392.1 6,398.1 2/172011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 Alt PF HMX,60 Deg.Phase ANCHOR, 7,OR. Mr, 7,645.0 7,655.0 6,440.8 6,447.0 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PACKER,7,058 PF HMX,60 Deg.Phase 11.11. Notes:General&Safety NIPPLE,7070 IL End Date Annotation 8/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 ili iii 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 II1/18/2012 NOTE:WAIVERED WELL-PACKER SET TOO HIGH ANCHOR, �.. 7,225 PACKER,7,227 1 lid NIPPLE,7,266 ury r SHOE,7,299 APERF, 7517-7,537 ?etaiis PRODUCTION, 31-7,568 Top Depth Top Port APERF, (TVD) Incl OD Valve Latch Size TRO Run 7561-7,574 SN Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type lin) (psi)Run Date Co ..m. WHIPSTOCK, 7,563 1 2,336.5 2,231.6 31.84 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 CMT PL 7,047 2 3,479.7 3,199.0 34.20 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/152011 WHIPSTOCK. 7.645\ 3 4,532.2 4,090.4 30.48 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 RF 7,61Si 411 4 5,396.7 4,838.1 28.96 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 5 6,199.8 5,538.0 35.58 CAMCO KGB2-9 1 GAS LIFT DMY BTM 0.000 0.0 7/16/2011 CMT Retainer, 7.998 i LINER A 5,492-7.860 TD(1E-08A), 7,860 2-10—k"6 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 27, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Thermal Multigate Decay Log: 1E-08A Run Date: 3/25/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-08A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20496-01 TMDL Sigma Log 1 Color Log 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 44/0-- Signed: AL-L/3 6.4 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 30, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Pressure/Temperature Log: 1E-08A Run Date: 9/25/2011 & 9/29/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-08A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20496-01 Pressure/Temperature Log 2 Color Logs 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 41146/I-- Signed: WU1 2t0 .4%1 Z�o-L,9 WELL LOG TRANSMITTAL G� To: Alaska Oil and Gas Conservation Comm. November 23, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1E-08A Run Date: 11/18/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-08A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 1.ft t2 Signed: Y14/44:11) .r+ ria4 I C--06A- PT6 itg ztc 1 1co Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, February 28, 2012 2:33 PM �ll� To: 'NSK Well Integrity Proj' Cc: Schwartz, Guy L(DOA) Subject: RE: 1E-08A(210-181) MI injection Test Decision about amending AIO 26.065 to allow MI injection will be handled the same as KRU 1A-04A(PTD 2001940; A10 2B.011). I have reviewed the well records and TIO pressure monitoring data provided monthly per AIO 26.065, including results of MITs witnessed by AOGCC on 11/24/11. KRU 1E-08A(PTD 2101810) has the required mechanical integrity to proceed with the MI test. AOGCC is allowing an 8-week MI injection in KRU 1E-08A,subject to additional time if necessary to gather information in support of the formal request to amend AIO 26.065. Baseline RST Sigma Log must be run prior to commencing MI injection, and after cycled back to water for overlay;a memory injection profile must be run while on MI injection. The test must be discontinued and well wagged back to water or shut in if there is any indication of pressure communication during the MI test. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Regg, James B(DOA) Sent: Thursday, February 02, 2012 9:48 AM To: 'NSK Well Integrity Proj' Subject: RE: 1E-08A(210-181) Have to research this; don't remember how this was done in past and was not involved in 1E request Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: NSK Well Integrity Proj [mailto:N1878conocophillips.com] Sent:Thursday, February 02, 2012 9:34 AM To: Regg, James B (DOA); Schwartz, Guy L(DOA) Subject: FW: 1E-08A(210-181) Jim, Guy, Would either of you be able to address the question below? Thanks MJ 1 • From: NSK Well Integrity Proj Sent: Tuesday, January 10, 2012 6:39 AM To: 'Maunder, Thomas E (DOA)' Subject: RE: 1E-08A (210-181) Tom, ConocoPhillips would like to start the testing and approval process for possible long term MI injection. In similar situations (1A-04A PTD 200-194) a gas detection log was run before and after a short(-12 week) MI cycle. We would like to request approval to do the same with 1 E-08A. What information do we need to supply to gain approval for the test MI cycle? Please Advise MJ Loveland /Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907)659-7043 MJ's Cell (907) 943-1687 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE:Tuesday,December 13,2011 Jim Regg P.I.Supervisor .r1 I Zl/ vZf t SUBJECT:Mechanical Integrity Tests C CONOCOPHILLIPS ALASKA INC 1E-08A FROM: John Crisp KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry:IP/— NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1E-08A API Well Number: 50-029-20496-01-00 Inspector Name: John Crisp Insp Num: mitJCr111125082550 Permit Number: 210-181-0 Inspection Date: 11/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1E-08A. Type Inj. N' TVD 5596 ' IA 260 360 360 360 P.T.D1 2101810• TypeTest SPT Test psi 3000 OA Interval REQVAR p/F P Tubing 760 3023 ' 2854 2823 ' Notes: MIT per MO 2B.065 1.4 bbls pumped for test. Tuesday,December 13,2011 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: '-Jim Regg I /"�, 12('62'Gl / DATE:Tuesday,December 13,2011 P.I.Supervisor ( SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-08A FROM: John Crisp KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1E-08A API Well Number: 50-029-20496-01-00 Inspector Name: John Crisp Insp Num: mitJCrl 11125083220 Permit Number: 210-181-0 Inspection Date: 11/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1E-o8A• Type Inj. N TVD 5596 " IA 375 375 400 400 P.T.D 2101810 TypeTest SPT Test psi 3000 - OA o 0 0 0 Interval REQVAR PAF P " Tubing 2819 3014 2989 2980 Notes: MITT per MO 2B.065..2 bbl pumped for test.Retest for CPAI. Tuesday,December 13,2011 Page 1 of 1 STATE OF ALASKA ALASK IL AND GAS CONSERVATION COMMIE V REPOR1 OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Rug Perforations r Stimulate f Other 170 Convert to Injector Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program f-' Operat.Shutdown r Perforate r Re-enter Suspended Well 1--- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [ Exploratory r - 210-181-0 3.Address: 6.API Number: P. 0. Box 100360,Anchore, Alaska 99510 StStratigraphic r Service ag - 50-029-20496-01 — 0 0 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651 4" —1E-08A 9.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10.Present Well Condition Summary: Total Depth measured 7860 feet Plugs(measured) 7698' true vertical 6571 feet Junk(measured) None Effective Depth measured 7714' feet Packer(measured) 6272, 7058, 7227 true vertical 6483' feet (true vertucal) 5596,6095,6193 Casing Length Size MD ND Burst Collapse CONDUCTOR 48 16 80 80' SURFACE 2864 10.75" 2896 2705' PRODUCTION 7537 7 7568 6543' LINER A 5491 5.5" 7860 6571' RECEIVED Perforation depth: Measured depth: 7517'-7537', 7564'-7574', 7645'-7655' pEC 1 3 2011 True Vertical Depth: 6364'-6376',6392'-6398',6441'-6447' COMMi•ssion g "pit&Gas C°r's. Andt011ige Tubing(size,grade,MD,and ND) 3.5, L-80, 7300 MD,6236 ND Packers&SSSV(type,MD,and ND) PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 6272 MD and 5596 ND PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 7058 MD and 6095 TVD PACKER-BAKER FAB PACKER 45-FA-36 @ 7227 MD and 6193 TVD NIPPLE-CAMCO NIPPLE @ 546 MD and 546 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 183 210 300 1150 179 Subsequent to operation 2261 550 817 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service- r Stratigraphic r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX , GSTOR r WIND ( WAG r GINJ r SUSP r SPLUG r 16.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: 311-294 Contact Christensen/Humphrey Printed Name Robert I Christe -.en Title Prod Eng Specialist Signatureto, 'hone:659-7535 Date / Form 111-404 Revised 10/2010,BDMS DEC 13 2O0F `a (2-/u-0 Submit Original Only r2 1 E-08A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/13/11 MEASURED BHP @ 7100' RKB: 2387 PSI. IN PROGRESS. 07/14/11 BRUSHED & FLUSHED TBG TO 7261' RKB. SET 2.813"XX PLUG @ 7070' RKB. SET CATCHER @ 7070' RKB. IN PROGRESS. 07/15/11 PULLED GLVs @ 2231', 3479', 4532', 5396', 6199' RKB. SET DVs @ 2231', 3479', 4532', 5396' RKB. LOADED WELL WITH INHIB SW& DSL CAP. IN PROGRESS. 07/16/11 SET DV @ 6199' RKB. MITIA 2500 PSI, PASSED. PULLED CATCHER &2.813"XX PLUG @ 7070' RKB. COMPLETE. 07/20/11 Commenced Water Injection • KUP 1 E-08A ConocoPhillips tell Attributes Max Angle&MD TO Wellbore APIIUWI Field Name Well Status Incl(") MD(RKS) Act Btm MKS) • ko„aaP11lt�y 500292049601 KUPARUK RIVER UNIT PROD 7,860.0 Comment 1125(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "' _SSSV:NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 Well Conic:DEVIATED-IE-08A,711712011 8.56:49 AM Schsmaoc-Actual Annotation Depth(18(8) End Date Annotation Last Mod...End Date Last Tag:SLM 7,712.0 2/9/2011 Rev Reason:GLV C/O ninam 7/17/2011 Casing Strings HANGER,24 Casing Description String 0... String ID...Top MKS) Set Depth(I...Set Depth(TVD)... String Wt..String... String Top Thrd L_ CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(/...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 103/4 9.794 31.8 2,895.6 2,704.5 45.50 K-55 BTC Cuing Description String 0... String ID...Top(f8(B) Set Depth(f...Set Depth(TVD)..•String Wt...String... String Top Thrd WINDOW A 8 6.000 5,712.0 5,722.0 5,120.5 26.00 L-80 Cuing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...'String Top Thrd PRODUCTION 7 6.276 30.9 7,568.0 6,394.5 26.00 K-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR, LINER A 51/2 4.871 5,491.6 7,860.0 6,570.8 15.50 L-80 HD-L 3250 NIPPLE,546 111 Liner Details IMO Top Depth (TVD) Top Incl Noml... GAS LIFT. y Top IBI (RKB °) It ) ( em Description Comment ID(in) 2,336 1, 5,491.6 4,921.3 28.84 PBR BAKER ZXP LINER TOP PACKER"ZXPN"w/5.5"Hyd 563 box down, 5.500 I 5.50"ID 10'PBR 5,508.1 4,935.7 29.19'HANGER BAKER LINER HANGER"HMC"Liner Hanger 4.890 SURFACE1 [ L. Tubing Strings 32.2895 Tubing Description String O.. String ID...Top IRKS) Set Depth(f...Set Depth(TVD)...StrIng Wt...String...String Top Thrd TUBING 'String I 2.992 I 24.3 I 7,299.9 I 6,2365 I 9.30 I L-80 I EUEm GAS LIFT 3.680 _{ Completion Details Top Depth ITVD) Top not Nomi... Top(RKB) (",B) I") Item Description Comment ID in) 24.3 24.3 -0.04 HANGER FMC Gen III TUBING HANGER 3.500 cos LIFT 545.8 545.8 0.76 NIPPLE CAMCO 3-112""X"NIPPLE w/2.813" 2.812 4532 - 6,253.5 5,581.0 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3.000 6,256.7 5,583.6 38.20 PBR 80-40 PBR w/special trim OD,3-1/2"EUE box 3.000 GAS LIFT 6,270.3 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 5.397 ,, 6,271.9 5,595.6 38.90 PACKER 3-1/2"x 5-1/2"BAKER FAB PACKER 45-FA-36 3.000 Eli 7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RD4 2.960 7,057.8 6,094.7 54.88 PACKER 3-1/2"x 5-1/2"Baker FAB Packer 45-FA-36 3.000 7,070.1' 6,101.8 54.90 NIPPLE CAMCO 3-1/2"X-NIPPLE,2.813"EUE 8 Rnd 2.813 •MI 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 WHIPSTOCK, 7,226.6 6,192.9 53.35 PACKER BAKER FAB PACKER 45-FA-36 3.000 5.712 _ 7,266.1 6,216.4 53.50 NIPPLE CAMCO X-NIPPLE w/2.813"profile EUE 8rd pin x pin 2.813 WINDOW q 5,712-5,722 7299.01 6,236.0 53.61 SHOE 3-1/2"WW1RELINE ENTRY GUIDE 2.960 Ur GAS LIFT, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 6,200 tlr Top Depth Its (TVD) Top Incl Top(RKB) MB) I") Description Comment Run Data ID Iln) SEAL ASSY, I• 7,563 6,391.5 52.92.WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR WESTERN 4/4/2011 0.000 6,253 - LATERALS 1E-08AL2 8 1E-08AL2-01 PBR,5257 '• 7,645 6,440.8 51.87WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 ANCHOR, I- LATERALS 6,270 I PACKER.6.272 7,698 6,475.3 54.64•CMT Retainer CMT RETAINER SET IN'A'FOR LATERAL SIDETRACKS 2/17/2011 0.000 a In I Perforations&Slots Shot Top(TVD) Btm(TVD) Dena Top(MB) Btm)RKa) IRKB) (RKB) Zone Dab (sh... Type Comment 7,517 7,537' 6,364.0 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PF HMX,60 Deg.Phase 7,564 7,574' 6,392.1' 6,398.1 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PF HMX,60 Deg.Phase ink ANCHOR, 056 ® 7,645 7,6551 6,440.8' 6,447.0 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PACKER,7.058 - PF HMX,60 Deg.Phase MMk i Notes:General&Safety NIPPLE,7.070 W. End Date Annotation I= 8/24/2010 NOTE:View Schematic w/Alaska Sdtematic9.0 MB 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 V ANCHOR, 1� 7,225 PACKER,7,227 -_ i I NIPPLE.7,286 la I SHOE,7,299 APERF. Mandrel Details 7.517-7537 PRODUCTION, Top Depth Top Port 31-7588 (TVD) Incl OD Valve Latch Size TRO Run APERF, Stn Top MKS) MKS) ('I Make Model (In) Sent Type Type (in) (psi) Run Date Com... 7.564-7,574 1 2,336.5 2,231.6 31.84 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 WHIPSTOCK, 7sea 2 3,479.7 3,199.0 34.20 CAMCO'KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 CMT PLUG, 7.047 WHIPSTOCCK,K, 3 4,532.2 4,090.4 30.48 CAMCO'KBMG 1-GAS LIFT DMY BK 0.000 0.0 7/15/2011 7' 4 5,396.7 4,838.1 28.96 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 APERF, 7.645-7,656if 5 6,199.8 5,538.0 35.58 CAMCO'KGB2-9 1 GAS LIFT DMY BTM 0.000 0.0 7/16/2011 CMT Retainer, 1 7,699 LINER A. 5,492-7,880 TD(1 E-0Bly, 7,860 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder,Thomas E(DOA) Sent: Monday, November 21, 2011 12:47 PM To: 'NSK Problem Well Supv'; Regg,James B(DOA) Subject: RE: 1E-08A(210-181)AIO 2B-065 Brent, It is acceptable to conduct the test with the WRP set as you describe. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, November 21, 2011 12:40 PM To: Maunder,Thomas E (DOA); Regg,James B(DOA) Cc: NSK Problem Well Supv Subject: RE: 1E-08A(210-181)AIO 2B-065 Tom, As a follow up to the message below, a WRP has been set @ 7260' MD and passed a pre-witnessed MITT. A witnessed test will be scheduled this week as long as this is an acceptable depth. Following the witnessed test,will ConocoPhillips need to request an amendment to AIO 2B.065 for future testing? Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Pager(907)659-7000 pgr. 909 From: NSK Well Integrity Proj Sent: Monday, October 17, 2011 4:04 PM To: 'Maunder,Thomas E(DOA)' Cc: 'Regg,James B(DOA)'; 'Schwartz, Guy L(DOA)'; NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1E-08A(210-181)AIO 2B-065 Tom, 1E-08A(210-181)failed a State Witnessed MITT on 10/16/11. It passed a pre State Witnessed MITT earlier in the week. After a review of the workover records,a leaking plug at the X nipple @ 7266 is suspected . The well has not been added to the monthly injector report as the test pressures indicate the plug is leaking. However, it will be added to the report if the trouble shooting indicates a tubing leak. Trouble shooting plans include pulling and resetting the plug and/or setting a WRP at—7265 followed by an additional State Witnessed MITT. Please let me know if you have any questions. MJ Loveland/Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office(907)659-7043 MJ's Cell(907)943-1687 11/21/2011 SlialfE ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Robert D. Christensen Production Engineering Specialist C3 ConocoPhillips Alaska, Inc. u P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-08A Sundry Number: 311-294 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of October, 2011. Encl. STATE OF ALASKA ,�( RECEIVED ED • ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 9 2011 • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 11 �� 1.Type of Request Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Fll jP pUVAIptl m sslon Suspend r Rug Perforations r Perforate r Rill Tubing r Aliewilip r Operational Shutdow n r Re-enter Susp.Well r StimulateAlter casingPJ • r r Other:Oil to WAG conversion 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska,Inc. Developmentkff Exploratory ❑ 210-181-0 • 3.Address: 6.API Number. Stratigraphic r Service r P.O.Box 100360,Anchorage,Alaska 99510 50-029-20496-01 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number where ownership or landownership changes: Spacing Exception Required? Yes r No r 1E-08A• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 7860 • 6571 ' 7714' • 6483' . 7698' Casing Length Size MD TVD Burst Collapse CONDUCTOR 96 16 80' 80' SURFACE 2864 13 2896' 2705' PRODUCTION 15106 7 7568' 6395' LINER A 2368 5-1/2" 7860' 6571' WINDOW AL2 6 - 7563' 6391' WINDOW AU 6 - 7643' 6444' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 3.5 L-80 7296 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) NIPPLE MD=546 TVD=546 PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 MD=6272 TVD=5596 PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 MD=7058 TVD=6095 PACKER-BAKER FAB PACKER 45-FA-36 MD=7227 TVD=6193 12.Attachments: Description Summary of Proposal [ 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch r Exploratory r Development r Service n 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/28/2011 Oil r, Gas r WDSPL r Suspended IT 16.Verbal Approval: Date: WINJ IVfGINJ r WAG r! ` Abandoned r Commission Representative: 7h. q.Z4.7/ GSTOR in SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Christensen/Humphrey Printed Name Ro.ert D.Christensen Title: Prod Eng Specialist / jr/ — Signature / Phone:659-7535 Date Commission Use Only Sundry Numb . / Conditions of approval: Notify Commission so that a representative may witness CCC��J"' Plug Integrity r BOP Test t Mechanical Integrity Test ri Location Clearance r � M I T'—l ree w�f J be-i-....- C o ti,...,`n<<_ I-rue-a oma. // // Other. if` .'ova.tLAA „ wA4 Service_ pe.n plc ik-S A a�ii ;h t•s'T�1 i we- Ar, Subsequent Form Required: �`JJ /0 —Yo APPROVED BY 4/7/ Approved by: SDMS ( ` COMMISSIONER THE COMMISSION Date:• :i �� Form 10-403 Revised 1/2010 T 0 4 ' . R I G I N A L 7-.47./1 Submit in Duplicate;I0 .0 1E-08A DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin WAG EOR injection service in Kuparuk well 1E-08A post sidetrack pre-production. Well 1E-08A will provide water and and MI support for Kuparuk A sands to improve sweep efficiency and increase A-sand oil recovery in the 1E-08A pattern. The 10-3/4"Surface casing (2896' and/2705'tvd)was cemented with 1350 sx Fondu and 250 sx AS. The 7" Production casing ( 7568' and/6395'tvd)was cemented with 530 sx Class'G'and 200 sx ASII. The 5-1/2" Liner(5492' and/4922'tvd)was cemented with 247 sx Class"G". The top of Kuparuk C sand was found at 7283' and/6226'tvd. The top of Kuparuk A sand was found at 7638' and/6436'tvd. The Cement Bond Log (01/24/11) performed indicated marginal cement bond below the top of the C sand. The 5-1/2" Liner was perforated and cement squeezed with 88 sx Class'G'. (7517'-7537', 7564'-7574', 7645'- 7655' and/6364'-6376', 6392'-6398', 6441'-6447'tvd) The Cement Bond Log (03/09/11) performed indicates uniform cement bond from the tubing tail located @ 6224'tvd (7279' md)to 6432'tvd (7630' md). The A sand Sidetrack Window(AL2)top is located @ 7563' and/6391'tvd. The A sand Sidetrack Window(AL1)top is located @ 7643 and/6444'tvd. The injection tubing/casing annulus is isolated via a Baker FAB Packer located @ 6272' and/5596'tvd. A MIT-IA was performed to 2600 psi on 08/09/11. Subsequently, a State Witnessed MIT-IA passed on 08/30/11. No (eServeS (e%•e�v /iecess4/ /N S i,�// i/fic�l COsh fie tec( c�i C rie i , Robert Christensen/Darrell Humphrey Production Engineering Specialists. IPPV Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhillips Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 September 25,2011 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska Inc. requests approval to convert KRU Wells 1 E-08A, 08AL 1, 08AL 1-01, 08AL 1-02, AL1-03, 08AL2, and 08AL2-01 from Oil Production service to ✓ WAG EOR Injection service. Theses wells will be used to improve sweep efficiency and increase A sand oil recovery. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips ' Alaska, Inc. for KRU Wells 1E-08A, 08AL 1, 08AL 1-01, 08AL 1-02, AL1-03, 08AL2, and 08AL2-01 (PTD 210-181-0, 211-019-0, 211-020-0, 211-021-0, 211-044-0, 211-022- 0, 211-023-0). If you have any questions regarding this matter, please contact myself or Darrell R. !, Humphrey at 659-7535. Sin erely, 4 Robert D. Christensen Attachments Sundry application RADIAL CEMENT `' HALLIBURTON BOND LOG Company ConocoPhillips, Alaska Inc. 1'i i , 'i wen 1 E-08 7 1'7�4K r N Q Field Kuparuk River Unit , D County North Slope State Alaska tri g s �•— `0 API No.: 50-029-20496-01 Sery#: 8022478 Other Services - n Location: 1013' FSL&629' FEL U C -- d -C O w 7 0 U r Y Z N/A T C d 8 '- LT c8 Sec: 16 TWP:11 N Rge: 10E _ Permanent Datum GROUND LEVEL Elevation 70' Elevation Log Measured From K.B. , 28 Ft.above perm.datum KB. 98' ' D.F. 97' Dulling Measured From K.B. G.L. 70' ' Date @ Time Logged 3-9-2011 1900 Type Fluid in Hole BRINE Run No. ONE Density of Fluid N/A Depth-Duller 7643' Fluid Level FULL • ` I Depth-Logger 7643' Cement Top Est.Logged 7279' Bottom-Logged Interval 7632' Equipment/Location 7519 / KUPARUK Top-Log Interval 7120' Recorded by J.CONDIO Max.Recorded Temp. N/A Wthessed by E. 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I I . f KM PAY CI-613 r _ i ' r A L I „e ' ce e.' �' _J 5 Ij I � _ (lS -. I 0 6FS,PERK STATUS DEPTH FEET 41 cs r} C3 ' ey a 4-3, �� 4 `� p "? o tl rillr40,411, V ' Inr IF I —____-__ ,_._.-___-- t ___I —._ pt 2 o a --...'� ,..� 11'x rA.-------,4M-11 - �_ .zt j- THROW F) I FAULT 2(0-( 81 Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 26, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc.requests approval to commence operations into Kuparuk well 1E-08A(PTD 210-181-0). This request is pursuant to Area Injection Order No. 2A, Rule 9 Administrative Approval. Kuparuk well 1 E-08A(PTD 210-181-0) was side tracked and completed with a packer that does not meet construction requirements in 20 AAC 25.412 (b). Pressure testing of tubing and casing strings indicates the well has competent mechanical integrity and can be safely operated. Three barriers have been defined that will prevent an inadvertent release and confine fluids to the approved zones. The attached Technical Justification includes a proposed operating and monitoring plan. Daily monitoring of the wellhead and casing mechanical integrity tests are proposed to verify the well continues to be safe to operate. Should observations or tests indicate a compromise of well integrity the well will be shut-in and the AGOCC notified. There is no source of underground drinking water in this area to be endangered by this proposal. If you need additional information, please contact myself or Martin Walters at 659-7043, or Brent Rogers/Kelly Lyons at 659-7224. Sincerely, MJ Love and (' Well Integrity Supervisor ConocoPhillips Alaska Inc. Attachments ConocoPhillips Alaska,Inc. Kuparuk Well 1E-08A (PTD 210-181-0) Technical Justification for Administrative Relief Request Proposal ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request for an exception of 20 AAC 25.412 (b) well construction standards for Kuparuk injection well 1E-08A which requires packer setting depth a maximum of 200 ft. MD above the top perforations. Well History and Status Kuparuk River Unit well 1E-08 (PTD 180-081) was originally completed in October 1980 as a producing well. In May 1990 the well was converted to an injection well. In January 2011 the well was rotary sidetracked in preparation for a CTD multi lateral sidetrack and re-named 1E- 08A. The well was converted back to a producing (development)well during the permitting process for the sidetrack. Paperwork is currently being submitted to convert the well back to WAG injection. The completion with the rotary sidetrack includes a packer that was set at 7227' MD (6193' TVD). The top of the perforated zone in the well is 7517' MD (6364' TVD). As per 20 AAC 25.412 (b),the completion configuration does not meet the 200' maximum distance from the packer to the injection zone. The distance between the packer and perforations is 290' MD (171' TVD) from the bottom packer. A State witnessed MITIA passed on 08/30/11. A temperature profile was run on 09/24/11 to establish a base line for zonal isolation during future injection. An MITT was also performed on the Doyon 141 rig,prior to perforating,to 3500 psi that passed on 01/29/11. Barrier and Hazard Evaluation Tubing: The 3.5", 9.3#L-80 tubing has integrity to the top packer @ 6272' MD based on the passing MITIA on 08/30/11 and below the top packer based on the MITT performed by the rig on 01/29/11. Production casing:The 7"26#K-55 production casing has integrity to the top packer @ 6272' MD based on the passing MITIA test on 08/30/11 described above. Surface casing: The well is completed with 10.75"45.5#K-55 surface casing with an internal yield pressure rating of 3580 psi. The surface casing is set at 2896' MD (2705' TVD). Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier:The production casing is the secondary barrier should the tubing fail. Third barrier: The surface casing and cement shoe will act as a third barrier should the first two barriers have failures. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily NSK Problem Well Supervisor 9/26/2011 monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut-in of the well. Proposed Operating and Monitoring Plan 1. Approve service for water and gas injection; 2. Perfouui a temperature profile after the well has been on injection and thermally stable to demonstrate proper zonal isolation. 3. Perform MIT-IA at 2-year frequency to verify tubing and production casing have not developed communication problems; 4. Notify the AOGCC should MIT test results, injection rates or wellhead pressures indicate annular communication problems have developed. L. /►4IT - he-fvre7.�• � , -1-41.‘/ Placing the well on the Monthly Failed MIT Report to the AOGCC is not proposed at this time. The well currently has no compromised mechanical condition to warrant additional reporting. NSK Problem Well Supervisor 9/26/2011 2 KU P 1 E-08A ConocoPhillipsWell Attributes Max Angie&MD ID At.t,t,,,in,., Wellbore APINWI Field Name Walt Status Inet(") MD OMB) Act Sim(tIKB) eurpc,,,,,a 500292049601. KUPARUK RIVER UNIT PROD 7,860.0 _ Comment HES(ppm) Date Annotation End Date KB-Ord(n) Rig Release Date Weil Crone,G=HATED-1E-1E-06A.71 S17/2011 0 5 6.49 AM -,SSSV:NIPPLE I Last WO: I 1/28/2011 38.99 10/28/1980 Schemale•Actual Annotation Depth 1111551 End Date Annotation Last Mod,.,End Date Last Tag:SLM 7,712.0 2/9/2011 Rev Reason:GLV C/O ninam 7/17/2011 MANGER.24 4: ..e Casing Strings'. - III Casing Description String 0... String 10_.Top(tlKe) Set Depth(1._Set Dap\t(TVD)_.String WL..String...String lap TMtl CONDUCTOR l 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED Casing Description String 0... String lD._Top(ttKB) Set Depth(L.Set Depth(153)...String WE..String._String Top Thrd SURFACE 103/4 9.794 31.8 2,895.6 2,704,5 45.50 K-55 BTC :s,•_, 7f'" Casing Deteription String0... String ID._Top(KKB) Sat Oeplh(1...Set Depth(TVO)...String WL..String...Siring Top Thrd WINDOWA 8 6.000 5,712.0 5,722.0 5,120.5 26.00 LA0 iiioii-is.-:' a.o'a Casing Description String A_, String ID...Top(188) Sat Depth(L,.Set Depth(TVD)_.String WL.String_Siring Top Thrd PRODUCTION 7 6,276 30.9 7,568.0 6,394.5 26.00 K-55 BTC Casing Description String D_. String ID_.Top 0068) Set Depth(L.Set Depth(TVD)_.Siring WL.String...String Top Thrd CONDUCTORin LINERA 51/2 4.871 5,491.6 7,860.0 6,570.8 15.50 L-60 HD-L 32.50 NIPPLE.546 Linea'Details Top Depth (TVD) 1091001 Notal... GAS LIFT- , Top(1108) IRKS( (") Item Description Comment ID(in)ZX 1136 5,491.6 4,921.3 28.84 PBR BAKER ZXP LINER TOP PACKER" PN"w/5.5"Hyd 563 box down, 5.500 5.50"1010'PBR i i 5,508.1 4,935.7 29.19 HANGER BAKER LINER HANGER"HMC"Liner Hanger 4.890 SURPeCT. Tubing Strings JZ2A96 Toting Deaerlpson String 0_. tang ID...lion( B) Set Depth(L.. et Depth(TVD)_.String W .Siring._String Top Thrd TUBING 31/2 j 2,992 I [MM 24.3 l 7,299.9 6,236.5 IL 9.30 I L-80 I EUEm DAs LIFT, 6 Co6lpietion Details - - ' Top Depth "i (ND) Top loot hotel... Top(71X8) (5001 C) Item Description Comment ID(in) 24.3 24.3 -0.04 HANGER FMC Gen III TUBING HANGER 3.500 GAS UFT, 545.8 545.8 0.76 NIPPLE CAMCO 3-112""X"NIPPLE w/2.813" 2.812 _ 4.5226,253.5 5,581.0 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3,000 ms's 6,256.7 5,583.6 3820 PBR 80-40 PBR w/speaal tern OD,3-1/2 EUE box 3.000 GAS UFT, 6,270.3 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 5.397AL WE 17 6,271.9 5,595.6 38.90 PACKER 3-1/2"x5-1/2"BAKER FAB PACKER 45-FA-36 3.000 MD 7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RDL 2.960 7,057.8 6,094.7 54.88 PACKER 3.112x5-172Baker FAB Packec45,FA=36 3.000 7,070.1 6,101.8 54.90 NIPPLE CAMCO 3-1/2'X-NIPPLE,2.813"EUE 8 Rod 2.813 MI` El 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 wwPSIDCII. 7,226.6 6,192.9 5135 PACKER BAKER FAB PACKER 45-FA-36 3.000 5,112 7,266.1 6,216.4 53.50 NIPPLE CAMCO X-NIPPLE w/2.813'profile EUE 8rd pin x pin 2-813 WIDOW A 5.7125,722rs 7,299,0 6,236.0 53.61 SHOE 3-1/2"WWIRELINE ENTRY GUIDE 2.960 GAS LIFT, Other In Hole(SNlellne:retrievable plugs,valves,pumps,fish,etc.) 5,220 Top Depth 11201 Top Ind we Top OMB) Mial P) Description Comment Run Date ID(In) SEAL ASSY. 7,563. 6,391,5 52.92 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR WESTERN 4/4/2011 0.000 5.255 LATERALS 1E-08AL2&1E-0BAL2-01 '. Pgtt,ga' 7.645 6,440.8 51.87 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 ANCHOR i LATERALS 6,270 i1 PACKER,6.272 7,698 6,475.3 54.64 CMT Retainer CMT RETAINER SET IN'A'FOR LATERAL SIDETRACKS 2/17/2011 0.000 BF Perforations&Slots -, Shot Top(T6D) Bim(TVD) Den: Top IRKS)81m(MB) Imo) (588) Zone Dote B.h„- Typo Comment 7,517 7,537 6,364.0 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 • PF HMX,60 Deg.Phase 7,564 7.574 6,392.1 6.398.1 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PF HMX,60 Deg.Phase ANCHOR. 7.056 - 7,645 7,655 6,440.8 6,447.0 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 . PACKER,7,055 PF HMX,60 Deg.Phase Notes:General&Safety NIPPLE.7.070 MIL End Date I Annotation fir, 8/24/2010 I NOTE:View Schematic w/Alaska Sdtematic9.0 4/20/2011 (NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 ANCHOR. 7.225 PACKER.7.227 _ - NIPPLE.7;265 SHOE,7299 APERF. Mandrel Details 7,517-7,53737Top Depth Top Port PRODUCTION, 11001 Inel Sloe 31-.5E6 OD Wee latch TRO Run APERF. Sin Top(ItKB) 15101 ("I Make Model 111 Ser. Type Type ON (Pei) Run Date Com._ 156/-1.94 WHIPSTOCK, 1 2,336.5 2,231.6 31.64 CAMCO KBMG 1 GAS LIFT DMY BK 0,000 0.0 7/15/2011 7,563 GMT PLUG. 2 3,479.7 3,199.0 34.20 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 ' OCR - - WHIPS70CK 3 4,532.2 4,090.4 30.48 CAMCO KBMG 1 GAS.LIFT DMY BK 0.000 0.0 7/152011 ' 7.645 \ APERF,RF, 4 5,396.7 4,838.1 28.96 CAMCO KBMG 1 GAS LIFT DMY BK (L000 0.0 7/1512011 7.64.1653 5 6,199.8 5,538.0 35.58 CAMCO KGB2-9 1 GAS LIFT DMY BTM 0.000 0.0 7/16/2011 CMT Retainer, L.. 7,695 LINER A • 5.492.7 5A TO liE-0DA), 7660 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(otalaska.gov; doa.aoocc.prudhoe.bay@alaska.gov: phoebe.brooksaalaska.gmc tom.maunder(5)alaska.gov OPERATOR: ConocoPhillips Inc. FIELD 1 UNIT I PAD: Kuparuk/KRU/1 E DATE: 08/30/11 OPERATOR REP: Mouser/Colee-AES AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 MM. Well 1E-08A Type In). W TVD 5,596' Tubing 1,500 1.550 1,550 1,550 Interval I P.T.D.2101810 Type test P Test psi 1500 Casing 150 2,600 2,530 2,510 P/F P Notes: OA 0 0 0 0 Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing _ P/F Notes: OA Well Type Inj. NO Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj, TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Wel Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring 1=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT KRU 1E-oaA05-30-l1.ws MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday,September 07,2011 TO: Jim Regg CIG P.I.Supervisor �e&!� (( t(i/ SUBJECT:Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 1E-08A FROM: Jeff Jones KUPARUK RIV UNIT 1E-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry SG(-- NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1E-08A API Well Number: 50-029-20496-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ110906085938 Permit Number: 210-181-0 Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j IE-08A "Type Inj. i{ W' TVD 5596 j IA T 190 1 2600 - 2530 1 2510 • P.T.D� 2101810 'TypeTest SPT Test psi Boo , OA o 0 0 0 Interval INITAL -- P/F P , Tubing i 1500 I 1550 j 1550 1550 Notes: 2.5 BBLS diesel pumped. 1 well inspected;no exceptions noted. Wednesday,September 07,2011 Page 1 of 1 sifaaLA\ LAsEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.065 AMENDED Ms. M. J. Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 RE: Kuparuk River Unit 1E-08A (210-181) Request for Administrative Approval Dear Ms. Loveland: On September 26, 2011 ConocoPhillips Alaska, Inc (CPAI) requested an administrative approval under Rule 9 of Area Injection Order (AIO) 2B to allow continued water injection in Kuparuk River Unit (KRU) well 1E-08A (PTD 210-181). The Alaska Oil and Gas Conservation Commission (AOGCC) GRANTS CPAI's request for WATER ONLY service, as detailed below. 1E-08A is a redrill of 1E-08. The new bottom-hole location was accessed by plugging the original well and exiting the production casing at about 5712' measured depth (md) and drilling new hole to 9160' md. The 5-1/2" liner got stuck off bottom while running and was set from 5491' — 7880' md. It was not possible to conventionally cement the liner and the well was completed with 2 packers in the liner to isolate squeeze perforations. The liner does have required formation isolation as evidenced by the bond log and the well passed a witnessed MIT- IA on August 30, 2011. However since the upper packer is set at—6257', some 1260' above the top perforation, 1E-08A does not meet the requirements of 20 AAC 25.412 (b) for an injection well which is required to be equipped with a packer set not more than 200' measured depth above the top of the perforations. The purpose of this requirement is to ensure that the injection string can be monitored throughout its length for possible leakage. As constructed, 1260' of this wellbore cannot be monitored. Where fresh water is not affected, 20 AAC 25.450 gives the AOGCC authority to approve less stringent well construction and integrity requirements. For wells similarly constructed, the AOGCC has exercised this discretionary authority and approved injection operations with the fluid limited to water only. CPAI has provided pressure test information using water that demonstrates that the tubing string and the production casing/liner combination do have integrity. Accordingly, the AOGCC believes that the well's condition will not result in an increased risk of movement of fluids outside the injection zone. AIO 2B.065 October 4,2011 Page 2 of 2 Per Rule 9 of Area Injection Order 2B, the AOGCC hereby grants CPAI's September 26, 2011 request to continue injection in KRU 1E-08A on the following conditions: 1. Injection is limited to WATER ONLY. CPAI may apply by Form 10-403 to perform diagnostic testing to qualify the well for MI; 2. CPAI shall perform a mechanical integrity test of the tubing/liner string ("MIT-T") every 2 years by employing the nipple profile at 8533' and to demonstrate continued integrity of the injection string; 3. CPAI shall perform a mechanical integrity test of the inner annulus ("MIT-IA") every 2 years to demonstrate continued integrity of production casing; 4. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; 6. Monthly reporting of daily rate and pressures is not required since this well do vNo a separate production casing string and does not demonstrate integrity loss. e DONE at Anchorage,Alaska an s sated I cto'er 4,2011. cAllii l" � `"ivo Daniel T. Seamount, Jr. e" . l 1 orman Cathy '. Foerster ETON Chair, Commissioner Commi ,io -r Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. Refer to the main well file, 1E-08A(210-181), for information regarding this matter. 211-019 1 E-08AL 1 211-020 1 E-08AL 1-01 211-021 1 E-08AL 1-02 211-022 1 E-08AL2 211-023 1 E-08AL2-01 211-044 1 E-08AL1-03 From: Maunder, Thomas E (DOA) Sent: Monday, September 19, 2011 12:36 PM To: 'NSK Problem Well Supv'; 'NSK Well Integrity Proj'; 'Alvord, Chip'; Cawvey, Von; 'Gantt, Lamar L' Cc: Schwartz, Guy L (DOA); Foerster, Catherine P (DOA); Ballantine, Tab A (LAW) Subject: RE: 1E-08A (PTD 210-181) Request to WAG to MI in prep for AA submission 09-17-11 Importance: High All, I received this request and in the course of reviewing the file have determined the following. 1. A 407 was filed 2/4/11 documenting the work accomplished with Doyon 141 to set up the well for a coil drilling work. 2. The status was listed as "oil" however this was changed to"suspended" which is correct since additional work was needed before the well would be capable of producing or injecting. 3. WL/WL work was begun 2/9/11 with CT operations following to drill the 6 laterals/spokes in March and April 2011. The CT work was completed about April 20 and the 407s for those penetrations were filed with the status of 1-oil. 3. A 404 was filed by the Production Engineer Specialist on May 4 changing the well status of 1E-08A from suspended to 1-oil. 4. Our production record shows the well complex produced 28 days in May and 25 days in June. It further shows the well complex has injected water for 12 days in July. August information has not yet been posted. Regulations require that an operator obtain approval from the Commission to convert a well from development to service prior to initiating injection. The Commission has no record of any Form 403 being filed to convert any of the penetrations to service. Any injection that has occurred is not authorized. Commissioner Foerster has been apprised of this matter and she has directed that the following be communicated to you: Pending resolution of this matter, CPAI is directed to cease injection into 1E-08A and secure the well appropriately. At your earliest convenience, prior to September 23, you should contact me or Guy Schwartz to arrange a meeting to discuss this matter. The Commission reserves the right to pursue an enforcement action in this matter. Please keep Guy and me apprised of CPAI's work accomplished to comply with the Commissioner's directive. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, September 17, 2011 12:44 PM To: Maunder, Thomas E (DOA) Subject: 1E-08A (PTD 210-181) Request to WAG to MI in prep for AA submission 09-17-11 Tom, ConocoPhillips requests permission to WAG 1E-08A(PTD 210-181)to MI in order to run diagnostics before applying for an AA. This well has a high packer and we need to confirm that no out-of-zone injection takes place while on gas. Instead of first applying for a water-only AA and then needing to amend after we get gas tests, I thought it would be expedient to conduct the MI tests first before requesting an AA. A passing, witnessed MITIA was performed on 8-30- 11. I'm not sure if you were sent the CBL data, so I've attached another copy to help base your decision. We still plan to run the same diagnostic program as was done on 1A-04A: 1. getting a baseline RST while on water, 2. putting the well on MI and getting an IPROF, 3. wagging back to water and getting a follow-up RST to look for residual gas. Thanks Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 STATE OF ALASKA ALASK/ .AND GAS CONSERVATION COMMISSI , REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r RugFe'rforations 17 Stimulate r- Other 1"'" Aker Casing r Pull Tubing r Fbrforate New Fbol r Waiver r Time Extension r Change Approved Rogram r Operat.Shutdow n r Perforate r Re-enter Suspended Well r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development go Exploratory r - 210-181-0 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 ' 50-029-20496-01—00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL?5651 ' —1E-08A 9.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10.Present Well Condition Summary: Total Depth measured 7860 feet Plugs(measured) 7698 true vertical 6571 feet Junk(measured) None Effective Depth measured 7720 feet Packer(measured) 5492',6272',7058',7227' true vertical 6493' feet (true vertucal) 4921', 5596',6095',6193' Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80 80' SURFACE 2864 10.75" 2896 2705' PRODUCTION 5693 7 5725 5124' LINER A 5491 5.5" 7860 6570' RECEIVED' Perforation depth: Measured depth: 7517-7537',7564'-7574', 7645'-7655' ' N 2011 True Vertical Depth: 6364'-6376',6392'-6398',6441'-6447' Alaska Oil & GPA Cage.Commission Tubing(size,grade,MD,and ND) 3.5, L-80, 7299 MD,6236 TVD .'. G',-,1r d f3 Packers&SSSV(type,MD,and ND) PACKER-BAKER ZXP LINER TOP PACKER @ 5492'MD and 4921'ND PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 6272 MD and 5596 TVD PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 7058 MD and 6095 ND PACKER-BAKER FAB PACKER 45-FA-36 @ 7227 MD and 6193 ND NIPPLE-CAMCO 3-1/2""X"NIPPLE w/2.813"@ 546 MD and 546 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 12. 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 776 1301 1350 -- 191 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 " Service r Stratigraphic IT 15.Well Status after work: -oil p' Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 16.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: 311-028 Contact Jill Lona a. 263-4093 Printed Name Jill Long Title Wells Engineer i�7' Signature Phone:263-4093 Date Form 10-404 vised 10/2010 BDMS JUN 0 8 ZQ G.9.iubmit Original Only 1 E-08A Well Work Summary DATE SUMMARY 2/9/11 PULL BPV, DRIFT TBG TO 2.78", __JULD NOT GET PAST 6985'SLM, RAN B._-SH AND 2.1" G RING TO TAG @ 7712' SLM. IN PROGRESS. 2/10/11 SET CATCHER @ 6232' SLM, REPLACE SOV @ 6199' RKB W/DMY VLV, PULL CATCHER, DRIFT TO 2.77"TO 7655' SLM, PERMORM PASSING 2500 PSI MIT-IA. IN PROGRESS. 2/11/11 RUN DUMMY WHIPSTOCK TO 7670' SLM. NO OBSTRUCTIONS. READY FOR E-LINE. 2/12/11 ATTEMPT TO PERFORM GR/CCL CORRELATION LOG AND PERFORATE. DELAYED START, HAD 0- RING FAILURE DURING PT. LAYDOWN TOOLS FOR NIGHT, RESTART IN AM. 2/17/11 LOGGED GR-CCL FROM CEMENT RETAINER TO 6000' ELM. CEMENT RETAINER TAGGED AT 7698' ELM. PERFORATED 3 INTERVALS, 7645'-7655', 7564'-7574', AND 7517'-7537' USING 2.5" HSD 2506 PF HMX, 6 SPF, 60 DEG PHASING. SET 3.5"X 5.5" BAKER THRU TUBING WHIPSTOCK AT 18.9 DEG RHS. TOWS AT 7645', BOWS AT 7658'. 2 RA TAGS INSTALLED IN WHIPSTOCK. RA TAGS 7.35' FROM TOWS AT 7652.35' ELM. RDMO, RU LRS FOR INJECTIVITY TEST. PUMPED DIESEL: 0.5 BPM AT 1600 PSI, 1 BPM AT 2150 PSI, AND 1.5 BPM AT 2600 PSI. PUMP REPORT IN ATTACHMENTS. 2/19/11 RESTART TOMORROW DUE TO PROBLEMS GETTING RIGGED UP AND PRESSURE TESTED. 2/20/11 PUMPED 15BBLS NEAT CEMENT(15.8PPG). LAYED IN FROM 7640FT CTMD TO 6750FT CTMD, PERFORMED 8 HESITATION SQUEEZES, PUSHED 5.5 BBLS INTO PERFS, DROPPED BALL, RIH, TAGGED CEMENT AT 7171T CTMD, UNABLE TO WASH PAST 7171 FT CTMD, WASHED TUBING THROUGHLY, FP WELL, BACK TOMORROW TO MILL TOP OF CEMENT TO TUBING TAIL, IN PROGRESS 2/21/11 MILL CEMENT FROM HRD TAG Ccs 6900 CTMD TO 7047 CTMD W/2.69 BI CENTER BIT, TERMINATE JOB DUE TO PHASE II CONDITIONS, FP WELL , IN PROGRESS 2/22/11 TAGGED UP @ 4516' CTMD W/2.80" PARABOLIC DIAMOND SPEED MILL. PUMP AT MIN. RATE&GOT BY EASY. ROTATE MILL WHILE RIH, HARD STALL @ 6999' CTMD. MAKE IT TO TO 7008' CTMD, PROGRESS SLOW W/ALOT OVER PULLS. FREEZE PROTECT THE WELL, RACK BACK FOR THE NIGHT, JOB IN PROGRESS. 2/23/11 MILLING JOB SUSPENDED. PERFORM WEEKLY BOPE TEST. RIG OFF THE WELL BUT UNABLE TO LAY DOWN MAST DUE TO HIGH WINDS. b"\‘`g'SQ-kS klt\€06,Cc '.3oc ao k Pc - C71)1) W o 1`t4"- /-,k, `!,L- t �`'\ KU P 1 E-08A Con0coPhiiiips $ Well Attributes Max Angle&MD TD S x, _ Wellbore APIIUWI Field Name Well Status Ind(") MD(ftKB) Act Ben(ftKB) Ala500292049601 KUPARUK RIVER UNIT PROD 7,860.0 R1` Comment 1125(ppm) Date Annotation End Date IKB-Grd(ft) Rig Release Date -'- SSSV-NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 _,We,�IC.anlj�, VIA,LC, 8 opn 0506,2uo 20598 PM - -, $diem.' Actual Annotation Depth(fIKB) End Date Annotation (Last Mod...l End Date Last Tag:SLM 7,712.0 2/9/2011 Rev Reason:GLV C/O _IL ninam 4/26/2011 Casing Stringsi..,a,,.,v.:.: HANGER,2<------�' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND) String Wt. String...String Top Thrd CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(ND)•••String Wt...String...String Top Thrd CSURFACE 10 3/4 9.794 31.8 2,895.6 2,704.5 45.50 K-55 BTC ... asing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND) String Wt..String.. String Top Thrd WINDOW A 8 6.000 5,712.0 5,722.0 5,120.5 26.00 L-80 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)..String WI...String.. Strong Top Thrd PRODUCTION 7 6.151 30 9 7,568.0 6,394.5 26.00 K-55 ETC Casing Description String 0... String ID...Top(HKB) Set Depth(f...Set Depth(ND)...String WI...String...String Top Thrd CONDUCTOR, LINER A i 5 1/2 4.871 5,491.6 7,860.0 6,570.8 15 50 L-80 HD-L 32-80 _... NIPPLE,5483. Liner Details illsTop Depth int (TVD) Top Ind Nomi... GAS LIFT, 111: i Top(ftKB) ("KB) (°) Item Description Comment ID(in) BAKER ZXP LINER TOP PACKER 2• 5,491.6 4,921.3 28.84 PACKER "ZXPN"w/5.5"Hyd 563 box down, 5.500 " " 5.50"ID 10'PBR 5,508.1 4,935.7 29.19 HANGER BAKER LINER HANGER"HMC Liner Hanger 4.890 SURFACE, Tubing Strings 92.2,898 Tubing Description String 0... String ID...Top(HKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd GPS LIFE, TUBING 3 1/2 2 992 I 24 3 7,299.9 6,236.5 9.30 L-80 EUEm _ 3480 i;.. Completion Details F Top Depth (ND) Top loci Monti._Top(ftB) Mks) ('1 Item Description Gaanem ID(In) 24.3 24.3 -0.04 HANGER FMC Gen III TUBING HANGER 3.500 GASLIFE, 545.8 545.8 0.76 NIPPLE CAMCO 3-1/2""X NIPPLE W/2.813" 2.812 4,532 -: _--. 6,253.5 5,581.0 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3.000 Illie 6,256.7 5,583.6 38.20 PBR 8040 PBR w/special trim OD,3-1/2"EUE box 3.000 I. GAS LIFT,_ : 6,270.3 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 5,397 IC. - "LW ; ':. 6,271.9 5,595.6 38.90 PACKER 3-1/2"x 5-1/2"BAKER FAB PACKER 45-FA-36 3.000 `I 7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RD/. 2.960 iNg 7,057.8 6,094.7 54.88 PACKER 3-1/2"x 5-12"Baker FAB Packer 45-FA-36 3.000 7,070.1 6,101.8 54.90 NIPPLE CAMCO 3-1/2"X-NIPPLE,2.813"EUE 8 Rnd 2.813 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 7,226 6 6,192.9 53.35 PACKER BAKER FAB PACKER 45-FA-36 3.000 eelp WHIPSTOCK, 5.712 7,266.1 6,216.4 53.50 NIPPLE CAMCO X-NIPPLE w/2.813"profile EUE 8rd pin x pin 2.813 WINDOWA, � 5,712-5,722 7,299.0 6,2360 53.61 SHOE 3-1/2"WWIRELINE ENTRY GUIDE 2.960 Mr GASLIFr, Other In Hole 'reline retrievable plugs,valves,pumps,fish,etc.) 6,200 -__-_- ellr:_^ Top Depth MIL (TVD) Top Incl Top(MB) (KB) C) Daacepeon Comment Run Date ID(In) SEAL ASSY, _ 7,563 6,391.5 52.92 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR WESTERN 4/4/2011 0.000 6,253 LATERALS 1E-08AL2&1 E-08AL2-01 PBR,6,257 __ 7,645 6,440.8 51.87 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 ANCHOR, ;� LATERALS 8,270 PACKER,6,272 7,698 6,475.3 54.64 CMT Retainer CMT RETAINER SET IN'A F OH I A I URAL SIDETRACKS 2/17/2011 0.000 [11.111,1 Perforations&Slots _...... Shot Top(ND) Btm(ND) Dens Top(nKB) Bim(11KB) (RKB) (HKB) Zone Date (oh... Type Comment 7,517 7537 6,364.0 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES:2.5'HSD 2506 PF HMX,60 Deg.Phase 7,564 7574 6,392.1 6,398.1 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PF HMX,60 Deg.Phaseillk ANcraR. 7,645 7,655 6,440.8 6,447.0 2/17/2011 6.0 APERF TUBING PUNCHES:2.5'HSD 2506 PACKER,7,058 7.42111M, PF HOAX,60 Deg.Phase Ilk -.: Notes:General&Safety NIPPLE,7,070 -- jam` End Dab AnnotationIlir 8/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 I ANCHOR,_ 7,227 - - PACKER,7,227 SI 1111/ NIPPLE,1,266 Air: SHOE,7,299 �'T APERF. +-",^ems 1 5+" �,-•y -ft "s3 `- t R• 7.517-7,537 • �9P".- .t^Z.:_.. .a va•,.>..>' ...•a_" -f`h�;•`�_ u'i".m:' PRODUCTION, Top Depth Top Port 31-7,568 (TVD) Ind OD Valve Latch SW TRO Run APERF, Sb,Top(MB) MEN (*) Make Model (In) Sean Type TIP. (i)) (MARun Date Can._ _ 7,566-7,574 1 2,336.5 2,231.6 31.84 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,370.0 4/25/2011 WHIPSTOCK, OMT PLUG, 2 3,479.7 3,199.0 34.20 CAMCO KBMG 1 GAS LIF I GLV BK 0.156 1,342.0 4/25/2011 I - 7,00 WHIPSTOCK, 3 4,532.2 4,080.4 30.48 CAMCO KBMG 1 GAS LIF I GLV BK 0.156 1,317.0 4/25/2011 , APES _ _ 4 5,396.7 4,838.1 28.96 CAMCO KBMG 1 GAS LIFT IGLV BK 0.188 1,332.0 4/24/2011 - ]s6s7.65s 5 6,199.8 5,538.0 35.58 CAMCO KGB2-9 1 GAS LIFT !OV Bko-3 0.250 0.0 4/24/2011 CUT Retainer, _. . 7,898 r. LINERA, 5,492-7,880 TD(1E-08A),N I 4 F 7,860 p[{t) 1 E-08 Well Work Summary DATE SUMMARY 2/9/11 PULL BPV, DRIFT TBG TO 2./6', COULD NOT GET PAST 6985' SLM, RAN BRUSH AND 2.1" G RING TO TAG @ 7712' SLM. IN PROGRESS. 2/10/11 SET CATCHER @ 6232' SLM, REPLACE SOV @ 6199' RKB W/ DMY VLV, PULL CATCHER, DRIFT TO 2.77"TO 7655' SLM, PERMORM PASSING 2500 PSI MIT-IA. IN PROGRESS. 2/11/11 RUN DUMMY WHIPSTOCK TO 7670' SLM. NO OBSTRUCTIONS. READY FOR E-LINE. 2/12/11 ATTEMPT TO PERFORM GR/CCL CORRELATION LOG AND PERFORATE. DELAYED START, HAD 0- RING FAILURE DURING PT. LAYDOWN TOOLS FOR NIGHT, RESTART IN AM. 2/17/11 LOGGED GR-CCL FROM CEMENT RETAINER TO 6000' ELM. CEMENT RETAINER TAGGED AT 7698' ELM. PERFORATED 3 INTERVALS, 7645'-7655', 7564'-7574', AND 7517'-7537' USING 2.5" HSD 2506 PF HMX, 6 SPF, 60 DEG PHASING. SET 3.5"X 5.5" BAKER THRU TUBING WHIPSTOCK AT 18.9 DEG RHS. TOWS AT 7645', BOWS AT 7658'. 2 RA TAGS INSTALLED IN WHIPSTOCK. RA TAGS 7.35' FROM TOWS AT 7652.35' ELM. RDMO, RU LRS FOR INJECTIVITY TEST. PUMPED DIESEL: 0.5 BPM AT 1600 PSI, 1 BPM AT 2150 PSI, AND 1.5 BPM AT 2600 PSI. PUMP REPORT IN ATTACHMENTS. 2/19/11 RESTART TOMORROW DUE TO PROBLEMS GETTING RIGGED UP AND PRESSURE TESTED, 2/20/11 PUMPED 15BBLS NEAT CEMENT(15.8PPG), LAYED IN FROM 7640FT CTMD TO 6750FT CTMD, PERFORMED 8 HESITATION SQUEEZES, PUSHED 5.5 BBLS INTO PERFS, DROPPED BALL, RIH, TAGGED CEMENT AT 7171T CTMD, UNABLE TO WASH PAST 7171 FT CTMD, WASHED TUBING THROUGHLY, FP WELL, BACK TOMORROW TO MILL TOP OF CEMENT TO TUBING TAIL, IN PROGRESS 2/21/11 MILL CEMENT FROM HRD TAG @ 6900 CTMD TO 7047 CTMD W/2.69 BI CENTER BIT, TERMINATE JOB DUE TO PHASE II CONDITIONS, FP WELL , IN PROGRESS ' 2/22/11 TAGGED UP @ 4516' CTMD W/2.80" PARABOLIC DIAMOND SPEED MILL. PUMP AT MIN. RATE & GOT BY EASY. ROTATE MILL WHILE RIH, HARD STALL @ 6999' CTMD. MAKE IT TO TO 7008' CTMD, PROGRESS SLOW W/ALOT OVER PULLS. FREEZE PROTECT THE WELL, RACK BACK FOR THE NIGHT, JOB IN PROGRESS. 2/23/11 MILLING JOB SUSPENDED. PERFORM WEEKLY BOPE TEST. RIG OFF THE WELL BUT UNABLE TO LAY DOWN MAST DUE TO HIGH WINDS. 3/1/11 PRE CTD PT SV, MV(PASSED) DDT SV, MV, SSV(PASSED)TREE TEST. 4/23/11 GAUGED TBG TO 2.62"TO TOP OF LINER @ 7262' SLM. MEASURED BHP @ 7100' RKB: 2963 PSI (DECLINING). IN PROGRESS. 4/24/11 SET CATCHER @ 7257' SLM. PULLED DVs @ 6199', 5396', 4532' RKB. SET OV @ 6199', GLV @ 5396' RKB. IN PROGRESS. 4/25/11 PULLED DVs @ 3479', 2336' RKB. SET GLVs @ 4532', 3479', 2336' RKB. CONFIRMED VALVES SET. PULLED EMPTY CATCHER @ 7257' SLM. COMPLETE. s s— C ( 1� e-0 _ s STATE OF ALASKA ALASKA —,L.AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Stipulate r Other r Change Status: Alter CasingPull Tubing r Ferforate New Pool Waiver Susp to Oil-1 r r r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Devebprpent r Exploratory r _f 210-181-0 3.Address: 6.API Number: Stratigraphic r Service r P.0. Box 100360,Anchorage,Alaska 99510 a 50-029-20496-01 00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651 —1E-08A 9.Field/Pool(s): — Kuparuk River Field/Kuparuk River Oil Pool 10.Present Well Condition Summary: Total Depth measured 7860 feet Plugs(measured) None true vertical 6571 feet Junk(measured) None Effective Depth measured 7860 feet Packer(measured) 6253,6272,7058,7227 j true vertical 6571 feet (true vertucal) 5581,5596,6095,6193 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80 80 0 0 SURFACE 2864 13 2896 2705 0 a WINDOW A 10 8 5722 5120 0 0 PRODUCTION 7537 7 7568 6394 0 0 LINER A 2368 7 7860 6571 0 0 0 0 0 Perforation depth: Measured depth: 7517-7537';7564-7574';7645-7655' RECEIVED True Vertical Depth: 6364-6376';6392-6398;6441-64'- Tubing(size,grade,MD,and TVD) 3.5, L-80,7299 MD,6236 TVDGpflhERISSIOn pagska un &f a Cene. Packers&SSSV(type,MD,and ND) SEAL ASSY-BAKER SEAL ASSEMBLY/LOCATOR @ 6253 MD and 558inicarage PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 6272 MD and 5596 ND PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 7058 MD and 6095 ND PACKER-BAKER FAB PACKER 45-FA-36 @ 7227 MD and 6193 ND NIPPLE-CAMCO 3-1/2""X"NIPPLE w/2.813"@ 546 MD and 546 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development F7 - Service r Stratigraphic r 15.Well Status after work: ,Oil r Gas r VVDSPL r Daily Report of Well Operations GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16.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 N/A Contact Bob Christensen/Darrell Humphrey Printed Name ••e .,D. Chri ,-nsen Title Production Engineering Specialist Signature .,, /- Phone:659-7535 Date Form 10-404 Revised 10/2010 RBDMS MAY 0 6 1011 6"./( Su it¢ ' aI Only 1E-08A J DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/23/11 GAUGED TBG TO 2.62"TO TOP OF LINER @ 7262'SLM. MEASURED BHP @ 7100' RKB: 2963 PSI (DECLINING). IN PROGRESS. 04/24/11 SET CATCHER @ 7257'SLM. PULLED DVs @ 6199', 5396',4532' RKB. SET OV @ 6199', GLV @ 5396' RKB. IN PROGRESS. 04/25/11 PULLED DVs @ 3479', 2336' RKB. SET GLVs @ 4532', 3479', 2336' RKB. CONFIRMED VALVES SET. PULLED EMPTY CATCHER @ 7257'SLM. COMPLETE. b \ KUP 1E-08A ConocoPhillips : a.ell Attributes x An le&MD TD 4 Aldirk; Wellbore APIIUWI Field Name Well Status Incl I") MD(RKB) Act Btm(66(6) gyyps 500292049601 KUPARUK RIVER UNIT PROD 7,860.0 Comment H23(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date ••• -SSSV:NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 Well Conk,DEVIATED-1E-0BA 4262011 2.45.38 PM - --- --- ScMmatic-Actual Annotation Depth MKS) End Date Annotation Last Mod End Date Last Tag:SLM 7,712.0 2/9/2011 Rev Reason:GLV C/O I anti 4/26/2011 �� ;k.�e. Casi HANGER,24 Casing in DescriptionStrn s String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd I- 1 CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED • Casing Description String 0... String ID...Top(MMB) Set Depth(f_.Set Depth(TVD)... String Wt...String... String Top Thrd 1 ' I SURFACE 103/4 9.794 31.8 2,895.6 2,704.5 45.50 K-55 BTC 1 ' • ' ' Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd WINDOWA 8 6.000 5,712.0 5,722.0 5,120.5 26.00 L-80 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.151 30.9 7,568.0 6,394.5 26.00 KS5 BTC Casing Description String 0... String ID...Top(RKB) Sat Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR. LINERA 51/2 4.871 5,491.6 7,860.0 6,570.8 15.50 L-80 HD-L 3290 la NIPPLE,546 IIIP Liner Details _ Top Depth' )TVD) Top Incl Nonni... GAS LIFT. Top(ftKB) )RKB( (") Item Description Comment ID(in) 2,336 5,491.6 4,921.3 28.84 PACKER BAKER ZXP LINER TOP PACKER"ZXPN"w/5.5"Hyd 563 box down, 5.500 S 5.50"ID 10'PBR y� 5,508.1 4,935.7 29.19 HANGER BAKER LINER HANGER"HMC"Liner Hanger 4.890 SURFACE, i l Tubing Strings 32-2,896 Tubing Description String 0. String ID...Top(RKB) Set Depth IL..Set Depth(TVD)...String Wt...String... String Top Thrd TUBING I 31/2 I 2.992 I 24.3 7,299.9 6,236.5 9.30 L-80 EUErT GAS3480 { Completion Details Top Depth (TVD) Top Incl Nonni... Top(ItKB) IRKS) _(") item Description Comment ID)in) 24.3 24.3 -0.04 HANGER FMC Gen III TUBING HANGER 3.500 GAS LIFT _ 545.8 545.8 0.76 NIPPLE CAMCO 3-1/2""X"NIPPLE Wl 2.813" 2.812 4,532 6,253.5 5,581.0 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3.000 NM 6,256.7 5,583.6 38.20 PBR 80-40 PBR w/special trim OD,3-1/2"EUE box 3.000 GAS LIFT. Ai 6,270.3 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 5,387 6,271.9 5,595.6 38.90 PACKER 3-1/2"x 5-1/2"BAKER FAB PACKER 45-FA-36 3.000 IMII 7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RDL " 2.960 7,057.8 6,094.7 54.88 PACKER 3-1/2"x 5-1/2"Baker FAB Packer 45-FA-36 3.000 7,070.1 6,101.8 54.90 NIPPLE CAMCO 3-112"X-NIPPLE,2.813"EUE 8 Rnd 2.813 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 7,226.6 6,192.9 53.35 PACKER BAKER FAB PACKER 45-FA-36 3.000 WHIPSTOCK, 5.712 7,266.1 6,216.4 53.50 NIPPLE CAMCO X-NIPPLE w/2.813"profile EUE 8rd pin x pin 2.813 WINDOW A s.nz-5.722 7,299.0 6,236.0( 53.61(SHOE I3-1Y2"WWIRELINE ENTRY GUIDE 12.960 GAS LIFT. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 6.270 Top Depth (TVG) Top Incl Top(RKB) VIM/ 1") Description _ Comment Run Dab ID(in) SEAL ASSY, 7,563 6,391.5 52.92 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR WESTERN 4/4/2011 0.000 6.253 LATERALS 1E-08AL2&1E-08AL2-01 PBR,6,257 IIIIMIIII 7,645 6,440.8 51.87 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 ANCHOR, LATERALS 6,270 EMI PACKER.6,272 7,698 6,475.3 54.64 CMT Retainer CMT RETAINER SET IN'A'FOR LATERAL SIDETRACKS 2/17/2011 0.000 l Perforations&Slots Top(TVD) Btm(TVD) Shot Dens Top(RKB) Sim(MB) (RKB) (MB) Zane Date ph... Type Comment 7,517 7,537 6,364.0 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PF HMX,60 Deg.Phase 7,564 7,574 6,392.1 6,398.1 2/17/2011 6.0 APERF TUBING PUNCHES:2.5"HSD 2506 PF HMX,60 Deg.Phase ANCHOR, 7,645 7,655 6,440.8 6,447.0 2/17/2011 6.O1APERF TUBING PUNCHES:2.5"HSD 2506 PACKER, 0 - PF HMX,60 Deg.Phase 11.' SNotes:General&Safety '' NIPPLE,7,070 GIL End Date Annotation IIIII 8/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 NI 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 a ANCHOR, �., 7,225 PACKER.7,227 I= NIPPLE.7,266 ME IN' SHOE.7.219 APERF, Mandrel Details 7'5177'537 Top Depth Top Port PROD 3,70569 )TVD) Incl OD Valve Latch Sloe TRO Run APERF,-.." -•••• Stn Top(RKB) (RKB) (") Make Model (int Sar, Type Type (in) (PM) Run Date Com... 7.564-7,574 • 1 2,336.5 2,231.631.84 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,370.0 4/25/2011 WHIPSTOCK, 7,5632 3,479.7 3,199.0 34.20 CAMCO KBMG - 1 GAS LIFT GLV BK 0.156 1,342.0 4/25/2011 CMT PLUG, 7,047 WHIPSTOCCK,K, 3 4,532.2 4,090.4 30.48 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,317.0 4/25/2011 45 7' -‘4%. 4 5,396.7' 4,838.1 28.96 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,332.0 4(24(2011 APERF, 110 7,6457,655 5 6,199.8 5,538.035.58 CAMCO KGB2-9 1 GAS LIFT OV Bko-3 0.250 0.0 4/24/2011 CMT Retainer, 1 7.698 I I LINER A 5,492-7,860 N TO(1E-08A).7.660 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 11, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 1E-08A Run Date: 3/9/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-08A Data in LAS format, Digital Log Image files 1 CD Rom 50-029-20496-01 Cement Bond Log 1 Color Log 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 g(O—1 ( (96S Fax: 907-273-3535 klinton.woo liburton.com _ Date: M I Signed: Page 1 of 2 Schwartz, Guy L (DOA) From: Long, Jill W[Jill.W.Long@conocophillips.com] Sent: Thursday, March 10, 2011 4:09 PM To: Schwartz, Guy L (DOA) F-Fp Cc: Allsup-Drake, Sharon K Subject: FW: Sundry#311-028 Attachments: 1 E-08_RCBL_9-MAR-2011.pdf Guy- We were able to get the RCBL tool down last night after the cleanout run. Attached is an electronic copy of the log for the State's files as per the request in the Sundry. If you have further questions please let me know. Thank you, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 From: Long, Jill W Sent: Wednesday, March 09, 2011 4:28 PM To: 'Schwartz, Guy L (DOA)' Subject: RE: Sundry #311-028 Guy- Just to summarize our phone conversation, we have made three attempts at running the RCBL tool across our perf locations in 1 E-08A and have, to this point, have been unsuccessful at getting down with the tools. We have spent the day performing an additional cleanout run with coil in hopes that we could remove any cement debris that might be prohibiting the tools from passing through. Tonight we will make one last attempt to get the tools down to evaluate the cement behind our KOPs but after that attempt, we plan to proceed with window milling. I will let you know in the morning if we were able to make it down or not. Thanks, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 3/10/2011 Page 2 of 2 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, February 17, 2011 4:23 PM To: Long, Jill W Subject: RE: Sundry #311-028 Jill, As per our phone discussion , I just wanted to make sure the commission got a copy of the log. It is not for UIC requirements. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Long, Jill W [mailto:JilI.W.Long@conocophillips.com] Sent: Thursday, February 17, 2011 3:30 PM To: Schwartz, Guy L (DOA) Subject: Sundry #311-028 Guy- I left you a voicemail earlier this afternoon but I wanted to follow-up with you in an email as well. I have a question for you regarding the comment noted on approved Sundry#311-028. This is the Sundry for pre-CTD wellwork required on Kuparuk well 1 E-08A. The question concerns the comment from the Commission that requests: "Submit CBL to Commission for review." Will you please describe the Commission's expectation with regards to the review? The primary reason ConocoPhillips is running the CBL is to better optimize the placement of our upper whipstock. (i.e. We would like to confirm there is good cement quality behind pipe at our kickoff location.) Please give me a call if you have any questions about what I am asking. We would just like to clarify the requirement in the Sundry before moving forward. Thank you, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 3/10/2011 u j 1 II . ■■■■■ ' :iii■■■■■ 1 f! 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I. 1 Emmy li Eimumw a -:.---. - - r:.;.: ' ■1MI_ I i:.: 1! 111 `' ,: j '.: t lit/iii 7600 —I : N r • _yy • i `g' `t pi. iI }:{ 1, .r ,i1 ,11 !ii ___, ,....:::- ,Il 1! 1,1 ill' -. MAI :' 3 MIMI MIN `,-- 7650 Ism MINI � \ f . 280 TT (usec) 180 LTEN 0 Amplitude (mV)100 AVG Sector Amplitude 200 MSG 1200 SECTORS CCL 0 (Ib;1500 Amp Amplitude 0 300 IIIIIB 0 Gamma 150 0 (mV) 10 MAX Sector Amplitude 300CLine Tens (Ib) 0 0 300 MIN Sector Amplitude 0 300 MAIN LOG PASS HALLIBURTON 5" = 100' HALLIBURTON FREE PIPE SECTION WELL LOG TRANSMITTAL To: State of Alaska February 22, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 1E-08A AK-MW-0007889723 1E-08A 50-029-20496-01 2"x 5" MD TRIPLE COMBO Logs: 1 Color Log 2"x 5"TVD TRIPLE COMBO Logs: 1 Color Log Digital Log Images&LWDG-formatted LIS Data w/verification listing; 1 CD Rom RE-ISSUE:THIS DATA SET SUPERCEDES ALL PREVIOUSLY-ISSUED DATA SETS, SPECIFICALLY THE ONE DATED 04-FEB-2011.THIS RE-ISSUE INCORPORATES A RE- SHIFTING OF THE MERGED DATA. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3536 c9/0. --/b/ go-457 F. 97733535 B '§ i �* . n.com FEB 2 4 2011 Date: Signed: " ON cC,> STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1a.Well Status: IELL COMPLETION OR RECOMPLETION REPORT AND LOG ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspende '[ ] lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory p GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _0 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Drilling Permit&Sundry Number: ConocoPhillips Alaska,Inc. Aband.:January 30,2011 Permit:210-181 &Sundry:311-015 3.Address: 6.Date Spudded: 13.API pNy1lber:l,4p P.O.Box 100360,Anchorage,Alaska 99510 January 11,2011 50-299-20496-01-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1013'FSL,629'FEL,Sec 16,T11 N,R10E January 16,2011 1 E-08A Top of Productive Horizon:(A-Sand) 8.KB(ft above MSL): 98.6' 15.Field/Pool(s): 902'FNL,676'FEL,Sec 16,T11 N,R10E GL(ft above MSL): 70.7' Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): Kuparuk River Oil Pool 710'FNL,602'FEL,Sec 16,T11 N,R1 OE 7714'MD/6483'MD 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 549,889.82' y- 5,960,600.23' Zone- 4 7860'MD/6570'ND ADL 25651 TPI: x- 549,845.81' y- 5,963,991.12' Zone- 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 549,885.72' y- 5,964,156.10' Zone- 4 None ALK 469 18.Directional Survey: Yes Q No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) Onshore (ft MSL) 1477' 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: RCBL on E-line. GR,RES,NEU,DEN,PWD on L/MWD TOW:5712'MD/5112'ND 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 0 80 0 80 24" 15 bbls AS II 0 10-3/4" 45.5 K-55 0 2896 0 2705 13-3/4" 1350 sx 12ppg,250 sx AS 0 1 7" 26 K-55 0 7568 0 6543 8-3/4" 300 sx 11.9 ppg,200 sx 14.2 0 5-1/2" 15.5 L-80 5491 6779 4921 5932 G"x 7" * 247 sx Class G(see cement 0 5-1/2" 15.5 L-80 6779 7860 5932 6571 (ok x 7" squeeze below) 0 rr r�.ndsr-rc.w4-Aer 2i, s•/i.di 24.Open to production or injection? Yes❑ No Q If Yes,list each 25. TUBING RECORD interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) g C.Tp s.J --m-o wc.1(da^e-• 3-1/2"EUE-M 5411' Top packer 6269'/5593' 3-1/2"IBT-M SCC 7296' Lower 7223'/6190' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. t:dir° ;GI DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED / DA 5491'-6750' Liner top squeeze-112 sx Class G f1l aEt j 6750'-7175 (71,3 Perforation Squeeze-47 sx Class G--t 7175'-7725' /17a. Perforation Squeeze-88 sx Class G _ L reci-'s- 41"4. r4.1-4.4.6.' <-1" d?'.77/s#Mb 27. PRODUCTION TEST '/ Date First Production: Method of Operation(Flowing,gas lift,etc.): /_" 3."r•it Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No E Sidewall Cores Acquired? Yes ❑ No❑., If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIViLift 1E-08A is a rotary sidetrack to be used as a CTD setup. The well is secured in preparation for CTD arrival. 1-+E) 0 4 1.I11' isglfa 0 &GP3 Cons.,C,7, .ssion Submit origina nerbne Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 3Oft l onginar *reh only G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top 0 0 needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1484' 1477' KOP 5712' 5112' Top HRZ(K-2) 6631' 5845' Upper Kalubik(Base HRZ) 6947' 6030' Top D 7278' 6223' Top C 7283' 6226' Top B 7419' 6306' Top A4 7638' 6436' Top A3 7747' 6503' Top Miluveach 7782' 6523' Formation at total depth: Miluveach 7860' 6571' 31. List of Attachments: Schematic, Daily Drilling Log,Definitive Surveys,and Tubing/Casing Pressure Test 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Elmo Cecchetti EQ 1 2/311% Printed Name: Chip Alvord Title: Alaska Drilling Manager Signature: 04 k Phone: 265-4249 Date: 2/3/2011 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 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 1E-08A Rotary Sidetrack - CTD Setup Completion Depth (Actual) A h 16"65#H-40 casing •3-1/2"Gen IV Tubing Hanger 80'MD/80'TVD •3-1/2"9.3#L-80 EUE 8RD •HES"X"Nipple 2.81"ID 545'/545' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 2,336'/2,231' , . ii •3-1/2"X 1"KBMG GLM 2.867"ID 3,479'/3,198' •3-I/2"X I"KBMG GLM 2.867"ID 4,532'/4,090' Ei ' •3-1/2"X I"KBMG GLM 2.867"ID 5,396'/4,837' •3-1/2"X I"KBG-2-9 GLM 2.867"ID 6,199'/5,537' w/2000 psi shear valve Drifted to 2.81" 10-3/4"45.5#K-55 •GBH-22 80-40 PBR,EUE 8 RD •KBH-22 Anchor Seal Assembly,EUE 8 RD casing 2,896'MD/ •3-1/2"X 5-1/2"FAB Production Packer 6,269'/5,593' 2,705'TVD •3-1/2"9.3#L-80 IBT-M SCC •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X 5-1/2"FAB Production Packer 7,055'/6,093' •HES"X"Nipple 2.81"ID 7,067'/6,100' 5-Y2"TOL @ 1 •3-1/2"9.3#L-80 IBT-M SCC 5,491'MD/4,921' •KBH-22 Anchor Seal Assembly,EUE 8 RD TVD Sidetrack KOP •3-1/2"X 5-1/2"FAB Production Packer 7,223'/6,190' thru window in 7"@ •HES"X"Nipple 2.81"ID 7,263'/6,214' 1116.: 5,712'MD/5,112'TVD •3-1/2"Mule Shoe WLEG 7,296'/6,234' -re.P r 'Al,e.✓r Baker"K-1"CIBP Bottom set @ 5,736' - - MD/5,124'TVD Packer 6,269'/5,593' �j//� wLeak at 6,293'/5,611' Packer 7,055'/6,093' 1. 5-1/2"15.5#L-80 HD-L Liner(1,300') Perfs 7,175'/6,162' Tubing cmt retainer >,, i.::_ Packer 7,223'/6,190' @ 6,753'MD/ } 5-1/2"15.5#L-80 HD-L Xio 5,993'TVD ST-L @ 6,779' /5,932' �B4� j Retainer 7,714'/6,483' Retainer 7,720'/6,486' Perfs 7,725'/6,489' i ... 1W 5-1/2"15.5#L-80 ST-L liner(1,038')@ 7"Open Hole TD @ 7,860'MD/6,571'TVD 7,860'MD/6,571'TVD • • • 7"26#K-55 casing Revised by: @ 7,568'MD/6,543'TVD Elmo Cecchetti Feb. 1, 2011 I I ConocoPhillips Time Log & Summary We/Niew Web Reporting Report Well Name: 1E-08 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 1/8/2011 6:00:00 PM Rig Release: 1/30/2011 12:00:00 PM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01/05/2011 24 hr Summary Release from BP at 12:00. Clean&clear rig floor&cellar. R/D skate elevator. Clean pits in rock washer and suction manifold. 12:00 18:00 6.00 0 0 DEMOB MOVE DMOB P Clean&inventory all subs&X/O's on rig floor. Clean pollution pan&cellar box. Service tools&equipment. Repair leak in pit 6&jet line brace in rock washer. 18:00 00:00 6.00 0 0 DEMOB MOVE DMOB P Organize&prepare cellar for move. Clean pits in rock washer. Blow down rig water,disconnect glycol& water lines. C/O ram on skate elevator. Pull&secure rail from skate. Clean suction manifold on mud pumps. 01/06/2011 Continue R/D 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P PJSM on slip&cut. Cut 63'of drilling line. Service draw works& top drive. Tighten break pad nuts& work on mud pump#2. Perform category 4 derrick inspection. C/O light bulbs in derrick. Perform annual harness&lanyard inspection. Inspect weld stops on hydraulic ram on skate elevator.Weld grating in pits&rockwasher. Repair door handle on geologist shack. Adjust stand jump on top drive. GCI representatives RID communications. 12:00 22:00 10.00 0 DEMOB MOVE DMOB P Stock Spill kits on each complex, Rig down berm around rockwasher. Cleaned&organize test equipment. Change out connection on vac system. Instal air line for sweeney tool.Clean rig floor.Change out liners on#1 mudpump.Wrap sub jack moving system with absorbant. 22:00 00:00 2.00 DEMOB MOVE DMOB P Prep rig for move to 1E-08 01/07/2011 Prep rig for move to 1 E-08 00:00 08:00 8.00 0 0 MIRU MOVE MOB P Pre-Job,Move rig camp to 1E-08. Complete rig prep for move. Blow down disconnect rockwasher. Disconnect Tioga from pipeshed Page 1 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:00 12:00 4.00 0 0 MIRU MOVE MOB P Move Boiler,Motor, Pit and Pump Complexes to 1 E-08 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Prep Pipe shed and sub structure for move. Load trucks with miscellaneous rig equipment. 18:00 23:00 5.00 0 0 MIRU MOVE MOB P Fuel boilers, motor complex, pit and pump complex.Mob peak trucks to NGI(Prudhoe)to move sub base and pipe shed 23:00 00:00 1.00 0 0 MIRU MOVE MOB P Begin move from NGI Pad(Prudhoe) with sub structure and pipeshed. 01/08/2011 Completed move/Rig Up. Rig Accepted @ 18:00 hrs. Pulled BPV&RV plug.Circulate out diesel freeze protect. Nipple down tree. 00:00 07:30 7.50 0 0 MIRU MOVE MOB P PJSM,Move sub Base and Pipe Sheds to 1 E-08 07:30 09:00 1.50 0 0 MIRU MOVE PSIT P Spot Sub Structure over well 09:00 11:30 2.50 0 0 MIRU MOVE PSIT P Set rig mats. Spot Rig modules-Pits &Pump complex,motor complex, Boiler complex. 11:30 12:00 0.50 0 0 MIRU MOVE PSIT P Set Berm,Spot rock washer complex. 12:00 13:30 1.50 0 0 MIRU MOVE SFTY P Held Safety and pre-spud meeting with Conoco Phillips Engineer, Company men, Doyon Drilling Superintendent and toolpushers. Discussed hand safety use of impact gloves, New cutting policy discontinue using open blades, Traction control devices to be used. Discussed 1 E-08 sidetrack well objectives. 13:30 18:00 4.50 0 0 MIRU MOVE RURD P PJSM, Hook up inter connects. Plug in electrical lines.Turn on steam& instal steam traps. Level rig Complete berming around rockwasher. Spot tioga, Prep pipeshed. Line up drains to slop tank in cellar. Rig up all mud lines and pumps.Complete rig acceptance list.Take on 580 bbl's brine to pits. Rig Accepted @ 18:00 hrs. 18:00 20:00 2.00 0 0 MIRU MOVE RURD P PJSM,Spot directional drillers unit on top of pit complex. Load pipeshed with BHA tools. 20:00 22:00 2.00 0 0 SLOT WHDBO RURD P Spot tiger tank,make up hard line to cellar and squeeze manifold for displacing out diesel freeze protect 22:00 23:00 1.00 0 0 SLOT WHDBO NUND P Open SSV.Master and Swab valve on tree, Monitor pressures-zero pressure.Open bleeder no fluid. Pull tree cap check poppit no psi. Pull BPV. Close master valve.Open IA pull VR plug. Page 2 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 SLOT WHDBO RURD P Rig up 1502 flange on inner annulus. Rig up lines to displace out diesel freeze protect. 01/09/2011 Displace diesel freeze protect.Set BPV, Nipple down tree. Nipple up BOPE.Test BOPE. BOPE Test waived by AOGCC rep Jeff Jones 1-8-11 @ 10:30. Rig up to pull 3-1/2"tubing.Circulate bottoms up. Begin laying down 3-1/2"tubing. 00:00 01:00 1.00 0 0 SLOT WHDBO RURD P PJSM continue rig up to displace out diesel freeze protect. Pressure test line 500 psi 5 minutes. Pressure test charted. 01:00 03:30 2.50 0 0 SLOT WHDBO CIRC P Displace diesel freeze protect- Pump 20 bbl's seawater down annulus to clear diesel from tubing @ 3 bpm w/600 psi.Swap over and pump down tubing taking returns at annulus to open top tank @ 4 bpm w/650 psi. Pumped 260 bbl's. Monitor well 5 min(Static)Rig down circulating equipment. Spill drill held 2 minute response time. 03:30 06:00 2.50 0 0 SLOT WHDBO NUND P Set BPV, Nipple down tree,Make up blanking plug in hanger per FMC rep. 06:00 10:30 4.50 0 0 SLOT WHDBO NUND P Nipple up 13-3/8"X 7-1/16"DSA,3' Spacer spool and GOP's 10:30 13:00 2.50 0 0 SLOT WHDBO NUND P Change out shear rams for Blind rams 13:00 17:00 4.00 0 0 SLOT WHDBO BOPE P Rig up and test BOPE 250 psi low 3,500 psi high.All tests charted. Witness of BOP test waived by b( )P1 rep Jeff Jones @ 10:20 hrs. �65� 1-8-2011. Ri• down from test. 17:00 18:00 1.00 0 0 SLOT WHDBO NUND P Verify no pressure on inner annulus. Pull blanking plug,Make up FMC set tool check poppit verify no pressure. Pull BPV. 18:00 20:00 2.00 0 0 SLOT CSGRC'RURD P Make up TIW valve,crossover and joint of 3-1/2"IBT, Pick up casing equipment and rig up. 20:00 21:00 1.00 0 0 SLOT CSGRC'PULL P Make up IBT joint to tubing hanger, Back out LDS. Pull hanger free with 85K up weight. Pull hanger above floor.Set slips make up TIW valve on top of tubing joint up to topdrive. 21:00 22:00 1.00 0 0 SLOT CSGRC'CIRC P Circulate bottoms up at 5 bpm with 300 psi 22:00 00:00 2.00 6,645 6,085 SLOT CSGRC'PULL P Lay down tubi g hanger Pull 560'of 3-1/2"tubing from hole. Up wt 80k down wt 80k. Hole took calculated displacement 01/10/2011 Completed laying down 3-1/2"tubing 213 joints total.Tested Rams and Hydril with 4"test joint.Set wear bushing. Picked up 10 stands 4"drillpipe and racked in derrick.Made up csg scraper BHA. Picked up 4" drillpipe going in hole.Circulated bottoms up.Tripped out and layed down scraper BHA.Started rigging up wireline. Page 3 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:30 6.50 6,085 0 SLOT CSGRC'PULL P Complete laying down 3-1/2"tubing 213 joints total. Calculated fill= 22.14 bbl's.Actual fill=22.3 bbl's. 06:30 07:00 0.50 0 0 SLOT CSGRC'RURD P Rig down casing equipment 07:00 09:00 2.00 0 0 SLOT WHDBO BOPE P Rig up and test Both sets pipe rams -3-1/2"X 6"variables top rams 2-7/8"X 5"bottom rams to 250 psi low test 3,500 psi high test.Test Hydril 250 psi low 2,500 psi high. Rig down test equipment.Set 6-3/8" wear bushing. 09:00 10:00 1.00 0 0 SLOT CSGRC'RURD P Clear and clean floor.Stage casing scraper tools on floor 10:00 11:30 1.50 0 0 SLOT CSGRC'PULD P Pick up 30 joints 4"drillpipe running in hole. Pull out of hole racking back pipe in derrick 11:30 12:00 0.50 0 0 SLOT CSGRC'PULD P Make up Csg scraper BHA. Kick while tripping drill held with 2 minute response. 12:00 19:00 7.00 0 6,700 SLOT CSGRC'TRIP P Trip in hole with Csg scraper BHA picking up singles of 4"drillpipe.to 5,727' reciprocate 90'four times area where CIBP to be set.Continue tripping in to 6,700'Up wt 122k Down wt 110k.Calculated displacement 38.38 bbl's actual displacement 39.3 bbl's. 19:00 20:00 1.00 6,700 6,700 SLOT CSGRC'CIRC P Circulate bottoms up at 6 bpm with 750 psi.Spot 37 bbl's 9.2 ppg corrosion inhibitor brine and chase with 58 bbl of 8.5 ppg sea water @ 4.5 bpm with 400 psi.Monitor well, Rack back stand and blow down top drive. 20:00 23:00 3.00 6,700 0 SLOT CSGRC'TRIP P Trip out of hole and lay down scraper BHA.Calculated fill 38.38 bbl's actual fill 38.75 bbl's. Kick while tripping drill 57 second response. 23:00 00:00 1.00 0 0 SLOT CSGRC'RURD P Rig up wireline to run cast iron bridge plug. 01/11/2011 RU e-line, RIH set 7"CIBP @ 5736'WLM, RD e line,Test 7"csg to 3200 psi f/15 min,chart test, PJSM, PU/MU Baker whipstock&BHA, PU 14 jts of 4"HWDP, RIH w/whipstock to 5692',orient to 47deg right,set whipstock(Tagged CIBP @ 5729'DPM RKB).Shear bolt w/30k down weight. Displace to 9.2 ppg LSND mud,obtain parameters,obtain SPR's.Tag top of whipstock at 5712'RKB,start milling window.TOW @ 5712', BOW @ 5725', milled to 5745'(20'below BOW), pump sweep,stand back a stand, RU then perform LOT,soeedsheet picked 14.9 EMW w/9.2 Ing mud and 1510 applied pressure. 00:00 00:15 0.25 SLOT WHPST SFTY P Pre job safety meeting 00:15 00:30 0.25 SLOT WHPST RURD P Rig up a line unit. 00:30 03:30 3.00 SLOT WHPST ELNE P RIH w/Baker CIBP.Top of plug set at 5736'WLM. (4'above a collar). POOH,then ri• down e line unit. 03:30 04:30 1.00 SLOT WHPST PRTS P Rig up,then pressure test 7"casing to 3200 psi f/15 minutes.Charted test. Blow down lines. Pumped 2.5 bbls total.Good test. Page 4 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 04:45 0.25 SLOT WHPST SFTY P Pre job safety meeting. 04:45 05:00 0.25 SLOT WHPST PULD P Pick up whipstock tools to the rig floor. 05:00 08:30 3.50 0 617 SLOT WHPST WPST P Make up Baker Gen 2 whipstock BHA.Shallow pulse test, pumping 250 gpm w/500 psi. Pick up 14 joints of 4"HWDP. 08:30 12:00 3.50 617 4,756 SLOT WHPST WPST P Trip in the hole w/Baker whipstock _ on 4"drill pipe to 4756'. 12:00 13:00 1.00 4,756 5,692 SLOT WHPST WPST P Continue trip in the hole w/Baker whipstock on 4"drill pipe to 5692'. Make up top drive. Break circulation @ 6 bpm w/1040 psi. PU wt 112k, SO wt 105k. Increased pumps to 7.25 bpm w/1440 psi.Orient whipstock to 47 deg right of high side.Tag top of CIBP @ 5729'DPM. ‘ft: Shut down pumps.Set down 10k. Nt PU to 15k over,set down 15k, PU 20k over,shear bolt w/30k set down. Picked up 5'w/112k PU wt. 13:00 13:15 0.25 5,692 5,692 SLOT WHPST SFTY P Pre job safety meeting. 13:15 14:30 1.25 5,692 5,712 SLOT WHPST WPST P Displace well from seawater to milling fluid. Pump 30 bbls spacer, follow w/192 bbls of 9.2 ppg LSND mud. Rotate 60 rpm and reciprocate. f)4, Off bottom torque 2k ft lbs. Rot wt 108k.Obtain SPR's:#1 @ 30 spm= 350 psi,40 spm=470 psi.#2@ 30 spm=360 psi,40 spm=460 psi. 14:30 22:00 7.50 5,712 5,745 SLOT WHPST WPST P Rotate 60 rpm,pump 6 bpm w/1050 psi. Start milling @ 5712' Starter mill exited casing @ 5717', increased pump rate to 7 bpm- LE-ol pumped a 20 bbl high vis sweep, G / increased rotary to 120 rpm,another sweep @ 5729'and after TD @ 5745'.Total milling time 6.2 hrs. Reamed window while pumping last sweep around. Passed through window with and without pumps and no rotary-good-2 to 3k drag. TOW @ 5712', BOW @ 5725'. 22:00 22:45 0.75 5,745 5,674 SLOT WHPST RURD P Stand back a stand. Blow down the top drive. Rig up to perform LOT. Fill lines with mud. Shut top pipe rams (3-1/2"x 6"VBR's). Page 5 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:45 00:00 1.25 5,674 5,674 SLOT WHPST LOT P Perform LOT,pumping 6 spm. Record pressure vs strokes,chart test,fill out LOT form. Form calculated 14.9 EMW.5725'MD= 5123'ND.5745=5140 ND. Definite pressure break at 1510 psi. Pumped 3 bbls to the formation w/ 1425 to 1420 psi @ 6 spm..After 10 minutes,final pressure 1275 psi w/ 9.2 ppg mud in the hole. Note: Bleed OA down f/1300 psi to 500 psi while milling window.Approx 20 gallons bled off to bleed trailer. 01/12/2011 Circulate and condition mud blending milling fluid w/9.2 ppg LSND, POOH w/Milling assembly, L/D mills-top mill full guage 6-1/8",flush stack w/washing tool,clear and clean floor,service rig, PJSM,MU BHA#3 (drilling assembly w/1.75 deg mtr), upload MWD, load nuke sources,continue MU BHA#3,trip in the hole to 5745'(slide through window-no problems), break circulation, begin directional drilling f/5745 to 6010'. 00:00 00:15 0.25 5,674 5,674 SLOT WHPST SFTY P Pre job safety meeting 00:15 00:45 0.50 5,674 5,674 SLOT WHPST CIRC P Circulate and condition mud. Blend milling fluid w/100 bbls LSND 9.2 ppg,45 vis. Pumping 7 bpm w/1300 psi.Circulated 347 bbls. PU wt 110k, SO wt 100k. 00:45 01:00 0.25 5,674 5,674 SLOT WHPST OWFF P Obtain SPR's.Monitor well static. 01:00 04:00 3.00 5,674 56 SLOT WHPST TRIP P Pull out of the hole f/5674'to 600'. Monitor well at BHA,static. Rack back 3 stands of 4"HWDP lay down 4"HWDP, rack back NMDC's. 04:00 05:30 1.50 56 0 SLOT WHPST PULD P Lay down Baker milling BHA.Guage mills-starter mill 1/4"out, upper mill full guage(6-1/8"). Calculated fill 36.2 bbls,actual 37 bbls. 05:30 06:00 0.50 0 0 SLOT WHPST CIRC P Make up stack washing tool,flush stack. 06:00 06:30 0.50 0 0 SLOT WHPST PULD P Clear floor of Milling tools. Bring drilling tools to the rig floor. 06:30 07:00 0.50 0 0 PROD1 DRILL OTHR P Clean rig floor. 07:00 07:30 0.50 0 0 PROD1 RIGMNT SVRG P Service Rig-Lubricate. 07:30 07:45 0.25 0 0 PROD1 DRILL SFTY P Pre job safety meeting. 07:45 08:30 0.75 0 103 PROD1 DRILL PULD P Make up BHA#3(drilling assembly). 08:30 09:30 1.00 103 103 PROD1 DRILL PULD P Upload Sperry Sun MWD. 09:30 09:45 0.25 103 103 PROD1 DRILL SFTY P Pre job safety meeting. 09:45 10:00 0.25 103 103 PROD1 DRILL PULD P Load nuke sources. 10:00 10:30 0.50 103 490 PROD1 DRILL PULD P Continue to make up BHA#3. 10:30 12:00 1.50 490 2,373 PROD1 DRILL TRIP P Trip in the hole w/BHA#3 to 2373'. PU wt 65k, SO wt 65k. 12:00 13:30 1.50 2,373 5,663 PROD1 DRILL TRIP P Continue trip in the hole f/2373'to 5663'. PU wt 120k,SO wt 102k. Calculated displacement 36.45 bbls, actual 37.35 bbls. Page 6 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 13:30 00:00 10.50 5,663 6,010 PROD1 DRILL DDRL P Break circualtion once in open hole, pumping 7 bpm w/2100 psi. Begin sliding @ 5745'to clear BHA of window(TOW 5712', BOW 5725') BHA went through window w/no problems. Directional drill 6"x7"intermediate hole w/1.75 deg bend SperryDrill motor f/5745'to 6010'.ADT=6.03 hrs,AST 4.48 hrs,ART 1.55 hrs. PU wt 122k,SO wt 105k, Rot wt 115k. Torque on 3-5k ftlbs,torque off bottom 3k ft lbs. ECD's 10.36 ppg. 01/13/2011 Continue directional drilling 6"x 7"intermediate hole w/1.75 deg motor f/6010'to 6977'(6045'TVD). 00:00 12:00 12.00 6,010 6,466 PROD1 DRILL DDRL P Continue to directional drill 6"x 7" intermediate hole w/1.75 deg bend motor f/6010'to 6466'(5742'TVD). ADT=8.65 hrs,ART=1.65 hrs,AST= 7.0 hrs.Total jar hrs 14.68. PU wt 125k,SO wt 110k, Rot wt 121k, torque on 4k,torque off bottom 3k ft lbs. ECD's 11.11ppg. Pumping 280 gpm w/2100 psi. Rotate 70 rpm. 12:00 00:00 12.00 6,466 6,977 PROD1 DRILL DDRL P Continue to directional drill 6"x7" intermediate hole f/6466'to 6977' (6045'TVD).ADT=8.74 hrs,ART= / 5.83 hrs,AST=2.91 hrs.Total jar hrs ✓ 23.42. PU wt 126-130k,SO wt 108-109k, Rot wt 120k,torque on 4 to 5k,torque off bottom 3k ft lbs. ECD's 11.31 ppg. Pumping 280 gpm w/2100 to 2550 psi. Rotate 70 rpm. 01/14/2011 Continue directional drilling 6"x 7"intermediate hole w/1.75 deg motor f/6977'to TD @ 7860'(6570'TVD). Obtain survey and SPR's.Circulate 2 BU,drop ball,open MI Swaco circ sub,circ 3.4 BU,drop ball to close circ sub,monitor well-static, POOH to 5900',drop ball to open circ sub,circ 2 BU w/sub inside of 7"casing, drop ball to close circ sub, RIH f/5900'to 7200',taking weight,packing off. PU a working single f/pipe shed. Make a top drive connection. Ream 7168'to 7180',taking weight,packed off,obtain circulation(180 gpm w/ 1300 psi)and rotation(30 rpm w/3k ft lbs of torque). 00:00 12:00 12.00 6,977 7,634 PROD1 DRILL DDRL P Continue to directional drill 6"x7" intermediate hole f/6977'to 7634' (6433'TVD).ADT=8.58 hrs,ART= 5.41 hrs,AST=3.17 hrs.Total jar hrs 32. PU wt 130-135k,SO wt 109k, Rot wt 120-125k,torque on 5k, torque off bottom 3k ft lbs. ECD's 11.5 ppg. Pumping 280 gpm w/2550-2700 psi. Rotate 70 rpm. Page 7 of 37 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 12:00 15:45 3.75 7,634 7,860 PROD1 DRILL DDRL P Continue to directional drill 6"x7" intermediate hole f/7634'to 7860' (6570'TVD).ADT=2.74 hrs,ART= 1.71 hrs,AST=1.03 hrs.Total jar hrs 34.74.PU wt 145k,SO wt 110k, Rot wt 125-127k,torque on 4-5k,torque off bottom 4k ft lbs. ECD's 11.51 PPg• Pumping 280 gpm w/2550-2525 psi. Rotate 80 rpm. 15:45 16:00 0.25 7,860 7,860 PROD1 DRILL CIRC P Obtain final survey,obtain SPR's. 16:00 17:00 1.00 7,860 7,860 PROD1 DRILL CIRC P Circulate 2.5 bottom's up, pumping 330 gpm w/3100 psi. Rotate 80 rpm w/4k ft lbs of torque.Circulated 508 bbls. 17:00 17:15 0.25 7,860 7,860 PROD1 DRILL CIRC P Break off the top drive,drop a 1.76" OD steel ball to open the MI Swaco Commander circ sub. Pump ball down 80 gpm w/400 psi. Rotate 50 rpm w/4k ftlbs.Once ball on seat, stage pressure up,sheared and opened circ sub w/3000 psi.Confirm sub is open. 17:15 18:30 1.25 7,860 7,860 PROD1 DRILL CIRC P With circ sub open,circulate @ 400 gpm w/1900 psi, rotate 50 rpm w/ 3.5k ft lbs of torque.Circulate till shakers clean up.Work pipe from 7860'to 7820'.Circulated 677 bbls, . 18:30 18:45 0.25 7,860 7,860 PROD1 DRILL CIRC P Break off the top drive,drop a 1.76" OD steel ball to close the MI Swaco Commander circ sub. Pump ball down 80 gpm w/200 psi.Once ball on seat,stage pressure up f/1500 psi in 500 psi increaments waiting 30 seconds each time,sheared and closed circ sub w/3225 psi.Confirm ✓ sub is closed. 18:45 19:15 0.50 7,860 7,860 PROD1 DRILL CIRC P Obtain SPR's.Then bring pumps up to drilling rate. Pumping 82 spm w/ 2350 psi. Rotate 50 rpm w/4k ftlbs of torque. ECD's 11.25ppg after circulateing. ECD's were 11.55 before circulating. Pressure was 2450 psi. 19:15 19:30 0.25 7,860 7,860 PROD1 DRILL OWFF P Monitor well-static. 19:30 19:45 0.25 7,860 7,822 PROD1 DRILL OTHR P Stand back a stand. Blow down the top drive. 19:45 21:00 1.25 7,822 5,900 PROD1 DRILL TRIP P Trip out of the hole f/7822'to 5900'. Monitor well on the trip tank. Calculated fill 10.8 bbls,actual 11.5 bbls. Page 8 of 37 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:30 0.50 5,900 5,900 PROD1 DRILL CIRC P Make a top drive connection. Break circulation. Break off the top drive, drop a 1.76"OD steel ball to open the MI Swaco Commander circ sub. Pump ball down 80 gpm w/370 psi. Once ball on seat(235 strokes), stage pressure up,sheared and opened circ sub w/3000 psi.Confirm sub is open. 21:30 22:00 0.50 5,900 5,900 PROD1 DRILL CIRC P Circulate 400 gpm w/1400psi, rotate 50 rpm w/3k ft lbs of torque. Reciprocaate f/5900'to 5871'.Circ sub is above the window.Circulated 2 BU and casing is clean. 22:00 22:30 0.50 5,900 5,943 PROD1 DRILL CIRC P Break off the top drive,drop a 1.76" OD steel ball to close the MI Swaco Commander circ sub. Pump ball down 80 gpm w/200 psi.Once ball on seat(245 strokes),stage pressure up f/1500 psi in 500 psi increaments waiting 30 seconds each time,sheared and closed circ sub w/2650psi.Confirm sub is closed. Blow down the top drive. 22:30 23:15 0.75 5,943 7,200 PROD1 DRILL TRIP P Trip in the hole f/5943'to 7200'. Obtain T&D while run in the hole. Took 20k weight and 25k overpull @ 7200'.Attempt to work through 3 times,no success. PU wt 140k,SO wt 102k. 23:15 00:00 0.75 7,200 7,168 PROD1 DRILL REAM T Make a top drive connection. Establish circulation, slack off to ream 7168'to 7180'.Took weight, stalled string,packed off. Rack back the stand,pick up a working single of 4"drill pipe from the pipe shed. Established circulation,then rotate 30 rpm w/3k ftlbs of torque. Pumping 180 gpm w/1300 psi. 01/15/2011 Circulating(180 gpm w/1300 psi)and rotation(30 rpm w/3k ft lbs of torque),stage pumps up to 280 gpm w/ 2340 psi,recip f/7168'to 7108'. UD working joint to the pipe shed,make a connection and attempt to run in on elevators,took wt @ 7298'. Reamed and back reamed to 7441'. RIH on elevators f/7441'to tag bottom @ 7860'-no fill.Circulate and weight up f/10.+to 10.4 ppg,monitor well-static. Pump out f/7860'to 6510', continue to POOH to 6039',monitor well-static.Trip in the hole f/6039'to 7860'-no problems-no fill.Circulate 2 bottom's up,monitor well-static,pump out of the hole f/7860'to 6603', POOH on elevators f/6603'to 5663' (no problems w/window),monitor well-static,pump dry job,con't to POOH to 492'(HWDP),monitor well- static,stand back HWDP and jars. PJSM,stand back flex collars, remove nuke sources,download MWD, stand back MWD,break bit, UD motor.Clean floor,flush stack, pull wear bushing,set test plug,test upper pipe rams(250/3500)and annular(250/2500),set wear bushing, R/D testing equipment. Rig up to run 5-1/2" liner. 00:00 01:15 1.25 7,168 7,168 PROD1 DRILL CIRC T Continue to circulate and rotate 30 rpm w/3k ftlbs of torque.Stage up f/ 180 gpm w/1300 psi,to 280 gpm w/ 2340 psi. Reciprocate f/7168'to 7108'. Page 9 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:15 02:00 0.75 7,168 7,225 PROD1 DRILL REAM T Lay down the joint of 4"drill pipe (working single)to the pipe shed. Make a top drive connection.Work stand#72 reaming down,then backreaming to cleanup hole f/7168' to 7225'. Pumping 280 gpm w/2340 psi. 02:00 03:45 1.75 7,225 7,348 PROD1 DRILL REAM T Attempt to run stand#73 f/7255'. Took weight(15 to 20k)@ 7298'. Make a top drive connection,then backream. Packed off at the top of the stand(stand 72 in the hole). Establish circulation,then stagged pumps to 280 gpm w/2450 psi. Ream and back ream two more times until cleared up.Slacked off f/ 7225'to 7348'with out pumps,SO wt 103 to 95k. 03:45 04:30 0.75 7,348 7,441 PROD1 DRILL REAM T Attempt to run stand 74 in the hole. Took weight @ 7360'.Make a top drive connection,then ream down w/ 213 gpm and 1500 psi, rotate 50 rpm w/3-4k ft lbs of torque. Backream f/ 7441'to 7348'pumping 280 gpm w/ 2360 psi,70 rpm w/4k ft lbs of torque. Run stand#74 in the hole w/ no pump,ok. 04:30 04:45 0.25 7,441 7,820 PROD1 DRILL TRIP P Latch up and run in the hole on elevators f/7441'to 7820. No problems.SO wt 105k. 04:45 05:00 0.25 7,820 7,860 PROD1 DRILL TRIP P Make a top drive connection on stand#79. Slack off and tag bottom @ 7860'. No fill on bottom. PU wt 140k,SO wt 108k. 05:00 08:00 3.00 7,860 7,860 PROD1 DRILL CIRC P Circulate and weight up f/10+ppg to 10.4 ppg. Pumping 280 gpm w/2450 psi. Rotate and reciprocate f/7860' to 7815'. 08:00 08:15 0.25 7,860 7,860 PROD1 DRILL OWFF P Obtain SPR's w/10.4 ppg. Monitor well-static. 08:15 10:30 2.25 7,860 6,510 PROD1 DRILL WPRT P Pump out of the hole f/7860'to 6510'. Pumping 140 gpm w/800 psi. PU wt 155k,SO wt 110k.Calculated fill 8.7 bbls, actual 19.5 bbls. 10:30 10:45 0.25 6,510 6,039 PROD1 DRILL WPRT P Continue to pull out of the hole on elevators f/6510'to 6039'. PU wt 120k,SO wt 105k.Calculated fill 2.7 bbls,actual 2.7 bbls. 10:45 11:00 0.25 6,039 6,039 PROD1 DRILL OWFF P Monitor well-static. 11:00 12:00 1.00 6,039 7,074 PROD1 DRILL WPRT P Trip in the hole f/6039'to 7074'. PU wt 125k,SO wt 115k. 12:00 12:30 0.50 7,074 7,860 PROD1 DRILL WPRT P Continue trip in the hole f/74074'to 7860'.Tagged on depth, no fill. Calculated displacement 10.8 bbls, actual 10.8 bbls. Page 10 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:30 13:30 1.00 7,860 7,860 PROD1 DRILL CIRC P Circulate 2 bottom's up. Pumping 280 gpm w/2500 psi. Rotate 70 rpm w/4k ft lbs of torque. Reciprocate 7860'to 7815'. 13:30 13:45 0.25 7,860 7,825 PROD1 DRILL OWFF P Set back a stand,Monitor well- static. 13:45 15:30 1.75 7,825 6,603 PROD1 DRILL TRIP P Pump out of the hole f/7825'to 6603'. Pumping 280 gpm w/2400 psi. 15:30 16:15 0.75 6,603 5,663 PROD1 DRILL TRIP P Pull out of the hole on elevators f/to 5663'. No problems pulling through window. 16:15 16:30 0.25 5,663 5,663 PROD1 DRILL OWFF P Monitor well-static. 16:30 16:45 0.25 5,663 5,663 PROD1 DRILL CIRC P Pump a dry job. Blow down the top drive. 16:45 18:30 1.75 5,663 492 PROD1 DRILL TRIP P Continue to pull out of the hole on elevators f/5663'to the HWDP @ 492'. 18:30 18:45 0.25 492 492 PROD1 DRILL OWFF P Monitor well-static. 18:45 19:00 0.25 492 207 PROD1 DRILL TRIP P Stand back the HWDP and jars. Lay down MI Swaco circ sub. 19:00 19:15 0.25 207 207 PROD1 DRILL SFTY P PJSM on BHA and nuke sources 19:15 19:30 0.25 207 145 PROD1 DRILL TRIP P Stand back a stand of flex collars. 19:30 19:45 0.25 145 70 PROD1 DRILL PULD P Remove nuke sources. 19:45 20:45 1.00 70 70 PROD1 DRILL PULD P Download Sperry Sun MWD. 20:45 21:00 0.25 70 35 PROD1 DRILL TRIP P Stand back Sperry Sun MWD. 21:00 21:15 0.25 35 0 PROD1 DRILL PULD P Break Reed Hycolog 6"x 7"bi center bit, lay down Sperry Sun motor(1.75 deg). 21:15 21:45 0.50 PROD1 WHDBO OTHR P Flush stack w/stack washing tool. 21:45 22:00 0.25 PROD1 WHDBO OTHR P Pull FMC wear bushing. 22:00 22:30 0.50 PROD1 WHDBO RURD P Rig up to test w/5-1/2"test joint. 22:30 23:30 1.00 PROD1 WHDBO BOPE P Test top pipe rams(3-1/2"x 6")to 250 psi low and 3500 psi high,test annular to 250 psi low and 2500 psi high. Hold each test f/5 minutes. Chart test. 23:30 23:45 0.25 PROD1 WHDBO OTHR P Set wear bushing(ID 6 3/8"). R/D test equipment. 23:45 00:00 0.25 COMPZ CASING RURD P Rig up to run 5-1/2"liner. Page 11 of 37 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01/16/2011 24 hr Summary PJSM,con't to rig up casing tools, PJSM, run liner per detail.Make up Baker liner hanger and liner top packer,mix and pour pal mix in top of liner,run a stand of 4"drill pipe,circ,con't to run liner on drill pipe f/ 2472'to 5670',circulate 60 bbls(a little over liner volume)@ 4.17 bpm w/900 psi.Continue to RIH w/5-1/2" liner f/5670'to 7830', PU a single of 4"drill pipe,MU Baker cementing head,circulate,circulate,staging pumps up f/30 gpm w/450 psi to 55 gpm w/550 psi,then 83 gpm w/650 psi. Hole packing off while pumping 83 gpm.Shut down pumps,work pipe f/75k to 175k with and without pumps. No success. Pump 86 gpm trying to establish circulation. Lost returns @ 1345 hrs.Continue to work pipe f/195k to 75k. Pump down the annulus,broke down at 1000 psi,injection rate of 13 gpm w/900 psi. Injected 12 bbls.Then try to pump down the liner,stage pumps f/13 gpm w/475-pressure increased to 720 psi, increased rate to 42 gpm w/880 psi, lost returns again.Attempting to regain circulation w/no success. Lost a total of 156.75 bbls of mud to the hole today. 00:00 00:15 0.25 COMPZ CASING SFTY P Pre job safety meeting. 00:15 01:15 1.00 COMPZ CASING RURD P Continue to rig up casing equipment 01:15 01:30 0.25 COMPZ CASING SFTY P Pre job meeting on running 5-1/2" liner. CS� 01:30 02:00 0.50 0 170 COMPZ CASING RUNL P Run casing as follows: Rays silver bullet,2 joints 5-1/2"15.5ppf L-80 ST-L casing,weatherford model 402 float collar,one joint of 5-1/2"15.5 ppf L-80 ST-L casing,next joint of ST-L has a Baker insert landing collar 1.5'up from the pin end.All of these joints were baker locked.All were torqued to 2500 ft lbs of torque. 02:00 02:15 0.25 170 170 COMPZ CASING CIRC P Circulate 15 bbls of fluid through the float equipment. Pump 2 bpm w/120 psi. 02:15 02:30 0.25 170 170 COMPZ CASING RURD P Rig down circulating equipment. 02:30 05:45 3.25 170 2,340 COMPZ CASING RUNL P Continue to run liner as follows:21 more joints of 5-1/2"15.5 ppf L-80 ST-L casing,crossover joint(ST-L pin x HD-L box),31 joints of 5-1/2" 15.5 ppf L-80 HD-L casing. Calculated displacement 12.5 bbls, actual 11 bbls. PU wt 63k,SO wt 63k. Used Jet Lube Seal guard dope. Torqued the ST-L to 1500 ft lbs, torqued the HD-L to 2250 ft lbs. Unique Machine shop rep Tristan on location. 05:45 07:00 1.25 2,370 2,374 COMPZ CASING RUNL P Pick up Baker 5.5"x 7"liner hanger and 5.5"x 7""ZXPN liner packer. Make up wiper to the bottom. Make up hanger.Slack off. Mix pal mix and allow to set up. SO wt with blocks 63k. Blocks 35k. 07:00 07:30 0.50 2,374 2,472 COMPZ CASING RUNL P Make up first stand of 4"drill pipe onto the liner running tool. Installed 3-1/2"IF x 4"XT39 crossover. 07:30 07:45 0.25 2,472 2,472 COMPZ CASING CIRC P Circulate 2 bpm w/400 psi,total of 15 bbls pumped. Blow down the top drive. Page 12 of 37 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:45 10:00 2.25 2,472 5,670 COMPZ CASING RUNL P Continue to run the 5-1/2"15.5 ppf L-80 liner f/2472'to 5670'. Record PU and SO wt's. PU wt 107k,SO wt 90k. 10:00 10:30 0.50 5,670 5,670 COMPZ CASING CIRC P Circulate @ 5670', 35 stands 4"dp in the hole(above the window). Pumping 4.17 bpm(175 gal/min) w/ 900 psi,total of 60 bbls pumped. Blow down the top drive. 10:30 12:00 1.50 5,670 6,986 COMPZ CASING RUNL P Continue to run the 5-1/2"15.5 ppf L-80 liner f/5670'to 6986'. Record PU and SO wt's. PU wt 107k,SO wt 90k. 12:00 12:45 0.75 6,986 7,830 COMPZ CASING RUNL P Continue to run the 5-1/7"15 5 ppf L-80 liner f/6986'to 7830' Calculated displacment 42.25 bbls, actual 31.8 bbls. 12:45 13:00 0.25 7,830 7,830 COMPZ CASING RUNL P Pick up a single of 4"drill pipe f/the pipe shed. Make up Baker cement head.Tag bottom @ 7860'. 13:00 13:30 0.50 7,830 7,860 COMPZ CEMEN"CIRC P Circulate,staging pumps up f/30 gpm w/450 psi to 55 gpm w/550 psi,then 83 gpm w/650 psi. 13:30 17:30 4.00 7,860 7,860 COMPZ CEMEN"OTHR T Hole packing off while pumping 83 gpm.Shut down pumps,work pipe f/ 75k to 175k with and without pumps. No success. Pump 86 gpm trying to establish circulation. Lost returns @ 1345 hrs.Continue to work pipe f/ 195k to 75k. Pump down the annulus,broke down at 1000 psi, injection rate of 13 gpm w/900 psi. Injected 12 bbls.Then try to pump down the liner,stage pumps f/13 gpm w/475-pressure increased to 720 psi, increased rate to 42 gpm w/ 880 psi, lost returns again. 17:30 19:30 2.00 7,860 7,860 COMPZ CEMEN"OTHR T Pump down the annuls 25 gpm w/ 1000 psi f/25 bbls pumped.bleed back,open well,establish circulation 14 gpm w/400 psi,staged up to 42 gpm w/500 psi(30 bbls total pumped). after a total of 50 bbls pumped, increased rate to 53 gpm w/ 540 to 500 psi,3%returns on TOTCO.After pumping 60 bbls, increased rate to 71 gpm w/680 psi, then packed off again. 19:30 22:15 2.75 7,860 7,860 COMPZ CEMEN"OTHR T Pump 5 bbls down the casing @ 32 gpm w/940 psi.,try to pump down the string @ 14 gpm-pressured up to 610 psi w/no returns,then pumped again down the annulus 10 bbls @ 25 gpm w/950 psi,bleed off pressure,then pumped down the stringl l gpm-pressured up to 680 psi,shut down and slowly bled off to 500 psi w/slight returns. Page 13 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:45 0.50 7,860 7,860 COMPZ CEMEN"OTHR T Pumped 25 bbls down the annulus again. Pumping 39 gpm w/1000 psi. bleed off pressure. 22:45 00:00 1.25 7,860 7,860 COMPZ CEMEN"OTHR T Attempt to pump down the string, stage up f/11 gpm to final of 21 gpm w/810 psi.Slight to no return. Total fluid lost to hole today: 10.75 bbls while running casing, 146 bbls while attempting to circulate=Total of 156.75 bbls lost to the hole today. 01/17/2011 Continue to attempt to circulate and work pipe-no success, release f/liner,pick up 35',circulate 2 bottom's up, monitor well,obtain SPR's, PJSM,slip and cut drill line, monitor well-static, POOH f/5490'to 32', break and lay down running tool, PJSM, RIH to 440'w/drilling BHA, POOH and lay down same,clear floor,service rig, perform work orders while mobilizing e line crew. Rig up lubricator and bring tools to the floor.Set lubricator in the hole,change plans,pull lubricator out and lay down on the floor. Rig up to lay down 22 stands of excess drill pipe f/the derrick. Lay down 22 stands via the mousehole. Install thread protectors and remove f/pipe shed.Work on work orders while Baker re-dress's the"HRD running tool to latch back into the liner. 00:00 01:00 1.00 7,860 7,860 COMPZ CEMEN"OTHR T Continue to try and establish circulation,working pipe f/f/175k to 90k. Holding 500 psi on string w/ very little flow. Bleed to 100 psi,work string several times f/195k to 80k w/ slight returns. Bleed off pressure. Work string several more times w/no change. Pressure string to 500 psi, allow to bleed off to 375 psi. Bled off string to zero. 01:00 01:15 0.25 7,860 5,523 COMPZ CEMEN"OTHR T Release from liner hanger per Baker rep. PU to 115k,work down a round of left hand torque.Apply another round of left hand torque.Work torque down. Slack off to 90k and observed shear/release. Pick up to 115k-free of liner. 01:15 01:30 0.25 5,523 5,493 COMPZ CEMEN"PULD P Lay down Baker cement head and a single of drill pipe to the pipe shed. 01:30 02:30 1.00 5,490 5,490 COMPZ CEMEN"CIRC P Circulate 2 bottom's up. Pumping 330 gpm w/1100 psi. Pumped 296 bbls.Obtain slow pump rates. Note:Observed 10.6 ppg fluid w/66 vis fluid initial, muck mixture of LCM,fine shale,and chunks of cuttings. Hole was clean after circulation. 02:30 03:00 0.50 5,395 5,395 COMPZ CEMEN"TRIP P Stand back a stand. Pre job safety meeting on cutting drilling line. 03:00 04:00 1.00 5,395 5,395 COMPZ RIGMNT SVRG P Slip and cut 72'of 1-1/2"drilling line. 04:00 04:30 0.50 5,395 5,395 COMPZ CEMEN"PULD P Pick up tools to the floor. 04:30 04:45 0.25 5,395 5,395 COMPZ CEMEN"OWFF P Monitor well-static. 04:45 06:00 1.25 5,395 32 COMPZ CEMEN"TRIP P Pull out of the hole with the Baker liner running tool f/5395'to 32'. Calculated displacement 31.3 bbls, actual 34 bbls. Page 14 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 32 0 COMPZ CEMEN"PULD P Lay down Baker liner running tool. 06:30 06:45 0.25 0 0 COMPZ CEMEN"SFTY P Pre job safety meeting. 06:45 07:30 0.75 0 440 COMPZ DRILL TRIP P Trip in the hole w/Sperry Sun MWD and 4"HWDP. 07:30 08:30 1.00 440 0 COMPZ DRILL PULD P Pull out of the hole laying down NMDC', HWDP,Jars. 08:30 09:00 0.50 COMPZ DRILL PULD P Lay down tools from the rig floor. 09:00 09:30 0.50 COMPZ RIGMNTSVRG P Lubricate rig. 09:30 15:15 5.75 COMPZ RIGMN1 SVRG T Stand by f/e line. Perform rig work orders:Top drvie gear oil and hydraulic filter change,adjust stand jump,check nitrogen pre charge. Blow down the kill line. Fix wind sock. 15:15 18:00 2.75 COMPZ CEMEN"RURD T Rig up Halliburton e line. Pick up tools and equipment from the beaver slide to the floor.Set lubricator extension in the rotary table.Change of plans,pull lubricator from rotary table. 18:00 20:15 2.25 COMPZ DRILL PULD P Rig up to lay down excess 4"drill pipe from the derrick(22 stands). Lay down 22 stands of 4"dp from the derrick via the mouse hole. Left 58 stands of 4"in the derrick. 20:15 00:00 3.75 COMPZ RIGMNT SVRG T Install box end protectors in the pipe shed. Remove excess 4"drill pipe from the pipe shed.Work on work orders: assemble drag chain f/trough in the pits.Monitor well on the trip tank. Note:Total of 6 bbls lost in last 24 hours.Total fluid lost to hole=162.75 hrs. 01/18/2011 Continue to work on work orders while Baker re-dress's the"HRD running tool to latch back into the liner, PU/MU Baker"HRD"running tool, RIH on 4"dp to 2000',circ, con't RIH to 5479',CBU, PU a single 4"dp, engage liner,pull test to 150k,set in slips w/90k. Rig down drilling bales, RU long casing bales, RU Halliburton pressure control, unable to latch onto pipe, re-configure, RIH w/freepoint toolstring to 7780', PU liner to 195k three times,set back in slips to 90k. Log 7780'to 6580', POOH w/toolstring, R/D wireline, change bales, release f/liner w/Baker tool,CBU,monitor well-static, BD top drive, LID single dp, POOH LID Baker running tool, clear floor, PJSM, RU halliburton e-line to perferate 5-1/2"liner, RIH w/2-3/4"5'perf gun loaded 6spf and CCL,depth at midnight 5500'. 00:00 00:15 0.25 COMPZ RIGMNT SFTY P Pre job safety meeting. 00:15 01:30 1.25 COMPZ RIGMNT SVRG T Work on work orders:assemble drag chain f/trough in the pits. Monitor well on the trip tank.Waiting on Baker Oil Tools"HRD"running tool to engage liner and perform e-line free point. 01:30 02:00 0.50 COMPZ CASING PULD T Pick up/Make up Baker"HRD running tool to engage the 5-1/2" liner(Top @ 5491') Page 15 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:00 03:00 1.00 0 2,000 COMPZ CASING TRIP T Run in the hole w/Baker"HRD"liner running tool to 2000'. Pipe running over w/mud. 03:00 04:00 1.00 2,000 2,000 COMPZ CASING CIRC T Circulate,pumping 300 gpm w/400 psi.Circulated 212 bbls. 04:00 05:30 1.50 2,000 5,479 COMPZ CASING TRIP T Continue to run in the hole w/Baker "HRD"liner running tool f/2000'to 5479'. 05:30 07:00 1.50 5,479 5,479 COMPZ CASING CIRC T Circulate bottom's up @ 5479'. Pumping 330 gpm w/800 psi. PU wt 104k. 07:00 07:30 0.50 5,479 7,860 COMPZ CASING FISH T Pick up a single 4"dp f/the pipe shed. Make a top drive connection. Slack off and no-go w/"HRD"running tool 11'below the top of the liner, engage collet w/the mule shoe15.58' below the top of liner(5507'). Set down to 85k,work 1 turn of RH torque down, PU and pull to 115,SO to 85k, Pull test twice to 150k.then slack off to 90k. 07:30 08:00 0.50 7,860 7,860 COMPZ EVALWE RURD T Rig down the short bales, rig up the longer bales to the top drive. 08:00 08:15 0.25 7,860 7,860 COMPZ EVALWE SFTY T Pre job safety meeting w/Halliburton e-line and rig crew. 08:15 10:00 1.75 7,860 7,860 COMPZ EVALWE RURD T Riq up Halliburton e line to run magnetic freepoint. Hang sheave at the collar finger in the derrick. 10:00 12:00 2.00 7,860 7,860 COMPZ EVALWE RURD T Unable to latch elevators on the drill string w/pressure control as rigged up. Rig down packoff and pump-in assembly. Reconfigure with headpin, valve,and pump-in assembly. 12:00 14:15 2.25 7,860 7,860 COMPZ EVALWE ELOG T Run in the hole w/Halliburton 1-11/16"OD freepoint tool string, 22.35'long on 7/32"wire to 7780' WLM. Toolstring: (Rope socket w/1.375" OD fishing neck,weight bar, knuckle joint,weight bar,knuckle joint, weight bar, Dual Effect freepoint tool. Logged w/90k on weight indicator, then set in slips. 14:15 14:30 0.25 7,860 7,860 COMPZ EVALWE ELOG T Pick up on pipe to 195k,SO to 95k three times.Set string in the slips w/90k on weight indicator. 14:30 17:00 2.50 7,860 7,860 COMPZ EVALWE ELOG T Halliburton log well f/7780'to 6580', Pull out of the hole w/e-line and freepoint toolstring. Note:5-1/2"liner appears stuck at , 6740'to 6760'. 17:00 18:00 1.00 7,860 7,860 COMPZ EVALWE RURD T Rig down e-line equipment,change out bales to short drilling bales,clear tools and equipment f/floor. 18:00 18:15 0.25 7,860 5,507 COMPZ CASING OTHR T Release from 5-1/2"liner w/Baker "HRD"running tool.Two turns of LH hand torque worked down.After release, PU wt 104k. Page 16 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:15 18:45 0.50 5,507 5,507 COMPZ CASING CIRC T Circulate bottom's up,pumping 180 gpm w/450 psi. 18:45 19:00 0.25 5,507 5,507 COMPZ CASING OWFF T Monitor well-static. 19:00 19:15 0.25 5,507 5,479 COMPZ CASING PULD T Blow down the top drive. Lay down a single 4"drill pipe to the pipe shed. 19:15 20:15 1.00 5,479 27 COMPZ CASING TRIP T Pull out of the hole w/Baker running tool f/5479'to 37'. 20:15 20:30 0.25 27 0 COMPZ CASING PULD T Lay down Baker"HRD running tool, clean and clear floor. 20:30 20:45 0.25 0 COMPZ CASING SFTY T Pre job safety meeting on rigging up Halliburton a-line to perferate the 5-1/2"liner. 20:45 23:15 2.50 COMPZ CASING RURD T Rig up lubricator, rig up wireline tools,7/32"wire. Toolstring: (Rope socket w/1.375" OD fishing neck,(2)1-11/16"5' weight bars,2-1/8"CCL,2-3/4"perf gun loaded w/6 shots/ft f/5'(30 shots total). 23:15 00:00 0.75 0 5,500 COMPZ CASING ELOG T Run in the hole w/perferating toolstring. Depth at midnight 5500'. 01/19/2011 Continue to RIH w/2-3/4"5'perf gun loaded 6spf and CCL f/5500'to tag insert float collar @ 7731',correlate wI depth,perforate 7730'to 7725', POOH w/logging tools-logging 5-1/2"liner connections, PJSM, Remove spent guns from well, MU gun run#2, RIH to perforate 7180'to 7175',correlate f/7407'to 6873'CCL,drop down to 7341', PU to 7172'CCL,shoot perfs f/7175'to 7180', POOH w/perf gun#2,all shots fired, R/D e-line, RU casing tongs, PJSM, PU Baker K-1 cement retainer on 3-1/2"PH-6 work string to 2347',change handling tools, RIH on 4"Dp,tag insert FC at 7729', PU to 7714',set cement retainer,CBU,sting into retainer,establish circulation,packed off after pumping 106 bbls,attempting to re-establish circulation. 00:00 00:45 0.75 5,500 7,731 COMPZ CASING ELOG T Continue to RIH w/2-3/4"5'perf gun loaded 6spf and CCL f/5500'to tag insert float collar @ 7731'. 00:45 01:00 0.25 COMPZ CASING ELOG T Correlate wl depth. 01:00 02:00 1.00 7,731 0 COMPZ CASING PERF T Perforate 7730'to 7725', POOH w/ logging tools-logging 5-1/2"liner connections. 02:00 02:15 0.25 0 0 COMPZ CASING ELOG T PJSM on pert guns. 02:15 02:45 0.50 0 0 COMPZ CASING ELOG T Remove spent guns from well.All 30 shots fired. 02:45 03:15 0.50 0 0 COMPZ CASING ELOG T MU gun run#2. 03:15 04:00 0.75 0 7,416 COMPZ CASING ELOG T RIH w/perf gun#2 to perf 7180'to 7175'. RIH w/toolstring to ccl depth of 7407'. 04:00 04:30 0.50 7,416 6,882 COMPZ CASING ELOG T Correlate wl depth. Pass f/7407'to 6873'CCL. Adjust depth to match log out w/gun#1. 04:30 04:45 0.25 6,873 7,180 COMPZ CASING PERF T Drop down to 7341'CCL, PU to 7172' CCL depth. Perforate 7180'to 7175' ()Al 04:45 06:00 1.25 7,180 0 COMPZ CASING ELOG T POOH w/logging tools f/7172'CCL to surface. 06:00 06:15 0.25 0 0 COMPZ CASING ELOG T Remove spent guns from well.All 30 shots fired. 06:15 08:00 1.75 0 0 COMPZ CASING RURD T Rig down a-line equipment.Open blind rams. Fill hole 08:00 08:30 0.50 0 0 COMPZ CASING OTHR T Clear and clean rig floor. Page 17 of 37 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:30 09:00 0.50 0 0 COMPZ CEMEN-RURD T Rig up Doyon casing tools(Double stack tongs)to PU/MU 75 joints of 3-1/2" 12.95 ppf P110 PH-6 work string. 09:00 09:15 0.25 0 0 COMPZ CEMEN'SFTY T Pre job safety meeting on picking up work string and running in the hole w/ cement retainer. 09:15 10:00 0.75 COMPZ CEMEN'PULD T Pick up,then make up Baker K-1 cement retainer. 10:00 10:30 0.50 COMPZ RIGMNT SVRG P Load test and certify the casing stabbing board in the derrick. 10:30 12:00 1.50 0 380 COMPZ CEMEN'PULD T Run in the hole w/cement retainer on 3-1/2"12.95 ppf L-80 PH-6 work string to 380'. Picking up pipe f/pipe shed. Using double stack tongs 12:00 12:30 0.50 380 380 COMPZ RIGMNT SVRG P Crew change and service rig 12:30 14:00 1.50 380 2,347 COMPZ CEMEN'PULD T Continue to run in the hole w/ cement retainer on 3-1/2"12.95 ppf L-80 PH-6 work string from 380'to 2347. Picking up pipe f/pipe shed. Usning double stack tongs.75 joints picked up. 14:00 14:15 0.25 2,347 2,347 COMPZ CEMEN'RURD T Change handling equipment. 14:15 17:15 3.00 2,347 7,704 COMPZ CEMEN'TRIP T Continue to RIH w/retainer on 4" drillpipe f/the derrick f/2347'to 7704'. 17:15 17:30 0.25 7,704 7,714 COMPZ CEMEN'OTHR T Pickup a single and tag the insert landing collar @ 7729'. PU 15',apply 10 rounds of RH torque,slack off,set retainer(a)7714'. PU to 160k,SO to 70k.Confirm retainer is set, PU to 160k, SO to 70k. PU to 165, unsting f/cement retainer.Weight indicator dropped off to 102k.Again confirm set by circulating 70 gpm w/400 psi w/returns.Sting back into retainer- pump 25 gpm w/380 psi w/no returns.Calculated displacement f/ trip 40.45 bbls,actual 39.75 bbls. 17:30 18:00 0.50 7,714 7,714 COMPZ CEMEN'RURD T Rig up to circulate with the 2" cementing hose. 18:00 19:15 1.25 7,714 7,714 COMPZ CEMEN'CIRC T Circulate bottom's up,2 bpm w/480 psi,stage up to 4 bpm w/900 psi, 36%flow out. PU wt 125k, SO wt 104k. Page 18 of 37 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment �' 19:15 21:00 1.75 7,714 7,714 INTRM1 CEMEN"CIRC T Sting into Baker K-1 cement retainer o (set down to 85k on weight indicator),establish circulation 3 spm(11 gpm)w/160 psi. Increase pump rate to 4 spm(14 gpm)w/190 psi after 5 bbls, increase rate to 7 spm(25gpm)w/230 psi-pumped 10 bbls at this rate, increased rate to 12 spm(1 bpm)-350 psi-3-4%flow on Totco-pumped 15 bbls at this rate, increased rate to 15 spm(53 gpm) w/450 psi-10%Totco flow-pumped 15 bbls at this rate,increased rate to 20 spm(71 gpm)w/760 to 820 psi w/16%Totco flow-pumped 49 bbls at this rate, increased rate to 24 spm (85gpm)w/950 psi 18%flow.After 12.3 bbls pumped,pressure increased to 1120 psi,lost returns. Shut down pumps, bleed off pressure to zero. Pumped a total of 106 bbls with returns. 21:00 21:45 0.75 7,714 7,709 COMPZ CEMEN"CIRC T Unsting f/cement retainer. Circulate bottom's up,2 bpm w/450 psi 25% Totco flow out. Stage up to 4 bpm w/ 880 psi-35%flow out. 21:45 22:15 0.50 7,709 7,714 COMPZ CEMEN CIRC T Monitor well-static. Sting back into retainer,try to circulate 3 spm, pressured up to 550 psi w/10 strokes,bleed off pressure,attempt again, no success,bleed off pressure. 22:15 23:15 1.00 7,714 7,714 COMPZ CEMEN-CIRC T Lined up to reverse circulate, pressured to 500 psi then up to 800 psi.Stopped every 100 psi after 500 to allow to bleed down.Attempted to reverse circ up to 990 psi. 23:15 00:00 0.75 7,714 7,714 COMPZ CEMEN"CIRC T Pump down the string, pumping 3 spm w/660 psi-no flow. PU wt 124k, SO wt 104k. 01/20/2011 While stung into the Baker K-1 cement retainer @ 7714',attempting to re-establish circulation. No success. Establish injection rates at.25, .5, 1 and 1.5 bpm. Unsting f/retainer,circulate with annular shut taking returns through the choke to hold cement in place while loading up the drill string. PJSM,circ while Dowell prepares to pump. Dowell pump 5 bbl mud push(12.5 ppg),follow w/18.3 bbls"G"cement w/additives(1.16 cuft/sx,mix water 5.094 gal sx,89 sx),follow with 5 bbls water. Rig displace w/10.4 ppg mud,with 1 bbl mud push still in string,slack off through the annular and into the retainer. Bleed off pressure on the back side and open annular,observing no flow on the backside.Squeeze cement through perfs @ 7725'to 7730', pumping.5 bpm w/initial 300 psi and final of 1100 psi final.Shut down with 18.3 bbls cement into retainer. Pickup to unsting f/retainer,circulate to clean dp, rig down circulating equipment, lay down 14'4"pup joint, install nerf ball in string to wipe pipe,circulate up to 330 gpm w/1800 psi. Rig down circ equipment,monitor well-static. POOH w/Baker running tool to 2347',change handling tools, POOH stand back 3-1/2"PH-6 work string(75 joints). L/D tools, make up another Baker K-1 cement retainer, RIH to 2347',change handling tools,con't to RIH on 4"dp to 7165',attempt to set retainer-no success,circulate bottom's up,attempt again with no success. Monitor well,blow down the top drive, POOH f/7165'to 5420',monitor well-static,con't to POOH f/5420'to 4792',service rig. (TOL @ 5491'). Page 19 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 7,714 7,714 COMPZ CEMENT CIRC T While stung into the retainer @ 7714', pump down the string, pumping 2-3 spm w/660-780 psi-no flow. Bleed off pressure.PU wt 124k, SO wt 104k. 00:30 00:45 0.25 7,714 7,714 COMPZ CEMENT CIRC T Change valve alignment to pump down the annulus and take returns up the drill pipe while still stung into the retainer. Pump @ 6 spm(.5 bbl) w/990 increasing to 1040 psi. Pumped 5.58 bbls. 00:45 02:45 2.00 7,714 7,714 COMPZ CEMEN'CIRC T Pump down the string 2 spm w/ pressure increasing to 640 psi-no returns.Continue to pump to get injectivity test. Increase rate to 3 spm(.25 bpm).After pumping 10.7 bbls the pressure was 900 psi. Pumped an additional 7.7 bbls with no returns @.25 bpm,pressure stable 900 to 910 to 890 psi. Pumping at.5 bpm w/940 psi, 1 bpm w/1000 psi, 1.5 bpm w/1060 psi-all with no returns.Shut down after pumping 29 bbls total. Pressure bled down f/1060 psi to 320 psi. 02:45 03:00 0.25 7,714 7,710 COMPZ CEMENT CIRC T Rig down circulating equipment,pull out of retainer.Move the 14.32'pup joint to be below a single.This was done to minimize a tool joint f/ passing through the annular. 03:00 04:45 1.75 7,710 7,710 COMPZ CEMENT CIRC T While unstug f/retainer, line up to circulate w/the annular closed, taking returns through the choke line to the pits. Pumping 2 bpm w/350 psi. PU wt 127k,SO wt 96k w/ annular closed. Calibrated indicator on choke panel to be able to hold back pressure on annulus. 04:45 05:00 0.25 7,710 7,710 COMPZ CEMENT CIRC T Pre lob safety meeting on cementing 5-1/2"liner,through retainer set at 7714', perfs @ 7725'to 7730',shoe at 7860',perfs at 7175'to 7180'. 05:00 05:30 0.50 7,710 7,710 COMPZ CEMENT CIRC T Circulate while Dowell gets all the ducks lined up. 05:30 06:08 0.64 7,710 7,710 COMPZ CEMENT CMNT T Dowell pump 5 bbls mud push(12.5 ppg)@ 2bpm w/400 psi,shut down. Close choke. Pressure test lines to 3000 psi. Mix up 15.8 ppg cement w/ additives(.2%BWOC D046, .3% BWOC D065, .5%BWOC D167, .2%BWOC D153, .02gal/sx D177). Open choke,then Dowell pumps 18.3 bbls(88.9 sx)Yield 1.16)(mix water 5.094 gal/sx)@ 2 bpm w/320 to 127 psi,followed w/5 bbls of water down the string-2 bpm w/130 psi.Shut choke. Page 20 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:08 06:36 0.47 7,710 7,710 COMPZ CEMEN'CMNT T Open the choke when the rig starts pumping. Rig displaced cement w/ 10.4 ppg mud. Pumping 2 bpm w/ 110 psi initial, and prior to stinging into the retainer the pressure was 210 psi. 06:36 07:16 0.67 7,710 7,710 COMPZ CEMEN'CMNT T Sting into the retainer with 1 bl of mud push left in drill string. Bleed off the annulus pressure and open the annular.Continue to pump at.5 bpm w/initial pressure 300 psi,final of 1100 psi with all the cement pumped through the retainer(18.3 bbls).Shut v I down @ 0716 hrs 1/20/2011.Pick up 11 ILI out of the cement retainer to close valve. 07:16 07:44 0.47 7,710 7,710 COMPZ CEMEN'CMNT T Circulate to clean the drill string. Circulated up 4 bbls of mud push on bottom's up. Pumping 250 gpm w/ 1800 psi. 07:44 07:59 0.25 7,710 7,690 COMPZ CEMEN'RURD T Rig down circulating equipment and lay down a 14'4"pup joint. 07:59 09:29 1.50 7,690 7,690 COMPZ CEMEN'CIRC T Install a wiper nerf ball in the drill string to wipe the drill string. Circulate 2 bottom's up,pumping 250 gpm w/1600 psi. Increase rate to 330 gpm w/1800 psi. 09:29 09:44 0.25 7,690 7,690 COMPZ CEMEN-RURD T Rig down circulating equipment. Blow down lines. 09:44 09:59 0.25 7,690 7,690 COMPZ CEMEN'OWFF T Monitor well-static. 09:59 12:44 2.75 7,690 2,347 COMPZ CEMEN'TRIP T Trip out of the hole w/Baker running tools f/7690'to 2347'. 12:44 13:14 0.50 2,347 2,347 COMPZ CEMEN'RURD T Change out handling tools. Rig up double stack tongs. 13:14 14:14 1.00 2,347 0 COMPZ CEMEN'TRIP T Continue to pull out of the hole w/the 3-1/2"PH6 workstring f/2347'to Baker running tool. Break and lay down tool.Calculated fill 41.28 bbls, actual 43.25 bbls. 14:14 14:44 0.50 0 0 COMPZ CEMEN'OTHR T Clean and clear rig floor. Rig up torque guage on double stack tongs. 14:44 14:59 0.25 0 0 COMPZ CEMEN'SFTY T Pre job safety meeting on running Baker K-1 cementing retainer#2. 14:59 16:29 1.50 2,347 2,347 COMPZ CEMEN"TRIP T _Make up Baker K-1 retainer,run in, the hole on 3-1/2"PH-6 work string to 2347'. 16:29 16:59 0.50 2,347 2,347 COMPZ CEMEN'RURD T Change handling tools. Rig down double stack tongs. 16:59 19:29 2.50 2,347 7,165 COMPZ CEMEN'TRIP T Continue to run in the hole w/Baker K-1 cementing retainer f/2347'to 7140'. Pick up a single 4"drill pipe (31.56'). Make a top drive connection.Calulated displacement 37.5 bbls,actual 37 bbls. Page 21 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:29 20:14 0.75 7,165 7,165 COMPZ CEMEN"OTHR T Attempt to set retainer at 7165'. Made several attempts to rotate and allow the slips to set.Work string f/ 125k PU to 96k down wt.Work f/ 7165'to 7155'. 20:14 21:29 1.25 7,165 7,165 COMPZ CEMEN"CIRC T Circulate bottom's up,pumping 168 gpm w/700 psi.Conditioning mud while circulating. 21:29 21:44 0.25 7,165 7,165 COMPZ CEMEN"OWFF T Blow down the top drive. Monitor well-static. 21:44 22:59 1.25 7,165 5,420 COMPZ CEMEN"TRIP T Pull out of the hole w/Baker K-1 cementing retainer f/7165'to 5420'. 22:59 23:14 0.25 5,420 5,420 COMPZ CEMEN"OWFF T Monitor well @ 5420'-static. 23:14 23:29 0.25 5,420 4,792 COMPZ CEMEN"TRIP T Pull out of the hole w/Baker K-1 cementing retainer f/5420'to 4792' at midnight. 23:29 23:59 0.50 4,792 4,792 COMPZ RIGMNT SVRG P Service rig. 01/21/2011 Con't to POOH w/Baker 5-1/2"K-1 Retainer f/4792'to surface,the retainer is NOT attatched to the running tool,clean floor, L/D running tool,MU another Baker K-1 cementing retainer, RIH to 7231', POOH to 7140', MU a single 4"dp, RIH and set retainer @ 7166', PU to 7160'(unstung from retainer),CBU(4 bpm w/800 psi),spot new mud in the drill string,sting into retainer @ 7166', perform injectivity test, PU 6'to 7160',circ through annular to choke, PJSM, Dowell mix mud push, Dowell pump 5 bbls of mud push(12.5 ppg @ 2 bpm w/337 psi.Shut down.Close choke. Dowell pressure test lines to 3500 psi-good. Dowell mix 10 bbls, 15.8 ppg class"G"cement w/additives(1.16 cuft/sx, mix water 5.094 gal sx,thickening time 4hr 34 min) additives: D046.2%BWOC, .D065.3%BWOC, D167.5%BWOC, D153.2 BWOC, D177.02 gal/sx).Open choke and pump 10 bbls of cement holding @ 2 bpm w/200 to 170 psi,350 to 315 psi back pressure on the choke. Follow cement w/5 bbls of water,still holding 220 to 210 back pressure.Shut choke.Open choke when rig starts displacing cement w/10.4 ppg mud @ 2 bpm w/400 psi,holding 360 psi back pressure.With 47.89 bbls of mud displaced(mudpush @ retainer),slack off to sting into the retainer. Let annulus pressure bleed off,then open annular.Squeeze 5 bbls of mud push pumping 1 bpm w/2000 psi initial, 1825 psi when cement is at the retainer. Pump a total of 9.64 bbls of cement through the retainer,final 1750 psi,bled down to 1440 psi when picking up to unsting and close valve on the retainer,once out pressure went to zero.CIP @ 1335 hrs 1/21/2011.Circ mud to clean drill string, pumping 4 bpm w/800 to 900 psi. LD a single, RD cementing equipment. Install nerf ball in drill string,circ,pumping 4 bpm w/650 psi.Monitor well-static. Pump a dry job. POOH w/Baker tool f/7135'to 2347'. RU tongs and 3-1/2"elev, POOH, LD running tool,MU liner to cmenting tool, RIH on 4"dp to 5400', make a TD conn,circ @ 5488'. 00:00 00:45 0.75 4,792 2,347 COMPZ CEMEN"TRIP T Pull out of the hole w/Baker K-1 cementing retainer f/4792'to 2347' 00:45 01:15 0.50 2,347 2,347 COMPZ CEMEN"RURD T Change handling tools,double stack casing tongs and slip type elevators. 01:15 02:45 1.50 2,347 0 COMPZ CEMEN"TRIP T Continue trip out,standing back 25 stands of 3-1/2"PH6.The Baker K-1 cement retainer is not attatched to the running tool.Calculated displacement 38.04 bbls,actual 39.75 bbls. 02:45 03:15 0.50 0 0 COMPZ CEMEN"OTHR T Clean floor. 03:15 03:30 0.25 0 0 COMPZ CEMEN"PULD T Lay down the running tool.Make up another K-1 cement retainer. 03:30 05:00 1.50 0 2,347 COMPZ CEMEN"TRIP T Run in the hole w/Baker K-1 cement retainer on 3-1/2"PH6 work string to 2347'. 05:00 05:15 0.25 2,347 2,347 COMPZ CEMEN"OTHR T Change handling tools to handle 4" drill pipe. Page 22 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 08:30 3.25 2,347 7,231 COMPZ CEMEN'TRIP T Continue trip in the hole with Baker K-1 cement retainer f/2347'to 7231'. 08:30 08:45 0.25 7,231 7,140 COMPZ CEMEN'TRIP T Pull out of the hole to 7140'. 08:45 09:00 0.25 7,140 7,166 COMPZ CEMEN'TRIP T Make up a single 4"drill pipe from the pipe shed. Run in the hole,setCV. Baker K-1 retainer Cgs 71662 kt 09:00 09:15 0.25 7,166 7,160 COMPZ CEMEN'RURD T Rig up to circulate through 2" cementing hose. Pick up 6'to 7160' (unstring from retainer). 1 09:15 10:45 1.50 7,160 7,160 COMPZ CEMEN'CIRC T Circulate bottom's up,pumping 4 bpm w/800 psi. Then pump and spot new mud in the drill string. 10:45 11:15 0.50 7,160 7,166 COMPZ CEMEN'CIRC T Sting into the Baker retainer @ 7166'. Pump 4 spm w/1400 psi,6 spm w/1500 psi, 12 spm w/1700 psi, 18 spm 1860 psi. Pumped a total of 15.2 bbls,bled back.75 bbls after test. Pressure bled down to 1300 psi. 11:15 12:00 0.75 7,166 7,160 COMPZ CEMEN"OTHR T Pick up 6'to 7160'(Unsting from retainer). Close annular,adjust presure to 600 psi. Fill choke and gas buster with mud,Obtain slack off wt w/annular closed(89K). 12:00 12:15 0.25 7,160 7,160 COMPZ CEMEN'SFTY T PJSM on cementing through retainer set @ 7166'. 12:15 12:30 0.25 7,160 7,160 COMPZ CEMEN"CIRC T Circulate(unstrung f/retainer)while dowel)mixes mud push. 12:30 12:45 0.25 7,160 7,160 COMPZ CEMEN"CMNT T Dowell pump 5 bbls of mud push (12.5 ppg @ 2 bpm w/337 psi.Shut down.Close choke. Dowell pressure test lines to 3500 psi-good. 12:45 13:00 0.25 7,160 7,160 COMPZ CEMEN"CMNT T Dowell mix 10 bbls, 15.8 ppg class "G"cement w/additives(1.16 cuft/sx,mix water 5.094 gal sx, thickening time 4hr 34 min) additives: D046.2%BWOC, .D065 .3%BWOC, D167.5%BWOC, D153.2 BWOC, D177.02 gal/sx). Open choke and pump 10 bbls of cement holding @ 2 bpm w/200 to 170 psi, 350 to 315 psi back pressure on the choke. Follow cement w/5 bbls of water down the string,still holding 220 to 210 back pressure.Shut choke. 13:00 13:30 0.50 7,160 7,166 COMPZ CEMEN'CMNT T Open choke when rig starts displacing cement w/10.4 ppg mud @ 2 bpm w/400 psi, holding 360 psi back pressure.With 47.89 bbls of mud displaced(mudpush @ retainer),slack off to sting into the retainer. Page 23 of 37 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 13:30 13:45 0.25 7,166 7,160 COMPZ CEMEN'CMNT T Let annulus pressure bleed off,then open annular.Squeeze 5 bbls of mud push pumping 1 bpm w/2000 psi initial, 1825 psi when cement is at the retainer. Pump a total of 9.64 bbls of cement through the retainer, final 1750 psi,bled down to 1440 psi when picking up to unsting and close valve on the retainer,once out pressure went to zero.CIP @ 1335 hrs 1/21/2011. 13:45 14:45 1.00 7,160 7,160 COMPZ CEMEN'CIRC T Circulate and condition mud to clean drill string, pumping 4 bpm w/800 to 900 psi. 14:45 15:00 0.25 7,160 7,135 COMPZ CEMEN'RURD T Lay down a single,rig down cementing equipment,blow down lines. Install nerf ball in drill string, make a top drive connection. 15:00 15:45 0.75 7,135 7,135 COMPZ CEMEN'CIRC T Circulate and condition mud, pumping 4 bpm w/650 psi. 15:45 16:00 0.25 7,135 7,135 COMPZ CEMEN'OWFF T Monitorwell-static. 16:00 16:15 0.25 7,135 7,135 COMPZ CEMEN'CIRC T Pump a dryjob. 16:15 17:45 1.50 7,135 2,347 COMPZ CEMEN'TRIP T Pull out of the hole w/Baker running tool f/7135'to 2347'. 17:45 18:00 0.25 2,347 2,347 COMPZ CEMEN-RURD T Change handling tools,elevators and Rig up double stack tongs. 18:00 19:15 1.25 2,347 7 COMPZ CEMEN'TRIP T Continue to pull out of the hole f/ 2347'to Baker running tool. 19:15 20:15 1.00 7 0 COMPZ CEMEN'PULD T Lay down running tool,pick up single f/pipe shed,break off circ headpin. clean floor. 20:15 20:30 0.25 0 46 COMPZ CEMEN'PULD T Pick up/Make uo Baker 5-1/2"top job tool, MU 4"XT39 b x 3-1/2"IF crossover on top of tool(total length 46.53'. 20:30 23:30 3.00 46 5,400 COMPZ CEMEN'TRIP T RIH w/Baker liner top cementing tool/liner setting,packer setting tool on 4"drill pipe f/46.53'to 5400 ✓ 23:30 00:00 0.50 5,400 5,488 COMPZ CEMEN'CIRC T Make a top drive connection on stand#58.Circulate and condition mud, pumping 36 spm w/260 psi- 33%Totco flow out. 01/22/2011 Circ&cond mud, Pump through choke w/annular closed, Pump 70 bbls new(10.4 ppg)down string(string vol.57.66 bbls). P/U single Slack off to tag liner top w/dog sub. R/U cementing equip. Press to 500 psi,shut down due to hydraulic pressure and string weight issue. L/D single w/head pin, P/U single and screw into string w/Top Drive. Press up to 3200 psi,set liner hanger, L/D single. P/U single w/head pin,drop ball (29/32") M/U single. Place perf circ sub 5'above TOL. R/U cementing equip.Close Annular and perform injectivity test, PJSM on squeeze, Pump 5 bbls Mud push w/SWS @13 ppg,test lines to 3400 psi, mix and pump 24.5 bbls cement(119 sx)w/additives @ 2 bpm followed by 5 bbls H2O(hold back pressure to keep cement f/running)Shut in choke switch over to rig and begin displacing cement @ 2 bpm holding 450 psi back pressure w/choke(final press 180 psi on string&520 on annulus). Displace cement to tools, (mud push @ perf sub)shut in choke and squeeze cement @ 1 bpm. Innitial pressure 180 psi final pressure 1220 psi w/1060 psi on annulus.Squeeze all 24.5 bbls cement.CIP @ 06:23 hrs. 1/22/2011.Slack off and set liner top packer,open annulus and observe no flow,press up to 3800 psi and blow ball seat. P/U string 30'w/ pumping(62 bbls)Shut down and test ZXP to 1500 psi/5 min(good test).Circ&Cond mud,TOOH L/D tools, M/U Clean out BHA and TIH. Page 24 of 37 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 5,488 5,488 COMPZ CEMEN"CIRC T Circulate and condition mud, pumping 36 spm(3bpm)w/260 psi- 33%Totco flow out. PU wt 110k,SO wt 88k. 01:15 01:30 0.25 5,488 5,488 COMPZ CEMEN-CIRC T Pump through choke w/annular closed,pumping 2 bpm w/240 psi. Slack off weight through the bag 84k, w/600 psi hydraulic pressure on the annular. 01:30 02:00 0.50 5,488 5,488 COMPZ CEMEN'CIRC T Pump 70 bbls of new mud(10.4 ppg) down string(String volume 57.66 bbls). Pumping 4 bpm w/400 psi. 02:00 02:15 0.25 5,488 5,524 COMPZ CEMEN'OTHR T Blow down the top drive. Pick up a single,make single up.Slack off to tag liner top w/dog sub 26'in the hole w/5k.SO wt 90k. 02:15 03:15 1.00 5,524 5,522 COMPZ CEMEN'RURD T Rig up cementing equipment and lines. Pressure to 500 psi. Shut down due to hydraulic pressure and string weight. Lay down single w/ headpin. Pick up another single and screw the top drive into joint.Slack off to 2'above top of liner w/dog sub, top of liner @ 5491.62',end of tools at 5522'. Pressure up to 3200 psi to set liner hanger,hold pressure f/5 minutes.Chart test. 03:15 03:45 0.50 5,522 5,510 COMPZ CEMEN"PULD T Lay down single, PU the other single dp. Drop a 29/32"ball.Make up the single with the headpin.Slack off single in the hole to 12'in(end of tools at 5510').(Pert circ sub 5' above the liner top. Rig up cementing equipment. 03:45 04:30 0.75 5,510 5,510 COMPZ CEMEN'OTHR T Close the annular,then perform injectivity test. Pumping.5 bpm w/ 1090 psi, 1 bpm w/1130 psi, 1.5 bpm w/1200 psi. Pumped a total of 18.3 bbls. Pressure bled down to 1020 psi when pumps were shut down. Bleed off pressure. 04:30 04:45 0.25 5,510 5,510 COMPZ CEMEN"SFTY T PJSM on cementing top of liner @ 5491.62'to 6750'. 04:45 05:11 0.44 5,510 5,510 COMPZ CEMEN-RURD T Dowell prepare to pump cement job. 05:11 05:21 0.17 5,510 5,510 COMPZ CEMEN"CMNT T Dowell pump 5 bbls mud push 13 ppg,pumping 1-2 bpm w/200-280 psi,shut down,close choke. Dowell test lines to 3400 psi-good. OP 05:21 05:25 0.07 5,510 5,510 COMPZ CEMEN"CMNT T Dowell start mixing Class"G" tarr(1- cement w/additives to 15.8 ppg .,y( (additives: D046.2%BWOC, D065 C^ .3%BWOC, D167.5%BWOC, ex D153.2%BWOC, D177.02 gal/sx) (Yield 1.16 cuft/sx,mix water 5.094 gal/sx)(Thickening time 3 hr 5�5i min) Total 119 sx,24.5 bbls. ,/ Page 25 of 37 } Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 05:25 05:40 0.26 5,510 5,510 COMPZ CEMEN"CMNT T Dowell start pumping cement, rig open choke partially to hold 280 to 370 psi while pumping 15.8 ppg cement @ 2 bpm and 270 to 60 psi. Follow cement w/5 bbls of water in the string.Shut choke line while lining up to displace w/rig-keeping cement f/falling. 05:40 05:50 0.17 5,510 5,510 COMPZ CEMEN-CMNT T As rig starts to displace,open the choke to maintain 450 psi back pressure. Rig starts displacement at 2 bpm w/initial 130 psi.After pumping 23.16 bbls of 10.4 ppg mud, shut the choke to squeeze cement to the liner lap(Mud push was at the perforated circ sub). Prior to closing well in,the pressure was 180 psi on string and 520 psi on the annulus. 05:50 06:21 0.53 5,510 5,510 COMPZ CEMEN"CMNT T With well shut in,squeeze cement, pumping 1 bpm w/initial 180 psi, with 52.66 bbls displaced(24.5 bbls of cement to the tool)the pressure was 1220 psi, holding 1060 psi on the annulus.Shut down pumping- pressure went to 1050 psi.Shut down @ 0623hrs 1/22/2011. 06:21 06:27 0.10 5,510 5,524 COMPZ CEMEN"CMNT T Slack off on the string to set the liner too packer. Slack off to 5524',putting dog sub on the liner top.Continue to slack off 30k.Saw a shear at 50k on weight indicator. 06:27 06:36 0.15 5,524 5,524 COMPZ CEMEN"CIRC T Open annulus,observed no flow. Pick up to 110k on the weight indicator. Pressure up to 3800 psi to blow the ball seat. 06:36 06:54 0.30 5,524 5,491 COMPZ CEMEN"CIRC T Pick up to remove single from hole. Pumping while picking up to clear any excess cement f/the liner top. Pumped 62 bbls. 06:54 07:12 0.31 5,491 5,491 COMPZ CEMEN"DHEQ T Test ZXPN liner top packer to 1500 psi f/5 minutes. Pump down string and down annulus w/annular closed. Pumped 1.27 bbls.Good test. Bled off pressure.Charted test. 07:12 07:42 0.50 5,491 5,491 COMPZ CEMEN"PULD T Lay down single drill pipe. Blow down cementing lines. 07:42 08:27 0.75 5,491 5,491 COMPZ CEMEN-CIRC T Circulate to clean pipe. Pumping 300 gpm w/800 psi. 08:27 08:42 0.25 5,491 5,491 COMPZ CEMEN"OWFF T Monitor well-static. 08:42 08:57 0.25 5,491 5,491 COMPZ CEMEN"CIRC T Pump a dry job, blow down the top drive. 08:57 09:42 0.75 5,491 5,491 COMPZ CEMEN"PULD T Clear floor of Halliburton e-line tools, Pick up tools and handling equipment f/handling BHA f/ upcoming cleanout run. Page 26 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:42 12:27 2.75 5,491 42 COMPZ CEMEN"TRIP T Pull out of the hole w/Baker liner top cementing/hanger setting/packer setting tools f/5491'to 1738'. 12:27 12:57 0.50 42 0 COMPZ CEMEN"PULD T Lay down Baker tools. 12:57 13:12 0.25 0 0 COMPZ CEMEN"SFTY T Pre job safety meeting on cleanout BHA. 13:12 14:42 1.50 0 173 COMPZ CEMEN"PULD T MU cleanout BHA. 14:42 15:57 1.25 173 2,521 COMPZ CEMEN"TRIP T Run in the hole w/BHA on 3-1/2" PH6 to 2521' 15:57 16:12 0.25 2,521 2,521 COMPZ CEMEN"OTHR T Change handling tools to 4" 16:12 19:12 3.00 2,521 6,939 COMPZ CEMEN"TRIP T Continue to run in the hole f/2521'to 6939'. Fill pipe every 25 stands 19:12 19:27 0.25 6,939 7,165 COMPZ CEMEN"COCF T Make a top drive connection on stand#48,fill pipe,while pumping 300 gpm w/2000 psi,wash f/6939' to 7165'.Tag up @ 7165. PU wt 11k. SO wt 90k, Rot wt 105k. Rot 100 rpm w/4k torque. 19:27 23:57 4.50 7,165 7,165 COMPZ CEMEN"COCF T Drill on Baker cement retainer f/ 7165'. Rot 100 rpm w/4-5k ftlbs of torque,pumping 140 to 300 gpm w/ 600 to 2000 psi. 01/23/2011 Clean out the 5-1/2"15.5 ppf L-80 STL and HD-Liner f/5165'to 7710'.Tag up on retainer set @ 7714',the retainer that fell off the running tool,and any remnants of the retainer which was set @ 7166'. PU wt 135k, SO wt 100k. Lay down a single.Circ 3 bottom's up,recip f/7690'to 7655'.Observe well for flow-static. Obtain slow pump rates. Pump a dry job. Blow down the top drive.Start trip out of the hole-25k overpull @ 7680',5855'&5508'.Con't POOH to the 3-1/2"PH6 at 2521',Con't POOH f/2521'to 180'. PJSM/LD 3-1/2" drill collars,xo's,4.75"OD mill. PU/MU stack washing tool,wash stack. RD/BD the top drive. PJSM on rig up and testing BOPE. Rig up to test BOPE w/4"test joint. Pull wear bushing. Install FMC test plug.2 week BOPE test.Witness of test waived by AOGCC inspector Lou Grimaldi.Test w/4"test joint,annular,top (3-1/2"x 6")and bottom pipe rams(2-7/8"x 5"),all valves on kill line and choke line,test demco mud line valve, upper IBOP, lower IBOP,floor safety valve,dart valve,and all valves in the choke manifold to 250 psi low and 3500 psi high.Test the Annular to 250 psi low and 2500 psi high.Test blinds to 250 psi low and 3500 psi high.All tests held f/5 minutes.Charted tests.Accumulator test initial 3000 psi,after closure 1800 psi, 200#build up in 41 seconds,full charge in 194 seconds.5 Bottles of nitrogen average 2035 psi. Remove 4"test joint, rig up w/3-1/2"test joint.Test top(3-1/2"x 6")and bottom pipe rams(2-7/8"x 5")to 250 psi low 3500 psi high.Test the annular to 250 psi low and 2500 psi high. Rig down testing equipment. Set wear bushing,blow down the TD,choke manifold,choke and kill lines. 00:00 04:00 4.00 7,165 7,408 COMPZ CEMEN"DRLG T Cleaning out the 5-1/2"15.5 ppf L-80 STL and HD-I liner f/5165'to 7714'to 7408'. Rotate 55 rpm w/4-6k ft lbs of torque. Pumping 40 spm w/650 psi. 04:00 04:30 0.50 7,408 7,408 COMPZ CEMEN"PULD T Lay down 2 stands of 4"drill pipe from the derrick,due to cold weather. Top drive hydraulics not working well. This will keep the top drive below the wind walls. 04:30 08:00 3.50 7,408 7,690 COMPZ CEMEN DRLG T Continue to clean out the 5-1/2"15.5 ppf L-80 STL and HD-I liner f/7408' to 7690'. Rotate 55 rpm w/4-6k ft lbs of torque. Pumping 40 spm w/650 psi. Page 27 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:15 0.25 7,690 7,710 COMPZ CEMEN"TRIP T Pick up a single,then slack off to 7710'w/no pump and no rotation f/ 7690'to 7710'.Tag up on retainer set @ 7714',the retainer that fell off the 1 running tool,and any remnants of the retainer which was set @ 7166'. PU wt 135k,SO wt 100k. 08:15 09:30 1.25 7,690 7,690 COMPZ CEMEN"CIRC T Lay down a single.Circulate bottom's up x 3,pumping 248 gpm w/1500 psi. Rotate 50 rpm w/4k ft lbs of torque. Reciprocate f/7690'to 7655'. 09:30 09:45 0.25 7,690 7,690 COMPZ CEMEN"OWFF T Observe well for flow-static. 09:45 10:00 0.25 7,690 7,690 COMPZ CEMEN-CIRCT Obtain slow pump rates. Pump a dry job. Blow down the top drive. 10:00 10:30 0.50 7,690 7,595 COMPZ CEMEN"TRIP T Start trip out of the hole.25k overpull @ 7680'.Slack off,going down free, but 25k overpull while picking up at 7680'. Make a top drive connection, rotate up w/20 rpm,5k ft lbs of torque. Rotate up to 7670'w/no problems,slack off without rotary to 7690'(SO wt 100k). Pick up w/10k overpull every 40-45'. 10:30 13:30 3.00 7,595 2,521 COMPZ CEMEN"TRIP T Continue trip out of the hole f/7595' to 2521'. Had 25k overpull @ 5855'& 5508'.Slack off with no problems. Picked up and slacked off several times, pulled free after several workings.Continue trip out of the hole to the 3-1/2"PH6 at 2521'. 13:30 13:45 0.25 2,521 2,521 COMPZ CEMEN"OTHR T Change out handling tools, rig up double stack tongs. 13:45 14:30 0.75 2,521 180 COMPZ CEMEN'TRIP T Continue to pull out of the hole f/ 2521'to 180'. 14:30 14:45 0.25 180 180 COMPZ CEMEN"SFTY T PJSM on laying down 3-1/2"drill collars,xo's,mill. 14:45 15:00 0.25 0 0 COMPZ CEMEN'RURD T Change out handling tools to work 3-1/2"drill collars. 15:00 15:45 0.75 190 0 COMPZ CEMEN'PUCM T Lay down 3-1/2"drill collars,x-o's and mill. Recovered a piece of slip segment f/retainer in the water coarse of the mill when out of the hole 15:45 16:00 0.25 0 0 COMPZ CEMEN-CIRCT Pick up/make up stack washing tool. Function rams and annular while washing stack. 16:00 16:15 0.25 0 0 COMPZ CEMEN-RURD T Rig down stack washing tool, blow down the top drive. 16:15 16:30 0.25 0 0 COMPZ WHDBO SFTY T Pre job safety meeting on rig up and testing BOPE. 16:30 18:00 1.50 0 0 COMPZ WHDBO RURD T Rig up to test BOPE w/4"test joint. Pull wear bushing. Install FMC test plug. Page 28 of 37 S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 22:45 4.75 0 0 COMPZ WHDBO BOPE T 2 week BOPE test.Witness of test waived by AOGCC inspector Lou Grimaldi.Test w/4"test joint, annular,top(3-1/2"x 6")and bottom pipe rams(2-7/8"x 5"),all valves on kill line and choke line,test demco mud line valve, upper IBOP, lower IBOP,floor safety valve,dart valve, and all valves in the choke manifold to 250 psi low and 3500 psi high. Test the Annular to 250 psi low and bop 2500 psi high.Test blinds to 250 psi low and 3500 psi high.All tests held f/5 minutes.Charted tests. Accumulator test initial 3000 psi, after closure 1800 psi,200#build up in 41 seconds,full charge in 194 seconds.5 Bottles of nitrogen average 2035 psi. Remove 4"test joint,rig up w/3-1/2" test joint.Test top(3-1/2"x 6")and bottom pipe rams(2-7/8"x 5")to 250 psi low 3500 psi high.Test the annular to 250 psi low and 2500 psi high. 22:45 00:00 1.25 0 0 COMPZ WHDBO RURD T Rig down testing equipment. Set wear FMC 6-3/8"ID wear bushing. Blow down the top drive,choke manifold,choke line and kill line. 01/24/2011 PJSM,slip and cut drilling line,sery rig, PJSM,MU csg scraper BHA, RIH on 3-1/2"PH6 work string to 2391', cont RIH on 4"drill pipe to 7710',Circ,displace to 10ppg brine,monitor well-static,clean under shakers, spot inhibited brine on bottom, monitor well-static, POOH w/scraper BHA, L/D BHA,clean floor, rig up lubricator, PJSM, rig up Halliburton e-line f/RCBL log. 00:00 00:15 0.25 0 0 COMPZ RIGMNT SFTY T Pre job safety meeting on slip and cutting 1-1/4"drilling line. 00:15 01:15 1.00 0 0 COMPZ RIGMNT SLPC T Slip and cut 58'of drilling line. 01:15 01:45 0.50 0 0 COMPZ RIGMNISVRG P Service rig and top drive. 01:45 02:00 0.25 0 0 COMPZ CEMEN'SFTY T Pre job safety meeting on picking up BHA. 02:00 02:30 0.50 0 0 COMPZ CEMEN-RURD T Rig up tools to make up BHA. 02:30 05:00 2.50 0 50 COMPZ CEMEN"PULD T Pick up a single 3-1/2"PH6.Make up crossover 3-1/2 PH6 to 2-3/8"IF, check torque on float sub,then break off 4-3/4"mill.MU x-o,junk basket, junk basket,x-o,csg scraper,4-3/4" mill. 05:00 05:15 0.25 50 50 COMPZ CEMEN-RURD T Rig up tongs to trip in the hole w/ 3-1/2"PH6 workstring and casing scraper. 05:15 07:15 2.00 50 2,391 COMPZ CEMEN"TRIP T Trip in the hole w/BHA:4-3/4"mill csg scraper,x-o, (2)junk baskets, x-o, bit sub,float sub,x-o,single 3-1/2",25 stands of 3-1/2",x-o(3-1/2 PH6 x 4"XT39)to 2391'. Page 29 of 37 a Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:15 07:30 0.25 2,391 2,391 COMPZ CEMEN-RURD T Change handling tools. 07:30 07:45 0.25 2,391 2,391 COMPZ CEMEN"CIRC T Fill pipe w/all the 3-1/2"PH6 in the hole. 07:45 08:00 0.25 2,391 2,391 COMPZ CEMEN"OTHR T Blow down the top drive. 08:00 08:15 0.25 2,391 5,250 COMPZ CEMEN'CIRC T Fill pipe at 5250' 08:15 08:30 0.25 5,250 5,250 COMPZ CEMEN"OTHR T Blow down the top drive. 08:30 10:30 2.00 5,250 7,654 COMPZ CEMEN.TRIP T Continue in the hole w/4.75"mill and scraper f/the 5-1/2"liner to 7654'. TOL @ 5491.62'. PU wt 126k,SO wt 94k. 10:30 10:45 0.25 7,654 7,710 COMPZ CEMEN'TRIP T Make a top drive connection, pumping 252 gpm w/1600 psi, rotate 20 rpm w/4-5k ft lbs of torque. PU wt 112k, Rot wt 105k.Tag PBTD at 7710'. 10:45 13:45 3.00 7,710 7,710 COMPZ CEMEN"CIRC T Circulate,pumping 6 bpm w/1600 psi, rotate 20 rpm w/4-5k ft lbs of torque. Reciprocate pipe. 13:45 14:45 1.00 7,710 7,710 COMPZ CEMEN"CIRC T Displace well f/10.4 ppg mud to 10 ppg brine, pumping 7 bpm w/2150 psi. 14:45 15:15 0.50 7,710 7,710 COMPZ CEMEN'OTHR T Shut down pumping,clean under shaker,trough,possum belly and trip tank. 15:15 15:45 0.50 7,710 7,710 COMPZ CEMEN"CIRC T Circulate bottom's up,pumping 210 gpm w/1150 psi. 15:45 16:15 0.50 7,710 7,710 COMPZ CEMEN"OWFF T Monitor well-static. 16:15 16:45 0.50 7,710 7,710 COMPZ CEMEN"CIRC T Circulate to spot inhibited brine f/ 7710'to 6477'. Pumping 168 gpm w/ 700 psi. 16:45 17:00 0.25 7,710 7,710 COMPZ CEMEN"OWFF T Monitor well-static. 17:00 19:15 2.25 7,710 2,391 COMPZ CEMEN"TRIP T Pull out of the hole w/the 4-4/5"mill and scraper f/7710'to 2391'. 19:15 19:30 0.25 2,391 2,391 COMPZ CEMEN'SFTY T Pre job safety meeting. 19:30 20:00 0.50 2,391 2,391 COMPZ CEMEN"RURD T Change out handling tools f/the 3-1/2"PH 6 works tring. 20:00 21:00 1.00 2,391 19 COMPZ CEMEN"TRIP T Continue to pull out of the hole w/ casing scraper f/the 5-1/2"liner. 21:00 21:30 0.50 19 0 COMPZ CEMEN"PULD T Break and lay down BHA. 21:30 22:00 0.50 0 0 COMPZ CEMEN'RURD T Rig down 5-1/2"Ekel double stack tongs,and handling tools. 22:00 22:15 0.25 0 0 COMPZ EVALWE RURD P Bring 7"lubricator to the floor. 22:15 22:30 0.25 0 0 COMPZ EVALWE SFTY P Pre job safety meeting on rigging up lubricator. 22:30 22:45 0.25 0 0 COMPZ EVALWE RURD P Position lubricator to rig up on. 22:45 23:00 0.25 0 0 COMPZ EVALWE SFTY P Pre job safety meeting on rigging up Halliburton e-line for RCBL log. Page 30 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 COMPZ EVALWE RURD P Rig up Halliburton e-line.2-3/4"OD Toolstring length 26.69':7/32"wire w/ 1-7/16"cable head(1.375"fishing neck),5"OD centralizer,CCL, 5"OD c61 centralizer,SCBL logging tool,5"OD centralizer,gamma ray logging tool, 5"OD centralizer. Gamma is 10.44'below SCBL,CCL is 8.08'above SCBL. 01/25/2011 Halliburton e-line RIH to tag at 7709', log to above top of liner @ 5491.62', repeat,log w/1000 psi f/7709'to 5400',bleed off pressure, POOH to 200', PJSM, rig down e-line and lubricator. Make up packer assembly run in on wireline set @ 7,220' 00:00 03:00 3.00 0 7,709 COMPZ EVALWE ELOG T Halliburton e line RIH to tag bottom @ 7709'WLM, Log 7709'to Above the top of the liner @ 5491.62'. RIH w/repeat pass 7709'to above the top of the liner. RIH to 7709'. 03:00 03:45 0.75 7,709 5,400 COMPZ EVALWE ELOG T Pressure well to 1000 psi. Log 7709' to 5400'. 03:45 04:30 0.75 5,400 200 COMPZ EVALWE ELOG T Bleed off pressure.Wireline POOH to 200'. 04:30 04:45 0.25 200 200 COMPZ EVALWE ELOG T Pre job safety meeting. 04:45 06:00 1.25 200 0 COMPZ EVALWE ELOG T Rig down e-line. Post logs to the"S" drive. 06:00 13:30 7.50 0 0 COMPZ EVALWE QEVL T Wait On RCBL logs,Clean pits, Service pipe skate, Drawworks,lron roughneck,double stacked casing tongs. 13:30 14:30 1.00 0 0 COMPZ EVALWE PRTS T PJSM,rig up and test casing and liner lap. Pressure up to 2,000 psi. �1 Shut down. Bleed off and record pressures bled down to 1,420 psi in 15 min. Bleed to trip tank. 3/4 bbl N" returned. w5� 14:30 16:30 2.00 0 0 COMPZ EVALWE OTHR T Continue waiting on log evaluation. G Perform drawworks MP2's evaluation. $16:30 18:30 2.00 0 73 COMPZ EVALWE PULD P PJSM,Mobilize tools to rig floor, Rig up double stack tongs,Change (y elevators, Make up packer and tail assembly. 18:30 23:30 5.00 73 73 COMPZ EVALWE RURD T PJSM,Make up cable head assembly and test. No communication through head assembly. Lay down packer running tool and re-wire head assembly. Make tools back up and test successfully. 23:30 00:00 0.50 73 3,000 COMPZ EVALWE ELOG P Run packer with tail pipe assembly in hole on wireline. 01/26/2011 Run upper packer in hole and set at 7,050'.Attempt pressure test to 2,500 psi with no success.Trouble shoot failed pressure test.Circulate, Release from packer and trip out of hole.test 7"packoff. Prep for test packer assembly. Page 31 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 03:30 3.50 0 0 COMPZ RPCOM ELOG P Run lower production packer in hole on E-line.Set at 7,220'md. Pull out of hole with E-line and packer running tool. Rig down E-line. 03:30 06:00 2.50 0 0 COMPZ RPCOM PACK P Rig up double stack tongs.Make up seal bore and upper packoff assembly. 06:00 11:00 5.00 0 7,119 COMPZ RPCOM TRIP P Run seal bore and upper packer assembly in hole to 7,119'md. Up weight 115k down weight 100k 11:00 12:00 1.00 7,119 7,119 COMPZ RPCOM PACK P Sting in and latch anchor slack off 5k, Pick up 10k over,slack off to neutral weight drop 1.43 ss ball. 12:00 17:00 5.00 7,119 7,050 COMPZ RPCOM PACK T PJSM,With ball on seat pressure up to 2,000 psi. Pick up 20k over while holding pressure,Set packer @ 7 050'Ind. Bleed pressure to 0 psi LlAd set 20k down weight on packer pressure up to 2,000 psi overpull 20k continue to pressure up to 3,300 psi. Observe ball shear. Rig up and pressure test inner annulus to 2,500 psi through kill line. Pressure did not hold. Pressure back up on IA to 2,500 psi with pressure again not holding.Check all surface equipment no leaks found.Attempted pressure rr" �rr test using top rams then hydril still y no pressure held. Double checked all surface equipment again and rigged back up attempting pressure test. (p 2 Pressure up to 3,000 psi with 30k overpull test failed.Attempted pressure test a final time with no success. Decision made to test drill string and cement retainer pressure up on drill string to 2,500 psi for 10 minute test lost 25 psi over 10 minutes. 17:00 17:15 0.25 7,050 7,050 COMPZ RPCOM PACK T Blow down lines. Release from packer, lay down pup joint. Kelly up on stump. Pick up weight 113k. 17:15 18:30 1.25 7,050 7,050 COMPZ RPCOM CIRC T Circulate @ 4 bpm,400 psi. Increase flow rate to 5 bpm with 700 psi. Monitor well. Blow down top drive. 18:30 20:45 2.25 7,050 0 COMPZ RPCOM TRIP T Trip out of hole to 2,519'Change out handling equipment, Rig up hydraulic tongs.Continue trip out of hole. Service break and lay down running tool. Calculated fill 38 bbl's actual fill 38 bbl's Page 32 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:15 1.50 0 0 COMPZ RPCOM PRTS T Test 7"packoff Upper pack off SN# 83-160-328 tested 500 psi low 5 minutes,5,000 psi high 10 minutes. Lower packoff SN#12-14-212 tested 500 psi low 5 minutes,2,800 psi high 10 minutes.Test results good.All tests charted. Sim ops-Clear rig floor lay down excess tools and equipment. 22:15 23:30 1.25 0 0 COMPZ RPCOM PULD T Bring test packer and associated tools up beaver slide.Thaw tools and strap.Clean rig floor. 23:30 00:00 0.50 0 0 COMPZ RIGMNT SVRG T Service rig topdrive,drawworks while designing test packer BHA. 01/27/2011 Make up test packer, run in hole on PH-6 work string add stop sub at 1,530'. Run in hole to 7,008'tag liner lap with stop sub. Pick up circulate bottoms up.Test upper and lower packers,test zxp 2,500 psi 30 minutes all tests good and charted.Test for casing leak. Leak Isolated between 6,285'and 6,305. Rig down from tests.Circulate bottoms up.Trip out of hole lay down stop sub and test packer. 00:00 02:30 2.50 0 1,530 COMPZ RPCOM PULD T PJSM,Make up test packer assembly with stop sub.Test packer, 16 stands PH-6 work string, Stop sub to 1,530' 02:30 06:30 4.00 1,530 6,977 COMPZ RPCOM TRIP T Trip in hole to 7,008'md. Set weight (5k)on liner lap @ 5,491'with stop sub. Up weight 115k down weight 100k. Pick up 30'above liner lap.Trip in displacement actual 37 bbl's- Calculated 38.36 bbl's 06:30 08:00 1.50 6,977 6,977 COMPZ RPCOM CIRC T Circulate bottoms up @ 3 bpm,250 psi. 08:00 09:00 1.00 6,977 6,994 COMPZ RPCOM PRTS T Blow down top drive, Lay down single,pick up 14'pup joint make up to topdrive.Slack off to 6,994'rotate 5 turns to right slack off to 80k. (20 k down weight) 09:00 09:45 0.75 6,994 6,994 COMPZ RPCOM PRTS T Test packer and cement retainer to 2,500 psi for 30 minutes.Test charted. (Good Test) 09:45 11:15 1.50 6,994 7,008 COMPZ RPCOM PRTS T Rig down cement line, Lay down 14' pup joint. Pick up single joint drillpipe. Make up to topdrive. rotate 3 turns left release packer. Slack off to 7,008'md.Stop sub on top of liner lap.Set down 47k, Pressure up on Inner Annulus,Test liner top to 2,500 psi for 30 minutes.Test charted (Good test) 11:15 12:00 0.75 7,008 7,008 COMPZ RPCOM PRTS T Lay down single joint drillpipe. Blow down kill line and cement line. Rig down test equipment. 12:00 12:30 0.50 7,008 5,527 COMPZ RPCOM TRIP T Pull out of hole from 7,008'md.to 5,527'md. Up weight 97k down weight 91k,Calculated fill 8.1 bbl's actual fill 8.1 bbl's Page 33 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:30 19:45 7.25 5,527 6,292 COMPZ RPCOM PRTS T Set packer,rig up to test annulus 2,500 psi for 30 minutes, Pressure decrease of 75 psi in 30 minutes. Release packer,Trip in hole to 5,567' and rig up to test below packer through drillpipe.Test failed lost 600 psi in 10 minutes.Continue trip in hole,test at 6,230'Test from packer down.Test failed, Run in hole to 6,605'and test below packer. Achieved good test. Pull out of hole to 6,417'md.Test from packer down. Achieved good test. Pull out of hole to 6,324'test from packer down. Achieved good test. Pull out of hole to 6,305'and test from packer down . Test failed.Test IA @ 6,305'and test good. Run in hole to 6,320' test IA. Test good.Test below packer at 6,320'and test good. Pull out of hole to 6,310'md.Test below packer.test good. Pull out of hole to 6,292'test below packer.Test failed. Leak location isolated between 6,285'and 6,310'.Suspect leak at collar at 6,293'md. 19:45 20:00 0.25 6,292 6,292 COMPZ RPCOM PRTS T Rig down from pressure test. Blow down lines. 20:00 21:00 1.00 6,292 6,292 COMPZ RPCOM CIRC T Circulate bottoms up @ 5 bpm,550 psi,Monitor well(Static)Blow down topdrive. 21:00 00:00 3.00 6,292 0 COMPZ RPCOM TRIP T Trip out of hole with test packer and stop sub to 1,530'.Change handling equipment. rig up hydraulic tongs. Continue trip out make service breaks on tools and lay down stop sub and test packer 01/28/2011 Make up anchor,Tubing and packer. Run in hole set packer at 6,265'Trip out of hole. Lay down PH-6 work string(75 jts)Begin running completion tubing. 00:00 02:45 2.75 0 0 COMPZ RPCOM OTHR T Do rig maintenance, Perform housekeeping while waiting on Baker tools from deadhorse.Tools delayed due to rig move. 02:45 06:30 3.75 0 785 COMPZ RPCOM RPTH T Strap and prep tools. Pick up anchor (1.71')Crossover(5.42') 24 joints tubing(752.64)3 pups(3.81'-3.81' -9.85')Crossover pup joint(5.41') Fab packer(3.23')to 785'and 06:30 12:00 5.50 785 6,990 COMPZ RPCOM RPTH T Trip in hole with packer assembly to 6,990'md. Lay down top single drillpipe from stand#41. up weight 110k down weight 100k. Crew change. Page 34 of 37 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 6,990 7,052 COMPZ RPCOM RPTH T PJSM,Continue trip in hole from 6,990'md.to 7,050'md. Up wt 110k dn wt 100k. Pick up 9'drillpipe pup joint.tag up at 7,052'.set down 5k to engage anchor assembly, pull 15k over up weight.drop 1.43"ball.Set slip make up string to topdrive wait for ball to seat. Displacement calculated 34.36 bbl's actual displacement 34.5 bbl's 12:30 14:00 1.50 7,052 7,052 COMPZ RPCOM PRTS T Pump down drillpipe pressure up against 1.43"ball,Set anchor 1,500 psi. Increase pressure to 2,500 psi, Pull 30k over pick up weight(up wt 110k). Bleed pressure off to zero. Slack off to pick up weight.set down 30k under down weight(dn wt 100k). Pick up and set slips, Break out of top drive and blow down topdrive. Pick up string ,close pipe rams, Pressure up through kill line on IA to 2,500 psi for 30 minutes. Pressure test successful. (Test charted)Bleed off pressure,open rams,blow down kill line. 14:00 14:30 0.50 7,052 7,049 COMPZ RPCOM PRTS P make up top drive pressure up to 2,500 psi, Hold pressure pull 20k over pick up wt(Up wt 110k) Increase pressure and shear with ball at 3,900 psi. Bleed pressure off to zero. Find neutral weight in string, Rotate to the right for 15 turns and release from packer. Pick up 3'verify string free.Set slips break out pup and blow down top drive. 14:30 19:30 5.00 7,049 0 COMPZ RPCOM TRIP P Pull out of hole. Pick up single previously layed down off of stand #41. Rack all 4"drillpipe back in derrick. Make up TIW valve to PH-6 crossover for well control. Lay down 75 joints PH-6. Lay down running tool.Calculated hole fill 33.18 bbl's Actual hole fill 32.7 bbl's 19:30 20:00 0.50 0 0 COMPZ RPCOM RCST P Clear floor, Pull wear bushing, Make up crossovers to TIW valve for well control. 20:00 20:30 0.50 0 0 COMPZ RPCOM SFTY P Verify completion tubing and mandrels are in correct running order in pipeshed with Rig supervisor, Baker rep, Driller. Hold Pre Job Safety Meeting with rig crew. Discussed hazards of job and keeping focus onlst day back. 20:30 00:00 3.50 0 1,700 COMPZ RPCOM RCST P Run completion string per detail. Toatl joints in hole @ 24:00 hrs=54. (1,700'+1-) Page 35 of 37 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01/29/2011 24 hr Summary Run 3-1/2"completion tubing to 6,254'.Displace to corrosion inhibitor,space out and land hanger.Set BPV, Nipple down BOPE, Nipple up tree,Test pack off, test tree. 00:00 06:00 6.00 1,700 5,300 COMPZ RPCOM RCST P Run 3-1/2"completion tubing string with mandrels and related equipment per program. 06:00 09:45 3.75 6,254 6,254 COMPZ RPCOM CRIH P PJSM rig up and displace well to 10.0 ppg. NACI/KCL Brine with 2% CRW-132. Pump 127.5 bbl's chase with 84 bbl's uninhibited brine @ 3 bpm 325 psi.Shut down pump well began U-tubing. 09:45 10:15 0.50 6,254 6,254 COMPZ RPCOM CIRC P Pump 10 bbl's 10.2 ppg slug to stop U tubing shut down pump.Well still U-tubing mix 10.4 ppg brine slug. 10:15 11:15 1.00 6,254 6,160 COMPZ RPCOM HOSO P PJSM, Pump 10 bbl's 10.4 ppg brine down tubing,Chase with 10 bbl's 10.0 ppg brine. Monitor well(Static) rig down cement line and crossover from tubing pick up joint#225 up wt 80k do wt 73k.Tag up at 6,271'md, set down 5k to set anchor, Pull 10 k over pick up wt.Slack of to neutral weight.Close rams and test through kill line to 1,500 psi for 10 minutes. Bleed off pressure,Open rams, Set down 10k to ensure anchor set. Pull 45k over pick up wt to shear PBR pin's. Pull out of hole and lay down 3 joints of 3-1/2"tubing. 11:15 14:45 3.50 6,160 6,254 COMPZ RPCOM HOSO P Pick up 3 pup joints(2.36'-6.15'- 10.14')Make up hanger and landing joint. Drain stack and land hanger. Confirm set point per FMC and Rig Supervisor. Run in lock down screws. Rig up to pump down tubing. Pressure up on tubing to 3,500 psi for 30 minutes(Recorded on chart) Bleed tubing pressure down to 2,000 psi and pressure up on IA to 2,600 psi. Both IA and tubing held pressure for 5 minutes. Bleed tubing pressure down to 2,000 psi, IA pressure held 2,550 psi. Both held for 30 minutes. (Recorded on chart) 14:45 15:45 1.00 6,254 0 COMPZ RPCOM RURD P Rig down test equipment,Crossover subs,Clear and clean floor 15:45 16:45 1.00 0 0 COMPZ RPCOM NUND P Set BPV and test through IA to 1,000 psi, Hold pressure 10 minutes. Bleed off pressure blow down all lines. 16:45 00:00 7.25 0 0 COMPZ RPCOM NUND P PJSM, Nipple down BOPE. Nipple up tree.Test packoff and tree 250 psi low 5,000 psi high. 01/30/2011 Freeze protect well, U-Tube, Secure well, Lay down drillpipe 00:00 00:45 0.75 0 0 COMPZ RPCOM FRZP P Pull Tree test plug, Rig up to freeze protect well using little red services. Page 36 of 37 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:45 02:15 1.50 0 0 COMPZ RPCOM FRZP P PJSM with little red. Pressure test lines to 2,500 psi. Pump 75 bbl's diesel @ 1 bpm. Initial circulating pressure 400 psi, Final circulating pressure 800 psi. 02:15 03:30 1.25 0 0 INTRMI RPCOM FRZP P Rig down little red. Rig up and U-tube well.Sim-ops. Instal mouse hole, Clean out drip pan, prep to lay down 4"drillpipe. 03:30 04:00 0.50 0 0 INTRMI RPCOM NUND P Set BPV,Secure well. 04:00 12:00 8.00 0 0 INTRMI MOVE DMOB P Lay dwon all 4"drillpipe,Change Saver sub.Sim-ops rig down to move rig to Alpine CD3-125. Rig release @ 12:00 hrs. Page 37 of 37 ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-08A 500292049601 Sperry nrilling Definitive Survey Report 17 January, 2011 HALLIBURTON Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1 E-08 North Reference: True Wellbore: 1 E-08A Survey Calculation Method: Minimum Curvature Design: 1 E-08A Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 E-08 Well Position +N/-S 0.00 ft Northing: 5,960,600.23 ft Latitude: 70°18'11.283 N +E/-W 0.00 ft Easting: 549,889.82 ft Longitude: 149°35'45.186 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.70 ft Wellbore 1 E-08A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 1/12/2011 21.45 80.85 57,683 Design 1 E-08A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 5,704.22 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 27.92 0.00 0.00 2.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 104.22 5,704.22 1E-08 GyroData(1E-08) GYD-CT-CMS Gyrodata cont.casing m/s 4/6/2010 12:0C 5,712.00 7,821.03 1 E-08A(1 E-08A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/12/2011 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.92 0.00 0.00 27.92 -70.70 0.00 0.00 5,960,600.23 549,889.82 0.00 0.00 UNDEFINED 104.22 0.93 160.17 104.22 5.60 -0.58 0.21 5,960,599.65 549,890.04 1.22 -0.57 GYD-CT-CMS(1) 124.22 0.88 134.56 124.21 25.59 -0.84 0.37 5,960,599.39 549,890.20 2.02 -0.83 GYD-CT-CMS(1) 144.22 0.71 128.71 144.21 45.59 -1.03 0.58 5,960,599.21 549,890.41 0.94 -1.01 GYD-CT-CMS(1) 164.22 0.63 196.75 164.21 65.59 -1.21 0.65 5,960,599.02 549,890.48 3.76 -1.19 GYD-CT-CMS(1) 184.22 0.89 177.50 184.21 85.59 -1.47 0.62 5,960,598.76 549,890.46 1.80 -1.45 GYD-CT-CMS(1) 204.22 0.89 134.65 204.21 105.59 -1.74 0.74 5,960,598.50 549,890.57 3.25 -1.71 GYD-CT-CMS(1) 224.22 0.77 109.21 224.21 125.59 -1.89 0.98 5,960,598.35 549,890.81 1.92 -1.85 GYD-CT-CMS(1) 244.22 0.63 98.89 244.20 145.58 -1.95 1.21 5,960,598.29 549,891.05 0.94 -1.91 GYD-CT-CMS(1) 264.22 0.68 177.76 264.20 165.58 -2.09 1.32 5,960,598.15 549,891.16 4.17 -2.04 GYD-CT-CMS(1) 284.22 0.83 128.89 284.20 185.58 -2.30 1.44 5,960,597.94 549,891.28 3.20 -2.24 GYD-CT-CMS(1) 304.22 0.44 107.78 304.20 205.58 -2.41 1.63 5,960,597.83 549,891.47 2.24 -2.35 GYD-CT-CMS(1) 324.22 0.74 153.86 324.20 225.58 -2.55 1.76 5,960,597.69 549,891.60 2.69 -2.49 GYD-CT-CMS(1) 1/17/2011 6:04:23PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1 E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1 E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1 E-08 North Reference: True Wellbore: 1 E-08A Survey Calculation Method: Minimum Curvature Design: 1 E-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 344.22 0.68 85.61 344.20 245.58 -2.66 1.93 5,960,597.59 549,891.78 3.99 -2.59 GYD-CT-CMS(1) 364.22 0.59 188.05 364.20 265.58 -2.75 2.04 5,960,597.49 549,891.88 4.96 -2.68 GYD-CT-CMS(1) 384.22 0.72 103.98 384.20 285.58 -2.88 2.14 5,960,597.36 549,891.99 4.41 -2.80 GYD-CT-CMS(1) 404.22 0.49 203.36 404.20 305.58 -2.99 2.23 5,960,597.25 549,892.08 4.67 -2.91 GYD-CT-CMS(1) 424.22 0.70 131.47 424.19 325.57 -3.15 2.29 5,960,597.10 549,892.14 3.59 -3.07 GYD-CT-CMS(1) 444.22 0.43 0.39 444.19 345.57 -3.16 2.38 5,960,597.09 549,892.23 5.17 -3.07 GYD-CT-CMS(1) 464.22 0.68 160.83 464.19 365.57 -3.19 2.42 5,960,597.05 549,892.27 5.47 -3.11 GYD-CT-CMS(1) 484.22 0.63 82.99 484.19 385.57 -3.29 2.57 5,960,596.96 549,892.42 4.12 -3.20 GYD-CT-CMS(1) 504.22 0.59 180.66 504.19 405.57 -3.38 2.68 5,960,596.87 549,892.52 4.59 -3.29 GYD-CT-CMS(1) 524.22 0.38 296.70 524.19 425.57 -3.45 2.62 5,960,596.79 549,892.46 4.15 -3.36 GYD-CT-CMS(1) 544.22 0.66 124.42 544.19 445.57 -3.49 2.65 5,960,596.76 549,892.50 5.19 -3.39 GYD-CT-CMS(1) 564.22 0.59 183.91 564.19 465.57 -3.66 2.74 5,960,596.59 549,892.59 3.12 -3.56 GYD-CT-CMS(1) 584.22 0.40 215.93 584.19 485.57 -3.82 2.69 5,960,596.43 549,892.54 1.64 -3.72 GYD-CT-CMS(1) 604.22 0.39 102.20 604.19 505.57 -3.89 2.72 5,960,596.36 549,892.57 3.31 -3.79 GYD-CT-CMS(1) 624.22 0.48 92.90 624.19 525.57 -3.91 2.87 5,960,596.34 549,892.72 0.57 -3.80 GYD-CT-CMS(1) 644.22 0.61 146.66 644.19 545.57 -4.00 3.01 5,960,596.25 549,892.86 2.53 -3.89 GYD-CT-CMS(1) 664.22 0.63 190.89 664.19 565.57 -4.20 3.05 5,960,596.05 549,892.90 2.34 -4.09 GYD-CT-CMS(1) 684.22 0.38 251.90 684.19 585.57 -4.32 2.96 5,960,595.93 549,892.82 2.78 -4.22 GYD-CT-CMS(1) 704.22 0.42 153.45 704.19 605.57 -4.41 2.93 5,960,595.84 549,892.79 3.03 -4.31 GYD-CT-CMS(1) 724.22 0.60 200.99 724.19 625.57 -4.57 2.93 5,960,595.68 549,892.78 2.21 -4.47 GYD-CT-CMS(1) 744.22 0.53 240.90 744.18 645.56 -4.72 2.81 5,960,595.53 549,892.67 1.96 -4.62 GYD-CT-CMS(1) 764.22 0.30 188.95 764.18 665.56 -4.81 2.72 5,960,595.43 549,892.58 2.09 -4.72 GYD-CT-CMS(1) 784.22 0.56 190.03 784.18 685.56 -4.96 2.70 5,960,595.29 549,892.55 1.30 -4.86 GYD-CT-CMS(1) 804.22 0.48 255.53 804.18 705.56 -5.08 2.60 5,960,595.17 549,892.46 2.83 -4.98 GYD-CT-CMS(1) 824.22 0.30 177.69 824.18 725.56 -5.15 2.52 5,960,595.10 549,892.38 2.55 -5.06 GYD-CT-CMS(1) 844.22 0.52 237.01 844.18 745.56 -5.25 2.45 5,960,594.99 549,892.31 2.24 -5.17 GYD-CT-CMS(1) 864.22 0.28 296.05 864.18 765.56 -5.28 2.33 5,960,594.96 549,892.19 2.23 -5.20 GYD-CT-CMS(1) 884.22 0.47 243.31 884.18 785.56 -5.30 2.21 5,960,594.95 549,892.07 1.87 -5.22 GYD-CT-CMS(1) 904.22 0.39 299.25 904.18 805.56 -5.30 2.08 5,960,594.94 549,891.94 2.05 -5.22 GYD-CT-CMS(1) 924.22 0.40 259.39 924.18 825.56 -5.28 1.95 5,960,594.96 549,891.81 1.35 -5.21 GYD-CT-CMS(1) 944.22 0.60 308.61 944.18 845.56 -5.23 1.80 5,960,595.01 549,891.66 2.27 -5.16 GYD-CT-CMS(1) 964.22 0.60 304.15 964.18 865.56 -5.10 1.63 5,960,595.14 549,891.49 0.23 -5.04 GYD-CT-CMS(1) 984.22 1.49 331.54 984.18 885.56 -4.82 1.42 5,960,595.42 549,891.28 4.98 -4.76 GYD-CT-CMS(1) 1,004.22 2.00 324.12 1,004.17 905.55 -4.30 1.09 5,960,595.93 549,890.94 2.78 -4.26 GYD-CT-CMS(1) 1,024.22 2.67 335.60 1,024.15 925.53 -3.60 0.69 5,960,596.64 549,890.54 4.07 -3.57 GYD-CT-CMS(1) 1,044.22 3.03 331.06 1,044.12 945.50 -2.71 0.24 5,960,597.52 549,890.09 2.12 -2.70 GYD-CT-CMS(1) 1,064.22 3.67 334.83 1,064.09 965.47 -1.67 -0.28 5,960,598.56 549,889.55 3.38 -1.68 GYD-CT-CMS(1) 1,084.22 3.91 336.61 1,084.05 985.43 -0.46 -0.83 5,960,599.76 549,889.00 1.34 -0.49 GYD-CT-CMS(1) 1,104.22 4.59 334.01 1,103.99 1,005.37 0.88 -1.45 5,960,601.10 549,888.37 3.53 0.83 GYD-CT-CMS(1) 1,124.22 5.35 334.01 1,123.92 1,025.30 2.44 -2.21 5,960,602.65 549,887.60 3.80 2.36 GYD-CT-CMS(1) 1/17/2011 6:04:23PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1E-08 North Reference: True Wellbore: 1 E-08A Survey Calculation Method: Minimum Curvature Design: 1 E-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,144.22 5.73 334.96 1,143.82 1,045.20 4.18 -3.04 5,960,604.39 549,886.76 1.95 4.07 GYD-CT-CMS(1) 1,164.22 6.21 333.09 1,163.71 1,065.09 6.05 -3.95 5,960,606.25 549,885.84 2.59 5.91 GYD-CT-CMS(1) 1,184.22 6.23 334.91 1,183.60 1,084.98 8.00 -4.90 5,960,608.19 549,884.87 0.99 7.82 GYD-CT-CMS(1) 1,204.22 6.97 334.91 1,203.46 1,104.84 10.08 -5.87 5,960,610.27 549,883.88 3.70 9.87 GYD-CT-CMS(1) 1,224.22 7.57 337.89 1,223.30 1,124.68 12.40 -6.88 5,960,612.58 549,882.86 3.54 12.15 GYD-CT-CMS(1) 1,244.22 8.92 340.91 1,243.10 1,144.48 15.09 -7.89 5,960,615.26 549,881.84 7.09 14.80 GYD-CT-CMS(1) 1,264.22 10.62 343.35 1,262.81 1,164.19 18.32 -8.92 5,960,618.48 549,880.78 8.75 17.99 GYD-CT-CMS(1) 1,284.22 11.20 341.54 1,282.44 1,183.82 21.92 -10.07 5,960,622.08 549,879.61 3.37 21.56 GYD-CT-CMS(1) 1,304.22 11.69 343.30 1,302.05 1,203.43 25.71 -11.26 5,960,625.86 549,878.39 3.01 25.30 GYD-CT-CMS(1) 1,324.22 12.01 342.86 1,321.62 1,223.00 29.64 -12.46 5,960,629.78 549,877.17 1.66 29.18 GYD-CT-CMS(1) 1,344.22 12.01 343.03 1,341.18 1,242.56 33.62 -13.68 5,960,633.75 549,875.92 0.18 33.12 GYD-CT-CMS(1) 1,364.22 12.36 342.54 1,360.73 1,262.11 37.65 -14.93 5,960,637.77 549,874.65 1.82 37.10 GYD-CT-CMS(1) 1,384.22 12.81 341.15 1,380.25 1,281.63 41.79 -16.29 5,960,641.90 549,873.26 2.71 41.19 GYD-CT-CMS(1) 1,404.22 13.16 339.43 1,399.74 1,301.12 46.02 -17.80 5,960,646.12 549,871.72 2.61 45.37 GYD-CT-CMS(1) 1,424.22 13.83 338.39 1,419.19 1,320.57 50.37 -19.48 5,960,650.47 549,870.01 3.56 49.66 GYD-CT-CMS(1) 1,444.22 14.35 337.65 1,438.59 1,339.97 54.89 -21.31 5,960,654.97 549,868.16 2.75 54.11 GYD-CT-CMS(1) 1,464.22 14.91 336.85 1,457.94 1,359.32 59.54 -23.26 5,960,659.61 549,866.17 2.98 58.70 GYD-CT-CMS(1) 1,484.22 15.59 336.53 1,477.23 1,378.61 64.38 -25.34 5,960,664.43 549,864.06 3.43 63.45 GYD-CT-CMS(1) 1,504.22 16.10 335.85 1,496.47 1,397.85 69.37 -27.55 5,960,669.41 549,861.82 2.71 68.37 GYD-CT-CMS(1) 1,524.22 16.80 336.84 1,515.65 1,417.03 74.56 -29.82 5,960,674.58 549,859.51 3.77 73.47 GYD-CT-CMS(1) 1,544.22 17.70 337.40 1,534.75 1,436.13 80.02 -32.12 5,960,680.03 549,857.17 4.58 78.85 GYD-CT-CMS(1) 1,564.22 18.26 337.53 1,553.78 1,455.16 85.73 -34.49 5,960,685.72 549,854.77 2.81 84.47 GYD-CT-CMS(1) 1,584.22 19.20 338.49 1,572.72 1,474.10 91.68 -36.89 5,960,691.65 549,852.33 4.95 90.34 GYD-CT-CMS(1) 1,604.22 19.82 338.47 1,591.57 1,492.95 97.89 -39.34 5,960,697.85 549,849.84 3.10 96.46 GYD-CT-CMS(1) 1,624.22 20.32 339.17 1,610.35 1,511.73 104.29 -41.82 5,960,704.23 549,847.31 2.77 102.77 GYD-CT-CMS(1) 1,644.22 21.29 338.92 1,629.05 1,530.43 110.93 -44.36 5,960,710.85 549,844.73 4.87 109.31 GYD-CT-CMS(1) 1,664.22 22.13 338.59 1,647.63 1,549.01 117.82 -47.05 5,960,717.73 549,842.00 4.24 116.11 GYD-CT-CMS(1) 1,684.22 22.84 338.40 1,666.11 1,567.49 124.94 -49.85 5,960,724.82 549,839.15 3.57 123.12 GYD-CT-CMS(1) 1,704.22 23.77 338.29 1,684.48 1,585.86 132.29 -52.77 5,960,732.16 549,836.18 4.66 130.37 GYD-CT-CMS(1) 1,724.22 24.29 338.10 1,702.75 1,604.13 139.86 -55.79 5,960,739.70 549,833.11 2.63 137.82 GYD-CT-CMS(1) 1,744.22 25.03 339.17 1,720.92 1,622.30 147.63 -58.83 5,960,747.45 549,830.02 4.32 145.48 GYD-CT-CMS(1) 1,764.22 25.88 340.01 1,738.98 1,640.36 155.68 -61.83 5,960,755.48 549,826.97 4.62 153.43 GYD-CT-CMS(1) 1,784.22 26.55 340.99 1,756.92 1,658.30 164.01 -64.78 5,960,763.79 549,823.97 3.99 161.65 GYD-CT-CMS(1) 1,804.22 27.24 341.87 1,774.76 1,676.14 172.59 -67.66 5,960,772.35 549,821.03 3.98 170.12 GYD-CT-CMS(1) 1,824.22 27.90 343.27 1,792.49 1,693.87 181.42 -70.43 5,960,781.16 549,818.20 4.62 178.85 GYD-CT-CMS(1) 1,844.22 28.52 343.98 1,810.11 1,711.49 190.49 -73.09 5,960,790.21 549,815.47 3.53 187.82 GYD-CT-CMS(1) 1,864.22 29.17 344.13 1,827.63 1,729.01 199.77 -75.75 5,960,799.47 549,812.76 3.27 197.00 GYD-CT-CMS(1) 1,884.22 29.49 344.53 1,845.07 1,746.45 209.20 -78.39 5,960,808.88 549,810.05 1.88 206.34 GYD-CT-CMS(1) 1,904.22 30.01 343.99 1,862.43 1,763.81 218.75 -81.08 5,960,818.42 549,807.30 2.92 215.79 GYD-CT-CMS(1) 1,924.22 30.56 343.07 1,879.70 1,781.08 228.42 -83.94 5,960,828.07 549,804.37 3.60 225.35 GYD-CT-CMS(1) 1/17/2011 6:04:23PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1 E-08 North Reference: True Wellbore: 1 E-08A Survey Calculation Method: Minimum Curvature Design: 1 E-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,944.22 31.10 342.35 1,896.88 1,798.26 238.21 -86.99 5,960,837.83 549,801.26 3.27 235.03 GYD-CT-CMS(1) 1,964.22 31.41 341.36 1,913.97 1,815.35 248.07 -90.22 5,960,847.67 549,797.97 3.00 244.77 GYD-CT-CMS(1) 1,984.22 31.65 340.89 1,931.02 1,832.40 257.97 -93.61 5,960,857.54 549,794.52 1.72 254.54 GYD-CT-CMS(1) 2,004.22 31.87 340.61 1,948.03 1,849.41 267.90 -97.08 5,960,867.46 549,790.98 1.32 264.35 GYD-CT-CMS(1) 2,024.22 31.79 340.39 1,965.02 1,866.40 277.85 -100.60 5,960,877.38 549,787.39 0.70 274.17 GYD-CT-CMS(1) 2,044.22 31.67 340.25 1,982.03 1,883.41 287.75 -104.14 5,960,887.26 549,783.79 0.70 283.94 GYD-CT-CMS(1) 2,064.22 31.58 340.09 1,999.06 1,900.44 297.62 -107.70 5,960,897.10 549,780.16 0.62 293.68 GYD-CT-CMS(1) 2,084.22 31.45 340.03 2,016.11 1,917.49 307.44 -111.26 5,960,906.90 549,776.53 0.67 303.37 GYD-CT-CMS(1) 2,104.22 31.37 339.81 2,033.18 1,934.56 317.23 -114.84 5,960,916.66 549,772.89 0.70 313.03 GYD-CT-CMS(1) 2,124.22 31.31 339.73 2,050.26 1,951.64 326.99 -118.44 5,960,926.40 549,769.23 0.37 322.66 GYD-CT-CMS(1) 2,144.22 31.06 339.74 2,067.37 1,968.75 336.71 -122.03 5,960,936.09 549,765.58 1.25 332.25 GYD-CT-CMS(1) 2,164.22 31.01 339.84 2,084.51 1,985.89 346.39 -125.59 5,960,945.74 549,761.95 0.36 341.79 GYD-CT-CMS(1) 2,184.22 31.02 339.95 2,101.65 2,003.03 356.06 -129.13 5,960,955.39 549,758.35 0.29 351.34 GYD-CT-CMS(1) 2,204.22 31.09 340.05 2,118.78 2,020.16 365.76 -132.66 5,960,965.06 549,754.75 0.43 360.91 GYD-CT-CMS(1) 2,224.22 31.16 340.18 2,135.90 2,037.28 375.48 -136.18 5,960,974.76 549,751.17 0.49 370.50 GYD-CT-CMS(1) 2,244.22 31.19 340.50 2,153.01 2,054.39 385.23 -139.66 5,960,984.49 549,747.63 0.84 380.12 GYD-CT-CMS(1) 2,264.22 31.35 340.77 2,170.11 2,071.49 395.02 -143.10 5,960,994.26 549,744.12 1.06 389.79 GYD-CT-CMS(1) 2,284.22 31.53 340.82 2,187.17 2,088.55 404.88 -146.53 5,961,004.08 549,740.62 0.91 399.51 GYD-CT-CMS(1) 2,304.22 31.67 340.94 2,204.21 2,105.59 414.78 -149.96 5,961,013.96 549,737.12 0.77 409.29 GYD-CT-CMS(1) 2,324.22 31.69 341.14 2,221.23 2,122.61 424.71 -153.38 5,961,023.87 549,733.65 0.53 419.10 GYD-CT-CMS(1) 2,344.22 31.93 341.07 2,238.22 2,139.60 434.68 -156.79 5,961,033.82 549,730.17 1.21 428.95 GYD-CT-CMS(1) 2,364.22 32.02 341.01 2,255.19 2,156.57 444.70 -160.23 5,961,043.81 549,726.66 0.48 438.84 GYD-CT-CMS(1) 2,384.22 32.12 340.92 2,272.14 2,173.52 454.74 -163.70 5,961,053.83 549,723.13 0.55 448.75 GYD-CT-CMS(1) 2,404.22 32.18 340.86 2,289.07 2,190.45 464.80 -167.18 5,961,063.86 549,719.58 0.34 458.68 GYD-CT-CMS(1) 2,424.22 32.06 340.57 2,306.01 2,207.39 474.83 -170.69 5,961,073.87 549,716.00 0.98 468.59 GYD-CT-CMS(1) 2,444.22 31.99 340.30 2,322.96 2,224.34 484.83 -174.24 5,961,083.84 549,712.38 0.80 478.45 GYD-CT-CMS(1) 2,464.22 32.09 340.27 2,339.92 2,241.30 494.81 -177.82 5,961,093.80 549,708.74 0.51 488.31 GYD-CT-CMS(1) 2,484.22 32.03 340.23 2,356.87 2,258.25 504.81 -181.41 5,961,103.77 549,705.08 0.32 498.17 GYD-CT-CMS(1) 2,504.22 32.06 340.36 2,373.82 2,275.20 514.80 -184.99 5,961,113.74 549,701.44 0.38 508.03 GYD-CT-CMS(1) 2,524.22 32.12 340.41 2,390.77 2,292.15 524.80 -188.56 5,961,123.72 549,697.81 0.33 517.90 GYD-CT-CMS(1) 2,544.22 32.14 340.49 2,407.70 2,309.08 534.83 -192.11 5,961,133.72 549,694.18 0.24 527.80 GYD-CT-CMS(1) 2,564.22 32.16 340.60 2,424.64 2,326.02 544.86 -195.66 5,961,143.73 549,690.57 0.31 537.70 GYD-CT-CMS(1) 2,584.22 32.21 340.56 2,441.56 2,342.94 554.91 -199.20 5,961,153.75 549,686.96 0.27 547.62 GYD-CT-CMS(1) 2,604.22 32.15 340.73 2,458.49 2,359.87 564.96 -202.73 5,961,163.78 549,683.37 0.54 557.54 GYD-CT-CMS(1) 2,624.22 32.26 340.71 2,475.41 2,376.79 575.02 -206.25 5,961,173.81 549,679.78 0.55 567.47 GYD-CT-CMS(1) 2,644.22 32.44 340.81 2,492.31 2,393.69 585.13 -209.78 5,961,183.89 549,676.19 0.94 577.45 GYD-CT-CMS(1) 2,664.22 32.38 340.92 2,509.19 2,410.57 595.25 -213.29 5,961,194.00 549,672.61 0.42 587.45 GYD-CT-CMS(1) 2,684.22 32.55 340.93 2,526.07 2,427.45 605.40 -216.80 5,961,204.12 549,669.03 0.85 597.46 GYD-CT-CMS(1) 2,704.22 32.71 340.95 2,542.91 2,444.29 615.59 -220.32 5,961,214.29 549,665.44 0.80 607.53 GYD-CT-CMS(1) 2,724.22 32.55 341.06 2,559.75 2,461.13 625.79 -223.83 5,961,224.46 549,661.86 0.85 617.60 GYD-CT-CMS(1) 1/17/2011 6:04:23PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1 E-08 North Reference: True Wellbore: 1 E-08A Survey Calculation Method: Minimum Curvature Design: 1 E-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 2,744.22 32.66 341.23 2,576.60 2,477.98 635.99 -227.31 5,961,234.63 549,658.31 0.72 627.67 GYD-CT-CMS(1) 2,764.22 32.52 341.32 2,593.45 2,494.83 646.19 -230.77 5,961,244.81 549,654.79 0.74 637.74 GYD-CT-CMS(1) 2,784.22 32.37 341.35 2,610.33 2,511.71 656.36 -234.21 5,961,254.95 549,651.29 0.75 647.78 GYD-CT-CMS(1) 2,804.22 32.38 341.51 2,627.22 2,528.60 666.51 -237.62 5,961,265.08 549,647.81 0.43 657.81 GYD-CT-CMS(1) 2,824.22 32.39 341.61 2,644.11 2,545.49 676.67 -241.01 5,961,275.22 549,644.36 0.27 667.85 GYD-CT-CMS(1) 2,844.22 32.28 341.74 2,661.01 2,562.39 686.82 -244.37 5,961,285.35 549,640.92 0.65 677.88 GYD-CT-CMS(1) 2,864.22 32.09 341.48 2,677.94 2,579.32 696.93 -247.73 5,961,295.43 549,637.50 1.18 687.86 GYD-CT-CMS(1) 2,884.22 31.99 342.16 2,694.89 2,596.27 707.01 -251.04 5,961,305.49 549,634.12 1.87 697.82 GYD-CT-CMS(1) 2,904.22 31.97 342.35 2,711.86 2,613.24 717.10 -254.27 5,961,315.56 549,630.83 0.51 707.79 GYD-CT-CMS(1) 2,924.22 32.13 342.69 2,728.81 2,630.19 727.22 -257.46 5,961,325.66 549,627.57 1.21 717.80 GYD-CT-CMS(1) 2,944.22 32.19 342.91 2,745.74 2,647.12 737.39 -260.60 5,961,335.81 549,624.36 0.66 727.85 GYD-CT-CMS(1) 2,964.22 32.21 343.19 2,762.66 2,664.04 747.59 -263.71 5,961,345.98 549,621.18 0.75 737.93 GYD-CT-CMS(1) 2,984.22 32.28 343.07 2,779.58 2,680.96 757.80 -266.81 5,961,356.17 549,618.02 0.47 748.03 GYD-CT-CMS(1) 3,004.22 32.14 343.45 2,796.50 2,697.88 768.01 -269.88 5,961,366.36 549,614.88 1.23 758.12 GYD-CT-CMS(1) 3,024.22 32.09 343.39 2,813.44 2,714.82 778.20 -272.91 5,961,376.52 549,611.78 0.30 768.20 GYD-CT-CMS(1) 3,044.22 32.14 343.33 2,830.38 2,731.76 788.39 -275.96 5,961,386.69 549,608.67 0.30 778.28 GYD-CT-CMS(1) 3,064.22 31.86 343.53 2,847.34 2,748.72 798.54 -278.98 5,961,396.83 549,605.58 1.50 788.32 GYD-CT-CMS(1) 3,084.22 31.94 343.45 2,864.32 2,765.70 808.68 -281.98 5,961,406.94 549,602.51 0.45 798.34 GYD-CT-CMS(1) 3,104.22 32.16 343.29 2,881.27 2,782.65 818.85 -285.02 5,961,417.09 549,599.40 1.18 808.40 GYD-CT-CMS(1) 3,124.22 31.94 343.66 2,898.22 2,799.60 829.02 -288.04 5,961,427.24 549,596.32 1.47 818.46 GYD-CT-CMS(1) 3,144.22 31.94 343.68 2,915.19 2,816.57 839.18 -291.01 5,961,437.37 549,593.27 0.05 828.51 GYD-CT-CMS(1) 3,164.22 32.05 343.69 2,932.16 2,833.54 849.35 -293.99 5,961,447.52 549,590.23 0.55 838.57 GYD-CT-CMS(1) 3,184.22 32.02 343.67 2,949.11 2,850.49 859.53 -296.97 5,961,457.68 549,587.18 0.16 848.64 GYD-CT-CMS(1) 3,204.22 31.97 343.62 2,966.07 2,867.45 869.70 -299.96 5,961,467.83 549,584.13 0.28 858.70 GYD-CT-CMS(1) 3,224.22 31.99 343.65 2,983.04 2,884.42 879.86 -302.94 5,961,477.97 549,581.08 0.13 868.75 GYD-CT-CMS(1) 3,244.22 31.80 343.60 3,000.02 2,901.40 890.00 -305.92 5,961,488.09 549,578.03 0.96 878.78 GYD-CT-CMS(1) 3,264.22 31.86 343.40 3,017.01 2,918.39 900.11 -308.92 5,961,498.18 549,574.97 0.61 888.78 GYD-CT-CMS(1) 3,284.22 31.67 343.16 3,034.01 2,935.39 910.19 -311.94 5,961,508.24 549,571.87 1.14 898.75 GYD-CT-CMS(1) 3,304.22 31.61 343.16 3,051.04 2,952.42 920.24 -314.98 5,961,518.26 549,568.77 0.30 908.68 GYD-CT-CMS(1) 3,324.22 31.83 343.15 3,068.05 2,969.43 930.30 -318.03 5,961,528.31 549,565.65 1.10 918,63 GYD-CT-CMS(1) 3,344.22 31.72 343.39 3,085.06 2,986.44 940.39 -321.06 5,961,538.37 549,562.56 0.84 928.61 GYD-CT-CMS(1) 3,364.22 31.81 343.52 3,102.06 3,003.44 950.48 -324.06 5,961,548.44 549,559.49 0.57 938.59 GYD-CT-CMS(1) 3,384.22 31.83 343.59 3,119.06 3,020.44 960.59 -327.05 5,961,558.54 549,556.44 0.21 948.59 GYD-CT-CMS(1) 3,404.22 32.33 343.79 3,136,00 3,037.38 970.79 -330.03 5,961,568.71 549,553.39 2.56 958.68 GYD-CT-CMS(1) 3,424.22 32.83 344.24 3,152.85 3,054.23 981.14 -332.99 5,961,579.04 549,550.36 2.78 968.92 GYD-CT-CMS(1) 3,444.22 33.45 344.51 3,169.60 3,070.98 991.67 -335.94 5,961,589.55 549,547.34 3.19 979.34 GYD-CT-CMS(1) 3,464.22 33.99 344.92 3,186.24 3,087.62 1,002.38 -338.87 5,961,600.24 549,544.34 2.93 989.94 GYD-CT-CMS(1) 3,484.22 34.20 345.23 3,202.80 3,104.18 1,013.21 -341.75 5,961,611.05 549,541.38 1.36 1,000.67 GYD-CT-CMS(1) 3,504.22 34.22 345.66 3,219.34 3,120.72 1,024.10 -344.58 5,961,621.92 549,538.49 1.21 1,011.45 GYD-CT-CMS(1) 3,524.22 33.99 346.10 3,235.90 3,137.28 1,034.97 -347.32 5,961,632.77 549,535.68 1.69 1,022.22 GYD-CT-CMS(1) 1/17/2011 6.04:23PM Page 6 COMPASS 2003 16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1 E-08 North Reference: True Wellbore: 1 E-08A Survey Calculation Method: Minimum Curvature Design: 1E-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,544.22 34.02 346.37 3,252.48 3,153.86 1,045.84 -349.98 5,961,643.62 549,532.95 0.77 1,032.98 GYD-CT-CMS(1) 3,564.22 34.15 346.50 3,269.04 3,170.42 1,056.73 -352.61 5,961,654.49 549,530.24 0.75 1,043.78 GYD-CT-CMS(1) 3,584.22 34.03 346.66 3,285.61 3,186.99 1,067.64 -355.21 5,961,665.38 549,527.57 0.75 1,054.59 GYD-CT-CMS(1) 3,604.22 33.95 346.78 3,302.19 3,203.57 1,078.52 -357.78 5,961,676.24 549,524.93 0.52 1,065.37 GYD-CT-CMS(1) 3,624.22 33.73 347.09 3,318.80 3,220.18 1,089.37 -360.29 5,961,687.07 549,522.34 1.40 1,076.13 GYD-CT-CMS(1) 3,644.22 33.14 347.64 3,335.49 3,236.87 1,100.12 -362.70 5,961,697.81 549,519.86 3.32 1,086.79 GYD-CT-CMS(1) 3,664.22 32.80 347.47 3,352.27 3,253.65 1,110.75 -365.05 5,961,708.42 549,517.44 1.76 1,097.33 GYD-CT-CMS(1) 3,684.22 32.59 347.48 3,369.10 3,270.48 1,121.29 -367.39 5,961,718.95 549,515.03 1.05 1,107.79 GYD-CT-CMS(1) 3,704.22 32.57 347.47 3,385.95 3,287.33 1,131.81 -369.73 5,961,729.45 549,512.63 0.10 1,118.21 GYD-CT-CMS(1) 3,724.22 32.65 347.51 3,402.80 3,304.18 1,142.33 -372.06 5,961,739.95 549,510.22 0.41 1,128.65 GYD-CT-CMS(1) 3,744.22 32.58 347.58 3,419.65 3,321.03 1,152.86 -374.39 5,961,750.46 549,507.83 0.40 1,139.09 GYD-CT-CMS(1) 3,764.22 32.65 347.91 3,436.49 3,337.87 1,163.39 -376.68 5,961,760.98 549,505.47 0.96 1,149.54 GYD-CT-CMS(1) 3,784.22 32.58 347.59 3,453.34 3,354.72 1,173.92 -378.96 5,961,771.50 549,503.11 0.93 1,159.98 GYD-CT-CMS(1) 3,804.22 32.32 347.40 3,470.22 3,371.60 1,184.40 -381.29 5,961,781.96 549,500.72 1.40 1,170.37 GYD-CT-CMS(1) 3,824.22 32.37 347.29 3,487.11 3,388.49 1,194.84 -383.63 5,961,792.38 549,498.31 0.39 1,180.72 GYD-CT-CMS(1) 3,844.22 32.54 347.23 3,503.99 3,405.37 1,205.31 -386.00 5,961,802.83 549,495.87 0.87 1,191.10 GYD-CT-CMS(1) 3,864.22 32.37 347.37 3,520.87 3,422.25 1,215.78 -388.36 5,961,813.29 549,493.44 0.93 1,201.49 GYD-CT-CMS(1) 3,884.22 32.45 347.06 3,537.75 3,439.13 1,226.23 -390.73 5,961,823.72 549,491.00 0.92 1,211.85 GYD-CT-CMS(1) 3,904.22 32.42 347.03 3,554.63 3,456.01 1,236.69 -393.13 5,961,834.16 549,488.53 0.17 1,222.21 GYD-CT-CMS(1) 3,924.22 32.29 347.12 3,571.53 3,472.91 1,247.12 -395.53 5,961,844.57 549,486.06 0.69 1,232.56 GYD-CT-CMS(1) 3,944.22 32.32 347.18 3,588.43 3,489.81 1,257.54 -397.91 5,961,854.98 549,483.62 0.22 1,242.89 GYD-CT-CMS(1) 3,964.22 32.20 347.18 3,605.34 3,506.72 1,267.95 -400.27 5,961,865.37 549,481.18 0.60 1,253.21 GYD-CT-CMS(1) 3,984.22 32.12 347.22 3,622.27 3,523.65 1,278.33 -402.63 5,961,875.73 549,478.75 0.41 1,263.50 GYD-CT-CMS(1) 4,004.22 32.21 347.05 3,639.20 3,540.58 1,288.71 -405.00 5,961,886.10 549,476.31 0.64 1,273.79 GYD-CT-CMS(1) 4,024.22 32.10 347.14 3,656.14 3,557.52 1,299.09 -407.38 5,961,896.46 549,473.87 0.60 1,284.08 GYD-CT-CMS(1) 4,044.22 32.07 347.07 3,673.08 3,574.46 1,309.44 -409.75 5,961,906.79 549,471.43 0.24 1,294.34 GYD-CT-CMS(1) 4,064.22 31.87 347.90 3,690.05 3,591.43 1,319.78 -412.05 5,961,917.12 549,469.06 2.41 1,304.59 GYD-CT-CMS(1) 4,084.22 31.69 347.99 3,707.05 3,608.43 1,330.08 -414.25 5,961,927.40 549,466.80 0.93 1,314.81 GYD-CT-CMS(1) 4,104.22 31.61 348.22 3,724.07 3,625.45 1,340.35 -416.41 5,961,937.65 549,464.57 0.72 1,325.00 GYD-CT-CMS(1) 4,124.22 31.71 348.37 3,741.10 3,642.48 1,350.63 -418.54 5,961,947.92 549,462.37 0.64 1,335.20 GYD-CT-CMS(1) 4,144.22 31.50 348.39 3,758.13 3,659.51 1,360.89 -420.65 5,961,958.17 549,460.19 1.05 1,345.39 GYD-CT-CMS(1) 4,164.22 31.53 348.30 3,775.18 3,676.56 1,371.13 -422.76 5,961,968.39 549,458.01 0.28 1,355.54 GYD-CT-CMS(1) 4,184.22 31.60 348.36 3,792.22 3,693.60 1,381.39 -424.88 5,961,978.63 549,455.82 0.38 1,365.72 GYD-CT-CMS(1) 4,204.22 31.39 348.47 3,809.28 3,710.66 1,391.62 -426.98 5,961,988.85 549,453.66 1.09 1,375.87 GYD-CT-CMS(1) 4,224.22 31.39 348.42 3,826.35 3,727.73 1,401.83 -429.06 5,961,999.04 549,451.50 0.13 1,386.00 GYD-CT-CMS(1) 4,244.22 31.47 348.52 3,843.42 3,744.80 1,412.05 -431.15 5,962,009.25 549,449.35 0.48 1,396.14 GYD-CT-CMS(1) 4,264.22 31.31 348.76 3,860.49 3,761.87 1,422.26 -433.20 5,962,019.44 549,447.23 1.02 1,406.28 GYD-CT-CMS(1) 4,284.22 31.26 348.53 3,877.58 3,778.96 1,432.44 -435.25 5,962,029.61 549,445.12 0.65 1,416.38 GYD-CT-CMS(1) 4,304.22 31.21 348.51 3,894.68 3,796.06 1,442.61 -437.31 5,962,039.76 549,442.99 0.26 1,426.47 GYD-CT-CMS(1) 4,324.22 31.12 348.77 3,911.79 3,813.17 1,452.75 -439.35 5,962,049.89 549,440.88 0.81 1,436.54 GYD-CT-CMS(1) 1/17/2011 6:04:23PM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1 E-08 North Reference: True Wellbore: 1E-08A Survey Calculation Method: Minimum Curvature Design: 1E-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,344.22 31.13 348.67 3,928.92 3,830.30 1,462.89 -441.37 5,962,060.02 549,438.79 0.26 1,446.60 GYD-CT-CMS(1) 4,364.22 31.01 348.54 3,946.05 3,847.43 1,473.01 -443.41 5,962,070.12 549,436.69 0.69 1,456.64 GYD-CT-CMS(1) 4,384.22 30.94 348.43 3,963.19 3,864.57 1,483.10 -445.46 5,962,080.19 549,434.57 0.45 1,466.65 GYD-CT-CMS(1) 4,404.22 30.90 348.37 3,980.35 3,881.73 1,493.16 -447,53 5,962,090.24 549,432.43 0.25 1,476.63 GYD-CT-CMS(1) 4,424.22 30.89 348.28 3,997.51 3,898.89 1,503.22 -449.61 5,962,100.29 549,430.29 0.24 1,486.61 GYD-CT-CMS(1) 4,444.22 30.68 348.56 4,014.70 3,916.08 1,513.25 -451.66 5,962,110.30 549,428.17 1.27 1,496.56 GYD-CT-CMS(1) 4,464.22 30.66 348.82 4,031.90 3,933.28 1,523.25 -453.67 5,962,120.29 549,426.10 0.67 1,506.49 GYD-CT-CMS(1) 4,484.22 30.62 348.77 4,049.11 3,950.49 1,533.25 -455.65 5,962,130.27 549,424.05 0.24 1,516.41 GYD-CT-CMS(1) 4,504.22 30.39 349.01 4,066.34 3,967.72 1,543.21 -457.60 5,962,140.22 549,422.03 1.30 1,526.30 GYD-CT-CMS(1) 4,524.22 30.58 349.05 4,083.57 3,984.95 1,553.17 -459.53 5,962,150.17 549,420.03 0.96 1,536.19 GYD-CT-CMS(1) 4,544.22 30.32 349.02 4,100.81 4,002.19 1,563.12 -461.46 5,962,160.10 549,418.04 1.30 1,546.07 GYD-CT-CMS(1) 4,564.22 30.06 349.52 4,118.10 4,019.48 1,573.01 -463.33 5,962,169.97 549,416.10 1.81 1,555.88 GYD-CT-CMS(1) 4,584.22 30.19 349.83 4,135.40 4,036.78 1,582.88 -465.13 5,962,179.83 549,414.24 1.01 1,565.68 GYD-CT-CMS(1) 4,604.22 30.00 349.67 4,152.70 4,054.08 1,592.75 -466.92 5,962,189.69 549,412.39 1.03 1,575.48 GYD-CT-CMS(1) 4,624.22 29.99 349.55 4,170.03 4,071.41 1,602.58 -468.72 5,962,199.51 549,410.52 0.30 1,585.25 GYD-CT-CMS(1) 4,644.22 30.31 350.14 4,187.32 4,088.70 1,612.47 -470.49 5,962,209.38 549,408.68 2.18 1,595.07 GYD-CT-CMS(1) 4,664.22 30.28 349.76 4,204.59 4,105.97 1,622.41 -472.25 5,962,219.31 549,406.86 0.97 1,604.94 GYD-CT-CMS(1) 4,684.22 30.45 349.77 4,221.84 4,123.22 1,632.35 -474.05 5,962,229.24 549,404.99 0.85 1,614.82 GYD-CT-CMS(1) 4,704.22 30.66 349.99 4,239.07 4,140.45 1,642.36 -475.83 5,962,239.24 549,403.14 1.19 1,624.76 GYD-CT-CMS(1) 4,724.22 30.49 349.93 4,256.29 4,157.67 1,652.38 -477.61 5,962,249.24 549,401.30 0.86 1,634.71 GYD-CT-CMS(1) 4,744.22 30.52 350.13 4,273.52 4,174.90 1,662.38 -479.37 5,962,259.23 549,399.48 0.53 1,644.64 GYD-CT-CMS(1) 4,764.22 30.64 350.06 4,290.74 4,192.12 1,672.40 -481.12 5,962,269.24 549,397.66 0.63 1,654.59 GYD-CT-CMS(1) 4,784.22 30.64 350.27 4,307.94 4,209.32 1,682.45 -482.86 5,962,279.27 549,395.85 0.54 1,664.57 GYD-CT-CMS(1) 4,804.22 30.75 350.34 4,325.14 4,226.52 1,692.51 -484.58 5,962,289.32 549,394.07 0.58 1,674.57 GYD-CT-CMS(1) 4,824.22 31.03 350.14 4,342.31 4,243.69 1,702.63 -486.32 5,962,299.43 549,392.26 1.49 1,684.62 GYD-CT-CMS(1) 4,844.22 30.75 350.29 4,359.47 4,260.85 1,712.75 -488.06 5,962,309.53 549,390.45 1.45 1,694.67 GYD-CT-CMS(1) 4,864.22 30.94 350.71 4,376.64 4,278.02 1,722.86 -489.75 5,962,319.63 549,388.69 1.44 1,704.72 GYD-CT-CMS(1) 4,884.22 30.94 350.56 4,393.79 4,295.17 1,733.01 -491.43 5,962,329.77 549,386.95 0.39 1,714.80 GYD-CT-CMS(1) 4,904.22 30.77 350.56 4,410.96 4,312.34 1,743.13 -493.11 5,962,339.87 549,385.20 0.85 1,724.85 GYD-CT-CMS(1) 4,924.22 30.84 350.67 4,428.14 4,329.52 1,753.23 -494.78 5,962,349.97 549,383.46 0.45 1,734.90 GYD-CT-CMS(1) 4,944.22 30.83 350.99 4,445.31 4,346.69 1,763.35 -496.41 5,962,360.07 549,381.76 0.82 1,744.95 GYD-CT-CMS(1) 4,964.22 30.65 350.79 4,462.50 4,363.88 1,773.45 -498.03 5,962,370.16 549,380.08 1.04 1,754.98 GYD-CT-CMS(1) 4,984.22 30.66 350.98 4,479.71 4,381.09 1,783.51 -499.65 5,962,380.21 549,378.39 0.49 1,764.99 GYD-CT-CMS(1) 5,004.22 30.44 351.12 4,496.93 4,398.31 1,793.56 -501.23 5,962,390.24 549,376.75 1.16 1,774.97 GYD-CT-CMS(1) 5,024.22 30.36 351.05 4,514.18 4,415.56 1,803.55 -502.80 5,962,400.23 549,375.11 0.44 1,784.91 GYD-CT-CMS(1) 5,044.22 30.29 351.20 4,531.45 4,432.83 1,813.53 -504.36 5,962,410.20 549,373.49 0.52 1,794.82 GYD-CT-CMS(1) 5,064.22 30.07 351.18 4,548.74 4,450.12 1,823.47 -505.90 5,962,420.12 549,371.88 1.10 1,804.70 GYD-CT-CMS(1) 5,084.22 30.02 351.02 4,566.05 4,467.43 1,833.36 -507.44 5,962,430.00 549,370.27 0.47 1,814.53 GYD-CT-CMS(1) 5,104.22 30.20 351.18 4,583.35 4,484.73 1,843.27 -509.00 5,962,439.90 549,368.65 0.99 1,824.39 GYD-CT-CMS(1) 5,124.22 29.77 352.24 4,600.67 4,502.05 1,853.16 -510.44 5,962,449.78 549,367.14 3.41 1,834.22 GYD-CT-CMS(1) 1/17/2011 6:04:23PM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1 E-08 North Reference: True Wellbore: 1 E-08A Survey Calculation Method: Minimum Curvature Design: 1 E-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,144.22 29.85 350.86 4,618.03 4,519.41 1,863.00 -511.90 5,962,459.61 549,365.62 3.45 1,844.00 GYD-CT-CMS(1) 5,164.22 29.78 351.99 4,635.38 4,536.76 1,872.83 -513.38 5,962,469.43 549,364.07 2.83 1,853.77 GYD-CT-CMS(1) 5,184.22 29.39 352.04 4,652.77 4,554.15 1,882.61 -514.75 5,962,479.20 549,362.63 1.95 1,863.50 GYD-CT-CMS(1) 5,204.22 29.74 351.91 4,670.17 4,571.55 1,892.38 -516.13 5,962,488.96 549,361.19 1.78 1,873.21 GYD-CT-CMS(1) 5,224.22 29.37 352.33 4,687.57 4,588.95 1,902.15 -517.48 5,962,498.72 549,359.77 2.12 1,882.93 GYD-CT-CMS(1) 5,244.22 29.38 352.62 4,704.99 4,606.37 1,911.88 -518.77 5,962,508.43 549,358.42 0.71 1,892.61 GYD-CT-CMS(1) 5,264.22 29.42 352.12 4,722.42 4,623.80 1,921.61 -520.07 5,962,518.16 549,357.05 1.24 1,902.29 GYD-CT-CMS(1) 5,284.22 29.20 352.63 4,739.86 4,641.24 1,931.31 -521.37 5,962,527.85 549,355.69 1.66 1,911.94 GYD-CT-CMS(1) 5,304.22 29.25 351.96 4,757.31 4,658.69 1,940.99 -522.68 5,962,537.52 549,354.32 1.65 1,921.57 GYD-CT-CMS(1) 5,324.22 29.22 353.28 4,774.77 4,676.15 1,950.68 -523.94 5,962,547.19 549,353.00 3.23 1,931.20 GYD-CT-CMS(1) 5,344.22 29.19 353.02 4,792.22 4,693.60 1,960.36 -525.10 5,962,556.87 549,351.77 0.65 1,940.84 GYD-CT-CMS(1) 5,364.22 29.10 352.42 4,809.69 4,711.07 1,970.03 -526.33 5,962,566.53 549,350.47 1.53 1,950.46 GYD-CT-CMS(1) 5,384.22 28.87 354.04 4,827.19 4,728.57 1,979.65 -527.48 5,962,576.14 549,349.27 4.09 1,960.03 GYD-CT-CMS(1) 5,404.22 28.90 353.61 4,844.70 4,746.08 1,989.25 -528.52 5,962,585.74 549,348.16 1.05 1,969.60 GYD-CT-CMS(1) 5,424.22 28.73 352.77 4,862.22 4,763.60 1,998.83 -529.66 5,962,595.30 549,346.96 2.20 1,979.12 GYD-CT-CMS(1) 5,444.22 28.74 354.51 4,879.76 4,781.14 2,008.38 -530.72 5,962,604.85 549,345.83 4.18 1,988.64 GYD-CT-CMS(1) 5,464.22 28.57 354.55 4,897.31 4,798.69 2,017.93 -531.64 5,962,614.39 549,344.85 0.86 1,998.14 GYD-CT-CMS(1) 5,484.22 28.69 353.32 4,914.86 4,816.24 2,027.46 -532.65 5,962,623.91 549,343.78 3.01 2,007.63 GYD-CT-CMS(1) 5,504.22 29.10 354.61 4,932.37 4,833.75 2,037.07 -533.67 5,962,633.51 549,342.70 3.73 2,017.20 GYD-CT-CMS(1) 5,524.22 29.34 354.28 4,949.83 4,851.21 2,046.78 -534.61 5,962,643.22 549,341.69 1.45 2,026.88 GYD-CT-CMS(1) 5,544.22 29.52 353.52 4,967.25 4,868.63 2,056.56 -535.66 5,962,652.98 549,340.58 2.07 2,036.61 GYD-CT-CMS(1) 5,564.22 29.83 354.76 4,984.63 4,886.01 2,066.40 -536.67 5,962,662.82 549,339.50 3.44 2,046.42 GYD-CT-CMS(1) 5,584.22 29.77 354.14 5,001.98 4,903.36 2,076.30 -537.63 5,962,672.71 549,338.47 1.57 2,056.27 GYD-CT-CMS(1) 5,604.22 30.12 353.69 5,019.31 4,920.69 2,086.22 -538.69 5,962,682.63 549,337.35 2.08 2,066.15 GYD-CT-CMS(1) 5,624.22 30.31 354.59 5,036.59 4,937.97 2,096.24 -539.71 5,962,692.63 549,336.26 2.46 2,076.12 GYD-CT-CMS(1) 5,644.22 30.61 353.56 5,053.83 4,955.21 2,106.32 -540.76 5,962,702.71 549,335.14 3.01 2,086.17 GYD-CT-CMS(1) 5,664.22 31.03 354.76 5,071.01 4,972.39 2,116.51 -541.80 5,962,712.89 549,334.03 3.72 2,096.32 GYD-CT-CMS(1) 5,684.22 30.91 353.74 5,088.16 4,989.54 2,126.75 -542.83 5,962,723.13 549,332.93 2.69 2,106.51 GYD-CT-CMS(1) 5,704.22 31.20 354.30 5,105.29 5,006.67 2,137.01 -543.91 5,962,733.38 549,331.79 2.05 2,116.73 GYD-CT-CMS(1) 5,712.00 31.32 354.45 5,111.94 5,013.32 2,141.03 -544.30 5,962,737.39 549,331.37 1.84 2,120.73 MWD+IFR-AK-CAZ-SC(2) 5,806.84 29.46 11.02 5,193.89 5,095.27 2,188.55 -542.23 5,962,784.92 549,333.13 9.03 2,168.29 MWD+IFR-AK-CAZ-SC(2) 5,854.68 26.87 12.57 5,236.07 5,137.45 2,210.65 -537.62 5,962,807.05 549,337.59 5.63 2,190.54 MWD+IFR-AK-CAZ-SC(2) 5,901.93 26.11 13.47 5,278.35 5,179.73 2,231.18 -532.88 5,962,827.61 549,342.20 1.82 2,211.23 MWD+IFR-AK-CAZ-SC(2) 5,994.35 27.37 14.91 5,360.89 5,262.27 2,271.49 -522.67 5,962,867.98 549,352.13 1.53 2,251.87 MWD+IFR-AK-CAZ-SC(2) 6,087.35 28.87 19.73 5,442.92 5,344.30 2,313.29 -509.59 5,962,909.86 549,364.93 2.93 2,294.10 MWD+IFR-AK-CAZ-SC(2) 6,134.19 31.08 20.57 5,483.49 5,384.87 2,335.26 -501.52 5,962,931.88 549,372.85 4.80 2,316.33 MWD+IFR-AK-CAZ-SC(2) 6,182.53 34.72 20.32 5,524.07 5,425.45 2,359.86 -492.36 5,962,956.54 549,381.86 7.54 2,341.24 MWD+IFR-AK-CAZ-SC(2) 6,229.15 36.93 19.64 5,561.87 5,463.25 2,385.50 -483.04 5,962,982.24 549,391.00 4.82 2,367.19 MWD+IFR-AK-CAZ-SC(2) 6,274.95 39.04 21.46 5,597.97 5,499.35 2,411.89 -473.14 5,963,008.69 549,400.73 5.22 2,393.91 MWD+IFR-AK-CAZ-SC(2) 6,321.22 39.89 23.11 5,633.69 5,535.07 2,439.10 -461.98 5,963,035.97 549,411.70 2.92 2,421.49 MWD+IFR-AK-CAZ-SC(2) 1/17/2011 6:04.23PM Page 9 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Well: 1E-08 North Reference: True Wellbore: 1 E-08A Survey Calculation Method: Minimum Curvature Design: 1 E-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 6,361.85 41.30 23.61 5,664.54 5,565.92 2,463.37 -451.50 5,963,060.31 549,422.03 3.56 2,446.11 MWD+IFR-AK-CAZ-SC(2) 6,408.84 43.08 22.87 5,699.36 5,600.74 2,492.36 -439.05 5,963,089.38 549,434.28 3.93 2,475.52 MWD+IFR-AK-CAZ-SC(2) 6,465.25 46.54 22.55 5,739.37 5,640.75 2,529.03 -423.70 5,963,126.15 549,449.38 6.15 2,512.71 MWD+IFR-AK-CAZ-SC(2) 6,511.26 49.09 22.84 5,770.27 5,671.65 2,560.48 -410.55 5,963,157.68 549,462.32 5.56 2,544.59 MWD+IFR-AK-CAZ-SC(2) 6,558.73 51.04 22.24 5,800.74 5,702.12 2,594.10 -396.60 5,963,191.39 549,476.05 4.22 2,578.68 MWD+IFR-AK-CAZ-SC(2) 6,652.94 54.16 23.12 5,857.95 5,759.33 2,663.14 -367.74 5,963,260.61 549,504.45 3.39 2,648.68 MWD+IFR-AK-CAZ-SC(2) 6,749.57 53.90 22.31 5,914.71 5,816.09 2,735.28 -337.54 5,963,332.94 549,534.17 0.73 2,721.83 MWD+IFR-AK-CAZ-SC(2) 6,842.04 54.61 22.94 5,968.73 5,870.11 2,804.55 -308.66 5,963,402.40 549,562.58 0.95 2,792.07 MWD+IFR-AK-CAZ-SC(2) 6,936.03 53.63 24.79 6,023.82 5,925.20 2,874.19 -277.86 5,963,472.23 549,592.91 1.91 2,862.74 MWD+IFR-AK-CAZ-SC(2) 7,028.21 54.84 23.15 6,077.69 5,979.07 2,942.54 -247.49 5,963,540.77 549,622.83 1.95 2,932.11 MWD+IFR-AK-CAZ-SC(2) 7,124.77 54.97 24.38 6,133.21 6,034.59 3,014.84 -215.65 5,963,613.28 549,654.18 1.05 3,005.48 MWD+IFR-AK-CAZ-SC(2) 7,223.07 53.34 26.14 6,190.77 6,092.15 3,086.90 -181.66 5,963,685.56 549,687.69 2.20 3,078.68 MWD+IFR-AK-CAZ-SC(2) 7,311.53 53.66 26.81 6,243.39 6,144.77 3,150.55 -149.96 5,963,749.41 549,718.96 0.71 3,143.40 MWD+IFR-AK-CAZ-SC(2) 7,405.27 54.87 26.98 6,298.14 6,199.52 3,218.41 -115.54 5,963,817.49 549,752.93 1.30 3,212.42 MWD+IFR-AK-CAZ-SC(2) 7,499.06 53.33 22.23 6,353.15 6,254.53 3,287.44 -83.89 5,963,886.72 549,784.11 4.42 3,282.51 MWD+IFR-AK-CAZ-SC(2) 7,593.56 52.79 20.25 6,409.95 6,311.33 3,357.83 -56.53 5,963,957.29 549,811.01 1.77 3,353.81 MWD+IFR-AK-CAZ-SC(2) 7,687.92 52.39 22.34 6,467.28 6,368.66 3,427.66 -29.32 5,964,027.29 549,837.75 1.81 3,424.55 MWD+IFR-AK-CAZ-SC(2) 7,780.95 53.52 20.03 6,523.33 6,424.71 3,496.89 -2.50 5,964,096.68 549,864.11 2.32 3,494.67 MWD+IFR-AK-CAZ-SC(2) 7,821.03 52.98 20.48 6,547.31 6,448.69 3,527.02 8.62 5,964,126.88 549,875.03 1.62 3,525.17 MWD+IFR-AK-CAZ-SC(2) 7,860.00 52.98 20.48 6,570.77 6,472.15 3,556.16 19.51 5,964,156.10 549,885.72 0.00 3,554.68 PROJECTED to TD 1/17/2011 6:04:23PM Page 10 COMPASS 2003.16 Build 69 111111111111111111111101 45 M. z. --- '''''' 10000001WANNommeriiiiii. . D.. till°11 0011141W.W1,=V~411041 solOsooloiliiimv°1111Wrinisminn,...II 11/141111 , '41101 i "W..FilitilloWS:=Am...... Alliftftimiv,411441 * . ----."'28.!fteiss..._ 44111114‹, , IFw- .. •01, 0001111111,11/ 1.1117.101•411wAllilllimimpillill 11 II il P-1-1744W •WiloollIWIMMINI/Wraliiiilip4OW , 011.°01101011W14=01=w1=1....111`411"P"r 4‘61441 11.1w— iiMra=riaiminoraWilliiiV <P. ,\ N41 N-1.%\lx \ � /ice- 0® ♦ rsriP1WO• \\*.N.40. •76N• \s„ OA=MP"*V 44 .._1 A t. ‘ \ / towate -0) .. Ws.‘ ' ‘‘ \ oo� i�E_►�., 'c‘ t.- It% 6 ♦ ♦ fie. �`/06 's'AN St o vntill\m 4 4 we ow.i... iO, �I'' 4III, ���,��j�1� �Pa Rk�,�y .9��1����1���`„",,,�� '''' ',,,, �1�j. ei f01111111r11011111111101111�i11'' 1111 'xtir 1 Wit ' Mbil„ IIII1111111��������... i 1III ... �\ , **60. 11, • , ll stait "`\\ �� ����si__ VII 'P\ MAI*I /�i . *♦ / �� 4 aa„. ,It pocjel,000#641# 44/101 1 90111 \ 4 o ��� ♦ ��. qii 41 hill 1011111111 .� .�oo FYI, // �/4/1,�igt-110 N ons . ter / h ifipiit illit ihe. i *go iftrarimIZI 4/0 `wayr==.0 0;0 / •••. as..0,�/ / / / w ♦ i Ail, r,, 10. . -ter /• r. 4•07111... . 414. ......., iiiilriflipiell1001 / � / --- ar fam,Romm,.. 11 /.,0, 4„,_4 „.7" ... --....milw,.....:5, • wog ..�- ----���� 00,-,- W5b Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 22, 2011 2:09 PM To: 'Long, Jill W Subject: RE: 1E-08A: Pre-Rig Wellwork Changes (PTD 210-181) Jill, The work scope has not changed substantially so just keep me up to date on any other possible changes to the well plan. We are working on the PTD for the laterals currently. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Long, Jill W [mailto:Jill.W.Long@conocophillips.com] Sent: Tuesday, February 22, 2011 1:49 PM To: Schwartz, Guy L (DOA) Subject: 1E-08A: Pre-Rig Wellwork Changes (PTD 210-181) Guy- As per our phone conversation, a portion of the pre-rig wellwork that was outlined in Sundry#311-028 will now occur after rig arrival. Due to complications with the cement squeeze, the top of cement was left in the 3.5" tubing rather than at the top of the whipstock. This has resulted in unplanned milling and underreaming work. Because the estimated rig arrival date is very near, the underreaming work is planned to take place with the rig, CDR2. The RCBL will need to be ran on the rig as well. If you have any questions or require further details please let me know. Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 2/22/2011 Note to File 1E-08A & 1E-08AL1 , L1-01,L1-02 ,L2 ,L2-01 pTU 2/6-15,1 The sidetrack 1E-08A was drilled as a CTD setup ( 5 laterals are planned out of this ST wellbore) after the failed RWO attempt on the 1E-08 left junk in the wellbore. Many difficulties were encountered in getting the 5 1/2 liner cemented ... the initial primary job packed off before any cement was pumped and the remedial shoot and sqz cementing went poorly also. There is enough cement above the Kuparuk zone to assure injection control but later during the completion phase a leak was also found in the liner at 6293' and so an additional packer was run above that to isolate it. This puts the top packer 1350' away from the injection zone (see attached 1E-08A well schematic) .... Well past the normal 200' limit for injectors. Additional sqz perfs have been shot below the lower packer and cement placed(for A to C sand isolation) ... the current operation is under-reaming the cement and then acquire another CBL in the 5.5" liner section below the packers. The well will initially be pre-produced for 3-6 months with it used ultimately as an injector(CPAI may request MWAG service). With the marginal cement quality and the placement of the upper packer an Administrative Approval (AA) should be generated for this well to insure extra safeguards and monitoring are in place before injection is started. CR ) ,Y7 Guy Scrtz Senior Petroleum Engineer 2-23-11 1E-06A Rotary Sidetrack - CTb Setup Completion Depth (Actual) A 1 16"65#H-40 casing @ •3-1/2"Gen IV Tubing Hanger 80'MD/80'TVD •3-1/2"9.3# •HES"X"Nipple 2.81"ID 500'/500' •3-1/2"9.3#L-3o LUL sf.o •3-1/2"X 1"KBMG GLM 2.867"ID 2,335'/2,230' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 3,483'/3,300' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 4,542'/4,100' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 5,400'/4,840' 10-3/4"45.5#K-55 •3-1/2"9.3#L-80 EUE 8RD .- casing @ 2,896'MD/ •3-1/2"9.3#L-80 EUE Box X IBT-M SCC 5,450'/4,884' 2,705'TVD •3-1/2"9.3#L-80 IBT-M SCC •3-1/2"X I"KBG-2-9 GLM 2.867"ID 6,190'/5,530' - i w/2000 psi shear valve Drifted to 2.81" •3-1/2"9.3#L-80 IBT-M SCC 5-''/z"TOL @ •3-1/2"9.3#L-80 IBT-M SCC Box X EUE 5,491'5-V2MD/4,921' •GBH-22 80-40 PBR,EUE 8RD •3 t....:: •KBH1/2-22"9.3#AnchorL-80 Seal NU As10RDsembly,Box X EUEEUE 8RD8RD TVD Sidetrack KOP •3-1/2"X 5-1/2"FAB Production Packer 6,265'/5,589' thru window in 7"@ •3-1/2"9.3#L-80 IBT-M SCC 5,712'MD/5,112'TVD •KBH-22 Anchor Seal Assembly,EUE 8 RD • •3-1/2"X 5-1/2"FAB Production Packer 7,050'/6,090' •3-1/2"9.3#L-80 NU 10RD Box X EUE 8RD •3-1/2"9.3#L-80 IBT-M SCC •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X 5-1/2"FAB Production Packer 7,220'/6,189' •3-1/2"9.3#L-80 NU 10RD Box X EUE 8RD •HES"X"Nipple 2.81"ID Baker"K-1"CIBP Bottom set @ 5,736' W •3-1/2"Mule Shoe LEG MD/5,124'TVD . ..- * Packer 6,265'/5,589' ,jj/ Packer 7,050'/6,090' , ., \j Lower Kalubik 7,150'/6,148' 4-1/2"15.5#L-80 HD-L Liner(1,300') » f Leak at 6,293' MD '��j.:: :. C-Sand 7,294'/6,233' Tubing cmt retainer; .,e -4. 41,2y, • @ 6,753'MD/ is 5 993'TVD - 5-1/2"15.5#L-80 HD-L X/O 4��� ' , ST-L @ 6,779'MD/5,930' ® / B-Shale 7,432'/6,313' TVD Perfs 7,175'/6,160' A-Sand 7,602'/6,415' Packer 7,220'/6,189' ; ,-, 1i I iluveach 7,795'/6,532' i ' '- Retainer 7,720'/6,493 `- Perfs 7,725'/6,498' ' 7"Open Hole TD @ 7,860'MD/6,571'TVD - ,_;;�,, 5-1/2"15.5#L-80 ST-L liner(1,038')@ 7,860'MD/6,571'TVD -17:- f ,,„.. 7"26#K-55 casing Revised by: .�' @ 7,568'MD/6,543'TVD Elmo Cecchetti Jan. 27. 2011 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 26, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1E-08A Run Date: 1/26/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-08A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 '9/(' •—`'/ Office: 907-273-3527 9 c) -/ Fax: 907-273-3535 rafael.barret•/),041paiillel.vpu 2 Date: FEB L 2011 Signed: Alaska Cil&Gas Cons. Cmnmissi)n Anci owe m WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 25, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 1E-08A Run Date: 1/24/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-08A Data in LAS format, Digital Log Image files 1 CD Rom 50-029-20496-01 Cement Bond Log 1 Color Log 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Rafael Barreto 6900 Arctic Blvd. z/ b 1 S I Anchorage, Alaska 99518 �� Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com RECF �> Date: FEB _ 21111 Signed: Alaska Oil&Gas Cons.C.,',,TninisCon An6.or e s WELL LOG TRANSMITTAL To: State of Alaska February 4, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 1E-08A AK-MW-0007889723 1E-08A 50-029-20496-01 2"x 5" MD TRIPLE COMBO Logs: 1 Color Log 2"x 5" TVD TRIPLE COMBO Logs: 1 Color Log Digital Log Images&LWDG-formatted LIS Data w/verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 ►:: ,.�. a urton.com DatEEL p I;, 2011 Signed: O....6 Alaska Oil it Gas Cons. C. ,inmission Anc;oroe giO '1c6 913 gas Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] li Sent: Monday, February 07, 2011 8:47 AM To: Schwartz, Guy L(DOA); Maunder, Thomas E (DOA) Cc: Cecchetti, Elmo B; Long, Jill W; Bommarito, Forest; NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 1E-08A Plan Forward (PTD 210-181) Guy, Thank you for the information. I guess we will pursue an MI service option at the same time as the AA process for the high packer(after the pre production period). The AA would be similar to the 1A-04A(200-194, AA AIO2B.11) amendment application. Additionally I believe they are planning on running some extra cement bond type logs on 1 E-08A to prove up cement/tubular integrity during the sidetrack/RWO process. Hopefully by that point we'll have enough integrity data for MI approval, or at least enough information to support an MI trial with before and after RST logs to confirm in zone injection.... Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, February 04, 2011 4:39 PM To: NSK Well Integrity Proj; Maunder,Thomas E (DOA) Subject: RE: 1E-08A Plan Forward (PTD 210-181) MJ, This well for some reason was permitted as a development well... although internally we knew that it was intended for injection service once the CTD sidetracks were drilled. The cementing and completion is less than optimum but we should be able to work out a more strenuous MIT cycle for an Admin Approval . I didn't realize you were also looking to inject MI in this well..... This is the first I have heard about MI. We haven't discussed internally about limiting the well service as of yet. The upcoming well work (cement squeezing of the liner) doesn't really impact our decision....it is mainly for CTD kickoff and A/C isolation issues as I understand. Regards, Guy Schwartz Senior Petroleum Engineer 4/7/2011 Page 2 of 3 AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Friday, February 04, 2011 9:56 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L(DOA) Cc: NSK Well Integrity Proj Subject: FW: 1E-08A Plan Forward (PTD 210-181) Tom and Guy, As I understand the CoP workover folks have been in contact with the Commission about the 1E-08A (PTD 210- 181). Please confirm the planned side track completion on 1E-08A(201-181)will allow for miscible or gas injection. I have attached a proposed schematic for your review. Please let me know if you have any questions or would like to discuss. This well is next in our well work schedule, therefore a timely response would be appreciated. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 om: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Se • Wednesday, January 26, 2011 8:24 AM To: Cecc ; i, Elmo B Cc: Long, Jill ►, Subject: RE: 1E-0: • 'Ian Forward (PTD 210-181) Elmo, yC� �• k.• Cc- As we discussed last night... the co •. ission approves the lower packer location and in general the completion plan for the well as you have outlined an. - own in the last updated schematic. With the marginal cement coverage above the target injection zone t e will be additional UIC monitoring requirements once the CTD sidetracks are drilled and the well is put o .••ection service. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Tuesday, January 25, 2011 4:41 PM To: Schwartz, Guy L(DOA) Subject: 1E-08A Plan Forward 4/7/2011 yug\in BF SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 / FAX (907)276-7542 Jill Long Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-08A Sundry Number: 311-028 Dear Ms. Long: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this T'day of February, 2011. Encl. 4111) ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Alaska 0'MF&G FEBaS 0 C3 ons. 2011 February 2, 2011 Commissioner-State of Alaska CORUIIISSIOq Alaska Oil &Gas Conservation Commission NnCfo ge 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a Sundry application to perforate and cement a portion of the liner in wellbore 1E-08A (PTD# 210-181). This work is being performed as part of the continued preparation for coiled tubing drilling (CTD) operations scheduled to begin March 1, 2011. The objective of the CTD project is to drill four lateral sidetracks (1 E-08AL1, 1 E-08AL1-01, 1 E-08AL2, and 1E- 08AL2-01) targeting the A4 and A5 sands. Two laterals each will be drilled from two single-string casing exits through the 5.5" liner. Permit to Drill applications for those laterals will be submitted separately from this Sundry application. Attached is an outline of the pre-CTD wellwork planned for 1 E-08A and a brief summary of CTD work. If you have any questions or require additional information please contact me at my office 907-263-4093 or on my cell phone 907-230-7550. Sincerely, Coiled Tubing Drilling Engineer STATE OF ALASKA (,, �,t 1 ,-.407 • ALAS L AND GAS CONSERVATION COMMIS, °I APPLICATION FOR SUNDRY APPROVALS �(rv�-4,'� 20 AAC 25.280 a 1.Type of Request: Abandon r Plug for Redrill r Perforate New Fool r Repair well r Change Approved Program r Suspend r Plug Perforations 17. Perforate p"..... Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Atter casing rOther: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17_ Exploratory r 210-181- 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-20496-01 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 1E-08A- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651- Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7860 6571 7720' 6493' 7720' Casing Length Size MD TVD Burst Collapse Conductor 48' 16" 80' 80' Surface 2864' 10.75" 2896' 2705' Intermediate 5693' 7" 5725' 5124' Liner 5491' 5.5" 7860' 6570' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 3.5" L-80 7296' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) 3.5"x 5.5"FAB 6269'MD and 5593'ND 3.5"x 5.5"FAB 7053'MD and 6093'ND 3.5"x 5.5"FAB 7223'MD and 6190'ND 12.Attachments: Description Summary of Proposal p' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development - Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/9/2011 Oil P - Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 Printed Name Jill Long Title: Wells Engineer Signature K—.)..1 IL- IM Phone:263-4093 Date 02/02j2.011 ommission Use Only Sundry Number: 311 -Q98 Conditions of approval: Notify Commission so that a representative may witness RECal Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r ""N ''-FB 0 3 ?O1 Other: -- 5 44 ; C131._ -fa Ce' ..,..-,.:s S:oa2c / ./a GC() . IIIIJJJJ ,;vRe rig s': G Corps.Ex- asion Subsequent Form Required: /a-yoy sri,;n(:age APPROVED BY / l Approved b / / COMMISSIONER THE COMMISSION Date: Z Form 10-403 Revis-• '► 's FEB 0 4 11 ° ' z'3."( Sub it in Duplicate Sundry Application for Perforating and Cementing KRU 1E-08A Well History Wellbore 1E-08 was originally drilled and completed as in 1980 as a commingled producer. In 1984 a workover was performed to install a selective completion allowing for isolation between the A and C-sands. Blast rings were placed in the straddle section. The wellbore was eventually converted to water injection in 1990. A leak was detected in the straddled section of tubing in 1995. A tubing patch was used to repair the leak and from that point on the well functioned as an A-sand only injector. From 2000-2008 the well was shut-in due to a corroded well line. When placed back in service in 2008, additional leaks were found in the straddle section. Leaks to the C-sand continued to be a problem in the wellbore. Since this well had been identified as a candidate for CTD, A-sand only sidetracks, the well was shut-in in February 2010 to allow for depressurization of the A-sand by crossflowing into the C. Preparation for CTD work began in November 2010 with a rig workover. The purpose of the workover was to replace the 3.5" leaking selective completion with new 3.5" tubing. During recovery operations, the tubing in the selective section parted resulting in some blast rings falling downhole. Due to the complications and low likelihood of recovering any equipment with broken blast rings present, workover operations were abandoned. A cement retainer was set and cement pumped. A rotary sidetrack was immediately planned in order to replace the well and set it up for CTD. The rotary sidetrack began January 5, 2011. After successfully sidetracking out of 1 E-08 and reaching TD, a )- . L 5.5" liner was run to bottom. While confirming circulation with the liner in place, the hole became packed off. ,t--°4- In an attempt to establish circulation and place cement above the Kuparuk, perforations were shot in the liner fie , ^'"" and a cement retainer was used for circulating in cement. Additional problems ensued but ultimately after a �. bond log was run, all parties agreed there was adequate cement above the top of the Kuparuk to proceed with I running the tubing completion. At that time, the post-rotary sidetrack/pre-CTD wellwork was planned to include remedial cement work, as is requested in this attached Sundry applications. This cement work d3 will help provide additional isolation between the A and C sands. The final 3.5" completion required three packers set in the liner to isolate the upper set of cement perforations as well as a liner leak., Operations on the rotary sidetrack were completed on January 31, 2011. CTD rig, Nabors CDR2-AC, is planned to begin operations on 1 E-08A on March 2, 2011. Operational Outline Pre-Rig Work 1. Changeout all gas lift valves to dummy valves. Drift wellbore with dummy whipstock. 2. Perforate the 5.5" liner across from potential CTD kickoff locations. Planned kickoff points are —7645' MD and —7564'MD. Perforations will also be shot across a backup kickoff location at—7527' MD. 3. Set the lower whipstock at—7645' MD. ✓ 4. Cement squeeze the openhole section behind the 5.5" liner. Contaminate and cleanout cement to the top of the whipstock at—7645' MD. (NOTE: This cement will provide additional isolation between the A and C sands as well as ensure there is good cement behind pipe at the kickoff locations.) 5. Drift and tag the top of the whipstock. 6. Run a cement bond log to evaluate the cement quality. V 7. Set BPV and prepare wellsite for rig arrival. Page 1 of 2 2/2/2011 4110 Sundry Application for Perforating and Cementing KRU 1E-08A CTD Procedure Overview 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Mill a 2.80", single-string window exit with high-side orientation off of the whipstock set pre-rig arrival 3. 1E-08AL1 Lateral a. Drill 2.70" x 3" bi-center lateral in the A4 sand b. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 1 E-08AL1-01 lateral 4. 1 E-08AL1-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the A5 sand b. Load well with kill weight fluid. Run 2%" slotted liner with a deployment sleeve on top from TD to just inside the window 5. Set the upper whipstock at—7564' MD. 6. Mill a 2.80", single-string window exit with high-side orientation off of the upper whipstock 7. 1 E-08AL2 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4 sand b. Load well with kill weight fluid. Run 2%"slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 1 E-08AL2-01 lateral 8. 1E-08AL2-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the A5 sand b. Load well with kill weight fluid. Run 2%"slotted liner with a deployment sleeve on top from TD to up inside the tubing tail 9. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Page 2 of 2 2/2/2011 11,e 1E-08A Rotary Sidetrack - CTD Setup Completion Depth (Actual) 4 1 16"65#H-40 casing •3-1/2"Gen IV Tubing Hanger 80'MD/80'TVD •3-1/2"9.3#L-80 EUE 8RD •HES"X"Nipple 2.81"ID 545'/545' •3-1/2"9.3#L-80 EUE 8RD • •3-1/2"X 1"KBMG GLM 2.867"ID 2,336'/2,231' • •3-1/2"X 1"KBMG GLM 2.867"ID 3,479'/3,198' - ,,:, •3-1/2"X 1"KBMG GLM 2.867"ID 4,532'/4,090' •3-1/2"X 1"KBMG GLM 2.867"ID 5,396'/4,837' •3-1/2"X 1"KBG-2-9 GLM 2.867"ID 6,199'/5,537' w/2000 psi shear valve Drifted to 2.81" 10-3/4"45.5#K-55 •GBH-22 80-40 PBR,EUE 8 RD •KBH-22 Anchor Seal Assembly,EUE 8 RD `_ casing 2,896'MD/ •3-1/2"X 5-1/2"FAB Production Packer 6,269'/5,593' 2,705'TVD •3-1/2"9.3#L-80 IBT-M SCC - -63 It •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X 5-1/2"FAB Production Packer 7,055'/6,093' •HES"X"Nipple 2.81"ID 7,067'/6,100' 5-1/2"TOL @ •3-1/2"9 3#L-80 IBT-M SCC 5,491'MD/4,921' i •KBH-22 Anchor Seal Assembly,EUE 8 RD TVD Sidetrack KOP •3-1/2"X 5-1/2"FAB Production Packer 7,223'/6,190' thru window in 7"@ •HES"X"Nipple 2.81"ID 7,263'/6,214' 5,712'MD/5,112'TVD •3-1/2"Mule Shoe WLEG 7,296'/6,234' i: 1: c. Baker"K-1"CIBP `` Bottom set @ 5,736' ', MD/5,124'TVD '0 Packer 6,269'/5,593' ,j// Leak at 6,293'/5,611' Packer 7,055'/6,093' 5-1/2"15.5#L-80 HD-L Liner(1,300') Perfs 7,175'/6,162' ;:: Tubing cmt retainer _ / jj Packer 7,223'/6,190' Ss @ 6,753'MD/ 5-1/2"15.5#L-80 HD-L X/• 5,993'TVD ; ST-L @ 6,779' /5,932' ;:13: 6411 �6K Mk 9 �7Retainer 7,720'/6,486' Perfs 7,725'/6,489' jjj j ASI i .;:.:;...;.:.‘..;:::.•:::;:...1'..:;.:..: 5-1/2"15.5#L-80 ST-L liner(1,038')@ 7"Open Hole TD @ 7,860'MD/6,571'TVD 7,860'MD/6,571'TVD i 7"26#K-55 casing Revised by: /'' 7,568'MD/6,543'TVD @ Elmo Cecchetti Feb. 1, 2011 Page l of 2 4 Schwartz, Guy L (DOA) From: Cecchetti, Elmo B [Elmo.B.Cecchetti@conocophillips.com] Sent: Friday, January 28, 2011 9:42 AM To: Schwartz, Guy L (DOA) Subject: RE: 1E-08A Liner Leak Straddle Packer Depth ( PTD 210-181) Guy, The leak is located between 6285' -6310' MD. A 5-1/2"flush joint HD-L connection is at 6293' MD. ConocoPhillips suspects the leak to be in the connection. The Atlas Bradford HD-L premium connection is a dual metal-to-metal gas tight seal. To assist with make-up during the liner run, a thread technician was onsite. The technician also inspected all threads previous to make up. Review of the directional profile does not show any doglegs that exceed the maximum uniaxial bend rating of the connection. Overpull of the packed off liner never exceeded the connection tensile strength including design factors. The RCBL does not show any cement behind the liner in this interval. I mentioned yesterday of a retainer slip wedged in the mill as a potential cause for the leak. After further investigation, the areas with overpull occurred at 7600' MD, well below the leak point. The slip is not thought to have created the leak. The root cause for the leak is not known at the this time. Thank you, Elmo From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, January 28, 2011 8:41 AM To: Cecchetti, Elmo B Subject: RE: 1E-08A Liner Leak Straddle Packer Depth ( PTD 210-181) Elmo, Not much of a choice but to set another packer higher up in the wellbore... Can you elaborate on what you think caused of the leak?? You mentioned yesterday that there was a slip missing from a packer that was drug uphole.... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Thursday, January 27, 2011 6:06 PM To: Schwartz, Guy L (DOA) Subject: 1E-08A Liner Leak Straddle Packer Depth Mr. Schwartz, A leak in the 5-1/2" liner has been found in the connection at 6293' MD. ConocoPhillips proposes to set a packer at 6265' MD to straddle the leak. This proposed packer with tubing will sting into a pre-existing packer at 7,050' MD. Please see attached schematic for further details. Page 2 of 2 i Thank you, Elmo 1/12/1111 1 1E-o8A Rotary Sidetrack - (. ID Setup A l Completion Depth (Actual) 16"65#H-40 casing @ •3-1/2"Gen IV Tubing Hanger 80'MD/80'TVD •3-1/2"9.3#L-80 Eu !> •HES"X"Nipple 2.81"ID 500'/500' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 2,335'/2,230' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 3,483'/3,300' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 4,542'/4,100' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 5,400'/4,840' 10-3/4" • 45.5#K-55 3-1/2"9.3#L-80 EUE 8RD casing @ 2,896'MD/ ••3-1/2'9.3#L-80 EUE Box X IBT-M SCC 5,450'/4,884' •3-1/2"9.3#L-80 IBT-M SCC 2,705'TVD ••3-1/2"X 1"KBG-2-9 GLM 2.867"ID 6,190'/5,530' - w/2000 psi shear valve Drifted to 2.81" 4 ,.. •3-1/2"9.3#L-80 IBT-M SCC 5-'1A"TOL @ •3-1/2"9.3#L-80 IBT-M SCC Box X EUE 5,491'MD/4,921' •GBH-22 80-40 PBR,EUE 8RD •KBH-22 Anchor Seal Assembly,EUE 8 RD TVD Sidetrack KOP •3-1/2"X 5-1/2"FAB Production Packer 6,265'/5,589' • •3-1/2"9.3#L-80 NU 10RD Box X EUE 8RD thru window in 7"@ •3-1/2 9 3#L-80 IBT-M SCC 5,712'MD/5,112'TVD •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X3 5-1/2"FAB Production Packer 7,050'/6,090' •31/2"9.31tL80NU10RDBox XEUE 8RD 3-1/2"9.3#L-80 IBT-M SCC •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X 5-1/2"FAB Production Packer 7,220'/6,189' •3-1/2'9.3#L-80 NU 10RD Box X EUE 8RD •3-1/2"9.3#L-80 EUE 8RD •HES"X"Nipple 2.81"ID Baker"K-1"CIBP _ .-, , ^-,r' C,^r.lr,Or" Bottom set @ 5,736' ./11 " •3-1/2"Mule Shoe WLEG MD/5,124'TVD Packer 6,265'/5,589' 'I\ Packer 7,050'/6,090' Lower Kalubik 7,150'/6,148' 5-1/2"15.5#L-80 HD-L Liner(1,300') Tubing cmt retainer' Leak at 6,293' MD ��j: . C-Sand 7,294'/6,233' @ 6,753'MD/ 5,993'TVD 5-1n"15.5#L-80 HD-L Xio III,ST-L @ 6,779'MD/5,930' // B-Shale 7,432'/6,313' TVD •E Perfs 7,175'/6,160' , A-Sand 7,602'/6,415' Packer 7,220'/6,189' ,,,$, l iluveach 7,795'/6,532' Retainer 7,720'/6,493' '� ••' Perfs 7,725'/6,498' 7"Open Hole TD @ i 7,860'MD/6,571'TVD 5-1/2"15.5#L-80 ST-L liner(1,038')@ 7,860'MD/6,571'TVD 7"26#K-55 casing Revised by: @ 7,568'MD/6,543'TVD Elmo Cecchetti Jan. 27, 2011 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 20, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1 E-08A Run Date: 1/19/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-08A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 ' 1 Office: 907-273-3527 ci 9C7 ) C)- Fax: 907-273-3535 rafael.barreto a1I burtoxr cont Date: Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 19, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Free Point Tool: 1E-08A Run Date: 1/18/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-08A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20496-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 to 1‘61 00(09 1 Fax: 907-273-3535 rafael.barreto@a_alhthurton corn ; Date: Signed: rn72-r - rAl \\ 59NSEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION / ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Drilling Engineer ConocoPhillips Alaska, Inc. •1 ( 0 3 I P.O. Box 100360 c�1 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-08A Sundry Number: 311-015 Dear Mr. Alvord: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair 1-4 DATED this Z 6 day of January, 2011. Encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConoCoPhilhips Telephone 907-276-1215 January 18t,2011 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 9 zQ1� Anchorage,Alaska 99501 JAN Re: Sundry Permit,Change of Approved Plan m$Ska thi Gas Cons•Cariissi0n .nro�nr�9� Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a sundry to change approved plan for 1E-08A Permit to Drill#210181. The modification will be to Section 18 defining cement quantity and placement procedure. . On January 11,2011 the 1E-08 wellbore was sidetracked from the 7"casing at 5712'MD/5113'TVD and drilled to a total depth of 7860' MD/6570'TVD.A 5-1/2"liner was run to TD and fluid circulation was established. While circulating bottoms up,the annulus packed off and liner stuck on bottom. After numerous failed attempts to establish circulation and reciprocation,the liner was released at 1:00am January 17t. To isolate the C-sand for future injection into the A-sands,ConocoPhillips is proposing the following cementing plan: 1. Run a free point to determine packoff depth. 2. Perforate the 5-1/2"liner at 7,725'MD/6,498'TVD and 7,175'MD/6,160'MD. 3. Set 5-1/2"cement retainer above first set of perforations at 7,720'MD and establish circulation. • 4. With circulation established,pump cement from 7,725'MD to 7,175'MD covering the A and C-Sands. 5. After cement is in place and set for 24 hours,a cement bond log will be run for evaluation. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 2. Proposed 5-1/2"liner cementing procedure. 3. Proposed 1E-08A schematic Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Elmo Cecchetti at 263-4249 or Chip Alvord at 265-6120. Sin erely, eieektf:Elmo Cecchetti Drilling Engineer STATE OF ALASKA ALASKA _.L AND GAS CONSERVATION COMMISSIL 1 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 lie- - 8.1......) 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r 2.; Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r J Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r , Exploratory r 210-181 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 _ 50-209-20496-01-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes:KPA:23800' Spacing Exception Required? Yes r No r 1E-08A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651 , Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 7860 • 6570 Casing Length Size MD ND Burst Collapse Structural Conductor 48' 16" 80' 80' Surface 2864' 10-3/4" 2896' 2705' 3580 psi 2090 psi Intermediate 5693' 7" 5725' 5124' 4980 psi 4330 psi Production Liner 5491' 5-1/2" 7860' 6570' 7000 psi 4990 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7175'&7725' 6160'&6498' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) Cement Retainer 7720'MD/6493'TVD 12.Attachments: Description Suninary of Proposal r 13. Well Class after proposed work: Detailed Operator's Program r BOP Sketch r Exploratory r Development r • Service �'' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Perforating and Cementing liner-1-19-2011 Oil F . Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Elmo Cecchetti G$(,. Printed Name Chip Alvord Title: Drilling Engineer Signature Ai_ &is_ Phone:263-4249 Date:1.18.2011 Commission Use Only ff ' rr�� Sundry Number3 i' V,5 Conditions of approval: Notify Commission so that a representative may witness E E Plug Integrity r BOP Test Mechanical Integrity Test [7-Location Clearance r > 3 Soo ts� Other: 0��S'r---- e„._1/4S-40 /pg.- Ahk�.i.., 1._, i-- Ct3t— � L ....C/S . A Ka &G as Coos. Cr7 ,ission Subsequent Form Required: 1epar-k ppr.."S.!1S O . U/.► oQ Ancnor4Je /o - yd—A / APPROVED BY J Approved by: i% / COMMISSIONER THE COMMISSION Date: //267i` t Form 10-403 Re -'7, '"'`i JAN a 8 10t'C � 1/ �7 .� N) RIGINAL bmit in Duplicat f` 1E-08A Perforating and.Cementing Procedure 1. Run Halliburton free point tool and determine stuck point. 2. Rig down E-line and release from liner hanger,pull out of hole drill pipe. 3. Rig up E-line and run in hole with 5' long 6 shot/ft, 2.75" squeeze perforating guns. 4. Perforate at 7,725' MD/6,498' TVD and pull out of hole. 5. Pick up second set of squeeze perforating guns and run in hole. 6. Perforate at 7,175' MD/6,160' TVD and pull out of hole. 7. Pick up 5-1/2"cement retainer on 3-1/2"PH-6 drill pipe and run in hole. 8. Set cement retainer at 7,720' MD/6,493' TVD and circulate annulus clean. 9. Pump 88.6 sacks/ 18.3 bbls Class G 15.8 ppg cement. 10.Release from cement retainer and circulate hole at max pump rate with rotation. 11. Continue pulling out of hole into 7"casing and circulate. 12. Wait on cement 12 hours. 13.Pick up cleanout BHA and cleanout to top of cement retainer. 14.Rig up E-line and run RCBL with Fast Cast for cement evaluation (Need 24 hours from cement in place). Cement Program Cement will be placed from 7,725' MD to 7,175' using a circulating squeeze. This will allow for 119' of cement above the C-Sand and 75' above the lower packer. The slurry consists of 88.6 sacks of Class G cement plus additives at 15.8 ppg with 20%excess yielding 1.16 ft3/sx. Cement System Spacer 10 bbls MudPush II Lead Slurry 88.6 sacks Class G Cement+0.2%bwoc D046+0.3 bwoc D065 +0.4%bwoc D167+ 0.02 gals/sack D177 Yield= 1.16 ft3/sx Mix Water.5.073 gal/sx Displacement 78.5 bbls(5400' 4"Drill pipe is 58.5 bbls and 2320' 3-1/2"PH-6 is 17.0 bbls=75.5 bbls) Slurry Volumes Length Capacity Excess Total Total Total Mix Water (ft) (ft) (ft3) (sacks) (bbls) (bbls) Liner Below Retainer 140 18.7 0% 18.7 16.1 3.3 1.9 4.95" Open Hole x Liner OD 685 70.0 20% 84.0 72.5 15.0 8.8 7"x 5.50" Total 102.7 88.6 18.3 10.7 1E-08A Rotary Sidetrack - CTD Setup Completion Depth (WP10) A I . 16"65#H-40 casing @ . 3-y,„Gen IV Tubing Hanger 80'MD/80'TVD • 3-W 9.3#L-80 EUE 8RD • 3-1/"9.3#L-80 EUE Box X IBT-M SCC 5,450'/4,884' • 3-'h"9 3#L-•80 IBT-M SCC • 3-'/z"X 5-W FAB Production Packer 7,100'/6,120' C • `.3-% 9 3#L_-80 IBT-M SCC • 3-W X 5-'/"FAB Production Packer 7,250'/6,205' • 3-W Mule Shoe WLEG /c; 1 /622r.' 10-3/4"45.5#K-55 casing @ 2,896'MD/ 2,705'TVD 5-'v2"TOL @ Liner Perforation & Squeeze Depth (Actual) 5,491'MD/4,921' • Lower Kalubik K 1 Top 7,150'/6,148' TVD r'erforations (Cement, 7,175'/6,160' Sidetrack KOP • C-Sand Top 7,294'/6,233' thru window in 7"@ • B-Shale Top 7,432'/6,313' 5,712'MD/5,112'TVD • A-Sand Top 7,602'/6,415' • Cement Retainer 7,720'/6,493' • Perforations (Cement) 7,725'/6,498 ' • Landing Collar 7,730'/6,503' • Top of Miluveach 7,795'/6,532' • 5-W Liner Shoe 7,860'/6,571' Baker"K-1"CIBP almagaawsrBottom set @ 5,736' - �% Packer 7,100' / 6,120' MD/5,124'TVD Lower Kalubik 7,150' /6,148' 5-1/2"15.58 L-80 HD-L Liner 0,300') �\ - ` 1 5-1/2"15.58 L-80 HD-L X/O // 11 Tubing cmt retainer 1, € ST-L @ 6,779'MD/5,930' i.....:.. C-Sand 7,294 /6,233 6,753'MD/ TVD • 5,993'TVD IIA B-Shale 7,432 / 6,313' Perfs 7,175' / 6,160' • A-Sand 7,602' /6,415' } Packer 7,250' / 6,205' ./' F;' 1 Miluveach 795' / 6,532' Perfs 7,725' / 6,498' 7"Open Hole TD @ 7,860'MD/6,571'TVD 5-1/2"15.58 L-80 ST-L liner(1,038')@ 7,860'MD/6,571'TVD 7"26#K-55 casing Revised by: �;-i :. ,'` @ 7,568'MD/6,543'TVD Elmo Cecchetti Jan. 17, 2011 1 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, January 26, 2011 8:24 AM To: 'Cecchetti, Elmo B' Cc: 'Long, Jill W Subject: RE: 1E-08A Plan Forward (PTD 210-181) Elmo, As we discussed last night.., the commission approves the lower packer location and in general the completion plan for the well as you have outlined and shown in the last updated schematic. With the marginal cement coverage above the target injection zone there will be additional UIC monitoring requirements once the CTD sidetracks are drilled and the well is put on injection service. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Tuesday, January 25, 2011 4:41 PM To: Schwartz, Guy L (DOA) Subject: 1E-08A Plan Forward Mr. Schwartz, Currently Doyon 141 is prepared to set the lower production packer and tubing tail on e-line. The production packer will be placed at 7220' MD (please note change in depth from 7250' MD). The top straddle packer will be placed with a work string above the upper perforations located at 7175' MD. To isolate the A/C sands, ConocoPhillips is proposing the following perforation and squeeze plan off rig: 1)E-line perforate at 7538', 7575', and 7656' MD. 2) CTU cement the perforated interval. 3) CTU clean out liner. Thank you, Elmo 1/26/2011 • �, Page 1 of 1 Schwartz, Guy L (DOA) From: Cecchetti, Elmo B [Elmo.B.Cecchetti©conocophillips.com] Sent: Tuesday, January 25, 2011 12:54 PM To: Schwartz, Guy L(DOA) Subject: 1 E-08A Perforation and Squeeze Proposal Attachments: 1E-08A RCBL Page 2 of 2.pdf; 1E-08A RST Perforation Schematic 1-25-11.pdf Mr. Schwartz, After further reviewing the RCBL run, ConocoPhillips has determined 60' MD of competent cement between the interval of 7100' -7194' MD. With this cement barrier above the lower packer(planned setting depth of 7250' MD), ConocoPhillips is proposing the following perforation and squeeze plan to isolate the C and A sands. CTD will be kicking off between 7470' MD -7590' MD. 1) Perforate from 7470' -7490' MD. 2) Set cement retainer at 7460' MD. 3) Squeeze 10 bbls cement from 7425'-7710' MD with 50%excess. 4) Mill retainer and clean out liner. 5) Run RCBL 6) Set lower packer at 7250' MD I will be dropping off a hard copy of the RCBL. Please excuse sending two emails due to size. Thanks, Elmo Cecchetti Drilling Engineer Conoco Phillips Alaska Inc. ATO 1564 Work (907)263-4249 Cell (907)903-3141 Fax (907)265-6916 1/25/2011 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, January 25, 2011 3:40 PM To: 'Long, Jill W Subject: RE: 1E-08A Perforation and Squeeze Proposal fJ�4. OK... thanks for the updated perf zones. Proceed as outlined below... 2-(O -18l Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Long, Jill W [mailto:Jill.W.Long@conocophillips.com] Sent: Tuesday, January 25, 2011 3:28 PM To: Schwartz, Guy L(DOA) Cc: Cecchetti, Elmo B Subject: RE: 1E-08A Perforation and Squeeze Proposal Guy- We are currently planning to perforate around the following depths: 7656' MD, 7575' MD, and 7538' MD. These depths are referenced to the RCBL log dated 01/24/2011. Please let me know if you have further questions. Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday,January 25, 2011 3:16 PM To: Cecchetti, Elmo B Cc: Long,Jill W Subject: RE: 1E-08A Perforation and Squeeze Proposal Please send me updated pert depths and I can give you a verbal to move ahead. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent:Tuesday, January 25, 2011 12:54 PM 1/25/2011 Page 2 of 2 To: Schwartz, Guy L(DOA) Subject: 1E-08A Perforation and Squeeze Proposal Mr. Schwartz, After further reviewing the RCBL run, ConocoPhillips has determined 60' MD of competent cement between the interval of 7100'-7194' MD. With this cement barrier above the lower packer(planned setting depth of 7250' MD), ConocoPhillips is proposing the following perforation and squeeze plan to isolate the C and A sands. CTD will be kicking off between 7470' MD-7590' MD. 1) Perforate from 7470' -7490' MD. 2) Set cement retainer at 7460' MD. 3) Squeeze 10 bbls cement from 7425'-7710' MD with 50%excess. 4) Mill retainer and clean out liner. 5) Run RCBL 6) Set lower packer at 7250' MD I will be dropping off a hard copy of the RCBL. Please excuse sending two emails due to size. Thanks, Elmo Cecchetti Drilling Engineer Conoco Phillips Alaska Inc. ATO 1564 Work (907)263-4249 Cell (907)903-3141 Fax (907)265-6916 1/25/2011 : ` 1 { . : 1 1 i x'111 l J ' '� . . ,: .1▪. PPi � � ��c '� 44. ... j , , ,,,,i.., 1 i (a, Illti ; +fig ,i 'i#t` srr - l f + rr y. moi___ • .1 t r I 1 E 100 . + ',) -. 3 ; f ▪ moi, i y% .( ( t i Y 5 - -- may- 4-- c " i illf .,xt. { _ ._ z t -1-__* J. f l h key, ,yy.". a ; _- •-_ r 1 r ; � I in - ' ii 150 —�_ i`'�i �: 1i3 , itiosex _ - � _ . 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L � • e t{ ' I 1 — 7700 - i l - �I--r_ I 1 1 , I r 1 \,.... , 250 Ti(usec) 150- Amplitude AVG Sector Amplitude 200 MSG 1200 SECTORS CCL 0 (mV) 10010 150 MINI 11111111111 0 Gamma 150 Amplitude x10 frIAX Sector Amplitude Line Tens 0 (mV) 1010 150 3000 (lb) 0' !MIN Sector Amplitude 1 0 150 HALLIBURTON MAIN LOG SECTION - 0 PSI 1E-08A Rotary Sidetrack - CTD Setup Completion Depth (Actual) A h 16"65#H-40 casing @ •3-1/2"Gen IV Tubing Hanger 80'MD/80'TVD 1/2"9.3#L-80; 3RD •HES"X"Nipple 2.81"ID 500'/500' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 2,335'/2,230' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 3,483'/3,300' '-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 4,542'/4,100' -3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 5,400'/4,840' 10-3/4"45.5#K-55 1/2"9 3#1-80 FUF 8RD J- casing @ 2,896'MD/ •3-1/2"9.3#L-80 EUE Box X IBT-M SCC 5,450'/4,884' 2,705'TVD •3-1/2"X 1"KBG-2-9 GLM 2.867"ID Drifted to 2.81" 6,318'/5,575' -1/2"9.3#L-80 IBT-M SCC •3-1/2"X 1"KBG-2-9 GLM 2.867"ID 6,980'/6,049 5-'/z"TOL @ �' w/2000 psi shear valve Drifted to 2.81" A •3-1/2"9 3#L-80 IBT-M SCC 5,491'MD/4,921' •3-1/2"9.3#L-80 IBT-M SCC Box X EUE TVD •G1311-22 80-40 PBR,EUE 8 RD Sidetrack KOP •KBH-22 Anchor Seal Assembly,EUE 8 RD thru window in 7"@ •3-1/2"X 5-1/2"FAB Production Packer 7,050'/6,090' 5,712'MD/5,112'TVD •3-1/2'9.3#L-80 NU lORD Box X EUE 8RD •3-1/2"9 3#L-80 EUE 8RD •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X 5-1/2"FAB Production Packer 7,250'/6,207' •3-1/2"9.3#L-80 NU 1ORD Box X EUE 8RD •3-1/2"9.3#L-80 EUE 8RD •HES"X"Nipple 2.81"ID 1'2"9.3#/ Rn FUF RRC •3-1/2"Mule Shoe WLEG : £? J Baker"K-1"CIBP Lt ..j°111'‘-(7A- Bottom set @ 5,736'. IIP ,o 5�,��.�, MD/5,124'TVD Packer 7,050'/6,090' / \\\ /•ZS'lr Lower Kalubik 7,150'/6,148' 5-1/2"15.5#L-80 HD-L , Liner(1,300') 4) 5-1/2"15.5#L-80 HD-L X/O / �j Tubing cmt retainer _ ST-L @ 6,779'MD/5,930' i / C-Sand 7,294'/6,233' @ 6,753'MD/ TVD 5,993'TVD II i�j , B-Shale 7,432'/6,313' Perfs 7,175'/6,160' A Sand 7,602'/6,415' Packer 7,250'/6,205' / / Y 'etainer 7,460' .' A , Qom iluveach 7,795'/6,532' 2- Perfs 7,470' /, 5az ► Retainer 7,720'/6,493 / 1 GPerfs 7,725'/6,498' <;i:3ic;::;::::;:i7"Open Hole TD @ 7,860'MD/6,571'TVD 5-1/2"15.5#L-80 ST-L liner(1,038')@ 7,860'MD/6,571'TVD 7"26#K-55 casing Revised by: Ai --- ,-- ----- @ 7,568'MD/6,543'TVD Elmo Cecchetti Jan. 25, 2011 1E-08A Rotary Sidetrack - CTD Setup Ppb zra-t 21 Completion Depth (Actual) A 16"65#H-40 casing @ •3-1/2"Gen IV Tubing Hanger P 80'MD/80'TVD •3-1/2"9.3#L-80 EUE 8RD •HES"X"Nipple 2.81"ID 500'/500' I •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 2,335'/2,230' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 3,483'/3,300' •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 4,542'/4,100' •3-1/2"9.3#L-80 EUE 8RD Pi •3-1/2"X 1"KBMG GLM 2.867"ID 5,400'/4,840' `! 10-3/4" • 45.5#K-55 •3-1/2"9 3#L-80 EUE 8RD casing @ 2,896'MD/ •3-1/2"9.3#L-80 EUE Box X IBT-M SCC 5,450'/4,884' 2,705'TVD • , 1,, J s#L-6,J ri,1-i„1,c,_; •3-1/2"X 1"KBG-2-9 GLM 2.867"ID Drifted to 2.81" 6,318'/5,575' •3-1/2"9.3#L-80 IBT-M SCC •3-1/2"X 1"KBG-2-9 GLM 2.867"ID 6,980'/6,049' 5-'/2"TOL @ w/2000 psi shear valve Drifted to 2.81" 5,491'MD/4,921' •3-1/2"9.3#L-80 IBT-M SCC •3-1/2"9.3#L-80 IBT-M SCC Box X EUE TVD •GBH-22 80-40 PBR,1{UF 8 RI) !...: ::.. . : Sidetrack KOP •KBH-22 Anchor Seal Assembly,EUE 8 RD thru window in 7"@ •3-1/2"X 5-1/2"FAB Production Packer 7,050'/6,090' 5,712'MD/5,112'TVD •3-1/2"9.3#L-80 NU lORD Box X EUE 8RD 3-1/2"9.3#L-80 EUE 8RD •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X 5-1/2"FAB Production Packer 7,250'/6,207' •3-1/2"9.3#L-80 NU10RDBoxXEUE8RD ...• 733- ES"X"Nipple 2.81"ID • •3-1/2"9.3#l \\\.,,., •3 1/2"Mule Shoe WLEG Baker"K-1"CIBP , ' .. 4# Bottom set @ 5,736' MD/5,124'TVD Packer 7,050'/6,090' Lower Kalubik 7,150'/6,148' . 40 -: ! : ,. -1/2"15.5#L-80 HD-L / Liner(1,300') ,,,,,,1*-- • 5-1/2"15.5#L-80 HD-L X/O .\$ .ij Tubing cmt retainer ST-L @ 6,779'MD/5,930 �!:: C-Sand 7,294'/6,233' @ 6,753'MD i TVDi 5,993'TVD `;� ,fr / B-Shale 7,432'/6,313' Perfs 7,175'/6,160' A-Sand 7,602'/6,415' f.. F: Packer 7,250'/6,205' iii 'Um/each 7795'/6,532' ; Retainer 7,720'/6,493' � ' . Perfs 7,725'/6,498' 1 7"Open Hole TD @ „ 7,860'MD/6,571'TVD 5-1/2"15.5#L-80 ST-L liner(1,038')@ /1c... 7,860'MD/6,571'TVD 7"26#K-55 casing Revised by: "' ' @ 7,568'MD/6,543'TVD Elmo Cecchetti Jan. 24, 2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, January 24, 2011 3:18 PM To: 'Cecchetti, Elmo B' prrt Zl o 181 Subject: RE: 1 E-08A Update January 24, 2011 Sounds good for the most part... It might be good to wait for the commission to look at the CBL before you set the packer(s) . We might have to move the packer location a small amount to make sure there is cement coverage at the lower packer. You won't be able to measure cement bond once the packers are set ..... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Monday, January 24, 2011 12:38 PM To: Schwartz, Guy L(DOA) Subject: 1E-08A Update January 24, 2011 Mr. Schwartz, Doyon 141 is currently running in the hole with the second clean out BHA(liner scraper and junk baskets). Once on bottom, the liner and casing will be displaced to 10.0 ppg completion brine. After pulling out of hole, E-line will be rigged up and a RCBL run from 7714' MD to top of liner at 5491' MD. Expected time logs will be available for review is 11:00pm tonight, January 24th. I will send the PDF of the log as soon as I receive it. Once the RCBL evaluation is complete, the lower straddle packer will be run on a-line to an approved setting depth of 7250' MD. If the evaluation shows cement remediation is required below the packer, the cement squeeze will be completed post rig. With the lower packer in place, the upper packer will be set on a work string at 7050' MD, isolating the perforations at 7175' MD. Please see updated Completion Schematic. Thank you, Elmo 1/24/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, January 20, 2011 11:05 AM To: 'Cecchetti, Elmo B' Subject: RE: 1E-08A Perforation and Liner Top Squeeze Proposal Elmo, It is unfortunate that the annulus plugged off. Your proposal as stated below is acceptable. Better luck this time.!! What is the reason the Ultrasonic tool (FastCast) can't be run?? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Thursday, January 20, 2011 10:18 AM To: Schwartz, Guy L(DOA) Subject: 1E-08A Perforation and Liner Top Squeeze Proposal Mr. Schwartz, After setting the cement retainer at 7714' MD circulation was established through the perforations at 7725' MD and 7175' MD. While staging pumps from 0.5 bpm to 2.0 bpm,the annulus packed off and returns were lost. Attempts to regain circulation through the perforations were unsuccessful. 18 bbls of Class G cement was squeezed into the lower perforations with no returns. To meet the required zonal isolation of the C-sand, ConocoPhillips is proposing the following plan: 1) Set a cement retainer at 7165' MD, 10' above upper perforations. 2) Squeeze 9.3 bbls Class G cement from upper perforations to stuck point at 6750' MD. 3) Pick up liner top squeeze assembly and sting into liner at 5491' MD. 4) Squeeze 24.6 bbls Class G cement from liner top to stuck point at 6750' MD. Set liner top packer. 5) Pick up 5-1/2" cleanout BHA and mill cement retainer at 7165' MD. Clean out to top of lower retainer at 7714' MD. 6) Run RCBL on e-line from 7714' MD to top of liner. The RCBL is a combination segment bond tool (provides 360 degree readings for channeling) and omni directional response. Please see attached schematic: Thank you, Elmo 1/20/2011 1E-08ti Aotary Sidetrack - CTD . tup • Completion Depth (WP10) A klik 16"65#1-1-40 casing @ • 3_Jh"Gen IV Tubing Hanger 80'MD/80'TVD • 3-W g 3#L-80 ELIE 8R0 = 3-W 9.3#L-80 EUE Box X IBT-M SCC 5.450'/4,884' • • 3-W 9.33#L-80 IBT-M GCC • • • 3-'/2"X 5-'/" FAB Production Packer 7,100'/6,120' • 3-W 9.3#L--80 IBT-M SCC • 3'/"X 5'/2"FAB Production Packer 7,250'16,205' • 3-/2"Mule Shoe WLEG 7,280'/6,225' 10-3/4"45.5#K-55 • casing @ 2,896'MD/ 2,705'TVD 5-'Y2"TOL @ Liner Perforation & Squeeze Depth (Actual) 5,491'MD/4,921' ,1Sidetrack KOP • Lower Kalubik K-1 Top 7,150'/6,148' TVD • Cement Retainer 7,165'/6,153' thru window in 7"@ • Perforations(Cement) 7,175'/6,160' 5,712'MD/5,112'TVD • C-Sand Top 7,294'/6,233' • B-Shale Top 7,432'/6,313' \ • A-Sand Top 7,602'/6,415' 1 `� Stuck Point • Cement Retainer 7,720'/6,493' ;, 6,750' / 5,914'• Perforations (Cement) 7,725'/6,498 Alitivin- • Landing Collar 7,730'/6,503' • Top of Miluveach 7,795'/6,532' iotitirinimen Baker K-1 CIBP ��, 5-/" Liner Shoe 7,860 /6,571 Bottom set @ 5,736' . MD/5,124'TVD Lower Kalubik 7,150' / 6,148' 5-1/2"15.5#L-80 HD-L Liner(1,300') L6778050 1 Tubing cmtretaiper S @9MD// 93 ' i C-Sand 7,294' / 6,233' @ 6,753'MD/ i TVD . 5,993'TVD 1 i� • B-Shale 7,432' / 6,313' Perfs 7,175' / 6,160' A-Sand 7,602' / 6,415' •, * Miluveach 7,795' / 6,532' Aja Perfs 7,725' / 6,498' . 7"Open Hole TD @ 7,860'MD/6,571'TVD 5-1/2"15.5#L-80 ST-L liner(1,038')@ 7,860'MD/6,571'TVD 7"264 K-55 casing Revised by: „ , a.,•..4: @ 7,568'MDI 6,543'TVD Elmo Cecchetti Jan. 20, 2011 Page 1of 3 Schwartz, Guy L (DOA) From: Cecchetti, Elmo B [Elmo.B.Cecchetti@conocophillips.com] 445 Sent: Tuesday, January 18, 2011 7:03 PM Zl O — To: Schwartz, Guy L(DOA) , ' Subject: RE: 1 E-08A Rotary Sidetrack Liner Perforation and Cementing Plan Guy, Thank you for the response. The Change of Program 403 Sundry will be sent tomorrow. Thanks, Elmo From: Schwartz, Guy L (DOA) jmailto:guy.schwartz@alaska.gov] Sent: Tuesday,January 18, 2011 6:57 PM To: Cecchetti, Elmo B Subject: Re: 1E-08A Rotary Sidetrack Liner Perforation and Cementing Plan Elmo, You have verbal approval to proceed as outlined in your attached sundry. Please use HES Fast Cast ultrasonic tool for cement evaluation. Regards, Guy Sent from my iPhone On Jan 18, 2011, at 6:29 PM, "Cecchetti, Elmo B" <Elmo.B.Cecchetti@conocophillips.com>wrote: Guy, The free point data has not changed the proposed perforation or straddle packer depths. I have attached a copy of the Change of Program 403 Sundry which includes the proposed cementing program. The official copy will be mailed tomorrow. Please let me know if you have any questions or comments, Thank you, Elmo Cecchetti Work(907)263-4249 Cell (907)903-3141 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, January 18, 2011 8:43 AM To: Cecchetti, Elmo B 1/19/2011 Page 2 of 4 Subject: RE: 1E-08A Rotary Sidetrack Liner Perforation and Cementing Plan Elmo, After our conversation this morning here is a follow-up response... The straddle packer proposal is acceptable as shown in your below diagram. The depths and cement placement are OK but they could change based on the results of the Free Point log. With the FP data it may allow the upper perforations to be moved uphole somewhat and give a better placement options for the packers and more standoff for the future CTD drilling. Once you have the Free Point data finalize your plan and send me an updated email. I can then give you a verbal on the cementing program... you will still need to submit a Change of Program 403 sundry as soon as possible. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Monday, January 17, 2011 4:28 PM To: Schwartz, Guy L(DOA) Subject: RE: 1E-08A Rotary Sidetrack Liner Perforation and Cementing Plan Guy, v c-- A straddle packer will be placed across the perforations at 7,175' MD. The lower packer will be at 7,250' MD and the upper will be at 7,100' MD. The top of cement is planned to be 75' MD above the lower packer. Please see schematic attached. CTD will be placing a whipstock at 7,432' MD and 7,675' MD. Please respond with any questions or comments. Thank you, Elmo :chetti,Elmo B Jay,January 17,2011 2:15 PM art,Guy L(DOA)' 1/19/2011 Page 3 of 4 1E-08A Rotary Sidetrack Liner Perforation and Cementing Plan Mr. Schwartz, Below is a proposed revision to the Permit to Drill 210181 for 1E-08A rotary sidetrack. The sidetrack is a CTD setup for drilling two laterals to the east and west. This well will be a pre- produced injector into the A-Sands. On January 16,2011 Doyon 141 landed the 5-1/2" liner in the Miluveach as planned. After landing the liner and attempting to establish circulation, the wellbore packed off. While trying to regain circulation, the liner became stuck on bottom. After numerous failed attempts to establish circulation and reciprocation, the liner was released today, January 17th at 1:00am. To meet the required zonal isolation of the C-sand, ConocoPhillips is proposing the following remediation plan (please see attached schematic): 1. Perforate the 5-1/2" liner at 7,725' MD/6,498'ND and 7,200' MD/6,180' MD using e-line. • In the event the liner is packed off in the Miluveach,this will allow circulation from the landing collar to above the top of C-Sand. 2. Set 5-1/2"cement retainer above first set of perforations at 7,720' MD and establish circulation. • If circulation cannot be established, cement will be squeezed around the shoe and through the upper perforations with an additional retainer. 3. With circulation established, cement will be pumped from 7,725' MD to 7,200' MD covering the A and C-Sands. 4. After cement is in place and set for 24 hours, a cement bond log will be run for evaluation. • A clean out run will be performed prior to running the CBL. Note: - Proposed cement will be placed from 7,725'MD to 7,200'MD for a length of 525'MD. tc - Top of cement is planned to be 94' MD above the top of C-sand. tj° o - Production packer to be placed at 7,120'MD fora length above the top of C-sand of 174' MD. Ne-e 1141A << File: 1E-08A RST Perforation Schematic 1-17-11.pdf>> S �� I Please respond with any questions or comments_ Thank you, Elmo Cscchetti Drilling Engineer Conoco Phillips Alaska Inc. ATO 1564 Work (907)263-4249 Cell (907)903-3141 1/19/2011 1E-08r. Rotary Sidetrack - CTD �etup Completion Depth (WP10) 16"65#H-40 casing @ • 3-y2"Gen IV Tubing Hanger 80'MD/80'TVD • 3'/"9.3#L-80 EUE 8RD • 3 '/"9.3#L-80 EUE Box X IBT-M SCC 5,450'/4,884' • 3-%2"9.3#L-80 IBT-M SCC • 3-W X 5-'/" FAB Production Packer 7,100'/6,120' • 3-'/1"9.3#L-80 NU 'I ORD Box X ELIE 8RD IP • 3'/z"X 51/2"FAB Production Packer 7,250'/6,205' • 3-'/2"Mule Shoe WLEG 7,280'/6,225' 10-3/4"45.5#K-55 t casing @ 2,896'MD/ 2,705'TVD 5-'/2"TOL @ ' 7Liner Perforation & Squeeze Depth (Actual) 5,491'MD/4,921' • Lower Perforation k K-1 Top 7,150'/6,148' TVD • Perforations(Cement) 7,175'/6,160' 11.::.--- Sidetrack KOP C-Sand Top 7,294'/6,233' • thru window in 7"@ • B-Shale Top 7,432'/6,313' 5,712'MD/5,112'TVD • A-Sand Top 7,602'/6,415' • Cement Retainer 7,720'/6,493' • Perforations (Cement) 7,725'/6,498 • Landing Collar 7,730'/6,503' • Top of Miluveach 7,795'/6,532' • 5-1/2" Liner Shoe 7,860'/6,571' Baker"K-l"CIBP Bottom set @ 5,736' " S MD/5,124'TVD 1 .4< p\\ Lower Kalubik 7,150' /6,148' 1/2"15.5#L-80 HD-L Liner(1,300') /� x5-1/2"15.5#L-80 HD-L X/O 4:4 # e Tubing cmt retainer ""=" ; ST-L @ 6,779'MD/5,930' �:: C-Sand 7,294 / 6,233' @ 6,753'MD/ ` +,. TVD -' 5,993'TVD $ v<e, { B-Shale 7,432' / 6,313' Pens 7,175' /6,160' A-Sand 7,602' /6,415' 1!' Miluveach 7,795' / � t ii 6,532' moi.. . • t.. Perfs 7,725' /6,498' 7"Open Hole TD @ ��. 7,860'MD/6,571'TVD 5-1/2"15.5#L-80 ST-L liner(1,038')@ 7,860'MD/6,571'TVD 7"26#K-55 casing Revised by: S @ 7,568'MD/6,543'TVD Elmo Cecchetti Jan. 17, 2011 1E-081-v Rotary Sidetrack - CTD getup Completion Depth (WP10) 16"65#H-40 casing @ • 3-1/2"Gen IV Tubing Hanger 80'MD/80'TVD . 3'%'9.3#L-80EUE 8RD • 3-W 9.3#L-80 EUE Box X IBT-M SCC 5,450'14,884' • 3-W 9.3#L-80 IBT-M SCC - a:11. • 3-1/2"X 5-'/Z" FAB Production Packer 7,120'/6,133' • 3-%"a3#L-80 NU 10 RD Box X EUE 8RD • 3-1/2"Mule Shoe WLEG 7.183`/6,169' 10-3/4"45.5#K-55 casing @ 2,896'MD/ 2,705'TVD 5-''/z"TOL @ ►I Liner Perforation & Squeeze Depth (Actual) •5,491'MD/4,921' i1:: • Lower Kalubik K-1 Top 7,150 /6,148' TVD • Perforations (Cement) 7,200'/6,180 • Sidetrack KOP • C-Sand Top 7,294'/6,233' thru window in 7"@ • B-Shale Top 7,432'/6,313' 5,712'MD/5,112'TVD • A-Sand Top 7,602'/6,415' • Cement Retainer 7,720'/6,493' • Perforations (Cement) 7,725'/6,498 • Landing Collar 7,730'/6,503' • Top of Miluveach 7,795'/6,532' • 5-'/2" Liner Shoe 7,860'/6,571' Baker"K-I"CIBP _ - Bottom set @ 5,736': MD/5,124'TVD T \ +(t Lower Kalubik 7,150' /6,148' -1/2"15.5#L-80 HDL , ;< Liner(1,300') // 5-1/2"15.5#L-80 HD-L X/O Tubing cm:retainer,' _ _ ; ST-L @ 6,779'MD/5,930' /. / . C-Sand 7,294' /6,233' @ 6,753'MD/ :, TVD 5,993'TVD B-Shale 7432' /6,313'd�� , � : A-Sand 7,602' /6,415' f .' ; ..f ' • Miluveach 7,795' / ,�: �i 6, , :::'iii i.. i ..: .•:::::::::::. : 5-1/2"15 5#L-80 ST-L liner(1,038')@ .: 7,860'MD/6,571'TVD _I--, 7"Open Hole TD @ 7,860'MD/6,571'TVD 7"26#K-55 casing Revised by: @ 7,568' MD/6,543'TVD Elmo Cecchetti Jan. 17, 2011 1E-081-1 Rotary Sidetrack — CTD iSetup ;l 16"65#H-40 casing @ 80'MD/80'TVD Completion Depth (WP10) • 3-'/2"Gen IV Tubing Hanger • 3-'/�"9.3#L-80 EUE 8RD • 3-'/2"X 1" KBMG GLM 2.867" ID 2,335'/2,230' • 3-W 9.3#L-80 EUE 8RD '` • 3-1/2"X 1"KBMG GLM 2.867"ID 3,724'/3,400 • 3-W 9.3#L-80 EUE 8RD • 3-1/2"X 1" KBMG GLM 2.867"ID 4,775'/4,300' 10-3/4"45.5#K-55 • 3-W 9.3#L-80 EUE 8RD casing @ 2,896'MD/ • 344"9.3#L-80 EUE Box X IBT-M SCC 5,400'/4,840' TOC on 7"casing 2,705'TVD • 3-''/i'9.3#L-80 IBT-M SCC @ 5,700'MD • 3-'/2"X 1" KBGM GLM 2.867"ID 5,450'/4,884' • 3-'/z"9.3#L-80 IBT-M SCC 5-''/2"TOL @ • 3-'/2"X 1" KBG-2-9 GLM 2.867"ID 6,290'/5,600' 5,500'MD/4,930' 3-'g9.3#L-80 IBT-M SCC TVD • • 3-'/2"X 1" KBG-2-9 GLM 2.867"ID 7,065'/6,100' Sidetrack KOP w/2000 psi shear valve thru window in 7"@ • 3-'W 9.3#L-8n!PT !,/, qnn 5,709'MD/5,109'TVD • 3-'/"9.3#L-80 IBT-M SCC Box X EUE • GBH-22 80-40 PBR,EUE 8 RD • KBH-22 Anchor Seal Assembly, EUE 8RD ,.120'/6,13: A /As ..... 1 SEAN PARNELL,GOVERNOR slacil 1E IF ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-08A ConocoPhillips Alaska, Inc. Permit No: 210-181 Surface Location: 1013' FSL, 629' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 710' FNL, 599' FEL, SEC. 16, T11N, R 10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. _ �` _ �oro�k«� Jec r74- 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 Commission 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 Commission 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 Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, O i I. Daniel T. Seamount, Jr. Chair DATED this) S day of December, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED A. .KA OIL AND GAS CONSERVATION COM, SION DEC 1 5 2010 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil&Gas Cons.C�try1115SI0n 1 a.Type of Work: • lb.Proposed Well Class: Development-Oil 0 . Service- Winj 0 Single Zone Q , 1 c.Specif9GMW �bposed for: Drill ❑ Redrill Q Stratigraphic Test 10Development-Gas 0 Service-Supply CI Multiple Zone ❑ Coalbed Gas 0 Gas Hydrates CI Re-entry ❑ Exploratory CI Service WAG CI Service-Disp CI Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: e"fA ConocoPhillips Alaska Inc. Bond No. 59-52-180 . 1E-08A • 5'a.T c4,/O 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage AK 99510-0360 MD: 7,853.9' ' TVD: •6,563.7' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1,013'FSL, 629'FEL, Sec 16, T11N,R10E• • ADL 25651 ' Kuparuk River Oil Pool • Top of Productive Horizon(A-Sand): 8.Land Use Permit: 13.Approximate Spud Date: 894'FNL,681'FEL,Sec 16,T11N,R10E ALK 469 1/2/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 710'FNL, 599'FEL, Sec 16,T11N,R10E 2560 >1 Mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above P 98.7 feet 15.Distance to Nearest Well Open Surface x- 549,889.825'•y- 5,960,600.230'• Zone-4 GL Elevation above! 70.7 feet to Same Pool: 1E-08,449' 16.Deviated wells: Kickoff depth: 5709 MD •feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 54 degrees Downhole: 3,746 '/ Surface: 3,104 ✓✓ 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) 7" 5-1/2" 15.50# L-80 HD-L 1,300 5,500 r4,928 6,800 5,944 7" 5-1/2" 15.50# L-80 ST-L 1,043 6,800 5,944 7,843'e- 6,557 286.1 sacks Class G Tubing 3-1/2" 9.3# L-80 EUE-M 5,372 28 28 5,400 4,844 Tubing 3-1/2" 9.3# L-80 IBTM SCC 1,814 5,400 4,844 7,214 6,187 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 7568 6594 6745 5986 Casing Length Size Cement Volume MD ND Conductor/Structural 48' 16" 15 bbl AS II 80' 80' Surface 2864.2' 10-3/4" 1350sx 12 ppg,250 sx AS 2896' 2705' Intermediate Production 7537.1' 7" 300 sx 11.9 ppg,230 sx 14.2 ppg 7568' 6595' Liner Perforation Depth MD(ft; PlK /Z•rs..o Perforation Depth ND(ft): pt. 5f 1j 1Z-' iZ•1S-/D .6192' 263',63 , 20. Attachments: Property Plat El BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑., 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 11 ill/4010 22. I hereby certify that the foregoing is true and correct. Contact Elmo Cecchetti 263-4249 cg(•, Printed Name Chip Alvord Title Alaska Drilling Manager Signature L ( jam, Phone 265-6120 Date 12 'r s 2 i ,�� Commission Use Only Permit to Drill / API Number: Permit Appr v I See cover letter for other Number: / / ,/ 50-(5�,c/ /7941,----71"- -'("----CDate: 1 i 1JJ 0 requirements. Conditions of approval: If box is checked,well mjnot pe used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Q Other: 7F' 3500 es:. BOP /1 e3 Samples req'd: Yes 0,No Mud log req'd: Yes ❑ No ❑r if. 050.0eS L Ahn K.wt /GS f 6".1.1 HZS measures: Yes[ No❑ Directional svy req'd: Yes 12 No ❑ �� APPROVED BY THE COMMISSION / 2_ l 0 DATE: ` COMMISSIONER 4. /2.15VD /'. j2•/C•ie) Form 10-401(Revised 7/2009) This permit is v0 f r t s the bate of approval(20 AAC 25.005(g)) Submit in Duplicate ConocoPhillips Alaska, Inc. PosOffice Box 990 ConocoPhillips Anchorage,Alaska 99510-0360 Telephone 907-276-1215 December 14t,2010 /- 2_b1( Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 D Anchorage,Alaska 99501 • EC r Pr` ^pdityyDEC 1I5� No Re: Application for Permit to Drill,Rotary Sidetrack,Produce,1E-08A s j alOn Dear Commissioner: �nGaS Cons-Cofl1 ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill/Sidetr.ck an onshore producer Alasr<a ` well from the ch0rape lE pa. The expected spud date for this well is January 3r1,2011 conducting op- .tions with Doyon Rig 141. The 1E-08 wellbore is currently temporarily abandoned with 51 bbls of cement place. • g -a "cement retainer set at 6,753' MD. The proposed plan is to set a CIBP at 5,727'MD with a permanent whipstock on top at 5,709'MD/ 5,109'TVD. Next,a 6-1/8"window will be cut along with 20' of new formation. A formation integrity test will be performed to 16.0 ppg EMW,with a required minimum leak-off of 12.5 ppg EMW. After a successful FIT/LOT,the intermediate section with be drilled with a 6"by 7"bi-center bit through the Kuparuk C and A sands continuing 59' into the Miluveach Shale for a total depth of 7,853' MD/6,563 ' TVD. The hole section will be lined from 5,500' MD to 7,843'MD with flush joint 5-1/2" 15.5#. A 3-1/2"tubing completion will be run with the production packer placed at 7,120'MD/6,134'TVD in preparation for coil tubing drilling operations. Doyon 141 will then rig down and move off to allow for CTD to sidetrack in the A- / sands. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Elmo Cecchetti at 263-4249 or Chip Alvord at 265-6120. Sincerely, fiehig; Elmo Cecchetti Drilling Engineer Application for Permit to Drill Document Kuparuk Well 1E-08A Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 1E-08A. 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 properly 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 1,013'FSL, 629'FEL, Sec 16, T11N,R10E,UM • NGS Coordinates RKB Elevation 98.7'AMSL Northings: 5,960,600.230' Eastings: 549,889.825' . • Pad Elevation 70.7'AMSL Location at Top of 1150'FNL,795'FEL,Sec 16,T11N,R10E,UM Productive Interval (Kuparuk C Sand) NGS Coordinates Measured Depth, RKB: 7,258.4' Northings: 5,963,715.4' Eastings:549,6964' Total Vertical Depth, RKB: 6,213.7' Total Vertical Depth, SS: 6,115.0' Location at Top of 894'FNL,681'FEL,Sec 16,T11N,R10E,UM Productive Interval (Kuparuk A Sand) NGS Coordinates Measured Depth,RKB: 7,603.8' Northings: 5,963,971.4' Eastings:549,808.3' Total Vertical Depth, RKB: 6,416.7' Total Vertical Depth, SS: 6,318.0' Location at Total Depth 710'FNL, 599'FEL, Sec 16,T11N,R10E,UM NGS Coordinates Measured Depth,RKB: 7,853.9' Northings: 5,964,1568' Eastings: 549,889.4' Total Vertical Depth, RKB: 6,563.7' Total Vertical Depth, SS: 6,465.0' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (l)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: Directional Plan No close approach issues exist. Separation factors are above 1.5 once the sidetrack is greater than 106' MD beyond the window and continue to increase with depth. The 1/4"mile pool scan of the top of Kuparuk A5 sands show the closest approach to be the original 1E-08 wellbore 449'away at 7,617.4' MD. 1 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. r RIGIN. L 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(13OPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 141. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application fbr a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including •(A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; SIBHP(shut in 384 hrs)was recorded for A-sand in October 2008 at 3,746 psi, 11.4 ppg EMW(Top perforation of A-sand at 6339' TVD). A commingled pressure for C and A-sands was taken in February 2010 at 2,800 psi, 8.7 ppg EMW(Top perforation of C-sand at 6142' TVD). Well has been shut in since March 2010 to allow for cross flow from the higher pressured A-sand to the C-sand. The maximum potential surface pressure(MPSP)while drilling 1E-08A is calculated using above maximum reservoir pressure, a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A sand at 6,416.7' TVD (WP10): A-sand SIBHP =3,746 psi A-sand estimated depth (WP10) = 6,416.7' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =6,416.7' TVD * 0.10 psi/ft = 641.7 psi MPSP= SIBHP—gas column =3,746 psi—641.7 psi =3104.3 psi • (R.)data on potential gas:ones; The well bore is not expected to penetrate any gas zones. And (()data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation_ones,and_ones that have a propensity for dierential sticking; See attached 1E-08A Drilling Hazards Summary 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: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. For 1E-08A the procedure will be followed after milling the window and 20' of new formation. The formation at the window depth will be pressured until leak-off occurs or to 16.0 ppg EMW is reached;which ever comes first.A required minimum leak off of 12.5 ppg EMW must be obtained. 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 onr file with the commission and identified in the application: - (6)a complete proposed Casing and cementing program as required by 20. 1C 25.030,and a description of any slotted linerpre perforated liner,or screen to he installed Casing Program Casing Hole weight Top Btm OD Size (lb/ft) Grade Connection Length 1VED/TVD MD/TVD • 16" Conductor • 65 H-40 Weld 48' Surface 32' 80'/80' Original 10-3/4" 13-3/4" 45.5 K-55 BTC 2864.2' Surface 31.8' 2896'/2705' Wellbore 7"(*) 8-3/4" 26 K-55 BTC 7537.1' Surface 30.9' 7568'/6595' 5-1/2"Liner 7" 15.5 L-80 HD-L** 1300' 5500'/4928.7' 6800'/5944.2' Sidetrack 5-1/2"Liner 7" 15.5 L-80 ST-L 1043' 6800'/5944.2' 7843'/6557' Out of 7" 3-1/2" Tubing 9.3 L-80 EUE-M 5372' Surface z 28' 5400'/4844' Casing IBT-M 3-1/2" Tubing 9.3 L-80 Special 1814' 5400'/4844' 7214'/6187' Clearence * Estimated top of cement behind 7"production casing at 5,400' MD. ** HD-L threads are used in upper section of hole for higher compression load rating. Single Stage Cement Program j Cement will be placed from TD at 7,853' MD to top of liner. The liner shoe will be at 7,843' MD and the ✓ top of liner set at 5,500' MD with 200'of overlap. The slurry consists of 281.6 sacks of Class G cement plus additives at 15.8 ppg with 35% excess yielding 1.16 ft3/sx. Cement System Preflush 30.0 bbls Chemical Wash Spacer 30.0 bbls MudPush II Lead Slurry 286.1 sacks Class G Cement+0.2%bwoc D046+0.3 bwoc D065 +0.4%bwoc D167+ 0.02 gals/sack D177 Yield= 1.16 ft3/sx Mix Water=5.073 gal/sx Displacement (Drill pipe is 59.7 bbls and liner displacement is 53 bbls= 112.7 bbls) Length Capacity Total Total Total Mix Water Slurry Volumes (ft) (ft3) Excess (ft3) (sacks) (bbls) (bbls) Cap on top of Liner 100 12.8 0% 12.8 11.0 2.3 1.6 6.276"X 4"DP Liner Lap 200 10.0 0% 10.0 8.6 1.8 1.1 6.276"x 5.50" Open Hole x Liner OD 2135 218.4 • 35% 294.8 ' 254.2 52.5 30.7 7"x5.50" Shoe Track ID 80 10.7 0% 10.7 9.2 1.9 1.1 4.95" Open Hole Below Shoe 10 2.7 35% 3.6 3.1 0.7 0.4 7" / I - Total -- 331.9 286.1 59.2 34.9 k ORIGINAL 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 ident fled in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 10 AAC 25.035(h)(2) This rotary sidetrack will exit pre-existing 7" casing at 5,709' MD. BOPE will be installed prior to exiting the casing, and therefore no diverter is required. ✓ Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling,fluid system,as required by 20 AAC 25.033; Mud Program Summary • Depth MD Mud Wt. Funnel API Fluid (ft) (ppg) Vis(cp) PV YP Loss pH Comments (cc/30min) Milling Fluid 9.0 50-60 15-20 18-25 <12 9.0-9.5 Milling fluid can be reconditioned 5,709—5,755 for dilling sidetrack LSND 9.2-11. ' 45-55 12-18 15-20 <5 9.0-9.5 5,755—7,853.9 Milling Fluid: A 9.0 ppg viscosified water based milling fluid consisting of pH control and weighting agents will be used to cut the 6-1/8"window and 20' of new formation. This fluid will maintain good rheology to remove metal fragments from the wellbore and prevent their recirculation. The milling fluid can be reconditioned for use in the sidetrack. Intermediate Sidetrack Fluid: A 9.2 ppg LSND drilling fluid with shale inhibitors will be used. (The commingled C and A-sands EMW is 8.8 ppg with an additional safety factor to result in a 9.2 ppg drilling mud weight). Fluid weight may be increased to 10.2 ppg with spike fluid for drilling HRZ and Kalubik for wellbore stability and will ✓ have sufficient density to overbalance the pressure of uncased formations penetrated. Additional focus will be on minimizing the potential of a hydrostatic pressure surge or swab and good hole cleaning practices. These practices-include monitoring tripping speeds and PWD data, controlling ROP, pumping regular sweeps, adjusting rheology, and charting drag weights. Diagram of Doyon 141 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A-Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A-Application is not for an exploratory or stratigraphic test well. • �� td Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must he accompanied hr each of the following items,except for an item already on file with the commission and identified in the application: 1. Move Doyon 141 on 1E-08 and rig up. • On December 5,2010 the rig workover placed a 7"Baker K-1 cement retainer at 6,753'MD and pumped 51 bbls of 15.8 ppg cement into the remaining completion and casing. - Pressure tested the cement and 7"casing to 250 psi low/3,500 psi high for 30 minutes. • Ran 3-1/2"tubing kill string and tagged cement at 6,745'MD, set at 6,667' MD • Pumped 175 bbls of 1%CRW-135 inhibited seawater and freeze protected with 75 bbls diesel. - Set BPV and VR plugs in tree and moved off well. 2. Pull BPV and VR plugs. Record tubing,IA,and OA pressures. Circulate out freeze protect and monitor well for pressure. 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOP test. • Test BOPE to 250 psi low/3,500 psi high as per drilling permit 4. Pull blanking plug and BPV. Pull tubing hanger and kill string consisting of 6,667' of 3-1/2"tubing. 5. Run 7"casing scraper to 6,000'MD. • 6. Rig up E-line and set bottom of CIBP in 7"casing at 5,727' MD(4' above collar). Test 7"casing and CIBP to 2,500 psi for 15 minutes. 7. Pick up 7"whipstock/milling assembly. Run in hole and orient whipstock to 45 degrees right of high side. Displace casing to milling fluid. 8. Set whipstock and mill window in 7"plus 20' of new formation for FIT/LOT. Perform FIT with rig pump as per CPAI procedure to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW. 9. Pull out of hole whipstock/milling assembly and gauge mills. If greater than 1/8"under,make another mill run with new mills. 10. Pick-up and make up 6"X 7"Reed Hycalog bit with 4-3/4"directional/MWD drilling BHA. 11. Run in hole with drilling BHA to top of window and displace to drilling mud. Drill 7"hole from 5,575' MD to TD ✓ 7,853.9' MD. • Town based CPF 1 Geologist would like to log A-sands and will call casing point. 12. Circulate hole clean and wiper trip to window. Once back on bottom,circulate until hole is clean and pump liner running pill. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 13. Pick up and run 26 joints of 5-1/2" 15.50#L-80 ST-L casing followed by 33 joints of 5-1/2" 15.50#L-80 HD-L casing. The top of liner will be placed at 5,500' MD allowing for 200' of overlap. 14. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Set liner hanger and circulate out excess cement above liner. Slackoff and set liner top packer. • Reciprocate liner with 30'stroke lengths for as long as possible to enhance the cement bond. • If there are signs of lost circulation prior to running casing,mix celloflakes into cement slurry. ORIGINAL 15. Monitor well then pull out of hole and rack back drill pipe as contingency for setting production packer. 16. Rig up E-line,run in hole with Fast Cast and CBL cement evaluation stools. Acquire logs from float collar to TOL. 17. Run 3-1/2"tubing tail and"FAB"production packer to packer setting depth of 7,120'MD/6,134'TVD on E-Line. 18. Run 3-1/2"L-80 9.3#tubing completion per schematic. 19. Pressure test 3-1/2"tubing to 2,500 psi then pressure test the tubing by casing annulus to 2,500 psi and chart for 30 min.✓ 20. Shear gas lift mandrel#5 dump valve with 2,000 psi casing to tubing shear. 21. Set BPV and N/D BOPE. 22. Nipple up tree,pull BPV and set test plug. • Test tree and tubing packoff to250 psi low/5,000 psi then pull test plug. 23. Freeze protect well by pumping diesel down the annulus taking returns from tubing and allowing fluids to U-tube. 24. Install BPV,rig down and move out. Turn well over to production via handover form. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill musts 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 25.080Jor an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored,tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic • ORIGINAL fl R G N ConocoPhillis (Alaska) Inc. -Ku 1! Kuparuk River Unit 1 Kuparuk 1E Pad 1E-08 Plan: 1E-08A da.: j S Plan: 1E-08A (wp10) i - ri II ei - L1 i Standard Proposal Report ril.., , lrt 13 December, 2010 ill • E- 4 i 1.• ' ! z_,: ,... =- s HALLIBURTE3N Sperry Drilling Services d11 8 ORtGINAL • Project: Kuparuk River Unit Site: Kuparuk 1E Pad WELL DETAILS: 1E-08 HALLIESURTON Grotmd Level: 7070 Well: 1 E-08 +M-S +F-/-NV Northing Eating Latittude Longitude Slot Sperry Drilling Wellbore: Plan: 1E-08A 0.00 0.00 5960600.23 549889.82 70°18'11.283 N 149°35'45.186 W Plan: 1E-08A (wp10) REFERENCE INFORMATION Co-ordinate 0.1/8)Reference:Wet 1E-08,'Tuve North • Vertical(TVD)Reference:Plan:1E-08A 6 98.708(D16(28+70.7)) Measured Depth Reference:Plan:1E-08A @ 98.7011(D15(28+70.7)) Calculation Method:Minimum Curvature • . . " 4750 . . . , , , . , . CASING DETAILS : 1r- TVD TVDSS MD Size Name 2699.21 2600.51 288930 10-3/4 10 3/4" 5000 . . , • - : 5109.40 5010.70 5709.01 7 7"TOW 1 ; ;--1--;--; : TOW©5709 MD 5109 TVD:2127 FM,1169'FEL 7 Sec16-TIIN-RIOE•--I- " 1-L-1 ' ,\`• 1----- . -••--: 7853.86 5-1/2 5 ur : - 1 6563.68 6464.98 . ! . . . ! 1 ,--r , . . : , : . . . , . 1 ' : I 11- . L - - 5250 . . : " I ; • • • • - 1--- [ : , ' 1 ! ; I 1 I ; : ; ' ' 1 • .1' : ! : : - • ' 1 ' i- DDI- 5.816 1 , - i : : : 1 • : : : F , , ' 4 5500 'b', ......, _ . . , , , , -I ---1- g,- , . . , , , - , , .. - • 1- 7 IL ai-5750 •1 1 1 L ' ' `i'' -I , . , , . ! j --1-710bp HKoi.eiohikC-,.2(ham',saer.lHkeRr:')Z) ----, :. 1_1[1 , .... -6000 - ..., _ _ _l 4 : 1 --I 4-.' I . . --3-II : Iiii ! - _1 J-1----- i - : . : . lelmills r , Top C @ 7258'MD,6214'TVD:1150'FM.,795'FEL-Sec16-T11N-R1OR i s -- 4. • - . i i .! i '- -1:41 ' .77--i i ! --.I'T:-_,.------=-7771- -- 111::-- ' 1 ' ' LJ r_ . . 6250 , - - - - - - - - I LL . . I 1 - . , : . • ; ; : : I 1 ' E 1 ; ' --11..]Ti : : : : : : __,-.' - -- - - . i _.1 il ,'! :,.- I:T.-,.-....'.-,.A 1.,p 11(v.11 :))--- 1 t- : ' ! ! 1 Top A@ 7604'MD,6417 TVD:894 FNL 681'FEL,-Sec16-T11N-R10E. • -.! --I .J.1 _I--7-_--2. j. _ _1 _!,1 J-4-4 , . _ ti-'F---T-=-7'T op.A 4'..i---1t - 7--r-r-1---F----7- -7----7--7--.---. - -1..-t-1"----- ---7-11-.! T-7-7-1 -77-7-7 --17-77---7-7----:-117-17-- 6500 - _ ' - ._: -.... --- _.IF,_08A 0 _ - • . :-7=i -v;--4---,., f i 1111, -.4-.--..4.___-!„.--___ •••- f-.1. I : r i E ; : I : . . : : TD(Miluveach) i ! i , . . , , . . . . , , , . . , . . . . , . . . ; 5 1/2" • • -1- • . , . , , ,• [ . .,1 r , . i . I 1 [ 1 : .• : tc, 7854114D 8;664 TVD: 01 FNI2569.FEL:Sed161111 0-1116E • 6750 . L.I. I Lr I L! ! ! ; I ---1 I I I 1 1 1 1 1 i ' III 1111 1111 1111 iiii iiii iiii lilt iiiiiiiii 111111111 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 Vertical Section at 2.00°(500 ft/in) 3750 ' 1 : .1 1 ; 1 1 ' , .1 1 . . . , . . . . . ; . . L • . . . . . . ' • ' -1: _1_-- 1 ' -1 ; ,-; ' , . _. , ,-- • : ,- • • • - • , , , : ,--t-. . ; Ei 1--51/2 - ,.----‘,- -6p,-,-, : , . ..__ __i-,,, ..-st.,....,_,1 _„).._____ : i ; i : . I ,/0.5.,k, ---L,].. 1 ' . 3500 ; 1 , " • 1 :i : 11 . 1111 : I „.11 ' : 1 ; !--'----_ 1 1 . . 1 1•I ..r, : . . / 10 1 TD 47854'rs0)0664'TVD 718 IfNLL 099'FEL-Sec-le-I11010E: iIii : 111 : ; 1 i I • ' ' I 1 ! 1 ! ! : • , .• 3250 : --' ' • ' I E-08A Top B(wp I Op /- _ --+ ' • : _ __.Top A @ 7604'MD,6417 TVD:894'FNL,681'FEL-Sec16-111N-R10E_ --q , 11,1_ + , , =]-- - 1 -1 -I-ill-------- r: .Top C®7258'MD,6214'TVD:1151:Y F1,11,7957EL-Sec_..116-171NrEHrEl 0E-i.:_____ -i-p 3000 ; 1 I - 1 1 ! 1 ! ' : : - -., : - ' 1 " o : I - - : - 1 i i o ; • : : • •,-, : ; ; ; : : , 1 1 1 : 1 . . . , ; , h ' : ; 1 1 1 i 1 , 1 ' ' - '-• ' 11 6.-, i ' NIL ' ' 1 : ; 1 H ; , 1 1 . 1- , -.0 2750 --I i 1 ! : - --.--!-- -!--- ' t . . : ' ; . „ : i__:! !I ; 1 ; , I , : , • - ' II H : ' : : IIIIiTiii - ; ' 1: . : , : ---4- ! : ',. -i-i- : : ! : : . • ! -',---:. : ; i ' , : : i i I ! : : ,. : ; i I : • .'E' - • • 1 t-4.4n I : i K i ' -0---1----1- --7- -- ---f---1---i- , 1 1 ' i 11 ' - iI _, i i i •1 0 i i i i . i I rn i i i 77-1-1- i -r- : ! 1 -r-f--: . ] : --,--j--r-, _ ' 5 1 1 , ! 1 ! ! ! . . : • i : 11 2250 ' , . , . , . ---1-, 1 7"TOW:7 , : „ ; , 1 :._A iv Azitputt1840 True North L_,L I I_ ! . . ! ,___1___. /I\ Migndtid North:-17. 9? 1 -_.. i- E 1' --:-!--i"- : ; ; I :---i---1--:-- - i ' ' -F-H4lAiknetic Field' ! .•! . ; • i i : ! 1-- -- : : ; : : . . . 2000 TOW@ 5709'MD,5109'TVD:2127'FNL,1169'FEL-Sec16-711N-R10F : , , : - /, 5 rip:57.1M.isnl i ! 1 1 . , •i 1 1 : ,-if=i-: Drp•iA:-?-gre;:7f]9:.i0.0-.] - 4-7-501I 1 1 1Ditet.r/2019 -÷- ---1- i -irodelBupi2909 _ __- I _ , 480 ! ,. -- ! I i . ] 1-] ] ! 1750 ; , , , 1111 iiii Hi ! Ili 1111 ill ! 1 1 1 1 IIII iIII Hit Ill III j iiii -2000 -1750 -1500 - -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 wes4-)/East(+)(500 ft/in) Cono03:Phillips . . ft*,,.a . _ ' 1 r). I C.; I NI A I • • Halliburton -Sperry 4. I B IJ Standard Proposal Report Database: •EDM 2003.16 Single User Db Local Co-ordinate Reference: 1.Well 1E-08 A Company: ConocoPhillips(Alaska)Inc.-Kup1 • TVD Reference: 'Plan:1E-08A @ 98.70ft(D15(28+70.7)) • Project: Kuparuk River Unit MD Reference: Plan:1 E-08A @ 98.70ft(D15(28+70.7)) Site: ;Kuparuk 1E Pad North Reference: 1 True Well: 1E-08 Survey Calculation Method: !Minimum Curvature- ., ? Wellbore: Plan:1E-08A , Design: 1E-08A(wp10) a Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) • System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1E Pad -.. ,r. :tunms37.T3,4...,..:,...,,,_.,.Matss. .:x.:Rr.,,v...nap_,rurrr;rl,,Va=s31,M,. ,^^7.n:_.,.�,.:srex.:::1au^e.='.r.„r»�vw,*sea��.ars*eu^:m:.-r....._tti.,r,..::scM;s��.21.1�..,1^.a_..s,,:.a'-,:_W2,,� Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.021 N From: Map Easting: 549,889.51 ft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.38° _ Well Position +N/-S 0.00 ft Northing: - 5,960,600.23 ft • Latitude: 70°18'11.283 N _. +E/-W 0.00 ft Easting: 549,889.82 ft • Longitude: 149°35'45.186 W • Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.70ft Wellbore Plan 1E-08A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 1;22/2010 17.39 79.80 57,364 Design 3 1E-08A(wp1 Audit Notes: Version: Phase: PLAN Tie On Depth: 5,709.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (1 .c 28.00 0.00 0.00 2.00 Plan Sections y i P . L., .. L 4 .» ... Measured Vertical ' TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°I100ft) (°1100ft) (°) 5,709.00 31.27 354.39 5,109.39 5,010.69 2,139.44 -544.15 0.00 0.00 0.00 0.00 5,721.00 32.65 356.89 5,119.57 5,020.87 2,145.77 -544.63 15.90 11.45 20.84 45.00 5,741.00 32.65 356.89 5,136.41 5,037.71 2,156.55 -545.21 0.00 0.00 0.00 0.00 6,067.13 29.50 21.59 5,416.85 5,318.15 2,319.76 -520.32 4.00 -0.96 7.57 114.28 6,077.54 29.50 21.59 5,425.91 5,327.21 2,324.52 -518.44 0.00 0.00 0.00 0.00 6,691.23 54.00 24.00 5,880.30 5,781.60 - 2,697.52 -359.42 4.00 3.99 0.39 4.69 - 7,396.23 54.00 24.00.. 6,294.69 6,195.99 3,218.57 -127.44 0.00 0.00 0.00 0.00 7,853.91 54.00 24.00 6,563.71 6,465.01 3,556.84 23.17 0.00 0.00 0.00 0.00 • 12/13/2010 10:30:14AM • Page 2 COMPASS 2003.16 Build 69 ("*N. ; dpi Q4 Halliburton -Sperry , Standard Proposal Report --� � - --..._ ., _.�. --- - _ ,_ -'7,-,--",---,---43-----------1 Database. '''--- -.EDM 2003.16 Single User Db Local Co-ordinate Reference Well 1E-08 Company: 1 ConocoPhillips(Alaska)Inc. Kup1 TVD Reference: I Plan:1E-08A @ 98.70ft(D15(28+70.7)) Project: 1 Kuparuk River Unit MD Reference: i Plan:1E-08A @ 98.70ft(D15(28+70.7)) Site: 'Kuparuk 1E Pad North Reference:; i True Well: 1E-08 Survey Calculation Method: Minimum Curvature - Wellbore: J Plan:1E-08A Design: 1E-08A(wp10) F Planned Survey Measured Vertical Map Map Depth, Inclination Azimuth Depth TVDss +N!-S +E!-W ' Northing Fasting DLS Vert Section (ft) (o) (`) (ft) :1 ft (ft) (ft) (ft) (ft) -70.70 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 5,960,600.23 549,889.82 0.00 0.00 104.30 0.93 160.17 104.30 5.60 -0.58 . 0.21 5,960,599.65 549,890.04 1.22 -0.57 124.30 0.88 134.56 124.29 25.59 -0.84 0.37 5,960,599.39 549,890.20 2.02 -0.83 144.30 0.71 128.71 144.29 45.59 -1.03 0.58 5,960,599.21 549,890.41 0.94 -1.01 164.30 0.63 196.75 164.29 65.59 -1.21 0.65 5,960,599.02 549,890.48 3.76 -1.19 184.30 0.89 177.50 184.29 85.59 -1.47 0.62 5,960,598.76 549,890.46 1.80 -1.45 204.30 0.89 134.65 204.29 105.59 -1.74 0.74 5,960,598.50 549,890.57 3.25 -1.71 224.30 0.77 109.21 224.29 125.59 -1.89 0.98 5,960,598.35 549,890.81 1.92 -1.85 244.30 0.63 98.89 244.28 145.58 -1.95 1.21 5,960,598.29 549,891.05 0.94 -1.91 264.30 0.68 177.76 264.28 165.58 -2.09 1.32 5,960,598.15 549,891.16 4.17 -2.04 284.30 0.83 128.89 284.28 185.58 -2.30 1.44. 5,960,597.94 549,891.28 3.20 -2.24 304.30 0.44 107.78 304.28 205.58 -2.41 1.63 5,960,597.83 549,891.47 2.24 -2.35 324.30 0.74 153.86 324.28 225.58 -2.55 1.76 5,960,597.69 549,891.60 2.69 -2.49 344.30 0.68 85.61 344.28 245.58 -2.66 1.93 5,960,597.59 549,891.78 3.99 -2.59 364.30 0.59 188.05 364.28 265.58 -2.75 2.04 5,960,597.49 549,891.88 4.96 -2.68 384.30 0.72 103.98 384.28 285.58 -2.88 2.14 5,960,597.36 549,891.99 4.41 -2.80 404.30 0.49 203.36 404.28 305.58 -2.99 2.23 5,960,597.25 549,892.08 4.67 -2.91 424.30 0.70 131.47 424.27 325.57 -3.15 2.29 5,960,597.10 549,892.14 3.59 -3.07 444.30 0.43 0.39 444.27 345.57 -3.16 2.38 5,960,597.09 549,892.23 5.17 -3.07 464.30 0.68 160.83 464.27 365.57 -3.19 2.42 5,960,597.05 549,892.27 5.47 -3.11 484.30 0.63 82.99 484.27 385.57 -3.29 2.57 5,960,596.96 549,892.42 4.12 -3.20 504.30 0.59 180.66 504.27 405.57 -3.38 2.68 5,960,596.87 549,892.52 4.59 -3.29 524.30 0.38 296.70 524.27 425.57 -3.45 2.62 5,960,596.79 549,892.46 4.15 -3.36 544.30 . 0.66 124.42 544.27 445.57 -3.49 2.65 5,960,596.76 549,892.50 5.19 -3.39 564.30 0.59 183.91 564.27 465.57 -3.66 2.74 5,960,596.59 549,892.59 3.12 -3.56 584.30 0.40 215.93 584.27 485.57 -3.82 2.69 . 5,960,596.43 549,892.54 1.64 -3.72 604.30 0.39 102.20 604.27 505.57 -3.89 2.72 5,960,596.36 549,892.57 3.31 -3.79 624.30 0.48 92.90 624.27 525.57 -3.91 2.87 5,960,596.34 549,892.72 0.57 -3.80 644.30 0.61 146.66 644.27 545.57 -4.00 3.01 5,960,596.25 549,892.86 2.53 -3.89 664.30 0.63 190.89 664.27 565.57 -4.20 3.05 5,960,596.05 549,892.90 2.34 -4.09 684.30 0.38 251.90 684.27 585.57 -4.32 2.96 5,960,595.93 549,892.82 2.78 -4.22 704.30 0.42 153.45 704.27 605.57 -4.41 2.93 5,960,595.84 549,892.79 3.03 -4.31 724.30 0.60 200.99 724.27 625.57 -4.57 2.93 5,960,595.68 549,892.78 2.21 " -4.47 744.30 0.53 240.90 744.26 645.56 -4.72 2.81 5,960,595.53 549,892.67 1.96 -4.62 - 764.30 0.30 188.95 764.26 665.56 -4.81 2.72 5,960,595.43 549,892.58 2.09 -4.72 784.30 0.56 190.03 784.26 685.56 -4.96 2.70 5,960,595.29 549,892.55 1.30 -4.86 804.30 0.48 255.53 804.26 705.56 -5.08 2.60 5,960,595.17 549,892.46 2.83 -4.98 824.30 0.30 177.69 824.26 725.56 -5.15 2.52 5,960,595.10 549,892.38 2.55 -5.06 844.30 0.52 237.01 844.26 - 745.56 -5.25 2.45 -5,960,594.99 549,892.31 2.24 -5.17 864.30 0.28 296.05 864.26 765.56 -5.28 2.33 5,960,594.96 549,892.19 2.23 -5.20 884.30 0.47 243.31 884.26 785.56 -5.30 2.21 5,960,594.95 549,892.07 1.87 -5.22 904.30 0.39 299.25 904.26 805.56 -5.30 2.08 5,960,594.94 549,891.94 2.05 -5.22 924.30 0.40 259.39 ' 924.26 825.56 -5.28 1.95 5,960,594.96 549,891.81 1,35 -5.21 . 944.30 0.60 308.61 944.26 845.56 -5.23 1.80 5,960,595.01 549,891.66 2.27 -5.16 964.30 0.60 304.15 964.26 865.56 . -5.10 1.63 5,960,595.14 549,891.49 0.23 -5.04 I . 12/13/2010 10:30:14AM Page 3 COMPASS 2003.16 Build 69 a : "" Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: T s `°EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-08 Company: 1"'ConocoPhillips(Alaska)Inc.-Kup1 ND Reference: ' PIan:1 E-08A @ 98.70ft(015(28+70.7)) Project: Kuparuk River Unit MD Reference: Plan:1E-08A©98.70ft(D15(28+70.7)) Site: Kuparuk 1 E Pad North Reference: True Well: i 1E-08 Survey Calculation Method: Minimum Curvature Wellbore: ;Plan:1E-08A Design: ,1E-08A(wp10) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 885.56 984.30 1.49 331.54 984.25 885.56 -4.82 1.42 5,960,595.42 549,891.28 4.98 -4.76 1,004.30 2.00 324.12 1,004.25 905.55 -4.30 1.09 5,960,595.93 549,890.94 2.78 -4.26 1,024.30 2.67 335.60 1,024.23 925.53 -3.60 0.69 5,960,596.64 549,890.54 4.07 -3.57 1,044.30 3.03 331.06 1,044.20 945.50 -2.71 0.24 5,960,597.52 549,890.09 2.12 -2.70 1,064.30 3.67 334.83 1,064.17 965.47 -1.67 -0.28 5,960,598.56 549,889.55 3.38 -1.68 1,084.30 3.91 336.61 1,084.13 985.43 -0.46 -0.83 5,960,599.76 549,889.00 1.34 -0.49 1,104.30 4.59 334.01 1,104.07 1,005.37 0.88 -1.45 5,960,601.10 549,888.37 3.53 0.83 1,124.3Q 5.35 334.01 1,124.00 1,025.30 2.44 -2.21 5,960,602.65 549,887.60 3.80 2.36 1,144.30 5.73 334.96 1,143.90 1,045.20 4.18 -3.04 5,960,604.39 549,886.76 1.95 4.07 1,164.30 6.21 333.09 1,163.79 1,065.09 6.05 -3.95 5,960,606.25 549,885.84 2.59 5.91 1,184.30 6.23 334.91 1,183.68 1,084.98 8.00 -4.90 5,960,608.19 549,884.87 0.99 7.82 1,204.30 6.97 334.91 1,203.54 1,104.84 10.08 -5.87 5,960,610.27. 549,883.88 3.70 9.87 1,224.30 7.57 337.89 1,223.38 1,124.68 12.40 -6.88 5,960,612.58 549,882.86 3.54 12.15 1,244.30 8.92 340.91 1,243.18 1,144.48 15.09 -7.89 5,960,615.26 549,881.84 7.09 14.80 1,264.30 10.62 343.35 1,262.88 1,164.19 18.32 -8.92 5,960,618.48 549,880.78 8.75 17.99 1,284.30 11.20 341.54 1,282.52 1,183.82 21.92 -10.07 5,960,622.08 549,879.61 3.37 21.56 1,304.30 11.69 343.30 1,302.13 1,203.43 25.71 -11.26 5,960,625.86 549,878.39 3.01 25.30 1,324.30 12.01 342.86 1,321.70 1,223.00 29.64 -12.46 5,960,629.78 549,877.17 1.66 29.18 1,344.30 12.01 343.03 1,341.26 1,242.56 33.62 -13.68 5,960,633.75 549,875.92 0.18 33.12 1,364.30 12.36 342.54 1,360.81 1,262.11 37.65 -14.93 5,960,637.77 549,874.65 1.82 37.10 1,384.30 12.81 341.15 1,380.33 1,281.63 41.79 -16.29 5,960,641.90 549,873.26 2.71 41.19 1,404.30 13.16 339.43 1,399.82 1,301.12 46.02 -17.80 5,960,646.12 549,871.72 2.61 45.37 1,424.30 13.83 338.39 1,419.27 1,320.57 50.37 -19.48 5,960,650.47 549,870.01 3.56 49.66 1,444.30 14.35 337.65 1,438.67 1,339.97 54.89 -21.31 5,960,654.97 549,868.16 2.75 54.11 1,464.30 14.91 336.85 1,458.02 1,359.32 59.54 -23.26 5,960,659.61 549,866.17 2.98 58.70 1,484.30 15.59 336.53 1,477.31 1,378.61 64.38 -25.34 5,960,664.43 549,864.06 3.43 63.45 1,504.30 16.10 335.85 1,496.55 1,397.85 69.37 -27.55 5,960,669.41 549,861.82 2.71 68.37 1,524.30 16.80 336.84 1,515.73 1,417.03 . 74.56 -29.82 5,960,674.58 549,859.51 3.77 73.47 1,544.30 17.70 337.40 1,534.83 1,436.13 80.02 -32.12 5,960,680.03 549,857.17 4.58 78.85 1,564.30 18.26 337.53 1,553.86 1,455.16 85.73 -34.49 5,960,685.72 549,854.77 2.81 84.47 1,584.30 19.20 338.49 1,572.80 1,474.10 91.68 -36.89 5,960,691.65 549,852.33 4.95 90.34 1,604.30 19.82 338.47 1,591.65 1,492.95 97.89 -39.34 5,960,697.85 549,849.84 3.10 96.46 1,624.30 20.32 339.17 1,610.43 1,511.73 104.29 -41.82 5,960,704.23 549,847.31 2.77 102.77 1,644.30 21.29 338.92 1,629.13 1,530.43 110.93 -44.36 5,960,710.85 549,844.73 4.87 109.31 1,664.30 22.13 338.59 1,647.71 1,549.01 117.82 -47.05 5,960,717.73 549,842.00 4.24 116.11 1,684.30 22.84 338.40 1,666.19 1,567.49 124.94 -49.85 5,960,724.82 549,839.15 3.57 123.12 1,704.30 23.77 338.29 1,684.56 1,585.86 132.29 -52.77 5,960,732.16 549,836.18 .. 4.66 130.37 1,724.30 24.29 338.10 1,702.83 1,604.13 139.86 -55.79 5,960,739.70 549,833.11 2.63 137.82 1,744.30 25.03 339.17 1,721.00 1,622.30 147.63 -58.83 5,960,747.45 549,830.02 4.32 145.48 1,764.30 25.88 340.01 1,739.06 1,640.36 155.68 -61.83 5,960,755.48 549,826.97 4.62 153.43 1,784.30 26.55 340.99 1,757.00 1,658.30 164.01 -64.78 5,960,763.79 549,823.97 3.99 161.65 1,804.30 27.24 341.87 1,774.84 1,676.14 172.59 -67.66 5,960,772.35 549,821.03 • 3.98 170.12 1,824.30 27.90 • 343.27 1,792.57 1,693.87 181.42 -70.43 5,960,781.16 549,818.20 4.62 178.85 1,844.30 28.52 343.98 1,810.19 1,711.49 190.49 -73.09 5,960,790.21 549,815.47 3.53 187.82 1,864.30 29.17 344.13 1,827.71 1,729.01 199.77 -75.75 5,960,799.47" 549,812.76 3.27 197.00 12/13/2010 10:30:14AM Page 4 COMPASS 2003.16 Build 69 , Halliburton -Sperry HALL1B URTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-08 Company: ConocoPhillips(Alaska)Inc.-Kup1 ND Reference: Plan:1E-08A©98.70ft(D15(28+70.7)) Project Kuparuk River Unit MD Reference: Plan:1E-08A©98.70ft(D15(28+70.7)) p Site: Kuparuk 1E Pad North Reference: True Well: 1 E-08 Survey Calculation Method: Minimum Curvature N Wellbore: Plan:1E-08A :4 Design: 1E-08A(wp10) ?a - la Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Fasting DLS Vert Section (ft) r) (1 (ft) ft (ft) (ft)" (ft) (ft) 1,746.45 1,884.30 29.49 344.53 1,845.15 1,746.45 209.20 -78.39 5,960,808.88 549,810.05 1.88 206.34 1,904.30 30.01 343.99 1,862.51 1,763.81 s 218.75 -81.08 5,960,818.42 549,807.30 2.92 215.79 1,924.30 30.56 343.07 1,879.78 1,781.08 228.42 -83.94 5,960,828.07 549,804.37 3.60 225.35 1,944.30 31.10 342.35 1,896.96 1,798.26 238.21 -86.99 5,960,837.83 549,801.26 3.27 235.03 1,964.30 31.41 341.36 1,914.05 1,815.35 248.07 -90.22 5,960,847.67 549,797.97 3.00 244.77 1,984.30 31.65 340.89 1,931.10 1,832.40 257.97 -93.61 5,960,857.54 549,794.52 1.72 254.54 2,004.30 31.87 340.61 1,948.11 1,849.41 267.90 -97.08 5,960,867.46 549,790.98 1.32 264.35 2,024.30 31.79 340.39 1,965.10 1,866.40 277.85 -100.60 5,960,877.38 549,787.39 0.70 274.17 2,044.30 31.67 340.25 1,982.11 1,883.41 287.75 -104.14 5,960,887.26 549,783.79 0.70 283.94 2,064.30 31.58 340.09 1,999.14 1,900.44 297.62 -107.70 5,960,897.10 549,780.16 0.62 293.68 2,084.30 31.45 340.03 2,016.19 1,917.49 307.44 -111.26 5,960,906.90 549,776.53 0.67 303.37 2,104.30 31.37 339.81 2,033.26 1,934.56 317.23 -114.84 5,960,916.66 549,772.89 0.70 313.03 2,124.30 31.31 339.73 2,050.34 1,951.64 326.99 -118.44 5,960,926.40 549,769.23 0.37 322.66 2,144.30 31.06 339.74 2,067.45 1,968.75 336.71 -122.03 5,960,936.09 549,765.58 1.25 332.25 2,164.30 31.01 339.84 2,084.59 1,985.89 346.39 -125.59 5,960,945.74 549,761.95 0.36 341.79 2,184.30 31.02 339.95 2,101.73 2,003.03 356.06 -129.13 5,960,955.39 549,758.35 0.29 351.34 2,204.30 31.09 340.05 2,118.86 2,020.16 365.76 -132.66 5,960,965.06 549,754.75 0.43 360.91 2,224.30 31.16 340.18 2,135.98 2,037.28 375.48 -136.18 5,960,974.76 549,751.17 0.49 370.50 2,244.30 31.19 340.50 2,153.09 2,054.39 385.23 -139.66 5,960,984.49 549,747.63 0.84 380.12 2,264.30 31.35 340.77 2,170.19 2,071.49 395.02 -143.10 5,960,994.26 549,744.12 1.06 389.79 2,284.30 31.53 340.82 2,187.25 2,088.55 404.88 -146.53. 5;961,004.08 549,740.62 0.91 399.51 2,304.30 31.67 340.94 2,204.29 2,105.59 414.78 -149.96 5,961,013.96 549,737.12 0.77 409.29 2,324.30 31.69 341.14 2,221.31 2,122.61 424.71 -153.38 5,961,023.87 549,733.65 0.53 419.10 2,344.30 31.93 341.07 2,238.30 2,139.60 434.68 -156.79 5,961,033.82 549,730.17 1.21 428.95 2,364.30 32.02 341.01 2,255.27 2,156.57 444.70 -160.23 5,961.,043.81 549,726.66 0.48 438.84 2,384.30 32.12 340.92 2,272.22 2,173.52 454.74 -163.70 5,961,053.83 549,723.13 0.55 448.75 2,404.30 32.18 340.86 2,289.15 2,190.45 464.80 -167.18 5,961,063.86 549,719.58 0.34 458.68 2,424.30 32.06 340.57 2,306.09 2,207.39 474.83 -170.69 5,961,073.87 549,716.00 0.98 468.59 2,444.30 31.99 340.30 2,323.04 2,224.34 484.83 -174.24 5,961,083.84 549,712.38 0.80 478.45 2,464,30 32.09 340.27 2,340.00 2,241.30. 494.81 -177.82 5,961,093.80 549,708.74 0.51 488.31 2,484.30 32.03 340.23 2,356.95 2,258.25 504.81 -181.41 5,961,103.77 549,705.08 0.32, 498.17 2,504.30 32.06 340.36 2,373.90 2,275.20 514.80 -184.99 5,961,113.74 549,701.44 0.38 508.03 2,524.30 32.12 340.41 2,390.84 2,292.15 524.80 -188.56 5,961,123.72 549,697.81 0.33 517.90 2,544.30 32.14 340.49 2,407.78 2,309.08 534.83 -192.11 5,961,133.72 549,694.18 0.24 527.80 2,564.30 32.16 340.60 2,424.71 2,326.02 544.86 -195.66 5,961,143.73,. 549,690.57 0.31 537.70 2,584.30 32.21 340.56 2,441.64 2,342.94 554.91 -199.20 5,961,153.75 549,686.96 0.27 547.62 2,604.30 32.15 340.73 2,458.57 2,359.87 564.96 -202.73 5,961,163.78 549,683.37 0.54 557.54 2,624.30 32.26 340.71 2,475.49 2,376.79 575.02 -206.25 5,961,173.81 549,679.78 0.55 567.47 2,644.30 32.44 340.81 2,492.39 2,393.69 585.13 -209.78 5,961,183.89 549,676.19 0.94 577.45 2,664.30 32.38 340.92 2,509.27 2,410.57 595.25 -213.29 5,961,194.00 549,672.61 0.42 587.45 2,684.30 32.55 340.93 2,526.15 2,427.45 605.40 -216.80 5,961,204.12 549,669.03 0.85 597.46 2,704.30 32.71 340.95 2,542.99 2,444.29 615.59 -220.32 5,961,214.29 549,665.44 0.80 607.53 2,724.30 32.55 341.06 2,559.83 2,461.13 625.79 -223.83 5,961,224.46 549,661.86 0.85 617.60 2,744.30 32.66 341.23 2,576.68 2,477.98 635.99 -227.31 5,961,234.63 549,658.31 0.72 627.67 2,764.30 32.52 341.32 2,593.53 2,494.83 ' 646.19 -230.77 5,961,244.81 549,654.79 0.74 637.74 12/13/2010 10:30:14AMPage 5 1 A COMPASS 2003.16 Build 69 L, -. L. t '% I iNte L Halliburton -Sperry .ALL' ®I Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: . Well 1E-08 `i Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: 1 Plan:1E-08A @ 98.70ft(D15(28+70.7)) c Project: {Kuparuk River Unit MD Reference: Plan:1E-08A @ 98.70ft(D15(28+70.7)) Site: ''a Kuparuk 1E Pad North Reference: '.True Well: '1 1E-08 Survey Calculation Method I Minimum Curvature Wellbore: Plan:1E-08A t � , Mile' N Design: 1E-08A(wp10) "' c Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (1 (ft) ft (ft) (ft) (ft) (ft) 2,511.71 2,784.30 32.37 341.35 2,610.41 2,511.71 656.36 -234.21 5,961,254.95 549,651.29 0.75 647.78 2,804.30. 32.38 341.51 2,627.30 2,528.60 666.51 -237.62 5,961,265.08 549,647.81 0.43 657.81 2,824.30 32.39 341.61 2,644.19 2,545.49 676.67 -241.01 5,961,275.22 549,644.36 0.27 667.85 2,844.30 32.28 341.74 2,661.09 2,562.39 686.82 -244.37 5,961,285.35 549,640.92 0.65 677.88 2,864.30 32.09 341.48 2,678.02 2,579.32 696.93 -247.73 5,961,295.43 549,637.50 1.18 687.86 2,884.30 31.99 342.16 2,694.97 2,596.27 707.01 -251.04 5,961,305.49 549,634.12 1.87 697.82 2,889.30 31.98 342.21 2,699.21 2,600.51 709.53 -251.85 5,961,308.01 549,633.29 0.51 700.31 10 314" 2,904.30 31.97 342.35 2,711.94 2,613.24 717.10 -254.27 5,961,315.56 549,630.83 0.51 707.79 2,924.30 32.13 342.69 2,728.89 2,630.19 727.22 -257.46 5,961,325.66 549,627.57 1.21 717.80 2,944.30 32.19 342.91 2,745.82 2,647.12 737.39 -260.60 5,961,335.81 549,624.36 0.66 727.85 2,964.30 32.21 343.19 2,762.74 2,664.04 747.59 -263.71 5,961,345.98 549,621.18 0.75 737.93 2,984.30 32.28 343.07 2,779.66 2,680.96 757.80 -266.81 5,961,356.17 549,618.02 0.47 748.03 3,004.30 32.14 343.45 2,796.58 2,697.88 768.01 -269.88 5,961,366.36 549,614.88 1.23 758.12 3,024.30 32.09 343.39 2,813.52 2,714.82 778.20 -272.91 5,961,376.52 549,611.78 0.30 768.20 3,044.30 32.14 343.33 2,830.46 2,731.76 788.39 -275.96 5,961,386.69 549,608.67 0.30 778.28 3,064.30 31.86 343.53 2,847.42 2,748.72 798.54 -278.98 5,961,396.83 549,605.58 1.50 788.32 3,084.30 31.94 343.45 2,864.40 2,765.70 808.68 -281.98 5,961,406.94 549,602.51 0.45 798.34 3,104.30 32.16 343.29 2,881.35 2,782.65 818.85 -285.02 5,961,417.09 549,599.40 1.18 808.40 3,124.30 31.94 343.66 2,898.30 2,799.60 829.02 -288.04 5,961,427.24 549,596.32 1.47 818.46 3,144.30 31.94 343.68 2,915.27 2,816.57 839.18 -291.01 5,961,437.37 549,593.27 0.05 828.51 3,164.30 32.05 343.69 2,932.24 2,833.54 849.35 -293.99 5,961,447.52 549,590.23 0.55 838.57 3,184.30 32.02 343.67 2,949.19 2,850.49 859.53 -296.97 5,961,457.68 549,587.18 0.16 848.64 3,204.30 31.97 343.62 2,966.15 2,867.45 869.70 -299.96 5,961,467.83 549,584.13 0.28 858.70 3,224.30 31.99 343.65. 2,983.12 2,884.42 879.86 -302.94 5,961,477.97 549,581.08 0.13 868.75 3,244.30 31.80 343.60 3,000.10 2,901.40 890.00 -305.92 5,961,488.09 549,578.03 0.96 878.78 3,264.30 31.86 343.40 3,017.09 2,918.39 900.11 -308.92 5,961,498.18 549,574.97 0.61 888.78 3,284.30 31.67 343.16 3,034.09 2,935.39 910.19 -311.94 5,961,508.24 549,571.87 1.14 898.75 3,304.30 31.61 . , 343.16 3,051.12 2,952.42 920.24 -314.98 5,961,518.26 549,568.77 0.30 908.68 3,324.30 31.83 343.15 3,068.13 2,969.43 930.30 -318.03 5,961,528.31 549,565.65 1.10 918.63 3,344.30 31.72 343.39 3,085.14 2,986.44 940.39 -321.06 5,961,538.37 549,562.56 0.84 928.61 3,364.30 31.81 343.52 3,102.14 3,003.44 950.48 -324.06 5,961,548.44 549,559.49 0.57 938.59 3,384.30 31.83 343.59 3,119.14 3,020.44 960.59 -327.05 5,961,558.54 549,556.44 0.21 948.59 3,404.30 32.33 343.79 3,136.08 3,037.38 970.79 -330.03 5,961,568.71 549,553.39 2.56 958.68 3,424.30 32.83 344.24 3,152.93 3,054.23 981.14 -332.99 5,961,579.04 549,550.36 2.78 968.92 3,444.30 33.45 344.51 3,169.68 3,070.98 991.67 -335.94 5,961,589.55 549,547.34 3.19 979.34 3,464.30 33.99 344.92 3,186.32 3,087.62 1,002.38 -338.87 5,961,600.24 549,544.34 2.93 989.94 3,484.30 34.20 345.23 3,202.88 3,104.18 1,013.21 -341.75 5,961,611.05 " 549,541.38 1.36 1,000.67, 3,504.30 34.22 345.66 3,219.42 3,120.72 1,024.10 -344.58 5,961,621.92 549,538.49 1.21 1,011.45 3,524.30 33.99 346.10 3,235.98 3,137.28 1,034.97 -347.32 5,961,632.77 549,535.68 1.69 1,022.22 3,544.30 34.02 346.37 3,252.56 3,153.86 1,045.84 -349.98 5,961,643.62 549,532.95 0.77 1,032.98 3,564.30 34.15 346.50 3,269.12 3,170.42 1,056.73 -352.61 5,961,654.49 549,530.24 0.75 ' 1,043.78. 3,584.30 34.03 346.66 3,285.69 3,186.99 1,067.64 -355.21 5,961,665.38 549,527.57 0.75 1,054.59 3,604.30 . 33.95 346.78 3,302.27 3,203.57 1,078.52 -357.78 5,961,676.24 549,524.93 0.52 1,065.37 3,624.30 33.73 347.09 3,318.88 3,220.18 1,089.37 -360.29 5,961,687.07 549,522.34 1.40 1,076.13 12/13/2010 10:30:14AM Page 6 COMPASS 2003.16 Build 69 Halliburton - Sperry EI B - Standard Proposal Report Database: `: EDM 2003.16 Single User Db Local Co-ordinate Reference: I Well 1E-08 l Company:: '' ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: I Plan:1E-08A @ 98.70ft(D15(28+70.7)) a1 Project: =j Kuparuk River Unit MD Reference: ' :PIan:1 E-08A @ 98.70ft(015(28+70.7)) Site: j Kuparuk 1E Pad North Reference: True Well: '1E-08 Survey Calculation Method: Minimum Curvature Wellbore: 1 Plan:1E-08A Design: 1E-08A(wp10) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E1-WI Northing Easting DLS Vert Section (ft) (°) (") (ft)' ft (ft) (ft) (ft) (ft) 3,236.87 3,644.30 33.14 347.64 3,335.57 3,236.87 1,100.12 -362.70 5,961,697.81 549,519.86 3.32 1,086.79 3,664.30 32.80 347.47 3,352.35 3,253.65 1,110.75 -365.05 5,961,708.42 549,517.44 1.76 1,097.33 3,684.30 32.59 347.48 3,369.18 3,270.48 1,121.29 -367.39 5,961,718.95 549,515.03 1.05 1,107.79 3,704.30 32.57 347.47 3,386.03 3,287.33 • 1,131.81 -369.73 5,961,729.45 549,512.63 0.10 1,118.21 3,724.30 32.65 347.51 3,402.88 3,304.18 1,142.33 -372.06 5,961,739.95 549,510.22 0.41 1,128.65 3,744.30 32.58 347.58 3,419.73 3,321.03 1,152.86 -374.39 5,961,750.46 549,507.83 0.40 1,139.09 3,764.30 32.65 347.91 3,436.57 3,337.87 1,163.39 -376.68 5,961,760.98 549,505.47 0.96 1,149.54 - 3,764.30 32.58 347.59 3,453.42 3,354.72 1,173.92 -378.96 5,961,771.50 549,503.11 0.93 1,159.98 3,804.30 32.32 347.40 3,470.30 3,371.60 1,184.40 -381.29 5,961,781.96 549,500.72 1.40 1,170.37 3,824.30 32.37 347.29 3,487.19 3,388.49 1,194.84 -383.63 5,961,792.38 549,498.31 0.39 1,180.72 3,844.30 32.54 347.23 3,504.07 3,405.37 1,205.31 -386.00 5,961,802.83 549,495.87 0.87 1,191.10 3,864.30 32.37 347.37 3,520.95 3,422.25 1,215.78 -388.36 5,961,813.29 549,493.44 0.93 1,201.49 3,884.30 32.45 347.06 3,537.83 3,439.13 1,226.23 -390.73 5,961,823.72 549,491.00 0.92 1,211.85 3,904.30 32.42 347.03 3,554.71 3,456.01 1,236.69 -393.13 5,961,834.16 549,488.53 0.17 1,222.21 3,924.30 32.29 347.12 3,571.61 3,472.91 1,247.12 -395.53 5,961,844.57 549,486.06 0.69 1,232.56 3,944.30 32.32 347.18 3,588.51 3,489.81 1,257.54 -397.91 5,961,854.98 549,483.62 0.22 1,242.89 3,964.30 32.20 347.18 3,605.42 3,506.72 1,267.95 -400.27 5,961,865.37 549,481.18 0.60 1,253.21 3,984.30 32.12 347.22 3,622.35 3,523.65 1,278.33 402.63 5,961,875.73 549,478.75 0.41 1,263.50 4,004.30 32.21 347.05 3,639.28 3,540.58 1,288.71 -405.00 5,961,886.10 549,476.31 0.64 1,273.79 4,024.30 32.10 347.14 3,656.22 3,557.52 1,299.09 -407.38 5,961,896.46 549,473.87 0.60 1,284.08 ' 4,044.30 32.07 347.07 3,673.16 3,574.46 1,309.44 -409.75 5,961,906.79 549,471.43 0.24 1,294.34 4,064.30 31.87 347.90 3,690.13 3,591.43 1,319.78 -412.05 5,961,917.12 549,469.06 2.41 1,304.59 4,084.30 31.69 347.99 3,707.13 3,608.43 1,330.08 -414.25 5,961,927.40 549,466.80 0.93 1,314.81 4,104.30 31.61 348.22 3,724.15 3,625.45 1,340.35 -416.41 5,961,937.65 549,464.57 0.72 1,325.00 4,124.30 31.71 348.37 3,741.18 3,642.48 1,350.63 -418.54 5,961,947.92 549,462.37 0.64 1,335.20 4,144.30 31.50 348.39 3,758.21 3,659.51 1,360.89 -420.65 5,961,958.17 549,460.19 1.05 1,345.39 4,164.30 31.53 348.30 3,775.26 3,676.56 1,371.13 -422.76 5,961,968.39 549,458.01 0.28 1,355.54 4,184.30 31.60 348.36 3,792.30 3,693.60 1,381.39 -424.88 5,961,978.63 549,455.82 0.38 1,365.72 4,204.30 31.39 348.47 3,809.36 3,710.66 1,391.62 -426.98 5,961,988.85 549,453.66 1.09 1,375.87 4,224.30 31.39 348.42 3,826.43 3,727.73 1,401.83 -429.06 5,961,999.04 549,451.50 0.13 1,386.00 ' 4,244.30 31.47 348.52 3,843.50 3,744.80 1,412.05 -431.15 5,962,009.25 549,449.35 0.48 1,396.14 4,264.30 31.31 348.76 3,860.57 3,761.87 1,422.26 -433.20 5,962,019.44 549,447.23 1.02 1,406.28 4,284.30 31.26 348.53 3,877.66 3,778.96 1,432.44 -435.25 5,962,029.61 549,445.12 0.65 1,416.38 4,304.30 31.21 348.51 3,894.76 3,796.06 1,442.61 -437.31 5,962,039.76 549,442.99 0.26 1,426.47 4,324.30 31.12 348.77 3,911.87 3,813.17 1,452.75 -439.35 5,962,049.89 549,440.88 0.81 1,436.54 4,344.30 31.13 348.67 3,929.00 3,830.30 1,462.89 -441.37 5,962,060.02 549,438.79 0.26 1,446.60 4,364.30 31.01 348.54 3,946.13 3,847.43 1,473.01 -443.41 5,962,070.12 549,436.69 0.69 1,456.64 4,384.30 30.94 348.43 3,963.27 3,864.57 1,483.10 -445.46 5,962,080.19 549,434.57 0.45 1,466.65 4,404.30 30.90 348.37 3,980.43 3,881.73 1,493.16 -447,53 5,962,090.24 549,432.43 0.25 1,476.63 4,424.30 30.89 348.28 3,997.59 3,898.89 1,503.22 -449.61 5,962,100.29 549,430.29 0.24 1,486.61 4,444.30 30.68 348.56 4,014.78 3,916.08 1,513.25 -451.66 5,962,110.30 549,428.17 1.27 1,496.56 4,464.30 30.66 348.82 4,031.98 3,933.28 1,523.25 -453.67 5,962,120.29 549,426.10 0.67 1,506.49 4,484.30 30.62 348.77 4,049.19 3,950.49 1,533.25 -455.65 5,962,130.27 549,424.05 0.24 1,516.41 4,504.30 30.39 349.01 4,066.42 3,967.72 1,543.21 -457.60 - 5,962,140.22 549,422.03 1.30 1,526.30 4,524.30 30.58 349.05 4,083.65 3,984.95 1,553.17 -459.53 5,962,150.17 549,420.03 0.96 1,536.19 12/13/2010 10:30:14AM Qape Z 9 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: I Well 1E-08 Company: ,ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: ;�Plan:1E-08A©98.70ft(D15(28+70.7)) Project: Kuparuk River Unit MD Reference: Plan:1E-08A©98.70ft(D15(28+70.7)) Site: i Kuparuk 1E Pad North Reference: True Well: I 1E-08 Survey Calculation Method: 'Minimum Curvature Wellbore: Plan:1E-08A .- Design: 1E-08A(wp10) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N!-S +E!-W Northing Easting DLS Vert Section (ft) (1 (1 (ft) ft (ft) (ft) (ft) (ft) 4,002.19 4,544.30 30.32 349.02 4,100.89 4,002.19 1,563.12 -461.46 5,962,160.10 549,418.04 1.30 1,546.07 4,564.30 30.06 349.52 4,118.18 4,019.48 1,573.01 -463.33 5,962,169.97 549,416.10 1.81 1,555.88 4,584.30 30.19 349.83 4,135.48 4,036.78 1,582.88 -465.13 5,962,179.83 549,414.24 1.01 1,565.68 4,604.30 30.00 349.67 4,152.78 4,054.08 1,592.75 -466.92 5,962,189.69 549,412.39 1.03 1,575.48 4,624.30 29.99 349.55 4,170.11 4,071.41 1,602.58 -468.72 5,962,199.51 549,410.52 0.30 1,585.25 4,644.30 30.31 350.14 4,187.40 4,088.70 1,612.47 -470.49 5,962,209.38 549,408.68- 2.18 1,595.07 4,664.30 30.28 349.76 4,204.67 4,105.97 1,622.41 -472.25 5,962,219.31 549,406.86 0.97. . 1,604.94 4,684.30 30.45 349.77 4,221.92 4,123.22 1,632.35 -474.05 5,962,229.24 549,404.99 0.85 1,614.82 4,704.30 30.66 349.99 4,239.15 4,140.45 1,642.36 -475.83 5,962,239.24 549,403.14 1.19 . 1,624.76 4,724.30 30.49 349.93 4,256.37 4,157.67 1,652.38 -477.61 5,962,249.24 549,401.30 0.86 1,634.71 4,744.30 30.52 . 350.13 4,273.60 4,174.90 1,662.38 -479.37 5,962,259.23 549,399.48 0.53 1,644.64 4,764.30 30.64 350.06 4,290.82 4,192.12 1,672.40 -481.12 5,962,269.24 " '549,397.66 0.63 1,654.59 4,784.30 30.64 350.27 4,308.02 4,209.32 1,682.45 -482.86 5,962,279.27 549,395.85 0.54 1,664.57 4,804.30 30.75 350.34 4,325.22 4,226.52 1,692.51 -484.58 ' 5,962,289.32 549,394.07 0.58 1,674.57 4,824.30 31.03 350.14 4,342.39 4,243.69 1,702.63 -486.32 5,962,299.43 549,392.26 1.49 1,684.62 4,844.30 30.75 350.29 4,359.55 4,260.85 1,712.75 -488.06 5,962,309.53 549,390.45 1.45 1,694.67 4,864.30 30.94 350.71 4,376.72 4,278.02 1,722.86 -489.75 5,962,319.63 549,388.69 1.44 1,704.72 4,884.30 30.94 350.56 4,393.87 4,295.17 1,733.01 -491.43 5,962,329.77 549,386.95 0.39 1,714.80 4,904.30 30.77 350.56 4,411.04 4,312.34 1,743.13 -493.11 5,962,339.87 549,385.20 0.85 1,724.85 4,924.30 30.84 350.67 4,428.22 4,329.52 1,753.23 -494.78 5,962,349.97 549,383.46 0.45 1,734.90 4,944.30 30.83 350.99 4,445.39 4,346.69 1,763.35 -496.41 5,962,360.07 549,381.76 0.82 1,744.95 4,964.30 30.65 350.79 4,462.58 4,363.88 1,773.45 -498.03 5,962,370.16 549,380.08 1.04 1,754.98 4,984.30 30.66 350.98 4,479.79 4,381.09 1,783.51 -499.65 5,962,380.21 549,378.39 0.49 1,764.99 5,004.30 30.44 351.12 4,497.01 4,398.31 1,793.56 -501.23 5,962,390.24 549,376.75 1.16 1,774.97 5,024.30 30.36 351.05 4,514.26 4,415.56 1,803.55 -502.80 5,962,400.23 549,375.11 0.44 1,784.91 5,044.30 30.29 351.20 4,531.53 4,432.83 1,813.53 -504.36 5,962,410.20 549,373.49 0.52 1,794,82 5,064.30 30.07 351.18 4,548.82 4,450.12 1,823.47 -505.90 5,962,420.12 549,371.88 1.10 1,804.70 5,084.30 30.02 351.02 4,566.13 4,467.43 1,833.36 -507.44 5,962,430.00 549,370.27 0.47 1,814.53 5,104.30 30.20 351.18 4,583.43 4,484.73 1,843.27 -509.00 5,962,439.90 549,368.65 0.99 1,824.39 5,124.30 29.77 352.24 4,600.75 4,502.05 1,853.16 -510.44 5,962,449.78 549,367.14 3.41 1,834.22 5,144.30 29.85 350.86 4,618.11 4,519.41 1,863.00 -511.90 5,962,459.61 549,365.62 3.45 1,844.00 5,164.30 29.78 351.99 4,635.46 4,536.76 1,872.83 -513.38 5,962,469.43 549,364.07 2.83 1,853.77 5,184.30 29.39 352.04 4,652.85 4,554.15 1,882.61 -514.75 5,962,479.20 549,362.63 1.95 1,863.50 5,204.30 29.74 351.91 4,670.25 4,571.55 1,892.38 -516.13 5,962,488.96 549,361.19 1.78 1,873.21 5,224.30 29.37 352.33 4,687.65 4,588.95 1,902.15 -517.48 5,962,498.72 549,359.77 2.12 1,882.93 5,244.30 29.38 352.62 4,705.07 4,606.37 1,911.88 -518.77 5,962,508.43 549,358.42 0.71 1,892.61 5,264.30 29.42 352.12 4,722.50 4,623.80 1,921.61 -520.07 5,962,518.16 549,357.05 1.24 1,902.29 5,284.30 29.20 352.63 4,739.94 4,641.24 1,931.31 -521.37 5,962,527.85 549,355.69 . 1.66 1,911.94 5,304.30 29.25 351.96 4,757.39 4,658.69 1,940.99 -522.68 5,962,537.52 549,354.32 1.65 1,921.57 5,324.30 29.22 353.28 4,774.85 4,676.15 1,950.68 -523.94 5,962,547.19 549,353.00 3.23 1,931.20 5,344.30 29.19 353.02 4,792.30 4,693.60 1,960.36 -525.10 5,962,556.87 549,351.77 0.65 1,940.84 5,364.30 29.10 352.42 4,809.77 4,711.07 1,970.03 -526.33 5,962,566.53 549,350.47 1.53 1,950.46 5,384.30 28.87 354.04 4,827.27 4,728.57 1,979.65 -527.48 5,962,576.14 549,349.27 4.09 1,960.03 5,404.30 28.90 353.61 4,844.78 4,746.08 1,989.25 -528.52 5,962,585.74 549,348.16 1.05 1,969.60 5,424.30 .28.73 352.77 4,862.30 4,763.60 1,998.83 -529.66 5,962,595.30 549,346.96 2.20 1,979.12 12/13/2010 10:30:14AM Page 8 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database:y ,i EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-08 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: I Plan:1 E-08A @ 98.70ft(D15(28+70.7)) Project: 1 Kuparuk River Unit MD Reference: Plan:1 E-08A @ 98.70ft(D15(28+70.7)) Site: I Kuparuk 1E Pad North Reference: True g. Well: _j 1E-08 Survey Calculation Method: Minimum Curvature ;'Wellbore: Plan:1E-08A Design: 5 1E-08A(wp10) 6 I Planned Survey Measured Vertical - r s,. �' n Map Map Depth Inclination Azimuth Depth TVDss +N!-S +E/-W Northing Easting DLS Vert Section (ft) (1 O (ft) ft (ft) (ft) (ft) (ft) 4,781.14 5,444.30 28.74 354.51 4,875.84 4,781.14 2,008.38 -530.72 5,962,604.85 549,345.83 4.18 1,988.64 5,464.30 28.57 354.55 4,897.39 4,798.69 2,017.93 -531.64 5,962,614.39 549,344.85 0.86 1,998.14 5,484.30 28.69 353.32 4,914.94 4,816.24 2,027.46 -532.65 5,962,623.91 549,343.78 3.01 2,007.63 5,504.30 29.10 354.61 4,932.45 4,833.75 2,037.07 -533.67 5,962,633.51 549,342.70 3.73 2,017.20 5,524.30 29.34 354.28 4,949.91 4,851.21 2,046.78 -534.61 5,962,643.22 549,341.69 1.45 2,026.88 5,544.30 29.52 353.52 4,967.33 4,868.63 2,056.56 -535.66 5,962,652.98 549,340.58 2.07 2,036.61 5,564.30 29.83 354.76 4,984.71 4,886.01 2,066.40 -536.67 5,962,662.82 549,339.50 3.44 2,046.42 5,584.30 29.77 354.14 5,002.06 4,903.36 2,076.30 -537.63 5,962,672.71 549,338.47 1.57 2,056.27 5,604.30 30.12 353.69 5,019.39 4,920.69 2,086.22 -538.69 5,962,682.63 549,337.35 2.08 2,066.15 5,624.30 30.31 354.59 5,036.67 4,937.97 2,096.24 -539.71 5,962,692.63 549,336.26 2.46 2,076.12 5,644.30 30.61 353.56 5,053.91 4,955.21 2,106.32 -540.76 5,962,702.71 549,335.14 3.01 2,086.17 5,664.30 31.03 354.76 5,071.09 4,972.39 2,116.51 -541.80 5,962,712.89 549,334.03 3.72 2,096.32 5,684.30 30.91 353.74 5,088.24 4,989.54 2,126.75 -542.83 5,962,723.13 549,332.93 2.69 2,106.51 5,704.30 31.20 354.30 5,105.37 5,006.67 2,137.01 -543.91 5,962,733.38 549,331.79 2.05 2,116.73 5,709.00 • 31.27 354.39 5,109.39 5,010.69 2,139.44 -544.15 5,962,735.80 549,331.54 1.85 2,119.15 5,7 31.27 354.39 5,109.40 5,010.70 2,139.45 -544.15 5,962,735.81 549,331.54 0.00 2,119.15 TOW(a 5709'MD,5109'TVD:2127'FNL,1169'FEL-Sec16-T11N-R10E-7"TOW 5,72 32.65 356.89 5,119.57 5,020.87 2,145.77 -544.63 5,962,742.13 549,331.01 15.91 2,125.46 5,741.00 32.65 356.89 5,136.41 5,037.71 2,156.55 -545.21 5,962,752.90 549,330.36 0.00 2,136.20 \/.. 5,800.00 31.74 0.99 5,186.35 5,087.65 2,187.96 -545.81 5,962,784.30 549,329.55 4.00 2,167.58 2,219.14 5,900.00 30.53 8.36 5,271.97 5,173.27 2,239.41 -541.66 5,962,835.77 549,333.36 4.00 6,000.00 29.75 16.18 5,358.49 5,259.79 2,288.38 -531.05 5,962,884.81 549,343.64 4.00 2,268.46 2,300.19 6,067.13 29.50 21.59 5,416.85 5,318.15 2,319.76 -520.32 5,962,916.26 549,354.16 4.00 6,077.54 29.50 21.59 5,425.91 5,327.21 2,324.52 -518.44 5,962,921.03 549,356.02 0.00 2,305.02 6,100.00 30.40 21.74 5,445.37 5,346.67 2,334.94 -514.30 5,962,931.48 549,360.09 4.00 2,315.57 6,200.00 34.39 22.30 5,529.80 5,431.10 2,384.59 -494.20 5,962,981.25 549,379.85 4.00 2,365.89 6,300.00 38.38 22.76 5,610.29 5,511.59 2,439.36 -471.47 5,963,036.17 549,402.21 4.00 2,421.42 6,400.00 42.37 23.14 5,686.46 '5,587.76 2,498.99 -446.21 5,963,095.96 549,427.08 4.00 2,481.90 6,500.00 46.36 23.48 5,757.93 5,659.23 2,563.19 -418.54 5,963,160.34 549,454.32 4.00 2,547.02 6,600.00 50.36 23.76 5,824.37 5,725.67 2,631.65 -388.60 5,963,228.98 549,483.80 4.00 2,616.48 6,642.02 52.03 23.88 5,850.70 5,752.00 2,661.60 -375.37 5,963,259.02 549,496.82 4.00 2,646.88 Top HRZ(K-2 marker) 6,691.23 54.00 24.00 5,880.30 5,781.60 2,697.52 -359.42 5,963,295.05 549,512.53 4.00 2,683.34 6,700.00 54.00 24.00 5,885.46 5,786.76 2,704.01 -356.54 5,963,301.55 549,515.38 0.00 2,689.92 6,800.00 54.00 24.00 5,944.24 5,845.54' 2,777.92 -323.63 5,963,375.67 549,547.79 0.00 2,764.93 6,900.00 54.00 24.00 6,003.01 5,904.31 2,851.82 -290.73 5,963,449.78 549,580.20 0.00 2,839.94 6,943.70 54.00 24.00 6,028.70 5,930.00 2,884.12 -276.35 5,963,482.17 549,594.36 0.00 2,872.72 Top Kalubik(base HRZ) 7,000.00 54.00 24.00 6,061.79 5,963.09 2,925.73 -257.82 5,963,523.90 549,612.61 0.00 2,914.95 7,100.00 54.00 24.00 6,120.57 6,021.87 2,999.64 -224.91 5,963,598.02 549,645.02 0.00 2,989.96 7,122.34 54.00 24.00 6,133.70 6,035.00 3,016.15 -217.56 5,963,614.57 549,652.26 0.00 3,006.72 K-1 marker 7,200.00 54.00 24.00 6,179.35 6,080.65 3,073.55 -192.01 5,963,672.13 549,677.43 0.00 3,064.97 7,258.39 54.00 24.00 6,213.67 6,114.97 3,116.70 -172.79 5,963,715.41 549,696.36 0.00 3,108.77 Top C @`.7258'MD,6214'TVD:1150'FNL,795'FEL-Sec16-T11N-R10E 12./13;2010 10:30:14AM Page 9 COMPASS 2003.16 Build 69 1 � L q Halliburton -Sperry TALL' U 1.'T®N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: I Well 1E-08 WW Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:1E-08A @ 98.70ft(D15(28+70.7)) k. Project: ii Kuparuk River Unit MD Reference: Plan:1E-08A @ 98.70ft(D15(28+70.7)) a Site: Kuparuk 1 E Pad 'North References True Well: 1 E-08 Survey Calculation Method:'' . Minimum Curvature Wellbore: Plan:1 E-08A Design: 1E-08A(wp10) Planned Survey Measured Vertical Map Map Depth Inclination r Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,115.00 7,258.44 54.00 24.00 6,213.70 6,115.00 3,116.74 -172.78 5,963,715.45 549,696.37 0.00 3,108.81 Top C Sand 7,300.00 54.00 24.00 6,238.13 6,139.43 3,147.45 -159.10 5,963,746.25 549,709.84 0.00 3,139.98 7,396.23 54.00 24.00 6,294.69 6,195.99 3,218.57 -127.44 5,963,817.57 549,741.03 0.00 3,212.16 1E-08A Top B(wp10) 7,396.25 54.00 24.00 6,294.70 6,196.00 3,218.59 -127.43 5,963,817.59 549,741.04 0.00 3,212.18 Top B Shale 7,400.00 54.00 24.00 6,296.91 6,198.21 3,221.36 -126.20 5,963,820.37 549,742.25 0.00 3,214.99 7,500.00 54.00 24.00 6,355.68 6,256.98 3,295.27 -93.29 5,963,894.48 549,774.66 0.00 3,290.00 7,600.00 54.00 24.00 6,414.46 6,315.76 3,369.17 -60.39 5,963,968.60 549,807.08 0.00 3,365.01 7,603.81 54.00 24.00 6,416.70 6,318.00 3,371.99 -59.13 5,963,971.42 549,808.31 0.00 3,367.87 Top A @ 7604'MD,6417'TVD:894'FNL,681'FEL-Sec16-T11N-R10E-Top A6 7,617.42 54.00 24.00 6,424.70 6,326.00 3,382.05 -54.65 5,963,981.51 549,812.72 0.00 3,378.08 Top.A5 7,654.84 54.00 24.00 6,446.70 6,348.00 3,409.71 -42.34 5,964,009.25 549,824.85 0.00 3,406.15 Top A4 7,700.00 54.00 24.00 6,473.24 6,374.54 3,443.08 -27.48 5,964,042.72 549,839.49 0.00 3,440.03 7,765.43 54.00 24.00 6,511.70 6,413.00 3,491.44 -5.95 5,964,091.21 549,860.69 0.00 3,489.10 Top A3 7,794.35 54.00 24.00 6,528.70 6,430.00 3,512.81 3.57 5,964,112.65 549,870.07 0 00 3,510.80 Top Miluveach 7,800.00 54.00 24.00 6,532.02 6,433.32 3,516.99 5.43 5,964,116.84 549,871.90 0.00 3,515.04 7,853.86 54.00 24.00 6,563.68 6,464.98 3,556.80 23.15 5,964,156.76 549,889.35 0.00 3,555.44 "51/2" 7,853.90 54.00 24.00 6,563.70 6,465.00 3,556.82 23.16 5,964,156.78 549,889.37 0.00 3,555.46 TD @ 7854'MD,6564'TVD:710'FNL,599'FEL-Sec16-T11N-R10E-TD(Miluveach) 7,853.91 54.00 24.00 6,563.71 6,465.01 3,556.84 23.17 5,964,156.80 549,889.37 0.00 3,555.48 Targets Target Name - -hit/miss target Dip Angle Dip Dir. TVD +Nl-S +E/-W Northing Easting • -Shape: (°) (°); (ft) (ft) (ft) (ft) (ft) 1E-OBA Top B(wp10) 0.00 0.00 6,294.69 3,218.57 -127.44 5,963,817.57 549,741.03 -plan hits target center -Point Casing Points Measured Vertical Casing _f1Hole Elr Depth Depth - Diameter Diiaatn ' } (ft) (ft) ._ Name -- 1 -1 .:(fes '''•"'" ()(' ';l?%.. ___ :_ ---�_11 - 5,709.01 5,109.40 7"TOW --- _- - -- - _- - 7 8-1/2 7,853.86 6,563.68 5 1/2" 5-1/2 6-3/4 2,889.30 2,699.21 10 3/4" 10-3/4 12-1/4 12/13/2010 10:30:14AM Page 10 COMPASS 2003.16 Build 69 Halliburton -Sperry F-I LLIBURTON Standard Proposal Report LDatabase ",EDM 2003.16 Single User Db Local Co-ordinate Reference .Well 1E-08 ro ;Company - ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference Plan:1E-08A @ 98.70ft(D15(28+70.7)) Project a Kuparuk River Unit MD Reference 1 Plan:1 E-08A @ 98.70ft(D15(28+70.7)) 1 Site ,. Kuparuk 1 E Pad North Reference True rWell {'i'r 1E-06 'Survey Calculation Method: Minimum Curvature Wellbore Plan:1E-08A la Desigm { 1E-08A(wp10) Formations . Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (a) (°) 6,943.70 6,028.70 Top Kalubik(base HRZ) 0.00 7,617.42 6,424.70 Top A5 0.00 7,603.81 6,416.70 Top A6 0.00 7,396.25 6,294.70 Top B Shale 0.00 7,122.34 6,133.70 K-1 marker 0.00 7,258.44 6,213.70 Top C Sand 0.00 7,853.90 6,563.70 TD(Miluveach) 0.00 6,642.02 5,850.70 Top HRZ(K-2 marker) 0.00 • 7,794.35 6,528.70 Top Miluveach 0.00 7,654.84 6,446.70 Top A4 0.00 7,765.43 6,511.70 Top A3 0.00 Plan Annotations Measured Vertical Local Coordinates Depth. Depth +N/-S +E!-W (ft) . .;(ft) (ft) (ft).., ,Comment 5,709.01 5,109.40 2,139.45 -544.15 TOW @ 5709'MD,5109'TVD:2127'FNL,1169'FEL-Sec16-T11 N-R10E 7,258.39 6,213.67 3,116.70 -172.79 Top C @ 7258'MD,6214'TVD:1150'FNL,795'FEL-Sec16-T11 N-R10E 7,603.81 6,416.70 3,371.99 -59.13 Top A @ 7604'MD,6417'TVD:894'FNL,681'FEL-Sec16-T11 N-R10E 7,853.90 6,563.70 3,556.83 23.16 TD @ 7854'MD,6564'TVD:710'FNL,599'FEL-Sec16-T11N-R1OE 12/13/2010 10:30:14AM Page 11 COMPASS 2003.16 Build 69 (., t i 1 a"A to a) ® U m- N CC 3 co c Ma 0 L 4 L Q.G) N T.- ®0 a- li N N U Ii is I I c c O N 3 ` w Ir R d y "5 a b o u• 4, alo d O rf in O• o w O T — o fiLl• SIM e-• 71,ICC .® (U ea 1 Td t i MI na) ▪ R W m ❑ ,o 3 -c- (1) ■o r 3 a _' U . L m N a °U 4 atO di QaW _ •• 0 = _ Wm o < m LL J Cr)aiim a 0 a Z m o R _c 'E / ■ 00 111 rn " nRE - m W s. O. = r'dN O xQ V m � L V n • 1- m _ w ; 28 $ _ : Od4. QOr = ' cdat9 o rn m o s. W 03 O L L co 3 o Z m c CO N xi yd a u_ :' C7 pYw L. o 1 . �i ' „ Li 1- C ra •� y a ❑ av o E. 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N vc '2 p CO NO 0 m 0 N ❑ n o N ❑ ,a G q 0 lb ❑ C.) bo (.) t, ❑ S * Fck HALLIEIURTDN Project: Kuparuk River Unit WELL DETAILS: 1E-08 ®PecrrorLut�� .r,riearz Site: Kuparuk 1E Pad GrormdLevel: 70.70 Well: 1E-08 +N/-S+E/-W Northing Easting Latittude Longitude Slot Wellbore: Plan: 1 E-08A 0.00 0.00 5960600.23 549889.8270°18'11.283 N149°35'45.186 W Plan: 1E-08A (wp10) — - REFERENCE INFORMATION Coordinate(NIE)Reference:Wel 1E-08,True North Vertical(TVD)Reference:Plan:1 E-08A @ 98.70ft(Nordic 3(28+70.7)) - Measured Depth Reference:PIan:1E-08A @ 98.70ft(Nordic 3(28+70.7)) - Calculation Method:Minimum Curvature 5250— - CASING DETAILS 5000- - TVD TVDSS MD Size Name - 2699.55 2600.85 2889.70 10-3/4 10 3/4" 4750— 5109.40 5010.70 5709.01 7 7"TOW _ 6565.70 6465.00 7855.90 5-1/2 5 1/2" 4500 4250— • 4000— 3750— _ 5 12" 3500— . IAF-oBA 3250— I E-r.4 0- ZSO IE-08A Top B(wpl r) 1VY� \V.1 3000— _ Y. - 2750— C - 2500— s7s0 n - - s I1E-08A 1/4 Mille - Sop 2250— + 7"TOW - 117-12.1P131 11' 2000— • . 5000 / SU . =1750—. \F;\1 0 cn - 1E-0 1500— �� 4000 ti" 3750 1250— F ' 35� 1000— a ^-V: 3250 3000 750— '- �e4'\ 10 3/4" - 11)'' 500— y150 o/' 7A70°°250— - 2; 1150 _ l4 0 0— 15 _ o -250— .. 7/ -500- T - M Azimuths to True North - Magnetic North:21.91° -750— - Magnetic Field - Strength:57651.8snT — . Dip Angle:80.84' -1000— Date: 1/22/2010 Model:BGGM2009 IIItllllltllllllllltllltllllllllll1ll11l1llllllittll11lllllllllltllllllllllllllllllllllllllllllllll11l11llltl -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 West(-)/East(+)(750 ft/in) �. ConocoPhillips \ VI . a M 130a NNW• it • 0 D. a 1 Y W O r aao cc 0 0 � =W �W o 0 0 D o YY� a � mai 0- U O O 0 °' 0 D N��a 0 V J� UUU1 CL 0( r a. --------------- - co r .._•__.__._•_•..___ 000 CV ol O Q ODZ N O h. W rn co LJ cci W • O O N N 0 O� 0 LIIOT H , 0 6°'v ~ - W r-aLnLn mm}X --- - 1 N. 7 N >Yaa N CO J�QQ c 01 ; J O =' IF , r N 0 ow 17, z e' W ^^ ( N Y / • N %,�,0 • W d r � _ ti O ;+ I\ N N J r , r- . N ` N - - W N - Wp_ 7 d D O • c,===:, � PR1NAL cn 1E-08A Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) • 7"Hole with 5-1/2" Liner Interval* Event Risk Level Mitigation Strategy Hole instability while drilling High Utilize a mud weight to stabilize Kalubik without sustaining losses Kalubik Shale section Placement of KOP and bottom hole location to allow for 4°DLS. Directional control Moderate Complete all directional work above the HRZ and use a bi-center bit with successful past performance. Drill 6"X 7"hole with proper mud weight for hole stability, Run liner to bottom Moderate directional plan with 4°DLS and a tangent from HRZ to TD,and run a slick flush joint liner. Reduced trip speeds,real time equivalent circulating density(ECD) Hole swabbing/surging Moderate monitoring,mud rheology,and proper hole filling. Pump and rotate out of hole as necessary. BOPE drills,keep mud weight above 9.2 ppg,check for flow during - Abnormal Reservoir Pressure Moderate f connections and if needed increase mud weight. Well has been shut-in since March 2010 to allow for cross flow from higher pressured A- sand to C-sand. Reduced pump rates,real time equivalent circulating density(ECD) Lost Circulation Moderate monitoring,mud rheology,and LCM. Use GKA LC decision tree as needed. Tracking along 7"casing during Kickoff at 5,709'MD where cement in the 7"annulus has been window milling Moderate confirmed with original CBL(TOC=5,400'MD) Due to running a slick liner without the ability to rotate,the liner will Cement Bonding Moderate be reciprocated during cementing.. In addition,30%excess cement will be pumped to ensure cement to liner top. Run CBL for evaluation Hydrogen Sulfide Gas Low H2S drills,detection systems,alarms,and standard well control practices. *See Well Plan for more detailed risk information and offset data. DRGINAL 1E-08A Rotary Sidetrack — CTD Setup 16"65#H-40 casing @ 80'MD/80'TVD Completion Depth (WP10) • 3-1/4"Gen IV Tubing Hanger : • 3-W 9.3#L-80 EUE 8RD • 3-1,4X 1"KBMG GLM 2.867" I1) 2.742' '2,575' • 31/2"9.3#L-80 EUE 8RD =::• .,'5,)I '7 ' • 3-'.-_"X 1"KBMG GLM 2.867" ID 4426'/400( • 3-'/z"9.3#L-80 EUE 8RD • ;-',_"X I"KBMG GLM 2.867" ID 5,467'/4,900' ."; 10-3/4"45.5#K-55 • 3'/<"9.3#L-80 EUE 8RD A ' casing @ 2,896'MD/ • 3-'/" 9.3#L-80 EUE Box X IBT-M SCC -' 3-1/2"9.3#L-80 IBT-M SCC TOC on 7 casing2,705'TVD �, • 3- _ X I ,KBG 9 GLM_867„ID 6,313'1 5,611' @ 5,700'MD 7.7 ja::-, • 3-%”9.3#L-80 IBT-M SCC 5-'/z"TOL@ • " 4"X 1"KBG-2-9 GLM 2.867" 11) 7,080'/"6,100 5,500'MD/4,930' :: �,�/2000 psi shear valve TVD 3-'/"9.3#L-80 IBT-M SCC Sidetrack KOP • 344 9.3#L-80 IBT-M SCC Box X EUE thru window in 7"@ • GBH-22 80-40 PBR,EUE 8RD 5,709'MD/5,109'TVD • KBH-22 Anchor Seal Assembly, EUE 8 RD • 3-'/"X 5 /" =AB Production Packer 7,120'16,132' e o5>Fo • 3-v2"9.3#L-80 NU 1 ORD Box X IBT-M SCC Pf • 3-'/"9.3#L-80 IBT-M SCC • HES"X"Nipple 2.81"ID • • 3-'/z"9.3#L-80 IBT-M SGC ''. • 3-1/" Mule Shoe WLEG 7,183'/6,169' Baker"K-1"CIBP : : below set point for ::::: whipstock ..... 41,1 Tagged cement in Tubing cmt retainer 3-1/4"9.3#L-80 EUE from surface to TOL 7"casing @ @ 6,753'MD 3-'/2"9.3#L-80 IBTM SCC(3.865"OD) 6,745'MD from TOL to 7,183'MD/6,169'TVD `] 5-1/2" 15.5#L-80 HD-L '< .:... ... X/O ST-L @ 6,800'MD/ cl 5,944'TVD o �` 1 •:•:•::•:•::it iai iii.:::::.iiii:. %.::iiii:::.. %:::::::::.. P L - U- 1. Perfs @ !ii 'rp 7,010'—7,104' .`;"`` `•`:::: C BtUn of tubing @ :. ., • 7 177'MD 5-1/2" 15.5#L-80 ST-L cemented liner @ 7,843'MD/6,557'TVD � 7"Open Hole TD @ , Perfs @ 7,853'MD/6,563'TVD -7,274'—7,29 7,304'—7,35 ' , 5..*!i://' :::::: 5 casing �` 7 568'MDS 6 543'TVD Revised �I. @ , Elmo Cecchetti ) ! (71 tk, I A Dec. 13, 2010 i'\ iNA 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. TRANSMITTAL LETTER CHECKLIST WELL NAME - I PTD# 7-10 / ti/ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: et/e)(:---v1/ POOL: /- °F6 ( Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - . API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name)must contact the Commission to obtain advance approval of such water well testing program. 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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. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 04 12:05:27 2011 Reel Header Service name LISTPE Date 11/02/04 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/02/04 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: 1E-08A API NUMBER: 500292049601 OPERATOR: ConocoPhillips (Alaska) , Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 04-FEB-11 JOB DATA MWD RUN 3 JOB NUMBER: K-MW-000788972 LOGGING ENGINEER: TYLER RITCHE OPERATOR WITNESS: GUY WHITLOCK SURFACE LOCATION SECTION: 16 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 1013 FEL: 629 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 98. 62 GROUND LEVEL: 70.70 90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 7.000 7.000 5712.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) , UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. RUN 1 WAS A CASING SCRAPPER RUN WITH NO MWD. 4. MWD RUN 2 WAS A DIRECTIONAL ONLY RUN. DURING THE RUN THE WHIPSTOCK WAS POSITIONED, WINDOW MILLED, AND A RAT HOLE DRILLED. THE TOP OF THE WHIPSTOCK WINDOW WAS 5712' MD, 5123' TVD. THE BOTTOM OF THE WHIPSTOCK WINDOW WAS 5745' MD, 5140' TVD. RATE OF PENETRATION DATA FOR MWD RUN 2 WAS MERGED ONTO THE TOP OF MWD RUN 3. 5. MWD RUN 300 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , DRILLSTRING DYNAMICS SENSOR (DDSr) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND AZIMUTHAL LITHO-DENSITY (ALD) . 6. LOG AND MERGED DIGITAL MWD DATA WERE BULK SHIFTED UP 11' . SHIFTING INSTRUCTIONS WERE PROVIDED VIA E-MAIL FROM LAIRD LITTLE (CONOCOPHILLIS) TO BRYAN BURINDA (SPERRY DRILLING) DATED 03-FEB-2011. LOG HEADER DATA AND ANNOTATIONS RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUN 3 REPRESENTS WELL 1E-08A WITH API # 50-029-20496-01. THIS WELL REACHED A TOTAL DEPTH OF 7, 860' MD, 6,571' TVD. ROPA = AVG RATE OF PENETRATION DGRC = DGR COMBINED GAMMA RAY R09P = 9in PHASE RESISTIVITY R15P = 15in PHASE RESISTIVITY R27P = 27in PHASE RESISTIVITY R39P = 39in PHASE RESISTIVITY EWXT = EWR FORMATION EXP TIME TNPS = CTN POROSITY SANDSTONE ALCDLC = ALD LCRB COMP DENSITY ALDCLC = ALD LCRB DEN CORRECTION ALPELC = ALD LCRB Pe FACTOR ALRPM = ALD RPM USED TO HIGHLIGHT ZONES WHERE DENSITY DATA WAS ACQUIRED WITHOUT ROTATION PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED MUD WEIGHT: 9.2 - 10.1 PPG WHOLE MUD CHLORIDES: 13, 660 - 18, 000 PPM CL FORMATION WATER SALINITY: 14,545 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/04 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5644.0 7788.0 RHOB 5691.0 7775.0 DRHO 5691.0 7775.0 PEF 5691.0 7775.0 RPM 5702.0 7806.0 NCNT 5702.0 7771.0 FCNT 5702.0 7771.0 RPX 5702.0 7806.0 RPS 5702.0 7806.0 NPHI 5702.0 7771.0 FET 5702.0 7806.0 RPD 5702.0 7806.0 ROP 5712.5 7860.0 CALN 5720.5 7775.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 5644.0 5655.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 5655.0 7860.0 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 CALN MWD IN 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 GR MWD API 4 1 68 20 6 FET MWD HR 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPM MWD OHMM 4 1 68 36 10 RPD MWD OHMM 4 1 68 40 11 ROP MWD FPH 4 1 68 44 12 FCNT MWD CP30 4 1 68 48 13 NCNT MWD CP30 4 1 68 52 14 NPHI MWD PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5644 7860 6752 4433 5644 7860 RHOB MWD G/CC 1.015 3.951 2.43049 4169 5691 7775 DRHO MWD G/CC -3. 929 1.061 0.0755469 4169 5691 7775 CALN MWD IN 5. 63 8.47 6.55507 2708 5720.5 7775 PEF MWD B/E 1.75 13.97 4.47311 4169 5691 7775 GR MWD API 27.08 485.69 139. 668 4289 5644 7788 FET MWD HR 0.37 26.47 1.74354 4209 5702 7806 RPX MWD OHMM 0.3 1556.68 4.8079 4209 5702 7806 RPS MWD OHMM 0.58 1552.34 5.79245 4209 5702 7806 RPM MWD OHMM 0.48 2000 10.5063 4209 5702 7806 RPD MWD OHMM 0.81 2000 10.7431 4209 5702 7806 ROP MWD FPH 0 216.4 73.3412 4296 5712.5 7860 FONT MWD CP30 99. 91 1353.29 249.031 4139 5702 7771 NCNT MWD CP30 13509.5 35943.3 19216. 6 4139 5702 7771 NPHI MWD PU 9. 93 62.3 36.2189 4139 5702 7771 First Reading For Entire File 5644 Last Reading For Entire File 7860 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/04 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/04 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 5655.0 7799.0 R09P 5702.0 7806.0 TNPS 5702.0 7771.0 TNNA 5702.0 7771.0 TNFA 5702.0 7771.0 R39P 5702.0 7806.0 R27P 5702.0 7806.0 R15P 5702.0 7806.0 ACDL 5702.0 7786.0 EWXT 5702.0 7806.0 ADCL 5702.0 7786.0 APEL 5702.0 7786.0 ROPA 5712.5 7860.0 AHSI 5731.5 7786.0 LOG HEADER DATA DATE LOGGED: 14-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7860.0 TOP LOG INTERVAL (FT) : 5712.0 BOTTOM LOG INTERVAL (FT) : 7860.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 26.1 MAXIMUM ANGLE: 55.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 67978 CTN COMP THERMAL NEUTRON 231710 EWR4 Electromag Resis. 4 67978 ALD Azimuthal Litho-Dens 231387 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 7.000 DRILLER'S CASING DEPTH (FT) : 5712.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.00 MUD VISCOSITY (S) : 40.0 MUD PH: 9.2 MUD CHLORIDES (PPM) : 17000 FLUID LOSS (C3) : 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .280 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .141 141.4 MUD FILTRATE AT MT: .250 68.0 MUD CAKE AT MT: .460 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units 4 Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD030 G/CC 4 1 68 4 2 DRHO MWD030 G/CC 4 1 68 8 3 CALN MWD030 IN 4 1 68 12 4 PEF MWD030 B/E 4 1 68 16 5 GR MWD030 API 4 1 68 20 6 FET MWD030 HR 4 1 68 24 7 RPX MWD030 OHMM 4 1 68 28 8 RPS MWD030 OHMM 4 1 68 32 9 RPM MWD030 OHMM 4 1 68 36 10 RPD MWD030 OHMM 4 1 68 40 11 ROP MWD030 FPH 4 1 68 44 12 FCNT MWD030 CP30 4 1 68 48 13 NCNT MWD030 CP30 4 1 68 52 14 NPHI MWD030 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5655 7860 6757.5 4411 5655 7860 RHOB MWD030 G/CC 1.015 3.951 2.43049 4169 5702 7786 DRHO MWD030 G/CC -3.929 1.061 0.0755469 4169 5702 7786 CALN MWD030 IN 5. 63 8.47 6.55507 2708 5731.5 7786 PEF MWD030 B/E 1.75 13. 97 4.47311 4169 5702 7786 GR MWD030 API 27.08 485.69 139. 668 4289 5655 7799 FET MWD030 HR 0.37 26.47 1.74354 4209 5702 7806 RPX MWD030 OHMM 0.3 1556. 68 4.8079 4209 5702 7806 RPS MWD030 OHMM 0.58 1552.34 5.79245 4209 5702 7806 RPM MWD030 OHMM 0.48 2000 10.5063 4209 5702 7806 RPD MWD030 OHMM 0.81 2000 10.7431 4209 5702 7806 ROP MWD030 FPH 0 216.4 73.3412 4296 5712.5 7860 FCNT MWD030 CP30 99.91 1353.29 249.031 4139 5702 7771 NCNT MWD030 CP30 13509.5 35943.3 19216. 6 4139 5702 7771 NPHI MWD030 PU 9.93 62.3 36.2189 4139 5702 7771 First Reading For Entire File 5655 Last Reading For Entire File 7860 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/04 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF Tape Trailer Service name LISTPE Date 11/02/04 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/02/04 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 22 12:20:21 2011 Reel Header Service name LISTPE Date 11/02/22 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/02/22 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: 1E-08A API NUMBER: 500292049601 OPERATOR: ConocoPhillips (Alaska) , Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 22-FEB-11 JOB DATA MWD RUN 3 JOB NUMBER: K-MW-000788972 LOGGING ENGINEER: TYLER RITCHE OPERATOR WITNESS: GUY WHITLOCK SURFACE LOCATION SECTION: 16 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 1013 FEL: 629 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 98.62 GROUND LEVEL: 70.70 acv - iii 00-96" 1 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 7.000 7.000 5712.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: THIS DATA SET SUPERCEDES ALL PREVIOUSLY-ISSUED DATA SETS, SPECIFICALLY THE ONE DATED 04-FEB-2011. THIS RE-ISSUE INCORPORATES A RE-SHIFTING OF THE MERGED DATA. 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) , UNLESS OTHERWISE NOTED. 2. ALL VERTICAL. DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. RUN 1 WAS A CASING SCRAPPER RUN WITH NO MWD. 4. MWD RUN 2 WAS A DIRECTIONAL ONLY RUN. DURING THE RUN THE WHIPSTOCK WAS POSITIONED, WINDOW MILLED, AND A RAT HOLE DRILLED. THE TOP OF THE WHIPSTOCK WINDOW WAS 5712' MD, 5123' TVD. THE BOTTOM OF THE WHIPSTOCK WINDOW WAS 5745' MD, 5140' TVD. RATE OF PENETRATION DATA FOR MWD RUN 2 WAS MERGED ONTO THE TOP OF MWD RUN 3. 5. MWD RUN 300 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , DRILLSTRING DYNAMICS SENSOR (DDSr) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND AZIMUTHAL LITHO-DENSITY (ALD) . 6. LOG AND MERGED DIGITAL MWD DATA WERE BULK SHIFTED UP 11' . SHIFTING INSTRUCTIONS WERE PROVIDED VIA E-MAIL FROM LAIRD LITTLE (CONOCOPHILLIS) TO BRYAN BURINDA (SPERRY DRILLING) DATED 03-FEB-2011. LOG HEADER DATA AND ANNOTATIONS RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUN 3 REPRESENTS WELL 1E-08A WITH API # 50-029-20496-01. THIS WELL REACHED A TOTAL DEPTH OF 7, 860' MD, 6,571' TVD. ROPA = AVG RATE OF PENETRATION DGRC = DGR COMBINED GAMMA RAY RO9P = 9in PHASE RESISTIVITY R15P = 15in PHASE RESISTIVITY R27P = 27in PHASE RESISTIVITY R39P = 39in PHASE RESISTIVITY EWXT = EWR FORMATION EXP TIME TNPS = CTN POROSITY SANDSTONE ALCDLC = ALD LCRB COMP DENSITY ALDCLC = ALD LCRB DEN CORRECTION ALPELC = ALD LCRB Pe FACTOR ALRPM = ALD RPM USED TO HIGHLIGHT ZONES WHERE DENSITY DATA WAS ACQUIRED WITHOUT ROTATION PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED MUD WEIGHT: 9.2 - 10.1 PPG WHOLE MUD CHLORIDES: 13, 660 - 18,000 PPM CL FORMATION WATER SALINITY: 14, 545 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/22 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5644.0 7788.0 NCNT 5691.0 7760.0 DRHO 5691.0 7775.0 FCNT 5691.0 7760.0 RPD 5691.0 7795.0 RPM 5691.0 7795.0 RPS 5691.0 7795.0 RPX 5691.0 7795.0 FET 5691.0 7795.0 PEF 5691.0 7775.0 RHOB 5691.0 7775.0 NPHI 5691.0 7760.0 ROP 5701.5 7849.0 CALN 5720.5 7775.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 5644.0 5655.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 5655.0 7860.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 CALN MWD IN 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 GR MWD API 4 1 68 20 6 FET MWD HR 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPM MWD OHMM 4 1 68 36 10 RPD MWD OHMM 4 1 68 40 11 ROP MWD FPH 4 1 68 44 12 FCNT MWD CP30 4 1 68 48 13 NCNT MWD CP30 4 1 68 52 14 NPHI MWD PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5644 7849 6746.5 4411 5644 7849 RHOB MWD G/CC 1.015 3.951 2.43049 4169 5691 7775 DRHO MWD G/CC -3. 929 1.061 0.0755469 4169 5691 7775 CALN MWD IN 5. 63 8.47 6.55507 2708 5720.5 7775 PEF MWD B/E 1.75 13.97 4.47311 4169 5691 7775 GR MWD API 27.08 485.69 139.668 4289 5644 7788 FET MWD HR 0.37 26.47 1.74354 4209 5691 7795 RPX MWD OHMM 0.3 1556.68 4.8079 4209 5691 7795 RPS MWD OHMM 0.58 1552.34 5.79245 4209 5691 7795 RPM MWD OHMM 0.48 2000 10.5063 4209 5691 7795 RPD MWD OHMM 0.81 2000 10.7431 4209 5691 7795 ROP MWD FPH 0 216.4 73.3412 4296 5701.5 7849 FCNT MWD CP30 99.91 1353.29 249.031 4139 5691 7760 NCNT MWD CP30 13509.5 35943.3 19216. 6 4139 5691 7760 NPHI MWD PU 9.93 62.3 36.2189 4139 5691 7760 First Reading For Entire File 5644 Last Reading For Entire File 7849 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/22 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/22 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 5655.0 7799.0 ACDL 5702.0 7786.0 TNNA 5702.0 7771.0 TNFA 5702.0 7771.0 R39P 5702.0 7806.0 R27P 5702.0 7806.0 R15P 5702.0 7806.0 R09P 5702.0 7806.0 EWXT 5702.0 7806.0 APEL 5702.0 7786.0 ADCL 5702.0 7786.0 TNPS 5702.0 7771.0 ROPA 5712.5 7860.0 AHSI 5731.5 7786.0 LOG HEADER DATA DATE LOGGED: 14-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7860.0 TOP LOG INTERVAL (FT) : 5712.0 BOTTOM LOG INTERVAL (FT) : 7860.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 26.1 MAXIMUM ANGLE: 55.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 67978 CTN COMP THERMAL NEUTRON 231710 EWR4 Electromag Resis. 4 67978 ALD Azimuthal Litho-Dens 231387 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 7.000 DRILLER'S CASING DEPTH (FT) : 5712.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.00 MUD VISCOSITY (S) : 40.0 MUD PH: 9.2 MUD CHLORIDES (PPM) : 17000 FLUID LOSS (C3) : 4 .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .280 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .141 141.4 MUD FILTRATE AT MT: .250 68.0 MUD CAKE AT MT: .460 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD030 G/CC 4 1 68 4 2 DRHO MWD030 G/CC 4 1 68 8 3 CALN MWD030 IN 4 1 68 12 4 PEF MWD030 B/E 4 1 68 16 5 GR MWD030 API 4 1 68 20 6 FET MWD030 HR 4 1 68 24 7 RPX MWD030 OHMM 4 1 68 28 8 RPS MWD030 OHMM 4 1 68 32 9 RPM MWD030 OHMM 4 1 68 36 10 RPD MWD030 OHMM 4 1 68 40 11 ROP MWD030 FPH 4 1 68 44 12 FCNT MWD030 CP30 4 1 68 48 13 NCNT MWD030 CP30 4 1 68 52 14 NPHI MWD030 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5655 7860 6757.5 4411 5655 7860 RHOB MWD030 G/CC 1.015 3.951 2.43049 4169 5702 7786 DRHO MWD030 G/CC -3. 929 1.061 0.0755469 4169 5702 7786 CALN MWD030 IN 5. 63 8.47 6.55507 2708 5731.5 7786 PEF MWD030 B/E 1.75 13.97 4.47311 4169 5702 7786 GR MWD030 API 27.08 485.69 139.668 4289 5655 7799 FET MWD030 HR 0.37 26.47 1.74354 4209 5702 7806 RPX MWD030 OHMM 0.3 1556.68 4 .8079 4209 5702 7806 RPS MWD030 OHMM 0.58 1552.34 5.79245 4209 5702 7806 RPM MWD030 OHMM 0.48 2000 10.5063 4209 5702 7806 RPD MWD030 OHMM 0.81 2000 10.7431 4209 5702 7806 ROP MWD030 FPH 0 216.4 73.3412 4296 5712.5 7860 FCNT MWD030 CP30 99.91 1353.29 249.031 4139 5702 7771 NCNT MWD030 CP30 13509.5 35943.3 19216.6 4139 5702 7771 NPHI MWD030 PU 9.93 62.3 36.2189 4139 5702 7771 First Reading For Entire File 5655 Last Reading For Entire File 7860 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/22 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF Tape Trailer Service name LISTPE Date 11/02/22 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/02/22 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
