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211-005
Originated: Delivered to:27-Mar-25Alaska Oil & Gas Conservation Commiss27Mar25-NR ! "# $$%$ !&$$'($)*%+ ($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDMT7-15 50-103-20885-00-00 224-037 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 5-Feb-251H-106 50-029-23800-00-00 224-117 Kuparuk River WL TTiX-PPROF FINAL FIELD 22-Feb-251C-157 50-029-23754-00-00 223-038 Kuparuk River WL TTiX-FSI FINAL FIELD 27-Feb-25CD3-127 50-103-20634-00-00 211-005 Colville River WL Patch&Packer FINAL FIELD 8-Mar-251C-151 50-029-23497-00-00 213-123 Kuparuk River WL TTiX-FSI FINAL FIELD 12-Mar-253S-624 50-103-20868-00-00 223-104 Kuparuk River WL TTiX-FSI FINAL FIELD 22-Mar-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8 " ! - +" 8 # !(3 . 8 ) "3 8 # !9 3 : 8" +8 6 8 8 " 8 # !;" " 3 - 3 " 3 ""+ 3 + < +3!% T40238T40239T40240T40241T40242T40243CD3-12750-103-20634-00-00211-005Colville RiverWLPatch&PackerFINAL FIELD8-Mar-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.03.28 08:11:16 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-03-03_23068_CD3-127_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23068 CRU CD3-127 50-103-20634-00 Coil Flag 03-Mar-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 ConocoPhilllips Alaska Attn: Ricky Elgarico GSRMC, ARO-3-380 700 G Street Anchorage, Ak. 99501 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 211-005 T40202 3/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.07 11:27:26 -09'00' TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit data drophard driveVia CD2-45 50-103-20395-00 201212_CD2-45_Patch_15May2023 CD2-53 50-103-20494-00 204089_CD2-53_LDL_30Nov2022 204089_CD2-53_Patch_14Oct2022 CD3-107 50-103-20529-01 206189_CD3-107_Packer_16Apr2022 CD3-125 50-103-20632-00 210189_CD3-125_LDL_23Feb23 210189_CD3-125_POGLM_03Apr2023 CD3-127 50-103-20634-00 211005_CD3-127_Patch_23Apr2022 211005_CD3-127_PPROF_18Apr2022 CD3-303 50-103-20568-00 208013_CD3-303_CHC_21Feb2023 CD4-499 50-103-20810-00 219161_CD4-499_PPROF_28Sep2023 WD-02 50-103-20285-00 198258_WD-02_WFL_22May2022 WD-03 50-103-20835-00 221103_WD-03_IBC DSLT_12Feb2022 221103_WD-03_USIT_28Feb2022 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38298 T38299 T38300 T38301 T38302 T38303 T38304 T38305 T38306 2/29/2024 CD3-127 50-103-20634-00 211005_CD3-127_Patch_23Apr2022 211005_CD3-127_PPROF_18Apr2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:46:16 -09'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 13, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Brennen Green ConocoPhillips Well Integrity Field Supervisor Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.04.13 11:34:18-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green ConocoPhillips Alaska Inc.Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-offReport of Sundry Operations (10-404)Alpine FieldWell Name API # PTD #Initial top of cementVol. of cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant dateft bbls in galCD3-106 5010320611-0000 210-001 N/APost Conductor Ext10.75" 4/5/2022 2 4/12/2023CD3-117 5010320596-0000 209-026 N/APost Conductor Ext13" 4/5/2022 3 4/12/2023CD3-127 5010320634-0000 211-005 18' 1.0 8" 4/9/2022 1 4/12/2023CD3-302A 5010320522-0100 210-035 N/APost Conductor Ext9" 4/5/2022 2 4/12/2023CD4-214 5010320537-0000 206-145 22' 8" 1.6 7" 4/9/2022 1.5 4/12/2023CD4-319 5010320516-0000 205-148 22' 3" 1.5 7" 4/9/2022 1.5 4/12/2023Date 04/13/2023CD3 & CD4 PadsCD3-1275010320634-0000211-00518'1.08"4/9/202214/12/2023 Originated: Halliburton Wireline & Perforating Attn: Fanny Haroun 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above 211-005 T36463 Transmittal Date: 8-Apr-22 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 1 CD3-127 50-103-20634-00 n/a Colville River Leak Detect Log Field- Final 19-Feb-22 0 1 2 WD-03 50-103-20835-00 907771752 Colville River Leak Detect Log with ACX Field & Processed 25-Mar-22 0 1 3 WD-03 50-103-20835-00 907771752 Colville River Leak Detect Log with ACX Field & Processed 30-Mar-22 0 1 4 WD-03 50-103-20835-00 907771752 Colville River CAST-M Record Field & Processed 31-Mar-22 0 1 5 WD-03 50-103-20835-00 907771752 Colville River CAST-M Record Field & Processed 31-Mar-22 0 1 6 WD-03 50-103-20835-00 907771752 Colville River Radial Bond Record Field- Final 29-Mar-22 0 1 7 WD-03 50-103-20835-00 907771752 Colville River Temperature Record Field- Final 31-Mar-22 0 1 8 9 10 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 g Meredith G u h l Digitally signed by Meredith Guhl Date: Signed: Date: 2022.04.08 15:28:47 -08'00' STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION By Samantha Carlisle at 4:33 pm, May 20, 2021 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: SC Repair 0 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ Stratigraphic ❑ Service ❑ 211-005-0 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-103-20634-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, ADL 025538, ADL 025526 CRU C133-127 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Alpine Oil Pool N/A Colville River Field/ Pool 11. Present Well Condition Summary: sFD 5/21/2021 Total Depth measured 20033' feet Plugs measured None feet true vertical 7049' feet Junk measured None feet Effective Depth measured 20033' feet Packer measured 14367', 14790' feet true vertical 7049' feet true vertical 6799', 6931' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 3202' 10-3/4" 3239' 2454' Intermediate 14935' 7-5/8" 14970' 6968' Liner 5233' 3-1/2" 20023' 7048' Perforation depth Measured depth 14429-14452', 15430-15450', 16320-16340', 18400-18420' feet True Vertical depth 6821-6829', 6981-6981', 6996-6996', 7008-7009' feet Tubing (size, grade, measured and true vertical depth) 4-1/2"x3-1/2" L80 14826' MD 6939' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer 14367' MD 6799' TVD Packer: Baker ZXP Liner Top Packer 14790' MD 6931' TVD SSSV: TRMAXX-5E SSSV 2152' MD 2001' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 512 2150 608 1271 244 Subsequent to operation: Well is still Shut-in 0 0 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 321-196 Authorized Name: Travis Smith Contact Name: Travis Smith Authorized Title: WINS Interventions and Integrity Engineer Contact Email: travis.t.smith@conocophillips.com Travis T. Smith Date: Authorized Signature with date: Date: 2021.05.20 15:36:48 -08'00' Contact Phone: (907) 265- 6846 Senior Engineer:VTL 9/9/21 ISenior Res. Engineer: cFn r,/91/9n91 RBDMS HEW 6/10/2021 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations CD3-127 Surface Casing Repair Summary of Operations DTTMSTART JOBTYP SUMMARYOPS 4/17/2021 ANNCOMM (AC EVAL) T X IA DDT TO 0 PSI (PASSED) 4/18/2021 ANNCOMM PUMP OA CEMENT SHOE (COMPLETE). WAIT 72 HOURS BEFORE OA DDT 4/21/2021 ANNCOMM (SC REPAIR PREP) IN PROGRESS-SCLD (FAILED) FIRST SC LEAK IDENTIFIED @ 44" BELOW OA VALVE. READY FOR EXCAVATION. OA DDT (PASSED) 4/22/2021 ANNCOMM (SC REPAIR) IN PROGRESS. EXCAVATED TO 4', WELDERS CUT& REMOVED STEEL CELLAR. RESUMED TO EXCAVATING. TARGET DEPTH OF EXCAVATION 24' WITH 2' BACKFILL. 4/23/2021 ANNCOMM (SC REPAIR) IN PROGRESS. EXCAVATED/BENCHED DOWN AREA IN FRONT OF WELLHEAD 5' FOR EQUIPMENT USAGE. EXCAVATED TO & AROUND WELLHEAD. TARGET DEPTH OF EXCAVATION 24' WITH 2' BACKFILL. 4/24/2021 ANNCOMM (SC REPAIR) IN PROGRESS. EXCAVATED TO 21' AROUND WELLHEAD. TARGET DEPTH OF EXCAVATION 24' WITH 2' BACKFILL 4/25/2021 ANNCOMM (SC REPAIR) IN PROGRESS. EXCAVATED TO 2T AROUND WELLHEAD. BEGAN EXCAVATING FOR EGRESS. NEXT STEP: SET SHORE BOX AND STAIRS. BUILD SCAFFOLD. 4/26/2021 ANNCOMM (SC REPAIR) IN PROGRESS. BACKFILLED TO 20' AROUND WELLHEAD. UNABLE TO SET SHORE BOX DUE TO HIGH WINDS. NEXT STEP: SET SHORE BOX, EXCAVATE FOR STAIRS, BUILD SCAFFOLD INSIDE SHORE BOX. 4/27/2021 ANNCOMM (SC REPAIR) IN PROGRESS. SET SHORE BOX EXCAVATION DEPTH, BEGAN EXCAVATING EGRESS. NEXT STEP: SCAFFOLD SET UP. 4/28/2021 ANNCOMM (SC REPAIR) IN PROGRESS- INSTALLED STAIRS AND EGRESS, COVERED EXCAVATION WITH BLANKETS TO PREVENT GROUND THAW. CONTACTED SCAFFOLD CREW FOR SCAFFOLD INSTALL. NEXT STEP; INSTALL PURGE JEWELRY, VERIFY WHP, CUT 20"X24" INSPECTION WINDOWS & INSULATED JACKET. 4/29/2021 ANNCOMM (SC REPAIR) IN PROGRESS, 2 WINDOWS CUT IN CONDUCTOR, HOLE FOUND @ 4 O'CLOCK, 42" DOWN FROM TOP OF CONDUCTOR (55" from OA), KAKIVIK ON SCHEDULE TO INSPECT 4/30/2021 ANNCOMM (SC REPAIR) IN PROGRESS, CUT AND REMOVED INSULATED CONDUCTOR. 5/1/2021 ANNCOMM (SC REPAIR) IN PROGRESS, CUT AND REMOVED 17' 1 V OF 16" CONDUCTOR, GOOD PIPE STARTING T BELOW BOTTOM OF OA, DRILLED AND TAPPED HOLE IN CONDUCTOR @ 4 O'CLOCK, KAKIVIK INSPECTION COMPLETE, WELDING TOP PLATE ON 34" INSULATED CONDUCTOR IN PROGRESS. MATT HERRERA WAVED STATE WITNESS OF DAMAGE 5/3/2021 ANNCOMM (SC REPAIR) IN PROGRESS, FIRST AND SECOND A & B COLLARS WELDED 5/4/2021 ANNCOMM (SC REPAIR) IN PROGRESS, INSTALL AND WELD T SLEEVE COMPLETE, UT INSPECTION COMPLETE, DENSO WRAP SURFACE CASING COMPLETE, INSTALL AND WELD 18' 4" CONDUCTOR COMPLETE, MATT HERRERA WAVED STATE WITNESS OF REPAIR 5/5/2021 ANNCOMM (SC REPAIR) BACK FILL AND INSTALL CELLAR BOX. Ni Tights reserved ' �"�;�pfi.R�Invlded =oche witlr'ggrr trss;bn to copy Wr its r YSR• COAYn$ Fw arty, of her Pose or hk any other party is h Ihitedlofi out {hp, express conyeny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Meredith Guhl at 3:02 pm, May 05, 2021 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: OA Cement Shoe 0 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 • Exploratory ❑ Stratigraphic ❑ Service ❑ 211-005-0 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-103-20634-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, ADL 025538, ADL 025526 CRU CD3-127 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Alpine N/A Colville River Field/ FoeFd Neeh^'mV Oil Pool 11. Present Well Condition Summary: Total Depth measured 20033' feet Plugs measured None feet true vertical 7049' feet Junk measured None feet Effective Depth measured 20033' feet Packer measured 14367', 14790' feet true vertical 7049' feet true vertical 6799', 6931' feet Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 3202' 10-3/4" 3239' 2454' Intermediate 14935' 7-5/8" 14970' 6968' Liner 5233' 3-1/2" 20023' 7048' Perforation depth Measured depth 14429-14452', 15430-15450', 16320-16340', 18400-18420' feet True Vertical depth 6821-6829', 6981-6981', 6996-6996', 7008-7009' feet Tubing (size, grade, measured and true vertical depth) 3-1/2" x 4-1/2" L-80 14826' MD Packers and SSSV (type, measured and true vertical depth) PACKER: Baker Premier Packer 14367' MD 6799' TVD PACKER: Baker ZXP Liner Top Packer 14790' MD 6931' TVD SSSV: TRMAXX-5E SSSV 2152' MD 2001' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 512 2150 608 1271 244 Subsequent to operation: Well still SI for repairs 0 0 0 0 14. Attachments (required Per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 321-171 Authorized Name: Travis Smith Contact Name: Travis Smith Authorized Title: WNS Interventions and Integrity Engineer Travis T. Smith Digitally signed by Travis T. Smith Contact Email: travis.t.smith(a)conocj hillips.com . Authorized Signature with date: Date: 2021.05.05 14:03:34 -08'00' Contact Phone: (907) 265-6846 Senior Engineer:VTL 5/6/21 Isenior Res. Engineer: SFD 5/7/2021 RBDMS HEW 5/6/2021 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations CD3-127 Cement OA Shoe Summary of Operations DTTMSTART JOBTYP SUMMARYOPS 4/15/2021 ANNCOMM CIRC-OUT WELL WITH3 BBLS METHANOL FOLLOWED BY 800 BBLS WITH CORROSION INHIBITED SEAWATER AND 85 BBLS DIESEL. 4/16/2021 ANNCOMM CIRC-OUT WELL W/ 3 BBLS METHANOL FOLLOWED BY 800 BBLS WITH CORROSION INHIBITED SEAWATER AND 85 BBLS DIESEL. U- TUBE DIESEL FOR FP. CMIT-TXIA TO 2500 PSI (PASSED). OA INJECTIVITY TEST (2 BPM @ 1065 PSI FOR 10 BBLS). T X IA DDT TO 0 PSI (IN PROGRESS) 4/17/2021 ANNCOMM (AC EVAL) T X IA DDT TO 0 PSI (PASSED) 4/18/2021 ANNCOMM PUMP OA CEMENT SHOE (COMPLETE). WAIT 72 HOURS BEFORE OA DDT 4/21/2021 ANNCOMM (SC REPAIR PREP) IN PROGRESS-SCLD (FAILED) FIRST SC LEAK IDENTIFIED @ 44" BELOW OA VALVE. READY FOR EXCAVATION. OA DDT (PASSED) �� WN$ PROD WELLNAME CD3-127 WELLBORE CD3-127 C017oCOPi11llIpS r� Well Attributes Max Angle & MD TD Alaska.lnc. Flod Name Wel lb*- APIIUWI Welk- slates F1 RD NE HELIK 103 3400 PROD cl {'} 2.11 MD 1RKR) Act 1511,3 ,397 20,033-0 71RK0 Pommant R25 (ppm) Rate AtmolAtlon End flute 150-Gro M) Rig R8108" ❑ata - SSSV: TRpP Last WO: I 36.30 3it8I2013 HORIZONTAL. CDY 127.4 IX21 1153-48 AM Last Tag Venial tmernalic (ecweq Annotallm Depth LRKBI I End Data Wellhom Lou Mod By Ftt.HDER; 31 3 Last Tag: SLM 14.700.0 1 M112013 CD3.127 losbarl Last Reason • 1a1. Mnotau0n End Date Weilbora Laet Mod By ason: Add Pens 711r2021 C➢3-1x7 rogerba I{■y g Strings eacnptlon OD Iml ID [In} Top IRHe1 SetDepth(RKS) Set Depth (TVD)- WULen Ii--- Grade Tap Thread CTOR Sfi 14.69 36.0 114.0 114.0 109.00 H-4D WELDED AAFETY VLV: 2.1si1 Geln2 Description OD pnl IO {K1) Top IRIS) an Depth IRKS) Set Depth t7dill .- M tfl_ n (I--- Grade Top Thead SURFACE 10 314 9.95 35.9 3.239.2 2.453.8 45.50 L80 BTOM Casing DesCnpaon GD on) IG{In) Top{RKe) Sat Depth IRKS) Set Depth tTVO},,, WLrLen II--. Grado Top Thmod INTERMEDIATE 7518 6.97 34.3 14,969.6 6,967-6 29.70 L-80 BTCM Cas4ng Dondptlon OD Ilnl ID{In} Top (hX81 Set Depth IRKB) Sal Depth (TVD)... VAn" (I... Grade Tap Thread LINER 3 V2 2.99 14,790-2 20.023.0 7.048-5 9.30 L-80 SLHT SIIRFA E. 35.%3_M.2- Liner Details Neminel lD Tap IRKS) Top (TVDI (RKB) Top ItW {'] "Mon Coal {H) 14,790.2 6,930.E 76,11 PACKER BAKER ZXP LINER TOP PACKER 4,950 Des uFT- s-79Y.1 14,808.9 6,93S.0 76.54 NIPPLE BAKER RS NIPPLE 4.880 14.811.8 6,935.7 76.61 HANGER BAKER FLEX LOCK LINER HANGER 4.830 14.821.4 6,937.9 76.83 SBE Baker 80-40 Seal Bare Extension P x P 4.000 I 15.028.5 6.976.0 83.24 Swell Packer SWELL PACKER 00 6.387 wl5' Sealing element 2.992 16.075.5 6.980.8 84.91 Swell Packer SWELL PACKER CO 6.38- wl5' Sealing element 2.992 cAs Lrr. 1ixm 15.495.0 6.980.9 89.99 FRAC PORT 3.1f2" SLHT Ball Actuated Sleeve (2.W seal ID) 2.680 2.129- BALL ON SEAT "'MILLED OUT TO 2-W ID"' 15,941-5 6,987-5 88-92 Swell Pecker SWELL PACKER OD 6.W w15' Sealing element 7992 OAS LIFT; 14.094.7 M Er 16,390.E 6,997,8 88-56 FRAC PORT 3-112" SLHT Ball Actuated Sleeve (1-875'seat 10) 2-680 2.0" BALL ON SEAT -MILLED OUT TO 2-68" ID"' GA06F_ 14,3422 16.838-3 6,998.5 90.39 Swell Packer SWELL PACKER OD 6.W w15' Sealing element 2.992 PACKFR; 14,387.2 17,289-1 7,DD1.5 89.75 FRAC PORT 3-112" SLHT Ball Actuated Sleeve 0.75'seal 10) 1.876" BALL ON SEAT 2.680 GAS DFT. 14=.6 "'MILLED OUT TO 2-W 10"' 17,739.2 6,996.9 90.1D Swell packer SWELL PACKER OD 6.38" W 5' Sealing element 2.992 IPEPF; 14,429.0-14,452.0-- 18,189.7 7,D03.5 88,91 FRAC PORT 3-1I2" SLHT Ball Actuated Sleeve (1-62V seat 10) 2.680 1.75" BALL ON SEAT "'MILLED OUT TO 2-68" 10' SLEL-VT- 14.49Sa 18.638-1 7.012.7 88-65 Swell Packer SWELL PACKER DD 6.38" wl 5' Sealing element 2-992 HiPPLE: 14JON.9 19,087-3 7.027.6 9D-87 FRAC PORT 3.112" SLHT Ball Actuated Sleeve (1-50" seal ID) 2-680 1-62V BALL ON SEAT "'MILLED OLTC TO 2.88" 1D"' 19.536-31 7.033,7 89-45 1 Swell Packer SWELL PACKER DO 6-38" w15' Sealing element 2-992 au�naav-14,a14.i 19,960-0 7,041-3 88-75 SLEEVE BAKER'P'5LEEVE 2-695 18,9$2-8 1AA1.8 88-88 1 VALVE BAKER WELLBORE ISOLATION VALVE 0-000 Tubing Strings 7 ! TLNng Des[fiptlon SUIng TUBING 3 Me-,. ID V2 (In) 2-99 Top IRKB) 31.3 Set Depth IR.. 14,825-6 Set Depth (TVD) I... YVI 6.938.9 IIbml 9,30 Grads Topca L80 EUE mcuon 1 4.5x3.5@1 O7' Completion Details I"TERM ECIATE: 34.3-14,989.6 Top (700} Tap Ind I Nominal Top IRKS) (RK01 (") Rem Des Com ID (in) 31-3 31-3 0-00 HANGER FMC TUSI NO HANGER 3-WO 1072 1072 OAD XO RBWuCIng CROSSOVER 4.112" IBT-m box x 3.112' EUE-m 3-500 2,152-1 2,001-5 48-56 SAFETYVLV TRMAXX-FIE SSSVwf2-812-'X- profile wl114"controlline (5-W 2-812 APERF; 16,430A•15,460.0 OD) FRAC:15.495.o RERFP; 15,49&%15A99.0� ! 14.3422 6,789-4 67-99 GAUGE SLB BHP Gmg% 3-M' NOPG single sub, EUE: pin x pin, wf encapsulated I-Mre 2.992 14.3672 6.798-6 68AI PACKER BAKER PREMIER PACKER 2.870 14,414.5 6,815.9 68.74 Blasi Ring PEST BLAST RING (1) 2,992 APERF; le,sxo-a-ls.s4a,o 14.495.3 6,844.5 70.19 SLEEVE BAKER CMD SLICING SLEEVE -OPEN 2.812 PERFP; 16,390.0.10.395.0 FRAC: 10-390.0L4 1 14,508.9 6,849.1 70.5E NIPPLE HES W LANDING NIPPLE 2.75" NO GO 2.750 14,814.7 fi,938.4 78.88 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY (10.39' 10 4.53` OD 2.970 [oWlOr] Perforations & Slots snot FRAC 17�&D PERFP: 17.28RR17.294.0� El Top(TVO) Bhn ITVDI Dam 40tsm Tnp(RKB) 31m IRKB) (RKB) IRKB) Llnked Zone Date I Type Com 14.429.0 14.452.0 6,821.2 6.829.4 Nechelik, CD3• &1312013 5.0 IPERF PERF KUPARUK SAND 0 127 14429' V 1445Z 15.M0 1SA50.0 6.981A 6.980.9 2112021 6.0 APERF 20' of holes, 6 SPF, 60 deg - PFRFP; 1 e,1s9-a1s.194.0 FRAC, 18.189.0 200E gm. Penelnallon PJ Omega HMx - 7.3 0,22' Ent hole - 21.8" 15.495.0 15.499.0 6,980.9 6.980.9 Nechelik, CD3- 3f29r2013 5.0 PERFP FRAC PORT APFn :1e,400a1s.4zu.o 127 16,32G.0 16,340-0 6,996-2 6.9%.6 Nechellk, CD3- 211P2021 6.0 APERF 20' of hok-, 6 SPF, 60 deg - 127 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21-9" PERFP; 19,067-0.19,0P2.0 FRAC: 19,087,0� Perm ration 16,380.0 16,395.0 6,997-8 6,988.0 NeChellk, CD3- 3/28/2013 5.0 PERFP FRAC PORT 127 17.289-0 17294-0 7.001-5 7.001-5 Nechelik, CD3- 3129r2013 5.0 PERFP FRAC PORT 127 18,T89-0 18,184-p 7,OD3-4 /.UW.5 Nechellk, Cp3- 4reWI013 5.0 PERFP FRAC PORT E 1 127 I LINER; 14.700.2-20-023.0 WNS PROD WELLNAME CO3-127 WELLBORE CD3-127 ►.' CDnocoP ills s Alaska. Inc. HORIZONTAL, 003-t27. An2021 t1. 5349 Nn Perforations & Slots VMical Top ITVD] elm (TVDI 5"t Lena (eh.%M HANGER; 31.3 Top IMM) Ben (RKBI IRKS) (ftKB) Linked Zone Date ] TYPe Cm 18,400-0 18,420-0 7,00S.2 7,008.7 NeOellk, CO3- 113112021 6-0 APERF 20' 0t h01B8, 6 BPF, 60 dog - 127 2006 PJ Omega HMX - 7.3 gm. 0.22' Ent hole - 21 A" Penetration caelwc7OR:3ewue - 19,087.0 19,092-0 7,027.E 7,027.5 NBChelik, CO3- 3/2912013 5.0 PERFP FRAC PORT 127 SAFETY VLV; 2,152. t Stimulation Intervals IMerva I Nul9he Pmppam Proppam Vol Clean Vol slurry r type snbtypa Start Data Top (ftl(B) Bhn (RKB] Dealgned (Ih) Total Ilbl Total (ehl] Total (bell 9 SURFACE; 354-3,23.2— 1 FRAC 3+2W2013 15,495.0 15.499.0 0.0 0,00 0.00 2 FRAC X2912013 16,390,0 16,395,0 0.0 0,00 0.00 3 FRAC 3l2912013 19,087.0 19.092.0 o o 0,00 0.00 4 FRAC X29QO13 17,289,0 17,293.0 0.0 0.00 0.00 OAS LIFT; 8.792.1 5 FRAC 3l292013 18.1810 18.194,0 0.0 0.00 0.00 Mandrel Inserts at all I ' °R Top N Top (RKBI (TVDI (RKBI µeke MWO 00 {In} Sery Valve Type Lawh Type Port Size TRO tin) Run 00 Run Dete C°m 1 5,792.1 3.404.1 Campo KBh4G 1 GASLIFT GLV BK 0.156 1,674.0 4112013 GAS LIFT; 11,e01. 1 2 11,801.1 5,610.5 Campo KBMG 1 GASLIFT GLV RK 0.188 1.730.0 411r2013 3 14,094.7 6,690.9 Camm KBMG 1 GASLIFT OV BK U13 0.0 4112013 4 14,393.6 6.808.3 Campo KBMG 1 GASLIFT OMY RK-5 0.000 6.0 3/1712013 r.s uFT; 14.W4.7 Notes: General & Safety End Date AnnOtadW 3J7912013 NOTE: FINISHED DRILLING&COMPLETION GA17CE;1 a,8a2.2 PACKER;: 14,3672 GAS LIFT, 14,390.8 1PERF, 14,429.0�14,452.0—. SLEEVE; 14,496.3 NIPPLE; 14,W&9 SEAL ASSY; 14.814 7 1 INTEitMEDFATE; 34.114,9645 [� APERF; 15,430.0-13,4509 FRAC: 18.496.0 PERFP; 15,495.0-15,4WO - N APERF; 18,320.0D 16,340.0 spa Ir PERFP: 19'm 01e,396.0 FRAC; 16.M..0--- 4 a FRAC; 17,28BA PERFP: 17—M.0-17,294.0�� N PERFP; 1s.1a%0o-18,'111 FRAC; 18,'80..01� p APERF; 18,400,008,420.0 PERFP: 19,nE7.P19,092A FRAC; 19.067.0��, a LINFFt %.790.2-10p230 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED By Samantha Carlisle at 2:28 pm, Apr 15, 2021 _] 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 21 • Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: SC Repair 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 21, Stratigraphic ❑ Service ❑ 211-005-0 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-103-20634-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ElNo ❑� CRU CD3-127 9. Property Designation (Lease Number): 10. Field/Pool(s): Alpine Oil Pool ADL 372105, ADL 025538, ADL 025526 1 Colville River Field/ I SFD4/19/2021 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): 20033' 7049' 20033' 7049' None None Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 3202' 10-3/4" 3239' 2454' Intermediate 14935' 7-5/8" 14970' 6968' Liner 5233' 3-1/2" 20023' 7048' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14429-14452', 15430-15450', 6821-6829', 981', 6996 3-1/2" x4-1/2" L-80 14826' MD 16320-16340', 18400-18420' 6996', 7008-70097009' Packers and SSSV Type: PACKER:: Baker Premier Packer Packers and SSSV MD (ft) and TVD (ft): PACKER: 14367'MD and 6799' TVD PACKER: Baker ZXP Liner Top Packer PACKER: 14790' MD and 6931' TVD SSSV: TRMAXX-5E SSSV SSSV: 2152' MD and 2001' TVD 12. Attachments: Proposal Summary ❑r Wellbore schematic ❑r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑r Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/19/2021 OIL ❑+ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Travis Smith Contact Name: Travis Smith Authorized Title: WNS Interventions and Integrity Engineer Contact Email: travls.t.smlth Conoco hull S.com DigitallysignedbyTravisT.Smith Contact Phone: 907-265-6846 Travis T. Smith Date: 2021.04.1513:49:36-08'00' Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 321-196 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance IR Other: Photo document all steps including cutting windows, leak repair, site clearance and SC before and after patch RBDMS HEW 4/21/2021 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No [A Subsequent Form Required: 1 0-404 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4�20�21 Commdts 4/20/2021 Comm. I Sr Pet EngVTL 4/20/211 1 Sr Pet GecDLB 04/15/2021 ISr Res Eng DSR-4/15/21 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 14, 2021 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well CRU CD3-127 (PTD 211-005) to repair surface casing. Please contact me at 265-6846 if you have any questions. Sincerely, Travis Smith WNS Intervention & Integrity Engineer ConocoPhillips Alaska, Inc. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 CD3-127 SC Repair proposal 1. Shut-in and secure well: Verify the IA fluid level is at surface and an MITIA passes. Freeze protect the tubing with diesel and set a tubing tail plug, pressure test plug and tubing. (Depending on IA FL and MITIA results, the tbg and IA may need to be displaced with seawater and a diesel cap to 2000' by circulating thru the bottom GLM.) 2. Bleed tubing, IA (4.5" x 7-5/8") and OA (7-5/8" x 10-3/4") to zero psi. Verify flow is zero; inability to maintain zero psi prior or during job will cancel the welding operation. 3. Remove wellhouse, floor kit, wellhead piping and platform. Remove wellhead jewelry and replace with alemites for excavation process. 4. Excavate to 26' backfill with 2' pea gravel. Set shoring and access point. (Stairs, scaffold work plat form and scaffold entry point from pad grade. 5. Connect indirect fired heater scaffold work platform for heat and ventilation. A second heater may be required for placing heat on the N2 manifold and break -shack (if needed). Station light plant on pad for increased visibility (if needed) during operation 6. Reinstall Wellhead jewelry and valve handles. 7. Pull VR plug and install opposing valve on casing head for N2 purge (NA). 8. Drill & Tap holes down the conductor to verify or remove any fluids. 9. Cut Inspection window in conductor. Contact Kakivik for MT/UT for conductor removal. Checking areas of greatest loss. 10. Cut and remove conductor. Prep 10 3/4" 45.5# L-80 surface casing for leak detect. 11. Inspect for visible leak points, pressure test SC to identify leak point. 12. Kakivik to NDE testing of surface casing for "A" & "B" bands. 13. Weld shop fabs collars and sleeve per Field Mechanical Engineer specs. 14. Verify OA fluid level is at least 12" to 36" below weld point; remove fluid via suction hose as needed. 15. Install purge lines from N2 bottle rack to OA and from OA to slop trailer. Discharge will be monitored for LEL and 02 levels and must be accessible. Position slop trailer downwind and as far from excavation as is practical. 16. Install/weld collars. NDE testing of collars. 17. Install/Weld sleeve/ NDE testing of sleeve. 18. Pressure testing of repair. 19. Denso wrap entire SC. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 20. Replace/weld 16" 109# H-40 conductor, from remaining conductor to bottom of the wellhead. 21. Remove hooch, scaffolding, and shoring box. 22. Backfill to within 4' of pad grade. 23. Install cellar box. Complete backfill operations. 24. Reinstall wellhead platform, piping, floor kit, and wellhouse. WNS PROD WELLNAME CD3-127 WELLBORE CD3-127 ConOCoPhillips 1 Alaska, Inc. I, cp,;li;p Well Attributes I Max Angle & MD TD Field Name FIORD NECHELIK Wellbore API/UWI 501032063400 Wellbore Status PROD I cl (°) 2.11 MD (ftKB) 15,327.97 Act Btm (ftKB) 20,033.0 Comment H2S SSSV: TRDP (ppm) Date Annotation Last WO: End Date KB-Grd (ft) 36.30 Rig Release Date 3/19/2013 HORIZONTAL, CD3-127, 2/4/2021 10:22:11 AM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Date Wellbore Last Mod By HANGER; 31.3- 01, CONDUCTOR; W 0-114.0 SAFETY VLV; 2,152.1 SURFACE; 35.9-3,239.2- GAS LIFT, 5,792.1 GAS LIFT; 11,801.1 GAS LIFT; 14,094.7 GAUGE;14,342.2 PACKER; 14,367.2 GAS LIFT; 14,393.E IPERF; 14,429.0-14,452.0---- a SLEEVE; 14,495.3 NIPPLE; 14,508.9 SEAL ASSY; 14,814.7 INTERMEDIATE; 34.3-14,969.6 APERF; 15,430.0-15,450.0 FRAC; 15,499.0.0 PERFP; 15,495.0-15,49� APERF; 16,320.0-16,340.0 PERFP; 16,390.0-163950 FRAc;1s,,3so.o.L� FRAC; 17,289.0 PERFP; 17,289.0-17,294.0 PERFP; 18,189.0-18,194.0 FRAC; 18,169.OL� APERF; 18,400.0-18,420.0 PERFP; 19,087.0-19,092.0 p FRAC; 19,087.0 LINER; 14,790.2-20,023.0 Last Tag: SLIM 1 14,700.0 3/31/2013 1 CD3-127 Iosborl Last Rev Reason Annotation I End Date Wellbore Last Mod By Rev Reason: Add Perfs 2/1/2021 CD3-127 I rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 14.69 Top (ftKB) 36.0 Set Depth (ftKB) 114.0 114.0 Set Depth (TVD)... WVLen (I... 109.00 Grade Top H-40 WELDED Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 35.9 Set Depth (ftKB) 3,239.2 Set Depth (TVD)... 2,453.8 WULen (I... 45.50 Grade Top L80 BTCM Thread Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 34.3 Set Depth (ftKB) 14,969.6 Set Depth (TVD)... 6,967.6 WULen (I... 29.70 Grade Top L-80 BTCM Thread Casing Description LINER OD (in) 31/2 ID (in) 2.99 Top (ftKB) 114,790.2 Set Depth (ftKB) 120,023.0 Set Depth (TVD)... 7,048.5 WULen (I... 19.30 Grade Top 1 L-80 JSLHT Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 14,790.2 6,930.6 76.11 PACKER BAKER ZXP LINER TOP PACKER 4.950 14,808.9 6,935.0 76.54 NIPPLE BAKER IRS NIPPLE 4.880 14,811.8 6,935.7 76.61 HANGER BAKER FLEX LOCK LINER HANGER 4.830 14,821.4 6,937.9 76.83 SBE Baker 80-40 Seal Bore Extension P x P 4.000 15,028.5 6,976.0 83.24 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15,075.5 6,980.8 84.91 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15,495.0 6,980.9 89.98 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (2.00" seat ID) 2.125" BALL ON SEAT ***MILLED OUT TO 2.68" ID*** 2.680 15,941.5 6,987.5 88.92 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 16,390.6 6,997.9 88.56 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.875" seat ID) 2.0" BALL ON SEAT ***MILLED OUT TO 2.68" ID- 2.680 16,838.3 6,998.5 90.39 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 17,289.1 7,001.5 89.75 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.75" seat ID) 1.875" BALL ON SEAT -MILLED OUT TO 2.68" ID*** 2.680 17,739.2 6,996.9 90.10 Swell packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 18,189.7 7,003.5 88.91 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.625" seat ID) 1.75" BALL ON SEAT ***MILLED OUT TO 2.68" ID*** 2.680 18,638.1 7,012.7 88.65 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 19,087.3 7,027.6 90.87 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.50" seat ID) 1.625" BALL ON SEAT ***MILLED OUT TO 2.68" ID*** 2.680 19,536.3 7,033.7 89.45 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 19,960.0 7,047.3 88.75 SLEEVE BAKER 'P' SLEEVE 2.695 19,982.9 7,047.8 88.88 VALVE BAKER WELLBORE ISOLATION VALVE 0.000 Tubing Strings Tubing Description String TUBING 31/2 4.5x3.5@107' Me... ID (in) 2.99 Top (ftKB) 31.3 Set Depth (ft.. 14,825.6 Set Depth (TVD) (... 6,938.9 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.3 31.3 0.00 HANGER FMC TUBING HANGER 3.900 107.2 107.2 0.40 XO Reducing CROSSOVER 4-1/2" IBT-m box x 3-1/2" EUE-m 3.500 2,152.1 2,001.5 48.56 SAFETY VLV TRMAXX-5E SSSV w/ 2.812" "X" profile w/ 1/4" control line (5.176" OD) 2.812 14,342.2 6,789.4 67.99 GAUGE SLB BHP Guage, 3-1/2" NDPG single sub, EUE pin x pin, w/ encapsulated I -wire 2.992 14,367.2 6,798.6 68.41 PACKER BAKER PREMIER PACKER 2.870 14,414.5 6,815.9 68.74 Blast Ring PESI BLAST RING (1) 2.992 14,495.3 6,844.5 70.19 SLEEVE BAKER CMD SLIDING SLEEVE - OPEN 2.812 14,508.9 6,849.1 70.5E NIPPLE HES "XN" LANDING NIPPLE 2.75" NO GO 2.750 14,814.7 6,936.4 76.68 SEAL ASSY I BAKER GBH-22 LOCATOR SEAL ASSEMBLY (10.39'to 4.53" OD locator) 2.970 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft ) Type Com 14,429.0 14,452.0 6,821.2 6,829.4 Nechelik, CD3- 127 3/13/2013 5.0 IPERF PERF KUPARUK SAND f/ 14429' t/ 14452' 15,430.0 15,450.0 6,981.1 6,980.9 2/1/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 15,495.0 15,499.0 6,980.9 6,980.9 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT 16,320.0 16,340.0 6,996.2 6,996.6 Nechelik, CD3- 127 2/1/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 16,390.0 16,395.0 6,997.8 6,998.0 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT 17,289.0 17,294.0 7,001.5 7,001.5 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT 18,189.0 18,194.0 7,003.4 7,003.5 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT wNs PROD WELLNAME C133-127 WELLBORE CD3-127 ConocoPhillips Alaska, Inc. l " HORIZONTAL, CD3-127, 2/4/2021 10:22:13 AM Perforations & Slots Vertical schematic (actual) Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft ) Type Com HANGER; 31.3^ l CONDUCTOR; 36.0-114.0 SAFETY VLV; 2,152.1 SURFACE; 35.9-3,239.2— GAS LIFT; 5,792.1 GAS LIFT; 11,801.1 GAS LIFT; 14,094.7 GAUGE; 14,342.2 PACKER; 14,367.2 GAS LIFT; 14,393.E IPERF; 14,429.0-14,452.0 SLEEVE; 14,495.3 NIPPLE; 14,508.9 SEAL ASSY; 14,814.7 INTERMEDIATE; 34.3-14,969.E APERF; 15,430.0-15,450.0 FRAC; 15,495.0 PERFP; 15,495.0-15,499.0—� APERF; 16,320.0-16,340.0 PERFP; 16,390.0-16, 395.0 FRAC; 16,390.01-4 FRAC; 17,289.0 PERFP; 17,289.0-17,294.0� PERFP; 18,189.0-18,194.0 FRAC; 18,189.0 APERF; 18,400.0-18,420.0 PERFP; 19,087.0-19,092.0 FRAC; 19,087.0 LINER; 14,790.2-20,023.0 M�'a Emir �E I 18,400.0 18,420.0 7,008.2 I 7,008.7 Nechelik, CD3- 127 I19,087.0 1/31/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 19,092.0 i 7,027.E 7,027.5 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT Frac Summary Start Date 3/29/2013 Proppant Designed (Ib) Proppant In Formation (lb) Stg # 1 Start Date 3/29/2013 Top Depth (ftKB) 15, 495.0 Btm (ftKB) Link 15, 499.0 to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Stan Date 3/29/2013 Proppant Designed (Ib) Proppant In Formation (lb) Stg # 1 Start Date 3/29/2013 Top Depth (ftKB) 16, 390.0 Btm (ftKB) Link 16, 395.0 to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 3/29/2013 Proppant Designed (Ib) Proppant In Formation (Ib) St"# Start Date 3/29/2013 119,087.0 Top Depth (ftKB) Btm (ftKB) Link 19, 092.0 to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 3/29/2013 Proppant Designed (Ib) Proppant In Formation (Ib) Stg # 1 Start Date 3/29/2013 Top Depth (ftKB) 17,289.0 Btm (ftKB) Link 17,293.0 to Fluid System Vol Clean (bbI) Vol Slurry (bbl) Start Date 3/29/2013 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 IStartDate 3/29/2013 Top Depth (ftKB) 18,189.0 Btm (ftKB) Link 18,194.0 to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Sery Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Corn 1 5,792.1 3,404.1 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,674.0 4/1/2013 2 11,801.1 5,610.5 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 4/1/2013 3 14,094.7 6,690.9 Camco KBMG 1 GAS LIFT OV BK 0.313 0.0 4/1/2013 4 14,393.E 6,808.3 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/17/2013 Notes: General & Safety End Date Annotation 3/19/2013 NOTE: FINISHED DRILLING & COMPLETION STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED By Samantha Carlisle at 9:20 am, Apr 08, 2021 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CA Cement Shoe ❑.. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑.. Stratigraphic ❑ Service ❑ 211-005-0 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-103-20634-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ElNo ❑� CRU CD3-127 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): Alpine Oil SFD 4/8/2021 ADL 372105, ADL 025538, ADL 025526 Colville River Field/ F.__d N__h _,_k- 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): 20033' 7049' 20033' 7049' None None Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 3202' 10-3/4" 3239' 2454' Intermediate 14935' 7-5/8" 14970' 16968' Liner 5233' 3-1/2" 20023' 7048' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14429-14452', 15430-15450', 6821-6829', 981', 6996 3-1/2" x4-1/2" L-80 14826' MD 16320-16340', 18400-18420' 6996', 7008-70097009' Packers and SSSV Type: PACKER:: Baker Premier Packer Packers and SSSV MD (ft) and TVD (ft): PACKER: 14367'MD and 6799' TVD PACKER: Baker ZXP Liner Top Packer PACKER: 14790' MD and 6931' TVD SSSV: TRMAXX-5E SSSV SSSV: 2152' MD and 2001' TVD 12. Attachments: Proposal Summary ❑.. Wellbore schematic ❑.. 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑.. ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/13/2021 OIL ❑.r WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Travis Smith Contact Name: Travis Smith Authorized Title: WNS Interventions and Integrity Engineer Contact Email: travis.t.smith COnoCO hill) S.COm Digitally signed hyhaviz T. Smith Contact Phone: 907-265-6846 Travis T. Smith Date:2021.04.0716:2035-08'00' Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 321-171 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS HEW 4/14/2021 Post Initial Injection MIT Req'd? Yes ❑ No ,1 ^ Spacing Exception Required? Yes ❑ No [A Subsequent Form Required: 1 0-A O,1 ��, - ' qi�— APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4/14/21 Comm.dtS 4/14/2021 1CommJLC 4/14/2021 JSr Pet EngVTL 4/14/211 1 Sr Pet GecDLB 04/08/2021 JSr Res Eng DSR-4/8/21 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. ConocoPhillips Date: April 7, 2021 Subject: CD3-127 OA Cement Shoe Overview Prepared By: Travis Smith, 670-4014 Objective CD3-127 is a producer that was originally drilled and completed in 2013. In January 2021 the well was re -perforated to remediate scale damage. On April 4, 2021 the well failed a diagnostic surface casing leak detect as well as a TIFL. Diagnostics indicate the leak in the surface casing is shallower than 12'. Slickline work in a separate procedure will troubleshoot and address the failing TIFL. Our intent is to address the surface casing repair with an external welded sleeve on the surface casing. In order facilitate this repair a cement shoe will be pumped to secure the OA and bleed the pressure to zero pre -welding. This procedure addresses the OA cement shoe: a separate document will follow for the welding repair. Overview Stem 1. Verify 10-403 Sundry form has been approved for OA cement shoe. 2. Move in cement pumping equipment and rig up to the OA. 3. Flush OA and follow immediately with cement design to place approximately 1,000 foot linear cement shoe in the OA. Displace the cement with spacer pill and diesel or dead crude for freeze protection. 4. After the cement cures, perform OA drawdown test. 5. Report well work to AOGCC on 10-404 form. CD3-127 Cement Shoe Overview Page 1 WNS PROD WELLNAME CD3-127 WELLBORE CD3-127 ConocoPhillips I Alaska, Inc. ... Well Attributes Max Angle & MD TD Field Name FIORD NECHELIK Wellbore APIIUWI 501032063400 Wellbore Status PROD I cI (°) 2.11 MD (ftKB) 15,327.97 Act Btm (ftKB) 20,033.0 Comment H2S SSSV: TRDP (ppm) Date Annotation Last WO: End Date KB-Grd (ft) 36.30 Rig Release Date 3/19/2013 HORIZONTAL, CD3-127, 4/7/2021 11:53:46 AM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Date Wellbore Last Mod By HANGER; 31.3- CONDUCTOR; 36.0-114.0 SAFETY VLV; 2,152.1 SURFACE; 35.9-3,239.2- GAS LIFT, 5,792.1 GAS LIFT; 11,801.1 GAS LIFT; 14,094.7 GAUGE;14,342.2 PACKER; 14,367.2 GAS LIFT; 14,393.6 IPERF; 14,429.0-14,452.0----- SLEEVE; 14,495.3 NIPPLE; 14,508.9 SEAL ASSY; 14,814.7 INTERMEDIATE; 34.3-14,969.6 APERF; 15,430.0-15,450.0 FRAC; 15,495.0 PERFP; 15,495.0-15,499.0 APERF; 16,320.0-16,340.0 PERFP; 16,390.0163950 FRAC;- 16,,390..0LA FRAC; 17289.0 PERFP; 17,289.0-17:294.0 PERFP; 18,189.0-18,194.0 FRAC; 18,189.0 APERF; 18,400.0-18,420.0 PERFP; 19,087.0-19,092.0 FRAC; 19,087.0 LINER; 14,790.2-20,023.0 Last Tag: SLIM 14,700.0 3/31/2013 CD3-127 osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Add Perfs 2/1/2021 CD3-127 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 14.69 Top (ftKB) 36.0 Set Depth (ftKB) 114.0 114.0 Set Depth (TVD)... WVLen (I... 109.00 Grade Top H-40 WELDED Thread Casing Description SURFACE OD (in) 10 314 ID (in) 9.95 Top (ftKB) 35.9 Set Depth (ftKB) 3,239.2 Set Depth (TVD)... 2,453.8 WULen (I... 45.50 Grade Top L80 BTCM Thread Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 34.3 Set Depth (ftKB) 14,969.6 Set Depth (TVD)... 6,967.6 WULen (I... 29.70 Grade Top L-80 BTCM Thread Casing Description LINER OD (in) 31/2 ID (in) 2.99 Top (ftKB) 114,790.2 Set Depth (ftKB) 120,023.0 17,048.5 Set Depth (TVD)... WULen (I... 19.30 Grade Top 1 L-80 JSLHT Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 14,790.2 6,930.6 76.11 PACKER BAKER ZXP LINER TOP PACKER 4.950 14,808.9 6,935.0 76.54 NIPPLE BAKER IRS NIPPLE 4.880 14,811.8 6,935.7 76.61 HANGER BAKER FLEX LOCK LINER HANGER 4.830 14,821.4 6,937.9 76.83 SBE Baker 80-40 Seal Bore Extension P x P 4.000 15,028.5 6,976.0 83.24 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15,075.5 6,980.8 84.91 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15,495.0 6,980.9 89.98 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (2.00" seat ID) 2.125" BALL ON SEAT -MILLED OUT TO 2.68" ID- 2.680 15,941.5 6,987.5 88.92 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 16,390.6 6,997.9 88.56 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.875" seat ID) 2.0" BALL ON SEAT -MILLED OUT TO 2.68" ID- 2.680 16,838.3 6,998.5 90.39 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 17,289.1 7,001.5 89.75 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.75" seat ID) 1.875" BALL ON SEAT -MILLED OUT TO 2.68" ID*** 2.680 17,739.2 6,996.9 90.10 Swell packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 18,189.7 7,003.5 88.91 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.625" seat ID) 1.75" BALL ON SEAT -MILLED OUT TO 2.68" ID - 2.680 18,638.1 7,012.7 88.65 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 19,087.3 7,027.6 90.87 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.50" seat ID) 1.625" BALL ON SEAT -MILLED OUT TO 2.68" ID"* 2.680 19,536.3 7,033.7 89.45 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 19,960.0 7,047.3 88.75 SLEEVE BAKER 'P' SLEEVE 2.695 19,982.9 7,047.8 88.88 VALVE BAKER WELLBORE ISOLATION VALVE 0.000 Tubing Strings Tubing Description String TUBING 31/2 4.5x3.5@107' Me... ID (in) 2.99 Top (ftKB) 31.3 Set Depth (ft.. 14,825.6 Set Depth (TVD) (... 6,938.9 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) I (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.3 31.3 0.00 HANGER FMC TUBING HANGER 3.900 107.2 107.2 0.40 XO Reducing CROSSOVER 4-1/2" IBT-m box x 3-1/2" EUE-m 3.500 2,152.1 2,001.5 48.56 SAFETY VLV TRMAXX-5E SSSV w/ 2.812" "X" profile w/ 1/4" control line (5.176" OD) 2.812 14,342.2 6,789A 67,99 GAUGE SLB BHP Guage, 3-1/2" NDPG single sub, EUE pin x pin, w/ encapsulated I -wire 2.992 14,367.2 6,798.6 68.41 PACKER BAKER PREMIER PACKER 2.870 14,414.5 6,815.9 68.74 Blast Ring PESI BLAST RING (1) 2.992 14,495.3 6,844.5 70.19 SLEEVE BAKER CMD SLIDING SLEEVE - OPEN 2.812 14,508.9 6,849.1 70.56 NIPPLE HES "XN" LANDING NIPPLE 2.75" NO GO 2.750 14,814.7 6,936.4 76.68 1 SEAL ASSY I BAKER GBH-22 LOCATOR SEAL ASSEMBLY (10.39'to 4.53" OD locator) 2.970 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft ) Type Com 14,429.0 14,452.0 6,821.2 6,829.4 Nechelik, CD3- 127 3/13/2013 5.0 IPERF PERF KUPARUK SAND f/ 14429' t/ 14452' 15,430.0 15,450.0 6,981.1 6,980.9 2/1/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 15,495.0 15,499.0 6,980.9 6,980.9 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT 16,320.0 16,340.0 6,996.2 6,996.6 Nechelik, CD3- 127 2/1/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 16,390.0 16,395.0 6,997.8 6,998.0 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT 17,289.0 17,294.0 7,001.5 7,001.5 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT 18,189.0 18,194.0 7,003.4 7,003.5 Nechelik, CD3- 127 3/29/2013 5.0 PERFP FRAC PORT wNs PROD WELLNAME CD3-127 WELLBORE CD3-127 ConocoPhillips Alaska, Inc. '' 1 HORIZONTAL, CD3-127, 4/7/2021 11:53:49 AM Perforations & Slots Vertical schematic (actual) Shot Dens HANGER; 31.3^ Top (TVD) Btm (TVD) (shots/ft Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Com 18,400.0 18,420.0 7,008.2 7,008.7 Nechelik, CD3- 1/31/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - h 127 2006 PJ Omega HMX - 7.3 � gm. 0.22" Ent hole - 21.8" Penetration CONDUCTOR; 36.0-114.0 -A - I I I I I I I I 19,087.0 19,092.0 7,027.E 7,027.5 Nechelik, CD3- 3/29/2013 5.0 PERFP FRAC PORT 1 127 1 I SAFETY VLV; 2,152.1 Stimulation Intervals Interva I Numbe Proppant Proppant Vol Clean Vol Slurry r Type Subtype Start Date Top (ftKB) Btm (ftKB) Designed (Ib) Total (Ib) Total (bbl) Total (bbl) SURFACE; 35.9-3,239.2— L 1 FRAC 3/29/2013 15,495.0 15,499.0 0.0 0.00 0.00 2 FRAC 3/29/2013 16,390.0 16,395.0 0.0 0.00 0.00 3 FRAC 3/29/2013 19,087.0 19,092.0 0.0 0.00 0.00 4 FRAC 1 13/29/2013 1 17,289.01 17,293.01 i0.01 0.00 0.00 GAS LIFT; 5,792.1 5 1 FRAC 1 13/29/2013 1 18,189.01 18,194.01 1001 0.00 0.00 Mandrel Inserts St ati I ? on N I Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Sery Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 5,792.1 3,404.1 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,674.0 4/1/2013 GAS LIFT; 11,801.1 2 11,801.1 5,610.5 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 4/1/2013 3 14,094.7 6,690.9 Camco KBMG 1 GAS LIFT OV BK 0.313 0.0 4/1/2013 41 14,393.61 6,808.3 1 Camco 1 KBMG 1 1 GAS LIFT IDMY I BK-5 1 0.0001 0.0 3/17/2013 GAS LIFT; 14,094.7 Notes: General & Safety End Date Annotation 3/19/2013 NOTE: FINISHED DRILLING & COMPLETION GAUGE; 14,342.2 1�4 PACKER; 14,367.2 GAS LIFT; 14,393.6 IPERF; 14,429.0-14,452.0-. SLEEVE; 14,495.3 NIPPLE; 14,508.9 SEAL ASSY; 14,814.7 C INTERMEDIATE; 34.3-14,969.E APERF; 15,430.0-15,450.0 FRAC; 15,495.0 PERFP; 15,495.0-15,499.0 m APERF; 16,320.0-16,340.0 PERFP; 16,390.0-16395.0 FRAC; 16:390.0� FRAC; 17,289.0 PERFP; 17,289.0-17,294.01 ll PERFP; 18,189.0-18,194.0 FRAC; 18,189.0�� APERF; 18,400.0-18,420.0 PERFP; 19,087.0-19,092.0 FRAC; 19,087.0�� ( ) LINER; 14,790.2-20,023.0 ----------- Al STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS sYSamantha Carlisle at8:48am, Mar 02,2021 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate --'J Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibition Treatment 0 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ Stratigraphic ❑ Service ❑ 211-005 3. Address: P.O. Box 100360, Anchorage, Alaska 99510 6. API Number: 50-103-20634-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, ADL 025538, ADL 025526 CRU CD3-127 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Alpine N/A Colville River Field/ iefd enk 11. Present Well Condition Summary: Total Depth measured 20,033 feet Plugs measured None feet true vertical 7,049 feet Junk measured None feet Effective Depth measured 20,033 feet Packer measured 14367, 14790 feet true vertical 7,049 feet true vertical 6799, 6931 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114 114 Surface 3203' 10.75" 3239 2454 Intermediate 14936' 7.625" 14970 6967 Liner 5233' 3.5" 20023 7049 Perforation depth Measured depth 14429-19092' feet Perforation depth Measured depth 15430-15450', 16320-16340', (re-perf) 18400-18420' feet True Vertical depth 6821-7028' feet True Vertical depth 6981-6981', 6996-6997', 7008-7009' feet Tubing (size, grade, measured and true vertical depth) 3.5"X4.5" L-80 14826' MD 6,939' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Production Packer 14367' MD 6799' TVD Packer: Baker ZXP Liner Top Packer 14790' MD 6931' TVD SSSV- Camco TRMAXX-5E 2152' MD 2,001' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 14790-20023' MD Treatment descriptions including volumes used and final pressure: See Attachment 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 460 1450 584 1330 260 Subsequent to operation: 352 1400 504 1306 254 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑r Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑.. Gas ❑ WDSPL❑ Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 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 Authorized Name: Mark Shulman Contact Name: Mark Shulman Authorized Title: Sr. Production Engineer Digitally signed by Mark Shulman Contact Email: mark.shulman@cop.com Mark Shulman Date: 2021.03.01 15:13:16 -09'00' Contact Phone: (907) 263-3782 Authorized Signature with date: Senior Engineer:VTL 3/3 21 1 ISenior Res. Engineer: DSR-3/2/21 RBDMS HEW 3/2/2021 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations CD3-127 Summary of Operations / Perforations DTTMSTART JOBTYP SUMMARYOPS 01/30/21 ZONAL MIRU. PERFORM WEEKLY BOP TEST. RIH WITH MOTOR AND MILL. TAG UP ON FRAC PORT @ 17289' RKB. WORK THROUGH FRAC PORT DOWN TO FINAL TAG @ 19,069' CTMD. PULL UP TO 14,000' CTMD, PULLED HEAVY OFF BOTTOM ALL THE WAY UP TO DEPTH. LOAD WELL WITH S/D WITH 776. RBIH FOR DRY TAG AND TAGGED FRAC PORT AGAIN. WORKED THROUGH FRAC PORT TO FINAL TAG @ 19,058' CTMD. POOH. JOB IN PROGRESS. 01/31/21 ZONAL CONTINUE POOH AFTER MOTOR/MILL CLEANOUT. STANDBY ON WEATHER HOLD FOR 5 HOURS UNTIL WARMED UP. RIH WITH PERF GUN #1. PERF INTERVAL FROM 18,400' - 18,420' RKB. RIH WITH PERF GUN #2. JOB IN PROGRESS 02/01/21 ZONAL RIH WITH PERF GUN #2. PERF INTERVAL FROM 16,320' - 16340' RKB AND INTERVAL FROM 15,430'-15,450' RKB (2" POWERJET OMEGA, 6 SPF, 60 DEG PHASING). RDMO TO CD3-316. 02/02/21 SCALE SQUEEZE INHIBITION 10 BBLS CRUDE FOR FREEZE PROTECT FLOW LINE 190 BBLS ARCTIC DIESEL/M209/WAW5206 190 BBLS 70/30 EG & SCW3001 1802BBL DEAD OIL/M209 OVER FLUSH (JOB COMPLETE) CD3-127 Scale Inhibition Treatment Scale Inhibitor Squeeze Job pumped from 0800 hrs to 1900 hrs on 2/2/21. LRS = Little Red Services ACF = Alpine Central Facility • Initial pressure TBG/IA/OA — 450/1229/23 • LRS and ACF pumped 190 bbls WAW5206/Diesel pre -flush at 0.5 - 1 bpm • LRS pumped 190 bbls Seawater/SCW3001 scale inhibitor main treatment at 0.5-1 bpm • ACF pumped 1802 bbls dead oil/M209 over -flush at 4.5 - 5 bpm, TBG/IA/OA — 464/1220/43 Interval treated: 14790' — 20023' MD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 14790' MD, 6930' TVD SSSV: TRMAXX-5E, 2152' MD, 2001' TVD P,Fj9-Fft--h4, WN5 PROD WELLNAME CD3-127 WELLBORE CO3.127 Conoc6Philfips � l Alaska, Inc. Cnc.Sl� Well Attributes Niax Angle & MD TD ax & Field Neme Weilhom RPDIIIMI YVellbore Sratue FI R N N IK 1 PR 1 2.1 f MD I - Act 15,327.87 20m, Bon lrtKa) Comment H251 W(A) gate SSSV: TRDP Annotelinn LasI WO, I End Data I KB-G d CM R1g 36:10 319I2013 Releeee Date NORLKDNTAL, CO3,127, 2r4R02110:M 11 AM Last Tag VankM schanwlk (W-l) Annnlatien Depth {SIKBI End Data Weabare Loot Mod By K WAR.313 LA r E 9 I I N 4Penetratlon N 1 Last Tag; SLM 14,700,U 3l31aD13 CD3-127 0560r1 Last Rev Reason Annolatlun End Dole Wellbore Laol Mod ey CONDUCTOR: 30.0.114.0 sVFTY VLV; 2,1521 auRFACE; M 9L .2"-2 OAS L-. 5.7 2 1 41 GAs LIFT; 11,801-1 4 GAS LIFT; t4,094.7 GAUGF- 14.42.2 PACXJM 14,367.2 cn9 LW T is s93s IPERF; 14,429.0-14,4520- SLEEVE• 14,495.3 NLPPLF- T4,508.II sEA4 A98Y; ts,814] l t INTERMEDIATE; 34.3-14,969.6 APFAF; 16,490.o.15AWz FRAC; 15.495.0 PERFP; 15,406.0.1SA90.0 APERF; 1a,a2D.a1a s4n.D PERFP; 18,390.0.10.393.0 FRAC, ISM 0� FRAC, 1T,Z19.0 PERFP; PERRFP; la,169.0.18,194.D FRAC; 19,189.aL� 4- APERF; 10,s00.0•t0A20.0 Iiiiiiiap PERFP; 10,057.0-19A92.0L4 FRAC, tB4O87.9 I ULER; 14,790.24D,025.o Rev Reason: Add Pe is 21112021 CP3-127 rpgerba Casing Strings Casing Deseripdpn CONDUCTOR 0O (In} 16 ID IMP 14.69 rap JnKBI 36.0 Set Depth [ttKet 114.0 Bel Depth (TVD)... 114.0 W11Len (I... 109.00 Grade H-40 rap Threa4 WELDED Caoing Description SURFACE 00 (M) 10314 IO lint 0.95 Tap Irtrlsl 35.9 Set 0eplh (ftKet 3,239.2 Sel Depth (TVD)... 2,453.8 Wul-en (I... 45.50 Grade LAO Tap Thread BTCM Casing D"crip9on INTERMEDIATE 00(1e) 75G 10 Pnl 6.87 Top (nKa) 3U Set Depth (nKBI 14,96a6 Sol Depth ITVD)... 6,967,6 WVLen (I... 29.70 Grade L•80 Top Thmad BTCM Casing Description LINER on 3112 10 lint 2.99 Top (ftKB) 14.790.2 50 Depth (11KBt 20.023.0 Sel Depth (M)... 7.048.5 WVLW 9.30 p... %rada L-80 Top Tnmad SLHT Liner Details Top (RKO) TOP ITVD) (Idea) TOP IMI (') nem Des Cam NomMal ID im) 14,790.2 6.93D-6 76.11 PACKER BAKER ZXP LINER TOP PACKER 4.950 14,W8.9 6,935-0 76.64 NIPPLE BAKER RS NIPPLE 4.880 14.811.8 6,935.7 76.61 MANGER BAKER FLEX LOCK LINER HANGER 4.830 14.821.4 6.937.9 76.83 SBE Baker 80-40 Seat Bore Extension P x P 4.000 15.028.5 6.976.0 83.24 Swell Packer SWELL PACKER OD 6.38" vd 5' Seating eleme it 2.992 15.075.5 6,980A 84.91 Swell Packer SWELL PACKER OD 6.38" w15' Seating element 2,992 15,495.0 6.9mo 89.98 FRAC PORT 3-112" SLHT Ball Actuated Sleeve (2.W seal IO) 2.125' BALL ON SEAT '"'MILLED OUT TO 2.66- ID"' 2,680 15.941.5 6.987.5 88.92 Swell Packer SWELL PACKER OD 6.38" wl 5' Seating element 2.992 1090.6 6,997.9 88.56 FRAC PORT 31I2" SLHT Ball Actuated Sleeve (1.875" seal iO) 2A' BALL ON SEAT "'MILLED OUT TO 2.68- ID"' 2.680 16.838.3 6,998.5 90.39 Swell Packer SWELL PACKER OD 6.38" w! 5' Sealing element 2.992 17289.1 7,001,5 89.76 FRAC PORT 3-112' SLHT Ball Actuated Sleeve (1,75'seat ID) 1.87S"'BALL ON SEAT "'M ILLED MT TO 2.69' I D"' 2.680 17,739.2 8,996.9 90.10 Swell packer SWELL PACKER OD 6.38" w15' Sealing element 2,W2 18,189.7 7.003.5 88.91 FRAC PORT 3-In' SLKT Ball Actuated Sleeve (1,625" seat ID) 1.75' BALL ON SEAT ""MILLED OUT TO 2,W ID"' 2,680 18'em.1 7.012.7 88.65 Swell Packer SWELL PACKER OD 6.38" w1 5' Sealing element 2.992 19.087.3 7.027.6 90.87 FRAC PORT 3112- S L HT Ball Actuated Sleeve (1.50-seal 10) 1.625" BALL ON SEAT M I LLED OUT TO 2.66' I D"' 2.680 19,536.3 7,033.7 89.45 Swell Packer SWELL PACKER OD 6.38" w1 5' Sealing element 2.992 19,960.0 7,047.3 88.75 SLEEVE BAKER 11 SLEEVE 2.696 19.982-9 7,047-8 88.88 1 VALVE BAKER WELLBORE ISOLATION VALVE 0-000 Tubing Strings Tubing Daacrlptlon TUBING 3112 4.5x3.5@1( -- Me... ID lin] 2.99 Top (11Ket 31.3 Sal* M- Set 14.825.6 6.93B.9 Daplh IWO) [.., m {mmt 9.30 Gnde Top LSO EUE Conmcdon Completion Details Top MKBt Top [TYDt itti(SI Top Inc ["I ilem Dee Cam nomlml ID (In) 31.3 31.3 ROD HANGER FMC TUBING HANGER 3.900 107.2 107.2 0.40 XO Reducing CROSSOVER 4.1121 IST-m box x 3112- EUE-m 3.500 2,152.1 2.001.5 48.SB SAFETY VLV TRMAXX-5E SSSV wl 2.812- "X" profile w1 V4" c ntrnl line (5.179' OD) 2.812 14,342.2 6,789.4 67.99 GAUGE SLB BHP Guage, 3112" NOPG single sub. EUE pin x pin. W encapsulated I-wlre 2.992 14,367.2 6,7%.6 68.41 PACKER BAKER PREMIER PACKER 2,870 14,414.5 6,815.9 68.7d Blast Ring PESI BLAST RING (1) 2,992 14,495.3 6,844,5 7D.19 SLEEVE BAKER CMD SLIDING SLEEVE - OPEN 2.812 f4,508.9 6,849.1 70.56 NIPPLE HES"XWLANDINGNIPPLE 2,75-NOGO 2.750 14,814.7 6,936.4 76.68 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY (10.39' 10 4.537 OD locator) 2.970 Perforations & Slots Tap (nKB) Btm (KKR) Top (TVD1 (1IKB) Btm 1NDi (f[KB) Driked Pons Data snot Dens fah -um i Type Cam 14,429.0 14.452.0 6.821.2 6.MA NecheFk, CO3 127 3/13/2013 5.0 IPERF PERT 14429' KUPARUK SAND V V 14452' 15,4W,O 15,450.0 6,9811 6,9w,9 2f1/2Ly11 5.0 APEFiF 2Yof 26 00gm. Wes, 5SPF,60deg - PJ Omega HMX • 7.3 0.22' Ent hole - 21.8' 15,495.0 15.499.0 6,980.9 6,980A Nechelik, CD3 127 3129/2013 5.0 PERFP FRAC PORT 16,320.0 16,340.0 6.995.2 6,9W,6 NeoheRk, CO3- 127 21T12021 6.0 APERF Arcf 2006 gm. Penehalion holes, 6 5PF, 60 deg - PJ Omega HMX • 7.3 0.22" Ent hole - 21.8' 16,390.0 16,395.0 6,997.8 6,598.0 Nechalik, CD3 127 3l2912{713 5.0 PERFP FRAC PORT 17,289.0 17,294.0 7.001.5 7,001.5 Nachatik, CD3 127 312912013 5.0 PERFP FRAC PORT 1B,189.0 18,194.0 7,UW,4 j 7,003.5 j NOC"Nk,CO3- 127 3QW2013 i 5-0 PERFP FRAC PORT WNS PROD WELLNAME CO3-127 WELLBORE CD3-127 ,1.' ConocoPhillips Alaska. Inc. NORIZDNrAL, CO3.127. 2WM 110:22: 13 AM Perforations & Slats vedlW erremeac lacking Top ITVDI B1m ITVDI Shd Dens (ahclsRt HANGER; 31.3 Top IRKS) BImMKBI IRKBI IRKS] Llnked Zone Date 1 Type o m 18,400.0 18,420.0 7.0082 7.008.7 Nechelik, CD3- 1131r2021 6.0 APERF & of holes, 6 SPF. 60 deg - 127 2DO6 PJ Omega HMx - 7.3 gm. 0.227 EnI hole - 21.8- Penetral lon CONDUCTOR; 38..0-114.0 - 19.087.0 19.092-0 7,G27,6 7.027.5 Nechelik, CD3- 3l2912013 5.0 PERFP FRAC PORT 1 127 SAFETY VLV; 2.152.1 Frac Summary Start Data PrappaM Dealgned IIhI Proppad In Fonmtiw (M} 329 2013 Stp a BMrt Bale Top Depth (RKB) Btrn j11KBl Drik to Fluld Syarem Vol Clean (hW) Vd Slurry lhhlJ 1 3r29r101 1 15,495.0 15,499.0 SURFACE. 85.g-3,238.2— Start fate Proppara Dealgned IIh[ Pmppcm In F—Ilm {m} 31912013 Sty a Start Darc Top Depth [RKB} Stm (SKS[ Lora, to Role Sysoem VW Clean (1,W] va Slurry 16e11 1 3129r2013 16,390.0 16,385.0 Stan Date Prapparlt Dtflgned 11al "pant In Fom slim [I➢} GAS LIFT; 5.792.1 V2902013 Sop N Short Dale Top Depth (IBGS} Stm MKSI Ddk [a Fluld 9yuem Vol clean (au] VolSluryy l➢alI I 3129/2013 19,087.0 19,092.0 SGd Date Proppam Dealgned 111,1 Prnppard In Fnmrarlon (h1t} i , 3r2912013 Sty IY Slart Date lop Depth Sort(AKBI Unk m Fluld Syatem Vm Clean (bwI Yd Slurry lhhlJ I' GAS LIFT; 11.601.+ 1 3r29120t3 289.0 17,293.0 start Data Proppam Dealgned 1101 Proppam In Fonnellon [I➢] 31M013 Stg F Slart Dale Top Depth (RKB} Stm (Mll) Dnk to Fluid Syalem VW Clean (aw) Val Slum/ I➢➢II 1 3/213 18.189.0 18,19a.0 9/20I Gice Urr; 14.0W.7 Mandrel Inserts 5+ au GAl1GE; 14,3422 N Top tMKBI Top JTYDI JrtKBI Make Nude) 06{ar} $ery Valve Type Latch Type Port $Iae (In) TRO Run {pall Run Date Co. 1 5,792.1 3.404.1 Campo KBMG i GASUFT GLV BK 0,166 1.674.0 411r2013 PACKER; 14,367.2 2 11,801.1 5,610.5 Campo KBMG i GASLIFT GLV SK 0-188 1.730.0 411r2013 GAS LIFE; 14 36a 6 3 14,094.7 6,690.9 Camm KBMG 1 GAS LIFT CV BK 0.313 0.0 411F2013 A 14.393.6 6.808.3 Campo KBMG 7 JOAS LIFT DMY BK-5 O.ODO D.0 3117/2013 IPERF; Notes: General & Safety End Dale Annotation 3119/2013 NOTE: FINISHED DRILLING& COMPLETION SLEEVE; 14,496.3 NIPPLE: 14.500.9 SEAL ASSY, 14.814 7 INTERMEDrATE, 34.114,6th96 APERF; 15 a30.0.16,i50.0 FRAC; 15,49a.0 PERFP; 15,495.0• a.499.0 5 APERF; 16,320.0.17,3400 PERFP: 16.3a0.P1a,3e6.p FRAC; 16.390.0�� FRAC; 11.11 PERFP; 17,266.0.17194.0_ •: PERFP: 16.186.D 1 a, 16e 0 FRAC; 1H,tBB.o1� APERF; 18,400.0. 10.4200 PERFP; 1a067.0-1G,082.0 FRAC; 19,067.0L� LINER; 14,790.2-20,023A I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations 0 Fracture Stimulate Ll Pull Tubing Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment ❑' 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ Stratigmphic ❑ Service ❑ 211-005 3. Address: PO Box 100360 6. API Number: Anchorage, AK 99510 50-103-20634-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, 025538, 025526 CD3-127 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 20033 feet Plugs measured None feet true vertical 7049 feet Junk measured None feet Effective Depth measured 20033 feet Packer measured 14367 feet true vertical 7049 feet true vertical 6799 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' °e /� Surface 3203' 10.75" 3239' 2454' RECEIVED Intermediate CE'F7 14936' 7.625" 14970' 6967' Production Liner 5233' 3.5" 20023' 7049' NOV 0 5 2019 Perforation depth Measured depth Perfs from 14429' - 14452', Perf Pups from 15495' - 19092' A®G ^O, (j True Vertical depth Perfs from 6821' - 6829', Perf Pups from 6981' - 7028' Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 14826' MD, 6939' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 14367' MD, 6799' TVD SSSV: TRMAXX-5E, 2152' MD, 2001' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 14970' - 20033' MD Treatment descriptions including volumes used and final pressure: Please see attached Summary 13. Representative Daily Average Production or Injection Data Oil-Bhl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 294 56 408 1198 240 Subsequent to operation: 428 73 568 1 1260 254 14. Attachments (required per 20 AAc 25.070, 25.071. a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development ❑� Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 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 Authorized Name: Ka Ile Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Engineer Contact Email: Kaylle.B.Plunkett(cbcop.com oProduction q Authorized Signature: Date: I I� t-I — I + Contact Phone: 265-6450 V71- Form 10-404 Revised 4/2017 i//q�� MM062019 Submit Original Only CD3-127 Scale Inhibition Treatment 10/6/19 Non -Aqueous Scale Inhibitor Squeeze Job pumped from 0930 - 1445 hrs on 10/6/19. LRS = Little Red Services ACF = Alpine Central Facility Initial pressure TBG/IA/OA — 460/1174/41 LRS pumped 90 bbls diesel/WAW5206 preflush at 0.4 bpm, TBG/IA/OA - 0/1135/7 LRS pumped 90 bbls 70/30 EG/water and SCW3001 scale inhibitor treatment at 1.5 bpm, TBG/IA/OA - 0/1117/5 ACF pumped 400 bbls diesel overflush at 0.1-1.2 bpm, TBG/IA/OA - 0/1122/15 Interval treated: 14970' — 20033' MD THE STATE GOVI RNOR SEAN PARNELL i1I1'. T n �T, �, i a� �' _ a> a�l' r d L Gu _G'- G116 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 © 667 Mike Hazen Wells Engineer , ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-127 SCANNED JUL 2 2 2014 Sundry Number: 314-140 Dear Mr. Hazen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner �`� DATED this I � day of March, 2014. Encl. STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM, ON R Yam! '4I E 1V 0 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MAR 0 7 490 1. Type of Request: Abandon r Rug for Redrill (— Perforate New Pool Repair w ell r Change o o r Suspend r Rug Perforations Perforate (" Pull Tubing Time Extension Operational Shutdow n r Re-enter Susp. Well r Stimulate r After casing r Other: r, 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc.. Exploratory r Stratigraphic r Development �, Service r 211-005 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20634-00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r CD3-127 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 372105, 25538, 25526 Colville River Field / Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (fty Effective Depth TVD (ft): Plugs (measured): Junk (measured): 20033 • 7049 20023' 7048'• none none Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 3206' 10.75" 3239' 2453' Intermediate 14935' 7.625" 14970' 6967' Liner 5233' 3.5" 20023' 7048' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14429-14452 6821'-6829' 4.5 x 3.5 L-80 14826 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER MD=14367 TVD=6799 PACKER - BAKER ZXP LINER TOP PACKER MD= 14790 TVD=6930 . SSSV - TRMAXX-5E SSSV MD= 2152 TVD=2001 t 12. Attachments: Description Summary of Proposal r7 13. Well Class after proposed work: Detailed Operations Program j— BOP Sketch r Exploratory r Stratigraphic (� Development r%-o • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/25/2014 Oil r • WINJ r Gas r WDSPL r Suspended r GINJ r WAG (— Abandoned r 16. Verbal Approval: Date: Commission Representative: GSTOR r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Hazen @ 265-1032 Email: Michael.C.Hazen(a)_conocophillips.com Printed Name Mi a Title: Wells Engineer Signature Phone: 265-1032 Date & m4 fZ {,- Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RBDMS MAY 11 2014 Other: Spacing Exception Required? Yes ❑ No 1Z/ Subsequent Form Required: / a — `T a 1 9 APPROVED BY / �I V Approved by:"�/ f COMMISSIONER THE COMMISSION Date:- Approved u i v I r ontns trom the date of approval. Form 10-403 (Revised 10/2012) % ��� 3��IW Submit Form and Attachments in D ilicate CD3-115 CD3-118 ! C D3-117 CD3-124 NIGLIQ 1A •i NIGLIQ 1 ;z C[-127PB1 0 0.125 0,25 0.5 Miles • h......... ....... �t t ••Nr :..........................1................,... ...... •::..r„ Legend `r,....•-••::.... :. <•.. •;::::.••,.... Frac Ports e.; �' „ 1/4 Mile Radius t ; ..- Well Type i ;•,. Well Suspended P+A • Service • • Producer ! • Observation A Injection: SW Injection: SAPW '•t�D3-125PB1 A Injection: PW Injection: MWAG t • ACTIVE, INJ, MG • ACTIVE, INJ, IWAG • ACTIVE, INJ, GAS • ACTIVE, INJ, DG • ACTIVE, INJ, <Null> Disposal Well Survey by PA ALP FIORDKUP . FIORDNECH NANKUP C D3-125 NANUQ QAN D3 7 ConocoPhillips CD3-127 Fracture Radius Evaluation N A CONFIDENTIAL NECHELIK 1 CD3-128 W14WNSFr=-d CSN 2/2612014 C133-127 Sundry Application CD3-127 was first drilled in February of 2011 (PTD 211-005), however, due to issues running the 7-5/8" casing, it was pulled, zonal isolation plugs were set, and the well suspended for future completion of the drilling program (Operational Shutdown Sundry 311-065). During the ice -road season of 2012, ConocoPhillips re-entered the CD3-127 wellbore under Sundry 312-101, set an ECP and laid in a kick off plug for re -drill operations for the winter operations of 2013 (Operational Shut Down Sundry 312-166). CD3-127 was completed in March of 2013. It was drilled as a horizontal producer targeting the Nechelik and Kuparuk formations. In the Nechelik, the well has an 5000' lateral completed with a 3.5" liner with six frac ports and swell packers. The Kuparuk formation is behind the 7 5/8" casing and was perforated before running the selective completion. The - selective completion consists of 3.5" tubing straddling the Kuparuk, a Baker Premier packer above, and a seal -bore stabbed into a Zxp liner top packer below. The Nechelik formation in CD3-127 was hydraulically fractured in March of 2013. This was a six stage treatment and 686,560 pounds of sand were successfully placed. The Kuparuk formation has never produced near expected rates, and it is believed near wellbore damage is the reason for the lack of production. The belief is a small frac into the Kuparuk formation will clean up the near well -bore damage and allow the well to reach forecasted production rates. The proposed frac stimulation will be a single stage job pumped through the production tubing string. Proposed Procedure: Schlumberger Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 1000 F seawater (approx. 2073 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 138 bbl breakdown stage (linear gel) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 25 BPM as quick as possible, pressure permitting. Slowly increase annulus (IA) pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 25 bpm with a maximum expected treating pressure of 4150 psi. Stage 1 • 440 bbl Schlumberger fluid Pad • 120 bbl Schlumberger fluid w/ 1 PPA • 120 bbl Schlumberger fluid w/ 2 PPA • 120 bbl Schlumberger fluid w/ 3 PPA • 150 bbl Schlumberger fluid w/ 4 PPA • 160 bbl Schlumberger fluid w/ 5 PPA • 160 bbl Schlumberger fluid w/ 6 PPA • 180 bbl Schlumberger fluid w/ 7 PPA • Flush with 120 bbl of linear fluid and freeze protect • Total Sand: Approx. 150,935-lb of 16/20 CarboLite Proppant 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). Cement Evaluation of CD3-127 and wells within'/4 mile of CD3-127 CD3-127: 7 -5/8" Casing two stage cement job was pumped on 2/21/2013 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, and was displaced with 10 ppg mud. The plugs were bumped at 950 psi and 200 psi respectively, floats held. Full returns were observed throughout the job. CD3-117: 7 5/8" Casing two stage cement job was pumped on 3/24/2009 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 10 ppg mud. The plugs were bumped on both stages to 2000 psi and floats held. Full returns were observed during the job. CD3-124: 7 5/8" Casing two stage cement job was pumped on 2/23/2010 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 11.3 ppg mud. The plugs were bumped on both stages to 1090 psi and 1600 psi respectively, floats held. Full returns were observed during the job. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a % mile radius or any other nearby well. Stimulation Surface Rig -Up Bleed / Tattle Tale Tank 4crul dwnd Pop -Off Tank mr4 r Z d C d l- J Frac Pump Frac Pump Frac Pump O Y V N U • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. PopdM Tark — Pump Truck Fra- F Limp Frac Purip Fra;; Pump Stimulation Tree Saver OPEN POSITION (PRIOR TO MANDREL INSERTION) WELLHE VAL% CLOScu I WT:T CLOSED POSITION LL INSERTED) IRON MECTION )TE OPERATED ER VALVE JAL OPERATED ER VALVE Q� O- Stinger IRE(. ®VENT f-- VALVE OPEN AND E WELLHEAD VALVES OPEN OUAD PACKOFF ASSEMBLY IN PLACE IN TUBING • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 % tubing and 1.75" down 3 %2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm CD2-01 Frac Model Frac Design 1 stage Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (gal) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Pad 20 YF125ST 600 25.0 0.00 2.0 PPA 20 YF125ST 240 25.0 CarboLite 16/20 2.00 4.0 PPA 20 YF125ST 480 25.0 CarboLite 16/20 4.00 4.0 PPA 20 YF125ST 240 25.0 CarboLite 16/20 4.00 7.0 PPA 20 YF125ST 800 25.0 CarboLite 16/20 7.00 Flush 20 YF125ST/WF125 145 25.0 0.00 YF125ST WF120 CarboLite 16/20 Totals (1stages) 2046 bbl 145 bbl 301,500 I bs Model Results Initial Fracture Top TVD - 7046 ft Initial Fracture Bottom TVD - 7110 ft Propped Fracture Half -Length - 316.2 ft EOJ Hyd Height at Well - 128.5 ft Average Propped Width - 0.486 in • Disclaimer Notice: — This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. 1 ConocoPhillips Alaska. Inc. 31 r CONDUCTOR, 36-114 SAFETY VLV, 2.152 SURFACE, 36-3,239 GAS LIFT, 5,792 GAS LIFT, 11,801 GAS LIFT, 14,095 GAUGE, 14,342 PACKER, 14.367 GAS LIFT, 14,394 IPERF, 14.429-14,452 SLEEVE, 14,495 NIPPLE, 14,509 SEAL ASSY, 14,815 34-14.970 PERFP, 15,495-15,499 FRAC, 15,495 PERFP, 16,390-16,395 FRAC, 16,390 FRAC, 17,289 PERFP, 17,289-17,294 PERFP, 18,189-18.194 FRAC, 18,189 { WNS CD3-127 Well Attributes Max Angle & MD TD Wellbore API/UWI 501032063400 Field Name FIORD NECHELIK Well Status PROD Incl (") 92.11 MD (ftKB) 15,327.97 Act Btm (ftKB) 20,033.0 013 10:52:34 AM Comment SSSV: TRDP I H2S (ppm) I Date Annotation I Last WO: I End Date KB-Grd (ft) 36.30 Rig Release Date 3/19/2013 Annotation Last Tag: SLM Depth (ftKB) I 14,700.0 End Date lAnnotation 3/31/2013 Rev Reason: GLV C/O Last Mod I End Date osborl 4/30/2013 4� i Casing Strings Casing Description CONDUCTOR String 0... 16 String ID ... 14.688 Top (ftKB) 36.0 Set Depth If... 114.0 Set Depth (TVD) ... 114.0 String Wt... 109.00 String ... H40 String Top Third WELDED I Casing Description SURFACE String 0... 10 3/4 String ID ... 9.950 Top (ftKB) 35.9 Set Depth (f... 3,239.2 Set Depth (TVD) ... 2,453.9 String Wt... 45.50 String ... L80 String Top Thrd BTCM Casing Description INTERMEDIATE String 0... 7 5/8 String ID ... 6.875 Top (ftKB) 34.3 Set Depth (f... 14,969.6 Set Depth (TVD) ... 6,966.9 String Wt... 29.70 String ... L-80 String Top Thrd BTCM Casing Description LINER String 0... 31/2 String ID ... 2.992 Top (ftKB) 14,790.2 Set Depth If... 20,023.0 Set Depth (TVD) ... 7,048.5 String Wt... 9.30 String ... L-80 String Top Thrd SLHT Liner Details Top (ftKB) Top Depth (TVD) (ftKB) Top Inc] (") Item Description Comment Nomi... ID (In) 14,790.2 6,930.4 76.20 PACKER BAKER ZXP LINER TOP PACKER 4.950 14,808.9 6,935.0 76.59 NIPPLE BAKER RS NIPPLE 4.880 14,811.8 6,935.7 76.65 HANGER BAKER FLEX LOCK LINER HANGER 4.830 14,821.4 6,937.9 76.85 SBE Baker 80-40 Seal Bore Extension P x P 4.000 15,028.6 6,976.0 83.43 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15,075.5 6,980.4 84.91 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15,495.0 6,980.8 89.95 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (2.00" seat ID) 2.125" BALL ON SEAT 2.000 15,941.5 6,987.9 88.92 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 16,390.6 6,995.6 87.05 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.875" seat ID) 2.0" BALL ON SEAT 1.875 _ 16,838.3 6,998.E 90.45 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 1! 17.289.11 7.001.21 89.751 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.75" seat ID) 1.875" BALL ON SEAT 1.750 19,087.41 7,027.51 90.87 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.50" seat ID) 11.525" BALL ON SEAT 1.500 19,536.3 7,032.9 87.82 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 19,960.0 7,047.3 88.88 SLEEVE BAKER'P'SLEEVE 2.695 1 19,982.9 7,047.8 88.88 VALVE BAKER WELLBORE ISOLATION VALVE 0.000 Tubing Strings Tubing Description TUBING 4.5x3.5@ 107' String 0... 31/2 String ID ... 2.992 Top (ftKB) 31.3 Set Depth If... 14,825.6 Set Depth (TVD) ... 6,938.9 String Wt... 9.30 String ... L80 String Top Thrd EUE Completion Detai Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°) Item Description Comment Noml... ID (in) 31.3 31.3 -0.04 HANGER FMC TUBING HANGER 3.900 107.2 107.2 0.29 XO Reducing CROSSOVER 4-1/2" IBT-m box x 3-1/2" EUE-m 3.500 2,152.1 2,001.4 48.56 SAFETY VLV TRMAXX-5E SSSV w/ 2.812" "X" profile w/ 1/4" control line (5.176" OD) 2.812 14.342.21 6.789.41 68.241 GAUGE SLB BHP Guaae. 3-1/2" NDPG sinole sub. EUE Din x Din, w/ 2.992 14,495.31 6,844.71 71.061 SLEEVE I BAKER CMD SLIDING SLEEVE 14,508.9 6,849.2 71.20 NIPPLE HES "XN" LANDING NIPPLE 2.75" NO GO 14,814.7 6,936.4 76.71 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY (10.39' to 4.53" OC locator) Perforations & Slots Shot Top (TVD) Btm(TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 14,429.0 14,452.0 6,821.1 6,829.4 Nechelik, 3/13/2013 5.0 IPERF PERF KUPARUK SAN[ CD3-127 14452' 15,495.0 15,499.0 6,980.8 6,980.8 Nechelik, 3/29/2013 5.0 PERFP FRAC PORT ' CD3-127 16,390.0 16,395.0 6,995.6 6,995.9 Nechelik, 3/29/2013 5.0 PERFP FRAC PORT CD3-127 17,289.0 17,294.0 7,001.2 7,001.3 Nechelik, 3/29/201 5.0 PERFP FRAC PORT CD3-127 18,189.0 18,194.0 7,003.4 7,003.2 Nechelik, 3/29/201 5.0 PERFP FRAC PORT CD3-127 19,087.0 19,092.0 7,027.5 7,027.5 Nechelik, 3/29/201 5.0 PERFP FRAC PORT CD3-127 0 PERFP, 19,087-19.087 992 FRAC, 19, i ' S,,, N..' Top (ftKB) (TVD) (ftKB) Incl P) Make Model OD (in) I Sent Valve Type Latch Type Size (in) TRO Run I (psi) 1 5,792.1 3,403.5 68.99 Carrico JKBMG I 1 GAS LIFT GLV BK 0.156 1,674.0 2 11,801.2 5,610.5 68.71 Carrico KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 3 14,094.7 6,691.0 66.41 Carrico KBMG 1 GAS LIFT OV BK 0.313 0.0 4 14,393.6 6,808.2 68.59 Carrico KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2.8 LINER, 14,790-20,023 TD (CD3-127), 20,033 WNS CD3-127 ConocoPhillips AI,1—!.In Well Confa: HORIZONTAL - CD3-127 4/30/2013 10 52 34 AM __... Schematic -Actual _.. CONDUCTOR, 36.114 SAFETY VLV, 2,152 SURFACE,- 36-3,239 GAS LIFT, 5,792 GAS LIFT, 11,801 GAS LIFT, 14,095 GAUGE, 14,342 PACKER, 14.367 GAS LIFT, 14.394 IPERF, 14,429-14,452 SLEEVE, 14,495 NIPPLE, 14,509 SEAL ASSY, 14,815 34-14,970 PERFP, 15,495-15,499 FRAC, 15,495 PERFP, 16,390-16,395 FRAC, 16,390 FRAC, 17,289 PERFP, 17,289-17,294 PERFP, 18,189-18,194 FRAC, 18,189 PERFP, 19,087-19.092 FRAC, 19,087 u I KB-Grd (ft) Rig Release Dab 36.30 3/19/2013 Mmulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 15,495.0 15,499.0 6,980.8 6,980.8 FRAC 3/29/2013 NECHILIK FRAC, 6 main stages utilizing Packers Plus StackFRAC system. Each stage placed approximately 113-118k# of 16/20 CarboLite Proppant (1-7 ppa) using 30# crosslink gel at 20-bpm, for a job total of 686,560# sand and 7999-bbl total volume pumped (100% of design). First stage was pumped through Baker'P' Sleeve at 19,960' MD, with subsequent stages initiated by dropping frac balls (1.625" - 2.125", in 0.125" increments) opening specific ports along the horizontal liner. The prop fracture treatment was preceded by a breakdown using 30# linear gel at 20-bpm. (118.1K#) Notes: General & LINER, 120,023 To (CD(CD3.127), 20,033 DATA SUBMITTAL COMPLIANCE REPORT 3/20/2014 Permit to Drill 2110050 Well Name/No. COLVILLE RIV FIORD CD3-127 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20634-00-00 MD 20033 TVD 7049 REQUIRED INFORMATION Completion Date 3/19/2013 Completion Status 1-OIL Current Status 1-OIL UIC No Mud Log No Samples No ✓ DATA INFORMATION Types Electric or Other Logs Run: GR/RES, NEU, DEN, MWD, CCL Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No Rpt o2p$(o LIS Verification Rpt ,2 3VtDirectional Survey ED C Asc a 3 MgDirectional Survey Rpt as�q¢gDirectional Survey ED C Lis 20810 Induction/Resistivity Log 20810 Induction/Resistivity 25 Col Log 20810 Induction/Resistivity 25 Col Log 20810 Induction/Resistivity 25 Col Log 20810 Induction/Resistivity 25 Col ED C Las 22434 See Notes Log 22585 Gamma Ray 25 Col Log 22585 Gamma Ray 25 Col Directional Survey Yes v (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments 3175 15261 Open 3/21/2011 PB1 ' 36 15261 Open 8/24/2011 PB 1 36 15261 Open 8/24/2011 PB 1 • 36 20033 Open 4/3/2013 Directional Survey Report + disc 3175 15261 Open 3/21/2011 PB1 LIS Veri, DTC, GR, NPHI, RPM, NPHI, FCNT, RPS, RPX, RPD, FET, NCNT, DRHO, ROP w/EWG TVD and MD logs in PDF graphics 114 15261 Open 3/21/2011 P61 MD BAT, DGR, EWR, CTN, ALD • 114 15261 Open 3/21/2011 PB1 TVD BAT, DGR, EWR, CTN, ALD► 114 15261 Open 3/21/2011 PB1 MD ROP, DGR, EWR, CTN, ALD 114 15261 Open 3/21/2011 PB1 TVD ROP, DGR, EWR, CTN, ALD. 14050 14390 Case 4/10/2013 Gamma-CCL TCP Correlation + Graphics tiff, las 2453 7048 Open 4/30/2013 TVD DGR Dual Gamma Ray/Gamma Module EWR Electromagnetic Wave Resistivity — Phase 4 ADR Azimuthal Deep Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron 3239 20033 Open 4/30/2013 MD ROP Rate of Penetration DGR Dual Gamma Ray/Gamma Module • EWR Electromagnetic Wave Resistivity — Phase 4 ADR Azimuthal Deep Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron Horizontal Presentation AOGCC Page I of 3 Thursday, March 20, 2014 DATA SUBMITTAL COMPLIANCE REPORT 3/20/2014 Permit to Drill 2110050 Well Name/No. COLVILLE RIV FIORD CD3-127 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20634-00-00 MD 20033 TVD 7049 Completion Date 3/19/2013 Completion Status 1-OIL Current Status 1-OIL UIC No ED C Las 22585 Gamma Ray 3239 20033 Open 4/30/2013 Digital Logs + Graphics cgm, pdf, dlis, las, ver, • emf, tiff ED C 23978 Digital Data 3/10/2014 Electronic File: CD3-127PB1 Definitive Survey • NAD27.pdf ED C 23978 Digital Data 3/10/2014 Electronic File: CD3-127PB1 Definitive Survey . NAD27.txt ED C 23978 Digital Data 3/10/2014 Electronic File: CD3-127PB1 Definitive Survey NAD83.pdf ED C 23978 Digital Data 3/10/2014 Electronic File: CD3-127PB1 Definitive Survey NAD83.txt ED C 23978 Directional Survey 0 0 2110050 COLVILLE RIV FIORD CD3-127 P61 • LOG HEADERS ED C 23979 Digital Data 3/10/2014 Electronic File: CD3-127 - Definitive Survey NAD ' 27.zip ED C 23979 Digital Data 3/10/2014 Electronic File: CD3-127 - Definitive Survey NAD 83.zip ED C 23979 Directional Survey 0 0 2110050 COLVILLE RIV FIORD CD3-127 LOG • HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report 0 Directional / Inclination Data Y Mud Logs, Image Files, Digital Data Y /6) Core Chips Y /CA Production Test Information Y / 1 Mechanical Integrity Test Information Y /a Composite Logs, Image, Data Files&Y Core Photographs Y /QP Geologic Markers/Tops 1' Daily Operations Summary Y� Cuttings Samples Y / lA Laboratory Analyses Y / NA COMPLIANCE HISTORY Completion Date: 3/19/2013 Release Date: 2/1/2011 Description Date Comments AOGCC Page 2 of 3 Thursday, March 20, 2014 DATA SUBMITTAL COMPLIANCE REPORT 3/20/2014 Permit to Drill 2110050 Well Name/No. COLVILLE RIV FIORD CD3-127 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20634-00-00 MD 20033 TVD 7049 Completion Date 3/19/2013 Completion Status 1-0I1- Current Status 1-0I1- UIC No Dt Well Not Compliant - In Requested 2/24/2014 MDG emailed Scott Brusnwick 2/24/2014. Dear Mr. Brunswick. Dt Well Non -Compliance Resolved Comments: Compliance Reviewed By: I am completing the final compliance check for the Colville River Fiord CD3-127/CD3-127PB1 well. As submitted, the form 10-407 "Well Completion Report" is incomplete because it does not include a list of all formations and geologic markers encountered. The purpose of form 10-407 is to provide a concise, two -page summary for AOGCC's well records. Please submit by March 11 a revised copy of form 10-407 that contains the following data: Box 29: A list of all formations and geologic markers encountered and the measured and true vertical depths of each formation and/or geologic marker. Please review AOGCC's reporting requirements in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. They can be accessed on the Internet at: -Statute AS 31.05.030: http://www.legis.state.a k. us/basis/folioproxy.asp?url=http://wwwj n u01.legis.state.a k. us/cgi- bin/folioisa.dll/stattx07/query=31 ! 2E05! 2E030/doc/{t13554}. -Regulations 20 AAC 25.070 and 20 AAC 25.25.071: http://www.legis.state.ak. us/basis/folioproxy.asp?url=http://wwwj n u01.legis.state.a k. us/cgi- bin/folioisa.dll/aac/query=[J UMP:'20+aac+25!2E070']/doc/{@ 1 ]?firsthit If you have any questions, please contact me via email or telephone. Sincerely, Meredith 3/7/2014 Updated 10-407 and list of formations received. Entered into RBDMS on 3/20/2014 by MDG. Date: '3_C9 AOGCC Page 3 of 3 Thursday, March 20, 2014 DATA SUBMITTAL COMPLIANCE REPORT 2/24/2014 Permit to Drill 2110050 Well Name/No. COLVILLE RIV FIORD C133-127 Operator CONOCOPHILLIPS ALASKA INC MD 20033 TVD 7049 Completion Date 3/19/2013 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION API No. 50-103-20634-00-00 UIC No Mud Log No Samples No Directional Survey Yes✓ DATA INFORMATION Types Electric or Other Logs Run: GR/RES, NEU, DEN, MWD, CCL (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments •Log a0g1 U Induction/Resistivity 25 Col 114 15261 Open 3/21/2011 PB1 MD BAT, DGR, EWR, CTN, ALDO ('q 1b • Log 810 Induction/Resistivity 25 Col 114 y525i Open 3/21/2011 PB1 TVD BAT, DGR, EWR, CTN, ALD, • Log 02O610 Induction/Resistivity 25 Col 114 15261 Open 3/21/2011 PB1 MD ROP, DGR, EWR, CTN, ALD* Log v2,0,51V Induction/Resistivity 25 Col 114 6g15� Open 3/21/2011 PB1 TVD PZP, DGR, EWR, CTN, ALD Rpt- Directional Survey 36 15261 Open 8/24/2011 PB 1-ate' 41 44_ = ' 3/ r o / z Y�--- ED C Asc Directional Survey 36 15261 Open 8/24/2011 PB 1 Rpt- Ev XO9)10 LIS Verification 3175 15261 Open 3/21/2011 PB1 Yv� 7, Rpt— Directional Survey 36 20033 Open 4/3/2013 Directional Survey Report + disc - I ��`r �.� u" • ED C Lis 20810 Induction/Resistivity 3175 15261 Open 3/21/2011 PB1 LIS Veri, DTC, GR, NPHI, RPM, NPHI, FCNT, RPS, RPX, RPD, FET, NCNT, DRHO, ROP w/EWG TVD and MD logs in PDF graphics oo ED C Las 22434 See Notes 14050 14390 Case 4/10/2013 Gamma-CCL TCP Correlation + Graphics tiff, las 0 Log 22585 Gamma Ray 25 Col 2453 7048 Open 4/30/2013 TVD DGR Dual Gamma Ray/Gamma Module EWR Electromagnetic Wave Resistivity - Phase 4 ADR Azimuthal Deep Resistivity ALD Azimuthal Lithodensity Log CTN Compensated Thermal Neutron 22585 Gamma Ray 25 Col 3239 20033 Open 4/30/2013 MD ROP Rate of Penetration 1 DGR Dual Gamma Ray/Gamma Module EWR Electromagnetic Wave Resistivity - Phase 4 • ADR Azimuthal Deep Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron Horizontal Presentation AOGCC Page 1 of 2 Monday, February 24, 2014 DATA SUBMITTAL COMPLIANCE REPORT 2/24/2014 Permit to Drill 2110050 Well Name/No. COLVILLE RIV FIORD CD3-127 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20634-00-00 MD 20033 TVD 7049 Completion Date 3/19/2013 Completion Status 1-OIL Current Status 1-OIL UIC No v ED C Las 22585 Gamma Ray 3239 20033 Open 4/30/2013 Digital Logs + Graphics cgm, pdf, dlis, las, ver, emf, tiff Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Y Directional / Inclination Data Mud Logs, Image Files, Digital Data Y / 1�A Core Chips Y Production Test Information Y Mechanical Integrity Test Information Y NA Composite Logs, Image, Data Files Y Core Photographs Y /iD Geologic Markers/Tops Y Daily Operations Summary Cuttings Samples Y� Laboratory Analyses Y /® COMPLIANCE HISTORY Completion Date: 3/19/2013 Release Date: 2/1/2011 Description Date Comments Comments: Compliance Reviewed By: Date: AOGCC Page 2 of 2 Monday, February 24, 2014 DATA SUBMITTAL COMPLIANCE REPORT 10/21/2013 Permit to Drill 2110050 Well Name/No. COLVILLE RIV FIORD CD3-127 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20634-00-00 MD 20033 TVD 7049 Completion Date 3/19/2013 Completion Status 1-OIL Current Status 1-OIL UIC No REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/RES, NEU, DEN, MWD, CCL Well Log Information: Log/ Electr Data Digital Dataset Type MQd/Frmt Number Name Log Induction/Resistivity Log ✓ Induction/Resistivity Log J Induction/Resistivity Log Induction/Resistivity Rpt irectional Survey / ED G Asc Directional Survey Rpt ✓ LIS Verification Rpt eibD�,rectional Survey ED C Lis //20810 Induction/Resistivity ED C Las /22434 See Notes Log L,_ 22585 Gamma Ray V Log 22585 Gamma Ray Samples No Directional (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval Start Stop OH / CH Received Comments 25 Col 114 15261 Open 3/21/2011 _ PB1 MD BAT, DGR, EWR, CTN, ALD 25 Col 114 15261 Open 3/21/2011 PB1 TVD BAT, DGR, EWR, CTN, ALD 25 Col 114 15261 Open 3/21/2011 PB1 MD ROP, DGR, EWR, CTN, ALD 25 Col 114 15261 Open 3/21/2011 PB1 TVD ROP, DGR, EWR, CTN, ALD 36 15261 Open 8/24/2011 PB 1 36 15261 Open 8/24/2011 PB 1 3175 15261 Open 3/21/2011 PB1 36 20033 Open 4/3/2013 Directional Survey Report + disc 3175 15261 Open 3/21/2011 PB1 LIS Veri, DTC, GR, NPHI, RPM, NPHI, FCNT, RPS, RPX, RPD, FET, NCNT, DRHO, ROP w/EWG TVD and MD logs in PDF graphics 14050 14390 Case 4/10/2013 Gamma-CCL TCP Correlation + Graphics tiff, las 25 Col 2453 7048 Open 4/30/2013 TVD DGR Dual Gamma Ray/Gamma Module EWR Electromagnetic Wave Resistivity — Phase 4 ADR Azimuthal Deep Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron 25 Col 3239 20033 Open 4/30/2013 MD ROP Rate of Penetration DGR Dual Gamma Ray/Gamma Module EWR Electromagnetic Wave Resistivity — Phase 4 ADR Azimuthal Deep Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron Horizontal Presentation AOGCC Page 1 of 2 Monday, October 21, 2013 DATA SUBMITTAL COMPLIANCE REPORT 10121 /2013 Permit to Drill 2110050 Well Name/No. COLVILLE RIV FIORD CD3-127 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20634-00-00 MD 20033 Tvn 7n49 Cmmnletinn Bate 3/1Q/2R13 Cmmnlptinn Status 1-0II Currpnt Status 1-011 111C Nn ED C Las 2585 Gamma Ray 3239 20033 Open 4/30/2013 Digital Logs + Graphics cgm, pdf, dlis, Ias, ver, emf, tiff Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Y� Directional / Inclination Data V Mud Logs, Image Files, Digital Data YQ , Core Chips Y / p ) Production Test Information Y / Mechanical Integrity Test Information Y Composite Logs, Image, Data Files 1 Core Photographs Y /t% Geologic Markers/Tops Y/oq Daily Operations Summary OY Cuttings Samples Y Laboratory Analyses Y ACA COMPLIANCE HISTORY Completion Date: 3/19/2013 Release Date: 2/1/2011 Description Date Comments Comments: 1f e� of: �q \ ill - �tiZ� \j�t�.r7iL�o.�it�f iS ��►wv+.},��"�'t �'r'w�'t �t'�-t✓ v` c Gc V.l ��ine{ CV �.yj�l� L � V '� d% �� i��.1 � � c: G ��(.�t. � 1 � lJr / /�]�'�.� Compliance Reviewed By: Date: 4 C ),tAjbC3_ AOGCC Page 2 of 2 Monday, October 21, 2013 G.L. Alvord Alaska Drilling Manager Drilling & Wells ConocoPhillips March 6, 2014 AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Subject: Revised Completion Report for CD3-127 and CD3-127PB1 Dear Commissioner: Attached for your review is the revised completion report for CD3-127 and CD3- 127PB1. Corrections to the original completion report include additional data in box 29. This package should be added to the data we already sent with the original completion report which includes the final directional survey, daily operations summary and a schematic. If you have any questions, please feel free to call me at anytime. Sincerely, lV-.-tie G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/SB/skad RECEIVED STATE OF ALASKA MAR 07 201/; ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN6QM 1a. Well Status: Oil a. Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: 1b. Well Class: Development Q ► Exploratory ❑ Service ❑ StratigraphicTest ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: March 19, 2013 ✓ 12. Permit to Drill Number: 211-005 / 4 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 11, 2011 • 13. API Number: 50-103-20634-00 / 50-103-20634-70 4a. Location of Well (Governmental Section): Surface: 1257' FSL, 1186' FEL, Sec. 5, T12N, R5E, LIM Top of Productive Horizon: Kuparuk C: 1833' FNL, 1774' FEL, Sec. 12, T12N, R4E, LIM Nechelik: 2310' FNL, 1801' FEL, Sec. 12, T12N, R4E, LIM Total Depth: 1245' FNL, 945' FWL, Sec. 18, T12N, R5E, LIM 7. Date TO Reached: March 8, 2013 14. Well Name and Number: CD3-127 / CD3-127PB1 8. KB (ft above MSL): 49' RKB GL (ft above MSL): 12.6' AMSL ; 15. Field/Pool(s): Colville River Field Fiord Oil Pool - 9. Plug Back Depth (MD +TVD): 20023' MD / 7048' TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 387857 y- 6003756 Zone-4 TPI: x- 377172 y- 6000834 Zone-4 Total Depth: x- 379815 y- 5996099 Zone-4 10. Total Depth (MD + TVD): % 20033' MD / 7049' TVD 16. Property Designation: ADL 372105, 25538, 25526 11. SSSV Depth (MD + TVD): SSSV @ 2152' MD / 2001' TVD ' 17. Land Use Permit: LAS2112 18. Directional Survey: Yes ID ` No ❑ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: 1574' MD / 1556' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res, Neutron, Density, MWD, CCL 22. Re-drill/Lateral Top Window MD/TVD 3039' MD / 2384' TVD 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 91.5# A-53 36' 114' 36' 114' 42" 15 cu yds AS III 10.75" 45.5# L-80 36' 3239' 36' 2453' 13.5" 445 sx Class G, 280 sx Class G 7.625" 29.7# L-80 34' 14970' 34' 6967' 9.875" 447 sx Alpine Intermediate, 286 sx Class G 3.5" 9.3# L-80 14790' 20023' 6930' 7048' 6.125" liner 24. Open to production or injection? Yes No If Yes, list each Interval open (tdD+TVD of Top & Bottom; Perforation Size and Number): 14429'-14452' MD 6821'-6829' TVD 5spf frac ports for perfs from: 15495'-15490' MD 6981'-6981' TVD 16390'-16395' MD 6996'-6996' TVD Ms7t ;ea 17289'-17294' MD 7001'-7001' TVD (:', f 18189'-18194' MD 7003'-7003' TVD= 19087'-19092' MD 7028'-7027' TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5 x 3.5 14826' 14367' MD / 6799' TVD and 14790' MD / 6930' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No Q DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 3039' 472 sx Class G, 202 sx Class G cement plug @ 3327'-3827' 393 sx Class G cement plug @ 7344-7744' 280 sx Class G cement plug @ 13207'-13607' 1259 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on representative well test Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS -OIL RATIO Flow Tubing Press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No ❑✓ ' If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10407 Revised 10/2012 CONTINUED ON REVERSE Submit original only ,49. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top ground surface ground surface Permafrost - Bottom 1574' 1556' needed, and submit detailed test information per 20 AAC 25.071. all formations for CD3-127, see attached spreadsheet N/A CD3-127PB1 total depth 15261' 6978' Formation at total depth: Nechelik and Kuparuk C 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Brunswick @ 263-4249 Email: SCOtt.A.BrunsWickt�D_cOnocOphillips.COnl Printed Name G. L. Alvord Title: Alaska Drilling Manager L �9Signature Phone 265-6120 Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 CD3-127 FmPicks * Well UWI Common Well Nar * Name Depth (feet) Depth [ND] 50103206340(CD3-127 C-30 3298.4219 2475.2307 50103206340(CD3-127 C-20 4234.9907 2852.3088 50103206340(CD3-127 K-3 7033.224 3850.3975 50103206340(CD3-127 K-3 BSL 7427.054 3996.9568 50103206340(CD3-127 K-2 7487.9785 4019.5295 50103206340(CD3-127 K-2_BSL 7754.3345 4118.467 50103206340(CD3-127 ALB_97 11062.107 5339.015 50103206340(CD3-127 ALB _96_work _dgk 12265.184 5799.046 50103206340(CD3-127 CCS_shale_above_HRZ 13672.534 6512.637 50103206340(CD3-127 CCS_shale_above_HRZ_bas 13722.6875 6536.182 50103206340(CD3-127 HRZ 13899.422 6612.8975 50103206340(CD3-127 HRZ_BASE 14115.282 6699.185 50103206340(CD3-127 K-1 14252.701 6754.3945 50103206340(CD3-127 KUP_D 14330.96 6784.7944 50103206340(CD3-127 KUP_C 14428.056 6820.721 50103206340(CD3-127 LCU 14452.448 6829.5874 50103206340(CD3-127 NUIQ_BASE 14654.722 6894.233 50103206340(CD3-127 NECH 14927.0 6959.961 50103206340(CD3-127 NECH_TRANSGR 14927.0 6959.961 50103206340(CD3-127 NECH_CRSUP 14951.692 6964.4287 50103206340(CD3-127 NECH_TOE 19991.0 7047.914 50103206340(CD3-127 DRILLERS TD 20033.0 7048.735 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, March 12, 2014 8:45 AM To: 'scott.a.brunswick@conocophillips.com' Cc: Davies, Stephen F (DOA) Subject: Reporting Compliance RE: 10-407 Incomplete Form: CD3-127/CD3-127PB1 Importance: High Dear Mr. Brunswick: This is the second email I have sent you regarding the incomplete form 10-407 submitted for CD3-127 and CD3-127 PB1, PTD: 211-005, API 50-103-20634-00-00, completed on 3/19/2013. As submitted, the form 10-407 "Well Completion Report" is incomplete because it does not include a list of all formations and geologic markers encountered in Box 29. The purpose of form 10-407 is to provide a concise, two -page summary for AOGCC's well records. As required by Regulation 20 AAC 25.071(b)(5) the operator shall file with the Commission (5) a list of the geologic markers encountered and the measured and true vertical depths of each marker. An updated form 10-407 is required for CD3-127. Please provide a revised form 10-407 by March 26, 2014. If you have any questions, please contact me. Sincerely, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 From: Guhl, Meredith (DOA sponsored) Sent: Monday, February 24, 2014 3:20 PM To: 'scott.a.brunswick@conocophillips.com' Subject: 10-407 Incomplete Form: CD3-127/CD3-127PB1 Dear Mr. Brunswick: I am completing the final compliance check for the Colville River Fiord CD3-127/CD3-127PB1 well. As submitted, the form 10-407 "Well Completion Report" is incomplete because it does not include a list of all formations and geologic markers encountered. The purpose of form 10-407 is to provide a concise, two -page summary for AOGCC's well records. Please submit by March 11 a revised copy of form 10-407 that contains the following data: Box 29: A list of all formations and geologic markers encountered and the measured and true vertical depths of each formation and/or geologic marker. Please review AOGCC's reporting requirements in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. They can be accessed on the Internet at: • Statute AS 31.05.030: http://www.Ieg is. state.ak.us/basis/folioproxy.asp?url=http://wwwinu01.legis. state. ak.us/cgi- bin/folioisa.dll/stattx07/query=31 !2E05!2E030/doc/ft135541. • Regulations 20 AAC 25.070 and 20 AAC 25.25.071: http://www.Ieg is. state.ak.us/basis/folioproxy.asp?url=http://wwwinu01.legis.state. ak.us/cgi- bin/folioisa.dll/aac/query=iJUMP:'20+aac+25!2E070'1/doc/f(aD-1 Pfirsthit If you have any questions, please contact me via email or telephone. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 2 Guhl, Meredith D (DOA) From: Guhl, Meredith (DOA sponsored) Sent: Monday, February 24, 2014 3:20 PM To:'scott.a.brunswick@conocophillips.com' Subject: 10-407 Incomplete Form: CD3-127/CD3-127PB1 Dear Mr. Brunswick: I am completing the final compliance check for the Colville River Fiord CD3-127/CD3-127PB1 well. As submitted, the form 10-407 "Well Completion Report" is incomplete because it does not include a list of all formations and geologic markers encountered. The purpose of form 10-407 is to provide a concise, two -page summary for AOGCC's well records. Please submit by March 11 a revised copy of form 10-407 that contains the following data: Box 29: A list of all formations and geologic markers encountered and the measured and true vertical depths of each formation and/or geologic marker. Please review AOGCC's reporting requirements in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. They can be accessed on the Internet at: • Statute AS 31.05.030: http://www.legis.state.ak.us/basis/folioproxv.asp?url=http://wwwinu01.legis.state. ak.us/cgi- bin/folioisa.dll/stattx07/guerv=31 !2EO5!2EO30/doc/ft135541. • Regulations 20 AAC 25.070 and 20 AAC 25.25.071: http://www.legis.state.ak.us/basis/folioproxv.asp?url=http://wwwinu01.legis. state. ak.us/cgi- bin/folioisa.dll/aac/query=[JUMP:'20+aac+25!2E070'1/doc/f(@1 Pfirsthit If you have any questions, please contact me via email or telephone. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 30, 2014 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7t' Avenue, Suite 100 Anchorage, AK 99501 SCANNED OCT 2 9 2014 FEB 12 2014 AOGGO c3, � Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRL). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped in the spring of 2007. The corrosion inhibitor/sealant was pumped in the month of January 2014. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field CD1&2 PAD U4LW !!JV�G1i 1`T Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-10 50103203530000 2001710 18" na 18" na 15.3 1/20/2014 CD1-12 50103205010000 2042050 4" na 4" na 4.5 1/20/2014 CD1-14 50103203710000 2010380 4" na 4" na 3.5 1/20/2014 CD1-18 02 501032050000 2042060 4" na 4" na 2.4 1/20/2014 CD1-26 50103203050000 1990880 6" na 6" na 6. 1l20/2014 CD1-35 50103202970000 .1990380 4" na 4" na 3.5 1/20/2014 CD1-45 50103203070000 :1991010 4" na 4" na 3.7 1/20/2014 CD1-48A 50103205920100 2120040 SF na 5" na 2.8 1/20/2014 CD1-49 50103206610000 2121770 12" na 12" na 2.4 1/20/2014 CD2-1 50103205140000 2051180 4" na 4" na 4.6 1/27/2014 CD2-3 50103205120000 2050920 4" na 4" na 4.4 1/27/2014 CD2-5 50103204950000 2040970 4" na 4" na 3.5 1/27/2014 CD2-19 50103204230000 2021120 4" na 4" na 4.9 1/27/2014 CD2-21 50103205040000 .2042450 6" na 6" na 4.2 1/27/2014 CD2-22 50103204210000 2020920 27" na 27" na 11.5 1/27/2014 CD2-32 50103204110000 2020290 4" na 4" na 2.7 1/27/2014 CD2-34 50103203930000 2011910 6" na 6" na 2.7 1/27/2014 CD2-36 50103204470000 2030140 7' 0.95 5" 3/21/07 5.7 1/27/2014 CD2-39 50103203870000 2011600 34" na 11" na 17.9 1/27/2014 CD2-49 50103204010000 2012490 8" na 8" na 5.5 1/27/2014 CD2-52 45 501032090000 2030930 5'7" 0.80 4" 3/21107 3.5 1/27/2014 CD2-54 50103204990000 2041780 8" na 8" na 5.4 1/27/2014 CD2-57 50103204920000 2040720 8" na 8" na 2.7 1/27/2014 CD2-72 50103205460000 2070570 6" na 6" na 4.3 1/27/2014 CD2-73 50103205900000 2081960 4'5" na 4'5" na 24.2 1/27/2014 CD2-465 50103205830000 2081450 19" na 19" na 9.3 1/27/2014 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 113012014 CD3&4 PAD Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft qal CD3-107 50103205290100 2061890 2-10" na 12" na 12.7 1/28/2014 CD3-108 50103205070000 2050330 10" na 10" na 3.2 1/28/2014 CD3-115 50103205930000 2090060 8" na 8" na 2.9 1/28/2014 CD3-119 50103206530000 2120070 19" na 19" na 1.7 1/28/2014 CD3-122 50103206090000 2091530 6'1" na 6'1" na 32.3 1/28/2014 CD3-123 50103206170000 21 b0310 17" na 17" na 5.1 °` 1/28/2014 CD3-124 50103206120000 2100080 17" na 17" na 5.1 1/28/2014 CD3-125 50103206320000 2101890 14" na 2' na 2.1 1/28/2014 CD3-127 50103206340000 2110050 8" na 10" na 3.4 1/28/2014 CD4-16 50103205350000 2061310 SF na 5" na 4.8 1/28/2014 CD4-27 50103206440000 2111460 SF na 15" na 1.7 1/28/2014 CD4-208A 50103205170100 2110600 SF na 7" na 2.9 1/28/2014 CD4-210A 50103205330100 2110720 SF na 7" na 2.9 1/28/2014 CD4-301B 50103205570200 2071800 SF na 7" na 4.2 1/28/2014 CD4-318A 50103205190100 2061130 SF na 7" na 3.4 1/28/2014 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Commission Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: LWD Formation Evaluation Logs: CD3-127 C123-127 50-103-20634-00-00 2" x 5" MD Triple Combo Logs: 2" x 5" TVD Triple Combo Logs: Digital Log Images, LAS Data, & DLIS Data w/verification listing RECEIVED APR 3 0 2013 AC April 26, 2013 -Z' - 2.2 5� 5 AK-MW-0009113890 1 Color Log 1 Color Log 1 CD ROM PLEASE ACKNOWLEDGE RECEIPT BY RETURNING A SIGNED AND DATED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster. Bryan tC@halliburton.com Benj amin.SchulzePhalliburton.com Date: Signed: � � �°�— STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND I "1('r 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: 1b. Well Class: Development Q Exploratory El Service ❑ StratigraphicTest ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: March 19, 2013 12. Permit to Drill Number: 211-005 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 11, 2011 13. API Number: 50-103-20634-00 / 50-103-20634-70 4a. Location of Well (Governmental Section): Surface: 1257' FSL, 1186' FEL, Sec. 5, T12N, R5E, UM Top of Productive Horizon: Kuparuk C: 1833' FNL, 1774' FEL, Sec. 12, T12N, R4E, UM Nechelik: 2310' FNL, 1801' FEL, Sec. 12, T12N, R4E, UM Total Depth: 1245' FNL, 945' FWL, Sec. 18, T12N, R5E, UM 7. Date TD Reached: March 8, 2013 14. Well Name and Number: CD3-127 / CD3-127PB1 8. KB (ft above MSL): 49' RKB ' GL (ft above MSL): 12.6' AMSL , 15. Field/Pool(s): Colville River Field - Fiord Oil Pool . 9. Plug Back Depth (MD + TVD): 2002T MD / 7048' TVD • 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 387857 y- 6003756 Zone-4 TPI: x- 377172 y- 6000834 Zone-4 Total Depth: x- 379815 - 5996099 Zone-4 10. Total Depth (MD + TVD): 20033' MD / 7049' TVD 16. Property Designation: ADL 372105, 25538, 25526 11. SSSV Depth (MD + TVD): SSSV @ 2152' MD / 2001TVD 17. Land Use Permit: LAS2112 18. Directional Survey: Yes Q No ❑ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: 1574' MD / 1556' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res, Neutron, Density, MWD, CCL 22. Re-drill/Lateral Top Window MD/TVD 3039' MD / 2384' TVD 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 91.5# A-53 36' 114' 36' 114' 42" 15 cu yds AS III 10.75" 45.5# L-80 36' 3239' 36' 2453' 13.5" 445 sx Class G, 280 sx Class G 7.625" 29.7# L-80 34' 14970' 34' 6967' 9.875" 447 sx Alpine Intermediate, 286 sx Class G 3.5" 1 9.3# L-80 1 14790' 1 20023' 6930' 7048' 6.125" Iliner 24. Open to production or injection? Yes No If Yes, list each Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): r 14429'-14452' MD 6821'-6829' TVD 5spf} frac ports for perfs from: 15495'-15490' MD 6981'-6981' TVD 16390'-16395' MD 6996'-6996' TVD "' "" ' 17289'-17294' MD 7001'-7001' TVD l . 18189'-18194' MD 7003'-7003' TVD cf r1 19087'-19092' MD 7028'-7027'TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5 x 3.5 14826' 14367' MD / 6799' TVD and 14790' MD / 6930' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 3039' 472 sx Class G, 202 sx Class G cement plug @ 3327'-3827' 393 sx Class G cement plug @ 7344-7744' 280 sx Class G cement plug @ 13207'-13607' 259 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on representative well test Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS -OIL RATIO Flow Tubing Press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE IRBOMS APR 16 2013 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE / v , 9, 13 Submit original only 29. 'GEOLOGIC MARKERS (List all formations and, :s 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 ground surface ground surface Permafrost - Bottom 1574' 1556' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 14428' 6821' Nechelik 14927' 6960' N/A CD3-127PB1 total depth 15261' 6978' Formation at total depth: Nechelik and Kuparuk C 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Brunswick @ 263-4249 Email: Scott.A. Brunswick[c@conocophillips.com Printed Name G. L. Alvord Title: Alaska Drilling Manager A 6..040L, Signature - Phone 265-6120 Date 4-t2at 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 la: Classification of Service wells: Gas injection, water injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 0 Cono4hillips' Alaska, kIC. "•Well Corift HORIZONTAL - CD3.127. E12/2073 1104:11 AM Schematic. Actual HANGER, 31 C 9 CONDUCTOR, 36-11, hIh SAFETY VLV, I 2,152 -� SURFACE. 36-3.239 GAS LIFT, GAS LIFT, 11.801 GAS LIFT, 14.095 3E, 14.342 PACKER, 14.367 GAS LIFT, 14.394 SLEEVE, _ 14,495 NIPPLE, 14,509- SEAL ASSY, _ 14,815 I <4 PERFP, 15.495-15,499 FRAC, 15.4955 /L PERFP, 6 -16,39 ^y\'✓l F0 FRAC, AC,18,39 FRAC, 17.289 PERFP, as, 17.289-17.294 PERFP, 18.18':194 FRAC, 18,189 PERFP, 19.087-19,092 FRAC. 19,087 1 u 0 L WNS CD3-127 Well Attributes Max Angle & MD ITD Wellbore API)UWI Field Name 501032063400 FIORD NECHELIK Well Status PROD Incl V) MD (RKB) 92.11 15,327.97 Act etm (RKB) 20,033.0 Comment H2S (ppm) I Date Annotation SSSV: TRDP Last W0: End Date KB- 13. (R) 6.30 Rig Release Date 3/19/2013 Annotation Depth Last Tag: SLM (ftKB) 14,700.0 End Date Annotation 3/31/2013 Rev Reason: BREAK DOWN FRAC DEPTHS I Last Mod ... osborl End Date I 4/12/2013 Casino Strincis Casing Description CONDUCTOR String 0... 16 String ID 14.688 ... Top(ftKB) 36.0 Set Depth(f... 114.0 Set Depth (TVD) 114.0 String Wt... String... 109.00 H40 String Top Thrd WELDED Casing Description SURFACE String C... 10314 String ID 9.950 ,.. Top (RKB) 35.9 Set Depth if... 3,239.2 Set Depth (TVD) ... 2,453.9 String Wt.. String... 45.50 L80 String Top Thrd BTCM Casing Description INTERMEDIATE String 0... 75/8 String ID... 6.875 Top (RKB) 34.3 Set Depth if 14,969.6 Set Depth (TVD) ... 6,966.9 String Wt.. String 29.70 ... L-80 String Top Thrd BTCM Casing Description LINER String 0... 31/2 String ID 2.992 ... Top(RKB) 14,790.2 Set Depth(C. 20,023.0 Set Depth ITVD)... 7,048.5 String Wt... String... 9.30 L-80 I String Top Thrd SLHT Liner Details Top (ftKS) Top Depth (TVD) (RKB) Top Inel (") Item Description Comment Noml... ID (in) 14,790.2 6,930.4 76.20 PACKER BAKER ZXP LINER TOP PACKER 4.950 14,808.9 6,935.0 76.59 NIPPLE BAKER RS NIPPLE 4.880 14.811.8 6,935.7 76.65 HANGER BAKER FLEX LOCK LINER HANGER 4.830 14,821.4 6,937.9 76.85 SBE Baker 80-40 Seal Bore Extension P x P 4.000 15,028.E 6,976.0 83.43 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15,075.5 6,980.4 84.91 Swell Packer SWELL PACKER OD 6.38" w/ 5' Seating element 2.992 15.495.0 6,980.8 89.95 FRAC PORT 3-1/2' SLHT Ball Actuated Sleeve (2.W' seat ID) 2.125" BALL ON SEAT 2.000 15,941.5 6,987.9 88.92 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 16,390.6 6,995.6 87.05 FRAC PORT 3.1/2" SLHT Ball Actuated Sleeve (1.875" seat ID) 2.0" BALL ON SEAT 1.875 16,838.3 6,998.6 90.45 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 17.289.1 7.001.2 89.75 FRAC PORT 3.1/2' SLHT Ball Actuated Sleeve (1.75" seat ID) 1.875" BALL ON SEAT 1.750 17,739.2 6,996.7 89.51 Swell packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 18,189.7 7.003.5 88.91 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.625" seat 10) 1.75" BALL ON SEAT 1.625 18,638.1 7,014.2 89.39 Swell Packer SWELL PACKER OD 6.38" w/ T Seating element 2.992 19,087.4 7,027.5 90.87 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.50" seat ID) 1.625" BALL ON SEAT 1.500 19,536.3 7,032.9 87.82 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 19,960.0 7,047.3 88.88SLEEVE BAKER'P'SLEEVE 2.695 19,982.9 7,047.8 88.88 VALVE IBAKER WELLBORE ISOLATION VALVE 0.000 Tubing Strin s Tubing Description TUBING 4.5x3.5@107 String 0... 31/2 string lD ... 2,992 Top(RKB) Set 31.3 1 Depth(f._ 14,825.E 1 Set Depth TVD) 6.938.9 String Wt.. String... 9.30 1 L80 String Top Thrd EUE Completion Details Top Top IRKS) Depth (�) (RKB) Topincl (") Rem Description Comment N-L.. ID an) 31.3 31.3 -0.04 HANGER FMC TUBING HANGER 3,9W 107.2 107.2 0.29 XO Reducing CROSSOVER 4-1/2' IBT-m box x 3-12" EUE-m 3.500 2,152.1 2,001.4 48.56 SAFETY VLV TRMAXX-5E SSSV w/ 2812" "X" profile w/ 1/4" control line (5.176' OD) 2.812 14,3422 6,789.4 68.24 GAUGE SUB BHP Guage, 3.1/2' NDPG single sub, EUE pin x pin, w/ encapsulated I -wire 2.992 14,367.2 6.798.6 68.41 PACKER BAKER PREMIER PACKER 2.870 14,414.5 6,815.8 68.74 Blast Ring PESI BLAST RING (1) 2.992 14,495.3 6,844.7 71.06 SLEEVE BAKER CMD SLIDING SLEEVE 2.812 14,50119 6,849.2 71.20 NIPPLE HES "XN" LANDING NIPPLE 2.75" NO GO 2.813 14,814.7 6,936.4 76.71 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY (10.39' to 4.53" OD locator) 2.970 Perforations & Slots To ftKB Btm RKB Top(TVD) (RKB) Stm(TVD) (RKB) Zone Date Shot Dens (sh••• Type Comment 14,429.0 14,452.0 6,821.1 6,829.4 Nechelik, CD3.127 3/13/2013 5.0 IPERF PERF KUPARUK SAND f/ 14429' U 14452 15,495.0 15.499.0 6,980.8 6,980.8 Nechelik, CD3-127 3/292013 5.0 PERFP FRAC PORT 16,390.0 16,395.0 6,9%.6 6,995.9 Nechelik, CD3-127 3292013 5.0 PERFP FRAC PORT 17,289.0 17.294.0 7,001.2 7,001.3 Nechelik, CD3-127 3I292013 5.0 PERFP FRAC PORT 18,189.0 18194.0 7,003.4 7,003.2 Nechelik, CD3.127 3/292013 5.0 PERFP FRAC PORT 19,087.0 19,092.0 7,027.5 7,027.5 Nechelik, CD3-127 3292013 5.0 PERFP FRAC PORT Mandrel Details S--- N-,- To fti EI Top Depth (TVD) (ftKB) Top Ind (') Make Model OD (in) Sery Valve Type Latch Type Port Size (m) TRO Run (psi) Run Date Com.. 1 5,792.1 3,403.5 68.99 Cameo KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/172013 2 11,801.2 5,610.5 68.71 Cameo KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/172013 3 14,094.7 6,691.0 66.41 Cameo KBMG 1 GAS LIFT DMY BEK 0.000 0.0 3/172013 DCK-2 4 14,393.6 6,808.2 68.59 Cameo KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/172013 LINER, 14,790-20,023 TD (CD3427), 20.033 WNS ConocoPhillips Naska, 11 K:. ••W,IlConfia HORaONTAL•CO3-1274/12/201311'04'. IAM Schematic - Actual HANGER. 31 M y Stimulations & Treatments Bottom Min Top Depth (ftKB) Max Btm Depth (ftKB) Top Depth (TVD) (ftKB) Depth (TVD) (ftKB) 15,495.0 15.499.0 6,980.8 6,980, CONDUCTOR. 38-114 SAFETY VLV, 2,152 SURFACE._ 36-3.239 GAS LIFT, 5,792 16,31 16,395.0 6,995.E 6,995, 17,289.0 17,293.0 7,001.2 7,001, 18,189.0 18,194.0 7.003.4 7,003 19,087.0 19.092.0 7,027.5 7,027, GAS LIFT. Notes: General & Safety End Date 3/8/2011 NOTE: -ELL SUSPEN GAS LIFT. 3/19/2013 NOTE: FINISHED DRII 14.095 GAUGE, 14.342 -- - PACKER. 14.367 GAS LIFT, 14,394 IPERF, I- — -- 14,429-14,452 SLEEVE, 14.495 NIPPLE, 14.509 SEALASSY, _ 14.815 PERFP. 15 495-15,499 FRAC. 15.495 PERFP, 18,3,18,395 FRAC. 18,390 FRAC.17,289 PERFP, 17.289-17.294 PERFP, mil 18,194 'RAC,18,189 PERFP, 19.087- 19,092 FRAC, 19'087 LINER, 14,790-20.023 TD (CD3-127). 20.033 I 1 1 CD3-127 Comment NECHILIK FRAC, 6 main stages utilizing Packers Plus StackFRAC system. Each stage placed approximately 113-118k# of 16/20 CarboUte Proppant (1-7 ppa) using 30# crosslink gel at 20-bpm, for a job total of 686,560# sand and 7999-bbl total volume pumped (100% of design). First stage was pumped through Baker'P' Sleeve at 19,960 MD, with subsequent stages initiated by dropping frac balls (1.625" - 2.125', in 0.125' increments) opening specific ports along the horizontal liner. The prop fracture treatment was preceded by a breakdown using 30# linear gel at 20-bpm. (118.1K#) ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: CD3-127 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 2/10/2011 5:00:00 PM Rig Release: 3/8/2011 6:00:00 AM Time Logs Date From To Dur S. Depth E. Del2th Phase Code Subcode T Comment 2/09/2011 2a hr Summary Release from CD2-77. Prepare camp and move to CD3 ice pad. Spot & RU same. Move ball mill complex and move motor and pit complexes on ice road to CD3. Move sub complex onto ice road. 10:00 12:30 2.50 0 0 MIRU MOVE MOB P Prepare camp for move from CD2 to CD3. 12:30 16:00 3.50 0 0 MIRU MOVE MOB P Rig down rig complexes. Move camp modules and spot same at CD3 ice pad. 16:00 19:00 3.00 0 0 MIRU MOVE MOB P Continue rigging down on CD2. Move ball mill complex, mechanic shop and electrical shop over to CD3. 19:00 00:00 5.00 0 0 MIRU MOVE MOB P Continue with rig move. Move motor and pit complexes onto ice road and bring sub complex up behind. 2/10/2011 Continue moving sub base to CD3. Spot sub over well and RU complexes. NU riser and flowline. Start PUDP. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move rig complexes to CD3 location. 12:00 16:00 4.00 0 0 MIRU MOVE MOB P Spot sub over CD3-127 conductor. Spot pits, motor complex and pipeshed. 16:00 17:00 1.00 0 0 MIRU MOVE MOB P Hook up service lines - steam, water, electrical and air. Rig on highline power at 1645 hrs. 17:00 19:15 2.25 0 0 MIRU DRILL NUND P Accept rig at 17:00 hrs. NU riser and flowline. Load pipeshed with tubulars. 19:15 00:00 4.75 0 0 MIRU DRILL PULD P RU handling tools to PUDP. PJSM. PU 5" DP using mousehole. 24 stds PU by end tour. 2/11 /2011 PU 5" DP & HWDP from pipeshed. Cut drlg line. Pre -spud meeting. Spud well at 09:15 hrs. Drill 13 1/2" hole to 1093' MD/1085' TVD. 00:00 02:45 2.75 0 0 MIRU DRILL PULD P Continue PU 5" DP and HWDP using mouse hole. 02:45 04:15 1.50 0 0 MIRU RIGMNT SLPC P Slip and cut drilling line. Service top drive and set block height. 04:15 07:30 3.25 0 0 MIRU DRILL PULD P Bring BHA components to rig floor. MU BHA #1 per DD. Hang sheave for gyro survey tool in derrick. 07:30 08:00 0.50 0 0 MIRU DRILL SFTY P Hold pre -spud meeting with rig crew and service company personnel. 08:00 09:00 1.00 0 0 MIRU DRILL PRTS P Fill riser with mud.and check for leaks. Flood lines and pressure test to 3500 psi - OK. Blow down top drive. 09:00 09:15 0.25 0 0 MIRU DRILL PULD P MU flex collars and wash down to 114'. Page 1 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09.15 12:00 2.75 0 280 SURFA( DRILL DDRL P Spud well at 09:15 hrs. Drill to 280' MD. ADT=1.13 hrs. 550 gpm. On btm = 1060 psi. Off btm = 1000 psi. 60 rpm. Torque = 4 kftlbs on/off btm. PUW/SOW/Rot Wt = 95 klbs. G roeve stand. 12:00 00:00 12.00 280 1,093 SURFA( DRILL DDRL P Continue drilling 13 1/2" surface hole to 1093' MD / 1085' TVD. AST=2.87 hrs. ART=3.35 hrs. ADT=6.22 hrs. PUW=120 klbs. SOW=120 klbs. ROT=120 klbs. (Pumps on). 6.5 klbs TQ on btm. 5.5 klbs TQ off btm. 10-25 klbs WOB. 60 RPM. Flow=500 gpm. PP=1200 psi on btm. Gyro surveys every stand to 354'. Well getting too close to planned future well CD3-128 so gyro every single to 476' MD. 2/12/2011 Drill 13 1/2" hole to 2805' MD / 2307' TVD 00:00 12:00 12.00 1,093 2,093 SURFA( DRILL DDRL P Continue drilling 13 1/2" surface hole from 1093' MD to 2056' / 1939' TVD. AST=3.05 hrs. ART=2.94 hrs. ADT= 5.99 hrs. PUW=135 klbs. SOW=132 klbs. ROT=135 klbs. (Pumps on). 7.5 klbs TQ on btm. 6.5 klbs TQ off btm. 10-25 klbs WOB. 60 RPM. Flow=650 gpm. PP= 1870 psi on btm. 12:00 00:00 12.00 2,093 2,805 SURFA( DRILL DDRL P Continue drilling 13 1/2" surface hole from 2056' MD to 2805' / 2307' TVD. AST=3.14 hrs. ART=5.07 hrs. ADT= 8.21 hrs. PUW=140 klbs. SOW=130 klbs. ROT=135 klbs. (Pumps on). 8.5 klbs TQ on btm. 7 klbs TQ off btm. 10-25 klbs WOB. 60 RPM. Flow=675 gpm. PP= 2405 psi on btm. 2/13/2011 Drill 13 1/2" hole to TD at 3250' MD/2457' TVD. Circ hole clean. Wiper trip up to HWDP. RIH to btm. Circ hole clean. POH to run 10 3/4" casing. Page 2 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 08:15 8.25 2,805 3,250 SURFA( DRILL DDRL P Drill ahead from 2805' MD to 3250' MD/2457' TVD. Surface hole TD. ADT= 6.32 hrs. ART=6.13 hrs. AST=0.19 hrs. PUW=135klbs. SOW=130 klbs. ROT=132 klbs. TQ ON=8.5 kftlbs. TQ OFF=7 kftlbs. @ 60 rpm 2410 psi at 675 gpm. 08:15 09:30 1.25 3,250 3,250 SURFA( DRILL CIRC P Circulate and condition mud - Pumped 2 X BU - 700 gpm / 2420 psi / 60 rpm - flow check well, static 09:30 14:30 5.00 3,250 904 SURFA( DRILL TRIP P Perform wiper trip - Backream from 3250' to 904' - 650 gpm / 2100 psi / 60 rpm - reduced rate to 500 gpm from 1500' Hole unloaded a large amount of cuttings while backreaming from 2039' to 1945' (45-40 degree angle) pulled slow until shakers cleaned up. Slowed pulling speed on the last two stands - observed a large push of cuttings (mostly sand) throughout. Flow check well, staic - blow down top drive 14:30 16:30 2.00 904 3,250 SURFA( DRILL TRIP P RIH from 904' to 3250' - no problems - precautionary washed and reamed last stand to bottom 16:30 18:30 2.00 3,250 3,250 SURFA( DRILL CIRC P Circulate and condition mud - 670 gpb / 2680 psi / 60 rpm through first BU - large amounts of sand across shakers - reduced rate to 500 gpm to manage increasing mud wt. from 9.7 ppg to 10.0 ppg - shakers pretty clean after second BU - flow check well, static. Blow down top drive. 18:30 21:30 3.00 3,250 909 SURFA( DRILL TRIP P POOH on elavators from 3250' to HWDP. PUW off bottom pumps off=143 klbs. Trip speed 1000-1500 fph. 10 mi flow check at HW. Slight fluid level drop in riser. 21:30 22:45 1.25 909 260 SURFA( DRILL TRIP P POH with HWDP. One minor overpull at —650' - 25 klbs overpull. Drop back down and wipe same - OK. No other problems or tight spots noted. No circulating required. 22:45 00:00 1.25 260 50 SURFA( DRILL PULD P LD BHA -jars, flex collars. 2/14/2011 Run 10 3/4" casing to 3239' MD shoe depth. Circ and cond hole. Cement with 445 sx AS Lite lead slurry and 280 sx 15.8 Class G tail slurry. Got back 56 bbls slurry to surface. ND riser. NU wellhead & BOPE. 00:00 01:00 1.00 50 0 SURFA( DRILL PULD P Finish LD BHA #1 and download MWD. 01:00 02:00 1.00 0 0 SURFA( DRILL PULD P Clear rig floor of BHA components and clean floor. 02:00 03:15 1.25 0 0 SURFA( CASING RURD P PJSM. RU casing tools to run 10 3/4" surface casing. Page 3 of 79 Time Logs Date From To ' Dur S. De th E. De th Phase Code Subcode T Comment 03:15 03:45 0.50 0 0 SURFA( CASING SFTY P PJSM with all crew members, mud engr, TP, Co Rep for running 10 3/4" casing. 03:45 06:00 2.25 0 0 SURFA( CASING RNCS P MU shoe track. Bakerlock connections on first 3 jts and pin on jt #4. RI with 10 3/4" casing. 06:00 06:45 0.75 1,626 1,626 SURFA( CASING CIRC P Establish circulation - Staged pumps up to 6.0 bpm - Reciprocate casing and condition mud casing PUW 145K SOW 123K FCP=380 psi - Circulated 1.5 X BU - observed mild amount of cuttings across shakers 06:45 09:00 2.25 1,626 3,239 SURFA( CASING RNCS P Run 10 3/4" casing from 1626' to 3201' (79 jts. total) MU FMC fluted hanger and landing joint - land casing w/ FS @ 3239' and FC @ 3158' 09:00 09:30 0.50 3,239 3,239 SURFA( CASING RURD P Rd casing tongs and scaffold - LD fill -up tool 09:30 09:45 0.25 3,239 3,239 SURFA( CEMEN- RURD P Ru 10 3/4" cement head and lines 09:45 12:45 3.00 3,239 3,239 SURFA( CEMEN-CIRC P Establish circulation - Reciprocate and stage pumps up to 7.0 bpm - condition mud and hole for cementing FCP 330 psi - total pumped 1023 bbls - PUW 187K SOW 148K MWT. 10.o ppg PV 22 YP 17 FV 55 10 sec gels 5 10 min. 11 Held PreJob safety and operations meeting with rig on upcoming cement job 12:45 14:30 1.75 3,239 3,239 SURFA( CEMEN' PUCM P Cemented 10 3/4" casing as follows: Rig pumped 120 bbls of 10.0 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 2 bbls of FW, tested lines to 3200 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 210 psi. Mixed & pumped 446_ sxs of 10.7 ppq lead slurry (4.49 cf/sx yield) (ASL) ave. 7.0 bpm at 276 - 190 psi. Observed nut plug marker at shakers w/ 240 bbls lead slurry pumped (pumped down surge can, 357 bbls total) Switched to tail slurry and pumped 280 sxs of 15.8 ppg tail cmt (1.16 cf/sx) 57 bbls (Class G w/ additives) ave.5.0 bpm at 180 psi. Page 4 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14.30 15:30 1.00 3,239 3,239 SURFA( CEMEN- DISP P Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 282 bbls of 10.0 ppg mud ave. 7.0 bpm, ICP 240, FCP 720 psi, slowed pump to 4 bpm at 550 psi (for the last 8.0 bbls of displacement) Bumped plug to 1180 psi. Checked floats OK, CIP @ 1622 hrs. Had full returns throughout job w/ 56 bbls of 10J ppg cement returns fo s rface. Reciprocated pipe until last 122 bbls of displacement (SOW had dropped Ito 100K). 15:30 17:30 2.00 3,239 3,239 SURFA( CEMEN" RURD P Bleed off pressure and check floats - OK. RD cement head. LID landing jt. RD and LD casing tools. Install bails and 5: DP elevators. 17:30 19:00 1.50 0 0 SURFA( WHDBO NUND P PJSM. ND and remove riser. 19:00 20:00 1.00 0 0 SURFA( WHDBO NUND P Orient and install FMC wellhead and test metal to metal seal to 1000 psi for 10 min - good test. 20:00 00:00 4.00 0 0 SURFA( WHDBO NUND P PJSM. NU BOPE. 2/15/2011 NU BOPE. PU 5" DP. Test BOPE to 250/3500 psi. Install wear ring. MU rotary steerable BHA #2. 00:00 01:15 1.25 0 0 SURFA( WHDBO NUND P Cont. NU BOPE - Install riser & flow line - Install mouse hole 01:15 01:30 0.25 0 0 SURFA( DRILL SFTY P Held PJSM on picking up 5" DP f/ pipe shed via mouse hole 01:30 05:00 3.50 0 0 SURFA( DRILL PULD P PU 5" DP f/ pipe shed & stand bvack in derrick 05:00 05:30 0.50 0 0 SURFA( RIGMNT SVRG P Service rig - grease drawworks & iron roughneck - Clean eyes on skate 05:30 13:30 8.00 0 0 SURFA( DRILL PULD P Cont. PU 5" DP f/ pipe shed & stand back in derrick (315 jts - 105 stds) 13:30 21:30 8.00 0 0 SURFA( WHDBO BOPE P Pull wear bushing. Set test plug on 5" test jt. Test BOPE. UPR, LPR, blinds, man & hyd choke valves, dart sub, floor valve, IBOP, choke manifold to 250/3500 psi. Annular to 250/2500 psi. Flush and fill gas buster. Check function of manual and hydraulic chokes w/ 1100 psi back pressure. Perform accumulator drawdown test and check nitrogen backup bottles. Witness of test waived by AOGCC Rep Bob Noble at 16:30 hrs on 2/13/2011. 21:30 22:00 0.50 0 0 SURFA( WHDBO BOPE P Pull test plug. Set wear bushing. 22:00 00:00 2.00 0 0 SURFA( DRILL PULD P PJSM. PU components for BHA #2 Geo Pilot rotary steerable. 2/16/2011 MU BHA #2. RIH PUDP to 2950'. Test casing to 3500 psi for 30 min. Good test. Drill shoe track plus 20' new hole to 3270' MD. Perform LOT to 17.O ppg EMW_Displace hole to 9.6 ppg LSND mud. Drill ahead to 3544' MD. Page 5 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 03:00 3.00 77 77 SURFA( DRILL PULD P Cont MU Geo Pilot BHA #2. Upload MWD.- Load RA sources in MWD tool 03:00 04:00 1.00 77 287 SURFA( DRILL WASH T Hit cmt stringer @ 185' after picking up 2nd NM flex DC - MU std f/ derrick - wash down f/ 185' to 287' @ 550 gpm @ 1060 psi w/ 50 rpm @ 6 k torque - Blow down TD - std back 1 std DP in derrick 04:00 04:45 0.75 287 629 SURFA( DRILL PULD P Cont. MU BHA - RIH f/ 185' to 629' w/ NM flex DC's - HWDP 04:45 05:15 0.50 629 629 SURFA( DRILL OTHR T PU ghost reamer # 1 - Observed wash out above blade on body of tool - Wait on decision 05:15 05:30 0.25 629 777 SURFA( DRILL TRIP P Cont. RIH f/ 629' to 777' w/ HWDP 05:30 07:30 2.00 777 2,951 SURFA( DRILL TRIP P Cont. RIH f/ 777' to 2951' - picking remaining 69 jts 5" DP f/ pipe shed (picked up ghost reamer 1786' f/ bit) 07:30 08:15 0.75 2,951 2,951 SURFA( DRILL CIRC P Circ btms up @ 2951' for casing test - 550 gpm @ 1650 psi w/ 50 rpm's @ 8.5 k torque - PU wt 140 SO wt 110 Rot wt. 130 - Blow down TD 08:15 08:30 0.25 2,951 2,951 SURFA( RIGMNT SFTY P PJSm on cut & slip of drill line 08:30 10:30 2.00 2,951 2,951 SURFA( RIGMNT SLPC P Slip & cut drill line 60' and service TD and draw works - replace broken cotter pin on draw works brake band pin - Calc. block height - 10:30 12:00 1.50 2,951 2,951 SURFA( DRILL PRTS P PJSM on testing casing - RU & test 10 3/4' casing to 3500 psi for 30 mins.- Blow down lines & RD 12:00 12:30 0.50 2,951 3,154 SURFA( DRILL WASH P Wash & ream f/ 2951' to 3154' (tagged up) 12:30 15:00 2.50 3,154 3,250 SURFA( CEMEN' DRLG P Drilled cmt & wiper plugs & FC @ 3158' - Drilled cmt to 3236' - drilled out shoe f/ 3236' to 3239' - Clean out rat hole to 3250' 15:00 15:30 0.50 3,250 3,270 SURFA( DRILL DDRL P Drilled 20' new hole f/ 3250' to 3270' (for FIT) - @ 700 gpm @ 2540 psi w/ 50 rpm @ 10 k torque 15:30 17:00 1.50 3,270 3,270 SURFA( DRILL CIRC P Circ and cond mud for FIT 700 gpm @ 2500 psi. 17:00 18:00 1.00 3,270 3,270 SURFA( DRILL FIT P Perform FIT. Shoe @ 2453' TVD. MW = 9.6 ppg. LO pressure = 950 psi. LOT value = 17.0 ppg EMW. Page 6 of 79 Time Logs Date From To Dur S. De th`' E. De th Phase Code Subcode T Comment 18.00 00:00 6.00 3,270 3,544 INTRM1 DRILL DDRL P Drill 9 7/8" hole from 3270'. Swap hole to 9.6 ppg LSND mud while drilling ahead. SD and flow check well after displacement complete - OK. Drill ahead to 3544' MD. Having to keep rotary speed low to reduce excessive BHA vibration. ADT=2.84 hrs. PUW=148 k. SOW=121 k. ROT=135 k. TQ ON=10000 ft lbs. TQ OFF=7500 ft lbs. 50 rpm. WOB=5-10 k. 750 gpm @ 2050 psi. ECD 10.2 ppg. 2/17/2011 Drilling ahead in 9 7/8" hole from 3544' to 6100' MD/3471' TVD. 00:00 12:00 12.00 3,544 4,747 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/ GP f/ 3544' to 4747' MD 3002' TVD ADT- 8.31 hrs ECD- 10.75 ppg Footage- 1203' WOB 5 - 15 k RPM 120 GPM 750 @ 2460 psi String wt. PU 150 SO 134 Rot 140 Torque on/off btm.- 10/8.5 k Ongoing issues with excessive BHA vibration and stick/slip preventing higher rotary RPM - turning at 90 rpm max. Increasing lubricant content of mud from 1 to 2% to see if any improvement is noted. 12:00 00:00 12.00 4,747 6,100 INTRM1 DRILL DDRL P Continue drilling 9 7/8" hole from 4747' to 6100' MD/3471' TVD. ADT = 7.44 hrs. ECD = 10.93 ppg EMW. Footage drilled = 1353'. WOB = 5-15 klbs. RPM = 145. 725 gpm @ 2870 psi. String wt: 165 k up. 142 k dn. 152 k rot. Torque on/off btm = 11/8.5 kft lbs. Maintaining ROP at —200 fph. Sweeps are bringing back a moderate amount of cuttings. 275 bbl whole mud dilutions at 4585', 5210' and 5970' to maintain MBT <20. Lube concentration at 2%. 2/18/2011 Drilled 9 7/8" hole w/ Geo Pilot f/ 6100' to 8776' MD/4440' TVD. Page 7 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 12:00 12.00 6,100 7,489 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/ GP f/ 6100' to 7489' MD 3999' TVD ADT- 7.23 hrs. ECD- 10.93 ppg Footage- 1389' WOB 5/20 k ROPM 150 GPM 775 @ 3020 psi String wt. PU 181 SO 150 Rot 165 Torque on/off btm.- 10.5 / 8 k 12:00 00:00 12.00 7,489 8,776 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Geo Pilot RSS from 7489' to 8776' MD/4440' TVD. ADT = 7.27 hrs. ROP = 250 fph. ECD = 10.8 ppg. Footage drilled = 1287' . RPM = 150. WOB = 10-18 klbs. 800 gpm @ 3120 psi. String wt: PU = 197 k. SO = 154 k. ROT = 172 k. Torque on/off btm = 13.5/10.5 kft lbs. Lubricant concentration at 2%. Whole mud dilutions to keep MBT <20. 2/19/2011 Drilled 9 7/8" hole w/ Geo Pilot f/ 8776' to 11555' MD/5490' TVD. 00:00 12:00 12.00 8,776 10,454 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 8776' to 10,454' MD 5082' TVD ADT- 7.21 hrs ECD- 10.84 ppg Footage- 1678' WOB 15/22 k RPM 150 GPM 800 @ 2950 psi String wt. PU 220 SO 160 Rot 189 Torque on/off btm.- 16/12.5 k 12:00 12:30 0.50 10,454 10,610 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geo Pilot f/ 10454' to 10610' M D. 12:30 13:30 1.00 10,610 10,610 INTRM1 DRILL CIRC T Circ at 450 gpm while repairing rod washer on mud pump. Rotate at 90 rpm. 13:30 00:00 10.50 10,610 11,555 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Geo Pilot from 10610' MD to 11555' MD/5490' TVD. ADT = 6.52 hrs. Footage = 945'. ECD = 10.9 ppg. WOB = klbs. Rotary = 145 rpm. 800 gpm @ 3150 psi. String Wt: PU = 240 klbs SO = 162 klbs ROT = 190 klbs Torque On/Off Btm = 2/20/2011 Drilled 9 7/8" hole w/ Geo Pilot from 11,555' MD to 13919' MD/6556' TVD. Page 8 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code - Subcode T Comment 00:00 12:00 12.00 11,555 12,762 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 11,555' to 12,762' MD 5964' TVD ADT- 7.95 hrs. ECD- 10.74 ppg Footage- 1207' WOB 10/20 k RPM 150 GPM 800 @ 3200 psi String wt PU 260 SO 165 Rot 200 Torque on/off btm.- 20.5/ 17.5 k 12:00 20:30 8.50 12,762 13,680 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geo Pilot from 12762' to 13680' MD. Pop off valve on mud pump #1 sheared at 3950 psi. 20:30 20:45 0.25 13,680 13,680 INTRM1 DRILL DDRL T PU off btm and circ with one pump while changing pop off assembly. 20:45 00:00 3.25 13,680 13,919 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geo Pilot from 13680' M D to 13919' M D/6556' TVD. ADT = 7.9 hrs. Footage = 1157'. (For 12 hr tour). ECD = 10.99 ppg. WOB = 16/18 klbs. RPM = 145 rpm. 750 gpm @ 3550 psi. String Wts: PU = 275 k. SO = 180 k. ROT = 225 k. Torque on/off btm = 21.5/17 kftlbs. Add black products for shale inhibition and weight up to 9.8+ ppg for shale stability prior to drilling into THRZ. HRZ may have come in high at—13750' MD. 2/21 /2011 Drilled 9 7/8" hole w/ GP f/ 13,919' to 15,261' MD JD 9 7/8" hole). Circ & cond hole. Backream to 13550'. Circ & clean up hole. RIH to bottom. 00:00 12:00 12.00 13,919 14,961 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 13,919' to 14,961' MD 6927' TVD ADT- 8.11 hrs ECD- 11.05 ppg Footage- 1042' WOB 10/20 k RPM 150 GPM 750 @ 3880 psi String wt. PU 307 SO 172 Rot 219 Torque on/off btm.- 21/17.5 k 12:00 14:45 2.75 14,961 15,261 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 14,961' to 15,261' MD - 6978' TVD ADT- 2.27 hrs ECD- 10.89 ppg Footage- 300' WOB 5 / 20 k RPM 150 GPM 750 @ 3720 String wt. PU 310 SO 175 Rot 218 Torque on/off btm.- 22.5/17 k TD of 9 7/8" hole section @ 15,261' 14:45 16:15 1.50 15,261 15,261 INTRM1 DRILL CIRC P Flow ck - static (2" below flow line) - Pumped hi-vis sweep & circulate sweep around - Page 9 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:15 17:45 1.50 15,261 15,261 INTRM1 DRILL CIRC P Circ btms up at 700 gpm/3200 psi and 120 rpm. Rack back 1 stand every 30 min to 14960' M D. 17:45 20:45 3.00 15,261 15,261 INTRM1 DRILL REAM P Start backreaming out of hole from 15261 to—13550'. (Approx 200' above THRZ). 700 gpm @ 3550 psi. 120 rpm. 20 ft/min backream speed. 20:45 22:15 1.50 15,261 15,261 INTRM1 DRILL CIRC P Circ until shakers clean up, working stand from 13550 to 13460'. 700 gpm @ 3300 psi. Blow down top drive. Flow check well - —2" below flowline and stable. 22:15 00:00 1.75 15,261 15,261 INTRM1 DRILL TRIP P RIH to 15242'. 2/22/2011 Circ & bump mud wt. to 10.0 ppg - POOH spotting WBS & CR pills to top of HRZ- BROOH f/ 13,731' to 12,785'- Flow ck (static) POOH on elevators to 8341' - Tight hole - BROOH f/ 8371' to 7,394' MD - CBU - Continue to BROOH t/ 4,558' MD 00:00 01:30 1.50 15,261 15,261 INTRM1 DRILL CIRC P Circ and bump mud wt. to 10.0 ppg - spot WBS/CR pills to bit 01:30 03:45 2.25 15,261 13,730 INTRM1 DRILL TRIP P POOH spotting WBS / CR pills f/ 15261' to 13,730' (above HRZ) - pumping @ 3 bbls/min - No rotation 03:45 05:30 1.75 13,730 12,785 INTRM1 DRILL TRIP P POOH f/ 13,370' to 12,785'- back reaming @ 120 rpm's w/ 700 gpm - Flow ck - well static 05:30 10:15 4.75 12,785 8,371 INTRM1 DRILL TRIP P POOH on elevators f/ 12,785' to 8341' - Tight spot @ 8341' - Attempt to work through - No Go - Run back to 8371' 10:15 12:00 1.75 8,371 8,282 INTRM1 DRILL REAM P BROOH f/ 8371' to 8282' @ 650 gpm @ 2250 psi w/ 120 rpm's 12:00 15:00 3.00 8,282 7,394 INTRM1 DRILL REAM P Cont. to BROOH f/ 8282' to 7,394' MD - 650 GPM @ 2100 Psi w/ 90 RPM 15:00 16:15 1.25 7,394 7,394 INTRM1 DRILL CIRC P CBU @ 600 GPM w/ 2100 Psi & 90 RPM 16:15 00:00 7.75 7,394 4,558 INTRM1 DRILL REAM P BROOH f/ 7,394' to 4,558' MD, 600 GPM w/ 1900 Psi and 115 RPM - OWFF and Attempted to POOH @ 6,071' and 4,653' MD; Hole Pulled Tight (60 K Over Pull) - Reamed Through Spots 2/23/2011 BROOH t/ 3,170' MD - Circ Sweep around; Significant increase in Cuttings - Slip & Cut Drill Line - Circ Sweep Around; No Increase in Cuttings - Pump Out of Hole t/ 128' MD - L/D NMFDC's and Remainder of BHA #2 - Change Upper Rams t/ 7 5/8" Solid Body Elements and Test t/ 250/3500 Psi - R/U and Run 7 5/8" Casing t/ 434' MD (10 Jts and Float Equipment) Page 10 of 79 V Time Logs Date From To Dur S. De th E. De th Phase" Code Subcode T Comment 00:00 04:30 4.50 4,558 3,170 INTRM1 DRILL REAM P Continue to BROOH f/ 4,558' to 3,170' MD 600 GPM w/ 1900 Psi and 120 RPM - Numerous Minor Pack Offs w/ ECD Excursions as High as 11.85 PPGE - Worked Pipe Through Tight Areas - BHA Packed OFF Pulling Into Casing Shoe - Worked Hole and Regained Returns 04:30 05:15 0.75 3,170 3,170 INTRM1 DRILL CIRC P Circ Bit Balling Sweep Surface to Surface @ 600 GPM w/ 1800 Psi and 60 RPM - Sweep Returned 300% Increase in Cutting Above the Bottoms Up Cuttings Load 05:15 05:30 0.25 3,170 3,170 INTRM1 DRILL OWFF P OWFF (Static) 05:30 06:45 1.25 3,170 3,170 INTRM1 DRILL SLPC P PJSM - Cut & slip drill line 60' - Service top drive 06:45 07:15 0.50 3,170 3,170 INTRM1 DRILL CIRC P Circ hi-vis sweep - @ 600 gpm @ 1750 psi 07:15 08:00 0.75 3,170 2,699 INTRM1 DRILL TRIP P POOH on TT f/ 3170' to 2699' improper hole fill ( well swabbing ) 08:00 12:30 4.50 2,699 128 INTRM1 DRILL TRIP P POOH w/ pump f/ 2699' to 128'( attempted to pull on elevators well would swab) 12:30 12:45 0.25 128 128 INTRM1 DRILL OWFF P Blow Down the Top Drive and OWFF (Static) 12:45 15:45 3.00 128 0 INTRM1 DRILL PULD P L/D NMFDC's - PJSM; Remove Nuclear Sources - L/D Remainder of BHA #2 15:45 16:30 0.75 0 0 INTRM1 DRILL PULD P Clean / Clear Rig Floor - Pull the Wear Bushing & Set Test Plug 16:30 18:00 1.50 0 0 INTRM1 WHDBO RURD P PJSM and Change the Top Rams to 7 5/8" Solid Body Elements 18:00 18:30 0.50 0 0 INTRM1 WHDBO BOPE P Test Upper Rams w/ 7 5/8" Test Joint t/ 250/3500 Psi 18:30 19:00 0.50 0 0 INTRM1 WHDBO RURD P Pull the Wear Bushing and Set Thin Walled Wear Ring 19:00 21:30 2.50 0 0 INTRM1 CASING RURD P PJSM & R/U to Run 7 5/8" Casing 21:30 00:00 2.50 0 434 INTRMI CASING RNCS P Run 7 5/8' Casing t/ 434' MD as Follows: Float Shoe, 2 Jts Casing, Float Collar w/ Baffle Adapter on Top, 1 Jt Casing, Baffle Collar, 1 Jt Casing - Fill Pipe and Check Floats - 7 As Casing 2/24/2011 Continue to Run 7 5/8" Casing t/ 13,621' MD (320 Jts Total) Stopped to Circulate & Condition Mud at the Following Depths 3,222' (Jt 77), 4,645' (Jt 110), 6,350' (Jt 150), 8,034' (Jt 190), 9,755' (Jt 230), 11,469' (Jt 270) and 13,621' MD (Jt 320) 00:00 02:15 2.25 434 3,222 INTRM1 CASING RNCS P Continue to Run 7 5/8" Casing t/ 3,222' MD (67 Joints, 77 Total) P/U 140, S/O 130 02:15 03:45 1.50 3,222 3,222 INTRM1 CASINGCIRC P Circulating and Conditioning Mud while Staging the Rate Up to 6 BPM @ 300 Psi Page 11 of 79 Time `Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:45 05:15 1.50 3,222 4,645 INTRM1 CASING RNCS P Continue to Run Casing t/ 4,645' MD (110 Total) P/U 160, S/O 137 05:15 06:15 1.00 4,645 4,645 INTRM1 CASING CIRC P Circulate and Condition Mud While Staging the Rate Up to 5 BPM @ 250 psi 06:15 08:15 2.00 4,645 6,350 INTRM1 CASING RNCS P Continue to run casing f/ 4645' to 6350' (150 jts. total) PU wt. 190 SO wt. 145 08:15 09:30 1.25 6,350 6,350 INTRM1 CASING CIRC P Circulate & Condition mud while staging the pump rate to 5 bbls/mnin @ 270 psi 09:30 12:00 2.50 6,350 8,034 INTRM1 CASING RNCS P Continue to run casing f/ 6350' to 8034' (190 jts total) Installed Halliburton stage collar on top of joint # 169' PU wt. 222 SO wt 152 12:00 13:45 1.75 8,034 8,034 INTRM1 CASING CIRC P Circulate & condition mud while staging the pump rate to 6 bbls/min @ 370 psi 13:45 15:45 2.00 8,034 9,755 INTRM1 CASING RNCS P Continue to run casing f/ 8034' to 9755' (230 jts. total ) PU wt. 250 SO wt 155 15:45 17:15 1.50 9,755 9,755 INTRM1 CASING CIRC P Circulate & Condition mud while staging pump rate to 6 bbl/min @ 420 Psi 17:15 19:45 2.50 9,755 11,469 INTRMI CASING RNCS P Continue to Run Caisng t/ 11,469' MD (270 Jts Total) P/U 280, S/O 156 19:45 21:30 1.75 11,469 11,469 INTRM1 CASINGCIRC P Circulating and Conditioning Mud while Staging the Rate Up to 6 BPM 420 Psi 21:30 00:00 2.50 11,469 13,621 INTRM1 CASING RNCS P Continue to Run Caisng t/ 13,621' MD (320 Jts Total) P/U 350, S/O 175 2/25/2011 Circulate and Condition Mud at Pre -Determined Circulation Point (13,620' MD) - Run Casing t/ 14,270' MD (Unable to Go Down) - Attempt to Circulate (Unable), Attempt to Go Down (Unable), Attempt to P/U (Unable; Max P/U 429 K) - Conferred w/ Anchorage and Revised P/U Limit to 520 K - Worked Pipe Free Establish Circulation @ 14,176' MD - Wait on Weather While Circulating @ 4 BPM w/ 250 Psi and Pulling/Laying Down 1 Joint Every 1.5 hrs t/ 13,408' MD 00:00 02:45 2.75 13,621 13,621 INTRM1 CASING CIRC P Circulate and Condition Mud While Staging the Rate Up to 6 BPM @ 480 Psi 02:45 03:30 0.75 13,621 14,270 INTRM1 CASING RNCS P Continue to Run Casing U 14,270' MD (335 Stands Total) - Took Weight @ 14,200' MD and Able to Work Down t/ — 14,270' MD Page 12 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03.30 07:45 4.25 14,262 14,176 INTRM1 CASING RNCS T Attempt to Establish Circulation & Wash Down (Unable) - Work Pipe With and Without Pumps (Unsuccessful) - Lay Down 1 Jt t/ 14,262' MD - Unable to L/D Second Joint, Pulled to 429K (Max) and Unable to Go Down - Continue to work pipe - Revised max. pull as per Anchorage office 520 K - worked pipe to 520 K - worked pipe free & establish circ - LD jts # 336 - 335 & 334 to 14,176' 07:45 09:30 1.75 14,176 14,176 INTRM1 CASING CIRC T Circ @ 2 bbls/min @ 440 psi - full returns - stage pump to 3 bbls/min @ 400 psi - Working pipe f/ 14,176' to 14110' 09:30 12:00 2.50 14,176 13,746 INTRM1 CASING RNCS T Pull and lay down casing f/ 14,176' to 13,746' (above HRZ) pumping @ 3 bbls/min @ 300 psi - break over wt. 375 - PU wt. 325 Due to Phase III weather conditions Decision made by Rig Superintendent to circ & work pipe waiting for weather to break before attempting to RIH 12:00 00:00 12.00 13,746 13,408 INTRMI CASING OTHR T Wait on Phase III Weather to Clear - Circulate @ 4 BPM w/ 340 Psi - Stand Back 1 Joint of Casing Every 1.5 Hrs t/ 13,408' MD 2/26/2011 Continue to Wait on Weather while Circulating and Conditioning Mud; Laying Down 1 Jt Every 2 Hours to 13,237' MD - RIH t/ 14,132' MD - Wash Casing Down t/ 14,186' MD; Tagged Obstruction - Confer w/ Drilling Superintendent - POOH w/ Pumps and L/D Casing t/ 11,469' MD (63 of 333 As Pulled . `7 00:00 12:00 12.00 13,408 13,452 INTRM1 CASING OTHR T Wait on Phase III Weather to Clear - Circulate @ 4 BPM w/ 340 Psi - Lay down 1 Joint of Casing Every 2 Hrs to 13,277- - Ran jts. back in hole f/ 13,277' to 13,452' 12:00 12:15 0.25 13,452 13,452 INTRM1 CASING SFTY P PJSM on running casing 12:15 13:45 1.50 13,452 14,186 INTRM1 CASING RNCS P RIH w/ 7 5/8" casing f/ 13,452' to 14,132' - Washed down f/ 14,132' to 14,186' (67' f/ base of HRZ) @ 3.5 bbls/min @ 360 psi - SO wt. 175 - Taking wt - 45 k down & packing off - unable to wash through Notified Rig Superintendent - discision made to pull & LD casing & make clean out run 13:45 00:00 10.25 14,186 11,469 INTRM1 CASING PULL T Pump Out of the Hole and L/D 7 5/8" Casing f/ 14,186' to 11,469' MD (63 of 333 Jts) - 3 BPM @ 300 Psi Page 13 of 79 Time Logs DateFrom To Dur S. Depth E. Depth Phase Code Subcode T Comment 2/27/2011 24 hr Summary Continue to L/D 7 5/8" Casing f/ 11,469' to 10,606' MD (250 As Remaining); Improper Hole Fill - OWFF (Static in 6 Minutes) - CBU - OWFF (Static in 12 Minutes) - Continue to Pump Out t/ 8,847' MD (210 Jts Remaining); Improper Hole Fill - CBU - OWFF (Static in 15 Minutes) - Continue to Pump Out t/ 7,133' MD (169 Jts Remaining); Improper Hole Fill - L/D HES Stage Collar - CBU, No Gas During Circulation 00:00 04:15 4.25 11,469 10,606 INTRM1 CASINGTRIP T Continue to Pump Out of the Hole Laying Down 7 5/8" Casing t/ 10,606' MD (Pulled 83 of 333 Jts) - 3 BPM @ 290 Psi - Hole Fill Incorrect 04:15 04:30 0.25 10,606 10,606 INTRM1 CASING OWFF T OWFF (Static in 6 Minutes) 04:30 05:45 1.25 10,606 10,606 INTRMI CASING CIRC T CBU Staging Pumps Up t/ 6 BPM @ 370 Psi - No Gas Observed at Bottoms Up 05:45 06:00 0.25 10,606 10,606 INTRM1 CASING OWFF T OWFF (Static in 12 mins.) 06:00 13:15 7.25 10,606 8,847 INTRM1 CASINGTRIP T Continue to pump out of hole laying down 7 5/8" casing f/ 10,606' to 8847' (Pulled 123 of 333 jts) pumping @ 3 bbls/min @ 200 psi - PU wt 220 SO wt 155 - Improper hole fill 13:15 14:45 1.50 8,847 8,847 INTRM1 CASING CIRC T Circ btms up while staging pump up to 6 bbls /min. @ 310 psi - Flow ck well static in 15 mins. 14:45 21:30 6.75 8,847 7,133 INTRM1 CASINGTRIP T Continue to pump out of hole laying down 7 5/8" casing f/ 8847' to 7,133' MD (Pulled 163 of 333 Jts) - 4 BPM @ 200 Psi - Improper Hole Fill 21:30 22:15 0.75 7,133 7,133 INTRMI CASING OWFF T OWFF (Decreasing to Static in 20 Minutes) - PJSM - Heat and UD HES Stage Collar on Bottom of Jt 170 22:15 00:00 1.75 7,133 7,133 INTRM1 CASING CIRC T CBU @ 6 BPM w/ 270 Psi - No Gas @ Bottoms Up 2/28/2011 Continue to Pump Out of the Hole While L/D Casing f/ 7,133' to 5,890' MD (139 As Remaining); Improper Hole Fill - OWFF (Static in 15 Minutes) - Continue to Pump Out of the Hole While UD Casing f/ 5,890' to 3,221' MD (77 Jts Remaining) - Pumped Bit Balling Sweep (Minimal Increase in Returns) - OWFF (Static in 10 Minutes) -Continue to Pump Out of the Hole While UD Casing t/ 848' MD (20 As Remaining) 00:00 05:00 5.00 7,133 5,890 INTRM1 CASINGTRIP T OWFF - Continue to UD Caisng f/ 7,133' to 5,890' MD (Pulled 194 of 333 Jts) - Hole Fill Incorrect 05:00 05:30 0.50 5,890 5,890 INTRM1 CASING OWFF T OWFF - Well static in 16 mins. 05:30 12:00 6.50 5,890 4,213 INTRM1 CASINGTRIP T Continue pumping out & laying down 7 5/8" casing f/ 5890' to 4213' (pulled & laid down 233 of 333 jts) 4 bbls/min @ 150 psi - PU wt. 150 SO wt. 138 12:00 14:30 2.50 4,213 3,221 INTRM1 CASINGTRIP T Continue pumping out & laying down 7 5/8" casing f/ 4213' to 3221' (256 jts laid down of 333 ) 14:30 17:30 3.00 3,221 3,221 INTRM1 CASING CIRC T Circ btms up @ 3221' - staging pump up to 8 bbls/min - Pumped bit balling sweep & circ out of hole - sweep brought little clay back. - Pulled up 20' w/ no pump - well swabbing - Flow ck well static in 10 mins. Page 14 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:30 00:00 6.50 3,221 848 INTRM1 CASING TRIP T Continue to L/D Casing t/ 848' MD (Pulled 313 of 333 Joints) 3/01 /2011 Continue to Pump Out of the Hole While L/D Casing f/ 848' to 220' MD (5 Jts Remaining) - OWFF (Static) - L/D Remaining Jts of Casing & Float Equipment - Clean/Clear the Rig Floor - Change Upper Rams t/ 3.5" X 6" VBR's - Test BOPE; Witness Waived by AOGCC Chuck Scheve - P/U BHA #3 to 227' MD - Slip & Cut Drill Line 00:00 02:30 2.50 848 220 INTRM1 CASING TRIP T Continue to Pump Out of the Hole While L/D Casing f/ 848' to 220' MD (5 Jts Remaining) 02:30 02:45 0.25 220 220 INTRM1 CASING OWFF T Monitor well (Static) 02:45 04:30 1.75 220 0 INTRM1 CASING PULD T Close Casing Rams - Heat Baker Locked Jts to 400° F and L/D Remaining Casing Joints 04:30 08:00 3.50 0 0 INTRM1 CASING RURD T Blow Down the Top Drive - Clean and L/D Casing Running Equipment - Clean & Clear the Rig Floor 08:00 08:15 0.25 0 0 INTRM1 WHDBO SFTY P PJSM on Changin Top Rams 08:15 10:30 2.25 0 0 INTRM1 WHDBO OTHR P Drain Stack - Change Top Rams f/ 7 5/8' Solid Body to 3 1/2" by 6" Variable Rams - Grease IBOP 10:30 12:00 1.50 0 0 INTRM1 WHDBO RURD P Pull Thin Walled Wear Ring - Set Test Plug - Fill Lines w/ Water for BOPE Test 12:00 16:30 4.50 0 0 INTRM1 WHDBO BOPE P Test BOPE as Follows: w/ 5" Test A Test Annular Preventer t/ 250/2500 Psi, Test Blinds, Upper & Lower Rams, Choke Manifold Valves 1-16, Auto & Manual IBOP, TIW, Dart, HCR/Manual Choke and Kill Valves t/ 250/3500 Psi, Perform Accumulator Test, Function Rams f/ the Remote Panel - AOGCC Inspector Chuck Scheve Waived Witnessing the Test 16:30 18:00 1.50 0 0 INTRM1 DRILL RURD T R/U to Handle BHA #3 18:00 21:15 3.25 0 227 INTRM1 DRILL PULD T P/U BHA #3 as Follows: Bit, Bit Sub w/ Float, XO, IBS, PWD, HCIM, DM, Pulser, 1 Std NMFDC's, 1 Std HWDP t/ 227' MD - Upload and Shallow Test MWD 21:15 23:30 2.25 227 227 INTRM1 RIGMNT SLPC P Slip & Cut Drill Line While T/S Electrical Problem 23:30 00:00 0.50 227 261 INTRM1 DRILL PULD T Continue to P/U BHA #3 t/ 261' MD 3/02/2011 Continue to RIH t/ 13,452' MD Stopping to Circulate and Condition @ 3,519', 6,356', 8,719', 11,083' and 13,452' MD - Circ and Condition Mud - Wash & Ream f/ 13,542' to 13,816' MD - Packed Off @ 13,670' MD (Worked Free), Reamed Hole Working "Tight" Spots f/ 13,743' to 13,749' MD - Drill String Packed Off @ 13,816' MD - Pulled t/ 13,746' and Regained Circulation - Pulled t/ 13,542' MD w/ Circulation - Condition Mud - OWFF (Static) - POOH on TT t/ 13,074' MD 00:00 02:30 2.50 261 3,519 INTRM1 DRILL TRIP T Continue to RIH w/ BHA #3 to Planned Circulation Point of 3,519' MD (Stand 30) Page 15 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02.30 03:15 0.75 3,519 3,519 INTRM1 DRILL CIRC T Stage Pumps Up t/ 750 GPM @ 2100 Psi w/ 60 RPM; Reduced Pump Rate to 675 GPM @ 1700 Psi Due to Trough Overflowing - Blow Down Top Drive - Began Processing Mud w/ Solids Control Van (From Pit 3 Discharge Into Pit 4) @ %: BPM Continuously Cuttings Over Shakers Mostly Fine Clays 03:15 05:15 2.00 3,519 6,356 INTRM1 DRILL TRIP T Continue to RIH w/ BHA #3 to Planned Circulation Point of 6,356' MD (Stand 60) 05:15 06:15 1.00 6,356 6,356 INTRM1 CASING CIRC T Stage Pumps Up t/ 750 GPM @ 2400 Psi w/ 120 RPM 9500 ft/lbs Tq. ECD 10.85 ppg Fine Clay Cuttings On Bottoms Up 06:15 08:15 2.00 6,356 8,719 INTRM1 CASINGTRIP T RIH from 6,356' to 8,719' PUW 177K SOW 132K 08:15 09:45 1.50 8,719 8,719 INTRM1 CASING CIRC T Stage Pumps Up t/ 750 GPM @ 2740 Psi w/ 120 RPM 11,500 ft/lbs Tq. ECD 10.78 ppg Small amount of Fine Cuttings throughout circulation 09:45 12:00 2.25 8,719 11,083 INTRM1 CASINGTRIP T RIH f/ 8,719'to 11,083' MD P/U 215, S/O 150 12:00 13:00 1.00 11,083 11,083 INTRM1 CASING CIRC T Circulate and Condition Mud - Staging the Rate Up to 750 GPM @ 2800 Psi Fine Clay Cuttings Throughout Circulation 13:00 15:00 2.00 11,083 13,452 INTRM1 CASINGTRIP T Continue to RIH f/ 11,083' to 13,452' MD P/U 265, S/O 170 15:00 17:15 2.25 13,452 13,452 INTRM1 CASING CIRC T Circulate and Condition Mud Staging Pumps up to 750 GPM@ 2920 Psi - Complete Mud Dilution and Process Returns Through the Solids Control Van ^� Page 16 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:15 21:00 3.75 13,452 13,542 INTRM1 CASING REAM T Wash & Ream f/ 13,542' to 13,816, MD; Packed Off @ 13,670' MD (Worked Free), Reamed Hole Working "Tight" Spots f/ 13,743' to 13,749' MD - Drill String Packed Off @ 13,816' MD, Rotary Stalled and Appeared to be Stuck, Worked Pipe as Deep as 13,828' MD - Pulled 80-100K Over Up Weight - Able to Work Pipe Free W/ Straight Pull @ 80-100K Over P/U - Regained Circulation @ 13,756' MD - Attempted Pulling w/ Rotary, Packed Off Again, Pulled U 13,746' and Regained Circulation - Pulled t/ 13,542' MD w/ Circulation 21:00 23:00 2.00 13,542 13,542 INTRM1 CASING CIRC T Circulate and Condition Mud @ 750 GPM w/ 2750 Psi - 120 RPM 23:00 00:00 1.00 13,542 13,074 INTRM1 CASINGTRIP T POOH on TT t/ 13,074' MD 3/03/2011 Continue to POOH t/ 6,061' MD - OWFF (Static) - Ream Through Tight Spot t/ 5,977' MD - POOH t/ 3,424' MD - Circ and Condition Mud While Standing Back t/ 3,235' MD - POOH w/ Pumps t/ 1,724' MD - OWFF (Static) - POOH t/ 690' MD - UD or S/B BHA #3 Components - R/U and P/U 3'/2" EUE Cement Stinger (913') - RIH on 5" DP t/ 7,528' MD 00:00 02:45 2.75 13,074 10,611 INTRM1 CASINGTRIP T Continue to POOH t/ 10,61 VIVID P/U 220, S/O 153 02:45 03:15 0.50 10,611 10,611 INTRM1 CASING CIRC T OWFF (Static) - Pump 20 Bbl, 10.7 PPG Dry Job 03:15 07:15 4.00 10,611 6,061 INTRM1 CASING TRIP T POOH on TT t/ 6,061' MD - Tight Hole P/U 165, S/O 135 07:15 07:30 0.25 6,061 6,061 INTRM1 CASINGOWFF T OWFF (Static) 07:30 08:30 1.00 6,061 5,977 INTRM1 CASING REAM T Ream Tight Spot f/ 6,061' to 5,977' MD - 120 RPM w/ 500 GPM @ 1080 Psi 08:30 11:00 2.50 5,977 31424 INTRM1 CASINGTRIP T POOH on TT t/ 3,424'MD; Worked Through Tight Spots @ 4,484' and 4,389' MD P/U 135, S/O 120 11:00 12:00 1.00 3,424 3,235 INTRM1 CASING CIRC T Circ and Condition Mud While Standing 2 Back to 3,235' MD - 750 GPM 1870 Psi w/ 120 RPM 12:00 12:15 0.25 3,235 3,046 INTRM1 CASINGTRIP T POOH on TT t/ 3,046' MD, Hole Fill Incorrect 12:15 14:15 2.00 3,046 1,724 INTRM1 CASINGTRIP T Pump Out of the Hole t/ 1,724' MD; 3 BPM @ 120 Psi - OWFF (Static) 14:15 16:00 1.75 1,724 690 INTRM1 CASINGTRIP T POOH on TT t/ 690' MD 16:00 17:00 1.00 690 0 INTRM1 CASING PULD T S/B and L/D BHA #3 Components per DD/MWD 17:00 18:00 1.00 0 0 INTRM1 CASING OTHR T Clean and Clear the Rig Floor 18:00 18:30 0.50 0 0 INTRM1 CEMEN' RURD T R/U to Handle Cement Stinger Page 17 of 79 Time Los Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:30 19:45 1.25 0 913 INTRM1 CEMEN- PUTB T P/U 3 1/2" EUE Tubing t/ 913' MD 19:45 00:00 4.25 913 7,528 INTRM1 CEMEN-TRIP T M/U 3 1/2 EUE to 4" XT 39 and 4" XT 39 to 4 1/2 IF Crossovers and RIH w/ Cement Stinger on 5" DP t/ 7,528' MD 3/04/2011 Continue to RIH w/ Cement String on 5" DP t/ 13,60T MD - Circ and Condition Mud - Set Lower Abandonment Plug w/ 15.8 PPG Class G Cement f/ 13,607' to 13,207' M_Q - POOH t/ 12,756' MD - Circulate Pipe Clean - POOH t/ 7,933' MD - Spot 30 Bbl Hi-Vis Pill t/ 7,744' MD - Begin Pumping Cement (Wrong Silo) - Circ Cement f/ Hole - Set Second Isolation Plug w/ 15.8 PPG Class G Cement f/ 7,744'- 7,344' MD - POOH t/ 6,862' MD - Circ Pipe Clean - S/B 11 Stands and L/D 5" DP t/ 913' MD 00:00 02:45 2.75 7,528 13,607 INTRM1 CEMEN-TRIP T Continue to RIH w/ Cement String on 5" DP t/ 13,607' MD (134 Stds and Single) 02:45 03:00 0.25 13,607 13,607 INTRM1 CEMEN"OWFF T OWFF 03:00 04:45 1.75 13,607 13,607 INTRM1 CEMEN"CIRC T Circ and Condition Mud Prior to Cementing; Stage Pumps Up t/ 12 BPM @ @ 1170 Psi 04:45 05:00 0.25 13,607 13,607 INTRM1 CEMEN-SFTY T PJSM on Lower Abandonment Plug - Blow Down the Top Drive 05:00 05:45 0.75 13,607 13,607 INTRM1 CEMEN" PLUG T Pump Lower Abandonment Plug as Follows: Pump 2 Bbls H2O and Pressrue Test Lines t/ 3000 Psi , Pump 20 Bbls 11.5 PPG Mud Push II, 53 Bbls of 15.8 PPG Glass G Cement, 3.3 Bbls 11.5 PPG Mud Push II 05:45 06:15 0.50 13,607 13,607 INTRM1 CEMEN' DISP T Displace Cement w/ 217 Bbls 10.2 PPG Mud - CIP 0615 - Est TOC 13,207' MD - ICP 1120 Psi @ 10 BPM; FCP 1420 Psi @ 10 BPM - 68 Bbl Pit Gain for Cement & Displacement 06:15 07:15 1.00 13,607 12,756 INTRM1 CEMEN-TRIP T Pull Out of Cement Plug t/ 12,756' MD @ 20 FPM 07:15 07:45 0.50 12,756 12,756 INTRM1 CEMEN' CIRC T Drop Drill Pipe wiper Ball and Circulate Pipe Clean @ 10 BPM w/ 810 Psi & 20 RPM 07:45 11:15 3.50 12,756 7,933 INTRM1 CEMEN-TRIP T POOH on TT t/ 7,933' MD 11:15 11:45 0.50 7,933 7,933 INTRM1 CEMEN-CIRC T Spot 30 Bbls High Vis Pill f/ 7,933'- 7,744' MD 11:45 12:00 0.25 7,933 7,744 INTRM1 CEMEN-TRIP T POOH t/ 7,744' MD 12:00 12:15 0.25 7,744 7,744 INTRM1 CEMEN-SFTY T PJSM on Setting Second Cement Plug 12:15 13:15 1.00 7,744 7,744 INTRM1 CEMEN"CMNT T Pump 2nd Stage Cement Plug as Follows: 2 Bbls Water, Pressure Test to 3,000 Psi, Pump 20 Bbls 11.5 PPG Mud Push, 12.6 Bbls 15.8 PPG Intermediate Cement (Wrong Silo) - Blow Down Cement Lines 13:15 15:00 1.75 7,744 7,744 INTRM1 CEMEN" CIRC T Circulate Cement Out of Hole @ 12 BPM w/ 860 Psi and 30 RPM 15:00 15:30 0.50 7,744 7,744 INTRM1 CEMEN" DISP T Displace Cement w/ 116.4 Bbls Mud @ 10 BPM; ICP 430 Psi, FCP 945 Psi Page 18 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15.30 16:00 0.50 7,744 7,744 INTRM1 CEMEN"CMNT T Pump Qannik Isolation Plug as Follows: Pump 2 Bbls Water, Pressure Test 3,000 Psi, Pump 12 Bbls 11.5 PPG Mud Push, 56.4 Bbls 15.8 PPG Cement, 3 Bbls 11.5 PPG Mud Push 16:00 17:00 1.00 7,744 6,862 INTRM1 CEMEN-TRIP T POOH t/ 6,862' MD 17:00 18:30 1.50 6,862 6,862 INTRM1 CEMEN" CIRC T Drop Drill Pipe Wiper Ball and Circulate Pipe Clean @ 10 BPM w/ 600 Psi and 30 RPM 18:30 19:15 0.75 6,862 5,821 INTRM1 CEMEN-TRIP T POOH on TT t/ 5,821' MD 19:15 19:30 0.25 5,821 5,821 INTRM1 CEMEN"CIRC T Pump 12 PPG 20 Bbl Dry Job 19:30 00:00 4.50 5,821 913 INTRM1 CEMEN'TRIP P L/D 5" DP While Waiting On Cement It/ 913' MD (157 Joints Laid Down) 3/05/2011 RIH w/ 3'/z" Tubing on 5" DP t/ 6,469' MD - Wash Down f/ 6,964' to 7,445' MD (Unable to Find Firm Cement) - POOH t/ 7,338' MD - CBU - Wash and Tag Firm Cement @ 7,469' MD (67' Above Top of Qannik) Witnessed by AOGCC Insp. Lou Gimaldi; State Requested Top Off Plug w/ Additional 200' of Cement w/o Requirement to Tag - Pumped 26.9 Bbls of 15.8 PPG Class G Cement f/ 7,465' to 7,265' MD (40% Excess) - POOH t/ 6,960' MD - Load Drill Pipe Wiper and Circ String Clean - OWFF (Static) - POOH t/ 3,650' MD - Spot 30 Bbl High-Vis Pill - POOH t/ 3,431' MD - Pump KOP; 54.5 Bbls of 17 PPG Class G Cement (Est TOC 3,031' MD) - POOH t/ 2,797' MD - Load Drill Pipe Wiper and Circ Surface to Surface to Clean String - Slip and Cut 120' Drill Line - POOH t/ 913' MD - L/D 3'/2' Tubing t/ 280' MD 00:00 03:00 3.00 913 6,964 INTRM1 CEMEN-TRIP T RIH with 3 1/2" tubing tail below 5" drill pipe from 913' to 6964' 03:00 04:45 1.75 6,964 7,445 INTRM1 CEMEN-WASH T Wash Down f/ 6,964' to 7,445' MD; 1 BPM w/ 130 Psi - Pressure Increased t/ 150-170 Psi @ 7,535' MD - Continued to Wash Down U 7,445' MD Unable to Find Cement but Appeared to be Washing - Pull Up to Give Cement More Time to Set (Time Since CIP 12 Hrs) 04:45 07:00 2.25 7,445 7,338 INTRM1 CEMEN- CIRC T POOH t/ 7,338' MD - Wait on Cement - CBU @ 10 BPM w/ 650 Psi 07:00 07:30 0.50 7,338 7,469 INTRM1 CEMEN-CIRC T Wash Down f/ 7,338' w/ 1 BPM / 130 Psi - located firm cement @ 7469' (67' above top of Qannik) Tag witnessed by Lou Grimaldi (AOGCC). 07:30 13:00 5.50 7,465 7,465 INTRM1 CEMEN" CIRC T Reciprocate pipe - Circulate and condition mud 6 bpm / 280 psi - Wait on Schlumberger to blend, load and transport cement and Mudpush to rig. ** State Inspector requested additional 200 linear foot plug w/ no need to tag plug again - Conferred with drilling engineer and agreed to request. Page 19 of 79 Time Logs Date From To Dur S. De th E. De th Phase -Code Subcode - T Comment 13.00 13:45 0.75 7,465 7,465 INTRM1 CEMEN-CMNT X With tubing tail @ 7465' - Line up to Dowell - pushed 2 bbls of water to fill lines - pressure test lines to 3000 psi - mixed and pumped 20 bbls of 11.5 ppg Mudpush, 26.9 bbls of 15.6 ppg G cement (130 sxs) - 3 bbls of 11.5 ppg Mudpush - switched to rig pumps and displaced to eqalization with 10.2 ppg mud - CIP @ 1343 hours - ETOC w/ 40% excess 7,269' - full returns throughout job 13:45 14:15 0.50 7,465 6,960 INTRMI CEMEN-TRIP X RD cement line - POOH from 7465' to 6,960' - observed proper hole fill volume 14:15 14:45 0.50 6,960 6,960 INTRM1 CEMEN-CIRC X Load wiper ball into drill pipe - Circulate to clear cement from drill pipe and tubing tail @ 10 BPM w/ 580 Psi / rotate @ 30 RPM pumped 160 bbls - Had full returns while circulating - Blow down top drive - flow check well, static 14:45 17:00 2.25 6,960 3,650 INTRM1 CEMEN-TRIP X POOH from 6,960' to 3,650' 17:00 17:30 0.50 3,650 3,650 INTRM1 CEMEN-CIRC X Pump 30 Bbl High-Vis Pill & Displace w/ 55 Bbls Mud 17:30 17:45 0.25 3,650 3,431 INTRM1 CEMEN-TRIP X POOH t/ 3,431' MD 17:45 18:00 0.25 3,431 3,431 INTRM1 CEMEN-SFTY X PJSM on Pumping KOP Cement 18:00 18:45 0.75 3,431 3,431 INTRM1 CEMEN" CMNT X Pump KOP as follows: Pump 2 Bbls of Water, Pressure Test Lines t/ 3000 Psi, Pump 40 Bbls of 11.5 PPG Mud Push, 54.5 Bbls of 17 PPG Class G Cement, 4.2 Bbls of Mud Push and 1 Bbl of Water 18:45 19:15 0.50 3,431 3,431 INTRMI CEMEN- DISP X Displace Cement w/ 41 Bbls of Mud @ 8 BPM; ICP 260 Psi FCP 610 Psi - 101 Bbl Pit gain Throughout Job (1 Bbl Loss) CIP 1915 19:15 19:45 0.50 3,431 2,797 INTRM1 CEMEN-TRIP X R/D Cement Equip and POOH t/ 2,797' MD 19:45 20:45 1.00 2,797 2,797 INTRMI CEMEN-CIRC X Drop DP Wiper and Circulate Sfc to Sfc @ 10 BPM w/ 300 Psi and 30 RPM 20:45 22:00 1.25 2,797 2,797 INTRMI RIGMNTSLPC P Slip and Cut 120' Drill Line 22:00 23:00 1.00 2,797 913 INTRMI CEMEN-TRIP X POOH on TT t/ 913' MD 23:00 23:30 0.50 913 913 INTRMI CEMEN- RURD X R/U to L/D 3 %" EUE Cement String 23:30 00:00 0.50 913 280 INTRMI CEMEN' PULD X L/D 3 %" Cement String t/ 280' MD 3/06/2011 Continue to L/D Cement String f/ 280' to 0' MD - Change Wear Ring - Run 3'/2' EUE Kill String t/ 2,177' MD (69 Jts) - RIH t/ 2,740' MD - WOC - Wash Down t/ 3,496' MD (Unable to Find Cement) - POOH t/ 2,177' MD - Stand Back Kill String - Change Wear Ring - P/U Clean Out BHA - RIH t/ 2,783' MD - Wash/Ream t/ 3,239' MD - Circulate Hole Clean - OWFF (Static) - POOH t/ 2,693' MD 00:00 00:45 0.75 280 0 INTRMI CEMEN' PULD X Continue of L/D 3'/2' EUE Cement String f/ 280' to 0' 00:45 01:00 0.25 0 0 INTRMI RPCOM RURD X Clear/Clean Rig Floor Page 20 of 79 Time Logs Date '' From To Dur S. De th E. De th Phase Code Subcode T Comment 01:00 01:30 0.50 0 0 INTRM1 WHDBO PULD X Change Wear Ring 01:30 03:45 2.25 0 2,177 INTRM1 RPCOM PULD X Run Kill String as Follows: WLEG, 69 Jts 3'/2" EUE Tubing, XO (EUE to XT39), XO (XT to 4'/2" IF) 2,177' MD 03:45 04:00 0.25 2,177 2,177 INTRM1 RPCOM RURD X Change Elevators - R/D Tubing Tongs 04:00 04:15 0.25 2,177 2,740 INTRM1 RPCOM TRIP X RIH w/ Tubing on 5" DP t/ 2,740' MD 04:15 10:45 6.50 2,740 2,740 INTRM1 RPCOM WOC X WOC - Clean Pits and Rig, Prep for Move - Monitor Well on TT 10:45 12:15 1.50 2,740 3,496 INTRM1 RPCOM WASH X Wash Down f/ 2,740' to 3,496' MD; 2 BPM w/ 90 Psi - Unable to Find Cement 12:15 13:30 1.25 3,496 3,496 INTRM1 RPCOM CIRC XT CBU @ 10 BPM w/ 600 Psi - Treat and Condition Mud - On Bottoms Up Noted Cuttings of Gelatin Consistency Across the Shakers 13:30 14:30 1.00 3,496 2,177 INTRM1 RPCOM TRIP XT POOH t/ 2,177' MD 14:30 15:00 0.50 2,177 2,177 INTRM1 RPCOM RURD XT R/U Tubing Handling Equipment 15:00 17:00 2.00 2,177 0 INTRM1 RPCOM TRIP XT Stand Back 69 Jts of 3'/2' EUE Kill String 17:00 17:30 0.50 0 0 INTRM1 RPCOM OTHR XT Clean and Clear the Rig Floor 17:30 18:15 0.75 0 0 INTRM1 WHDBO PULD P Change Wear Ring 18:15 19:00 0.75 0 140 INTRM1 RPCOM PULD XT P/U Bit, Bit Sub, XO, IBS, 1 Std NMFDC's, Jars,U 140' MD 19:00 20:15 1.25 140 2,783 INTRM1 RPCOM TRIP XT RIH w/ BHA #4 on 5" DP t/ 2,783' MD 20:15 22:00 1.75 2,783 3,239 INTRM1 RPCOM WASH XT Wash/Ream U 3,239' MD @ 10 BPM w/ 500 Psi and 120 RPM 22:00 22:45 0.75 3,239 3,239 INTRM1 RPCOM CIRC XT Circ Surf to Surf @ 10 BPM w/ 480 Psi; Noted More Gelatin Like Cuttings on Bottoms U 22:45 23:00 0.25 3,239 3,239 INTRM1 RPCOM OWFF XT OWFF (Static) 23:00 00:00 1.00 3,239 2,693 INTRM1 RPCOM TRIP XT POOH on TT t/ 2,693' MD 3/07/2011 Continue to POOH t/ 140' MD - L/D BHA Clean Out BHA - M/U CIBP, RIH and Set @ 3,138' MD - Disengage from CIBP and Pressure Test to 2500 Psi f/ 10 Minutes - POOH L/D Running Tool - Test BOPE w/ 3 1/2" Test Joint t/ 250/2500 Psi (Annular) and 250/3500 Psi (Rams) - P/U 3 1/2" EUE Kill String and RIH on 5" DP t/ 3,128' MD - Displace Well t/ 9.6 PPG Inhibited/Uninhibited Brine - POOH t/ 2,145' MD - M/U and Land Tubing Hanger w/ TWC Installed (Tail @ 2,180' MD) - Test Hanger Seals t/ 5000 Psi f/ 10 Minutes - Test TWC in Direction of Flow t/ 2500 Psi f/ 10 Minutes - N/D BOPE - N/U Tree - Test Upper Hanger Seals and Tree t/ 5000 Psi f/ 10 Minutes - Pull TWC and R/U to Freeze Protect Well. 00:00 00:45 0.75 2,693 140 INTRM1 DRILL TRIP XT Continue to POOH 2,693' to 140' MD 00:45 01:15 0.50 140 0 INTRM1 DRILL PULD XT Stand Back Drill Collars, Break Bit and L/D Remaining BHA Items 01:15 02:00 0.75 0 0 INTRM1 DRILL PULD XT Remove BHA Components f/ the Floor - P/U Cement Retainer 02:00 02:30 0.50 0 0 INTRM1 DRILL PULD XT PJSM - M/U Cement Retainer and XO's; OD of Cement Retainer 9.44" 02:30 04:45 2.25 0 3,138 INTRM1 DRILL TRIP XT RIH w/ Cement Retainer on 5" DP U 3,138' MD (Middle of 10 3/4" Jt #3) - P/U 130, S/O 115 04:45 05:15 0.50 3,138 1 3,138 INTRM1 DRILL PLUG XT Set CIBP @ 3,138' MD per BOT Rep Page 21 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:15 05:45 0.50 3,138 3,128 INTRM1 DRILL PRTS XT P/U to 3,128' MD and Pressure Test CIBP and Surface Casing t/ 2500 Psi f/ 10 Minutes (Lost 0 Psi) 05:45 06:00 0.25 3,128 3,128 INTRM1 DRILL RURD XT Open Rams, R/D Pressure Testing Manifold and Blow Down Kill Line 06:00 07:45 1.75 3,128 0 INTRM1 DRILL TRIP XT POOH - Lay down running tool - clean up rig floor 07:45 08:15 0.50 0 0 INTRM1 DRILL OTHR X Pull wear ring and set test plug with 3 1/2" test joint 08:15 09:30 1.25 0 0 INTRM1 WHDBO BOPE X Test annular preventor to 250 / 2500 psi - test top pipe rams to 250 / 3500 psi - pull test plug and set retrievable wear bushing 09:30 10:00 0.50 0 0 INTRM1 RPCOM RURD XT PJSM - change running tools to 3 1/2" - RU tubing tongs 10:00 11:30 1.50 0 2,142 INTRM1 RPCOM TRIP XT RIH with 3 1/2", 9.2#, L-80 tubing to 2142' 11:30 12:00 0.50 2,142 2,142 INTRM1 RPCOM OTHR X RD tubing tongs - change running tools to 5" 12:00 12:30 0.50 2,142 3,128 INTRM1 RPCOM TRIP X RIH with 5" drill pipe from 2142' to 3128' 12:30 12:45 0.25 3,128 3,128 INTRM1 RPCOM SFTY X PJSM on displacing well to brine 12:45 15:00 2.25 3,128 3,128 INTRM1 RPCOM CIRC X Displaced well with 150 bbls of fresh water, 150 bbls of 9.6 ppg Nacl brine, 150 bbls of 9.6 ppg Nacl brine with corrosion inhibitor - 20 bbls of 10 ppg nacl brine - hole cleaned up well. 15:00 15:30 0.50 3,128 2,145 INTRM1 RPCOM TRIP X POOH to 2145' 15:30 16:00 0.50 2,145 2,154 INTRM1 RPCOM RURD X R/U Tubing Handling Equipent - Pull Wear Ring 16:00 17:00 1.00 2,154 2,180 INTRM1 RPCOM HOSO X M/U Tubing Hanger w/TWC Installed - Land w/Tail @ 2,180' MD 17:00 18:00 1.00 2,180 2,180 INTRM1 WHDBO PRTS X Test Hanger Seals t/ 5000 Psi f/ 10 Minutes 18:00 18:30 0.50 2,180 2,180 INTRM1 WHDBO PRTS X R/U Hard Lines and Test TWC in Direction of Flow U 2500 Psi f/ 10 Minutes 18:30 19:00 0.50 2,180 0 INTRM1 WHDBO RURD X R/D Hard Lines and L/D Landing Joint B 19:00 22:00 3.00 0 0 INTRM1 WHDBO NUND X N/D Riser and BOPE Stack 22:00 23:00 1.00 0 0 INTRM1 WHDBO NUND X N/U Tree 23:00 23:30 0.50 0 0 INTRM1 WHDBO PRTS X Test Hanger Top Seals t/ 5,000 Psi f/ 10 Minutes - Test Tree t/ 5000 Psi f/ 10 Minutes 23:30 00:00 0.50 0 0 INTRM1 DRILL RURD X Pull TWC - R/U Hard Lines and Manifold to Freeze Protect 3/08/2011 LDDC's. Install BPV. Secure well for move off to next well. Release rig at 06:00 hrs. 00:00 00:45 0.75 0 0 INTRM1 DRILL RURD X Continue to R/U to Freeze Protect Well 00:45 01:00 0.25 0 0 INTRM1 DRILL SFTY X PJSM on Freeze Protect 01:00 03:00 2.00 0 0 INTRM1 DRILL FRZP X Freeze Protect Well w/ 155 Bbls Diesel - Allow to U-Tube Across Manifold Page 22 of 79 Time Logs Date from To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 04:00 1.00 0 0 INTRM1 DRILL RURD X Blow Down and Rig Down Hard Lines and Manifold - Clean Cellar & Pits 04:00 04:30 0.50 0 0 INTRM1 WHDBO OTHR X Set BPV w/ FMC Lubricator 04:30 05:00 0.50 0 0 INTRM1 DRILL PULD X Install Mouse Hole - L/D Drill Collars. 05:00 06:00 1.00 0 0 INTRM1 DRILL RURD X Secure well. Pump out cellar. Release rig for move to CD3-125. Move rig from CD3-119 to CD3-127, Rig acceptance @ 1500 HES 4-24-2012 RU, pull BPV, displace out diesel freeze protection to 9.6 brine, PSI test casing to 3500 psi, set BPV, test BPV, 00:00 01:00 1.00 0 0 INTRM1 MOVE MOB P Move MI Swaco ball mill away from rig. Rig is on CD3-119, moving 160' to CD3-127. Sim ops: Pre job safety meeting, then prepare pits and motors to move away from rig. Jacking pipe shed to move away. Cleaning drip pans. 01:00 01:15 0.25 0 0 INTRM1 MOVE SFTY P PJSM, Rig Move 01:15 01:30 0.25 0 0 INTRM1 MOVE RURD P Continue working to ready pipe shed and pits/motors. 01:30 02:00 0.50 0 0 INTRM1 MOVE MOB P Move pits/motors away from sub. 02:00 03:30 1.50 0 0 INTRM1 MOVE RURD P Skid rig floor, raise windwalls, raise feet. 03:30 06:45 3.25 0 0 INTRM1 MOVE MOB P Pull Sub off CD3-119, move and spot Sub on CD3-127. 06:45 07:15 0.50 0 0 INTRM1 MOVE RURD P Lower and set feet, lower and secure windwalls. 07:15 08:15 1.00 0 0 INTRM1 MOVE RURD P PJSM and skid floor to drilling position. 08:15 09:15 1.00 0 0 INTRM1 MOVE MOB P PJSM and spot pits and motor complexes. 09:15 12:00 2.75 0 0 INTRM1 MOVE MOB P Spot pipe shed and ball mill. RU service lines 12:00 15:00 3.00 0 INTRM1 MOVE MOB P PJSM, r/u service lines, rig up hard lines to tiger tank and test lines with air, take on water to rig. Rig acceptance 1500 hrs 4/24/2012 15:00 17:00 2.00 INTRM1 RIGMNT RGRP T trouble shoot electrical & change out braker f/ generator # 3 and cold start. change out fuseable link on engines #3and 4 17:00 18:00 1.00 INTRM1 WHDBO RURD P PJSM, pull tree cap, and rig up FMC lubricator 18:00 18:15 0.25 INTRM1 WHDBO PRTS P Test lubricator @ 2500 psi, for 5 min, pull BPV 18:15 18:45 0.50 INTRM1 WHDBO PRTS P PJSM, Test lines to tiger tank @ 500 psi, blow lines down w/air 18:45 19:15 0.50 INTRM1 WHDBO PRTS P Test lines U well head (TBG side) @ 2000 psi for 5 min. Page 23 of 79 of Time Logs Date From To Dur S. De th E. De th Phase .<Code Subcode T Comment 19:15 21:45 2.50 INTRM1 RPCOM CIRC P PJSM, Displace diesel w/ 41 bbls safe surf- o, 229 bbls 9.6 ppg brine, @ ICP = 1160 psi - FCP = 7.5 BPM / 2020 PSI change 2 chik-sans on hard line due to failure, and ran steam through hard line, check all unions 21:45 22:00 0.25 INTRM1 RPCOM CIRC P Shut in annulas and B/D lines 22:00 22:45 0.75 INTRM1 RPCOM DHEQ P PJSM, Test casing @ 3500 psi, F/ 30 min, 4 bbl T/ pressure up, 2.5 bbls back to pits 22:45 23:15 0.50 INTRM1 RPCOM RURD P B/D hard line to TBG & R/D 23:15 23:30 0.25 INTRM1 WHDBOTHGR P Set BPV 23:30 00:00 0.50 INTRM1 RPCOM THGR P Test BPV T/ 1000 psi, F/ 10 min Pump down annulas 4/25/2012 Observe well static, ND tree, NU BOP's, body test BOP's, LID 3.5" kill string, test BOPE, MU 9-7/8" clean out ass 00:00 00:15 0.25 0 0 INTRM1 RPCOM THGR P Continue test BPV to 1000 psi for 10 min in direction of flow. 00:15 01:00 0.75 0 0 INTRM1 RPCOM OWFF P Observe well for 30 min, static. 01:00 03:30 2.50 0 0 INTRM1 WHDBO NUND P ND tree, install FMC blanking plug, NU BOP's, tighten choke line. 03:30 06:15 2.75 0 0 INTRM1 WHDBO PRTS P RU, fill stack, shell test BOP stack 250/3500 psi for 5 min. Test gas alarms. 06:15 06:30 0.25 0 0 INTRMI WHDBOTHGR P Pull FMC blanking plug, pull BPV. 06:30 07:00 0.50 0 0 INTRM1 RPCOM RURD P RU to pull 3-1/2" tubing kill string. 07:00 09:15 2.25 2,179 1,611 INTRM1 RPCOM PULD P PJSM and pull Hgr free with 82K (80K string wt) LID 3-1/2" tubing kill string from 2179'. 09:15 09:30 0.25 1,611 1,611 INTRM1 RPCOM RURD P Change out power tongs. 09:30 11:30 2.00 1,611 0 INTRM1 RPCOM PULD P Continue LD 3-1/2" tubing kill string. 68 As total. 11:30 12:30 1.00 0 0 INTRM1 RPCOM RURD P RD Tbg equipment, observe well static. 12:30 13:30 1.00 0 0 INTRM1 WHDBO RURD P Change out elevators, install Dbl valve on annulus, drain stack, clear floor. 13:30 14:00 0.50 0 0 INTRM1 WHDBO RURD P PJSM and RU for BOP test. Page 24 of 7'9 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:00 20:45 6.75 0 0 INTRM1 WHDBO PRTS P Install test plug - RU to test BOPE - Tested BOPE as follows: Tested annular to 250 & 2500 psi - 3.5" x 6" pipe rams - choke & kill lines - choke manifold valves - TD IBOP's - floor safety & dart valves to 250 & 3500 psi - performed accumulator recover test - Pulled 4" test jt. - Tested blind rams to 250 & 3500 psi - Perform Koomey test - MU 3 1/2" test jt - Tested pipe rams to 250 & 3500 psi - Tested annular to 250 & 2500 psi LD 3 1 /2" test jt. - Tested manual & hydraulic chokes - Witnessing of test waived by Lou Grimaldi AOGCC 20:45 21:15 0.50 0 INTRM1 WHDBO PRTS P Pull test plug, drain stack and install W/R ( 10.3 ID) 21:15 21:30 0.25 INTRMI WHDBO PRTS P B/D choke and kill lines 21:30 22:00 0.50 INTRMI RPCOM OTHR P PJSM, Move DP F/ ODST/ DS ( 14 stds) 22:00 00:00 2.00 INTRM1 RPCOM PULD P M/U BHA as per detail T/192' 4/26/2012 M/U clean -out assy, RIH, tag bridge plug at 3137', displace to 9.6 ppg LSND mud, drill bridge plug, safety stand down, cont drill bridge plug, ream/ push retainer to 3544', pump NP sweep around and condition mud, BROOH into casing, circ hole clean, Pump out of hole, LD BHA, P/U stack wash tool and wash out stack. 00:00 01:45 1.75 0 781 INTRMI DRILL PULD P PJSM and continue MU BHA as per Sperry DD to 781'. 01:45 03:45 2.00 781 3,137 INTRM1 DRILL TRIP P RIH with 4" DP from derrick. Tag bridge plug at 3137'. PUW = 115K, SOW = 107K. 03:45 04:45 1.00 3,137 3,137 INTRM1 DRILL CIRC P PJSM and displace well from 9.6 ppg brine to 9.6 ppg LSND mud with 35 bbls high vis spacer and 284 bbls mud at 650 gpm at 1220 psi, 30 rpm at 6K torque. 04:45 06:15 1.50 3,137 3,137 INTRM1 DRILL DRLG P Drill on bridge plug with 650 gpm at 1250 psi, 120 rpm at 6.5K torque. 06:15 06:45 0.50 3,137 3,137 INTRM1 DRILL SFTY P PU 30', blow down top drive, flow check static. Safety stand down meeting. 06:45 07:45 1.00 3,137 3,163 INTRMI DRILL DRLG P Continue drilling bridge plug from 3137'. 650 gpm at 1260 psi, 140 rpm at 7.5K torque. Through at 3138'. Continue to push and ream remainder of retainer to stand down at 3163'. 07:45 08:00 0.25 3,163 3,228 INTRMI DRILL TRIP P Attempt RIH, took 10k weight at 3228'. 08:00 11:00 3.00 3,228 3,544 INTRMI DRILL REAM P Ream from 3228' to 3544'. 650 gpm at 1320 psi, 120-140 rpm at 7.5 to 9.5K torque, 15-20K WOB. (Safety stand down with second crew at re -tour meeting) 11:00 12:00 1.00 3,544 3,544 INTRM1 DRILL CIRC P Pump 33 bbl high vis nut plug caliper sweep around. 750 gpm at 1910 psi, sweep back 20 bbls early. Cont circ and condition mud. Page 25 of 79 Time Logs Date From To : Dur S. De th E. De th Phase Code Subcode T Comment 12:00 12:45 0.75 3,544 3,067 INTRM1 DRILL REAM P BROOH to shoe at 3239', continue backreaming to 3067' to clean up. (Dropped hollow 2-3/8" drift at 3449') 750 gpm at 1990 psi, 140 rpm at 8.51K torque. 12:45 14:00 1.25 3,067 3,067 INTRM1 DRILL CIRC P Flow check static, circulate and clean up casing. Took 4.5 bottoms up to clean up clay cuttings. 750 gpm at 1790 psi, 140 rpm at 8K torque. 14:00 15:00 1.00 3,067 2,781 INTRM1 DRILL TRIP P POOH on trip tank three stands. Observed 25K overpull at 2826', slacked off and PU overpull gone. Insufficient hole fill. 15:00 19:45 4.75 2,781 229 INTRM1 DRILL TRIP P Flow check static, Pump OOH to Jars. 22 bbls talc hole fill, 35 bbls actual. 19:45 20:15 0.50 229 INTRM1 DRILL TRIP P C/O elevators, B/D top drive, line up on TT 20:15 20:30 0.25 INTRM1 DRILL TRIP P PJSM, L/D BHA 20:30 21:00 0.50 INTRM1 RIGMNTSVRG P Service rig 21:00 22:45 1.75 INTRM1 DRILL TRIP P Continue laying down BHA 22:45 23:00 0.25 INTRM1 DRILL OTHR P Change out elevators and M/U stack washer on std of drill pipe 23:00 00:00 1.00 INTRM1 DRILL OTHR P Wash out stack @ 16 BPM - 120 PSI, B/D top drive 4/27/2012 Wash out stack, RU, PJSM, RIH w/ 7-5/8" ECP on 3.5" EUE tubing, R/D tubing tools, MU x-o, RIH on 4" dp to 2883', hanging up, attempt work past, no go, POOH to tubing, repair Dwks/dynomatic linkage, POOH w/ ECP, MU and RIH with Baker clean -out assy. 00:00 00:15 0.25 INTRM1 PLUG SFTY P Pre job safety meeting. 00:15 00:45 0.50 INTRM1 PLUG OTHR P Clean and clear rig floor. 00:45 01:15 0.50 INTRM1 PLUG RURD P Change elevators, rig up 3.5" tubing equipment. 01:15 01:30 0.25 INTRM1 PLUG SFTY P Pre job safety meeting on running Baker 7-5/8" External casing packer on 3.5" 9.3 ppf L-80 EUE tubing and 4" drill pipe. 01:30 04:30 3.00 0 939 INTRM1 PLUG TRIP P Pick up/ Make up Baker 7-5/8" IsoZone exernal casing packer on 3.5" 9.3 ppf L-80 EUE tubing (29 jts) Fill every jt from the top. PU wt 76k, SO wt 77k, blocks 72k. 04:30 04:45 0.25 939 939 INTRM1 PLUG SFTY P Pre job safety meeting. 04:45 05:00 0.25 939 939 INTRM1 PLUG RURD P Rig down3.5" equipment, rig up 4" elevators. 05:00 07:00 2.00 939 2,843 INTRM1 PLUG TRIP P Make up 4" XT39 x 3-1/2" EUE crossover. Run 7-5/8" Baker ECP in the hole f/ 939' to 2843' on 4" drill pipe. Work past obstruction from 2748' to 2843' with out pump, no over pull. Appears pushing some junk. Page 26 of 79 Time Logs' Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:00 08:00 1.00 2,843 2,883 INTRMI PLUG TRIP P Wash/work down from 2843' to 2883'. 42 gpm at 140 psi, 126 gpm at 190 psi. No success pushing or getting past junk. 08:00 08:15 0.25 2,883 2,843 INTRMI PLUG TRIP P POOH, Stand back stand w/o pump, 25K overpull at 2873'. Pick up 100k Down wt. 100K 08:15 12:45 4.50 2,843 912 INTRMI PLUG TRIP P Blow down TD, flow check static, POOH on elevators from 2843' to 912'. 20K overpull at 2730'. 12:45 13:00 0.25 912 912 INTRMI PLUG RURD P RU to stand back 3.5" tubing. 13:00 17:00 4.00 912 912 INTRM1 PLUG RGRP T PJSM and repair drawworks 17:00 19:30 2.50 912 0 INTRM1 PLUG TRIP P PU single 3.5" tubing and rack back 10 stds tubing. LD ECP. Lots of clay on ECP, recovered alot more slip segments stuck to clay. ECP rubber had a deep slice over a couple feet. Calc disp = 19.8 bbls, Act disp = 21 bbls. Pictures are posted on S drive, in CD3-127 folder 19:30 20:00 0.50 0 0 INTRM1 PLUG RURD P Clean and clear floor, PU Baker BHA equipment to floor. 20:00 21:30 1.50 0 0 INTRMI PLUG PULD P PU Baker BHA equipment to floor. 21:30 21:45 0.25 INTRMI PLUG SFTY P PJSM on picking up BHA 21:45 22:45 1.00 INTRMI PLUG PULD P Pick up BHA 22:45 23:00 0.25 INTRMI PLUG SFTY P PJSM 23:00 23:45 0.75 INTRMI PLUG RURD P C/O elevators & continue picking up BHA 23:45 00:00 0.25 INTRM1 PLUG RURD P C/O iron roughneck heads 4/28/2012 RIH w/ Baker Jet/Boot Bskts/Scpr to 3501', POOH to 3102', pump weighted sweep around, POOH to 2816', RIH to 3501' to ensure clean, POOH to 3198', pump weighted sweep around, POOH LID BHA, Run new 7-5/8" ECP packer to 3467' shoe depth, top @ 3441' top of external casing packer. Dowell pump cement job, rig displace w/ 9.6 ppg mud. 00:00 02:00 2.00 338 2,721 INTRM1 PLUG TRIP P RIH w/ Baker rev circjunk basket from 338' to 2721', brk circ every 5 stds. 02:00 02:30 0.50 2,721 2,721 INTRM1 PLUG CIRC P CBU at 650 gpm, 800 psi, PUW = 110K, SOW = 100K 02:30 02:45 0.25 2,721 2,936 INTRM1 PLUG TRIP P Continue RIH f/ 2721' to 2936', taking 10-15K weight. 02:45 05:45 3.00 2,936 3,501 INTRMI PLUG TRIP P Wash down f/ 2911' to 3501', taking weight. 650 gpm at 820 psi, PUW = 115K, SOW = 110K Taking weight @ 2941', 2944', 3038', 3072', 3362', 3387' and 3501' 05:45 06:30 0.75 3,501 3,102 INTRMI PLUG TRIP P Pump OOH from 3501' to 3102'. 6 bpm at 280 psi. 06:30 07:00 0.50 3,102 3,102 INTRMI PLUG CIRC P Pump 30 bbl weighted (11.9 ppg) high vis NP( 5 sx) sweep around. 750 pm at 1280 psi, 20 rpm at 7K tq. Page 27 of 79 Time Logs Date from To Dur S. De th E. De th Phase'. Code Subcode T Comment 07:00 07:30 0.50 3,102 2,816 INTRMI PLUG TRIP P Flow check static, POOH on trip tank from 3102' to 2816'. 07:30 08:30 1.00 2,816 3,501 INTRM1 PLUG TRIP P RIH from 2816' to 3501'. All good. 08:30 08:45 0.25 3,501 3,198 INTRM1 PLUG TRIP P POOH on trip tank from 3501' to 3198'. PUW = 120K, SOW = 105K 08:45 09:30 0.75 3,198 3,198 INTRM1 PLUG CIRC P Pump 31 bbl weighted (11.6 ppg) high vis NP ( 5 sx) sweep around. 750 gpm at 1280 psi, 20 rpm at 7.5K tq. 09:30 12:30 3.00 3,198 338 INTRM1 PLUG TRIP P Blow dwn TD, flow check static, POOH on trip tank from 3198' to 338'. 12:30 14:15 1.75 338 0 INTRM1 PLUG PULD P Flow check static, PJSM, LD BHA (Std back 3 stds 5" HWDP) 14:15 15:30 1.25 0 0 INTRM1 PLUG RURD P Clean and clear floor, RU to run 3.5" tubing. 15:30 15:45 0.25 0 0 INTRMI PLUG SFTY P PJSM 15:45 16:00 0.25 0 30 INTRM1 PLUG PULD P MU Baker 7-5/8" ECP 16:00 17:15 1.25 30 907 INTRMI PLUG TRIP P RIH w/ ECP on 29 jts 3.5" tubing cement stinger from derrick. LD single. 17:15 17:30 0.25 907 907 INTRMI PLUG RURD P Change out elevators 17:30 20:15 2.75 907 3,432 INTRMI PLUG TRIP P RIH w/ ECP with 22 stds 4" DP from derrick, 15' pup and 4 more stds 4" DP to 3432' 20:15 20:30 0.25 3,432 3,467 INTRMI PLUG TRIP P PU 2 singles 4" DP and place ECP on depth, bottom at 3467' 20:30 20:45 0.25 3,467 3,467 INTRM1 PLUG CIRC P Circulate pipe volume. 2 bpm at 160 psi, 4 bpm at 210 psi, 5 bpm at 240 psi, 36 bbls total 20:45 21:15 0.50 3,467 3,467 INTRM1 PLUG CIRC P Brk pipe and insert DP pump down plug. Pump down at 2 bpm, 140 psi, reduced rate to 1 bpm, 110 psi 5 bbls before calc latch. Latched up wiper plug with 370 psi indication 4.5 bbls late, pumped 1 more bbl to bump plug with 500 psi. 21:15 22:00 0.75 3,467 3,441 INTRM1 PLUG PACK P Inflate Baker 7-5/8" ECP: Stage pressure up from 1000 psi at 200 psi increments. At 1920 psi, pressure drop to 1420 psi indicated packer inflation. Increased pressure back to 1920 psi with .25 bbls indicating packer inflated to 10.375" hole size. Bled of all pressure to close pkr valve. Pressure back up and successfuly release from packer with 2900 psi. Left shoe at 3467', bottom of element at 3455', top of element at 3445' and top of assy at 3441'. 22:00 22:30 0.50 3,441 3,439 INTRMI PLUG RURD P LD single 4" DP, blow down top drive, RU cement lines. 22:30 23:15 0.75 3,439 3,439 INTRMI PLUG CIRC P Circulate and condition mud at 5 bpm, 150 psi. 23:15 23:30 0.25 3,439 3,439 INTRMI PLUG SFTY P PJSM on cement job. Page 28 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:30 00:00 0.50 3,439 3,439 INTRM1 PLUG CMNT P Dowell mix mud push to 11.5 ppg. Dowelll pump .6 bbl, pressure test lines to 3000 psi. Dowell continue to pump a total of 23.1 bbls of mud push @ 4.5 bpm w/ 250 psi final pressure. Dowell mix 17 ppg cement. Pumping 17 ppg cement (yield 1 cuft/sx, water 3.87 gal/sx, additives D046 .2% BWOC, D065 1.0 BWOC, D167 .2 BWOC, thickening time 5 hr 26 min) @ 4.7 bpm w/ 860 psi initial pressure and 4.3 bpm w/ 600 psi final pressure. Pumped a total of 84.2 bbls, 473 sx, follow w/ 3.6 bbls (2.6 bbls in the pipe) of 11.5 ppg mud push. Rig displace w/ 9.6 ppg LSND mud pumping 6 bpm till caught up w/ cement. Took 13 bbls to catch cement. Reduced rate to 4 bpm w/ 220 psi. Pumped 21.5 bbls to balance cement (cut 5 bbls short). Shut down, check valves and well balanced. Full returns through -out job. Shut down @ 0012 hrs 4/29/2012. 4/29/2012 RD Cmt line, pull out of cement plug to 3039', circ out 25 bbls excess cement with wiper ball and 20 bbls water to clean pipe, displaced to 9.7 ppg brine, spotted inhibited brine, POOH sideways, LID pipe from derrick, slip and cut drlg line, ran 3.5" tubing kill string to 2176.07', tested hanger seals, WOC. 00:00 01:00 1.00 3,439 3,039 INTRM1 PLUG TRIP P RD, blow down lines, POOH from 3439' to 3039'. 108K Up, 103K Dwn. 01:00 03:30 2.50 3,039 3,039 INTRM1 PLUG CIRC P Load wiper plug, pump 20 bbls water and circ at 650 gpm 1170 psi to clean pipe. Observed mud push and 25 bbls excess cement returned to surface. 03:30 05:00 1.50 3,039 3,039 INTRM1 PLUG CIRC P PJSM and displace to 9.7 ppg brine as follows: Pumped 34 bbls hi vis spacer followed with 340 bbls 9.7 ppg brine followed with 72 bbls inhibited 9.7 ppg brine, spot on bottom. 550 gpm at 1040 psi. 05:00 08:30 3.50 3,039 313 INTRM1 PLUG PULD P POOH laying down 4" DP and 3.5" cement strin /ECD running tool. 08:30 08:45 0.25 313 313 INTRM1 PLUG SFTY P H2S drill - Alarm sounded, rig evacuated, determined false alarm. 08:45 09:15 0.50 313 0 INTRM1 PLUG PULD P Cont LD 3.5" cement string to shed. 09:15 09:45 0.50 0 0 INTRM1 PLUG RURD P RD Tbg equip, clear floor. 09:45 10:30 0.75 0 0 INTRM1 WHDBO RURD P Pull wear ring, install tubing running wear ring. 10:30 12:45 2.25 0 0 INTRM1 PLUG PULD P PJSM and LID tubulars from derrick: 5" HWDP and 4" DP VIA mousehole. 12:45 14:00 1.25 0 0 INTRM1 RIGMNT SLPC P PJSM and slip and cut 60' drilling line. 14:00 14:45 0.75 0 0 INTRM1 RIGMNT SVRG P Service top drive, drawworks and iron roughneck. Page 29 of 79 Time Logs Date - From To Dur S. De th E. De th Phase Code Subcode T Comment 14:45 15:15 0.50 0 0 INTRMI RPCOM RURD P RU to run 3.5" kill string. 15:15 18:00 2.75 0 2,139 INTRM1 RPCOM PULD P PJSM and run 68 jts, 3.5", 9.2#, L-80 tubing kill string to 2139'. 85K Up, 85K dwn. 18:00 18:45 0.75 2,139 2,139 INTRM1 WHDBO RURD P MU retrieval tool and retrieve wear ring. 18:45 19:30 0.75 2,139 2,176 INTRM1 RPCOM HOSO P MU tubing hanger with TWC installed. Land with tail at 2176' MD. 19:30 20:00 0.50 2,176 2,176 INTRM1 WHDBO PRTS P RU and test hanger seals to 5000 psi for 10 minutes. 20:00 00:00 4.00 2,176 0 INTRM1 PLUG WOC P While waiting on cement to cure: Attempt to calibrate the top drive torque- Rig electricain doesn't have enough information /or wrong procedure. Lay down landing joint B. Lay down mouse hole. Clean rig floor and drains. Perform work orders. Remove iron roughneck and rotary table top so as to clean cavity of rotarty table. 4/30/2012 Test 10-3/4" csg/cement top @ 3039'/TWC to 1500psi-OK. Nipple down, NU 4-1/6" FMC Horiz tree, test void to 5000 psi, test tree to 5000 psi, freeze protect- "U" tube diesel to tubing, rig down lines. Install BPV w/ lubricator. Secure well. Lay down 12 stands of 4" drill pipe f/ derrick. Clean floor drip pans & pits. Prepare to move to CD4-213B. Rig released @ 1800 hrs 4-30-12. 00:00 01:00 1.00 0 INTRM1 PLUG WOC P While waiting on cement: Continue to clean rig floor, install iron roughneck track, install iron roughneck back on the track 01:00 01:15 0.25 INTRMI PLUG SFTY P Pre job safety meeting on testing 10-3/4" casing to top of cement @ 3039' and two way check. 01:15 01:30 0.25 INTRMI PLUG RURD P Rig up to test casing and cement job. Use BOP test pump, pumping into the 10-3/4" x 3-1/2" anulus. 01:30 02:15 0.75 INTRM1 PLUG DHEQ P Test 10-3/4" csg/cement top @ 30397TWC to 1500psi-chart test for 30 minutes. Good test -lost 40 psi. 02:15 02:30 0.25 INTRM1 PLUG RURD P I Rig down testing equipment. 02:30 02:45 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting on flushing stack. 02:45 03:00 0.25 INTRMI WHDBO RURD P Rig up stack washing tool. 03:00 03:30 0.50 INTRMI WHDBOCIRC P Close blind rams, then open. Close top and bottom pipe rams, then open, close annular, then open. Flush stack with stack washing tool. 03:30 03:45 0.25 INTRM1 WHDBO PULD P Lay down stack washing tool. Blow down the top drive and all lines. 03:45 04:00 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting on nippling down BOPE. 04:00 05:30 1.50 INTRM1 WHDBO NUND P Nipple down 13-5/8" BOP stack. Change out saver sub (4" XT39) on the top drive. Change dies in the grab heads f/ the top drive. 05:30 05:45 0.25 INTRMI WHDBO SFTY P Pre job safety meeting. Page 30 of 79 Time Logs Date > From To Dur S. De th ` E. De th Phase Code Subcode T Comment 05:45 07:00 1.25 INTRM1 WHDBO NUND P Nipple up FMC 4-1/6" Horizontal tree. 07:00 07:30 0.50 INTRM1 WHDBO DHEQ P Test void to 5000 psi for 10 minutes. Test tree to 5000 psi f/ 10 minutes. 07:30 07:45 0.25 INTRM1 WHDBO RURD P Rig down testing equipment. 07:45 08:15 0.50 INTRM1 WHDBO OTHR P Pull two way check. 08:15 08:30 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting 08:30 09:00 0.50 INTRM1 WHDBO RURD P Rig up to freeze protect well w/ 150 bbls of diesel. 09:00 10:00 1.00 INTRM1 WHDBO FRZP P PJSM. Pressure test lines to 2500 psi. Dowell pump down the 10-3/4" x 3-1/2" annulus, pumping 4 bpm w/ 880 psi final. 10:00 10:30 0.50 INTRM1 WHDBO OTHR P "U" tube diesel from the annulus to the tubing. 10:30 10:45 0.25 INTRM1 WHDBO OTHR P Dowell fush lines to cellar tote with water. 10:45 11:00 0.25 INTRM1 WHDBO RURD P Rig down squeeze manifold and lines. 11:00 11:15 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting. 11:15 12:00 0.75 INTRM1 WHDBOOTHR P Install BPV w/ lubricator. Secure well. 12:00 13:00 1.00 INTRM1 WHDBO PULD P Lay down lubricator. Clear and lay down excess from floor. Cleaning pits. 13:00 14:00 1.00 INTRM1 PLUG PULD P Lay down 12 stands of 4" drill pipe f/ derrick. Clean floor drip pans, pits. Prepare to move. 14:00 18:00 4.00 INTRM1 MOVE RURD P Prepare to move: Break lines and hoses from pits and subbase. Clean rig floor, drains, drip pans and mats. Continue to clean pits, disconnect fuel line in pipe shed. Prepare pipe shed to move away from the rig. Prepare cellar for move. Remove suction caps from mud pumps. Check tire pressures. 18:00 18:00 0.00 INTRM1 Rig released for pad to pad move from CD3-127 to CD4-213B, approx 12 mile move. 72D'f3- � ._ - _• _ �_T _-�r, �__-__ � __ .. _._-T_, __..�� �z._..... _. _..- �a ��=_a_a-��.a� �.....,.:m ,mA�e=._,, Cleaning rig floor, removing fluids from rig, disconnect lines. Jack up pipe shed, prepare to move. MI Swaco ball mill cleaning fluids, prepare unit to be moved. 18:00 00:00 6.00 0 0 INTRM1 MOVE RURD P Cleaning rig floor, removing fluids from rig, disconnect lines. Jack up pipe shed, prepare to move. MI Swaco ball mill cleaning fluids, prepare unit to be moved. 1 /26/2013 Moved pipe shed f/ CD1 to CD3 - Moved rig camp, sewer plant & shop f/ CD4 to CD3 - Separate ball mill, motor & pit complexes - Skid floor to moving position - Prep to move modules & Sub base f/ CD1- 49 to CD3 127 Page 31 of 79 Time Logs Date From To Dur S. De th E. De th-Phase Code Subcode T Comment 00.00 00:00 24.00 0 0 MIRU MOVE MOB P Moved pipe shed f/ CD1-49 to CD3 - Moved rig camp, sewer plant & shop f/ CD4 to CD3 - @ CD1-49 - separated ball mill f/ pit module and moved down well row near injection skid - Separated motor & pit modules f/ sub & moved down well row - Skidded rig floor to moving position - Prep to raise feet in sub base - Notified DSO to bleed off pressure from gas lift line which was in the lift path of the foot on the off driller's side - Prep to move sub base, motor/pit complexes & ball mill f/ CD1 to CD3 " Performed injection tests w/ Little Red Services on CD3-114 & CD3-198 1 /27/2013 Cont w/ rig move. At midngiht: Sub on ice road ramp by CD2, pits, motors and ball mill at the end of the Alpine runway. 00:00 00:00 24.00 0 MIRU MOVE MOB P Cont. w/ rig move f/ CD1-49 to CD3-127 - Moved sub base f/ well row @ CD1 to Alpine ATC building - Lost power on moving motor - Trouble shoot - Cont. moving Sub Base f/ATC building down airport runway - past CD4 intersection and down CD2 road past bridge # 2 - Trouble shoot rear jacking system - Moved down CD2 road - Lost power on moving engine - Trouble shoot - Moved Sub base to within .8 mile from ice raod turn off from CD2 road. Rear wheel of Sub base went off road @ 1000 hrs.- Group up with ASRC - Peak - Doyon rig crew & CPAI Reps. - formulate plan & held pre job meeting - Worked plan to get Sub back on road - Sub back on raod @ 1530 hrs. No equipment damage - no spills - Trouble shoot power issue - Cont.moving Sub Base toward ice road ramp @ CD2 - Motor - pit modules & Ball mill are hooked up to Peak sows @ CD1 ready to move once Sub Base reaches ice raod intersection @ south end of CD2. Once Sub was on Ice Road ramp by CD2, rig sub blacked out again. While troubleshooting blackout, moved Pits, motors and Ball Mill to end of runway. Lights/power back on rig sub @ midnight. 1 /28/2013 Move pit & motor complexes and ball mill f/ end of runway to ice road ramp @ CD2 - Trouble sub base moving engine - Moving sub - pit & motor complexes & ball mill on CD3 ice road. At midnight the pits, motors and Ball mile @ mile 5.5 on the ice road. Rig Sub @ mile 4 of the ice road. Page 32 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Moved pit, motor modules and ball mill from end of runway to ice road ramp at CD2 - Trouble shoot Sub Base moving engine - @ 1615 hrs began to move Sub Base - Moved to guard shack @ termitation of resuppy ice road - Moved pit & motor complexes and ball mill past sub base @ guard shack - moving modules & Sub on CD3 ice road. At crew change: the sub @ approx 4 mile marker on the ice road, Pits, mtrs, ball mill are @ 5.5 mile marker on the ice road. 1 /29/2013 Cont moving to CD3 - All complexes over ice bridge @ 0230 hrs.- Sub Base over ice bridge @ 0345 hrs. - Move all complexes to CD3 pad - Sub base @ CD3 @ 0500 hrs. - Moved complexes up onto well row - change wind walls on sub - Spot Sub over Well -Spot Pit & Motor complexes - Spot Ball Mill - Hook up service lines. 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Cont. moving down CD3 ice road w/ pit - motor - ball mill & Sub - Pit & motor complexes over ice bridge @ 0230 hrs - Ball mill over Ice bridge @ 0230 hrs - Sub over ice bridge @ 0345 hrs - All modules & Sub on CD3 location @ 0500 hrs.- Moved ball mill - pit & motor complexes onto well row - Move Sub onto well row - Change Wind walls on sub - spot over well- jack floor into drilling position - Spot pits/motors & pipe shed - Spot ball mill - hook up electrical,air steam & water - Hook up Service lines - Chink cellar - Thaw mud lines in pits. 1 /30/2013 Rig Accepted @ 0000 hrs - Thaw suction lines in pits - spot tiger tank and R/U hard lines t/ cellar - R/U displacement manifold - take on load of brine t/ pits - test hanger void - test casing t/ 2000 psi f/ 10 min - displace well t/ 9.8ppg brine - set BPV test in dir. of flow - N/D tree - N/U BOP's - R/U & Test, leak on adaptor flange - leak on choke line fix and retest. 00:00 06:30 6.50 0 0 MIRU MOVE RURD P RU service lines, RU to displace to tiger tank, thaw lines in pits, load brine to pits 06:30 07:00 0.50 0 0 SLOT WHDBO PRTS P Test hanger/adapter void to 5000 psi for 10 min 07:00 07:30 0.50 0 0 SLOT MOVE PRTS P Test line to tiger tank, change out to/torque valve 07:30 08:45 1.25 0 0 SLOT MOVE PRTS P Test cement, casing and BPV to 2000 psi for 10 min (Thaw ice plugs) 08:45 09:45 1.00 0 0 SLOT WHDBO PRTS P PU, Test FMC lubricator to 2000 psi f/ 5 min, Pull BPV 09:45 10:30 0.75 0 0 SLOT RPCOM CIRC P RU to displace diesel out 10:30 11:00 0.50 0 1 0 SLOT RPCOM SFTY P PJSM on displacement Page 33 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11.00 12:30 1.50 0 0 SLOT RPCOM CIRC P Displace out diesel with 9.8 ppg brine. pumped 40 bbls warm brine w/ Safe-Surf-O followed with 247 bbls 9.8 brine at 8 bpm ICP of 1200 psi, taking returns to tiger tank, FCP at 1570 psi at 7 bpm 12:30 13:00 0.50 0 0 SLOT RPCOM OWFF P Monitor well static 30 minutes 13:00 13:15 0.25 0 0 SLOT RPCOM RURD P B/D & R/D hard lines 13:15 14:15 1.00 0 0 SLOT RPCOM OTHR P Set BPV & Test in direction of flow t/ 2000 psi f/ 10 min. 14:15 15:30 1.25 0 0 SLOT WHDBO NUND P N/D Tree, intsall blanking plug. 15:30 17:45 2.25 0 0 SLOT WHDBO NUND P N/U BOP stack, bell nipple & flow line, secure stack 17:45 18:45 1.00 0 0 SLOT WHDBO RURD P R/U t/ test BOP's, fill stack w/ H2O. 18:45 00:00 5.25 0 0 SLOT WHDBO BOPE P Atttempt t/ test BOP's w/ 5" test jt, leak on adaptor flange, tighten flange, retest leak on choke line, tighten flange leaking, blow down choke, c/o oteco ring tighten and retest. 1 /31 /2013 Test BOPE, witnessed by AOGCC John Crisp, RD, Pull BPV, RU and pull Hgr to floof, LD 3.5" tubing 68 jts, R/U Geo span unit, B/U BHA components, P/U Flex Collars HWDP & Jars stand back in derrick, P/U 5" DP and stand back in derrick ( 45 stands ) 00:00 07:30 7.50 0 0 SLOT WHDBO BOPE P Tested BOPE as follows: w/ 5" test jt. tested Annular to 250 & 2500 psi - Tested upper 3-1/2" x 6" pipe rams, TD IBOP's, 5" Floor safety & dart valves, Choke & kill line valves, Choke manifold valves # 1,2,3,4,5,6,7, 8, 9,10,11,12,13,14,15, & 16 and needle valve to 250 & 3500 psi - HCR choke and Kill - 4" Demco on kill line - manual kill & choke valves - Lower 3-1/2" x 6" pipe rams to 250 & 3500 psi - Performed accumulator recovery test, 3000 psi start, 1600 psi end, 40 sec to 200 psi, 175 sec to 3000 psi - Tested Blind rams 250/3500 psi - Tested gas alarms - With the 3-1/2" test joint tested annular, 250 PSI low/ 2500 PSI high, upper and lower variable pipe rams 250 PSI low/ 3500 PSI high. Annulus open and monitored during test. All tests charted, 5 min/ test. John Crisp (AOGCC) witnessed tests. 07:30 08:00 0.50 0 0 SLOT WHDBO RURD P LD test Jt, blow down lines and pull BPV with dry rod 08:00 09:15 1.25 0 0 SLOT RPCOM RURD P PJSM, RU to lay down 3.5" tubing 09:15 09:45 0.50 0 0 SLOT RPCOM SFTY P Pre Job Safety Meeting On UD 3.5 Tubing 09:45 14:30 4.75 2,176 0 SLOT RPCOM PULL P BOLDS, Pull hanger t/ floor, UD 3.5 kill string. F- Page 34 of 79 Time Logs Date From To Dui S. De th E. De th' Phase Code Subcode- T Comment 14:30 15:15 0.75 0 0 SLOT RPCOM RURD P R/D tubing equipment &clear floor. 15:15 15:45 0.50 0 0 SLOT RPCOM OTHR P Set 9.875 ID wear ring 15:45 18:00 2.25 0 0 INTRMI DRILL PULD P P/U Flex collars, HWDP & jars from shed stand back in derrick. 18:00 18:45 0.75 0 0 INTRMI DRILL RURD P R/U Geo span unit, P/U subs & reamers and other BHA components. 18:45 00:00 5.25 0 0 INTRMI DRILL PULD P P/U 5" DP and stand back in derrick via mouse hole (45 stands P/U & stood back ) 2/01 /2013 P/U stand back 5" Dp 137 stands, P/U BHA upload MWD Funtion test riptide reamer SHT MWD, Repair TD & Draworks disc brakes. 00:00 04:30 4.50 0 0 INTRM1 DRILL PULD P P/U & Stand back 5" DP via mouse hole. ( 38 Stands ) 04:30 05:00 0.50 0 0 INTRM1 RIGMNTSVRG P Service Rig & Draworks 05:00 11:30 6.50 0 0 INTRMI DRILL PULD P P/U & Stand back 5" DP via mouse hole. ( 54 Stands 137 total in derrick) 11:30 12:00 0.50 0 0 INTRMI DRILL PULD P P/U BHA components f/ next run. 12:00 17:45 5.75 0 158 INTRM1 DRILL PULD P P/U BHA as per DID & Weatherford Rep. Upload MWD, Test geo span t/ 3500 psi, Function test riptide reamer, Shallow pulse test MWD, Drop closing tags, verify reamer closed, Instal jets in reamer. 17:45 18:15 0.50 158 158 INTRM1 RIGMNTSVRG P Service Rig & draworks 18:15 20:45 2.50 158 158 INTRM1 RIGMNT RGRP T C/O repair Booster Pump on top drive. 20:45 22:15 1.50 158 158 INTRMI RIGMNT SLPC P Slip & Cut Drill Line 22:15 00:00 1.75 158 158 INTRMI RIGMNT RGRP T Repair Booster & Disc Brakes on Draworks 2/02/2013 Trouble shoot booster pump on TD( 0200 hrs Operational ), P/U & load sources, RIH w/ Flex collars & HWDP, Single in the hole f/ shed, R/U & perform casing test t/ 3500 psi, TOC 3043' Drill cmt t/ 3310' Observe WOB loss, Surveys show tracking old well bore RIH t/ 3420' No CMT 00:00 00:30 0.50 158 158 INTRM1 DRILL SVRG P Service Rig 00:30 02:00 1.50 158 158 INTRM1 DRILL RGRP T Continue C/O booster pump on TD 02:00 03:30 1.50 158 630 INTRM1 DRILL PULD P Load Sources, Continue P/U BHA as per DD. 03:30 06:30 3.00 630 2,799 INTRMI DRILL PULD P P/U 5" DP f/ shed t/ 2799' 06:30 07:00 0.50 2,799 2,893 INTRMI DRILL TRIP P RIH f/ 2799' t/ 2893' 07:00 07:30 0.50 2,893 3,043 INTRMI DRILL WASH P Wash in the hole f/ 2863' U 3043' Tag top of cement @ 3043' 07:30 09:00 1.50 3,043 3,043 INTRMI DRILL PRTS P R/U & perform casing test t/ 3500 psi f/ 30 min. R/D 09:00 10:15 1.25 3,043 3,043 INTRM1 DRILL RGRP P Replace wash pipe test t/ 3500 psi 10:15 12:00 1.75 3,043 3,043 INTRM1 DRILL CIRC P Displace well w/ 9.8ppg LSND mud, 327 bbls @ 336 gpm 700 psi, observe well f/ flow well static. 12:00 16:30 4.50 3,043 3,270 INTRMI DRILL DRLG P Drill Cement f/ 3043' t/ 3270' 700 gpm 1440 psi 12-14 tq PUW- 140 SOW- 105 ROT WT- 130 Page 35 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:30 19:30 3.00 3,270 3,255 INTRM1 DRILL REAM P Attepmt t/ ream shoe unable t/ get geo pilot back into shoe, slight pack off and stalling of rotary. Work string unable t/ get stab into shoe. 19:30 00:00 4.50 3,255 3,420 INTRM1 DRILL DRLG P Drill Cement f/ 3270' t/ 3310' observe loss of all WOB, ROP 350-450 FPH surveys correlate w/ old wellbore, RIH w/ pumps 700 gpm 1580 psi 65 RPM 10.5-12 tq No cement obesrved, Ream in hole f/ 3310' t/ 3420' 2/03/2013 Ream in the hole t/ 3471' No CMT or ECP Plug, CBU X 3, BROOH t/ shoe @ 3236', Observe well for 30 min static, POOH, Stand back & UD BHA, M/U clean Out BHA RIH t/ 3396' Wash & Ream t/ 4015' No ECP Observed, CBU @ 650 pm 00:00 00:15 0.25 3,420 3,471 INTRM1 DRILL REAM T Wash/Ream from 3420' to 3471' at 700 gpm, 1600 psi, 70 RPM, 12K Tq, 145K up, 105K dwn. (No cement found and ECP was not at set depth of 3441') 00:15 01:15 1.00 3,471 3,471 INTRM1 DRILL CIRC T CBU x3, 700 gpm at 1630 psi, 70 RPM at 11.5K Tq. Decision made to POOH for cement and check assy for excess wear. 01:15 02:45 1.50 3,471 3,176 INTRM1 PLUG TRIP T LD single, obtain SPR's, Flow check static, BROOH from 3458' to 3176'. 2 bpm at 80 psi, 40 RPM at 11 K Tq. (No problems getting into shoe) 02:45 03:30 0.75 3,176 3,176 INTRM1 PLUG OWFF T Blow down top drive, observe well static 30 min. 03:30 03:45 0.25 3,176 3,081 INTRM1 PLUG TRIP T Attempt POOH on trip tank one stand. Insufficient hole fill, swabbing 03:45 05:30 1.75 3,081 2,138 INTRM1 PLUG TRIP T Flow check static, Pump OOH from 3081' to 2138' at 3 bpm at 170 psi. 05:30 05:45 0.25 2,138 2,138 INTRM1 PLUG TRIP T Attempt POOH on trip tank one stand. Insufficient hole fill, swabbing 05:45 06:45 1.00 2,138 2,138 INTRM1 PLUG CIRC T Flow check static, circulate at 800 gpm at 1850 psi, 100 rpm at 8K tq. Hole unloaded hard cement cuttings and mush. 06:45 09:00 2.25 2,138 630 INTRM1 PLUG TRIP T B/D TD POOH on TT f/ 2138' t/ 630' Hole took proper fill. 09:00 09:15 0.25 630 630 INTRM1 PLUG OWFF T Observe well f/ flow well static. 09:15 09:45 0.50 630 163 INTRM1 PLUG TRIP T Stand Back BHA f/ 630 t/ 163 09:45 10:15 0.50 163 163 INTRM1 PLUG OTHR T Unload sources. 10:15 10:45 0.50 163 65 INTRM1 PLUG TRIP T Stand back BHA as Per DID t/ 65' 10:45 12:00 1.25 65 0 INTRM1 PLUG OTHR T Down load MWD UD BHA as per DID 12:00 14:00 2.00 0 0 INTRM1 PLUG PULD T Clean & Clear floor, P/U BHA components, C/O elevators. 14:00 15:30 1.50 0 476 INTRM1 PLUG PULD T M/U clean out BHA t/ 476' 15:30 18:00 2.50 476 3,396 INTRM1 PLUG TRIP T RIH w/ 5" DP f/ 476 t/ 3396' fill pipe evey 20 stands. 18:00 19:00 1.00 3,396 3,576 INTRM1 PLUG REAM T Wash & Ream f/ 3396t/ 3576' @ 650 pm 860 psi 40 rpm 10-12k tq. Rage 36 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:00 20:15 1.25 3,576 3,576 INTRM1 PLUG CIRC T Circ & Condition hole, 700 gpm 840 psi hole unloaded cmt cuttings @ Bottoms up. 20:15 23:15 3.00 3,576 4,015 INTRM1 PLUG REAM T Wash & Ream f/ 3576' t/ 4015' no CMT or ECP observed. Hardest CMT seen was @ 3670' -3678' 23:15 00:00 0.75 4,015 4,015 INTRM1 PLUG CIRC T Circ. Bottoms Up @ 650 gpm 820 psi 30 RPM 10k tq. 2/04/2013 POOH w/ Clean out Assy. Pumps @ 136 gpm t/ shoe, Circ. casing clear, OWFF well static, POOH on TT, L/D BHA, P/U & RIH w/ 7" ECP t/ 3951' unable to see packer inflate, pressure up and shear off plug @ 4015', Mix & pump forma -set pill, POOH t/ shoe. 00:00 00:30 0.50 4,015 4,015 INTRM1 PLUG CIRC T Circ & condition mud @ 650 gpm 750 psi 30 rpm. 00:30 02:15 1.75 4,015 3,204 INTRM1 PLUG TRIP T POOH w/ pumps @ 136 gpm 100 psi f/ 4015' t/ 3204' 02:15 02:45 0.50 3,204 3,204 INTRM1 PLUG CIRC T Circ casing clean @ 750 gpm 930 psi 80 RPM. 02:45 03:15 0.50 3,204 3,204 INTRM1 PLUG OWFF T Observe welll for flow f/ 30 min well static. 03:15 06:30 3.25 3,204 476 INTRM1 PLUG TRIP T Pooh On Trip tank f/ 3204' t/ 476' hole took proper fill. 06:30 07:00 0.50 476 0 INTRM1 PLUG PULD T L/D BHA as per DD 07:00 07:45 0.75 0 0 INTRM1 PLUG RURD T Clean & clear Rig floor P/U BHA components R/U t/ tubing equipment. 07:45 10:15 2.50 0 1,077 INTRM1 PLUG PUTB T RIH w/ ECP on 3.5 tubing cement string. t/ 1077 10:15 10:30 0.25 1,077 1,077 INTRM1 PLUG RURD T R/D tubing equip. M/U cross over t/ 5" DP 10:30 11:00 0.50 1,077 1,166 INTRM1 PLUG TRIP T RIH w/ CMT string on 5" DP f/ 1077' t/ 1166' Rabbiting pipe f/ derrick 2.50 OD 11:00 11:30 0.50 1,166 1,166 INTRM1 PLUG CIRC T Fill pipe check floats, floats held. 11:30 15:15 3.75 1,166 3,951 INTRM1 PLUG TRIP T RIH w/ 5" DP f/ 1166' t/ 3951' Rabbiting pipe f/ derrick 2.50 OD 15:15 16:30 1.25 3,951 3,951 INTRM1 PLUG PACK T Drop Dart pump dart down @ 136 gpm 140 psi, observe first plug release 380 psi, latched second plug 460 psi, work through setting procedure pumping up t/ 2500 psi no indication packer inflating, Bleed pressure off t/ 550 Make second attempt t/ inflate packer same results, P/U on pipe no change in drag or over pull. 16:30 16:45 0.25 3,951 3,951 INTRM1 PLUG OTHR T Blow Down Top Drive 16:45 18:00 1.25 3,951 4,015 INTRM1 PLUG PACK T RIH f/ 3951' t/ 4015' ECP taking weight set down 15K no over pull observed, pressure up t/ 2800 psi observe pressure loss, Returns observed, P/U 3200 Psi P/U 5 ft pressure @ 136 gpm was 120 psi. No indication ECP tried to inflate prior to releasing. Page 37 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18.00 19:30 1.50 4,015 3,951 INTRM1 PLUG CIRC T Load Nerf pipe wiper ball into 5" circ surface to surface @ 336 gpm 210 psi, no visible pressure change ball passed through tool also indicating released from ECP. Prepping pits to pump MI Form -a -set pill. 19:30 19:45 0.25 3,951 3,951 INTRM1 PLUG OWFF T Observe well for flow well static. 19:45 21:00 1.25 3,951 3,367 INTRM1 PLUG TRIP T POOH on TT f/ 3967' t/ 3360' while waiting f/ MI to stage FORMA -SET products in pits and prepping pits 21:00 22:00 1.00 3,367 3,992 INTRM1 PLUG TRIP T RIH w/ DP f/ 3367' t/ 3992' While Mixing FORMA -SET Pill 22:00 22:30 0.50 3,992 3,992 INTRM1 PLUG CIRC T Pump 20 bbl hi vis sweep, 40 bbl FORMA -SET pill, chase w/ 598 stks hi vis mud. 22:30 00:00 1.50 3,992 3,214 INTRM1 PLUG TRIP T POOH w/ 5" DP f/ 3992 t/ 3214' 2/05/2013 Flow check static, circ pipe clean, wait on Form -A -Set to set up, Flow check static, RIH to 3497', Wash down to 3780', 204' from base of Forma -A -Set pill, CBU, no definitive indication of set up Form -A -Set back, drop down 47' and CBU, no set up Forma -A -Set seen but more patties, thicker mud and pill products observed, RU, PJSM, pump 20 bbls 11.5ppg mud push, 70 bbls 17ppg cement, 3 bbls 11.5ppg mud push (2 bbls downhole), 47 bbls 9.8 mud to balance, CIP @ 0830, POOH to 3026', flow check static, monitor well while WOC. Pump 2nd cement plug. From 3354' up to 3039' MD. pump 20 bbls 11.5ppg mud push, 36 bbls 17ppg cement, 3 bbls 11.5ppg mud push (2 bbls downhole), 40 bbls 9.8 mud to balance. 00:00 01:00 1.00 3,214 3,214 INTRM1 PLUG CIRC T Flow check, circulate and clean pipe at 8 bpm, 210 psi, blow down top drive. 01:00 03:00 2.00 3,214 3,214 INTRMI PLUG WOC T Wait on Forma -A -Set to cure 03:00 03:15 0.25 3,214 3,497 INTRMI PLUG TRIP T Flow check static, RIH from 3214' to 3497' 03:15 04:00 0.75 3,497 3,780 INTRM1 PLUG TRIP T Wash down from 3497' to 3780' , 5 bpm, 170 psi. 120K PU wt, 110K SO wt. This is 204' above base of Form -A -Set 04:00 05:15 1.25 3,780 3,780 INTRM1 PLUG CIRC T Circulate and condition, 5 bpm, 170 psi, no definitive indication of set up Form -A -Set to surface 05:15 05:30 0.25 3,780 3,780 INTRMI PLUG OWFF T Blow down top drive, flow check static 05:30 05:45 0.25 3,780 3,823 INTRM1 PLUG TRIP T PJSM, pu single and 16' pup to 3823' 05:45 06:30 0.75 3,823 3,823 INTRM1 PLUG CIRC T CBU, 575 gpm, 490 psi. no indication of set up Form -A -Set to surface, seen more patties, thicker mud and looked like pill products. 06:30 06:45 0.25 3,823 3,827 INTRM1 PLUG RURD T Blow down top drive, PJSM, RU to cement 06:45 07:15 0.50 3,827 3,827 INTRM1 PLUG SFTY T Circulate, 5 bpm, 210 psi while PJSM Page 38 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:15 08:30 1.25 3,827 3,827 INTRM1 PLUG CMNT T Pump cement plug - Dowell cementers flood lines with water - Tested lines to 3000 psi - Mix and pump 19.8 bbls of 11.5 ppg Mudpush - Insert foam seperation ball to pipe - Dowell pump 69.9 bbls of 17.0 ppg G cement w/ adds (393 sxs - 1 cf/sx yld) - 3.0 bbls of Mudpush behind (2.0 bbls in pipe) and rig displaced to equalization with 47 bbls 9.8 ppg mud (cut 3.5 bbls short) 8 bpm to catch cement with 30 bbls, 5.3 bpm at 200 psi ICP, 300 psi FCP - Reduced to 4.2 bpm 5 bbls from equalization, 180 psi ICP, 230 psi FCP - Shut down and open valves - well balanced - CIP @ 0830 hrs - full returns throughout - ETOC w/ 50% excess in OH = 3327' 08:30 09:45 1.25 3,827 3,026 INTRM1 PLUG TRIP T Flow check static, LD pup and single, POOH on trip tank wet to 3026'. Pulling speed 12007hr slowed to 7507hr 09:45 10:45 1.00 3,026 3,026 INTRM1 PLUG CIRC T Flow check static, PJSM, load nerf ball, circ pipe clean at 550 gpm, 410 psi, 20 rpm, 5K tq, 114K up, 110K dwn, 1110K rot. No cement or mud push observed at surface. 10:45 11:00 0.25 3,026 3,026 INTRM1 PLUG OWFF T Blow down top drive, flow check 11:00 12:00 1.00 3,026 3,026 INTRM1 PLUG WOC T WOC - SIMOPS - Monitor well, perform maintenance work orders on drawworks and equipment 12:00 19:00 7.00 3,026 3,026 INTRM1 PLUG WOC T WOC - SIMOPS - Monitor well, perform maintenance work orders on drawworks and equipment 19:00 20:30 1.50 3,026 3,354 INTRM1 PLUG WASH T PJSM. Wash down from 3026' MD to 3354' MD. 3 BPM/ 100 PSI. Tag cement stringer @ 3334' MD. Tag good cement @ 3354' MD. Set down 8k while pumping. Retag. Saw 30 PSi increase in PP. 20:30 21:45 1.25 3,354 3,354 INTRM1 PLUG CIRC T CBU. Stage pumps up to 500 GPM's/ 370 PSI. Saw mud push on bottoms up. Minimal cement returns. 21:45 22:00 0.25 3,354 3,354 INTRM1 PLUG SFTY T Prejob safety meeting on blowing down TD.. Stand back one stand. Blow down TD. 22:00 22:30 0.50 3,354 3,354 INTRM1 PLUG RURD T Pick up single, and a 12 foot pup. Rig up to pump cement with 1502 cement head. 22:30 22:45 0.25 3,354 3,354 INTRM1 PLUG SFTY T Circulate through cement head. PJSM in dog house. Cement job. Page 39 of 79 Time Logs DateFrom To Dur S. De th E. De th Phase Code Subcode T Comment 22:45 00:00 1.25 3,354 3,354 INTRM1 PLUG CMNT T Dowell tested lines to 3000 PSI. Dowell pumped 20 BBLs 11.5 PPG Mud Push, drop nerf ball, pump 36 BBLs 17 PPG cement, 2 BBLs 11.5 PPG Mud Push. Rig pumped 40 BBLs displacement. CIP @ 24:00 HRS. 2/06/2013 Complete 2nd balanced cement plug job. CIP @ 00:01. POOH to 2932' MD. CBU. Flow check well. Static. POOH on TT to 2553' MD. Methane gas high level alarm. Evac. Rig. Verify with two hand held gas detectors that sensor in rig panel issued a false alarm. Good evacuation drill. Replace faulty sensor. POOH to 1052' MD. Top of 3'/" work string. Observe well bore. Static. Lay down 32 joints tubing. Rig up and test BOPE. Pick up BHA#9 Sperry rotary steerable system. 9 7/8" hole size. 00:00 00:30 0.50 3,354 3,354 INTRM1 PLUG OWFF T Flow check. Observe well bore. Static. Rig down cement lines. Blow down cement lines. CIP @ 00:00 hrs. Plug balanced. 00:30 00:45 0.25 3,354 2,932 INTRM1 PLUG TRIP T POOH slowly. Constant hole fill on trip tank. Pull 4 stands. 00:45 01:30 0.75 2,932 2,932 INTRM1 PLUG CIRC T Observe well. Static. Load and pump nerf ball surface to surface. 550 GPM/ 410 PSI. Mud push seen at surface. No cement returns. 01:30 02:00 0.50 2,932 2,932 INTRM1 PLUG OWFF T Observe well. Static. 02:00 02:45 0.75 2,932 2,553 INTRM1 PLUG TRIP T POOH on trip tank. From 2932' to 2553' M D. 02:45 03:30 0.75 2,553 2,553 INTRM1 PLUG SFTY T High level methane gas alarm. Rig evacuation. Verify with two hand held gas detectors that no gas was present. Electrician replaced bad sensor. Return to work when all was clear. All personnel accounted for. 03:30 05:30 2.00 2,553 1,052 INTRM1 PLUG TRIP T Trip out of the hole on elevators. Monitor well on trip tank. Good hole fill. 05:30 05:45 0.25 1,052 1,052 INTRM1 PLUG OWFF T Observe well for flow at top of work string. 3Y2' EUE tubing. Static. 05:45 06:00 0.25 1,052 1,052 INTRM1 PLUG SFTY T Prejob on rigging up to lay down tubing into pipe shed. 06:00 09:00 3.00 1,052 0 INTRM1 PLUG PULD T Rig up tubing equipment. Lay down 32 joints of 3Y2' 9.3# L-80 tubing. Cement stinger. 09:00 09:30 0.50 0 0 INTRM1 PLUG RURD T Clean and clear rig floor. 09:30 10:00 0.50 0 0 INTRM1 PLUG BOPE T Pull wear ring. Install test plug. 10:00 11:15 1.25 0 0 INTRM1 PLUG BOPE T PJSM. Testing BOPS. Rig up to test. Warm up top drive. 11:15 12:00 0.75 0 0 INTRM1 PLUG BOPE T Test BOPE. Test annular to 250 PSI low/ 2500 PSI high 5mins each, charted. Test with 5" test joint on all tests. Test Upper Pipe Rams, choke valves 1,5,14,15,16- HCR kill -All tests 250 PSI low, 3500 PSI high, 5 mins each charted. Jeff Jones AOGCC Inspector waived witness of test. Page 40 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 16:30 4.50 0 0 INTRM1 PLUG BOPE T Test BOPE. Test with 5" test joint. All tests 5 mins. All tests charted. Test choke valves 2,3,4,6,7,8,9,10,11,12,13. Needle valve, HCR choke, Auto and manual IBOP, 4" Demco, Manual choke and kill valves, lower pipe rams (3%2 x 6"), blind rams, all tests 250 PSI low 3500 PSI high.Performed accumulator recovery test, 3000 psi start, 1500 psi end, 33 sec to 200 psi, 178 sec to 3000 psi. Isolated accumulators. Close 2 pipe rams, open HCR choke, with electric pump only obtain full pressure in 40 secs. Close 2 pipe rams, open HCR kill, with air system only obtain full pressure in 62 secs. Perform draw down on Super choke, and manual choke to 1200 PSI. Flush Gas buster @ 2 BPM. *Test all rig gas alarms, test rig evacuation alarm. Jeff Jones AOGCC Inspector waived witness of test. 16:30 16:45 0.25 0 0 INTRM1 PLUG RURD T Pull test plug and blow down choke manifold, choke line, kill line. 16:45 17:15 0.50 0 0 INTRM1 PLUG RURD T Set wear ring. 9.875" ID. 17:15 17:30 0.25 0 0 INTRM1 PLUG PULD T Pick up BHA components to rig floor. 17:30 19:15 1.75 0 108 INTRM1 PLUG PULD T PJSM. Make up GeoPilot, box up long gauge bit, MWD system to 108' MD. 19:15 20:30 1.25 108 108 INTRM1 PLUG PULD T Up load MWD. CTN tool unable to read due to cold temps. 20:30 21:30 1.00 108 108 INTRM1 PLUG CIRC T Circulate through BHA 200 GPM to warm MWD string. SIMOPS: Steam tools. 21:30 22:15 0.75 108 108 INTRM1 PLUG PULD T Plug in and load MWD. 22:15 22:45 0.50 108 159 INTRM1 PLUG PULD T Continue to make up BHA#9. to 159' MD. 22:45 00:00 1.25 159 159 INTRM1 PLUG CIRC T Install blank jets in Rip Tide Weatherford Reamer. Drop opening chips. Pump @ 600 GPM/ 840 PSI. Unsuccessful. Drop 2nd batch of opening chips. Pump @ 700 GPM/ 1180 PSI. Unsuccessful. Drop 3rd batch of opening chips. Steam tool, Pump 200 GPM/ 85 PSI. 2/07/2013 Trouble shoot Weatherford Rip tide reamer. Change out tools. Build BHA#9. Sperry Geo-Pilot rotary steerable system. 9 7/8" hole size. Trip to the top of cement plug. Dress off plug from 3020' to 3270' MD. Kick off. Drill 30 feet from 3270' to 3300' MD. 80% deflection 180' toolface. Perform LOT to 14.8 PPG EMW. Continue to Directional Drill 9 7/8" hole exiting old wellbore. Drill from 3300' MD to 3340' MD. Page 41 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00.00 00:30 0.50 159 159 INTRM1 PLUG CIRC T Drop opening chips to Rip Tide Weatherford reamer. Pump @ 700 GPM/ 1050 PSI. No opening sequence. Apply steam to tool. Drop another set of opening chips. No response. Remove blank jets from reamer. 00:30 01:15 0.75 159 159 INTRM1 PLUG PULD T PJSM. Blow down top drive. Lay down single. Lay down pony collar and ghost reamer. Lay down failed Weatherford Rip Tide Reamer. 01:15 01:45 0.50 159 159 INTRM1 PLUG PULD T PJSM. Pick up new Rip Tide Reamer from pipe shed. Install blank jets, pick up pony collar and ghost reamer, pick up two singles of 5" DP. 01:45 03:00 1.25 159 159 INTRM1 PLUG CIRC T Pump @ 600 GPM/ 810 PSI. Confirm the tool opened fully. Good. Pump down closing RFID chips @ 2 BPM. Let sit still for 5 mins. Pick up to floor, pump 600 GPM. Confirm not opening, but still drifting open some. Repeat 3 times to get the tool to remain 99% closed. blow down top drive, lay down 2 singles. 03:00 03:30 0.50 159 159 INTRM1 PLUG PULD T PJSM. Load nuclear sources into SperryMWD tools. 03:30 04:00 0.50 159 623 INTRM1 PLUG PULD T Continue to make up BHA from 159' MD to 623' MD. 04:00 06:30 2.50 623 2,886 INTRM1 PLUG TRIP T Trip in the hole from 623' MD to 2886' MD. Fill pipe @ 20 stands. Blow down top drive. Break in GeoPilot bearings. 130K up, 115K down. Actual displacement=22.9 BBLS. Calculated displacement=26.9 BBLS 06:30 07:00 0.50 2,886 2,999 INTRM1 PLUG REAM T Ream down from 2886' MD to 2999' MD. 130k Up/ 115k Dn/ 125k Rot. 07:00 12:00 5.00 2,999 3,257 INTRM1 PLUG REAM T Ream/ Drill out cement inside casing from 2999' MD to 3257' MD. @ 500 GPM/ 950 PSI. 750 GPM/ 1740 PSI. 50 RPM. 10K. Hard cement found @ 3020' M D. 12:00 12:15 0.25 3,257 3,270 INTRM1 PLUG REAM T Drill/Ream out cement fr 3257' MD. to 3270' M D. 12:15 12:45 0.50 3,270 3,300 INTRM1 PLUG DDRL T Directional Drill 9.875" hole. Oriented 150° left 80% deflection. 750 GPM/ 1960 PSI/ 60 RPM/ 12k TQ. Sidetrack point calcualted to be 3270'. 30 feet of new hole exposed. 12:45 13:15 0.50 3,300 3,300 INTRM1 PLUG CIRC T Displace out cement contaminated mud with new 9.8 ppg LSND system. 600 GPM/ 1150 PSI. 11.5k TQ. 13:15 14:45 1.50 3,300 3,239 INTRM1 PLUG SVRG T Unable to break out of stand. Top drive booster pump frozen, auto IBOP partially frozen open. Blow down top drive, lay down 4 singles and bring TD to rig floor to steam. 30k overpull seen as bit was pulled into shoe @ 3327' MD. Page 42 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code -- Subcode T Comment 14:45 15:15 0.50 3,239 3,239 INTRM1 PLUG LOT T I Rig up to perform FIT/LOT. 15:15 16:00 0.75 3,239 3,239 INTRM1 PLUG LOT T Perform LOT to 14.82 PPG EMW/ 640 PSI. 16:00 16:30 0.50 3,239 3,239 INTRM1 DRILL RURD P Blow down cement line, kill line, rig down cement hose and head pin. 16:30 17:00 0.50 3,239 3,239 INTRM1 DRILL PULD P PJSM. Pick up 3 singles from shed and rack back a full stand. 17:00 17:30 0.50 3,239 3,239 INTRM1 DRILL SVRG P Work on auto IBOP and service top drive and draw works. 17:30 17:45 0.25 3,239 3,300 INTRM1 DRILL TRIP P Trip in from 3239' MD to 3300' MD. 17:45 19:00 1.25 3,300 3,320 INTRM1 DRILL DDRL P Directional Drill from 3300' MD to 3320' MD. 700 GPM/ 1950 PSI/ 5k WOB/ 12k TQ. 1007hr. 19:00 00:00 5.00 3,320 3,340 INTRM1 DRILL DDRL P Begin time drilling @ 3320' MD. Survey showed no drop or turn. Slow down to exit the old wellbore fully. Drill from 3320' MD to 3340' MD. ADT=5.94 HRs since sidetracking. 550 GPM/ 1040 PSI/ 4k WOB/ 120 RPM. 2/08/2013 Directional Drill 9 7/8" hole. Sperry rotary steerable system. Time drill due to loss of bit weight. From 3339' MD to 3377' MD. Regained bit weight. Assured of sidetrack. Drill from 3377' MD to 3600' MD. Unable to build angle, and turn left to follow the well plan. POOH for Mud Motor assembly to re-establish our wellbore on plan. 00:00 10:15 10.25 3,340 3,365 INTRM1 DRILL DDRL P Directional Drill. Time drill. 1 to 2' per hour. From 3339' to 3342', 1/10th inch per 6 mins. From 3342' to 3344', 1/10th inch per 4 mins. From 3344' to 3350', 1/10th inch per 3 mins. From 3350' to 3355', 1/10th inch per 2 mins, From 3355' to 3365', 1/10th inch per min. Started with 550 GPM/ 990 PSI. Finished with 650 GPM/ 1360 PSI. Variable RPM's from 60 to 130 depending on down hole conditions. Bit weight 3 to 7k. 10:15 12:00 1.75 3,365 3,377 INTRM1 DRILL DDRL P Control drill @ 107hr. From 3365' to 3377' MD. 650 GPM/ 1400 PSI, 120 RPM, 5k WOB, 11 k TQ on bottom. 12:00 16:15 4.25 3,377 3,600 INTRM1 DRILL DDRL P Directional Drill from 3377' to 3600' MD. 650 GPM/ 1350 PSI/ 120 ROM/ 5 to 8k WOB/ ADT=3.08. Unable to stop a dropping tendency. GeoPilot not'hooking up'. Housing roll. POOH for Motor. 16:15 17:15 1.00 3,600 3,239 INTRM1 DRILL TRIP T Pump out of the hole from 3600' to 3239'. Inside casing. Experienced some problems as the BHA entered the casing. Slight pack off, and torque. 575 GPM/ 1160 PSI/ 60 RPM/ 10k TO. 17:15 18:00 0.75 3,239 3,239 INTRM1 DRILL CIRC T Circulate one bottoms up. 800 GPM/ 2100 PSI/ 50 RPM. Some clay seen on shakers. 18:00 18:30 0.50 3,239 3,239 INTRM1 DRILL OWFF T Blow down top drive. Observe well for flow. Static. Page 43 of 79 i v' Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:30 19:45 1.25 3,239 2,603 INTRM1 DRILL TRIP T Trip out on the elevators. Monitor well on trip tank. Good hole fill for first 5. Stand #6 tool ''/z barrel intead of .68. Stand #7 swabbed 1.5 barrels out. 19:45 20:30 0.75 2,603 2,603 INTRM1 DRILL CIRC T Drop down one stand. Circulate 5 x's bottoms up.800 GPM/ 2000 PSI/ 50 RPM. Large quatities of clay/ formaset/ material seen on the shakers. ECD's dropped from 10.5 PPG to 10.19 PPG. 20:30 21:00 0.50 2,603 2,603 INTRM1 DRILL OWFF T Blow down top drive. Observe well for flow. Static. 21:00 23:30 2.50 2,603 623 INTRM1 DRILL TRIP T Trip out of the hole on elevators. Good hole fill. Monitor well on trip tank. To top of HWDP. 23:30 00:00 0.50 623 623 INTRM1 DRILL OWFF T Observe well bore. Static. 2/09/2013 POOH with BHA#9. Rotary Steerable. Lay down tools. Pick up BHA#10. Mud Motor set on 1.50, Gamm/Res/PWD/Dir MWD system. Trip to bottom and Directional Drill 9 7/8" hole from 3600' MD to 4515' MD. 00:00 00:15 0.25 623 159 INTRM1 DRILL TRIP T Stand back HWDP and one stand of monel drill collars 00:15 00:45 0.50 159 159 INTRM1 DRILL PULD T PJSM. Time. Distance. Shielding. Retrieve nuclear sources from MWD tools. 00:45 01:30 0.75 159 108 INTRM1 DRILL PULD T PJSM. Lay down BHA as per DD to 108' MD. 01:30 02:45 1.25 108 108 INTRM1 DRILL PULD T Down load MWD tools. 02:45 04:15 1.50 108 0 INTRM1 DRILL PULD T Lay down BHA as per DD. Grade bit. Clear rig floor. Calc. fill=31.6 BBLS. Actual fill=31.5 BBLS. 04:15 04:30 0.25 0 0 INTRM1 DRILL RURD T Clear and clean rig floor. 04:30 05:15 0.75 0 0 INTRM1 DRILL PULD T PJSM. Pick up test joint. Make up running tool. Service wear ring, Reinstall wear ring. Lay down running tool and test joint. 05:15 07:15 2.00 0 83 INTRM1 DRILL PULD T Make up BHA #10. Mud Motor, place 1.5° bend in motor. 07:15 08:15 1.00 83 83 INTRM1 DRILL PULD T Up load MWD system. Tools too cold to up load. 08:15 08:45 0.50 83 83 INTRMI DRILL CIRC T Pump on BHA to warm up. Blow down top drive. Finish Up loading. 08:45 09:15 0.50 83 635 INTRM1 DRILL PULD T PJSM. Trip in the hole with monel collars/ HWDP to 635' MD. 09:15 09:45 0.50 635 635 INTRM1 DRILL CIRC T Shallow pulse test MWD system. 550 GPM/ 1000 PSI. Good. Blow down top drive. 09:45 11:15 1.50 635 3,255 INTRM1 DRILL TRIP T Trip in the hole from 635' to 3255' MD. 140k Up/ 110k Dn. Fill every 20 stands. Calculated fill=32.9 BBLs. Actual fill=32.0 BBLs. Take weight 3255' MD. 10-15k Dn. 11:15 12:15 1.00 3,255 3,600 INTRMI DRILL REAM T Ream from 3255' to 3600' MD. 2 BPM/ 200 PSI/ 30 RPM/ 10k TQ. Page 44 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:15 00:00 11.75 3,600 4,515 INTRM1 DRILL DDRL P Directional Drill 9 7/8" hole from 3600' MD to 4515' MD. TVD=3117'. ADT=6.60 HRS/ ART=5.17 Hrs/ AST=1.43 Hrs. ECD=10.40 PPG. 750 GPM/ 2600 PSI/ 5-25k WOB/ 50-80 RPM/ Weights: 150k Up/ 125k Dn/ 135k Rot. TQ= 12k on/ 11 k off. 2/10/2013 Directional Drill 9 7/8" hole from 4515' MD to 6510' MD. 750 GPM/ 3100 PSI/ 18k WOB/ 80-100 RPM/ Weights: 164k Up/ 135k Dn/ 148k Rot. TQ= 13k on/ 11k off. Pumping viscosified weighted sweeps or weighted sweeps periodically for hole cleaning purposes. Maintain lubes around 2%. Perform 275 BBL dilutions every 4 to 6 stands. Slide 15 to 20 feet off the top of each stand to follow directional plan. 00:00 12:00 12.00 4,515 5,556 INTRM1 DRILL DDRL P Directional Drill 9 7/8" hole from 4515' MD to 5556' MD. TVD=3324'. ADT=7.03 HRS/ART=5.82 Hrs/ AST=1.21 Hrs. ECD=10.72 PPG. 750 GPM/ 2990 PSI/ 18k WOB/ 80-100 RPM/ Weights: 160k Up/ 125k Dn/ 140k Rot. TQ= 13k on/ 11 k off. Pumping weighted sweeps every other stand to great effect. 250% increase in cuttings each time. Maintain lubes around 2%. Perform 275 BBL dilution every 5 to 6 stands. 12:00 00:00 12.00 5,556 6,510 INTRM1 DRILL DDRL P Directional Drill 9 7/8" hole from 5556' MD to 6510' MD. TVD=3656'. ADT=6.98 HRS/ ART=5.60 Hrs/ AST=1.38 Hrs. ECD=10.76 PPG. 750 GPM/ 3100 PSI/ 18k WOB/ 80-100 RPM/ Weights: 164k Up/ 135k Dn/ 148k Rot. TQ= 13k on/ 11 k off. Pumping viscosified weighted sweeps every third stand to great effect. 250% increase in cuttings each time. Maintain lubes around 2%. Perform 275 BBL dilution every 3 to 4 stands. 2/11 /2013 Directional Drill 9 7/8" hole from 6510' MD to 7419' MD. 750 GPM/ 3100 PSI/ 18k WOB/ 80-100 RPM/ Weights: 164k Up/ 135k Dn/ 148k Rot. TQ= 13k on/ 11k off. Pumping viscosified weighted sweeps or weighted sweeps periodically for hole cleaning purposes. Maintain lubes around 2%. Perform 275 BBL dilutions every 2 to 3 stands. Slide 15 to 20 feet off the top of each stand to follow directional plan. Circculate the hole clean. Trip into the casing. Circulate the casing clean. POOH for Rotary Steerable system. 00:00 10:15 10.25 6,510 7,419 INTRM1 DRILL DDRL P Directional Drill 9 7/8" hole from 6510' MD to 7419' MD. TVD=3994'. ADT=6.22 HRS/ ART=5.06 Hrs/ AST=1.16 Hrs. ECD=10.8 PPG. 775 GPM/ 3170 PSI/ 15k WOB/ 80-100 RPM/ Weights: 170k Up/ 143k Dn/ 155k Rot. TQ= 13k on/ 12k off. Pumping viscosified weighted sweeps every third stand. Maintain lubes around 2%. Perform 275 BBL dilution every 3 to 4 stands. Page 45 of 79 Time Logs Date From To Dur S. De th E. De th Phase < Code Subcode T Comment 10:15 12:00 1.75 7,419 7,232 INTRM1 DRILL CIRC P Circulate and condition hole. Pump 775 GPM/ 2820 PSI/ 80 RPM- Stand back a stand every % hour. Pump a HI-Vis weighted sweep. 66 BLS @ 775 GPM/ 100 RPM. Minimal returns seen at shakers. After 3 bottoms up pulled on elevators. Final circ. rate 800 GPM/ 3040 PSI/ 80 RPM/ 11.5k TQ/ 172k UP/ 142k Dn/ 155k Rot. 12:00 17:00 5.00 7,232 3,556 INTRM1 DRILL TRIP P Trip out of the hole on elevators. Good hole fill. From 7232' to 3556' MD. 17:00 18:00 1.00 3,556 3,274 INTRM1 DRILL REAM P Back ream out into the casing. Precautionary. 540 GPM/ 1450 PSI/ 50 RPM/ 7K TQ. No cuttings beds encountered. 18:00 19:00 1.00 3,274 3,180 INTRM1 DRILL CIRC P Inside the casing. Circulate a Hi-Vis 2 Ibs over weighted sweep, and two more bottoms up strokes. 200 % increase in cuttings load on shakers. 800 GPM/ 2800 PSI/ 50 RPM/ 7K TQ. 19:00 19:45 0.75 3,180 3,180 INTRM1 DRILL OWFF P Blow down top drive. Observe well for flow. Static. 19:45 21:30 1.75 3,180 2,048 INTRM1 DRILL TRIP P Trip out of the hole on elevators. Monitor well on trip tank.From 3180' to 2143'. Good hole fill. Stand 16 saw 15 k over pull, improper hole fill. Stop. 21:30 22:30 1.00 2,048 1,855 INTRM1 DRILL CIRC P Slow back ream. Pump 800 GPM/2550 PSI/ 50 RPM/ Pump weighted sweep. Saw 100% increase in cuttings. Approx. 2 to 3 BBLS clay returns. 22:30 23:00 0.50 1,855 1,855 INTRM1 DRILL OWFF P Blow down top drive. Observe well for flow. Static. 23:00 00:00 1.00 1,855 1,199 INTRM1 DRILL TRIP P Trip out on the elevators. Monitor well on trip tank. From 1855' to 1199' MD. Good hole fill. 2/12/2013 Trip out of the hole on elevators. Monitor the well on the trip tank. Lay down BHA #10 Mud Motor assembly. Pick up BHA#11 GeoPilot Rotary Steerable assembly. 9 7/8" bit. MWD system Gamma/ Res/Neutron/Density/ Pick up Weatherford Rip Tide Reamer. Test all tools. TIH to shoe. Slip and cut. Service rig. TIH to bottom. Precautionary ream last three stands to bottom. Directional Drill 9 7/8" hole from 7415' to 7695;' MD. 00:00 00:30 0.50 1,199 547 INTRM1 DRILL TRIP P Continue to trip out of the hole on elevators. Monitor well on trip tank. From 1199' to 547' MD. 00:30 01:30 1.00 547 83 INTRM1 DRILL TRIP P Flow check. Static. Stand back HWDP, change out jars. (HRS). 01:30 01:45 0.25 83 83 INTRM1 DRILL PULD P Down load MWD. 01:45 03:15 1.50 83 0 INTRM1 DRILL PULD P PJSM. Lay down remaining BHA components. Grade bit. Calculated fill=66.3 BBLS. Actual fill 68 BBLS. 03:15 03:45 0.50 0 0 INTRM1 DRILL RURD P Clear and clean rig floor. Page 46 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:45 05:30 1.75 0 107 INTRM1 DRILL PULD P PJSM. Make up BHA#11. 9 7/8" FX65 short gauge bit/ 7600 GeoPilot EDL/ DM/DGR/RES/ALD/CTN/ Rip Tide Reamer. to 107' MD. 05:30 07:30 2.00 107 107 INTRM1 DRILL PULD P Upload MWD tools.- pumped thru string to warm up tools - BD TD - Cont. to upload MWD 07:30 08:00 0.50 107 159 INTRM1 DRILL PULD P Continue to make up BHA to 158' as per DD. 08:00 09:00 1.00 159 159 INTRM1 DRILL PULD P Pick up two single, function test Weatherford Rip Tide Reamer @ 600 GPM, Pump closing RFID chips, confirmed closed, shallow pulse test MWD tools, lay down singles. Blow down top drive.- Change jets in reamer 09:00 09:30 0.50 159 159 INTRM1 DRILL PULD PJSM. Load nuclear sources into MWD tools. 09:30 10:00 0.50 159 622 INTRM1 DRILL TRIP P Trip in the hole with Non Mag Flex Collars, HWDP from 159' to 622' MD. 10:00 12:00 2.00 622 2,696 INTRM1 DRILL TRIP P Trip in the hole to the shoe. From 622' to 2696 MD. Fill pipe every 20 stands. Blow down top drive. 12:00 12:30 0.50 2,696 3,262 INTRM1 DRILL TRIP P Cont. RIH f/ 2696' to 3262' 12:30 15:00 2.50 3,262 3,262 INTRM1 DRILL SLPC P PJSM on slip & cut - Slip and cut drill line 60'. Perform work orders, service top drive and draw works. Calibrate block height indicator. - Change hydrualic hose for disc brake. 15:00 15:15 0.25 3,262 3,262 INTRM1 DRILL CIRC P Circulate. Down link to GP. Pulse test MWD. Blow down TD. 15:15 19:00 3.75 3,262 7,131 INTRM1 DRILL TRIP P Trip in the hole. Hole in good condition. 19:00 20:15 1.25 7,131 7,415 INTRM1 DRILL REAM P Ream to bottom the last three stands. No fill. 700 GPM/ 2600 PSI/ 100 RPM 20:15 00:00 3.75 7,415 7,695 INTRM1 DRILL DDRL P Directional drill 9 7/8" hole with GeoPilot. From 7419' to 7695' MD. 750 GPM/ 2560 PSI/ 15k Wob/ 16k TQ on bottom. 2/13/2013 Directional Drill 9 7/8" hole w/ Sperry Rotary Steerable system from 7695' to 10238' MD. 750 GPM. 2550 PSI. 150 RPM. Drilled 2543'. 00:00 12:00 12.00 7,695 8,900 INTRM1 DRILL DDRL P Drilled 9 7/8" hole f/ 7695' to 8900' MD 4542' TVD ADT- 7.59 hrs ECD- 10.67 ppg Footage - 1205' WOB 8/12 k RPM 150 GPM 750 gpm @ 2570 psi String wt PU 192 SO 153 ROT 170 Torque on/off btm.- 17/12.5 k ft/lbs Note: Began back reaming 60' on connections @ 8826' MD Page 47 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 22:45 10.75 8,900 10,144 INTRM1 DRILL DDRL P Drilled 9 7/8" hole f/ 8900' to 10144' MD 4999 TVD ADT- 7.41 hrs ECD- 10.65 ppg Footage - 1244' WOB 8/12 k RPM 150 GPM 750 gpm @ 2570 psi String wt PU 198 SO 160 ROT 182 Torque on/off btm.- 19/14 k ft/lbs Note: Began back reaming 60' on connections from 8826' MD to 9109' MD Began back reaming every 30' on connections from 9109' MD to 9673' MD. Then began a pattern of reaming 30 feet on two stands and a full 90 on the third stand. 22:45 23:30 0.75 10,144 10,144 INTRM1 DRILL CIRC P Saw a loss of 150 PSI Pump Pressure drilling fr 9980' to 10040' MD. Next stand fr 10065' to 10144' MD lost another 200 PSI during a dilution. Stopped. Flow checked well bore. Static. Tested both pumps to 2500 PSI. Good. Tested GeoSpan. Good. 23:30 00:00 0.50 10,144 10,238 INTRM1 DRILL DDRL P Drilled 9 7/8" hole f/ 10144' to 10238' MD 5033 TVD ADT- .45 hrs ECD- 10.65 ppg Footage - 96' WOB 8/12 k RPM 150 GPM 750 gpm @ 2570 psi String wt PU 200 SO 160 ROT 182 Torque on/off btm.- 19/14 k ft/lbs 2/14/2013 Drilled 9 7/8" hole w/ GP f/ 10,238' to12595' MD. 750 GPM/ 150 RPM/ 2400 PSI PP. Drilled 2357'. 00:00 12:00 12.00 10,238 11,439 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 10,238' to 11,439' MD - 5477' TVD ADT- 7.7 hrs ECD- 10.76 ppg Footage - 1201' WOB 10/15 k RPM 170 GPM 750 @ 2310 psi String wt. PU 225 SO 165 ROT 185 Torque on/off btm.- 21/16 k ft/lbs 12:00 00:00 12.00 11,439 12,595 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 11,439' to 12,595' MD - 5957' TVD ADT- 7.43 hrs ECD- 10.79 ppg Footage - 1156' WOB 10/15 k RPM 160 GPM 750 @ 2310 psi String wt. PU 237 SO 172 ROT 199 Torque on/off btm.- 23/17 k ft/lbs Page 48 of 79 Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T Comment 2/15/2013 24 hr Summary Drilled 9 7/8" hole w/ GP f/ 12,595' to 13,442' MD - Open Rip Tide UR - Performed 825 bbls whole mud dilution w/ black product for drilling HRZ - Drilled 9 7/8" x 11" hole f/ 13,442' (top of 11" hole @ 13,321'), from 13,442' to 14,009' MD. 6657' TVD. 800 GPM/ 3200 PSI/ 150 RPM. Drilled 1414'. 00:00 09:30 9.50 12,595 13,442 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 12,595' to 13,442' MD ADT- 5.07 hrs ECD - 10.76 ppg Footage - 847' WOB 9/15 k RPM 160 GPM 750 @ 2330 psi String wt. PU 265 SO 175 ROT 210 Torque on/off btm.- 24.5 / 19 k ft/lbs 09:30 10:30 1.00 13,442 13,442 INTRM1 DRILL CIRC P Obtain drilling parameters w/ pumps PU 250 ROT 170 750 gpm @ 2230 psi - Dropped RFID tag & pump down to open Rip Tide UR - observed 80 psi pressure drop - torque imcrease & downhole virbration f/ MWD tools - Dropped & pumped down 2nd RFID tag - Observed 180 psi pressure drop - tool appears to be open. 10:30 12:00 1.50 13,442 13,531 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole f/ 13442' to 13,531' MD. ADT- 1.55 hrs ECD - 10.72 ppg Footage - 89' WOB 9/15 k RPM 120 - GPM 750 @ 2300 psi String wt. PU 270 SO 175 ROT 215 Torque on/off btm.- 29 / 22 k ft/lbs Experiencing hi torque & variable TD RPM & low P rate while drilling f/ 13,442'- after opening UR Note - Top of 11" hole @ 13,315' Note- Performed 825 bbls whole mud dilution w/ 5% Inhibycol, 5 ppb Soltex, 5 ppb Resinex, 0.5 ppb Drispac plus SL , 2 % Lotorq - Lube percentage @ 3 % 12:00 00:00 12.00 13,531 14,009 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole f/ 13,531' to 14,009' MD. ADT- 8.17 hrs ECD - 10.72 ppg Footage - 478' WOB 9/15 k RPM 120 - 150 GPM 800 @ 3200 psi String wt. PU 280 SO 175 ROT 215 Torque on/off btm.- 29 / 22 k ft/lbs 2/16/2013 Drilled 9 7/8" x 11" hole f/ 14,009' to to 14,624' MD. Drop RFID chips to de -activate Weatherford reamer. Bit depth was 14,745' when the Rip Tide Reamer was turned off. From 14,624' MD to 13,321' MD was opened up to 11" hole. Page 49 of 79 Time Logs Date From To Dui S. De th E. De th Phase Code Subcode T Comment 00:00 12:00 12.00 14,009 14,526 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole w/ GP & Rip Tide UR f/ 14,009' to 14,526' MD. 6855' TVD ADT- 8.8 hrs ECD - 10.53 ppg Footage - 517' WOB 10/15 k RPM 150 GPM 800 @ 3250 psi String wt. PU 298 SO 173 ROT 215 Torque on/off btm.- 29.5 / 21.5 k ft/lbs Tops f/ Geo top HRZ slump 13,675' base HRZ slump 13,726' Top HRZ 13,900 Base HRZ 14,116 K-1 marker 14,255' Rig pick Top Kup"C" - 14,430' 12:00 18:15 6.25 14,526 14,670 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole w/ GP & Rip Tide UR f/ 14526' to 14670' MD. 6896' TVD. ADT=5.04 Hrs. ECD= 10.70 ppg / Footage = 144' WOB = 22k / RPM = 150 / GPM 800 / 3200 PSI PP. Up 295k / Dn 175k./ Rot 221 k 18:15 18:30 0.25 14,670 14,670 INTRM1 DRILL SFTY P Pre job safety meeting. Loose saver sub spotted on last connection. Discuss the proceedure to remove the clamp and retorque to 34k. 18:30 18:45 0.25 14,670 14,670 INTRM1 DRILL SVRG P Lay down one single. Put the trip tank on the hole. Break top drive saver sub @ 28k TQ. Inspect threads. Good. Re -dope. Torque to 34k with rig tongs, after getting 28k on with top drive. 18:45 19:00 0.25 14,670 14,670 INTRM1 DRILL RURD P Pick up single and make back up to stand. Wash single back to bottom. Make connection. 19:00 22:45 3.75 14,670 14,745 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole w/ GP & Rip Tide UR f/ 14,670' to 14,745' MD. 6920' TVD. ADT=3.58 Hrs. ECD= 10.63 ppg / Footage = 75' WOB = 12k / RPM = 120 / GPM 800 / 3200 PSI PP. Up 296k / Dn 172k./ Rot 222k/ TQ on/off= 28.5k/ 24k Page 50 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 22:45 00:00 1.25 14,745 14,745 INTRM1 DRILL CIRC P PJSM. De -activate Weatherford reamer. Pick up and break tool joint. Drop 6 RFID closing tags & pump down with 750 GPM/ 2530 PSI/ 120 RPM/ 28k TQ, slow pump down to 200 GPM/ 450 PSI as tags pass through reamer. Shut pump off and wait 5 mins. Pick up 60' to assist reamer blades to close. Pump with 750 GPM/ 2650 PSI. Wash and ream to bottom. Pumped two sweeps. 1. @ 14655' MD nut plug. Minimal returns. 2.@ 14711' MD Hi-Vis, weighted, nut plug. Minimal returns. Drilled actual 11" hole from 13,321 to 14,624' cutter depths. 1303' total. 2/17/2013 Drilled 9 7/8" hole w/ GP f/ 14,745' to 14,980' MD 6969' TVD - TD of section - Circ - Pumped Hi-Vls sweep, CBU"4, POOH w/ pumps f/ 14575' to 13631', RIH to 13725', blow down the top drive, monitor well, RIH f/ 13725' to 14858', precautionary wash/ream f/ 14858' to TD @ 14980', CBU (increase MW f/ 9.8 ppg to 10 ppg). 00:00 10:45 10.75 14,745 14,980 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 14,745' to 14,980' MD 6969' TVD (TD of hole section) ADT- 8.47 hrs. ECD - 10.60 ppg Footage - 235' WOB 10/15 k RPM 100/150 GPM 800 @ 3150 psi String wt. PU 310 SO 170 ROT 218 Torque on/off btm.- 29.5 / 24 k ft/lbs Note - Closed UR @ 14,745' bit depth Top of Nechelik @ 14,927' 10:45 12:00 1.25 14,980 14,858 INTRM1 CASING CIRC P Circ hole - Pumped 35 bbls Hi-vis nut plug sweep @ 800 gpm @ 3290 psi w/ 120 rpm @ 29 k torque - std back1 std every hr. f/ 14980' to 14,858' 12:00 15:45 3.75 14,858 14,575 INTRM1 CASING CIRC P Circulate 4 bottom's up while setting back a stand every hr f/ 14858' to 14575'. Pumping 800 gpm w/ initial 3290 psi, final 3190 psi. Rotate 120 rpm w/ 29k ft Ibs of torque. 15:45 18:45 3.00 14,575 13,631 INTRM1 CASING WPRT P Pull out with pumps only f/ 14575' to 13631'. Pumping 3.5 bpm w/ 350 psi, no rotation. Pulling speed 300-350 feet per minute. Noted overpull of 30k @ 14155' & 14103'. Wiped both out-ok. Upper ghost reamer was @ 8632' with bit @ 13631'. 18:45 19:00 0.25 13,631 13,725 INTRM1 CASING OTHR P RIH f/ 13631' to 13725'. Blow down the top drive. Page 51 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:00 19:30 0.50 13,725 13,725 INTRM1 CASING OWFF P Monitor well- static. 19:30 21:30 2.00 13,725 14,858 INTRM1 CASING WPRT P Trip in the hole on f/ 13725' to 14858'. No tight spots noted. Down weight 170k to 160k. 21:30 21:45 0.25 14,858 14,980 INTRMI CASING REAM P Precautionary wash/ream f/ 14858' to TD @ 14980'. No fill. Pumping 800 gpm w/ 3230 psi, rotate 120 rpm w/ 26.5k ft Ibs of torque. 21:45 00:00 2.25 14,980 14,907 INTRM1 CASING CIRC P Circulate 1.4 bottom's up, increasing mud weight f/ 9.8 ppg to 10 ppg. Pumping 800 gpm w/ 3230 psi. Rotate 120 rpm w/ 26.5k ft Ibs while going down, 27.5k ft Ibs while picking up. Work string f/ 14980' to 14907' (set back a stand after 1-1/4 hr). Added 275 bbl of 9.9 ppg mud as a dilution. Moderate cuttings coming back. Initial ECD's 10.73 to final 10.66 ppg. 2/18/2013 Circ, Spot wellbore casing running pill to 13442', POOH f/ 13442' to 10144', pump a dry job, POOH f/ 10144' to 7790', Circ to clean up hole @ 7790', POOH f/ 7790' to 6376', BR f/ 6376' to 6282', POOH f/ 6376' to 4742', circ to clean up ghost reamer, BR out to 4675'. 00:00 00:45 0.75 14,907 14,812 INTRM1 CASING CIRC P Circulate 1.6 bottom's up (total of 3).Pumping 800 gpm w/ 3230 psi. Rotate 120 rpm w/ 26.5k ft Ibs while going down, 27.5k ft Ibs while picking up. Work string f/ 14980' to 14812'. Moderate cuttings coming back. Initial ECD's 10.73 to final 10.66 ppg. 00:45 01:00 0.25 14,812 14,980 INTRM1 CASINGTRIP P Trip in f/ 14812' to TD @ 14980'. 01:00 01:45 0.75 14,812 14,980 INTRM1 CASING CIRC P Pump 35 bbl wellbore strengthening pill followed by 165 bbl casing running pill, chase with 60 bbls mud from the active pits. Pumping 600 gpm w/ 2000 psi, slowed to 4bpm w/ 390 psi. Pill: 5 ppb ea: Sack Black, Safe-Carb 20, Safe-Carb 40, Alpine beads, 3% extra Glydril & 2% Extra LoTorq. 01:45 04:00 2.25 14,980 13,442 INTRM1 CASINGTRIP P Pull out of the hole f/ 14980' to 13442', pumping 2.5 bpm w/ 290 psi. Pulling 12007hr, laying in the casing runningpill. 04:00 04:30 0.50 13,442 13,442 INTRM1 CASING OWFF P Blow down the top drive, monitor well- static. 04:30 10:45 6.25 13,442 10,144 INTRM1 CASING TRIP P Pull out of the hole on the trip tank f/ 13442' to 10,144' - Worked thru various tigh spots - 13,174, 13,102,' 12,432', 12,274', 12,034', 11,940', 11,660', 11,502', 11,330', 11,282', 10,905', & 10,804' 10:45 11:15 0.50 10,144 10,144 INTRM1 CASING CIRC P Pumped 31 bbls 12.0 ppg mud for dry job @ 6 bbls/min @ 380 psi 11:15 12:00 0.75 10,144 9,956 INTRM1 CASING TRIP P Cont. POOH on TT f/ 10,144' to 9956' Page 52 of 79 Time togs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 15:00 3.00 9,956 7,790 INTRM1 CASING TRIP P Cont. POOH on TT f/ 9956' to 7790'- worked thru various tight spots - 9737', 7790' - @ 7790' unable to work thru attempt to rotate w/o pump 15:00 16:30 1.50 7,790 7,790 INTRM1 CASING CIRC P Break circ - circ & clean up hole @ 700 gpm @ 2030 psi w/ 120 rpm's w/ 16 k toruqe - wroking pipe f/ 7884' to 7790'. Initial ECD's 10.9 ppg, final 10.65 16:30 16:45 0.25 7,790 7,790 INTRM1 CASING OWFF P Blow down the top drive. Monitor well- static. 16:45 19:00 2.25 7,790 6,376 INTRM1 CASING TRIP P Continue to pull out on the trip tank f/ 7790' to 6376'. Pulled tight @ 6448' & 6397' and 6325'-- 200-205k. Drop back down to 6376'. 19:00 19:45 0.75 6,376 6,376 INTRM1 CASING REAM P Make a top drive connection @ 6376', Back ream slow f/ 6376' to 6282'. Pumping 700 gpm w/ 1790 psi. Rotate 120 rpm w/ 14k ft Ibs of torque. Initial ECD's 10.71 ppg, final 10.55 ppg. MW in and out when through circ 1.7 BU was 10+ ppg. Torqued up a little @ 6327'. 19:45 20:00 0.25 6,376 6,376 INTRM1 CASING OTHR P Blow down the top drive. 20:00 20:15 0.25 6,376 6,376 INTRM1 CASING OWFF P Monitor well- static -slight drop. 20:15 22:30 2.25 6,376 4,742 INTRM1 CASING TRIP P Continue to POOH on the trip tank f/ 6376' to 4742'. Wipe tight hole @ 6242' & 4742' (Ghost reamer @ the csg shoe). Observed overpull with ghost reamer @ the csg shoe. Wiped through, then dropped back down to 4769' to circulate and clean up. 22:30 23:45 1.25 4,742 4,675 INTRM1 CASING REAM P Make a top drive connection @ 4769'. Pumping 300 gpm w/ 490 psi. Worked into casing w/ ghost reamer f/ 4769' to 4735' bit depth with no problems. Rotating 100 rpm w/ 11.5k ft Ibs of torque. Dropped back down to 4769', increased flow rate to 700 gpm w/ 1600 psi, ECD's of 10.62 ppg initial. Worked up into casing to clean up ghost reamer. Final ECD of 10.52 ppg. One pressure spike of 10.82 ppg, then back down to 10.52 ppg- Circulated a total of 2 BU. 23:45 00:00 0.25 4,675 4,675 INTRM1 CASING OTHR P Blow down the top drive. Monitor well- static. 2/19/2013 POOH f/ 4675' to 3252', pump and confirm underreamer is closed, circ casing clean w/ sweep to 3167', monitor well -static, pump dry job, POOH f/ 3167' to 622', monitor well -static. Work BHA, clean/clear floor. RU, then perform BOPE BI-Weekly test w/ 5" test joint (witness of test waived by AOGCC insp Bob Noble). Change top pipe rams to 7-5/8", change out upper IBOP on top drive, test annular to 250 & 2500 psi w/ 7-5/8" test joint. Note: Finished BOPE test @ 0030 hrs 2/20/2013. Page 53 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 02:00 2.00 4,675 3,262 INTRM1 CASING TRIP P Pull out of the hole on the trip tank f/ 4675' to 3262'. PU 137k, SO 120k. Wipe 3440'-- 20k over 02:00 02:15 0.25 3,262 3,252 INTRM1 CASING DHEQ P Pull out f/ 3262' to 3251'. Confirm cutters are closed on underreamer by pumping 650 gpm w/ 1280 psi @ 3252' bit depth (ghost reamer blades 9' above shoe) and slack off. OK. 02:15 02:45 0.50 3,252 3,167 INTRM1 CASING CIRC P Pump out f/ 3252' to clean up casing, pumping 650 gpm w/ 1280 psi, rotate 120 rpm w/ 8k ft Ibs of torque. Pump a 34 bbl 11.5 ppg Hi-Vis nut plug sweep. Initial ECD's 10.48 ppg @ 650 gpm, final 10.46 ppg @ 700 gpm w/ 1480 psi. 02:45 03:00 0.25 3,167 3,167 INTRM1 CASING OTHR P Blow down the top drive. 03:00 03:15 0.25 3,167 3,167 INTRM1 CASINGOWFF P Monitorwell- static. 03:15 03:30 0.25 3,167 3,167 INTRM1 CASING CIRC P Pump a 24 bbl dry job (11.5 ppg) - BD TD 03:30 06:00 2.50 3,167 622 INTRM1 CASING TRIP P Cont. POOH on TT f/ 3167' to 622'- Monitor well (slight drop) 06:00 06:45 0.75 622 220 INTRM1 CASING TRIP P Pull & LD 3 jts. HWDP &jars - Pulled & stood back 3 stds HWDP f/ 622' to 220' 06:45 07:00 0.25 220 220 INTRM1 CASING SFTY P Held PJSM w/ crew, MWD, & DD on pulling RA sources & laying down BHA 07:00 07:30 0.50 220 155 INTRM1 CASING PULD P Pull & LD (2) NM flex DC's - Pull RA sources 07:30 08:45 1.25 155 107 INTRM1 CASING PULD P Pull & LD - pony DC - Rip Tide UR - ghost reamer & float sub 08:45 09:45 1.00 107 107 INTRM1 CASING OTHR P Plug in & down load MWD 09:45 11:15 1.50 107 0 INTRM1 CASING PULD P Cont. LD BHA - MDW tools - Geo-pilot & bit Calc. hole fill 129.47 bbls / Actual fill 148.5 bbls 11:15 12:00 0.75 0 0 INTRM1 CASING OTHR P Housekeeping on rig floor - clear BHA tools from floor & clean up floor 12:00 12:15 0.25 0 0 INTRM1 WHDBO SFTY P Pre job safety meeting on rigging up to test BOPE. 12:15 12:45 0.50 0 0 INTRM1 WHDBOOTHR P Pull FMC wear bushing, set FMC upper test plug. 12:45 13:45 1.00 0 0 INTRM1 WHDBO RURD P Rig up BOPE testing equipment. Fill lines, check for leaks. Page 54 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:45 19:00 5.25 0 0 INTRM1 WHDBO BOPE P Test BOPE: Full BOPE test with 5" test joint and FMC upper test plug, test to 250 psi low and 3500 psi high all componets --except test of the annular to 250 psi low and 2500 psi high. Hold all tests f/ 5 minutes, chart all tests. Witness of test waived by AOGCC inspector Bob Noble. The top drive SOP failed to test. Will change out while changing top pipe rams to run casing, will test when testing the pipe rams and annular w/ 7-5/8" test joint. Functioned rams f/ the remote station in boiler room after accumulator test. Pumped through both the auto choke and manual choke, choked to 1200 psi then opened. Accumulator test: 3000 psi initial, 1550 after closing annular, top, bottom and both HCR's + operate top pipe one more time to simulate operating blinds. 200 psi build up in 38 seconds, full charge in 190 seconds. Nitrogen backup 4 bottle average 1900 psi. Performed CPAI test of both the air and electric pumps on the accumulator with bottles isolated: Functioned two rams and 1 HCR: 43 seconds to full charge of 3000 psi f/ the electric pump. 66 seconds to full charge of 2500 psi f/ the air pumps. 19:00 19:15 0.25 0 0 INTRM1 WHDBO OTHR P Blow down choke and kill lines and choke manifold. Note: Hole was kept full while testing, hole took 3 bbls f/ 1330 to 1915 hrs= .52 bph loss. 19:15 19:30 0.25 0 0 INTRM1 WHDBO SFTY P Pre job safety meeting on changing top pipe rams f/ 3-1/2" x 6 to 7-5/8". Pre job safety meeting on change out of the auto IBOP on the top drive. 19:30 22:00 2.50 0 0 INTRM1 WHDBOOTHR P Change top pipe rams f/ 3-1/2" x 6 to 7-5/8". Working to change out upper automatic IBOP on the top drive. 22:00 23:00 1.00 0 0 INTRM1 RIGMNT RGRP T Continue working on replacement of top drive auto IBOP. Putting clamps on, connecting grabber, connect hoses. 23:00 23:45 0.75 0 0 INTRM1 WHDBO RURD P Rig up to test top pipe rams (7-5/8"), annular and upper IBOP. 23:45 00:00 0.25 0 0 INTRM1 WHDBO P Test with FMC upper test plug and 7-5/8" test joint, both kill and choke HCR valves closed. Test annular to 250 psi low and 2500 psi high. Hold all tests f/ 5 minutes, chart all tests. Page 55 of 79 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 2/20/2013 24 hr Summary Finish BI-weekly BOPE test, set wear bushing, RU to run 7-5/8" 29.7 ppf L-80 BTC-m casing, PJSM, Run 7-5/8" intermediate casing to 10140'. 00:00 00:30 0.50 0 0 INTRM1 WHDBO BOPE P Testing upper pipe rams L7-5/8'I upper auto IBOP on the top drive, both kill and choke HCR's to 250 psi and 3500 psi. Hold each test f/ 5 minutes 00:30 01:15 0.75 0 0 INTRM1 WHDBO RURD P Rig down testing equipment. Blow down all lines. 01:15 01:45 0.50 0 0 INTRM1 WHDBOOTHR P Pull test plug, set FMC thin wall casing running wear bushing (10.5" 1 D). 01:45 03:15 1.50 0 0 INTRM1 CASING RURD P Rig up Tesco casing running tool for running 7-5/8" casing. 03:15 03:45 0.50 0 0 INTRM1 CASING SFTY P Pre job safety meeting on running 7-5/8" casing. 03:45 09:30 5.75 0 3,239 INTRM1 CASING RNCS P Ran 7 5/8" 29.7# L-80 BTC-m casing as follows: Float shoe (Ray Oil tools silver bullet) 1 jt csg - Float collar (Halliburton Super Seal II w/ baffle adaptor) - 2 jts. csg - Shut-off baffle collar (Halliburton) - 1 jt csg to 169' All connections made up w/BakerLoc - filled pipe & checked floats) - Cont. RIH w/ 7 5/8" 29.7# L-80 BTC-m casing f/ 169' to 3239' (77 total jts + (1) 10' pup jt in hole) - PU wt 132 SO wt 125 Installed 1 straight blade cent on stop jt 10' up w/ stop ring & Hydroform cents. on jts 2 thru 35 - Installed 10' pup jt. on the top of jt # 17 09:30 10:15 0.75 3,239 3,239 INTRM1 CASING CIRC P Break circ & circulate casing volume - Staged pump up to 6 bbls/min @ 220 psi 10:15 12:00 1.75 3,239 3,964 INTRM1 CASING RNCS P Cont. RIH w/ 7 5/8" 29.7# L-80 BTC-m casing f/ 3239' to 3964' (94 jts total in hole) - PU wt 145 SO wt. 127 12:00 14:30 2.50 3,964 5,709 INTRMI CASING RNCS P Cont. RIH w/ 7 5/8" 29.7# L-80 BTC-m casing f/ 3964' to 5709' (135 jts total in hole) PU wt 170 SO wt 130 14:30 15:30 1.00 5,709 5,709 INTRM1 CASING CIRC P Break circ & stage pumps up to 6 bbls/min - ICR - 2 bbls/min @ 210 psi - FCR - 6 bbls/min @ 320 psi. Pumped 400 bbls. 15:30 17:30 2.00 5,709 6,930 INTRM1 CASING RNCS P Cont. RIH w/ 7 5/8" 29.7# L-80 BTC-m casing f/ 5709' to 6930' Qt # 164 in the hole. Installed hydraform centralizer on jt #164. 17:30 17:45 0.25 6,930 6,933 INTRM1 CASING RNCS P Baker lock Halliburton stage collar between jt # 164 and Jt # 165. Installed hydraform centralizer on jt #165. Page 56 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17.45 19:30 1.75 6,933 8,246 INTRM1 CASING RNCS P Continue to run 7-5/8" 29.7 ppf L-80 casing f/ 6933' to 8246' (195 jts in the hole). Installing hydraform centralizers to it # 191--total of 62 hydraform centralizers in the hole. PU wt 250k, SO wt 142K 19:30 21:30 2.00 8,246 8,246 INTRM1 CASING CIRC P Break circ & stage pumps up to 6 bbls/min - ICR - 2 bbls/min @ 180 psi - FCR - 6 bbls/min @ 270 psi. Circulated 630 bbls to achieve 10 ppg in and out. After circulating: PU wt 225k, SO wt 148k. 21:30 00:00 2.50 8,246 10,130 INTRM1 CASING RNCS P Continue to run 7-5/8" 29.7 ppf L-80 casing f/ 8246' to 10130' (240 its in the hole). SO wt 2/21 /2013 Continue running 7-5/8" 29.7 ppf L-80 BTC-m casing f/ 10140' to 14970', R/D TESCO, RU bales and cement head, circ and condition mud and hole f/ cement, cement 1 st stage with full returns, bump plug, load second stage closing plug. 00:00 01:00 1.00 10,130 10,760 INTRMI CASING RNCS P Continue to run 7-5/8" 29.7 ppf L-80 casing f/ 101 30'to 10760' (255 jts in the hole). PU wt 300k, SO wt 150k 01:00 03:45 2.75 10,760 10,760 INTRM1 CASING CIRC P Break circ & stage pumps up to 6 bbls/min - ICR - 2 bbls/min @ 230 psi - FCR - 6 bbls/min @ 300 psi. Circulated 900 bbls to achieve 10 ppg in and out. After circulating: PU wt 265k, SO wt 160k. 03:45 08:00 4.25 10,760 13,411 INTRMI CASING RNCS P Continue to run 7-5/8" 29.7 ppf L-80 casing f/ 10760' to 13,411' (318 its in the hole). PU wt 390 k(broke over) pumping 1 bbl/min PU wt 370 k - SO wt 158 k 08:00 11:15 3.25 13,411 13,411 INTRMI CASING CIRC P Break circ - Stage pump up to 6 bbls/min - ICR - 1.1 bbls/min @ 300 psi FCR - 6 bbls/min @ 410 psi - final string wt. w/ pump PU 330 SO 160 -Pumped 867 bbls 11:15 14:00 2.75 13,411 14,970 INTRMI CASING RNCS P Cont. RI w/ 7 5/8" 29.7# L-80 BTC-m casing f/ 13411' to 14,932' (354 its total in hole) SO wt 155 - MU FMC fluted casing hanger - PU & MU landing jt. - Land casing in wellhead on hanger w/ shoe @ 14,969.57' - FC @ 14,924' - Shut -off baffle collar @ 14,839' - HES cementer @ 8036' 14:00 14:15 0.25 14,970 14,970 INTRM1 CEMEN' OTHR P Blow down the top drive 14:15 14:30 0.25 14,970 14,970 INTRM1 CEMEN- SFTY P Pre job safety meeting on removing TESCO casing running tool and installing long bales and MU of Dowell cement head. 14:30 15:00 0.50 14,970 14,970 INTRM1 CEMEN' RURD P Rig down TESCO casing running tools. Page 57 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:00 15:30 0.50 14,970 14,970 INTRM1 CEMEN- RURD P Pick up long casing running bales, casing elevators, Rig up Dowell cement head and hose. 15:30 20:45 5.25 14,970 14,970 INTRM1 CEMEN-CIRC P Circulate and condition mud and hole for cement. Stage up f/ 1.5 bpm to 6 bpm. Final circ pressure of 440 psi w/ 6 bpm. Circulated until 10 ppg MW in and out, PVNP 10/20. Held pre job safety meeting while circulating. Circulated a total of 1650 bbls. Attempted to reciprocate pipe after circulating a bottom's up. Broke over @ 420k. Worked pipe up hole with drag dropping to 365-375k with intermittent overpull to 400k. Moved pipe f/ 14970' to 14960'. SO wt 155k. Decision to leave on hanger @ 1800 hrs. Note: Total losses while running casing = 39 bbls. Total losses today = 28 bbls. 20:45 22:00 1.25 14,970 14,970 INTRM1 CEMEN- CMNT P Dowell flood lines to floor w/ CW100, pressure test to 4000 psi-ok, finish pumping a total of 40.2 bbls of CW100. Batch up 11.5 ppg mudPush, pump a total of 39 bbls @ 4 bpm, drop bottom plug, kick out plug w/ 1 bbl more mudPush (40 bbls total). Shut down, load shutoff plug in the head. Dowell mix and pump 92.4 bbls (447 sx) of 15.8ppg cement (Alpine intermediate Tail- yield 1.16 cuft/sx, mix water 5.076 gal/sx, thickening time 5.75 hrs) @ 5.7 bpm w/ 456-370 psi. Shut down, drop shutoff plug, then Dowell kick out plug w/ 20 bbls of water. 22:00 00:00 2.00 14,970 14,970 INTRM1 CEMEN' DISP P Rig displace cement w/ 10 ppg mud, pumping 8 bpm to catch cement, then reduce rate to 6 bpm, slow to 4 bpm f/ top plug to go through cementer, increase back to 6 bpm, slow to 4 bpm f/ shutoff plug to go through cementer, then back to 6 bpm. Slowed to 4 bpm while bottom plug went through baffle collar and landed on the float collar, increased to 6 bpm, slowed to 3 bpm f/ last 8.6 bbls pumped. Bumped plug @ 2347 hrs 2/20/2013. Final pressure was 450 psi, bumped to 950 psi, held f/ 5 minutes, bleed off pressure. Floats held. Load second stage cement plug in the cement head. Full returns. Page 58 of 79 5" 7 160 b CJ^< Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 2/22/2013 za hMr Summary Open HES cementer f/ 2nd stage cement job, perform cement job, bump plug, pressure up to close cementer, Rig down casing/cementing equipment, install FMC packoff-test to 5000, change top pipe rams, test w/ 4" test joint, S& C drill line - UD 5" dp f/ derrick (70 out of 159). 00:00 00:15 0.25 14,970 14,970 INTRM1 CEMEN" CIRC P Pressure up to 3240 psi to open the 7-5/8" HES cementer in the hole @ 8036.67'. Circulate and condition mud and hole f/ cement. Pumping 6 bpm w/ 290 psi. 00:15 00:45 0.50 14,970 14,970 INTRM1 CEMEN'SFTY P Pre job safety meeting on 2nd stage cement job. Continue to circulate. Pumped a total of 190 bbls. MW in and out 10 ppg. 00:45 01:30 0.75 14,970 14,970 INTRM1 CEMEN-CMNT P Dowell pump 30 bbls of CW 100, batch up mudPush to 11.5ppg, pump 33.2 bbls @ 4.5 bpm, batch up cement to 15.8 ppg (Alpine Quannik- yield 1.16 cuft/sx, mix water 5.092 gal/sx, thickening time 4.85 hr), then pump 59 1 bbls, shut down, drop second stage closing plug, Dowell kick out plug w/ 20 bbls of water. 01:30 02:30 1.00 14,970 14,970 INTRM1 CEMEN- DISP P Rig displace w/ 10 ppg mud @ 6 bpm until last 18.3 bbls, then slowed to 3 bpm. Bumped plug pumping 3 bpm w/ 220 psi. Increased pressure to 2000 psi and held f/ 5 minutes to shut cementer. HES cementer closed @ observed 1260 psi._E retufns. Bleed off pressure. CIP @ 0223 hrs 2/22/2013. 02:30 02:45 0.25 14,970 14,970 INTRM1 CEMEN-SFTY P Pre job safety meeting on rigging down casing and cementing equipment. 02:45 04:45 2.00 14,970 0 INTRM1 CEMEN- RURD P Blow down lines, rig down cement head, long bales, casing slips. Break and lay down FMC landing joint (8.5-4 Acme LH thread). Send tools down the beaver slide. 04:45 05:00 0.25 0 0 INTRM1 WHDBO RURD P Pull FMC thin wall casing wear bushing. 05:00 06:00 1.00 0 0 INTRM1 WHDBO OTHR P Install FMC 7-5/8" packoff.& test to 5000 psi for 10 mins. 06:00 08:30 2.50 0 0 INTRM1 WHDBO OTHR P PJSM on chaning rams & saver sub - Changed top pipe rams f/ 7 5/8" to 3 1/2" x 6" VBR - Changed TD saver sub f/ 4 1/2" IF to 4" XT-39 08:30 09:00 0.50 0 0 INTRM1 WHDBO OTHR P Install mouse hole - Set test plug 09:00 09:45 0.75 0 0 INTRM1 WHDBO OTHR P Changed dies in iron roughneck for 4" DP - MU floor valves - Fill BOP stack Page 59 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:45 10:45 1.00 0 0 INTRM1 WHDBO OTHR P Test annular to 250 & 2500 psi - Tested upper & lower pipe rams to 250 & 3500 psi - Tested 4" floor safety & dart valves to 250 & 3500 psi - All tests were for 5 mins. & tested against HRC kill & choke valves 10:45 11:15 0.50 0 0 INTRM1 WHDBO OTHR P RD test equipment - Pull test plug - Install short wear bushing W/ 6.9375"ID 11:15 11:45 0.50 0 0 INTRM1 CEMEN" SFTY P Held PJSM on slip & cutting drill line - Reviewed safety observation of crew changing pipe rams 11:45 12:30 0.75 0 0 INTRM1 CEMEN-SLPC P Slip & cut drill line. Change heads in iron roughneck. Install bales and 4" elevators. Performed Annular LOT ( 15.4 ppg) & Freeze protect of 10 3/4" x 7 5/8" annulus w/ Dowell. Pumped 21 bbls water f/ test, 300 bbls water flush, and 60.11 bbls diesel. 12:30 12:45 0.25 0 0 INTRM1 RIGMNT SFTY P Held PJSM on slip & cutting drill line - Crew change. 12:45 13:45 1.00 0 0 INTRM1 RIGMNT SLPC P Slip & cut 82.5' of 1-3/8" drill line. 13:45 14:15 0.50 0 0 INTRM1 RIGMNT SVRG P Service top drive and drawworks. 14:15 14:30 0.25 0 0 INTRM1 CEMEN"RURD P Lay down a joint of 4", change elevators to 5". 14:30 00:00 9.50 0 0 INTRM1 CEMEN" PULD P Lay down 5" drill pipe f/ the derrick. 70 stands la ed down. 2/23/2013 UD 5" dp f/ the derrick, service rig, repair iron roughneck, cont to lay down 5" dp f/ derrick, prepare then PU stand back 25 stands of 4" dp @ midnight. 00:00 05:00 5.00 0 0 INTRM1 CEMEN- PULD P Lay down 5" drill pipe from the derrick. 05:00 05:30 0.50 0 0 INTRM1 CEMEN'SVRG P Service rig 05:30 09:00 3.50 0 0 INTRM1 CEMEN" RGRP T Change out ram on iron roughneck - trouble shoot pipe skate 09:00 12:00 3.00 0 0 INTRM1 CEMEN- PULD P Cont. LD 5" DP f/ shed via mouse hole 12:00 19:15 7.25 0 0 INTRM1 CEMEN- PULD P Cont. LD 5" DP f/ shed via mouse hole ( 45 stands, total of 160 Iayed down). 19:15 20:30 1.25 0 0 INTRM1 CEMEN RURD P Change heads f/ 5" to 4" on the iron roughneck, change elevators to 4", empty pipe shed of 5" drill pipe. 20:30 00:00 3.50 0 0 INTRM1 CEMEN- PULD P Pick up 4" drill pipe f/ pipe shed and stand back in the derrick, via the mouse hole. Total of 25 stands picked up @ midnight. 2/24/2013 PU/MU stand back 4" dp (Total of 43 stands in derrick, MU cleanout BHA, single in hole to 7835', test casing to 1000 psi f/ 10 minutes-ok, wash to stage collar @ 8036', drill stage collar, wash to 8217', circ, RU then test casing to 3500 psi f/ 10 minutes-ok, pump dry job, POOH to 4070' @ midnight. Page 60 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:15 1.25 0 0 INTRM1 CEMEN- PULD P Pick up 4" drill pipe f/ pipe shed and stand back in the derrick, via the mouse hole. 18 stands picked up since midnight. Total of 43 stands picked up and stood back. 01:15 01:30 0.25 0 INTRM1 CEMEN'SFTY P Pre job on picking up/ making up clean out BHA. 01:30 03:00 1.50 0 299 INTRM1 CEMEN- PULD P MU Clean out assembly - bit - BS - Stab - (3) NM flex DC's - XO - 1 jt HWDP - jars - 1 jt HWDP - drilling bumper sub - 3 jts HWDP to 299' 03:00 05:45 2.75 299 2,203 INTRM1 CEMEN" PULD P RIH w/ clean out assembly f/ 299' to 2203' - picking up 4" DP f/ pipe shed 05:45 06:15 0.50 2,203 2,203 INTRM1 CEMEN-SVRG P Service rig 06:15 12:00 5.75 2,203 6,975 INTRM1 CEMEN- PULD P Cont. RIH w/ clean out assembly f/ 2203' to 6975' - picking up 4" DP f/ shed - filled pipe every 20 stds. 12:00 12:45 0.75 6,975 7,835 INTRM1 CEMEN- PULD P Cont. RIH w/ clean out assembly f/ 6975' to 7835' - picking 4" DP f/ shed 12:45 13:30 0.75 7,835 7,835 INTRM1 CEMEN"CIRC P Fill pipe - Blow down TD 13:30 14:30 1.00 7,835 7,835 INTRM1 CEMEN' PRTS P RU & pressure test 7 5/8" casing to 1000 psi for 10 mins - Good test - Bleed off - Blow down lines - RD 14:30 14:45 0.25 7,835 7,952 INTRM1 CEMEN" WASH P Wash down f/ 7835' to 7952' @ 300 gpm @ 1260 psi w/ 60 rpm's - ROT wt 110 k- Tagged cmt @ 7952' 14:45 17:15 2.50 7,952 8,041 INTRM1 CEMEN- DRLG P Clean out cmt f/ 7952' to 8036' ( top of stage collar) - Drill stage collar f/ 8036' to 8041'. Pumping 300 gpm w/ 1250 psi, rotate 40-70 rpm w/ 11.5k ft Ibs of torque. WOB 18-19k. 17:15 18:00 0.75 8,041 8,217 INTRM1 CEMEN-REAM P Wash and ream f/ 8041' to 8217'. Pumping 410 gpm w/ 1910 psi, rotate 60 rpm w/ 11.5kk ft Ibs of torque. 18:00 18:30 0.50 8,217 8,217 INTRM1 CEMEN" CIRC P Circ bottom's up. Pumping 412 gpm w/ 1910 psi, rotate 60 rpm w/ 11.5k ft Ibs of torque. PU wt 175k, SO wt 110. 18:30 18:45 0.25 INTRM1 CEMEN" SFTY P Pre job safety meeting on casing test rig up. 18:45 19:00 0.25 8,217 8,217 INTRM1 CEMEN- RURD P Blow down the top drive. Rig up to pressure test 7-5/8" 29.7 ppf L-80 BTC casing to 3500 psi f/ 10 minutes. Remove bell guide f/ top d rive. 19:00 19:30 0.50 8,217 8,217 INTRM1 CEMEN- DHEQ P Test casing to 3500 psi f/ 10 min - good test. Charted test, pumped 7.7 bbls of 10 ppg mud, 10 min gels 18. Pressured to 3580, lost 75 psi in 10 minutes to 3505 psi. 19:30 19:45 0.25 8,217 8,217 INTRM1 CEMEN'OTHR P Blow down the kill line. 19:45 20:15 0.50 8,217 8,217 INTRM1 CEMEN"CIRC P Pump a 31 bbl dry job (1.5 ppg over MW= 11.5 ppg). Blow down lines. 20:15 22:45 2.50 8,217 4,715 INTRM1 CEMEN" TRIP P Pull out of the hole f/ 8217' to 4715'. Monitor well on the trip tank. Page 61 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 22:45 23:00 0.25 4,715 4,715 INTRM1 CEMEN" SFTY P BOP drill while trip out of hole @ 4715', raised float. Post drill recap. 23:00 00:00 1.00 4,715 4,017 INTRM1 CEMEN" TRIP P Continue to pull out of the hole f/ 4715' to 4070'. Monitor well on the trip tank. 2/25/2013 Con't POOH w/ stage collar cleanout BHA f/ 4070', L/D BHA, RU then Bi-Weekly test of BOPE (witness of test waived by AOGCC inspector Jeff Jones), MU 6-3/4" GeoPilot BHA to 420', single in the hole w/ 4" Weatherford drill pipe f/ the pipe shed to 5611'. 00:00 01:15 1.25 4,017 299 INTRM1 CEMEN" TRIP P Continue to pull out of the hole f/ 4070' to 299'. Monitor well on the trip tank. 01:15 01:30 0.25 299 299 INTRM1 CEMEN-OWFF P Monitorwell- static. 01:30 01:45 0.25 299 101 INTRM1 CEMEN' PULD P Lay down bumper sub, stand back and 4" HWDP. 01:45 02:15 0.50 101 0 INTRM1 CEMEN- PULD _jars P Change elevators to 3-1/2", lay down cleanout BHA per directional driller. 02:15 03:15 1.00 0 0 INTRMI WHDBO RURD P Blow down the top drive, gas buster line. Drain the stack. 03:15 04:00 0.75 0 0 INTRM1 WHDBO RURD P Pull wear bushing - Set upper test plug w/ 4" test joint. RU testing equipment. Fill hole, work the air out. 04.00 08:45 4.75 0 0 INTRM1 WHDBO BOPE P Test BOPE as follows: annular to 250 & 2500 psi - Upper pipe rams, choke manifold valves, choke & kill line manual & HCR valves - Floor safety & dart valves - Auto & manual IBOP valves - Lower pipes to 250 & 3500 psi - Performed accumulator recovery test - LD test jt. (4") - tested blind rams to 250 & 3500 psi - Tested upper and lower pipe rams and annular preventer with 3 1/2" and 4" test joints - Rams 250/3500 - annular 250/2500 psi - Witnessing of test waived by Jeff Jones w/ AOGCC. Note: Electrician tested gas alarms. 08:45 09:15 0.50 0 0 INTRMI WHDBOOTHR P Pull test plug - Install wear bushing 6.9375" 1 D) 09:15 09:30 0.25 0 0 INTRM1 CEMEN-OTHR P Blow down lines - Bring BHA components to rig floor 09:30 09:45 0.25 0 0 INTRM1 CEMEN-SFTY P Held PJSM on MU BHA - Reveiwed incident on Doyon 15 ( finger injury) 09:45 12:00 2.25 0 129 INTRM1 CEMEN- PULD P MU BHA # 13 - bit - 6 3/4" GP - GP flex collar - Stab - ADR collar - Stab - DM collar - GM collar - ALD collar - CTN collar - PWD - TM collar - to 129' 12:00 14:15 2.25 129 129 INTRM1 CEMEN-OTHR T Plug into MWD & attempt to down load 14:15 14:45 0.50 129 129 INTRMI CEMEN-CIRC T Circulate to warm up tools. Break in seals on the GeoPilot, pumping 250 gpm w/ 950 psi. 14:45 15:00 0.25 129 --r129 129 INTRM1 CEMEN-OTHR T Blow down the top drive. 15:00 15:30 0.50 129 INTRM1 CEMEN-OTHR P I Plug into MWD & load info. Page 62 of 79 13 Time 'Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:30 16:00 0.50 129 129 INTRMI CEMEN-SFTY P Pre job safety meeting, then install Nuke sources. 16:00 16:45 0.75 129 420 INTRM1 CEMEN- PULD P Continue to MU BHA f/ 129' to 420'. 16:45 17:15 0.50 420 420 INTRM1 CEMEN" DHEQ P Shallow pulse test MWD tools. Pumping 250 gpm w/ 970 psi. Rotate 40 rpm w/ 4k ft Ibs of torque to break in seals on the GeoPilot. 17:15 17:30 0.25 420 420 INTRM1 CEMEN-OTHR P Blow down the top drive. 17:30 17:45 0.25 420 420 INTRM1 CEMEN' SFTY P Pre job safety meeting on picking up 324 jts (108 stands) of 4" Weatherford 14 ppf rental drill pipe and singling in the hole. 17:45 00:00 6.25 420 5,611 INTRM1 CEMEN- PULD P PU/MU RIH w/ 4" dp from the pipe shed f/ 420' to 5611'. Fill pipe every 20 stands. Break in geoPilot. Drifted pipe w/ 2.38" OD rabbit. 2/26/2013 Cont to single in the hole w/ 4" dp f/ pipe shed f/ 5611' to 8246' Rotate through debris f/ stage collar to 8261', con't RIH w/ dp f/ pipe shed to 10622', Trip f/ derrick to 14727', slip and cut drill line, wash f/ 14727' to 14795'- tag cement. CBU, displ f/ 10 ppg Glydril to 9 ppg Flothru, test casing to 3500 psi f/ 30 minutes -good. Drill cement, stage collar, float collar and float shoe +20' new hole to 15000'. CBU, stand back a stand to 14918', RU to test formation to 12.5 ppg EMW. 00:00 03:00 3.00 5,611 8,246 INTRM1 CEMEN" PULD P Con't to PU/MU RIH w/ 4" dp from the pipe shed f/ 5611' to 8246'. Fill pipe every 20 stands. Drifted pipe w/ 2.38" OD rabbit. Monitor well on the trip tank. 03:00 03:30 0.50 8,246 8,261 INTRM1 CEMEN- REAM P Circulate and rotate through an obstruction (debris f/ stage collar) @ 8246'. Pumping 198 gpm w/ 1160 psi, rotate 60 rpm w/ 13.5k ft Ibs of torque. Rotate f/ 8246' to 8261'. PU wt 175k, SO wt 105k, Rot wt 133k. 03:30 03:45 0.25 8,261 8,261 INTRM1 CEMEN' OTHR P Blow down the top drive. 03:45 05:45 2.00 8,261 10,622 INTRMI CEMEN- PULD P Con't to PU/MU RIH w/ 4" dp from the pipe shed f/ 8261' to 10622'. Fill pipe every 20 stands. Drifted pipe w/ 2.38" OD rabbit. Monitor well on the trip tank. 05:45 10:00 4.25 10,622 14,727 INTRM1 CEMEN-TRIP P Trip in the hole w/ 6-3/4" bit and GeoPilot assembly f/ 106222' to 14727'. Fill pipe every 20 stands. Monitor well on the trip tank. 10:00 10:15 0.25 14,727 14,727 INTRM1 RIGMNT SFTY P Pre job safety meeting on slip and cut drill line. 10:15 11:30 1.25 14,727 14,727 INTRM1 RIGMNT SLPC P Slip and cut 60' of 1-3/8" drill line. 11:30 12:00 0.50 14,727 14,727 INTRMI RIGMNTSVRG P Service rig. 12:00 12:15 0.25 14,727 14,795 INTRMI CEMEN- WASH P Wash down f/ 14727' to 14795', tag cement @ 14795'. Pumping 250 gpm w/ 2300 psi. 12:15 13:30 1.25 14,795 14,795 INTRM1 CEMEN-CIRC P Circulate bottom's up, pumping 250 gpm w/ 2250 psi. PU wt 250k, SOW 120k, Rot wt 168k. Torque 19.5 ft lbs. Page 63 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:30 13:45 0.25 14,795 14,795 INTRM1 CEMEN-SFTY P Pre job safety meeting on displacement to 9 ppg Flow Thru mud. 13:45 15:15 1.50 14,795 14,795 INTRM1 CEMEN-CIRC P Displace 10 ppg Glydril mud to 9 ppg Flow Thru mud. Pumping 300 gpm w/ 2430 psi. Reciprocate. Rotate 80 rpm w/ 16k ft Ibs of torque. PU wt 215, SO wt 145k, Rot wt 172k, Torque 11.5k ft lbs. 15:15 15:30 0.25 14,795 14,795 INTRMI CEMEN-OTHR P Blow down the top drive. 15:30 15:45 0.25 14,795 14,795 INTRM1 CEMEN- SFTYP Pre job safety meeting 15:45 16:00 0.25 14,795 14,795 INTRM1 CEMEN-RURD P Rig up to test the 7-5/8" 29.7 ppf L-80 BTC-m casing. 16:00 17:00 1.00 14,795 14,795 INTRM1 CEMEN" DHEO P Test casing to 3500 psi f/ 30 minutes- good test. 17:00 17:15 0.25 14,795 14,795 INTRM1 CEMEN" RURD P Blow down lines, rig down testing equipment. 17:15 21:45 4.50 14,795 14,980 INTRM1 CEMEN- DRLG P Drill cement f/ 14795' to 14839', baffle @ 14839', float collar @ 14924', shoe @ 14967'-14969', clean out rat hole f/ 14969' to TD @ 14980'. Drill w/ 10 to 4 k WOB, 298 gpm w/ 2360 to 2440 psi, Rotate 60-100 rpm w/ 18-12.3k ft Ibs of torque. 21:45 22:00 0.25 14,980 15,000 INTRM1 CEMEN" DRLG P Drill f/ 14980' to 15000' (6973' TVD). WOB 6-10k, Pumping 298 gpm w/2500 psi. Rotate 100 rpm w/ 15k ft Ibs of torque. 22:00 23:15 1.25 15,000 15,000 INTRM1 CEMEN-CIRC P Circulate bottoms up, pumping 300 gpm w/ 2440 psi. Rotate 100 rpm w/ 16-19k ft Ibs of torque. 23:15 23:30 0.25 15,000 14,918 INTRM1 CEMEN-TRIP P Stand back a stand f/ 15000' to 14918'. Blow down the top drive. 23:30 23:45 0.25 14,918 14,918 INTRM1 CEMEN" OWFF P Monitor well- static. 23:45 00:00 0.25 14,918 14,918 INTRM1 CEMEN- RURD P Rig up to test formation to 12.5 ppg EMW. 2/27/2013 Perform FIT to 12.58 ppg, Drill f/ 15000' to 15109' w/ high torque & aired up mud. Pump out to 14631', work on mud, change shaker screens, RIH f/ 14631' to 15018', precautionary ream 15018' to 15109', drill 6-3/4" hole w/ GP f/ 15109' to 15823'. 00:00 00:15 0.25 14,918 14,918 INTRM1 CEMEN- FIT P Perform FIT to 12.58 ppg. 9 ppg mud weight 1300 psi applied pressure. Drilled to 15000'. 00:15 00:45 0.50 14,918 14,918 PROD1 DRILL RURD P Blow down lines, rig down testing equipment. Charge (2) pulsation dampners back up. 00:45 03:15 2.50 14,918 15,109 PROD1 DRILL DDRL P Make a connection, drill f/ 15000' to 15109' (6982' TVD). ADT= 2.09 hrs. Note: Mud aired up excessively, torque at max. 03:15 04:15 1.00 15,109 14,631 PROD1 DRILL TRIP T Pull out of the hole w/ pumps f/ 15109' to 14631'. Rotate 100 rpm w/ 17.5k ft Ibs of torque. Pumping 290 pm w/ 2440 psi. Page 64 of 79 Time Logs Date From To Dur S. De th E. De thPhase Code Subcode T Comment 04:15 05:00 0.75 14,631 14,631 PROD1 DRILL CIRC T Circulate and condition mud, pumping 290 gpm w/ 2500 psi. Adding lubes, adding defoamer, changing shaker screens. 05:00 05:30 0.50 14,631 14,631 PROW DRILL OTHR T Change out shaker screens, observe well static 05:30 10:00 4.50 14,631 14,631 PROD1 DRILL CIRC T Circulate and condition mud to reduce foaming and torque. 250 gpm, 1880 psi. Added de -foam X and mobilized and added Screenkleen to successfuly reduce aeration and torque to acceptable levels. (Checked and confirm top drive torque readings against tong and IR gauges OK). FCP at 250 gpm, 2030 psi. Pump off Rot wt = 172K w/ 12K tq at 100 rpm 10:00 10:30 0.50 14,631 15,018 PROD1 DRILL TRIP T RIH from 14631' to 15018' 10:30 10:45 0.25 15,018 15,109 PROD1 DRILL REAM T Precautionary ream last stand to bottom. 250 gpm at 2190 psi, 100 rpm at 12.5k tq. 10:45 12:00 1.25 15,109 15,178 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ GP f/ 15,109' to 15,178' MD - 6984' TVD ADT- .95 hrs ECD- 10.17 ppg Footage - 69' WOB 6 k RPM 120 GPM 270 @ 2440 psi String wt. PU 215 SO 145 ROT 178 Torque on/off btm.- 14/12 k ft/lbs 12:00 00:00 12.00 15,178 15,823 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ GP f/ 15,178' to 15,823' MD - 6986' TVD ADT- 8.12 hrs ECD- 10.33 ppg Footage - 645' WOB 6 k RPM 120 GPM 300 @ 2880 psi String wt. PU 212 SO 144 ROT 175 Torque on/off btm.- 11.5/8.5 k ft/lbs 2/28/2013 Drill 6-3/4" hole w/ GP f/ 15823' to 16932', trouble shoot MWD (pulsar), set back 2 stands, con't trouble shooting (Not working), POOH f/ 16731' to 15395' (Monitor well on the trip tank). 00:00 12:00 12.00 15,823 16,512 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ GP f/ 15,823' to 16,512' MD - 7002' TVD ADT- 8.47 hrs ECD- 10.46 ppg Footage - 689' WOB 8 k RPM 120 GPM 294 @ 3150 psi String wt. PU 212 SO 146 ROT 174 Torque on/off btm.- 11/8 k ft/lbs 250 bbl whole mud dilution @ 16000'. Page 65 of 79 Time Logs Date From To Dur S. De th E. De th 'Phase Code Subcode T Comment 12:00 19:15 7.25 16,512 16,932 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ GP f/ 16,512' to 16932' MD - 6998' TVD ADT- 5.13 hrs ECD- 10.5 ppg Footage - 420' WOB 6-9 k RPM 120 GPM 298 @ 3420 psi String wt. PU 212 SO 148 ROT 176 Torque on/off btm.- 12/10.5 k ft/lbs 250 bbl whole mud dilution @ 16650'. 19:15 21:15 2.00 16,932 16,827 PROD1 DRILL OTHR T Trouble shoot MWD(Pulsar-no detection). Stand back 2 stands, obtain slow pump rates. Trouble shoot MWD- no success. 21:15 21:30 0.25 16,827 16,731 PROD1 DRILL OTHR T Pull a stand f/ 16827' to 16731'. Blow down the top drive. 21:30 21:45 0.25 16,731 16,731 PROD1 DRILL OWFF T Monitor well- static, slight drop. 21:45 00:00 2.25 16,731 15,395 PROD1 DRILL TRIP T POOH f/ 16731' to 15395'. Monitor well on the trip tank. 3/01 /2013 Con't POOH f/ 15395' to 14823', CBU- attempt to trouble shoot MWD, Monitor well- static, Pump out f/ 14823' to 13867', monitor- static, POOH on elevators f/ 13867' to 10056', monitor well, pump out f/ 10056' to 8639', monitor well, pump out 8639' to 7693', monitor, pull f/ 7693' to 7504', pump out f/ 7504' to 3438', CBU'2, POOH f/ 3438' to 3344', monitor well, POOH on trip tank f/ 3344' to 1454' @ midnight. 00:00 00:30 0.50 15,395 14,823 PROD1 DRILL TRIP T POOH f/ 15395' to 14823'. Monitor well on the trip tank. Calculated fill 12.4 bbls, actual 17 bbls. PU wt 207k, SO wt 153k. 00:30 01:45 1.25 14,823 14,823 PROD1 DRILL CIRC T Circ and condition mud, pumping 275 gpm w/ 2590 psi, rotate 120 to 140 rpm w/ 8k ft Ibs of torque. Trouble shooting MWD. 01:45 02:00 0.25 14,823 14,823 PROD1 DRILL OWFF T Monitor well- static. 02:00 03:30 1.50 14,823 13,867 PROD1 DRILL TRIP T Pump out of the hole f/ 14823' to 13867'. Pumping 250 gpm w/ 1980 psi. PU wt 198k, SO wt 150k. 03:30 04:00 0.50 13,867 13,867 PROD1 DRILL OWFF T Monitor well- static. 04:00 08:45 4.75 13,867 10,056 PROD1 DRILL TRIP T POOH on trip tank from 13867' to 10056'. (Flow check at 11958', ok) PU wt = 160K, SO wt = 120K. Calc fill = 24.32 bbls, Actual fill = 24.5 bbls, Last 5 stds 1/2 bbl short of calc disp. 08:45 09:00 0.25 10,056 10,056 PROD1 DRILL OWFF T Flow check, slight drop 09:00 11:45 2.75 10,056 8,639 PROD1 DRILL TRIP T Pump OOH from 10056' to 8639'. 250 gpm at 1680 psi to 9111', then 100 gpm at 500 psi. Calc fill = 8.1 bbls, Actual fill = 16 bbls 11:45 12:00 0.25 8,639 8,639 PROD1 DRILL OWFF T Flow check, slight drop. 12:00 13:45 1.75 8,639 7,693 PROD1 DRILL TRIP T Pump OOH from 8639' to 7693' at 100 gpm at 490 psi. 13:45 14:00 0.25 7,693 7,693 PROD1 DRILL OWFF T Flow check, slight drop. Blow down top drive. Page 66 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode ' T Comment 14:00 14:30 0.50 7,693 7,504 PROD1 DRILL TRIP T Attempt POOH on elevators 2 stands from 7693' to 7504'. Insufficient hole fill. Flow check, slight drop 14:30 21:15 6.75 7,504 3,438 PROD1 DRILL TRIP T Pump OOH from 7504' to 3438' at 100 gpm at 490 to 380 psi. Calc displacement 21.3 bbls, actual 23 bbls. 21:15 22:00 0.75 3,438 3,438 PROD1 DRILL CIRC T Circulate and condition mud, MWD still not working. Circ 2 bottom's up to clean up @ shakers. Pumping 250 gpm w/ 1260 psi. Rotate 60 rpm w/ 4.5k ft Ibs of torque. 22:00 22:15 0.25 3,438 3,344 PROD1 DRILL TRIP T Set back a stand f/ 3438' to 3344'. Blow down the top drive. 22:15 22:30 0.25 3,344 3,344 PROD1 DRILL OWFF T Monitor well- static, slight drop. 22:30 00:00 1.50 3,344 1,454 PROD1 DRILL TRIP T POOH on the trip tank f/ 3344' to 1454'. Monitor well on the trip tank. Calculated displacement 10 bbls, actual 13.5 bbls. PU 95k, SO 98k. 3/02/2013 Con't POOH on trip tank f/ 1454' to 420', monitor well, stand back HWDP to 254', PJSM on nukes, stand back NMDC's, remove sources, download MWD- no go, LD BHA, PU new BHA to 420', RIH f/ 420' to 14154' filling pipe every 20 stands. 00:00 01:00 1.00 1,454 420 PROD1 DRILL TRIP T POOH on the trip tank f/ 1454' to 420'. Monitor well on the trip tank. Calculated displacement 5.47 bbls, actual 7.5 bbls. 01:00 01:15 0.25 420 420 PROD1 DRILL OWFF T Monitor well- static, slight losses 01:15 01:30 0.25 420 222 PROD1 DRILL TRIP T Pull and stand back 2 stands of 4" HWDP. Lay down Weatherford bumper sub. Remove crossover. Note: A small thin piece of aluminum ( 4-1/2" x 2-1/8" x 1/16" thick) was retrieved f/ the mandrel of the bumper sub. 01:30 01:45 0.25 222 222 PROD1 DRILL RURD T Change elevators to 3-1/2". 01:45 02:00 0.25 222 222 PROD1 DRILL SFTY T Pre job safety meeting on removing sources and working BHA. 02:00 02:15 0.25 222 129 PROD1 DRILL TRIP T Stand back a stand of NM Flex drill collars. Monitor well on the trip tank. Calculated 1.54, actual 1.5 bbls. 02:15 02:30 0.25 129 60 PROD1 DRILL OTHR T Pick up, then remove (2) sources from BHA. Pick up and plug in to download. 02:30 03:30 1.00 60 129 PROD1 DRILL OTHR T Attempt to download MWD information- no go. Monitor well on the trip tank- slight losses. Slack off to start laying down tools. 03:30 05:15 1.75 129 0 PROD1 DRILL PULD T Lay down BHA. Grade bit. Actual displacement 1.5 bbls. 05:15 05:30 0.25 0 0 PROD1 DRILL OTHR T Clean floor. 05:30 05:45 0.25 0 0 PROD1 DRILL SFTY T Pre job safety meeting on PU/MU BHA. 05:45 08:15 2.50 0 129 PROD1 DRILL PULD T PU new 6-3/4" Rotary steerable BHA w/ same good bit. Page 67 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08.15 08:45 0.50 129 129 PROD1 DRILL CIRC T Make up crossover, then the top drive. Circulate 2-3 bpm w/ 140 to 290 psi to warm up tools. Rotate 10 to 50 rpm w/ 3k ft Ibs of torque, breaking in the seals on the geoPilot. 08:45 09:00 0.25 129 129 PROW DRILL OTHR T Break off the crossover, blow down the top drive. 09:00 10:00 1.00 129 129 PROW DRILL OTHR T Upload to the MWD tools. 10:00 10:15 0.25 129 129 PROD1 DRILL SFTY T Pre job safety meeting on loading nuke sources. 10:15 10:30 0.25 129 129 PROD1 DRILL OTHR T Load nuke sources in Sperry tools. 10:30 10:45 0.25 129 222 PROD1 DRILL TRIP T Trip in f/ the derrick f/ 129' to 222' 10:45 11:00 0.25 222 420 PROD1 DRILL TRIP T Pre job safety meeting, then change elevators f/ 3-1 /2" to 4". Trip in f/ 222' to 420'. 11:00 11:30 0.50 420 420 PROD1 DRILL DHEQ T Shallow pulse test MWD tools @ 420'. Pumping 250 gpm w/ 1020 psi - good. Rotate 50 rpm w/ 3k ft Ibs of torque. 11:30 11:45 0.25 420 420 PROD1 DRILL OTHR T Blow down the top drive. 11:45 12:00 0.25 420 889 PROD1 DRILL TRIP T Trip in the hole f/ 420' to 889'. 12:00 00:00 12.00 889 14,154 PROD1 DRILL TRIP T Continue to trip in the hole f/ 889' to 14154'. Filling every 20 stands. Blowing down the top drive after each fill. 3/03/2013 Con't RIH f/ 14154' to 14918' filling pipe every 20 stands. Circ, slip and cut drill line -service TD, con't RIH f/ 14918' to 15300', make a top drive connection, obtain some surveys on the way in the hole, ream f/ 16827' to 16932'. Drill 6-3/4" horiz prod hole w/ GP f/ 16932' to 17781'. 00:00 00:30 0.50 14,154 14,918 PROD1 DRILL TRIP T Continue to trip in the hole f/ 14154' to 14918'. Filling every 20 stands. Blowing down the top drive after each fill. 00:30 02:15 1.75 14,918 14,918 PROD1 DRILL CIRC T Circulate and condition mud (circ surf -surf). Start off pumping 250 gpm w/ 2190 psi f/ 100 bbls, increase rate to 300 gpm w/ 2840 psi. Try rotating @ 40 to 100 rpm not finding a sweet spot. Torque erratic f/ 7.5k to 10k with vibration- shut down rotary after 19 minutes, continued to reciprocate and circulate. No losses or gains. PU wt 195k, SO wt 145k w/ pumps. 02:15 02:30 0.25 14,918 14,918 PROD1 DRILL OWFF T Monitor well- static. Blow down the top drive. Pre job safety meeting on slip and cut drilling line. 02:30 03:45 1.25 14,918 14,918 PROD1 DRILL SLPC P Slip and cut 45' of 1-3/8" drill line. Inspect and service top drive and drawworks. Perform maint orders. 03:45 04:15 0.50 14,918 15,300 PROD1 DRILL TRIP T Con't RIH f/ 14918' to 15300'. Page 68 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 04:15 05:45 1.50 15,300 15,778 PROD1 DRILL TRIP T Make a top drive connection, obtain some surveys on the way in the hole. Obtain slow pump rates @ 15347'. Survey @ 15347', 15442', 15538', 15634' and 15728'. Survey pumping 250 gpm w/ 2120 psi. 05:45 06:00 0.25 15,778 15,778 PROD1 DRILL OTHR T Blow down the top drive. 06:00 07:00 1.00 15,778 16,827 PROD1 DRILL TRIP T Trip in the hole on elevators f/ 15778' to 16827'. 07:00 07:45 0.75 16,827 16,932 PROD1 DRILL REAM T Precautionary ream f/ 16827' to 16932'. Pumping 250 gpm w/ 2450 psi. Rotate 50-100 rpm w/ 8-10.5k ft Ibs of torque. 07:45 12:00 4.25 16,932 17,136 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ GP f/ 16,932' to 17136' MD - 6998' TVD ADT- 2.39 hrs ECD- 10.46 ppg Footage - 204' WOB 5-8 k RPM 120 GPM 300 @ 3120 psi String wt. PU 206 SO 147 ROT 176 Torque on/off btm.- 11/10.0 k ft/lbs 250 bbl whole mud dilution @ 16932'. 12:00 00:00 12.00 17,136 17,781 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ GP f/ 17136' to 17781' MD - 6997' TVD ADT- 7.82 hrs ECD- 10.59 ppg Footage - 645' WOB 8 k RPM 120 GPM 300 @ 3200 psi String wt. PU 213 SO 141 ROT 176 Torque on/off btm.- 12/11.5 k ft/lbs 250 bbl whole mud dilution @ 17590'. Adding Dyna red fine and medium (8 sx/hr). Observed hole taking fluid @ 17200', observation on connections were about 2' below flow line on connections. Mud losses f/ the tour = 79 bbls. 3/04/2013 Drill 6-3/4" horiz prod hole w/ GP f/ 17781' to 18641', circulate a Lo/Hi sweep out of the hole, backream to 18067' while circulating, Lost MWD detection, trouble shoot while BR to 17972'- no success, pump out of the hole f/ 17972' to 17685' @ midnight. Page 69 of 79 Time Logs Date From To Dur S. De th E. De`th Phase Code Subcode T Comment 00.00 12:00 12.00 17,781 18,372 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ GP f/ 17781' to 18372' MD - 7007' TVD ADT- 7.83 hrs ECD- 10.69 ppg Footage - 591' WOB 5-10 k RPM 120 GPM 300 @ 3300 psi String wt. PU 230 SO 137 ROT 175 Torque on/off btm.- 19k / 14.5k ft/lbs 250 bbl whole mud dilution while drilling f/ 18263' to 18359' (1000- 1130 hrs). Adding Dyna red fine and medium (8 sx/hr) until 18163'. Added 25 sx of nut plug medium to attempt to clean hole @ 18163'. Mud losses f/ the tour = 162 bbls. 12:00 17:30 5.50 18,372 18,641 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ GP f/ 18372' to 18641' MD - 7011.63' TVD ADT- 4.27 hrs ECD- 10.69 ppg Footage - 269' WOB 8 k RPM 120 GPM 300 @ 3290 psi String wt. PU SO ROT??? Torque on/off btm.- 19.5k / 14.5k ft/lbs Pumped a 40 bbl 5% lube pill whiloe drilling @ 18360', attempting to decrease torque. Pumped a 20 bbl low, then 30 bblHi vis sweep while drilling 18545' to 18641', attempting to clean hole. Adding Dyna red fine and medium (8 sx/hr) after to hi sweep was pumped. Mud losses while drilling f/ 18372' -18641' = 127 bbls. 17:30 18:15 0.75 18,641 18,545 PROD1 DRILL CIRC P Circulate Lo vis hi vis sweep out of the hole. Recip, rotate f/ 18641' to 18545'. Rotate 120 rpm w/ 19.5 k ft Ibs of torque. Pumping 300 gpm w/ 3290 psi. 18:15 21:00 2.75 18,545 18,067 PROD1 DRILL CIRC P Back ream while continuing to circ another 2BU f/ 18545' to 18067'. Pumping 300 gpm w/ 3300 psi. Rotate 120 to 90 rpm w/ 19 to 14.5 k ft Ibs of torque. Set back a stand every 30 minutes. ECD's down to 10.36 ppg. Torque still higher than anticipated. MWD lost detection @ 2045 hrs. 21:00 23:00 2.00 18,067 17,972 PROD1 DRILL OTHR T Back ream out f/ 18067' to 17972' while trouble shooting MWD. Pumping 290 gpm w/ 3290 psi, rotate 100-105 rpm w/ 18k ft Ibs of torque. Trouble shooting MWD- no success. Page 70 of 79 Time Logs Date From To Dur S.`De th E. De th Phase Code Subcode T Comment 23:00 00:00 1.00 17,972 17,685 PROW DRILL TRIP T Pump out of the hole f/ 17972' to 17685'. Pumping 250 gpm w/ 2290 psi. Losses f/ the tour= 222 bbls Losses f/ the day = 384 bbls Total losses to the well= 463 bbls 3/05/2013 Pooh w/ pumps f/ 17685' t/ 14918' Circ & condition hole, OWFF well static, POOH w/ pumps U 13390' Circ & Condition hole, B/D TD OWFF static POOH on Trip tank t/ 4383', pump 34 bbl dry job, continue POOH w/ BHA t/ 420', OWFF static, function test pipe rams. 00:00 04:15 4.25 17,685 14,918 PROM DRILL TRIP T Continue to POOH f/ 17685' t/ 14918' w/ pumps 250 gpm 2250 psi drop 2.37" hollow drift @ 15300' 04:15 06:15 2.00 14,918 14,918 PROW DRILL CIRC T Circ. & Condition hole w/ 300 gpm 3010 psi 90-120 rpm no obvious increase in cuttings on bottoms up. PUW- 205k SOW- 147k 06:15 06:45 0.50 14,918 14,918 PROM DRILL OWFF T Flow check well static slight loss. 06:45 09:15 2.50 14,918 13,390 PROD1 DRILL TRIP T POOH f/ 14918' t/ 13390' w/ pumps 250 gpm 2280 psi 09:15 10:45 1.50 13,390 13,390 PROM DRILL CIRC T Circ. & Condition Hole w/ 375 gpm 4060 psi 120 rpm still no noticeable increase in cuttings. 10:45 11:15 0.50 13,390 13,390 PROM DRILL OWFF T Blow Down TD Observe well for flow static. 11:15 20:15 9.00 13,390 4,383 PROM DRILL TRIP T POOH on Trip Tank f/ 13390' t/ 4383' 20:15 20:45 0.50 4,383 4,383 PROM DRILL CIRC T Pump 34 bbl dry jop 210 gpm 1020 psi B/D TD 20:45 23:30 2.75 4,383 420 PROM DRILL TRIP T POOH on trip tank f/ 4383' t/420' 23:30 00:00 0.50 420 420 PROM DRILL OWFF T Observe well for flow well static, function test pipe rams. 3/06/2013 Unload sources, attempt to down load MWD unable to connect no signal, L/D BHA, M/U BHA Upload MWD Shallow pulse test, RIH t/ 14946' filling pipe every 20 stands, get baseline Tq & Drag, displace well t/ 9.0 ppg flo thru, RIH t/16884' filling pipe every 20 stands. 00:00 01:30 1.50 420 127 PROM DRILL PULD T Stand back BHA t/ 127' ck torque on jars 30k to break connections, unload sources, plug in & attempt to down load MWD unable to download tool no signal, 01:30 02:00 0.50 127 127 PROM DRILL SVRG P Service rig, electrician looking at SCR's 02:00 03:30 1.50 127 0 PROD1 DRILL PULD T PJSM, UD BHA components, break bit, UD BHA and attempt to download in shed, clean & clear rig floor. 03:30 05:45 2.25 0 92 PROM DRILL PULD T P/U BHA components to floor, MU BHA to 92' with same bit and all other components replaced. ADR resistivity tool was replaced with a SP4 tool. 05:45 06:15 0.50 92 92 PROM DRILL CIRC T MU XO and TD, break in GP seals, pump at 3-4 bpm, 220-360 psi to warm up MWD Page 71 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:15 07:15 1.00 92 92 PROD1 DRILL OTHR T Blow down TD, plug in and upload MWD 07:15 08:15 1.00 92 473 PROD1 DRILL TRIP T RIH from 92' to 473' (changed out jars) 08:15 08:30 0.25 473 473 PROD1 DRILL CIRC T Shallow hole test MWD, 250 gpm at 860 psi 08:30 12:00 3.50 473 5,574 PROD1 DRILL TRIP T Blow down TD, RIH from 473' to 5574', filling pipe every 20 stds 12:00 19:15 7.25 5,574 14,946 PROD1 DRILL TRIP T RIH f/ 5574' t/ 149406, filling pipe every 20 stands. 19:15 21:30 2.25 14,946 14,946 PROD1 DRILL CIRC T Obtain benchline Tq & Drag 12 k tq 208-PUW 149-SOW, displace well t/ 9.0 ppg flo thru mud @ 300 gpm 2477 psi, blow down top drive 21:30 00:00 2.50 14,946 16,884 PROD1 DRILL TRIP T Trip in hole f/ 14946' t/ 16884' fill pipe every 20 stands, PUW- 213 SOW- 139. 3/07/2013 Continue RIH f/ 16884' t/ 18550', Circ & Cond. hole, Madd Pass f/ 18550' t/ 18641', Drill New hole f/ 18641' t/ 19728', Safety Stand down with all personnel about hand injuries. 00:00 00:45 0.75 16,884 18,316 PROD1 DRILL TRIP T RIH from 16844'to 18316'. Total calc disp for trip in = 116.3 bbls, Actual disp = 69 bbls 00:45 02:15 1.50 18,316 18,550 PROD1 DRILL CIRC T Circulate and condition, mud aired up 02:15 04:15 2.00 18,550 18,641 PROW DRILL SRVY P Gamma MAD pass, kick drill, survey, ream to btm120 RPM 300 gpm 2870 psi 04:15 12:00 7.75 18,641 19,709 PROD1 DRILL DDRL P Drill New Hole f/ 18641' t/ 19709' TVD-7030, ADT-5.04,PUW-218,SOW-137, RT WT-175, 120 RPM 10K TQ, 300 GPM 3020 PSI,WOB 6-10, ECD-10.41 12:00 00:00 12.00 19,709 19,728 PROD1 DRILL DDRL P Drill New Hole f/ 19079' t/ 19728' TVD-7043',ADT-8.06, PUW-229, SOW-133, RT WT-175, 120 RPM 16K TQ, 300 GPM 3110 PSI, WOB 8-11, ECD-10.81 Held Safety Stand Down with crew about hand incidents. 3/08/2013 Drill f/ 19728' t/ TD @ 20033' Circ & condition hole 3 bottoms ups @ 300 gpm 120 rpm 3460 psi 17k tq, OWFF static, POOH w/ pumps 100 gpm 790 psi t/ 16503' work through tight spots @ 19464',19383',19373',19270'-19174' MADD PASS f/ 17096-16990', trouble shoot top drive unable to rotate or break out 00:00 07:00 7.00 19,728 20,033 PROD1 DRILL DDRL P Drill f/ 19728' t/ TD @ 20033' TVD-7078', ADT-4.4, PUW-240,SOW-134, RT WT-176, 120 RPM 18K TQ, 300 GPM 3480 PSI, ECD-10.89 07:00 11:45 4.75 20,033 20,033 PROD1 CASING CIRC P Circ. Bottoms Up x 3 w/ 300 gpm 3260 psi 120 rpm 17k tq 11:45 12:00 0.25 20,033 20,033 PROD1 CASING OWFF P Observe well for flow well static slight drop Page 72 of 79 Time 'Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 19:15 7.25 20,033 16,503 PROD1 CASING REAM P Pooh w/ pumps 100 gpm 790 psi f/ 20033' t/ 16503' ( work throught tight spots @ 19464', 19383', 19373', 19270'-19174') Top drive unable to screw out of stand 19:15 19:45 0.50 16,503 16,503 PROD1 CASING SVRG P Service rig while working string & pumping @ 100 gpm 848 psi. 19:45 00:00 4.25 16,503 16,503 PROW CASING RGRP T Trouble shoot top drive while working string & pumping 100 gpm 848 psi unable to rotate top drive. 3/09/2013 Continue trouble shooting top drive still unable to rotate, fix rotation, air swivel developed a leak unable to funtion air components on top drive, POOH w/ pumps 100 gpm, f/ 16503' t/ 14880' drop drift@ 15262', circ. wt sweep around, slip & cut drill line service rig & repair TD service loop cable & Air swivel, POOH on trip tank f/ 14880' U 1323' 00:00 03:30 3.50 16,503 16,407 PROD1 CASING RGRP T Continue to trouble shoot top drive, fix electrical system and air swivel developed a leak, trouble shoot air system. stand back one stand t/ 16407' 03:30 07:00 3.50 16,407 14,880 PROD1 CASING TRIP P POOH w/ pumps 100 gpm 830 psi f/ 16407' t/ 14880' drop hollow drift @ 15262' Stand #157 07:00 08:45 1.75 14,880 14,880 PROD1 CASING CIRC P Pump 40 bbl wt sweep @ 300 gpm 2820 psi 120 rpm 11 k tq 08:45 09:00 0.25 14,880 14,880 PROD1 CASING OWFF P Observe well for flow well static slight drop 09:00 10:30 1.50 14,880 14,880 PROD1 CASING SLPC P Slip & cut drill line & Service rig. 10:30 11:15 0.75 14,880 14,480 PROD1 CASING SVRG P Service rig, Work on air swivel, repair cable on service loop to top drive. 11:15 12:00 0.75 14,480 14,403 PROD1 CASING TRIP P POOH on trip tank f/ 14880' U 14403' 12:00 00:00 12.00 14,403 1,323 PROD1 CASINGTRIP P POOH on trip tank f/ 14403' t/ 1323' 3/10/2013 POOH t/ BHA Down load MWD, L/D BHA, Pull wear ring set test plug R/U & Test BOP's, state waived witness, B/D lines set wear ring, R/U & Run 3.5 liner as per detail t/ 5191' 00:00 00:15 0.25 1,323 382 PROD1 CASING TRIP P POOH on trip tank f/ 1323 t/ 382' 00:15 00:45 0.50 382 185 PROD1 CASING TRIP P Flow check static, POOH on trip tank from 382' to 185' 00:45 01:15 0.50 185 90 PROD1 CASING PULD P PJSM, change out elevators, LD BHA 01:15 01:45 0.50 90 90 PROD1 CASING PULD P Plug in, Download MWD (clean/clear floor, brk down Geo Span w/ download) 01:45 03:45 2.00 90 0 PROD1 CASING PULD P LD BHA as per Sperry (Daylight savings time) 03:45 04:15 0.50 0 0 PROD1 CASING PULD P LD tools and equip VIA beaver slide 04:15 04:30 0.25 0 0 PROD1 CASING OTHR P Pull wear ring as per FMC Page 73 of 79 Time Logs Date From To bur S. De th E. De th Phase Code Subcode T Comment'> 04.30 10:45 6.25 0 0 PROD1 WHDBO BOPE P PJSM, RU and test BOPE as follows: w/ 4" test jt. tested Annular to 250 & 2500 psi - Tested upper 3-1/2" x 6" pipe rams, TD IBOP's, 5" and 4" Floor safety & dart valves, Choke & kill line valves, Choke manifold valves # 1-16 and needle valve to 250 & 3500 psi - HCR choke and Kill - 4" Demco on kill line - manual kill & choke valves - Lower 3-1/2" x 6" pipe rams to 250 & 3500 psi - Performed accumulator recovery test, 3000 psi start, 1660 psi end, 36 sec to 200 psi, 182 sec to 3000 psi, Isolate bottles/function rams - 82 sec air pump recovery, 85 sec electric pump recovery - Tested Blind rams 250/3500 psi - Tested gas alarms - Tested rig evacuation alarm - With the 3-1/2" test joint tested annular, 250 PSI low/ 2500 PSI high, upper and lower variable pipe rams 250 PSI low/ 3500 PSI high. Annulus open and monitored during test. All tests charted, 5 min/ test. (AOGCC) Lou Grimaldi waived witnessing tests. 10:45 11:30 0.75 0 0 PROD1 WHDBO OTHR P R/D test equipment, blow down lines, drain stack pull test plug, set retrievable wear ring. 11:30 12:00 0.50 0 0 PROD1 CASING SVRG P Service Rig Top Drive and draworks. 12:00 14:15 2.25 0 0 PROD1 CASING RGRP T C/O Air Swivel on top drive, function test new swivel works properly. 14:15 15:15 1.00 0 0 PROW CASING RUNL P R/U t/ run 3.5 liner 15:15 15:45 0.50 0 0 PROD1 CASING SFTY P Pre Job Safety Meeting w/ all parties involved. 15:45 00:00 8.25 0 5,191 PROW CASING RUNL P RIH w/ 3.5 liner as per detail t/ 5191' 3/11 /2013 Continue P/U 3.5 Liner t/ 5330' cross over t/ 4" dp, RIH w/ liner on 4" dp t/ 20033' tag bottom, P/U space out liner hanger @ 20023' drop ball pump down staging pumps t/ 84 gpm @ 1600 psi, slight losses observed while pumping 7 bph. 00:00 01:45 1.75 5,191 5,232 PROD1 CASING RUNL P M/U sealbore ext. & liner hanger mix & load pal mix, wait 30 min on pal mix to set, c/o elevators, M/U safety valve. 01:45 02:15 0.50 5,232 5,232 PROD1 CASING RUNL P Establish circ. 126 gpm 450 psi circ. liner vol. Obtain base line RT TQ 4k tq @ 10 rpm 98k rot wt, Blow down top drive 02:15 12:00 9.75 5,232 14,215 PROD1 CASING RUNL P RIH w/ liner on 4" DP f/ 5232' t/ 14215' 12:00 22:00 10.00 14,215 20,033 PROD1 CASING RUNL P RIH w/ liner on 4" DP f/ 14215' t/ 20033'tag bottom 22:00 22:30 0.50 20,033 20,023 PROD1 CASING RUNL P Obtain peramiters, Space out Drop ball put liner hanger on depth @ 20023' Page 74 of 79 M Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 22:30 00:00 1.50 20,023 20,023 PROD1 CASING CIRC P Drop 1" ball circ. ball t/ seat stage pumps f/ 21 gpm t/ 84 gpm 1600 psi, slight losses observed while pumping 7 bph. 3/12/2013 Continue U pump 1" ball to seat @ 84 gpm 1600 psi ball on seat @ 1780 stks, pressure up t/ 3500 psi set hanger, test liner, set packer test ann t/ 2000 psi f/ 10 min. release f/ liner hanger, displace well t/ 9.3 NACL brine, POOH w/ running tool, L/D BHA, P/U TCP BHA, RIH w/ TCP guns t/ 8823' PUW - 145 SOW - 125 00:00 01:15 1.25 20,023 14,790 PROD1 CASING PACK P Continue circ. 1" ball t/ seat @ 84 gpm 1600 psi, total strokes t/ bump 1780 pressure up t/ 2200 psi, set liner hanger as per baker rep pressure up to 3500 psi hold f/ 5 min on chart, set packer and test ann t/ 2000 psi f/ 10 min. Release f/ Hanger top of hanger 14790.20' 01:15 04:00 2.75 14,790 14,765 PROD1 CASING CIRC P Displace well U 9.3ppg 6% KCL NACL @ 300 gpm 2250 psi, Pump 35 bbl spacer wt vis. pill ahead, NTU 150 in 300 out 04:00 04:30 0.50 14,765 14,765 PROD1 CASING OWFF P Observe well for flow well static 04:30 14:30 10.00 14,765 25 PROD1 CASINGTRIP P POOH f/ 14765't/ Liner running tool 25' 14:30 15:45 1.25 25 0 PROD1 CASING PULD P L/D Liner running tool, clear floor. 15:45 16:15 0.50 0 0 COMPZ PERF SVRG P Service Rig, Drawork & top drive. 16:15 16:45 0.50 0 0 COMPZ PERF SFTY P Pre Job Safety Meeting on P/U perf. gun BHA with all parties involved. 16:45 17:45 1.00 0 132 COMPZ PERF PULD P P/U BHA as per TCP hand t/ 132' 17:45 00:00 6.25 132 8,823 COMPZ PERF TRIP P RIH w/ perf gun BHA on 4" DP f/ 132' t/ 8823' 3/13/2013 Contintue to RIH t/ 10051', Cut and Slip DL, RIH t/ 14458'; PU=190, SO=150. PJSM f/ RU wireline, MU same. RIH with WL correlate depth and POH with WL. RD/LD same. Space out and set packer at 14328'. K4. Close annular preventer, hold 500 psi. Pressure test lines to 4000 psi. Displace DP volume with 6.8 diesel. V Pressure up to 3500 with Dowel pumps to fire perf guns. Init=SIP 900 psi, circ on chole to pressure schedule to balance with 190 bbls away. Circulate 9.5 ppg around for trip margin, well static. 00:00 01:00 1.00 8,823 10,051 COMPZ PERF TRIP P RIH w/ perf gun BHA on 4" DP f/ 8823' t/ 10051' 01:00 02:30 1.50 10,051 10,051 COMPZ PERF SLPC P PJSM; Slip and cut drill line, Service TD 02:30 06:00 3.50 10,051 14,474 COMPZ PERF TRIP P RIH w/ perf gun BHA on 4" DP f/ 10051' t/ 14,474' PU wt 190 SO wt 150 - Calc. displacement 33.1 bbls -Actual displacement 32..5 bbls 06:00 06:30 0.50 14,474 14,474 COMPZ PERF OTHR P PJSM - MU XO & TIW valve to drill string f/ wireline run 06:30 07:45 1.25 14,474 14,474 COMPZ PERF RURD P PJSM on rigging up E line - RU Halliburton E line 07:45 10:15 2.50 14,474 14,474 COMPZ PERF ELOG P RIH w/ GR / CCL to TCP correlation - correlate GR to Open hole LWD log 9' correction - needed to PU RA tag 22' to have guns on depth - POOH w/ wireline 10:15 11:00 0.75 14,474 14,474 COMPZ PERF RURD P RD Halliburton E line & LD tools Page 75 of 79 d Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:00 12:00 1.00 14,474 14,453 COMPZ PERF OTHR P PJSM on pert gun space out - Space out pert guns - set Champ packer w/ Ra tag @ 14,338.78' - w/ pert guns 14,429' to 14,452' 12:00 12:15 0.25 14,453 14,453 COMPZ PERF SFTY P PJSM for setting packer, 12:15 13:00 0.75 14,453 14,453 COMPZ PERF PACK P Set packer with 45k downand 4.5 RH turns. RU circ equip/latch elevators 13:00 14:00 1.00 14,453 14,453 COMPZ PERF PACK P Close ann. preventer, pressure up t/ 500psi on annulus, PU drillsring to oen port sub w/ 180k pu wt. Psi drop observed,f/ open. SPR's; #1) 10=50, 20=190, 30=430 psi #2) 10= 50, 20=200, 30=430 psi. 14:00 16:00 2.00 14,453 14,453 COMPZ PERF CIRC P PJSM diesel disp. with Dowel pump. PT lines to 4000 psi. Disp. 148 bbl. 6.8 ppg, 3bpm rate with 220 to 1062 psi. Monitor returns, close port with 45k down. Monitor drillstring for negative pressure test. 16:00 17:00 1.00 14,453 14,453 COMPZ PERF PERF P Pressure up with Dowel pump to 3500 psi on guns, guns fired at 6 min 3 sec; 11 bbls return after fire; 400 - 1100 psi. 17:00 19:15 2.25 14,453 14,453 COMPZ WELCTL KLWL P [nit SIP= 900psi, circ 2 bbl/min on choke with pressure schedule to disp. with 150 bbls away the SIP= 200psi with a mud wt out of 8.3 ppg. Continued circ at 2 bbl/min. At 180 bbls away the mud wt out was 9.3 ppg, at 190 bbls away SIP= 0 psi. 19:15 19:45 0.50 14,453 14,453 COMPZ WELCTL KLWL P Monitor well; Init. flow 6 bbl/hr final flow 3 bbl/hr. 19:45 22:45 3.00 14,453 14,453 COMPZ PERF CIRC P Circulate 9.5 ppg 2 BU until 9.5 in and 9.5 ppg out. 22:45 23:15 0.50 14,453 14,453 COMPZ WELCTL OWFF P Monitor well for flow. 23:15 00:00 0.75 14,453 14,439 COMPZ PERF OTHR P Blow Down top drive, UD pup jt. line up trip tank. 3/14/2013 POOH w/ perf guns - LD Perf. guns all shots fired , MU & RIH w/ Burr Mill Assy, RIH t/ 10922' . 00:00 12:00 12.00 14,439 3,150 COMPZ PERF TRIP P Cont. POOH w/ perf gun assambly on TT f/ 14,439' to 3150' - Calc fill 68.4 bbls - Actual fill 72 bbls. 12:00 15:00 3.00 3,150 132 COMPZ PERF TRIP P Finish POOH on TT w/ perf gun assembly f/ 3150' to 132' Flow checked well @ 2000' for 15 mins. - fluid level dropped approx. 8" 15:00 15:15 0.25 132 132 COMPZ PERF SFTY P PJSM on laying down perf guns 15:15 16:30 1.25 132 0 COMPZ PERF TRIP P POOH f/ 132'- LD packer - 2 jts 2 7/8" tbg - RA sub - ported sub & perf guns (all shots fired) L/D BHA comp. clear floor. 16:30 17:30 1.00 0 527 COMPZ PERF PULD P P/U clean out BHA U 527' 17:30 00:00 6.50 527 10,922 COMPZ PERF TRIP P RIH w/ clean out BHA f/ 527' t/ 10922' Page 76 of 79 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 3/15/2013 2a hr Summary RIH w/ Clean out assembly f/ 10922' t/ 14400', Est circ at 3 BPM with 330 psi, 60 RPM with 11-12K torque, made two passes over perf area. TIH and tag TOIL at 14786'. Circ and recip 2X BU with 8 BPM at 1750 psi. Monitor well; static. POOH to LID Burr Mill Assy. 00:00 01:30 1.50 10,922 14,360 COMPZ PERF TRIP P RIH f/ 10,922' to 14,360' w/ clean out assembly - PU wt 202 SO wt 144 Calc displacement 15.5 bbls Actual di lacement 13.5 bbls 01:30 02:30 1.00 14,360 14,472 COMPZ PERF REAM P MU TD - Break circ @ 2 bbls/min @ 180 psi - 3 bbls/min @ 330 psi - Wash down f/ 14,360' to 14,400' - Kick in rotary @ 60 rpm's @ 11 to 12.5 k torque - wash & ream thru pert section f/ 14,400' to 14,472' w/ MI Burr Mill & magnets - Made two passes thru pert section 02:30 03:00 0.50 14,456 14,786 COMPZ PERF TRIP P RIH f/ 14,472' to 14,786'( tagged top of liner @ 14,786' 03:00 05:00 2.00 14,786 14,551 COMPZ PERF CIRC P Circ 2X btms up @ 8 bbls/min @ 1750 psi - No rotation - Pulling & standing back 1 std every 30 mins to 14,551' 05:00 05:30 0.50 14,551 14,551 COMPZ PERF OWFF P Blow down TD - Flow ck well for 15 mins - Fluid level dropped approx 6" 05:30 12:00 6.50 14,551 10,256 COMPZ PERF TRIP P POOH w/ clean out assembly f/ 14,551' to 10,256' - Calc. fill 27.9 bbls Actual fill 27.5 bbls 12:00 00:00 12.00 10,256 527 COMPZ PERF TRIP P Continue POOH w/ clean out assembly f/ 10256' t/527' 3/16/2013 Finish POOH, L/D BHA 1/2 gal of metal filings on magnets, R/U & RIH w/ 3.5 completion as per detail w/ i wire t/9021'. 00:00 01:00 1.00 527 0 COMPZ PERF PULD P L/D BHA clean Magnets & well patroler, 1/2 gal of metal debris( small filings) 01:00 05:00 4.00 0 0 COMPZ RPCOM RURD P R/U t/ run 3.5 completion, rig up i wire spool & control line spool. 05:00 07:15 2.25 0 1,717 COMPZ RPCOM RCST P Rih w/ 3.5 completion as per detail t/ 493' M/U & test i wire, continue RIH w/ 3.5 completion t/ 1717' 07:15 00:00 16.75 1,717 9,021 COMPZ RPCOM RCST P Contiune RIH w/ 3.5 completion f/ 1717' t/ 9021' test wire every 25 jts. 3/17/2013 Cont. RIH w/ 3 1/2" completion t/ 14825' space out P/U & Pump 25 bbls 9.5 ppg Inhibited brine followed by 150 bbls 9.5 ppg brine around, OWFF static, M/U space out pups & hanger terminate lines through hanger & test, Land tubing on hanger @ 14825', test seals t/ 1000 psi good test, test hanger seals t/ 5000psi good test. 00:00 06:30 6.50 9,021 12,703 COMPZ RPCOM RCST P Cont. RIH w/ 3 1/2" completion f/ 9021' to 12,703' ( 391 jts total in hole) PU SSSV (TRMAXX-5E) 06:30 07:15 0.75 12,703 12,703 COMPZ RPCOM OTHR P RU control line spool for SSSV - connect line to SSSV & test to 6300 psi for 10 mins. 07:15 11:30 4.25 12,703 14,744 COMPZ RPCOM RCST P Cont. RIH w/ 3.5 tubing as per detail t/ 14744' 11:30 12:00 0.50 14,744 14,744 COMPZ RPCOM OTHR P C/O elevators M/U XO & 1 stand of drill pipe. 12:00 12:30 0.50 14,744 14,744 COMPZ RPCOM RCST P Space out w/ 42 gpm 70 psi Page 77 of 79 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:30 13:00 0.50 14,744 14,744 COMPZ RPCOM RCST P service rig 13:00 13:15 0.25 14,744 14,744 COMPZ RPCOM RGRP T Trouble shoot top drive blower motor failure, unable to break out, use rig tongs to break out of TD, Blow down lines. 13:15 16:00 2.75 14,744 14,744 COMPZ RPCOM RCST P RIH w/ 4' dp unable to get into seal bore extention, work pipe dropped in observe pressure increase, UD 4" dp R/U t/ circ. 16:00 17:45 1.75 14,744 14,744 COMPZ RPCOM RCST P Circ. 25 bbls 9.5 ppg inhibited brine followed by 150 bbls 9.5 brine @ 126 gpm @ 350 psi 17:45 18:15 0.50 14,744 14,744 COMPZ RPCOM OWFF P Observe well for flow well static 18:15 19:45 1.50 14,744 14,744 COMPZ RPCOM RCST P M/U space out pups, jt of 4.5 & wear ring puller, retrieave wear ring, UD puller. 19:45 20:30 0.75 14,744 14,744 COMPZ RPCOM RCST P P/U jt of 4.5 M/U hanger & landing jt. A 20:30 21:45 1.25 14,744 14,744 COMPZ RPCOM RCST P Terminate control lines through hanger, test lines t/ 5000 psi. test seals on hanger connections t/ 5000 psi test good. 21:45 22:30 0.75 14,744 14,825 COMPZ RPCOM RCST P Land tubing on hanger @ 14825' RILDS (totol canon clamps run 465) 22:30 00:00 1.50 14,825 14,825 COMPZ WHDBO PRTS P Test tubing seal U 1000 psi f/ 5 min. set TWC test hanger seals t/ 250/5000 psi 3/18/2013 Pull TWC, R/U & test tubing t/ 3500 psi bleed off t/ 2000 test ann. t/ 3500psi bleed tubing down & shear DCK valve, Instal TWC test in direction of flow U 3000 psi, OWFF f/ 30 min well static, N/D BOP, terminate control lines through well head, N/U tree & test U 5000 psi, pull TWC, R/U & freeze protect well w/ 75 bbls of diesel, set BPV, secure well, L/D 4" dp via mouse hole. 83 Stands 00:00 01:00 1.00 14,825 14,825 COMPZ RPCOM OTHR P Pull landing jt B - Pull TWC - Install landing jt. A 01:00 02:15 1.25 14,825 14,825 COMPZ RPCOM RURD P Pull mouse hole - Clean up rig floor - Rig up squeeze manifold & hardlines to tbg & annulus 02:15 04:15 2.00 14,825 14,825 COMPZ RPCOM PRTS P Attempt to pressure up on tbg to set packer - Pressure up to 3200 psi - pressure bled off to 1000 psi - pumping away @ 2 bbl/min @ 900 psi - shut down ( pumped away 5 bbls - Dropped rod /ball assembly - pumped @ 2 bbls/min @ 1320 psi (pumped 10 bbls) pressured up on tbg to 3500 psi to set packer - Tested tbg for 30 mins @ 3500 psi - bled tbg down to 2000 psi - Pressure up on annulus to 3500 psi & test for 30 mins.(both tests good) - Bled down tbg to shear DCK valve 04:15 04:45 0.50 14,825 14,825 COMPZ RPCOM OTHR P Pull landing jt. A- Install TWC & Install jt. B Page 78 of 79 Time Logs Date From To Dur S.'De th E. De th Phase Code Subcode T Comment 04.45 06:00 1.25 14,825 14,825 COMPZ RPCOM PRTS P Pressure up on annulus to 3000 psi & test TWC in direction of flow for 10 mins - bleed off pressure & monitor for 30 mins (static) LD landing jt.B & hard line to annulus Blow down kill & choke lines 06:00 07:45 1.75 14,825 14,825 COMPZ WHDBO NUND P PJSM - ND BOP stack 07:45 09:15 1.50 14,825 14,825 COMPZ WHDBO NUND P Terminate control lines & i wire thru well head. 09:15 10:45 1.50 14,825 0 COMPZ WHDBO NUND P N/U & test tree t/ 5000 psi f/ 10 min 10:45 11:00 0.25 0 0 COMPZ WHDBOOTHR P Pull TWC 11:00 12:00 1.00 0 0 COMPZ WHDBO RURD P R/U t/ freeze protect well 12:00 13:00 1.00 0 0 COMPZ WHDBO FRZP P Flood lines test lines t/ 3500 psi, pump 75 bbls of diesel @ 2.2 bpm 1650 psi allow t/ U-Tube. 13:00 14:00 1.00 0 0 COMPZ WHDBO RURD P B/D lines R/D squeeze manifold & hardlines. 14:00 16:00 2.00 0 0 COMPZ WHDBO OTHR P R/U & test lubricator t/ 3000 psi, set BPV, secure well, P/U cellar. 16:00 00:00 8.00 0 0 COMPZ MOVE PULD P L/D 4" dp via mouse hole 83 stands 3/19/2013 Cont. LD 4" DP f/ derrick, PJSM, change out saver sub, grabs and bell guide on the top drive. Rig released f/ move f/ CD3-127 to CD3-320 (140') @ 1900 hrs 3/19/2013. 00:00 04:30 4.50 0 0 COMPZ RPCOM PULD P Cont. LD 4" DP f/ derrick via mouse hole 04:30 05:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig 05:00 12:00 7.00 0 0 COMPZ RPCOM PULD P Cont. LD 4" DP f/derrick via mouse hole total of 90 stds laid down last 12 hrs for 173 stds of 230 to lay down 12:00 18:00 6.00 0 0 COMPZ RPCOM PULD P Cont. LD 4" DP f/ derrick via mouse hole (57 stands) 18:00 18:15 0.25 0 0 COMPZ RPCOM PULD P Pre job safety meeting on changing out the saver sub on the top drive f/ 4" to 5" (4-1/2" IF). 18:15 19:00 0.75 0 0 COMPZ RPCOM RURD P Change out grab heads, change saver sub and bell guide on the top drive. Rig released f/ CD3-127 to CD3-320. 140' move. Page 79 of 79 ConocoPhillips(Alaska) Inc. NAD27 Western North Slope CD3 Fiord Pad CD3-127 AP1:50103206340000 - PTD:211-005 Sperry Drilling Services Definitive Survey Report 28 March, 2013 Sperry Drilling Services Company: ConocoPhillips(Alaska) Inc. NAD27 Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: CD3-127 Design: CD3-127 ConocoPhillips (Alaska) Inc. Definitive Survey Report Local Co-ordinate Reference: Well C133-127 TVD Reference: CD3-127 @ 49.0ft MD Reference: CD3-127 @ 49.0ft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM 2003.16 Single User Db Project Western North Slope, 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 Well CD3-127 Well Position +N/-S 0.0 ft Northing: 6,003,757.26 ft Latitude: 70° 25' 9.114 N +E/-W 0.0 ft Easting: 387,857.43 ft Longitude: 150° 54' 48.827 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 12.6ft Wellbore CD3-127 M .. Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1) (nT) BGGM2012 3/1/2012 20.12 80.86 57,586 Design CD3-127 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,202.6 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (I 36.4 0.0 0.0 145.00 Survey Program Date 3/28/2013 From To Survey (ft) Ift) Survey (Wellbore) Tool Name Description Start Date 79.4 476.4 CD3-127PB1 Gyro (CD3-127P61) CB -GYRO -SS Camera based gyro single shot 02/11/2011 476.4 3,202.6 CD3-127PB1 (CD3-127PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 02/11/2011 3,270.0 19,968.0 MWD+IFR-AK-CAZ-SC (CD3-127) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 02/08/2013 14,967.6 19,968.0 MWD+IFR-AK-CAZ-SC (CD3-127) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 02/08/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1) (1) (ft) (ft) (it) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.4 0.00 0.00 36.4 -12.6 0.0 0.0 6,003,757.3 387,857.4 0.0 0.00 UNDEFINED 79.4 0.35 234.33 79.4 30.4 -0.1 -0.1 6,003,757.2 387,657.3 0.8 0.00 CB-GYRO-SS(1) 170.4 0.52 207.98 170.4 121.4 -0.6 -0.5 6,003,756.7 387,856.9 0.3 0.19 CB -GYRO -SS (1) 262.4 0.85 228.13 262.4 213.4 -1.4 -1.2 6,003,755.8 387,856.2 0.4 0.46 CB-GYRO-SS(1) 354.4 1.17 247.26 354A 305.4 -2.2 -2.6 6,003,755.0 387,854.8 0.5 0.35 CB-GYRO-SS(1) 386A 1.33 260.21 386.4 337.4 -2.4 -3.3 6,003,754.9 387,854.1 1.0 0.12 CB-GYRO-SS(1) 416.4 1.67 279.06 416.3 367.4 -2.4 -4.0 6,003,754.9 387,853.3 2.0 -0.33 CB-GYRO-SS(1) 445A 2.15 299.36 445.3 396.3 -2.1 -4.9 6,003,755.2 387,852.5 2.8 -1.12 CB-GYRO-SS(1) 476A 3.01 314.14 476.3 427.3 -1.2 -6.0 6,003,756.1 387,851.4 3.5 -2.44 CB-GYRO-SS(1) 516.1 4.03 321.86 516.0 467.0 0.6 -7.6 6,003,758.0 387,849.8 2.8 -4.86 MWD+IFR-AK-CAZ-SC (2) 577.6 6.32 325.73 577.2 528.2 5.1 -10.9 6,003,762.5 387,846.6 3.8 -10.40 MWD+IFR-AK-CAZ-SC (2) 3/28/2013 2:11:47PM Page 2 COMPASS 2003.16 Build 69 Company: ConocoPhillips(Alaska) Inc. NAD27 Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: CD3-127 Design: CD3-127 ConocoPhillips (Alaska) Inc. Definitive Survey Report Local Co-ordinate Reference: Well CD3-127 ND Reference: CD3-127 @ 49.Oft MD Reference: CD3-127 @ 49.Oft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (I V) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 671.6 8.05 314.21 670.4 621.4 13.9 -18.5 6,003,771.5 387,839+1 2.4 -22.04 MWD+IFR-AK-CAZ-SC (2) 763.9 7.91 311.32 761.9 712.9 22.6 -27.9 6,003,780.3 387,829+9 0.5 -34.57 MWD+IFR-AK-CAZ-SC (2) 856.1 8.17 305.21 853.1 804.1 30.6 -38.0 6,003,788.4 387,819.9 1.0 -46.89 MWD+IFR-AK-CAZ-SC (2) 952.1 10.89 302.07 947.8 898.8 39.4 -51.3 6,003,797.4 387,806.7 2.9 -61.66 MWD+IFR-AK-CAZ-SC (2) 1,045.9 12.42 298.39 1,039.7 990.7 48.9 -67.7 6,003,807.1 387,790.5 1.8 -78.85 MWD+IFR-AK-CAZ-SC (2) 1,140.5 12.58 296.55 1,132.0 1,083.0 58.3 -85.8 6,003,816.8 387,772.5 0.5 -96.99 MWD+IFR-AK-CAZ-SC (2) 1,234.9 12.83 296.14 1,224.2 1,175+2 67.5 -104.5 6,003,826.3 387,754.0 0.3 -115.23 MWD+IFR-AK-CAZ-SC (2) 1,329.0 15.44 286.25 1,315.4 1,266+4 75.6 -125.9 6,003,834.8 387,732.7 3.8 -134.14 MWD+IFR-AK-CAZ-SC (2) 1,423.5 19.30 279.59 1,405.6 1,356+6 81.8 -153.4 6,003,841.3 387,705.3 4.6 -154.94 MWD+IFR-AK-CAZ-SC (2) 1,518.1 22.46 275A2 1,494.0 1,445+0 86.1 -186.8 6,003,846.1 387,672.0 3.7 -177.63 MWD+IFR-AK-CAZ-SC (2) 1,612.6 26.70 270.91 1,579.9 1,530.9 88.1 -226.0 6,003,848.7 387,632.8 4.9 -201.80 MWD+IFR-AK-CAZ-SC (2) 1,707.9 30.00 268.38 1,663.8 1,614.8 87.8 -271.2 6,003,849+1 387,587.6 3.7 -227.48 MWD+IFR-AK-CAZ-SC (2) 1,802.6 35.83 269.68 1,743.2 1,694.2 87.0 -322.6 6,003,849.0 387,536.2 6.2 -256.28 MWD+IFR-AK-CAZ-SC (2) 1,849.4 37.89 269.97 1,780.7 1,731.7 86.9 -350.7 6,003,849.4 387,508.1 4.4 -272.33 MWD+IFR-AK-CAZ-SC (2) 1,897.5 38.49 270.30 1,818.5 1,769.5 86.9 -380.5 6,003,849.9 387,478.4 1.3 -289.44 MWD+IFR-AK-CAZ-SC (2) 1,991.7 42.51 267.56 1,890.1 1,841.1 85.7 -441.6 6,003,849+6 387,417.2 4.7 -323.51 MWD+IFR-AK-CAZ-SC (2) 2,086.5 47.07 264.32 1,957.4 1,908.4 80.9 -508.2 6,003,845.8 387,350.6 5.4 -357.78 MWD+IFR-AK-CAZ-SC (2) 2,133.5 47.99 263.29 1,989.1 1,940.1 77.2 -542.6 6,003,842.6 387,316.1 2.5 -374.48 MWD+IFR-AK-CAZ-SC (2) 2,176.0 49.30 262.69 2,017.2 1,968.2 73.3 -574.3 6,003,839.2 387,284.3 3.3 -389.45 MWD+IFR-AK-CAZ-SC (2) 2,275.5 53.98 263.40 2,078.9 2,029.9 63.9 -651.7 6,003,830.9 387,206.8 4.7 -426.12 MWD+IFR-AK-CAZ-SC (2) 2,365.6 57.90 262.91 2,129.3 2,080.3 55.0 -725.8 6,003,823.1 387,132.6 4.4 -461.33 MWD+IFR-AK-CAZ-SC (2) 2,464.2 62.96 263.91 2,178.0 2,129.0 45.2 -810.9 6,003,814.6 387,047.3 5.2 -502.12 MWD+IFR-AK-CAZ-SC (2) 2,514.6 64.92 263.93 2,200A 2,151.1 40.4 -856.0 6,003,810.5 387,002.2 3.9 -524.03 MWD+IFR-AK-CAZ-SC (2) 2,558.6 66.38 264.57 2,218.3 2,169.3 36.3 -895.9 6,003,807.0 386,962.2 3.6 -543.64 MWD+IFR-AK-CAZ-SC (2) 2,653.5 68.37 264.51 2,254.7 2,205.8 28.0 -983.0 6,003,800.0 386,875.0 2.1 -586.79 MWD+IFR-AK-CAZ-SC (2) 2,748.4 70.13 264.33 2,288.4 2,239.4 19.4 -1,071.4 6,003,792.7 386,786.5 1.9 -630.41 MWD+IFR-AK-CAZ-SC (2) 2,842.7 71.06 263.74 2,319.7 2,270.7 10.1 -1,159.8 6,003,784.8 386,698.0 1.1 -673.56 MWD+IFR-AK-CAZ-SC (2) 2,937.5 71.07 263.37 2,350.5 2,301.5 0.1 -1,248.9 6,003,776.1 386,608.8 0.4 -716.41 MWD+IFR-AK-CAZ-SC (2) 3,031+8 70.29 262.76 2,381.7 2,332.7 -10.7 -1,337.3 6,003,766.7 386,520.3 1.0 -758.29 MWD+IFR-AK-CAZ-SC (2) 3,125.9 69.55 262.57 2,414.0 2,365.0 -22.0 -1,425.0 6,003,756.7 386,432.4 0.8 -799.33 MWD+IFR-AK-CAZ-SC (2) 3,202.6 69.45 262.24 2,440.9 2,391.9 -31.5 -1,496.2 6,003,748.3 386,361.0 0.4 -832.42 MWD+IFR-AK-CAZ-SC (2) 3,270.0 68.83 263.42 2,464+8 2,415.9 -39.3 -1,558.7 6,003,741.4 386,298.5 1.9 -861.80 MWD+IFR-AK-CAZ-SC (3) 3,327.5 68.32 263.94 2,485.9 2,436.9 45.2 -1,611+9 6,003,736.3 386,245.2 1.2 -887.50 MWD+IFR-AK-CAZ-SC (3) 3,421+4 65.36 263.40 2,522.8 2,473.8 -54.7 -1,697.7 6,003,728.0 386,159.3 3.2 -928.90 MWD+IFR-AK-CAZ-SC (3) 3,516.1 62.90 264.73 2,564.1 2,515.1 -63.5 -1,782.4 6,003,720.5 386,074.4 2.9 -970.28 MWD+IFR-AK-CAZ-SC (3) 3,616.9 62.64 264.35 2,610.2 2,561.2 -72A -1,871.6 6,003,713.3 385,985.1 0.4 -1,014.49 MWD+IFR-AK-CAZ-SC (3) 3,711.2 65.14 260.61 2,651.7 2,602.8 -83.2 -1,955+6 6,003,703.5 385,901.0 4.4 -1,053.52 MWD+IFR-AK-CAZ-SC (3) 3,805+0 66.28 258.60 2,690.3 2,641.3 -98.6 -2,039.6 6,003,689.3 385,816.7 2.3 -1,089.11 MWD+IFR-AK-CAZ-SC (3) 3,899.8 67.88 257.78 2,727.2 2,678.3 -116.5 -2,125+1 6,003,672.7 385,731.0 1.9 -1,123.49 MWD+IFR-AK-CAZ-SC (3) 3,996.0 69.44 257.28 2,762.3 2,713.3 -135.8 -2,212.6 6,003,654.7 385,643.2 1.7 -1,157.83 MWD+IFR-AK-CAZ-SC (3) 312812013 2:11:47PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. NAD27 Local Co-ordinate Reference: Well CD3-127 Project: Western North Slope ND Reference: CD3-127 @ 49.Oft Site: CD3 Fiord Pad MD Reference: CD3-127 @ 49.Oft Well: CD3-127 North Reference: True Wellbore: CD3-127 Survey Calculation Method: Minimum Curvature Design: CD3-127 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (') (1) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,089.1 67.70 255.91 2,796.3 2,747.3 -155.9 -2,296.9 6,003,635.9 385,558.7 2.3 -1,189.71 MWD+IFR-AK-CAZ-SC (3) 4,183+7 67.14 254.70 2,832.6 2,783.6 -178.1 -2,381.3 6,003,615.0 385,473.9 1.3 -1,220.02 MWD+IFR-AK-CAZ-SC (3) 4,277+5 67.63 253.83 2,868.7 2,819.7 -201.6 -2,464.7 6,003,592.8 385,390.2 1.0 -1,248.60 MWD+IFR-AK-CAZ-SC (3) 4,370A 69.58 253.95 2,902.5 2,853.5 -225.5 -2,547.8 6,003,570+0 385,306.8 2.1 -1,276.59 MWD+IFR-AK-CAZ-SC (3) 4,466.1 70.86 254.18 2,934.9 2,886.0 -250.3 -2,634.4 6,003,546.6 385,219.8 1.4 -1,306.02 MWD+IFR-AK-CAZ-SC (3) 4,561.2 70.23 253.79 2,966.6 2,917.6 -275.0 -2,720.6 6,003,523.2 385,133+3 0.8 -1,335.18 MWD+IFR-AK-CAZ-SC (3) 4,654.7 69.74 254.68 2,998.6 2,949.6 -298.9 -2,805.1 6,003,500+6 385,048+4 1.0 -1,364+12 MWD+IFR-AK-CAZ-SC (3) 4,749.5 68.49 256.20 3,032+4 2,983+4 -321.2 -2,890.9 6,003,479.6 384,962+3 2.0 -1,395.05 MWD+IFR-AK-CAZ-SC (3) 4,843.2 68.81 257.87 3,066+5 3,017.5 -340.7 -2,975.9 6,003,461+3 384,877.0 1.7 -1,427.79 MWD+IFR-AK-CAZ-SC (3) 4,937.6 68.30 259.75 3,101.1 3,052.1 -357.8 -3,062.1 6,003,445.5 384,790.5 1.9 -1,463.27 MWD+IFR-AK-CAZ-SC(3) 5,031.0 68.78 260.80 3,135.2 3,086.2 -372.5 -3,147.7 6,003,432.1 384,704.7 1.2 -1,500+37 MWD+IFR-AK-CAZ-SC(3) 5,125.5 68.59 262.41 3,169.5 3,120.6 -385.3 -3,234.8 6,003,420.6 384,617.5 1.6 -1,539.78 MWD+IFR-AK-CAZ-SC (3) 5,217.3 69.69 260.33 3,202.2 3,153.3 -398.2 -3,319.6 6,003,409.0 384,532.5 2.4 -1,577.88 MWD+IFR-AK-CAZ-SC (3) 5,311.4 68.97 259.66 3,235.5 3,186.5 413.5 -3,406.3 6,003,395.0 384,445.6 1.0 -1,615.07 MWD+IFR-AK-CAZ-SC (3) 5,405.6 68.73 258.31 3,269.5 3,220.5 430.3 -3,492+6 6,003,379.5 384,359.1 1.4 -1,650.80 MWD+IFR-AK-CAZ-SC (3) 5,499.9 69.07 258.46 3,303.4 3,254.4 448.0 -3,578.7 6,003,363.1 384,272.7 0.4 -1,685.70 MWD+IFR-AK-CAZ-SC (3) 5,594+1 69.91 257.60 3,336.4 3,287.4 466.3 -3,665.0 6,003,346.1 384,186.1 1.2 -1,720.21 MWD+IFR-AK-CAZ-SC (3) 5,687.7 69.94 258.69 3,368.5 3,319.5 -484.3 -3,751+1 6,003,329.3 384,099.8 1.1 -1,754.78 MWD+IFR-AK-CAZ-SC (3) 5,782+2 70.25 259.89 3,400.7 3,351.7 -500.9 -3,838+4 6,003,314.2 384,012.3 1.2 -1,791.33 MWD+IFR-AK-CAZ-SC (3) 5,876+0 68.78 260.74 3,433.5 3,384.6 -515.6 -3,925.0 6,003,300+7 383,925.4 1.8 -1,828.91 MWD+IFR-AK-CAZ-SC (3) 5,971.9 68.54 261.20 3,468.4 3,419.4 -529.7 -4,013.2 6,003,288.0 383,837.0 0.5 -1,868.01 MWD+IFR-AK-CAZ-SC (3) 6,065.8 69.98 261.41 3,501.7 3,452.7 -542.9 -4,100.0 6,003,276+0 383,750.1 1.5 -1,906.92 MWD+IFR-AK-CAZ-SC (3) 6,159.7 69.57 262.35 3,534.2 3,485.2 -555.4 -4,187.3 6,003,264+9 383,662+6 1.0 -1,946.78 MWD+IFR-AK-CAZ-SC (3) 6,255+4 70.40 261.35 3,566.9 3,517.9 -568.1 -4,276.2 6,003,253+5 383,573+5 1.3 -1,987.37 MWD+IFR-AK-CAZ-SC (3) 6,348+1 69.81 262.45 3,598.4 3,549.4 -580.4 -4,362.5 6,003,242+5 383,487.1 1.3 -2,026.80 MWD+IFR-AK-CAZ-SC (3) 6,443.5 68.71 262.49 3,632.2 3,583.2 -592.1 4,451.0 6,003,232.1 383,398.4 1.2 -2,067.96 MWD+IFR-AK-CAZ-SC (3) 6,537.2 67.69 262.41 3,667.0 3,618+0 -603.5 4,537.3 6,003,222.0 383,312.0 1.1 -2,108.08 MWD+IFR-AK-CAZ-SC (3) 6,632.5 68.33 262.66 3,702.7 3,653.7 -615.0 4,624.9 6,003,211.8 383,224.2 0.7 -2,148.92 MWD+IFR-AK-CAZ-SC (3) 6,726.5 67.53 264.27 3,738.0 3,689+0 -624.9 4,711A 6,003,203.2 383,137.6 1.8 -2,190.44 MWD+IFR-AK-CAZ-SC (3) 6,821.2 68.89 264.41 3,773.2 3,724.2 -633.6 4,798.9 6,003,195.9 383,050+0 1.4 -2,233.51 MWD+IFR-AK-CAZ-SC (3) 6,914.8 68.81 262.45 3,807.0 3,758.0 -643.6 4,885.6 6,003,187.2 382,963.1 2.0 -2,275.07 MWD+IFR-AK-CAZ-SC (3) 7,009.8 68.30 259.97 3,841.7 3,792.7 -657.1 4,973.1 6,003,175.0 382,875.5 2.5 -2,314.15 MWD+IFR-AK-CAZ-SC (3) 7,102.9 68.11 260.04 3,876.3 3,827.3 -672.1 -5,058.1 6,003,161.3 382,790.2 0.2 -2,350.66 MWD+IFR-AK-CAZ-SC (3) 7,197.3 67.97 260.17 3,911.6 3,862.6 -687.2 -5,144.4 6,003,147.5 382,703.7 0.2 -2,387.82 MWD+IFR-AK-CAZ-SC (3) 7,292.7 68.30 260.25 3,947.1 3,898.1 -702.2 -5,231+6 6,003,133.8 382,616.3 0.4 -2,425.52 MWD+IFR-AK-CAZ-SC (3) 7,386.5 68.10 259.92 3,981.9 3,933.0 -717.2 -5,317.5 6,003,120.1 382,530.2 0.4 -2,462.47 MWD+IFR-AK-CAZ-SC (3) 7,477.8 68.41 260.70 4,015.8 3,966.8 -731.5 -5,401+0 6,003,107.1 382,446.5 0.9 -2,498.72 MWD+IFR-AK-CAZ-SC (3) 7,572.7 68.08 260.41 4,050.9 4,001.9 -745.9 -5,488.0 6,003,093.9 382,359.4 0.4 -2,536.73 MWD+IFR-AK-CAZ-SC (3) 7,666.6 68.23 259.92 4,085.9 4,036.9 -760.8 -5,573.8 6,003,080.3 382,273.3 0.5 -2,573.79 MWD+IFR-AK-CAZ-SC (3) 7,761.1 68.15 260.30 4,121.0 4,072.0 -775.9 -5,660.3 6,003,066.5 382,186.6 0.4 -2,611.02 MWD+IFR-AK-CAZ-SC (3) 312812013 2:11:47PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report 10 marnoiiium mm�nem Company: ConocoPhillips(Alaska) Inc. NAD27 Local Co-ordinate Reference: Well CD3-127 Project: Western North Slope TVD Reference: CD3-127 @ 49.0ft Site: CD3 Fiord Pad MD Reference: CD3-127 @ 49.0ft Well: CD3-127 North Reference: True Wellbore: CD3-127 Survey Calculation Method: Minimum Curvature Design: CD3-127 Database: EDM 2003.16 Single User Db Survey Map Map Vertical ( WO" MD Inc Azi TVD TVDSS +NI-S +Ei-W Northing Easting DLS Section „illy) (ft) (1) C) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 7,852.7 67.59 260.14 4,155.5 4,106.5 -790.3 -5,743.9 6,003,053.4 382,102.8 0.6 -2,647.17 MWD+IFR-AK-CAZ-SC (3) 7,949.1 67.67 261.75 4,192.2 4,143.2 -804.3 -5,831.9 6,003,040.7 382,014.6 1.5 -2.686.17 MWD+IFR-AK-CAZ-SC (3) 8,042.7 68.21 263.38 4,227.3 4,178.4 -815.6 -5,918.0 6,003,030.7 381,928.4 1.7 -2,726.34 MWD+IFR-AK-CAZ-SC (3) 8,136.4 69.08 262.12 4,261.4 4,212.5 -826.6 -6,004.5 6,003,021.0 381,841.7 1.6 -2,766.94 MWD+IFR-AK-CAZ-SC (3) 8,230.1 68.41 263.62 4,295.4 4,246.4 -837.4 -6,091.2 6,003,011.5 381,754.9 1.7 -2,807.77 MWD+IFR-AK-CAZ-SC (3) 8,324.4 68.67 263.36 4,329.9 4,280.9 -847.4 -6,178.4 6,003,002.9 381,667.6 0.4 -2,849.64 MWD+IFR-AK-CAZ-SC (3) 8,420.4 68.61 262.87 4,364.9 4,315.9 -858.1 -6,267.1 6,002,993.5 381,578.7 0.5 -2,891.77 MWD+IFR-AK-CAZ-SC (3) 8,515.1 68.74 262.43 4,399.3 4,350.3 -869.4 -6,354.6 6,002,983.5 381,491.1 0.5 -2,932.68 MWD+IFR-AK-CAZ-SC (3) 8,609.5 68.13 261.14 4,434.0 4,385.1 -881.9 -6,441.5 6,002,972.3 381,403.9 1.4 -2,972.29 MWD+IFR-AK-CAZ-SC (3) 8,703.3 68.05 260.39 4,469.0 4,420.0 -895.9 -6,527.4 6,002,959.6 381,317.9 0.7 -3,010.10 MWD+IFR-AK-CAZ-SC (3) 8,797.4 68.08 260.73 4,504.2 4,455.2 -910.2 -6,613.5 6,002,946.6 381,231.6 0.3 -3,047.75 MWD+IFR-AK-CAZ-SC (3) 8,891.4 68.41 260.71 4,539.0 4,490.0 -924.3 -6,699.7 6,002,933.8 381,145.2 0.4 -3,085.65 MWD+IFR-AK-CAZ-SC (3) 8,984.9 68.27 261.12 4,573.5 4,524.5 -938.0 -6,785.5 6,002,921.4 381,059.2 0.4 -3,123.62 MWD+IFR-AK-CAZ-SC (3) 9,079.2 68.27 261.24 4,608.5 4,559.5 -951.4 -6,872.1 6,002,909.2 380,972.5 0.1 -3,162.28 MWD+IFR-AK-CAZ-SC (3) 9,173.4 68.51 260.55 4,643.1 4,594.2 -965.3 -6,958.5 6,002,896.7 380,885.8 0.7 -3,200.52 MWD+IFR-AK-CAZ-SC (3) 9,267.0 68.46 260.86 4,677.5 4,628.5 -979.4 -7,044.5 6,002,883.9 380,799.7 0.3 -3,238.30 MWD+IFR-AK-CAZ-SC (3) 9,361.8 68.47 260.78 4,712.3 4,663.3 -993.4 -7,131.5 6,002,871.2 380,712.5 0.1 -3,276.68 MWD+IFR-AK-CAZ-SC (3) 9,454.4 68.40 260.46 4,746.3 4,697.3 -1,007.4 -7,216.4 6,002,858.4 380,627.3 0.3 -3,313.91 MWD+IFR-AK-CAZ-SC (3) 9,549.3 68.27 259.94 4,781.3 4,732.3 -1,022.5 -7,303.3 6,002,644.7 380,540.2 0.5 -3,351.46 MWD+IFR-AK-CAZ-SC (3) 9,643.9 68.40 260.40 4,816.3 4,767.3 -1,037.5 -7,390.0 6,002,831.0 380,453.3 0.5 -3,388.87 MWD+IFR-AK-CAZ-SC (3) 9,737.7 68.42 260.10 4,850.8 4,801.8 -1,052.2 -7,475.9 6,002,817.5 380,367.2 0.3 -3,426.06 MWD+IFR-AK-CAZ-SC (3) 9,832.1 68.47 260.28 4,885.4 4,836.5 -1,067.2 -7,562.4 6,002,803.9 380,280.5 0.2 -3,463.43 MWD+IFR-AK-CAZ-SC (3) 9,926.4 68.74 260.63 4,919.8 4,870.9 -1,081.8 -7,649.0 6,002,790.6 380,193.7 0.4 -3,501.17 MWD+IFR-AK-CAZ-SC (3) 10,019.9 68.68 260.64 4,953.8 4,904.8 -1,095.9 -7,735.0 6,002,777.7 380,107.5 0.1 -3,538.88 MWD+IFR-AK-CAZ-SC (3) 10,114.9 68.61 260.21 4,988.4 4,939.4 -1,110.7 -7,822.2 6,002,764.3 380,020.1 0.4 -3,576.86 MWD+IFR-AK-CAZ-SC (3) 10,209.0 68.53 260.60 5,022.8 4,973.8 -1,125.3 -7,908.7 6,002,751.0 379,933.4 0.4 -3,614,46 MWD+IFR-AK-CAZ-SC (3) 10,302.7 68.75 260.12 5,056.9 5,007.9 -1,139.9 -7,994.7 6.002,737.7 379.847.2 0.5 -3,651.83 MWD+IFR-AK-CAZ-SC (3) 10,397.3 68.88 259.83 5,091.1 5,042.1 -1,155.2 -8,081.5 6,002,723.7 379,760.2 0.3 -3,689.06 MWD+IFR-AK-CAZ-SC (3) 10,491.4 68.28 259.87 5,125.5 5,076.5 -1,170.7 -8,167.8 6,002,709.5 379.673.7 0.6 -3,725.88 MWD+IFR-AK-CAZ-SC (3) 10,585.8 67.67 261.06 5,160.9 5,111.9 -1,185.2 -8,254.0 6,002,696.3 379,587.2 1.3 -3,763.49 MWD+IFR-AK-CAZ-SC (3) 10.680.4 67.74 261.84 5,196.8 5,147.8 -1,198.2 -8,340.6 6,002,684.6 379,500.5 0.8 -3,802.49 MWD+IFR-AK-CAZ-SC (3) 10,774.9 67.79 262.91 5,232.5 5,183.5 -1,209.8 -8,427.3 6,002,674.3 379,413.6 1.0 -3,842.71 MWD+IFR-AK-CAZ-SC (3) 10,869.4 68.00 263.52 5,268.1 5,219.1 -1,220.1 -8,514.3 6,002,665.3 379,326.5 0.6 -3,884.11 MWD+IFR-AK-CAZ-SC (3) 10,963.2 68.48 263.06 5,302.9 5,253.9 -1,230.3 -8,600.8 6,002,656.4 379,239.9 0.7 -3,925.39 MWD+IFR-AK-CAZ-SC (3) 11,058.2 68.61 262.88 5,337.6 5,288.6 -1,241.1 -8,688.5 6,002,646.9 379,152.0 0.2 -3,966.87 MWD+IFR-AK-CAZ-SC (3) 11,152.8 68.74 262.41 5,372.0 5,323.0 -1,262.4 -8,775.9 6,002,636.9 379,064.4 0.5 -4,007.75 MWD+IFR-AK-CAZ-SC (3) 11,246.7 68.73 260.93 5,406.0 5,357.0 -1,265.1 -8,862.4 6,002,625.6 378,977.7 1.6 -4,047.00 MWD+IFR-AK-CAZ-SC (3) 11,341.9 68.07 260.28 6,441.1 5,392.1 -1,279.5 -8,949.8 6,002,612.4 378,890.2 0.9 -4,085.27 MWD+IFR-AK-CAZ-SC (3) 11,435.6 68.06 259.95 5,476.1 5,427.1 -1,294.5 -9,035.4 6,002,598.8 378,804.3 0.3 -4,122.16 MWD+IFR-AK-CAZ-SC (3) 11,529.5 68.34 259.84 5,511.0 5,462.0 -1,309.7 -9,121.2 6,002,584.8 378,718.3 0.3 -4,158.84 MWD+IFR-AK-CAZ-SC (3) 3/28/2013 2:11:47PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. NAD27 Local Co-ordinate Reference: Well CD3-127 Project: Western North Slope TVD Reference: CD3-127 @ 49.Oft Site: CD3 Fiord Pad MD Reference: CD3-127 @ 49.Oft Well: CD3-127 North Reference: True Wellbore: CD3-127 Survey Calculation Method: Minimum Curvature Design: CD3-127 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El-W Northing Easting DLS Section (ft) V) V) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 11,624+6 68.49 260.75 5,546.0 5,497.0 -1,324.7 -9,208.5 6,002,571.2 378,630.9 0.9 -4,196.66 MWD+IFR-AK-CAZ-SC (3) 11,719.7 68.54 260.57 5,580.8 5,531.8 -1,339.0 -9,295.7 6,002,558.1 378,543.4 0.2 -4,234+96 MWD+IFR-AK-CAZ-SC (3) 11,813+8 68.74 257.27 5,615.1 5,566.1 -1,355.9 -9,381.7 6,002,542.6 378,457.2 3.3 -4,270.48 MWD+IFR-AK-CAZ-SC (3) 11,907.3 67.93 253.65 5,649.6 5,600.6 -1,377.7 -9,465.8 6,002,522+1 378,372.8 3.7 -4,300.86 MWD+IFR-AK-CAZ-SC (3) 12,002.6 66.23 250.29 5,686+7 5,637.7 -1,404.8 -9,549.2 6,002,496.2 378,289+0 3.7 -4,326.48 MWD+IFR-AK-CAZ-SC (3) 12,097.0 64.81 247.79 5,725.9 5,676.9 -1,435.5 -9,629.5 6,002,466+7 378,208.3 2.8 4,34T34 MWD+IFR-AK-CAZ-SC (3) 12,189.6 63.94 246.52 5,765.9 5,716.9 -1,467.9 -9,706.4 6,002,435.4 378,130.9 1.6 -4,364.92 MWD+IFR-AK-CAZ-SC (3) 12,284.6 64.03 244.69 5,807.6 5,758.6 -1,503.2 -9,784.2 6,002,401.3 378,052.6 1.7 -4,380.64 MWD+IFR-AK-CAZ-SC (3) 12,378.5 62.69 241.75 5,849.7 5,800.7 -1,541.0 -9,859.1 6,002,364.7 377,977.1 3.1 -4,392.64 MWD+IFR-AK-CAZ-SC (3) 12,471A 60.58 237.99 5,893.8 5,844.8 -1,582.0 -9,929.8 6,002,324.7 377,905.8 4.2 -4,399.61 MWD+IFR-AK-CAZ-SC(3) 12,566.4 60.51 235.05 5,940.5 5,891.5 -1,627.6 -9,998.8 6,002,280.2 377,836.2 2.7 -4,401.80 MWD+IFR-AK-CAZ-SC (3) 12,659.9 59.95 230.43 5,987.0 5,938.0 -1,676.7 -10,063.3 6,002,232.0 377,770.9 4.3 -4,398.61 MWD+IFR-AK-CAZ-SC (3) 12,755.1 58.95 226.01 6,035.4 5,986.4 -1,731.3 -10,124.5 6,002,178.4 377,709.0 4.1 -4,388.96 MWD+IFR-AK-CAZ-SC (3) 12,849.6 58.72 223.09 6,084.3 6,035.3 -1,788.9 -10,181.2 6,002,121.6 377,651.4 2.7 -4,374.30 MWD+IFR-AK-CAZ-SC (3) 12,944.1 59.08 219.13 6,133.1 6,084.2 -1,849.9 -10,234.4 6,002,061.4 377,597.3 3.6 -4,354.86 MWD+IFR-AK-CAZ-SC (3) 13,038.2 58.31 214.97 6,182.0 6,133.0 -1,914.0 -10,282.8 6,001,998.1 377,547.9 3.9 -4,330.11 MWD+IFR-AK-CAZ-SC (3) 13,132.3 57.85 210.21 6,231.8 6,182.8 -1,981+3 -10,325.8 6,001,931.5 377,503.9 4.3 -4,299.68 MWD+IFR-AK-CAZ-SC (3) 13,224.1 58.24 207A7 6,280.4 6,231.4 -2,049.6 -10,363.2 6,001,863.7 377,465.5 2.8 -4,265.14 MWD+IFR-AK-CAZ-SC(3) 13,318.5 58.52 202.99 6,329.9 6,280.9 -2,122.4 -10,397.3 6,001,791.5 377,430.3 3.8 -4,225.08 MWD+IFR-AK-CAZ-SC (3) 13,412.9 58.08 198.98 6,379.5 6,330.5 -2,197.4 -1Q426.0 6,001,717.0 377,400.5 3.6 -4,180.16 MWD+IFR-AK-CAZ-SC (3) 13,507.7 58.14 196.01 6,429.6 6,380.6 -2,274.1 AQ450.2 6,001,640.6 377,375.1 2.7 -4,131.15 MWD+IFR-AK-CAZ-SC (3) 13,601.7 59.73 193.85 6,478.1 6,429.1 -2,351.9 -10,470+9 6,001,563.1 377,353.2 2.6 -4,079.35 MWD+IFR-AK-CAZ-SC (3) 13,696.3 61.96 193.03 6,524.2 6,475.2 -2,432.3 -10,490.2 6,001,483.0 377,332.8 2.5 -4,024.51 MWD+IFR-AK-CAZ-SC (3) 13,791.0 64.10 193.31 6,567.2 6,518.2 -2,514.4 -10,509+4 6,001,401.2 377,312.4 2.3 -3,968.24 MWD+IFR-AK-CAZ-SC (3) 13,885.6 65.65 193.22 6,607.3 6,558.3 -2,597.8 -10,529.0 6,001,318.1 377,291.5 1.6 -3,911.21 MWD+IFR-AK-CAZ-SC (3) 13,980.1 66.82 193.87 6,645.4 6,596.4 -2,681.9 -10,549.3 6,001,234.4 377,269.9 1.4 -3,853.96 MWD+IFR-AK-CAZ-SC (3) 14,074.5 66.45 194.49 6,682.8 6,633.8 -2,765.9 -10,570.5 6,001,150.7 377,247.5 0.7 -3,797.34 MWD+IFR-AK-CAZ-SC (3) 14,169.1 66.32 193.43 6,720.7 6,671.7 -2,850.0 -10,591.4 6,001,067.0 377,225.3 1.0 -3,740+43 MWD+IFR-AK-CAZ-SC (3) 14,263.3 66.21 193.09 6,758.7 6,709.7 -2,934.0 -10,611.2 6,000,983.3 377,204.2 0.4 -3,682.97 MWD+IFR-AK-CAZ-SC (3) 14,358.2 68,35 191.05 6,795.3 6,746.3 -3,019.5 -10,629.5 6,000,898.0 377,184.7 3.0 -3,623.40 MWD+IFR-AK-CAZ-SC (3) 14,452.3 69.00 188.99 6,829+5 6,780+5 -3,105.8 -10,644.7 6,000,812.0 377,168.2 2.2 -3,561.45 MWD+IFR-AK-CAZ-SC (3) 14,545.9 71.58 187.55 6,861+1 6,812+1 -3,193.0 -10,657.4 6,000,725.0 377,154.2 3.1 -3,497.27 MWD+IFR-AK-CAZ-SC (3) 14,640.5 72.55 183.99 6,890.2 6,841.3 -3,282.6 -10,666.4 6,000,635.6 377,143.8 3.7 -3,429.10 MWD+IFR-AK-CAZ-SC (3) 14,735.6 74.86 181.39 6,916.9 6,867.9 -3,373+7 -10,670.7 6,000,544+5 377,138.2 3.6 -3,356.88 MWD+IFR-AK-CAZ-SC (3) 14,830.1 77.03 178.71 6,939.9 6,890.9 -3,465.4 -10,670.8 6,000,452.8 377,136.7 3.6 -3,281.81 MWD+IFR-AK-CAZ-SC (3) 14,924.6 78.99 177.27 6,959.5 6,910.5 -3,557.8 -10,667.5 6,000,360.4 377,138.6 2.6 -3,204.30 MWD+IFR-AK-CAZ-SC (3) 14,948.3 79.49 177.52 6,963.9 6,914.9 -3,581.0 -10,666.5 6,000,337.2 377,139.3 2.4 -3,184.66 MWD+IFR-AK-CAZ-SC (3) 15,040.9 83.82 176.79 6,977.4 6,928.4 -3,672.5 -1Q661.9 6,000,245.6 377,142.5 4.7 -3,107.06 MWD+IFR-AK-CAZ-SC (4) 15,137.1 86.86 176.63 6,985.2 6,936.2 -3,768.3 -10,656.4 6,000,149.8 377,146.5 3.2 -3,025.50 MWD+IFR-AK-CAZ-SC (4) 15,232.0 90.75 173.42 6,987.2 6,938+2 -3,862.7 -10,648.2 6,000,055.3 377,153.3 5.3 -2,943.41 MWD+IFR-AK-CAZ-SC (4) 312812013 2:11:47PM Page 6 COMPASS 2003.16 Build 69 r ConocoPhillips (Alaska) Inc. Definitive Survey Report - ,..i ,m'�maan m .�^ _.. . ,�nmm iirrm umimnrtaUnnunimmnnnnnrxaw - ,wa,ni� Company: ConocoPhillips(Alaska) Inc. NAD27 Local Co-ordinate Reference: Well CD3-127 Project: Western North Slope TVD Reference: CD3-127 @ 49.0ft Site: CD3 Fiord Pad MD Reference: CD3-127 @ 49.0ft Well: CD3-127 North Reference: True Wellbore: CD3-127 Survey Calculation Method: Minimum Curvature Design: CD3-127 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +EI-W Northing Easting DLS Section (ft) (1) (1) (ft) (ft) (ft) (ft) (ft) (ft) (°1100-) (ft) Survey Tool Name 15,279.9 91.87 171.49 6,986.1 6,937.1 -3,910.2 -10,641.9 6,000,00T7 377,158.9 4.7 -2,900.95 MWD+IFR-AK-CAZ-SC (4) 15,328.0 92.11 168.44 6,984.4 6,936.4 -3,957.5 -10,633.5 5,999,960.3 377,166.5 6.4 -2,857.38 MWD+IFR-AK-CAZ-SC (4) 15,374.8 92.06 166.20 6,982.7 6,933.7 -4,003.1 -10,623.3 5,999,914.5 377,176.1 4.8 -2,814.09 MWD+IFR-AK-CAZ-SC (4) 15,422.2 91.32 163.06 6,981.3 6,932.3 -4,048.8 -10,610.7 5,999,868.6 377,188.0 6.8 -2,769.45 MWD+IFR-AK-CAZ-SC (4) 15,470.9 89.83 160.53 6,980.8 6,931.8 -4,095.1 -10,595.5 5,999,822.2 377,202.5 6.1 -2,722.86 MWD+IFR-AK-CAZ-SC (4) 15,519.2 90.14 157.85 6,980.8 6,931.8 -4,140.2 -10,578.4 5,999,776.8 377,219.0 5.6 -2,676.05 MWD+IFR-AK-CAZ-SC (4) 16,566.8 90.51 154.75 6,980.6 6,931.6 -4,183.8 -10,559.2 5,999,732.9 377,237.5 6.6 -2,629.34 MWD+IFR-AK-CAZ-SC (4) 15,614.1 88.85 153.12 6,980.8 6,931.8 -4,226.3 -10,538.4 5,999,690.1 377,257.6 4.9 -2,582.62 MWD+IFR-AK-CAZ-SC (4) 15,660.6 88.35 151.88 6,982.0 6,933.0 -4,267.5 -10,517.0 5,999,648.5 377,278.4 2.9 -2,536.52 MWD+IFR-AK-CAZ-SC (4) 15,708.6 88.84 149.86 6,983.1 6,934.1 -4,309.4 -10,493.7 5,999,606.3 377,301.1 4.3 -2,488.87 MWD+IFR-AK-CAZ-SC (4) 15,805.6 88.35 146.24 6,986.5 6,936.5 -4,391.7 -10,442.3 5,999,523.3 377,351.2 3.8 -2,392.04 MWD+IFR-AK-CAZ-SC (4) 15,899.5 89.77 143.94 6,987.1 6,938.1 -4,468.7 -10,388.6 5,999,445.5 377,403.8 2.9 -2,298.13 MWD+IFR-AK-CAZ-SC (4) 15,996.5 87.80 143.55 6,989.1 6,940.1 -4,546.8 -10,331.3 5,999,366.5 377,469.9 2.1 -2,201.22 MWD+IFR-AK-CAZ-SC (4) 16,091.9 88.47 143.77 6,992.2 6,943.2 -4,623.6 -10,274.8 5,999,288.9 377,515.2 0.7 -2,105.90 MWD+IFR-AK-CAZ-SC (4) 16,187.4 89.21 142.12 6,994.1 6,945.2 -4,699.8 -10,217.2 5,999,211.8 377,571.6 1.9 -2,010.47 MWD+IFR-AK-CAZ-SC (4) 16,282.2 89.09 138.98 6,995.6 6.946.6 -4,773.1 -10,157.0 5,999,137.7 377,630.8 3.3 -1,915.90 MWD+IFR-AK-CAZ-SC (4) 16,377.6 88.54 137.93 6,997.5 6.948.5 -4,844.5 -10,093.7 5,999,065.4 377,692.9 1.2 -1,821.18 MWD+IFR-AK-CAZ-SC (4) 16,473.7 88.66 141.28 6,999.9 6,950.9 -4,917.6 -10,031.5 5,998,991.3 377,754.0 3.5 -1,725.60 MWD+IFR-AK-CAZ-SC (4) 16.568.9 90.51 143.08 7,000.6 6,951.6 -4,992.8 -9,973.1 5,998,915.2 377,811.3 2.7 -1,630.47 MWD+IFR-AK-CAZ-SC (4) 16,664.0 90.45 143.56 6,999.8 6,950.8 -5,069.1 -9,916.3 5,998,838.1 377,866.9 0.5 -1,535.42 MWD+IFR-AK-CAZ-SC (4) 16,757.6 90.39 143.56 6,999A 6,950.1 -5,144.3 -9,860.7 5,998,762.0 377,921.4 0.1 -1,441.88 MWD+IFR-AK-CAZ-SC (4) 16,854.3 90.39 143.73 6,998.4 6,949.4 -5,222.3 -9,803.4 5,998,683.3 377,977.6 0.2 -1,345.16 MWD+IFR-AK-CAZ-SC (4) 16,949.1 90.02 142.12 6,998.1 6,949.1 -5,297.9 -9,746.2 5,998,606.8 378,033.5 1.7 -1,250.46 MWD+IFR-AK-CAZ-SC (4) 17,044.9 89.83 141.60 6,998.2 6,949.2 -5,373.2 -9,687.1 5,998,530.6 378,091.6 0.6 -1,154.78 MWD+IFR-AK-CAZ-SC (4) 17,139.8 89.09 142.42 6,999.1 6,950.1 -5,448.0 -9,628.7 5,998,455.0 378,148.8 1.2 -1,060.04 MWD+IFR-AK-CAZ-SC (4) 17,235.0 88.84 143.93 7,000.8 6,951.8 -5,524.2 -9,571.6 5,998,377.9 378,204.7 1.6 -964.89 MWD+IFR-AK-CAZ-SC (4) 17,330.2 90.45 144.49 7,001.4 6,952.4 -5,601.4 -9,516.0 5,998,299.9 378,259.2 1.8 -869.73 MWD+IFR-AK-CAZ-SC (4) 17,426.0 90.20 144.85 7,000.9 6.951.9 -5,679.6 .9,460.6 5,998,220.9 378,313.4 0.5 -773.92 MWD+IFR-AK-CAZ-SC (4) 17,521.3 90.51 145.60 7,000.3 6,951.3 -5,757.8 -9,406.2 5,998,141.9 378,366.6 0.9 -678.67 MWD+IFR-AK-CAZ-SC (4) 17,617.3 91.50 144.18 6,998.6 6,949.6 -5,836.3 -9,351.0 5,998,062.5 378,420.6 1.8 -582.69 MWD+IFR-AK-CAZ-SC (4) 17,713.2 90.39 141.90 6,997.0 6,948.0 -5,913.0 -9,293.4 5,997,985.1 378,477.1 2.6 -486.83 MWD+IFR-AK-CAZ-SC (4) 17,806.4 89.34 140.41 6,997.2 6,948.2 -5,985.5 -9,234.9 5,997,911.6 378,534.5 2.0 -393.85 MWD+IFR-AK-CAZ-SC (4) 17,904.0 89.09 139.93 6,998.6 6,949.6 -6,060.5 -9,172.4 5,997,835.7 378,595.9 0.6 -296.54 MWD+IFR-AK-CAZ-SC (4) 17,999.4 89.46 139.16 6,999.8 6,9%8 -6,133.1 -9,110.5 5,997,762.2 378,656.6 0.9 -201.61 MWD+IFR-AK-CAZ-SC (4) 18,094.9 88.60 136.44 7,001.4 6,952.4 -6,203.9 -9,046.3 5,997,690.5 378,719.7 3.0 -106.86 MWD+IFR-AK-CAZ-SC (4) 18,190.3 88.91 137.62 7,003.5 6,954.5 -6,273.6 -8,981.3 5,997,619.8 378,783.7 1.3 -12.42 MWD+IFR-AK-CAZ-SC (4) 18,285.6 88.60 138.32 7,005.6 6,956.6 -6,344.4 -8,917.5 5,997,548.1 378,846.4 0.8 82.12 MWD+IFR-AK-CAZ-SC (4) 18,381.3 88.66 139.58 7,007.8 6,958.8 -6,416.6 -8,854.7 5,997,475.0 378,908.1 1.3 177.29 MWD+IFR-AK-CAZ-SC (4) 18,478.1 89.27 142.29 7,009.6 6,960.6 -6,491.6 -8,793.8 5,997,399.0 378,967.9 2.9 273.74 MWD+IFR-AK-CAZ-SC (4) 18,543.1 88.88 143.72 7,010.6 6,961.6 -6,543.6 -8,754.6 5,997,346.5 379,006.2 2.3 338.70 MWD+IFR-AK-CAZ-SC (4) 3/28/2013 2:11:47PM Page 7 COMPASS 2003.16 Build 69 Company: ConocoPhillips(Alaska) Inc. NAD27 Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: CD3-127 Design: CD3-127 Survey ConocoPhillips (Alaska) Inc. Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well CD3-127 CD3-127 @ 49.Oft CD3-127 @ 49.Oft True Minimum Curvature EDM 2003.16 Single User Db Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1) (1) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 18,632.6 88.69 145.36 7,012.5 6,963.5 -6,616.5 -8,702.7 5,997,272.8 379,057.0 1.8 428.21 MWD+IFR-AK-CAZ-SC (4) 18,724.3 88.08 142.15 7,015.1 6,966.1 -6,690.4 -8,648.5 5,997,198.1 379,110.1 3.6 519.88 MWD+IFR-AK-CAZ-SC (4) 18,822.4 86.59 141.74 7,019.7 6,970.7 -6,767.5 -8,588.1 5,997,120.1 379,169.3 1.6 617.67 MWD+IFR-AK-CAZ-SC (4) 18,914.7 87.33 147.43 7,024.6 6,975.6 -6,842.6 -8,534.7 5,997,044.2 379,221.6 6.2 709.84 MWD+IFR-AK-CAZ-SC (4) 18,967.6 87.71 150.00 7,026.9 6,977.9 -6,887.8 -8,507.3 6,996,998.6 379,248.4 4.9 762.55 MWD+IFR-AK-CAZ-SC (4) 19,011.1 89.62 149.99 7,027.9 6,978.9 -6,925.4 -8,485.6 5,996,960.7 379,269.5 4.4 805.85 MWD+IFR-AK-CAZ-SC (4) 19,106.0 91.17 149.71 7,027.2 6,978.2 -7,007.5 -8,43T9 5,996,877.9 379,315.9 1.7 900.39 MWD+IFR-AK-CAZ-SC (4) 19,203.6 88.82 149.22 7,027.2 6,978.2 -7,091.6 -8,388.3 5,996,793.1 379,364.3 2.5 997.74 MWD+IFR-AK-CAZ-SC (4) 19,300.4 88.08 150.28 7,029.8 6,980.9 -7,175.1 -8,339.6 5,996,708.8 379,411.7 1.3 1,094.12 MWD+IFR-AK-CAZ-SC (4) 19,395.1 88.26 149.72 7,032.9 6,983.9 -7,257.1 -8,292.2 5,996,626.1 379,457.8 0.6 1,188.48 MWD+IFR-AK-CAZ-SC (4) 19,490.5 90.67 149.60 7,033.8 6,984.8 -7,339.4 -8,244.1 5,996,543.2 379,504.7 2.5 1,283.47 MWD+IFR-AK-CAZ-SC (4) 19,585.8 88.14 147.35 7,034.8 6,985.8 -7,420.7 -8,194.2 5,996,461.1 379,553.4 3.5 1,378.67 MWD+IFR-AK-CAZ-SC (4) 19,681.1 88.76 144.36 7,037.3 6,988.3 -7,499.5 -8,140.8 5,996,381.5 379,605.6 3.2 1,473.89 MWD+IFR-AK-CAZ-SC (4) 19,776.5 87.77 142.55 7,040.2 6,991.2 -7,576.1 -8,084.0 5,996,304.1 379,661.2 2.2 1,569.19 MWD+IFR-AK-CAZ-SC (4) 19,871.3 87.33 142.00 7,044.3 6,995.3 -7,651.0 -8,026.1 5,996,228.3 379,718.0 0.7 1,663.77 MWD+IFR-AK-CAZ-SC (4) 19,968.0 88.88 142.39 7,047.5 6,998.5 -7,727.3 -7,966.8 5,996,151.1 379,776.1 1.7 1,760.28 MWD+IFR-AK-CAZ-SC (4) 20,033.0 88.88 142.39 7,048.7 6,999.7 -7,778.8 -7,927.1 5,996,099.0 379,815.0 0.0 1,825.23 PROJECTED to TD 3/28/2013 2:11:47PM Page 8 COMPASS 2003.16 Build 69 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gamma-CCL TCP Correlation: CD3-127 Run Date: 3/13/2013 March 28, 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 CD3-127 Digital Data in LAS format, Digital Log Image file 50-103-20634-00 1 CD Rom 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 Date: Signed: Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Tuesday, February 19, 2013 3:45 PM To: 'Brunswick, Scott A' Cc: Bettis, Patricia K (DOA) Subject: RE: PTD 211-005 - CD3-127 7-5/8" upcoming casing cement Scott, We have reviewed offset wells where these three zones are present and not cemented and agree that remaining with the original plan of cement top @ 13900 ft MD (Kuparuk top is @-14431 ft MD) is acceptable for CD3-127. Thanx, Victoria From: Brunswick, Scott A fmailto:Scott.A.Brunswick@)conocophill ips.coml Sent: Tuesday, February 19, 2013 12:45 PM To: Ferguson, Victoria L (DOA) Subject: FW: [EXTERNAL]RE: PTD 211-005 - CD3-127 7-5/8" upcoming casing cement Sent with Good (www.good.com) -----Original Message ----- From: Samuell, John G Sent: Tuesday, February 19, 2013 03:31 PM Central Standard Time To: Brunswick, Scott A Subject: FW: [EXTERNAL]RE: PTD 211-005 - CD3-127 7-5/8" upcoming casing cement Scott, See top of cement for the 4 wells I looked up in Wellview. I'm out of the office, but can log in remotely if you need more data. Sent with Good (www.good.com) -----Original Message ----- From: Samuell, John G Sent: Tuesday, February 19, 2013 01:52 PM Central Standard Time To: Samuell, John G Subject: FW: [EXTERNAL]RE: PTD 211-005 - CD3-127 7-5/8" upcoming casing cement TOC CD3-125—10,160' MD CD3-128—11,977' MD CD3-124-14,100' MD CD3-117—13,450' MD J.G. Samuell Drilling Engineer I ConocoPhillips Alaska I Direct: (907) 265-6309 i Mobile: (832) 465-8148 From: Boccanera, Justine Sent: Tuesday, February 19, 2013 9:54 AM To: Brunswick, Scott A Cc: Samuell, John G Subject: RE: [EXTERNAL]RE: PTD 211-005 - CD3-127 7-5/8" upcoming casing cement Scott, The nearby offset wells which have these zones above the HRZ include the CD3-117, CD3-124 and CD3-128. These intervals are less developed, but also present, in the CD3-125 & 125PI31. Justine From: Brunswick, Scott A Sent: Tuesday, February 19, 2013 9:35 AM To: Boccanera, Justine Cc: Samuell, John G Subject: FW: [EXTERNAL]RE: PTD 211-005 - CD3-127 7-5/8" upcoming casing cement Justine Could you help with finding offset wells that we saw the three zones and did not cement them? JG can you help with this while I'm in school? Thanks Sent with Good (www.good.com) -----Original Message ----- From: Ferguson, Victoria L (DOA) [victoria.fer u son a,alaska.€,ov] Sent: Tuesday, February 19, 2013 12:08 PM Central Standard Time To: Brunswick, Scott A Subject: [EXTERNAL]RE: PTD 211-005 - CD3-127 7-5/8" upcoming casing cement Scott, We are currently reviewing this. Do you have examples of the other offset wells that were not cemented but showed similar zones. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.ferguson(o)alaska.gov From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Monday, February 18, 2013 1:33 PM To: Ferguson, Victoria L (DOA) Subject: PTD 211-005 - CD3-127 7-5/8" upcoming casing cement Victoria I wanted to send you a note to make sure there are no objections to remaining with the original plan of cement top @ 13900 ft MD (Kuparuk top is @-14431 ft MD). Please review the attached logs @ depths; 12765 ft MD, 13075 ft MD, & 13230 ft MD. Although the zones may be hydrocarbon bearing, there is no expectation that these zones could produce at economic rates. The top zone looks to be very tight. These zones have been observed on offset wells and not cemented; I just wanted to be sure it is acceptable to the AOGCC. Thanks Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-263-4249 Cell: (907)-227-8499 STATE OF ALASKA Al CA OIL AND GAS CONSERVATION COM._„SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r— Repair well ) ` Plug Perforations j — Perforate ) — Other (" After CasingPull Tubing r� t -_. ) g Stimulate - Frac j✓ Waiver Time ExtensiorY'k fit Change Approved Program '" Operat. Shutdown Stimulate - Other r Re-enter Suspended Well i 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ' Exploratory r— Stratigraphic Service 211-005 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20634-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, 025538, 25526 CD3-127 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 20033 feet Plugs (measured) none true vertical 7049 feet Junk (measured) None Effective Depth measured 20033 feet Packer (measured) 14367, 14790 true vertical 7049 feet (true vertical) 6799, 6930 Casing Length Size MD ND Burst Collapse Conductor 78' 16" 114' 114' Surface 3203' 10.75" 3239' 2454' Intermediate 14936' 7.625" 14970' 6967' Liner 5233' 3.5" 20023' 7049' Perforation depth: Measured depth: 14429-14452, 15495-15499, 16390-16395, 17289-17294, 18189-18194, 19087-19092 True Vertical Depth: 6821-6829, 6981-6981, 6996-6996, 7001-7001, 7003-7003, 7028-7027 Tubing (size, grade, MD, and TVD) 4.5 x 3.5, L-80, 14826' MD and 6939' TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIE PACKER @ 14367 MD and 6799 TVD PACKER - BAKER ZXP LINER TOP PACKER @ 14790 MD and 6930 TVD SSSV - TRMAXX-5E SSSV @ 2152 MD and 2001 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 15495-19092' Treatment descriptions including volumes used and final pressure: ISIP= 1800 psi, 686560# of 16/20 carbolite proppant 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory — Development (✓ Service r— Stratigraphic f- 16. Well Status after work: Oil ✓ Gas F WDSPL I Daily Report of Well Operations XXX GSTOR I— WINJ F WAG I— GINJ r SUSP " SPLUG F 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313-073 Contact Robert Blakney Ca) 265-6417 Email Robert.G.Blakneyaa conocophillips.com Printed Name Robert Blaknev Title Completion Engineer Signature Phone: 265-6417 Date �BDMS APR 16 20U J:;w Form 10-404 Revised 10/2012 4/14,/13 Submit Original Only WNS CD3-127 Cono4WIIips Alaske, hC. ; CONDUCTOR. ---o 36414 SAFE7Y VLV, 2.152 SURFACE, 36-3,239 GAS LIFT 5.792 GAS LIFT, 11.801 GAS LIFT, 14,095 a�cfF=K PACKER._ 14,367 GAS LIFT, 14.394 SLEEVE, _ 14,495 E. 14,509 SEAL ASSY, 14.815 PERFP, 15,495-15,499 FRAC. 15.495 PERFP, 16,390-16,395 ' FRAC, 16,390 FRAC289 PERFP. ea� PERFP, ar , 17,289-17,294 PERFP, 18,189-18,194 FRAC, 18,189 W 41 Atbtbutes Max Angle & MD TD Wellborn APW WI Field Name Well Shtua 501032063400 FIORD NECHELIK PROD 1-1(°) MD (ftKB) 92.11 15,327.97 Act Btm (ftKB) 20,033.0 Comment H2S (ppm) SSSV: TRDP Date Annotation Last WO: End Dale KB-Grd (R) 36.30 Rig Release Dale 3/19/2013 Annotation Last Tag: SLM Depth (RKB) 14,700.0 End Date 3/31/2013 Annotation Last Rev Reason: BREAK DOWN FRAC DEPTHS Mod ... osborl End Date 4/12/2013 Casing Strings Casing Description CONDUCTOR String 0... 16 String ID ... 14.688 Top (ftKB) Set 36.0 Depth If- 114.0 Set Depth (TVD)... 114.0 String Wt... String 109.00 H-00 ... String Top Thrd WELDED Casing Description SURFACE String 0... 10 314 String ID ... 9.950 Top (ftKB) Set 35.9 Depth (f... 3,239.2 Set Depth (TVD) ... 2,453.9 String Wt... String 45.50 L80 ... String Top Thrd BTCM Casing Description INTERMEDIATE String 0... 7518 String ID ... 6.875 Top (ftKB) Set 34.3 Depth If... 14,969.6 Set Depth (TVD) ... 6,966.9 String Wt.. String 29.70 L-80 ... String Top Thrd BTCM Casing Description LINER String 0... 31/2 String ID ... 2.992 Top (RKB) Set 14,790.2 Depth (C.. 20,023.0 Set Depth (TVD) ... 7,048.5 String Wt... String 9.30 L-80 ... String Top Thrd SLHT Liner Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (") Rem Description Comment Nomi... ID (in) 14,790.2 6,930.4 76.20 PACKER BAKER ZXP LINER TOP PACKER 4.950 14,808.9 6,935.0 76.59 NIPPLE BAKER RS NIPPLE 4.880 14,811.8 6,935.7 76.65 HANGER BAKER FLEX LOCK LINER HANGER 4.830 14,821.4 6,937.9 76.85 SBE Baker 80-40 Seal Bore Extension P x P 4.000 15.028.6 6,976.0 83.43 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15.075.5 6,980.4 84.91 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 15,495.0 6,980.8 89.95 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (2.W' seat ID) 2.125" BALL ON SEAT 2.000 15,941.5 6,987.9 88.92 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 16,390.6 6,995.6 87.05 FRAC PORT 3-1/2' SLHT Ball Actuated Sleeve (1.875" seat ID) 2.0" BALL ON SEAT 1.875 16,838.3 6,998.6 90.45 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 17,289.1 7,001.2 89.75 FRAC PORT 3.1/2' SLHT Ball Actuated Sleeve (1.75" seat ID) 1.875" BALL ON SEAT 1.750 17,739.2 6,996.7 89.51 Swell packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 18,189.7 7,003.5 88.91 FRAC PORT 3-1/2' SLHT Ball Actuated Sleeve (1.625" seat ID) 1.75" BALL ON SEAT 1.625 18,638.1 7,014.2 89.39 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 19,087.4 7,027.5 90.87 FRAC PORT 3-1/2" SLHT Ball Actuated Sleeve (1.50" seal ID) 1.625" BALL ON SEAT 1.500 19.536.3 7,032.9 87.82 Swell Packer SWELL PACKER OD 6.38" w/ 5' Sealing element 2.992 19,960.0 7,047.3 88.88 SLEEVE BAKER'? SLEEVE 2.695 19,982.9 7,047.8 88.88 VALVE BAKER WELLBORE ISOLATION VALVE 0.000 Tubing Strings Tubing Description TUBING 4.5x3.5@107' String 0... 31/2 String 10 ... 2.992 Top (RKB) Set 31.3 Depth (f... 14,825.E 1 Set Depth (TVD) ... 6,938.9 String Wt... String 9.30 1 L80 ... String Top Thrd EUE Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Inc. f) Rem Description Comment Nomi... ID (in) 31.3 31.3 -0.04 HANGER FMC TUBING HANGER 3.900 107.2 107.2 0.29 XO Reducing CROSSOVER 4-1/2' IBT-m box x 3.12" EUE-m 3.500 2,152.1 2,001.4 48.56 SAFETY VLV TRMAXX-5E SSSV w/ 2.812" "X" profile w/ 1/4" control line (5.176" OD) 2.812 14,342.2 6,789.4 68.24 GAUGE SLB BHP Guage, 3-1/2" NDPG single sub, EUE pin x pin, w/ encapsulated I -wire 2.992 14,367.2 6,798.6 68.41 PACKER BAKER PREMIER PACKER 2.870 14,414.5 6,815.8 68.74 Blast Ring PESI BLAST RING (1) 2.992 14,495.3 6,844.7 71.06 SLEEVE BAKER CMD SLIDING SLEEVE 2.812 14,508.91 6,849.21 71.20 NIPPLE HES "XN" LANDING NIPPLE 2.75" NO GO 2.813 14,814.7 6,936.4 76.71 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY (10.39 to 4.53" OD locator) 2.970 Perforations & Slots To RKB Stan ftKB Top(TVD) IRKS) Btm(TVD) (ftKB) Zone Date Shot Dens (sh••• Type Comment 14,429.0 14,452.0 6,821.1 6,829.4 Nechelik, CD3-127 3/132013 5.0 IPERF PERF KUPARUK SAND N 14429' U 14452 15,495.0 15,499.0 6,980.8 6,980.8 Nechelik, CD3-127 329/2013 5.0 PERFP FRAC PORT 16,390.0 16,395.0 6,995.6 6,995.9 Nechelik, CD3-127 3292013 5.0 PERFP FRAC PORT 17.289.0 17,294.0 7,001.2 7,001.3 Necttelik, CD3-127 3292013 5.0 PERFP FRAC PORT 18,189.0 18,194.0 7,003.4 7,003.2 Nechelik, CD3-127 3292013 5.0 PERFP FRAC PORT 19,087.0 19,092.0 7,027.5 7,027.5 Nechelik, CD3-127 3292013 5.0 PERFP FRAC PORT Mandrel Details g-,- N••• Top (TVD) To RKB) (ftKB) Depth Top Incl () Make Model OD (in) Sam Valve Type Latch Type Port Size ON TRO Run (Psi) Run Date Com... 1 5,792.1 3,403.5 68.99 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/172013 2 11,801.2 5,610.5 68.71 Carrico KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/172013 3 14,094.7 6,691.0 66.41 Carrico KBMG 1 GAS LIFT DMY BEK 0.000 0.0 3/'172013 DCK-2 4 14,39a6 6,808.2 68.59 Carrico KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3(172013 LINER, 14'790.20,023 TO (CD3.127), 20,033 WNS CD3-127 ConocoPhillips Alaska, Ir1C. • • Well Congo. HORIZONTAL - CD3-127. M12P2013 110411 AM Schemallo-AduaI HANGER, 31 � +. CONDUCTOR,_JJ 36-114 SAFETY VLV, 2.152 SURFACE,_ 36-3.239 GAS LIFT, 5,792 GAS LIFT 11.801 GAS LIFT. 14,095 3E, 14,342 PACKER, 14,367 GAS LIFT, 14,394 NIPPLE, 14,509— SEAL ASSY, _ 14.815 PERFP, 16,390-16,395 FRAC, 16,3W ' FRAC, 17,289 PERFP. 17,289-17.294 PERFP, 18.189-16C, ,194 FRA18,189 ' PERFP, 19,087-19,092 ' FRAC, 19.087 Min Top Max Btm I Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type 15,495.0 15,499.0 6,980.8 6,980.8 FRAC 3/19/2013 Date Comment 3/29/2013 NECHILIK FRAC, 6 main stages utilizing Packers Plus S1ackFRAC system. Each stage placed approximately 113-118k# of 16120 Carbot-ite Proppant (1-7 ppa) using 30# crosslink gel at 20-bpm, for a job total of 686,5604 sand and 7999-bbl total volume pumped (100% of design). First stage was pumped through Baker'P' Sleeve at 19,960' MD, with subsequent stages initiated by dropping frac balls (1.625" - 2.129', in 0. 126' increments) opening specific ports along the horizontal liner. The prop fracture treatment was preceded by a breakdown using 30# linear gel at 20-bpm. (118.1K#) LINER, 14,790-20.023 TO (CD3.127), 20.033 CD3-127 Frac Summary DATE SUMMARY 3/29/2013 Performed Nechelik-sand fracturing treatment consisting of 6 main stages utilizing Packers Plus StackFRAC system. Each stage placed approximately 113-118k# of 16/20 Carbol-ite Proppant (1-7 ppa) using 30# crosslink gel at 20-bpm, for a job total of 686,560# sand and 7999-bbl total volume pumped (100% of design). First stage was pumped through Baker'P' Sleeve at 19,960' MD, with subsequent stages initiated by dropping frac balls (1.625" - 2.125", in 0.125" increments) opening specific ports along the horizontal liner. The prop fracture treatment was preceded by a breakdown using 30# linear gel at 20-bpm. 3/31/2013 PULLED FRAC SLEEVE FROM SSSV @ 2152' RKB, TAGGED BTM @ 14,700' SLM, SET CATCHER SUB @ 14,472' SLM, PULLED 1" DMY VLV FROM STA # 3 @ 14,094' RKB. IN PROGRESS 4/1/2013 INSTALLED NEW GAS LIFT DESIGN, PULLED CATCHER FROM XN @ 14,508, RKB, PREFORM CLOSER TEST ON SSSV **PASS** READY FOR EXPRO FLOW BACK THE STATE Alaska Oil and Gas 01ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney Completion Engineer ConocoPhillips Alaska, Inc.t P.O. Box 100360 1 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD3-127 Sundry Number: 313-073 Dear Mr. Blakney: 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, CatJPPoerster Chair DATED this`= day of March, 2013. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RE2'10EI�V[r3p D FEB 2Z AOGCC 1. Type of Request: Abandon r Plug for Redrill (— Perforate New Fool f— Repair w e1 t— Change Approved Program F- Suspend r Plug Perforations r Perforate r PUN Tubing r Time Extension I— Operational Shutdown F- Re-enter Susp. Well j-- Stimulate rV • Aker casing I- Other: 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rr ' Exploratory j— Stratigraphic r Service f— 211-M 3. Address: 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50.103-20634-00 7. Nperforating, What 8. Well Name and Number. Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spackV exception? Yes f— No W CD3-127 - 9. Property Designation (Lease Number): - 10. Fiel flPool(s): lColvills ADL 372105, 025538, 2552E River Field / Alpha 01 Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (it): Total Depth TVD (ft Effective Depth MD (ft): Effective Depth TVD (it): Plugs (measured): jJunk (measured): • 15261 6978 3039 2384' 30391, 7344', 13207'- Casing Length Size MD TVD Burst Collapse Conductor 77' le, 114' 114' Surface 3202' 10.76, 3239 245Y Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Thing MD (ft): none none 3.5 kill string L-80 2176 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal + N 13. Well Class after proposed work: Detailed Operations Program I— SOP Sketch r'' Exploratory r"' Stratigraphic r Development R+ Service I 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 oil W + Gas I-" WDSPL )� Suspended r WINJ (y GINJ r WAG r Abandoned (— 16. Verbal Approval: Date: Commission Representative: GSTOR I— SPLUG f 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney a 265-6417 Email: Robart.G.Blakogy@conoopphillips,com Printed Name Robert SlIbneyTitle: Signature Completion Engineer / Phone: 265-6417 Date Commission Use Only Sundry Number: �y 3 - �3 Conditions of approval: Notify Commission so that a representative may witness ✓� Plug Integrity I— SOP Test r Mechanical Integrity Test (— Location Clearance I — other: MEMMS MAR 0 5 201 Spacing Exception Required? Yes ❑ No 6 Subsequent Form Required: l Q 4-0 Moved by: APPROVED BY I Date: 3 — Form 10-403 (Reviled 10/2012) ORIGINAL rz_ % 3//// 3 Submit Form and Attachments in Duplicate ConocoPhillips Ali, k,,, In,; i MAlIGER. 31 VAEG.2 176 SURFACE, 36]2M ~ a Cunt Plug. J.O3a ESP. s,NI-A ' D 1lVV�q i Cen'.anl Plug I,3aa 1 Csment Plug. 13,207 r TD (CD3.121), 1 5.261 119 CD3-127 Well Attributes IMax Angle & MD TD Nlellbor<APYIIWI RJtl Nam< w<u stawa Intl(,) rto(nKaJ Ad Sun ("Kb) 5010320G3400 FIOftD NECHELIK PROD 83.42 15.231.51 Comment H2s (pP.) Date AnnOOU.. End Data NB Grtl (R) Rlg Raises Date SSSv: Last WO :_ 36.30 _ Annotation Depth(RKB) End Date Annotation past l.fod ... End Date Last Tag: Rev Reason: FIX TBG DUPLICATIONS oslxxl 1 1/28/2013 casino Stfinciis Caslnq Descripaon string O... Shiny lD .., Top (NKe) Set Depth (f... Set Oaplh (TVDi... 9hinp Wl... slriny ... string Top Turd CONDUCTOR 16 14.688 36.0 114.0 114.0 109.00 Hd0 WELDED -- Casing Description 1SWng 0 ISUIng ID ... Top (IRS) set Depth (/... 18.1 Depth I ISI,IngWt ..Slrinp ----- Top Thrd SURFACE 10314 9.950 35.9 32392 2.4534 45.50 L80 RTCM Tubing Strings Tubing Description 51r[ng (t N W., shiny Top Thrd TUBING 3 2.992 30.9 2,176.0 2,014.4 9.20 L-&1 KILL STRING 1 1 Com letion Details Top Depth (TVDI lop Inc[ Nomi... To KKB (aKa) (°I nsm Daserlplion Comment ID (ln) 30.9 30.9 0.26 HANGER FMC TUBING HANGER 4.500 2,175.5 2,016.7 49.30 WLEG WLEG 3.000 Other In Hole Wiretine retrievable Plugs, valves pumps, f1s11 etc. Top Depth "Vol Top Inci To flHf3 IDKB) 1°1 Descrl lion Comment Run Date ID (In) 3,441 C 2,527.3 68.18 ECP Ran ISO zone ECP, for cement plug, 4282012 2.430 Conim Ix). 301-39-5306, Ran Weatherford 7 S18 float shoe w/ centralizer (straight blade 9 118) 9.24 pup Cement Squeezes Top Depth St., Depth (TVD) Iwo) Tap (AKa) Btni (IKDI (IIKB) (IIHBJ Descriplion start Date Comment 3,039.0 3,441.0 2.383.5 2,527.3 Cement Plug 428/2012 AbandenmonMCkoff plug. Dowell nix mud push to 11.5 ppg. Dovelll pump .6 btA, pressure lest lines to 3000 psi. Dowell continue to Jump a Iola[ or 23.1 buts of mud push @ 4.5 bpm wl 250 psi final pressure. Dowell mix 17 ppg cement Pumping 17 Ppg cement (yield 1 cuft/sx, water 3,87 gallsx, add(lives D046.2%BWOC. D065 1.0 BWOC, D167 ,2 BWOC, thickening time 5 hr 26 min) @ 4.7 bpm w/ 860 psi Initial pressure and 4.3 bpm w/ 600 psi final pressure. Pumped a total of 84.2 bbis, 473 sx, follow wl 3.6 buts (2.6 bbls in the pipe) of 11.5 ppg mud push. Rig displace w/ 9.6 ppg LSND mud pumping 6 bpm fill caught up w/ cement. Tole 13 hints to catch cement. Reduced rate to 4 bpm w/ 22D psi. Pumped 21.5 buts to balance cement (cut 5 MIS shod). Shun dawn. check vaNas and well balanced. Full returns through -out job. Shut dot ni @ 0012 firs 41M012. 7,344.0 7,744.0 3,947.3 4,094.2 Cement P1 3/4/2011 Isolate Oannik Reservoir 1 ,207.0 13,651.6 6,181.E 6,394.3 Cement Plug 3142011 Isolate Nechebk Reservoir Notes: General & Safe End Date Annotation 318.'20I 1,401E: WELL SUSPENDED, INTERMEDIATE CSG PULLED & KILL STRING SET U���������� �����������^� Purposed ~ Schematic �D3_1 27 Neche|'k/KUap[uk Production Well Completion Lencith� 1)Tubing Hanger Packer Fluid mix: 2)4'y,"12.O#1ft|8T'ModTubing (2]is).XO 62' Inhibited Kill weight 3)3'1/2'8.3#/ft L'00EUE'MndTubing 4>CumcoTRMAXX'5ESSSV(2812^ID) 4.5' with 2000'TVD with control line tosurface. diesel cap s>3-1/2"x1^Carrico KBMGGUNw0JCK'2V0^> 7.1' Pinned for 250Opsi casing to(hgshear d 6)3-1/2"x1^ComouKBMGOLMn/DV(68^) 7.1' Surface Casing 7> Camoo KBMGGLk8 (2.867^ ID) wYDV(O0^) 7.1' `=--4- --� 245- 8) SLBBHPGau0o.Enoapou|ated|'VWre cemented hosurface n/mannonclamps onevery joint 1.5' S} 3'Y,"X7'50^Baker Premier Packer 10.8. 103'1/2"xi^Carrico K8MGGLMmlDV(08l 71' 11}8'y2"8.3Hyd5V3with 25' 31' . h|a�hngn&cmouonv�ing T0C+�8974 K�D . 12) Baker ''X^CMD0idingSleeve 2.813^ 1.5 C\mnnik|nhen/o| 13} HEG2.818^XProfile 1.5' Top+/- 7474'NYD/ 4019'TVD 14) Seal assembly (79^) 10, | ES�emenher��7U74'K�O / Lencith 15) Baker 5^x7-5/8^ZXPLiner top packer 12.2' 16) Baker 5'i/2^vz5/8^F|exkmkLiner Hanger wboVingsleeve and 4.0'PBR 9.8' 17) X05'1/2' Hydh| 521 X3'y2" GLHT 1.5' 18) Bake Seal Bore Extension 10.01 19> 3'1/2'9.3#/hL80 8LHTblank & fraosleeves/swell packers 20}Baker P'8|ooveGL ���' 21)Baker Well Isolation Valve (VV|V) 27 22)Guide Shoe 1.5' 3'1/2''93ppfL80EUEM tubing run with Jet Luba Run'n'Gonl pipe dope Top NuparukC�� 1'48'/@D/6.829'TVD -- — ---------- TupNoche|ih 1,098K8D/6.074'TVD TOC Calculated -15'Pedonmion» run mom Casing at 15078'MD/6985'TVD CD3 — 127 Sundry Application CD3 -127 had its top hole completed in April of 2012 as horizontal producer in the Nechelik formation and will be re-entered in Jan 2013 to finish the well. The well will be completed with 3.5" tubing and a 4.5" liner with 8 ball actuated sliding sleeves and swellable packers between each sleeve. We will drop a ball (progressively getting larger) after each stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. We expect the increased production to be 150 bpd in 2013 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Nechelik Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 19 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 1000 F seawater (approx. 8400 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 300 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ]SIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7750 psi. Stage 1 • 280 bbls YF125FX-D Pad • 80 bbls YF125FX-D w/ 1 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 200 bbls YF125FX-D w/ 3 ppa 16/20 Carbolite • 320 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Drop ball 1 Stage 2 • 280 bbls YF125FX-D Pad • 80 bbls YF125FX-D w/ 1 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 200 bbls YF125FX-D w/ 3 ppa 16/20 Carbolite • 320 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Drop ball 2 Stage 3 • 280 bbls YF125FX-D Pad • 80 bbls YF125FX-D w/ 1 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 200 bbls YF125FX-D w/ 3 ppa 16/20 Carbolite • 320 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Drop ball 3 Stage 4 • 280 bbls YF125FX-D Pad • 80 bbls YF125FX-D w/ 1 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 200 bbls YF125FX-D w/ 3 ppa 16/20 Carbolite • 320 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Drop ball 4 Stage 5 • 280 bbls YF125FX-D Pad • 80 bbls YF125FX-D w/ 1 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 200 bbls YF125FX-D w/ 3 ppa 16/20 Carbolite • 320 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Drop ball 5 Stage 6 • 280 bbls YF125FX-D Pad • 80 bbls YF125FX-D w/ 1 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 200 bbls YF125FX-D w/ 3 ppa 16/20 Carbolite • 320 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite Drop ball 6 Stage 7 • 280 bbls YF125FX-D Pad • 80 bbls YF125FX-D w/ 1 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 200 bbls YF125FX-D w/ 3 ppa 16/20 Carbolite • 320 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Drop ball 7 Stage 8 • 280 bbls YF125FX-D Pad • 80 bbls YF125FX-D w/ 1 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 200 bbls YF125FX-D w/ 3 ppa 16/20 Carbolite • 320 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 100 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Drop ball 8 • Flush with 144 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 800,000 Ibs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Foowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Cement Evaluation of CD3-127 and wells within % mile of CD3-127 C1133-117: 7" Casing two stage cement job was pumped on 3/24/2009 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 10 ppg mud. The plugs were bumped on both stages to 1100 psi and 2000 psi respectively, floats held. Full returns were observed during the job. CD3-117: 7 5/8" Casing two stage cement job was pumped on 2/23/2010 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 10 ppg mud. The plugs were bumped on both stages to 590 psi and 300 psi respectively, floats held. Full returns were observed during the job. CD3-128: 7" Casing two stage cement job was pumped on 2/23/2010 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 11.3 ppg mud. The plugs were bumped on both stages to 530 psi and 320 psi respectively, floats held. Full returns were observed during the job. Pop -ON Tank Stimulation Surface Rig -Up • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. PLV,OfY Tank Punp Truck Stimulation Tree Saver OPEN POSITION WELLHEAD VALVES CLOSED CLOSED POSITION FRAC IRON CONNECTION jj REMOTE OPERATED MASTER VALVt J, MANUAL OPIE9^TfD VASTER VALVE AANDRFL OVAD PACKOIFF ASSEMBLY IN PLACE IN TUBING Stinger VENT 41 VALVE OPEN • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 V2tubing and 1.75" down 3 V2tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm CD3- 127 Nechelik Multi -stage Frac Model Frac Design 1 stage Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (gal) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Pad 18.0 YF125ST 11760 25.0 0.00 1.0 PPA 18.0 YF125ST 3360 25.0 16/20 C-Lite 1.00 2.0 PPA 18.0 YF125ST 4200 25.0 16/20 C-Lite 2.00 3.0 PPA 18.0 YF125ST 8400 25.0 16/20 C-Lite 3.00 4.0 PPA 18.0 YF125ST 13440 25.0 16/20 C-Lite 4.00 6.0 PPA 18.0 YF125ST 4200 25.0 16/20 C-Lite 6.00 Flush 18.0 YF125ST 4930 25.0 0.00 Totals (8 stages) YF 125 FX-D - 8000 bbls WF 125 - 359 bbis 16/20 Carbolite - 793,136 Ibs Model Results Initial Fracture Top TVD - 6910.0 ft Initial Fracture Bottom TVD - 7050.0 ft Propped Fracture Half -Length - 280.0 ft EOJ Hyd Height at Well - 140. ft Average Propped Width - 0.21 in • Disclaimer Notice: — This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. C D 3 12 7 w p 11 Quarter Mile View WELLSORE TARGET DETAILS (M1'WP CC -ORDINATES) 11 • 59, February 05 2013 ry Name TVDSS +N/-S +E/-W Northing Easting Shape CD3-K i60ctT2 Toe 7030.00-9257.12 -6659.74 6994350.00 7521082.00 Circle (Radius: 1320.00) G G �� w GO 03;�ti GOg, G03 GOg• GOB' GO,y GOg• GOB, N r9 0- v9 �� -2500- 4C, 7 O CO3'12p O N-5000 , •tip ' Go,, � i ti0 G I O GQg'� � z -7500 I j O Nechelik 1 -10000 "XI i � GOB -12500 - Co2-466 -17500 -15000 -12500 -10000 -7500 -5000 -2500 0 2500 P-TD -01- oL Perguson, Victoria L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, February 04, 2013 10:12 AM To: Brunswick, Scott A Cc: Stinson, Rob D; Ferguson, Victoria L (DOA) Subject: RE: CD3-127 PTD 211-005 - Cement kick off plug required It must be Monday... I can't type or read properly. I am blaming the football game yesterday. Sorry Rob... Scott... FYI Victoria will be picking up most of the permitting for CPAI now. She is out today as she works a flex Monday schedule. Also, Sundry 312-101 is probably closed out so go ahead and include the added cement plugs in the final 10- 407 for the new sidetrack. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) SCANNED O C T 2 9 2014 From: Brunswick, Scott A unswick@conocophillips.coml Sent: Monday, February 04, 2013 9:58 AM To: Schwartz, Guy L (DOA) Cc: Stinson, Rob D Subject: RE: CD3-127 PTD 211-005 - Cement kick off plug required I'm unsure who Rod is. The cement plug was tagged and pressure tested both last year and this. We drilled competent cement down to -V3320 ft MD while steering for the sidetrack, where the cement simply disappeared (was not there anymore). Good solid cement existed from 3043 ft MD to 3320 ft MD, cement was supposed to be from 3043 ft MD to 3441 ft MD (the top of the ECP), lower 121 ft of cement and ECP were missing. Shoe was at 3239 ft MD. I'm going to go ahead and perform a two stage cement job this time to ensure there is a good firm bottom to set the final kick off plug on top of. We should begin pumping the first this afternoon. We did a clean out run yesterday to clean out to 4015 ft MD so that we could set another ECP in a higher shale content zone, then perform the two stage cement job that is planned. Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-263-4249 Cell: (907)-227-8499 From: Schwartz, Guy L (DOA) _nailto:guy.schwartz@alaska.gov Sent: Monday, February 04, 2013 9:48 AM To: Brunswick, Scott A Cc: Stinson, Rob D Subject: [EXTERNAL]RE: CD3-127 PTD 211-005 - Cement kick off plug required That's Rod for update... Setting a new kickoff plug is approved.. Was it not tagged last year when it was set ? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brunswick, Scott A ".-_:Scott. A.Brunswick@conocophillps.com Sent: Sunday, February 03, 2013 12:26 AM To: Schwartz, Guy L (DOA) Cc: Stinson, Rob D Subject: CD3-127 PTD 211-005 - Cement kick off plug required Guy We were drilling cement tonight attempting to sidetrack the CD3-127 wellbore off the cement plug that was set in 2012, at 3320 ft MD the ROP went to increased speeds indicating lack of cement, the ECP was set at 3441 ft MD last year, we tripped in to 3471 ft MD finding no cement, nor tagging the ECP. With the BHA that includes sources in the density/neutron tools in the BHA, we decided the least risk was to POOH and lay those tools down instead of tripping in further to locate the ECP. Our plan forward is to run a cement stinger tomorrow (Sunday), set another kick off plug, and sidetrack the well returning to the original permit to drill. Please advise if I may supply further information required. Thanks Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-263-4249 Cell: (907)-227-8499 Page 1 of 2 .01 '.. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, February 04, 2013 10:12 AM To: 'Brunswick, Scott A' Cc: Stinson, Rob D; Ferguson, Victoria L (DOR) Subject: RE: CD3-127 PTD 211-005 - Cement kick off plug required It must be Monday... I can't type or read properly. I am blaming the football game yesterday. Sorry Rob... Scott... FYI Victoria will be picking up most of the permitting for CPAI now. She is out today as she works a flex Monday schedule. Also, Sundry 312-101 is probably closed out so go ahead and include the added cement plugs in the final 10-407 for the new sidetrack. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Monday, February 04, 2013 9:58 AM To: Schwartz, Guy L (DOA) Cc: Stinson, Rob D Subject: RE: CD3-127 PTD 211-005 - Cement kick off plug required I'm unsure who Rod is. The cement plug was tagged and pressure tested both last year and this. We drilled competent cement down to -3320 ft MD while steering for the sidetrack, where the cement simply disappeared (was not there anymore). Good solid cement existed from 3043 ft MD to 3320 ft MD, cement was supposed to be from 3043 ft MD to 3441 ft MD (the top of the ECP), lower 121 ft of cement and ECP were missing. Shoe was at 3239 ft MD. I'm going to go ahead and perform a two stage cement job this time to ensure there is a good firm bottom to set the final kick off plug on top of. We should begin pumping the first this afternoon. We did a clean out run yesterday to clean out to 4015 ft MD so that we could set another ECP in a higher shale content zone, then perform the two stage cement job that is planned. Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-263-4249 Cell: (907)-227-8499 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] 2/4/2013 Page 2 of 2 Sent: Monday, February 04, 2013 9:48 AM To: Brunswick, Scott A Cc: Stinson, Rob D Subject: [EXTERNAL]RE: C133-127 PTD 211-005 - Cement kick off plug required Tbat's Rod for update... Setting a new kickoff plug is approved.. Was it not tagged last year when it was set ? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Sunday, February 03, 2013 12:26 AM To: Schwartz, Guy L (DOA) Cc: Stinson, Rob D Subject: CD3-127 PTD 211-005 - Cement kick off plug required Guy We were drilling cement tonight attempting to sidetrack the CD3-127 wellbore off the cement plug that was set in 2012, at 3320 ft MD the ROP went to increased speeds indicating lack of cement, the ECP was set at 3441 ft MD last year, we tripped in to 3471 ft MD finding no cement, nor tagging the ECP. With the BHA that includes sources in the density/neutron tools in the BHA, we decided the least risk was to POOH and lay those tools down instead of tripping in further to locate the ECP. Our plan forward is to run a cement stinger tomorrow (Sunday), set another kick off plug, and sidetrack the well returning to the original permit to drill. Please advise if I may supply further information required. Thanks Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-2634249 Cell: (907)-227-8499 2/4/2013 Schwartz, Guy L (DOA) From: Brunswick, Scott A [Scott.A.Brunswick@conocophillips.com] Sent: Monday, January 14, 2013 2:59 PM To: Schwartz, Guy L (DOA) Cc: Stinson, Rob D; Morrow, Dustin W Subject: RE: [EXTERNAL]RE: CD3-127 (PTD 211-005) Guy It is correct that we were planning to run 39 ppf casing the bottom -600 ft. The modeling we performed that steered us to choose the 39 ppf casing was for a scenario assuming absence of cement behind casing with pore pressure in the annulus. The failure case was during frac screen out. During the proposed hydraulic fracture treatment of CD3-127 the tri-axial and burst safety factors are below corporate design limits for the production casing. This would potentially eliminate the first of two barriers in the well at the production packer. The second barrier at the wellhead would not be effected by the potential failure of the casing around the production packer. The following safeguards will be in place to reduced the risk of a production casing failure: 1) a pressure relief valve will be utilized during the frac job to release pressure below the casing burst pressure, 2) the frac will be designed for minimum rate, 3) the shutdown pressure on treating side will be set as close as reasonable to treating pressure, 4) a data frac will be pumped before each frac to determine pad size to reduce the chance of screen out, 5) the propant loading will be kept as low as possible to reduce the chances of a screen out The probably off bursting the casing is considered rare. This was a qualitative assessment based on reasonable inquiries of well integrity engineers and stimulation engineers. Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-263-4249 Cell: (907)-227-8499 -----Original Message ----- From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, January 07, 2013 3:49 PM To: Brunswick, Scott A Subject: RE: [EXTERNAL]RE: CD3-127 (PTD 211-005) I assume the 29# will still meet your standard for quite awhile. The 39# was see frac pressure as I recall. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) Safety factor minimum? Seems like 29# has been the for just the very last section of liner that would -----Original Message ----- From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Monday, January 07, 2013 1:57 PM To: Schwartz, Guy L (DOA) Subject: RE: [EXTERNAL]RE: CD3-127 (PTD 211-005) It was for the burst case to meet our company safety factors. 1 Sent with Good (www.aood.com) -----Original Message ----- From: Schwartz, Guy L (DOA) [guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov>] Sent: Monday, January 07, 2013 04:36 PM Central Standard Time To: Brunswick, Scott A Subject: [EXTERNAL]RE: CD3-127 (PTD 211-005) Scott, No sundry required. I will update the well file with this email. Can you refresh my memory on why you were running heavy 7 5/8" in the intermediate section? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Monday, January 07, 2013 1:24 PM To: Schwartz, Guy L (DOA) Subject: CD3-127 (PTD 211-005) Guy Our 7-5/8" 39 ppf casing won't arrive in time for running on CD3-127 intermediate hole, therefore, to relieve ECD in the production we will change from drilling a 6-1/8" production section to drill a 6-3/4" hole. Is a sundry required for this change? Thanks Scott Brunswick Drilling Engineer Alpine Drilling Team Office.: (907)-263-4249 Cell: (907)-227-8499 [cid:image001.jpg@01CDECDB.94F7E7801 2 THE STATE F 0 ly, SMAW�Wb mvs"'�' GOVERNOR SEAN PARNELL C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: Colville River Field, Fiord Oil Pool, CD3-127 ConocoPhillips Alaska, Inc. Permit No: 211-005 (revised) Surface Location: 4022' FNL, 1185' FEL, SEC. 05, T12N, R5E, UM Bottomhole Location: 2721' FNL, 2623' FEL, SEC. 18, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated February 1, 2011. 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, a 1114,44 ____ Cathy . Foerster Chair -- DATED this / / day of December, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA AU OIL AND GAS CONSERVATION COMM N DEC 0 4 2012 PERMIT TO DRILL " 2 16111 gn AAA 9� nn� KEU151 on ILl111 Anil ,l 1 a. Type of Work: 1 b. Proposed Well Class: Development - Oil Service - Winj ❑ Single Zone ❑ 1 c. Specify if well is proposed for: Drill ❑ Redrill❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone Q • Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • CD3-127 • 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100369 Anchorage, AK 99510-0360 MD: 21969.49' • TVD: 7078.9' . Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 4022' FNL, 1185' FEL, Sec. 5, T12N, R5E, UM ADL 372105, 025538, 025526 Fiord Oil Pool - Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2434' FNL, 1800' FEL, Sec. 12, T12N, R4E, UM LAS2112 9. Acres in Property: ?10 9pZ 14. Distance to Nearest Property: Total Depth: 2721' FNL, 2623' FEL, Sec. 18, T12N, R5E, UM 0 7 f $0 3� ;e60 12.' ( +/- 4.0 miles to ADL 391451 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 48.9 , 15. Distance to Nearest Well Open Surface: x- 387857.4' y- 6003756.3' Zone- 4 • GL Elevation above MSL: 12.6 • to Same Pool: 1454.4' CD3-128i 16. Deviated wells: Kickoff depth: 3290 feet • 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.32 degrees r Downhole: 2945 - Surface: 2237 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) 24" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre Installed 13.5" 10.75" 45.5# L-80 BTC 3202' 35.9' 35.9' 3239' 2453' 1998.05 Ft3 Lead / 324.8 Ft3 Tail 9.875" x 11' 7.625" 29.7& 39# L-80 BTCM/HYD 15044.3 33.7 33.7 15078' 6985' 480 ft3 Shoe / 584 ft3 2nd stg Qaanik 3.5" 9.3# L-80 ELIE 30.7 30.7 Tubing 6.125" 3.5" 9.3# 1 L-8 ISLHT 1 121970' 7079' 1 Liner w/swell packers & SS f/Frac 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural 77' 16.0" Pre -Installed 114.0' 114.0' Surface 3202' 10.75" 1998.05 Ft3 Lead / 324.8 Ft3 Tail 3239' 2453' Intermediate Production Liner 2277.2' 4.5" None - Kill String 2300.3' 2091.44' Perforation Depth MD (ft): 14449 Perforation Depth TVD (ft): 6829 20. Attachments: Property Plat ❑ 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 2 1411'1 22. 1 hereby certify that the foregoing is true and correct. Contact Scott Brunswick @ 907-263-4249 scott.a. brunswick0conocophillips.com Printed Name C. Alvord Title Alaska Drilling Manager Signature A Ot Phone L,S'-- 6 I L. Date 12- q (C-3 Commission Use Only Permit to Drill API Number: 1 I Permit Approval See cover letter for other Number: a O S 50- / 03 - 0(a3y - 00 - oo Date: ,\ requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: x--3 'oo P 5j /S& i' Gi s Samples req'd: Yes ❑ No [� Mud log req'd: Yes ❑ No [� v HZS measures: Yes ❑ No [Z Directiona_l_svy req'd: Yes 17f No ❑ '� F �7' .) n APPROVED BY THE COMMISSION DATE: / Z - 12-1 Z 1S i-- , COMMISSIONER Form 10-401 (Revised 7/2009) 5 � This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) p- Submit in Duplicate RECEIVED DEC 0 42012 November 281h, 2012 AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-127 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD3 (Fiord) pad. The intended spud date for this well is January 10th, 2013. It is intended that Doyon Rig 19 be used to drill the well. CD3-127 was first drilled in February of 2011 (PTD 211-005), however, due to issues running the 7-5/8" casing, the 7-5/8" casing was pulled, zonal isolation plugs were set, and it was suspended for future completion of the drilling program (Operational Shutdown Sundry 311-065). During the CD3 season of 2012 ConocoPhillips re-entered the CD3-127 wellbore under Sundry 312-101, set an ECP and laid in a kick off plug for re -drill operations for the 2013 winter operations (Operational Shut Down Sundry 312-166). _/ Nd°'� yQ���o►Y Once the campaign of 2013 is under way and after setting 7-5/8" intermediate casing, the horizontal section will be drilled in the Nechelik reservoir. The well is currently planned to produce from both the Nechelik and Kuparuk formations after finding quality pay in the Kuparuk when the intermediate of CD3-127PB1 was first drilled in 2011. The lower Nechelik completion will consist of 3-1/2"blank liner with ball actuated frac sleeves; the Kuparuk completion will consist of a Baker CMD sliding sleeve with a packer above and below, the upper completion will be 3-1/2" tubing anchored into the top packer. The well will be flowed back to mitigate reservoir damage and then hooked up to begin production. • It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. Please find attached the information required by 20 ACC 25.006 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 or Rob Stinson at 263-4449. Sincerely, Scott Brunswick Drilling Engineer Attachments cc: CD3-127 Well File / Sharon Allsup Drake ATO 1530 Rob Stinson ATO 1700 Lanston Chin Kuukpik Corporation App i for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 CD3-127 Application for Permit to Drill Document Wiling &Wells ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25. 005 (/))............................................................ 3 2. Location Summary (Requirements of20AAC25.005(c)(2))............................................ 3 Requirements of 20 AAC 25.050(b)............................................................................................................. 4 3. Blowout Prevention Equipment Information (Requirements of20AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) ........................ 4 ASP CALCULATIONS.................................................................................................... 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c) (5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of20AAC 25.005(c)(6))................... 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) ......................... 6 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)).................................... 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))......................................... 7 It. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ........................ 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))................................... 7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) ......................... 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ..................... 11 (Requirements of 20 AAC 25.005(c)(14))........................................................................... 11 CD3-127 APD Page 1 of 17 Printed: 4-Dec-12 App n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 15. Attachments............................................................................................................. 11 AttachmentI Directional Plan................................................................................................................ 11 Attachment 2 Drilling Hazards Summary ................................................................................................. 11 Attachment 3 Well Schematic.................................................................................................................. 11 Attachment 4 Cement Summary ............................................................................................................... 11 CD3-127 APD Page 2 of 17 Printed. 4-Dec-12 Apr n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 1. Well Name (Requirements of 20 AAC 25.005 69) The well for which this application is submitted will be designated as C133-127. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a Nechelik and Kuparuk producer. The well will be drilled after pulling the tubing kill string and preparing the well. Location at Surface 4023' FNL, 1185' FEL, Sec 5, T12N, R5E, UM NAD 1927 Northings: 6,003,756.30' Eastings: 387,857.40' RKB Elevation 48.9' AMSL Pad Elevation 12.6' AMSL Location at top of Kuparuk productive horizon 1828' FNL, 1784' FEL, Sec 12, T12N, R4E, UM Nad 1927 Northings: 6,000,838.30' Eastings: 377,162.63' Measured Depth, RKB: 14,448.41' Total Vertical Depth, RKB: 6,828.90' Total Vertical Depth, SS: 6,780.00, Location at top of Nechelik productive horizon 2434' FNL, 1800' FEL, Sec 12, T12N, R4E, UM Nad 1927 Northings: 6,000,233.80' Eastings: 377,137.20' Measured Depth, RKB: 15,077.16' Total Vertical Depth, RKB: 6,984.91' Total Vertical Depth, SS: 6,936.01' Location at Total Depth 2721' FNL, 2623' FEL, Sec 18, T12N, R5E, UM Nad 1927 Northings: 5,994,603.05' Eastings: 381,029.89' Measured Depth, RKB: 21,969.49" Total Vertical Depth, RKB: 7,078.90' Total Vertical De th, SS: 7,030.00' CD3-127 APD Page 3 of 17 Printed: 4-Dec-12 Apr n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP schematics on file for Doyon 19. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD(ft) Fracture Gradient (lbs. / al) Pore pressure (psi) ASP Drilling (psi) 16 114 / 114 10.9 52 53 10-3/4 3239 / 2453 14.5 1109 1604 7-5/8 15078 / 6985 12.5 2906** 2237 N/A 21970 / 7079 12.5 2945 * * N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. • ** NOTE: Pore Pressure is estimated reservoir pressure PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP — (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052) — 0.1 ] D = [(14.5 x 0.052) — 0.1 ] x 2453 = 1604 psi OR ASP = FPP — (0.1 x D) = (.052*6985*8.0) — (0.1 x 2453') = 2661 psi 2. Drilling below intermediate casing (7-5/8") CD3-127 APD Page 4 of 17 Printed: 4-Dec-12 App n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 ASP = Reservoir Pressure — (0.1 x D) = (.052*7079'*8.0) — (0.1 x 7079') = 2237 psi (B) data on potential gas zones; Please see Attachment 2 - Drilling Hazards Summary (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking, Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20 AAC 25.005 (c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of20AAC25.005(c)(6)) Existing Casing as of November 2012: Casin and ementing Program— xisting As of This PTD Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Conn. (ft) A (ft) Cement Program Driven 16 24 62.5 H-40 Welded 114' Surf 114'/114' Cemented to Surface with 10 3/4" 13 1/i" 45.5 L-80 BTC 3202' Surf 3239/2453' 324.8 ft3 15.8 ppg Class G Tail & 1998.05 ft3 AS 3 Lite 10.7 ppg Lead C133-127 Completion casing and cementing program: Casing and Cementing,Program Hole Top Btm CsglTbg Size Weight Length MD/TVD MD/TVD OD in in Ib/ft Grade Conn. ft (ft) ft Cement Program Driven 16 24 62.5 H-40 Welded 114' Surf 114'/114' Cemented to Surface with 10 3/4" 13 1/2" 45.5 L-80 BTC 3202' Surf 3239/2453' 324.8 ft3 15.8 ppg Class G Tail & 1998.05 ft3 AS 3 Lite 10.7 ppg Lead 9 7/8" Qaanik 2nd stage cement with 480 ft3 7-5/8 x 11" 29.7 L-80 BTCM 14432' Surf 14467/6836' 15.8 ppg Class G, Shoe cement with 584 ft3 15.8 ppg Class G Qaanik 2nd stage cement with 480 ft3 7-5/8" 9 7/8' 39 C110 HYD56 578' 14467/6836' 15078 /6985' 15.8 ppg Class G, Shoe cement with 584 x 11" 3 ft3 15.8 ppg Class G Liner w/swell packers & SS f/Frac 31/2" 61/8" 9.3 L-80 SLHT 6970' 14500'/6847' 21970'/7079' Tubing, single selective Kuparuk 3 1/2" 9.3 L-80 EUE 15000' Surf 15000'/6959' completion w/sliding sleeve, 3-1/2" Pilo across Kuparuk interval CD3-127 APD Page 5 of 17 G 4-Dec-12 E, App n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 7. Dlverter System Information (Requirements of20AAC25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h) (2) is granted. At CD3, there has not been a significant show of shallow gas or gas hydrates. Surface hole has been drilled, cased, and cemented previously. The BOP stack will be rigged up during CD3-127 2013 operations. 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Drilling will be done using mud systems having the following properties: A WBM mud system will be used to drill the 9-7/8" x I I" hole section. A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 9.8 ppg to minimize losses, and lost circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be beneficial in maintaining wellbore stability. MW may be increased to 10.0 ppg for tripping. LSND Mud 3239'—15078' Density (ppg) 9.8 - 10.0 Yield Point (cP) 13 - 22 Plastic Viscosity (cP) 10- 16 Initial Gels 8- 10 10 minute gels </= 20 API filtrate < 8 cc/30 min A WBM mud system will be used to drill the 6-1/8" hole section. The horizontal production interval will be drilled with a MI Swaco's Flo-Thru drill -in fluid. The base fluid will consist of 3% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. Klagard will be used for inhibition. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. Flo-Thru Mud 15078' — 21970' Density (,ppg) 8.8 — 9.0 - Yield Point (cP) 10 - 15 Plastic Viscosity (cP) 7 - 12 Initial Gels 6-9 10 minute gels 8 — 12 API filtrate < 10 cc/30 min Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. CD3-127 APD 3 Page 6 of 17 Printed: 4-Dec-12 Apr n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Well Schematics. 1. See Sundry to shut down operations on CD3-127 312-166. 2. Move & Rig up Doyon 19 rig onto well. 3. Check 10-3/4" casing & tree for pressure. 4. Prepare 9.8 ppg LSND mud. 5. Test tree to 5,000 psi for 10 minutes. 6. Pump down annulus testing casing and BPV in direction of flow to 2,000 psi for 10 minutes. s 7. Rig up and test lubricator to 2,000 psi for 5 minutes. 8. Remove the BPV. 9. Circulate out the diesel freeze protect swapping to 9.8 ppg brine. 10. Check well for flow, monitor for 30 minutes. 11. Install TWC & test in direction of flow to 1,000 psi for 10 minutes. 12. Nipple down the tree. 13. Nipple up BOPE. 14. Perform full BOPE test to 250/3500 psi (250/2500 psi on the annular) using 5" & 4'h" test joints. 15. Pull the TWC. 16. Pull and lay down the tubing kill string. 17. Install wear ring into wellhead. 18. Pick up and rack back all 5" drillpipe needed to drill the intermediate hole section. 19. Make up the directional BHA to include RSS, MWD, GR/RES/PWD, & 11" WTI Reamer. 20. Test the WTI reamer on surface to ensure activation and deactivation functions. 21. Stage in the hole circulating and conditioning the mud every 1,000 ft, or more frequently based on company representatives observation and discretion. 22. Once cement is tagged, close the top pipe rams and test the casing to 3,500 psi for 30 minutes. 23. Chart and send in the pressure test. 24. Polish off and drill cement down to kick off point. 25. Swap 9.8 ppg brine to 9.8 ppg LSND. 26. Circulate and condition mud until even in and out. CD3-127 APD Page 7 of 17 t " 9 Printed. 4-Dec-12 Apr n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 27. Monitor well for flow for 30 minutes. 28. Begin kicking off the well per directional driller and company representatives' instructions. 29. Sidetrack below the existing surface casing shoe with the 9 7/8" x I I" RSS Drilling BHA (LWD Program: GR/RES/P WD/DEN SITY/NEUTRON/SONIC). 30. Drill out 20' of new hole. Perform LOT, stop @ 18 ppg if no leak off point is achieved. Minimum required is 12.5 ppg EMW. ✓ 31. Drill ahead with 9.8 ppg LSND. 32. Drill enough rat hole to clear the reamer at minimum 10 feet outside the surface casing shoe. 33. Pull reamer back into shoe to test overpull before dropping RFID activation chips. 34. Place reamer back outside surface casing shoe. 35. Drop the RFID chips to activate the reamer. 36. Ream and condition the hole for proper reamer function. 37. Perform pull test to check reamer activation. 38. Drill the 9 7/8" x I I" hole to 300 ft below the Qannik formation. 39. CBU X3. 40. Drop RFID chips to close the reamer. 41. Perform short trip out of hole, stopping once RSS is within 30 ft of the surface shoe. 42. Trip back in hole. 43. Ream down last two stands. 44. Circulate and condition mud once back to bottom. 45. Drop RFID chips to re -activate the reamer. 46. Drill ahead in the 9 7/8" x I I" hole to just above the HRZ. 47. CBU X3. 48. Drop RED chips to close the reamer. 49. Perform short trip out of hole, stopping once RSS is within 30 ft of previous short trip beginning depth. 50. Trip back in hole. 51. Ream down last three stands. 52. Circulate and condition mud once back to bottom. 53. Treat the active system with wellbore stability mud additives prior to drilling into the HRZ. 54. Drop RED chips to re -activate the reamer. 55. Drill 9 7/8" x I I" hole to total depth. 56. After TD, circulate hole clean with 4 BU a. A quadrant ream with the RSS may be performed based on the company representative discretion. The purpose of the quadrant ream is to open up the rat hole from the reamer to the bit, 57. Drop the RFID chips to close the reamer. 58. Weight up the system to 10.0 ppg for trip margin. 59. Pump out of hole to the top of the HRZ. 60. Trip back to bottom. CD3-127 APD Page 8 of 17 Printed: 4-Dec-12 Apr n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 61. Pump out of the hole to the top of the HRZ while spotting a casing running pill with 3% lubes. 62. POOH with directional BHA, download data, and lay down same. 63. Swap top rams to 7-5/8" solid body rams and test same 250/3500 psi. 64. Rig up 7 5/8" casing running equipment, prepare a 4'/z" IF B X 7 5/8" BTCM Pin and make up with TIW valve for well control purposes. 65. Pull wear bushing and install casing running sleeve. 66. RIH to TD filling pipe regularly based on company representatives schedule. 67. Rig up cement equipment and test to 3500 psi. 68. Pump I" stage cement job placing the cement top at a minimum 500 feet above Kuparuk & Nechelik formations, secondly 300 ft minimum above the packer setting depth on subsequent liner run. 69. Prior to bumping the plug land the casing on the hanger. 70. Pump 2nd stage cement job. Cement will be placed 500 feet above the top of the Qaanik sand. 71. Lay down 7 5/8" landing joint. 72. Remove casing running ring and install the 7 5/8" pack off. 73. Test pack off to 5,000 psi for 10 minutes. 74. Swap out the 7 5/8" solid body rams for 3 '/2" x 6" VBR. 75. Perform full bi-weekly BOPE test to 250/3500 psi, 250/2500 psi on the annular. Test with 3 '/2" & 4" test joints. 76. Install wear bushing. 77. Perform a leak off test down the 11" x 7-5/8" casing annulus to confirm the fracture pressure referenced to the surface casing shoe. a. Ensure a minimum wait on cement time of 6 hours has passed before performing the backside LOT and freeze protecting. 78. Freeze protect the I I" x 7-5/8" casing annulus. 79. Lay down 5" drillpipe. 80. Make up clean out BHA and single in hole with 4" drillpipe. 81. Before tagging the stage collar, pressure test casing integrity above the collar to 1,000 psi for 10 minutes. 82. Drill out stage tool equipment. 83. Perform casing pressure test after drilling out stage equipment to 3,500 psi for 10 minutes. 84. POOH and lay down clean out BHA. 85. Pick up remaining 4" drillpipe. 86. Pick up the 6 1/8" RSS Directional BHA (LWD Program: GR/RES/PWD/DENSITY/NEUTRON). 87. TIH with the drilling BHA. 88. Tag up on cement. 89. Displace 9.8 LSND fluid in hole with fresh 8.8 - 9.0 ppg Flo-Thru with 3% lubes. 90. Pressure test casing to 3500 psi for 10 minutes. Chart and send in. 91. Drill out cement and shoe track. 92. Drill out 20' of new hole. CD3-127 APD Page 9 of 17 Printed:4-Dec-12 Apr n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 93. Circulate and condition mud until even in and out. 94. Perform leak off test. Minimum leak off point required is 11.0 ppg EMW. 95. Drill to TD utilizing LWD for geosteering. 96. Once TD is reached, CBU x 4 while standing one stand back every hour. 97. Monitor the well for flow after CBU x 4. a. Be aware that past Nechelik wells have "breathed" during lateral drilling operations. If the well is flowing back due to this phenomenon, do not continue tripping operations until it is firmly established the well is breathing and flow rate back is decreasing. Perform an exhale test if necessary and contact the drilling superintendent. 98. Pump out of the hole pulling 5 to 6 stands per hour. 99. Once bit is inside the intermediate casing, CBU x 1 and monitor the well for flow. 100.POOH, ensuring hole is taking proper fluid every stand during trip. 101.Lay down the directional BHA. 102.Rig up to run completions. 103.Prepare a 4" XT 39 B X 3 '/2" SLHT Pin and make up with TIW valve for well control purposes. 104.Run lower completions to include: 3-1/2" SLHT blank with frac sleeve system, swell packers, liner top packer, and hanger. 105. Set liner top packer and release running tools. 106.POOH and lay down running tools. 107.Rig up wireline. 108.Run in hole with TCP perforating guns. 109.Perforate the Kuparuk zone with wireline. 110.POOH and rig down wireline. I I I.Pick up clean out BHA with magnets and perform clean out run. 112. Scrape perforations and packer setting area. 1 l3.POOH and lay down clean out BHA. 114.Prepare a 4" XT 39 B X 3 '/2" EUE Pin and make up with TIW valve for well control purposes. 115.Run the upper completions to include: 3-1/2" EUE 9.3 ppf, L-80 tubing with SSSV, 4 x gas lift mandrel, Carrico KBMG GLM w/DCK2 pinned for 2500 psi casing to tubing shear, packer, sliding sleeve, landing nipple, and seal assembly. 116. Sting in, space out. 117.Drop ball and rod on RHC plug. 118. Set two packers and pressure test tubing to 4000 psi. 119.Shear assembly above PBR on upper packers. 120.Pick up seal assembly out of PBR. 12 1. Circulate inhibited packer fluid. 122.Run in lock down screws. 123.Back out landing joint. CD3-127 APD Page 10 of 17 r, z Printed. 4-Dec-12 App n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 124.Drop ball and rod. 125.Pressure test tubing and annulus to 3,500 psi for 30 minutes. 126.Bleed down the tubing to 2,000 psi and pressure test the annulus to 3,500 psi for 30 minutes. 127.Bleed down the tubing pressure to 0 psi to shear the casing to tubing DCK-2 SOV. 128.Bleed the tubing and annulus pressure to 0. 129.Land tubing hanger. 130.Pressure test tubing hanger seals 250/2500 psi for 10 minutes. 131.Install the two way check valve and pressure test through the SOV to 2,500 psi for 10 minutes in the direction of flow. 132.Nipple down the BOPE. 133.Nipple up the tree. 134.Pressure test tree to 5,000 psi. 135.Remove the two way check valve with lubricator. 136.Circulate sufficient diesel to fill the tubing plus provide 2000 ft TVD of diesel freeze protection on the annulus. 137.Set Back Pressure Valve & test in direction of flow. 138.Secure well. 139.Rig down and move off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) CD3-114 was originally permitted for annular disposal in February 2010 (approval number 310-037) and had a total of 32,000 bbls of fluid injected under that permit. The well was permitted for additional volume in March 2012 for a total capacity of 70,000 bbls (PTD 207-033 Approval Number 312-088). To ensure total disposal volumes stay within the permitted values, plan to stop injecting at 67,000 bbls. The total injection volume as of April 23`d, 2012 was 32,025 bbls. The permit was extended in March 2012 with an expiration date of 3/22/2013. The surface casing FIT was 16.4 ppg EMW with the casing shoe at 2,485' TVD. Annular LOT was 14.2 ppg EMW. The maximum allowable pressure at the surface casing shoe is equivalent to 2,119 psi. If annular injection exceeds allowable volume/time, or pressures exceed the maximum allowable injection pressure for the fluid pumped, then freeze protection will be pumped and the well no longer used for annular injection. If unable to inject down the annulus, dispose of waste into the class I disposal well at CDl-01A. Refer to the Alpine Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Attachments Attachment I Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary CD3-127 APD Page 11 of 17 Printed. 4-Dec-12 s' App n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 Attachment 1— Directional Plan CD3-127 APD Page 12 of 17 a f I Printed: 4-Dec-12 ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-127 Plan: CD3-127 Plan: CD3-127wp11 Changed hole sizes, and minor risked Nechelik 1 and CD3-127PB1. Corrected tie-in error due to glitch in Compass. Standard Proposal Report 03 December, 2012 'permit Pal C"k ' ' HALLIBURTON Sperry Drilling Services Easting (5000 ftlin) _ rn 13:17, December 03 2012 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD 1W3-130wp03 CD3-109 C 3-106 CD3- dip?-108 CD3- 10 CD 1STM (Rig Surveys) CD3-1 L1 3 C 1 CD3- 1 CD3-3 CD3-1 CD3-107 CD3-11 CD3-30 A D3-30 1 CD3-1 C -30 CD3- &D3- 5 CD3-316Bwp01 3- M%0 CD3-307 CD3-12 CD3-1 CD3- PB1 Nigh 1A CD3-303 iq - CD3-31 3-198 CD3- CD3-199 CD3-121 CD3-304 CD3-30 3iA1pwp03 CD3-122 3-305 CD3-123 CD3-125 CD3-320wp09 N helik 1 CD3-128 CD3-127wp11 CD3-126wp04 CD3-129wp01 CD2-466 CD2-462wp05 CD2- 68 Easting (5000 ft/in) ConocoPhi I I i Project: Western North Slope CO3-127wp11 ps Welibo ele PIDan: CD3122'7 Alaska OD &0 6:4 ih Ap�h,Wda u�a Y n1 Vdi swih bw, urger vdLt with Iwv,orium D01 BA -SA Lwg walls with rda0vdy,atuws polies ,Mu°us pof"!Mtn a high Agree of tli8iwlty DDI = 7.263 HALLIBURTONREFERENCE INFORMATION S-aaL°e0°n C° d,,- (WE) Rdo,.nm: W W CD3127, True North Vertical (TVD) Reference: Ran: 38.3�12.8 ®46.BOII ((Doyon 19) Section (VS) Refermca: Sb, - (O.00N. 0.00E) Cakvla,ion Melh Minimum Curve ure Ged0c Zane: Alaspe Zone 4 Northing 8003504.46 Eastinp 1527889.34 GrwM Lase) 12.60 U,gd,M 150M7O.M$W ----- ;Merry OrMing 13:2q, December 03 2012 Geaa40c Darum: NOOK American Dalum 1983 CASING DETAILS SURVEY PROGIVM TVD TVDSS MD Name Sim 2453A5 2404.95 3239.62 1"4 103/4• 89N.90 8538.00 1507&OS 74/8 7.&r X1 7/8 to 11� 707&90 7030.00 21970.15 31/2 312•x31/C A.30 47&30 CD1127PB1 Ow RI00)ICIXt-127PDI) CB-0171695 51&&t 3202.56 CD}127PB1 iNW ((CD}127PB1) MWDriR•AK4:I1L 330&93 3290.N CD}127FSI IR200 (D0}1Z7PB1) MWDWRAK4; Nano TVDSS C034 i8Q412 Toe 7030.00 -9: Sec MD Inc " TVD TVDSS MS 1 3290.00 68.64 263.77 2472.05 2423.15 -41.41 •1; 2 3330.00 67.95 263.34 2486.84 2437.94 45.59 -1f 3 3360.00 67.50 262.49 2498.21 2.9.31 -49.01 .11 4 3760.00 68.02 249.54 2650.17 Mot 27 .138.32 It 5 112.51 6&42 261.00 2848.35 27"AS-263.73 .24 6 11840./t 6&42 261.00 %25.00 %76.10-1361.68 .91 7 13589.35 59.69 192.63 6470.00 6421.10-2318.31 -1W 8 139M W 66.60 192.63 W26A0 07.10 •2618.91 •1W 9 '4370.42 66.60 192.63 6199.w 6750.10 J008.97 -IN 10 15078.05 83.11 17319 6984.90 6,36.00 4685.32 -IN 11 15098.05 83./1 173.29 6987.30 6938.40 4705.04 -IN 12 15287.15 89.32 468.96 6999.78 6950A8 -91.33 AN 13 15952.W 89.32 142.36 7007.80 6958.90 4491.62.101 14 21970.15 89.32 142.36 7079.90 7030.00 4257.12 41 -7500 500 C-30 o C20------ 0 N_ L a 0 K-3 K-3 Basal j Basal K-2 C7annik (K-2) d F- 500D Albian 97 Abian 96 CCS_Sh_AbV-HI�_sh Abv_HRZ bad Base HRZ/fo� Up.. NEC 7Sg�qRSUP . CU Top KupCrop- Kup_D/Base Top_ - -7500 -500 1 1 40000 .7500 5000 .2500 0 CD3-127wpl 1 Plan View o� 0 o 0 0 0 0 0 0 0 0 0 0 0 0 10 3/4" 0 0 -1500 o 0 0 0 p o 0 �00 O 74000 c 3000 w J l 15000 7-5/8" X 9-7/8 to 11.... o L 60 ,±�4500 1 z 1000 1 00 N 6000 100 00 00 i 1 -7500 �0000 O 3-1/2" x 6-1/8" `L1OO '11�1Q -9000 �1�10 _ _T __ ______T -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 West( -)/East(+) (1500 ft/in) I 1500 �s. o o LO L 3000 a �. as aD 0 c c � U 4500 m 6000 7500 CD3-127wpl 1 Section View M.- o `D 0 v CD o r- 0 0 0 h c� oo o0 CD rn T r T T T 09- N N N Q Cm 7-5/8" X 9-7/8 to 11"° 3-1/2" x 6-1/8" C� 0 -6000 -4500 -3000 -1500 0 1500 3000 4500 6000 Vertical Section at 145.000 (1500 ft/in) ' w Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wpl1 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well CD3-127 TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope 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 CD3 Fiord Pad Site Position: Northing: 6,003,886.80ft Latitude: 70° 25' 10.481 N From: Map Easting: 388,488.10ft Longitude: 150° 54' 30.391 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: -0.86 ° Well CD3-127 - _-- Well Position +N/-S 0.00 ft Northing: 6,003,757.25ft Latitude: 70° 25' 9.114 N +E/-W 0.00 ft Easting: 387,857.43 ft Longitude: 150° 54' 48.827 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore Plan: CD3-127 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 12/3/2012 15.43 79.87 57.352 Design CD3-127wp11 Audit Notes: Version: Phase: PLAN Tie On Depth: 3.290.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 36.30 0.00 0.00 145.00 Plan Sections 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) (°/100ft) (°/100ft) (°) 3,290.00 68.64 263.77 2,472.05 2,423.15 -41.41 -1,577.26 0.00 0.00 0.00 0.00 3,330.00 67.95 263.34 2,486.84 2,437.94 -45.59 -1,614.19 2.00 -1.73 -1.08 -150.00 3,360.00 67.50 262.49 2,498.21 2,449.31 -49.01 -1,641.73 3.00 -1.49 -2.81 -120.00 3,760.00 68.02 249.54 2,650.17 2,601.27 -138.32 -1,999.99 3.00 0.13 -3.24 -90.00 4,292.51 68.42 261.00 2,848.35 2,799.45 -263.73 -2,477.22 2.00 0.07 2.15 90.00 11,840.41 68.42 261.00 5,625.00 5,576.10 -1,361.68 -9,409.43 0.00 0.00 0.00 0.00 13,589.35 59.69 192.63 6,470.00 6,421.10 -2,318.31 -10,481.59 3.50 -0.50 -3.91 -113.70 13,934.86 66.60 192.63 6,626.00 6,577.10 -2,618.91 -10,548.94 2.00 2.00 0.00 0.00 14,370.42 66.60 192.63 6,799.00 6,750.10 -3,008.97 -10,636.34 0.00 0.00 0.00 0.00 15,077.08 83.07 173.34 6,984.90 6,936.00 -3,684.34 -10,667.01 3.51 2.33 -2.73 -51.45 15,097.08 83.07 173.34 6,987.31 6,938.41 -3,704.06 -10,664.70 0.00 0.00 0.00 0.00 15,287.50 89.32 168.98 6,999.96 6,951.06 -3,891.65 -10,635.49 4.00 3.28 -2.29 -35.00 15,952.81 89.32 142.36 7,007.97 6,959.07 -4,492.39 -10,363.85 4.00 0.00 -4.00 -90.15 21,969.49 89.32 142.36 7,078.90 7,030.00 -9,256.53 -6,689.83 0.00 0.00 0.00 0.00 121312012 2:33:56PM Page 2 COMPASS 2003.16 Build 69 HALLIBURTON Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wpl1 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (ft) (°) (°) (ft) ft 3,290.00 68.64 263.77 2,472.05 2,423.15 KOP: DLS 2.00 TFO -150.00 3,295.07 68.55 263.71 2,473.90 2,425.00 C-30 3,300.00 68.47 263.66 2,475.70 2,426.80 3,330.00 67.95 263.34 2,486.84 2,437.94 Start DLS 3.00 TFO-120.00 3,360.00 67.50 262.49 2,498.21 2,449.31 Start DLS 3.00 TFO -90.00 3,400.00 67.51 261.19 2,513.52 2,464.62 3,500.00 67.56 257.95 2,551.74 2,502.84 3,600.00 67.69 254.71 2,589.82 2,540.92 3,700.00 67.87 251.47 2,627.64 2,578.74 3,760.00 68.02 249.54 2,650.17 2,601.27 Start DLS 2.00 TFO 90.00 3,800.00 68.02 250.40 2,665.14 2,616.24 3,900.00 68.05 252.56 2,702.55 2,653.65 4,000.00 68.10 254.71 2,739.90 2,691.00 4,100.00 68.18 256.86 2,777.14 2,728.24 4,200.00 68.29 259.01 2,814.22 2,765.32 4,292.51 68.42 261.00 2,848.35 2,799.45 Start 7647.90 hold at 4292.51 MD 4,300.00 68.42 261.00 2,851.11 2,802.21 4,307.59 68.42 261.00 2,853.90 2,805.00 C-20 4,400.00 68.42 261.00 2,887.89 2,838.99 4,500.00 68.42 261.00 2,924.68 2,875.78 4,600.00 68.42 261.00 2,961.47 2,912.57 4,700.00 68.42 261.00 2,998.26 2,949.36 4,800.00 68.42 261.00 3,035.04 2,986.14 4,900.00 68.42 261.00 3,071.83 3,022.93 5,000.00 68.42 261.00 3,108.62 3,059.72 5,100.00 68.42 261.00 3,145.40 3,096.50 5,200.00 68.42 261.00 3,182.19 3,133.29 5,300.00 68.42 261.00 3,218.98 3,170.08 5,400.00 68.42 261.00 3,255.76 3,206.86 5,500.00 68.42 261.00 3,292.55 3,243.65 5,600.00 68.42 261.00 3,329.34 3,280.44 5,700.00 68.42 261.00 3,366.13 3,317.23 5,800.00 68.42 261.00 3,402.91 3,354.01 5,900.00 68.42 261.00 3,439.70 3,390.80 6,000.00 68.42 261.00 3,476.49 3,427.59 6,100.00 68.42 261.00 3,513.27 3,464.37 6,200.00 68.42 261.00 3,550.06 3,501.16 6,300.00 68A2 261.00 3,586.85 3,537.95 Conocoftillips Standard Proposal Report Local Co-ordinate Reference: Well CD3-127 TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Map Map +N/S +E/-W Northing Easting DLS Vert Section (ft) (ft) (ft) (ft) 2,423.15 -41.41 -1,577.26 6,003,739.54 386,279.86 1.88 -870.75 -41.93 -1,581.95 6,003,739.10 386,275.16 2.00 -873.03 -42.43 -1,586.51 6,003,738.66 386,270.60 2.00 -875.23 -45.59 -1,614.19 6,003,735.93 386,242.88 2.00 -888.52 -49.01 -1,641.73 6,003,732.92 386,215.28 3.00 -901.51 -54.25 -1,678.31 6,003,728.22 386,178.63 3.00 -918.20 -70.98 -1,769.18 6,003,712.87 386,087.53 3.00 -956.62 -92.83 -1,859.02 6,003,692.36 385,997.38 3.00 -990.24 -119.76 -1,947.57 6,003,666.77 385,908.44 3.00 -1,018.98 -138.32 -1,999.99 6,003,649.01 385,855.76 3.00 -1,033.85 -151.02 -2,034.84 6,003,636.83 385,820.72 2.00 -1,043.43 -180.48 -2,122.77 6,003,608.69 385,732.37 2.00 -1,069.73 -206.62 -2,211.77 6,003,583.90 385,642.99 2.00 -1,099.36 -229.41 -2,301.73 6,003,562.47 385,552.71 2.00 -1,132.30 -248.81 -2,392.55 6,003,544.43 385,461.62 2.00 -1,168.49 -263.73 -2,477.22 6,003,530.79 385,376.74 2.00 -1,204.84 -264.82 -2,484.10 6,003,529.80 385,369.84 0.00 -1,207.89 -265.92 -2,491.07 6,003,528.80 385,362.86 0-00 -1,210.99 -279.37 -2,575.94 6,003,516.64 385,277.80 0.00 -1,248.66 -293.91 -2,667.79 6,003,503.47 385,185.76 0.00 -1,289.42 -308.46 -2,759.63 6,003,490.31 385,093.71 0.00 -1,330.18 -323.00 -2,851.47 6,003,477.15 385,001.67 0.00 -1,370.95 -337.55 -2,943.31 6,003,463.98 384,909.63 0.00 -1,411.71 -352.10 -3,035.16 6,003,450.82 384,817.58 0.00 -1,452.47 -366.64 -3,127.00 6,003,437.65 384,725.54 0.00 -1,493.24 -381.19 -3,218.84 6,003,424.49 384,633.50 0.00 -1,534.00 -395.74 -3,310.69 6,003,411.33 384,541.46 0.00 -1,574.76 -410.28 -3,402.53 6,003,398.16 384,449.41 0.00 -1,615.53 -424.83 -3,494.37 6,003,385.00 384,357.37 0.00 -1,656.29 -439.38 -3,586.21 6,003,371.83 384,265.33 0.00 -1,697.05 -453.92 -3,678.06 6,003,358.67 384,173.28 0.00 -1,737.81 -468.47 -3,769.90 6,003,345.51 384,081.24 0.00 -1,778.58 -483.02 -3,861.74 6,003,332.34 383,989.20 0.00 -1,819.34 -497.56 -3,953.59 6,003,319.18 383,897.15 0.00 -1,860.10 -512.11 -4,045.43 6,003,306.01 383,805.11 0.00 -1,900.87 -526.66 -4,137.27 6,003,292.85 383,713.07 0.00 -1,941.63 -541.20 -4,229.11 6,003,279.69 383,621.02 0.00 -1,982.39 -555.75 -4,320.96 6,003,266.52 383,528.98 0.00 -2,023.16 12/3/2012 2:33:56PM Page 3 COMPASS 2003.16 Build 69 HALLIBURTON ConocoPhillips Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: Conoco Phillips (Alaska) Inc. ND Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-127 Design: CD3-127wpl1 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Nl-S +El-W Northing Easting DLS Vert Section (ft) (°) {°) (ft) ft (ft) (ft) (ft) (ft) 3,574.74 6,400.00 68.42 261.00 3,623.64 3,574.74-570.30-4,412.80 6,003,253.36 383,436.94 0.00-2,063.92 6,500.00 68.42 261.00 3,660.42 3,611.52-584.84-4,504.64 6,003,240.19 383,344.89 0.00-2,104.68 6,600.00 68.42 261.00 3,697.21 3,648.31-599.39-4,596.49 6,003,227.03 383,252.85 0.00-2,145.45 6,700.00 68.42 261.00 3,734.00 3,685.10-613.93-4,688.33 6,003,213.87 383,160.81 0.00-2,186.21 6,800.00 68.42 261.00 3,770.78 3,721.88-628.48-4,780.17 6,003,200.70 383,068.76 0.00-2,226.97 6,900.00 68.42 261.00 3,807.57 3,758.67-643.03-4,872.01 6,003,187.54 382,976.72 0.00-2,267.74 7,000.00 68.42 261.00 3,844.36 3,795.46-657.57-4,963.86 6,003,174.37 382,884.68 0.00-2,308.50 7,012.35 68.42 261.00 3,848.90 3,800.00-659.37-4,975.20 6,003,172.75 382,873.31 0.00-2,313.53 K-3 7,100.00 68.42 261.00 3,881.14 3,832.24-672.12-5,055.70 6,003,161.21 382,792.64 0.00-2,349.26 7,200.00 68.42 261.00 3,917.93 3,869.03-686.67-5,147.54 6,003,148.05 382,700.59 0.00-2,390.02 7,300.00 68.42 261.00 3,954.72 3,905.82-701.21-5,239.39 6,003,134.88 382,608.55 0,00-2,430.79 7,400.00 68.42 261.00 3,991.51 3,942.61-715.76-5,331.23 6,003,121.72 382,516.51 0.00-2,471.55 7,406.51 68.42 261.00 3,993.90 3,945.00-716.71-5,337.21 6,003,120.86 382,510.51 0.00-2,474.20 K-3 Basal 7,474,47 68.42 261.00 4,018.90 3,970.00-726.59-5,399.62 6,003,111.92 382,447.96 0.00-2,501.91 Qannik (K-2) 7,500.00 68.42 261.00 4,028.29 3,979.39-730.31-5,423.07 6,003,108.55 382,424.46 0.00-2,512.31 7,600.00 68.42 261.00 4,065.08 4,016.18-744.85-5,514.92 6,003,095.39 382,332.42 0.00-2,553.08 7,700.00 68.42 261.00 4,101.87 4,052.97-759.40-5,606.76 6,003,082.23 382,240.38 0.00-2,593.84 7,746.30 68.42 261.00 4,118.90 4,070.00-766.13-5,649.28 6,003,076.13 382,197.76 0.00-2,612.72 Basal K-2 7,800.00 68.42 261.00 4,138.65 4,089.75-773.95-5,698.60 6,003,069.06 382,148.33 0.00-2,634.60 7,900.00 68.42 261.00 4,175.44 4,126.54-788.49-5,790.44 6,003,055.90 382,056.29 0.00-2,675.37 8,000.00 68.42 261.00 4,212.23 4,163.33-803.04-5,882.29 6,003,042.73 381,964.25 0.00-2,716.13 8,100.00 68.42 261.00 4,249.01 4,200.11-817.59-5,974.13 6,003,029.57 381,872.20 0.00-2,756.89 8,200.00 68.42 261.00 4,285.80 4,236.90-832.13-6,065.97 6,003,016.41 381,780.16 0.00-2,797.66 8,300.00 68.42 261.00 4,322.59 4,273.69-846.68-6,157.82 6,003,003.24 381,688.12 0.00-2,838.42 8,400.00 68.42 261.00 4,359.38 4,310.48-861.22-6,249.66 6,002,990.08 381,596.07 0.00-2,879.18 8,500.00 68.42 261.00 4,396.16 4,347.26-875.77-6,341.50 6,002,976.91 381,504.03 0.00-2,919.95 8,600.00 68.42 261.00 4,432.95 4,384.05-890.32-6,433.34 6,002,963.75 381,411.99 0.00-2,960.71 8,700.00 68.42 261.00 4,469.74 4,420.84-904.86-6,525.19 6,002,950.59 381,319.95 0.00-3,001.47 8,800.00 68.42 261.00 4,506.52 4,457.62-919.41-6,617.03 6,002,937.42 381,227.90 0.00-3,042.24 8,900.00 68.42 261.00 4,543.31 4,494.41-933.96-6,708.87 6,002,924.26 381,135.86 0.00-3,083.00 9,000.00 68.42 261.00 4,580.10 4,531.20-948.50-6,800.72 6,002,911.09 381,043.82 0.00-3,123.76 9,100.00 68.42 261.00 4,616.88 4,567.98-963.05-6,892.56 6,002,897.93 380,951.77 0.00-3,164.52 9,200.00 68.42 261.00 4,653.67 4,604.77-977.60-6,984.40 6,002,884.77 380,859.73 0.00-3,205.29 9,300.00 68.42 261.00 4,690.46 4,641.56-992.14-7,076.24 6,002,871.60 380,767.69 0.00-3,246.05 9,400.00 68.42 261.00 4,727.25 4,678.35-1,006.69-7,168.09 6,002,858.44 380,675.64 0.00-3,286.81 9,500.00 68.42 261.00 4,764.03 4,715.13-1,021.24-7,259.93 6,002,845.27 380,583.60 0,00-3,327.58 9,600.00 68.42 261.00 4,800.82 4,751.92-1,035.78-7,351.77 6,002,832.11 380,491.56 0.00-3,368.34 9,700.00 68.42 261.00 4,837.61 4,788.71-1,050.33-7,443.62 6,002,818.95 380,399.51 0.00-3,409.10 9,800.00 68.42 261.00 4,874.39 4,825.49-1,064.88-7.535.46 6,002,805.78 380,307.47 0.00-3,449.87 9,900.00 68.42 261.00 4,911.18 4,862.28-1,079.42-7,627.30 6,002,792.62 380,215.43 0.00-3,490.63 10,000.00 68.42 261.00 4,947.97 4,899.07-1,093.97-7,719.14 6,002,779.45 380,123.38 0.00-3,531.39 12/3/2012 2:33:56PM Page 4 COMPASS 2003.16 Build 69 HALLIBURTON Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Welt CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wpl1 Planned Survey Measured Depth Inclination Azimuth 10,100.00 68.42 261.00 10,200.00 68.42 261.00 10,300.00 68.42 261.00 10,400.00 68.42 261.00 10,500.00 68.42 261.00 10,600.00 68.42 261.00 10,700.00 68.42 261.00 10,800.00 68.42 261.00 10,900.00 68.42 261.00 11,000.00 68.42 261.00 11,035.51 68.42 261.00 Albian_97 11,100.00 68.42 261.00 11,200.00 68.42 261.00 11,300.00 68.42 261.00 11,400.00 68.42 261.00 11,500.00 68.42 261.00 11,600.00 68.42 261.00 11,700.00 68.42 261.00 11,800.00 68.42 261.00 11,840.41 68.42 261.00 Start DLS 3.50 TFO-113.70 11,900.00 67.59 258.93 12,000.00 66.27 255.41 12,100.00 65.02 251.82 12,200.00 63.87 248.16 12,284.83 62.96 245.00 Albian_96 12,300.00 62.80 244.43 12,400.00 61.84 240.63 12,500.00 60.99 236.76 12,600.00 60.25 232.84 12,700.00 59.62 228.86 12,800.00 59.12 224.83 12,900.00 58.75 220.77 13,000.00 58.50 216.68 13,100.00 58.38 212.57 13,200.00 58.39 208.46 13,300.00 58.54 204.36 13,400.00 58.82 200.27 13,500.00 59.22 196.22 13,589.35 59.69 192.63 Start DLS 2.00 TFO 0.00 13,600.00 59.90 192.63 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature Vertical Map Map Depth TVDss +N/S +E/-W Northing Easting DLS Vert Section (ft) ft (ft) (ft) (ft) (ft) 4,935.86 4,984.76 4,935.86 -1,108.52 -7,810.99 6,002,766.29 380,031.34 0.00 -3,572.16 5,021.54 4,972.64 -1,123.06 -7,902.83 6,002,753.13 379,939.30 0.00 -3,612.92 5,058.33 5,009.43 -1,137.61 -7,994.67 6,002,739.96 379,847.25 0.00 -3,653.68 5,095.12 5,046.22 -1,152.15 -8,086.52 6,002,726.80 379,755,21 0.00 -3,694.45 5,131.90 5,083.00 -1,166.70 -8,178.36 6,002,713.63 379,663.17 0.00 -3,735.21 5,168.69 5,119.79 -1,181.25 -8,270.20 6,002,700.47 379,571.13 0.00 -3,775.97 5,205.48 5,156.58 -1,195.79 -8,362.04 6,002,687.31 379,479.08 0.00 -3,816.73 5,242.26 5,193.36 -1,210.34 -8,453.89 6,002,674.14 379,387.04 0.00 -3,857.50 5,279.05 5,230.15 -1,224.89 -8,545.73 6,002,660.98 379,295.00 0.00 -3,898.26 5,315.84 5,266.94 -1,239.43 -8,637.57 6,002,647.81 379,202.95 0.00 -3,939.02 5,328.90 5,280.00 -1,244.60 -8,670.18 6,002,643.14 379,170.27 0.00 -3,953.50 5,352.63 5,303.73 -1,253.98 -8,729.42 6,002,634.65 379,110.91 0.00 -3,979.79 5,389.41 5,340.51 -1,268.53 -8,821.26 6,002,621.49 379,018.87 0.00 -4,020.55 5,426.20 5,377.30 -1,283.07 -8,913.10 6,002,608.32 378,926.82 0.00 -4,061.31 5,462.99 5,414.09 -1,297.62 -9,004.94 6,002,595.16 378,834.78 0.00 -4,102.08 5,499.77 5,450.87 -1,312.17 -9,096.79 6,002,581.99 378,742.74 0.00 -4,142.84 5,536.56 5,487.66 -1,326.71 -9,188.63 6,002,568.83 378,650.69 0.00 -4,183.60 5,573.35 5,524.45 -1,341.26 -9,280.47 6,002,555.67 378,558.65 0.00 -4,224.37 5,610.13 5,561.23 -1,355.81 -9,372.32 6,002,542.50 378,466.61 0.00 -4,265.13 5,625.00 5,576.10 -1,361.68 -9,409.43 6,002,537.18 378,429.41 0.00 -4,281.60 5,647.32 5,598.42 -1,371.31 -9,463.83 6,002,528.38 378,374.88 3.50 -4,304.92 5,686.52 5,637.62 -1,391.71 -9,553.52 6,002,509.32 378,284.90 3.50 -4,339.65 5,727.77 5,678.87 -1,417.39 -9,640.90 6,002,484.97 378,197.15 3.50 -4,368.74 5,770.92 5,722.02 -1,448.24 -9,725.66 6,002,455.40 378,111.95 3.50 -4,392.08 5,808.90 5,760.00 -1,478.38 -9,795.26 6,002,426.31 378,041.90 3.50 -4,407.31 5,815.81 5,766.91 -1,484.14 -9,807.47 6,002,420.72 378,029.62 3.50 -4,409.59 5,862.27 5,813.37 -1,524.98 -9,886.02 6,002,381.08 377,950.46 3.50 -4,421.20 5,910.13 5,861.23 -1,570.58 -9,961.03 6,002,336.61 377,874.78 3.50 -4,426.87 5,959.21 5,910.31 -1,620.79 -10,032.22 6,002,287.48 377,802.85 3.50 -4,426.57 6,009.32 5,960.42 -1,675.41 -10,099.32 6,002,233.88 377,734.95 3.50 -4,420.31 6,060.28 6,011.38 -1,734.25 -10,162.08 6,002,176.00 377,671.32 3.50 -4,408.12 6,111.90 6,063.00 -1,797.07 -10,220.26 6,002,114.06 377,612.20 3.50 -4,390.02 6,163.98 6,115.08 -1,863.66 -10,273.65 6,002,048.29 377,557.82 3.50 -4,366.11 6,216.34 6,167.44 -1,933.75 -10,322.05 6,001,978.94 377,508.38 3.50 -4,336.45 6,268.77 6,219.87 -2,007.09 -10,365.28 6,001,906.26 377,464.06 3.50 -4,301.17 6,321.09 6,272.19 -2,083.40 -10,403.18 6,001,830.53 377,425.02 3.50 -4,260.40 6,373.09 6,324.19 -2,162.41 -10,435.60 6,001,752.03 377,391.41 3.50 -4,214.28 6,424.58 6,375.68 -2,243.80 -10,462.43 6,001,671.05 377,363.37 3.50 -4,162.99 6,470.00 6,421.10 -2,318.31 -10,481.59 6,001,596.85 377,343.10 3.50 -4,112.95 6,475.36 6,426.46 -2,327.29 -10,483.60 6,001,587.90 377,340.95 2.00 -4,106.74 12132012 2:33:56PM Page 5 COMPASS 2003.16 Build 69 HALLIBURTON ConocoPhillips Standard Proposal Report Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wpl1 Local Co-ordinate Reference: Well CD3-127 TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature 'Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (to (ft) (ft) (ft) 6,436.00 13,617.12 60.24 192.63 6,483.90 6,435.00 -2,341.77-10,486.85 6,001,573.48 377,337.49 2.D0 -4,096.74 CCSSh_Abv_HRZ 13,700.50 61.90 192.63 6,523.99 6,475.09 -2,412.55-10,502.71 6,001,502.94 377,320.57 2.00 -4,047.86 13,762.67 63.15 192.63 6,552.90 6,504.00 -2,466.81-10,514.86 6,001,448.88 377,307.60 2.00 -4,010.39 CCS_sh Abv_HRZ_base 13,800.00 63.90 192.63 6,569.54 6,520.64 -2,499.42-10,522.17 6,001,416.39 377,299.81 2.00 -3,987.87 13,844.72 64.79 192.63 6,588.90 6,540.00 -2,538.75-10,530.98 6,001,377.20 377,290.40 2.00 -3,960.70 HRZ 13,900.00 65.90 192.63 6,611.96 6,563.06 -2,587.78-10,541.97 6,001,328.34 377,278.68 2.00 -3,926.84 13,934.86 66.60 192.63 6,626.00 6,577.10 -2,618.91-10,548.94 6,001,297.32 377,271.24 2.00 -3,905.34 Start 435.66 hold at 13934.86 MD 14,000.00 66.60 192.63 6,651.87 6,602.97 -2,677.25-10,562.01 6,001,239.19 377,257.30 0.00 -3,865.05 14,100.00 66.60 192.63 6,691.59 6,642.69 -2,766.80-10,582.08 6,001,149.96 377,235.89 0.00 -3,803.20 14,130.99 66.60 192.63 6,703.90 6,655.00 -2,794.55-10,588.29 6,001,122.31 377,229.26 0.00 -3,784.03 Basek _HRZ/Top Up. Kalubi 14,200.00 66.60 192.63 6,731.31 6,682.41 -2,856.35-10,602.14 6,001,060.72 377,214.49 0.00 -3,741.35 14,256.87 66.60 192.63 6,753.90 6,705.00 -2,907.29-10,613.55 6,001,009.97 377,202.31 0.00 -3,706.17 K-1/Top Lower Kalubik 14,300.00 66.60 192.63 6,771.03 6,722.13 -2,945.91-10,622.21 6,000,971.49 377,193.08 0.00 -3,679.50 14,344.99 66.60 192.63 6,788.90 6,740.00 -2,986.20-10,631.23 6,000,931.34 377,183.45 0.00 -3,651.67 Top_Kup_D/Base Lwr. Kalubik 14,370.42 66.60 192.63 6,799.00 6,750.10 -3,008.97-10,636.34 6,000,908.65 377,178.01 0.00 -3,635.95 Start DLS 3.51 TFO -51.45 14,400.00 67.25 191.75 6,810.59 6,761.69 -3,035.57-10,642.08 6,000,882.14 377,171.86 3.51 -3,617.45 14,448.41 68.32 190.33 6,828.90 6,780.00 -3,079.56-10,650.66 6,000,838.30 377,162.63 3.51 -3,586.34 Top_Kup_C 14,467.54 68.75 189.77 6,835.90 6,787.00 -3,097.08-10,653.76 6,000,820.82 377,159.26 3.51 -3,573.77 LCU 14,500.00 69.48 188.83 6,847.47 6,798.57 -3,127.01-10,658.67 6,000,790.97 377,153.91 3.51 -3,552.06 14,600.00 71.75 186.00 6,880.67 6,831.77 -3,220.54-10,670.83 6,000,697.64 377,140.35 3.51 -3,482.42 14,695.79 73.97 183.36 6,908.90 6,860.00 -3,311.75-10,678.28 6,000,606.56 377,131.52 3.51 -3,411.98 Base_Nuigsut 14,700.00 74.07 183.25 6,910.06 6,861.16 -3,315.80-10,678.51 6,000,602.52 377,131.23 3.51 -3,408.80 14,800.00 76.42 180.55 6,935.53 6,886.63 -3,412.43-10,681.71 6,000,505.96 377,126.58 3.51 -3,331.48 14,900.00 78.80 177.91 6,956.99 6,908.09 -3,510.07-10,680.39 6,000,408.31 377,126.44 3.51 -3,250.73 14,997.05 81.13 175.39 6,973.90 6,925.00 -3,605.47-10,674.80 6,000,312.85 377,130.59 3.51 -3,169.39 Top_Nechelik 15,000.00 81.20 175.31 6,974.35 6,925.45 -3,608.37-10,674.56 6,000,309.95 377,130.79 3.51 -3,166.88 15,003.60 81.29 175.22 6,974.90 6,926.00 -3,611.91-10,674.27 6,000,306.40 377,131.03 3.51 -3,163.80 NECH_CRSUP 15,077.08 83.07 173.34 6,984.90 6,936.00 -3,684.34-10,667.01 6,000,233.88 377,137.20 3.51 -3,100.31 CD3-K 11Jan12 Heel (copy) (copy) 15,078.05 83.07 173.34 6,985.02 6,936.12 -3,685.30-10,666.90 6,000,232.92 377,137.29 0.00 -3,099.46 Start 20.00 hold at 15078.05 MD - 7-5/8" X 9-7/8 to 11"" 15,097.08 83.07 173.34 6,987.31 6,938.41 -3,704.06-10,664.70 6,000,214.13 377,139.20 0.00 -3,082.84 12/3/2012 2:33:56PM Page 6 COMPASS 2003.16 Build 69 HALLIBURTON Database: EDM v16 Prod Company: Conoco Phillips (Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Weilbore: Plan: CD3-127 Design: CD3-127wpl1 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (ft) 0 (1 (ft) ft 15,098.05 83.10 173.31 6,987.43 Start US 4.00 TFO -35.00 15,100.00 83.16 173.27 6,987.67 15,200.00 86.44 170.97 6,996.72 15,287.15 89.31 168.98 6,999.95 Start US 4.00 TFO -90.16 15,287.50 89.32 168.98 6,999.96 15,300.00 89.32 168.48 7,000.11 15,400.00 89.31 164.48 7,001.30 15,500.00 89.31 160.47 7,002.51 15,600.00 89.30 156.47 7,003.73 15,700.00 89.31 152.47 7,004.94 15,800.00 89.31 148.47 7,006.15 15,900.00 89.32 144.47 7,007.35 15,952.00 89.32 142.39 7,007.96 Start 6018.16 hold at 15962.00 MD 15,952.81 89.32 142.36 7,007.97 16,000.00 89.32 142.36 7,008.53 16,100.00 89.32 142.36 7,009.71 16,200.00 89.32 142.36 7,010.88 16,300.00 89.32 142.36 7,012.06 16,400.00 89.32 142.36 7,013.24 16,500.00 89.32 142.36 7,014.42 16,600.00 89.32 142.36 7,015.60 16,700.00 89.32 142.36 7,016.78 16,800.00 89.32 142.36 7,017.96 16,900.00 89.32 142.36 7,019.14 17,000.00 89.32 142.36 7,020.32 17,100.00 89.32 142.36 7,021.49 17,200.00 89.32 142.36 7,022.67 17,300.00 89.32 142.36 7,023.85 17,400.00 89.32 142.36 7,025.03 17,500.00 89.32 142.36 7,026.21 17,600.00 89.32 142.36 7,027.39 17,700.00 89.32 142.36 7,028.57 17,800.00 89.32 142.36 7,029.75 17,900.00 89.32 142.36 7,030.93 18,000.00 89.32 142.36 7,032.10 18,100.00 89.32 142.36 7,033.28 18,200.00 89.32 142.36 7,034.46 18,300.00 89.32 142.36 7,035.64 18,400.00 89.32 142.36 7,036.82 18,500.00 89.32 142.36 7,038.00 18,600.00 89.32 142.36 7,039.18 18,700.00 89.32 142.36 7,040.36 6,938.53 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well CD3-127 TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Map Map +Nl-S +El-W Northing Easting US Vert Section (ft) (ft) (ft) (ft) 6,938.63 -3,705.01-10,664.59 6,000,213.17 377,139.30 4.00-3,081.99 6,938.77 -3,706.94 -10,664.37 6,000,211.24 377,139.50 4.00 -3,080.28 6,947.82 -3,805.57 -10,650.71 6,000,112.43 377,151.67 4.00 -2,991.66 6,951.05 -3,891.31 -10,635.55 6,000,026.47 377,165.53 4.00 -2,912.73 6,951.06 -3,891.65 -10,635.49 6,000,026.13 377,165.60 4.00 -2,912.41 6,951.21 -3,903.92 -10,633.04 6,000,013.84 377,167.85 4.00 -2,900.96 6,952.40 -4,001.12 -10,609.66 5,999,916.30 377,189.77 4.00 -2,807.93 6,953.61 -4,096.45 -10,579.56 5,999,820.54 377,218.44 4.00 -2,712.57 6,954.83 -4,189.45 -10,542.88 5,999,727.01 377,253.71 4.00 -2,615.35 6,956.04 -4,279.66 -10,499.80 5,999,636.16 377,295.43 4.00 -2,516.74 6,957.25 -4,366.65 -10,450.53 5,999,548.45 377,343.38 4.00 -2,417.23 6,958.45 -4,449.99 -10,395.31 5,999,464.30 377,397.33 4.00 -2,317.29 6,959.06 -4,491.75 -10,364.34 5,999,422.08 377,427.67 4.00 -2,265.32 6,959.07 -4,492.39-10,363.85 5,999,421.43 377,428.16 4.00 -2,264.51 6,959.63 -4,529.76 -10,335.03 5,999,383.64 377,456.41 0.00 -2,217.37 6,960.81 -4,608.94 -10,273.96 5,999,303.56 377,516.27 0.00 -2,117.48 6,961.98 -4,688.12 -10,212.90 5,999,223.47 377,576.13 0.00 -2,017.59 6,963.16 -4,767.31 -10,151.84 5,999,143.39 377,636.00 0.00 -1,917.71 6,964.34 -4,846.49 -10,090.77 5,999,063.30 377,695.86 0.00 -1,817.82 6,965.52 -4,925.67 -10,029.71 5,998,983.22 377,755.72 0.00 -1,717.93 6,966.70 -5,004.85 -9,968.65 5,998,903.14 377,815.58 0.00 -1,618.05 6,967.88 -5,084.03 -9,907.58 5,998,823.05 377,875.45 0.00 -1,518.16 6,969.06 -5,163.22 -9,846.52 5,998,742.97 377,935.31 0.00 -1,418.27 6,970.24 -5,242.40 -9,785.45 5,998,662.89 377,995.17 0.00 -1,318.38 6,971.42 -5,321.58 -9,724.39 5,998,582.80 378,055.03 0.00 -1,218.50 6,972.59 -5,400.76 -9,663.33 5,998,502.72 378,114.90 0.00 -1,118.61 6,973.77 -5,479.94 -9,602.26 5,998,422.64 378,174.76 0.00 -1,018.72 6,974.95 -5,559.13 -9,541.20 5,998,342.55 378,234.62 0.00 -918.84 6,976.13 -5,638.31 -9,480.13 5,998,262.47 378,294.48 0.00 -818.95 6,977.31 -5,717.49 -9,419.07 5,998,182.38 378,354.34 0.00 -719.06 6,978.49 -5,796.67 -9,358.01 5,998,102.30 378,414.21 0.00 -619.18 6,979.67 -5,875.86 -9,296.94 5,998,022.22 378,474.07 0.00 -519.29 6,980.85 -5,955.04 -9,235.88 5,997,942.13 378,533.93 0.00 -419.40 6,982.03 -6,034.22 -9,174.81 5,997,862.05 378,593.79 0.00 -319.51 6,983.20 -6,113.40 -9,113.75 5,997,781.97 378,653.66 0.00 -219.63 6,984.38 -6,192.58 -9,052.69 5,997,701.88 378,713.52 0.00 -119.74 6,985.56 -6,271.77 -8,991.62 5,997,621.80 378,773.38 0.00 -19.85 6,986.74 -6,350.95 -8,930.56 5,997,541.71 378,833.24 0.00 80.03 6,987.92 -6,430.13 -8,869.50 5,997,461.63 378,893.11 0.00 179.92 6,989.10 -6,509.31 -8,808.43 5,997,381.55 378,952.97 0.00 279.81 6,990.28 -6,588.49 -8,747.37 5,997,301.46 379,012.83 0.00 379.69 6,991.46 -6,667.68 -8,686.30 5,997,221.38 379,072.69 0.00 479.58 12/32012 2:33:56PM Page 7 COMPASS 2003.16 Build 69 HALLIBURTON ConocoPhillips Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-127 Design: CD3-127wpl1 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) 6,992.64 18,800.00 89.32 142.36 7,041.54 6,992.64 -6,746.86 -8,625.24 5,997,141.30 379,132.56 0.00 579.47 18,900.00 89.32 142.36 7,042.71 6,993.81 -6,826.04 -8,564.18 5,997,061.21 379,192.42 0.00 679.36 19,000.00 89.32 142.36 7,043.89 6,994.99 -6,905.22 -8,503.11 5,996,981.13 379,252.28 0.00 779.24 19,100.00 89.32 142.36 7,045.07 6,996.17 -6,984.41 -8,442.05 5,996,901.05 379,312.14 0.00 879.13 19,200.00 89.32 142.36 7,046.25 6,997.35 -7,063.59 -8,380.98 5,996,820.96 379,372.00 0.00 979.02 19,300.00 89.32 142.36 7,047.43 6,998.53 -7,142.77 -8,319.92 5,996,740.88 379,431.87 0.00 1,078.90 19,400.00 89.32 142.36 7,048.61 6,999.71 -7,221.95 -8,258.86 5,996,660.79 379,491.73 0.00 1,178.79 19,500.00 89.32 142.36 7,049.79 7,000.89 -7,301.13 -8,197.79 5,996,580.71 379,551.59 0.00 1,278.68 19,600.00 89.32 142.36 7,050.97 7,002.07 -7,380.32 -8,136.73 5,996,500.63 379,611.45 0.00 1,378.57 19,700.00 89.32 142.36 7,052.15 7,003.25 -7,459.50 -8,075.67 5,996,420.54 379,671.32 0.00 1,478.45 19,800.00 89.32 142.36 7,053.32 7,004.42 -7,538.68 -8,014.60 5,996,340.46 379,731.18 0.00 1,578.34 19,900.00 89.32 142.36 7,054.50 7,005.60 -7,617.86 -7,953.54 5,996,260.38 379,791.04 0.00 1,678.23 20,000.00 89.32 142.36 7,055.68 7,006.78 -7,697.05 -7,892.47 5,996,180.29 379,850.90 0.00 1,778.11 20,100.00 89.32 142.36 7,056.86 7,007.96 -7,776.23 -7,831.41 5,996,100.21 379,910.77 0.00 1,878.00 20,200.00 89.32 142.36 7,058.04 7,009.14 -7,855.41 -7,770.35 5,996,020.12 379,970.63 0.00 1,977.89 20,300.00 89.32 142.36 7,059.22 7,010.32 -7,934.59 -7,709.28 5,995,940.04 380,030.49 0.00 2,077.77 20,400.00 89.32 142.36 7,060.40 7,011.50 -8,013.77 -7,648.22 5,995,859.96 380,090.35 0.00 2,177.66 20,500.00 89.32 142.36 7,061.58 7,012.68 -8,092.96 -7,587.15 5,995,779.87 380,150.21 0,00 2,277.55 20,600.00 89.32 142.36 7,062.76 7,013.86 -8,172.14 -7,526.09 5,995,699.79 380,210.08 0.00 2,377.44 20,700.00 89.32 142.36 7,063.93 7,015.03 -8,251.32 -7,465.03 5,995,619.71 380,269.94 0.00 2,477.32 20,800.00 89.32 142.36 7,065.11 7,016.21 -8,330.50 -7,403.96 5,995,539.62 380,329.80 0.00 2,577.21 20,900.00 89.32 142.36 7,066.29 7,017.39 -8,409.68 -7,342.90 5,995,459.54 380,389.66 0.00 2,677.10 21,000.00 89.32 142.36 7,067.47 7,018.57 -8,488.87 -7,281.84 5,995,379.46 380,449.53 0.00 2,776.98 21,100.00 89.32 142.36 7,068.65 7,019.75 -8,568.05 -7,220.77 5,995,299.37 380,509.39 0.00 2,876.87 21,200.00 89.32 142.36 7,069.83 7,020.93 -8,647.23 -7,159.71 5,995,219.29 380,569.25 0.00 2,976.76 21,300.00 89.32 142.36 7,071.01 7,022.11 -8,726.41 -7,098.64 5,995,139.20 380,629.11 0.00 3,076.64 21,400.00 89.32 142.36 7,072.19 7,023.29 -8,805.60 -7,037.58 5,995,059.12 380,688.98 0.00 3,176.53 21,500.00 89.32 142.36 7,073.37 7,024.47 -8,884.78 -6,976.52 5,994,979.04 380,748.84 0.00 3,276.42 21,600.00 89.32 142.36 7,074.54 7,025.64 -8,963.96 -6,915.45 5,994,898.95 380,808.70 0.00 3,376.31 21,700.00 89.32 142.36 7,075.72 7,026.82 -9,043.14 -6,854.39 5,994,818.87 380,868.56 0.00 3,476.19 21,800.00 89.32 142.36 7,076.90 7,028.00 -9,122.32 -6,793.32 5,994,738.79 380,928.43 0.00 3,576.08 21,900.00 89.32 142.36 7,078.08 7,029.18 -9,201.51 -6,732.26 5,994,658.70 380,988.29 0.00 3,675.97 21,969.49 89.32 142.36 7,078.90 7,030.00 -9,256.53 -6,689.83 5,994,603.05 381,029.89 0.00 3,745.38 CD3-K 180ctl2 Toe (copy) (copy) 12/32012 2:33:56PM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: Conoco Phillips (A]aska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-127 Design: CD3-127wpl1 Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape r (1) C) (ft) (ft) (ft) (ft) (ft) CD3-K 11Janl2 Heel (copy) (copy) 0.00 6,984.90-3,684.34-10,667.01 6,000,233.88 377,137.20 - plan hits target center - Circle (radius 100.00) CD3-K 180ctl2 Toe (copy) (copy) 0.00 0.00 7,078.90-9,256.53-6,689.83 5,994,603.05 381,029.89 - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Depth Depth (ft) (ft) Name 3,239.52 2,453.85 10 3/4" 15,078.05 6,985.02 7-5/8" X 9-7/8 to 11 21,970.15 7,078.91 3-1/2" x 6-1/8" Formations Measured Vertical Vertical Depth Depth Depth SS (ft) (ft) ft Name 12,284.83 5,808.90 Albian_96 13,617.12 6,483.90 CCS_Sh_Abv_HRZ 14,997.05 6,973.90 Top_Nechelik 14,344.99 6,788.90 Top_Kup_D/Base Lwr. Kalubik 15,003.60 6,974.90 NECH_CRSUP 4,307.59 2,853.90 C-20 14,256.87 6,753.90 K-1/Top Lower Kalubik 14,695.79 6,908.90 Base_Nuigsut 7,406.51 3,993.90 K-3 Basal 14,448.41 6,828.90 Top_Kup_C 13,762.67 6,552.90 CCS_sh_Abv_HRZ_base 13,844.72 6,588.90 HRZ 14,467.54 6,835.90 LCU 3,295.07 2,473.90 C-30 7,474.47 4,018.90 Qannik (K-2) 11,035.51 5,328.90 Albian_97 7,746.30 4,118.90 Basal K-2 7,012.35 3,848.90 K-3 14,130.99 6,703.90 Base_HRZ/Top Up. Kalubik Casing Hole Diameter Diameter 10-3/4 12-1 /4 7-5/8 11 3-1/2 6-1/8 Dip Dip Direction Lithology C) (') 121312012 2:33:56PM Page 9 COMPASS 2003.16 Build 69 Database: EDM v16 Prod Company: Conoco Phillips (Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wpl1 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) 3,290.00 2,472.05 -41.41 -1,577.26 3,330.00 2,486.84 -45.59 -1,614.19 3,360.00 2,498.21 -49.01 -1,641.73 3,760.00 2,650.17 -138.32 -1,999.99 4,292.51 2,848.35 -263.73 -2,477.22 11,840.41 5,625.00 -1,361.68 -9,409.43 13,589.35 6,470.00 -2,318.31 -10,481.59 13,934.86 6,626.00 -2,618.91 -10,548.94 14,370.42 6,799.00 -3,008.97 -10,636.34 15,078.05 6,985.02 -3,685.30 -10,666.90 15,098.05 6,987.43 -3,705.01 -10,664.59 15,287.15 6,999.95 -3,891.31 -10,635.55 15,952.00 7,007.96 -4,491.75 -10,364.34 21,970.15 Comment ConocoPhillips Standard Proposal Report Well CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature KOP: DLS 2.00 TFO-150.00 Start DLS 3.00 TFO-120.00 Start DLS 3.00 TFO -90.00 Start DLS 2.00 TFO 90.00 Start 7547.90 hold at 4292.51 MD Start DLS 3.50 TFO-113.70 Start DLS 2.00 TFO 0.00 Start 435.56 hold at 13934.86 MD Start DLS 3.51 TFO -51.45 Start 20.00 hold at 15078.05 MD Start DLS 4.00 TFO -35.00 Start DLS 4.00 TFO -90.15 Start 6018.16 hold at 15952.00 MD TD at 21970.15 121312012 2:33:56PM Page 10 COMPASS 2003.16 Build 69 ConocoPhiIli ps(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-127 Plan: CD3-127 CD3-127wp11 Sperry Drilling Services Clearance Summary Anticollision Report 03 December, 2012 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3-127 - Plan: CD3-127 - CD3-127wp11 Well Coordinates: 6,003,504.45 N, 1,527,889.34 E (70° 25' 07.95" N, 150' 55' 00.20" W) Datum Height: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Scan Range: 3,290.00 to 21,970.15 ft. Measured Depth. Scan Radius is 2,393.39 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference failed A901MOD HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for CD3-127 - CD3-127wp11 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3-127 - Plan: CD3-127 - CD3-127wp11 Scan Range: 3,290.00 to 21,970.15 ft. Measured Depth. Scan Radius is 2,393.39 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips(Alaska) Inc. -WNS Western North Slope Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad CD3-112 - CD3-112 - CD3-112 3,290.00 1,923.97 3,290.00 1,859.56 4,400.00 29.869 Clearance Factor Pass - Major Risk CD3-114 - CD3-114 - CD3-114 3,307.47 478.35 3,307.47 428.12 3,625.00 9.523 Clearance Factor Pass - Major Risk CD3-115 - CD3-115 - CD3-115 3,305.69 457.48 3,305.69 382.15 3,525.00 6.073 Clearance Factor Pass - Major Risk CD3-117 - CD3-117 - CD3-117 13,891.31 288.61 13,891.31 101.55 13,475.00 1.543 Clearance Factor Pass - Major Risk CD3-117 - CD3-117 - CD3-117 13,932.73 275.61 13,932.73 113.39 13,575.00 1.699 Centre Distance Pass - Major Risk CD3-118 - CD3-118 - CD3-118 3,315.07 362.06 3,315.07 280.04 3,400.00 4.415 Centre Distance Pass - Major Risk CD3-118 - CD3-118 - CD3-118 4,013.49 370.27 4,013.49 271.19 4,050.00 3.737 Clearance Factor Pass - Major Risk CD3-122 - CD3-122 - CD3-122 3,313.15 1,114.94 3,313.15 1,054.65 3,825.00 18.494 Clearance Factor Pass - Major Risk CD3-123 - CD3-123 - CD3-123 3,290.00 749.77 3,290.00 679.17 3,550.00 10.621 Clearance Factor Pass - Major Risk CD3-124 - CD3-124 - CD3-124 4,071.61 347.28 4,071.61 251.32 4,000.00 3.619 Centre Distance Pass - Major Risk CD3-124 - CD3-124 - CD3-124 4,116.77 347.67 4,116.77 250.67 4,050.00 3.584 Clearance Factor Pass - Major Risk CD3-125 - CD3-125 - CD3-125 3,293.20 215.76 3,293.20 162.78 3,350.00 4.073 Clearance Factor Pass - Major Risk CD3-125 - CD3-125PB1 - CD3-125PB1 3,293.20 215.76 3,293.20 162.78 3,350.00 4.073 Clearance Factor Pass - Major Risk CD3-127 - CD3-127PB1 - CD3-127PB1 - CD3-127 - CD3-127PB1 - CD3-127PB1 - CD3-128 - CD3-128 - CD3-128 3,300.19 184.88 3,300.19 113.12 3,275.00 2.577 Centre Distance Pass - Major Risk CD3-128 - CD3-128 - CD3-128 3,923.68 185.29 3,923.68 110.94 3,875.00 2.492 Clearance Factor Pass - Major Risk CD3-128 - CD3-128 (Intermediate) - CD3-128 (Interme 3,299.13 184.75 3,299.13 112.98 3,275.00 2.574 Centre Distance Pass - Major Risk CD3-128 - CD3-128 (Intermediate) - CD3-128 (Interme 3,922.73 185.30 3,922.73 110.91 3,875.00 2.491 Clearance Factor Pass - Major Risk Plan: CD3-126 - Plan: CD3-126 - CD3-126wp04 3,302.08 148.69 3,302.08 78.71 3,250.00 2.125 Clearance Factor Pass - Major Risk Plan: CD3-129 - Plan: CD3-129 - CD3-129wp01 3,312.82 240.48 3,312.82 169.02 3,175.00 3.365 Clearance Factor Pass - Major Risk WNS (Various) Nechelik 1 - Nechelik 1 -. Nechelik 1 Nechelik 1 - Nechelik 1 - Nechelik 1 03 December, 2012 - 12:57 Page 2 of 5 COMPASS HALLIBURTON Anticollision Report for CD3-127 - CD3-127wp11 Survey tool program From (ft) 79.30 516.03 3,300.93 3,290.00 15,078.05 To (ft) 476.30 3,202.56 3,290.00 15,078.05 CD3-127wp11 21,970.15 CD3-127wp11 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Survey/Plan Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Con ocoPhillips(Alaska) Inc. -WNS Survey Tool CB -GYRO -SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Western North Slope 03 December, 2012 - 12:57 Page 3 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-127 Plan: CD3-127 CD3-127wp11 Sperry Drilling Services Clearance Summary Anticollision Report 03 December, 2012 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3-127 - Plan: CD3-127 - CD3-127wp11 Well Coordinates: 6,003,504.45 N, 1,527,889.34 E (70' 25' 07.95" N, 150' 55' 00.20" W) Datum Height: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Scan Range: 3,290.00 to 21,970.15 ft. Measured Depth. Scan Radius is 2,393.39 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for CD3-127 - CD3-127wp11 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3-127 -Plan: CD3-127 - CD3-127wp11 Scan Range: 3,290.00 to 21,970.15 ft. Measured Depth. Scan Radius is 2,393.39 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad CD3-112 - CD3-112 - CD3-112 3,290.00 1,923.97 3,290.00 1,859.56 4,400.00 29.869 Clearance Factor Pass - Major Risk CD3-114 - CD3-114 - CD3-114 3,307.47 478.35 3,307.47 428.12 3,625.00 9.523 Clearance Factor Pass - Major Risk CD3-115 - CD3-115 - CD3-115 3,305.69 457.48 3,305.69 382.15 3,525.00 6.073 Clearance Factor Pass - Major Risk CD3-117 - CD3-117 - CD3-117 13,891.31 288.61 13,891.31 101.55 13,475.00 1.543 Clearance Factor Pass - Major Risk CD3-117 - CD3-117 - CD3-117 13,932.73 275.61 13,932.73 113.39 13,575.00 1.699 Centre Distance Pass - Major Risk CD3-118 - CD3-118 - CD3-118 3,315.07 362.06 3,315.07 280.04 3,400.00 4.415 Centre Distance Pass - Major Risk CD3-118 - CD3-118 - CD3-118 4,013.49 370.27 4,013.49 271.19 4,050.00 3.737 Clearance Factor Pass - Major Risk CD3-122 - CD3-122 - CD3-122 3,313.15 1,114.94 3,313.15 1,054.65 3,825.00 18.494 Clearance Factor Pass - Major Risk CD3-123 - CD3-123 - CD3-123 3,290.00 749.77 3,290.00 679.17 3,550.00 10.621 Clearance Factor Pass - Major Risk CD3-124 - CD3-124 - CD3-124 4,071.61 347.28 4,071.61 251.32 4,000.00 3.619 Centre Distance Pass - Major Risk CD3-124 - CD3-124 - CD3-124 4,116.77 347.67 4,116.77 250.67 4,050.00 3.584 Clearance Factor Pass - Major Risk CD3-125 - CD3-125 - CD3-125 3,293.20 215.76 3,293.20 162.78 3,350.00 4.073 Clearance Factor Pass - Major Risk CD3-125 - CD3-125PB1 - CD3-125PB1 3,293.20 215.76 3,293.20 162.78 3,350.00 4.073 Clearance Factor Pass - Major Risk CD3-127 - CD3-127PB1 - CD3-127PB1 CD3-128 - CD3-128 - CD3-128 3,300.19 184.88 3,300.19 113.12 3,275.00 2.577 Centre Distance Pass - Major Risk CD3-128 - CD3-128 - CD3-128 3,923.68 185.29 3,923.68 110.94 3,875.00 2.492 Clearance Factor Pass - Major Risk CD3-128 - CD3-128 (Intermediate) - CD3-128 (IntermE 3,299.13 184.75 3,299.13 112.98 3,275.00 2.574 Centre Distance Pass - Major Risk CD3-128 - CD3-128 (Intermediate) - CD3-128 (IntermE 3,922.73 185.30 3,922.73 110.91 3,875.00 2.491 Clearance Factor Pass - Major Risk Plan: CD3-126 - Plan: CD3-126 - CD3-126wp04 3,302.08 148.69 3,302.08 78.71 3,250.00 2.125 Clearance Factor Pass - Major Risk Plan: CD3-129 - Plan: CD3-129 - CD3-129wp01 3,312.82 240.48 3,312.82 169.02 3,175.00 3.365 Clearance Factor Pass - Major Risk WNS (Various) Nechelik 1 - Nechelik 1 - Nechelik 1 21,030.31 1,005.90 21,030.31 993.76 7,075.00 82.875 Clearance Factor Pass - Minor 1/10 03 December, 2012 - 12:53 Page 2 of 5 COMPASS MALLIBURTON Anticollision Report for C013-127 - CD3-127wp11 Survey tool program From (ft) 79.30 516.03 3,300.93 3,290.00 15,078.05 To (ft) 476.30 3,202.56 3,290.00 15,078.05 CD3-127wp11 21,970.15 CD3-127wp11 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Survey/Plan Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Con ocoPhillips(Alaska) Inc. -WNS Survey Tool CB -GYRO -SS MWD+I F R-AK-CAZ-SC MWD+I F R-AK-CAZ-SC MWD+I F R-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Western North Slope 03 December, 2012 - 12:53 Page 3 of 5 COMPASS GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-127wp11 3290.00 To 21970.15 Ellipsoid Color -e- qn Mrew e,,..r;n.,, - 0 3200 4200 _ _-- --- -- 4450 6450 7200 12200 14700 22700 24200 cm;ze� i`�iooiico3l�m'eii w`s`m.F6�uuz-� s nro° aioar 3200 - -- .aI cm r=1 iaxw� cmnma,I w 3450 4450 4700 7200 8200 14700 17200 24200 25200 ,. mi""'wi;i�.�mi�n c - 3450 3700 4700 5200 8200 9200 17200 19200 25200 26200 3700 3950 5200 5700 9200 10700 19200 21200 26200- 26950 3950 4200 5700 6450 10700 12200 21200 22700 26950 27450 CD3-12 -90/ 0 D3-127PB 0 / 360 SVIINA1.161 Failed AD4 0 0,010 SECTION DETAILS 12:56 r 03 2012 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 -51.45-3099.37 CD3-K 11Jan12 Heel 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00 3081.88 12 11287'15 89.32 168.96 6.9.78-3.1.33-10635.33 4.00 -35.00 11112.59 13 15952.00 89.32 142.36 7007.80-449,.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3-K 18Od12 Toe LEGEND CD3-112 CD3.112, CO&112 V3 CD&114, CD3.114, CO3.114 V14 CD3-115, CD3-115, CD3.115 VO CO3-117, C133-117, CD3.117 VO CO3-118, C133-118, C103-11e VO -60 CO3.119, CD3.119, CD3119 VO CM119, CO3-119P81, CD3-119PB1 VO CD3-119, CD&119P81. CDS119PS1 (Rip Survey VO C03121, CD3-121, CD3.121 VO CD3122, CM122, C133.122 VO CMAM, CD3.123, CO3-123 VO CD3.124, CD3-124, CD3-124 VO CD3-125, CD3425, CD3.125 VO 90 CD3-125, CD3-125PB1, CD3-1251'B1 VO cD3-125. CD3-125PB1 (surface), CD&125%1 (at no) VO -90 / 270 CD3-127, CD3-127PB1, CD3-127PB1 VO CD3-12e, CD3-128, CD3.128 VO CD3-128, CD3.128 (Intermediate), CO3-128 (Inter io o) VO CD3316, CD3316, CD3316 VO CD3316, C03316A, C03316A VO CD3316, CD3316AP1131, CD3316AP81 VO CD3-316, Nan: CD33168, CD3.3168ap01 VO CD3-316, Nan: CD3.316BSTJ11p, CDMI68ST 3VO D3-12 Nan: CC3-126, Plan: CD3-126, CD3-126wp04 VO -1 20 Nan: CD3-129, Nan: CD3-129, CD3-12%,01 VO Nan: D332qD33 CD3-130, Nan: CD3.130, CD3-130ep03 VO 28 (Intermediat) Nan: CD3320, Plan: CC20ep09 VO Nechelik 1, NecheM1k 1, Nechelik 1 VO CD3-127x 11 Travelling Cylinder Azimuth (TFO+AZI) [I vs Centre to Centre Separation [100 tin] D3-127PB 0 / 360 90 -180 / 180 Azimuth (TFO+A2I) [e] vs Centre to Centre Separation [25 fdin] CD3-127wp11 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 3290.00 To 21970.15 Ellipsoid Color M w s,,..r.+l- 0 3200 4200 4450 6450 7200 12200 14700 22700 242DO _ a,n m, �.,zn.wsa zm�e; i�aoi ipes,zmen 3200 3150 1450 4700 7200 _ -- -_-_-- 8200 14700 17200 24200 25200 3450 3700 4700 5200 8200 9200 17200 192DO 25200 262DO 3700 3950 5200 5700 9200 10700 19200 -- - _ - 21200 26200 -'- ' 26950 3950 4200 5700 fi450 10700 12200 21200 -"-- 22700 -0 27450 211111 in D3-127PB 0 / 360 51 -180 / 180 LEGEND CD3-112, CD3.112, CD3.112 V3 CD3-114, CD3-114, CD3-114 V14 CD3-115. CD3-115, CD3-115 VO CD3-117, CD3-117, CD3-117 VO CD3-118, CD3-ll8,CD3-118 VO CD3-119, CD3-119, CD3-119 VO CD3-119, CD3.1191`131, CD3-119PB1 VO CO3-119, CD34191`111, CM-119P81 (Rig S-) CD3121, CD3-121, CD3.121 VO CO3-122, CD3-122, CD3-122 VO CO3-123, CD3-123, CD3-123 VO CO3.124, CD3-124, CD3-124 VO CO3-125, CM-125, CD3-125 VO CM25, CD3-725P81, CD3-125P81 VO 90 CDe-125, CD3-125P81 (dace). CD3-125P81 (s su CD3127, CD3-127PB1, CD3-127PB1 VO CD&126, CD3-128, CD3-128 VO DD3-128, CD3-128 (Iniennedlaie). CM-128 (hie, CO3.316, CD3316, CD3316 VO CD3316, CD3316A, C03316A VO C03316. CD3316AP131, CD3316APB1 VO CD3316, Ran: CD3-316B. CD3-316Bap01 VO CD3-316, Ran: CD3316BSTJ11p, CD3.316BST_ D3-12 Ran: CD8-126. Plan: CD3.126, CD3.126wp04 VO Ran: CD3-129, Ran: CD3-129, CD3-129Ap01 VO Plan: CD3-130, Plan. =-130, CD3-130.vpO3 VO InterRlediat 28 ( Ran: CD3320, Ran CD3320, CD33201p09 VO Nechelik 1, N--11, Nechelik 1 VO CD3-127ap11 Travelling Cylinder Azimuth (TFO+AZI) [o] vs Centre to Centre Separation [100 ft/in] VO -90 / ') VO Vo SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Meg Vace VSec Target 1 3290,00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00 3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00 3635.95 10 15078.05 83.11 173.29 6984.90 3685.32-10666.77 3.51 -51.45-3099.37 CD3-K 11Jan12 Heel 11 15098.05 83.11 173.29 6987.30 3705.04-10664.45 0.00 0.00 3081.88 12 15287.15 89.32 168.96 6999.78-3891.33-10635.33 4.00 35.00-2912.59 13 15952.00 89.32 142.36 7007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3-K 180ct12 Toe D3-127PB 0/360 90 -180 / 180 Azimuth (TFO+A71) [°] vs Centre to Centre Separation [25 Win] HALLIBURTON ConocoPhilliipss C D 3-12 7w p 11 aska Sperry Drilling ANTI -COLLISION SETTINGS 13:05, December 032012 Interpolation Method: MD, interval: 25.00 Depth Range From: 3290.00 To 21970.15 Results Limited By: Centre Distance: 2393.39 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 79.30 476.30 CD3-127PB1 Gyro (R100) (CD3-127PB1) CB -GYRO -SS 516.03 3202.56 CD3-127PB1 (R100) (CD3-127PB1) MWD+IFR-AK-CAZ-SC 3300.93 3290.00 CD3-127PB1 (R200) (CD3-127PB1) MWD+IFR-AK-CAZ-SC 3290.00 15078.05 CD3-127wp11 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC 15078.05 21970.15 CD3-127wp11 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2453.85 3239.52 10 3/4" 10-3/4 6984.90 15078.05 7-5/8" X 9-7/8 to 11 "" 7-5/8 7078.90 21970.15 3-1 /2" x 6-1 /8" 3-1/2 9 Nechelik 1 s a� rn ao N ❑ O O❑ U U W ❑ ❑ U U 300pppppp it -- - I CL � 150 I 419d A W01 �'III�. i I III 'l,ij �I i ilia D INL� o1�12111111111 I � �i I I I 6000 9000 12000 15000 18000 21000 Measured Depth LEGEND �- CD3-112, CD3-112, CD3-112 V3 CD3-123, CD3-123, CD3-123 VO -- CD3-316, CD3-316APB1, CD3-316APB1 VO CD3-114, CD3-114, CD3-114 V14 CD3-124, CD3-124, CD3-124 VO CO3-316, Plan: CD3-3166, CD3-316Bwp01 VO -�- CD3-115, CD3-115, CD3-115 VO $ CD3-125, CD3-125, CD3-125 VO CD3-316, Plan: CD3-316BST_Alp, CD3-316BST_Alpwp03 VO CD3-117, CD3-117, CD3-117 VO CD3-125, CD3-125PBi, CD3-125P61 VO Plan: CD3-126, Plan: CD3-126, CD3-126wp04 VO CD3-118, CD3-118, CD3-118 VO - - CD3-125, CD3-125PB7 (surface), CD3-125PB1 (sur(ace)®B- Plan: CD3-129, Plan: CD3-129, CD3-129wp01 VO -� CD3-119, CO3-119, CD3-119 VO CO3-127, CD3-127PBi, CD3-127PB7 VO $ Plan: CD3-130, Plan: CD3-130, CD3-130wp03 VO �- CD3-119, CO3-119PB1, CD3-119PB1 VO CD3-128, CD3-128, CD3-128 VO Plan: CD3-320, Plan: CD3-320, CD3-320wp09 VO CD3-119, CD3-119PB1, CD3-119PB1 (Rig Surveys) VG-E3-- CD3-128, CD3-128 (Intermediate), CD3-128 (Intennedial®f0 Nechelik 1, Nechelik 1, Nechelik 1 VO CD3-121, CD3-121, CD3-121 VO -49- CD3-316, CD3-316, CD3-316 VO $ CO3-127wp11 CD3-122, CD3-122, CD3-122 VO CD3-316, CD3-316A, CD3-316A VO HAL LIBURTON ConocoPhillips CD3-127wp l l Sperry Drilling Alaska ANTI -COLLISION SETTINGS 12:52, December 03 2012 Interpolation Method: MD, interval: 25.00 Depth Range From: 3290.00 To 21970.15 Results Limited By: Centre Distance: 2393.39 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 79.30 476.30 CD3-127PB1 Gyro (R100) (CD3-127PB1) CB -GYRO -SS 516.03 3202.56 CD3-127PB1 (R100) (CD3-127PB1) MWD+IFR-AK-CAZ-SC 3300.93 3290.00 CD3-127PB1 (R200) (CD3-127PB1) MWD+IFR-AK-CAZ-SC 3290.00 15078.05 CD3-127wp11 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC 15078.05 21970.15 CD3-127wpll (Plan: CD3-127) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2453.85 3239.52 10 3/4" 10-3/4 6984.90 15078.05 7-5/8" X 9-7/8 to 11"" 7-5/8 7078.90 21970.15 3-1/2" x 6-1/8" 3-1/2 3ZI M« c om U U UU o 0 U U 300 O a ro a. 0 s~ y 150 U 0 a� a U 0 6000 9000 12000 15000 18000 21000 Measured Depth LEGEND -�- CD3-112, CD3-112, CD3-112 V3 $- CD3-123, CD3-123, CD3-123 VO CD3-316, CD3-316APB1, CD3-316APB1 VO CD3-114, CD3-114, CD3-114 V14 CD3-124, CD3-124, CD3-124 VO CD3-316, Plan: CD3-316B, CD3-316Bwp01 VO - CD3-115, CD3-115, CD3-115 VO -B- CD3-125, CD3-125, CD3-125 VO CD3-316. Plan: CD3-316BST_Alp, CD3-316BST_Alpwp03 VO - CD3-117, CD3-117, CD3-117 VO CD3-125, CD3-125PBI, CD3-125PBI VO Plan: C133-126, Plan: CD3-126, CD3-126wp04 VO - CD3-118, CD3-118, CD3-118 VO- CD3-125, CD3-125PB1 (surface), CD3-125PB1 (surface) Plan: CD3-129, Plan: CD3-129, CD3-129wp01 VO CD3-119, CD3-119, CD3-119 VO CD3-127, CD3-127PB1, CD3-127PB1 VO $ Plan: CD3-130, Plan: CM-130, CD3-130wp03 VO -49- CD3-119, CD3-119PB1. CD3-119PB1 VO $ CD3-128, CD3-128, CD3-128 VO --- Plan: CD3-320, Plan: CD3-320, CD3-320wp09 VO CD3-119, CD3-119PB1, CD3-119PB1 (Rig Surveys) VO-E3- CD3-128, CD3-128 (Intermediate), CD3-128 (Intermediat4gQ Nechelik 1, Nechelik 1. Nechelik 1 VO CD3-121, CD3-121, CD3-121 VO CD3-316, C133-316, CD3-316 VO $ CD3-127wp11 -�- CD3-122, CD3-122, CD3-122 VO CD3-316, CD3-316A, CD3-316A VO - l.. 7 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad E(N wi GD3-126wp04 CD3-129wp01 (5000 ft/in) 13:14, December 03 2012 ;T_Alpwp03 CD3-320wp09 Easting (5000 ft/in) C D 3 12 7 w p 11 Name WELLBORE TARGET DETAILS (MAP CO-ORDINATES) TVDSS +NIS +E/-W Northing Easting Shape 17:17, November 16 2012 CD3-K 180ct12 Toe 7030.00-9395.58-7318.635994350.001521062.00 Circle (Radius: 100.00) Quarter Mile View CD3-K 180ct12 Toe Circle 7030.00-9395.58-7318.635994350.001521062.00 Circle (Radius: 1320.00) -2000 ►BIG( 0 0 0 N -6000 r_ O Z -8000 O (n -10000 -12000 -18000 -16000 -14000 -12000 -10000 -8000 -6000 -4000 -2000 West( -)/East(+) (2000 Win) C `-0 oR.aa: cm«anwxlARBBa B1c.-vMs RYd: VA9Mn Natn Sbp9 YM CD3.129WD10 R* ON/A sD.BB�1«aBn x 152786934 It y: 600350-5 tt Comments: WNCa.BtlBn: -0!6 Y4No: RN/A M."� Dw d— 19.76 AR: No: RN/A 00 60.90 ANNOY BN/A Do*g- 100 rt Sys—(IM RBIN— M S--M Oriynd VS Rine: 145.00 • P ." VA* CD3-121 View VS Plane: 145.00 R HWO: 66.9a B POOL: CD3-127wp10 Plan: 15077' to 21970.15' MD CD3-128: 13010' to 20387' MD CD3-118: 13694' to 21228' MD CD3-117: 15654' to 21597' MD W Syo—: AVIBm /WS SBd (VS)RB — 5W Play V' w u M S 0 1 p S a a Z Section View -CD3-127wp10%an -CD3-128 —CD3-118 ---CD3-117 Vertical Section dong "View VS Plane" 6010000 6009000 600M 6007000 6001000 600000D 59990DO 5998000 7000 5000 5000 M 3000 xm Combo Preuew Page 1 of 1 (CD3127wp10 ToolboxAs) 11/19/2012 11:21 AM Closest in POOL Closest Approach: Reference Well: CD3-127wp11 Plan Offset Well: C133-128 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance. Depth Angle Azi. TVD E(+)/W(- (1451 Comments Depth Angle Azi. TVD E(+)/W(- (1451 Comments m Distance (1454.43 in Distance (1454.43 ft) in POOL (15077 ft) in POOL (15077 - 21970.15 MD) to - 21970.15 MD) to CD3-128 (13010 - CD3-127wpl0 Plan 1454.41 1 21970.15 89.32 142.36 7030.818 5994349 1521062 3746.045 20387 MD) 19312.7 90.51 143.97 7022.61 5995190 1529949 3723.26 (13010 - 20387 MD) Closest Approach: Reference Well: CD3-127wp10 Plan Offset Well: CD3-118 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance. Depth Angle Azi. TVD E(+)/W(- (1451 Comments Depth Angle Azi. TVD E(+)/W(- (1451 Comments PUUL n Distance (2013.98 POOL Min Distance (2013.98 it) in POOL (15077 it) in POOL (15077 - 21970.15 MD) to - 21970.15 MID) to CD3-118 (13694 - CD3-127wp10 Plan 20141 1 15077.16 83.09 173.31 6936.365 5999980 1517168 -3100.32 21228 MD) 13669 84.61 325.47 6891.31 6001928 1517678 -4491.26 (13694- 21228 MD) Closest Approach: Reference Well: CD3-127wp10 Plan Offset Well: CD3-117 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance, Depth Angle Azi. TVD E(+)/W(- (145`7 Comments Depth Angle Azi. TVD E(+)/W(- (1451 Comments 70777i-n Distance (2531.2 it) FOOL Min Distance (2531.2 ft) in POOL (15077 - in POOL (15077 - 21970.15 MD) to 21970.15 MD) to CD3-117 (15654 - CD3-127wpl0 Plan 2531.2 15077.16 83.09 173.31 6936.365 5999980 1517168 -3100.32 21597 MD) 15629 7 83.41 328.15 6901.25 6001986 1515624 -5698.66 (15654 - 21597 MD) PoolSummaryl 11/19/2012 1:44 PM CD3-127wp11 Surface Location M CPAI Coordinate Converter - ---------- - 0 From: To: Datum: �t-.�AE'833 Region: jalaska Datum: FRegion: N A D 2 —7- Falask—a—_- r Latitude.,'LonjtUde Decimal degrees ---------- LatitudelLongitude Decimal Degrees C- UTM Zone: South r, UTM Zone: Truef— South State Plane Zone: 4 Units: I us-ft State Plane Zone: True Units: us ft Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11527889.34 Township: f0-12 [—N—,—] Range: 0-05 Y: 16003504.45 Meridian: Section:5 JFNL � 14022.0836 IFEL 11185.2521 .............. .......... ......................... Transform Quit Help CD3-127wp11 Kick-off Point M CPAI Coordinate Converter❑ From: To: Datum: FN----D -------- 7 jalaska -,j .4 83 Region: I Datum: i Region: NA.D27 s C- Latitude"Lon6tude Decimal Degrees _7J C- Latitude/Longitude IDecimal Degrees r UTM Zone: F South C UTM Zone: [—ri .Ae. F South Units: (o— Skate Plane Zone: Fu S—f T 771 C' Zone: Fru_e_�-:] Units: State Plane ru—sft _:1 r Legal Description IIN.6.1127 unl_yl IT Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11526311.77 Township: 0-12 rN;I Range: 0_05— Y: 16003486.82 Meridian: JU Section:15 FNL 4063-5286 FFE—L 2762.6-258 ............ . r a'ns'Gm ... .......................................................... .......................................................... ....... Quit Help L CD3-127wp11 Intermediate Casing F21 CIPAI Coordinate Converter W U-FM1Lj From: i- To: Region: Datum: lalaska Datum: i Region: alaska rNAD27 Latitude/Longitude !FecimalDegrees Latitude/Longitude Decimal D-egrees C- UTM Zone: r south C- UTM Zone: [—True f- South r* State Plane Zone: Units: us State Plane Zone: [True j Units: i us-ft r Legal Description (NAD27 only) Starting Coordinates:---- 1 Legal Description X: 11517169.15 Township: ro j72— FN-7, Range: 0-04 Y: 15999980.65 3Meridian: Section: 112 rFNL - 12433.7597 FEL - I F1-799 .5808 - ---------------- - -- .......... ............. ran4�i mQuit ... . . ..... Help CD3-127Wp11 TD n CPAI Coordinate Converter From: i- To: Datum: INAD83 Region: aska Fa 1 -13 Datum: Fr—jAD Region. jalaska U Latitude"Longitude Decimal Degrees -1 C Latitude/Longitude V--,-,Mal Degrees UTM Zone: F F- South C UTM Zone: FTrl_je F South Co- State Plane Zone: 14 Units: us f C- Stale Plane Zone: [TueUnits: fus-ft---, I- Legal Description IN'AD27 Legal Description (NAD27 only) Starting Coordinates: i Legal Description X: 11521062.00 Township: [0-12 IN I Range: Fo—or Y: 15994350.00 Meridian: 15 S ection: lg JFNL T 2721.3342 FFEL I F2622.7363 ........... Help............................................................ CD3-127wp11 3290.00 To 4001.00 m cm°S.�zme� iesoo� iwa�zmen uw. e,e os e,em,+ eo. �i� iw cm �z'"i, ,ww.sax-erz-se CD3-1, -90/ m GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TlEace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 Ellipsoid Cokx 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650A7-138.32-1999.99 3.00 -90.00-1033.85 0 -- 3200 4200 4450 6450 7200 12200 14700 22700 24200 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 320D 3450 4450 4700 7200 8200 14700 17200 24200 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00 4281.60 3450 3700 4700 5200 8200 9200 17200 19200 25200 262DO 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 3700 3950 5200 5700 9200 10700 19200 21200 26200 - 26950 8 9 13934.86 14370.42 66.60 192.63 6626.00 -2618.91-10548.94 66.60 192.63 6799.00-3008.97-10636.34 2.00 0.00 0.00-3905.34 0.00 3635.95 3950 4200 6700 6450 10700 12200 21200 22700 26950 27450 10 11 12 15078.05 15098.05 15287.15 83.11 173.29 6984.90-3685.32-10666.77 83.11 173.29 6987.30-3705.04-10664.45 89.32 168.96 6999.78-3891.33-10635.33 3.51 0.00 4.00 -51.45-3099.37 CD3-K 11Jan12 Heel 0.00 3081.88 -35.00-2912.59 13 15952.00 89.32 142.36 7007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3-K 180ct12 Toe 0 / 360 D3 127PB 0 / 360 LEGEND -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 f/in] CM112, CD3-112, C133.112 V3 CD3-114, CD3-114, CD3-114 V14 CD3-115, CO3.115. CD -115 VO CD3-117, CD3-117, CO3.117 VO CD3-118. CD3418, CO3-118 VO CD3.119, C133.119, CD3419 VO CD3.119, CD3.119Pa1, CO3-119POI VO CD3-119, CD3.1191i'B1, CD&1191`B1 (Rig Survey VO CD3-121, CD3-121, CO3-121 VO CD3-122, CD3.122, CO3-122 VO CMA 23, CD3-123, C133-123 VO CD3-124, CD3-124, CD3.124 VO 2133.125, C133.125, CD3-125 VO CD3-125, CM-125PB7, CD3-125PBI VO CD3.125, CD3-125PB1 (suftce), CD3-125P61 (s ace CD3-127, CD3-1271'B7. CD3.127PB7 VO CD3.128, CD3-128, CD3.128 VO CD3.128, CD3.128 (InlennediaM). CD3.128 to is CD3316. CD3316, CD3316 VO CD3316, CD3316A, C03316A VO CD3316, CD3316APB1. C1)3316APB1 VO CD3316, Ran: CD33161l. CD3-3168ap01 VO CD3316, Ran: C1)331613ST Alp, CD3316BS-r Ran: CD3-126. Ran: CD3-126, CO3-126wpO4 VO Ran: CD3.129. Plan: CD3.129, CD3-129aW 1 VO Ran: CD3-130, Plan: CD3130, CO3-130,4W VO Ran: CD3320. Ran: CD3.320, C03320-p09 VO Nechelik 1, Necheik 1, NechNik 1 VO CD3-127wpll -60 / v9 -90 1270 1 VO VO -120 / 90 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 Win] CD3-127wp11 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS 13:08, DECEMBER 03 2012 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 3290.00 To 5001.00 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 Ellipsoid Color 2 3330.00 67.95 263.34 2486.84 -45.59 •1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.()0 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 0 3200 4200 4450 6450 7200 12200 14700 22700 242DO 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 _ onaq-,z moss 3200 3450 4450 4700 7200 --- 8200 14700 17200 24200 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 �amol�,zzven wp. LD1w�zi.,n m.. za 3450 3700 4700 5200 8200 9200 17200 19200 25200 26� 7 13934.86 192.63 6626.00-2618.91-10548.94 3.00 -110.00-3905.95 3700 3950 5200 5700 9200 10700 19200 21200 26200 26950 g 9 13934.86 14370.42 66.60 66.60 192.63 6626.00-2618.91-10548.94 66.60 192.63 6799.00-3008.97-10636.34 2.00 0.00 34 0.00 �905.34 0.00-3635.95 3950 4200 5700 6450 10700 12200 21200 22700 26950 27450 10 11078.05 883.1111 173.29 6984.90 .3685.32-10666.77 3.51 -51.45-3099.37 CD3-K 11Jan12 Heel 11 15098.05 3.173.29 6987.30 -3705.04-10664.45 0.00 0.00-3081.88 mza.o znA.,a a,rr.u,.rr s,a 12 15 287.15 89.32 168.96 6999.78-3891.33-10635.33 4.00 •35.00-2912.59 13 15952.00 89.32 1 42. 36 700780-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3•K 180ct12 Toe -90 / K 0 / 360 D3 127P6 0 / 360 LEGEND -180 / 180 CD3-112, CD3-112, CD3112 V3 CD3114, CD3.114, CD3114 V14 CD3715. CD3-115, CD3115 VO 371 CD7, CD3117, CD 3118. -117 VO CDCD3-11 a, CD3118 VO CD3119, CD3.119, CD3119 VO CD3719, CD31191`81, M3-119PB1 VO CD3119, CD3119PB1, CD3119PB1 (Rig Survey VO CD3121, CD3121, CD3121 VO C133122, C133-122, CO3-122 VO CD3-123, CD3-123, CD3123 VO CD3124, CD3-124, CD3124 VO CO3-125, CD3125, CO3-125 VO C03425, CD3125P81, CD3125P81 VO CO3-125. CD3125P81 (-Ia.). CO3-125PB1 (a a e CD3127, CD3127PB1, C133127PB7 VO CD3/28, CD3-128, CD3128 VO DD3128, CD3128 (Intermediate). CD3-128 (hter is CD3316, CD3-3 CD3.116 VO CD3.316, CD3316A, CD3J16A VO C03316, CD3.316AP81, CD3-316AP81 VO D3-12 CD3316, Plan: CD33168, CD3316BapO1 VO CD33/6, Nan: CD33168STJVp, CD3.3168STJ pp Plan: CD3126. Plan: CD3126, CD3126vpO4 VO Nan: CD3129. Plan: CD3129, CD3129apO1 VO Nan: 0103130, Plan: CD3130, CD3-130apO3 VO (Irltermediat) Nan: CD3-320, Plan: CD3320, CO3-320w,09 VO Ne"elik 1, Nechehk 1,14 chelik I VO CD3-127a,p11 Travelling Cylinder Azimuth (TFO+AZI) [1] vs Centre to Centre Separation [100 ft/in] -60 / v9 -90 / 270 VO -120 / -180 / 180 Azimuth (TFO+A7.I) [°] vs Centre to Centre Separation [25 Win] CD3-127wp11 3290.00 To 6001.00 M. M. mwm cosuman wm.m,lwui ix m�z�wnln..S �m MYo.P�a�.�.Y �sam.os mno.,s cm�zawn �A., co°}o.�al c,�sNc Dams tsar maw zmm.�s s,rs�au• s,rz i L -90/ IIE GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Ellipsoid Wor 0 - - 3200 4200 4450 6450 7200 12200 14700 22700 24200 3200 3450 4450 4700 7200 8200 14700 17200 24200 25200 3450 3700 4700 _-- 5200 8200 9200 17200 19200 25200 26200 3700 3950 5200 5700 9200 10700 19200 21200 26200 - 26950 3950 4200 5700 6450 10700 12200 21200 22700 26950 27450 D3-127PB 0 / 360 -180 / 180 LEGEND CD3112, CD3-112, CD3-112 V3 CD3-114, CD3-774, CD3.114 V14 CD3.115. CD3-175, CD3-715 VO CD3-117, CD3-177, CD3-117 VO CD3-118, CD3-118, CD3-118 VO CD3419, CD3-119, CD3-119 VO CO3-119. CA-I1SPB1, CD3.119PB1 VO CM 9. CD3119PB1, CD3119PB1 (Big VO CD3121. CD3121, CD3121 VO CD3-122, CD - 22, CD3122 VO CD3-123, C03123, CD3123 VO CD3124, CD3124, CD3124 VO 0D3725, CD3-125, CD3-125 VO CD3125, CD3425PB1, CD3.125PB1 VO 90 CM 25, CD3/25PB7 (suAaca), CO3-125PB1 (s a CD3127, CD3-127PB1, CM127POI VO 49- CD3-128, CD3-128, CD3128 VO CD8-128, CD3728 (Inlennedialel. CD3-128 (FN is CD3-316. CD3316. CD3316 VO CD3316, CD3316A, C03316A VO CD3316, CD331SAPS1, CD3.316APBI VO D3-12 C03316, Han: C03316K C13316Bwp01 VO CD33 Plan: CDM BST Alp, CD3316BST_ Nan: CD3126, Plan: CD3126, CD3-126wp04 VO Nan: CD3129, Plan: CD3-129, CD3-129ap01 VO Nan: CD313O, Plan: CO3-130, CD3-130wp03 VO 28 (Int@rmedlet ) Nan: CD3320, Plan: CO3.320, CD3.20xp09 VO Nenhelik 1, Neskehk 1, Ne Wik 1 VO 44- CD3-127vp11 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ttfin] v0 -90 / r1 VO SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3290,00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.D0 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17 •138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73 •2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68 •9409.43 0.00 0.00-4281.60 7 13589.35 69.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00 3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 -51.45-3099.37 CD3-K llJan12 Heel 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00 3081.88 12 15287.15 89.32 168.96 6999.78-3891.33-10635.33 4.00 -35.00-2912.59 13 15952.00 89.32 142.36 7007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90 •9257.12-6689.14 0.00 0.00 3746.26 CD3-K 18Oct12 Toe D3 127P6 0 / 360 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) ['] vs Centre to Centre Separation (25 ft/in] CD3-127wp11 3290.00 To 7001.00 oqm a s�.n�n� w � creinre; id�o'iiwal,rne,l�Owm�vs-c4z c,eNc oar 0 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference FJ4=id Color 0 3200 4200 4450 6450 7200 12200 14700 22700 242DO 32DO 3450 4450 --- 4700 7200 -- ---- - 8200 14700 17200 24200 25200 3450 3700 4700 5200 8200 92DO 17200 19200 25200 262DO 3700 3950 5200 5700 9200 10700 19200 21200 26200 - 26950 3950 4200 5700 6450 10700 12200 21200 22700 26950 27450 D3-127P8 0 / 360 -180 / 180 LEGEND CD3-112, CO3-112, CD3112 V3 CD3-114, CD3-114, CD3114 V14 CD3115, CD3-115, CO3-115 VO CD3117, CD3-117, C03117 VO CD3118. CD3-118, CD3-118 VO C03119, C03119, CD3119 VO CD3119, CD3119PB1, CD3119P81 VO CO3-119, CD3119PS1, CD3419PB1 (Rig Su VO CD3121, CD3121, CD3121 VO CD3122, CD3122, CD3122 VO C03123, CD3123, CD3123 VO CD3124, CD3124, CD3124 VO C03125, CD3125, CD3125 VO 9D CD3125, CD3125P81, CD3-125PB1 VO CD3125. CD3125PB7 (sudeca), C03125P81 (s ace) VO -90 / CD3-127, CD3-127P81, CD3-127PB1 VO CD3128, C03128, CD3128 VO 13- cD3-128, C133-128 (Inlelmediale), CD3128 (intern ediala) VO CD3.316, CD3-316. CD3316 VO CD3316, CD3316A, CD3316A VO CD3-318. CD3J16APB1, CD"16APB1 V0 D3-12 CD3316, Plan: CD33168. CD3316Bap01 VO CD3 , Plan: CD3.3168ST-fJP, CD33168ST_ 3 VO Plan: CD3126, Plan: CD3126, CD3-126WP04 VO -� Plan: CD3129, Plan: CD3129, CD3129Ap01 VO Plan: CD3130, Plan: CD3130, C03130vp03 VO 28 (Intermediat) Plan: CD3320, Plan: CD3320, CD3. OmD 9 VO Nechelik 1, Necheak 1, Neohelik I VO CD3-127a 11 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ftlin] SECTION DETAILS Sec MD Inc Azi TVD +W-S +E1-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.439 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848-35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00 -3635.95 10 15078.05 83.11 173.29 6984.90 a685.32-10666.77 3.51 -51.45-3099.37 CD3-K 11Jan12 Heel 11 15098.05 83.11 173.29 6987.30 -3705.04-10664.45 0.00 0.00-3081.88 12 15287.15 89.32 168.96 6999.78-3891.33-10635.33 4.00 -35.00-2912.59 13 15952.00 89.32 142.36 7007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.D0 0.00 3746.26 CD3-K 18Oct12 Toe D3 �Z�PB 0 / 360 90 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 Win] CD3-127wp11 3290.00 To 8001.00 re; idoo�i ic°siz�'+o'en�wm�rww�ic azaol icmineen w.o.m.vc `cop0a �m c�vna °ems tD3-1. -90 / GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS 932012 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 Ellipsoid Color 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 0 3200 4200 4450 6450 7200 12200 14700 22700 24200 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 3200 3450 4450 4700 7200 8200 14700 17200 24200 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0,00-4281.60 3450 3700 4700 5200 8200 9200 17200 19200 25200 26200 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 3700 3950 5200 5700 9200 10700 19200 21200 2620D 26950 8 9 14370.42 14370.42 66.60 192.63 6799.00 -3026 8.91-10636.34 66.60 192.63 6799.00-3008.97-10636.34 2.00 0.00 34 0.00-3635.95 0.00 3635.95 3950 4200 5700 6450 10700 12200 21200 22700 26960 27450 10 11 12 15078.05 15098.05 15287.15 83.11 173.29 6984.90-3685.32-10666.77 83.11 173.29 6987.30-3705.04-10664.45 89.32 168.96 6999.78-3891.33-10636.33 3.51 0.00 4.00 -51.45-3099.37 CD3-K 11Jan12 Heel 0.00-3081.88 -35.00-2912.59 13 1 5952. 00 89.32 142.36 7007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3-K 18OC112 Toe D3-127P8 0 / 360 03-127PB 0 / 360 LEGEND -180 / 180 CO3-112. CD3-112. C03112 V3 CD3.114, CD3-114. CD3-114 V14 CD3-115. CD3.115. C133.115 VO CDS-117, CD3117, CD3117 VD CD3118. CD3-118. CD3.118 VO CD3-119, CD3.119. CD3.119 VO CD3119, CD3-119P81, CD3-119P81 VO CD3119, CD&119PB1. CD3119PBi (Rig su'er VO CD3121, CD3-121, CD3-121 VO CD3-122, CD3.122, CO3.122 VO DD3123, CM-123, CD3-123 VO CD3-124, CD3-124, CD3-124 VO CD3-125, CD3125, CD3.125 VO 90 CDD3 3.125, CD3.125PBl. C-125P81 VO CD3125, CD3-125PB1 (suda°e), CD3125PB1 Ia ace) VO -90/ CD3127, CD3-127PB1. CD3-127PB1 VO 49- CD3128, CM 28, CD3-128 VO CD3128, CD3128 (InleOnediaW), CD3-128 (.. edi,W) VO CD3316, CM-316. CD3316 VO CD3316, CD3316A, CD3.316A VO CD3316, Cl)" 6APB1. CD3416APB1 V0 D3-12 CD3316. Ran: CD":8. CD3316Bwp01 VO CD3J16, Plan: CD3.3185T_A1p, CD3-316BST_ VO Plan: CD3126, Plan: CD3126, CD3-126wpO4 VO -1 Ran: CD3129, Plan: CD3129, CD3.129Wp01 VO Ran: CD3-130, Plan', CD3130, CD3-130wp03 VO 28 (Interrnediat) Ran: CD3320, Plan', DD3320, CD34120wp09 VO 49- Nechelik 1, NecheGk 1, Nechelik 1 VO CD3-127wpll Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ft/in] 90 -180 / 180 Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 Win] CD3-127wp11 3290.00 TO 10001.00 D3-127PB Fd GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Sec 1 MD 3290.00 SECTION DETAILS Inc Azi TVD +N1-S +E/-W Meg 68.64 263.77 2472.05 -41.41-1577.26 0.00 TFace VSec Target 0.00-870.75 EGipsoid Color 2 3330'00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.00-888.52 3 3360.D0 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 0 - - 32DO 4200 4450 6450 7200 12200 14700 22700 24200 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 32DO 3450 4450 _- _ 4700 7200 -- --- - 8200 1470D 172DD 24200 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 3450 3700 4700 5200 8200 9200 17200 19200 252W 262DO 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 3700 3950 5200 5700 9200 10700 19200 - 21200 26200 26950 8 9 13934.86 14370.42 66.60 192.63 6626.00-2618.91-10548.94 66.60 192.63 6799.00 3008.97-10636.34 2.00 0.00 0.00 3905.34 0.00 3635.95 3950 42DO 5700 6450 10701) 12200 21200 22700 26950 27450 10 11 12 15078.05 15098.05 15287.15 83.11 173.29 6984.90 3685.32-10666.77 83.11 173.29 6987.30-3705.04-10664.45 89.32 168.96 6999.78-3891.33-10635.33 3.51 0.00 4.00 -51.45-3099.37 CD3-K 11Jan12 Heel 0.00 3081.88 -35.00-2912.59 13 15952.00 89.32 142.36 7007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3-K 18Oct12 Tie 0 / 360 D3-127P6 0 / 360 LEGEND -180 / 180 CD3.112, CD3.112, C03112 V3 C03114, CO3-114, CO3-114 VI CD3,115. CD3-115, CO3.115 VO CD3.117, CD3117, CD3.117 VO CD3-11 e. CO3-11e, CD3-116 VO CD3.119, C133.119, CD3.119 VO CD3.119, CD3.119PB1, CD3-119P81 VO OD3-119. CD3.119P81, CD3.119P81 (Rig Survey VO CD3-121, CD3-121, CD3-121 VO CD3122, CD3.122, CD3122 VO CD3.123, CD3-123, CD3.123 VO CD3-124, CD3.124, CD3-124 VO OD3-125, CD3.125, CD3.125 VO 90 CD3-125, CD3-125PB1, CD3-125PB1 VO CD3-125, CD3-125PB1 (surface), CD3-125PB7 (s ace CM 27, CD3.127P81, CD3-127PB1 VO CD3.126,. 26, CD3.126 VO CD3.126, CD3.126 (InNrmediam), CD3.126 (hNr edia CD3-31s. CD3316. CD3316 VO CO3-3 . CD3316A, C03316A VO CD3316, CD3316APB1, CD3316APB1 VO D3-12 C03316, Plan: CD3.316B, CD33168ap01 VO CO3.316, Plan: CD3316BSTflp, CD3-31613ST Plan: CD3.126, Plan: CD3-126, CD3.126wpG4 VO Plan: CDb129, Plan: CO3A 29, CD3.129,Wl VO %en: CD3-130, Plan: CD3,130, CD3-130ny03 V0 28 (Intermediat) %an: CD3320, Plan: DD332D, CD3320xp09 VO Nechelik 1, NecheAk 1, Nxhelik 1 VO CD3-127.pll Travelling Cylinder Azimuth (TFO+AZI) [I vs Centre to Centre Separation [100 ft/in] vo -90 / O VO -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation 90 CD3-127wp11 3290.00 To 13001.00 � o,oe ro s..wrd, sv re, apram-,xm'��aw.oss a cro;zx'ir�, in,m) -1),wvo.aa.wcux m w.+zme, �axom cw,x,.sn .xo. �u.rxs D3-127PB . -90 / 1 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS ' Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 Ellipsoid Color 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.D0-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 0 - - 3200 4200 4450 6450 72DO 12200 14700 22700 24200 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 32W 3450 4450 470D 7200 - - 8200 14700 17200 242DO 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 3450 3700 4700 52DO 8200 9200 17200 192DO 25200 262DO 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 370D 3950 5200 5700 9200 10700 19200 212DO 2620D - 26950 8 9 13934.86 14370.42 66.60 192.63 6626.00-2618.91-10548.94 66.60 192.63 6799.00-3008.97-10636.34 2.00 0.00 0.00 3905.34 0.00 3635.95 3950 42DO 5700 6450 10700 12200 21200 22700 26950 27450 10 11 12 15078.05 15098.05 15287,15 83.11 173.29 6984.90-3685.32-10666.77 83.11 173.29 6987.30-3705.04-10664.45 89.32 168.96 6999.78-3891.33-10635.33 3.51 0.D0 4.00 -51.45-3099.37 CD3-K 11Jan12 Heel 0.00 3081.88 , -35.00-2912.59 13 15952.00 119.32 1 42 .367007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3-K 180ct12 Toe D3-127P6 0 / 360 1 1 0 / 360 -180 / 180 LEGEND CD3.112, C133.112, CD3.112 V3 CD3114, C133-114, CD3.114 V14 C1)3-115. CD3-115, CD3.115 VO CD3-117. C133-117, CD3.117 VO CO3-118. CD3-118, CO3AIS VO $0 ) C133-119, CD3.119, CO3.119 VO C133.119. CD3-119PB1, CD3-119P81 VO CD3.119, CD3.119P81, CD3119PB1 (Rig SulVO CD3-121, C133-121, CD3-121 VO CD3-122, CD3-122, CO3-122 VO CD3-123, CD3-123, CD3-123 VO CD3-124, CD3-124, CO3-124 VO CD3-125, CD3.125, CO3-125 VO 90 CD3-125, CD3.125PB1, CD3.125P81 VO CD3-125, CD3-125PB1 (sudae), CD3-125PB1 (s aee) VO -90 / 270 CD3-127, CD3-127PB1, C133-127P131 VO CD3-128, CD3-128, CD3-128 VO cD3.128, CM12e Onrermediatel. CD3-128 (rater ediale) VO 0D3316, CD3316. CD3316 VO 0D3316, COMM. CD3316A VO CD3316, CD3316APBl, CD3316APBI VO CD3316, Plan: CD33168. CD3316Ba4101 VO D3-12 CD3316, Plan: CD3316BST_AIP, CD331613ST VO Plan: CD3-126, Plan: CM-126, CD3A26wp04 VO -120 ) ` Plan: CD3129. Plan: CD3.129, CD3-129x 01 VO %en: CD3-130, %an: CD3-130, CD3-1301p03 VO 128 (Intermediai) %an: C133320, %en: CD3320, CD3320ep09 VO Neehelik 1, Ne hehk 1, Nmhelik 1 VO CD3.127wpll Travelling Cylinder Azimuth (TFO+AZI) [I vs Centre to Centre Separation [100 ft/in] -180 / 180 Azimuth (TFO+AZI) [°] vs Centre to Centre 90 [25 Win] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-127wp11 3290.00 To 14001.00 Ellipsoid Color me = avn Te s, vw 0 3200 4200 4450 6450 7200 122W 14700 22700 winvs� llrAs,2-1 - - m°Yiiluml cas+aT.en r.�n 3200 3450 4450 4700 72DO 8200 14700 17200 24200 Iw.=cm'm ,sore . - wwm�rx.ac 3450 3700 4700 5200 8200 9200 17200 19200 25200 c, onws 3700 3950 5200 5700 9200 10700 192W - 21200 26200 Tun ao a... sn 3950 4200 5700 6450 10700 122DO 212W 22700 26950 M D3-127PB 0/360 -180 / 180 SECTION DETAILS LUjj&aMWP 2012 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -1 WOO -888.52 3 3360.00 67,50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 24200 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 26200 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.60 -113.70-4112.95 26950 8 9 1 3934.86 14370.42 66.60 192.63 6626.00-2618.91-10548.94 66.60 192.63 6799.00 3008.97-10636.34 2.00 0.00 0.00 3905.34 0.00 3635.95 27450 10 11 12 15078.05 15098.05 15287.15 83.11 173.29 6984.90 3685.32-10666.77 83.11 173.29 6987.30 3705.04-10664.45 89.32 168.96 6999.78-3891.33-10635.33 3.51 0.00 4.00 -51.45-3099.37 CD3-K 11Janl2 Heel 0.00-3081.88 -35.00-2912.59 13 15952.00 89.32 142.36 7007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3-K 180012 Toe LEGEND CD3-112, CD3.1/2. CO3.112 V3 CD3-114, C034/4, CD3.114 V14 CD3-115. CD3-1115, CD3-115 VO CD3-117, CD3-117, CD3-117 VO CD3-ne. CO3-n8. CD3-n8 VO -60 CD3-119, CD3.119, CD3119 VO C03119, CO3.119PS1, CD3-119PB7 VO CD3119, CD3.119PS1, CD3.119PB1 (Rig sU,-Y VO C133-121, CD3-121, CD3-121 VO CDe-122, CDe-122, CD8-122 VO CD3-123, CD3-123, CD3.123 VO CD3-124, CD3-124, CD3124 VO CD3.125, CD3-125, CD3.126 VO 90 CO3.125, CD3-125P81, CD3-125PB1 VO CD3125, CD3-125PB1 (surface(, CDe-125P81 is ace) VO -90 / 270 C03127, CD3427P81, CD3-127PB1 VO CD3-128, CD3-128, CD3.128 VO CD3.128, CD3.128 (Inlennediale). CD3.128 (mte ed,,la) VO CD3316, CD3316. CD3316 VO CD3316. CD3316A, CD3316A VO CD3316, CD3316APB1, CD3316AP81 VO D3-12 CD3316, Plan: CD3316B, CD3.316Bvp01 VO CD3-3 ,Plan: CD3-3 BST_A , CD3316BST_ VO Nan: C133-126, Plan: CD3-126, CD3-126ap04 VO -120 Nan: CD3.129. Plan: CD3.129, CD3-129v01 VO Nan: CD3.130, Plan: CD3.130, CD3-130vpa13 VO 28 (Intermediat) Nan: CD3-320, Plan: COMM, C03320wp09 VO Nechelik 1, Nechahk 1, Nechelik 1 VO CD3-127wp11 D3-127PB 0 / 360 Travelling Cylinder Azimuth (TFO+AZI) [o] vs Centre to Centre Separation [100 ft/in] Travelling Cylinder Azimuth 90 -180 / 180 v6 Centre to Centre Separation [25 Win] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS CD3-127wp11 Sec MD Inc Azi TVD +W-S +E/-W Meg TFace VSec Target 14000.00 To 21001.00 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 0 3200 4200 4450 Ellipsoid Cob, 6450 7200 12200 14700 22700 24200 2 3 4 5 3330.00 3360.00 3760.00 4292.51 67.95 263.34 2486.84 -45.59-1614.19 67.50 262.49 2498.21 -49.01-1641.73 68.02 249.54 2650.17-138.32-1999.99 68.42 261.00 2848.35-263.73-2477.22 2.00 3.00 3.00 2.00 -150.00-888.52 -120.00-901.51 -90.00-1033.85 90.00-1204.84 -- m,om nm.a*:aLvxoa ro�1cm.+,zxron wm.rn+Y.az.ac vxm..a+ar.�z-ec 3200 3450 4450 4700 7200 8200 14700 17200 24200 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 1 pw,xxren ,w °u0°s zwm wwra«cuzac r 3450 3700 3950 3700 3950 4200 4700 5200 5700 52DO 5700 6450 8200 9200 10700 9200 172W 10700 19200 - 12200 21200 19200 25200 21200 26200 - 22700 26950 262DO 266950 27. 7 8 9 10 13589.35 14370.42 14370.42 15078.05 59.69 192.63 6470.00-2318.31-10481.59 66.60 192.63 6799.00 -30 8.91-10636.34 66.60 192.63 6799.00-3008.97-10636.34 83.11 173.29 6984.90-3685.32-10666.77 3.50 0.00 0.00 3.51 -113.70-4112.95 0.00-3905.34 0.00 3635.95 -51.45-3099.37 CD3-K 11Janl2 Heel 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00 3081.88 -Z. 12 13 14 15287.15 15952.00 21970.15 89.32 168.96 6999.78-3891.33-10635.33 89.32 142,36 7007.80-4491,62-10363.81 89.32 142.36 7078.90-9257.12-6689.14 4.00 4.00 0.00 -35.00-2912.59 .90.15-2265.11 0.00 3746.26 CD3-K 18Oct12 Toe -90/ a 0 / 360 I 0 / 360 LEGEND -180 / 180 cD3.112, CD3112. CD3112 V3 DD3114. 003-114, CD3.114 V14 CD3115. CD3115. CD3.115 VO CD3117 CD3.117, CO3-117 VO CD3118. CD3-118. CD3118 VO CD3119, CD3119. CD3119 VO CD3119, CD3119PB1, CD3119PB7 VO CD3119. CD3119PB1, CD3119PB1 (Rig S-p VO CD3-121. CA3121, CD3121 VD C03122, CD3122, CD3122 V0 13- CO3-123, CD3-123, CD3123 VO CD3124, CD3-124, C03124 VO CD3125, CD3125, CD3125 VO 90 CO3.125CD3125PB7, CD3-125PB1 VO CD3.125: CD3125PB1 (aunace), CD31251`81 (s a e CO3-127, CD3127PB1, CD3-127PB1 VO CD3128, CD3128, CD3128 VO DD3128,CD3-128(lnlemiediale), CD3128(k- edla CD3316, CD3316, CD3316 VO CD3-3 CD3318A, DD3316A VO CD3316, CD3316APB1,CD3316APB1 V0 CD3316. Nan: CD33168. CO3.316Bep01 V0 C113316, Nan: CD3316BST_Alp, CI)M1611ST_ Nan: CD3126, Plan: CD3126, CD3126np04 VO Nan: CD3129, Nan: CD3129, CD3129.p01 VO Nan: CD3130, Plan: C03130, CD3-130.pO3 VO Nan: CD3320, Plan: CD3.920, C03320.p09 VO 49- Neohelik 1, Neohehk 1, Nm"hk 1 VO CD3-127w 11 Travelling Cylinder Azimuth (TFO+AZI) [o] vs Centre to Centre Separation [100 ft/in] -60 / vo -90 / 270 1 VO VO -120 / -180 / 180 Azimuth (TFO+AZI) ['] vs Centre to Centre Separation [25 Win] CD3-127wp11 21000.00 To 21970.15 r� 1% To -� m+i..oi/lin.6m m em , c0>,zr..vn ,w� � wm.Fn.wuzsc i GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Ellipsoid Color 0 3200 4200 4450 6450 7200 12200 14700 22700 3200 3450 4450 - _- -- - 4700 7200 8200 14700 172DO 24200 3450 3700 4700 5200 8200 9200 17200 192DO 25200 3700 3960 5200 5700 9200 10700 19200 - -- 21200 26200 3950 42DO 5700 6450 10700 12200 212DO 22700 26950 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [I vs Centre to Centre Separation [100 ft/in] LEGEND SECTION DETAILS DECEMBER 03 2012 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 - 24200 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 - 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 - 26200 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 26950 9 13934.86 14370.42 66.60 192.63 6626.00-2618.91-105,18.94 66.60 192.63 6799.00-3008.97-10636.34 2.00 0.00 0.00-3905.34 0.00-3635.95 - 27450 10 11 12 15078.05 15098.05 1 5287. 15 83.11 173.29 6984.90 3685.32-10666.77 83.11 173.29 6987.30-3706.04-10664.45 89.32 168.96 6999.78 3891.33-10635.33 3.51 0.00 4.00 -51.45-3099.37 CD3-K 11Jan12 Heel 0.00 3081.88 -35.00-2912.59 13 15952.00 89.32 142.36 7007.80-4491.62-10363.81 4.00 -90.15-2265.11 14 21970.15 89.32 142.36 7078.90-9257.12-6689.14 0.00 0.00 3746.26 CD3-K 180c112 Toe CD3-112. CD3-112, C133412 V3 CD3114, C133-114, C136114 V14 CD3115, CA3-115, CD3115 VO CD3.117, CO3-117, C133.117 VO . 1C118 VOCCDD3118. C& D318, CD3-119 VO CD3.119, CO3-1191`81, CD3.119PB1 VO CD3-119, CM-119PB1, CD3-119PBi (Rip Sune1 CD3-121, CD3-121, CD3.121 VO C133-122, 0133-122, CD3.122 VO CD3.123, CD3-123, C133-123 VO CD3-124, CD3-124, CD3.124 VO CO3-125, CD3-125, CD3.125 VO C03125, CD3-125P81, CD3-125P81 VO CD3.125, CD3.125PB1 (eudace), CD3-125PB1 is C133-127, CD3-127PB1, CD3427P81 VO CD3-128, 033-128, CD3-128 VO CD3-126, CD3-128 (46ennediale). CD3-128 (nor CD3.316, CD3316, CD3316 VO C133316, C03316A, C133316A VO CD3316, CD3316APB1, CD3316APB1 VO CD3-316, Nan: CD331613. CD3316Bv Ol VO CD3-316, Nan: CD3316BST-,Mp, CD33168ST_. Nan: CM126, Plan: CD3.126, CD3-126wpD4 VO Nan: CD3-129, Pl.: CD3-129, CD3-129w901 VO Nan: CD3-130, Plan: CD3-130, CD3430wp03 VO Nan: CD3.320, Plan: CD3320, CD3320wpO9 VO Nechelik 1, Nechelik 1, Nechelik 1 VO CD3-127w 11 vo -90 / 270 �) VO -120 / 0 / 360 -180 / 180 Travelling Cylinder Azimuth (TFO+A71) [°] vs Centre to Centre 90 [25 Win] 1 10I 2/2/11 I CZ I DB I C.A.I UPDATED PER K110003ACS 111 I#/H/HI CZ I GD I C.A. I UPDATED PER K110003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE O/S EXIST WELL Y' X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3-X98 6,003,630.37 1 528 434.35 150' 54' 44.278" 7.3 12.5 CD3-X99 6,003,625.99 1,528,415.38 7 1" 150' 54' 44.833" 1 7' 7.3 12.8 CD3-301 6,003,621.33 1.528.395.58 7 17 " 150' 54' 45.411" 1 7.3 13.5 CD3-302 6,003,616.72 1,528,376.38 7 1 4" 150' 54' 45.972" 1377' 700' 7.3 13.2 CD3-303 6,003,612.52 1 528 356.72 7 5' 150' 54' 46.547" 1373' 719' 7.3 13.3 CD3-304 6,003,607.82 1.528.337.04 7 031" 150' 54' 47.122" 1368' 739' 7.3 13.4 CD3-3051 6.003.603.48 1,528,317.56 70' 150' 54' 47.691" 1363' 758' 7.3 13.6 CD3-106 6,003,599.43 1.528.298.37 4 " 150' 54' 48.252" 1359' 777' 7.3 13.4 CD3-107 6,003,594.38 1,528.278.93 70' 25' 08.890" 150' 54 48.820 1354' 797' 7.3 13.2 CD3-108 6,003,589.85 1,528,259.61 0' 42" 150' 54' 49.385" 1349' 816' 7.3 13.1 CD3-109 6,003,585.27 1,528,239.85 70' 25' 08.794" 150' 54 49.962 1344' 836 7.3 13.1 CD3-110 6.003.580.97 1,528,220.32 70' 25' 08.749" 150' 54 50.533 1339' 855' 7.3 13.0 CD3-111 6,003,576.13 1,528,201.08 70' 25' 08.699" 150' 54 51.095 1334' 874' 7.3 12.9 CD3-112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150' 54 51.676" 1330' 894' 7.3 13.1 CD3-113 6,003,567.62 1,528,161.38 70' 25' 08.609" 150' 54 52.255 1325' 914' 7.3 13.1 CD3-114 6,003,563.04 1,528,142.21 70' 25' 08.561" 150' 54 52.815 1320' 933' 7.3 13.3 CD3-115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150' 54 53.388 1315' 953' 7.3 13.2 CD3-316A 6,003,554.04 1,528,103.39 70' 25' 08.467" 150' 54 53.950' 1311' 972' 7.3 13.2 CD3-117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150' 54 54.516 1306' 991' 7.3 13.1 CD3-118 6 003 544.88 1,528,064.44 70' 25' 08.372" 150' 54 55.086 1301' 1011' 7.3 12.8 CD3-X19 6,003,540.17 1 528 044.86 70' ' 0 150' 54' 55.660" 1 7.3 12.8 CD3-X20 6,003,535.95 1,528,025.39 7 ' 0 .278" 150' 54' 56.229" 1 1' 1 7.3 12.6 CD3-X21 6,003,531.41 1.528.006.04 7 ' 08.230" 150' 54' 56.794" 7.3 12.5 CD3-122 6,003,527.00 1 527 986.67 70' .1 4" 150' 54' 57.360' 7.3 12.6 CD3-X23 6,003,522.43 1,527,967.12 7 .1 150' 54' 57.932" 77' 11 7.3 12.6 CD3-124 6,003,518.17 1,527,947.59 70' 5' 08.091" 150' 54' 58.502" 7.3 12.5 CD3-X251 6,003,513.62 1,527,927.89 70' ' 08.044" 150' 54' 59.078" 7.3 12.6 CD3-X27 6,003,504.45 1.527.889.34 7 7. 4 " 150' 55' 00.204" 7.3 12.6 CD3-X28 6,003,500.08 1,527.870.01 150' 55 00.769 7.3 12.6 CD3-X29 CD3-X30 CD3-X31 CD3-X32 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) ALPINE MODULE:CD30 UNIT: CD ConocoPhillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A-2 3-17-05 CE-CD30-111 1 2 OF 3 11 Apr -)n for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 9-7/8" x 11" Hole / 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight above 9.6 ppg. Flow Surface Formations checks during connections. Mud weight increase if >2000' TVD needed. Lost circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties and increased mud weight for trips. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density (ECD). Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight. No over Pressure pressured zones. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, and standard , well control practices. Employ mud scavengers. 6-1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Moderate Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7-5/8" shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density (ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 9.0 ppg. Check Pressure for flow during connections and if needed, increase , mud weight. Perform well control drills. Increase mud weight if needed. Hydrogen Sulfide gas Low HZS drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. CD3-127 wpl 1 fails major risk analysis with the plugged and abandoned exploration well Nechelik 1 and the abandoned CD3-127PB 1 intermediate hole. A tolerable collision worksheet and evaluation has been performed to mitigate close approach issues and risk. CD3-127 APD Page 13 of 17 Printed. 4-Dec-12 Ap m for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 The planned CD3-127 lateral hole fails major risk anti -collision requirements with the Nechelik-1 Exploration Well and also the CD3-127PB1. The CD3-127wpll path violates the major risk rules with Nechelik-1 between 21,027' - 21,033' MD and corresponding to measured depths of 6,575' - 7,600' MD on Nechelik 1 which has been plugged and abandoned. The CD3-127wpI I path violates the major risk rules with CD3-127PB1 between 3,300' - 3,376' MD and corresponding to measured depths of 3,300' - 3,376' MD on CD3-127PB1, and again between 7179' MD and corresponding to measured depths of 7,875 - 12,225' MD on CD3-127PB1 which has been plugged and abandoned. Intermediate Hole The greatest geological risk with the intermediate hole section is a possibly under pressured Nechelik sand due to production on the adjacent CD3-128 wellbore. A static bottom hole pressure will be measured in offset wells during the month of November 2012 to further evaluate predicted reservoir pressures for the CD3-127 wellbore. The rig crew must have heightened awareness when penetrating the Nechelik zone and be prepared for lost circulation mitigation measures. An additional risk associated with the section is hole stability with regards to the Kalubik shale. Mitigating this risk begins during the planning phase of the well, when the well path is optimized to reduce unnecessary steering and dog legs in the lower, unstable shale sections. To gauge the effectiveness of the drilling program, the rig crews are to monitor and record drilling parameters such as torque and drag, ECD, drilling losses, returns at the shaker, etc. If necessary, adjustments to the drilling strategy will be discussed with the drilling engineer / drilling superintendent and implemented as needed. The use of a reamer to open the hole to II" from 9 7/8" will be utilized; effectively increasing the annular space for running the 7-5/8" intermediate casing. Production Hole Faulting within the Nechelik reservoir is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Reservoir Summary The CD3-127 wellbore is expected to have three hydrocarbon bearing formations open once drilled to TD, creating an additional risk in this hole section. These formations and their associated depths and pressures are listed below: Formation SS TVD (ft) Predicted Fracture Gradient (EMW - ppg) Predicted Pore Pressure (EMW - ppg) Comments Qannik 3,975 12.50 9.0 No development in area, expect initial pressure Kuparuk C 6,793 12.50 9.0 Separate zone Sand static bottom hole pressure will be measured during November in CD3-118 to verify Kuparuk CD3-127 APD Page 14 of 17 Printed: 4-Dec-12 Apr m for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 predicted pressure Nechelik 6,936 12.50 8.0 2900 psi Sand predicted using the Nechelik model All three formations will be drilled overbalanced to mitigate well control risks. CD3-127 APD Page 15 of 17 Printed: 4-Dec-12 F tion for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 Attachment 3 — Well Schematic Colville River Field Updated 11/26/2011 CD3-127 Nechelik/Kuapruk Production Well Sperry Drilling Services CD3-127wp10 Completion I ; 15' Comdk ctor to ' 14' Upper Completion hLEL IM i# 1) Tubing Hanger 36' 38' Packer Fluic mix: 2) 4 T 12.8#.M IBT-Mad Tubing (2 jts), XO 1: E Ins- bited gill weight 3) 3-W 9.3 #t L-80 EUE-Mod Tubing t 35b KCI B•ine 4) Camco TRMAXX-5E SSSV (2.812' ID) 22017 1992' with 23 DCTtdD with control line to surface. a J l c ese--ac 5) 3-IA2 9.3 #tft L-60 EUE-Mod Tubing 6) 3-W x 1' Camco KBMG GLA1 w1 DV 585(Y 3400' 10-%" 45.5 ppf L-80 BTC-Mod 7) 3-W 9.3 #tk L-80 EUE-Mod Tubing Surface Casing 8) 3-% x 1' Camco KBMG GLM wi DV 11808, 5600, 3289' MD / 2450' TVp 9) 3-%" 9.3 #{,'ft L-80 EUE-Mod Tubing E cemented to surface 10) Camoo KBMG GLM (2.887' ID) wiDCK2 14.350' x' sk Pinned for 2500 psi casing to tbg shear 11) 3-Ya 9.3 Will L-80 EUE-Mod Tubing (2 joints) TOC a +t- 12) HES 2.813" X Profile 14450' x' li a? 8974' MD t 3635' TVD 13) 3-W 9.3 #4t L-83 El-E-Mod Tubing (1 joint) 14) 3-1h" X 7-W8" Baker Premier Packer 14500' x' Qannik Interval 15) 3-%' 9.3 *It L-e0 EUE-Mod Tubing (1 joint) Top +1- 7545' MD 1 4023' TVD 16) 3-W x I' Camco KBMG GL%1 wf DV 14560' x' 17) 3-VP 9.3 #,Ift L-W EUE-Mod Tubing (1 joint) ES Cementer 18) Baker "X" CMD sliding Sleeve 2.813" 146600' x' +1- 8097' MD 1 19) 3-b4 9.3 #Mt L-80 EUE-Mad Tubing 422T' TVfl 20) 3-W 9.3 IBT with 35' b3ast rings €, cross coupling fnxn 14641' to 14851' MD 21) 3-%" X 7-5d8" Baker Premier Packer 14950' x' 22) 3-W 9.3 #tR L-80 EUE-Mod Tub ng 1,1 joint) 23) HES -XN" 2.813" (2.75' NoGc) wi RHC plug 1500a x' 24'. 9.2 4tft L-23 EUE-Mod Tubing (1 joints 25' °ec91 ass=_moly 150(f0' 6" 3-V2" 9.3 ppf L-SC EUE M Lower Completion: Tm YD MM tubing run with Jet Lube 26) HRD Setting Sleeve wt 1C' Tie back extension 15000' t1948' Run'n'Seal pipe dope 27) Baker 5-1.2 W-A!o Flexlock Liner Hanger wisetting sleeve 15DIT x' 28) XO 5-'h" Hyc•il ?21 X 3-W SLHT 29) 3-Y<_" 9.3 Mt L-80 SLHT blank 3 frac sleevesiped pupstswell pckrs 30) Orange Peel Shoe with 3-1•':" 9.3# L-80 Box Up 22325' 707W to 15' Perfc•ations: TOC Calculated .d +'-144-_ %.10 4.- 12900' MD 8312' TVD 7 - 3 '/h" Frac Sleeves 2"-1.25" with pert pups Top Kuparuk C : o= o 14.449 PAD 6,829' o 0 ... _. _._ o a 7'-.,' D --- — — -------------- Top Nechelik 7-518" 29.7 ppf L-80 BTC Mod Casing at +1-14467' MD 16836' TVD 14,997 MD 16,974' T!D 7-518" 39.0 ppf L-80 HYD563 Casing tail 15078'MD16985'TVD to +l- 611811 Hole TD at 14467'MC16836'TVD at 21,970' MD I ° 7,079' TVD CD3-127 APD Page 16 of 17 /Nil ti 6 ( Printed: 4-Dec 12 tion for Permit to Drill, Well CD3-127 Saved: 4-Dec-12 Attachment 4 - Cement Summary 7-5/8" Casing Cement Job - 11" hole Size Cement from ports in an HES stage collar set 500' below the K2 interval to +/- 500' above the K2 interval with class G + additives @ 15.8 ppg. Assume 40% excess annular volume. K-2 Expected at 7,474.47' MD. Plug: (7,975' - 6,974') x 0.3425 ft3/ft x 1.40 (40% excess) = 479.98 ft3 in open hole Total volume = 479.98 ft3 => 410.24 Sx @ 1.17 ft3/sk System: 411 Sx Class G @ 15.8 PPG Cement 7-5/8" casing from 15,078.05' MD to 13,900 'MD (minimum 300' MD above the packer & minimum of 500' above the top of the Kuparuk) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the annular volume. Plug: (15,078' - 13,900') x 0.3425 ft3/ft x 1.40 (40% excess) = 564.85 ft3 in open hole 80' shoe track x 0.2392 ft3/ft x 1.0 (0% excess) = 19.14 ft3 Total volume = 564.85 ft3 + 19.14 ft3 = 583.99 ft3 => 499.18 Sx @ 1.17 ft3/sk System: 500 Sx Class G @ 15.8 PPG CD3-127 APD Page 17 of 17 Printed: 4-Dec-12 TRANSMITTAL LETTER CHECKLIST WELL NAME C1AU. PTD# � d l o c S ✓ Development Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: (�fowi%���2;�E�- POOL: Check Box for 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 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. Rev: 9/09/2011 WELL PERWft HE KLJST Field & Pool COLVILLE RIVER, FIORD OIL - 120120 PTD#:2110050 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: COLVILLE RIV FIORD CD3-127 Program DEV Well bore seg DEV / 1-OIL GeoArea 890 Unit 50360 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 372105; top prod interval in ADL 025526; 3 Unique well name and number Yes TD in ADL 025538. 4 Well located in a defined pool Yes COLVILLE RIVER, FIORD OIL - 120120, governed by CO 569 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 569 contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 569 has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 569 has no interwell spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included Yes external property line where ownership or landownership changes. 9 Operator only affected party Yes Well lies entirely within Colville River Unit. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 12/11/2012 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers. AIO 30.. Conclusion 3 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie-in long string to surf csg No Intermediate casing TOC at 13900'md. ( 1st stage is 500 ft above Kuparuk) 22 CMT will cover all known productive horizons Yes Qannik to be isolated with 2nd stage in Intermediate casing. 23 Casing designs adequate for C, T, B & permafrost Yes (production section will 3.5" uncemented liner with swell packers and frac sleeves. ) 24 Adequate tankage or reserve pit Yes Rig has steel pits. All waste to approved disposal wells. 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Close crossing with CD3-117. 75' from elipses. 27 If diverter required, does it meet regulations NA Wellhead is in place from previous drilling on this PTD. Surface casing is set and kickoff plug is at shoe. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation press= 2945 psi (8.0 ppg EMW) Will drill with8.8-10 ppg mud GLS 12/14/2012 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2237 psi Will test BOP to 3500 psi 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No No H2S on CD3. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S and gas detectors will be used during drilling. Mitigation measures in Hazards Geology 36 Data presented on potential overpressure zones Yes Anticipated reservoir pressure is 8.02 ppg EMW; will be drilled with 8.8 -9.0 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 12/11/2012 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering lic Revision of PTD due to adding Kuparuk C sand in the completion (will straddle C sand with packers). Will kick off from cement Date: Date Date Commissioner: PI/ Co�m,�, loner: Co plug set at surface casing shoe to sidetrack well away from collapsed section on intermediate hole. GIs STATE OF ALASKA AU OIL AND GAS CONSERVATION COM, 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r- Repair w ell r- Plug Fiarforations Perforate r Other " Alter Casing r Pull Tubing r- Stimulate - Frac Waiver r Time Extension r Change Approved Program ]` 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 Stratigraphic r Exploratory Service r 211-005 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20634-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, 025538, 25526 CD3-127 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 15261 feet Plugs (measured) 3039 true vertical 6978 feet Junk (measured) None Effective Depth measured 3039 feet Packer (measured) 3441 true vertical 2384 feet (true vertucal) 2527 Casing Length Size MD TVD Burst Collapse Conductor 77 16" 114 114 Surface 3202 10.75" 3239 2453 RECEIVED MAY 2 42012 Perforation depth: Measured depth: none True Vertical Depth: none AOGCC Tubing (size, grade, MD, and TVD) 3.5" kill string, L-80, 2176' MD, 2014' TVD Packers & SSSV (type, MD, and TVD) no Packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 not applicable Subsequent to operation not applicable 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r' Stratigraphic Well Status after work: Oil r- Gas I— WDSPL r- Daily Report of Well Operations _XXX rGSTORj"""" WINJ r WAG r GINJ r- SUSP r✓ SPLUG r- 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312-101, 312-166 Contact J. G. Samuel[ 265-630 Printed Name J.G. S muell jJ - Title Senior Drilling Engineer Signature Phone: 265-6309 Date %DMS MAY 2 4 2012 0- r� Form 10-404 Revised 11/2011 �� h �� Submit Original Only WNS CD3-127 cmloco 'l fillips Well Attributes IMaxAnqle&MD TD Alaska Ifu- Wellbore API/UWI Field Name Well Status Incl (°) MD (RKB) Act Bt. (RKB) 501032063400 FIORD NECHELIK PROD 83.42 15,231.51 Comment H2S (ppm) Date Annotation End Date K8-Ord (ft) Rig Release Date SSSV: Last WO: 36.30 Well Cor :HORIZONTAL-CD3-127523120129:19:31AM schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod... End Date Last Tag: Rev Reason: WELL SUSPENDED ninam 5/23/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third CONDUCTOR 16 14.688 36.0 114.0 114.0 109.00 1 H-40 WELDED --_- --- Casing Description String 0... String ID ITop(ftKB) ISet Depth (I Set Depth(TVD)... String Wt... String... String Top Third SURFACE 103/4 9.950 1 35.9 1 3,239.2 1 2,453.4 45.50 L80 BTCM HANGER, 31 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth if... Set Depth (TVD) ... String Wt... String ... String Top Third TUBING 3112 2.992 30.9 2,176.0 2,014.4 9.20 L-80 EUE Com lotion Details XO Reducing. Top Depth 35 (ND) Top Incl No I. - Top (RKB) (ftKB) (°) Item Description Comment ID (in) Nireline retrievable Top Intl CONDUCTOR, 36-11 a 3,441 2,527.3 68.18 ECP Ran ISO zone ECP, for cement plug, 4282012 2.43C Comm no. 301-39-5306, Ran Weatherford 7 5/8 Boat shoe w/ centralizer (straight blade 91/8) 9.24 pup Cement Squeezes Top Depth Btm Depth (ND) (ND) To ftKO) St. RKB (RKB) (NCB) Description Start Date Comment w�Ec, z.n6 3,039.0 3,439.2 2,383.5 2,526.7 Cement Plug 3/5/2011 KOP 3,039.0 3,441.0 2,383.5 2,527.3 Cement Plug 428/2012 Abandenmont/kickoff plug. Dowell mix mud push to 11.5 ppg. Dowelll pump .6 bbl, pressure test lines to 3000 psi. Dowell continue to pump a total of 23.1 bbls of mud push @ 4.5 bpm w/ 250 psi final pressure. Dowell mix 17 ppg cement. Pumping 17 ppg cement (yield 1 cuf 1sx, water 3.87 gal/sx, additives D046.2 h BWOC, D065 1.0 BWOC, D167 .2 BWOC, thickening time 5 hr 26 min) @ 4.7 bpm w/ 860 psi initial pressure and 4.3 bpm w/ 600 psi final pressure. Pumped a total of 84.2 bbls, 473 sx, follow w/ 3.6 bbls (2.6 bbls in the pipe) of 11.5 ppg mud push. Rig displace w/ 9.6 ppg LSND mud pumping 6 bpm till caught up w/ cement. Took 13 Dials to catch cement. Reduced rate to 4 bpm w/ 220 psi. Pumped 21.5 bbls to balance cement (cut 5 bbls short). Shut down, check valves and well balanced. Full returns through -out job. Shut down @ 0012 hrs 4/2W2012. , KILL SURFACE, 36-3,239 Cement Plug, 3.039 Cement Plug. 3.039 ECP, 3,441 Cement Plug, 7,269 Cement Plug, 7,344 Cement Plug. 13,207 TO. 15,261 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:15 05:45 0.50 3,138 3,128 INTRM1 DRILL PRTS XT P/U to 3,128' MD and Pressure Test CIBP and Surface Casing t/ 2500 Psi f10 Minutes (Lost 0 Psi) 05:45 06:00 0.25 3,128 3,128 INTRM1 DRILL RURD XT Open Rams, R/D Pressure Testing Manifold and Blow Down Kill Line 06:00 07:45 1.75 3,128 0 INTRM1 DRILL TRIP XT POOH - Lay down running tool - clean up rig floor 07:45 08:15 0.50 0 0 INTRM1 DRILL OTHR X Pull wear ring and set test plug with 3 1/2" test joint 08:15 09:30 1.25 0 0 INTRM1 WHDBO BOPE X Test annular preventor to 250 / 2500 psi - test top pipe rams to 250 / 3500 psi - pull test plug and set retrievable wear bushing 09:30 10:00 0.50 0 0 INTRM1 RPCOM RURD XT PJSM - change running tools to 3 1/2" - RU tubing tongs 10:00 11:30 1.50 0 2,142 INTRM1 RPCOM TRIP XT RIH with 3 1/2", 9.2#, L-80 tubing to 2142' 11:30 12:00 0.50 2,142 2,142 INTRM1 RPCOM OTHR X RD tubing tongs - change running tools to 5" 12:00 12:30 0.50 2,142 3,128 INTRM1 RPCOM TRIP X RIH with 5" drill pipe from 2142' to 3128' 12:30 12:45 0.25 3,128 3,128 INTRM1 RPCOM SFTY X PJSM on displacing well to brine 12:45 15:00 2.25 3,128 3,128 INTRM1 RPCOM CIRC X Displaced well with 150 bbls of fresh water, 150 bbls of 9.6 ppa Nacl brine, 1.50 b b I q 0f 9.6,ppg._Na l bring -with corrosion rnhibitor 20 bbls of 10 ppg nacl brine - hole cleaned up well. 15:00 15:30 0.50 3,128 2,145 INTRM1 RPCOM TRIP X POOH to 2145' 15:30 16:00 0.50 2,145 2,154 INTRM1 RPCOM RURD X R/U Tubing Handling Equipent - Pull Wear Ring 16:00 17:00 1.00 2,154 2,180 INTRM1 RPCOM HOSO X M/U Tubing Hanger w/TWC Installed - Land w/ Tail @ 2,180' MD 17:00 18:00 1.00 2,180 2,180 INTRM1 WHDBO PRTS X Test Hanger Seals U 5000 Psi f/ 10 Minutes 18:00 18:30 0.50 2,180 2,180 INTRM1 WHDBO PRTS X R/U Hard Lines and Test TWC in Direction of Flow U 2500 Psi f/ 10 Minutes 18:30 19:00 0.50 2,180 0 INTRM1 WHDBO RURD X R/D Hard Lines and UD Landing Joint B 19:00 22:00 3.00 0 0 INTRM1 WHDBO NUND X N/D Riser and BOPE Stack 22:00 23:00 1.00 0 0 INTRM1 WHDBO NUND X N/U Tree 23:00 23:30 0.50 0 0 INTRM1 WHDBO PRTS X Test Hanger Top Seals t/ 5,000 Psi f/ 10 Minutes - Test Tree t/ 5000 Psi f/ 10 Minutes 23:30 00:00 0.50 0 0 INTRM1 DRILL RURD X Pull TWC - R/U Hard Lines and Manifold to Freeze Protect 3/08/2011 LDDC's. Install BPV. Secure well for move off to next well. Release rig at 06:00 hrs. 00:00 00:45 0.75 0 0 INTRM1 DRILL RURD X Continue to R/U to Freeze Protect Well 00:45 01:00 0.25 0 0 INTRM1 DRILL SFTY X PJSM on Freeze Protect 01:00 03:00 2.00 0 0 INTRM1 DRILL FRZP X Freeze Protect Well w/ 155 Bbls Diesel - Allow to U-Tube Across Manifold Page 22 of 31 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 04:00 1.00 0 0 INTRM1 DRILL RURD X Blow Down and Rig Down Hard Lines and Manifold - Clean Cellar & Pits 04:00 04:30 0.50 0 0 INTRM1 WHDBOOTHR X Set BPV w/ FMC Lubricator 04:30 05:00 0.50 0 0 INTRM1 DRILL PULD X Install Mouse Hole - UD Drill Collars. 05:00 06:00 1.00 0 0 INTRM1 DRILL RURD X Secure well. Pump out cellar. Release rig for move to CD3-125. 4/24/2012 Move rig from CD3-119 to_C_D3-127, Rig acceptance @ 1500 HES 4-24-2012 -RU, pull BPV,�displace out diesel freeze protection to 9.6 brine, PSI test casing to 3500 psi, set BPV, test BPV, 00:00 01:00 1.00 0 0 INTRM1 MOVE MOB P Move MI Swaco ball mill away from rig. Rig is on CD3-119, moving 160' to CD3-127. Sim ops: Pre job safety meeting, then prepare pits and motors to move away from rig. Jacking pipe shed to move away. Cleaning drip pans. 01:00 01:15 0.25 0 0 INTRM1 MOVE SFTY P PJSM, Rig Move 01:15 01:30 0.25 0 0 INTRM1 MOVE RURD P Continue working to ready pipe shed and its/motors. 01:30 02:00 0.50 0 0 INTRM1 MOVE MOB P Move pits/motors away from sub. 02:00 03:30 1.50 0 0 INTRM1 MOVE RURD P Skid rig floor, raise windwalls, raise feet. 03:30 06:45 3.25 0 0 INTRM1 MOVE MOB P Pull Sub off CD3-119, move and spot Sub on CD3-127. 06:45 07:15 0.50 0 0 INTRM1 MOVE RURD P Lower and set feet, lower and secure windwalls. 07:15 08:15 1.00 0 0 INTRM1 MOVE RURD P PJSM and skid floor to drilling position. 08:15 09:15 1.00 0 0 INTRM1 MOVE MOB P PJSM and spot pits and motor complexes. 09:15 12:00 2.75 0 0 INTRM1 MOVE MOB P Spot pipe shed and ball mill. RU service lines 12:00 15:00 3.00 0 INTRM1 MOVE MOB P PJSM, r/u service lines, rig up hard lines to tiger tank and test lines with air, take on water to rig. Rig acceptance 1500 hrs 4/24/2012 15:00 17:00 2.00 INTRM1 RIGMNT RGRP T trouble shoot electrical & change out braker f/ generator # 3 and cold start. change out fuseable link on engines #3and 4 17:00 18:00 1.00 INTRM1 WHDBO RURD P PJSM, pull tree cap, and rig up FMC lubricator 18:00 18:15 0.25 INTRM1 WHDBO PRTS P Test lubricator @ 2500 psi, for 5 min, pull BPV 18:15 18:45 0.50 INTRM1 WHDBO PRTS P PJSM, Test lines to tiger tank @ 500 psi, blow lines down w/air 18:45 19:15 0.50 INTRM1 WHDBO PRTS P Test lines U well head (TBG side) @ 2000 psi for 5 min. Page 23 of 31 Time Logs Date From To Dur S. De th E. DeDth Phase Code Subcode T Comment 19:15 21:45 2.50 INTRM1 RPCOM CIRC P PJSM, Displace diesel w/ 41 bbls safe surf- o, 229 bbls 9.6 ppg brine, @ ICP = 1160 psi - FCP = 7.5 BPM / 2020 PSI change 2 chik-sans on hard line due to failure, and ran steam through hard line, check all unions 21:45 22:00 0.25 INTRM1 RPCOM CIRC P Shut in annulas and B/D lines 22:00 22:45 0.75 INTRM1 RPCOM DHEQ P PJSM, Test casing @ 3500 psi, F/ 30 min, 4 bbl T/ pressure up, 2.5 bbls back to pits 22:45 23:15 0.50 INTRM1 RPCOM RURD P B/D hard line to TBG & R/D 23:15 23:30 0.25 INTRM1 WHDBOTHGR P Set „BPV 23:30 00:00 0.50 INTRM1 RPCOM THGR P Test BPV T/ 1000 psi, F/ 10 min Pump down annulas 4/25/2012 Observe well static, ND tree NU BOP's, body test BOP's, LD�3.5" kill_strina. test BOPE. MU 9-7/8" clepn .W- ass 00:00 00:15 0.25 0 0 INTRM1 RPCOM THGR P Continue test BPV to 1000 psi for 10 min in direction of flow. 00:15 01:00 0.75 0 0 INTRM1 RPCOM OWFF P Observe well for 30 min, static. 01:00 03:30 2.50 0 0 INTRM1 WHDBO NUND P ND tree, install FMC blankingplug, NU BOP's, ti hten choke line. 03:30 06:15 2.75 0 0 INTRM1 WHDBO PRTS P RU, fill stack, shell test BOP stack 250/3500 psi for 5 min. Test gas alarms. 06:15 06:30 0.25 0 0 INTRM1 WHDBOTHGR P Pull FMC blanking plug, pull BPV. 06:30 07:00 0.50 0 0 INTRM1 RPCOM RURD P RU to pull 3-1/2" tubing kill string. 07:00 09:15 2.25 2,179 1,611 INTRM1 RPCOM PULD P PJSM and pull Hgr free with 82K (80K string wt) LD 3-1/2" tubing kill string from 2179'. 09:15 09:30 0.25 1,611 1,611 INTRM1 RPCOM RURD P Change out power tongs. 09:30 11:30 2.00 1,611 0 INTRM1 RPCOM PULD P Continue LD 3-1/2" tubing kill string. 68 Jts total. 11:30 12:30 1.00 0 0 INTRM1 RPCOM RURD P RD Tbg equipment, observe well static. 12:30 13:30 1.00 0 0 INTRM1 WHDBO RURD P Change out elevators, install Dbl valve on annulus, drain stack, clear floor. 13:30 14:00 0.50 0 0 INTRM1 WHDBO RURD P PJSM and RU for BOP test. Page 24 of 31 Time Logs Date From To Dur S. De th E. DeDth Phase Code Subcode T Comment 14:00 20:45 6.75 0 0 INTRM1 WHDBO PRTS P Install test plug- RU to test BOPE - Tested BOPE as follows: Tested annular to 250 & 2500 psi - 3.5" x 6" pipe rams - choke & kill lines - choke manifold valves - TD IBOP's - floor safety & dart valves to 250 & 3500 psi - performed accumulator recover test - Pulled 4" test jt. - Tested blind rams to 250 & 3500 psi - Perform Koomey test - MU 3 1/2" test jt - Tested pipe rams to 250 & 3500 psi - Tested annular to 250 & 2500 psi LD 3 1/2" test jt. - Tested manual & hydraulic chokes - Witnessing of test waived _by Lou Grimaldi_AOGCC 20:45 21:15 0.50 0 INTRM1 WHDBO PRTS P Pull test plug, drain stack and install W/R ( 10.3 ID) 21:15 21:30 0.25 INTRM1 WHDBO PRTS P B/D choke and kill lines 21:30 22:00 0.50 INTRM1 RPCOM OTHR P PJSM, Move DP F/ ODST/ DS ( 14 stds) 22:00 00:00 2.00 INTRM1 RPCOM PULD P M/U BHA as per detail T/192' 4/26/2012 M/U clean -out assy, RIH, tag bridge plug at 3137', displace to 9.6 ppg LSND mud, drill bridge plug, safety stand down, cont drill bridgepluq ream/ push retainer to 3544' pgTRNP sweep around and condition mud, BROOH into casing, circ hole clean, Pump out of hole, LD BHA, P/U stack wash tool and wash out stack. 00:00 01:45 1.75 0 781 INTRM1 DRILL PULD P PJSM and continue MU BHA as per Sperry DD to 781'. 01:45 03:45 2.00 781 3,137 INTRM1 DRILL TRIP P RIH with 4" DP from derrick. Tag bridge plug at 3137'. PUW = 115K, SOW = 107K. 03:45 04:45 1.00 3,137 3,137 INTRM1 DRILL CIRC P PJSM and displace well from 9.6 ppg brine to 9.6 ppg LSND mud with 35 bbls high vis spacer and 284 bbls mud at 650 gpm at 1220 psi, 30 rpm at 6K torque. 04:45 06:15 1.50 3,137 3,137 INTRM1 DRILL DRLG P Drill on bridge plug with 650 gpm at 1250 psi, 120 rpm at 6.51K torque. 06:15 06:45 0.50 3,137 3,137 INTRM1 DRILL SFTY P PU 30', blow down top drive, flow check static. Safety stand down meeting. 06:45 07:45 1.00 3,137 3,163 INTRM1 DRILL DRLG P Continue drilling bridge plug from 3137'. 650 gpm at 1260 psi, 140 rpm at 7.51K torque. Through at 3138'. Continue to push and ream remainder of retainer to stand down at 3163'. 07:45 08:00 0.25 3,163 3,228 INTRM1 DRILL TRIP P Attempt RIH, took 10k weight at 3228'. 08:00 11:00 3.00 3,228 3,544 INTRM1 DRILL REAM P Ream from 3228' to 3544'. 650 gpm at 1320 psi, 120-140 rpm at 7.5 to 9.51K torque, 15-20K WOB. (Safety stand down with second crew at re -tour meeting) 11:00 12:00 1.00 3,544 3,544 INTRM1 DRILL CIRC P Pump 33 bbl high vis nut plug caliper sweep around. 750 gpm at 1910 psi, sweep back 20 bbls early. Cont circ and condition mud. Page 25 of 31 Time Logs Date From To Dur S. De th E. De th Phase cod T Comment 12:00 12:45 0.75 3,544 3,067 INTRM1 DRILL REAM P BROOH to shoe at 3239', continue backreaming to 3067' to clean up. (Dropped hollow 2-3/8" drift at 3449') 750 gpm at 1990 psi, 140 rpm at 8.51K torque. 12:45 14:00 1.25 3,067 3,067 INTRMI DRILL CIRC P Flow check static, circulate and clean up casing. Took 4.5 bottoms up to clean up clay cuttings. 750 gpm at 1790 psi, 140 rpm at 8K torque. 14:00 15:00 1.00 3,067 2,781 INTRM1 DRILL TRIP P POOH on trip tank three stands. Observed 25K overpull at 2826', slacked off and PU overpull gone. Insufficient hole fill. 15:00 19:45 4.75 2,781 229 INTRM1 DRILL TRIP P Flow check static, Pump OOH to Jars. 22 bbls calc hole fill, 35 bbls actual. 19:45 20:15 0.50 229 INTRMI DRILL TRIP P C/O elevators, B/D top drive, line up on TT 20:15 20:30 0.25 INTRM1 DRILL TRIP P PJSM, UD BHA 20:30 21:00 0.50 INTRM1 RIGMNT SVRG P Service rig 21:00 22:45 1.75 INTRM1 DRILL TRIP P Continue laying down BHA 22:45 23:00 0.25 INTRM1 DRILL OTHR P Change out elevators and M/U stack washer on std of drill pipe 23:00 00:00 1.00 INTRM1 DRILL OTHR P Wash out stack @ 16 BPM - 120 PSI, B/D top drive 4/27/2012 Wash out stack, RU, PJSM, RIH w/ 7-5/8" ECP on 3.5" EUE tubing,R/D_tubing-tools, MU x-o, RIH-on 4" dp to 2883', hanging up, attempt work past, no go, POOH to tubing, repair Dwks/dynomatic linkage, POOH w/ ECP, MU and RIH with Baker clean -out ass . 0000 00:15 0.25 INTRM1 PLUG SFTY P Pre job safety meeting. 00:15 00:45 0.50 INTRM1 PLUG OTHR P Clean and clear rig floor. 00:45 01:15 0.50 INTRM1 PLUG RURD P Change elevators, rig up 3.5" tubing equipment. 01:15 01:30 0.25 INTRM1 PLUG SFTY P Pre job safety meeting on running Baker 7-5/8" External casing packer on 3.5" 9.3 ppf L-80 EUE tubing and 4" drill pipe. 01:30 04:30 3.00 0 939 INTRM1 PLUG TRIP P Pick up/ Make up Baker 7-5/8" IsoZone exernal casing packer on 3.5" 9.3 ppf L-80 EUE tubing (29 jts) Fill every jt from the top. PU wt 76k, SO wt 77k, blocks 72k. 04:30 04:45 0.25 939 939 INTRM1 PLUG SFTY P Pre job safety meeting. 04:45 05:00 0.25 939 939 INTRM1 PLUG RURD P Rig down3.5" equipment, rig up 4" elevators. 05:00 07:00 2.00 939 2,843 INTRM1 PLUG TRIP P Make up 4" XT39 x 3-1/2" EUE crossover. Run 7-5/8" Baker ECP in the hole f/ 939' to 2843' on 4" drill pipe. Work past obstruction from 2748' to 2843' with out pump, no over pull. Appears pushing some junk. Page 26 of 31 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:00 08:00 1.00 2,843 2,883 INTRM1 PLUG TRIP P Wash/work down from 2843' to 2883'. 42 gpm at 140 psi, 126 gpm at 190 psi. No success pushing or getting past junk. 08:00 08:15 0.25 2,883 2,843 INTRM1 PLUG TRIP P POOH, Stand back stand w/o pump, 25K overpull at 2873'. Pick up 100k Down wt. 100K 08:15 12:45 4.50 2,843 912 INTRM1 PLUG TRIP P Blow down TD, flow check static, POOH on elevators from 2843' to 912'. 20K overpull at 2730'. 12:45 13:00 0.25 912 912 INTRM1 PLUG RURD P RU to stand back 3.5" tubing. 13:00 17:00 4.00 912 912 INTRM1 PLUG RGRP T PJSM and repair drawworks 17:00 19:30 2.50 912 0 INTRM1 PLUG TRIP P PU single 3.5" tubing and rack back 10 stds tubing. LD ECP. Lots of clay on ECP, recovered alot more slip segments stuck to clay. ECP rubber had a deep slice over a couple feet. Calc disp = 19.8 bbls, Act disp = 21 bbls. Pictures are posted on S drive, in CD3-127 folder 19:30 20:00 0.50 0 0 INTRM1 PLUG RURD P Clean and clear floor, PU Baker BHA equipment to floor. 20:00 21:30 1.50 0 0 INTRMI PLUG PULD P PU Baker BHA equipment to floor. 21:30 21:45 0.25 INTRM1 PLUG SFTY P PJSM on picking up BHA 21:45 22:45 1.00 INTRM1 PLUG PULD P Pick up BHA 22:45 23:00 0.25 INTRM1 PLUG SFTY P PJSM 23:00 23:45 0.75 INTRM1 PLUG RURD P C/O elevators & continue picking up BHA 23:45 00:00 0.25 INTRM1 PLUG RURD P C/O iron roughneck heads 4/28/2012 RIH w/ Baker Jet/Boot Bskts/Scpr to 3501', POOH to 3102', pump weighted sweep around, POOH to 2816'. RIH to 3501' to ensure clean, POOH to 3198', pump weighted sweep around, POOH LD BHA, Run new 7-5/8" ECP packer to 3467' shoe depth, top @ 3441' top of external casing packer. Dowell pump cement job, rig dis lace w/ 9.6 ppg mud. 00:00 02:00 2.00 338 2,721 INTRM1 PLUG TRIP P RIH w/ Baker rev circ junk basket from 338' to 2721', brk circ every 5 stds. 02:00 02:30 0.50 2,721 2,721 INTRM1 PLUG CIRC P CBU at 650 gpm, 800 psi, PUW = 110K, SOW = 100K 02:30 02:45 0.25 2,721 2,936 INTRM1 PLUG TRIP P Continue RIH f/ 2721' to 2936', taking 10-15K weight. 02:45 05:45 3.00 2,936 3,501 INTRM1 PLUG TRIP P Wash down f/ 2911' to 3501', taking weight. 650 gpm at 820 psi, PUW = 115K, SOW = 110K Taking weight @ 2941', 2944', 3038', 3072', 3362', 3387' and 3501' 05:45 06:30 0.75 3,501 3,102 INTRM1 PLUG TRIP P Pump OOH from 3501'to 3102'. 6 bpm at 280 psi. 06:30 07:00 0.50 3,102 3,102 INTRM1 PLUG CIRC P Pump 30 bbl weighted (11.9 ppg) high vis NP( 5 sx) sweep around. 750 m at 1280 psi, 20 rpm at 7K tq. Page 27 of 31 Time Logs Date From To Dur S. De th E. DeDth Phase Code Subcode T Comment 07:00 07:30 0.50 3,102 2,816 INTRM1 PLUG TRIP P Flow check static, POOH on trip tank from 3102' to 2816'. 07:30 08:30 1.00 2,816 3,501 INTRM1 PLUG TRIP P RIH from 2816' to 3501'. All good. 08:30 08:45 0.25 3,501 3,198 INTRM1 PLUG TRIP P POOH on trip tank from 3501' to 3198'. PUW = 120K, SOW = 105K 08:45 09:30 0.75 3,198 3,198 INTRM1 PLUG CIRC P Pump 31 bbl weighted (11.6 ppg) high vis NP ( 5 sx) sweep around. 750 gpm at 1280 psi, 20 rpm at 7.5K tq. 09:30 12:30 3.00 3,198 338 INTRM1 PLUG TRIP P Blow dwn TD, flow check static, POOH on trip tank from 3198' to 338'. 12:30 14:15 1.75 338 0 INTRM1 PLUG PULD P Flow check static, PJSM, LD BHA (Std back 3 stds 5" HWDP) 14:15 15:30 1.25 0 0 INTRM1 PLUG RURD P Clean and clear floor, RU to run 3.5" tubing. 15:30 15:45 0.25 0 0 INTRM1 PLUG SFTY P PJSM 15:45 16:00 0.25 0 30 INTRM1 PLUG PULD P MU Baker 7-5/8" ECP 16:00 17:15 1.25 30 907 INTRM1 PLUG TRIP P RIH w/ ECP on 29 jts 3.5" tubing cement stinger from derrick. LD single. 17:15 17:30 0.25 907 907 INTRM1 PLUG RURD P Change out elevators 17:30 20:15 2.75 907 3,432 INTRM1 PLUG TRIP P RIH w/ ECP with 22 stds 4" DP from derrick, 15' pup and 4 more stds 4" DP to 3432' 20:15 20:30 0.25 3,432 3,467 INTRM1 PLUG TRIP P PU 2 singles 4" DP and place ECP on de th, bottom at 3467' 20:30 20:45 0.25 3,467 3,467 INTRM1 PLUG CIRC P Circulate pipe volume. 2 bpm at 160 psi, 4 bpm at 210 psi, 5 bpm at 240 psi, 36 bbls total 20:45 21:15 0.50 3,467 3,467 INTRM1 PLUG CIRC P Brk pipe and insert DP pump down plug. Pump down at 2 bpm, 140 psi, reduced rate to 1 bpm, 110 psi 5 bbls before calc latch. Latched up wiper plug with 370 psi indication 4.5 bbls late, pumped 1 more bbl to bump plug with 500 psi. 21:15 22:00 0.75 3,467 3,441 INTRM1 PLUG PACK P Inflate Baker 7-5/8" ECP: Stage pressure up from 1000 psi at 200 psi increments. At 1920 psi, pressure drop to 1420 psi indicated packer inflation. Increased pressure back to 1920 psi with .25 bbls indicating packer inflated to 10.375" hole size. Bled of all pressure to close pkr valve. Pressure back up and successfuly release from packer with 2900 psi. Left shoe at 3467', bottom of element at 3455', top of element at 3445' and top of assy at 3441'. 22:00 22:30 0.50 3,441 3,439 INTRM1 PLUG RURD P LD single 4" DP, blow down top drive, RU cement lines. 22:30 23:15 0.75 3,439 3,439 INTRM1 PLUG CIRC P Circulate and condition mud at 5 bpm, 150 psi. 23:15 23:30 0.25 3,439 3,439 INTRM1 PLUG SFTY P PJSM on cement job. Page 28 of 31 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:30 00:00 0.50 3,439 3,439 INTRM1 PLUG CMNT P Dowell mix mud push to 11.5 ppg. Dowelll pump .6 bbl, pressure test lines to 3000 psi. Dowell continue to pump a total of 23.1 bbls of mud push @ 4.5 bpm w/ 250 psi final pressure. Dowell mix 17 ppg cement. Pumping 17 ppg cement (yield 1 cuft/sx, water 3.87 gal/sx, additives D046 .2% BWOC, D065 1.0 BWOC, D167 .2 BWOC, thickening time 5 hr 26 min) @ 4.7 bpm w/ 860 psi initial pressure and 4.3 bpm w/ 600 psi final pressure. Pumped a total of 84.2 bbls, 473 sx, follow w/ 3.6 bbls (2.6 bbls in the pipe) of 11.5 ppg mud push. Rig displace w/ 9.6 ppg LSND mud pumping 6 bpm till caught up w/ cement. Took 13 bbls to catch cement. Reduced rate to 4 bpm w/ 220 psi. Pumped 21.5 bbls to balance cement (cut 5 bbls short). Shut down, check valves and well balanced. Full returns through -out job. Shutdown @ 0012 hrs 4/29/2012. 4/29/2012 RD Cmt line, pull out of cement plug to 3039', circ out 25 bbls excess cement with wiper ball and 20 bbls water to clean pipe, displaced to 9.7 ppg brine, spotted inhibited brine, POOH sideways, LD pipe from derrick, slip and cut drlg line, ran 3.5" tubing kill string to 2176.07', tested hanger seals WOC. 00:00 01:00 1.00 3,439 3,039 INTRM1 PLUG TRIP P RD, blow down lines, POOH from 3439' to 3039'. 108K Up, 103K Dwn. 01:00 03:30 2.50 3,039 3,039 INTRM1 PLUG CIRC P Load wiper plug, pump 20 bbls water and circ at 650 gpm 1170 psi to clean pipe. Observed mud push and 25 bbls excess cement returned to surface. 03:30 05:00 1.50 3,039 3,039 INTRM1 PLUG CIRC P PJSM and displace to 9.7 ppg brine as follows: Pumped 34 bbls hi vis spacer followed with 340 bbls 9.7 ppg brine followed with 72 bbis inhibited 9.7 ppg brine, spot on bottom. 550 gpm at 1040 psi. 05:00 08:30 3.50 3,039 313 INTRM1 PLUG PULD P POOH laying down 4" DP and 3.5" cement string/ECD running tool. 08:30 08:45 0.25 313 313 INTRM1 PLUG SFTY P H2S drill - Alarm sounded, rig evacuated, determined false alarm. 08:45 09:15 0.50 313 0 INTRM1 PLUG PULD P Cont LD 3.5" cement string to shed. 09:15 09:45 0.50 0 0 INTRM1 PLUG RURD P RD Tbg equip, clear floor. 09:45 10:30 0.75 0 0 INTRM1 WHDBO RURD P Pull wear ring, install tubing running wear ring. 10:30 12:45 2.25 0 0 INTRM1 PLUG PULD P PJSM and LD tubulars from derrick: 5" HWDP and 4" DP VIA mousehole. 12:45 14:00 1.25 0 0 INTRM1 RIGMN7 SLPC P PJSM and slip and cut 60' drilling line. 14:00 14:45 0.75 0 0 INTRM1 RIGMNi SVRG P Service top drive, drawworks and iron roughneck. Page 29 of 31 Time Logs Date From To D r S. De th E. De th Phase Code Subcode T Comment 14:45 15:15 0.50 0 0 INTRM1 RPCOM RURD P RU to run 3.5" kill string. 15:15 18:00 2.75 0 2,139 INTRM1 RPCOM PULD P PJSM and run 68 jts, 3.5", 9.2#, L-80 tubing kill string to 2139'. 85K Up, 85K dwn. 18:00 18:45 0.75 2,139 2,139 INTRMI WHDBO RURD P MU retrieval tool and retrieve wear ring. 18:45 19:30 0.75 2,139 2,176 INTRM1 RPCOM HOSO P MU tubing hanger with TWC installed. Land with tail at 2176' MD. 19:30 20:00 0.50 2,176 2,176 INTRMI WHDBO PRTS P RU and test hanger seals to 5000 psi for 10 minutes. 20:00 00:00 4.00 2,176 0 INTRM1 PLUG WOC P While waiting on cement to cure: Attempt to calibrate the top drive torque- Rig electricain doesn't have enough information /or wrong procedure. Lay down landing joint B. Lay down mouse hole. Clean rig floor and drains. Perform work orders. Remove iron roughneck and rotary table top so as to clean cavity of rotarty table. 4/30/2012 Test 10-3/4" csg/cement top @ 30391fWC to 1500psi-OK. Nipple down, NU 4-1/6" FMC Horiz tree, test void to 5000 psi, test tree to 5000 psi, freeze protect "U" tube diesel to tubing, rig down lines. Install BPV w/ lubricator. Secure well. Lay down 12 stands of 4" drill pipe f/ derrick. Clean floor drip pans & pits. Prepare to move to CD4-213B. Rig released @ 1800 hrs 4-30-12. 00:00 01:00 1.00 0 INTRM1 PLUG WO C P While waiting on cement: Continue to clean rig floor, install iron roughneck track, install iron rou hneck back on the track 01:00 01:15 0.25 INTRM1 PLUG SFTY P Pre job safety meeting on testing 10-3/4" casing to top of cement @ 3039' and two way check. 01:15 01:30 0.25 INTRM1 PLUG RURD P Rig up to test casing and cement job. Use BOP test pump, pumping into the 10-3/4" x 3-1/2" anulus. 01:30 02:15 0.75 INTRM1 PLUG DHEQ P Test 10-3/4" csg/cement top @ 30397FWC to 1500psi-chart test for 30 minutes. Good test -lost 40 psi. 02:15 02:30 0.25 INTRMI PLUG RURD P Rig down testing equipment. 02:30 02:45 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting on flushing stack. 02:45 03:00 0.25 INTRM1 WHDBO RURD P Rig up stack washing tool. 03:00 03:30 0.50 INTRM1 WHDBO CIRC P Close blind rams, then open. Close top and bottom pipe rams, then open, close annular, then open. Flush stack with stack washing tool. 03:30 03:45 0.25 INTRM1 WHDBO PULD P Lay down stack washing tool. Blow down the top drive and all lines. 03:45 04:00 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting on nippling down BOPE. 04:00 05:30 1.50 INTRM1 WHDBO NUND P Nipple down 13-5/8" BOP stack. Change out saver sub (4" XT39) on the top drive. Change dies in the grab heads f/ the top drive. 05:30 05:45 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting. Page 30 of 31 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:45 07:00 1.25 INTRM1 WHDBO NUND P Nipple up FMC 4-1/6" Horizontal tree. 07:00 07:30 0.50 INTRM1 WHDBO DHEQ P Test void to 5000 psi for 10 minutes. Test tree to 5000 psi f/ 10 minutes. 07:30 07:45 0.25 INTRM1 WHDBO RURD P Rig down testing equipment. 07:45 08:15 0.50 INTRM1 WHDBOOTHR P Pull two way check. 08:15 08:30 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting 08:30 09:00 0.50 INTRM1 WHDBO RURD P Rig up to freeze protect well w/ 150 bbls of diesel. 09:00 10:00 1.00 INTRM1 WHDBO FRZP P PJSM. Pressure test lines to 2500 psi. Dowell pump down the 10-3/4" x 3-1/2" annulus, pumping 4 bpm w/ 880 psi final. 10:00 10:30 0.50 INTRM1 WHDBO OTHR P �"U" tube diesel from the annulus to the tubing. 10:30 10:45 0.25 INTRM1 WHDBO OTHR P Dowell fush lines to cellar tote with water. 10:45 11:00 0.25 INTRM1 WHDBO RURD P Rig down squeeze manifold and lines. 11:00 11:15 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting. 11:15 12:00 0.75 INTRM1 WHDBO OTHR P Install BPV w/ lubricator. Secure well. 12:00 13:00 1.00 INTRM1 WHDBO PULD P Lay down lubricator. Clear and lay down excess from floor. Cleaning its. 13:00 14:00 1.00 INTRM1 PLUG PULD P Lay down 12 stands of 4" drill pipe f/ derrick. Clean floor drip pans, pits. Pre are to move. 14:00 18:00 4.00 INTRM1 MOVE RURD P Prepare to move: Break lines and hoses from pits and subbase. Clean rig floor, drains, drip pans and mats. Continue to clean pits, disconnect fuel line in pipe shed. Prepare pipe shed to move away from the rig. Prepare cellar for move. Remove suction caps from mud pumps. Check tire pressures. 18:00 18:00 0.00 INTRM1 Rig released for pad to pad move from CD3-127 to CD4-213B, approx 12 mile move. Page 31 of 31 - y LrSEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMS'S'ION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J. G. Samuell Drilling Engineer /, ) O E- ConocoPhillips Alaska, Inc.` P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD3-127 Sundry Number: 312-166 Dear Mr. Samuell: 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. Commissioner k DATED this 2 day of May, 2012. Encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 26, 2012 ConocoPhillips RECEIVED Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 APR 2 6 2012 Anchorage, Alaska 99501 Re: Sundry Permit: CD3-127 Operational Shutdown (PTD: 211-005) A OGCC Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to shutdown the operations with the currently approved plan for well CD3-127 (PTD: 211-005). Doyon 19 moved onto CD3-127 on April 24th, 2011 under Sundry #312-101 with the goal of preparing the well for a sidetrack from the surface casing for the 2013 winter drilling season. The well will need to be suspended until next year due to the limited ice road access to CD3 pad. Please find attached: ■ Form 10-403 Application ■ Proposed Plan forward ■ Current well schematic ■ Proposed operational shutdown schematic If you have any questions or require further information, please contact J.G. Samuell 265-6309 or Liz Galiunas at 265-6247. Sincerely, - V �-- J.G. Samuell Drilling Engineer CC: CD3-127 Well File Liz Galiunas Chip Alvord V STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED APR 2 6 2012 AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension fl Operations Shutdown Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ Stratigraphic ❑ Service El6. 211-005 • 3. Address: API Number:56 /C- i P.D. Box 100630, Anchorage, AK 99510 50-18--634W-00 /L- 7. if perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑� CD3-127, 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 372105, 025538, 025526 Colville River Field / Alpine 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): 3039' 2384' 3039' Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 3202' 10.75" 3239' 2453' 3580 psi 2480 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft) and TVD ift): 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Apr. 27, 2012 Oil 7" Gas ❑ WDSPL ❑ WIND ❑ y�Z? GINJ ❑ WAG ❑ Suspended Abandoned ❑ 16. Verbal Approval: Date: 4/265/2012 Commission Representative: Guy Schwartz GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact J.G. Samuell Printed Name J.G. Samuell Title Drilling Engineer Signature Phone 265-6309 Date 4/26/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3r2-44 � 3lz-lvi� Subsequent Form Required: �►�/;l( er/ox APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: C r 12, I } 2 xe,b Form 10-403 Revised 1/20MMS MAY 0 3 G G7�Submit in Duplicate »\NA L .Z Proposed Plan Forward 1. Wash down with 9-7/8" clean out BHA to 3,539' MD. 2. Pull out of hole with clean out assembly. 3. RIH with external casing packer (ECP). 4. Set ECP at +/- 3,439' MD. 5. Inflate ECP with drilling mud. 6. Disconnect from plug and pump 17.0 ppg cement for Abandonment / KOP. Estimated top of cement at 3,039' MD (200' above casing shoe). 7. Pull up one joint above cement and circulate to clean drill pipe. 8. Displace well over to 9.6 NaCl brine. 9. Blow down top drive, pull out of hole. 10. Pull out of hole and lay down cement stinger. 11. RIH with 3-1/2" kill string to 2,179.5' MD. 12. Make up tubing hanger and land in wellhead. 13. Test Hanger seals to 5000 psi. 14. Install BPV. 15. Chart and record casing pressure test to42500 psi ffor3Q minutes. 16. ND BOPE, NU Tree and test to 5000 psi. 17. Pull BPV. 18. Displace upper wellbore to diesel. 19. Install BPV. 20. RDMO Doyon 19. CD3-127 Current Well Schematic RKB-GL=36.3' 10-3/4" 40 ppf L-80 BTCM Surface Casing 3,239' MD / 2,453' TVD Cemented to Surface Too Qannik 7,536' MD / 4017' TVD Base Qannik 7,808' MD / 4117' TVD Top Nanua, Albian 96 12.349' MD / 5750' TVD Too HRZ 13,750' MD / 6422' TVD Packed off at 13,670' MD Unable to recover hole past 13,816' MD due to shale stability/hole collapse. Top Kuparuk C 14.622' MD Top Nuiasut 14,642' MD Too Nechelik 15,172' MD / 6918' TVn 9.6 PP9 brine below tubing 30 bbls hi vis Wellhead 16" Conductor to 114' 3-'/2" Tubing Kill String to 2179.5' MD / 2,106.8' TVD Bridge Plug set at 3126' MD / 2,414.6' TVD Top of Plug 7350' MD Btm of Plug (100' Below Pay) 7750' MD Top of Plug #1 13,200' MD Bottom of Plug #1 13,600' MD 9-7/8" Intermediate Hole TD of hole at +/- 15,261' MD / 6,978' TVD 3/4/2011 Proposed Operational Shutdown Schematic RKB-GL=36.3' 9.6 PP9 brine below 10-3/4" 40 ppf L-80 BTCM Surface Casing 3,239' MD / 2,453' TVD Cemented to Surface 4/26/2011 Wellhead 16" Conductor to 114' 3-'/z" Tubing Kill String to 2179.5' MD / 2,106.8' TVD Top of Plug (200' in casing) 3,039' MD Btnn of Plug (200' below casing) 3,439' MD ECP Set at +1- 3,439' MD Lead slurry: (3239'-3039') X 0.540 ft3/ft X 1.0 (0% excess) = 108 ft3 (3439'-3239') X 0.532 ft3/ft X 3.5 (250% excess) = 372 ft3 Total Volume: 108 ft3 + 372 ft3 = 480 ft3 / 1.0 ft3/sk = 480 Sx of 17.0 class G cement Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 26, 2012 5:22 PM To: 'Samuell, JG (John G)' Subject: RE: CD3-127 Sundry for Operational Shutdown You have verbal approval to proceed with the Operational Shutdown as proposed in the attached procedure. Submit 10-403 as soon as possible. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Samuell, JG (John G)[mailto:John.G.Samuell@conocophillips.com] Sent: Thursday, April 26, 2012 12:28 PM To: Schwartz, Guy L (DOA) Cc: Allsup-Drake, Sharon K Subject: CD3-127 Sundry for Operational Shutdown Guy, As per our conversation this morning, attached is the sundry application for operational shutdown for CD3-127. The originals will be sent to your office this afternoon. J.G. Samuell Chilling Engineer I ConocoPhiilips Alaska I Direct: (907) 265-6:109 1 Mobile (832) 465-8143 4/27/2012 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 26, 2012 1:30 PM To: 'Samuell, JG (John G)' Cc: Allsup-Drake, Sharon K Subject: RE: CD3-127 Sundry for Operational Shutdown JG, Sorry for not being more clear. I just talked to Sharon ... the OP shutdown needs to be submitted with a 10-403. Your procedure looks fine... When all the wellwork is completed then submit a 10-404 (referencing both the old sundry 312-101 and this new one for OP Shutdown) to close out both the sundries. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Samuell, JG (John G) [mailto:John.G.Samuell@conocophillips.com] Sent: Thursday, April 26, 2012 12:28 PM To: Schwartz, Guy L (DOA) Cc: Allsup-Drake, Sharon K Subject: CD3-127 Sundry for Operational Shutdown Guy, As per our conversation this morning, attached is the sundry application for operational shutdown for CD3-127. The originals will be sent to your office this afternoon. J.G. Samuell Drilling Engineer I Conoco Phillips Alaska I Direct. (907) 265-6309 1 Mobile. (832) 465-8148 4/27/2012 �I SEAN PARNELL, GOVERNOR A I ASSA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONS19RVATION COMMISSION �� ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J.G. Samuell Drilling Engineer ConocoPhillips Alaska, Inc. 00 C5 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-127 Sundry Number: 312-101 Dear Mr. Samuell: 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, ,Q Cathy . F/oerster Chair DATED this?,?, day of March, 2012. Encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 16th, 2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit -- Request to Re -Enter CD3-127 (permit no. 211-005) Dear Sir or Madam: ConocoPhillips p RECEIVE® MAR 16 202 Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to re-enter well CD3-127 and resume drilling ✓ operations with Doyon Rig 19. Estimated date to resume operations on CD3-127 is April 10th, 2012. During the 2011 ice road drilling season, CD3-127 was suspended at the surface casing shoe due to problems running the intermediate 7-5/8" casing string. The decision was made to delay further operations on CD3-127 and continue with the remaining wells for the 2011 drilling program. A 10-403 sundry for operational shutdown was y submitted and approved (Sundry # 311-065). The original CD3-127 scope was to drill and complete the Nechelik zone as a horizontal producer. Ice road timing prevents drilling and completing the Nechelik horizontal in 2012. A volume of Kuparuk C sand was found in CD3-127PB-1, which justifies completion as a producer. Also, the weather forecast indicates the ice road will last long enough to complete the shallower Kuparuk zone and safely move the Doyon 19 rig. Recompleting the CD3- 127 well as a Nechelik producer as originally proposed will still be an option for winter 2013 or later. Once the 7-5/8" intermediate casing has been run and cemented, the well will be completed as a Kuparuk producer with the planned change to the program shown in the attached wellbore schematic. The completion will include a single retrievable packer, an SSSV, and gas lift mandrels. The Kuparuk C sand will be perforated after the rig moves off. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. A proposed re-entry and de -complete program 3. CD3-127 Current Schematic 4. CD3-127 Kickoff Schematic 5. CD3-127 Final Schematic with proposed completion 6. Kick-off plug cement calculations 7. CD3-127wp08 Plan Summary Application information already on file with 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 J.G. Samuell at 265-6309 or Chip Alvord at 265-6120. Since ely, J.G. Samuell Drilling Engineer cc: CD3-127 Well File / Sharon Allsup Drake ATO 1530 Brian Noel ATO 1700 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation - Y�&' / STATE OF ALASKA 3�'' ALASKA OIL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROV gn AAr 9c; qRn RECEIVED �j LIAR 16 2012 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Wel C angge Aee roved Program e ' Suspend n Plug Perforations ❑ Perforate Q - Pull Tubing"'9j f1CflUra _ im Operations Shutdown , Re-enter Susp. We:. Stimulate ❑ Alter Casing❑ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc. Development Q , Exploratory ❑ Stratigraphic ❑ Service ❑ 211-005 ' 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 50-103-20634-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑J C133-127 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 372105, 025538,`25526 ' I Colville River Field / Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY - DOYON 19 RKB Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15261' - 6978' 16261' 6978' 3126' Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114' 114' Surface 3202' 10.75" 3239' 2463' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): n/a n/a 3-1/2" L-80 2,180 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): no packer, no SSSV 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/10/2012 Oil Q Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: n/a Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact J.G. Samuell Printed Name J.G. Samuell Title Drilling Engineer Phone 907265-6309 Date 3/16/2012 Signature COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ ❑ Location Clearance Other: —' I� i �'e (� l� S ��� i.�,�t- 't S & C) r-s' Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:3 . 2 2 —1 Z_ m 1 - 10 % c `�� Submit in Duplicate 1 ConocoPhillips Alaska, live HANGER, 31 CONDUCTOR, 36-114 WLEG, 2, 179 — m } - PLUG, 3.126 SURFACE, 36-3,239 Cement Plug, 7,269 Cement Plug, 7,344 Came t Plug. 13,207 TD, 15,261 WNS CD3-127 Well Attributes Max An le & MD ,TD Wallbon APW WI Field Name Wdl Stems Inel (•) MD (4KB) Act St. IRKS) 501032063400 FIORD NECHELIK ISUSP 93.42 15,231.51 Comment HIS (Pam) Date Annobtlon b A Rlg Release Dab SSSV: I LasWO 36.30 Annotation - Depth Last Tag. (ftKB) End Date Annotation ,Rev Reason: Last Mod ... End Dab WELL SUSPENDED Imosbor ( 3/27/2011 easing strings Casing Description String 0... String ID ... Top KB)th (f... ,Set Depth (TVD)String ... String Top Thrd CONDUCTOR 16 14.688 0 114.0 109.00 H-40Casing SMngID ... Top Description String 0... th (f... Set Depth (TV Wt..�String ... String Top Thrd SURFACE 10 3/4 9.960 9.2 2,453.4 1 45.50 L80 BTCM Tubing St In s Tubing Deuriptlon String 0... SMng ID ... Top (ftKB) Set Depth (f... Set Depth (TV I ... Strng Wt... String... String Top Thrd TUBING 311 2.992 30.9 2,180.0 2,017.1 9.20 L-80 EUE KILL STRING Com ieHon Details Top Depth (fVD) Top Inc.: Noml Top (ftKB)(ftKB) (•) fterrt Description Comment ID (Ir IIIl 30.91 30.91 0.26 HANGER IFMC Tubing Hanger (2.52' pup 4 1/2" IBT) 1 4.00 Other In Hole Mirellne retrievable plugs, valves pumps, fish etc. Top Depth (TVD) Too Incl Permanent - Start Data & 13/8/2011 1 NOTE: WELL SUSPENDED, INTERMEDIATE CSG PULLED & KILL STRING SET I Doyon 19 C133-127 Re -Entry Procedure The proposed scope of work for this sundry application includes: 1. MIRU Doyon 19. 2. Pull BPV. Circulate diesel freeze protect over to KWF through the kill string at 2180' MD. 3. Pressure test 10-3/4" surface casing and cement retainer set at 3138' MD to 3500 psi for 30 minutes. 4. Confirm well static. Set BPV. 5. Rig up to pump down the IA to confirm a pressure test of the BPV in the direction of flow. Monitor for 30 minutes. z1 6. With tested barriers in place, ND the tree and NU BOPE. 7. Shell test BOPE and flange break. O/C - Wz 8. Pull BPV. L-� + �L �f" 9. RIH with 4-1/2" landing joint and screw into tubing hanger 10. Pull 4-1/2" Tubing Hanger and 3-1/2" kill string to floor. 11. Set test plug and test BOPE to 250 psi low and 3500 psi high. 12. Pick up 9.875" clean out drilling assembly. 13. RIH and drill out cement retainer set in the 10.75" surface casing shoe. Continue to wash down to +/- 100 1/ below planned setting depth for ECP. POOH. l ?/J 14. RIH with Baker P&A kit and 7-5/8" inflatable ECP on DP and 3-1/2" cement stinger. Set at +/- 3350' MD. ✓15. Inflate ECP with drilling mud. Disconnect from plug and set cement KOP to +/- 56' outside the surface casing shoe. POOH. 16. Pick up 9.875" drilling assembly with 10-3/4" under reamer. 17. Drill out 20' of new hole. Perform leak off test. Lo' i A, - = " pry 18. Open hole sidetrack below surface casing with 9.875" Drilling assembly. jN 19. Drill to approx. 13.500' MD. Drop ball, open reamer. m =% S,e�7 �/� �� 20. Drill I drop reamer deactivation ball ` 21. Drill 9.875" hole to 7-5/8" casing point in the Nechelik sand at 15078' MD / 6985' TVD. (LWD Program: GR/RES/PW D/MW D/Neutron/Density/GABI) 22. Drop reamer deactivation ball, perform circulation clean up cycles, POOH. 23. Run and cement 7-5/8" casing as per program. Cement 2"d stage to cover Qannik. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 24. Run upper completion string consisting of 3-1/2" tubing, SSSV, GLM's, and single zone packer. Land hanger. 25. Install 2 way check and test and pressure test hanger seals to 5000 psi. Nipple down BOP. 26. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 27. Drop ball and rod, shear valve in GLM and test tubing and annulus to 3500 psi / 30 mins 28. Circulate tubing to diesel and install freeze protection in the annulus. 29. Set BPV and secure well. Move rig off. 30. Kuparuk perforations will be performed post rig. CD3-127 Current Schematic CD3-127 Operational Shutdown Schematic RKB-GL=36.3' 10-3/4" 40 ppf L-80 BTCM Surface Casing 3,239' MD / 2,453' TVD Cemented to Surface Too Qannik 7,536' MD / 401T TVD Top HRZ 13.750' MD / 6422' TVD Packed off at 13,670' MD Unable to recover hole past 13,816' MD due to shale stability/hole collapse. Top hupawk C 14,622' MD Too Nechelik 15,172' MD / 6918' TVD 3/4/2011 <-- Wellhead 16" Conductor to 114' 1900' 3-'h" Tbg Kill String 9.6 pp9 Inhibited Brine with 1900' Diesel FP Top of Plug (200' in casing) 3,039' MD ----;; :.: ' Btm of Plug 200' below casing) 3,439' MD 30 bbls hi vis 30 bbls hi vis 10.2 ppg mud in hole Top of Plug 7350' MD Btm of Plug (100' Below Pay) 7750' MD Top of Plug #1 13,200' MD Bottom of Plug #1 13,600' MD 9-7/8" Intermediate Hole TD of hole at +/- 15,261' MD / 6,978' TVD CD3-127 Proposed Kickoff Schematic CD3-127 Proposed Re -Entry Schematic RKB - GL = 36.3' 10-3l4" 40 ppf L -80 STCM Surface Casing 3,239' MD / 2,453' TVD Cemented to Surface Kick -Off Point 3,295' MD 12473' TVD Top Clannik 7,536' MD 14017' TVD Base Qannik 7,808' MD 14117' TVD Top Nanuq. Albian 96 12,349' MD 1 5750' TVD Top HRZ 13,750' MD 16422' TVD Packed off at 13,670' MD Unable to recover hole past 13,816' MD due to shale stability/hole collapse. Top Kuparuk C 14,622' MD Top Nuiqsut 14,642' MD Top Nechehk 15,172' MD 16918' TVD Wellhead 16" Conductor to 114' 9.6 PPg rrud in hole Top of Plug ':€ 3,289' MD f_ External Casing Packer 3,339' MD 30 bbls hi vis Top of Plug 7350' MD Btm of Plug (100' Below Pay) 7750' MD Top of Plug #1 13,200' MD Bottom of Plug #1 13,600' MD 9-718" Intermediate Hole TD of hole at +1- 15,261' MD 1 6,978' TVD 3/16/2012 CD3-127 Proposed New Schematic with Selective Single Completion Colville River Field CD3-127 Kuparuk Producer Well Completion I I 16" 62.6# Welded Conductor to 114' AID I I I I 4-112" 12.6# L-80 IBT-M to 110' MD I 3-112" 9.3# L-80 EUE-8RD-Mod below 10-3/4" 40 ppf L-80 BTC-Mod Surface Casing _ (4, 3239' AID,' 2453' TVD /63.1 ° cemented to surface (I ES Cementer @ 8000' MD 14212' TVD Intermediate casing Updated 03/16/2012 JGS Upper Completion (planned): MD 1) 3-'/:" Camco TRMAXX-5E w/Frac sleeve 2170' 2.812" X Profile 2) 3-%" x 1" Camco KBMG GLM w/ DV (68°) 7004' 3) 3-/2" x 1" Camco KBMG GLM wl DV (67°) 11900' 4) 3-'/z" x 1" Camce KBMG GLM wl no valve (66°) 14258' Mandrel left open for circulation 5) Baker FHL Packer and 20' PBR (66°) 14298' 6) HES 2.812" XN Profile w/ 2.75" No -Go (67°) 14338' wl Pump open plug 7) wrreline Entry Guide (67°) 14348' Calculated TOC @ 13,948' MD 16638' TVD Top Kuparuk C v 14448' MD /6828' TVD 168` Kuparuk C sand Perforations ° 14448' IeD TRF P' TVn l 62.3°)-14468' MD (6835' TVD) 62.5° Top Nechelik 14997' MD / 6973' TVD 181 ` ✓ 7.518" 29.7# L-80 BTC-Mod 15078' MD 16985' TVD 1 83" 1-0 CD3-127 Kick -Off Plug Cement Calculations Kick -Off Plug: 3339' MD to 3289' MD = 50' Cement with Class G + additives @ 17 ppg. Assume 15 % excess on open hole volume. Slurry: 50' X 0.5319 ft3lft X 1.15 (15% excess) = 30.58 ft3 annular vol. b 30.58 Sx @ 1.0 ft3/sk. ConocoPhillips(Alaska) Inc. Western North Slope C133 Fiord Pad CD3-127 Plan: C133-127 Kick off below surface casing. 20/100, Plan: CD3-127wpO8 build through upper HRZ, then hold until Top of Kuparuk D. Standard Proposal Report 15 March, 2012 11 REVISED Updated formation tops. 1:06 pm, Mar 13, 2012 Permit pacK NAD 27 Sperry Drilling Services O O N O O C t O z Temptation 1 A CD2-466 Easting -- --Nu 1 �- - i u -puu CD2-462wp05 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Easting (5500 Min) Project: Westem North Slope CD1 Fiord Pad CD3-127wp08 ConocoPhillli�pl's^ N WeIIt"I PDan Aaska DOI a6.0: RelelhelTdlort. daplewdKre.mMPrdOemwNhlaw mmuelY MR 8.D-BA: SlMawe4e xlm Nyl tonlmyalalgerwela wnn le4r DDI = 7.248 W16..4 2: Lmgwdb wvM relaSWYtahnis Pd4e8 HALLIBURTONREFERENCEINFORMADON L-OM Ca-adrlete "E) Rdelrroe: We# CD3-127, I- Nrtl1 Nonhhg 6OD3504.45 VmI (iw)Rdelrae: Ran: 36.3s12.6 Q48.90003oYw 19) -in91527889.34 Sperry Drilling Seal.. (VS) Rdermea Sloe-(0.00N. OAOE) Cakul dm Md Mirin-I CU Gmmtl L-1 12.60 13:58, March 132012 MQ GapZ atria l OaoODrmrc MMMaN D40m 198] Wk Le0lutle 70257.9/8N Lm9tude t50.550204w CASNG DETAILS 710RIEY MOmw88 WD TVDSS MD Name 81as 2453.85 24OC95 3239.52 1634 10 3w 79.30 476.30 CDS12]R31 Gyro (RIM) (CD332VB1) CL1-GYROSS 6984.90 6936.00 19076.05 74 7078.90 7030.00 2174959 3-1R 74r8'X97I8' 3.17C863 S18.03 ]202.58 CD3427R31 (RIM) (CD3.127PB1) M-FR-AKLA -BC 3300.93 11":00 LD3-127R31(R2m) (CO3-127PB1) MW FR-AKL C 3290.00 15078.05 M3-127w08(Ran: CD3-127) MW FR-AKLAZ4C 15079.05 21749.59 CO]-12W8 (Ran: CD3.127) M-FR-AK-CAZ-3C T.9- 0 CDC 2~0 Tam ro�30.W-1Q�W]9 -,==%S218�7087 M- SECTION DETALS Sec MD Inc A81 TVD TVDSS 9W-9 + m NarINnO E 1,,g OLm9 TFaam VS. TmrOr 1 3290.m 68.60 263.77 24TI.05 1123.15 41.41 .1577.28 9009488.82 1526311.77 0.00 0.00 470.75 2 3330.m 87.95 2fi3.34 2686.84 2437.94 �5.59-1614.19 fi003483.20 1526274.79 2.00 .150.00 488.52 3 3360.m 67.50 262.49 2498.21 1441.31 A9.01-1.1.71 -34-10 1526117.19 3.00 .120.00 .901.51 4 3760.00 68.02 249.54 2650.17 260127-138.32-1999.99 N033-31 1:25887.66 5 4292.51 68.42 261.00 2848.35 2799A5-283.73-24]7,22 6003278+11 1525408.64 3.00 2.00 -90.00 90.00 .1033+85 -1214.84 6 11840.41 68.42 261.00 .25.00 5576.10-1361.68-9409.43 fi0022B4B7 1518461.26 0.00 0.00 d181.60 7 13589.35 59.69 192.63 6470.M 6421.10-2318.31-1001.59 fi001344.59 1517374.r 3SO .113.70 d112.95 8 13934.Bfi 6650 192.63 .26.00 6577.10-2618.91-105/8.94 W010d5.06 1517303.02 2.00 0.00 3905.34 9 14370.42 66.60 192.63 6799.00 6]50.10-3008.97 -10fi36.34 6000656.40 11,7209.1 0.00 0.00 3635.95 10 15078.05 83.11 1]].29 698d.90 8938.00-3685.]2 -1 ON 17 5999980.65 1517169.15 11 15098.05 83.t1 t71.29 6987.30 6938A0-3705.04 .10fifid.41 5999960.89 15t7171.1] 3.51 0.00 41.45 0.00 -9099.37 CD3-K 11Jan13 Keel -3081.88 12 15286.24 89.29 168.98 099.77 6950.87-3890.43-106]5.51 5999775AO 1517197.31 4,00 .35.00 -2913.42 13 15873.71 89.30 145.48 7007.10 6958.20 -28.30-10409,75 5999233.94 1517414.12 4.11 -90.12 -2343.34 14 21749.59 89.30 145.48 7078.90 7030.00-926923-7080.16 599434379 1520670.8] 0.00 0.00 3531.89 CD3-K 25Mey10 Toe -7500 4000 -2%0 0 _ I I I I I I I I I I -- I _, I I 1000 2p�0Spa C-30 -1060o -75H aaaa s0` _ _ _ _ _ _ Wesg-yEaat(+)(25M ttAn) C-20 P - - - - - - - - - - - - - - - - K-3 K-3 Basel Qannik (K-2) - 10 3/4' ------------ Basal K-2 ®e$ Abian_97 - - _ - "b _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Albian_96 >2Q-,,�- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - CCS_Sh Abv_HRZ CCS sh Abv HRZ base 1"�Oc _ o0 0 0 o O � 127wp0 K-1/Top Lower Kalubik SUP \ ' - ` 7-5/8' X 9-7/8' ` Top_Kup_D/Base Lwr. Kalubik` CD3-K 25Mey10 T 3-1/2' x 63/4' p NecheAk Bas61_Nulgsut LCU Top_Kup_C CD3-127PB1 CD3-K 11Jani2 Heel Nechelik 1 -7500 4, -2500 0 2500 am 7500 Vertical Section at 145.00'(2500 Win) -10000 .7500 -on -2000 0 4000 0 ANNOrATK1NS Tw 7VDS6 w anlldrn4 2472.05 2423.16 3290.00 K .. OLS 2.00 TFO-150.00 2486.84 2437.94 3330.00 SIrt OLS 3.0D TFO-120.00 2498.21 2449.31 3360.00 StW OLS 3.00 TFO 9000 2650.17 2801.27 3760.00 Slmrt DLS2.00TF090.00 2848.35 27B9A5 4292.51 alert 7547.90 holtld 4292.51 MD 5625.00 5578.10 11840.41 Slat DLS 3.50 TFO-113.70 6470.00 6421.10 13589.35 Slaty 2.00 TFG 0.00 6826.00 0 .10 13934.86 Slat 435.56 hold d 13934.86 MD 67M M 6750.10 1437042 Slat DLS 3.51 TFO.61.AS NG4.90 6987.30 6936.00 15078.05 Slat 20.00 Mtld 15078.06 MD 6 WAD 15098.05 gat DIS 400 TF035.00 6999.77 8950.87 15286.24 Stet DLS 4.00 TF090.12 7007.10 0958.20 16873.71 Sat 5875.87 hold d I SM.71 ND 7078.90 7030.00 21749.69 7Dd 21749.5E FORMADON TOP DETAILS TLTOPdh TVD3sPa81 MDPam Formation 2473.90 2425,00 W9607 C-M 2853.90 280500 4307.59 C-20 3848.90 3800 00 7012.35 K3 3993.90 3945.00 7406.51 K-3 Beset 4018.90 3970.00 7474.47 Qa (K-2) 4118,90 407000 7746.30 Brol K-2 028.90 5808.90 5280.00 11035.51 atolm_97 5760.00 12254.83 atdan_96 6483.90 6435.00 13617.12 CCS_Sh_al7s_HRZ 6552.0 6504.00 13762.67 CCS_eh_ALv_HRZ_b 6%8.9D 6540.00 13844.72 HRZ 670390 %55.00 141M 993ese_HRZrrW Lb. Kdubk 6]5390 :70600 14256.87 K-1ROP Lc-KdubN 6788.90 740.00 14344Ti0_Kup_OIBaze Lwr. KduOk 6828.90 6835,w 67M 00 1.48 41 TM Kuo C 6787.00 14467.54 LCU 6974.90 6926.00 15004.21 NECH_CRSUP CD3-127wpO8 Plan View o� o d o o o o o 0 0 c3 0 0 0 10 3/4" o 0 -1500— 0 0 0 7 00 0 u'OOO 1,� 0 _3000 0 o 1U 5000 -- 7-5/8" X 9-7/8" ,t-4500—I 6000 z 1�00 c)6000- -7500— p4O � 0 9000�, 3-1/2" x 6-3/4" �J,,R -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 West( -)/East(+) (1500 ft/in) CD3-127wpO8 Section View 0 AO 0 1000 1500 300 c 2000 600 o 0C:) 10 3/4° -- '1100 Oo 3000 O � m 000 p O 00 � � 000 4500 ®pO (D 0 00 ,z 000 ~ �X O O 7 6000 ��0 0 0 0 0 Ln Ln cm 0 0 00 rn CD 0 o o T11- ti -� OC) N N N 'e F 7500 7-5/8" X 9-7/8"3-1 /2" x 6-3/4' M U -6000 -4500 -3000 -1500 0 1500 3000 4500 6000 Vertical Section at 145.000(1500 ft/in) • FA _ - _ 1_ Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wp08 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well CD3-127 TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope 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 CD3 Fiord Pad Site Position: Northing: 469.98ft Latitude: 53' 58' 43.652 N From: Map Easting:-401.28ft Longitude: 152' 19' 30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88 ° Well CD3-127 Well Position +N/-S 0.00 ft Northing: 6,003,757.25 ft Latitude: 70' 25' 9.114 N +E/-W 0.00 ft Easting: 387,857.43 ft Longitude: 150' 54' 48.827 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore Plan: CD3-127 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (') (nT) BGGM2011 2/1 /2012 15.82 79.83 57,345 Design CD3-127wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 3,290.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (1) 36.30 0.00 0.00 145.00 Plan Sections Measured Vertical TVD Depth Inclination Azimuth Depth System +N/-S +E/-W (ft) (1) V) (ft) ft (ft) (ft) 3,290.00 68.64 263.77 2,472.05 2,423.15 -41.41 -1,577.26 3,330.00 67.95 263.34 2,486.84 2,437.94 -45.59 -1,614.19 3,360.00 67.50 262.49 2,498.21 2,449.31 -49.01 -1,641.73 3,760.00 68.02 249.54 2,650.17 2,601.27 -138.32 -1,999.99 4,292.51 68.42 261.00 2,848.35 2,799.45 -263.73 -2,477.22 11,840.41 68.42 261.00 5,625.00 5,576.10 -1,361.68 -9,409.43 13,589.35 59.69 192.63 6,470.00 6,421.10 -2,318.31 -10,481.59 13,934.86 66.60 192.63 6,626.00 6,577.10 -2,618.91 -10,548.94 14,370.42 66.60 192.63 6,799.00 6,750.10 -3,008.97 -10,636.34 15,077.08 83.07 173.34 6,984.90 6,936.00 -3,684.34 -10,667.01 15,097.08 83.07 173.34 6,987.31 6,938.41 -3,704.06 -10,664.70 15,286.58 89.29 169.00 6,999.95 6,951.05 -3,890.76 -10,635.66 15,874.51 89.30 145.48 7,007.28 6,958.38 -4,429.05 -10,409.79 21,748.88 89.30 145.48 7,078.90 7,030.00 -9,268.60 -7,080.85 Dogleg Build Turn Rate Rate Rate Tool Face (°/100ft) (°/100ft) (°/100ft) V) 0.00 0.00 0.00 0.00 2.00 -1.73 -1.08 -150.00 3.00 -1.49 -2.81 -120.00 3.00 0.13 -3.24 -90.00 2.00 0.07 2.15 90.00 0.00 0.00 0.00 0.00 3.50 -0.50 -3.91 -113.70 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 3.51 2.33 -2.73 -51.45 0.00 0.00 0.00 0.00 4.00 3.28 -2.29 -35.00 4.00 0.00 -4.00 -90.12 0.00 0.00 0.00 0.00 3/152012 7:18:10PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Welibore: Plan: CD3-127 Design: CD3-127wp08 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) -48.90 3,290.00 0.00 0.00 0.00 -48.90 0.00 0.00 6,003,757.25 387,857.43 136.90 0.00 KOP: DLS 2.00 TFO -150.00 3,295.07 68.55 263.71 2,473.90 2,425.00 -41.93 -1,581.95 6,003,739.10 386,275.16 1,350.81 -873.03 C-30 3,300.00 68.47 263.66 2,475.70 2,426.80 -42.43 -1,586.51 6,003,738.66 386,270.60 2.00 -875.23 3,330.00 67.95 263.34 2,486.84 2,437.94 -45.59 -1,614.19 6,003,735.93 386,242.88 2.00 -888.52 Start DLS 3.00 TFO-120.00 3,360.00 67.50 262.49 2,498.21 2,449.31 -49.01 -1,641.73 6,003,732.92 386,215.28 3.00 -901.51 Start DLS 3.00 TFO -90.00 3,400.00 67.51 261.19 2,513.52 2,464.62 -54.25 -1,678.31 6,003,728.22 386,178.63 3.00 -918.20 3,500.00 67.56 257.95 2,551.74 2,502.84 -70.98 -1,769.18 6,003,712.87 386,087.53 3.00 -956.62 3,600.00 67.69 254.71 2,589.82 2,540.92 -92.83 -1,859.02 6,003,692.36 385,997.38 3.00 -990.24 3,700.00 67.87 251.47 2,627.64 2,578.74 -119.76 -1,947.57 6,003,666.77 385,908.44 3.00 -1,018.98 3,760.00 68.02 249.54 2,650.17 2,601.27 -138.32 -1,999.99 6,003,649.01 385,855.76 3.00 -1,033.85 Start DLS 2.00 TFO 90.00 3,800.00 68.02 250.40 2,665.14 2,616.24 -151.02 -2,034.84 6,003,636.83 385,820.72 2.00 -1,043.43 3,900.00 68.05 252.56 2,702.55 2,653.65 -180.48 -2,122.77 6,003,608.69 385,732.37 2.00 -1,069.73 4,000.00 68.10 254.71 2,739.90 2,691.00 -206.62 -2,211.77 6,003,583.90 385,642.99 2.00 -1,099.36 4,100.00 68.18 256.86 2,777.14 2,728.24 -229.41 -2,301.73 6,003,562.47 385,552.71 2.00 -1,132.30 4,200.00 68.29 259.01 2,814.22 2,765.32 -248.81 -2,392.55 6,003,544.43 385,461.62 2.00 -1,168.49 4,292.51 68.42 261.00 2,848.35 2,799.45 -263.73 -2,477.22 6,003,530.79 385,376.74 2.00 -1,204.84 Start 7547.90 hold at 4292.51 MD 4,300.00 68.42 261.00 2,851.11 2,802.21 -264.82 -2,484.10 6,003,529.80 385,369.84 0.00 -1,207.89 4,307.59 68.42 261.00 2,853.90 2,805.00 -265.92 -2,491.07 6,003,528.80 385,362.86 0.00 -1,210.99 C-20 4,400.00 68.42 261.00 2,887.89 2,838.99 -279.37 -2,575.94 6,003,516.64 385,277.80 0.00 -1,248.66 4,500.00 68.42 261.00 2,924.68 2,875.78 -293.91 -2,667.79 6,003,503.47 385,185.76 0.00 -1,289.42 4,600.00 68.42 261.00 2,961.47 2,912.57 -308.46 -2,759.63 6,003,490.31 385,093.71 0.00 -1,330.18 4,700.00 68.42 261.00 2,998.26 2,949.36 -323.00 -2,851.47 6,003,477.15 385,001.67 0.00 -1,370.95 4,800.00 68.42 261.00 3,035.04 2,986.14 -337.55 -2,943.31 6,003,463.98 384,909.63 0.00 -1,411.71 4,900.00 68.42 261.00 3,071.83 3,022.93 -352.10 -3,035.16 6,003,450.82 384,817.58 0.00 -1,452.47 5,000.00 68.42 261.00 3,108.62 3,059.72 -366.64 -3,127.00 6,003,437.65 384,725.54 0.00 -1,493.24 5,100.00 68.42 261.00 3,145.40 3,096.50 -381.19 -3,218.84 6,003,424.49 384,633.50 0.00 -1,534.00 5,200.00 68.42 261.00 3,182.19 3,133.29 -395.74 -3,310.69 6,003,411.33 384,541.46 0.00 -1,574.76 5,300.00 68.42 261.00 3,218.98 3,170.08 -410.28 -3,402.53 6,003,398.16 384,449.41 0.00 -1,615.53 5,400.00 68.42 261.00 3,255.76 3,206.86 -424.83 -3,494.37 6,003,385.00 384,357.37 0.00 -1,656.29 5,500.00 68.42 261.00 3,292.55 3,243.65 -439.38 -3,586.21 6,003,371.83 384,265.33 0.00 -1,697.05 5,600.00 68.42 261.00 3,329.34 3,280.44 -453.92 -3,678.06 6,003,358.67 384,173.28 0.00 -1,737.81 5,700.00 68.42 261.00 3,366.13 3,317.23 -468.47 -3,769.90 6,003,345.51 384,081.24 0.00 -1,778.58 5,800.00 68.42 261.00 3,402.91 3,354.01 -483.02 -3,861.74 6,003,332.34 383,989.20 0.00 -1,819.34 5,900.00 68.42 261.00 3,439.70 3,390.80 -497.56 -3,953.59 6,003,319.18 383,897.15 0.00 -1,860.10 6,000.00 68.42 261.00 3,476.49 3,427.59 -512.11 -4,045.43 6,003,306.01 383,805.11 0.00 -1,900.87 6,100.00 68.42 261.00 3,513.27 3,464.37 -526.66 -4,137.27 6,003,292.85 383,713.07 0.00 -1,941.63 6,200.00 68.42 261.00 3,550.06 3,501.16 -541.20 -4,229.11 6,003,279.69 383,621.02 0.00 -1,982.39 6,300.00 68.42 261.00 3,586.85 3,537.95 -555.75 -4,320.96 6,003,266.52 383,528.98 0.00 -2,023.16 3/15/2012 7:18:10PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-127 Design: CD3-127wp08 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) 3,674.74 6,400.00 68.42 261.00 3,623.64 3,574.74 -570.30 -4,412.80 6,003,253.36 383,436.94 0.00 -2,063.92 6,500.00 68.42 261.00 3,660.42 3,611.52 -584.84 -4,504.64 6,003,240.19 383,344.89 0.00 -2,104.68 6,600.00 68.42 261.00 3,697.21 3,648.31 -599.39 -4,596.49 6,003,227.03 383,252.85 0.00 -2,145.45 6,700.00 68.42 261.00 3,734.00 3,685.10 -613.93 -4,688.33 6,003,213.87 383,160.81 0.00 -2,186.21 6,800.00 68.42 261.00 3,770.78 3,721.88 -628.48 -4,780.17 6,003,200.70 383,068.76 0.00 -2,226.97 6,900.00 68.42 261.00 3,807.57 3,758.67 -643.03 -4,872.01 6,003,187.54 382,976.72 0.00 -2,267.74 7,000.00 68.42 261.00 3,844.36 3,795.46 -657.57 -4,963.86 6,003,174.37 382,884.68 0.00 -2,308.50 7,012.35 68.42 261.00 3,848.90 3,800.00 -659.37 -4,975.20 6,003,172.75 382,873.31 0.00 -2,313.53 K-3 7,100.00 68.42 261.00 3,881.14 3,832.24 -672.12 -5,055.70 6,003,161.21 382,792.64 0.00 -2,349.26 7,200.00 68.42 261.00 3,917.93 3,869.03 -686.67 -5,147.54 6,003,148.05 382,700.59 0.00 -2,390.02 7,300.00 68.42 261.00 3,954.72 3,905.82 -701.21 -5,239.39 6,003,134.88 382,608.55 0.00 -2,430.79 7,400.00 68.42 261.00 3,991.51 3,942.61 -715.76 -5,331.23 6,003,121.72 382,516.51 0.00 -2,471.55 7,406.51 68.42 261.00 3,993.90 3,945.00 -716.71 -5,337.21 6,003,120.86 382,510.51 0.00 -2,474.20 K-3 Basal 7,474.47 68.42 261.00 4,018.90 3,970.00 -726.59 -5,399.62 6,003,111.92 382,447.96 0.00 -2,501.91 Qannik (K-2) 7,500.00 68.42 261.00 4,028.29 3,979.39 -730.31 -5,423.07 6,003,108.55 382,424.46 0.00 -2,512.31 7,600.00 68.42 261.00 4,065.08 4,016.18 -744.85 -5,514.92 6,003,095.39 382,332.42 0.00 -2,553.08 7,700.00 68.42 261.00 4,101.87 4,052.97 -759.40 -5,606.76 6,003,082.23 382,240.38 0.00 -2,593.84 7,746.30 68.42 261.00 4,118.90 4,070.00 -766.13 -5,649.28 6,003,076.13 382,197.76 0.00 -2,612.72 Basal K-2 7,800.00 68.42 261.00 4,138.65 4,089.75 -773.95 -5,698.60 6,003,069.06 382,148.33 0.00 -2,634.60 7,900.00 68.42 261.00 4,175.44 4,126.54 -788.49 -5,790.44 6,003,055.90 382,056.29 0.00 -2,675.37 8,000.00 68.42 261.00 4,212.23 4,163.33 -803.04 -5,882.29 6,003,042.73 381,964.25 0.00 -2,716.13 8,100.00 68.42 261.00 4,249.01 4,200.11 -817.59 -5,974.13 6,003,029.57 381,872.20 0.00 -2,756.89 8,200.00 68.42 261.00 4,285.80 4,236.90 -832.13 -6,065.97 6,003,016.41 381,780.16 0.00 -2,797.66 8,300.00 68.42 261.00 4,322.59 4,273.69 -846.68 -6,157.82 6,003,003.24 381,688.12 0.00 -2,838.42 8,400.00 68.42 261.00 4,359.38 4,310.48 -861.22 -6,249.66 6,002,990.08 381,596.07 0.00 -2,879.18 8,500.00 68.42 261.00 4,396.16 4,347.26 -875.77 -6,341.50 6,002,976.91 381,504.03 0.00 -2,919.95 8,600.00 68.42 261.00 4,432.95 4,384.05 -890.32 -6,433.34 6,002,963.75 381,411.99 0.00 -2,960.71 8,700.00 68.42 261.00 4,469.74 4,420.84 -904.86 -6,525.19 6,002,950.59 381,319.95 0.00 -3,001.47 8,800.00 68.42 261.00 4,506.52 4,457.62 -919.41 -6,617.03 6,002,937.42 381,227.90 0.00 -3,042.24 8,900.00 68.42 261.00 4,543.31 4,494.41 -933.96 -6,708.87 6,002,924.26 381,135.86 0.00 -3,083.00 9,000.00 68.42 261.00 4,580.10 4,531.20 -948.50 -6,800.72 6,002,911.09 381,043.82 0.00 -3,123.76 9,100.00 68.42 261.00 4,616.88 4,567.98 -963.05 -6,892.56 6,002,897.93 380,951.77 0.00 -3,164.52 9,200.00 68.42 261.00 4,653.67 4,604.77 -977.60 -6,984.40 6,002,884.77 380,859.73 0.00 -3,205.29 9,300.00 68.42 261.00 4,690.46 4,641.56 -992.14 -7,076.24 6,002,871.60 380,767.69 0.00 -3,246.05 9,400.00 68.42 261.00 4,727.25 4,678.35 -1,006.69 -7,168.09 6,002,858.44 380,675.64 0.00 -3,286.81 9,500.00 68.42 261.00 4,764.03 4,715.13 -1,021.24 -7,259.93 6,002,845.27 380,583.60 0.00 -3,327.58 9,600.00 68.42 261.00 4,800.82 4,751.92 -1,035.78 -7,351.77 6,002,832.11 380,491.56 0.00 -3,368.34 9,700.00 68.42 261.00 4,837.61 4,788.71 -1,050.33 -7,443.62 6,002,818.95 380,399.51 0.00 -3,409.10 9,800.00 68.42 261.00 4,874.39 4,825.49 -1,064.88 -7,535.46 6,002,805.78 380,307.47 0.00 -3,449.87 9,900.00 68.42 261.00 4,911.18 4,862.28 -1,079.42 -7,627.30 6,002,792.62 380,215.43 0.00 -3,490.63 10,000.00 68.42 261.00 4,947.97 4,899.07 -1,093.97 -7,719.14 6,002,779.45 380,123.38 0.00 -3,531.39 3/15/2012 7:18:10PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Welibore: Plan: CD3-127 Design: CD3-127wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/S +E/-W Northing Easting DLS Vert Section (ft) V) V) (ft) ft (ft) (ft) (ft) (ft) 4,935.86 10,100.00 68.42 261.00 4,984.76 4,935.86 -1,108.52 -7,810.99 6,002,766.29 380,031.34 0.00 -3,572.16 10,200.00 68.42 261.00 5,021.54 4,972.64 -1,123.06 -7,902.83 6,002,753.13 379,939.30 0.00 -3,612.92 10,300.00 68.42 261.00 5,058.33 5,009.43 -1,137.61 -7,994.67 6,002,739.96 379,847.25 0.00 -3,653.68 10,400.00 68.42 261.00 5,095.12 5,046.22 -1,152.15 -8,086.52 6,002,726.80 379,755.21 0.00 -3,694.45 10,500.00 68.42 261.00 5,131.90 5,083.00 -1,166.70 -8,178.36 6,002,713.63 379,663.17 0.00 -3,735.21 10,600.00 68.42 261.00 5,168.69 5,119.79 -1,181.25 -8,270.20 6,002,700.47 379,571.13 0.00 -3,775.97 10,700.00 68.42 261.00 5,205.48 5,156.58 -1,195.79 -8,362.04 6,002,687.31 379,479.08 0.00 -3,816.73 10,800.00 68.42 261.00 5,242.26 5,193.36 -1,210.34 -8,453.89 6,002,674.14 379,387.04 0.00 -3,857.50 10,900.00 68.42 261.00 5,279.05 5,230.15 -1,224.89 -8,545.73 6,002,660.98 379,295.00 0.00 -3,898.26 11,000.00 68.42 261.00 5,315.84 5,266.94 -1,239.43 -8,637.57 6,002,647.81 379,202.95 0.00 -3,939.02 11,035.51 68.42 261.00 5,328.90 5,280.00 -1,244.60 -8,670.18 6,002,643.14 379,170.27 0.00 -3,953.50 Albian_97 11,100.00 68.42 261.00 5,352.63 5,303.73 -1,253.98 -8,729.42 6,002,634.65 379,110.91 0.00 -3,979.79 11,200.00 68.42 261.00 5,389.41 5,340.51 -1,268.53 -8,821.26 6,002,621.49 379,018.87 0.00 -4,020.55 11,300.00 68.42 261.00 5,426.20 5,377.30 -1,283.07 -8,913.10 6,002,608.32 378,926.82 0.00 -4,061.31 11,400.00 68.42 261.00 5,462.99 5,414.09 -1,297.62 -9,004.94 6,002,595.16 378,834.78 0.00 -4,102.08 11,500.00 68.42 261.00 5,499.77 5,450.87 -1,312.17 -9,096.79 6,002,581.99 378,742.74 0.00 -4,142.84 11,600.00 68.42 261.00 5,536.56 5,487.66 -1,326.71 -9,188.63 6,002,568.83 378,650.69 0.00 -4,183.60 11,700.00 68.42 261.00 5,573.35 5,524.45 -1,341.26 -9,280.47 6,002,555.67 378,558.65 0.00 -4,224.37 11,800.00 68.42 261.00 5,610.13 5,561.23 -1,355.81 -9,372.32 6,002,542.50 378,466.61 0.00 -4,265.13 11,840.41 68.42 261.00 5,625.00 5,576.10 -1,361.68 -9,409.43 6,002,537.18 378,429.41 0.00 -4,281.60 Start DLS 3.50 TFO-113.70 11,900.00 67.59 258.93 5,647.32 5,598.42 -1,371.31 -9,463.83 6,002,528.38 378,374.88 3.50 -4,304.92 12,000.00 66.27 255.41 5,686.52 5,637.62 -1,391.71 -9,553.52 6,002,509.32 378,284.90 3.50 -4,339.65 12,100.00 65.02 251.82 5,727.77 5,678.87 -1,417.39 -9,640.90 6,002,484.97 378,197.15 3.50 -4,368.74 12,200.00 63.87 248.16 5,770.92 5,722.02 -1,448.24 -9,725.66 6,002,455.40 378,111.95 3.50 -4,392.08 12,284.83 62.96 245.00 5,808.90 5,760.00 -1,478.38 -9,795.26 6,002,426.31 378,041.90 3.50 -4,407.31 Albian_96 12,300.00 62.80 244.43 5,815.81 5,766.91 -1,484.14 -9,807.47 6,002,420.72 378,029.62 3.50 -4,409.59 12,400.00 61.84 240.63 5,862.27 5,813.37 -1,524.98 -9,886.02 6,002,381.08 377,950.46 3.50 -4,421.20 12,500.00 60.99 236.76 5,910.13 5,861.23 -1,570.58 -9,961.03 6,002,336.61 377,874.78 3.50 -4,426.87 12,600.00 60.25 232.84 5,959.21 5,910.31 -1,620.79 -10,032.22 6,002,287.48 377,802.85 3.50 -4,426.57 12,700.00 59.62 228.86 6,009.32 5,960.42 -1,675.41 -10,099.32 6,002,233.88 377,734.95 3.50 -4,420.31 12,800.00 59.12 224.83 6,060.28 6,011.38 -1,734.25 -10,162.08 6,002,176.00 377,671.32 3.50 -4,408.12 12,900.00 58.75 220.77 6,111.90 6,063.00 -1,797.07 -10,220.26 6,002,114.06 377,612.20 3.50 -4,390.02 13,000.00 58.50 216.68 6,163.98 6,115.08 -1,863.66 -10,273.65 6,002,048.29 377,557.82 3.50 -4,366.11 13,100.00 58.38 212.57 6,216.34 6,167.44 -1,933.75 -10,322.05 6,001,978.94 377,508.38 3.50 -4,336.45 13,200.00 58.39 208.46 6,268.77 6,219.87 -2,007.09 -10,365.28 6,001,906.26 377,464.06 3.50 -4,301.17 13,300.00 58.54 204.36 6,321.09 6,272.19 -2,083.40 -10,403.18 6,001,830.53 377,425.02 3.50 -4,260.40 13,400.00 58.82 200.27 6,373.09 6,324.19 -2,162.41 -10,435.60 6,001,752.03 377,391.41 3.50 -4,214.28 13,500.00 59.22 196.22 6,424.58 6,375.68 -2,243.80 -10,462.43 6,001,671.05 377,363.37 3.50 -4,162.99 13,589.35 59.69 192.63 6,470.00 6,421.10 -2,318.31 -10,481.59 6,001,596.85 377,343.10 3.50 -4,112.95 Start DLS 2.00 TFO 0.00 13,600.00 59.90 192.63 6,475.36 6,426.46 -2,327.29 -10,483.60 6,001,587.90 377,340.95 2.00 -4,106.74 311512012 7:18:10PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-127 Design: CD3-127wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) V) (1) (ft) ft (ft) (ft) (ft) (ft) 6,435.00 13,617.12 60.24 192.63 6,483.90 6,435.00 -2,341.77-10,486.85 6,001,573.48 377,337.49 2.00 -4,096.74 CCSSh_Abv_HRZ 13,700.50 61.90 192.63 6,523.99 6,475.09 -2,412.55-10,502.71 6,001,502.94 377,320.57 2.00 -4,047.86 13,762.67 63.15 192.63 6,552.90 6,504.00 -2,466.81-10,514.86 6,001,448.88 377,307.60 2.00 -4,010.39 CCS_sh_Abv_HRZ_base 13,800.00 63.90 192.63 6,569.54 6,520.64 -2,499.42-10,522.17 6,001,416.39 377,299.81 2.00 -3,987.87 13,844.72 64.79 192.63 6,588.90 6,540.00 -2,538.75-10,530.98 6,001,377.20 377,290.40 2.00 -3,960.70 HRZ 13,900.00 65.90 192.63 6,611.96 6,563.06 -2,587.78-10,541.97 6,001,328.34 377,278.68 2.00 -3,926.84 13,934.86 66.60 192.63 6,626.00 6,577.10 -2,618.91-10,548.94 6,001,297.32 377,271.24 2.00 -3,905.34 Start 435.56 hold at 13934.86 MD 14,000.00 66.60 192.63 6,651.87 6,602.97 -2,677.25-10,562.01 6,001,239.19 377,257.30 0.00 -3,865.05 14,100.00 66.60 192.63 6,691.59 6,642.69 -2,766.80-10,582.08 6,001,149.96 377,235.89 0.00 -3,803.20 14,130.99 66.60 192.63 6,703.90 6,655.00 -2,794.55-10,588.29 6,001,122.31 377,229.26 0.00 -3,784.03 Base_HRZ/Top Up. Kalubik 14,200.00 66.60 192.63 6,731.31 6,682.41 -2,856.35-10,602.14 6,001,060.72 377,214.49 0.00 -3,741.35 14,256.87 66.60 192.63 6,753.90 6,705.00 -2,907.29-10,613.55 6,001,009.97 377,202.31 0.00 -3,706.17 K-1/Top Lower Kalubik 14,300.00 66.60 192.63 6,771.03 6,722.13 -2,945.91-10,622.21 6,000,971.49 377,193.08 0.00 -3,679.50 14,344.99 66.60 192.63 6,788.90 6,740.00 -2,986.20-10,631.23 6,000,931.34 377,183.45 0.00 -3,651.67 Top_Kup_D/Base Lwr. Kalubik 14,370.42 66.60 192.63 6,799.00 6,750.10 -3,008.97-10,636.34 6,000,908.65 377,178.01 0.00 -3,635.95 Start DLS 3.51 TFO -51.45 14,400.00 67.25 191.75 6,810.59 6,761.69 -3,035.57-10,642.08 6,000,882.14 377,171.86 3.51 -3,617.45 14,448.41 68.32 190.33 6,828.90 6,780.00 -3,079.56-10,650.66 6,000,838.30 377,162.63 3.51 -3,586.34 Top_Kup_C 14,467.54 68.75 189.77 6,835.90 6,787.00 -3,097.08-10,653.76 6,000,820.82 377,159.26 3.51 -3,573.77 LCU 14,500.00 69.48 188.83 6,847.47 6,798.57 -3,127.01-10,658.67 6,000,790.97 377,153.91 3.51 -3,552.06 14,600.00 71.75 186.00 6,880.67 6,831.77 -3,220.54-10,670.83 6,000,697.64 377,140.35 3.51 -3,482.42 14,695.79 73.97 183.36 6,908.90 6,860.00 -3,311.75-10,678.28 6,000,606.56 377,131.52 3.51 -3,411.98 Base_Nuigsut 14,700.00 74.07 183.25 6,910.06 6,861.16 -3,315.80-10,678.51 6,000,602.52 377,131.23 3.51 -3,408.80 14,800.00 76.42 180.55 6,935.53 6,886.63 -3,412.43-10,681.71 6,000,505.96 377,126.58 3.51 -3,331.48 14,900.00 78.80 177.91 6,956.99 6,908.09 -3,510.07-10,680.39 6,000,408.31 377,126.44 3.51 -3,250.73 14,997.05 81.13 175.39 6,973.90 6,925.00 -3,605.47-10,674.80 6,000,312.85 377,130.59 3.51 -3,169.39 Top_Nechelik 15,000.00 81.20 175.31 6,974.35 6,925.45 -3,608.37-10,674.56 6,000,309.95 377,130.79 3.51 -3,166.88 15,003.60 81.29 175.22 6,974.90 6,926.00 -3,611.91-10,674.27 6,000,306.40 377,131.03 3.51 -3,163.80 NECH_CRSUP 15,077.08 83.07 173.34 6,984.90 6,936.00 -3,684.34-10,667.01 6,000,233.88 377,137.20 3.51 -3,100.31 CD3-K 11Jan12 Heel 15,078.05 83.07 173.34 6,985.02 6,936.12 -3,685.30-10,666.90 6,000,232.92 377,137.29 0.00 -3,099.46 Start 20.00 hold at 15078.05 MD - 7-5/8" X 9-7/8" 15,097.08 83.07 173.34 6,987.31 6,938.41 -3,704.06-10,664.70 6,000,214.13 377,139.20 0.00 -3,082.84 311512012 7:18 10PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-127 Design: CD3-127wp08 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) 6,938.53 15,098.05 83.10 173.31 6,987.43 6,938.53 -3,705.01-10,664.59 6,000,213.17 377,139.30 4.00 -3,081.99 Start DLS 4.00 TFO -35.00 15,100.00 83.16 173.27 6,987.67 6,938.77 -3,706.94-10,664.37 6,000,211.24 377,139.50 4.00 -3,080.28 15,200.00 86.44 170.97 6,996.72 6,947.82 -3,805.57-10,650.71 6,000,112.43 377,151.67 4.00 -2,991.66 15,286.24 89.28 169.00 6,999.94 6,951.04 -3,890.42-10,635.73 6,000,027.37 377,165.37 4.00 -2,913.56 Start DLS 4.00 TFO -90.12 15,286.58 89.29 169.00 6,999.95 6,951.05 -3,890.76-10,635.66 6,000,027.03 377,165.43 4.00 -2,913.24 15,300.00 89.29 168.46 7,000.11 6,951.21 -3,903.91-10,633.04 6,000,013.84 377,167.86 4.00 -2,900.96 15,400.00 89.28 164.46 7,001.36 6,952.46 -4,001.11-10,609.63 5,999,916.31 377,189.80 4.00 -2,807.92 15,500.00 89.28 160.46 7,002.61 6,953.71 -4,096.43-10,579.50 5,999,820.55 377,218.49 4.00 -2,712.55 15,600.00 89.28 156.46 7,003.87 6,954.97 -4,189.42-10,542.80 5,999,727.03 377,253.79 4.00 -2,615.33 15,700.00 89.29 152.46 7,005.12 6,956.22 -4,279.62-10,499.69 5,999,636.20 377,295.54 4.00 -2,516.72 15,800.00 89.29 148.46 7,006.36 6,957.46 -4,366.60-10,450.40 5,999,548.50 377,343.51 4.00 -2,417.20 15,873.71 89.30 145.51 7,007.27 6,958.37 -4,428.40-10,410.24 5,999,486.11 377,382.73 4.00 -2,343.54 Start 5875.87 hold at 15873.71 MD 15,874.51 89.30 145.48 7,007.28 6,958.38 -4,429.05-10,409.79 5,999,485.45 377,383.18 4.00 -2,342.74 15,900.00 89.30 145.48 7,007.59 6,958.69 -4,450.05-10,395.35 5,999,464.24 377,397.30 0.00 -2,317.26 16,000.00 89.30 145.48 7,008.81 6,959.91 -4,532.44-10,338.68 5,999,381.02 377,452.72 0.00 -2,217.27 16,100.00 89.30 145.48 7,010.02 6,961.12 -4,614.82-10,282.01 5,999,297.80 377,508.14 0.00 -2,117.28 16,200.00 89.30 145.48 7,011.24 6,962.34 -4,697.20-10,225.34 5,999,214.58 377,563.56 0.00 -2,017.29 16,300.00 89.30 145.48 7,012.46 6,963.56 -4,779.59-10,168.67 5,999,131.36 377,618.98 0.00 -1,917.30 16,400.00 89.30 145.48 7,013.68 6,964.78 -4,861.97-10,112.00 5,999,048.14 377,674.40 0.00 -1,817.31 16,500.00 89.30 145.48 7,014.90 6,966.00 -4,944.36-10,055.33 5,998,964.92 377,729.82 0.00 -1,717.32 16,600.00 89.30 145.48 7,016.12 6,967.22 -5,026.74-9,998.66 5,998,881.70 377,785.24 0.00 -1,617.33 16,700.00 89.30 145.48 7,017.34 6,968.44 -5,109.13-9,942.00 5,998,798.48 377,840.66 0.00 -1,517.34 16,800.00 89.30 145.48 7,018.56 6,969.66 -5,191.51-9,885.33 5,998,715.27 377,896.08 0.00 -1,417.36 16,900.00 89.30 145.48 7,019.78 6,970.88 -5,273.89-9,828.66 5,998,632.05 377,951.50 0.00 -1,317.37 17,000.00 89.30 145.48 7,021.00 6,972.10 -5,356.28-9,771.99 5,998,548.83 378,006.92 0.00 -1,217.38 17,100.00 89.30 145.48 7,022.22 6,973.32 -5,438.66-9,715.32 5,998,465.61 378,062.34 0.00 -1,117.39 17,200.00 89.30 145.48 7,023.44 6,974.54 -5,521.05-9,658.65 5,998,382.39 378,117.76 0.00 -1,017.40 17,300.00 89.30 145.48 7,024.66 6,975.76 -5,603.43-9,601.98 5,998,299.17 378,173.18 0.00 -917.41 17,400.00 89.30 145.48 7,025.88 6,976.98 -5,685.81-9,545.31 5,998,215.95 378,228.60 0.00 -817.42 17,500.00 89.30 145.48 7,027.09 6,978.19 -5,768.20-9,488.64 5,998,132.73 378,284.02 0.00 -717.43 17,600.00 89.30 145.48 7,028.31 6,979.41 -5,850.58-9,431.98 5,998,049.51 378,339.44 0.00 -617.44 17,700.00 89.30 145.48 7,029.53 6,980.63 -5,932.97-9,375.31 5,997,966.29 378,394.86 0.00 -517.45 17,800.00 89.30 145.48 7,030.75 6,981.85 -6,015.35-9,318.64 5,997,883.08 378,450.28 0.00 -417.46 17,900.00 89.30 145.48 7,031.97 6,983.07 -6,097.73-9,261.97 5,997,799.86 378,505.70 0.00 -317.48 18,000.00 89.30 145.48 7,033.19 6,984.29 -6,180.12-9,205.30 5,997,716.64 378,561.12 0.00 -217.49 18,100.00 89.30 145.48 7,034.41 6,985.51 -6,262.50-9,148.63 5,997,633.42 378,616.54 0.00 -117.50 18,200.00 89.30 145.48 7,035.63 6,986.73 -6,344.89-9,091.96 5,997,550.20 378,671.96 0.00 -17.51 18,300.00 89.30 145.48 7,036.85 6,987.95 -6,427.27-9,035.29 5,997,466.98 378,727.38 0.00 82.48 18,400.00 89.30 145.48 7,038.07 6,989.17 -6,509.66-8,978.62 5,997,383.76 378,782.80 0.00 182.47 18,500.00 89.30 145.48 7,039.29 6,990.39 -6,592.04-8,921.96 5,997,300.54 378,838.22 0.00 282.46 18,600.00 89.30 145.48 7,040.51 6,991.61 -6,674.42-8,865.29 5,997,217.32 378,893.64 0.00 382.45 18,700.00 89.30 145.48 7,041.73 6,992.83 -6,756.81-8,808.62 5,997,134.10 378,949.06 0.00 482.44 311512012 7:18:10PM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-127 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-127 Design: CD3-127wp08 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) 6,994.05 18,800.00 89.30 145.48 7,042.95 6,994.05 -6,839.19 -8,751.95 5,997,050.88 379,004.48 0.00 582.43 18,900.00 89.30 145.48 7,044.16 6,995.26 -6,921.58 -8,695.28 5,996,967.67 379,059.90 0.00 682.42 19,000.00 89.30 145.48 7,045.38 6,996.48 -7,003.96 -8,638.61 5,996,884.45 379,115.33 0.00 782.40 19,100.00 89.30 145.48 7,046.60 6,997.70 -7,086.34 -8,581.94 5,996,801.23 379,170.75 0.00 882.39 19,200.00 89.30 145.48 7,047.82 6,998.92 -7,168.73 -8,525.27 5,996,718.01 379,226.17 0.00 982.38 19,300.00 89.30 145.48 7,049.04 7,000.14 -7,251.11 -8,468.60 5,996,634.79 379,281.59 0.00 1,082.37 19,400.00 89.30 145.48 7,050.26 7,001.36 -7,333.50 -8,411.94 5,996,551.57 379,337.01 0.00 1,182.36 19,500.00 89.30 145.48 7,051.48 7,002.58 -7,415.88 -8,355.27 5,996,468.35 379,392.43 0.00 1,282.35 19,600.00 89.30 145.48 7,052.70 7,003.80 -7,498.27 -8,298.60 5,996,385.13 379,447.85 0.00 1,382.34 19,700.00 89.30 145.48 7,053.92 7,005.02 -7,580.65 -8,241.93 5,996,301.91 379,503.27 0.00 1,482.33 19,800.00 89.30 145.48 7,055.14 7,006.24 -7,663.03 -8,185.26 5,996,218.69 379,558.69 0.00 1,582.32 19,900.00 89.30 145.48 7,056.36 7,007.46 -7,745.42 -8,128.59 5,996,135.48 379,614.11 0.00 1,682.31 20,000.00 89.30 145.48 7,057.58 7,008.68 -7,827.80 -8,071.92 5,996,052.26 379,669.53 0.00 1,782.30 20,100.00 89.30 145.48 7,058.80 7,009.90 -7,910.19 -8,015.25 5,995,969.04 379,724.95 0.00 1,882.28 20,200.00 89.30 145.48 7,060.01 7,011.11 -7,992.57 -7,958.58 5,995,885.82 379,780.37 0.00 1,982.27 20,300.00 89.30 145.48 7,061.23 7,012.33 -8,074.95 -7,901.91 5,995,802.60 379,835.79 0.00 2,082.26 20,400.00 89.30 145.48 7,062.45 7,013.55 -8,157.34 -7,845.25 5,995,719.38 379,891.21 0.00 2,182.25 20,500.00 89.30 145.48 7,063.67 7,014.77 -8,239.72 -7,788.58 5,995,636.16 379,946.63 0.00 2,282.24 20,600.00 89.30 145.48 7,064.89 7,015.99 -8,322.11 -7,731.91 5,995,552.94 380,002.05 0.00 2,382.23 20,700.00 89.30 145.48 7,066.11 7,017.21 -8,404.49 -7,675.24 5,995,469.72 380,057.47 0.00 2,482.22 20,800.00 89.30 145.48 7,067.33 7,018.43 -8,486.88 -7,618.57 5,995,386.50 380,112.89 0.00 2,582.21 20,900.00 89.30 145.48 7,068.55 7,019.65 -8,569.26 -7,561.90 5,995,303.29 380,168.31 0.00 2,682.20 21,000.00 89.30 145.48 7,069.77 7,020.87 -8,651.64 -7,505.23 5,995,220.07 380,223.73 0.00 2,782.19 21,100.00 89.30 145.48 7,070.99 7,022.09 -8,734.03 -7,448.56 5,995,136.85 380,279.15 0.00 2,882.18 21,200.00 89.30 145.48 7,072.21 7,023.31 -8,816.41 -7,391.89 5,995,053.63 380,334.57 0.00 2,982.17 21,300.00 89.30 145.48 7,073.43 7,024.53 -8,898.80 -7,335.23 5,994,970.41 380,389.99 0.00 3,082.15 21,400.00 89.30 145.48 7,074.65 7,025.75 -8,981.18 -7,278.56 5,994,887.19 380,445.41 0.00 3,182.14 21,500.00 89.30 145.48 7,075.87 7,026.97 -9,063.56 -7,221.89 5,994,803.97 380,500.83 0.00 3,282.13 21,600.00 89.30 145.48 7,077.08 7,028.18 -9,145.95 -7,165.22 5,994,720.75 380,556.25 0.00 3,382.12 21,700.00 89.30 145.48 7,078.30 7,029.40 -9,228.33 -7,108.55 5,994,637.53 380,611.67 0.00 3,482.11 21,748.88 89.30 145.48 7,078.90 7,030.00 -9,268.60 -7,080.85 5,994,596.86 380,638.76 0.00 3,530.98 CD3-K 25May10 Toe Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (°) (°) (ft) (ft) (ft) (ft) (ft) CD3-K 25J;ay1 I u. 0.00 0.00 7,078.90 -9,268.60 -7,080.85 5,994,596.86 380,638.76 plan hits target center Point CD3-K 11Jan12 Heel 0.00 6,984.90 -3,684.34 -10,667.01 6,000,233.88 377,137.20 plan hits target center Circle (radius 100.00) 3/15/2012 7:18:1OPM Page 8 COMPASS 2003.16 Build 69 Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wp08 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name 15,078.05 6,985.02 7-5/8" X 9-7/8" 7-5/8 9-7/8 3,239.52 2,453.85 10 3/4" 10-3/4 12-1/4 21,749.59 7,078.91 3-1/2" x 6-3/4" 3-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology 7,474.47 4,018.90 Qannik (K-2) 15,003.60 6,974.90 NECH_CRSUP 14,448.41 6,828.90 Top_Kup_C 12,284.83 5,808.90 Albian_96 14,344.99 6,788.90 Top_Kup_D/Base Lwr. Kalubik 7,012.35 3,848.90 K-3 14,467.54 6,835.90 LCU 7,746.30 4,118.90 Basal K-2 3,295.07 2,473.90 C-30 11,035.51 5,328.90 Albian_97 14,695.79 6,908.90 Base_Nuigsut 14,256.87 6,753.90 K-1/Top Lower Kalubik 14,130.99 6,703.90 Base_HRZ/Top Up. Kalubik 14,997.05 6,973.90 Top_Nechelik 13,617.12 6,483.90 CCS_Sh_Abv_HRZ 4,307.59 2,853.90 C-20 13,762.67 6,552.90 CCS_sh_Abv_HRZ_base 7,406.51 3,993.90 K-3 Basal 13,844.72 6,588.90 HRZ Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 3,290.00 2,472.05 -41.41 -1,577.26 KOP: DLS 2.00 TFO-150.00 3,330.00 2,486.84 -45.59 -1,614.19 Start DLS 3.00 TFO-120.00 3,360.00 2,498.21 -49.01 -1,641.73 Start DLS 3.00 TFO -90.00 3,760.00 2,650.17 -138.32 -1,999.99 Start DLS 2.00 TFO 90.00 4,292.51 2,848.35 -263.73 -2,477.22 Start 7547.90 hold at 4292.51 MD 11,840.41 5,625.00 -1,361.68 -9,409.43 Start DLS 3.50 TFO-113.70 13,589.35 6,470.00 -2,318.31 -10,481.59 Start DLS 2.00 TFO 0.00 13,934.86 6,626.00 -2,618.91 -10,548.94 Start 435.56 hold at 13934.86 MD 14,370.42 6,799.00 -3,008.97 -10,636.34 Start DLS 3.51 TFO -51.45 15,078.05 6,985.02 -3,685.30 -10,666.90 Start 20.00 hold at 15078.05 MD 15,098.05 6,987.43 -3,705.01 -10,664.59 Start DLS 4.00 TFO -35.00 15,286.24 6,999.94 -3,890.42 -10,635.73 Start DLS 4.00 TFO -90.12 15,873.71 7,007.27 -4,428.40 -10,410.24 Start 5875.87 hold at 15873.71 MD 21,749.59 TD at 21749.59 3/15/2012 7:18:10PM Page 9 COMPASS 2003.16 Build 69 m so ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-127 Plan: CD3-127 CD3-127wp08 Bperry Drilling Services Clearance Summary Anticollision Report 13 March, 2012 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3-127 - Plan: CD3-127 - CD3-127wp08 Well Coordinates: 6,003,504.45 N, 1,527,889.34 E (70° 25' 07.95" N, 150' 55' 00.20" W) Datum Height: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Scan Range: 3,290.00 to 21,749.59 ft. easured Depth. Scan Radius is 2,371.33 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTE APPLIED: II wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 --° --- HALLIBURTON Sperry Drilling Services ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for CD3-127 - CD3-127wp08 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3-127 - Plan: CD3-127 - CD3-127wp08 Scan Range: 3,290.00 to 21,749.59 ft. Measured Depth. Scan Radius is 2,371.33 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad CD3-112 - CD3-112 - CD3-112 3,290.00 1,923.97 3,290.00 1,859.66 4,400.00 29.914 Clearance Factor Pass - Major Risk CD3-114 - CD3-114 - CD3-114 3,307.47 478.35 3,307.47 428.17 3,625.00 9.532 Clearance Factor Pass - Major Risk CD3-115 - CD3-115 - CD3-115 3,305.69 457.48 3,305.69 382.28 3,525.00 6.083 Clearance Factor Pass - Major Risk CD3-117 - CD3-117 - CD3-117 13,891.31 288.61 13,891.31 101.77 13,475.00 1.545 Clearance Factor Pass - Major Risk CD3-117 - CD3-117 - CD3-117 13,932.73 275.61 13,932.73 113.49 13,575.00 1.700 Centre Distance Pass - Major Risk CD3-118 - CD3-118 - CD3-118 3,315.07 362.06 3,315.07 280.19 3,400.00 4.422 Centre Distance Pass - Major Risk CD3-118 - CD3-118 - CD3-118 4,013.49 370.27 4,013.49 271.34 4,050.00 3.743 Clearance Factor Pass - Major Risk CD3-122 - CD3-122 - CD3-122 3,313.15 1,114.94 3,313.15 1,054.74 3,825.00 18.521 Clearance Factor Pass - Major Risk CD3-123 - CD3-123 - CD3-123 3,290.00 749.77 3,290.00 679.30 3,550.00 10.639 Clearance Factor Pass - Major Risk CD3-124 - CD3-124 - CD3-124 4,071.61 347.28 4,071.61 251.47 4,000.00 3.625 Centre Distance Pass - Major Risk CD3-124 - CD3-124 - CD3-124 4,116.77 347.67 4,116.77 250.83 4,050.00 3.590 Clearance Factor Pass - Major Risk CD3-125 - CD3-125 - CD3-125 3,293.20 215.76 3,293.20 162.85 3,350.00 4.078 Clearance Factor Pass - Major Risk CD3-125 - CD3-125PB1 - CD3-125PB1 3,293.20 215.76 3,293.20 162.85 3,350.00 4.078 Clearance Factor Pass - Major Risk CD3-127 - CD3-127PB1 - CD3-127PB1 - CD3-127 - CD3-127PB1 - CD3-127PB1 _ CD3-128 - CD3-128 - CD3-128 3,300.19 184.88 3,300.19 113.25 3,275.00 2.581 Centre Distance Pass - Major Risk CD3-128 - CD3-128 - CD3-128 3,923.68 185.29 3,923.68 111.05 3,875.00 2.496 Clearance Factor Pass - Major Risk CD3-128 - CD3-128 (Intermediate) - CD3-128 (Interme 3,299.13 184.75 3,299.13 113.02 3,275.00 2.576 Centre Distance Pass - Major Risk CD3-128 - CD3-128 (Intermediate) - CD3-128 (Interme 3,922.73 185.30 3,922.73 110.94 3,875.00 2.492 Clearance Factor Pass - Major Risk Plan: CD3-126 - Plan: CD3-126 - CD3-126wp04 3,302.08 148.69 3,302.08 78.82 3,250.00 2.128 Clearance Factor Pass - Major Risk Plan: CD3-129 - Plan: CD3-129 - CD3-129wp01 3,312.82 240.48 3,312.82 169.09 3,175.00 3.369 Clearance Factor Pass - Major Risk WNS (Various) Nechelik 1 - Nechelik 1 - Nechelik 1 F 13 March, 2012 - 13:16 Page 2 of 5 COMPASS Conocophillips(Alaska; Tne. -WNS HALLIBURTON Anticollision Report for CD3-127 - CD3-127wp08 Survey tool grogram From To Survey/Plan Survey Tool (ft) (ft) 79.30 476.30 CB -GYRO -SS 516.03 3,202.56 MWD+IFR-AK-CAZ-SC 3,300.93 3,290.00 MWD+IFR-AK-CAZ-SC 3,290.00 15,078.05 CD3-127wp08 MWD+IFR-AK-CAZ-SC 15,078.05 21,749.59 CD3-127wp08 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Western North Slope 13 March, 2012 - 13:16 Page 3 of 5 COMPASS m m H M = < N C l0 O o H U V �i,rn v�i,m voi,m t4 GQ p�ONN�mf000O�c]N � �pggtpph rl t?t�NNM FpO gN�SOt700�0050 N QGHt7 l7 lV Gt7N yO NjOQOG W 3^N�pnSNVNQOd�i �t�plrVNr� Z W NtO fOS V mO(t{pp�(fO(pOp fIQfpOpS V O W �Q�OCN'f rf0 t'+lA W m0 V MN N 2�uf of t�i t��O���o giN� *vvv�Nt7'„ tOnmdN i>OW{7 OOO fhn�A CI tm�G Ip �C�n GayG tYOf OO fG Ol opmf�I�Oi IG�W N �Q`1 N �0y`1 N(ON tO m(D tDSro00 �r�ON�S N m S N N COI O< CI Ih N NNfV OI OImNN t0 f0 f00f0 f0 AOI OIhhtOdd C tdO A YOfO QQm�S�pp .....ffpp 2 OpS6g�p.; lql mO CGq- N 17 �'1�N�NO�i t7rONop� lh l7 l�mQ� �2 V;l����N m�Nl7d Of0 l�Wg0'N" N Immil 14"M I HH 8as�i� I-- O O W srss��ps����am�oatt� w oa $$$$$��a€ouUuuuuo N a �u u:.i amawNNwaa"e,6 � - N N V .O o E o HALLIBURTOIN, ConocoPhillips CD3-127wp08 Alaska Sperry Drilling ANTI -COLLISION SETTINGS 1 10 V, h 132012 Interpolation Method: MD, interval: 25.00 Depth Range From: 3290.00 To 21749.59 Results Limited By: Centre Distance: 2371.33 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 79.30 476.30 CD3-127PB1 Gyro (R100) (CD3-127PB1) CB -GYRO -SS 516.03 3202.56 CD3-127PB1 (R100) (CD3-127PB1) MWD+IFR-AK-CAZ-SC 3300.93 3290.00 CD3-127PB1 (R200) (CD3-127PB1) MWD+IFR-AK-CAZ-SC 3290.00 15078.05 CD3-127wp08 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC 15078.05 21749.59 CD3-127wp08 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2453.85 3239.52 10 3/4" 10-3/4 6984.90 15078.05 7-5/8" X 9-7/8" 7-5/8 7078.90 21749.59 3-1/2" x 6-3/4" 3-1/2 E ^e as G M V CN 300 - - O I m CL d 150 _ ___ o Failed ui- olli ioD l C N 0 i 6000 9000 12000 15000 1800, 210,)n Measured Depth LEGEND - CD3-112, CD3-112, CD3-112 V3 -- C133-125, CD3-125, CD3-125 VO -e- Plan: CD3-120, Plan: CD3-120, CO3-120wp08 VO C133-114, CD3-114, C133-114 V14 CD3-125, CD3-125PB1, CD3-125PB1 VO $ Plan: CO3-126, Plan: CD3-126, CD3-126wp04 VO CO3-115, CD3-115, CD3-115 VO CD3-125, CD3-125PB1 (surface), CD3-125PB1 (surface) VO Plan: CD3-129, Plan: CD3-129, CD3-129wp01 VO -�- CD3-117, CD3-117, CD3-117 VO CD3-127, CD3-127P81, CD3-127PB1 VO -$- Plan: CO3-130, Plan: CD3-130, CD3-130wp03 VO -� CD3-118, C133-118, CD3-118 VO CO3-128, CO3-128. CD3-128 VO -e- Rig: CD3-119, Plan: C133-119, CD3-119wp13 VO CD3-121, CD3-121, CO3-121 VO -- CO3-128, CD3-128 (Intermediate), C133-128 (Intermediate) VO --e- Rig: CD3-119, Plan: CD3-119PB1, CD3-119PB1 VO CD3-122, CD3-122, CO3-122 VO -e- CO3-316, CD3-316, CD3-316 VO Rig: CD3-119, Plan: CD3-119P61, CD3-119PB1wp12 VO - CD3-123, C01123, CD3-123 VO CD3-316, CD3-316A, CD3-316A VO Nechelik 1, Nechelik 1, Nechelik 1 VO CD3-124, CO3-124, CD3-124 VO CD3-316. CD3-316AP81, CD3-316APB1 VO CD3-127wp08 Northing (4000 ftlin) C 0 0 CD w m A W N T O N Cl) T L V i l6 pip V m O (p M C`') (� M ❑ co N U 0 n N Cl M 3 nrn 0 p U U T Cl) ❑ CJ M U n O U N co r Cl) N N m Ln ❑ U Cl) N M ❑ U LO N M co O ❑ N O cY 3 aN U ❑ .N- N a>.- €M M ❑ M cU ❑ iV U Q Cl) to N CO CDY ' ❑ Q N t U M Cl) N N Z U A U p U Cl) ❑ n U Cl) ❑ U y Z e. G. p-0 M C o IL a o0 L vZ M 30 Q- L. M V� s U v� O C O U (U!Ill OOOti) pui4PoN 0009z9L 0007ZSL OOO<:ZS L OOL 1 OOOLZSL 000OZ9L f � { 0006M 000BLSL OOOLl4l 0009LS1 0009M 0007LSL g 8 OOOELSL v R R � � RLL O CL E) 4V�oS / (+) WON c S c Y > s° s p D7 GCy O � N N p 0 p cc > 00 ti n 0o i- O O CO N (7) "T N M N Lo O r O r r n N N N O f6 00 0 0 cn CO(Mr to O O co M LO r r r r 3 J N N r r r r r e� 0 M M M M U O 0000 m IL UUUU z p5 E 5 OOL9 OOL9 OOLP OOLC WE OOLL OOL OOE- a� a m- OOEZ- 0 0 rO oaci- b U t 00cv- 0065- OOf9- ODEL- OO£8- OOC6- 00£OL- 00£LL- OOCZL- J 0 a O V w Q a v co o � � (L � N ❑ � O V WaCM, (NO � ❑ O th C� O J � O N_ 5F N QaQ y_ �`8yi 1� J � Q N N QJ u? U a ad O gm 5 I s a E O E c EE N U r M ❑ C N co, O N U a cn > W fO N <n > � N m � co > � W N m co > � N V j > zww W V lfi In r N N W z w ¢ a z w a z w 6 a z w Y r co N t9 co `B> > `B> > > rn r (n r M M M v aa)) w o p w ❑ w ❑ w Z � ry U (If\/ W F- M V F M 01 0 0 vi n v O po ry N ❑ � w O tN0 � ❑ c� �3pS J � (7 lMU J � m s C o QQ �_ r. N y c Q rn ❑^ Q m 0 E ,� °v' t ro d E . p . c5 E a ;z m E .. s o5 rn g V ❑ N Z ^ O d N ❑U ❑ N U N ❑ N ❑U N cn n U)M U) u� m uvi > > r > > p r a N IL co ao co Co y �3 5 3 6 3 65 C a a a $ N ¢ z w N ¢ z w N ¢ z w N c5 ¢ z` w ❑ n N o ~ ❑i � r w n ❑ h r n cQ `oS W `B> > U) r e M U M V M V ❑ U w r ui _ w ui _ w c+i _ w ci _ ¢ ¢ ¢ ¢ O O O Z m m m O O O O k k k k U) M N7 tll co (a N O ii m O t'i A N O Ti m O Ts A N CD3-127wp08 Surface Location El (PAI (oot dinate (onvetter ��`p From: _ _ To: _ Datum: NA-3 .', Region: Ialaska . Datum: NAD27 Region: Ialaska .� C Latitude/Lon itude 9 ;Decimal Degrees . �' LatitudefLongitudeDecimal Degrees 71 C UTM Zone: F— F" South r UTM Zone: True South r* State Plane Zone: ; Units: us�t ( State Plane Zone: True Units: rus•ft f al rF<rrintinr, (NAD27 only) to Legal Description (NAD27 only) Starting Coordinates: — Legal Description ------------------- X: "1527889.34 Township: i012 �N ,—1 Range: 005 E � Y: 6003504.45 Meridian: U Section: !FNL .] 14022.0836 FEL w] 1185.2521 ........................................................... Transform Quit Help CD3-127wp08 Kick-off Point M (F'AI (oot dinate (onvetter ��❑ r n I VI II. Datum: NAD83 Region jalaska r Latitude/Longitude Decimal Degrees l' UTM Zone: South fe State Plane Zone: 14 Units: us-ft t Legal Description (NAD27 only) Starting Coordinates: Y 1152Ml.77 Y: 6003486.82 Datum: ;NAD27 Region: lalaska { Latitude/Longitude IDecimal Degrees r UTM Zone: True F South r State Plane Zone: True . Units: us.ft r* Legal Description (NAD27 only) Legal Description Township: 012 N Range: juva E Meridian: IU Section:F �FNL 4063.5286 FEL 2762.6 558 Transform ............. Quit ! Help CD3-127wp08 Intermediate Casing n (F'AI (oordinate (onverter- From: To: _._. Datum: NAD83 Region: alasca . Datum: NAD27 Region: alaska r Latitude/Longitude DDecimal Degrees J r LatitudelLongitude Decimal Degrees (' UTM Zone: ' South r State Plane Zone: iii4 Units: ;us-ft r Legal Description (NAD27 only) Starting Coordinates: X: 1617169.15 Y: 15999980.64 (- UTM Zone: (True r South C State Plane Zone: True . Units: '',us-ft� +: Legal Description (NAD27 only) Legal Description ----------------- ---- Township: F012 _ I" Range: I�^E Meridian U - Section 12 JFNL J 2433.7597 !FEL •� 1799.5808 Transform ............ _._Quit (--- Help ---� CD3-127wp08 TD n (RAI Coordinate Converter From: Datum: NAD83 Region: alaska Datum: NAD27 . Region: jalaska C Latitude/Longitude Decimal Degrees �J f Latitude/Longitude IDecimalDegrees C UTM Zone: — ( South C" UTM Zone: Fue — r South r: State Plane Zone: ;4 Units: C State Plane Zone: due � Units: us-ft C` Legal Description [NAD" only) r• Legal Description (NAD27 only) Starting Coordinates: Legal Description ------ --- X: 1520670.87 Township: F012 rN .wRam 005 E I Y: 5994343.79 Meridian: �U3,Section 18 FNL w 2733.7714 FEL w 3013.7962 ` Transform Quit Help CD3-127wp08 3290.00 To 4001.00 ova 111 411 b a,...n.�.. ..`®` moo.» "� ac n ,lazaoi wo3.vre.m+xczsc C -90/ 51 NO GLOBAL FILTER: Using user defined selection & filtering criteria E6psoid Cclor 0 3200 4200 4450 6450 7200 1220D 14700 22700 24200 3200 3450 4450 4700 7200 8200 14700 17200 24200 25200 3450 3700 4700 -- 5200 8200 9200 17200 19200 25200 26200 3700 3950 5200 5700 9200 10700 19200 - 21200 26200 -- 26950 3950 _-- -- 4200 5700 6450 10700 -- -- 12200 21200 22700 26950 -- 27450 0 / 360 -180 / 180 90 �D3-12 errnediat ) Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation (100 ailedArxi-Callisi LEGEND CD3112, CD3112, CD3112 V3 CO3N4, CD3114, CM114 V14 C133115, CD3115, CM115 VO SECTION DETAILS I Iaia% March 13 21 Sec MD Inc Azi TVD +N/S +EI-W DLeg TFace VSee Target 1 3290.00 68.64 263.77 2472.05 41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00 4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70 4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 -51.45-3099.37 CD3-K 11Jan12 Heel 11 1508.05 83.11 173.29 6987.30-3705,04-10664.45 0.00 0.00-3081.88 12 152:6.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 35.00-2913.42 13 15873.71 89.30 145.48 7007.10 4428.30-10409.75 4.00 -90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CD3-K 25May10 Toe C03117. CD3117, CM117 VO -60 ) CD3118, CD3118, CD3118 VO CD3121, M3.121, CM121 VO CD3122. CM 22, CO3.122 VO CD3123, CO3-123, C03123 VO C03124, C103-124, CO3-124 VO C03125, CD3125, CM125 VO C03125, CD3125PB1, CD3.125PB1 VO CD3125, CD3al 125PB1 (aace), CD3.125PB1 (aeKece) 0 CD3-127, C03127P81, CD3127PB1 VO CD3128, CD3128, CD3128 VO -90 / 270 CD3128, CD3128 (Intermediate), CD3128 (Intemedate VO CD3316, CD3316, COM16 VO CD3316 C03316A, C03316A VO CO3.316, C103316AP81, CD3316APB1 VO Plan: CD3120, Nan: CD3120, CD3120ap08 VO Plan: CD3126, Nan: CD3126, CD3126ap04 VO Plan: CO3.129, Nan: CD3129, CD3129p01 VO Nan: CD3130, Nan: C133130, CD3-130p03 VO Rig: CD3119, Plan: CO3-119, CD3119ap13 VO 1 -120 / Rig: CD3119, Plan: CD3119PB1, CD3119PB1 VO Rig: CD3119, Plan: CD3119PB1, CD3119PBI p12 VO Nechelik 1, Nechelik 1, NadWik 1 VO CD3-127PB1 0 / 360 90 -180 / 180 Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 Win] CD3-127wp08 3290.00 To 5001.00 NO GLOBAL FILTER: Using user defined selection & filtering criteria 0 3200 3450 3700 3950 3200 3450 3700 39M 4200 4200 4450 4700 5200 5700 4450 4700 5200 5700 6450 Elpsoklcaor 6450 7200 8200 9200 10MO 72M 122M 8200 14700 9200 17200 10700 19200 - 12200 212W 14700 22700 17200 24200 19200 25200 21200 26200 =700 26%0 tmn r..o�n n arv.r oei�ima+nr"rz s 4 cmp3.i�:o m.w.czsc 6D3 -90 / K 0 / 360 -180 / 180 LEGEND �- CD3112, CD3112, CD3112 V3 C03114, CD3.114, CD3114 V14 -E)- C03115, CD3.115, CD3115 VO --*- CD3117, CD3.117, CM117 VO C03118, CD3118, CM118 VO �- C03121, CD3121, CD3121 VO -{}- CD3122, CD3122, CD3122 W �- CD3.123, C03123, CD3123 VO CD3124, CD3.124, CD3124 VO �- CD3.125, CD3.125, CD3125 VO -ie CD3125, CO3-125PB1, CD3125PB1 VO -� CD3125, CD3125PB1 (aurfete), CD3-125PB1 (wr(aea) 90 - CD3127, CD3127P81, CD3.127PB1 VO -8- CD3128, CM 28, CD3128 VO CD3128, CD3-128 (Inlemretliale), CD3128 Omer-diale _,q- CD3316, CD3316, CD3316 VO -� CD3316, CD3316A, CD3316A W - CD3316, CD3316APB1, CD3316AP81 W �- Plan: CD3120, Fan: CD3120, CD3.120p08 VO $- Fan: CD3126, Fan: CD3.126, CD3.126p04 VO -8- Fan: CD3.129 Ran: CD3.129, CD3129p01 VO �- Fan: CD3130, Fan: CD3.130, CD31p 3003 W �- Mg: CD3.119, Fan: C03119, C03119m13 VO Fg' CD3119, Fan: CD3.119PB1, CD3119P81 VO D3-12 $ Mg: CD3119, Fan: CD3.119PB1, CD3119PB1 p12 W - . NediNik 1, Nechelik 1, Nechelik 1 W -�- CD3127rp08 (Intermediat ) Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ft/in] 24200 25200 26200 26950 27450 -90/ VO SECTION DETAILS I 13.40. March 13 21 Sec MD Inc Azi TVD +N1-S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 41.41-1577.26 0.00 0.00 -870.75 2 3330.00 67.95 263.34 2.6.84 45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00 4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70 4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 51.45-3099.37 CD3-K 11Jan12 Heel 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 35.00-2913.42 13 15873.71 89.30 145.48 7007.10-4428.30-10409.75 4.00 -90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CO3-K 25May10 Toe FCD3-127PB11. 0 / 360 90 -180 / 180 Azimuth (TFO+AZI) [o] vs Centre to Centre Separation [25 ft/in] CD3-127wp08 3290.00 To 6001.00 CD3 -90 / Qil NO GLOBAL FILTER: Using user defined selection & filtering criteria 0 3200 4200 4450 6450 3200 3450 4450 4700 7200 3450 3700 4700 5200 8200 3700 - 3950 5200 5700 9200 3950 4200 5700 6450 10700 D3-127PB 0 / 360 -180 / 180 Empadd Cdor 7200 12200 147DO 227DO 24200 8200 14700 17200 242DO 25200 9200 17200 19200 25200 26200 10700 19200 21200 26200 - - 26950 12200 21200 22700 26950 27450 LEGEND C133-112. CD3112, CD3112 V3 CD3114, CD3114, CD3.114 V14 -�- CD3115, CD3.115, CD3.115 VO -� C133-117. CM117. CD3.117 VO -� CD3.118, CD3118, CM11B VO -� CD3.121, CD3.121, CD3.121 VO CD3.122, CD3.122, CD3.122 VO CD.3.123, CD3123, CD3123 VO �- CD3.124, CD3.124, CD3124 VO -�- CD3.125, CD3.125, CD3-125 VO 003.125, CD3.125PB1, CD3.125P81 VO --�- CD3.125, CD3.125P81 (surface), CO3-125P81 (surface) CD3-127, CD3-127PB1, CD3.127PB1 VO 90 CD3.128. CD3128. CD3-128 VO -£- CD3.128, CD3.128 (Intermediate), CD3-128 9nbmledak C03316, C03316, C03316 VO -� CD3316. CD3316A, CD3316A VO CD3316, CD3316APB1, CD3316APB1 VO Plat CO3.120, Plan: CD3120, CD3-120sp08 VO -B- Ma: CO3-126, Plan: CD3126, CD3-126ep04 VO -Q- Nan: CO3.129, Plan: C03129, CD3.129p01 VO Man: CD3130, Men: CD3.130. CD313Dp03 VO $- 16g: CD3.119, Man: CD3119, CD3.119ep13 VO R9' CD3119, Man: CD3119PB1, CD3119PB1 VO D3-12 F Rig: C03119, Men: CD3119PB1, CD3119PBi sp12 VO -$- Nechalik 1. Nackelik 1, Neckelik 1 VO CD3-127wp08 (Intennediat ) Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ft/in] SECTION DETAILS 1 13:40, March 13 2012 See MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00-150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00-120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00 4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50-113.70-4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905-34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 51.45-3099.37 CD3-K 11Jan12 Heel 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 -35.00-2913.42 13 15873.71 89.30 145.48 7007.10-4428.30-10409.75 4.00 -90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CD3-K 25May10 Toe -60 / -90 / 270 -120 / CD3-127PB7 0 / 360 -180 / 180 Cylinder Azimuth (TFO+AZF) [°] vs Centre to Centre 90 CD3-127wp08 3290.00 To 7001.00 NO GLOBAL FILTER: Using user defined selection & filtering criteria 0 32DO 3450 37DO 3950 3200 3450 3700 3950 4200 4200 4450 4700 5200 5700 4450 4700 5200 5700 6450 6450 72DO 82DO 92DO 10700 Ellipsoid Color 7200 12200 8200 14700 9200 17200 107W 19200 12200 21200 14700 22700 17200 242DO 19200 252DO - - 21200 26200 22700 26M 24200 25200 26200 26950 27450 l �sma os��.nsecminwn`pOBa. :�:u wi s"`.c.r zsc / 11 D3-127P8 0 / 360 -180 / 180 LEGEND -f-- CD3-112, CD3112, CM112 V3 -I&- C133114, CD3114, CM114 V14 -B- CD3115. CD3115. CM115 VO -� C133-117. M3 17. CD3417 VO -� M3.118, C133-118, CD3118 VO --&- M3.121, CO3-121, C133121 VO CD3122, C133122, CM122 VO CD3123, C131123, CM123 VO -�- M3.124, CD3124, CD3124 VO -�- M3.125, CD3.125, CD3125 VO C133125, CD3125PB1, CD3125PB1 VO -� M3.125, CD3.125PB1 (eudaee), CD3.12SP81 (wdace) CD3127, CD3127PB1, CD3-127PB1 VO 90 CD3128, CO3-128, CD3.128 VO -�- CD3.128, CD3.128 (Int-diate), CD3.128 (Inl-did CD3316, CD3318, CD3316 VO -�- CD3316, C133316A. CD3316A VO C03316, C133316AP81, CD331SAP81 VO Plan: C153-120, Plan: CD3.120, CD3120"M VO -B- Plan: CD3.126 Plan: CD3126, CD1126xp04 VO -e- Nan: C133-129, Plan: C03129, CD3129p01 VO Nan: C133130, Nan: C03130, CD313DmM VO Rig: CD3-119, Nan: C133119, C03119v 13 VO 99: CD3119, Nan: CD3119P81, CD3119PB1 VO k D3-12 $ Rig: CD3119, Nan: C133119PB1, CD3119PB1"12 V0 -f 3- Nec ik 1, Neckelik 1, Ne"ik 1 VO -� CD3127wp08 (Intermediat ) Travelling Cylinder Azimuth (TFO+AZI) [y vs Centre to Centre Separation [100 ft/in] -90/ 51 SECTION DETAILS 1 13:41, March 13 21 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00-150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00-120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.61 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00-4281.60 7 13689.35 59.69 192.63 6470.00-2318.31-10481.59 3.50-113.70 4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 -51.45-3099.37 CD3-K Men12 Heel 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 -35.D0-2913.42 13 15873.71 89.30 145.48 7007.10 -4428.30-10409.75 4.00 -90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00. 3531.89 CD3-K 25May10 Toe CD3-127PB1 0 / 360 -180 / 180 Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre 90 CD3-127wp08 3290.00 To 6001.00 0 z,va; 1`i°m"�im a�.'na�O n« caac 3200 9se min�°0°pe�w«c 3450 3700 3950 -30 / D3-126wp0 -60 / 300 Ails -90 / 270 D3-127P6 NO GLOBAL FILTER: Using user defined selection & filtering criteria E9ipeaid Cale 3200 4200 4450 6450 72DO 12200 14700 22700 - 3450 4450 4700 7200 8200 14700 17200 24200 - 3700 4700 ---" 52DO 8200 9200 17200 19200 25200 - 39W 5200 5700 9200 10700 19200 21200 26200 - 4200 5700 6450 10700 - 12200 21200 - --- 227DO 26950 0 / 360 � 1 1 / -120 / 240 -150 / 210 -180 / 180 F�IedA LEGEND $ CD3112, CO3-112, CO3-112 V3 $ CD3114, CD1114, CD3-114 V14 -{�- CD1115, CD3-115, CD3-115 VO 60 $ CD3117, CD3m, CD3.117 VO CD3118, CD3118, CD3-118 VO -�- CD3121, CD3121, CD3-121 VO -f3- CD3122, CD3122, CD3-122 VO $ CD3123, CD3123. CD3123 VO CD3124, C03124, CD3-124 VO -�- CD3125, C133125, CD3-125 VO CD3.125, CD3.125P81, CD3.125PB1 VO -� CD3.125, CD3125PB1 (solace), CD3125PBl (.dace) M3-127, CD3127P81, CD3127PB1 VO 90 $ CD3128, CD3128, CD3128 VO $ cc1128, C133-128 CD3128 Dnlemodiak $ CD3316, CD3316, CD3416 VO -� CD3316, CD33164, C033184 VO CD3316, CD3.3 6APB1, CD3316AP81 VO Plan: CD3120, Ren: C03120, CD3120gM VO �- Plan: CD3126, Ren: CD3126, CD3128ap04 VO $ Ran: CD3129, Ran: CD3-129, CD3129ep01 VO $ Ren: CD3130, Ran: CD3130, CD3130ep63 VO 120, $ Rg: CD3119, Ran: CD3119. C03119e 13 VO D3-12 $ �(- Big: CD3.119, Ren: CD3119P81, CD3119MI VO Po9: CD3119, Plan CD - 9PB1, CD3119P61xp121N $ Netlhe ik 1, Nad.8k 1, N3a"ik 1 VO III l $ CD3/27m,08 V D3-128 (Intermediat ) 50 Travelling Cylinder Azimuth (TFO+AZI) [y vs Centre to Centre Separation [100 ft/in] SECTION DETAILS 1 1 •41 1 Sac MD Inc Azi TVD +NIS +E/-W DLeg TFace VSec Target 1 3290.DO 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 45.59-1614.19 2.00 -150.00 -888.52 3 3360.00 67.50 262.49 2498.21 49.01-1641.73 3.D0 -120.00-901.51 24200 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 25200 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 6 11840.41 68.42 261.00 5625.D0-1361.68-9409.43 2.00 0.D0 90.00-1204.84 0.00-4281.60 26200 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 26950 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 27450 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.D0 3.51 0.00 0.00-3635.95 51.45-3099.37 CD3-K 11J802 Heal 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 -35.00-2913.42 13 15873.71 89.30 145.48 7007.10 4428.30-10409.75 4.00 -90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CO3-K 25May10 Toe -60 / -90 / 270 -120 / CD3-127PB1 0 / 360 180 / 180 Azimuth (TFO+AZI) [a] vs Centre to Centre 90 Win CD3-127wp08 3290.00 To 10001.00 rmow. n a.�.�..,.� 0 zsrolI� 's`xux 3200 �s,n os��.a�cmizrs'pOBom aimwm,�xrizac 3450 3700 3950 im -90/ 51 NO GLOBAL FILTER: Using user defined selection & filtering criteria Ellipsoid Color 3200 4200 4450 6450 7200 12200 14700 227DO 3450 4450 4700 7200 -- 8200 14700 17200 24200 - 3700 4700 5200 8200 9200 17200 19200 252DO - 3950 52DO 5700 9200 10700 19200 21200 26200 4200 5700 6450 10700 12200 21200 22700 269M D3-127PB 0 / 360 -180 / 180 LEGEND -� C133-112, CD3.112. CD3.112 V3 -e- C083114, C1333114, CM114 V14 43- C03115, CD3115, CD3-115 VO --0- C03117, CD3117, CD3.117 VO -� C133118, C133118, CD3118 VO -�- C03121, CD3121, CD3.121 VO CD3.122, C133.122, CD3.122 VO -£- C133.123, CD3.123, CD3.123 VO CD3124, CO3-124, CD3.124 VO -�- CD3-125, CD3-125, CM125 VO CD3.125, C103-125Pa1, CO3�125P61 VO $- W3.125, CD3125P81 (eudacel. CD3125PB1 (aedece) CD3.127. CD3127P81, CD3.127P81 VO 90 -� C03128, CD3128. CD3128 VO -�- .1. CD3126 (Inlemietliab), C133126 Qnleff,"ak C03316, CD3316, CD3316 VO -� CD3316, CD3316A, CDM16A VO C13"16, CD3316AP131, CD3.316APB1 VO Ran: C03120, Plan: C133120, CD3120MM VO -� Ran: C03126, Ran: M3.128, CD3126vp04 VO -Q- PIw: C133129. Ren: C03129, CD3129a4)01 VO Ran: C133130, Ran: M3.130, CD3.130npM VO 1 g: C133-119, Plan: C03119, CD1119vp13 VO RB' CD3118, PI- CD3119PB7, CD3119PBl VO aq: CD3119, Plan: CD3119PBi, CD3n9PBlwl2 VO - 3- Nedielk 1, Nechefk 1, Ne iWik 1 VO CD3.127vvp08 (Intermediat ) Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 Win] SECTION DETAILS 1 Sec MD Inc Azi TVD +NAS +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 49.01-1641.73 3.00 -120.00-901.51 24200 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 25200 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00 4281.60 26200 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.60 -113.70 4112.95 26950 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 27450 9 14370.42 66.60 192.63 6799.00-3DO8.97-10636.34 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.00 3.51 0.DO 0.00-3635.95 51.45-3099.37 CD3-K 11Jan12 Heel 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 35.00-2913.42 13 15873.71 89.30 145.48 7007.10 4428.30-10409.75 4.00 -90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CD3-K 25May10 Toe -60 / -90 / 270 -120 / CD3-127PB1 0 / 360 -180 / 180 Travelling Cylinder Azimuth (TFO+AZD [°] vs Centre to Centre 90 NO GLOBAL FILTER: Using user defined selection & filtering criteria CD3-127wp08 3290.00 To 13001.00 Ellipsoid color omn raumn n a,.rm� 0 3200 4200 4450 6450 7200 12200 14700 22700 24200 slemai'm°:�ccin 11=r'ima�a°m°O°+xrzsc aaaiRaaara„1�x 3200 3450 4450 4700 7200-�- ffi00 14700 17200 24200 25200 leono ��. ss wi fin:,: aw-.+r zs�c s a c 3450 3700 4700 - 5200 8200 9200 17200 19200 25200 26200 caxn cePaa 3700 3950 5200 5700 9200 10700 19200 - 21200 26200 26950 ro 18,07 ®.•1r�. M a 8 3960 4200 5700 6450 10700 12200 21200 - - 22700 26950 27450 C / D3-127PB 0/360 -180 / 180 Failed AH-Coll ision LEGEND C01112, CD3.112. CD3.112 V3 -Q- CD3414, CD3.114, CD3114 V14 $- CD3415, CD3115, CM115 VO �- CD3117, CD3117, CD3-117 VO CD3118, C03118, CD3118 VO CD3121, CD3121, CD3121 VO -�- C03122, CD3122, CD3122 VO CD3123, CD3123, 033123 VO CD3124, CD3124, CD3124 VO �- CD3.125, CD3125, CD3.125 VO CD3.125, CD3125PB1, CD3125P81 VO --�- CD3.125, CD3125PB1 (auRece), CD3-125PB1 (.rf-) 0 90 CD3127, CD3127PB1, CD3127PB1 VO -e- CD3128, C03128, CD3-128 VO CD3128, CD3129 (Inlerm diale), CD3128 6nlermedi VO -� CD3316, CD3316, CD3316 VO -�- CD3316, CD3316A, CD3316A W CD3316, C MIMP81, CD3316AP111 W Plan: CD3120. Hen: C133120, CD3120gM W Plan: CD3126. Plan: C103126, CD3.126ag04 W Plan: CD3.129, Plan: W3129, CD3129W01 W -e- Hen: CD3130, Plan: CD3.130, C03130mM VO -� Hp: CD3119. Hen: CD3119, CD3119"13 W D3 12 -� H9 CD3119. Plan: CD3119H11, CD3.119PB1 W - f8g: CD3119, Hen: CD3-119P81, CD3119P81"12 W -� NO&Alik 1, N Mlik 1, N.Wik 1 W -� CD3127.08 (Intennedia ) Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ft/in] -90 / SECTION DETAILS Sec MD Inc Azi TVD +NAS +EAW Meg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 45.59-1614.19 2.00-150.00-888.52 3 3360.00 67.50 262.49 2498.21 49.01-1641.73 3.00-120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00 4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -M.70 4112.95 8 13934.86 66.60 192.63 6626.00-2618.91.10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 51.45-3099.37 CD3-K 11Jan12 Heel 11 1 5098 .05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 -35.00-2913A2 13 15873.71 89.30 145.48 7007.10 4428,30-10409.75 4.00 -90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CD3-K 25May10 Toe CD3-127PB1 0 / 360 -180 / 180 Travelling Cylinder Azimuth (TFO+AZi) [°] vs Centre to Centre 90 CD3-127wp08 13000.00 To 14001.00 NO GLOBAL FILTER: Using user defined selection & filtering criteria 0 3200 3450 3700 3950 3200 3450 3700 3950 4200 4200 4450 4700 5200 5700 4450 4700 '- 5200 5700 6450 6450 7200 8200 9200 10700 Ellipsoid Color 7200 12200 -_- - __._. 8200 14700 9200 17200 10700 19M 12200 21200 14700 22700 17200 24200 19200 25200 - 21200 26200 227DO 26950 24200 25200 28200 26950 27450 omn..w -a. m1.. ��'� ."'� zmei �aawao.n+a.�zs�c i�i 1�ra os�l.s�cmlzr7'"p01.m i%°aw+x"`crs -90/ 51 0 / 360 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [7 vs Centre to Centre Separation [100 Win] LEGEND -+- CD&112, CD3-112, CD3.112 V3 CD3-n4, CD3.114, C133-114 V14 -E3- CD3.115, CD3.115, CD3-115 V0 SECTION DETAILS 1 13:43, March 13 21 Sec MD Inc Azi TVD +N/S +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 .41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 -45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00 -4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 51.45-3099.37 CD3-K 11Jan12 Heel 11 15098.05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 35.00-2913.42 13 15873.71 89.30 145.48 7007.10-4428.30-10409.75 4.00 .90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CD3-K 25May10 Toe $ CD3.117, C133-117, CD3-117 VO -60 I -� CD3.118, C03118, CD3-118 VO -� CD3.121, C133-121, CD3-121 VO -E3- CD3-122, CD3-122, CD3.122 VO �- CD3123, CD3-123, CM123 VO -�- CO3-124, C133-124, CM-124 VO �- CD3-125, CM125, CD3-125 VO - CD3.125, CD3.125PB1, CD3125PB1 VO -�- CD3.125, CD3125PB1 (sonata). CD3.125PB1 (sonata) 0 - - CD3.127, CD3127PB1, CD3-127PB1 VO $ CD3-128, CD3-128, CD3-128 VO -90 / 270 CO3.128, CO3-128 (lnlanne6ale), CD3128 (1,1 d,ale VO -�- CD3316, CD3316, CD3316 VO -A- CD3316, CD3316A, CD3316A VO - CD3316, CD3316APB1, CD3316APB1 VO $- M. CM120, Plan: CD3.120, CD3120"M VO $- Plan: CD3126, Ran: CD3.126, CD3-120M304 VO -� Ran: C08.129, Ran: CD3129, CD3.129p01 VO -� Ran: CD3.130, Ran: CD3130, CD3-130p03 VO -� Rig: CO3-119. Plan: CD3-119, CDX119vp13 VO -120 / Rig: CO3-119, Ran: CD3.119PB1, CD3119PB1 VO -)(- Rig: CD3-119, Ran: C03119PB1, CD3-119PB1p12 VO $- Nechelik 1, N fik 1, Neohelik 1 VO CD3127wp08 0 / 360 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre 90 CD3-127wp08 14000.00 To 21001.00 NO GLOBAL FILTER: Using user defined selection & filtering criteria 0 3200 3450 3700 3950 3200 3450 3700 3950 4200 4200 4450 4700 - 5200 5700 4450 4700 5200 5700 6450 Ellipsoid color 6450 7200 8200 9200 10700 7200 12200 8200 14700 9200 17200 10700 19200 12200 21200 14700 22700 172DO 24200 19200 25200 21200 26200 22700 26M 24200 25200 26200 26950 27450 n ei iim�s>+ m�zrcm enrm. � a n m�zr..os law:au.�wm.�c"�rizsxc -90/ 1 0 / 360 -180 / 180 90 Travelling Cylinder Azimuth (TFO+AZI) [I vs Centre to Centre Separation [100 LEGEND -�- CD3112, CIX3.112, C131112 V3 -� CD3-114, CD3114, CD3-114 V14 CD3-115, CIX3-115, CD3.115 VO -8- CD3.117, CD3.117, CD3.117 VO -&- CD3-118. CD3.118, C133-118 VO -� CD3-121, C133-121, C133-121 VO -E3- CD3-122, CM122, CD3.122 VO -�- W3123, CD3-123, CM123 VO -�- C03124, CD3-124, CD3-124 VO -� C131125, CD3-125, CD3.125 VO - C133-125, CD3.125Pe1, CD3.125P61 VO C133.125, CD3-125P81 (1Wsoa), CD3125PB1 (surface) 0 - - Gas. 27, CO3-127PB1, CD3127PB1 VO -�- CD3-128. =0 28, CD3-128 VO CD3.128, CD&128 (Intermediate), CD3-128 Qnte ,ate VO -� C113316, CD3-316, CD3-316 VO -� CD3316, CD3316A, CD3316A VO C03316, CD3316APB1, CD3316APB1 VO Plan: C03120, Plan: CD3120, CM120a308 VO -E3- Plan: CD3-125, Plan: C131126, CM126.VD4 VO �- Ran: C133.129, Plan: CD3129, CD3-129ap01 VO -�- Ran: CD3130, Ran: CD3.130, CD3.130ag03 VO Rig: CD3.119, Ran: C133119, CD3119 g13 VO Rig: CD3.119, Ran: CD3.119PB1, CD3119P81 VO Rg: CD3-119, Ran: CO3-119M. CD3-119P81vp12 V0 $- Nechelik 1, Nechelik 1, Nechelik 1 VO CD3-127mM WIM SECTION DETAILS I 13:43. March 13 2( See MD Inc Azi TVD +N/-S +EAW DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 45.59-1614.19 2,00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70 4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 51.45-3099.37 CD3-K 11Jan12 Heel 11 1 5098 .05 83.11 173.29 6987.30-3705.04-10664.45 0.00 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 -35.00-2913.42 13 15873.71 89.30 145.48 7007-10 4428.30-10409.75 4.00 -90.12-2343.34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CD3-K 25May10 Toe 01360 -180 / 180 Azimuth (TFO+AZr) [e] vs Centre to Centre 90 ft/in] CO3-127wp08 21000.00 To 21749.59 NO GLOBAL FILTER: Using user defined selection & filtering criteria 0 3200 3450 3700 3950 3200 3450 3700 3950 4200 4200 4450 4700 _- 5200 5700 4450 4700 5200 5700 6450 6450 7200 8200 9200 10700 EllipsM Color 7200 12200 8200 14700 9200 17200 - --- 107W IWW -- - _-. 12200 21200 14700 22700 17200 24200 192M 25200 21200 26200 '- 22700 26950 24200 25200 26200 26950 27450 o F �co>,�,Pa, m,ocli®�.aoea .se co>,z,va, id'oo, lco>waF®m u<uzsc <a, Inxml imsa.xaamxcersc ,w,e os, x.e ss coD1sinZ1xp0°wsi�.im�r o°:s°"rz,wvzsc csnn oEnas ssin ,ow 1-.- I1'1411 11 0 / 360 -180 / 180 ailed AptrCalUSiep LEGEND - - CD3-112. CD3.112, CD3-112 V3 CD3114, C133114, CM114 V14 -� CD3-115, CD3115, CD3.115 VO -�- CD3117, C133-117, C03117 VO -� CD3-118, CD3118, CM118 VO -� CD3121, C133121, CD3.121 VO -3- CO3-12Z CD3122, CM122 VO CD3-123, CD3123, CD3-123 VO �- CD3124, CD3124, CD3124 VO -� CD3125, CD3125, CD3-125 VO CD3125, CMA251`111, CD3125PB1 VO -� CD3125, CM125PBI (8uxlece), CD3.125P81 (wrf n) 0 90 CD3127, CD3127R91, CD3127PB1 VO CD3128, CD3128, C03128 VO M3.128, C33-128 (Inert al&X CD3.128 (!,W- to VO -e- CD3316, CD3316, CD3318 W �- CD3316, CD3316A, CD3318A VO - CD3318, CD3a16APB1, CD3316APB1 VO - G - Plan: CD3.120, Plan: C03120, CD3120MM VO -B- Plan: CD3-126, Plan: C03126, CD3120v4)04 VO -� Plan: CD3129, Ran: CD3.129, CD3129ap01 VO �- Ran: CD3130, Ran CD3130, CD3130ap03 VO Po9: CM-119, Ran: CD3119, CD3.119ap13 VO -� i8g: CD3119, Plan: CD3.119PB1, CD311W81 VO - - Po9 CD3119, Plan: CD3119PB1, CD3.119PB1.P12 VO Nechelik 1, Nechelik 1, Ne helik 1 VO -f3- CD3127xy08 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 fUn] -90 / SECTION DETAILS 1 13:44- March 13 21 Sec MD Inc A21 TVD +NAS +E/-W DLeg TFace VSec Target 1 3290.00 68.64 263.77 2472.05 -41.41-1577.26 0.00 0.00-870.75 2 3330.00 67.95 263.34 2486.84 .45.59-1614.19 2.00 -150.00-888.52 3 3360.00 67.50 262.49 2498.21 -49.01-1641.73 3.00 -120.00-901.51 4 3760.00 68.02 249.54 2650.17-138.32-1999.99 3.00 -90.00-1033.85 5 4292.51 68.42 261.00 2848.35-263.73-2477.22 2.00 90.00-1204.84 6 11840.41 68.42 261.00 5625.00-1361.68-9409.43 0.00 0.00 -4281.60 7 13589.35 59.69 192.63 6470.00-2318.31-10481.59 3.50 -113.70-4112.95 8 13934.86 66.60 192.63 6626.00-2618.91-10548.94 2.00 0.00-3905.34 9 14370.42 66.60 192.63 6799.00-3008.97-10636.34 0.00 0.00-3635.95 10 15078.05 83.11 173.29 6984.90-3685.32-10666.77 3.51 -51.45-3099.37 CD3-K 11Jan12 Heel 11 15098.05 83.11 173.29 6987.30-3706.04-10664.45 0.00 0.00-3081.88 12 15286.24 89.29 168.98 6999.77-3890.43-10635.51 4.00 -35.00-2913.42 13 15873.71 89.30 145.48 7007.10 -4428.30-10409.75 4.00 -90.12-2343,34 14 21749.59 89.30 145.48 7078.90-9269.23-7080.16 0.00 0.00 3531.89 CD3-K 25May10 TDe 0 / 360 90 -180 / 180 Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] 1 10I 2/2/11 I CZ I DB I C.A. I UPDATED PER K110003ACS 111 II/#/#I CZ I GD I C.A. I UPDATED PER K110003ACS � ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0 S WELL 'Y' 'X' LAT.(N) LONG.(W) FSL EEXIST L GND PAD CD3-X98 6,003,630.37 1.528.434.35 150' 54' 44.278" 12.5 CD3-X99 6,003,625.99 1 528 415.38 150' 54 44.833 7.3 12.8 CD3-301 6,003,621.33 1.528.395.58 150' 54 45.411 7.3 13.5 CD3-302 6,003,616.72 1,528,376.38 150' 54' 45.972" 1377' 700' 7.3 13.2 CD3-303 6,003,612.52 1,528,356.72 150' 54 46.547 1373' 719' 7.3 13.3 CD3-304 6 003 607.8 1,528,337.04 150' 54' 47.122" 1368' 739' 7.3 13.4 CD3-305 6 003 603.48 1,528,317.56 7 150' 54 47.691 1363' 1 758' 7.3 13.6 CD3-106 6 003 599.43 1,528,298.37 150' 54' 48.252" 1359' 777' 7.3 13.4 CD3-107 6,003,594.38 1,528,278.93 70' 25' 08. 90" 15054 48.820 1354 797' 7.3 13.2 CD3-108 6 003 589.85 1,528,259.61 150' 54' 49.385" 1349' 816' 7.3 13.1 CD3-109 6,003,585.27 1.528.239.85 70' 25' 08.794" 150' 54 49.962 1344 836 7.3 13.1 CD3-110 6,003,580.97 1,528,220.32 70' 25' 08.749" 150' 54 50.533 1339 855' 7.3 13.0 CD3-111 6,003,576.13 1,528,201.08 70' 5' 0 150' 54 51.095 1334' 874' 7.3 12.9 CD3-112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150' 54 51.676 1330' 894' 7.3 13.1 CD3-113 1 6 003 567.62 1,528,161.38 70' 25' 08.609" 150' 54 52.255 1325' 914' 7.3 13.1 CD3-114 6 003 563.04 1,528,142.21 70' 25' 08.561" 150' 54 52.815 1320' 933' 7.3 13.3 CD3-115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150' 54 53.388 1 ' 953' 7.3 CD3-316A 6,003,554.04 1.528.103.39 70' 25' 08.467" 150' 54 53.950 1311' 972' 7.3 139 CD3-117 6,003,549.51 1,528,083.99 7 4 0" 150' 54 54.516 1 6' 7.3 CD3-118 6,003,544.88 1,528,064.44 70' 25' 08.372" 150' 54 55.086 1301' 1011' 7.3 12.8 CD3-X19 6 003 540.17 1 528 044.86 7 150' 54' 55.660" 7.3 12.8 CD3-X20 6 003 535.95 1 528 025.39 150' 54 56.229 7.3 12.6 CD3-X21 6.003.531.41 1 528 006.04 150' 54 56.794' 7.3 12.5 CD3-122 6,003,527.00 1,527,986.67 150' 54' 57.360" 7.3 12.6 CD3-X23 6,003,522.43 1,527,967.12 7 150' 54 57.932" 7.3 12.6 CD3-124 6,003,518,17 1,527,947.59 150' 54' 58.502" 7.3 12.5 CD3-X25 6.003513-69 1. 527 927.89 150' 54 59.078 7.3 12.6 CD3-X27 6,003,504.45 1,527,889.34 150' 55 00.204 7.3 12.6 CD3-X281 6 003 500.08 1,527,870.01 150' 55 00.769 7.3 12.6 CD3-X29 CD3-X30 CD3-X31 CD3-X32 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) �� ALPINE MODULE:CD30 UNIT: CD ConocoPhillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A-2 3-17-05 1 CE-CD30-111 1 2 OF 3 11 Page 1 of 2 Schwartz, Guy L (DOA) From: Samuell, JG (John G) [John.G.SamuelI@conocophillips.com] Sent: Wednesday, March 21, 2012 4:25 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3-127 ( PTD 211-005) Attachments: CD3-127 Cementing Program 032112.doc Cementing details attached. J.G. Samuell Drilling Engineer I Conoco Phillips Alaska Direct (907) 265-6309 i Mobile: (832) 465-8143 From: Schwartz, Guy L (DOA)[mailto:guy.schwartz@alaska.gov] Sent: Wednesday, March 21, 2012 3:59 PM To: Samuell, JG (John G) Subject: [EXTERNAL]RE: CD3-127 ( PTD 211-005) 1 need the new cementing details for the intermediate. (original PTD didn't have under -reamer) Missed it last round. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Samuel!, ", (lnhn. l,1 rm;iltn=lnhn r gam+lall( rnnnrn.nhJ'll n=_ i'r mml Sent: Wednesday! March 21, 2012 3.2E f #A! Subzect: RE: CD3-127 l PTD 211 J051 Guy, Answers below in blue. If you need me to re -submit, please advise and I will do so. Thank you. [)ruing 'Engineer ,i Conoco Phillips Alaska I Direct. (907) 265-6309 I Mobile: (832) 465-8148 From: Schwartz, vuV L ("-"'-'A)IA� mu'iIto: uuV=$CiiVJartziaiaSlCa=eaJv i �S3T;t• T .a^fly;!1 t.f i �n �nj i inn < __.._a. :a To: Samuel!, JG (John v Subie: fEXTER"J/".LIC DJ-127 (PTD 211<005Z Page 2 of 2 JG 1) In CD3-127 can you clarify the under -reamer footage as you propose in steps 18-22. Doesn't make sense to me. The plan is to ream only the bottom 2600' of the hole from 13,500' MD to 15,100' MD. 2) What is your KWF for the well in step 2. (weight and composition) 9.6 ppg KCL brine 3) In step 7 the shell test should include testing a 4.5 inch joint. Full BOP test is appropriate after you get tubing out of the well. Correct. We will need to test a 3.5" and 4.5" joint followed by a full BOP test once the tubing is out of the well. 4) Is Step 17 LOT min value same as in PTD? Yes, the minimum value will be remain the same at 11.0 ppg. 5) Are you still planning on under -reaming well based on previous well experience? We have had successful liner runs as the result of under -reaming hole sections, so we feel confident that this is a good practice to continue. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 3/21/2012 Cementing Program: 7-5/8" Intermediate Casing run to 15.078 MD / 6985' ND First Stage: Cement from 15078' MD to 14070' MD. (500' of Class G above Kuparuk + additives @ 15.8 PPG and minimum 300' MD above the packer). Assume 40% excess annular volume. /v 3, 00 Lead Slurry: (15,078'-14,070') X 0.3132 ft3/ft X 1.4 (40% excess) = 442 ft3 annular vol. 120' x 0.2577 fft = 30.9 ft3 shoe joint volume Total volume = 30.9 ft3 + 442 ft3 = 473 ft3 => 408 Sx @ 1.16 ft3/sk System: 408 Sx Class G + 0.2% D046 antifoamer, + 1%S2, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.17 ft3/sk Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume i CEO 7f1 A ram'% v r, 0 1 A.: €? 4 -I A iZ F+3 - �cau: �..i i7� - .:_. h v.-+w is ;+. t ,A kw�C cx�.c�$j = viv uia^r vOS. i o:al plume =Jib rt-=> 212.5 aK Qa2. 1.16 WISK System: ')71 `v r'i T° + i'1 ")C` rIIIA� ��S t1..'2.�u ���� dispersant rl tisx..t osw v:ado es v.c iu uts-r antifoar`ner, - U5 dispersal �t and .., O"LAj- a__ I2r�tGr i:i. I f'"l3 yiC.'' ii irl( 1.1 % tt-1SK Page 1 of 2 60 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent Wednesday, March 07, 2012 10:01 AM To: 'Anderson, Nina M' Cc: Davies, Stephen F (DOA) Subject: RE: CD3-127 PTD/Sundry (211-005) Nina, Based on what you have told me a 403 sundry will be sufficient to reenter the well and continue drilling. Submit the new directional and any other changes including the completion plan for producing the Kuparuk zone. The current PTD is still applicable though it may get complicated once the Kuparuk is completed and you want to return to the well next year (2013) and drill the Nechelik lateral. I thought we did something like this for another well at CD3?? CD3—/Zg Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Seat: Tuesday, March 06, 2012 5:12 PM To: Schwartz, Guy L (DOA) Swlyect. CD3-127 PTO/Sundry Guy - CA3-127 (PTO 211-WSJ was temporarily suspended last winter and the operational stwt down expires on 3/18. The well currently has surface casing as we were unsuccessful in running intermediate casing last winter. The plan forward would be to sidetrack and xe-drill the ""mediate IiWe secboa and "4he tatien in the Ned mW reservoir. Due to ice road timing, there will be not be enough time this year to complete both the intermediate and the lateral sections. The plan for 2042 wawkt be WA" and case intermediate so that tpe iCi+pa lc can be perforated and produced. Then in the following 2013 ice road drilling season, Doyon 19 would return and th* vtrt the iatmat. Due to the expiration on the operational shut down, my plan is to submit a 10-403 sundry to re-enter the well and m*nue epera bons under the eriginal PTO. The most separration bekveeri the PTO plan (in pink) and the sidetrack plan (in blue) center to center distance is 486'. The sidetrack plan swings inboard of #lie erigic+al pka► but the final x y laaali" is the reservoir is 21Z center t®cefnter. Please advise if a sundry to re-enter would be sufficient for the re -drill of the intermediate hole section. Thanks, 3/7/2012 ConocoPhill'i;��u�s(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-127PB1 501032063470 �6 •tw,Qoa ur 6 1 Sperry Drilling Definitive Survey Report 09 March, 2011 HALLIBURTON SperrV Drilling Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: CD3-127PB1 Design: CD3-127P61 ConocoPhillips (Alaska) Inc. Definitive Surrey Report Local Co-ordinate Reference: Well CD3-127 TVD Reference: Rig: CD3-127 @ 48.60ft (D19) MD Reference: Rig: CD3-127 @ 48.60ft (D19) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production 'roject Western North Slope clap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point flap Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-127 Well Position +N/-S 0.00 ft Northing: 6,003,757.25ft Latitude: 70° 25' 9.114 N +E/-W 0.00 ft Easting: 387,857.43It Longitude: 150° 54' 48.827 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Declination Dip Angle Field Strength (°) (°) (nT) 20.69 80.83 57,604 Version: 1.0 Phase: ACTUAL Tie On Depth: 36.00 Vertical Section: Depth From (TVD) +N/-S +E/-W - Direction (ft) (ft) (ft) {°) 36.00 0.00 0.00 153.00 DateM n,.,;^ - .sue, (Survey Program From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 79.00 476.00 CD3-127PB1 Gyro (R100) (CD3-127PB1 CB -GYRO -SS Camera based gyro single shot 2/11/2011 12:C 515.73 3,202.26 CD3-127PI31 (R100) (CD3-127PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/11/2011 12:C 3,300.63 15,231.51 CD3-127PB1 (R200) (CD3-127PI31) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2011 12:C MD Inc" Azi TVD (ft) (°} (°) (ft) 36.00 0.00 0.00 36.00 79.00 0.35 234.33 79.00 170.00 0.52 207.98 170.00 262.00 0.85 228.13 261.99 354.00 1.17 247.26 353.98 386.00 1.33 260.21 385.97 416.00 1.67 279.06 415.96 445.00 2.15 299.36 444.94 476.00 3.01 314.14 475.91 515.73 4.03 321.86 515.57 577.23 6.32 325.73 576.81 671.19 8.05 314.21 670.04 Map Map TVDSS +N/-S +E/-W Northing Easting DLS (ft) (ft) (ft) (ft) (ft) (°/100') -12.60 0.00 0.00 6,003,757.25 387,857.43 0.00 30.40 -0.08 -0.11 6,003,757.18 387,857.32 0.81 121.40 -0.60 -0.53 6,003,756.66 387,856.89 0.28 213.39 -1.43 -1.23 6,003,755.85 387,856.18 0.44 305.38 -2.25 -2.60 6,003,755.05 387,854.79 0.50 337.37 -2.44 -3.27 6,003,754.87 387,854.12 1.01 367.36 -2.43 -4.05 6,003,754.89 387,853.35 1.98 396.34 -2.09 -4.94 6,003,755.24 387,852.46 2.84 427.31 -1.24 -6.03 6,003,756.10 387,851.38 3.49 466.97 0.58 -7.64 6,003,757.95 387,849.80 2.83 528.21 5.08 -10.88 6,003,762.50 387,846.63 3.76 621.44 13.94 -18.51 6,003,771.47 387,839.13 2.39 action (ft) Survey Tool Name 0.00 UNDEFINED 0.02 CB -GYRO -SS (1) 0.30 CB -GYRO -SS (1) 0.71 CB -GYRO -SS (1) 0.82 CB-GYRO-SS(1) 0.68 CB -GYRO -SS (1) 0.32 CB -GYRO -SS (1) -0.38 CB -GYRO -SS (1) -1.63 CB -GYRO -SS (1) -3.99 MWD+IFR-AK-CAZ-SC (2) -9.47 MWD+IFR-AK-CAZ-SC (2) -20.83 MWD+IFR-AK-CAZ-SC (2) 31912011 10:16:03AM Page 2 COMPASS 2003.16 Build 69 Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: CD3-127PB1 Design: CD3-127PB1 Survey ConocoPhillips (Alaska) Inc. Definitive Survey Report Local Co-ordinate Reference: Well CD3-127 TVD Reference: Rig: CD3-127 @ 48.60ft (D19) MD Reference: Rig: CD3-127 @ 48.60ft (D19) 14orth Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1) (1) (ft) (ft) (ft) (ft) (ft) (ft) (°/100-) (ft) Survey Tool Name 763.54 T91 311.32 761.49 712.89 22.65 -27.92 6,003,780.32 387,829.86 0.46 -32.85 MWD+IFR-AK-CAZ-SC (2) 855.69 8.17 305.21 852.74 804.14 30.61 -38.03 6,003,788.43 387,819.87 0.97 -44.54 MWD+IFR-AK-CAZ-SC (2) 951.70 10.89 302.07 947.41 898.81 39.36 51.29 6,003,797.38 387,806.74 2.88 58.36 MWD+IFR-AK-CAZ-SC (2) 1,045.52 12.42 298.39 1,039.30 990.70 48.86 -67.68 6,003,807.13 387,790.50 1.81 -74.26 MWD+IFR-AK-CAZ-SC (2) 1,140.07 12.58 296.55 1,131.61 1,083.01 58.30 -85.83 6,003,816.83 387,772.49 0.45 -90.91 MWD+IFR-AK-CAZ-SC (2) 1,234.56 12.83 296.14 1,223.78 1,175.18 67.52 -104.46 6,003,826.33 387,754.01 0.28 -107.59 MWD+IFR-AK-CAZ-SC (2) 1,328.62 15.44 286.25 1,315.00 1,266.40 75.63 -125.86 6,003,834.76 387,732.73 3.77 -124.53 MWD+IFR-AK-CAZ-SC (2) 1.423.16 19.30 279.59 1,405.22 1,356.62 81.76 -153.36 6,003,841.30 387,705.33 4.59 -142.47 MWD+IFR-AK-CAZ-SC (2) 1,517.74 22.46 275.42 1,493.58 1,444.98 86.07 -186.77 6,003,846.11 387,671.99 3.69 -161.48 MWD+IFR-AK-CAZ-SC (2) 1,612.25 26.70 270.91 1,579.52 1,530.92 88.11 -225.99 6,003,848.74 387,632.81 4.90 -181.11 MWD+IFR-AK-CAZ-SC (2) 1,707.56 30.00 268.38 1,663.39 1,614.79 87.78 -271.23 6,003,849.09 387,587.57 3.68 -201.35 MWD+IFR-AK-CAZ-SC (2) 1,802.20 35.83 269.68 1,742.80 1,694.20 86.95 -322.63 6,003,849.04 387,536.17 6.20 -223.95 MWD+IFR-AK-CAZ-SC (2) 1,849.04 37.89 269.97 1,780.28 1,731.68 86.87 350.72 6,003,849.38 387,508.08 4.41 -236.63 MWD+IFR-AK-CAZ-SC (2) 1,897.12 38.49 270.30 1,818.07 1,769.47 86.94 -380.45 6,003,849.89 387,478.36 1.32 -250.19 MWD+IFR-AK-CAZ-SC (2) 1,991.30 42.51 267.56 1,889.67 1,841.07 85.74 -441.58 6,003,849.61 387,417.23 4.67 -276.87 MWD+IFR-AK-CAZ-SC (2) 2,086.14 47.07 264.32 1,956.97 1,908.37 80.94 -508.19 6,003,845.81 387,350.56 5.38 -302.83 MWD+IFR-AK-CAZ-SC (2) 2,133.12 47.99 263.29 1,988.69 1,940.09 77.19 -542.64 6,003,842.58 387,316.06 2.54 -315.13 MWD+IFR-AK-CAZ-SC (2) 2.175.63 49.30 262.69 2,016.78 1,968.18 73.30 -574.31 6,003,839.16 387,284.34 3.26 -326.04 MWD+IFR-AK-CAZ-SC (2) 2,275.09 53.98 263.40 2,078.49 2,029.89 63.87 -651.70 6,003,830.90 387,206.82 4.74 -352.78 MWD+IFR-AK-CAZ-SC (2) 2,365.18 57.90 262.91 2,128.93 2,080.33 54.97 -725.79 6,003,823.12 387,132.61 4.37 -378.48 MWD+IFR-AK-CAZ-SC (2) 2,463.77 62.96 263.91 2,177.57 2,128.97 45.15 -810.94 6,003,814.58 387,047.32 5.21 -408.39 MWD+IFR-AK-CAZ-SC (2) 2,514.19 64.92 263.93 2,199.72 2,151.12 40.36 -855.98 6,003,810.46 387,00222 3.89 -424.56 MWD+IFR-AK-CAZ-SC (2) 2.558.25 66.38 264.57 2,217.89 2,169.29 36.34 -895.92 6,003,807.04 386,962.23 3.57 -439.11 MWD+IFR-AK-CAZ-SC (2) 2,653.06 68.37 264.51 2,254.36 2,205.76 28.01 -983.03 6,003,800.02 386,875.01 2.10 -471.24 MWD+IFR-AK-CAZ-SC (2) 2,748.04 70.13 264.33 2,288.01 2,239.41 19.37 -1,071.42 6,003,792.72 386,786.51 1.86 -503.68 MWD+IFR-AK-CAZ-SC (2) 2,842.30 71.06 263.74 2,319.32 2,270.72 10.13 -1,159.85 6,003,784.81 386,697.96 1.15 -535.59 MWD+IFR-AK-CAZ-SC (2) 2,937.07 71.07 263.37 2,350.08 2,301.48 0.07 -1,248.92 6,003,776.08 386,608.76 0.37 -567.06 MWD+IFR-AK-CAZ-SC (2) 3.031,39 70.29 262.76 2,381.28 2,332.68 -10.68 -1,337.28 6,003,766.67 386,520.26 1.03 -597.60 MWD+IFR-AK-CAZ-SC (2) 3,125.52 69.55 262.57 2,413.60 2,365.00 -21.96 -1,424.96 6,003,756.70 386,432.42 0.81 -627.35 MWD+IFR-AK-CAZ-SC (2) 3,202.26 69.45 262.24 2,440.48 2,391.88 -31.46 -1,496.21 6,003,748.27 386,361.04 0.42 -651.23 MWD+IFR-AK-CAZ-SC (2) 3,300.63 68.54 263.96 2,475.74 2,427.14 -42.50 -1,587.37 6,003,738.61 386,269.73 1.88 -682.79 MWD+IFR-AK-CAZ-SC (3) 3,394.88 68.36 264.78 2,510.36 2,461.76 -51.10 -1,674.61 6,003,731.32 386,182.38 0.83 -714.73 MWD+IFR-AK-CAZ-SC (3) 3,489.03 68.24 264.73 2,545.17 2,496.57 -59.10 -1,761.72 6,003,724.63 386,095.17 0.14 -747.15 MWD+IFR-AK-CAZ-SC (3) 3,583.78 68.35 263.86 2,580.21 2,531.61 -67.85 -1,849.32 6,003,717.20 386,007.46 0.86 -779.12 MWD+IFR-AK-CAZ-SC (3) 3,678.88 68.55 263.19 2,615.14 2,566.54 -77.82 -1,937.21 6,003,708.55 385,919.44 0.69 -810.13 MWD+IFR-AK-CAZ-SC (3) 3,772.20 68.49 262.74 2,649.31 2,600.71 -88.46 -2,023.39 6,003,699.21 385,833.11 0.45 -839.78 MWD+IFR-AK-CAZ-SC (3) 3,866.43 68.54 262.03 2,683.83 2,635.23 -100.08 -2,110.30 6,003,688.90 385,746.05 0.70 -868.89 MWD+IFR-AK-CAZ-SC (3) 3,960.97 68.62 262.08 2,718.35 2,669.75 -112.24 -2,197.46 6,003,678.04 385,658.71 0.10 -897.62 MWD+IFR-AK-CAZ-SC (3) 4,055.01 68.69 261.11 2,752.58 2,703.98 -125.05 -2,284.11 6,003,666.54 385,571.89 0.96 -925.55 MWD+IFR-AK-CAZ-SC (3) 4,150.01 68.75 260.84 2,787.06 2,738.46 -138.93 -2,371.54 6,003,653.97 385,484.27 0.27 -952.87 MWD+IFR-AK-CAZ-SC (3) 31912011 10:16:03AM Page 3 COMPASS 2003.16 Build 69 Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-127 Wellbore: CD3-127PB1 Design: CD3-127PB1 ConocoPhillips (Alaska) Inc. Definitive Survey Report Local Co-ordinate Reference: Well CD3-127 TVD Reference: Rig: CD3-127 @ 48.60ft (1319) PAD Reference: Rig: CD3-127 @ 48.60ft (D19) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) V) V) (ft) (ft) (ft) (ft) (ft) (ft) (-/100-) (ft) Survey Tool Name 4,244.51 68.55 260.73 2,821.4/ 2,772.87 -153.03 -2,458A2 6,003,641.19 385,397.20 0.24 -979.75 MWD+IFR-AK-CAZ-SC(3) 4,338.71 68.81 261.48 2.855.71 2,807.11 -166.59 -2,545.11 6,003,628.92 385,310.32 0.79 -1,007.02 MWD+IFR-AK-CAZ-SC (3) 4,433.20 69.14 261.63 2,889.62 2,841.02 -179.55 -2,632.36 6,003,617.28 385,222.90 0.38 -1,035.09 MWD+IFR-AK-CAZ-SC (3) 4,527.93 69.28 261.60 2,923.24 2,874.64 -192.46 -2,719.97 6,003,605.69 385,135.11 0.15 -1,063.36 MWD+IFR-AK-CAZ-SC (3) 4,622.55 68.95 260.31 2,956.97 2,908.37 -206.36 -2,807.27 6,003,593.11 385,047.61 1.32 -1,090.61 MWD+IFR-AK-CAZ-SC (3) 4,716.56 68.89 259.78 2,990.78 2,942.18 -221.52 -2,893.67 6,003,579.24 384,961.00 0.53 -1,116.32 MWD+IFR-AK-CAZ-SC (3) 4,811.18 68.55 259.59 3,025.12 2,976.52 -237.31 -2,980.41 6,003,564.76 384,874.04 0.41 -1,141.64 MWD+IFR-AK-CAZ-SC (3) 4,905.84 68.22 259.73 3,059.99 3,011.39 -253.11 -3,066.99 6,003,550.27 384,787.25 0.37 -1,166.87 MWD+IFR-AK-CAZ-SC (3) 5,000.55 68.56 260.97 3,094.88 3,046.28 -267.86 3,153.79 6,003,536.82 384,700.24 1.27 -1,193.12 MWD+IFR-AK-CAZ-SC (3) 5,095.40 68.42 262.05 3,129.65 3,081.05 -280.89 -3,241.07 6,003,525.10 384,612.78 1.07 -1,221.t4 MWD+IFR-AK-CAZ-SC (3) 5,189.61 69.32 261.96 3,163.62 3,115.02 -293.11 -3,328.09 6,003,514.19 384,525.60 0.96 -1,249.75 MWD+IFR-AK-CAZ-SC(3) 5,284.01 69.03 262.46 3,197.18 3,148.58 -305.07 -3,415.51 6,003,503.55 384,438.02 0.58 -1,278.79 MWD+IFR-AK-CAZ-SC (3) 5,379.69 68.76 263.09 3,231.63 3,183.03 -316.30 -3,504.06 6,003,493.65 384,349.31 0.68 -1,366.98 MWD+IFR-AK-CAZ-SC (3) 5,473.44 68.64 263.01 3,265.68 3,217.08 -326.87 -3,590.76 6,003,484.39 384,262.47 0.15 -1,338.93 MWD+IFR-AK-CAZ-SC (3) 5,568.25 68.89 262.67 3,300.02 3,251.42 -337.88 -3,678.45 6,003,474.69 384,174.64 0.43 -1,368.92 MWD+IFR-AK-CAZ-SC (3) 5,662.07 68.81 261.33 3,333.88 3,285.28 -350.06 3,765.09 6,003,463.82 384,087.82 1.33 -1;397.41 MWD+IFR-AK-CAZ-SC (3) 5,756.90 68.81 261.21 3,368.15 3,319.55 -363.48 -3,852.49 6,003,451.71 384,000.25 0.12 -1,426.13 MWD+IFR-AK-CAZ-SC (3) 5,851.58 68.88 260.26 3,402.32 3,353.72 -377.70 -3,939.63 6,003,438.81 383,912.90 0.94 -1,462.03 MWD+IFR-AK-CAZ-SC (3) 5,945.78 68.34 260.57 3,436.68 3,388.08 -392.30 -4,026.12 6,003,425.51 383,826.21 0.65 -1,478.28 MWD+IFR-AK-CAZ-SC (3) 6,040.37 68.63 260.09 3,471.37 3,422.77 -407.09 4,112.87 6,003,412.03 383,739.26 0.56 -1,504.40 MWD+IFR-AK-CAZ-SC (3) 6,134.71 68.55 260A0 3,505.81 3,45721 422.19 4,199.39 6,003,398.23 383,652.53 0.09 -1;530.31 MWD+IFR-AK-CAZ-SC (3) 6,229.33 68.67 260.40 3,540.32 3,491.72 437.11 4,286.22 6,003,384.61 383,565.49 0.32 -1,556.43 MWD+IFR-AK-CAZ-SC(3) 6,324.65 68.22 261.37 3,575.34 3,526.74 -451.16 4,373.75 6,003,371.88 383,477.77 1.06 -1,583.66 MWD+IFR-AK-CAZ-SC (3) 6,418.99 68.42 262.20 3,610.19 3,561.59 463.68 4,460.52 6,003,360.66 383,390.83 0.84 -1,611.89 MWD+IFR-AK-CAZ-SC (3) 6,513.78 68.41 262.39 3,645.06 3,596.46 -475.50 -4,547.86 6,003,350.16 383,303.32 0.19 -1,641.01 MWD+IFR-AK-CAZ-SC (3) 6,608.32 68.20 263.00 3,680.01 3,631.41 -486.67 4,634.99 6,003,340.30 383,216.04 0.64 -1,670.62 MWD+IFR-AK-CAZ-SC (3) 6,702.51 68.82 264.10 3,714.52 3,665.92 -496.51 4,722.08 6,003,331.77 383,128.83 1.27 -1,701.38 MWD+IFR-AK-CAZ-SC (3) 6,796.62 68.95 264.75 3,748.42 3,699.82 -505.04 4,809.46 6,003,324.56 383,041.34 0.66 -1,733.45 MWD+IFR-AK-CAZ-SC (3) 6,890.85 68.76 263.57 3,782.41 3,733.81 -513.98 -4,896.88 6,003,316.93 382,953.80 1.19 -1,765.17 MWD+IFR-AK-CAZ-SC (3) 6,985.69 68.75 262.82 3,816.78 3,768.18 -524.46 4,984.65 6,003,307.78 382,865.89 0.74 -1,796.69 MWD+IFR-AK-CAZ-SC (3) 7,079.84 68.42 261.54 3,851.15 3,802.55 -536.38 -5,071.49 6,003,297.16 382,778.89 1.31 -1,824.49 MWD+IFR-AK-CAZ-SC (3) 7,175.60 68.56 261.96 3,886.27 3,837.67 -549.17 -5,159.66 6,003,285.70 382,690.55 0.43 -1,853.12 MWD+IFR-AK-CAZ-SC (3) 7.270.37 68.83 26223 3,920.70 3,872.10 -561.31 -5,247.11 6,003,274.87 382,602.93 0.39 -1,882.01 MWD+IFR-AK-CAZ-SC (3) 7,364.76 68.82 261.99 3,954.79 3,906.19 -573.39 -5,334.29 6,003,264.10 382,515.58 0.24 -1,910.82 MWD+IFR-AK-CAZ-SC (3) 7,458.90 68.35 261.71 3,989.17 3,940.57 -585.82 -5,421.05 6,003,252.99 382,428.66 0.57 -1,930.14 MWD+IFR-AK-CAZ-SC (3) 7,554.26 68.57 261.34 4,024.18 3,975.58 -598.89 -5,508.78 6,003,241.23 382,340.75 0.43 -1,967.32 MWD+IFR-AK-CAZ-SC (3) 7,648.71 68.29 261.30 4,058.90 4,010.30 -612.14 -5,595.61 6,003,229.28 382,253.74 0.30 -1,994.93 MWD+IFR-AK-CAZ-SC (3) 7,743.18 68.76 260.95 4,093.49 4,044.89 -625.71 -5,682.47 6,003,217.03 382,166.69 0.61 -2,022.28 MWD+IFR-AK-CAZ-SC (3) 7,837.98 68.55 260.69 4,127.99 4,079.39 -639.79 -5,769.63 6,003,204.25 382,079.33 0.34 -2,049.30 MWD+IFR-AK-CAZ-SC (3) 7,932.53 68.16 261.42 4,162.87 4,114.27 -653.46 -5,856.45 6,003,191.90 381,992.33 0.83 -2,076.53 MWD+IFR-AK-CAZ-SC (3) 3/9/2011 10:16:03AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD3-127 Project: Western North Slope TVD Reference: Rig: CD3-127 @ 48.60ft (D19) Site: CD3 Fiord Pad MD Reference: Rig: C133-127 @ 48.6Dft (1319) Well: CD3-127 North Reference: True Wellbore: CD3-127PB1 Survey Calculation Method: Minimum Curvature Design: CD3-127PB1 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 8,026.22 68.09 261.30 4,197.78 4,149.18 -666.52 -5,942.40 6,003,180.13 381,906.19 0.14 -2,103.92 MWD+IFR-AK-CAZ-SC (3) 8,121.72 68.43 261.44 4,233.15 4,184.55 -679.83 -6,030.11 6,003,168.14 381,818.31 0.38 -2,131.88 MWD+IFR-AK-CAZ-SC(3) 8,216.19 68.61 261.99 4,267.74 4,219.14 -692.50 -6,117.10 6,003,156.78 381.731.14 0.57 -2,160.08 MWD+IFR-AK-CAZ-SC (3) 8,310.81 68.30 262.45 4,302.49 4,253.89 -704.41 -6,204.30 6,003,146.18 381,643.78 0.56 -2,189,06 MWD+IFR-AK-CAZ-SC (3) 8,405.21 68.63 262.70 4,337.14 4,288.54 -715.76 -6,291.37 6,003,136.14 381,556.56 0.43 -2,218.48 MWD+IFR-AK-CAZ-SC (3) 8,500.36 68.95 262.13 4,371.56 4,322.96 -727.47 -6,379.30 6,003,125.75 381,468.47 0.65 -2,247.96 MWD+IFR-AK-CAZ-SC (3) 8,593.95 68.88 262.21 4,405.23 4,356.63 -739.37 -6,465.81 6,003,115.16 381,381.80 0.11 -2,276.64 MWD+IFR-AK-CAZ-SC (3) 8,689.36 68.34 262.16 4,440.03 4,391.43 -751.44 -6,553.82 6,003,104.41 381,293.62 0.57 -2,366.83 MWD+IFR-AK-CAZ-SC (3) 8,784.24 69.16 262.97 4,474.42 4,425.82 -762.89 -6,641.50 6,003,09428 381,205.78 1.17 -2,335.44 MWD+IFR-AK-CAZ-SC (3) 8.878.77 68.63 262.93 4,508.46 4,459.86 -773.71 -6,729.03 6,003,084.78 381,118.12 0.56 -2,366.53 MWD+IFR-AK-CAZ-SC (3) 8,973.17 68.42 262-54 4,543.02 4,494.42 -784.82 -6,816.17 6,003,074.98 381,030.83 0.44 -2,305.20 MWD+IFR-AK-CAZ-SC (3) 9,068.07 68.77 262.40 4,577.65 4,529.05 -796.40 -6,903.76 6,003,064.72 380,943.08 0.39 -2,424.66 MWD+IFR-AK-CAZ-SC (3) 9,162.36 68.22 263.02 4,612.22 4,563.62 -807.53 -6,990.78 6,003,054.90 380,855.91 0.85 -2,454.23 MWD+IFR-AK-CAZ-SC (3) 9,256.64 69.02 262.41 4,646.59 4,597.99 -818.66 -7,077.86 6,003,045.07 380,768.68 1.04 -2,483.86 MWD+IFR-AK-CAZ-SC (3) 9,351.26 68.82 263.43 4,680.62 4,632.02 -829.55 -7,165.47 6,003,035.51 380,680.92 1.03 -2,513.93 MWD+IFR-AK-CAZ-SC (3) 9,446.06 68.95 262.76 4,714.77 4,666.17 -840.18 -7,253.26 6,003,02620 380,592.98 0.67 -2,544.31 MWD+IFR-AK-CAZ-SC (3) 9,540.24 68.76 262.18 4,748.74 4,700.14 -851.69 -7,340.34 6,003,016.00 380,505.75 0.61 -2,573.59 MWD+IFR-AK-CAZ-SC (3) 9,634.77 68.63 261.81 4,783.09 4,734.49 -863.95 -7,427.56 6,003,005.04 380,418.37 0.39 -2,602.25 MWD+IFR-AK-CAZ-SC (3) 9,729.53 69.14 261.50 4,817.23 4,768.63 -876.78 -7,515.02 6,002,993.53 380,330.73 0.62 -2,630.53 MWD+IFR-AK-CAZ-SC (3) 9,824.08 68.62 261.82 4,851.30 4,802.70 -889.58 -7,602.28 6,002,982.05 380,243.29 0.63 -2,658.75 MWD+IFR AK-CAZ-SC (3) 9.918.47 68.14 261.15 4,886.07 4,837.47 -902.57 -7,689.06 6,002,970.37 380,156.33 0.83 -2,686.57 MWD+IFR-AK-CAZ-SC (3) 10,012.90 67.89 260.24 4,921.42 4,872.82 -916.72 -7,775.47 6,002,957.51 380,069.73 0.93 -2,713.18 MWD+IFR-AK-CAZ-SC (3) 10,107.67 68.15 260.48 4,956.90 4,908.30 -931.44 -7,862.11 6,002,944.10 379,982.88 0.36 -2,735.41 MWD+IFR-AK-CAZ-SC (3) 10,202.09 69.08 260.36 4,991.32 4,942.72 -946.07 -7,948.81 6,002,930.77 379,895.99 0.99 -2,765.73 MWD+IFR-AK-CAZ-SC (3) 10,296.79 68.75 260.15 5,025.39 4,976.79 -961.03 -8,035.89 6,002,917.13 379,808.70 0.41 -2,791.94 MWD+IFR-AK-CAZ-SC (3) 10,391.47 68.95 260.75 5,059.55 5,010.95 -975.68 -8,122.97 6,002,903.79 379,721.42 0.63 -2,818.42 MWD+IFR-AK-CAZ-SC (3) 10,485.95 69.07 261.47 5,093.40 5,044.80 -989.31 -8,210.12 6,002,891.47 379,634.08 0.72 -2,845.83 MWD+IFR-AK-CAZ-SC (3) 10,580.42 68.69 262.53 5,127.44 5,078.84 -1,001.58 -8,297.38 6,002,880.51 379,546.65 1.12 -2,874.52 MWD+IFR-AK-CAZ-SC (3) 10,675.37 68.29 262.44 5,162.25 5,113.65 -1,013.13 -8,384.96 6,002,870.28 379,458.91 0.43 -2,903.00 MWD+IFR-AK-CAZ-SC (3) 10,769.56 68.15 261.90 5,197.20 5.148.60 -1,025.04 -8,471.61 6,002,859.67 379,372.10 0.55 -2;932.71 MWD+IFR-AK-CAZ-SC (3) 10,865.06 68.49 262.64 5,232.48 5,183.88 -1,036.98 -8,559.55 6,002,849.06 379,284.00 0.80 -2,W2.00 MWD+IFR-AK-CAZ-SC(3) 10,959.06 68.47 262.46 5,266.96 5,218.36 -1,048.32 -8,646.26 6,002,839.02 379,197.14 0.18 -2,991.26 MWD+IFR-AK-CAZ-SC (3) 11,053.17 68.28 26229 5,301.65 5,253.05 -1,059.93 -8,732.97 6,002,828.72 379,110.27 0.26 -3,020.28 MWD+IFR-AK-CAZ-SC (3) 11,148.34 68.68 262.50 5,336.56 5,287.96 -1,071.64 -8,820.73 6,002,818.32 379,022.35 0.47 -3,049.69 MWD+IFR-AK-CAZ-SC (3) 11,242.45 68.43 263.04 5,370.96 5,322.36 -1,082.67 -8,907.63 6,002,808.60 378,935.31 0.60 -3,079.31 MWD+IFR-AK-CAZ-SC (3) 11,336.68 68.22 263.28 5,405.77 5,357.17 -1,093.10 -8,994.57 6,002,799.48 378,848.22 0.33 3,109.49 MWD+IFR-AK-CAZ-SC (3) 11.432.64 68.40 262.95 5,441.23 5,392.63 -1,103.79 -9,083.09 6,002,790.13 378,759.56 0.37 -3,140.16 MWD+IFR-AK-CAZ-SC (3) 11,525.23 68.83 263.46 5,474.99 5,426.39 -1,113.99 -9,168.70 6,002,781.21 378,673.81 0.69 -3,169.93 MWD+IFR-AK-CAZ-SC (3) 11,620.08 69.02 262.80 5,509.10 5,460.50 -1,124.57 -9,256.57 6,002,771.95 378,585.80 0.68 -3,200.39 MWD+IFR-AK-CAZ-SC (3) 11,715.04 68.62 262.26 5,543.41 5,494.81 -1,136.08 -9,344.36 6,002,761.76 378,497.85 0.68 -3,229.66 MWD+IFR-AK-CAZ-SC (3) 31912011 10:16:03AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhiIli ps(Alaska) Inc. l..ocal Co-ordinate Reference: Well CD3-127 Project: Western North Slope TVD Reference: Rig: CD3-127 @ 48.60ft (D19) Site: CD3 Fiord Pad 1'AD Reference: Rig: CD3-127 @ 48.60ft (1319) Well: CD3-127 North Reference: True Wellbore: CD3-127PB1 Survey Calculation Method: Minimum Curvature Design: CD3-127PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +IE/-W Northing Easting DLS Section (ft) (1) (1 (ft) (ft) (ft) (ft) (ft) A (°/100-) (ft) Survey Tool Name 11,809.83 68.37 26L58 5,578A6 5,529.56 -1,148.48 -9,431.68 6,002,750.68 378,410.37 0.72 -3,25859 MWD+IFR-AK-CAZ-SC(3) 11,904.20 68.10 261.31 5,613.15 5,564.55 -1,161.52 -9,518.35 6,002,738.95 378,323.52 0.39 3,286.32 MWD+IFR-AK-CAZ-SC (3) 11,998.74 68.88 261.53 5,647.82 5,599.22 -1,174.64 -9,605.32 6,002,727.13 378,236.37 0.85 3,314.11 MWD+IFR-AK-CAZ-SC (3) 12,093.19 67.87 261.85 5,682.62 5,634.02 -1,187.33 -9.692.20 6,002,715.75 378,149.32 1.11 -3,342.26 MWD+IFR-AK-CAZ-SC (3) 12,188.15 67.49 260.60 5,718.69 6,670.09 -1,200.73 -9,779.01 6,002,703.66 378,062.32 1.28 -3,369.72 MWD+IFR-AK-CAZ-SC (3) 12,282.31 67.42 258.56 5,754.79 5.706.19 -1,216.46 -9,864.54 6,002,689.22 377,976.58 2.00 3,304.54 MWD+IFR-AK-CAZ-SC (3) 12,377.09 65.93 256.14 5,792.33 5,743.73 -1,235.50 -9,949.45 6,002,671.45 377,891.40 2.82 -3,416.11 MWD+IFR-AK-CAZ-SC(3) 12,471.81 64.31 253.04 5,832.18 5,783.58 -1,258.32 -10,032.28 6,002,649.88 377,808.24 3.43 3,433.39 MWD+IFR-AK-CAZ-SC (3) 12,566.24 63.63 250.36 5,873.63 5,825.03 -1,284.95 -10,112.83 6,002,624.47 377,727.31 2.65 3,446.23 MWD+IFR-AK-CAZ-SC (3) 12,660.71 62.38 245.82 5,916.53 5,867.93 -1,316-33 -10,190.90 6,002,594.26 377,648.78 4.48 -3,463,71 MWD+IFR-AK-CAZ-SC (3) 12,755.23 61.90 242.47 5,960.71 5,912.11 -1,352.76 -10,266.09 6,002,558.97 377,573.06 3.17 -3,456,36 MWD+IFR-AK-CAZ-SC (3) 12,849.48 61.35 238.91 6,005.51 5,956.91 -1,393.34 -10,338.38 6,002,519.48 377,500.17 3.37 -3,452.05 MWD+IFR-AK-CAZ-SC(3) 12,944.56 60.29 235.44 6,051.88 6,003.28 -1,438.32 -10,408.13 6,002,475.56 377,429.76 3.38 -3,443.64 MWD+IFR-AK-CAZ-SC (3) 13,039.19 59.83 231.13 6,099.12 6,050.52 -1,487.32 -10,473.85 6,002,427.56 377,363.32 3.98 -3,429.82 MWD+IFR-AK-CAZ-SC (3) 13,133.55 59.30 227.88 6,146.93 6,098.33 -1,540.14 -10,535.71 6,002,375.68 377,300.68 3.02 3,410.84 MWD+IFR-AK-CAZ-SC (3) 13,228.15 58.98 223.95 6,195.47 6,146.87 -1,596.61 -10,594.03 6,002,320.09 377,241.52 3,58 -3,386.99 MWD+IFR-AK-CAZ-SC (3) 13,322.44 58.26 221.06 6,244.57 6,195.97 -1,655.94 -10,648.41 6,002,261.59 377,186.26 2.73 -3,358.82 MWD+IFR-AK-CAZ-SC (3) 13,417.06 58.33 217.32 6,294.31 6,245.71 -1,718.32 -10,699.26 6,002,199.99 377,134.48 3.36 -3,326.33 MWD+IFR-AK-CAZ-SC (3) 13,511.62 58.19 213.56 6,344.07 6,295.47 -1,783.82 -10,745.88 6,002,135.21 377,086.88 3.38 -3,289.14 MWD+IFR-AK-CAZ-SC (3) 13,605.67 57.92 209.06 6,393.85 6,345.25 -1,851.97 -10,787.34 6,002,067.69 377,044.41 4.07 3,247.23 MWD+IFR-AK-CAZ-SC (3) 13,701.24 58.20 204.65 6,444.43 6,395.83 -1,924.30 -10,823.96 6,001,995.93 377,006.71 3.93 -3,199.41 MWD+IFR-AK-CAZ-SC (3) 13.795.09 58.55 200.19 6,493.66 6,445.06 -1,998.15 -10,854.42 6,001,922.55 376,975.15 4.06 3,147.44 MWD+IFR-AK-CAZ-SC (3) 13,890.11 59.21 199.26 6,542.77 6,494.17 -2,074.72 -10,881.87 6,001,846.41 376,946.55 1.09 -3,091.68 MWD+IFR-AK-CAZ-SC (3) 13,984.64 61.11 198.91 6,589.80 6,541.20 -2,15220 -10,908.68 6,001,769.34 376,918.59 2.04 -3,034.81 MWD+IFR-AK-CAZ-SC (3) 14,079.40 63.16 196.72 6,634.09 6,585.49 -2,231.95 -10,934.29 6,001,689.99 376,891.78 2.98 -2,975.38 MWD+IFR-AK-CAZ-SC (3) 14,173.85 65.35 195.62 6,675.12 6,626.52 -2,313.66 -10,967.98 6,001,608.66 376,866.87 2.54 -2,613.33 MWD+IFR-AK-CAZ-SC (3) 14,268.42 67.42 193.14 6,713.00 6,664.40 -2,397.58 -10,979.48 6,001,525.07 376,844.12 3.25 -2,848.32 MWD+IFR-AK-CAZ-SC (3) 14,362.47 68.83 191.63 6,748.05 6,699.45 -2,482.83 -10,998.19 6,001,440.13 376,824.13 2.11 -2,780.86 MWD+IFR-AK-CAZ-SC (3) 14.457.15 70.00 189.52 6,781.34 6,732.74 -2,569.95 -11,014.45 6,001,353.26 376,806.56 2.42 -21710.61 MWD+IFR-AK-CAZ-SC (3) 14,551.77 70.91 187.66 6,813.00 6,764.40 -2,658.11 -11,027.76 6,001,265.32 376,791.93 2.09 -2,638.10 MWD+IFR-AK-CAZ-SC (3) 14,645.89 71.82 184.94 6,843.08 6,794.48 -2,746.75 -11,037.54 6,001,176.85 376,780.82 2.90 -2,563.57 MWD+IFR-AK-CAZ-SC (3) 14,740.99 73.20 182.82 6,871.66 6,823.06 -2,837.24 -11,043.67 6,001,086.47 376,773.33 2.57 -2,485.73 MWD+IFR-AK-CAZ-SC (3) 14,835.21 74.99 179.76 6,897.48 6,848.88 -2,927.81 -11,045.70 6,000,995.94 376,769.94 3.66 -2,405.94 MWD+IFR-AK-CAZ-SC (3) 14,929.46 76.89 177.30 6,920.38 6,871.78 -3,019.20 -11,043.35 6,000,904.54 376,770.92 3.24 -2,323.45 MWD+IFR-AK-CAZ-SC (3) 15,023.59 78.29 173.56 6,940.62 6,892.02 -3,110.81 -11,036.02 6,000,812.83 376,776.87 4.16 -2,238.49 MWD+IFR-AK-CAZ-SC (3) 15,118.17 79.86 169.10 6,958.55 6,909.95 -3,202.59 -11,022.01 6,000,720.87 376,789.50 4.92 -2,160.36 MWD+IFR-AK-CAZ-SC (3) 15,212.85 83.23 167.81 6,972.47 6,923.87 -3,294.33 -11,003.27 6,000,628.86 376,806.86 3.81 -2,060.11 MWD+IFR-AK-CAZ-SC (3) 15,231.51 83.42 167.35 6,974.64 6,926.04 -3,312.43 -10,999.28 6,000,610.71 376,810.57 2.65 -2,042;17 MWD+IFR-AK-CAZ-SC (3) 15,261.00 83.42 167.35 6,978.02 6,929.42-3,341.01-10,992.87 6,000,582.03 376,816.56 0.00-2,013.79 PROJECTED to TD 3/9/2011 10:16:03AM Page 6 COMPASS 2003.16 Build 69 Halliburton Sperry Drilling 6900 Arctic Blvd Anchorage, AK 99518 cv3-�Z�i: Z�9�9 August 23, 2011 AOGCC Christine Mahnken 333 W. 7ch Ave., Suite 100 Anchorage, AK 99501 Dear Sir or Madam: Subject: CD3-127PB1 Definitive Survey Reports Enclosed are two hard copies (NAD83 and NAD27) of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit@Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK 18 Received b : CAI Date: AA Rece y � � / Please contact me at 907.263.4657with questions or concerns. Regards, Avinash Ramjit A I I - to S- Halliburton Sperry Drilling 6900 Arctic Blvd Anchorage, AK 99518 August 23, 2011 AOGCC Christine Mahnken 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Sir or Madam: Subject: CD3-127PB1 Definitive Survey Reports Enclosed are two hard copies (NAD83 and NAD27) of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit@Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK 18 Received by: DAI Date: 1 y �, � Please contact me at 907.263.4657with questions or concerns. Regards, Avinash Ramjit 211 - oos_... STATE OF ALASKA ALAS, DIL AND GAS CONSERVATION COMM. ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon" Repair w ell jr Rug Perforations Stimulate r Other r" Alter Casing r Pull Tubing Perforate New Pool Waiver F Time Extension [- Change Approved Program ] " 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 17 Exploratory Stratigraphic � Service 211-005 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 „ 50-103-20634 0 ' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, 025538, 025526 ' CD3-127 `(.(�•// 9. Field/Pool(s): Colville River Field / Fiord Oil Pool • 10. Present Well Condition Summary: Total Depth measured 15261 feet Plugs (measured) 3126 true vertical 6978 feet Junk (measured) none Effective Depth measured 15261 feet Packer (measured) none true vertical 6978' feet (true vertucal) none Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114 114' Surface 3202' 10.75" 3239' 2453' 3580 psi 2480 psi Intermediate Production RECE — u) Perforation depth: p the Measured depth: none True Vertical Depth: none APR 6 6 ,�(��p p • aska & Gas Cos. caffnaft Tubing (size, grade, MD, and TVD) 3.5" tubing, L-80, EUE @ 2180' MD / 2017' TVD Ar "Osage Packers & SSSV (type, MD, and TVD) no packer, no SSSV 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 na Subsequent to operation na 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run XXX Exploratory r Development r Service - Stratigraphic r 15. Well Status after work: Oil rv- Gas r WDSPL r- Daily Report of Well Operations XXX GSTOR j" WINJ WAG �GINJ SUSP SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311-065 Contact Nina Anderson (aD- 265-6403 Printed Name Nina Anderson Title Alpine Drilling Engineer Signature Phone: 265-6403 Date A'111'AR 6&,- RBDMS APR 0 6 101 Form 10-404 Revised 10/2010 4�k Y�./( Submit Original Only --'Ze y//r WNS CD3-127 ConocoPhillip5 Well Attributes �, __ __ Max An le 8 MD TD _ -- 9___-_ —_ WNlb—APW WI Feld Name Well Stat Ind (') MD (ftKB) Act elm (ftKB) ]_. " 501032063400 _ IFIORD NECHELIK _ ISUSP 8342 15,23t51 Comment H2S (ppm) notation End Date KB Grd (ft) Rig Release Date IDate SSSV. Annotation Depth (ftKB) Entl Date Ann talon Last WO _3630 Last Mod .. End Data weuGonrgHOR!U__A4;_, 3t37„_3zr�oil2zg1�PM _ S_cinmaghp -Agla , Last Tag I __. �ReN Reason WELL SUSPENDED 1 Imosbor 3/27/2011 Casing Strings - Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR_ 16 14.688 36.0 114.0 114.0 109.00 H-40 - - -- -- . Cosing Daacdplion -- String 0... String ID ... Top (fdW) _ _ Sat De ti (f.. Set Depth (TVD) ... String Wt_. String ... String Top Tint SURFACE 10314 9.950 35.9 3,239.2 2,453.4 45.50 L80 BTCM HANGER. 31— - TUbin9Stllil.9_S ___:-- - :�... 7 Tubing Description String 0... String ID ... Top, Sat Depth (L.. Sat Depth (TVD) .. String Wt... IString ... Strirg Top Thrd - TUBING 31,2 12 2.992 30.9 2 180.02,017.1 920 L-80 EUE KILL STRING ComQletion Details — !.. Top Depth_— " (TVD) Top IncI N i... To B (ft!B) () itam Description Comment ID (in) 30.9 309 026 HANGER FMC Tubing Hanger (2 S2'pup 41/2"IBT) 4000 2, 179.5 2,01lid 1982WLEG WLLG 3.500 OtherH_ol _In_e(Wireline retrievable _ plugsLyaives pumps fishnet" _ Top Depth' (TVD) Top Incl Tqp Mil tItIC6) 0 Description Comment Ron Data ID in - 3.126-0 2,414.6 70.1E PLUG Bridge Plug - Permanent -Pressure Tested V 2500 Psi 11110 3172011 0.000 Minutes CONDUCTOR, Ciein@nt `JmueeZ@S SURFACE, 36-3.239 Cement PWg, 7,269 Cemem Pkg. 7,344 Cemem Pkp, 13,207 TD, 15.261 tylr�/ — "_- --_ T 'p Depth Btrn Depth - (rvDl (TVDI , LftKS gim�gKg (ttKB) (ftKB) DesolPtit n_ Star) Date Comment 7,269.0 7,465.0 - 3,920.2 3,991.4 _ Cemem Plug 362011 - Isolate Qannik Reservoir (Remedial) 7,344.0 7,744.0 3,947.3 4,094.2 Cement Plug 3/42011 Isolate Qannik Reservoir 13,207.0 13,6U7.D 6,184.E __ 6,394.3 Cement Plug __._. ___ 3/47 _._ _ Isolate Nechelik Reservoir dotes: General_& Safety_ _ --_-__ — - -- -- End Data Annotation HKZ- ConocoPhillips Time Log & Summary Wellview Web Reportmg Report Well Name: CD3-127 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 2/10/2011 5:00:00 PM Rig Release: 3/8/2011 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 2/09/2011 24 hr Summary Release from CD2-77. Prepare camp and move to CD3 ice pad. Spot & RU same. Move ball mill complex and move motor and it complexes on ice road to CD3. Move sub complex onto ice road. 10:00 12:30 2.50 0 0 MIRU MOVE MOB P Prepare camp for move from CD2 to CD3. 12:30 16:00 3.50 0 0 MIRU MOVE MOB P Rig down rig complexes. Move camp modules and spot same at CD3 ice pad. 16:00 19:00 3.00 0 0 MIRU MOVE MOB P Continue rigging down on CD2. Move ball mill complex, mechanic shop and electrical shop over to CD3. 19:00 00:00 5.00 0 0 MIRU MOVE MOB P Continue with rig move. Move motor and pit complexes onto ice road and bring sub complex up behind. 2/10/2011 Continue moving sub base to CD3. Spot sub over well and RU complexes. NU riser and flowline. Start PUDP. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move rig complexes to CD3 location. 12:00 16:00 4.00 0 0 MIRU MOVE MOB P Spot sub over CD3-127 conductor. Spot pits, motor complex and pipeshed. 16:00 17:00 1.00 0 0 MIRU MOVE MOB P Hook up service lines - steam, water, electrical and air. Rig on highline power at 1645 hrs. 17:00 19:15 2.25 0 0 MIRU DRILL NUND P Accept rig at 17:00 hrs. NU riser and flowline. Load pipeshed with tubulars. 19:15 00:00 4.75 0 0 MIRU DRILL PULD P RU handling tools to PUDP. PJSM. PU 5" DP using mousehole. 24 stds PU by end tour. 2/11 /2011 PU 5" DP & HWDP from pipeshed. Cut drlg line. Pre -spud meeting. Spud well at 09:15 hrs. Drill 13 1/2" hole to 1093' MD/1085' TVD. 00:00 02:45 2.75 0 0 MIRU DRILL PULD P Continue PU 5" DP and HWDP using mouse hole. 02:45 04:15 1.50 0 0 MIRU RIGMNT SLPC P Slip and cut drilling line. Service top drive and set block height. 04:15 07:30 3.25 0 0 MIRU DRILL PULD P Bring BHA components to rig floor. MU BHA #1 per DD. Hang sheave for yro survey tool in derrick. 07:30 08:00 0.50 0 0 MIRU DRILL SFTY P Hold pre -spud meeting with rig crew and service company personnel. 08:00 09:00 1.00 0 0 MIRU DRILL PRTS P Fill riser with mud.and check for leaks. Flood lines and pressure test to 3500 psi - OK. Blow down top drive. 09:00 09:15 0.25 0 0 MIRU DRILL PULD P MU flex collars and wash down to 114'. Page 1 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:15 12:00 2.75 0 280 SURFA( DRILL DDRL P Spud well at 09:15 hrs. Drill to 280' MD. ADT=1.13 hrs. 550 gpm. On btm = 1060 psi. Off btm = 1000 psi. 60 rpm. Torque = 4 kftlbs on/off btm. PUW/SOW/Rot Wt = 95 klbs. G ro every stand. 12:00 00:00 12.00 280 1,093 SURFA( DRILL DDRL P Continue drilling 13 1/2" surface hole to 109T MD / 1085' TVD. AST=2.87 hrs. ART=3.35 hrs. ADT=6.22 hrs. PUW=120 klbs. SOW=120 klbs. ROT=120 klbs. (Pumps on). 6.5 klbs TQ on btm. 5.5 klbs TQ off btm. 10-25 klbs WOB. 60 RPM. Flow=500 gpm. PP=1200 psi on btm. Gyro surveys every stand to 354'. Well getting too close to planned future well CD3-128 so gyro every single to 476' MD. 2/12/2011 Drill 13 1/2" hole to 2805' MD / 2307' TVD 00:00 12:00 12.00 1,093 2,093 SURFA( DRILL DDRL P Continue drilling 13 1/2" surface hole from 1093' MD to 2056' / 1939' TVD. AST=3.05 hrs. ART=2.94 hrs. ADT= 5.99 hrs. PUW=135 klbs. SOW=132 klbs. ROT=135 klbs. (Pumps on). 7.5 klbs TQ on btm. 6.5 klbs TQ off btm. 10-25 klbs WOB. 60 RPM. Flow=650 gpm. PP= 1870 psi on btm. 12:00 00:00 12.00 2,093 2,805 SURFA( DRILL DDRL P Continue drilling 13 1/2" surface hole from 2056' MD to 2805' / 230T TVD. AST=3.14 hrs. ART=5.07 hrs. ADT= 8.21 hrs. PUW=140 klbs. SOW=130 klbs. ROT=135 klbs. (Pumps on). 8.5 klbs TQ on btm. 7 klbs TQ off btm. 10-25 klbs WOB. 60 RPM. Flow=675 gpm. PP= 2405 psi on btm. 2/13/2011 Drill 13 1/2" hole to TD at 3250' MD/2457' TVD. Circ hole clean. Wiper trip up to HWDP. RIH to btm. Circ hole clean. POH to run 10 3/4" casing. Page 2 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 08:15 8.25 2,805 3,250 SURFA( DRILL DDRL P Drill ahead from 2805' MD to 3250' MD/2457' TVD. Surface hole TD. ADT= 6.32 hrs. ART=6.13 hrs. AST=0.19 hrs. PUW=135kibs. SOW=130 klbs. ROT=132 klbs. TQ ON=8.5 kftlbs. TQ OFF=7 kftlbs. @ 60 rpm 2410 psi at 675 gpm. 08:15 09:30 1.25 3,250 3,250 SURFA( DRILL CIRC P Circulate and condition mud - Pumped 2 X BU - 700 gpm / 2420 psi / 60 rpm - flow check well, static 09:30 14:30 5.00 3,250 904 SURFA( DRILL TRIP P Perform wiper trip - Backream from 3250' to 904'- 650 gpm / 2100 psi / 60 rpm - reduced rate to 500 gpm from 1500' Hole unloaded a large amount of cuttings while backreaming from 2039' to 1945' (45-40 degree angle) pulled slow until shakers cleaned up. Slowed pulling speed on the last two stands - observed a large push of cuttings (mostly sand) throughout. Flow check well, staic - blow down to drive 14:30 16:30 2.00 904 3,250 SURFA( DRILL TRIP P RIH from 904' to 3250' - no problems - precautionary washed and reamed last stand to bottom 16:30 18:30 2.00 3,250 3,250 SURFA( DRILL CIRC P Circulate and condition mud - 670 gpb / 2680 psi / 60 rpm through first BU - large amounts of sand across shakers - reduced rate to 500 gpm to manage increasing mud wt. from 9.7 ppg to 10.0 ppg - shakers pretty clean after second BU - flow check well, static. Blow down top drive. 18:30 21:30 3.00 3,250 909 SURFA( DRILL TRIP P POOH on elavators from 3250' to HWDP. PUW off bottom pumps off=143 klbs. Trip speed 1000-1500 fph. 10 mi flow check at HW. Slight fluid level drop in riser. 21:30 22:45 1.25 909 260 SURFA( DRILL TRIP P POH with HWDP. One minor overpull at —650' - 25 klbs overpull. Drop back down and wipe same - OK. No other problems or tight spots noted. No circulating required. 22:45 00:00 1.25 260 1 50 SURFA( DRILL PULD P LD BHA - jars, flex collars. 2/14/2011 Run 10 3/4" casing to 3239' MD shoe depth. Circ and cond hole. Cement with 445 sx AS Lite lead slurry and 280 sx 15.8 Class G tail slurry. Got back 56 bbls slurry to surface. ND riser. NU wellhead & BOPE. 00:00 01:00 1.00 50 0 SURFA( DRILL PULD P Finish LD BHA #1 and download MWD. 01:00 02:00 1.00 0 0 SURFA( DRILL PULD P Clear rig floor of BHA components and clean floor. 02:00 03:15 1.25 0 0 SURFA( CASING RURD P PJSM. RU casing tools to run 10 3/4" surface casing. Page 3 of 23 n Time Logs Date From To Dur S. DeDth E. De th Phase Code Subcode T Comment 03:15 03:45 0.50 0 0 SURFA( CASING SFTY P PJSM with all crew members, mud engr, TP, Co Rep for running 10 3/4" casing. 03:45 06:00 2.25 0 0 SURFA( CASING RNCS P MU shoe track. Bakerlock connections on first 3 jts and pin on jt #4. RI with 10 3/4" casing. 06:00 06:45 0.75 1,626 1,626 SURFA( CASING CIRC P Establish circulation - Staged pumps up to 6.0 bpm - Reciprocate casing and condition mud casing PUW 145K SOW 123K FCP=380 psi - Circulated 1.5 X BU - observed mild amount of cuttings across shakers 06:45 09:00 2.25 1,626 3,239 SURFA( CASING RNCS P Run 10 3/4" casing from 1626' to 3201' (79 jts. total) MU FMC fluted hanger and landing joint - land casing w/ FS @ 3239' and FC @ 3158' 09:00 09:30 0.50 3,239 3,239 SURFA( CASING RURD P Rd casing tongs and scaffold - LD fill -up tool 09:30 09:45 0.25 3,239 3,239 SURFA( CEMEN" RURD P Ru 10 3/4" cement head and lines 09:45 12:45 3.00 3,239 3,239 SURFA( CEMEN" CIRC P Establish circulation - Reciprocate and stage pumps up to 7.0 bpm - condition mud and hole for cementing FCP 330 psi - total pumped 1023 bbls - PUW 187K SOW 148K MWT. 10.o ppg PV 22 YP 17 FV 55 10 sec gels 5 10 min. 11 Held PreJob safety and operations meeting with rig on upcoming cement job 12:45 14:30 1.75 3,239 3,239 SURFA( CEMEN- PUCM P Cemented 10 3/4" casino as follows - Rig pumped 120 bbls of 10.0 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 2 bbls of FW, tested lines to 3200 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 210 psi. Mixed & pumped 446 sxs of 10.7 ppg lead slurry (4.49 cf/sx yield) (ASL) ave. 7.0 bpm at 276 - 190 psi. Observed nut plug marker at shakers w/ 240 bbls lead slurry pumped (pumped down surge can, 357 bbls total) Switched to tail slurry and pumped 280 sxs of 15.8 ppg tail cmt (1.16 cf/sx) 57 bbls (Class G w/ additives) ave.5.0 bpm at 180 psi. Page 4 of 23 s�6 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:30 15:30 1.00 3,239 3,239 SURFA( CEMEN" DISP P Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 282 bbls of 10.0 ppg mud ave. 7.0 bpm, ICP 240, FCP 720 psi, slowed pump to 4 bpm at 550 psi (for the last 8.0 bbls of displacement) Bumped plug to 1180 psi. Checked floats OK, CIP @ 1622 hrs. Had full returns throughout job w/ 56 bbis of 10.7 ppg cement returns to surface. Reciprocated pipe until last 122 bbls of displacement (SOW had dropped to 100K). 15:30 17:30 2.00 3,239 3,239 SURFA( CEMEN- RURD P Bleed off pressure and check floats - OK. RD cement head. LD landing jt. RD and LD casing tools. Install bails and 5: DP elevators. 17:30 19:00 1.50 0 0 SURFA( WHDBO NUND P PJSM. ND and remove riser. 19:00 20:00 1.00 0 0 SURFA( WHDBO NUND P Orient and install FMC wellhead and test metal to metal seal to 1000 psi for 10 min - good test. 20:00 00:00 4.00 0 0 SURFA( WHDBO NUND P PJSM. NU BOPE. 2/15/2011 NU BOPE. PU 5" DP. Test BOPE to 250/3500 psi. Install wear ring. MU rotary steerable BHA #2. 00:00 01:15 1.25 0 0 SURFA( WHDBO NUND P Cont. NU BOPE - Install riser & flow line - Install mouse hole 01:15 01:30 0.25 0 0 SURFA( DRILL SFTY P Held PJSM on picking up 5" DP f/ pipe shed via mouse hole 01:30 05:00 3.50 0 0 SURFA( DRILL PULD P PU 5" DP f/ pipe shed & stand bvack in derrick 05:00 05:30 0.50 0 0 SURFA( RIGMNT SVRG P Service rig - grease drawworks & iron roughneck - Clean eyes on skate 05:30 13:30 8.00 0 0 SURFA( DRILL PULD P Cont. PU 5" DP f/ pipe shed & stand back in derrick (315 jts - 105 stds) 13:30 21:30 8.00 0 0 SURFA( WHDBO BOPE P Pull wear bushing. Set test plug on 5" test jt. Test BOPE. UPR, LPR, blinds, man & hyd choke valves, dart sub, floor valve, IBOP, choke manifold to 250/3500 psi. Annular to 250/2500 psi. Flush and fill gas buster. Check function of manual and hydraulic chokes w/ 1100 psi back pressure. Perform accumulator drawdown test and check nitrogen backup bottles. Witness of test waived by AOGCC Rep Bob Noble at 16:30 hrs on 2/13/2011. 21:30 22:00 0.50 0 0 SURFA( WHDBO BOPE P Pull test plug. Set wear bushing. 22:00 00:00 2.00 0 0 SURFA( DRILL PULD P PJSM. PU components for BHA #2 Geo Pilot rotary steerable. 2/16/2011 _ MU BHA #2. RIH PUDP to 2950'. Test casing to 3500 psi for 30 min. Good test. Drill shoe track plus 20' new hole to 3270' MD. Perform LOT to 17.0 ppg EMW. Displace hole to 9.6 ppg LSND mud. Drill ahead to 3544' MD. Page 5 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 03:00 3.00 77 77 SURFA( DRILL PULD P Cont MU Geo Pilot BHA #2. Upload MWD.- Load RA sources in MWD tool 03:00 04:00 1.00 77 287 SURFA( DRILL WASH T Hit cmt stringer @ 185' after picking up 2nd NM flex DC - MU std f/ derrick - wash down f/ 185' to 287' @ 550 gpm @ 1060 psi w/ 50 rpm @ 6 k torque - Blow down TD - std back 1 std DP in derrick 04:00 04:45 0.75 287 629 SURFA( DRILL PULD P Cont. MU BHA - RIH f/ 185' to 629' w/ NM flex DC's - HWDP 04:45 05:15 0.50 629 629 SURFA( DRILL OTHR T PU ghost reamer # 1 - Observed wash out above blade on body of tool Wait on decision 05:15 05:30 0.25 629 777 SURFA( DRILL TRIP P Cont. RIH f/ 629' to 777' w/ HWDP 05:30 07:30 2.00 777 2,951 SURFA( DRILL TRIP P Cont. RIH f/ 777' to 2951' - picking remaining 69 jts 5" DP f/ pipe shed (picked up ghost reamer 1786' f/ bit) 07:30 08:15 0.75 2,951 2,951 SURFA( DRILL CIRC P Circ btms up @ 2951' for casing test - 550 gpm @ 1650 psi w/ 50 rpm's @ 8.5 k torque - PU wt 140 SO wt 110 Rot wt. 130 - Blow down TD 08:15 08:30 0.25 2,951 2,951 SURFA( RIGMNT SFTY P PJSm on cut & slip of drill line 08:30 10:30 2.00 2,951 2,951 SURFA( RIGMNT SLPC P Slip & cut drill line 60' and service TD and draw works - replace broken cotter pin on draw works brake band pin - Calc. block height - 10:30 12:00 1.50 2,951 2,951 SURFA( DRILL PRTS P PJSM on testing casing - RU & test 10 3/4' casing to 3500 psi for 30 mins.- Blow down lines & RD 12:00 12:30 0.50 2,951 3,154 SURFA( DRILL WASH P Wash & ream f/ 2951' to 3154' (tagged up) 12:30 15:00 2.50 3,154 3,250 SURFA( CEMEN" DRLG P Drilled cmt & wiper plugs & F 3158' - Drilled cmt to 3236' - drilled out shoe f/ 3236' to 3239' - Clean out rat hole to 3250' 15:00 15:30 0.50 3,250 3,270 SURFA( DRILL DDRL P Drilled 20' new hole f/ 3250' to 3270' (for FIT) - @ 700 gpm @ 2540 psi w/ 50 rpm 10 k torque 15:30 17:00 1.50 3,270 3,270 SURFA( DRILL CIRC P Circ and cond mud for FIT 700 gpm 2500 psi. 17:00 18:00 1.00 3,270 3,270 SURFA( DRILL FIT P Perform FIT. Shoe @ 2453' TVD. MW = 9.6 ppg. LO pressure = 950 psi. LOT value = 17.0 ppg EMW. Page 6 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:00 00:00 6.00 3,270 3,544 INTRM1 DRILL DDRL P Drill 9 7/8" hole from 3270'. Swap hole to 9.6 ppg LSND mud while drilling ahead. SD and flow check well after displacement complete - OK. Drill ahead to 3544' MD. Having to keep rotary speed low to reduce excessive BHA vibration. ADT=2.84 hrs. PUW=148 k. SOW=121 k. ROT=135 k. TQ ON=10000 ft lbs. TQ OFF=7500 ft lbs. 50 rpm. WOB=5-10 k. 750 gpm @ 2050 psi. ECD 10.2 ppg. 2/17/2011 Drilling ahead in 9 7/8" hole from 3544' to 6100' MD/3471' TVD. 00:00 12:00 12.00 3,544 4,747 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/ GP f/ 3544' to 4747' MD 3002' TVD ADT- 8.31 hrs ECD- 10.75 ppg Footage- 1203' WOB 5 - 15 k RPM 120 GPM 750 @ 2460 psi String wt. PU 150 SO 134 Rot 140 Torque on/off btm.- 10/8.5 k Ongoing issues with excessive BHA vibration and stick/slip preventing higher rotary RPM - turning at 90 rpm max. Increasing lubricant content of mud from 1 to 2% to see if any im rovement is noted. 12:00 00:00 12.00 4,747 6,100 INTRM1 DRILL DDRL P Continue drilling 9 7/8" hole from 4747' to 6100' MD/3471' TVD. ADT = 7.44 hrs. ECD = 10.93 ppg EMW. Footage drilled = 1353'. WOB = 5-15 klbs. RPM = 145. 725 gpm @ 2870 psi. String wt: 165 k up. 142 k dn. 152 k rot. Torque on/off btm = 11/8.5 kft lbs. Maintaining ROP at —200 fph. Sweeps are bringing back a moderate amount of cuttings. 275 bbl whole mud dilutions at 4585', 5210' and 5970' to maintain MBT <20. Lube concentration at 2%. 2/18/2011 Drilled 9 7/8" hole w/ Geo Pilot f/ 6100' to 8776' MD/4440' TVD. Page 7 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00.00 12:00 12.00 6,100 7,489 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/ GP f/ 6100' to 7489' MD 3999' TVD ADT- 7.23 hrs. ECD- 10.93 ppg Footage- 1389' WOB 5/20 k ROPM 150 GPM 775 @ 3020 psi String wt. PU 181 SO 150 Rot 165 Torque on/off btm.- 10.5 / 8 k 12:00 00:00 12.00 7,489 8,776 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Geo Pilot RSS from 7489' to 8776' MD/4440' TVD. ADT = 7.27 hrs. ROP = 250 fph. ECD = 10.8 ppg. Footage drilled = 1287' . RPM = 150. WOB = 10-18 klbs. 800 gpm @ 3120 psi. String wt: PU = 197 k. SO = 154 k. ROT = 172 k. Torque on/off btm = 13.5/10.5 kft lbs. Lubricant concentration at 2%. Whole mud dilutions to keep MBT <20. 2/19/2011 Drilled 9 7/8" hole w/ Geo Pilot f/ 8776' to 11555' MD/5490' TVD. 00:00 12:00 12.00 8,776 10,454 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 8776' to 10,454' MD 5082' TVD ADT- 7.21 hrs ECD- 10.84 ppg Footage- 1678' WOB 15/22 k RPM 150 GPM 800 @ 2950 psi String wt. PU 220 SO 160 Rot 189 Torque on/off btm.- 16/12.5 k 12:00 12:30 0.50 10,454 10,610 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geo Pilot f/ 10454' to 10610' M D. 12:30 13:30 1.00 10,610 10,610 INTRMI DRILL CIRC T Circ at 450 gpm while repairing rod washer on mud pump. Rotate at 90 rpm. 13:30 00:00 10.50 10,610 11,555 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Geo Pilot from 10610' MD to 11555' MD/5490' TVD. ADT = 6.52 hrs. Footage = 945'. ECD = 10.9 ppg. WOB = klbs. Rotary = 145 rpm. 800 gpm @ 3150 psi. String Wt: PU = 240 klbs SO = 162 klbs ROT = 190 klbs Torque On/Off Btm = 2/20/2011 Drilled 9 7/8" hole w/ Geo Pilot from 11,555' MD to 13919' MD/6556' TVD. Page 8 of 23 Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 11,555 12,762 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 11,555' to 12,762' MD 5964' TVD ADT- 7.95 hrs. ECD- 10.74 ppg Footage- 1207' WOB 10/20 k RPM 150 GPM 800 @ 3200 psi String wt PU 260 SO 165 Rot 200 Torque on/off btm.- 20.5/ 17.5 k 12:00 20:30 8.50 12,762 13,680 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geo Pilot from 12762' to 13680' MD. Pop off valve on mud pump #1 sheared at 3950 psi. 20:30 20:45 0.25 13,680 13,680 INTRM1 DRILL DDRL T PU off btm and circ with one pump while changing pop off assembly. 20:45 00:00 3.25 13,680 13,919 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geo Pilot from 13680' MD to 13919' MD/6556' TVD. ADT = 7.9 hrs. Footage = 1157'. (For 12 hr tour). ECD = 10.99 ppg. WOB = 16/18 klbs. RPM = 145 rpm. 750 gpm @ 3550 psi. String Wts: PU = 275 k. SO = 180 k. ROT = 225 k. Torque on/off btm = 21.5/17 kftlbs. Add black products for shale inhibition and weight up to 9.8+ ppg for shale stability prior to drilling into THRZ. HRZ may have come in high at—13750' MD. 2/21 /2011 Drilled 9 7/8" hole w/ GP f/ 13,919' to 15,261' MD JD 9 7/8" hole). Circ & cond hole. Backream to 13550'. Circ & clean up hole. RIH to bottom. 00:00 12:00 12.00 13,919 14,961 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 13,919' to 14,961' MD 6927' TVD ADT- 8.11 hrs ECD- 11.05 ppg Footage- 1042' WOB 10/20 k RPM 150 GPM 750 @ 3880 psi String wt. PU 307 SO 172 Rot 219 Torque on/off btm.- 21/17.5 k 12:00 14:45 2.75 14,961 15,261 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 14,961' to 15,261' MD - 6978' TVD ADT- 2.27 hrs ECD- 10.89 ppg Footage- 300' WOB 5 / 20 k RPM 150 GPM 750 @ 3720 String wt. PU 310 SO 175 Rot 218 Torque on/off btm.- 22.5/17 k TD of 9 7/8" hole section @ 15,261' 14:45 16:15 1.50 15,261 15,261 INTRM1 DRILL CIRC P Flow ck - static (2" below flow line) - Pumped hi-vis sweep & circulate sweep around - Page 9 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:15 17:45 1.50 15,261 15,261 INTRM1 DRILL CIRC P Circ btms up at 700 gpm/3200 psi and 120 rpm. Rack back 1 stand every 30 min to 14960' M D. 17:45 20:45 3.00 15,261 15,261 INTRM1 DRILL REAM P Start backreaming out of hole from 15261 to—13550'. (Approx 200' above THRZ). 700 gpm @ 3550 psi. 120 rpm. 20 ft/min backream speed. 20:45 22:15 1.50 15,261 15,261 INTRM1 DRILL CIRC P Circ until shakers clean up, working stand from 13550 to 13460'. 700 gpm @ 3300 psi. Blow down top drive. Flow check well - —2" below flowline and stable. 22:15 00:00 1.75 15,261 15,261 INTRM1 DRILL TRIP P RIH to 15242'. 2/22/2011 Circ & bump mud wt. to 10.0 ppg - POOH spotting WBS & CR pills to top of HRZ- BROOH f/ 13,731' to 12,785'- Flow ck (static) POOH on elevators to 8341' - Tight hole - BROOH f/ 8371' to 7,394' MD - CBU - Continue to BROOH U 4,558' MD 00:00 01:30 1.50 15,261 15,261 INTRM1 DRILL CIRC P Circ and bump mud wt. to 10.0 ppg - spot WBS/CR pills to bit 01:30 03:45 2.25 15,261 13,730 INTRM1 DRILL TRIP P POOH spotting WBS / CR pills f/ 15261'to 13,730' (above HRZ) - pumping @ 3 bbls/min - No rotation 03:45 05:30 1.75 13,730 12,785 INTRM1 DRILL TRIP P POOH f/ 13,370' to 12,785'- back reaming @ 120 rpm's w/ 700 gpm - Flow ck - well static 05:30 10:15 4.75 12,785 8,371 INTRM1 DRILL TRIP P POOH on elevators f/ 12,785' to 8341' - Tight spot @ 8341' - Attempt to work through - No Go - Run back to 8371' 10:15 12:00 1.75 8,371 8,282 INTRM1 DRILL REAM P BROOH f/ 8371' to 8282' @ 650 gpm 2250 psi w/ 120 rpm's 12:00 15:00 3.00 8,282 7,394 INTRM1 DRILL REAM P Cont. to BROOH f/ 8282' to 7,394' MD - 650 GPM @ 2100 Psi w/ 90 RPM 15:00 16:15 1.25 7,394 7,394 INTRM1 DRILL CIRC P CBU @ 600 GPM w/ 2100 Psi & 90 RPM 16:15 00:00 7.75 7,394 4,558 INTRM1 DRILL REAM P BROOH f/ 7,394' to 4,558' MD, 600 GPM w/ 1900 Psi and 115 RPM - OWFF and Attempted to POOH @ 6,071' and 4,653' MD; Hole Pulled Tight (60 K Over Pull) - Reamed Through Spots 2/23/2011 BROOH t/ 3,170' MD - Circ Sweep around; Significant increase in Cuttings - Slip & Cut Drill Line - Circ Sweep Around; No Increase in Cuttings - Pump Out of Hole t/ 128' MD - L/D NMFDC's and Remainder of BHA #2 - Change Upper Rams U 7 5/8" Solid Body Elements and Test t/ 250/3500 Psi - R/U and Run 7 5/8" Casing t/ 434' MD (10 As and Float Equipment) Page 10 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 04:30 4.50 4,558 3,170 INTRM1 DRILL REAM P Continue to BROOH f/ 4,558' to 3,170' MD 600 GPM w/ 1900 Psi and 120 RPM - Numerous Minor Pack Offs w/ ECD Excursions as High as 11.85 PPGE - Worked Pipe Through Tight Areas - BHA Packed OFF Pulling Into Casing Shoe - Worked Hole and Regained Returns 04:30 05:15 0.75 3,170 3,170 INTRM1 DRILL CIRC P Circ Bit Balling Sweep Surface to Surface @ 600 GPM w/ 1800 Psi and 60 RPM - Sweep Returned 300% Increase in Cutting Above the Bottoms Up Cuttings Load 05:15 05:30 0.25 3,170 3,170 INTRM1 DRILL OWFF P OWFF (Static) 05:30 06:45 1.25 3,170 3,170 INTRM1 DRILL SLPC P PJSM - Cut & slip drill line 60' - Service top drive 06:45 07:15 0.50 3,170 3,170 INTRM1 DRILL CIRC P Circ hi-vis sweep - @ 600 gpm @ 1750 psi 07:15 08:00 0.75 3,170 2,699 INTRM1 DRILL TRIP P POOH on TT f/ 3170' to 2699' improper hole fill ( well swabbing) 08:00 12:30 4.50 2,699 128 INTRM1 DRILL TRIP P POOH w/ pump f/ 2699' to 128'( attempted to pull on elevators well would swab) 12:30 12:45 0.25 128 128 INTRM1 DRILL OWFF P Blow Down the Top Drive and OWFF (Static) 12:45 15:45 3.00 128 0 INTRM1 DRILL PULD P UD NMFDC's - PJSM; Remove Nuclear Sources - UD Remainder of BHA #2 15:45 16:30 0.75 0 0 INTRM1 DRILL PULD P Clean / Clear Rig Floor - Pull the Wear Bushing & Set Test Plug 16:30 18:00 1.50 0 0 INTRM1 WHDBO RURD P PJSM and Change the Top Rams to 7 5/8" Solid Body Elements 18:00 18:30 0.50 0 0 INTRM1 WHDBO BOPE P Test Upper Rams w/ 7 5/8" Test Joint t/ 250/3500 Psi 18:30 19:00 0.50 0 0 INTRM1 WHDBO RURD P Pull the Wear Bushing and Set Thin Walled Wear Ring 19:00 21:30 2.50 0 0 INTRM1 CASING RURD P PJSM & R/U to Run 7 5/8" Casing 21:30 00:00 2.50 0 434 INTRM1 CASING RNCS P Run 7 5/8' Casing U 434' MD as Follows: Float Shoe, 2 Jts Casing, Float Collar w/ Baffle Adapter on Top, 1 Jt Casing, Baffle Collar, 1 Jt Casing - Fill Pipe and Check Floats - 7 As Casing 2/24/2011 Continue to Run 7 5/8" Casing t/ 13,621' MD (320 As Total) Stopped to Circulate & Condition Mud at the Following Depths 3,222' (Jt 77), 4,645' (Jt 110), 6,350' (Jt 150), 8,034' (Jt 190), 9,755' (Jt 230), 11,469' (Jt 270) and 13,621' MD (Jt 320) 00:00 02:15 2.25 434 3,222 INTRM1 CASING RNCS P Continue to Run 7 5/8" Casing U 3,222' MD (67 Joints, 77 Total) P/U 140, S/O 130 02:15 03:45 1.50 3,222 3,222 INTRM1 CASINGCIRC P Circulating and Conditioning Mud while Staging the Rate Up to 6 BPM 300 Psi Page 11 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:45 05:15 1.50 3,222 4,645 INTRM1 CASING RNCS P Continue to Run Casing t/ 4,645' MD (110 Total) P/U 160, S/O 137 05:15 06:15 1.00 4,645 4,645 INTRM1 CASINGCIRC P Circulate and Condition Mud While Staging the Rate Up to 5 BPM @ 250 psi 06:15 08:15 2.00 4,645 6,350 INTRMI CASING RNCS P Continue to run casing f/ 4645' to 6350' (150 jts. total) PU wt. 190 SO wt. 145 08:15 09:30 1.25 6,350 6,350 INTRM1 CASINGCIRC P Circulate & Condition mud while staging the pump rate to 5 bbls/mnin 270 psi 09:30 12:00 2.50 6,350 8,034 INTRM1 CASING RNCS P Continue to run casing f/ 6350' to 8034' (190 jts total) Installed Halliburton stage collar on top of joint # 169' PU wt. 222 SO wt 152 12:00 13:45 1.75 8,034 8,034 INTRM1 CASINGCIRC P Circulate & condition mud while staging the pump rate to 6 bbls/min @ 370 psi 13:45 15:45 2.00 8,034 9,755 INTRM1 CASING RNCS P Continue to run casing f/ 8034' to 9755' (230 jts. total ) PU wt. 250 SO wt 155 15:45 17:15 1.50 9,755 9,755 INTRM1 CASINGCIRC P Circulate & Condition mud while staging pump rate to 6 bbl/min @ 420 Psi 17:15 19:45 2.50 9,755 11,469 INTRMI CASING RNCS P Continue to Run Caisng t/ 11,469' MD (270 Jts Total) P/U 280, S/O 156 19:45 21:30 1.75 11,469 11,469 INTRM1 CASINGCIRC P Circulating and Conditioning Mud while Staging the Rate Up to 6 BPM 420 Psi 21:30 00:00 2.50 11,469 13,621 INTRM1 CASING RNCS P Continue to Run Caisng t/ 13,621' MD (320 As Total) P/U 350,S/O 175 2/25/2011 Circulate and Condition Mud at Pre -Determined Circulation Point (13,620' MD) - Run Casing t/ 14,270' MD (Unable to Go Down) - Attempt to Circulate (Unable), Attempt to Go Down (Unable), Attempt to P/U (Unable; Max P/U 429 K) - Conferred w/ Anchorage and Revised P/U Limit to 520 K - Worked Pipe Free Establish Circulation @ 14,176' MD - Wait on Weather While Circulating @ 4 BPM w/ 250 Psi and Pulling/Laying Down 1 Joint Every 1.5 hrs t/ 13,408' MD 00:00 02:45 2.75 13,621 13,621 INTRM1 CASINGCIRC P Circulate and Condition Mud While Staging the Rate Up to 6 BPM @ 480 Psi 02:45 03:30 0.75 13,621 14,270 INTRM1 CASING RNCS P Continue to Run Casing t/ 14,270' MD (335 Stands Total) - Took Weight @ 14,200' MD and Able to Work Down U — 14,270' MD Page 12 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:30 07:45 4.25 14,262 14,176 INTRM1 CASING RNCS T Attempt to Establish Circulation & Wash Down (Unable) - Work Pipe With and Without Pumps (Unsuccessful) - Lay Down 1 Jt t/ 14,262' MD - Unable to L/D Second Joint, Pulled to 429K (Max) and Unable to Go Down - Continue to work pipe - Revised max. pull as per Anchorage office 520 K - worked pipe to 520 K - worked pipe free & establish circ - LD jts # 336 - 335 & 334 to 14,176' 07:45 09:30 1.75 14,176 14,176 INTRM1 CASING CIRC T Circ @ 2 bbls/min @ 440 psi - full returns - stage pump to 3 bbls/min @ 400 psi - Working pipe f/ 14,176' to 14110' 09:30 12:00 2.50 14,176 13,746 INTRM1 CASING RNCS T Pull and lay down casing f/ 14,176' to 13,746' (above HRZ) pumping @ 3 bbls/min @ 300 psi - break over wt. 375 - PU wt. 325 Due to Phase III weather conditions Decision made by Rig Superintendent to circ & work pipe waiting for weather to break before attempting to RIH 12:00 00:00 12.00 13,746 13,408 INTRM1 CASING OTHR T Wait on Phase III Weather to Clear - Circulate @ 4 BPM w/ 340 Psi - Stand Back 1 Joint of Casing Every 1.5 Hrs t/ 13,408' MD 2/26/2011 Continue to Wait on Weather while Circulating and Conditioning Mud; Laying Down 1 Jt Every 2 Hours to 13,237' MD - RIH t/ 14,132' MD - Wash Casing Down t/ 14,186' MD; Tagged Obstruction - Confer w/ Drilling Superintendent - POOH w/ Pumps and L/D Casing t/ 11,469' MD (63 of 333 Jts Pulled) 00:00 12:00 12.00 13,408 13,452 INTRM1 CASING OTHR T Wait on Phase III Weather to Clear - Circulate @ 4 BPM w/ 340 Psi - Lay down 1 Joint of Casing Every 2 Hrs to 13,277- - Ran jts. back in hole f/ 13,277' to 13,452' 12:00 12:15 0.25 13,452 13,452 INTRM1 CASING SFTY P PJSM on running casing 12:15 13:45 1.50 13,452 14,186 INTRM1 CASING RNCS P RIH w/ 7 5/8" casing f/ 13,452' to 14,132' - Washed down f/ 14,132' to 14,186' (67' f/ base of HRZ) @ 3.5 bbls/min @ 360 psi - SO wt. 175 - Taking wt - 45 k down & packing off - unable to wash through Notified Rig Superintendent - discision made to pull & LD casing & make clean out run 13:45 00:00 10.25 14,186 11,469 INTRM1 CASING PULL T Pump Out of the Hole and L/D 7 5/8" Casing f/ 14,186' to 11,469' MD (63 of 333 Jts) - 3 BPM @ 300 Psi Page 13 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 2/27/2011 24 hr Summary Continue to L/D 7 5/8" Casing f/ 11,469' to 10,606' MD (250 Jts Remaining); Improper Hole Fill - OWFF (Static in 6 Minutes) - CBU - OWFF (Static in 12 Minutes) - Continue to Pump Out t/ 8,847' MD (210 As Remaining); Improper Hole Fill - CBU - OWFF (Static in 15 Minutes) - Continue to Pump Out t/ 7,133' MD (169 As Remaining); Improper Hole Fill - UD HES Stage Collar - CBU, No Gas During Circulation 00:00 04:15 4.25 11,469 10,606 INTRM1 CASING TRIP T Continue to Pump Out of the Hole Laying Down 7 5/8" Casing U 10,606' MD (Pulled 83 of 333 Jts) - 3 BPM @ 290 Psi - Hole Fill Incorrect 04:15 04:30 0.25 10,606 10,606 INTRM1 CASING OWFF T OWFF (Static in 6 Minutes) 04:30 05:45 1.25 10,606 10,606 INTRM1 CASING CIRC T CBU Staging Pumps Up t/ 6 BPM @ 370 Psi - No Gas Observed at Bottoms U 05:45 06:00 0.25 10,606 10,606 INTRM1 CASING OWFF T OWFF (Static in 12 mins.) 06:00 13:15 7.25 10,606 8,847 INTRM1 CASING TRIP T Continue to pump out of hole laying down 7 5/8" casing f/ 10,606' to 8847' (Pulled 123 of 333 jts) pumping @ 3 bbls/min @ 200 psi - PU wt 220 SO wt 155 - Improper hole fill 13:15 14:45 1.50 8,847 8,847 INTRM1 CASING CIRC T Circ btms up while staging pump up to 6 bbls /min. @ 310 psi - Flow ck well static in 15 mins. 14:45 21:30 6.75 8,847 7,133 INTRM1 CASING TRIP T Continue to pump out of hole laying down 7 5/8" casing f/ 8847' to 7,133' MD (Pulled 163 of 333 Jts) - 4 BPM 200 Psi - Improper Hole Fill 21:30 22:15 0.75 7,133 7,133 INTRM1 CASING OWFF T OWFF (Decreasing to Static in 20 Minutes) - PJSM - Heat and UD HES Stage Collar on Bottom of Jt 170 22:15 00:00 1.75 7,133 7,133 INTRM1 CASING CIRC T CBU @ 6 BPM w/ 270 Psi - No Gas @ Bottoms Up 2/28/2011 Continue to Pump Out of the Hole While UD Casing f/ 7,133' to 5,890' MD (139 As Remaining); Improper Hole Fill - OWFF (Static in 15 Minutes) - Continue to Pump Out of the Hole While UD Casing f/ 5,890' to 3,221' MD (77 Jts Remaining) - Pumped Bit Balling Sweep (Minimal Increase in Returns) - OWFF (Static in 10 Minutes) - Continue to Pump Out of the Hole While UD Casing U 848' MD (20 As Remaining) 00:00 05:00 5.00 7,133 5,890 INTRM1 CASINGTRIP T OWFF - Continue to UD Caisng f/ 7,133'to 5,890' MD (Pulled 194 of 333 Jts) - Hole Fill Incorrect 05:00 05:30 0.50 5,890 5,890 INTRM1 CASING OWFF T OWFF - Well static in 16 mins. 05:30 12:00 6.50 5,890 4,213 INTRM1 CASING TRIP T Continue pumping out & laying down 7 5/8" casing f/ 5890' to 4213' (pulled & laid down 233 of 333 jts) 4 bbls/min @ 150 psi - PU wt. 150 SO wt. 138 12:00 14:30 2.50 4,213 3,221 INTRM1 CASING TRIP T Continue pumping out & laying down 7 5/8" casing f/ 4213' to 3221' (256 jts laid down of 333 ) 14:30 17:30 3.00 3,221 3,221 INTRM1 CASING CIRC T Circ btms up @ 3221' - staging pump up to 8 bbls/min - Pumped bit balling sweep & circ out of hole - sweep brought little clay back. - Pulled up 20' w/ no pump - well swabbing - Flow ck well static in 10 mins. Page 14 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 00:00 6.50 3,221 848 INTRM1 CASING TRIP T Continue to L/D Casing t/ 848' MD (Pulled 313 of 333 Joints) 3/01 /2011 Continue to Pump Out of the Hole While UD Casing f/ 848' to 220' MD (5 Jts Remaining) - OWFF (Static) - UD Remaining Jts of Casing & Float Equipment - Clean/Clear the Rig Floor - Change Upper Rams t/ 3.5" X 6" VBR's - Test BOPE; Witness Waived by AOGCC Chuck Scheve - P/U BHA #3 to 227' MD - Slip & Cut Drill Line 00:00 02:30 2.50 848 220 INTRM1 CASING TRIP T Continue to Pump Out of the Hole While UD Casing f/ 848' to 220' MD (5 Jts Remaining) 02:30 02:45 0.25 220 220 INTRM1 CASINGOWFF T Monitor well (Static) 02:45 04:30 1.75 220 0 INTRM1 CASING PULD T Close Casing Rams - Heat Baker Locked Jts to 400° F and UD Remaining Casing Joints 04:30 08:00 3.50 0 0 INTRM1 CASING RURD T Blow Down the Top Drive - Clean and UD Casing Running Equipment - Clean & Clear the Rig Floor 08:00 08:15 0.25 0 0 INTRM1 WHDBO SFTY P PJSM on Changin Top Rams 08:15 10:30 2.25 0 0 INTRM1 WHDBO OTHR P Drain Stack - Change Top Rams f/ 7 5/8' Solid Body to 3 1/2" by 6" Variable Rams - Grease IBOP 10:30 12:00 1.50 0 0 INTRM1 WHDBO RURD P Pull Thin Walled Wear Ring - Set Test Plug - Fill Lines w/ Water for BOPE Test 12:00 16:30 4.50 0 0 INTRM1 WHDBO BOPE P Test BOPE as Follows: w/ 5" Test Jt, Test Annular Preventer t/ 250/2500 Psi, Test Blinds, Upper & Lower Rams, Choke Manifold Valves 1-16, Auto & Manual IBOP, TIW, Dart, HCR/Manual Choke and Kill Valves t/ 250/3500 Psi, Perform Accumulator Test, Function Rams f/ the Remote Panel - AOGCC Inspector Chuck Scheve Waived Witnessing the Test 16:30 18:00 1.50 0 0 INTRM1 DRILL RURD T R/U to Handle BHA #3 18:00 21:15 3.25 0 227 INTRM1 DRILL PULD T P/U BHA #3 as Follows: Bit Bit Sub w/ Float, XO, IBS, PWD, HCIM, DM, Pulser, 1 Std NMFDC's, 1 Std HWDP t/ 227' MD - Upload and Shallow Test MWD 21:15 23:30 2.25 227 227 INTRM1 RIGMNT SLPC P Slip & Cut Drill Line While T/S Electrical Problem 23:30 00:00 0.50 227 261 INTRM1 DRILL PULD T Continue to P/U BHA #3 U 261' MD 3/02/2011 Continue to RIH t/ 13,452' MD Stopping to Circulate and Condition @ 3,519', 6,356', 8,719', 11,083' and 13,452' MD - Circ and Condition Mud - Wash & Ream f/ 13,542' to 13,816' MD - Packed Off @ 13,670' MD (Worked Free), Reamed Hole Working "Tight" Spots f/ 13,743' to 13,749' MD - Drill String Packed Off @ 13,816' MD - Pulled t/ 13,746' and Regained Circulation - Pulled t/ 13,542' MD w/ Circulation - Condition Mud - OWFF (Static) - POOH on TT t/ 13,074' MD 00:00 02:30 2.50 261 3,519 INTRM1 DRILL TRIP T Continue to RIH w/ BHA #3 to Planned Circulation Point of 3,519' MD (Stand 30) Page 15 of 23 C,to pgA- Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02.30 03:15 0.75 3,519 3,519 INTRM1 DRILL CIRC T Stage Pumps Up U 750 GPM @ 2100 Psi w/ 60 RPM; Reduced Pump Rate to 675 GPM @ 1700 Psi Due to Trough Overflowing - Blow Down Top Drive - Began Processing Mud w/ Solids Control Van (From Pit 3 Discharge Into Pit 4) @'/2 BPM Continuously Cuttings Over Shakers Mostly Fine Clays 03:15 05:15 2.00 3,519 6,356 INTRM1 DRILL TRIP T Continue to RIH w/ BHA #3 to Planned Circulation Point of 6,356' MD (Stand 60) 05:15 06:15 1.00 6,356 6,356 INTRM1 CASING CIRC T Stage Pumps Up t/ 750 GPM @ 2400 Psi w/ 120 RPM 9500 ft/lbs Tq. ECD 10.85 ppg Fine Clay Cuttings On Bottoms Up 06:15 08:15 2.00 6,356 8,719 INTRM1 CASINGTRIP T RIH from 6,356' to 8,719' PUW 177K SOW 132K 08:15 09:45 1.50 8,719 8,719 INTRM1 CASING CIRC T Stage Pumps Up t/ 750 GPM @ 2740 Psi w/ 120 RPM 11,500 ft/lbs Tq. ECD 10.78 ppg Small amount of Fine Cuttings throughout circulation 09:45 12:00 2.25 8,719 11,083 INTRM1 CASINGTRIP T RIH f/ 8,719'to 11,083' MD P/U 215, S/O 150 12:00 13:00 1.00 11,083 11,083 INTRM1 CASINGCIRC T Circulate and Condition Mud - Staging the Rate Up to 750 GPM @ 2800 Psi Fine Clay Cuttings Throughout Circulation 13:00 15:00 2.00 11,083 13,452 INTRM1 CASINGTRIP T Continue to RIH f/ 11,083' to 13,452' MD P/U 265, S/O 170 15:00 17:15 2.25 13,452 13,452 INTRM1 CASING CIRC T Circulate and Condition Mud Staging Pumps up to 750 GPM@ 2920 Psi - Complete Mud Dilution and Process Returns Through the Solids Control Van Page 16 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:15 21:00 3.75 13,452 13,542 INTRMI CASING REAM T Wash & Ream f/ 13,542' to 13,816' MD; Packed Off @ 13,670' MD (Worked Free), Reamed Hole Working "Tight" Spots f/ 13,743' to 13,749' MD - Drill String Packed Off @ 13,816' MD, Rotary Stalled and Appeared to be Stuck, Worked Pipe as Deep as 13,828' MD - Pulled 80-100K Over Up Weight - Able to Work Pipe Free W/ Straight Pull @ 80-100K Over P/U - Regained Circulation @ 13,756' MD - Attempted Pulling w/ Rotary, Packed Off Again, Pulled t/ 13,746' and Regained Circulation - Pulled t/ 13,542' MD w/ Circulation 21:00 23:00 2.00 13,542 13,542 INTRM1 CASING CIRC T Circulate and Condition Mud @ 750 GPM w/ 2750 Psi - 120 RPM 23:00 00:00 1.00 13,542 13,074 INTRM1 CASINGTRIP T POOH on TT U 13,074' MD 3/03/2011 Continue to POOH U 6,061' MD - OWFF (Static) - Ream Through Tight Spot t/ 5,977' MD - POOH t/ 3,424' MD - Circ and Condition Mud While Standing Back t/ 3,235' MD - POOH w/ Pumps t/ 1,724' MD - OWFF (Static) - POOH U 690' MD - UD or S/B BHA #3 Components - R/U and P/U 3'/2" EUE Cement Stinger (913') - RIH on 5" DP t/ 7,528' MD 00:00 02:45 2.75 13,074 10,611 INTRM1 CASINGTRIP T Continue to POOH t/ 10,61 VIVID P/U 220, S/O 153 02:45 03:15 0.50 10,611 10,611 INTRM1 CASING CIRC T OWFF (Static) - Pump 20 Bbl, 10.7 PPG Dry Job 03:15 07:15 4.00 10,611 6,061 INTRM1 CASINGTRIP T POOH on TT t/ 6,061' MD - Tight Hole P/U 165, S/O 135 07:15 07:30 0.25 6,061 6,061 INTRM1 CASING OWFF T OWFF (Static) 07:30 08:30 1.00 6,061 5,977 INTRMI CASING REAM T Ream Tight Spot f/ 6,061' to 5,977' MD - 120 RPM w/ 500 GPM @ 1080 Psi 08:30 11:00 2.50 5,977 3,424 INTRM1 CASINGTRIP T POOH on TT t/ 3,424' MD; Worked Through Tight Spots @ 4,484' and 4,389' MD P/U 135, S/O 120 11:00 12:00 1.00 3,424 3,235 INTRM1 CASING CIRC T Circ and Condition Mud While Standing 2 Back to 3,235' MD - 750 GPM@ 1870 Psi w/ 120 RPM 12:00 12:15 0.25 3,235 3,046 INTRM1 CASINGTRIP T POOH on TT t/ 3,046' MD, Hole Fill Incorrect 12:15 14:15 2.00 3,046 1,724 INTRM1 CASING TRIP T Pump Out of the Hole t/ 1,724' MD; 3 BPM @ 120 Psi - OWFF (Static) 14:15 16:00 1.75 1,724 690 INTRM1 CASINGTRIP T POOH on TTt/690' MD 16:00 17:00 1.00 690 0 INTRM1 CASING PULD T S/B and UD BHA #3 Components DD/MWD 17:00 18:00 1.00 0 0 INTRM1 CASING OTHR —per T Clean and Clear the Rig Floor 18:00 18:30 0.50 0 0 INTRM1 CEMEN' RURD T R/U to Handle Cement Stinger Page 17 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:30 19:45 1.25 0 913 INTRM1 CEMEN' PUTB T P/U 3 1/2" EUE Tubing t/ 913' MD 19:45 00:00 4.25 913 7,528 INTRM1 CEMEN"TRIP T M/U 3 1/2 EUE to 4" XT 39 and 4" XT 39 to 4 1/2 IF Crossovers and RIH w/ Cement Stinger on 5" DP t/ 7,528' MD 3/04/2011 Continue to RIH w/ Cement String on 5" DP t/ 13,60T MD - Circ and Condition Mud - Set Lower Abandonment Plug w/ 15.8 PPG Class G Cement f/ 13,607' to 13,20T MD - POOH t/ 12,756' MD - Circulate Pipe Clean - POOH t/ 7,933' MD - Spot 30 Bbl Hi-Vis Pill t/ 7,744' MD - Begin Pumping Cement (Wrong Silo) - Circ Cement f/ Hole - Set Second Isolation Plug w/ 15.8 PPG Class G Cement f/ 7,744'- 7,344' MD - POOH t/ 6,862' MD - Circ Pipe Clean - S/B 11 Stands and UD 5" DP t/ 913' MD 00:00 02:45 2.75 7,528 13,607 INTRM1 CEMEN-TRIP T Continue to RIH w/ Cement String on 5" DP U 13,607' MD (134 Stds and Sin le) 02:45 03:00 0.25 13,607 13,607 INTRM1 CEMEN-OWFF T OWFF 03:00 04:45 1.75 13,607 13,607 INTRM1 CEMEN' CIRC T Circ and Condition Mud Prior to Cementing; Stage Pumps Up U 12 BPM @ @ 1170 Psi 04:45 05:00 0.25 13,607 13,607 INTRM1 CEMEN' SFTY T PJSM on Lower Abandonment Plug - Blow Down the Top Drive 05:00 05:45 0.75 13,607 13,607 INTRM1 CEMEN- PLUG T Pump Lower Abandonment Plug as Follows: Pump 2 Bbls H2O and Pressrue Test Lines t/ 3000 Psi , Pump 20 Bbls 11.5 PPG Mud Push II, 53 Bbls of 15.8 PPG Glass G Cement, 3.3 Bbls 11.5 PPG Mud Push II 05:45 06:15 0.50 13,607 13,607 INTRM1 CEMEN' DISP T Displace Cement w/ 217 Bbls 10.2 PPG Mud - CIP 0615 - Est TOC 13,20T MD - ICP 1120 Psi @ 10 BPM; FCP 1420 Psi @ 10 BPM - 68 Bbl Pit Gain for Cement & Displacement 06:15 07:15 1.00 13,607 12,756 INTRM1 CEMEN'TRIP T Pull Out of Cement Plug t/ 12,756' MD @ 20 FPM 07:15 07:45 0.50 12,756 12,756 INTRM1 CEMEN'CIRC T Drop Drill Pipe wiper Ball and Circulate Pipe Clean @ 10 BPM w/ 810 Psi & 20 RPM 07:45 11:15 3.50 12,756 7,933 INTRM1 CEMEN' TRIP T POOH on TT t/ 7,933' MD 11:15 11:45 0.50 7,933 7,933 INTRM1 CEMEN-CIRC T Spot 30 Bbls High Vis Pill f/ 7,933' - 7,744' MD 11:45 12:00 0.25 7,933 7,744 INTRM1 CEMEN-TRIP T POOH t/ 7,744' MD 12:00 12:15 0.25 7,744 7,744 INTRM1 CEMEN-SFTY T PJSM on Setting Second Cement Plug 12:15 13:15 1.00 7,744 7,744 INTRM1 CEMEN' CMNT T Pump 2nd Stage Cement Plug as Follows: 2 Bbls Water, Pressure Test to 3,000 Psi, Pump 20 Bbls 11.5 PPG Mud Push, 12.6 Bbls 15.8 PPG Intermediate Cement (Wrong Silo) - Blow Down Cement Lines 13:15 15:00 1.75 7,744 7,744 INTRM1 CEMEN' CIRC T Circulate Cement Out of Hole @ 12 BPM w/ 860 Psi and 30 RPM 15:00 15:30 0.50 7,744 7,744 INTRM1 CEMEN- DISP T Displace Cement w/ 116.4 Bbls Mud @ 10 BPM; ICP 430 Psi, FCP 945 Psi Page 18 of 23 LJ Pl"p Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:30 16:00 0.50 7,744 7,744 INTRM1 CEMEN- CMNT T Pump Qannik Isolation Plug as Follows: Pump 2 Bbls Water, Pressure Test 3,000 Psi, Pump 12 Bbls 11.5 PPG Mud Push, 56.4 Bbls 15.8 PPG Cement, 3 Bbls 11.5 PPG Mud Push 16:00 17:00 1.00 7,744 6,862 INTRM1 CEMEN'TRIP T POOH t/ 6,862' MD 17:00 18:30 1.50 6,862 6,862 INTRM1 CEMEN-CIRC T Drop Drill Pipe Wiper Ball and Circulate Pipe Clean @ 10 BPM w/ 600 Psi and 30 RPM 18:30 19:15 0.75 6,862 5,821 INTRM1 CEMEN'TRIP T POOH on TT U 5,821' MD 19:15 19:30 0.25 5,821 5,821 INTRM1 CEMEN-CIRC T Pump 12 PPG 20 Bbl Dry Job 19:30 00:00 4.50 5,821 913 INTRM1 CEMEN'TRIP P UD 5" DP While Waiting On Cement U 913' MD (157 Joints Laid Down) 3/05/2011 RIH w/ 3Y2' Tubing on 5" DP t/ 6,469' MD - Wash Down f/ 6,964' to 7,445' MD (Unable to Find Firm Cement) - POOH t/ 7,338' MD - CBU - Wash and Tag Firm Cement @ 7,469' MD (67' Above Top of Qannik) Witnessed by AOGCC Insp. Lou Gimaldi; State Requested Top Off Plug w/ Additional 200' of Cement w/o Requirement to Tag - Pumped 26.9 Bbls of 15.8 PPG Class G Cement f/ 7,465' to 7,265' MD (40% Excess) - POOH t/ 6,960' MD - Load Drill Pipe Wiper and Circ String Clean - OWFF (Static) - POOH t/ 3,650' MD - Spot 30 Bbl High-Vis Pill - POOH t/ 3,431' MD - Pump KOP; 54.5 Bbls of 17 PPG Class G Cement (Est TOC 3,031' MD) - POOH t/ 2,797' MD - Load Drill Pipe Wiper and Circ Surface to Surface to Clean String - Slip and Cut 120' Drill Line- POOH t/ 913' MD - UD 3 ''/2" Tubin t/ 280' MD 00:00 03:00 3.00 913 6,964 INTRM1 CEMEN-TRIP T RIH with 3 1/2" tubing tail below 5" drill pipe from 913' to 6964' 03:00 04:45 1.75 6,964 7,445 INTRM1 CEMEN- WASH T Wash Down f/ 6,964' to 7,445' MD; 1 BPM w/ 130 Psi - Pressure Increased t/ 150-170 Psi @ 7,535' MD - Continued to Wash Down t/ 7,445' MD Unable to Find Cement but Appeared to be Washing - Pull Up to Give Cement More Time to Set (Time Since CIP 12 Hrs) 04:45 07:00 2.25 7,445 7,338 INTRM1 CEMEN' CIRC T POOH t/ 7,338' MD - Wait on Cement - CBU @ 10 BPM w/ 650 Psi 07:00 07:30 0.50 7,338 7,469 INTRM1 CEMEN' CIRC T Wash Down f/ 7,338' w/ 1 BPM / 130 Psi - located firm cement @ 7469' (67' above top of Qannik) Tag witnessed by Lou Grimaldi (AOGCC). 07:30 13:00 5.50 7,465 7,465 INTRM1 CEMEN-CIRC T Reciprocate pipe - Circulate and condition mud 6 bpm / 280 psi - Wait on Schlumberger to blend, load and transport cement and Mudpush to rig. " State Inspector requested additional 200 linear foot plug w/ no need to tag plug again - Conferred with drilling engineer and agreed to request. Page 19 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13.00 13:45 0.75 7,465 7,465 INTRM1 CEMEN- CMNT X With tubing tail @ 7465' - Line up to Dowell - pushed 2 bbls of water to fill lines - pressure test lines to 3000 psi - mixed and pumped 20 bbls of 11.5 ppg Mudpush, 26.9 bbls of 15.6 ppg G cement (130 sxs) - 3 bbls of 11.5 ppg Mudpush - switched to rig pumps and displaced to eqalization with 10.2 ppg mud - CIP @ 1343 hours - ETOC w/ 40% excess 7,269' - full returns throughout job 13:45 14:15 0.50 7,465 6,960 INTRM1 CEMEN'TRIP X RD cement line - POOH from 7465' to 6,960' - observed proper hole fill volume 14:15 14:45 0.50 6,960 6,960 INTRM1 CEMEN' CIRC X Load wiper ball into drill pipe - Circulate to clear cement from drill pipe and tubing tail @ 10 BPM w/ 580 Psi / rotate @ 30 RPM pumped 160 bbls - Had full returns while circulating - Blow down top drive - flow check well, static 14:45 17:00 2.25 6,960 3,650 INTRM1 CEMEN-TRIP X POOH from 6,960'to 3,650' 17:00 17:30 0.50 3,650 3,650 INTRM1 CEMEN' CIRC X Pump 30 Bbl High-Vis Pill & Displace w/ 55 Bbls Mud 17:30 17:45 0.25 3,650 3,431 INTRM1 CEMEN'TRIP X POOH t/ 3,431' MD 17:45 18:00 0.25 3,431 3,431 INTRM1 CEMEN-SFTY X PJSM on Pumping KOP Cement 18:00 18:45 0.75 3,431 3,431 INTRM1 CEMEN" CMNT X Pump KOP as follows: Pump 2 Bbls of Water, Pressure Test Lines t/ 3000 Psi, Pump 40 Bbls of 11.5 PPG Mud Push, 54.5 Bbls of 17 PPG Class G Cement, 4.2 Bbls of Mud Push and 1 Bbl of Water 18:45 19:15 0.50 3,431 3,431 INTRM1 CEMEN- DISP X Displace Cement w/ 41 Bbls of Mud @ 8 BPM; ICP 260 Psi FCP 610 Psi - 101 Bbl Pit gain Throughout Job (1 Bbl Loss) CIP 1915 19:15 19:45 0.50 3,431 2,797 INTRM1 CEMEN-TRIP X R/D Cement Equip and POOH t/ 2,797' MD 19:45 20:45 1.00 2,797 2,797 INTRM1 CEMEN' CIRC X Drop DP Wiper and Circulate Sfc to Sfc @ 10 BPM w/ 300 Psi and 30 RPM 20:45 22:00 1.25 2,797 2,797 INTRM1 RIGMNTSLPC P Slip and Cut 120' Drill Line 22:00 23:00 1.00 2,797 913 INTRM1 CEMEN-TRIP X POOH on TT U 913' MD 23:00 23:30 0.50 913 913 INTRM1 CEMEN- RURD X R/U to UD 3 %' EUE Cement String 23:30 00:00 0.50 913 280 INTRM1 CEMENrPULD X UD 3 %" Cement String t/ 280' MD 3/06/2011 Continue to L/D Cement String f/ 280' to 0' MD - Change Wear Ring - Run 3Y2' EUE Kill String t/ 2,177' MD (69 Jts) - RIH U 2,740' MD - WOC - Wash Down t/ 3,496' MD (Unable to Find Cement) - POOH t/ 2,177' MD - Stand Back Kill String - Change Wear Ring - P/U Clean Out BHA - RIH U 2,783' MD - Wash/Ream t/ 3,239' MD - Circulate Hole Clean - OWFF (Static) - POOH t/ 2,693' MD 00:00 00:45 0.75 280 0 INTRM1 CEMEN- PULD X Continue of L/D 3'/2" EUE Cement String f/ 280' to 0' 00:45 01:00 0.25 0 0 INTRM1 RPCOM RURD X Clear/Clean Rig Floor Page 20 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:00 01:30 0.50 0 0 INTRM1 WHDBO PULD X Change Wear Ring 01:30 03:45 2.25 0 2,177 INTRM1 RPCOM PULD X Run Kill String as Follows: WLEG, 69 Jts 3 %" EUE Tubing, XO (EUE to XT39), XO (XT to 4'/z" IF) 2,17T MD 03:45 04:00 0.25 2,177 2,177 INTRM1 RPCOM RURD X Change Elevators - R/D Tubing Ton s 04:00 04:15 0.25 2,177 2,740 INTRM1 RPCOM TRIP X RIH w/ Tubing on 5" DP t/ 2,740' MD 04:15 10:45 6.50 2,740 2,740 INTRM1 RPCOM WOC X WOC - Clean Pits and Rig, Prep for Move - Monitor Well on TT 10:45 12:15 1.50 2,740 3,496 INTRM1 RPCOM WASH X Wash Down f/ 2,740' to 3,496' MD; 2 BPM w/ 90 Psi - Unable to Find Cement 12:15 13:30 1.25 3,496 3,496 INTRM1 RPCOM CIRC XT CBU @ 10 BPM w/ 600 Psi - Treat and Condition Mud - On Bottoms Up Noted Cuttings of Gelatin Consistency Across the Shakers 13:30 14:30 1.00 3,496 2,177 INTRM1 RPCOM TRIP XT POOH t/ 2,177' MD 14:30 15:00 0.50 2,177 2,177 INTRM1 RPCOM RURD XT R/U Tubing Handling Equipment 15:00 17:00 2.00 2,177 0 INTRM1 RPCOM TRIP XT Stand Back 69 Jts of 3'/2" EUE Kill String 17:00 17:30 0.50 0 0 INTRM1 RPCOM OTHR XT Clean and Clear the Rig Floor 17:30 18:15 0.75 0 0 INTRM1 WHDBO PULD P Change Wear Ring 18:15 19:00 0.75 0 140 INTRM1 RPCOM PULD XT P/U Bit, Bit Sub, XO, IBS, 1 Std NMFDC's, Jars,U 140' MD 19:00 20:15 1.25 140 2,783 INTRM1 RPCOM TRIP XT RIH w/ BHA #4 on 5" DP t/ 2,783' MD 20:15 22:00 1.75 2,783 3,239 INTRM1 RPCOM WASH XT Wash/Ream t/ 3,239' MD @ 10 BPM w/ 500 Psi and 120 RPM 22:00 22:45 0.75 3,239 3,239 INTRM1 RPCOM CIRC XT Circ Surf to Surf @ 10 BPM w/ 480 Psi; Noted More Gelatin Like Cutting s on Bottoms U 22:45 23:00 0.25 3,239 3,239 INTRM1 RPCOM OWFF XT OWFF (Static) 23:00 00:00 1.00 3,239 2,693 INTRM1 RPCOM TRIP XT POOH on TT t/ 2,693' MD 3/07/2011 Continue to POOH t/ 140' MD - UD BHA Clean Out BHA - M/U CIBP, RIH and Set @ 3,138' MD - Disengage from CIBP and Pressure Test to 2500 Psi f/ 10 Minutes - POOH L/D Running Tool - Test BOPE w/ 3 1/2" Test Joint t/ 250/2500 Psi (Annular) and 250/3500 Psi (Rams) - P/U 3 1/2" EUE Kill String and RIH on 5" DP t/ 3,128' MD - Displace Well t/ 9.6 PPG Inhibited/Uninhibited Brine - POOH U 2,145' MD - M/U and Land Tubing Hanger w/ TWC Installed (Tail @ 2,180' MD) - Test Hanger Seals t/ 5000 Psi f/ 10 Minutes - Test TWC in Direction of Flow t/ 2500 Psi f/ 10 Minutes - N/D BOPE - N/U Tree - Test Upper Hanger Seals and Tree t/ 5000 Psi f/ 10 Minutes - Pull TWC and R/U to Freeze Protect Well. 00:00 00:45 0.75 2,693 140 INTRM1 DRILL TRIP XT Continue to POOH 2,693' to 140' MD 00:45 01:15 0.50 140 0 INTRM1 DRILL PULD XT Stand Back Drill Collars, Break Bit and UD Remaining BHA Items 01:15 02:00 0.75 0 0 INTRM1 DRILL PULD XT Remove BHA Components f/ the Floor - P/U Cement Retainer 02:00 02:30 0.50 0 0 INTRM1 DRILL PULD XT PJSM - M/U Cement Retainer and XO's; OD of Cement Retainer 9.44" 02:30 04:45 2.25 0 3,138 INTRM1 DRILL TRIP XT RIH w/ Cement Retainer on 5" DP t/ 3,138' MD (Middle of 10 3/4" A #3) - P/U 130, S/O 115 04:45 05:15 0.50 3,138 3,138 INTRM1 DRILL PLUG rXT. Set CIBP @ 3,138' MD per BOT Rep Page 21 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:15 05:45 0.50 3,138 3,128 INTRM1 DRILL PRTS XT P/U to 3,128' MD and Pressure Test CIBP and Surface Casing t/ 2500 Psi f/ 10 Minutes (Lost 0 Psi) 05:45 06:00 0.25 3,128 3,128 INTRM1 DRILL RURD XT Open Rams, R/D Pressure Testing Manifold and Blow Down Kill Line 06:00 07:45 1.75 3,128 0 INTRM1 DRILL TRIP XT POOH - Lay down running tool - clean up rig floor 07:45 08:15 0.50 0 0 INTRM1 DRILL OTHR X Pull wear ring and set test plug with 3 1/2" test joint 08:15 09:30 1.25 0 0 INTRM1 WHDBO BOPE X Test annular preventor to 250 / 2500 psi - test top pipe rams to 250 / 3500 psi - pull test plug and set retrievable wear bushing 09:30 10:00 0.50 0 0 INTRM1 RPCOM RURD XT PJSM - change running tools to 3 1/2" - RU tubing tongs 10:00 11:30 1.50 0 2,142 INTRM1 RPCOM TRIP XT RIH with 3 1/2", 9.2#, L-80 tubing to 2142' 11:30 12:00 0.50 2,142 2,142 INTRM1 RPCOM OTHR X RD tubing tongs - change running tools to 5" 12:00 12:30 0.50 2,142 3,128 INTRM1 RPCOM TRIP X RIH with 5" drill pipe from 2142' to 3128' 12:30 12:45 0.25 3,128 3,128 INTRM1 RPCOM SFTY X PJSM on displacing well to brine 12:45 15:00 2.25 3,128 3,128 INTRM1 RPCOM CIRC X Displaced well with 150 bbls of fresh water, 150 bbls of 9.6 ppg Nacl brine, 150 bbls of 9.6 ppg Nacl brine with corrosion inhibitor - 20 bbls of 10 ppg nacl brine - hole cleaned up well. 15:00 15:30 0.50 3,128 2,145 INTRM1 RPCOM TRIP X POOH to 2145' 15:30 16:00 0.50 2,145 2,154 INTRM1 RPCOM RURD X R/U Tubing Handling Equipent - Pull Wear Ring 16:00 17:00 1.00 2,154 2,180 INTRM1 RPCOM HOSO X M/U Tubing Hanger w/ TWC Installed - Land w/ Tail @ 2,180' MD 17:00 18:00 1.00 2,180 2,180 INTRM1 WHDBO PRTS X Test Hanger Seals t/ 5000 Psi f/ 10 Minutes 18:00 18:30 0.50 2,180 2,180 INTRM1 WHDBO PRTS X R/U Hard Lines and Test TWC in Direction of Flow t/ 2500 Psi f/ 10 Minutes 18:30 19:00 0.50 2,180 0 INTRM1 WHDBO RURD X R/D Hard Lines and L/D Landing Joint B 19:00 22:00 3.00 0 0 INTRM1 WHDBO NUND X N/D Riser and BOPE Stack 22:00 23:00 1.00 0 0 INTRM1 WHDBO NUND X N/U Tree 23:00 23:30 0.50 0 0 INTRM1 WHDBO PRTS X Test Hanger Top Seals t/ 5,000 Psi f/ 10 Minutes - Test Tree U 5000 Psi f/ 10 Minutes 23:30 00:00 0.50 0 0 INTRM1 DRILL RURD X Pull TWC - R/U Hard Lines and Manifold to Freeze Protect 3/08/2011 LDDC's. Install BPV. Secure well for move off to next well. Release rig at 06:00 hrs. 00:00 00:45 0.75 0 0 INTRM1 DRILL RURD X Continue to R/U to Freeze Protect Well 00:45 01:00 0.25 0 0 INTRM1 DRILL SFTY X PJSM on Freeze Protect 01:00 03:00 2.00 0 0 INTRM1 DRILL FRZP X Freeze Protect Well w/ 155 Bbls Diesel - Allow to U-Tube Across Manifold Page 22 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 04:00 1.00 0 0 INTRM1 DRILL RURD X Blow Down and Rig Down Hard Lines and Manifold - Clean Cellar & Pits 04:00 04:30 0.50 0 0 INTRM1 WHDBO OTHR X Set BPV w/ FMC Lubricator 04:30 05:00 0.50 0 0 INTRM1 DRILL PULD X Install Mouse Hole - L/D Drill Collars. 05:00 06:00 1.00 0 0 INTRM1 DRILL RURD X Secure well. Pump out cellar. Release rig for move to CD3-125. Page 23 of 23 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ��II DATE: March 05, 2011 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Plug Tag Petroleum Inspector CPAI CRU CD3-127 Colville River Unit PTD 2110050 Saturday, March 5, 2011: 1 witnessed the tag of the cement plug covering the Qannik formation in well CRU CD3-127. This test came up unexpectedly as CPAI decided to plug back this well over the weekend. I received most of the formation information from Dave Burley, CPAI company rep. The Qannik top was reported as 7543 ft MD (RKB). The rig ran in and started taking weight at 7440 ft but was able to wash down to 7468 ft where it appeared to be solid. 8- 1 OK was set down while pumping at approximately 4 bbls/minute. This was 25 ft shy of the required 100 ft above top of formation. The plug that was there was very hard and agreed if they placed another 200 ft of cement that would be more than enough. I waived a tag requirement if the cement job went off without losses. I asked Dave Burley to send me the pumping details after the job was completed. The following is the text of the e-mail I received from Mr. Burley. Attachments: 3/5/11 email from CPAI Non -Confidential WA Plug CRU CD3-127 lg 3-5-11 1 of 2 t N 3/5/11 Well CD3-127 (PTD 2110050) Doyon 19 Operations Lou, Per your request: With tubing tail @ 7465' - Line up to Dowell - pushed 2 bbls of water to fill lines - pressure test lines to 3000 psi - mixed and pumped 20 bbls of 11.5 ppg Mudpush, 26.9 bbls of 15.6 ppg G cement (130 sxs) - 3 bbls of 11.5 ppg Mudpush - switched to rig pumps and displaced to eqalization with 10.2 ppg mud - CIP @ 1343 hours - ETOC w/ 40% excess 7,269' - full returns throughout job RD cement line - POOH from 7465' to 6,960' - observed proper hole fill volume Load wiper ball into drill pipe - Circulate to clear cement from drill pipe and tubing tail @ 10 BPM w/ 580 Psi / rotate @ 30 RPM pumped 160 bbls - Had full returns while circulating - Blow down top drive - flow check well, static If you have any questions or need other information please let me know. Thank you David Burley Plug CRU CD3-127 lg 3-5-11 2 of 2 HALLIBURTON 1 P�11y Dlillilg WELL LOG TRANSMITTAL To: State of Alaska March 15, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-127 P131 AK-MW-0007896020 CD3-127 PB1 50-103-20634-70 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 2" x 5" MD BAT SONIC Logs: 1 Color Log 2" x 5" TVD BAT SONIC 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 Bryan-8 I ib rit com Date: Signed: I/l IVVs- ���/V ME OF ALASKA SEAN PARNELL, GOVERNOR AI.ASSA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Nina Anderson Alpine Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-127 Sundry Number: 311-065 Dear Mr. Anderson: 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 7 day of March, 2011. Encl. IL ConocoPhillips Alaska, Inc. Post Office Box 100360 ConocoPhillips Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 4, 2011 Alaska Oil and Gas Conservation Commission RECEIVED) 333 West 7t" Avenue, Suite 100 MAR 0 �019 Anchorage, Alaska 99501 Re: Sundry Permit: CD3-127 Operational Shutdown (PTD: 211-005) 44A$k8 Oil & Go$ COOS. C n �n�orage Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to shutdown the operations with the currently approved plan for well CD3-127 (PTD: 211-005). Doyon 19 moved onto CD3-127 on February 11th, 2011 with the goal of drilling a 6-3/4" horizontal well to produce the Nechelik reservoir. The surface hole was drilled and cased to the planned depth. After drilling the 9-7/8" intermediate hole to 15,261' MD, the 7-5/8" casing was run to a depth of 13,816' MD at which point it became stuck. The casing was pulled free and subsequent attempts to wash down the casing further were unsuccessful. The decision was made to pull the casing and run a cleanout BHA. Due to HRZ instability, the cleanout BHA was unable to reach TD. The intermediate hole appears to have collapsed around 13,816' MD which is approximately 146' MD into the HRZ shale. The decision was made to pull out of hole and plug back with cement. The new plan is to isolate CD3-127 with three cement plugs: Lower plug to isolate the Nechelik/Kuparuk reservoirs, a balanced plug across the Qannik interval, and an abandonment/kick off plug across the surface casing shoe. A 3.5" kill string will be run to 1900' MD and landed in the tubing hanger. Diesel freeze protect will be circulated from 1900' and the well secured with a BPV. CD3-127 will be completed in the 2012 winter drillina Drcnram at CD3. �/ a G�c<i�iaftCs� ire S-t /�`S" 2016 7" 7n" Upon isolaloNthe oygirrSf well will maintain API:f18-6399=70 and nameid CD3- 127PB1. The -new well w'll become CD3-127 (API: 50-103-2063q-00.-o4'* if Please find attached: 5: ■ Form 10-403 Application ■ Plan forward ■ Proposed final well schematic If you have any questions or require further information, please contact Nina Anderson 265-6403 or Liz Galiunas at 265-6247. Sincerely, /Vtldk Nina Ande s Drilling Engineer Attachments CC: CD3-127 Well File Liz Galiunas Chip Alvord STATE OFALASKA ALASKA _ AND GAS CONSERVATION COMMISSIL APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program Suspend Rug Perforations Perforate r Pull Tubing r Time Extension r Operational Shutdow n F ' Re-enter Susp. Well Stimulate [- Alter casing _i Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli sAlaska, Inc. p Development p r Exploratory 17 Stratigraphic r Service 17 211005 3. Address: 6. API >" P. O. Box 100360, Anchorage, Alaska 99510 50 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: } 7 where ownership or landownership changes: Spacing Exception Required? Yes [7 No r%�- CD3-127 9. Property Designation (Lease Number): ' 10. Field/Pool(s): r/t-,; �k'2>-7 ADL 372105, 025538,025526 Colville River Field / Alpii e 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): 0 0 Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 3202' 10.75" 3239' 2453' 3580 psi p 2480 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 0 0 0 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) 12. Attachments: Description Summary of Proposal rv— 13. Well Class after proposed work: Detailed Operatio s Program r BOP Sketch r! Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status afte proposed work: 1/15/2012, CD3 Ice road opening Oil ih� Gas r WDSPL Suspended n 16. Verbal Approval: Date: 03/03/2011 WAG WINJ [- ��'� GIi J�` ri Abandoned r Commission Representative: Guy Schwartz j s �� ��� � "� c3,vt GSTOR r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina Anderson Printed Name ina Anderson Title: Alpine Drilling Engineer Signature 4A4�Phone:?b -6 y03 Date 3 -V-20/1 Commission Use Only Sundry Number I �C06 Conditions of approval: Notify Commission so that a representative may witness ,,,//JJ RECEIVE[: Plug Integrity BOP Test ,j Mechanicalal Integrity/T-est r Location Clearance n Other: 1 Yo4- % IhJ1°e-�r To w ThG'S5 4S ;hd i GA Ar-4 LIAR 0 4 2011 �.L r Aluka Oil$ Gas CywL wwi Subsequent Form Required: `�Uy /D - Anchorage /l APPROVED BY Approved by: f✓ O THE COMMISSION Date: / it Sim Form 10-403R� 0 ►R 9 ��� t / • y !/ Submit in C1'u I' ate oW 11eli Proposed Plan 1. Pull out of hole with clean out BHA. 2. Pick up cement stinger and run in hole to +/- 13,600' MD and set 15.8 ppg Class G plug to 13,200' MD (400' plug). 3. Circulate above plug and pull stinger up to the Qannik interval and set hi viscosity gel pill. 4. Rig up and pump 15.8 ppg balanced plug to isolate the Qannik from 7,750' MD to 7,350' MD. 5. Circulate above plug and pull stinger up into the surface shoe and wait on cement. 6. RIH and tag cement plug. Contact state to witness. 7. Pull stinger to — 200' below surface shoe and set hi viscosity gel pill. 8. Rig up and pump densified 17.0 ppg balance plug for kick off from 3439' MD in the 9-7/8" open hole to 3039' MD. (200' inside 10-3/4" surface casing). 9. Displace plug with 9.6 ppg inhibited brine. 10. Circulate above plug and wait on cement. , 11. RIH to tag and pressure test to 2500 psi for 30 minutes. Chart and record test. 12. Pull out of hole and lay down cement stinger. 13. RIH with 3-1/2" kill string to 1900' MD. 14. Make up tubing hanger and land in wellhead. 15. Test Hanger seals to 5000 psi. . 16. ND BOPE, NU Tree and test to 5000 psi. 17. Displace upper wellbore to diesel. 18. Install BPV. RDMO Doyon 19. f Li T st CD3-127 Operational Shutdown Schematic RKB - GL = 36.3' 3/4/2011 Wellhead 16" Conductor to 114' 1900' 3-'/z" Tbg Kill String 9.6 ppg Inhibited Brine with 1900' Diesel 10-3/4" 40 ppf L-80 BTCM FP Surface Casing Top of Plug (200' in casing) 3,239' MD / 2,453' TVD 3,039' MDCemented to Surface 11M Btm of Plug (200' below casing) 3,439' MD 30 bbls hi vis ,kN� ys I4W` Top Qannik 7,536' MD / 4017' TVD Top HRZ 13,750' MD / 6422' TVD Packed off at 13,670' MD Unable to recover hole past 13,816' MD due to shale stability/hole collapse. Top Kuparuk C 14,622' MD Top Nechelik 15,172' MD / 6918' TVD 30 bbls hi vis 10.2 ppg mud in hole Top of Plug 7350' M D Btm of Plug (100' Below Pay) 7750' MD Top of Plug #1 13,200' MD Bottom of Plug #1 13,600' MD 9-7/8" Intermediate Hole TD of hole at +/- 15,261' MD / 6,978' TVD Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, March 07, 2011 8:23 AM To: 'Anderson, Nina M' Subject: RE: CD3-127 Operational Shutdown (211-005) Nina, As we discussed on the phone this is acceptable as a barrier for the operational shutdown. Sorry I didn't respond earlier, I didn't see your email till this morning. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Sunday, March 06, 2011 4:38 PM To: Schwartz, Guy L (DOA) Cc: 'nwoods@mac.com' Subject: CD3-127 Operational Shutdown (211-005) Guy - To temporarily suspend CD3-127, ConocoPhilips would like to propose setting a plug or cement retainer in the surface casing about 100' up from the shoe. This plug will be tested to 2500 psi and the test will be charted. It is the intention of Conocophillips to return to CD3-127 during the next winter drilling season at CD3. At that time, the retainer will be drilled out and a new cement kick off plug will be set. Please let me know if you have any concerns. Thanks Nina Anderson Alpine Drilling Engineer 907-229-4008 3/7/2011 CD3-127 Operational Shutdown Schematic RKB-GL=36.3' 10-3/4" 40 ppf L-80 BTCM Surface Casing 3,239' MD / 2,453' TVD Cemented to Surface Top Qannik 7.536' MD / 4017' TVD Base Qannik 7.808' MD / 4117' TVD Top Nanua, Albian 96 12,349' MD / 5750' TVD Packed off at 13,670' MD Unable to recover hole past 13,816' MD due to shale stability/hole collapse. Top Kuparuk C 14,622' MD Top Nuiasut 14.642' MD Top Nechelik 15.172' MD / 6918' TVD 10.2 ppg mud in hole 30 bbls hi vis 30 bbls hi vis 3/3/2011 Wellhead 16" Conductor to 114' Top of Plug (200' in casing) 3,039' MD Btm of Plug (200' below casing) 3,439' MD Top of Plug 7350' MD Btm of Plug (100' Below Pay) 7750' MD Top of Plug #1 13,200' MD Bottom of Plug #1 13,600' MD 9-7/8" Intermediate Hole TD of hole at +/- 15,261' MD / 6.978' TVD PT D Page 1 of 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, March 04, 2011 8:38 AM To: DOA AOGCC Prudhoe Bay Cc: Regg, James B (DOA) Subject: FW: CD3-127 Operational Shutdown ?Ta 211-0oS Lou, Here is the verbal email I gave to CPAI last night. ( after talking to Commissioner Norman) . As we discussed last night during our phone conversation my thought process for not witnessing tagging the bottom plug was that it already had base with the collapsed hole section at 13800' md. ( The Kuparuk C and N--UiV- are considered one pool so zone islation is not needed for the two oil horizons) . I thought it more important that we tag the Qannik zone which did not have a base to build from. I agree with you too on the p request for the pumping schedule / returns details from any plug setting operation , especially if we don't think we 7 4 can get there for a witness. Very good idea and I will put that into action on any future plug requests from the 1.1.11 slope operators. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Thursday, March 03, 2011 7:34 PM To: Anderson, Nina M Cc: Regg, James B (DOA) Subject: Re: CD3-127 Operational Shutdown Nina, You have verbal approval to proceed with the plugging operat'%n as outlined below( deleting steps 12 & 13). Please submit a 403 sundry as soon as possible. A follow up 10 -404 will be required also reporting well operations up to and including the Operational Shutdown. Sent from my Whone On Mar 3, 2011, at 6:16 PM, "Anderson, Nina M" <Nina.Anderson@conocophilips. com> wrote: Guy — Please disregard steps 12 — 13 in the previous email. This will not be a sidetrack operation. Nina Anderson Drilling Engineer Alpine Drilling Team 3/4/2011 Page 2 of 4 Office: (907)-265-6403 Cell: (907) 229-4008 From: Anderson, Nina M Sent: Thursday, March 03, 2011 5:59 PM To: Anderson, Nina M; 'Schwartz, Guy L (DOA)' Cc: Winfree, Michael Alex (Jr.); Chambers, Mark A; Galiunas, Elizabeth C Subject: RE: CD3-127 Operational Shutdown Guy — The following is the procedure per our discussion: 1. Pull out of hole with clean out BHA (Currently laying down BHA at surface Thursday March 3rd). 2. Pick up cement stinger and run in hole to +/- 13,600' MD and set 15.8 ppg Class G balanced plug to 13,200' MD (400' plug). 3. Circulate above plug and pull stinger up to the Qannik interval and set hi viscosity gel pill. 4. Rig up and pump 15.8 ppg balanced plug to isolate the Qannik from 7,750' MD to 7,350' MD. 5. Circulate above plug and pull stinger up into the surface shoe and wait on cement. 6. RIH and tag cement plug. Contact state to witness. 7. Pull stinger to — 200' below surface shoe and set hi viscosity gel pill. 8. Rig up and pump densified 17.0 ppg balance plug for kick off from 3439' MD to 3039' MD. 9. Circulate above plug and wait on cement. 10. RIH to tag and pressure test. 11. Pull out of hole and lay down cement stinger is up 42. opera io Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 229-4008 From: Anderson, Nina M Sent: Thursday, March 03, 2011 5:45 PM To: 'Schwartz, Guy L (DOA)' Cc: Winfree, Michael Alex (Jr.); Chambers, Mark A; Galiunas, Elizabeth C Subject: RE: CD3-127 Operational Shutdown Guy — Per our most recent conversation, the Alpine team has made the final decision to submit an operational shutdown to isolate the intermediate hole on CD3-127. Due to the uncertainty of drilling and running casing through the shales and timing with the CD3 winter program, the sidetrack will be completed next winter. A 10-403 sundry will be submitted for isolating CD3-127 with three cement plugs; Lower plug to isolate the Nechelik/Kuparuk reservoirs, a balanced plug across the Qannik interval, and an abandonment/kick off plug across the surface casing shoe. The depths and cement plugs are shown in the attached schematic. Please let me know if you have any questions or concerns. 3/4/2011 Page 3 of 4 Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 229-4008 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, March 03, 2011 2:31 PM To: Anderson, Nina M Cc: Winfree, Michael Alex (Jr.) Subject: RE: CD3-127 Cement Plug placement Revision 1 Nina, Your plan below to set cement plugs and sidetrack is acceptable. The Kuparuk and Nechelik are considered the same pool so a cement plug across the two zones is not required by regulation. Also, a sundry or PTD revision is not necessary as you are staying with 500' of the planned wellbore path. Good luck with the sidetrack. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Thursday, March 03, 2011 10:28 AM To: Schwartz, Guy L (DOA) Cc: Winfree, Michael Alex (Jr.) Subject: CD3-127 Cement Plug placement Revision 1 Guy — Per our earlier conversation regarding operations at Doyon 19, due to HRZ instability we were unable to get our cleanout BHA back to bottom to prep for the casing run. The intermediate hole section appears to have collapsed around 13,816' MD which is approximately 146' MD into the HRZ shale. The drilling BHA also encountered pack off events above the HRZ starting at 13,670' MD. The decision was made last night to pull out of hole and prepare for a sidetrack pending state approval of the procedure below. The geologist is currently working with the well planner on a plan forward for the sidetrack; therefore the attached schematic will not have exact KOP depths or depths for the second cement plug. I'll send a follow up email once we have the final plan with depths. Please let me know if you have any concerns or questions. Thanks 1. Pullout of hole with clean out BHA (Currently laying down BHA at 4350' MD at 1000 hrs Thursday March 3rd) 2. Pickup cement stinger and run in hole to +/- 13,600' MD and set 15.8 ppg Class G balanced plug to 13,200' MD (400' plug) 3/4/2011 Page 4 of 4 3. Circulate above plug and pull stinger up to kick off point and set hi viscosity gel pill 4. Rig up and pump densified 17.0 ppg balanced plug for kick off 5. Pull out of hole and lay down cement stinger 6. Pick up drilling BHA and run in hole and tag kick off plug 7. Begin sidetrack operations Plugs are planned with 40% excess Nina Anderson Senior Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 229-4008 3/4/2011 k E OF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COmnSSIoN 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 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-127 ConocoPhillips Alaska, Inc. Permit No: 211-005 Surface Location: 4023' FNL, 1185' FEL, SEC. 05, T12N, R5E, UM Bottomhole Location: 2734' FNL, 3014' FEL, SEC. 18, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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, Daniel T. Seamount, Jr. Chair DATED this I day of February, 2011. cc: Department of Fish 8v Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 JA 18 Mil 'Ancr()ratl6 C" . 'ssioin 1a. Type of Work: Drill ❑✓ - ' Re -drill ❑ Re-entry ❑ 1 b. Proposed Well Class: Development - Oil ❑✓ Service - Winj ❑ Single Zone ❑✓ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ✓ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: CD3-127 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 22335' • TVD: 7079' • 12. Field/Pool(s): Colville River Field Fiord Oil Pool 4a. Location of Well (Governmental Section): 4023' FNL, 1185' FEL, Sec. 5, T12N, R5E, UM Top of Productive Horizon: 2120' FNL, 2106' FEL, Sec. 12, T12N, R4E, UM Total Depth: 2734' FNL, 3014' FEL, Sec. 18, T12N, R5E, UM 7. Property Designation (Lease Number): ADL 372105, 025538, 025526� 8. Land Use Permit: LAS2112 13. Approximate Spud Date: 2/8/2011 9. Acres in Property: 2560 14. Distance to Nearest Property: +/- 4.0 miles to ADL 391451 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 387857.4 - y- 6003756.3 Zone- 4 10. KB Elevation above MSL: 48.9 feet GL Elevation above MSL: 12.6 feet 15. Distance to Nearest Well Open to Same Pool: CD3-118 , 1821' 16. Deviated wells: Kickoff depth: 350 ft. Maximum Hole Angle: 89.4° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3305 psig . Surface: 2597 psig 18. Casing Pro5 ram: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks stage data Hole Casing Weight Grade Coupling Length MD TVD MD TVD(including 24" 16" 62.5 H-40 Welded 77 37 37 114 114 Pre Installed 13.5" 10.75" 45.5# L-80 BTC 3252 37 37 3289 2450 597 sx AS Lite 3, 270 sx 15.8 'G' 9.875" 7.625" 29.7# L-80 BTC-M 15197 37 37 15234 6985 1st -326 sx 15.8 'G' 2nd - 273 sx 15.8 G 3.5" 9.3# L-80 EUE 15028 32 32 15060 6959 Tubing 6.75" 3.5" 9.3# L-80 SLHT 7325 15000 6948 22325 7079 Liner with Swell PKRS and SS for Frac 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑✓ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact Nina Anderson 265-6403 Printed Name Chip Alvord Title Alaska Drilling Manager Signature 01 /1J Phone 265-6120 Date l (( 7 (Zo c zd (�t•/�'_ I Commission Use Only Permit to Drill / Number: 2 (� � API Number: 50-/v'� ,� r � L Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbedm�(ethane, gas hydrates, or gas contained in shales: -)f- 3rN 105 L a0P 7 t - Samples req'd: Yes ❑ No M Mud log req'd: Yes ❑ No Other: 157"Qd �S� �yrf lCS f- H2S measures: Yes ❑ No [V� Directional svy req'd: Yes [ No ❑ Z CA X APPROVED BY THE COMMISSION DATE: COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 nt s rom e a e of approval (20 AAC 25.005(g)) AM it in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 101h, 2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-127 Dear Sir or Madam: ConocoPhilli s p hz _j 8 '011 € '$Sion IiilCiEf�°'a�J�' ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD3 " (Fiord) pad. The intended spud date for this well is February 8th, 2010. It is intended that Doyon Rig 19 be used to drill the well. After setting 7-5/8" intermediate casing, the horizontal section will be drilled in the Nechelik reservoir.,' The lower completion will consist of a blank liner and ball actuated sleeves; the upper completion will be tubing and packer. The well will be flowed back to mitigate reservoir damage and then hooked up to . begin production. It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. This will be the 7th winter season of drilling on the Fiord pad and there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Nina Anderson at 265-6403 or Liz Galiunas at 265-6247. Sincere y, A44�� Nina Anderson Drilling Engineer CD3-127 Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole / 10-3/4" Casina Interval Event Risk Level Mitiqqt!qq_Sqategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Employ gyro single shots and traveling cylinder diagrams. Gas Hydrates Low Monitor well at base of permafrost, increase mud weight, decrease mud viscosity, increase circulating times, control drilling rates and low mud temperatures. Running Sands and Gravel Low Maintain planned mud parameters, increase mud weight if needed and use weighted sweeps. Abnormal Pressure in Low Increase mud weight. Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, thin mud rheology, pump LCM ills and use of low density cement slurries. 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight above 9.6 ppg. Flow Surface Formations checks during connections. Mud weight increase if >2000' TVD needed. Lost circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties and increased mud weight for trips. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density (ECD). Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight. No over Pressure pressured zones. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, and standard well control practices. Employ mud scavengers. 6-3/4" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Moderate Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7-5/8" shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density (ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 9.0 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Perform well control drills. Increase mud weight if needed. Hydrogen Sulfide gas Low H2S drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengeis., ORIGIN A-L Rig Procedure 1. Move Doyon 19 on CD3-127, dewater cellar as needed. 2. Rig up riser. � 3. Drill 13-1/2" hole to the surface casing point as per the directional plan. (Directional/MWD/LWD). P ZVrj a 4. Run and cement 10-3/4" surface casing. 5. Install and test BOPE to 3500 psi. 6. Pressure test casing to 3500 psi. - 7. Pick up and run in hole with 9-7/8" drilling BHA. 8. Drill out 20' of new hole and perform leak off test. Zdf- 9. Drill 9-7/8" hole to intermediate casing point into the Nechelik reservoir sand (LWD Program: GR/RES/PWD/Dens/Neut/Sonic). C/o TY''2�lMs 10. Run and cement 7-5/8" casing as per program. Perform a leak off test down the 10-3/4" x 7-5/8" casing annulus to confirm the fracture pressure referenced to the surface casing shoe. Freeze protect casing annulus and casing. 11. BOPE test to 3500 psi high and 250 psi low. 12. Pick up 6-3/4" directional drilling BHA and RIH. Drill out Stage Collar. Pressure test casing to 3500 psi. 13. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 14. Displace well to Flo-Thru drilling fluid. 15. Drill 6-3/4" horizontal section to well TD. (LWD Program: GR/RES/PWD/Dens/Neut) 16. Circulate the hole clean and pull out of hole. 17. Run lower completion of 3-1/2" blank liner with Frac sleeve system with liner top packer and hanger. - 18. Run upper completion: 3-%, 9.3#, L-80 tubing with SSSV, gas lift mandrels, packer, landing nipple and wireline entry guide. Sting in, space out and land hanger. 19. Install 2 way check and pressure test hanger seals to 5,000 psi. Pull TWC. - 20. Test tbg to 3500 psi for 30 minutes. Bleed down tbg to 2000 psi and pressure test annulus to 3500 psi for 30 minutes. Bleed tbg to 0 psi to sheer casing to tbg DCK-2 SOV. Bleed tubing and annulus pressure to zero. 21. Install TWC and pressure test through SOV to 100Q psi in the direction of flow. Nipple down BOP. 22. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 23. Circulate tubing to diesel and install freeze protection in the annulus. 24. Set BPV and secure well. Move rig off. ORIGINAL Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. CD3-124 is the closest existing well with an uncertainty ellipse to ellipse separation of 39.95' @ 769.16' MD. The closest existing well with a clearance factor less than 2.0 is CD3-117 with an uncertainty ellipse to ellipse separation of 75.64' at 14,388' MD. Drilling Area Risks: There are no high -risk events (e.g. over -pressures zones) anticipated. Faulting within the Nechelik reservoir is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-127 will be injected into a permitted annulus on CD3 pad or the class 2/class 1 disposal well on CD1 pad. The CD3-127 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2,000' TVD. The significant hydrocarbon zones are the Nechelik reservoir, and potentially the Qannik and Kuparuk reservoirs. There will be 500' of cement fill above the top of the Kuparuk reservoir along with 500' above and below the Qannik reservoir per regulations. Once CD3-127 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 would then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2,450') + 1,500 psi = 3028 psi Pore Pressure = 1,108 psi Therefore Differential = 3028 —1108 = 1920 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 10-3/4" 45.5 L-80 3 BTC-M 2480 2108 psi 3580 psi 3043 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi ORIGINAL DRILLING FLUID PROGRAM SPUD to 10-3/4"surface casing point — 13-1/2" Intermediate hole to 7- 5/8" casing point — 9-7/8" Production Hole Section — 6-3/4" Density 8.7 — 9.8 ppg 9.6 —10.0 ppg 9.0-9.4 ppg ✓ PV 10-16 7-12 YP 30 — 60 13-16 upper clays, 18-22 in lower section 10 - 15 Funnel Viscosity 70 — 300 4-8 Initial Gels 10 Sec 8-10 6-9 10 minute gels < 20 8 - 12 API Filtrate NC— 10 cc / 30 min < 5 cc / 30 min HPHT Fluid Loss at 160 < 8 cc / 30 min by HRZ < 10 cc/30 min PH 8.5-9.0 9.0-10.0 9.0-9.5 KCL < 20 — 3 MBT Surface Hole: A standard high viscosity fresh water gel spud mud is planned for the surface interval. Flow line viscosity will be kept at ± 300 sec/qt while drilling gravels. Viscosity prior to cementing will be reduced to ± 80-100 sec/qt. Mud weight will be maintained at < 9.6 ppg by use of solids control system and dilution where necessary. Using cold make up water will help keep the flow line temperature as low as possible. Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 9.8 ppg to minimize losses, and lost circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be beneficial in maintaining wellbore stability. For shale stability, MW may be increased to 10.0 ppg for tripping. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo-Thru drill -in fluid. The base fluid will consist of 3% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan f/ Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. Klagard will be used for inhibition. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. ORIGINAL Completion Schematic — Upper Completion Colville River Field CD3-127 Nechelik Production Well Completion Updated 1/14/2011 Sperry Drilling Services CD3-127wp03 16" Conductor to 114' Page 1 of 2 — Upper Completion Packer Fluid mix: Inhibited Kill weiaht 6% KCI Brine with 2000' TVD diesel cap 10 '/4' 45.5 ppf L-80 BTC-Mod Surface Casing @ 3289' MD / 2450' TVD cemented to surface TOC @ +/- Upper Completion MD ND 7045' MD / 3838' TVD 1) Tubing Hanger 36' 36' 2) 4-%" 12.6#/ft IBT-Mod Tubing (2 jts), XO Qannik Interval 3) 3 ''1V 9.3 #/ft L-80 EUE-Mod Tubing 4) Camco TRMAXX-5E SSSV (2.812" ID) 2200' 1992' Top +/- 7545' MD / 4023' TVD with control line to surface. Cannon Cross -coupling clamps on every joint ES Cementer 5) 3-%" 9.3 #/ft L-80 EUE-Mod Tubing +/- 8097' MD / 6) 3-'/2" x 1" Camco KBMG GLM w/ DV 5858' 3400' 4227' TVD 7) 3-'/2' 9.3 #/ft L-80 EUE-Mod Tubing 8) 3-'/2" x 1" Camco KBMG GLM w/ DV 11808' 5600' 9) 3-'/2' 9.3 #/ft L-80 EUE-Mod Tubing 10) Camco KBMG GLM (2.867" ID) w/DCK2 14,200' 6707' Pinned for 2500 psi casing to tbg shear 11) 3-1/2' 9.3 #/ft L-80 EUE-Mod Tubing 12) HES XN 2.813" (2.75" NoGo) - with RHC Plug 14330' 6757' 13) 3-'/2' 9.3 #/ft P-110 EUE-mod Tubing joints 3-1/2" 9.3 ppf L-80 EUE M 14) 80-40 GBH-22 Seal Assembly w/'/2 Mule Shoe 15060' 6959' tubing run with Jet Lube Run'n'Seal pipe dope TOC Calculated @ +/- 14078' MD / 6656' TVD (300' above Packer & 500' MD above Kuparuk) 14 - ---- - ------ ------- -------------------- Top Kuparuk C 14 14,578' MD / 6,841' TVD — ----------- Top Nechelik 15,234 MD / 6,985' TVD 7-5/8" 29.7 ppf L-80 BTC Mod from 36' to 14900' MD / 6927' TVD 6 %" Hole TD at 7-5/8" 29.7 ppf P-110 BTC Mod from 14900' MD to 15234' MD / 6985' TVD at 22,335' MD / 7,079' TVD ORIGINAL Completion Schematic — Lower Completion Colville River Field CD3-127 Nechelik Production Well Completion Updated 1/14/2011 Sperry Drilling Services CD3-127wp03 s" Conductor to 114' Page 2 of 2 — Lower Completion Packer Fluid mix: Inhibited Kill weight 6% KCI Brine with 2000' TVD diesel cap 10 1/" 45.5 ppf L-80 BTC-Mod Surface Casing @ 3289' MD / 2450' TVD cemented to surface TOC @ +/- 7045' MD / 3838' TVD Qannik Interval Top +/- 7545' MD / 4023' TVD ES Cementer +/- 8097' MD / 4227' TVD 3-1/2" 9.3 ppf L-80 EUE M tubing run with Jet Lube Run'n'Seal pipe dope TOC Calculated @ +/- 14078' MD / 6656' TVD (300' above Packer & 500' MD above Kuparuk) Top Kuparuk C 14,578' MD / 6,841' Lower Completion MID Lm 15) Baker 5-1/2" X 7-5/8" ZXP Liner Top Packer with 15000" 6948' Flex Lock Hanger w/ Seal bore Extension 16) XO 5-%" Hydril 521 X 3-%" SLHT 17) 3-1/:", 9.3 #/ft, SLHT Tubing 18) 3-1/2" x 6-1/2" Centralizers SLHT Box x Box 19) Swell Packer (3-%" SLHT) OD 6.38" w/ 10' sealing element TBD TBD 20) 3-1/2" x 6-1/" Centralizers SLHT Box x Pin 21) 3-1/2", 9.3 #/ft, SLHT Tubing 22) 3-1/2" SLHT Ball Actuated Sleeve (2.000" Seat ID) (2.125" Ball) TBD TBD 23) 3-1/2", 9.2 #/ft, SLHT Tubing 24) 3-1/V x 6-%" Centralizers SLHT Box x Box 25) Swell Packer (3-1/2" SLHT) OD 6.38" w/ 10' sealing element TBD TBD 26) 3-1/2" x 6-%" Centralizers SLHT Box x Pin 27) 3-1/2", 9.3 #/ft, SLHT Tubing 28) 3-11W SLHT Ball Actuated Sleeve (1.875" Seat ID) (2.000" Ball) TBD TBD 29) 3-1/.", 9.3 #/ft, SLHT Tubing 30) 3-1/2" x 6-%" Centralizers SLHT Box x Box 31) Swell Packer (3-1/2" SLHT) OD 6.38" w/ 10' sealing element TBD TBD 32) 3-%" x 6-1/2" Centralizers SLHT Box x Pin 33) 3-1/2", 9.3 #/ft, SLHT Tubing 34) 3-1/2" SLHT Ball Actuated Sleeve (1.750" Seat ID) (1.875" Ball) TBD TBD 35) 3-1/2", 9.3 #/ft, SLHT Tubing 36) 3-1/2" x 6-1/2" Centralizers SLHT Box x Box 37) Swell Packer (3-1/2" SLHT) OD 6.38" w/ 10' sealing element TBD TBD 38) 3-1/." x 6-1/2" Centralizers SLHT Box x Pin 39) 3-1/2", 9.3 #/ft, SLHT Tubing 40) 3-1/2" SLHT Ball Actuated Sleeve (1.625" Seat ID) (1.750" Ball) TBD TBD 41) 3-1/2", 9.3 #/ft, SLHT Tubing 42) 3-1/2" x 6-1/2" Centralizers SLHT Box x Box 43) Swell Packer (3-1/2" SLHT) OD 6.38" w/ 10' sealing element TBD TBD 44) 3-1/2' x 6-1/2" Centralizers SLHT Box x Pin 45) 3-1/", 9.3 #/ft, SLHT Tubing 46) 3-1/2" SLHT Ball Actuated Sleeve (1.500" Seat ID) (1.625" Ball) TBD TBD 47) 3-1/2", 9.3 #/ft, SLHT Tubing 48) 3-1/2" x 6-%" Centralizers SLHT Box x Box 49) Swell Packer (3-1/2" SLHT) OD 6.38" w/ 10' sealing element TBD TBD 50) 3-1/2" x 6-1/2" Centralizers SLHT Box x Pin 51) 3 %", 9.3 #/ft, SLHT Tubing 52) 3-1/" SLHT Ball Actuated Sleeve (1.375" Seat ID) (1.500" Ball) TBD TBD' 53) 3-1/2", 9.3 #/ft, SLHT Tubing 54) 3-1/2" x 6-1W" Centralizers SLHT Box x Box 55) Swell Packer (3-1/2" SLHT) OD 6.38" w/ 10' sealing element TBD TBD 56) 3-%" x 6-1/V Centralizers SLHT Box x Pin 57) 3-%", 9.3 #/ft, SLHT Tubing 58) 3-%" SLHT Ball Actuated Sleeve (1.250" Seat ID) (1.375" Ball) TBD TBD 59) 3-1/2", 9.3 #/ft, SLHT Tubing 60) 3-%" x 6-1/2" Centralizers SLHT Box x Box 61) Swell Packer (3-1/2" SLHT) OD 6.38" w/ 10' sealing element TBD TBD 62) 3-%" x 6-1/2" Centralizers SLHT Box x Pin 63) 3-%", 9.3 #/ft, SLHT Tubing rforated Pup PICK TBD TBD 65) 3-1/2", 9.3 #/ft, SLHT Tubing 5w`� 66) 3-1/2" SLHT Orange Peel 22325' 7079' o 7-5/8" 29.7 ppf L-80 BTC Mod from 36' to 14900' MD / 6927' TVD , , Top Nechelik 7-5/8" 29.7 ppf P-110 BTC Mod from 14900' MD to 15234' MD / 6985' at 2 Hole TD at 15,234 MD / 6,985' TVD TVD at 2,335' MD / 7,079' TVD ORIGINAL CD3-127 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al(psi)si Pore pressure ASP Drilling 16 114 / 114 10.9 52 53 10-3/4" 3289 / 2450 14.5 1108 1602 7-5/8" 15,234 / 6985 16.0 3160 2597 N/A 22,335 / 7079 16.0 3305 "* N/A NOTE: The Doyon 19 5,000 psi BOP equipment is adequate. Test BOP's to 3500 psi. ** NOTE: Pore Pressure for production interval is estimated reservoir pressure PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP — (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) — 0.1] D = [(10.9 x 0.052) — 0.1] x 114 = 53 psi OR ASP = FPP — (0.1 x D) = 1108 — (0.1 x 2450') = 863 psi 2. Drilling below surface casing (10 3/4") ASP = [(FG x 0.052) — 0.1] D _ [(14.5 x 0.052) — 0.1] x 2450 = 1602 psi OR ASP = FPP — (0.1 x D) = 3160 — (0.1 x 6985') = 2462 psi 3. Drilling below intermediate casing (7-5/8") ASP = Reservoir Pressure — (0.1 x D) = 3305 — (0.1 x 7079') = 2597 psi OR IGINAL Cementing Program: 10-3/4" Surface Casing run to 3289' MD / 2450' TVD. Cement from 3289' MD to 2789' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2789' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1717' MD). Lead slurry: (2789 - 1555') X 0.3638 ft3/ft X 1.5 (50% excess) = 673.4 ft3 below permafrost 1555' X 0.3638 ft3/ft X 3.5 (250% excess = 1980 ft3 above permafrost Total volume = 673.4 + 1980 = 2653.4 ft => 597 Sx @ 4.45 ft3/sk System: 597 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (50% excess) = 272.8 ft3 annular volume 80' X 0.5397 ft3/ft = 43.2 ft3 shoe joint volume Total volume = 272.8 + 43.2 = 316.0 ft3 => 270 Sx @ 1.17 ft3/sk System: 270 Sx Class G + 0.2% D046 antifoamer, + 1 %S2, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7-5/8" Intermediate Casing run to 15,234 MD / 6985' TVD First Stage: Cement from 15,234' MD to 14078' MD. (500' of Class G + adds @ 15.8 PPG and minimum 300' MD above the packer). Assume 40% excess annular volume. Lead Slurry: (15,234'-14,078') X 0.2146 ft3/ft X 1.4 (40% excess) = 347 ft3 annular vol. 120' x 0.2577 ft3/ft = 30.9 ft3 shoe joint volume Total volume = 30.9 ft3 + 347 ft3 = 378 ft3 => 326 Sx @ 1.16 ft3/sk System: 326 Sx Class G + 0.2% D046 antifoamer, + 1 %S2, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.17 ft3/sk Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (8097' - 7045') x 0.2146 ft3/ft x 1.4 (40% excess) = 316 ft3 annular vol. CX,nn i Total Volume = 316 ft3 => 272.5 Sk @ 1.16 ft3/sk System: 273 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ORIGINAL N' ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: C133-127 Plan: C133-127 Plan: CD3-127wp03 a.k.a. 117 outh or K S Standard Proposal Report 17 December, 2010 Plan misses Heel by 145 ft. Changed surface casing depth and updated surface location from as -built. Permirt PacK HALLIBURTON Sperry Drilling Services ORIGINAL CD El GI I�UJ- I LOWPU,+ CD3-129wp01 CD3-127wp03 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Easting (5000 Win) CD3-120wp06 CD3-304 B1 15 Fiord 2 11:38, December 17 2010 Easting (5000 Min) Project: Western North Slope CD3-127wp03 ConocoPhillips Wellboree Plan: CD3 �27 Alaska 6, GDI<0 Rtlatiey steal, simge wdbasinpe profiles wiN Mxv lorWod DDI 6.0-14: Share wdb with hph takudtyaNrga welb w:M law DDI 6.4 - 8.8 : Lang wM w4h rddrvdJ lOrhrOua pniJes DDI = 7.191 DDI > 8.5 : LanO, trla0ux Ha61a v4N a him d�ree d drrzaay u 9 ■ALLIBURTON REFERENCE iNFOIWAMON Coadnds (WE Rdaenn: WeN %ai: CO}127, Tme Norh VMk'FI (TVD).Rdermca'Rar 38.3.12.8 48.906 19 D- ) 5BL6a1 (VS)Rdamce Sbt-10. ) E.Urg 0003503.45 Ez.;527869.34 oround Lerel 12.60 ---'-"`--' Drilling Sperry Q ,0. Celwle6an Metlgd Minimum Curvdura Gmhdc Zme Aaska 2me 4 Lditada 70•n•7.M8N Lagituda IM-M-0204 W 12:47, December 17 2010 Gaoeena DdOm: Na1h ama� Dadm 1983 CASING DETAILS SURVEY PROGRAM 2ASO.Op 2401.10 32890D1 10-3]4 103M-z 1} 6s84.90 89J8.00 15234.58 75/8 7518'X&7/6' 3e30 1400.00 C0}12rvp0.1 OD3-1 GYOGCSS 13Ma0 829.01 CD1127Ap08 CW-t MWD.ffR-AKLAZ-SC 7078.90 7030.00 22336.55 112 }1r1 x831I' 321.01627A80 CWIx)lapq CD}t MWDNFRdK4:AZ5C 16974.00 2t736.55 C113,121wp03 CD3.1 MWD.iR-AKZKSC Tarpdr --- Name TVD65 +ws •EAW NaOwg Euarg Shape C 25Ma(10 Heel BB36.00-35ts.89 _11M.86 BD0013 1. 151676037 Print CD}K 256HJ10 T. 703000-9NSB.23-7D80.18 5994343.79 112.1..1 Pdnt - S40 MD Ins Aid TVD TVD66 +WS +FJ.W Narlhin9 E floq M - TFaa4 Vale Targt 1 38.10 0.00 0.00 38.10 -12.60 2 349.90 0.00 0.00 349.80 300.90 0.00 0.00 a.. 0.00 0.00 080 0.00 0.00 0.00 O.OD 3 699,98 3.75 311.00 599.80 550.90 4 902.45 10.40 307.79 899. Ba $50.90 5.37 5.18 28.62 .35.25 1.50 2.20 311.00 -5,00 i1.11 5 1002+45 12.97 300.11 99773 9. 3 6 11.10 8830 212:11 2215.50 2168.60 39.711 1 10 24.61-1081.51 3.00 3.53 J5.00 42.33 -59,10 503.84 7 12159.41 68.30 262.00 5]29.80 5680.90 8 13]89,25 58.79 198.32 6519.80 6470.90 -1204.41 -8806.61 4041.75-10864,37 0.00 3.50 0.00 -114.00 -33)8.95 _ 3.11 9 14120.68 65.41 198.32 6674.80 6625.90 10 15234.58 8300 165.00 6984.90 6936.00 -2319.65-10956.41 -3369.9710973.13 2.00 3-27 0.00 -66.75 -2907,28 -19]9.03 11 15284.58 83.00 165.do 6990.99 6942.09 12 15{93.97 89.J8 165.00 ]004.90 3{17.90 10980.28 .3619.61-10906.23 0.00 3.05 0.00 0.00 .1930.{9 -1]28.21 13 16526.81 89.38 144.34 ]016.19 696].29 14 22J36.55 .38 144.34 7078.90 7030.00 IW 07-10466.1] -9268.23-7080.18 2.00 0.do -90.11 0.00 589A5 5041.72 M-25Mry1DToe 0 2500 Start Build 1.50 //'A D Start DLS 2.20 TFO S:OQ Start DLS 3.00 TFO -35.06 - , 0' - Base Permafrost Start DLS 3.53 TFO -02.83` ___ 000 Start 9504.61 hold at 2654.80 -- C-00 G30 10-3/4" x 13-1/2" ? u�i� V C-20-- L Ll S 0+ `0O K-3 K-3 Basal 6� FO m K-2 Basal Oannik K Start DLS 3.50 TFO-114.00 11010 Start 50.00 hold at 15234.58 MD 2 9000 77 Start 50.00 hold at 15234.58 MD 500D Apron 97 r7 'Start Build 3.05 - a - - - - Start DLS 2.00 TFO -90.11 Albion 96 SfaIt DLS 2.00 TFO 0 �00 r J Start 5809.71 hold at 16526.83 MD Top HRZBase HRzr op Kupanik D 13"710 O 7 o0 o J i CD3-1 - --- - -I- - - -------`�----`�-- -Top KuparukC 1 7500 I To Nui sut LCU Start DLS 3.27 TFO -69.-W X 9-7/8" Necheli 1 Top Nechelik Base Nuigsutt zsoo o zsoo Vertical Section at 153.00'(2500 ft/in) -9000 5 io0 aoro 0 Start DLS 2.10 TFO.5.00 Start DLS 3.00 TFO 45.00 Start Owd 1.50 1 Start DLS 3.53 TFO -0233 � I Start DLS 3.50 TFO-114.00 - _ Start 9504.61 hofd at 2654.80 MD 6 Start DLS 2.00 TFO 0.00 _ _ _ _ _ 1,s 0 I o 0 1 N O O G03 I $ c o 10d/4" x 13-1112" 14000- o Start DLS 3.27 TFO -66.75 115w00 7-518" X 9-7/8" 300o Start 50.00 hold at 15234.58 MD I 11Ypb Start 50.00 hold at 15234.58 MD 1 Start Build 3.05 N -Start DLS 2.00 TFO -90.11 1 CD 34( 25Mry10 Heal 1b00 Start 5609.71 hold at 16526.83 MD J000 O i ra 000 11. 000 �O �O 3-1/2" x 6-3/4" 00 ' 1-----G0 1ti1W CDW 25 O T .,M 4006 4000 0 West( -)/East(+) (3000 Win) ANNOTATIONS TVD TVD55 MD A7ndatkm 349300.90 349.80 Star Build 1.50 ME 550.90 599.98 Slat DLS 2.20 TFO 5.00 899.80 850.W 902.45 Slat DLS 3.00 TFO J680 997.73 948.83 1002.45 Slat DLS 3.53 TFO -42.33 2215.50 2165.60 2654.80 St. 950461 holdd 2654.80 MD 572E 80 MW.90 12159,41 Slat DLS 3.50 TFO-114.00 01980 s47090 13789.25 Stet DLS 2.00 TFO 0.00 - - - - - -- M74.50 M 5.90 14120.68 Slat DLS 3.27 TFO 56.75 - ` `" - ... _ - 698490 6938.00 15234,M Slat 50.00 hold a 15234.5a MD - - - - - Sm t* 69420) 152M:58 Slat BWd 305 7004.90 6956.00 1549397 Slat DLS 2.00 TFO 50.11 7016.19 6987.29 165M 83 Star SON) 71 hdd d 16526.83 MD 7078.% 703000 U336.65 TDd2233655 3-1/2" z CD3-127 03 M C1 i N 3-K 25May1 Toe 6000 FORrAnnoN TOP DErats ___ - - _- TVOPdh TVDaaPdh MDPath F9rmatcn 12 tW 231090 1173.00 2262.00 1236.16 2912.81 Ba P-drod GO 2478.90 2859.90 2-00 2811.00 3367.17 4397.61 rr.30 Gn MOM 400890 U14.00 3960.00 7110.28 75D&14 K-3 K41 S-1 402390 413090 n75.00 4082.00 7545.71 7835.10 Oannk K-2 K-2 Basel 538090 5824.90 5332.00 5776.00 11215.79 123B9.51 Ab 97 ANan w 6576.90 870390 61 1.01 68MM 13903.20 14191.SO Top HRZ Bros HW 8]5490 6789.90 61 1 6741.00 14323.79 14420.91 K.1 TW Kupauk D 6841 90 684890 6793.00 680oo0 145]8.86 14601.72 Top Kupaak C LCU 6849.90 6898.90 6801.00 6850.00 14605.02 14780.70 TW Nupdd Base .4- 698490 69M 00 15234.58 TW N4ohdk CD3-127wpO3 Plan View o� 0- 0 0 0 0 0 0 0 0 10-3/4" x 13-1 /2" -1500 0 0 �O 00 0 00 14000 3000 15000 1 -- 7-5/8" X 9-7/8" 0 0 160p0 4500 0 z O ca6000 O 000 0000 ti -7500 O ti�00 On' ��Q 000 -9000 3-1 /2" x 6-3/4" 2?2��'t -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 West( -)/East(+) (1500 ft/in) I CD3.127wpO3 Section View 9 1500 c 0 0 3000 U 4500 m 6000 7500 000 -4500 1000 10-3/4" x 13-1 /2" 30. 20�0 sO0 00 Q O 00 S 0 6' 00 0 00 O 8 SSO00 00 90, 0 70 0 0 77, 00 7�0� O O 1 0 00 0 0 0 � o 7-5/8" X 9-7/8" 0 0 0 0 rn orn o r CO N 3-1/2" x 6-3/4" -3000 -1500 0 1500 3000 4500 6000 7500 Vertical Section at 153.00°(1500 ft/in) HALLIBURTON Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: Plan: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wp03 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-127 TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) T MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope 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 CD3 Fiord Pad Site Position: From: Map Position Uncertainty: 0.00 ft Well Plan: CD3-127 Well Position +N/-S 0.00 ft +E/-W 0.00 ft Position Uncertainty 0.00 ft Wellbore Plan: CD3-127 Magnetics Model Name BGGM2009 Design Audit Notes: Version: Vertical Section: CD3-127wp03 Northing: 469.98ft Easting:-401.27 ft Slot Radius: Latitude: 53° 58' 43.652 N Longitude: 152° 19' 30.231 W Grid Convergence: -1.88 ° Northing: 6,003,756.25ft Latitude: 70° 25' 9.104 N Easting: 387,857.43 ft - Longitude: 150° 54' 48.826 W Wellhead Elevation: ft Ground Level: 12.60ft. Sample Date Declination Dip Angle Field Strength (°) (I (nT) 12/16/2010 16.41 79.73 57,371 Phase: Depth From (TVD) (ft) 36.30 Plan Sections Measured Vertical TVD Depth Inclination Azimuth Depth System (ft) I (°) (I (ft) ft 36.30 0.00 0.00 36.30 -12.60 349.80 0.00 0.00 349.80 300.90 599.98 3.75 311.00 599.80 550.90 902.45 10.40 307.79 899.80 850.90 1,002.45 12.97 300.11 997.73 948.83 2.654.80 68.30 262.00 2,215.50 2,166.60 j 12,159.41 68.30 262.00 5,729.80 5,680.90 13,789.25 58.79 198.32 6,519.80 6,470.90 14,120.68 65.41 198.32 6,674.80 6,625.90 15,234.58 83.00 165.00 6,984.90 6,936.00 15,284.58 83.00 165.00 6,990.99 6,942.09 15,493.97 89.38 165.00 7,004.90 6,956.00 16,526.74 89.38 144.34 7,016.19 6,967.29 22,335.64 89.38 144.34 7,078.90 7,030.00 1211712010 3:47:33PM PLAN Tie On Depth: 36.30 +N/ S +E/-W Direction (ft) (ft) (°) 0.00 0.00 153.00 Dogleg Build Turn +W-S +E1-W Rate Rate Rate Tool Face (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.37 -6.18 1.50 1.50 0.00 311.00 28.62 -35.25 2.20 2.20 -1.06 -5.00 39.78 -52.10 3.00 2.57 -7.69 -35.00 24.61 -1,061.51 3.53 3.35 -2.31 -42.33 -1,204.43 -9,806.61 0.00 0.00 0.00 0.00 -2,041.75 -10,864.37 3.50 -0.58 -3.91 -114.00 -2,319.65 -10,956.41 2.00 2.00 0.00 0.00 -3,369.97 -10,973.12 3.27 1.58 -2.99 -66.75 -3,417.90 -10,960.28 0.00 0.00 0.00 0.00 -3,619.61 -10,906.23 3.05 3.05 0.00 0.00 -4,548.00 -10,466.82 2.00 0.00 -2.00 -90.11 -9,267.60 -7,080.87 0.00 0.00 0.00 0.00 Page 2 COMPASS 2003.16 Build 69 ORIGINAL. Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: Plan: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wp03 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (ft) (°) (°) (ft) ft 36.30 0.00 0.00 36.30 -12.60 100.00 0.00 0.00 100.00 51.10 200.00 0.00 0.00 200.00 151.10 300.00 0.00 0.00 300.00 251.10 349.80 0.00 0.00 349.80 300.90 Start Build 1.50 400.00 0.75 311.00 400.00 351.10 500.00 2.25 311.00 499.96 451.06 599.98 3.75 311.00 599.80 550.90 Start DLS 2.20 TFO -5.00 600.00 3.75 311.00 599.82 550.92 700.00 5.95 309.15 699.46 650.56 800.00 8.15 308.29 798.70 749.80 900.00 10.34 307.80 897.39 848.49 902.45 10.40 307.79 899.80 850.90 Start DLS 3.00 TFO -35.00 1,000.00 12.90 300.26 995.34 946.44 1,002.45 12.97 300.11 997.73 948.83 Start DLS 3.53 TFO 42.33 1,100.00 15.69 291.49 1,092.24 1,043.34 1,200.00 18.72 285.33 1,187.77 1,138.87 1,236.16 19.85 283.56 1,221.90 1,173.00 Base Permafrost 1,300.00 21.89 280.87 1,281.55 1,232.65 1,400.00 25.16 277.50 1,373.22 1,324.32 1,500.00 28.49 274.87 1,462.45 1,413.55 1,600.00 31.86 272.75 1,548.89 1,499.99 1,700.00 35.26 271.00 1,632.21 1,583.31 1,800.00 38.68 269.52 1,712.10 1,663.20 1,900.00 42.11 268.25 1,788.25 1,739.35 2,000.00 45.56 267.13 1,860.38 1,811.48 2,100.00 49.02 266.14 1,928.20 1,879.30 2,200.00 52.48 265.25 1,991.46 1,942.56 2,300.00 55.95 264.44 2,049.92 2,001.02 2,400.00 59.43 263.69 2,103.37 2,054.47 2,500.00 62.91 263.00 2,151.59 2,102.69 2,600.00 66.39 262.34 2,194.40 2,145.50 2,654.80 68.30 262.00 2,215.50 2,166.60 Start 9504.61 hold at 2654.80 MD 2,700.00 68.30 262.00 2,232.21 2,183.31 2,800.00 68.30 262.00 2,269.19 2,220.29 2,900.00 68.30 262.00 2,306.16 2,257.26 2,912.81 68.30 262.00 2,310.90 2,262.00 C-40 3,000.00 68.30 262.00 2,343.14 2,294.24 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature Map Map +N/-S +E/-W Northing Easting DLS Vert Section (ft) (ft) (ft) (ft) -12.60 0.00 0.00 6,003,756.25 387,857.43 0.00 0.00 0.00 0.00 6,003,756.25 387,857.43 0.00 0.00 0.00 0.00 6,003,756.25 387,857.43 0.00 0.00 0.00 0.00 6,003,756.25 387,857.43 0.00 0.00 0.00 0.00 6,003,756.25 387,857.43 0.00 0.00 0.22 -0.25 6,003,756.47 387,857.18 1.50 -0.31 1.94 -2.23 6,003,758.23 387,855.23 1.50 -2.74 5.37 -6.18 6,003,761.72 387,851.33 1.50 -7.59 5.37 -6.18 6,003,761.72 387,851.33 0.00 -7.59 10.79 -12.67 6,003,767.24 387,844.92 2.20 -15.37 18.46 -22.25 6,003,775.04 387,835.46 2.20 -26.55 28.35 -34.91 6,003,785.12 387,822.96 2.20 -41.11 28.62 -35.25 6,003,785.40 387,822.61 2.20 -41.51 39.50 -51.62 6,003,796.53 387,806.41 3.00 -58.64 39.78 -52.10 6,003,796.81 387,805.94 3.00 -59.10 50.11 -73.84 6,003,807.46 387,784.35 3.53 -78.17 59.31 -101.90 6,003,817.08 387,756.44 3.53 -99.10 62.28 -113.47 6,003,820.23 387,744.92 3.53 -107.00 67.07 -135.70 6,003,825.35 387,722.76 3.53 -121.36 73.36 -175.10 6,003,832.23 387,683.47 3.53 -144.86 78.16 -219.96 6,003,837.71 387,638.69 3.53 -169.50 81.46 -270.10 6,003,841.75 387,588.61 3.53 -195.20 83.23 -325.34 6,003,844.36 387,533.41 3.53 -221.86 83.47 -385.46 6,003,845.50 387,473.30 3.53 -249.37 82.19 -450.24 6,003,845.19 387,408.52 3.53 -277.63 79.38 -519.43 6,003,843.42 387,339.30 3.53 -306.54 75.06 -592.76 6,003,840.20 387,265.91 3.53 -335.98 69.23 -669.97 6,003,835.54 387,188.63 3.53 -365.85 61.94 -750.75 6,003,829.46 387,107.76 3.53 -396.02 53.19 -834.80 6,003,821.98 387,023.59 3.53 -426.39 43.03 -921.80 6,003,813.13 386,936.46 3.53 -456.83 31.50 -1,011.41 6,003,802.94 386,846.69 3.53 -487.24 24.61 -1,061.51 6,003,796.81 386,796.50 3.53 -503.84 18.77 -1,103.10 6,003,791.59 386,754.83 0.00 -517.52 I 5.84 -1,195.11 6,003,780.04 386,662.65 0.00 -547.77 -7.10 -1,287.12 6,003,768.49 386,570.46 0.00 -578.02 -8.75 -1,298.90 6,003,767.02 386,558.65 0.00 -581.89 -20.03 -1,379.13 6,003,756.95 386,478.28 0.00 -608.27 1211712010 3:47:33PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: Plan: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wp03 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature 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) 2,331.21 3,100.00 68.30 262.00 2,380.11 2,331.21 -32.96 -1,471.14 6,003,745.40 386,386.09 0.00 -638.52 3,200.00 68.30 262.00 2,417.09 2,368.19 -45.89 -1,563.14 6,003,733.86 386,293.91 0.00 -668.77 3,289.01 68.30 262.00 2,450.00 2,401.10 -57.40 -1,645.04 6,003,723.58 386,211.85 0.00 -695.69 10-3/4" x 13-1/2" 3,300.00 68.30 262.00 2,454.06 2,405.16 -58.82 -1,655.15 6,003,722.31 386,201.72 0.00 -699.01 3,367.17 68.30 262.00 2,478.90 2,430.00 -67.51 -1,716.96 6,003,714.55 386,139.80 0.00 -719.33 C-30 3,400.00 68.30 262.00 2,491.04 2,442.14 -71.75 -1,747.16 6,003,710.76 386,109.54 0.00 -729.26 3,500.00 68.30 262.00 2,528.01 2,479.11 -84.68 -1,839.17 6,003,699.22 386,017.35 0.00 -759.51 3,600.00 68.30 262.00 2,564.99 2,516.09 -97.61 -1,931.18 6,003,687.67 385,925.17 0.00 -789.76 3,700.00 68.30 262.00 2,601.96 2,553.06 -110.54 -2,023.19 6,003,676.12 385,832.98 0.00 -820.01 3,800.00 68.30 262.00 2,638.94 2,590.04 -123.48 -2,115.20 6,003,664.58 385,740.80 0.00 -850.26 3,900.00 68.30 262.00 2,675.91 2,627.01 -136.41 -2,207.21 6,003,653.03 385,648.61 0.00 -880.51 4,000.00 68.30 262.00 2,712.89 2,663.99 -149.34 -2,299.22 6,003,641.48 385,556.43 0.00 -910.76 4,100.00 68.30 262.00 2,749.86 2,700.96 -162.27 -2,391.23 6,003,629.94 385,464.24 0.00 -941.01 4,200.00 68.30 262.00 2,786.83 2,737.93 -175.20 -2,483.23 6,003,618.39 385,372.06 0.00 -971.26 4,300.00 68.30 262.00 2,823.81 2,774.91 -188.13 -2,575.24 6,003,606.84 385,279.87 0.00 -1,001.51 4,397.61 68.30 262.00 2,859.90 2,811.00 -200.75 -2,665.05 6,003,595.57 385,189.89 0.00 -1,031.04 C-20 4,400.00 68.30 262.00 2,860.78 2,811.88 -201.06 -2,667.25 6,003,595.30 385,187.69 0.00 -1,031.76 4,500.00 68.30 262.00 2,897.76 2,848.86 -213.99 -2,759.26 6,003,583.75 385,095.50 0.00 -1,062.01 4,600.00 68.30 262.00 2,934.73 2,885.83 -226.92 -2,851.27 6,003,572.21 385,003.32 0.00 -1,092.26 4,700.00 68.30 262.00 2,971.71 2,922.81 -239.85 -2,943.28 6,003,560.66 384,911.13 0.00 -1,122.51 4,800.00 68.30 262.00 3,008.68 2,959.78 -252.79 -3,035.29 6,003,549.11 384,818.95 0.00 -1,152.76 4,900.00 68.30 262.00 3,045.66 2,996.76 -265.72 -3,127.30 6,003,537.57 384,726.76 0.00 -1,183.01 5,000.00 68.30 262.00 3,082.63 3,033.73 -278.65 -3,219.31 6,003,526.02 384,634.58 0.00 -1,213.26 5,100.00 68.30 262.00 3,119.61 3,070.71 -291.58 -3,311.32 6,003,514.47 384,542.39 0.00 -1,243.51 5,200.00 68.30 262.00 3,156.58 3,107.68 -304.51 -3,403.32 6,003,502.93 384,450.21 0.00 -1,273.76 5,300.00 68.30 262.00 3,193.56 3,144.66 -317.44 -3,495.33 6,003,491.38 384,358.02 0.00 -1,304.01 5,400.00 68.30 262.00 3,230.53 3,181.63 -330.37 -3,587.34 6,003,479.83 384,265.84 0.00 -1,334.26 5,500.00 68.30 262.00 3,267.51 3,218.61 -343.30 -3,679.35 6,003,468.29 384,173.65 0.00 -1,364.51 5,600.00 68.30 262.00 3,304.48 3,255.58 -356.23 -3,771.36 6,003,456.74 384,081.47 0.00 -1,394.76 5,700.00 68.30 262.00 3,341.46 3,292.56 -369.16 -3,863.37 6,003,445.20 383,989.28 0.00 -1,425.01 5,800.00 68.30 262.00 3,378.43 3,329.53 -382.10 -3,955.38 6,003,433.65 383,897.10 0.00 -1,455.25 5,900.00 68.30 262.00 3,415.40 3,366.50 -395.03 -4,047.39 6,003,422.10 383,804.91 0.00 -1,485.50 6,000.00 68.30 262.00 3,452.38 3,403.48 -407.96 -4,139.40 6,003,410.56 383,712.73 0.00 -1,515.75 6,100.00 68.30 262.00 3,489.35 3,440.45 -420.89 -4,231.41 6,003,399.01 383,620.54 0.00 -1,546.00 6,200.00 68.30 262.00 3,526.33 3,477.43 -433.82 -4,323.42 6,003,387.46 383,528.36 0.00 -1,576.25 6,300.00 68.30 262.00 3,563.30 3,514.40 -446.75 -4,415.42 6,003,375.92 383,436.17 0.00 -1,606.50 6,400.00 68.30 262.00 3,600.28 3,551.38 -459.68 -4,507.43 6,003,364.37 383,343.99 0.00 -1,636.75 6,500.00 68.30 262.00 3,637.25 3,588.35 -472.61 -4,599.44 6,003,352.82 383,251.80 0.00 -1,667.00 6,600.00 68.30 262.00 3,674.23 3,625.33 -485.54 -4,691.45 6,003,341.28 383,159.62 0.00 -1,697.25 6,700.00 68.30 262.00 3,711.20 3,662.30 -498.47 -4,783.46 6,003,329.73 383,067.43 0.00 -1,727.50 6,800.00 68.30 262.00 3,748.18 3,699.28 -511.41 -4,875.47 6,003,318.19 382,975.25 0.00 -1,757.75 6,900.00 68.30 262.00 3,785.15 3,736.25 -524.34 -4,967.48 6,003,306.64 382,883.06 0.00 -1,788.00 1211712010 3:47:33PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL HALLIBURTQN Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: Plan: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wp03 Planned Survey Measured Depth Inclination Azimuth (ft) V) V) 7,000.00 68.30 262.00 7,100.00 68.30 262.00 7,110.28 68.30 262.00 K-3 7,200.00 7,300.00 7,400.00 7,500.00 7,505.14 K-3 Basal 7,545.71 Qannik K-2 7,600.00 7,700.00 7,800.00 7,835.10 K-2 Basal 7,900.00 8,000.00 8,100.00 8,200.00 8,300.00 8,400.00 8,500.00 8,600.00 8,700.00 8,800.00 8,900.00 9,000.00 9,100.00 9,200.00 9,300.00 9,400.00 9,500.00 9,600.00 9,700.00 9,800.00 9,900.00 10,000.00 10,100.00 10,200.00 10, 300.00 10,400.00 10, 500.00 10,600.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature Vertical Map Map Depth TVDss +N/S +E/-W Northing Easting DLS Vert Section (ft) ft (ft) (ft) (ft) (ft) 3,773.23 3,822.13 3,773.23 -537.27 -5,059.49 6,003,295.09 382,790.88 0.00 -1,818.25 3,859.10 3,810.20 -550.20 -5,151.50 6,003,283.55 382,698.69 0.00 -1,848.50 3,862.90 3,814.00 -551.53 -5,160.95 6,003,282.36 382,689.22 0.00 -1,851.61 68.30 262.00 3,896.08 3,847.18 -563.13 -5,243.51 6,003,272.00 382,606.51 0.00 -1,878.75 68.30 262.00 3,933.05 3,884.15 -576.06 -5,335.51 6,003,260.45 382,514.32 0.00 -1,909.00 68.30 262.00 3,970.02 3,921.12 -588.99 -5,427.52 6,003,248.91 382,422.14 0.00 -1,939.25 68.30 262.00 4,007.00 3,958.10 -601.92 -5,519.53 6,003,237.36 382,329.95 0.00 -1,969.50 68.30 262.00 4,008.90 3,960.00 -602.59 -5,524.26 6,003,236.77 382,325.21 0.00 -1,971.05 68.30 262.00 4,023.90 3,975.00 -607.83 -5,561.59 6,003,232.08 382,287.81 0.00 -1,983.32 68.30 262.00 4,043.97 3,995.07 -614.85 -5,611.54 6,003,225.81 382,237.77 0.00 -1,999.75 68.30 262.00 4,080.95 4,032.05 -627.79 -5,703.55 6,003,214.27 382,145.58 0.00 -2,030.00 68.30 262.00 4,117.92 4,069.02 -640.72 -5,795.56 6,003,202.72 382,053.40 0.00 -2,060.25 68.30 262.00 4,130.90 4,082.00 -645.25 -5,827.85 6,003,198.67 382,021.04 0.00 -2,070.86 68.30 262.00 4,154.90 4,106.00 -653.65 -5,887.57 6,003,191.18 381,961.21 0.00 -2,090.50 68.30 262.00 4,191.87 4,142.97 -666.58 -5,979.58 6,003,179.63 381,869.03 0.00 -2,120.75 68.30 262.00 4,228.85 4,179.95 -679.51 -6,071.59 6,003,168.08 381,776.84 0.00 -2,151.00 68.30 262.00 4,265.82 4,216.92 -692.44 -6,163.60 6,003,156.54 381,684.66 0.00 -2,181.25 68.30 262.00 4,302.80 4,253.90 -705.37 -6,255.60 6,003,144.99 381,592.47 0.00 -2,211.49 68.30 262.00 4,339.77 4,290.87 -718.30 -6,347.61 6,003,133.44 381,500.29 0.00 -2,241.74 68.30 262.00 4,376.75 4,327.85 -731.23 -6,439.62 6,003,121.90 381,408.10 0.00 -2,271.99 68.30 262.00 4,413.72 4,364.82 -744.16 -6,531.63 6,003,110.35 381,315.92 0.00 -2,302.24 68.30 262.00 4,450.70 4,401.80 -757.10 -6,623.64 6,003,098.80 381,223.73 0.00 -2,332.49 68.30 262.00 4,487.67 4,438.77 -770.03 -6,715.65 6,003,087.26 381,131.55 0.00 -2,362.74 68.30 262.00 4,524.64 4,475.74 -782.96 -6,807.66 6,003,075.71 381,039.36 0.00 -2,392.99 68.30 262.00 4,561.62 4,512.72 -795.89 -6,899.67 6,003,064.17 380,947.18 0.00 -2,423.24 68.30 262.00 4,598.59 4,549.69 -808.82 -6,991.68 6,003,052.62 380,854.99 0.00 -2,453.49 68.30 262.00 4,635.57 4,586.67 -821.75 -7,083.69 6,003,041.07 380,762.81 0.00 -2,483.74 68.30 262.00 4,672.54 4,623.64 -834.68 -7,175.70 6,003,029.53 380,670.62 0.00 -2,513.99 68.30 262.00 4,709.52 4,660.62 -847.61 -7,267.70 6,003,017.98 380,578.44 0.00 -2,544.24 68.30 262.00 4,746.49 4,697.59 -860.54 -7,359.71 6,003,006.43 380,486.25 0.00 -2,574.49 68.30 262.00 4,783.47 4,734.57 -873.47 -7,451.72 6,002,994.89 380,394.07 0.00 -2,604.74 68.30 262.00 4,820.44 4,771.54 -886.41 -7,543.73 6,002,983.34 380,301.88 0.00 -2,634.99 68.30 262.00 4,857.42 4,808.52 -899.34 -7,635.74 6,002,971.79 380,209.70 0.00 -2,665.24 68.30 262.00 4,894.39 4,845.49 -912.27 -7,727.75 6,002,960.25 380,117.51 0.00 -2,695.49 68.30 262.00 4,931.37 4,882.47 -925.20 -7,819.76 6,002,948.70 380,025.33 0.00 -2,725.74 68.30 262.00 4,968.34 4,919.44 -938.13 -7,911.77 6,002,937.16 379,933.14 0.00 -2,755.99 68.30 262.00 5,005.32 4,956A2 -951.06 -8,003.78 6,002,925.61 379,840.96 0.00 -2,786.24 68.30 262.00 5,042.29 4,993.39 -963.99 -8,095.79 6,002,914.06 379,748.77 0.00 -2,816.49 68.30 262.00 5,079.26 5,030.36 -976.92 -8,187.79 6,002,902.52 379,656.59 0.00 -2,846.74 68.30 262.00 5,116.24 5,067.34 -989.85 -8,279.80 6,002,890.97 379,564.40 0.00 -2,876.99 68.30 262.00 5,153.21 5,104.31 -1,002.78 -8,371.81 6,002,879.42 379,472.22 0.00 -2,907.24 1211712010 3:47:33PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD3-127 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan: CD3-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-127 Design: CD3-127wp03 Planned Survey Measured Vertical Map Map i Depth Inclination Azimuth Depth TVDss +N/S +E/-W Northing Easting DLS Vert Section (ft) V) V) (ft) ft (ft) (ft) (ft) (ft) 6,141.29 10,700.00 68.30 262.00 5,190.19 5,141.29 -1,015.72-8,463.82 6,002,867.88 379,380.03 0.00 -2,937.49 10,800.00 68.30 262.00 5,227.16 5,178.26 -1,028.65-8,555.83 6,002,856.33 379,287.85 0.00 -2,967.73 10,900.00 68.30 262,00 5,264.14 5,215.24 -1,041.58-8,647.84 6,002,844.78 379,195.66 0.00 -2,997.98 11,000.00 68.30 262.00 5,301.11 5,252.21 -1,054.51-8,739.85 6,002,833.24 379,103.48 0.00 -3,028.23 11,100.00 68.30 262.00 5,338.09 5,289.19 -1,067.44-8,831.86 6,002,821.69 379,011.29 0.00 -3,058.48 11,200.00 68.30 262.00 5,375.06 5,326.16 -1,080.37-8,923.87 6,002,810.14 378,919.11 0.00 -3,088.73 11,215.79 68.30 262.00 5,380.90 5,332.00 -1,082.41-8,938.39 6,002,808.32 378,904.55 0.00 -3,093.51 Albian 97 11,300.00 68.30 262.00 5,412.04 5,363.14 -1,093.30-9,015.88 6,002,798.60 378,826.92 0.00 -3,118.98 11,400.00 68.30 262.00 5,449.01 5,400.11 -1,106.23-9,107.88 6,002,787.05 378,734.74 0.00 -3,149.23 11,500.00 68.30 262.00 5,485.99 5,437.09 -1,119.16-9,199.89 6,002,775.51 378,642.55 0.00 -3,179.48 11,600.00 68.30 262.00 5,522.96 5,474.06 -1,132.10-9,291.90 6,002,763.96 378,550.37 0.00 -3,209.73 11,700.00 68.30 262.00 5,559.94 5,511.04 -1,145.03-9,383.91 6,002,752.41 378,458.18 0.00 -3,239.98 11,800.00 68.30 262.00 5,596.91 5,548.01 -1,157.96-9,475.92 6,002,740.87 378,366.00 0.00 -3,270.23 11,900.00 68.30 262.00 5,633.88 5,584.98 -1,170.89-9,567.93 6,002,729.32 378,273.81 0.00 -3,300.48 12,000.00 68.30 262.00 5,670.86 5,621.96 -1,183.82-9,659.94 6,002,717.77 378,181.63 0.00 -3,330.73 12,100.00 68.30 262.00 5,707.83 5,658.93 -1,196.75-9,751.95 6,002,706.23 378,089.44 0.00 -3,360.98 12,159.41 68.30 262.00 5,729.80 5,680.90 -1,204.43-9,806.61 6,002,699.37 378,034.68 0.00 -3,378.95 Start DLS 3.60 TFO-114.00 12,200.00 67.73 260.60 5,745.00 5,696.10 -1,210.13-9,843.81 6,002,694.23 377,997.39 3.50 -3,390.77 12,300.00 66.37 257.09 5,784.00 5,735.10 -1,227.92-9,934.14 6,002,677.80 377,906.81 3.50 -3,415.92 12,399.51 65.10 253.54 5,824.90 5,776.00 -1,250.90-10,021.88 6,002,656.14 377,818.75 3.50 -3,435.28 Albian 96 12,400.00 65.10 253.52 5,825.11 5,776.21 -1,251.03-10,022.31 6,002,656.02 377,818.32 3.50 -3,435.36 12,500.00 63.91 249.87 5,868.17 5,819.27 -1,279.36-10,107.98 6,002,628.99 377,732.24 3.50 -3,449.01 12,600.00 62.81 246.15 5,913.02 5,864.12 -1,312.80-10,190.85 6,002,596.79 377,648.89 3.50 -3,456.83 12,700.00 61.82 242.36 5,959.50 5,910.60 -1,351.24-10,270.59 6,002,559.56 377,568.58 3.50 -3,458.79 12,800.00 60.93 238.51 6,007.42 5,958.52 -1,394.53-10,346.92 6,002,517.43 377,491.61 3.50 -3,454.87 12,900.00 60.15 234.59 6,056.62 6,007.72 -1,442.50-10,419.55 6,002,470.55 377,418.28 3.50 -3,445.10 13,000.00 59.49 230.61 6,106.91 6,058.01 -1,494.98-10,488.20 6,002,419.11 377,348.85 3.50 -3,429.50 13,100.00 58.95 226.58 6,158.10 6,109.20 -1,551.78-10,552.63 6,002,363.29 377,283.58 3.50 -3,408.15 13,200.00 58.54 222.52 6,210.00 6,161.10 -1,612.68-10,612.59 6,002,303.31 377,222.72 3.50 -3,381.11 13,300.00 58.26 218.42 6,262.41 6,213.51 -1,677.45-10,667.85 6,002,239.38 377,166.50 3.50 -3,348.49 13,400.00 58.11 214.31 6,315.15 6,266.25 -1,745.85-10,718.22 6,002,171.75 377,115.11 3.50 -3,310.41 13,500.00 58.09 210.18 6,368.01 6,319.11 -1,817.63-10,763.50 6,002,100.66 377,068.76 3.50 -3,267.01 13,600.00 58.21 206.06 6,420.80 6,371.90 -1,892.52-10,803.52 6,002,026.39 377,027.62 3.50 -3,218.45 13,700.00 58.45 201.96 6,473.32 6,424.42 -1,970.24-10,838.14 6,001,949.21 376,991.84 3.50 -3,164.92 13,789.25 58.79 198.32 6,519.80 6,470.90 -2,041.75-10,864.37 6,001,878.10 376,964.54 3.50 -3,113.11 Start DLS 2.00 TFO 0.00 13,800.00 59.00 198.32 6,525.36 6,476.46 -2,050.49-10,867.27 6,001,869.41 376,961.52 2.00 -3,106.63 13,900.00 61.00 198.32 6,575.35 6,526.45 -2,132.70-10,894.49 6,001,787.62 376,933.06 2.00 -3,045.74 13,903.20 61.06 198.32 6,576.90 6,528.00 -2,135.36-10,895.37 6,001,784.98 376,932.15 2.00 -3,043.78 Top HRZ 14,000.00 63.00 198.32 6,622.30 6,573.40 -2,216.52-10,922.25 6,001,704.24 376,904.05 2.00 -2,983.67 14,100.00 65.00 198.32 6,666.13 6,617.23 -2,301.84-10,950.50 6,001,619.37 376,874.52 2.00 -2,920.48 1211712010 3:47:33PM Page 6 COMPASS 2003.16 Build 69 HALLIBURTON Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: Plan: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wp03 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W (ft) (°) (°) (ft) ft (ft) (ft) 14,120.68 65.41 198.32 6,674.80 6,625.90 -2,319.65-10,956.41 Start DLS 3.27 TFO -66.75 14,191.89 66.35 195.99 6,703.90 6,655.00 -2,381.75-10,975.57 Base HRZ 14,200.00 66.46 195.73 6,707.15 6,658.25 -2,388.90-10,977.60 14,300.00 67.84 192.51 6,745.99 6,697.09 -2,478.26-11,000.06 14,323.79 68.17 191.75 6,754.90 6,706.00 -2,499.82-11,004.70 K-1 14,400.00 69.28 189.36 6,782.55 6,733.65 -2,569.63-11,017.70 14,420.91 69.59 188.71 6,789.90 6,741.00 -2,588.97-11,020.78 Top Kuparuk D 14,500.00 70.77 186.27 6,816.72 6,767.82 -2,662.73-11,030.46 14,578.86 71.99 183.87 6,841.90 6,793.00 -2,737.16-11,037.06 Top Kuparuk C 14,600.00 72.32 183.23 6,848.38 6,799.48 -2,757.25-11,038.30 14,601.72 72.35 183.18 6,848.90 6,800.00 -2,758.88-11,038.39 LCU 14,605.02 72.40 183.08 6,849.90 6,801.00 -2,762.02-11,038.57 Top Nuiqsut 14,700.00 73.91 180.25 6,877.43 6,828.53 -2,852.88-11,041.20 14,780.70 75.23 177.88 6,898.90 6,850.00 -2,930.65-11,039.92 Base Nuiqsut 14,800.00 75.55 177.31 6,903.77 6,854.87 -2,949.31-11,039.14 14,900.00 77.22 174.42 6,927.32 6,878.42 -3,046.23-11,032.13 15,000.00 78.92 171.57 6,948.00 6,899.10 -3,143.32-11,020.19 15,100.00 80.64 168.75 6,965.75 6,916.85 -3,240.27-11,003.37 15,200.00 82.39 165.96 6,980.50 6,931.60 -3,336.76-10,981.72 15,234.58 83.00 165.00 6,984.90 6,936.00 -3,369.97-10,973.12 Start 50.00 hold at 15234.58 MD - Top Nechelik - 7-5/8" X 9-7/8" 15,284.58 83.00 165.00 6,990.99 6,942.09 -3,417.90-10,960.28 Start Build 3.06 15,300.00 83.47 165.00 6,992.81 6,943.91 -3,432.69-10,956.31 15,400.00 86.52 165.00 7,001.54 6,952.64 -3,528.91-10,930.53 15,493.97 89.38 165.00 7,004.90 6,956.00 -3,619.61-10,906.23 Start DLS 2.00 TFO -90.11 15,500.00 89.38 164.88 7,004.97 6,956.07 -3,625.43-10,904.66 15,600.00 89.38 162.88 7,006.05 6,957.15 -3,721.49-10,876.90 15,700.00 89.37 160.88 7,007.14 6,958.24 -3,816.52-10,845.80 15,800.00 89.37 158.88 7,008.24 6,959.34 -3,910.40-10,811.40 15,900.00 89.37 156.88 7,009.33 6,960.43 -4,003.03-10,773.75 16,000.00 89.37 154.88 7,010.43 6,961.53 -4,094.29-10,732.89 16,100.00 89.37 152.88 7,011.53 6,962.63 -4,184.07-10,688.87 16,200.00 89.37 150.88 7,012.63 6,963.73 -4,272.25-10,641.74 16,300.00 89.37 148.88 7,013.72 6,964.82 -4,358.74-10,591.56 16,400.00 89.38 146.88 7,014.81 6,965.91 -4,443.42-10,538.40 ConocoPhillips Standard Proposal Report Well Plan: CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature Map Map Northing Easting DLS Vert Section (ft) (ft) 6,626.90 6,001,601.64 376,868.35 2.00-2,907.28 6,001,539.84 376,848.26 3.27-2,860.65 6,001,532.72 376,846.12 3.27-2,855.20 6,001,443.72 376,822.32 3.27-2,785.78 6,001,422.23 376,817.36 3.27-2,768.67 6,001,352.63 376,803.31 3.27 -2,712.37 6,001,333.35 376,799.95 3.27 -2,696.54 6,001,259.75 376,789.16 3.27 -2,635.22 6,001,185.43 376,781.45 3.27 -2,571.89 6,001,165.36 376,779.90 3.27 -2,554.56 6,001,163.73 376,779.78 3.27 -2,553.15 6,001,160.59 376,779.57 3.27 -2,550.42 6,001,069.80 376,775.57 3.27 -2,470.67 6,000,992.02 376,775.68 3.27 -2,400.79 6,000,973.35 376,776.18 3.27 -2,383.81 6,000,876.35 376,781.73 3.27 -2,294.27 6,000,779.09 376,792.21 3.27 -2,202.34 6,000,681.91 376,807.57 3.27 -2,108.32 6,000,585.11 376,827.77 3.27 -2,012.52 6,000,551.79 376,835.87 3.27 -1,979.03 6,000,503.67 376,847.99 0.00 -1,930.49 6,000,488.82 376,851.73 3.05-1,915.51 6,000,392.24 376,876.06 3.05-1,818.08 6,000,301.19 376,898.99 3.05-1,726.23 6,000,295.34 376,900.47 2.00 -1,720.33 6,000,198.89 376,926.79 2.00 -1,622.14 6,000,103.41 376,956.45 2.00 -1,523.35 6,000,009.03 376,989.43 2.00 -1,424.08 5,999,915.85 377,025.68 2.00 -1,324.45 5,999,824.00 377,065.17 2.00 -1,224.59 5,999,733.58 377,107.83 2.00 -1,124.61 5,999,644.70 377,153.63 2.00 -1,024.64 5,999,557.48 377,202.50 2.00 -924.80 5,999,472.01 377,254.38 2.00 -825.21 1211712010 3:47:33PM Page 7 COMPASS 2003.16 Build 69 0 R I G'1 NL HALLIBURTON Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: Plan: CD3-127 Wellbore: Plan: CD3-127 Design: CD3-127wp03 Planned Survey Measured Vertical Depth Inclination Azimuth Depth 16,500.00 89.38 144.88 7,015.90 16,526.74 89.38 144.34 7,016.19 16,526.83 89.38 144.34 7,016.19 Start 5809.71 hold at 16526.83 MD 16,600.00 89.38 144.34 7,016.98 16,700.00 89.38 144.34 7,018.06 16,800.00 89.38 144.34 7,019.14 16,900.00 89.38 144.34 7,020.22 17,000.00 89.38 144.34 7,021.29 17,100.00 89.38 144.34 7,022.37 17,200.00 89.38 144.34 7,023.45 17,300.00 89.38 144.34 7,024.53 17,400.00 89.38 144.34 7,025.61 17,500.00 89.38 144.34 7,026.69 17,600.00 89.38 144.34 7,027.77 17,700.00 89.38 144.34 7,028.85 17,800.00 89.38 144.34 7,029.93 17,900.00 89.38 144.34 7,031.01 18,000.00 89.38 144.34 7,032.09 18,100.00 89.38 144.34 7,033.17 18,200.00 89.38 144.34 7,034.25 18,300.00 89.38 144.34 7,035.33 18,400.00 89.38 144.34 7,036.41 18,500.00 89.38 144.34 7,037.49 18,600.00 89.38 144.34 7,038.57 18,700.00 89.38 144.34 7,039.65 18,800.00 89.38 144.34 7,040.73 18,900.00 89.38 144.34 7,041.81 19,000.00 89.38 144.34 7,042.89 19,100.00 89.38 144.34 7,043.97 19,200.00 89.38 144.34 7,045.05 19,300.00 89.38 144.34 7,046.13 19,400.00 89.38 144.34 7,047.21 19,500.00 89.38 144.34 7,048.29 19,600.00 89.38 144.34 7,049.37 19,700.00 89.38 144.34 7,050.44 19,800.00 89.38 144.34 7,051.52 19,900.00 89.38 144.34 7,052.60 20,000.00 89.38 144.34 7,053.68 20,100.00 89.38 144.34 7,054.76 20,200.00 89.38 144.34 7,055.84 20,300.00 89.38 144.34 7,056.92 20,400.00 89.38 144.34 7,058.00 20,500.00 89.38 144.34 7,059.08 20,600.00 89.38 144.34 7,060.16 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature Map Map TVDss +N/S +E/-W Northing Easting DLS Vert Section ft (ft) (ft) (ft) (ft) 6,967.00 6,967.00 -4,526.20 -10,482.31 5,999,388.41 377,309.21 2.00 -726.00 6,967.29 -4,548.00 -10,466.82 5,999,366.39 377,324.37 2.00 -699.54 6,967.29 -4,548.07 -10,466.77 5,999,366.31 377,324.42 0.00 -699.45 6,968.08 -4,607.52 -10,424.12 5,999,306.23 377,366.17 0.00 -627.12 6,969.16 -4,688.77 -10,365.83 5,999,224.13 377,423.23 0.00 -528.27 6,970.24 -4,770.01 -10,307.54 5,999,142.02 377,480.28 0.00 -429.41 6,971.32 -4,851.26 -10,249.25 5,999,059.91 377,537.34 0.00 -330.56 6,972.39 -4,932.51 -10,190.96 5,998,977.80 377,594.40 0.00 -231.70 6,973.47 -5,013.76 -10,132.67 5,998,895.70 377,651.45 0.00 -132.85 6,974.55 -5,095.01 -10,074.38 5,998,813.59 377,708.51 0.00 -33.99 6,975.63 -5,176.25 -10,016.10 5,998,731.48 377,765.57 0.00 64.86 6,976.71 -5,257.50 -9,957.81 5,998,649.37 377,822.63 0.00 163.72 6,977.79 -5,338.75 -9,899.52 5,998,567.27 377,879.68 0.00 262.57 6,978.87 -5,420.00 -9,841.23 5,998,485.16 377,936.74 0.00 361.43 6,979.95 -5,501.25 -9,782.94 5,998,403.05 377,993.80 0.00 460.28 6,981.03 -5,582.49 -9,724.65 5,998,320.95 378,050.85 0.00 559.14 6,982.11 -5,663.74 -9,666.36 5,998,238.84 378,107.91 0.00 657.99 6,983.19 -5,744.99 -9,608.07 5,998,156.73 378,164.97 0.00 756.85 6,984.27 -5,826.24 -9,549.78 5,998,074.62 378,222.03 0.00 855.70 6,985.35 -5,907.48 -9,491.49 5,997,992.52 378,279.08 0.00 954.56 6,986.43 -5,988.73 -9,433.20 5,997,910.41 378,336.14 0.00 1,053.41 6,987.51 -6,069.98 -9,374.91 5,997,828.30 378,393.20 0.00 1,152.27 6,988.59 -6,151.23 -9,316.63 5,997,746.19 378,450.25 0.00 1,251.12 6,989.67 -6,232.48 -9,258.34 5,997,664.09 378,507.31 0.00 1,349.98 6,990.75 -6,313.72 -9,200.05 5,997,581.98 378,564.37 0.00 1,448.83 6,991.83 -6,394.97 -9,141.76 5,997,499.87 378,621.43 0.00 1,547.69 6,992.91 -6,476.22 -9,083.47 5,997,417.77 378,678.48 0.00 1,646.54 6,993.99 -6,557.47 -9,025.18 5,997,335.66 378,735.54 0.00 1,745.40 6,995.07 -6,638.71 -8,966.89 5,997,253.55 378,792.60 0.00 1,844.25 6,996.15 -6,719.96 -8,908.60 5,997,171.44 378,849.65 0.00 1,943.11 6,997.23 -6,801.21 -8,850.31 5,997,089.34 378,906.71 0.00 2,041.97 6,998.31 -6,882.46 -8,792.02 5,997,007.23 378,963.77 0.00 2,140.82 6,999.39 -6,963.71 -8,733.73 5,996,925.12 379,020.83 0.00 2,239.68 7,000.47 -7,044.95 -8,675.45 5,996,843.01 379,077.88 0.00 2,338.53 7,001.54 -7,126.20 -8,617.16 5,996,760.91 379,134.94 0.00 2,437.39 7,002.62 -7,207.45 -8,558.87 5,996,678.80 379,192.00 0.00 2,536.24 7,003.70 -7,288.70 -8,500.58 5,996,596.69 379,249.05 0.00 2,635.10 7,004.78 -7,369.95 -8,442.29 5,996,514.59 379,306.11 0.00 2,733.95 7,005.86 -7,451.19 -8,384.00 5,996,432.48 379,363.17 0.00 2,832.81 7,006.94 -7,532.44 -8,325.71 5,996,350.37 379,420.22 0.00 2,931.66 7,008.02 -7,613.69 -8,267.42 5,996,268.26 379,477.28 0.00 3,030.52 7,009.10 -7,694.94 -8,209.13 5,996,186.16 379,534.34 0.00 3,129.37 7,010.18 -7,776.18 8,150.84 5,996,104.05 379 591.40 0.00 3,228.23 7,011.26 -7,857.43 8,092.55 5,996,021.94 379 648.45 0.00 3,327.08 1211712010 3:47:33PM Page 8 COMPASS 2003.16 Build 69 ORIGINAL HALLIBURTON ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: EDM v16 Prod ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3-127 Plan: CD3-127 CD3-127wp03 Local Co-ordinate Reference: Well Plan: CD3-127 TVD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) MD Reference: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature 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) 7,012.34 20,700.00 89.38 144.34 7,061.24 7,012.34 -7,938.68 -8,034.26 5,995,939.83 379,705.51 0.00 3,425.94 20,800.00 89.38 144.34 7,062.32 7,013.42 -8,019.93 -7,975.98 5,995,857.73 379,762.57 0.00 3,524.79 20,900.00 89.38 144.34 7,063.40 7,014.50 -8,101.18 -7,917.69 5,995,775.62 379,819.62 0.00 3,623.65 21,000.00 89.38 144.34 7,064.48 7,015.58 -8,182.42 -7,859.40 5,995,693.51 379,876.68 0.00 3,722.50 21,100.00 89.38 144.34 7,065.56 7,016.66 -8,263.67 -7,801.11 5,995,611.41 379,933.74 0.00 3,821.36 21,200.00 89.38 144.34 7,066.64 7,017.74 -8,344.92 -7,742.82 5,995,529.30 379,990.80 0.00 3,920.21 21,300.00 89.38 144.34 7,067.72 7,018.82 -8,426.17 -7,684.53 5,995,447.19 380,047.85 0.00 4,019.07 21,400.00 89.38 144.34 7,068.80 7,019.90 -8,507.42 -7,626.24 5,995,365.08 380,104.91 0.00 4,117.92 21,500.00 89.38 144.34 7,069.88 7,020.98 -8,588.66 -7,567.95 5,995,282.98 380,161.97 0.00 4,216.78 21,600.00 89.38 144.34 7,070.96 7,022.06 -8,669.91 -7,509.66 5,995,200.87 380,219.02 0.00 4,315.63 21,700.00 89.38 144.34 7,072.04 7,023.14 -8,751.16 -7,451.37 5,995,118.76 380,276.08 0.00 4,414.49 21,800.00 89.38 144.34 7,073.12 7,024.22 -8,832.41 -7,393.08 5,995,036.65 380,333.14 0.00 4,513.34 21,900.00 89.38 144.34 7,074.20 7,025.30 -8,913.65 -7,334.80 5,994,954.55 380,390.20 0.00 4,612.20 22,000.00 89.38 144.34 7,075.28 7,026.38 -8,994.90 -7,276.51 5,994,872.44 380,447.25 0.00 4,711.05 22,100.00 89.38 144.34 7,076.36 7,027.46 -9,076.15 -7,218.22 5,994,790.33 380,504.31 0.00 4,809.91 22,200.00 89.38 144.34 7,077.44 7,028.54 -9,157.40 -7,159.93 5,994,708.23 380,561.37 0.00 4,908.76 22,300.00 89.38 144.34 7,078.52 7,029.62 -9,238.65 -7,101.64 5,994,626.12 380,618.42 0.00 5,007.62 22,335.64 89.38 144.34 7,078.90. 7,030.00 -9,267.60 -7,080.87 5,994,596.86 380,638.76 0.00 5,042.85 CD3-K 25May10 Toe Targets Target Name - hittmiss target Dip Angle Dip Dir. TVD +N/S +E/ W Northing Easting - Shape (°) (°) (ft) (ft) (ft) (ft) (ft) CD3-K 25Mayl0 Toe 0.00 0.00 7,078.90 -9,267.60-7,080.87 5,994,596.86 380,638.76 - plan hits target center - Point CD3-K 25Mayl0 Heel 0.00 0.00 6,984.90 -3,534.97-11,078.10 6,000,388.39 376,728.43 plan misses target center by 144.82ft at 15366.33ft MD (6999.19 TVD,-3496.46 N,-10939.23 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (11) (11) 3,289.01 2,450.00 10-3/4" x 13-1/2" 10-3/4 13-1/2 15,234.58 6,984.90 7-5/8" X 9-7/8" 7-5/8 9-7/8 22,336.55 7,078.91 3-1/2" x 6-3/4" 3-1/2 6-3/4 1211712010 3:47:33PM Page 9 COMPASS 2003.16 Build 69 ,�^1i` ConocoPhillips HALLIBURTON Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: EDM v16 Prod ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3-127 Plan: CD3-127 CD3-127wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: CD3-127 Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Plan: 36.3+12.6 @ 48.90ft (Doyon 19) True Minimum Curvature Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology 14,323.79 6,754.90 K-1 14,605.02 6,849.90 Top Nuiqsut 14,191.89 6,703.90 Base HRZ 14,780.70 6,898.90 Base Nuiqsut 15,234.58 6,984.90 Top Nechelik 7,835.10 4,130.90 K-2 Basal 3,367.17 2,478.90 C-30 4,397.61 2,859.90 C-20 13,903.20 6,576.90 Top HRZ 7,545.71 4,023.90 Qannik K-2 14,578.86 6,841.90 Top Kuparuk C 14,420.91 6,789.90 Top Kuparuk D 1,236.16 1,221.90 Base Permafrost 0.00 11,215.79 5,380.90 Albian 97 7,505.14 4,008.90 K-3 Basal 14,601.72 6,848.90 LCU 2,912.81 2,310.90 C-40 0.00 12,399.51 5,824.90 Albian 96 7,110.28 3,862.90 K-3 Plan Annotations Measured Vertical Depth Depth (ft) (ft) 349.80 349.80 599.98 599.80 902.45 899.80 1,002.45 997.73 2,654.80 2,215.50 12,159.41 5,729.80 13,789.25 6,519.80 14,120.68 6,674.80 15,234.58 6,984.90 15,284.58 6,990.99 15,493.97 7,004.90 16,526.83 7,016.19 22,336.55 1211712010 3:47:33PM Local Coordinates +N/-S +E/-W (ft) (ft) Comment 0.00 0.00 Start Build 1.50 5.37 -6.18 Start DLS 2.20 TFO -5.00 28.62 -35.25 Start DLS 3.00 TFO -35.00 39.78 -52.10 Start DLS 3.53 TFO -42.33 24.61 -1,061.51 Start 9504.61 hold at 2654.80 MD -1,204.43 -9,806.61 Start DLS 3.50 TFO-114.00 -2,041.75 -10,864.37 Start DLS 2.00 TFO 0.00 -2,319.65 -10,956.41 Start DLS 3.27 TFO -66.75 -3,369.97 -10,973.12 Start 50.00 hold at 15234.58 MD -3,417.90 -10,960.28 Start Build 3.05 -3,619.61 -10,906.23 Start DLS 2.00 TFO -90.11 -4,548.07 -10,466.77 Start 5809.71 hold at 16526.83 MD TD at 22336.55 Page 10 COMPASS 2003.16 Build 69 ! A L CD ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3-127 Plan: CD3-127 CD3-127wp03 Sperry Drilling Services Clearance Summary Anticollision Report 17 December, 2010 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3-127 - Plan: CD3-127 - CD3-127wp03 Well Coordinates: 6,003,503.45 N, 1,527,889.34 E (70° 25' 07.94" N, 150' 55' 00.20" W) Datum Height: Plan: 36.3+12.6 @ 48.90ft (Doyon 19) Scan Range: 0.00 to 22,336.55 ft. Measured Depth. Scan Radius is 2,430.02 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services ConocoPhillips(Alaska) Inc. -WNS HAI= ,LIBURTONn Western North Slope Anticollision Report for Plan: CD3-127 - CD3-127wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3-127 - Plan: CD3-127 - CD3-127wp03 Scan Range: 0.00 to 22,336.55 ft. Measured Depth. Scan Radius is 2,430.02 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad CD3-112 - CD3-112 - CD3-112 612.67 292.63 612.67 281.88 625.00 27.221 Centre Distance Pass - Major Risk CD3-112 - CD3-112 - CD3-112 1,087.46 298.20 1,087.46 279.77 1,150.00 16.182 Clearance Factor Pass - Major Risk CD3-114 - CD3-114 - CD3-114 372.95 259.59 372.95 252.27 375.00 35.469 Centre Distance Pass - Major Risk CD3-114 - CD3-114 - CD3-114 517.30 261.40 517.30 251.27 525.00 25.810 Clearance Factor Pass - Major Risk CD3-115 - CD3-115 - CD3-115 1,634.62 180.96 1,634.62 154.30 1,750.00 6.788 Centre Distance Pass - Major Risk ✓ CD3-115 - CD3-115 - CD3-115 1,679.33 181.10 1,679.33 153.99 1,800.00 6.682 Clearance Factor Pass - Major Risk CD3-117 - CD3-117 - CD3-117 961.79 168.82 961.79 �:!\ 1,000.00 9.358 Centre Distance Pass -Major Risk CD3-117 - CD3-117 - CD3-117 14,388.06 250.67 14,388.06 75.64 14,025.00 1.432 Clearance Factor Pass - Major Risk CD3-118 - CD3-118 - CD3-118 1,225.41 131.35 1,225.41 1114§- 1,275.00 6.503 Centre Distance Pass - Major Risk CD3-118 - CD3-118 - CD3-118 1,387.04 132.81 1,387.04 109.76 1,450.00 5.762 Clearance Factor Pass - Major Risk CD3-121 - CD3-121 - CD3-121 546.19 114.90 546.19 105.35 550.00 12.029 Centre Distance Pass - Major Risk CD3-121 - CD3-121 - CD3-121 595.38 115.28 595.38 104.89 600.00 11.096 Clearance Factor Pass - Major Risk CD3-122 - CD3-122 - CD3-122 399.48 97.07 399.48 89.99 400.00 13.700 Centre Distance Pass - Major Risk CD3-122 - CD3-122 - CD3-122 572.02 98.25 572.02 88.22 575.00 9.797 Clearance Factor Pass - Major Risk CD3-123 - CD3-123 - CD3-123 695.50 69.23 695.50 55.61 700.00 5.082 Centre Distance Pass - Major Risk CD3-123 - CD3-123 - CD3-123 744.66 69.66 744.66 55.06 750.00 4.771 Clearance Factor Pass - Major Risk CD3-124 - CD3-124 - CD3-124 720.23 53.52 720.23 40.35 725.00 4.062 Centre Distance Pass - Major Risk CD3-124 - CD3-124 - CD3-124 769.16 53.81 769.16 39.95 775.00 3.881 Clearance Factor Pass - Major Risk CD3-316 - CD3-316 - CD3-316 566.65 218.55 566.65 208.02 575.00 20.763 Centre Distance Pass - Major Risk CD3-316 - CD3-316 - CD3-316 590.67 218.68 590.67 207.82 600.00 20.132 Clearance Factor Pass - Major Risk CD3-316 - CD3-316A - CD3-316A 566.65 218.55 566.65 208.02 575.00 20.763 Centre Distance Pass - Major Risk CD3-316 - CD3-316A - CD3-316A 590.67 218.68 590.67 207.82 600.00 20.132 Clearance Factor Pass - Major Risk CD3-316 - CD3-316APB1 - CD3-316APB1 566.65 218.55 566.65 208.02 575.00 20.763 Centre Distance Pass - Major Risk CD3-316 - CD3-316APB1 - CD3-316APB1 590.67 218.68 590.67 207.82 600.00 20.132 Clearance Factor Pass - Major Risk Plan: CD3-119 - Plan: CD3-119 - CD3-119wp07 224.80 159.81 224.80 155.41 225.00 36.330 Centre Distance Pass - Major Risk Plan: CD3-119 - Plan: CD3-119 - CD3-119wp07 398.53 161.07 398.53 153.27 400.00 20.657 Clearance Factor Pass - Major Risk Plan: CD3-119 - Plan: CD3-119 - CD3-119wp06 398.62 159.32 398.62 151.57 400.00 20.552 Centre Distance Pass - Major Risk Plan: CD3-119 - Plan: CD3-119 - CD3-119wp06 594.07 161.30 594.07 149.73 600.00 13.941 Clearance Factor Pass - Major Risk 17 December, 2010 - 10:56 Page 2 of 6 COMPASS Con ocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3-127 - CD3-127wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3-127 - Plan: CD3-127 - CD3-127wp03 Scan Range: 0.00 to 22,336.55 ft. Measured Depth. Scan Radius is 2,430.02 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Plan: CD3-120 - Plan: CD3-120 - CD3-120wp06 349.80 139.80 349.80 132.95 350.00 20.414 Centre Distance Pass - Major Risk Plan: CD3-120 - Plan: CD3-120 - CD3-120wp06 472.11 140.78 472.11 131.55 475.00 15.266 Clearance Factor Pass - Major Risk Plan: CD3-125 - Plan: CD3-125 - CD3-125wp04 474.10 39.36 474.10 31.01 475.00 4.715 Centre Distance Pass - Major Risk Plan: CD3-125 - Plan: CD3-125 - CD3-125wp04 747.25 41.14 747.25 28.05 750.00 3.143 Clearance Factor Pass - Major Risk Plan: CD3-126 - Plan: CD3-126 - CD3-126wp04 549.37 18.07 549.37 8.45 550.00 1.878 Centre Distance Pass - Major Risk Plan: CD3-126 - Plan: CD3-126 - CD3-126wp04 749.11 19.56 749.11 6.43 750.00 1.489 Clearance Factor Pass - Major Risk O Plan: CD3-128 - Plan: CD3-128 - CD3-128wp02 625.32 17.11 625.32 4.95 625.00 1.407 Centre Distance Pass - Major Risk Plan: CD3-128 - Plan: CD3-128 - CD3-128wp02 675.32 17.64 675.32 4.50 675.00 1.343 Clearance Factor Pass - Major Risk Plan: CD3-129 - Plan: CD3-129 - CD3-129wp01 475.56 39.74 475.56 30.48 475.00 4.291 Centre Distance Pass - Major Risk Plan: CD3-129 - Plan: CD3-129 - CD3-129wp01 601.28 40.81 601.28 29.12 600.09 3.492 Clearance Factor Pass - Major Risk --- WNS Non -Pad 1 Q0 0.548 Centre Distance FAIL - Major Risk 1 llllri 0.648 Clearance Factor FAIL - Major Risk huge ellipses Survey tool program Gyrodata tool From To Survey/Plan Survey Tool (ft) (ft) 36.30 1,400.00 CD3-127wp03 GYD-GC-SS 1,399.80 3,289.01 CD3-127wp03 MWD+IFR-AK-CAZ-SC 3,289.01 15,234.58 CD3-127wp03 MWD+IFR-AK-CAZ-SC 15,234.58 22,336.55 CD3-127wp03 MWD+IFR-AK-CAZ-SC 17 December, 2010 - 10:56 Page 3 of 6 COMPASS CD3-127wpO3 36.30 To 22336.55 si Major Risk GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Ellipsoid Color 36 250 1250 1500 3500 4250 9250 11750 19750 21250 250 500 1500 1750 4250 5250 11750 --- 14250 21250 22250 500 750 1750 2250 5250 6250 14250 16250 22250 23250 750 1000 2250 ---- 2750 6250 7750 16250 18250 23250 24000 1000 1250 2750 3500 7750------- 9250 18250 19750 2400D 24500 SECTION DETAILS 11:22, December 17 2010 Sec MD Inc Azi TVD +N/-S +E/-w Meg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 3W25 2.20 5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 52.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 -42.33 503.84 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0.00 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.00-3113.11 9 14120.68 65.41 198.32 6674.80-2319+65-10956+41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90-3369.97-10973.12 3.27 -66.75-1979.03 11 15284.58 83.00 165.00 6990.99-3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 69.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89.38 144.34 7016.19 -4548.07-10466.77 2.00 -90.11-699.45 14 22336.55 89.38 144.34 7078.90-9268+23-7080+18 0.00 0.00 5043.72 CD3-K 25May10 Toe 0/3 E-12 30 / 330 30 D3-12 3-126wp0 D312 LEGEND D3-125wp0 -60 / 300 60 -A MA 124, M&124, CO3-124 V6 -60 / �- Plan: CD3-126, Plan: CD3.126, CD3-1 v0 V Plan: CD3-119, Plan: CD3-119, CD3-119,VN VO / -�- CD3-121, CD3-121, CD3-121 VO CD3-112, CD3-172, CD3-112 V3 -�- CD3-115, CD3-775, CD3-115 VO �- CD3-316, CD3316, CD3316 VO $ CD3-316, CD3316APB1, CD331WB1 VO $- C133-316, CD3-316& C0331 W VO / 270 9D -6 - Plan: CD3-128, Plan: CD3.128, CD3-128v90 pan: CD3.129, Plan: CD3.129, CD3-129mO VO VO -90 / 270 r-90 D3-119wp0 NaCCAk 1, Nwhefk 1, NeNleMk 1 VO Ran: CD3-125. pan: 25. CD3-12 VO D3-120wp0 � $ a03-122 1n,c.Coa-1z03.12zv9 _ , $ C33-114, CD1114, CD3-114 V14 _ - - - -� CD3-117, CD3-117, CD3-117 VO D3-11 - CO3-118, CD3-118, C133-118 V0 -� C133-123, CO3-123, CD3-123 VO D3 128wp0 $ Plan: CD3119, Plan CD3-119, CD3-119W0 VO -120 / 240 120 -A- Ran: CD3-120, Plan: MA 120, CD3-12 VO -120 / -$- CD3-127wp03 - - --D3-11 D3-129wp0 Travelling Cylinder Azimuth (TFO+AZI) [] vs Centre to Centre Separation [100 Win] D3-129w D3-12 n 1 pan -180 / 180 D3-128wp0 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] HALLIBURTON ConocoPhillips CD3-127wp03 Alaska Sperry Drilling ANTI -COLLISION SETTINGS 10:53, December 172010 Interpolation Method: MD, interval: 25.00 Depth Range From: 36.30 To 22336.55 Results Limited By: Centre Distance: 2430.02 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1400.00 CD3-127wp03 (Plan: CD3-127) GYD-GC-SS 1399.80 3289.01 CD3-127wp03 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC 3289.01 15234.58 CD3-127wp03 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC 15234.58 22336.55 CD3-127wp03 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 3289.01 10-3/4" x 13-1/2" 10-3/4 6984.90 15234.58 7-5/8" X 9-7/8" 7-5/8 7078.90 22336.55 3-1/2" x 6-3/4" 3-1/2 CD3-117 i ®o M 0➢ ®G ftl f01V Nechelik 1 60 I I I a m U) c a� U $ 30 N � I c N U 0 0 3500 7000 10500 14000 17500 21000 Measured Depth LEGEND CD3-124, CD3-124, CD3-124 VO � CD3-316, CD3-316, C133-316 VO --j--- Plan: CD3-125, Plan: CD3-125, CD3-125wp04W Plan: CD3-119, Plan: CD3-119, CD3-119wp07 VO -�- Plan: CD3-126, Plan: CD3-126, CD3-126wp04B- CD3-316, C133-316AP131, CD3-316APB1 VO-e- CD3-122, CD3-122, C133-122 VO Plan: CD3-120, Plan: CD3-120, CD3-120wp06 VO Plan: CD3-119, Plan: CD3-119, CD3-119wp06W CD3-316, CD3-316A, CD3-316A VO --&- C133-114, CD3-114, CD3-114 V14 CD3-127wp03 CD3-121, CD3-121, CD3-121 VO $- Plan: CD3-128, Plan: CD3-128, CD3-128wp92496- CD3-117, CD3-117, CD3-117 VO CD3-112, CD3-112, CD3-112 V3 Plan: CD3-129, Plan: CD3-129, CD3-129wp0+W CD3-118, CD3-118, CD3-118 VO CD3-115, CD3-115, CD3-115 VO -£- Nechelik 1, Nechelik 1, Nechelik 1 VO CD3-123, CO3-123, CD3-123 VO HALLIBURTQN Phillips Conoco` CD3-127w 03 Sperry Drilling Alaska ANTI -COLLISION SETTINGS 10:53, December 172010 Interpolation Method: MD, interval: 25.00 Depth Range From: 36.30 To 22336.55 Results Limited By: Centre Distance: 2430.02 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1400.00 CD3-127wp03 (Plan: CD3-127) GYD-GC-SS 1399.80 3289.01 CD3-127wp03 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC 3289.01 15234.58 CD3-127wp03 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC 15234.58 22336.55 CD3-127wp03 (Plan: CD3-127) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 3289.01 10-3/4" x 13-1/2" 10-3/4 6984.90 15234.58 7-5/8" X 9-7/8" 7-5/8 7078.90 22336.55 3-1 /2" x 6-3/4" 3-1/2 n 3 3 3 3 o ® o c c V W V U U 0 60 III 12 ... 1 N 0) L O 3p N c U I 0 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND CO3-124, C133-124, CD3.124 VO - CD3-316, CD3-316, CD3-316 VO --I- Plan: C133-125, Plan: CD3-125, CD3-125wp04W Plan: C133-119, Plan: CD3-119, CD3-119wp07 VO - Plan: CD3-126, Plan: C133.126, CD3-126wp04E2�- C133-316, CD3-316APB1, CD3-316APB1 VO-[3- C103-122, CD3-122, CD3-122 VO - Plan: CD3-120, Plan: CD3-120, CD3-120wp06 VO $- Plan: C133-119, Plan: CD3-119, CD3-119wP06W CD3-316, CD3-316A, CD3.316A VO --e- CD3-114, CD3-114, CD3-114 V14 -f3-- CD3-127wp03 -�- CD3-121, CO3-121, CD3-121 VO Plan: CD3-128, Plan: CD3-128, CD3-128wp024$9- CD3-117, CD3-117, CD3-117 VO -�� CD3-112, 0133-112, CD3-112 V3 Plan: CD3-129, Plan: CD3-129, CD3-129wp04*- CD3-118, CD3-118, C103-118 VO �- CD3-115, CD3-115, CD3-115 VO ---I--- Nechelik 1, Nechelik 1, Nechelik 1 VO -.&- CD3-123, CD3-123, CD3-123 VO III i\IVIIIbI1III-- AC wells (NOT a 5i ConocoPhillips(Ala Western Nor CD3 FIUl u v au Easting (4000 Win) 1 -r Ann.., -AG 11:20, December 17 2010 316APB1 CD3-316A Easting (4000 ft/in) C D 3 12 7 w p 0 3 Name WELLBORE TARGET DETAILS (MAP C0.0RDINATES) TVDSS +N/-S +E/-W Northing Easting Shape 13:11, December 17 2010 CD3-K 25May10 Heel 6936.00 -3535.99-11077.886000135.1,0516760.37 Circle (Radius: 1320,00) QuarterMile View CD3-K 25May10 Toe 7030.00-9268.23-7080.18i994343.791520670.87 Circle (Radius: 1320.00) 3000 U c o -3000 CO Z -6000 +-r 0 -12000 13694 - TD - -- - 15654 - TD o W w v � I W Lic G li ,yg GO,y,� o� e 15234 - TD - 1 Nechelik 6900 - 7000 ssTVD -18000 -15000 -12000 -9000 -6000 -3000 0 West( -)/East(+) (3000 Win) 3000 6000 CP da'. CanuNldb.(Abkq Fc.-VMs 6idCarrMbn: -0!M lab No: RN/A MYS W.tl�n Nalh SbpR Mlgp kD. dbn: w0 l APF N. .N/A 'MIR C 3-127w 0 DR. .UIV AMNc .N/A Rig .N/A D09bgw 1w 11 S,M—JMR--. Mbm Sw WN s�tPc. wcdim Ofigind VS Plane: 16100 .oM w.[ Pb.rn2.1n x 1527-3. rt View VS Plane: 15100 RRR HW h1: .s..D . V: 60D 503tt Wl syA.m: APi.d .O SMbn IVS) PM1ww: Sk/ Comments: POOL:'" vi S CD3-127wp03 Plan. 15234 to 22336.55 MD CD3-117: 15654' to 21597' MD CD3-118: 13694' to 21228' MD Nechelik 1: 6900' to 7000' TVDss 0 Z L Q m C, U t m 1 N 2 E 1D Coaft PrWew i --_- - j j _ I _------- 1 ---------------- I - 600 600 - ----- --- ------ -- --- -- --- - --- s --- 599 Verticd Section dong "View VS Plane' Page 1 oil (CD3-127qp03 TodboxAs) 0 u I 6003000 2000 1000 6000000 999000 8000 7000 6000 soon 4000 3000 arm 6500 7500 12/17/2010 2:10 PM PoolSummaryl Closest in POOL Closest Approach: Reference Well: CD3-127wp03 Plan Offset Well: C133-118 Coords. - Coords. - ASP ASP 3-D dr-tr Mess. Ind. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance. Depth Angle Azi. TVD E(+)/W(- (153) Comments Depth Angle Azi. TVD E(+)/W(- (153) Comments rOUCT m Distance (1820.98 i Distance (1820.98 ft) in POOL (15234 ft) in POOL (15234 - 22336.55 MD) to - 22336.55 MD) to CD3-118 (13694 - CD3-127wp03 Plan 1 15234.58 83 165 6935.967 6000299 1516W -1978.98 21228 MD) 13669 84.61 325.47 6891.31 6001928 1517678 -3124.86 (13694- 21228 MD Closest Approach: Reference Well: CD3-127wp03 Plan Offset Well: Nechelik 1 words. - Coords. - ASP ASP 3-D ctr-ctr Mess. Incl. TRUE Subsea N(+)/S(-) View Vs Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance. Depth Angle Azi T`✓D E(+)/W(- (153) ments Depth Angle Azi. TVD E(+)/W(- (153) ments POOL n Distance (712.16 ft) Distance in POOL (15234 - in POOL (15234 - 22336.55 MD) to 22336.55 MD) to CD3-127wp03 Plan Nechelik 1 (6900 - (6900 - 7000 712.16 71(3t>) 89 38 1M 34 7022 71 5994906 1520279 4365.06 7000 TVDss) 70631 0.5 -0.02 7005.46 5994500 1519694 -309.43 TVDss) Closest Approach: Reference Well: CD3-127wp03 Plan Offset Well: CD3-117 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Ind. TRUE Subsea N(+)/S(-) View VS Distance. Depth Angle Azi. TVD E(+)/W(- (153) Comments Depth Angle Azi. TVD E(+)/W(- (153) Comments IIUUL m Distance (2096.04 POOL Min Distance (2096.04 ft) in POOL (15234 ft) in POOL (15234 - 22336.55 MD) to - 22336.55 MD) to C133.117 (15654 - CD3-127wp03 Plan 2096 152:i4 53 83 165 6935.967 6000299 1516867 -1978.98 21597 MD) 15629.7 83.41 328.15 6901.25 6001986 1515624 -4085.89 (15654 - 21597 MD 12/17/2010 2:33 PM CD3-127wpO3 36.30 To 501.00 -90 / 51 36 250 500 750 1000 GLOBAL FILTER APPLIED: All wellpaths within 2004 100/1000 of reference Ellipsoid Color 250 1250 1500 3500 4250 9250 11750 19750 21250 500 1500 1750 4250 5250 11750 - 14250 21250 22250 750 1750 __ 2250 5250 6250 14250 16250 22250 23250 ---------- --- 1000 2250 -------- ..----- 2750 6250 7750 16250 18250 23250 240DO 1250 2750 3500 T750 9250 18250 19750 24000 246W 01360 -180 / 180 LEGEND -A- C133-124, CD3-124, CO3-124 V0 -�- Plan: CD3126, Plan: CO3-126, C031 VO Ran: CD3-119, Plan: CD3-119, CD3.119,PM VO CD3.121, C03121, CD3-121 VO - CMA12, CD3Al2, CD3,112 V3 CD3115, CD3.115, CD3-115 VO CD3316, CD3316, CD3316 VO $- CD3316, CD3318APB1, CD3316A 131 VO CD3316, CD3-316& C03316A VO -e- Ran: CD3128, Plan: CD3128, CWA28v 0 VO Ran: CD3129, Ran: CD3129, CWA2' 8 VO -�- Nx llk 1, Nftl a k 1, Nmhebk 1 VO �- Ran: C03125, Ran: C03125, C0312 VO -�- C133122, CD3.122, CD3122 VO CD3114, M3-114, C133114 V14 C133117, CD3117, C133117 VO CD3118, CD3418, CO3.118 VO CD3.123, C133.123, C133-123 VO Ran: CO3-119, Ran: CO3-119, C133119wp0 VO Ran: C03120, Plan: 003120, C031 VO CD3127wpO3 SECTION DETAILS 1 11:24, December 17 20 Sec MD Inc Azi TVD +N/-S +EJ-W DLeg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 -35.25 2.20 -5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 -52.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 -42.33-503.84 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0.00 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.76-10864.37 3.50 -114.00-3113.11 9 14120.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90 3369.97-10973.12 3.27 -66.75-1979.03 11 15284.58 83.00 165.00 6990.99 3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89.38 144.34 7016.19 -4548.07-10466.77 2.00 -90.11 -699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CD3-K 25May10 Tce 0 / 360 180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ft/in] I I Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-127wp03 500.00 TO 1001.00 Ellipsoid Color p„ O.onaa msn 1otl i.>o 36 250 1250 1500 3500 4250 9250 11750 19750 21250 wm .ca.inlm ga-.m veew coiizn.w�i� rnvno cz.s -"c'ma�.z-sc 'mie.ecw�:n.m 250 500 1500 1750 4250 5250 11750 14250 21250 22250 u:M.x i'n". min 500 750 1750 """""""-"-"""""""" 2250 5250 6250 14250 16250 22250 23250 750 """-- 1000 2250 --- 2750 6250 -- 7750 16250 18250 23250 24000 1000 1250 2750 3500 7750 9250 18250 19750 24000 --" 24WO aa•r�ar IM 0 / 360 6I:h1fE:D1 Travelling Cylinder Azimuth (TFO+AZI) [j vs Centre to Centre Separation [100 Min] LEGEND -A- CD3.124, C03124, CD3.124 VO �- Flan: CD3.126, Plan. CD3-126, CD3-12&.V $- Plan: CD3-119, Plan: CD3-119, CD3119. p( - - CD3-121,, CD}121, CD3.121 VO CD2,D3-12. CO3-112 V3 C311115D35CD3, CO3-115 VO CD3316, CD3316, CO3J16 VO -�}- '.316, CD3318APB1, CD3316APB1 VO �- CD3316, C113-316A, CD3 16A VO -�- Ran: CD3128, Plan: CD3128, CD3-128vp( - Ren: CD3129, Pl.:CD3-129, C133-129ap( �- Nerhekk 1, Nechelik 1, Neaelik 1 VO -�- Ran: CD3125, Ren: CD3-125, CD3-125,W -$- -� OD3122, DD3122, CD3-122 VO COS. D14CD3114V 14 C0113117, D37, CO3-117 VO C03118, CD3118, CD3-118 VO -� CD3123, CMA23, CMA23 VO -� Ran: CD3-119, Plan: C133119, CD3119ap( -�- Ran: CD3120, Ran: CD3120, CD3-120W $- CD3127wp03 -90 / D3- SECTION DETAILS 11:25. peconber 17 20 Sec MD Inc Azi TVD +N/-S -E/-W DLeg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 35.25 2.20 5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 -52.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 42.33-503.84 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0.00 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.00-3113.11 9 14120.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90 3369.97-10973.12 3.27 -66.75-1979.03 11 15284.58 83.00 165.00 6990.99-3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89.38 144.34 7016.19 4548.07-10466.77 2.00 -90. 11-699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CD3-K 25May10 Tce 0 / 360 125wp 90 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) ['] vs Centre to Centre Separation [25 fl/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-127wp03 1000.00 To 1501.00 Ellirsoi, Color =.T 36 250 1250 -- - 16W 35W 4250 9250 11750 19750 212M 250 500 1500 1750 4250 5250 11750 - -- 14250 21250 22M w1 �i - 500 760 1750 2260 5250 6250 __ 14250 - - 16250 22250 23250 750 10DO 2250 2750 6250 7750 16M 18250 23250 24000 1000 1250 2750 3500 7750 9250 18250 19750 24000 24500 1E 0 / 360 -180 / 180 12j LEGEND CD3-124, CD3.124, CD3-124 VO �- Plan: C133-126, Plan: C133-126, CD3.120.VO VO Ren: CO3-119, Pl- C100419, C103-11 VO $- CD3.121, CO3-121, C103-121 VO CD3-112, CD3-112, 033-112 V3 CD3.115, CD3-115, CD3-115 VO -+- CO3-318, CD3316, CD3-316 VO -E3- C33-316, CD3316APB1, CD3316APB1 VO CD3.316, CD3.316A, C03316A VO $- Ren: CD3128, Plarc CD3-128, CD3-128wP0 VO Ren: CD3-12g, Plan: CD3-129, C133-129a 0 VO Nechshk 1, Nechelik 1, Nechekk i VO Ran: CD33125, Ran: CD3-125, CD3-12 VO -$- CD3.122, C133.122, CD3.122 VO CO3.114, CD3414, C131114 V14 �- CD3-117, C133-117, CD3-117 VO - CD3-118. CD3.118, CD3-118 VO -&- C133-123, C133-123, CD3-123 VO -�- Ran: C133-119, Plan: CD3-119, CD3-119ep0 VO -�- Ran: CD3120, Plan: CD3-120, CD3-iaml VO -{�- CO3.127wp03 -90 / SECTION DETAILS 1 11:26, December 17 20 Sec MD Inc Azi TVD +N/-S +E/-w DLeg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.D0 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 35.25 2.20 5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 -62.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 42.33 503.84 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0.D0 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.00-3113.11 9 14120.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90 3369.97-10973.12 3.27 -66.75-1979,03 11 15284.58 83.00 165.00 6990.99 3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89.38 144.34 7016.19 4548.07-10466.77 2.00 -90.11-699.45 14 22336.55 89.38 144.34 7078.90-9268,23-7080.18 0.00 0.00 5043.72 CD3-K 25Mey10 Tae D3-128wp0 t-125wp 90 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-127wp03 1500.00 To 2001.00 ENpwW Color A.. .o 1v.., 36 250 1250 1500 3500 4250 9250 11750 19750 21250 win. 'om �i 250 600 1500 1750 4250 5250 11750 14250 21250 22250 500 750 1750 2250 5250 6250 14250 16250 22250 23250 750 IWO 2250 2750 6250 7750 16M 18250 23250 - 24000 1000 1250 2750 3600 7750 9250 18250 19750 240DO 24600 ME 0 / 360 -nh -180 / 186 . D3-12 3-12 LEGEND SECTION DETAILS 11:27. QpMber 17 20 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0,00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.DO 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5,37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 .35.25 2.20 -5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 52.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 42.33 503.84 7 12159'41 68.30 262.00 5729.80-1204.43-9806.61 0.00 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.00-3113.11 9 14120.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90-3369.97-10973.12 3.27 -66.76-1979.03 11 15284.58 83.00 165.00 6990.99-3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89.38 144.34 7016.19 4548.07-10466.77 2.00 -90.11-699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CD3-K 25May10 Toe --&- CD3.124, CD3.124, Cl VO $0 -#- Plan: C133-126, Plan: Cl ClVO $- Plan: CD3.119. Plan: CD3119, ClVO C133.121, CD3.121, C:33-121 VO CD3.112, CD3-112, CD3-112 W -� CD3.115, CD3.115, CD3-115 VO CD3-316, CD3316, CD3316 VO $- CD3-316, CD3-316APBi, CD3-316APBi VO CD3-316, CD3-316A, CD3316A VO -�- Plan: CD3.128, Plan: CD3-128, CD3-128vp0 VO 1 - Plan: CD3.129, Plan: CD3-129, CD3129.}9 vO -90 / 270 -� Nechelik 1, NftWik 1, Nechelik 1 VO -�- Plan: CM125, Plan: CD3-125, CD3-12 VO $- CD1122, CO3-122, CD3-122 VO C133.114, CD3.114, Cl V14 Cl CD3.117, CD3.117 VO CD3-118, M3A18, C33-118 VO -� CD3-123, CD3-123, CD3-123 VO -q- Plan: CO3-119. Plan: CD3-119, C3111 VO -A- flan: Cl Plan: Cl CD3-1 VO -120 , -e- CD3-127vp03 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ft/in] 0/360 90 -180 / 180 Travelling Cylinder Azimuth (TFO+AZt) [o] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-127wp03 2000.00 To 3001.00 ElllpsoW Color 36 250 1250 1500 3500 4250 9250 11750 18750 21250 250 500 1500 1750 4250 5250 11750 -- 14250 2125D 22250 p61"0m Cp0'' 500 750 1750 2250 5250 6250 14250 16260 22250 23250 750 1000 2250 2750 6250 7750 16250 18250 23250 24000 1000 1250 2750 3500 T750 9250 18250 19750 24000 245W -90 / K 0/360 -180 / 180 D3-11 D3-129wp0 LEGEND 25wp0 $ CD: 124, 003-124, CD3-124 V0 Nan: C131126, Plan: CD3.126, CD3-126Mp( Nan: C1)3-119, Plan: CD3-119, CD3-119MA -�- CD3.121, CD3.121, CO3-121 VO - CD3.112, CD3-112, CO3-112 V3 CD3-115, C133.115, CD3-115 VO -� CD3.316, C133316, C03316 VO $- CD3-316, CD3-316AP81, CD3-316AP81 VO $- CD3-316, CD3-318A, C03316A VO Nan: CD3-128, Plan CD3.128, CD3-128vp( - Nan: CD3.129, Nan CWA29, CD3-129ep( �- Ne fik 1, Nechefik 1, Nechekk 1 VO Nan: CD3-125, Nan: CW-/25, CD3-125ap( Ct 3 122, CD3.122. CD3.122 VO -�- CO3-114, CD3-114, C03114 V14 CD3-117, C133-117, CO3-117 VO CO3.118, C103.118, CO3-118 VO CD3-123, CD3.123, CD3-123 VO �- Nan: CD3-119, Plan: CD3-119, CD3-119ap( -&- Nan: CO3-120, Nan: CD3.120, CO V 2Dvp( -$- C133127mW Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 Win] SECTION DETAILS 1 11:27, December 17 20 Sec MD Inc Azi TVD +N/-S +E1-W DLeg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 -35.25 2.20 -5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 -52.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 -42.33-503.84 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0.00 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.00-3113.11 9 14120.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90-3369.97-10973.12 3.27 -66.75-1979.03 11 15284.58 83.00 165.00 6990.99-3417.90 -10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89.38 144.34 7016.19-4548.07-10466.77 2.00 -90.11 -699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CD3-K 251ollay10 Toe -601 -90 / 270 SKIN,, 0 / 360 90 -180 / 180 Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] j CD3-127wp03 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 3000.00 To 5001.00 E*PS 4 Color 36 250 500 250 500 750 1250 1500 1750 1500 1750 2250 3500 4250 - 5250 4250 5250 6260 9250 11750 14260 11750 19750 14250 21250 16250 22250 21250 22250 23250 750 10DO 2250 2750 6250 7750 16250 18M 23250 24000 1000 1250 2750 35W T750 9250 18260 19760 240DO 24500 MIT111 IE 0 / 360 -180 / 180 D3-129wp0 LEGEND CD3124, MD 124, CD3-124 VO -� Plan: C113126, Plan: CD3.126, CD3-1 VO Ran: CD3-119, Plan: C133-118, CD3.11 VO C33.121, CO3.121, CD3.121 VO - CO3-112, C133-112, CD3-112 V3 C33-115, CD3-115, CD3-115 VO C33-316, CD3318, CD3316 VO -B- C01316, 003318APB1, CD3-316APB1 VO C31316, CD3316A, CD3316A VO Ran: CD3.128, Ran: CD3-128, CD3-12&vp0 VO 90 Ran: C133-129, Ran: CD3-129, CD3-129sy0 VO -90/ -� NfthOk 1, NacMlik 1, Nschehk 1 VO Ran: C03125, Ran: CD3-/25, C1)3-1 VO CD3-122, CD3.122, C33-122 VO -�- CD3114, CD3-114, CO3-114 V14 -� CD3-117, CD3-117, CO3.117 VO - CD3.118, C133-118, CO3-118 VO -6- CD3-123, CD3-123, CD3-123 VO -g- Ran: CD3-119, Plan: CD3-119, CD3-119MO VO -� Ran: CD3-120, Ran: C133-120, CD3-1 VO 3-128wp0 $ CD3-127wp03 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 Win] SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 .35.25 2.20 5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 52.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 -42.33 503.84 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0.00 0.00-3378.95 8 13789.26 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.D0-3113.11 9 14120.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90-3369.97-10973.12 3.27 -66.75-1979.03 11 15284.58 83.00 165.00 6990.99-3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89.38 144.34 7016.19 -4548.07-10466.77 2.00 -90.11-699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CD3-K 25May10 Toe 0 / 360 90 -180 / 180 Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-127wp03 5000.00 To 10001.00 E„r-id Co,., A.. aon T, w�.r 36 250 1250 _ 1500 3500 4250 9250 11750 19750 21250 250 500 1500 1750 4250 5250 11750 -- - 14250 21250 22250 500 750 1750 - ----- 2250 5250 6250 14250 16250 22250 23250 750 1000 2250 2750 6250 7750 16M 18250 23250 24000 IWO 125D 2750 3500 T750 9250 18250 19750 240DO 24500 -90/ Si 0 / 360 -180 / 180 SECTION DETAILS 1 11:29, December 17 20 Sec MD Inc Azi TVD +NI-S +EI-W DLeg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 -35.25 2.20 -5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 52.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 -42.33 503.84 7 12159.41 68.30 262.00 5729.80-1204.43-98D6.61 0.00 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.00-3113.11 9 1 41 20.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90 3369.97-10973.12 3.27 -66.75-1979.03 11 15284.58 83.00 165.00 6990.99 3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3,05 0.00-1726.23 13 16526.83 89.38 144.34 7016.19 -4548.07-10466.77 2.00 -90.11 -699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CD3-K 25May10 Toe LEGEND $ C03124, CD3124, CD3-124 VO -60 / Ran: CO3-126, Pl- C133426, CD3.126.10 VO -�}- Ran: CD3.119, Plan: CD3119, CD3419,0 VO -e- CD3121, C133121, CD3121 VO CD3112, C133-112, CD3-112 V3 $ CD3115, CD3115, CD3115 VO -�-- CD3316, CD3-316, CD3-316 VO CD3-316, C133-316AP131, CD3316APBI VO CD3-316, CD3.316A, CD3J16A VO 90 --480-- Ran: CD3-128, PI: CD3128, C03128wy0 VO - Ran: CD3129, Ran: CD3129, CD3129w O VO -90 / 270 $ Nx k 1. Nwh ik 1, Nwhakk 1 VO �- Ran: CD3-125. Ran: C03125, CD312 VO C03122, CD3122, CD3122 VO �- CD3114, C133114, CO3-114 V14 CD3117, CD3117, C03117 VO - - CD3118, CD3118, CD3.118 VO $ CD3-123, CD3123, CD3123 VO Ran: CD3119, Plan: CD3-119, CD3119wpO VO $ Ran: CD3120, Ran: CD3120, CD31 VO .1201 -{3- CD3127Wp03 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 Win] 0 / 360 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre 90 [25 ft/in] CD3-127wp03 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10000.00 To 13501.00 Ellipsoid Colo, 1e a�.r>'an 36 250 1250 1500 3100 4250 9250 11750 19150 21250 ii in3 250 500 750 5w 750 10D0 1500 1760 2250 1750 2250 2750 4250 5250 6250 5250 6250 7750 11750 -- 14250 16250 -- 14250 21250 16250 22250 18250 23250 22260 23250 24000 T. 10D0 1250 2750 3500 7750 9250 18250 19750 24DDO -- -- 24500 CD a_aaaaa. -90/ 10 0 / 360 -180 / 180 LEGEND -6- CD3124, C133124, CO3-124 VO Plan: CD3.126, Plan: CD3.126, CD3-1 VO Wan: CD3119, Plan: CD3119, CD311 VO -e- CD3121, CD3A21, C103.121 VO CD3-112, M3-112, CD3-112 V3 -�- CD3-116, M3-115. CD3115 VO -�-- C133.316, CD3J76, CD3-316 VO C33316, M3.316APe1, CD3316APe1 VO C133316, CD3.316A, CD3316A VO Wan: CD3128, Wan: M3-128, CD3-128ap0 VD 90 - flan: CD3129, Wan: CD3129, M3-129aa9 VO -90/ -� Neonelik 1, Nechelik 1, NaMelik 1 VO Wen: CD3125, Wan: CD3125, CD3-12 VO CD312.2, M3.122, CD3122 VO �- CO3-114, CD3-114, C03114 V14 -�- CD3117, CD3.117, C133117 VO - - C133118, M3.118, CD3118 VO -6- CD3423, C01123. CD3.123 VO Wan: M3-119, Plan: CD3119, C03119wO VO -�- Plan: CD3120, Wan: CD3120, CM-1 VO -1 -{3- CD3127rp03 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 Win] SECTION DETAILS 11.30, Li@C61[Iber 17 211 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 699.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 3525 220 -6.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 52.10 3.00 -35.00 59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 -42.33 503.84 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0,00 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.00-3113.11 9 14120.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907+28 10 15234.58 83.00 165.00 6984.90 3369.97-10973.12 3.27 -66.75-1979.03 11 15284.58 83.00 165.00 6990.99-3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89,38 144,34 7016.19 -4548.07-10466.77 2.00 -90.11-699.45 14 221.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CD3-K 25May10 Toe 0 / 360 90 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] CD3-127wp03 13500.00 To 14501.00 M o-a 1a Ica �lni -90/ IE GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 36 250 1250 1500 3500 250 500 15W 1750 4250 500 750 1750 2250 5250 750 10DO 2250 2750 6250 1D00 1250 2750 35W 7750 0 / 360 -180 / 180 Ellipsoid Color 90 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ft/in] 4250 9250 11750 19750 21250 5250 11750 --- 14250 21250 22250 6250 14250 16260 22250 23250 7750 16250 18250 23250 24000 9250 18250 19750 24000 24500 LEGEND -A, C133-124, C133-124, CD3-124 VO Nan: CD3-126, Plan: CD3.126, CD3-1 VO Per: CD3.119, Plan: C133119, CD3-11 VO C133-721, CD3-121, C133-121 VO - CD3.112, CD3-112, C133-112 V3 -� CD3-118, CD3-115, C133.115 VO CM-318, CD3316, C03316 VO $- CM-316, CD3316APB1, C33316APe1 VO CD3-316, CD3316A, CD3316A VO Nan: CD3.128, Nan: CD3428, CD3-128vp9 VO -F PI:; C1333129, Nan: CD3-129, CD3-129a►0 VO -90/ NWh1fik 1, Nachelik 1, Narhelik 1 VO �- Nan: CD3-125, Plan: CD3-125. CO3-12 VO -e- C03122, CD3-122, CD3-122 VO CD3.114, C133.114, C133-114 V14 CD3117, C133-117, C133-117 VO CD1118, CD3118, C133.118 VO CD3-123, CD3-123, C133-123 VO Nan: CD34W. Pl- C133-119, C03119wpO VO �- Nan: C133-12% Nen: CD3-120, CD3-1 VO -1 -f3- CD3127w 03 SECTION DETAILS 11.31. December 17 20 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFaoa VSec Target 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 5.37 -6.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 35.25 2.20 5.00 -41.51 5 1002.45 12.97 300.11 997.73 39.78 -52.10 3.00 -35.00 -59.10 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 -42.33 503.84 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0.00 0.00-3378.95 8 13789.25 58.79 198.32 6519.80-2041.75-10864.37 3.50 -114.00-3113.11 9 14120.68 65.41 198.32 6674.80-2319.65-10956.41 2.00 0.00-2907.28 10 15234.58 83.00 165.00 6984.90 3369.97-10973.12 3.27 -66.75-1979.03 11 15284.58 83.00 165.00 6990.99-3417.90-10960.28 0.00 0.00-1930.49 12 15493.97 89.38 165.00 7004.90-3619.61-10906.23 3.05 0.00-1726.23 13 16526.83 89.38 1445.34 7016.19 -4548.07-10466.77 2.00 -90.11 -699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CO3-K 25Wy10 Toe 0 / 360 90 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS r 17 20 CD3-127wp03 Sec MD Inc Azi TVD +N/-S ♦E/-W DLeg TFace VSec Target 14500.00 To 21501.00 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 36 250 1250 1500 EksoW Color 3500 4250 9250 11750 19750 21250 2 3 4 5 349.80 599.98 902A5 1002.45 0.00 0.00 349.80 0.00 0.00 3.75 311.00 599.80 5.37 -6.18 10.40 307.79 899.80 28.62 .35.25 12.97 300.11 997.73 39.78 52.10 0.00 1.50 2.20 3.00 0.00 0.00 311.00 -7.59 5.00 -41.51 -35.00 -59.10 a nm o.n m a„Y.,m.n cLp1m.+ n 250 500 1500 1750 4250 5250 11750 14250 21250 22250 6 2654.80 68.30 262.00 2215.50 24.67-1061.57 3.53 -42.33 503.84 500 750 1000 750 1000 1250 1750 2250 2750 2250 2750 35M 5250 6250 7760 6250 14250 7750 16250 9250 18250 16250 22250 18250 23250 19750 24000 23250 24000 24500 7 8 9 10 12159.41 13789.25 14120.68 15234.58 68.30 262.00 5729.80-1204.43-9806.61 58.79 198.32 6519.80-2041.75-10864.37 65.41 198.32 6674.80-2319.65-10956.41 83.00 165.00 6984.90 3369.97-10973.12 0.00 3.50 2.00 3.27 0.00-3378.95 -114.00-3113.11 0.00-2907.28 -66.75-1979.03 mn+o max ivr.cw i+a 11 15284.58 83.00 165.00 6990.99 3417.90-10960.28 0.00 0.00-1930.49 12 13 15493.97 16526.83 89.38 165.00 7004.90-3619.61-10906.23 89.38 144.34 7016.19 -4548.07-10466.77 3.05 2.00 0.00-1726.23 -90.11 -699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043-72 CD3-K 25May10 Toe M 0 / 360 1 0 / 360 -180 / 180 LEGEND -6- CD3.124, CD3.124, CD3-124 VO -60 Plan: C133126, Plan: CD3126, CD3-1 VO -�- Plan: CD3-119. Plan: CO3-119, CD311 VO CD3121, C03121, CD3121 VO CD3112, C133112, CD3112 V3 -� CD3-115, CD3115, CD3115 VO CO3-316, CD3318, C03316 VO CD3316, M3.316APB1, CD3316APBI VO C03316, CD3316A, CD3.316A VO Plan: CD3128, Plan: CD3128, CD3-128vg0 VO 90 Ran: CD3129, Plan: CD3129, CD3-129oy0 W -90 / 270 -� Nadnolik 1, Nechelik 1, Ne alik 1 VO Plan: CD3126. Plan: CD3-125, CD-VO C33122, C133122, CD3.122 VO �- CD3114, CD3.114, CD3114 V14 CD3117, CD3117, C133.117 VO CD3.118, C03118, CD3118 VO -6- C03123, CD3123, CD3123 VO -�- Plan: CD3-119, Plan: CD3119, CD3aP 1190 VO -6- Ran: CD3.120, Plan: CD3120, C1331 VO -120 , -E3- CD3127wy03 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ft/in] -180 / 180 Travelling Cylinder Azimuth (TEO+AZI) [°] vs Centre to Centre 90 Win CD3-127wp03 21500.00 To 22336.55 pn o4n n Major Risk GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Elfp-d G. 4 36 250 1250 1500 3500 4250 9250 11750 19750 250 5DO 1500 1760 4250 5250 11750 - - 14250 21250 500 750 1750 2250 5250 --- 6250 14250 16250 22250 750 1DD0 2250 2750 6250 - - 7750 16250 18250 23250 1000 1250 2750 35W 7750 -- 9250 18250 19750 24000 SECTION DETAILS 1 11:32, December 17 2010 Sec 1 MD 36.30 Inc Azi TVD +N/-S +FJ-W 0.00 0.00 36.30 0.00 0.00 DLeg 0.00 TFace VSec Target 0.00 0.00 2 349.80 0.00 0.00 349.80 0.00 0.00 0.00 0.00 0.00 3 599.98 3.75 311.00 599.80 6.37 E.18 1.50 311.00 -7.59 4 902.45 10.40 307.79 899.80 28.62 35.25 220 5.00 -41.51 21250 5 1002.45 12.97 300.11 997.73 39.78 -52.10 3.00 35.00 -59.10 22250 6 2654.80 68.30 262.00 2215.50 24.61-1061.51 3.53 -42.33-503.84 23250 7 12159.41 68.30 262.00 5729.80-1204.43-9806.61 0.00 0.00-3378.95 24000 8 9 13789.25 14120.68 58.79 198.32 6519.80-2041.75-10864.37 65.41 198.32 6674.80-2319.65-10956.41 3.50 2.00 -114.00-3113.11 0.00-2907.28 245M 10 11 12 15234.5 15284.5: 15493.97 83.00 165.00 6984.90 3369.97-10973.12 83.00 165.00 6990-99 3417.90-10960.28 89.38 165.00 7004.90-3619.61-10906.23 3.27 0.00 3.05 -66.75-1979.03 0.00-1930.49 0.00-1726.23 13 16526.83 89.38 144.34 7016.19 -4548.07-10466.77 2.00 -90.11 -699.45 14 22336.55 89.38 144.34 7078.90-9268.23-7080.18 0.00 0.00 5043.72 CD3-K 25May10 Toe 0 / 360 0 / 360 100 50 -30 / 330 30 -30 / 330 30 LEGEND -60 / 300 60 -� c03124, c03-124, CDa-124 VO 60 / 300 60 echelik 50 Flan: CD312Q Plan: CD1126, CD31 VO 25 -$- Ran: C133-119, Pl- CD3119, C133-11 VO -�- CD3121, CD3121, C03121 VO D3-126wp0 �� CD3.112, CD3112. CO3-112 V3 $ CD3115, CD3.118, CO3-115 VO ' -�- CD3.316, CDMIG, CD3.316 VO C131316, CD3318AP61, CD3316AP91 W Q CD3316, C133-316A, CD3J16A VO -� Plan: CD3128, Plan: CD3128, CD3.128wp0 �� Plan: CD3129, Plan: CD3129, CD3-129ap0 VO VO -90 / 27t) 90 -y4 / 270, 90 $ Nec6Nik 1, Nechellk 1, NeMekk 1 W -�- Ran: CD3125, Plan: CD3125, CD31 VO I -�}- CD31Y2, CD3122, C133122 W C133114, C133114, C113114 V14 CD3417, C133117, CD3.117 W - - W3-118, C133118, CD3.118 W $ CD3123, CD3123, C133-123 VO 5 Ran: CD3-119, Plan: CD3119, CD3119ap0 W -120 / 240 ` 120 $ Ran: CD3120, Plan: C133120, M3-1 VO -120 / 240 120 -9- CD3127ep03 -150 / 210 : ' 150 -150 / 210 150 100 50 -180 / 180 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [5000 ft/in] Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# 0eaC ZDevelopment Service Ex loratoExploratory Non -Conventional Well Stratigraphic Test FIELD: -L5 l tf 7 /le POOL: Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTILATERAL 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. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & PTD#:2110050 Com Administration 17 Appr Date SFD 1/25/2011 4 5 6 7 :8 9 10 11 12 13 14 15 16 18 Engineering 19 21 22 Appr Date GLS 1/27/2011 Geology Appr Date SFD 1/25/2011 - 120120 Well Name: COLVILLE RIV FIORD CD3-127 Program DEV _ Well bore seg ❑ —__ Initial Class/Type DEV / PEND_ GeoArea 890 Unit 50360On/Off Shore On Annular Disposal Nonconven. gas conforms to AS31.05 03%.1.A),(y2.A-D) - _ _ _ _ _ _ _ _ NA_ - - - - - Permit fee attached NA Lease _number appropriate- - - - - - - - - - - - - - - - - - Yes Surface location in ADL 372105; top_ prod_ interval in ADL 025526, Unique well. name and number - - - - - - - - - - - - - I _ _ _ _ _ - - - Yes TD in ADL 025538._ - - - - - Well located in_a_defined -pool - - _ _ - _ - - - - - - - - - - - - - - - - - - - - Yes COLVILLE, RIVER,_FIORD OIL-_120120,-governed-by CO 569 Well located proper distance from_ drilling unit -boundary - - - - - - Yes Conservation Order No. 569 contains no spacing restrictions with respect to drilling unit boundaries. - - - - - - - - Well located proper distance from other wells - - - - - _ - - - . Yes Conservation Order No. 569 has no interwell_spacing _restrictions - - - - - - - - - - Sufficient acreage_ available in drilling unit Yes Conservation Order No. 569 has no interwell spacing_ restrictions. Wellbore_will be more than 500' from - - - - - - _ If deviated, is.wellbore plat -included . - _ - - - Yes external property line where_ownership or landowne_rship.changes - - - - - - Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - Yes Well lies entirely within Colville River Unit. - - - - - - - - - - - - - _ _ Operator has.appropriate_ bond in force _ _ _ _ _ - - _ Yes - _ Permit can be issued without conservation order Yes Permit_c_an be issued without administrative. approval - - - - - - - - Yes Can permit be approved before 15-day wait- Yes Well located within area and strata authorized by Injection Order # (put 10# in -comments) -(For- NA_ All wells within 1/4_mil_e area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ Pre -produced injector: duration of pre production less than 3 months —(For —service will only) - NA_ 2-3 days flowback for clean up - - - - - - - - _ _ - . _ -- Conductor string provided - - - - - - Yes Surface casing protects all known USDWs - - _ _ _ - . _ _ _ NA No Aquifers._ AIO- 30,. Conclusion 3_ CMT vol. adequate to circulate on conductor. & surf_csg - - - - - _ _ . - _ - - - - - - Yes - - - - - - - - _ _ _ _ _ _ - - - - - - CMT-vol adequate to tie-in long string to surf csg_ No Intermediate casing TOC at 14070'md. j 1st stage) - CMT_will cover all known productive horizons No Qannik to be isolated with 2nd stage in Intermediate casing._ - - - Casing designs adequate for C, T, B &_ permafrost_ - - - - - _ _ _ _ - - - - - Yes - - - Adequate tankage or reserve pit _ _ - _ _ _ _ - - - - Yes _ Rig has steel pits, All waste_to approved disposal wells-. - - - - - - - - _ _ If a_re-drill, has_a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ NA - _ _ - - - - - - - - - - - - - - - - _ _ _ - - - - - - - - _ Adequate wellbore separation proposed _ - - Yes Proximity_ analysis performed. Close crossing with CD3-117..75' from elipses._ If_diverter required, does it meet regulations- - NA_ _ _ _ . - - Diveter_waiver requested. No shallow gas in_CD3. 20 AAC 25.035 (h)(2)_ Drilling fluid program schematic & equip list adequate Yes Max formation press=_3305 psi (9.0_ppg EMW)_ Will drill with9.0- 9.4_ppg mud BOPEs,-do they meet regulation _ _ _ _ Yes - _ _ _ _ - BOPE_presS rating appropriate; test to _(put psig in comments)_ - - - Yes _ .. _ _ MASP= 2597 psi _Will test BOP to 3500 psi - - - - - - - - - - - - - - - - Choke_manifold complies w/API_RP-53 (May 84)_ Yes _ _ - - _ - _ Work will occur without operation shutdown- . Yes - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ----------------------- Is presence of H2S gas probable No_ - _ _ _ . _ _ No H2S on CD3. Rig has sensors and alarms. Mechanical condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - - - - - - - - - - - - - Permit_can be issued w/o hydrogen_ sulfide measures - - - - - - _ _ _ _ - - - Yes _ _ _ _ _ _ _ None expected,_but H2S and gas detectors will be used during drilling. Mitigation measures- in Hazards - Data -presented on potential overpressure zones - - - - - - - - - - - - - - Yes - - _ _ _ _ Summary. _ Expected_ gradient is 9.0.ppg EMW; will be drilled with 9.0 - 9.4 ppg mud. Seismic analysis of shallow gas -zones- _ _ - _ - - - - - - - NA- - _ _ _ _ _ _ _ _ _ _ Seabed condition survey (if off -shore) NA Contact name/phone for weekly_ progress reports [exploratory only NA Geologic Engineering Public Commissioner: Date: Co issioner: Date Co i ner Date 05'k'� �4_ 3i_// /-S/, // IVN'ell History File Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 11 08:08:12 2011 Reel Header Service name.............LISTPE Date .....................11/03/11 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library Tape Header Service name.............LISTPE Date .....................11/03/11 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 -MW-0007896020 PAUL ORTH DON MICKEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services CD3-127 PB1 501032063470 ConocoPhillips Alaska, Inc. Sperry Drilling 11-MAR-11 5 12N 5E 4023 1185 48.60 12.60 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 1ST STRING 9.875 10.750 2ND STRING 3RD STRING PRODUCTION STRING 2t! -csoS go£r1a DRILLERS DEPTH (FT) 3239.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWRP4), AZIMUTHAL LITHO -DENSITY (ALD), COMPENSATED THERMAL NEUTRON (CTN), BI-MODAL ACOUSTIC SONIC (BAT), ACOUSTIC CALIPER (ACDC), PRESSURE -WHILE -DRILLING (PWD), GEO-PILOT ROTARY STEERABLE BHA WITH AT -BIT GAMMA (ABG), AND DRILLSTRING DYNAMICS SENSOR (DDSr). ABG DATA WERE APPENDED TO DGR DATA 15,206.5'MD - 15,256'MD. 5. MWD RUN 3, A CLEAN -OUT RUN WITH PWD ONLY, DID NOT REACH BOTTOM - NO NEW DATA WERE ACQUIRED. THIS WELLBORE WAS SUBSEQUENTLY ABANDONED. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEP- TEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVER- SATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1-3 REPRESENT WELL CD3-127 PB1 WITH API#: 50-103-20634- 70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15,261'MD/6978'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION DGRC DGR COMBINED GAMMA RAY BGCG ABG COMBINED GAMMA RAY R09P 9 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME TNPS CTN POROSITY — SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACDC ACAL COMPOSITE HOLE DIAMETER AHSI ALD HOLE -SIZE INDICATOR ACDL ALD LCRB COMPENSATED DENSITY ADCL ALD LCRB DENSITY CORRECTION APEL ALD LCRB Pe FACTOR BTCS BAT COMPRESSIONAL SLOWNESS BCSS BAT COMBINED SHEAR SLOWNESS BVPS BAT VP/VS RATIO BSFG BAT SHEAR FLAG PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: VARIABLE (ACDC-DERIVED) - 9.875" BIT MUD WEIGHT: 9.6 PPG MUD SALINITY: 500 PPM CHLORIDES FORMATION WATER SALINITY: 22,500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 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 SMOTHED WITH A 1.1 FT WINDOW. BTCS, BCSS, BVPS CURVES ARE SMOOTHED WITH A 2.0 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 ....... 11/03/11 Maximum Physical Record..65535 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 CALA 3175.0 15172.5 DTC 3175.0 15153.5 GR 3195.0 15256.0 NPHI 3230.0 15169.0 RPM 3230.0 15220.0 FCNT 3230.0 15169.0 RPS 3230.0 15220.0 RPX 3230.0 15220.0 RPD 3230.0 15220.0 FET 3230.0 15220.0 NCNT 3230.0 15169.0 PEF 3230.0 15183.0 CALN 3230.0 15183.0 DRHO 3230.0 15183.0 RHOB 3230.0 15183.0 ROP 3250.5 15261.0 DTSH 4438.0 15153.5 SCRA 4438.0 15153.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3175.0 15261.0 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 CALA MWD IN 4 1 68 4 2 RHOB MWD G/CC 4 1 68 8 3 DRHO MWD G/CC 4 1 68 12 4 CALN MWD IN 4 1 68 16 5 PEF MWD B/E 4 1 68 20 6 DTSH MWD USPF 4 1 68 24 7 DTC MWD USPF 4 1 68 28 8 SCRA MWD 4 1 68 32 9 GR MWD API 4 1 68 36 10 FET MWD HR 4 1 68 40 11 RPX MWD OHMM 4 1 68 44 12 RPS MWD OHMM 4 1 68 48 13 RPM MWD OHMM 4 1 68 52 14 RPD MWD OHMM 4 1 68 56 15 ROP MWD FPH 4 1 68 60 16 FCNT MWD CP30 4 1 68 64 17 NCNT MWD CP30 4 1 68 68 18 NPHI MWD PU 4 1 68 72 19 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3175 15261 9218 24173 3175 15261 CALA MWD IN 8.13 11.55 9.68466 23677 3175 15172.5 RHOB MWD G/CC 0.4 3.277 2.39277 23907 3230 15183 DRHO MWD G/CC -2.685 0.25 0.0349416 23907 3230 15183 CALN MWD IN 8.19 12.42 9.67704 23907 3230 15183 PEF MWD B/E 1.91 15.55 3.01695 23907 3230 15183 DTSH MWD USPF 132.67 279.04 186.409 21394 4438 15153.5 DTC MWD USPF 59.69 158 98.2935 23958 3175 15153.5 SCRA MWD 1.42 2.78 1.97621 21394 4438 15153.5 GR MWD API 30.44 390.8 110.086 24123 3195 15256 FET MWD HR 0.15 133.58 0.655356 23981 3230 15220 RPX MWD OHMM 0.95 1058.78 5.25599 23981 3230 15220 RPS MWD OHMM 0.64 24.63 5.4249 23981 3230 15220 RPM MWD OHMM 0.1 1386.18 5.81949 23981 3230 15220 RPD MWD OHMM 0.09 2000 7.27545 23981 3230 15220 ROP MWD FPH 0.51 2123.41 186.106 24022 3250.5 15261 FCNT MWD CP30 419.35 1475.18 701.389 23879 3230 15169 NCNT MWD CP30 91318.4 136852 112156 23879 3230 15169 NPHI MWD PU 14.31 57.11 31.1936 23879 3230 15169 First Reading For Entire File .......... 3175 Last Reading For Entire File ........... 15261 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 11/03/11 Maximum Physical Record..65535 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 ....... 11/03/11 Maximum Physical Record..65535 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH BTCS 3175.0 15153.5 ACDC 3175.0 15172.5 DGRC 3195.0 15256.0 ACDL 3230.0 15183.0 TNNA 3230.0 15169.0 ADCL 3230.0 15183.0 AHSI 3230.0 15183.0 TNFA 3230.0 15169.0 APEL 3230.0 15183.0 R15P 3230.0 15220.0 R39P 3230.0 15220.0 TNPS 3230.0 15169.0 EWXT 3230.0 15220.0 R27P 3230.0 15220.0 R09P 3230.0 15220.0 ROPA 3250.5 15261.0 BCSS 4438.0 15153.5 BVPS 4438.0 15153.5 LOG HEADER DATA DATE LOGGED: 21-FEB-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 15261.0 TOP LOG INTERVAL (FT): 3175.0 BOTTOM LOG INTERVAL (FT): 15261.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 57.9 MAXIMUM ANGLE: 83.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON BAT Bi-modal Acoustic ALD Azimuthal Litho -Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 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 DEPT CALA MWD020 RHOB MWD020 DRHO MWD020 CALN MWD020 PEF MWD020 DTSH MWD020 DTC MWD020 SCRA MWD020 GR MWD020 FET MWD020 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 ROP MWD020 FCNT MWD020 NCNT MWD020 NPHI MWD020 216787 244601 195179 10603721 9.875 3239.0 Lignosulfonate 9.90 40.0 9.2 500 2.9 2.200 70.0 1.040 155.5 2.100 70.0 2.400 70.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 IN 4 1 68 4 2 G/CC 4 1 68 8 3 G/CC 4 1 68 12 4 IN 4 1 68 16 5 B/E 4 1 68 20 6 USPF 4 •1 68 24 7 USPF 4 1 68 28 8 4 1 68 32 9 API 4 1 68 36 10 HR 4 1 68 40 11 OHMM 4 1 68 44 12 OHMM 4 1 68 48 13 OHMM 4 1 68 52 14 OHMM 4 1 68 56 15 FPH 4 1 68 60 16 CP30 4 1 68 64 17 CP30 4 1 68 68 18 PU 4 1 68 72 19 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3175 15261 9218 24173 3175 15261 CALA MWD020 IN 8.13 11.55 9.68466 23677 3175 15172.5 RHOB MWD020 G/CC 0.4 3.277 2.39277 23907 3230 15183 DRHO MWD020 G/CC -2.685 0.25 0.0349416 23907 3230 15183 CALN MWD020 IN 8.19 12.42 9.67704 23907 3230 15183 PEF MWD020 B/E 1.91 15.55 3.01695 23907 3230 15183 DTSH MWD020 USPF 132.67 279.04 186.409 21394 4438 15153.5 DTC MWD020 USPF 59.69 158 98.2935 23958 3175 15153.5 SCRA MWD020 1.42 2.78 1.97621 21394 4438 15153.5 GR MWD020 API 30.44 390.8 110.086 24123 3195 15256 FET MWD020 HR 0.15 133.58 0.655356 23981 3230 15220 RPX MWD020 OHMM 0.95 1058.78 5.25599 23981 3230 15220 RPS MWD020 OHMM 0.64 24.63 5.4249 23981 3230 15220 RPM MWD020 OHMM 0.1 1386.18 5.81949 23981 3230 15220 RPD MWD020 OHMM 0.09 2000 7.27545 23981 3230 15220 ROP MWD020 FPH 0.51 2123.41 186.106 24022 3250.5 15261 FCNT MWD020 CP30 419.35 1475.18 701.389 23879 3230 15169 NCNT MWD020 CP30 91318.4 136852 112156 23879 3230 15169 NPHI MWD020 PU 14.31 57.11 31.1936 23879 3230 15169 First Reading For Entire File .......... 3175 Last Reading For Entire File ........... 15261 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 11/03/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name.............LISTPE Date .....................11/03/11 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Reel Trailer Service name.............LISTPE Date .....................11/03/11 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Physical EOF Physical EOF Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File
