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Home My WebLink About206-032CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification (CRU CD3-112 (PTD 206-032) Date:Tuesday, May 27, 2025 4:07:30 PM Attachments:image001.png AnnComm Surveillance TIO for CD3-112.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Tuesday, May 27, 2025 3:47 PM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: AOGCC Notification (CRU CD3-112 (PTD 206-032) Well Name: CD3-112 Facility: WNS PTD: 206-032 Well Type: Injector AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): N/A Type of Issue: OPL Maximum Pressure (if applicable): 1091 psi Date of Occurrence (if applicable): 5/25/25 Chris, CRU CD3-112 (PTD 206-032) is a WAG injector currently on seawater injection. On 5/25/25, OPS reported the OA exceeding the OPL of 1091 psi. (OPL for the OA is 1,000 psi). On 5/25/25, the seawater line developed a leak and the seawater had to be directed into CD3 injection wells to clean the lines to repair the leak. CD3-112 injection rate was quickly increased and the IA and OA temperature and pressures increased to a max of 1091 psi. The injection rate was reduced and the OA pressure dropped and is stable at 650 psi. CPAI plans on putting the well on a 30-day monitor. Depending on results, proper notifications will be made as needed. Attached is the 90-day TIO plot and wellbore schematic. Please, let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD3-112 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD3-112 2025-03-31 460 960 500 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:CD3-112 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled and re-set injection valve for drift CD3-112 3/22/2024 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic10.0 4/19/2019 jennalt NOTE: Waiver for water-only injection cancelled 4/17/19 post RWO. 4/17/2019 sheskin NOTE: TREE - FMC UNIHEAD GEN II 4 1/16" 5K PSI - TREE CAP - 7" OTIS 4/16/2006 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 24" 16 15.01 36.0 114.0 114.0 84.00 J-55 WELDED SURFACE 9 5/8 8.83 36.5 2,726.0 2,485.4 40.00 L-80 BTC INTERMEDIATE 7 6.28 34.2 8,572.6 6,920.7 26.00 L-80 BTCM OPEN HOLE 6 1/8 8,572.6 16,021.0 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.1 Set Depth … 7,998.0 Set Depth … 6,758.0 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.1 31.1 0.00 HANGER 10.860 FMC 11" x 4-1/2" 5k PSI Alpine horizontal producer with elastomer seals FMC Alpine Hroz 3.900 116.1 116.1 0.60 XO ENLARGING 5.190 4-1/2" 12.6# L-80 563 Hydril x 3-1/2" 9.3# L-80 563 Hydril X-O 00 2.992 2,181.3 2,030.7 32.91 NIPPLE 4.490 3-1/2" (2.813" HES "X" nipple) S/N 21605-03 SLB 0 2.813 7,817.2 6,657.2 52.01 INJ 5.700 3-1/2" x1-1/2" MMG W/SOV 563 BxP set to shear IA to Tbg 2000psi SN;20819-05 SLB MMG 2.867 7,908.4 6,710.7 56.13 PACKER 6.276 Baker Premier Packer Assy PN H784-63-0255 BOT 0 2.870 7,966.7 6,742.1 58.80 NIPPLE 4.490 2.813" XN with 2.75" No-Go Hyd 563 BxP SLB 0 2.750 7,987.5 6,752.7 59.75 XO ENLARGING 6.050 3-1/2" 9.3# L-80 563 Hydril B x EUE 8rd Pin BOT 0 2.992 7,989.3 6,753.6 59.83 POORBOY OVERSHOT 6.060 Baker Poorboy 4.5" Tubing Stub Overshot W/O Packing 7" x 3-1/2" Nominal 6.5' of swallow BOT 0 4.800 Top (ftKB) 7,993.8 Set Depth … 8,096.5 Set Depth … 6,803.7 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,023.1 6,770.2 61.36 PACKER 5.970 BAKER PREMIER PACKER Baker T&C Upset 3.875 8,084.0 6,798.3 63.80 NIPPLE 5.000 HES 'XN' NIPPLE **Nipple Reducer Installed w/ 2.313" X Profile** T&C Upset 3.725 8,095.1 6,803.1 64.24 WLEG 5.000 WIRELINE ENTRY GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,181.3 2,030.7 32.91 INJ VALVE 3.5" A-1 Injection valve (SN: 5212.2, OAL=45") on 2.81" X- Lock 3/22/2024 1.250 7,993.0 6,755.5 60.00 TUBING CUT TUBING CUT @ 7993' RKB Casing bridge plug 3/18/2019 3.958 8,084.0 6,798.3 63.79 NIPPLE REDUCER 3.813" XN NIPPLE x 2.313" X NIPPLE REDUCER (OAL=54") 12/18/2018 2.313 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,817.2 6,657.2 52.01 1 INJ DMY RKP 1 1/2 4/20/2019 RK Latch Schlumb erger Camco MMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,572.6 6,920.7 86.10 OPEN HOLE 6.125 Horizontal, CD3-112, 3/23/2024 7:35:27 AM Vertical schematic (actual) OPEN HOLE; 8,572.6-16,021.0 INTERMEDIATE; 34.2-8,572.6 NIPPLE REDUCER; 8,084.0 PACKER; 8,023.1 TUBING CUT; 7,993.0 NIPPLE; 7,966.7 PACKER; 7,908.4 INJ; 7,817.2 SURFACE; 36.5-2,726.0 NIPPLE; 2,181.3 CONDUCTOR Insulated 24"; 36.0-114.0 HANGER; 31.1 WNS INJ KB-Grd (ft) 42.76 RR Date 4/13/2006 Other Elev… CD3-112 ... TD Act Btm (ftKB) 16,021.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032052700 Wellbore Status INJ Max Angle & MD Incl (°) 92.84 MD (ftKB) 10,277.56 WELLNAME WELLBORECD3-112 Annotation Last WO: End Date 4/10/2019 H2S (ppm) DateComment SSSV: A-1 INJ VLV ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION FIELD 206032 BP North Slope 1 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. 1 0 0 Attn: NSK-69 RECEIVED 700 G Street MAY 2 12019 Anchorage. Alaska 99501 0 )I 0 V: Natural Resources Technician II ka Oil & Gas Conservation Commision W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 1 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Print Name Signa Please return viva e-mail a copy to both Alaska E -Line Services and Phillips Alaska: !/f Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY 0 9 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ �pypa�) Performetl: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing E] Chan ¢'e /Ep�Fovro rem 9 ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well (] Re-enter Susp Well ❑ Other: Tubing Patch 0 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service p 206-032 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 1 50-103-20527-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, ADL 364471, ADL 384215 CRU CD3 -112 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 16,021 feet Plugs measured None feel true vertical 6,946 feet Junk measured None feet Effective Depth measured 16,021 feet Packer measured 7908, 8023 feet true vertical 6,946 feet true vertical 6711, 6770 feet Casing Length size MD TVD Burst Collapse CONDUCTOR 78 feet 16 114' MD 114' TVD SURFACE 2,690 feet 9 5/8 " 2,726' MD 2485' TVD INTERMEDIATE 8,538 feet 7 8,573' MD 6920' TVD OPEN HOLE 7,448 feet 6 1/8 " 16,021' MD 6946' TVD Perforation depth: Measured depth: N/A feet True Vertical depth: N/A feet Tubing (size, grade, measured and true vertical depth) 3.5 x 4.5 L-80 8,095' MD 6,803' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PACKEF 7,908' MD 6,711' TVD PACKER - BAKER PREMIER PACKER 8,023' MD 6,770' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA 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: NIA 2000 2000 700 3400-Gasrz500-Water Subsequent to operation: NIA 1700 2000 600 3400-Gas/2500-Water 14. Attachments (required per 2c AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 17 Exploratory ❑ Development ❑ Service O Stratigmphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG EI 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: 318573 Contact Name: Dusty Ward Authorized Name: Dusty Ward Contact Email: Dusty.Ward@cop.com Authorized Title: Sr. Wells Engineer Authorized Signature: Date S 1 Contact Phone: (907) 2655531 Form 10-404 Revised 4/2017 V%•1— 5-12//lg 1(/% 1BDMS.( j MAY 10 2019 Submit Original Only WNS INJ WELLNAME C133-112 ConocoPhillips w.fi Attributes IFIeW Neme �TWea-Z-PBUW) W+e'IMre'. AIBSI(a. i1C. FIORfJ NFCHFI IK 1SnfatJn9lnn INJ VLV I I IL.tWO'. WELLBORE CD3 -112 nmimael-cD3-nz seno+Paso:+a AM Last Tag Vm0' °tlaaTlaaEnll AnnahMn oep+h (N(6) End Dab weNWre LaaLMo]By Last Tag: CD3 -112 Inne,vals, _.._..........................._........... ....... ......_..... Last Rev Reason xarei annoblion End Dab wNllwre LastMI Rev Reason'. Post RWO, NU for IT, 4202019 CD3 -112 lboehmbh Casing Strings .. _...... ___.. .... ... Casing Deaen"On O9 oral It)(.) TnPmKa CONDUCTOR Insulated 16 15.01 35.0 24' BM Depm mKB) set Depth irvoe.. wuLen n_6raae INEWD 114.0 114.0 84.00 J-55 WEIDED Coming DO 6DD (in)) ID OnI Top IMB)) setoewh(nKel set Dagn lrvbl... wuLm9...araae Topmroaa SURFACE 9518 8.83 38.5 2.T16.0 24854 40.00 L-80 BTC wn Casing Deriptio00 (in) ID(Jn) Top INTERMEDIATE ] 6.26 34.2 IMKB) SN Kom(WEN SH Dent CENN IWn.en (I - Grade Tap ThmM 8,572.6 6.9207 26.00 L-80 BTCM Casing Dewnpnon U,U pin'ID(nj ioPmK81 OPEN HOLE 61/0 8,572.6 Set Oepm mKB) SA Grant No sal (I...Grade Top Thmtl 16,021.0 Tubing Strings CONOUCTOROUWaml 3P, aB.anaD Tubing Donamn a. Ma...mpn) Top mKB) sM brom ht_am Depth MED IIM(I.1 Grade Tooc*nnmhon Tubing -W02019 3112 299 31.1 >,998.0 6.758.0 9.30 L-80 C. Completion Details TO0M ) Top Incl TOO RIK'"Bj 1'1 IMM Des B) Nomura+ Onm ID (in) 31.1 31.1 000 Hanger FMC 11"x4-/ I Alpine RAIICOtel producer III ei3SlDmer 3.900 seals 116.1 116.1 0.60 TO Enlarging 4-12-12640L-8056311ydrilx3l 3r LdO5 HydrilX-0 2992 2,1813 2,03.7 32.91 Nipple - X 3-12'(2.813- HES "X"nip*)S/N 1605-03 2.813 7,9084 8,]10.] 56,13 Packer BakerPremier Pecker Assy PN H] 63-0255 2.840 7.9663 8742.1 58.80 Nipple-XN 2.813- XN vath 2.75'NO-Go Hyd 563 BXPWIN PRO plug installed 2.750 SM 21605a4 7,987.5 6,7523 59.75 TOEnlarging 3-12'9.340--80553 HyddI B x EUE Min 2.992 7,989.3 6)53.6 59.83 oor Dy Baer DONDy 4.5"7ubing LIverslFat WlO Padang 7"x 12" 4.80 Overshot Npminal6.5'ol Swallow Tubing D9KriPlion el+mg Ma... la (n) TOP (BK81 Tubing -Original 4112 396 7,993.8 Postal . set OePh+nVDl l-. W111M6 stale TOp LOnneclion 96.5 6,8037 12.60 L-80 Completion Details SURFACE M5 2,72ru- ToplNDl Topmnl Top(nKB) yon.) I Imor Deo Nominal Com 10 (in) 8,023.1 6,770.2 61.36 PACKER BAKER PREMIER PACKER 3875 8,084.0 6.ImS6 1 63.80NIPPLE HES WIN NIPPLE 'Nipple Reducer Installed or 231W XProfile^ 3.725 8,095.1 6,803.1 1 64.24 WLEG WIRELINE ENTRY GUIDE 3875 M°ndmezevs Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) ran (IDI Top +n c+ Top mKel mKB) I'I Ma coin para Dam IDIm) 2,181 3 2,030 J 291 INJ VALVE "A- Injection valve 5212.2. OAL= on 2.81" 420/2019 1,250 X- 0d 7.903.01 6,755.5 60.00 TUBING CUT ITUBING CUT @ 799Y PIKE 31182019 3.958 PaLRB1'° 8, 40 6498.3 ..'a NIP LE REDUCER 381YXNN1PPLEx2,313"%NIPPLE U 12118/20 2.313 (DAL=54") e Mandrel Inserts aslti N TOPw 1 ToM"-B) I mKB) Mak¢ Matlel O011nl 3ery Valle Type Lamb IPI9ite Tyya lin) TRORun (psi) Ren. I Com 1 7,81].2 6,65]2 SLB MM 112 U,ASLIFT DMY RKP 4202019 RK Latch Notes: General a Safety End Data Assistance 7117006 NOTE:TREE-FMC UNIHEAD ENII41/16"5KPSI-TREECAP-7"OTIS M91F NOTE:VIEWSCHEMATICWAlas"S5 emauc9. TUBING CUT TRIED PoaRq'OwNgt 7,Sg3 PACNER, x02]1 NIPPLE, 8084.0 NIPPLE REDUCER. e.N4.0 WLEG;Bf4e_I INTERMEONTE.3SUMLE726 OPEN HOLE, 1IMS-160210-� •••• Operations Summary (with Timelog Depths) CD3 -112 ' Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Time End TimDur (hQ Phase Op Cone Activity Code Time P -T -X Operation Stan Depen (ftKB) EM Depth(ftKB) 4/5/2019 4/5/2019 5.50 MIRU MOVE RURD P RDMO from CD3 -115 00:00 05:30 4/5/2019 415/2019 9.00 MIRU MOVE RGRP T Hydraulic drive motor blew out seal on 05:30 14:30 driller side out side drive axle. Spill reported to security and first report was generated, called DSO lead. Removed and replaced drive motor. 4/5/2019 4/512019 3.50 MIRU MOVE RURD P MIRU on CD3 -112 spot rig over hole 14:30 18:00 1 shim up rig spot in cuttings tank 4/5/2019 4/5/2019 1.00 MIRU WHDBOP NUND P N/D Tree, set on rig mats. 18:00 19:00 1 4/5/2019 4/6/2019 5.00 MIRU WHDBOP NUND P Install Blanking plug, install needle 19:00 00:00 valve on control line, N/U 11" BOP Stack. 4/6/2019 4/6/2019 2.00 MIRU WHDBOP NUND P Continue N/U BOP'S, hook up choke 7,990.0 7,990.0 00:00 02:00 & kill lines, install riser. 4/6/2019 4/6/2019 2.00 MIRU WHDBOP BOPE P Rig up to test BOP'S 7,990.0 7,990.0 02:00 04:00 4/6/2019 4/6/2019 8.50 MIRU WHDBOP BOPE P Test BOP'S with 3 1/2 and 4 1/2 test 7,990.0 7,990.0 04:00 12:30 joints, test annulars @ 250/3500, test rams, choke valves, HCR kill and choke valves @ 250/4000 PSI f/ 5 Min each. 4/6/2019 4/612019 2.00 MIRU WHDBOP BOPE P Pull blanking plug. pull BPV, BOLDS, 7,990.0 7,990.0 12:30 14:30 clear pipehouse , reseal riser nipple. 4/6/2019 4/6/2019 1.00 COMPZN RPCOMP PULD P Pull hanger UFloor, Broke @ 100k, p/u 7,990.0 7,990.0 14:30 15:30 wt 84 k, lay DWN hanger and landing joint. 4/6/2019 4/6/2019 1.50 COMPZN RPCOMP CIRC P PJSM, reverse circulate 20 bbls, 9.8 7,990.0 7,990.0 15:30 17:00 ppg, circ 40 bbls, down tubing. 4/6/2019 416/2019 1.00 COMPZN RPCOMP PULD P PJSM, LID 4 1/2" 12.6# L-80 IBTM 7,990.0 6,532.0 17:00 18:00 tubing 416/2019 4/6/2019 1.00 COMPZN RPCOMP OTHR T Inspect Derrick. Safety pin fell out of 6,532.0 6,532.0 18:00 19:00 derrick onto rig floor. 4/6/2019 4/7/2019 5.00 COMPZN RPCOMP PULD P PJSM, UD 4 1/2" 12.6# L-80 IBTM 6,532.0 6,532.0 19:00 00:00 tubing 4/7/2019 4/7/2019 12.75 COMPZN RPCOMP PULD P Continue UD 4 1/2" 12.6# L-80 IBTM 6,532.0 0.0 00:00 12:45 tubing F/6532'T/surface3l. REcovered 59 SS bands from control line. 4/7/2019 47/2019 3.25 COMPZN RPCOMP RURD P Clear floor ofequipment perform 12:45 16:00 Derrick Inspection, finish slarpping pipe removed from well, crane spooler unit off rig floor with 3rd party crane, change out power tongs from Nordic to Weatherford, unload pipe shed, 4/7/2019 4/8/2019 8.00 COMPZN RPCOMP RURD P Load and process new 3 112 9.3# 16:00 00:00 HYD 563, completion in pipe shed, Drift w/ 2.867drift, Rig up weatherford power tongs, swp handling equip. F/ 4 112 T/ 3 112 4/8/2019 4/8/2019 2.00 COMPZN RPCOMP RURD P Continue to Load and process new 3 00:00 02:00 1/2 9.3# HYD 563, completion in pipe shed, Drift w/ 2.867drift, 4/8/2019 4/8/2019 1.00 COMPZN RPCOMP OTHR T Safety stand down, Investigate 02:00 03:00 dropped object, lost pipe off of pipe elevator. 4/8/2019 4/8/2019 3.00 COMPZN RPCOMP RURD P Continue to Load and process new 3 03:00 06:00 1/2 9.3# HYD 563, completion in pipe shed, Drift w/ 2.867drift, Page 1/2 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) CD3 -112 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Op Cade Ad" Code Time P -T -X Operation Stan Depth (4Ka) End Depth (111<8) 4/8/2019 4/8/2019 1.00 COMPZN RPCOMP RGRP T Ball vavle on fresh water line failed 06:00 07:00 spilled water into motor room and containment 20 gallons to the pad. isolated valve and replaced cleaned up spill. 4/8/2019 4/8/2019 4.50 COMPZN RPCOMP RURD P Continue to Load and process new 3 07:00 11:30 1/2 9.3# HYD 563, completion in pipe shed, Drift w/ 2.867drift, 4/8/2019 4/8/2019 0.50 COMPZN RPCOMP SFTY P Hold prejob safety meeting on running 11:30 12:1 tubing. 4/8/2019 4/8/2019 0.25 COMPZN RPCOMP KURD P Rig up floor to run tubing 12:00 12:15 1 4/8/2019 4/8/2019 5.75 COMPZN RPCOMP PUTS P Start running in the hole with 3-1/2" 24.2 3,499.0 12:15 18:00 563 Hydril 9.3# 1-80 4/8/2019 4/8/2019 0.50 COMPZN RPCOMP SFTY P Crew C/O new tour on shift have crew 3,499.0 3,499.0 18:00 18:30 C/O on rig to familiarize incoming crew with current operation. 4/8/2019 4/9/2019 5.50 COMPZN RPCOMP PUTB P Continue RIH with 3-1/2" 563 Hydril 3,499.0 7,540.0 18:30 00:00 9.3# 1-80 T/ 7540'. 4/9/2019 4/9/2019 COMPZN 00:00 00:00 4/9/2019 4/9/2019 2.00 COMPZN RPCOMP PUTB P Continue RIH with 3-1/2" 563 Hydril 00:00 02:00 9.3# 1-80 F/ 7540' T/ 7990'. Tag with overshot[ @ 7990, P/U 63 K, S/O 58K, Slack of 14K, shear shear screws, $IO 3"V nogo 4/9/2019 4/9/2019 4.00 COMPZN RPCOMP THGR P LD 5 jts 3.5lbg, p/u 3 pups, 2 ea. 4 02:00 06:00 1/2 jts, make up hanger and landing jt. drain stack and land hanger. Run in LDS. Test ahnger. Drop ball and rod. 4/9/2019 4/9/2019 1.50 COMPZN RPCOMP RURD P R/U test hoses to squeeze manifold 06:00 07:30 4/9/2019 4/9/2019 2.00 COMPZN RPCOMP PRTS P Set PKR, pressure test tubing @ 3500 07:30 09:30 psi F/ 5 min, bleed tubing T/ 2000 psi, test IA @ 3000 psi F/ 30 min. bleed down tubing and shear SOV. 4/9/2019 4/9/2019 0.50 COMPZN RPCOMP RURD P Rig down hoses, UD landing joint. 09:30 10:00 4/9/2019 4/912019 1.00 COMPZN RPCOMP MPSP P Set BPV and test @ 1000 psi from 10:00 11:00 below F/ 5 min. 419/2019 4/9/2019 6.00 COMPZN WHDBOP NUND P PJSM, Nipple OWN BOP'S. 11:00 17:00 4/9/2019 4/9/2019 2.00 COMPZN WHDBOP NUND P N/U FMC 5 K tree, test void @ 5000 17:00 19:00 1 psi. 4/9/2019 4/10/2019 5.00 COMPZN WHDBOP MPSP P Rig up and test tree @ 250 / 5000 psi. 19:00 00:00 1 I Pull BPV, rig up to freeze protect well. 4/10/2019 4/10/2019 5.00 COMPZN WHDBOP FRZP P Rig up and test lines, Freeze protect 00:00 05:00 well w/ 80 bbls diesel, U Tube well blow down surface lines. at BPV, rig down lines and valves from tree, install flange and gauge on IA valve. 4/10/2019 4/10/2019 1.00 COMPZN WHDBOP MPSP P Install H BPV. RIG RELEASED at 05:00 06:00 06:00 4/10/2019 4/11/2019 18.00 COMPZN MOVE RURD P Prep rig for rig for demob. remove 06:00 00:00 equipment from rig floor and pipe house. Remove canvas wind walls from cellar, clean up location, load out equip. Page 212 Report Printed: 5/312019 MEMORANDUM TO: Jim Regg `2e,69 P.I. Supervisor FROM: Matt Herrera Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 1, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. CD3 -112 COLVILLE RIV FIORD CD3 -112 Src: Inspector Reviewed By: -EF— NON-CONFIDENTIAL Supry -EF— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3 -112 API Well Number 50-103-20527-00-00 Inspector Name: Matt Herrera Permit Number: 206-032-0 Inspection Date: 4/28/2019 Insp Num: mitMFH190429053253 Rel Insp Num: Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well CD3112 �Typelnj c jTVD 6770 ..Tubing 3428 - 3430 3429 - 3129 " PTD 2060320 '�Type Test SPT ,Test DSI 1692 LA 680 2020 - 1970 1960 BBL Pumped. !BBL Returned: 1 OA 405 522_�sas w Interval INITAL iPIF P Notes: Initial MIT -IA Post RAO Per Sundry 318-573 IA Pressure testd to 2000 PSI per Operator Wednesday, May 1, 2019 Page I of 1 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Ward Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3 -112 Permit to Drill Number: 206-032 Sundry Number: 318-573 Dear Mr. Ward: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.clo5ka.gov Enclosed is the approved application for the 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, OX2�� Daniel T. Seamount, Jr. Commissioner T DATED this zt day of February, 2019. SCANNED FEB 0 4 2019 r) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �rL " zui6 20 AAC 25.280 1. Type of Request: Abandon Plug Perforations ❑ Fracture Stimulate LJ Repair Well ° Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class. 5. Permit to Drill Number. ConocoPhilll s Alaska Inc. Exploratory ❑ Development❑ Stratigraphic ❑ Service ❑� 206-032 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20527-00 —cu 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this por N/A Will planned Perforations require a spacing exception? Yes ElNo ❑� CRU CD3 -112 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 0372105 / ADL 0364471 / ADL0384215 Colville River Field / Fiord Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft) Effective Depth MD: Effective Depth TVD MPSP (psi):/ Plugs (MD): Junk (MD): 16,021' • 6,946' 16021' 6946' 3869 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2,690' 9-5/8" 2,726' 2.485' Intermediate 8,538' 7" 8,573' 6,920' Open Hole 7448' 6-1/8" 16,021' 6,946' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4.500" L-80 8,097' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SSSV - SAL -0 W/ DB PROFILE MD= 2169 TVD= 2020 PACKER-PARAGONII MD=3108 TVD=2806 PACKER-PARAGONII MD= 3128 TVD=2823 PACKER-PARAGONII MD= 3150 TVD=2842 PACKER-PARAGONII MD= 4768 TVD=4228 PACKER-PARAGONII MD=4788 TVD=4244 PACKER-PARAGONII MD= 4868 TVD=4306 PACKER-PARAGONII MD= 4900 TVD=4330 PACKER - BAKER PREMIER PACKER MD= 8023 TVD= 6770 12. Attachments. Proposal Summary Wellbore schematicO 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑ Service ❑✓ 14. Estimated Date for�„,�� 9 15. Well Status after proposed work: Commencing Operations: / s�1 G9 / OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG Q 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. Dusty Ward Contact Name: Dusty Ward Authorized Title: Sr. Wells Engineers Contact Email: Dusty.Ward@conocophillips.com Authorized Signature: % ^1 Contact Phone: ;907) 265-6531 —✓ ifi�' Date: 11-0101 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ I l Plug Integrity ❑ BOP TestR Mechanical Integrity TestLJ location Clearance ❑ - Le Othereop ffSi- to #06/0P56 /`<5 t- 7a"t, -7a uliow %tn✓tr lar�7-�✓rnt<r A 'ar-/6 i � J1lac<d uio7o' D abo✓ Post Initial Injection MIT Red'I Yes �No ❑ th +! packr6Mt Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Z Approved by: a COMMISSIONER THE COMMISSION Date: Form 10-403 Revise 42017 Z0Submit Form and GG FEB 0 5 2nehments 77 ad aPPlcal m e d1J 1J �0�2at,/ F/1 -V ConoeoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 19 Dec, 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 711 Avenue Suite 100 /V DearAnchorage, Alaska 99501 I V Dear Commissioner: ConocoPhillips Alaska, Inc. (CPAI) hereby applies for Sundry Approval to workover Injector CD3 -112 (PTD# 206- 032). CD3 -112 was drilled and completed in April of 2006 as a Fjord Nechelik WAG injection well. The well was briefly flowed back then put on WAG injection. In March 2016 the well experienced IA pressurization after a bleed down. T x IA communication on MI was confirmed in May 2016. Various patches have been set in the well to mitigate the issue, but this well became a RWO candidate to replace the tubing completion with gas tight connections back to surface to get it back on MI. The well will have a plug placed in the XN-nipple profile in the tubing tail as a barrier to the formation. The tubing will be pulled down to the pre -rig cut. The well will be recompleted with a non -sealing overshot and a stacked packer with gas tight completion to surface. The tubing size will be reduced for majority o t e well om 4.5" to 3- 7rTu 'ulars. The new stacked packer will beset at approximately 7900' RKB, which is about 330' below calculated TOC and 670' MD above open hole interval. This Sundry requests a variance from 20 AAC 25.412 to al ow the stacked packer to be set approximately 670' MD above the open hole interval. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty WardA�� Senior Wells Engineer CPAI Drilling and Wells CD3 -112 RWO Procedure Alpine Injector PTD #206-032 Pre-Rie Work 1. Remove injection valve. 2. Remove tubing patch. 3. Get additional SBHP. 4. Set reducer nipple and plug in tubing tale XN nipple at 8084' RKB to isolate RWO from formation. 5. Cut tubing at —7990' RKB. 6. Confirm deepest GLM is open. 7. Install BPV. Rig Work MIRU 1. MIRU Nordic 1. 2. Record shut-in pressures on the T & IA. Plug and packer should provide competent barrier. If there is pressure, bleed off IA and/or tubing pressure and pull BPV. Complete 30 -minute NFT. Verify well is dead. a. Primary barrier: Plug, packer and competent casing. KWF will be available as backup primary. b. Secondary barrier: Packoffs and Tree OR BOP. (BPV in place and confirmed in direction of flow while swapping tree to BOP and vice versa.) 3. Set BPV if pulled to bleed off pressure, confirm BPV, ND Tree, NU BOPE and test to 250/4,000 psi. Test annular 250/3,500 psi. a. MPSP of 3869 PSIG calculated from SBHP of 4547psig at 8050' RKB (6782' TVD) on 8/22/2014. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2" tubing with jewelry down to pre -rig cut at 7990' RKB. Install in 4-1/2" and 3-Y:" Gas Tight Tubing 6. MU 4-1/2" x 3-1/2' completion with non -sealing overshot, nipples (one set up for wireline conveyed injection valve), packer, and GLMs. RIH and confirm overshot has engaged tubing stub. 7. Space out, land tubing hanger and install packoffs. 8. Drop ball and rod and set packer top @ approximately 7900' RKB (6705' TVD) w/ completion. a. TOC calculated at 7588' RKB (6502' TVD). 9. Pressure test tubing to 4200 psi for 5 minutes. 10. Pressure test inner annulus to 3300 psi for 30 minutes on chart. ND BOP, NU Tree 11. Confirm pressure tests, then shear out SOV with pressure differential. 12. Install BPV. Confirm BPV. 13. NO BOPE. NU tree. 14. Freeze protect well. 15. RDMO. Page 1 of 1 WNS INJ CD3 -112 COIRJIVritlI[lp$ W�IAttributes MaxAgkBMD TO M x Angle Wellp1 PPWNN Fk14 Name WNI0on 51Aue MI aM (XKB) AIa5k6.ln.. 501032062]00 FIORDNECHEUK INJ 92.84 10.277.56 16,ML0 C¢mIMM H28lPPn) Dale AnnoWbn -Dab KB-0MIX) PIB fleIeM ONe SSSV A -i INJ VLV Laa1W0. 4276 4/132006 Hab I-C01112.4DWGta102a24RN Last Tag .."NommamL.Naha, AnrolMen OPIR, IXKB) I En40Me LMMW By Lasi Tag: Imoa60r War Last Rev Reason NANGM 312 Anncoup.. Enopale Laal Matl By �. ...... RCV Reason: SET PATCHES b RESET AT iNJ VLV 4252018 JO,R, Casing Strings Ga¢mp Dexnpllen OD(Im 1.(I.) ITP,,LNmn lam. 1IIHKR) $110[Wn ITV.).. WtlLen 11 One Top TM1naa CONDUCTOR InsUlaietl i6 15.010 SRO 1140 t14.0 &4.00 Y55 WELDED 24" Cxlnp De¢npllen OD(In) IOIIn) TOP INS.) SM CaMM1IM1KB) Bel (epM IlVD1... WVLan Q... G25e Top TbeaE SURFACE 95`8 8.835 38.5 27260 2.485A 40.00 L-00 BTC cmanO Gncnglon OOHn) ID(ln) Top(XKBI 8M 0.MF(XKe) 8e1 Oman 1TVD1WaLen 11... UMe TOPTXrtaO INTERMEDIATE J 8.276 34.2 &,5]2.6 8.9207 26.00 LBO BTCM Chains.-HpWn 00 (in) ID (in) Tep UuNN-Mpn(na., M0.pIM1 1TVD)... WIILan (L.. GR4e Top Th NO CONDUCTOR Ieemm!2 y0� OPEN HOLE 6118 86726 160210 Tubing Strings TUNng Des[npllon SIXng Ma.. lO(ln) iep IM1NR) SN won1X„BN Osp1M1 nY0)I... WIBDm) GraOe To, Lonne[Ylon j TUBING 412 3.958 312 80965 6003.7 12601.80 Ilr Completion Details BPFETV Y -V, 2.LNR Top(TVD) To,a. Nominal A, VALVE:2J8a.9 T0p(M1KB) (M1KB) (°) Xem R¢ Cam 10 (In) v°LVEq,IaeA 31.2 31.2 000 HANGER FMC TUBING HANGER 3,958 2.168.9 2.020.3 33.02 SAFETYVLV BALD WIDE PROFILE 3.812 60231 6770.2 61.35 PACKER BAKER PREMIER PACKER 3,875 6084.0 67983 63.60 NIPPLE HIS XN'NIPPLE 3725 8,095.1 6803.1 64.24 WILES WIRELINE ENTRY GUIDE 387 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tep(T0) Top Incl TOPUTRS) (nrca) 1•) oe8 Com Run OL. I01m) 2,168.9 2020.3 33,021NJVALVE MODIFIED A4 INJ VALVE (SN: MRS4H ON 3.81- DB- 4I2S2018 1350 LOCK sugFAc82eSv2eA l 3.108A 2806.4 3209 Upper Packer UPPER 3M' PARAGON 2 PACKER ISN: ALPPo5011) 4Y 018 2,000 PATCH EXTENSION (OAL=22.OT1 MIN ID = T) upper Pe[Xer: m0e0 3.112.0 2.809.8 32.06 Spacer Plea SPACER %P BLATCH SEAL ASSEMBLY (SN: 4 18 1.£95 swnrPpe:vae CPAL45007) 3,128.0 2.823.4 31.95 LOWer Packer UPPER PARAGON PACKER ISN: AlPPo5008)MID 442/2018 2.000 Lover Peon: i Iia G ELEMENT @ 3152 RKB ( DAL OF PATCH ASSEMBLY 23.35') 9gnrPpeeuhnsRh G le SASSO 2827.6 31.92 Spacer Pipe& LaiC6 e9al SPACER PIP & LATCH SEAL ASSEMBLY (ALPAL45005) 5 Lweree[ker J450D 3AWA 2.842 ,1 31.81 LOWer Packer 3M" PARAGON 2 PACKER (SN: ALPP4S006/480 DAL / MIN ID T) MID ELEMENT @ 3152' RKB. 4768.0 4,MLl 39.37 Upper Packer UPPER 378' PARAGON 2 PACKER (SN: ALPP450upnrPeaer:11.1 GAL OF UPPER PATCH 21.5'/ MIN ID 1.995 t4�MOIS 47]20 4.231.2 3939 Spapar pipe& SPACER PIPE& LATCH SEAL(SN'. ALPAL )5 LmmrPe[bnVfiaG 47850 4,243.6 3944 LDWer P.O. LOWER 3.]8' PARAGONZ ACKER(SN: 0ALPP450IU IT ID 1089' DAL ) SET MID ELEMENT 4]90' RKB, 4,868.1 4,305.6 3915 Upper Packer UPPER 378' PARAGON 2 PACKER (SN: FLPP4S0071 44061018 2000 upper Penes Oaaa1 OAL 431')MIDEUEMENT,1870RKB,(OWLOF a•en RINaLercn8n4 UPPER PATCH= 33.67) OA726 4,8726 4,309.0 39.13 Spacal ACER PIPE B LATCH SEAL ASSEMBLY ISM 41102018 1.995 LMCX Seal ALPAL45002) LMrPe[An: 4.900.0 4,906.0 4.330.3 3879 Lmver Packer EWPSLEME WTWITH 4/154018 2000 Nib r#ALP4S012I .Sv OA-) SET WITH MID ELEMENT i @ 4074501214.89'OAL) X4902 RKB Mandrel Inserts s1 pl Gl4LIGT:]At]] N Top (XKSI Tap IllVeale (XI®1 Mme MOON OD On) Gry THIN Lalen Type PM SItt HS TqO Run (066 Run DMe Lam 1 7,913) 6713) Camaq KBG2 1 GAS LIFT DMY BH 0.000 0.0 14T/20W Notes: General 8 Safety Ena Ds[ Mammalian 4/1612006 NOTE: TREE FMCUMHEADGENH4UW5KPSI-TREECAPTOTS 5'22/2010 NOTE: VIEWSCHEMAOCW/Alaska SCKemitkSO PACKER: 80271 NIPPLE: 6A890 WLED.R.11 INTERMEDATE:112$572.8 OPEN HOLE: 6S]2B18A21 O- ••, CD3 -112 Proposed RWO Completion 6.15" Open Hole @ 16021' RKB 4-1/2" 12.6# HYD 563 Hanger 4-112" 12.6# HYD 563 crossover to 3-1/2" 9.3# HYD 563 3-1/2" X landing nipple at -2169' RKB (2.812" min ID) Set up for wireline set injection valve. 3-1/2" Camco gas Iib mandrels @ TBD Baker 3-1/2" x7" Premier Packer xxxx' RKB (2.850" ID) 3-1/2" 9.3# HYD 563 3-1/2" X landing nipple at x x' RKB (2.812" min ID) 3-1/2" 9.3# HYD 563 crossover to 4-1/2" 12.6# HYD 563 4-1/2" Non -Sealing Overshot @ -7990' RKB REMAINING COMPLETION LEFT IN HOLE Baker 4-1/2" x 7" Premier Packer @ 8023' RKB (3.875" ID) HES XN nipple @ 8084' RKB (3.725" ID) Nipple Reducer added for drifting plugs through 3.5" 9.3# tubing. Baker Wireline Entry Guide @ 8095' RKB • • 206032 WELL LOG TRANSMITTAL#904786333 2 9 3 8 1 To: Alaska Oil and Gas Conservation Comm. June 11, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 202018 AOGCC RE: Packer Set Record: CD3-112 Run Date: 04/15/2018, 04/21/2018, and 04/22/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 CD3-112 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20527-00 Packer Set Record 1 Color Log- each 50-103-20527-00 SCOW PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 n Office: 907-275-2605 FRS_ANC@halliburton.com :zoo Signed: ' � L Date: STATE OF ALASKA RECEIVED AA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS MAY 1 6 2018 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Oper.tio s s td vn U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Chant •• "�n� ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑., Re-enter Susp Well❑ Other: Tubing Patch U 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 206-032 3.Address: P.O.Box 100360 Stratigraphic ❑ Service ❑✓ 6.API Number: Anchorage,AK 99510 50-103-20527-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0372105/ADL0364471/ADL0384215 CRU CD3-112 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 16021' feet Plugs measured N/A feet true vertical 6946' feet Junk measured N/A feet Effective Depth measured 16021' feet Packer measured 8023' feet true vertical 6946' feet true vertical 6770' feet Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2690' 9-5/8" 2726' 2485' Intermediate 8538' 7" 8573' 6920' Perforation depth Measured depth 8572'-16021' feet True Vertical depth 6921'-6946' feet Tubing(size,grade,measured and true vertical depth) 4-1/2" L-80 8097' 6804' Packers and SSSV(type,measured and true vertical depth) Packer Baker Premier 8023' 6770' SSSV BAL-O Nipple 2169' 2020' Upper Patch Packer Paragon-II 3108' 2806' Mid Patch Packer Paragon-II 3128' 2823' Lower Patch Packer Paragon-II 3150' 2842' I SCANNED AA�� Upper Patch Packer Paragon-II 4768' 4228' JIJN 1 1. 20 M Lower Patch Packer Paragon-II 4788' 4243' Upper Patch Packer Paragon-II 4868' 4306' Lower Patch Packer Paragon-II 4900' 4330' 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&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 ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑., GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-163 Authorized Name: Rachel Kautz Contact Name: Travis Smith/Rachel Kautz Authorized Title: Well�JIntegrity Supervisor� / Contact Email: N2549Cu�conocophillips.com Authorized Signature: `,=�/i�/�'t�L-.� Date: --/3 '/( Contact Phone: 659-7126 Form 10-404 Revised 4/2017 VTI- C-16. 1 /D RBDMS KAY 15t MS Submit Original Only • • ConocoPh i lli ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 13, 2018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French: Enclosed please find the 10-404 Report of Sundry Well Operations for the tubing patch repair completed on CRU CD3-112 (PTD 206-032). Please contact Travis Smith or myself at 659-7126 if you have any questions. Sincerely, ,//261 Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska, Inc. • • Date Event Summary Executive Alpine well CRU CD3-112 was previously discovered to have TxIA communication while Summary injecting water. The results of a diagnostic leak detect log suggested multiple leak points. Multiple tubing patches were set across the suspected leak depths in an attempt to repair the tubing. After the patches were set, a MITIA was performed and passed. 04/15/18 3.76" P2P w/AGGRESSIVE SLIPS (#ALPP45012) MID ELEM @ 4902' RKB. SET TEST TOOL IN P2P. ATTEMPT TO CMIT; LOSING 150 PSI PER MIN. IN PROGRESS. 04/16/18 SET TEST TOOL IN P2P @ 4902' RKB. CMIT TO 2500 (PASS). PULLED TEST TOOL. SET 3.76" P2P w/AGGRESSIVE SLIPS (#ALPP45011), SPACER PIPE, ANCHOR LATCH (#ALPAL45002) MID ELEM @ 4872' RKB. ATTEMPTED CMIT TO 2500 PSI WITH TEST TOOL SET IN P2P. FAIL. LOST 200 PSI PER MIN. RD FOR HIGHER PRIORITY WORK. 04/18/18 ATTEMPT CMIT TBG x IA WITH TTS TEST TOOL SET IN UPPER PACKER & D&D HOLE FINDER, BOTH FAILED. PULLED 33'x 3.76" PIIP PACTH ASSEMBLY @ 4872' RKB. IN PROGRESS. 04/20/18 B&F TBG TO PIIP PACKER SET @ 4902' RKB. TEST PACKER TO 2500PSI. SET UPPER PATCH ASSY(OAL=33.67', MIN ID 1.995") ON HES DPU @ SAME. IN PROGRESS... 04/21/18 SET TEST TOOL IN UPPER PACKER @ 4870' RKB. CMIT TBG x IA 2500 PSI ( PASS ) SET LOWER 3.76" PIIP MID ELEMENT @ 4790' RKB. CMIT TBG x IA 2500 PSI ( PASS ) IN PROGRESS 04/22/18 SET UPPER 3.76"x 21.5' PIIP PATCH ASSEMBLY MID ELEMENT @ 4770' RKB. CMIT AGAINST TEST TOOL 2500 PSI ( PASS ) SET LOWER 3.76" PIIP MID ELEMENT @ 3152' RKB. CMIT AGAINST TEST TOOL 2500 PSI ( PASS ) SET UPPER 3.76"x 21.35' PIIP PATCH ASSEMBLY MID ELEMENT @ 3130' RKB. MIT x IA 3000 PSI, FAILED WITH AN INJECTIVITY RATE OF .2 BPM. SET TEST TOOL IN UPPER PACKER @ 3130' RKB. CMIT TBG x IA 2500 PSI (PASS ) IN PROGRESS. 04/25/18 SET MODIFIED A-1 INJ VALVE (SN: HRS-44) @ 2168' RKB. PERFORMED GOOD CLOSURE TEST. COMPLETE 05/10/18 State Witnessed (Austin McLeod) MIT-IA Passed to 3310 psi. Initial T/I/O =2000/1180/566. IA FL @ surface. Pressurized IA to 3310 psi w/ 1.4 bbls diesel. Starting T/I/O = 2000/3310/826. 15 min T/I/O=2002/3210/813. (-100). 30 min T/I/O= 2002/3200/809. (-10). Passed. Bled IA to 1100 psi (bled back 1.5 bbls), continued to bleed IA to 915 psi. Final T/I/O =2002/915/530. WNS INJ CD3-112 r1A "� n s Well Attributes • Max Angle&MD TD CUCIOCOPhil�ips WellboreAPVUWI Field Name WellboreStatu9 Incl(T) MD MB) Act Btm(ftKB) Alaska,Inc. �Y 501032052700 FIORD NECHELIK INJ 92.84 10,277.56 16,021.0 CODOCOPt' Ps Comment 1125(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date .-- SSSV:A-1 INJ VLV Last WO: 42.76 4/13/2006 Horizontal-CD3-112.426201510:23:24AM Last Tag Vertical schematic(actual) Ar tatlon Depth(ftKB) End Date Laet Mod B1' Last Tag: Imosbor Last Rev Reason ff- HANGER,31 2 Annotation End Dale cLastla"Mad d Rev Reason:SET PATCHES&RESET A-1 INJ VLV 4!25/2016 claytg By 1 1 Casing Description OD(in) ID(int Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... WtlLen(I...Grade Top Thread ') I CONDUCTOR Insulated 16 15.010 36.0 114.0 114.0 84.00 J-55 WELDED 1 24" Casing Description OD(In) ID(in) Top(ftKB) Set Depth(RKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread LI jl'i D SURFACE 95/8 8.835 36.5 2.726.0 2,485.4 40.00 L-80 BTC Casing Description INTERMEDIATE OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread 7 6.276 34.2 8.572.6 6,920.7 26.00 L-80 BTCM Casing Description OD(In) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread OPEN HOLE 6 1/8 8.572.6 16.021,0 CONDUCTOR Insulated 24s. a Tubing Strings 360-1140 Tubing Description String Ma...ID(in) Top(HUB) Set Depth(ft...Set Depth(TVD)(...Wt(IbIH) Grade Top Connection TUBING 41/2 3.958 31.2 8.096.5 6.803.7 12.60 L-80 Completion Details SAFETY VLV;2,1685 Top(TVD) Top incl Nominal INJ VALVE 2 1St 9-. Top(ftKB) (ftKB) (°) Item Des Com ID(in) VALVE.2.165.0ill 31.2 31.2 0,00 HANGER FMC TUBING HANGER 3.958 2.168.9 2.020.3 33.02 SAFETY VLV BALD w/DB PROFILE 3.812 8,023.1 6,770.2 61.35 PACKER BAKER PREMIER PACKER 3.875 -- - 8084.0 6,798.3 63.80 NIPPLE HES'XN'NIPPLE 3.725 8,095.1 6,803.1 64.24 WLEG WIRELINE ENTRY GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB( (ftKB) ("I Des Com Run Date ID(In) 2,168.9 2;020.3 33.02 INJ VALVE MODIFIED A-1 INJ VALVE(SN:HRS-44)ON 3,81"DB- 4/25/2018 1.250 LOCK .• SURFACE;76.5-2.7210 3,108.0 2;806.4 32.09 Upper Packer UPPER 3.76"PARAGON 2 PACKER(SN:ALPP45011) 4/23/2018 2.000 PATCH EXTENSION(OAL=22.07'/MIN ID=2") Upper Packer,3,10e.0 3,112.0 2,809.8 32,06 Spacer Pipe SPACER PIP 8 LATCH SEAL ASSEMBLY(SN: 4/23/2018 1.995 Spacer Pipe:3112CPAL45007) .0 3,128.0 2,823.4 31.95 Lower Packer UPPER PARAGON 2 PACKER(SN:ALPP45008)MID 4/22/2018 2.000 Lower Packer;1128.0ri ELEMENT @ 3152'RKB(OAL OF PATCH ASSEMBLY 23.35') Opener Plpa a Latch sant1 3.133.0 2,827.6 31.92 Spacer Pipe& SPACER PIPE&LATCH SEAL ASSEMBLY 4!22/2018 1.995 1.1]].0 Latch seal (ALPAL45005) Lower PeckaC 1150.011 3,150.0 2,842.1 31.81 Lower Packer 3.76"PARAGON 2 PACKER(SN:ALPP45006/4.89' 4/22/2018 2.000 OAL/MIN ID 2")MID ELEMENT m 3152'RKB. 4,768.0 4,228.1 39.37 Upper Packer UPPER 3.76"PARAGON 2 PACKER(SN:ALPP45009) 4/22/2018 2.000 OAL OF UPPER PATCH 21.5'/MIN ID 1.995 Upper Packer 1,768.0 Spacer pipe&latch seat 4,772.0 4,231.2 39.39 Spacer pipe& SPACER PIPE&LATCH SEAL(SN'ALPAL45004) 4/22/2018 1.995 4.772.0 latch seal Lower Packer:4.7510 4,788.0 4,243.6 39.44 Lower Packer LOWER 3.76"PARAGON 2 PACKER(SN: 4/21/2018 2.000 ALPP45010/2"ID/4.89'GAL)SET MID ELEMENT� 4790'RKB. ri 4,868.1 4,305.6' 39.15 Upper Packer UPPER 3.76"PARAGON 2 PACKER(SN:ALPP45007/ 4/20/2018 2.000 Upper Packer:4.068.1 OAL-4.31')MID ELEMENT 4870'RKB.(OAL OF UPPER PATCH=33.67') Spacer Pipe&Latch Seal; 4172 64,872.6 4,309.0 39,13 Spacer Pipe& SPACER PIPE&LATCH SEAL ASSEMBLY(SN: 4/20/2018 1.995 Q Latch Seal ALPAL45002) Lower Packer.4,900.0 4,900.0 4,330.3 38.79 Lower Packer 3.76"PARAGON 2 PACKER W/AGRASSIVE SLIPS 4/15/2018 2.000 (1tALPP45012!4.89'OAL)SET WITH MID ELEMENT f1 4902'RKB Mandrel Inserts St all Top(TVD) Valve Latch Port Size TRO Run GAS LIFT;7,913.7 l on N Top(ftKB) (ftKB) Make Model OD)In) SerieType Type (in) (pal) Run Date Corn 1 7,913.7 6,713.7 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/22/2007 Notes:General&Safety End Date Annotation 4/16/2006 'NOTE:TREE-FMC UNIHEAD GEN 114 1/16"5K PSI-TREE CAP-T"OTIS 5/22/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PACKER:8.023.1 NIPPLE.8,084.0 WLEG.8095.1 INTERMEDIATE,34.2-9572.6 TE tea. OPEN HOLE,8,572.6-16,021.0 r t t 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(o(alaska.gov AOGCC.Inspectors@alaska.gov phoebe.brooks@alaska.gov chris.wallace(o,alaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/CRU/CD3 Pad DATE: 05/10/18 OPERATOR REP: Miller AOGCC REP: Austin Mcleod Well CD3-108 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2050330 Type lnj W Tubing 1952 1953 1952 1952 Type Test P Packer TVD 6695 BBL Pump 1.9 IA 1050 3300 3260 3250 Interval 0 Test psi 3000 BBL Return 2.0 OA 508 532 533 533 Result P Notes: MITIA per Sundry 317-217 Well CD3-112 ' Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2060320 Type Inj W Tubing 2000 2000 2002 2002 Type Test P Packer TVD 6770 BBL Pump 1.4 IA 1180 3310 3210 3200 Interval 0 Test psi 3000 BBL Return 1.5 OA 566 826 813 809 Result P Notes: MITIA per AIO 30.007 to maximum anticipated injection pressure and per Sundry 318-163 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT CRU CD3-108 CD3-112 05-10-18.xlsx MEMORANDA? • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 5 lz,1l DATE: Tuesday,May 15,2018 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD3-112 FROM: Austin McLeod COLVILLE RIV FIORD CD3-112 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-112 API Well Number 50-103-20527-00-00 Inspector Name: Austin McLeod Permit Number: 206-032-0 Inspection Date: 5/10/2018 Insp Num: mitSAM180512190251 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-112 Type Inj W 'TVD6770 Tubing 2000 2000 - 2002 = 2002 Type - - — sSP- p PTD 2060320 T e Testt SPT Test SI 3000 IA 1180 3310 - 3210 - 3200 BBL Pumped: 1.4 BBL Returned: 1.5 ' OA 566 ' 826 - 813 - 809 - IntervalOTHER P/F P Notes: MIT-IA as per AIO 30.007.2 year.Sundry 318-163.Post patch test.Well was shut in during February testing. Bled to 1100psi once test complete %MitI JUN 44 ti Tuesday,May 15,2018 Page 1 of 1 • N c0 . a, N7 _ N _c CD co n3 Ln CO >. .. N -0 — > E c Cmo o (0 Y 0 + a) o u L. a C C c 2 co +., L Y -O @ o 0 a 7 w C C m Y c7 CO E o N. o a N Q 47 C -C L v w c rO U a oY L 0 N U a C U 92 > -p a -u O C s Y u '' co O I ra N 0 u O C L a p as J •co C E u O W rn a a Q J a r > -c a C az u a a o .a`, o a r a LL = _ - > -- - - t Y >a) a3 C a) C E N U ON -'0 C O co C u C L a 0 U C a3 E - a— i_ > u O u O U Q a aC CO ° C a C U N -C C w u O_ 0 0 ,� a F- " w a) a 8 ao n a ~O Ill C „ o u Ln J '_-` a) N w \`l ro ro > Y 0 N rO p .,-.. C22 z UD W u zo0. w O > lr z N L V a J W 0 1 m c cc c 3 0 Q < < m < wn vui I Uin 2 1 L u Q inW Z J UJ • 0 S 9 J L T CO cc _1 . C a U OC CN4 - - OA = d'kriiari X In cr T w ro tv a- 0 w xt a 8 m m 4:4,1-03 oc o c m u in o • C ao N N O L n o O u N N s L �_ n M G1 ,n R O i 01 7 L' I • t) G O v d1 w •c ' y m w F- m C cu > Y L..., Y _ C CD op w F al Q N 2 N ( % a 7 d a a ai Q +' E , In a z 1n (U Z M cc L a l'oc a Q o N w U Z W cow = Q2 H V C 1-7. as _....iL N r0 0 y a Lo Q 4 \ H a d G AF • • \�� 1/774, t THE STATE Alaska Oil and Gas o fAlJl TT A® c TT �1��1 Conservation Commission _=_ -_- ��„� 333 West Seventh Avenue ttri,tx _ Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 Off” ALAS Fax:Fax: 907.276.7542 www.aogcc.alaska.gov Dana Glessner SCANNED Petroleum Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CRU CD3-112 Permit to Drill Number: 206-032 Sundry Number: 318-163 Dear Ms. Glessner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this ( day of April, 2018. APR 13 20 -- — • 0 fig/pn� rEIVED STATE OF ALASKA APR 1 2 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION .°7-3 •� r3 APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon U Plug Perforations Li Fracture Stimulate Li Repair Well E ' Operations shutdown U Suspend n Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill n Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing patch❑✓ ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 206-032 • 3.Address: 6.API Number: Stratigraphic ❑ Service ❑� ' P. O. Box 100360,Anchorage,Alaska 99510 50-103-20527-00 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 2CRU CD3-112 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0372105, 0364471, 0384215 Colville River Field/Fiord Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 16,021' . 6,946' • 16,021' . 6946' • NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2,690' 9-5/8" 2,726' 2,485' Intermediate 8,538' 7" 8,573' 6,920' Open Hole 7,448' 6-1/8" 16,021' 6,946' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4.500" L-80 8,095' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER PREMIER PACKER MD=8023 TVD=6770 SSSV-BAL-O w/DB PROFILE MD=2169 TVD=2020 12.Attachments: Proposal Summary 1,./1 Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch I] Exploratory ❑ Stratigraphic ❑ Development❑ Service 0 ' 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ WDSPL n Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG n ' GSTOR n SPLUG Commission Representative: GINJ I I Op Shutdown Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dana Glessner Contact Name: Dana Glessner Authorized Title: Petroleum Engineer Contact Email: glessd@conocophillips.com 41/7 (4t. Contact Phone: 907-265-1308 Authorized Signature: Date: 4 ' /2- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1� I ty3 Plug Integrity I I BOP Test ❑ Mechanical Integrity Test Yr Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ri No • J PR cucutSpacing Exception Required? Yes n No d Subsequent Form Required: 1 a-' 4 4- ��'. ,( i. 1 APPROVED BY 4 I 1> 6 Approved by: COMMISSIONER THE COMMISSION Date: t l/'TL I//3//8 � z,/, y../z,.... QRIGIMiI SutFormand Form 10-403 Revised 4/2017 Approvepinis f " 1s from the date of approval. Attachments in Duplicate 111 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 12th, 2018 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for a tubing patch repair in ConocoPhillips Alaska, Inc. injector CRU CD3-112 (PTD 206-032). Sincerely, 4,14A. I 1 Dana Glessner 265-1308 Petroleum Engineer ConocoPhillips Alaska,Inc. • • ConocoPhillips Alaska,Inc. CRU CD3-112 (PTD 206-032) SUNDRY NOTICE 10-403 TUBING REPAIR 4/12/2018 On January 8, 2018, the AOGCC was initially notified of suspect IA pressurization in CD3-112 during water injection service (the well operates under AIO 30.007 as a water only injector due to previously identified tubing to IA communication on gas injection service). Diagnostic MITIAs failed and a liquid leak rates was identified between the tubing and IA. A subsequent leak detect log identified suspected leak points at several depths (3147', —4775' and 4875'). The repair plan is to set tubing patches over the leak points, conduct an MITIA to verify tubing integrity has been restored, and then return the well to water injection status operation under AIO 30.007. REPAIR PLAN 1. Set multiple tubing patches across the suspected leaks. 2. MIT-IA to verify patch integrity. t S� 3. Submit 10-404 post-repair. CPAI Well Integrity Supervisor 1' WNS INJ CD3-112 ....- .... ,,OIL Conocolotitilips !!0610.....• Weil Attributes - iblax Angle&MD TD , < Atoska.inn Wellbore API/OAR Field Name Wellbore Status ncl(.1 MD(ftKB) Act Bier(ftKB) 501032052700 FIORD NECHELIK INJ 92.84 10,277.56 16,021.0 ••• Con,mont H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Hortzontal-CD3.112.1013112014 6.4227 AM SSSV:WRDP Last WO: 42.76 4/13/2006 5,46 8 1 '''''''"at' cNa0 Annotation Depth(flKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET(NJ VLV hipshkf 10/31/2014 Casing Sthngs ill 'i I Casing Description OD(in) ID(in) Top(ftl<B) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I._Grade Top Thread HANGER,312 '4.; CONDUCTOR Insulated 16 15.010 36.0 114.0 114.0 84.00 J-55 WELDED galiii ..4.siiriziAllacriptio'n OD(in) ID(in) Top(ftKB) Set Depth MKS) Set Depth(TVD)...WI/Len(I.-Grade Top Thread 95/8 8.835 36.5 2,726.0 2,485.4 40.00 L-80 BTC Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread TUBING GMEDIATE 4112 7 3.965.2876 3341.2.2 8,0988.,5572.6 8,8063,.9220.7 12.8026.00L-80L-80 BTCM • Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(IVO).-Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 8,572.6 16,021.0 Tung Strings Tubing Descriptic=1 1 String Ma...ID(in) 'Top(ftKB) Set Depth(ft..) Depth(11/0)(...IWt(1b/ft) 'Grade Top Connection . ,. ' lotion Details Cern') HANGERItomFMC TUBING HANGER 3.958 IN's m PACKER -BAKER PREMIER PACKER WLEG W1RELINE ENTRY GUIDE Nominal ID lie) 33..887152 I Top gt88,K,00B239)351...211 Top(TVD66)781f307tK03113...221) Top.1646n0c1l...203(°0451 .i Co i ,,,_ . _ . 2,168.9 2,020.3 33.02 SAFETY VLV BALA w/DB PROFILE CONDUCTOR Insulated 24. 8,084.0 6,798.3— 63.80 NIPPLE HES'XN'NIPPLE 36.0-114.0 ,. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc-) 33:82755 I ------- Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Coin Run Date 10(10) 2,169.0 2,020.4 33.02 VALVE MODIFIED A-1 INJ VALVE W/DUAL PKG ON 3.81" 10/10/2014 2.125 . ' DB LOCK(S/N:HABS-0029) SAFETY VLV,2,1689 .;- VALVE,2,169 0 ; Mandrel Inserts tl St ati on Top(TVD) Valve Latch Port Size TRO Run • N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Coin I ( 7,913.7 6,713.7 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/22/2007 Notes:OetteiralA Safety; End Date Annotation 4/16/2006 NOTE:TREE-FMC UNIHEAD GEN 114 1/16"5K PSI-TREE CAP-7"OTIS 5/22/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE.36 5-2,726 0— I GAS LIFT,7.9137 I I ,n, PACKER.0,523.1 I / i NIPPLE;0,064.0 111 I WLEG,0,095.1 INTERMEDIATE,34.2-8.572 6 .0•0 0• .... OPEN HOLE,8,572 6-16,021 0—.`'4 • S Loepp, Victoria T (DOA) From: Glessner, Dana <Dana.Glessner@conocophillips.com> Sent: Thursday,April 12, 2018 11:40 AM To: Loepp,Victoria T(DOA) Subject: CD3-112 (PTD#206-032-0) - requesting verbal approval to start work this weekend Attachments: CD3-112 10-403 Submitted 4-11-18.pdf Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria—the attached 10-403 is in the mail to you today. However, I am writing to request verbal approval to start this job this weekend. The reason I am requesting a verbal approval is because we only have a short window to set 3 patches in this well due to the ice road ending at CD3 in the next 1-2 weeks. Please let me know if you have any questions about the work. thanks, Dana Glessner ConocoPhillips Alaska, Inc Petroleum Engineer office (907) 265-1308 Dana.Glessner@ conocophillips.com 1 N 0 h, v o ID H N Q0 *' la >, `° dl - o `0E v o U N 4 > c o ° o U a a C C vC > CD 6. 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V' cr 00 If) C 0 N 0 0 0 0 0 0 0 0 0 N a N N N N N N N N Cil L. -0 r\ Q M M M M A M A M r) • a) 7.1,1 Ch p 0 o o o 0 0 0 0 0 .3 L G O 0 0 0 0 0 0 0 0 �+ 0 a) o C N IA In N O If) O N N Q I,) T co tic, 444, Lu go CID uQ O u) LL' 1 C 0 al N.-1 � i Q Q in N N CO N To a) 7 d �1 z ✓ N < 0 0 p p N N N N +' V) E a) to ^ Z 0 0 u') N CV N A la Q. C f1 L N --i 3 0000 ° U 0 In z N ro Ta C9 r+ u �` 3 fa C v Ia OVDa. 3a` � �) a as • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday,January 9, 2018 8:30 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CD3-112 (PTD#206-032,AIO 30.007) High IA Pressure Hello Chris— Yesterday CRU water injection well CD3-112 (PTD#206-032,A10 30.007)showed a pressurization of the IA during normal water injection service. The well has been shut-in and freeze protected. CD3-112 operates as a water-only injector due to TxIA communication on gas injection service. CPAI intends to conduct diagnostics at the earliest reasonable opportunity—CD3 is a roadless location and logistics are slower than other locations. We will notify you of the outcome of these diagnostics and submit the proper paperwork for a proposed fix when we determine one. Please let us know if you have any questions or disagree with this plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCAN 1 0(40-o'3Z, • WELL LOG TRANSMITTAL#904005210 To: Alaska Oil and Gas Conservation Comm. June 12, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED DATA LOGGED Anchorage, Alaska 99501 (4/u/201 ? ivl.K.BENDER JUN 222017 RE: Leak Detect Log with ACX: CD3-112 AO G C C Run Date: 5/1/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-112 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20527-00 Leak Detect Log with ACX 1 Color Log 50-103-20527-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 sat4NED3�J i . 1 2 )P Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,Av , eifteat • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, March 25, 2016 3:25 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: CRU CD3-112(PTD#206-032)IA re-pressurization Attachments: CD3-112.pdf; CD3-112 90 Day TIO plot.JPG Chris, CRU CD3-112 (PTD#206-032) has experienced IA re-pressurization after an IA bleed was conducted. DHD will perform the initial diagnostic tests, including an MITIA, POTs, and an IA DDT. A 30 day monitor period on miscible injection will follow the diagnostics to watch for IA stabilization or to determine the pressure build up rate and the number of bleeds it would require to maintain the well within WOG. Depending on the outcome of the diagnostic testing and MI monitor period the well will either be returned to normal injection status if integrity is proven or if TxIA communication becomes apparent while on MI injection the well will be WAG'd to water injection for a series of"de-gassing" bleeds followed by a 30 day diagnostic water injection period. If integrity is proven while on water injection an AA application for water injection only due to TxIA communication while on MI will be submitted. Attached are a 90 day TIO trend and wellbore schematic. Please let us know have any questions or disagree with this plan. Dusty Freeborn I Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 40114.WELLS TEAM ConocoPhillips SCANNED JUN 2 8 2016 W I I y ..: W tel Z W H Q =. v N W cc o_ C. O 1/1 V W U CL o Ui a e ✓ x ✓ W lfl (A W 0. U p• rl c ZV I- 14 Q. IL, . 2 cv Hc"Ji D h. JI J rl CJ O 0 0 0 0 0 0 Co L., .. C', `�'�6aR CD CD CD U U +- .— .— .— Ot CO F- CO CS,' t{,i I I I I I I I r i I --` � w w W1.'1',..NULi C a) w CO C 0 03 ra V ❑ C w C O W U Na; m 3 Z C I Q i U 4L L) dJ LA VI 117 N e- C C M {D O] yy I N CIN V N _ o r a. a c 5 ' u I I I i I �i y o U v v v CD CD" I 1 I I 3, E r al O U CJ U U U U C] U v O A c Ci vi CD ll, CD 4' CD U, i= 3 I Y C H N •� Z ❑ MI `r .r Cl c l� d CZea c ISd in ❑ w • S Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, May 12, 2016 12:22 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: CRU CD3-112 (PTD#206-032)IA Re-pressurization Update Attachments: CD3-112.pdf; CD3-112 TIO plot_90 day.docx Chris, CRU CD3-112 (PTD#206-032) was shut in at the conclusion of its monitor period on MI injection and will remain shut in until we are able to WAG it to water injection. Pressure trends from the monitor confirm TxIA communication while on MI. Once CD3-112 is WAG'd to water injection,we will perform a series of de-gassing bleeds followed by a 30 day diagnostic water injection period. If integrity is proven while on water injection, an AA application for water injection only will be submitted. Please let me know if you have any questions or disagree with this plan. Attached is a schematic and 90 day T/I/O plot. Regards, Rachel Kautz Well Integrity Engineer SCANNED MAY 1 8 2016 ConocoPhillips Alaska, Inc. Temp.Slope Phone:907-659-7126 1 • • Well Name CD3-112 Notes: Start Date 2/12/2016 Days 90 End Date 5/12/2016 Annular Communication Surveillance 4ED_WHP — 1ED 4D.. — 1L` — 14D 35DD — 1?D 3DDD - 1:D LL 2SDD p} -v11 20GD 15DD — 1DDD E — 7C:: EC Feb-16 Mar-16 Apr-16 Way-15 =--•- — D, —BLPD Feb-16 Mar-16 Apr-16 May-16 Date • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, April 27, 2016 1:32 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CRU CD3-112(PTD# 206-032)IA re-pressurization update 4/27/2016 Attachments: CRU CD3-112 TIO Plot 90 day.docx; CRU CD3-112 TIO Plot 90 day.docx; CD3-112.pdf Chris, This is an update on CRU CD3-112 (PTD#206-032),which was initially reported when it experienced IA re-pressurization after an IA bleed was conducted. The well was put on MI for 30 days to determine if we have TxIA communication while injecting MI and today that monitor period ends. However, the pressure trends over the 30 day monitor period are not definitive enough to say whether we have TxIA communication while on MI or not. I'd like to extend the monitor period for another 14 days to be certain. We will send an update at the end of the 14 day monitor period. Attached are a 90 day TIO trend and wellbore schematic. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz Well Integrity Engineer Za�u ConocoPhillips Alaska, Inc. _�uN�O NI AY 0 9 u Temp.Slope Phone:907-659-7126 (�1� From: NSK Problem Well Supv Sent: Friday, March 25, 2016 3:25 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc: Senden, R.Tyler<R.Tyler.Sejnden@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: CRU CD3-112(PTD#2061-632).. re pressurization Chris, CRU CD3-112 (PTD#206-032) has experienced IA re-pressurization after an IA bleed was conducted. DHD will perform the initial diagnostic tests, including an MITIA, POTs, and an IADkT. A 30 day monitor period on miscible injection will follow the diagnostics to watch for IA stabilization or to determine the,pressure build up rate and the number of bleeds it would require to maintain the well within WOG. Depending on the outcome of the diagnostic testing and MI monitor period the well will either be returned to normal injection status if integrity is prpven or if TxIA communication becomes apparent while on MI injection the well will be WAG'd to water injection for a series of"de-gassing" bleeds followed by a 30 day diagnostic water injection period. If integrity is proven while on water injection an AA application for water injection only due to TxIA communication while on MI will be submitted. Attached are a 9 ay TIO trend and wellbore schematic. Please let us know have any questions or disagree with this plan. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 #111ZELLS TEAM ConocoPhillips 1 • • W U 5 f/1 d' ca 0 `I N -- U in Lu et na LL: L 8 . . o N N a 0 0 al x aI w 0] y W Cr t, a I :, I- ,n F rV C1 .'J J I J r W CI } U 00 ito a 0 CI r, o Cl0 0 ABaR 0 m m 2 I (13I m U C R W 3 opil.0 C C ` top m c: R 0 - U c 7 E E p j U R N oC Q ,' fD W LL N t0 cc N O N 31) 0 N civ V ca N I I G I I I ( I 0vuo a w IE w a) r• ci c u' g Z O R V C CA C', CI CI l ' e- / . ^ + n V Q — C N O Cdlli'0!OA a) ,C >.v ISd .1 p w WNS INJ • CD3-112 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/DWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Blm(ftKB) t rarrrJlalkfs 501032052700 FIORD NECHELIK INJ 92.84 10,277.56 16,021.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) —Rig Release Date Horizontal-CD3-112,10/31/20146.42:27 AM SSSV:WRDP Last WO: 42.76 4/13/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET INJ VLV hipshkf 10/31/2014 ................... asmg rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sal Depth(ND)... Wt/Len(I...Grade Top Thread HANGER.at z CONDUCTOR Insulated 16 15.010 36.0 114.0 114.0 84.00 J-55 WELDED 24" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread f SURFACE 9 5/8 8.835 36.5 2,726.0 2,485.4 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread INTERMEDIATE 7 6.276 34.2 8,572.6 6,920.7 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread OPEN HOLE 61/8 8,572.6 16,021.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection TUBING 4 1/2 3.958 31.2 8,096.5 6,803.7 12.60 L-80 Completion Details I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.2 31.2 0.00 HANGER FMC TUBING HANGER 3.958 glgiku eek 2,168.9 2,020.3 3302 SAFETY VLV BAL-O w/DB PROFILE 3.812 8,023.1 6,770.2 61.35 PACKER BAKER PREMIER PACKER 3.875 CONDUCTOR Insulated 24", s 8,084.0 6,798.3 63.80 NIPPLE HES'XN'NIPPLE 3.725 38.0-114.0 8,095.1 6,803.1 64.24 WLEG WIRELINE ENTRY GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Das Corn Run Date ID(in) 2,169.0 2,020.4 33.02 VALVE MODIFIED A-1 INJ VALVE W/DUAL PKG ON 3.81" 10/10/2014 2.125 DB LOCK(S/N:HABS-0029) SAFETY VLV,2,168.8 VALVE;2,169.0 Mandrel Inserts st ati N Top(TVD) Valve Latch Port Size TRO Run iNa Top(ftKB) _ (ftKB) _ Make Model OD(in) Sery Type Type (in) (psi) - Run Date Com 1' 7,913.7 6,713.7 Camco KBG-2 1 GAS LIFT DMY BK 0.000' 0.0 1/22/2007 Notes:General&Safety End Date Annotation 4/16/2006 NOTE:TREE-FMC UNIHEAD GEN 114 1/16"5K PSI-TREE CAP-7"OTIS 5/22/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE,36 5-2,726.0 GAS LIFT;7,813.7 ■ PACKER;1023.1 NIPPLE 80840 WLEG,8095.1 INTERMEDIATE;34.2-0,672.0 ,... ,,•• OPEN HOLE;8,572.618,021 0 , Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original fife, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o~Q Y~ - ~ ~ ~ Well History File Identifier Organizing (done> RE CAN Calor Items: Greyscale Items: ^ Poor Quality Originals: ^ Other: o,.os~ea iuuiuiuimuii DIG TAL DATA Diskettes, No. , ^ Other, No/Type: o R.sG~~eed~ iiiumioiiiiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ^ Other:: ~,5 ~ ~ /s/ Project Proofing III IIIIIIIIIII II III BY: Maria Date: ~ 0 U /s/ Scanning Preparation _~ x 30 = ~ + _S~ =TOTAL PAGES BY: Maria Date: 1 n / (Count does not include cover sheet) ~ ~7 /C~~i lsl 1/ V I Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~/~~ ~ S /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point Unless rescanning is required. II I II'I II I II II I I III ReScanned III II'lII IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III IIII III 10/6!2005 Well History File Cover Page.doc STATE OF ALASKA �.; a A. AKA OIL AND GAS CONSERVATION COMMISSION \V APPLICATION FOR SUNDRY APPROVALS ( 20 AAC 25.280 �^ I I.1 1: 1 �- 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well I- Change ApOr ( -„. •: - Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational r Re-enter Susp. r Stimulate r Alter casing r Other:Conductor Extension 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Developmen r 206-032 • 3.Address: 6.API Number: Stratigraphi r Service r• P.O.Box 100360,Anchorage,Alaska 99510 50-103-20527-00• 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F CD3-112• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0372105,0364471,0384215. Colville River Field/Fiord 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): 16021 ' 6946 ' Casing Length Size MD TVD Burst Collapse •,;CONDUCTOR 78 16 114' 114' SURFACE 2690 9 5/8 2726' 2485' INTERMEDIATE 8538 7 8573' 6920' OPEN HOLE 7448 6.125 16021' 6946' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Open 8573-16021 Open 6920-6946 4.5 L-80 8095 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) VALVE-A-1 INJECTION VALVE(HABS-0029) MD=2169 TVD=2020 PACKER-BAKER PREMIER PACKER MD=8023 TVD=6770 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program (l BOP Sketch r Exploratory n Stratigraphic r Development (- Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil r Gas I- WDSPL r Suspended E 16.Verbal Approval: Date: WINJ r GINJ r WAG F • Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878@cop.com Printed Name MJ Loveland Title: Well e5Project Signature Phone:659-7043 Date 1/11/14 Commission Use Only Sundry Number: 31 (4j0( ,7,} Conditions of approval: Notify Commission so that a representative may witness /I Plug Integrity r BOP Test fl Mechanical Integrity Test iT Location Clearance r REIit. r MAY Q 9 2014 Other: Spacing Exception Required? Yes 0 No 11 Subsequent Form Required: /b " � /5 APPROVED BY _ Approved by: P COMMISSIONER THE COMMISSION Date:4-- 7 / A d s .I r nths from the date of approval. Form 10-403(Revised 10/ 012) pp � L pp P/Aq3 015 PI Form and Attachments in Duplicate VLF- 1 /1( l/rovea 4 /0me I INNS INJ CD3-112 ConocoPhillips0o n Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status Inci(') MD(RUB) Act inn(MKB) carwml'lvinps 501032052700 FIORD NECHELIK INJ 92.84 10,277.56 16,021.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date • Well Conrp.Moruon1a6G0}112,62412013 6 28 23 AM SSSV:WRDP Last WO: 42.76 4/13/2006 Schemeoc Acwel Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O,RESET INJ VLV osborl 8/24/2013 — — ; ,. Casing Strings HANGER,31 MIll'' , Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(NU)...String Wt...String...String Top Thrd CONDUCTOR 16 15.010 36.0 114.0 114.0 84.00 J-55 WELDED Insulated 24" - — - _ — - — Cuing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE 95/8 8.835 36.5 2,726.0 2,485.5 40.00 L-80 BTC rl Cuing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd INTERMEDIATE 7 6.276 342 8,572.6 6,920.7 26.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd OPEN HOLE 6 1/8 8,572.6 16,021.0 Tubing Strings I Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING 1 41/2 I 3.958 I 31.2 I 8,096.5 I 6,803.6 I 12.60 L-80 Completion Details Top Depth (ND) Top Incl Noml... Top(ftKB) (ftKe) (°) Item Description Comment ID(in) 31.2 31.2 -0.05 HANGER FMC TUBING HANGER 3.958 CONDUCTOR 2,168.9 2,020.3 33.02 SAFETY VLV CAMCO SSSV BAL-0 w/DB PROFILE 3.812 Insulated36714 8,023.1 6,770.2 61.35 PACKER BAKER PREMIER PACKER 3.875 8,084.0 6,798.0 63.80 NIPPLE HES%N.NIPPLE 3.725 8,095.1 6,803.0 64.24 WLEG WIRELINE ENTRY GUIDE 3.875 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) SAFETY VLV, Top Depth VALVE,2,169 (ND) Top Incl " 11 Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 2,169.0 2,020.4 33.02 VALVE A-1 INJECTION VALVE(HABS-0029) 8/23/2013 2.125 I Notes:General&Safety End Date Annotation 4/16/2006 NOTE:TREE-FMC UNIHEAD GEN II 4 1/16"5K PSI-TREE CAP-7"OTIS 5/22/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SU30-2,RFACE. A k 726 I GASUFT, 7 914 • PACKER,8,023 -- )' S-----7. NIPPLE.8.084 - WLEG.8,095 ._.. 1 ---i Mandrel Details Top Depth Top Port S... (ND) Incl OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type lin) (psi) Run Date Com... 1 7,913.7 6,713.6 56.37 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/22/2007 NTERMEDIATE. I11e 34-8,573 o • OPEN HOLE, o e 6,573-16,021 TD.16,021 J " _ . ,, i 7.1 ConocoPhillips Alaska A 0 r P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 10, 2014 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD3-112, PTD 206-032 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Alpine Well CD3-112 (PTD 206-032) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 10, 2014 This application for Sundry approval for Alpine well CD3-112 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 11". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor • t�' �\� //%%.`�� THE SSLATE i - ! r, �; a ii ,�'�'"`�''>"2 . 74 A �Y {\ i , G 1, s j - 333 West Seventh Avenue kritop . \. ,i, -7/ GOVERNOR SI AN PAR ELi. Anchorage, Alaska 99501 3572 C' � '-, Main 907.279 1433 MJ Loveland Well Integrity Project SCA ConocoPhillips NAY �� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 a6 Re: Colville River Field, Fiord Oil Pool, CD3-112 Sundry Number: 314-029 Dear Ms. Loveland: 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, a.g. P;e_(.44.____ Cathy . Foerster Chair DATED this 17da of January, 2014. Encl. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 3, 2011 r3 O („ — 0 3 a-- IT 3 - 1 1 a Commissioner Dan Seamount p . ,.. , .. Alaska Oil & Gas Commission . k, ' .... ,,,64 333 West 7 Avenue Suite 100 1 Anchorage, AK 99501 L �� r 4 'iii L N a�1$& ; . ,,Si0f Commissioner Dan Seamount: , ' . ., Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped January 31, 2011. 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 Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, ,_...,...7 , 77 / 7 / MJ Loveland 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 Date 213/2011 CD3 Pad Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD3 -106 50103206110000 2100010 16" NA 16" NA 7.65 1/31/2011 CD3 -110 50103205090000 2050410 4" NA 6" NA 2.13 1/31/2011 CD3 -112 50103205270000 2060320 3" _ NA 16" NA 2.73 1/31/2011 CD3 -114 50103205440000 2070330 5" NA 14" NA r 2.55 1/31/2011 CD3 -121 50103206150000 2100220 32" NA 32" NA 27.2 1/31/2011 CD3 -122 50103206090000 2091530' 74" NA 74" NA 32.2 1/31/2011 CD3 -124 50103206120000 2100080 17" NA _ 17" NA _ 5.1 1/31/2011 CD3 -301A 50103205430100 2060170 9" NA _ 15" NA 4.25 1/31/2011 CD3 -302A 50103205220100 2100350 5" NA 16" NA 3.83 1/31/2011 CD3 -304 50103205980000 2090280 18" NA 18" NA 5.9 1/31/2011 • • ~.« ,~ ., .~~ ~,; .~ _~, ` '~`, _ » 4 F ~ f I 1I 's ' ..YY L. i.. :. ~Y ..:: ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Nticrofilm_Marker.doc MEMORANDUM To: Jim Regg ~~~ 3(~~ 4l `~ P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March O1, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-] 12 COLVILLE RIV FIORD CD3-112 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv S~ Comm Well Name: COLVILLE RIV FIORD CD3-112 API Well Number: 50-103-20527-00-00 Inspector Name: John Crisp Insp Num: mitJCr100227174837 Permit Number: 206-032-0 Inspection Date: 2/26/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-112 Type Inj. G/ TVD 6770 IA 1938 2737 ~ 2714 2712 .~ P.T.D 206032 ypeTest SPT ~ TeSt Sl 1692 QA 406 450 458 459 Interval 4YRTST p~ P ~ Tubing 3220 _1-3220 3220 3220 NOtes• •4 bbl's pumped for test. %.:1Y+w.V~~ ~p Lart"rs+~ 1''t ~ ~ k~ .. ~ I„j ~ id Monday, March O1, 2010 Page 1 of 1 Regarding 4 year state witnesse~ITIA's on CD3 pad • Regg, James B DOA ~~ From: Regg, James B (DOA) `\~~~ Sent: Wednesday, June 10, 2009 12:51 PM To: 'NSK Problem Well Supv' Cc: Fleckenstein, Robert J (DOA) Subject: RE: Regarding 4 year state witnessed MITIA's on CD3 pad ~1~C . ._-- ~'TD Zoe-~4! ~~ cy ~i "3 2~(c c3ttz Z.r~U ° c% ~ 2~ ~~, -' ~ `'~ 3 .~ Your request to defer MITs at Colville River Unit CD3 pad until February 2010 is approved. The agreement to test in summer was driven by weather considerations and efficiency at CPAI's request. Testing the below listed wells in February 2010 will still accomplish the requirement to test at least every 4 years. We will make the necessary changes in our database to reflect a new due date of February 28. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 '~`°~~' ~~~»~' `i~~R r ~ ADC Anchorage, AK 99501 907-793-1236 _ _ _ __ From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, June 09, 2009 2:28 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Maunder, Thomas E (DOA) Subject: Regarding 4 year state witnessed MITIA's on CD3 pad Jim, By prior agreement with the Commission, Alpine CD3 pad is due for 4 year state witnessed MITIA's in July of 2009. Due to the remote location of that pad, the only available way to perform the MIT's during July would be to use a small triplex pump. The small triplex pumps have a 3 bbl capacity of fluid on board. With 8 wells to test on that pad, that would require to refill the triplex tank several times during the testing, possibly extending the testing time from 1 day to 2 or even 3 days, pending diesel availability. ConocoPhillips requests the testing cycle of CD3 to be deferred until February of 2010 when the pad is accessible with a larger pump by ice road. In reviewing our records of test dates, CD3-108 (PTD 205-033) has the oldest test date of 09-29-06. The other wells have more recent tests than that date (see table below). All of the wells will still be in compliance in February. February would become the new test month for CD3 and 2010 would be the start of the 4 year cycle. CD3-110 (PTD 205-041) last tested on 01/12/07 - Ao~ce w`t~~s tl Iz,~z~°7 CD3-112 (PTD 206-032) last tested on 04/28/07 ~- ~~~ ~'~'~~~s 4~~~0 ~ CD3-114 (PTD 207-033) last tested on 04/02/08 - l~~c w~-1~-~ess 4(Z~ z~ CD3-118 (PTD 208-025) last tested on 03/07/09 - A-cxti-~'-c ~~~ss 3i-~(-u'~`t CD3-302 (PTD 206-010} last tested on 07/19/07 _ ,c>~ce Wfi~e~s ~~ i~ t~c~ ~~ ~~~ ~~ CD3-316A (PTD 208-011) lasttested on 05/16/08 _ ~~~~ ~,,1~+nr3s 5~! 7.~%O~iS CD3-305 (PTD 208-193) tentatively scheduled to have initial witnessed test on /13/09. Please let me know if you have any questions and if this is acceptable. Brent Rogers/Martin Walters 6/10/2009 Cp3-110 -See ~~Cl~ce~ Regarding 4 year state witnesse~ITIA's on CD3 pad . Page 2 of 2 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 6/10/2009 CRU CD3-110 PTD 205-041 6/9/2009 TIO Pressures ~~ • ConocoPhillips ~as~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 ~•.>:-~i.~~~~ j. ~ ~ ~ 4 « ,~, ~' J Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • APF~ ~ 2005 ~~: _ ~~ ~~ ~~~ s ~ ~~~~~ ~~ Enclosed please find a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped April 5~', 2009. 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 Perry Klein at 907-659-7043, if you have any questions. Sincerely, i ~ ~G?~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off -~ ; Report of Sundry Operations (10-404) Alpine Field Date 4/6/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD3-301 206-020 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA 0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4/5/2009 l a ~.~ DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060320 Well Name/No. COLVILLE RIV FIORD CD3-112 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20527-00-00 MD 16021 TVD 6946 Completion Date 4/12/2006 Completion Status WAGIN Current Status WAGIN UIG Y --- - - - - - -_._. --- t/ REQUIRED INFORMATION /'1 Mud log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 36 16021 Open 6/27/2006 ED C Lis 13970 Induction/Resistivity 1-2 2726 8573 Open 6/27/2006 GR, EWR4, ROP, PWD, Geoplot t 1 7 I V n 39 0 L S erificatio 1-2 2726 8573 Open 6/27/2006 LISTPE 15-Jun-2006 /' I~ Cement Evaluation 2 Col 1 6516 8800 Case BAT Bi-Model Cement www I~ Eval Trial 25-Mar-2006 pt 14364 LIS Verification 2699 16021 Open 1/29/2007 LIS Veri, GR, FET, ROP '~D C „j,as~.ItS 14364~duction/Resistivity 2699 16021 Open 1/29/2007 LIS Veri, GR, FET, ROP ~g Induction/Resistivity 25 Col 114 16021 Open 4/21/2008 MD ROP, DGR, EWR 11- Apr-2006 ~ CiXog Induction/Resistivity 25 Col 114 6946 Open 4/21/2008 TVD DGR, EWR 11-Apr- D C 1612 ' 2006 ~ See Notes 5 ~ 0 0 Open 4/21/2008 MD and TVD logs in PDF, EMF and CGm graphics Well Cores/Samples Information; Sample Interval Set Name Start Stop Sent Received Number Comme nts ADDITIONAL INFORMATION Well Cored? `v`ii~wJ Chips Received? ~-~.pl..+ Analysis `/ N~ Received? Daily History Received?- \:YN Formation Tops ('y N DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060320 Well Name/No. COLVILLE RIV FIORD CD3-112 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20527-00-00 MD 16021 TVD 6946 Completion Date 4/12/2006 Completion Status WAGIN Current Status WAGIN UIC Y Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-112 April 11, 2008 AK-MW-429509 CD3-112: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20527-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20527-00 Digital Log Images: 1 CD Rom 50-103-20527-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 gate: 'r Signed: v ~~ ate- c~3 a ~1 ~ ~a~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number. 206-032 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-112 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20527-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^ or Final ^Q 307-002 1/11/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352"' 352 totals (bbls): CD3-107, CD3-113, CD3-112, 2oo7/1st 31555 100 0 31655 35 1/12/2007 3/20/2007 CD3-302, CD3-114 2007 / 2nd 0 0 0 0 0 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 Total Ending Report is due on the 20th volume 31555 100 352* 32007 35 Ex: of the month following the final month of the quarter (bbls): . Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. !~ Signature: ~ l --._ Date: ''t~~r 6 $ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 ~. Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 206-032 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-112 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20527-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 307-002 1/11/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352* 352 totals (bbls): CD3-107, CD3-113, CD3-112, 2007 / 1st 31555 100 0 31655 35 1/12/2007 3/20/2007 CD3-302, CD3-114 2007 / 2nd 0 0 0 0 0 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 Total Ending * Report is due on the 20th volume 31555 100 352 - 32007 35 (bbls): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Descriptions>: freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. /' Signature: ~. Date: ~ ~~ (O ~ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 2QQ-032 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-112 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20527-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^Q or Final ^ 307-002 1/11/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352* 352 totals (bbls): CD3-107 CD3-113, CD3-112 zoo? / 1st 31555 100 0 31655 35 1/12/2007 3/20/2007 , , CD3-302, CD3-114 2007 / 2nd 0 0 0 0 0 2007 / 3rd 0 0 0 0 0 2007 / 4th Total Ending ' Report is due on the 20th volume 31555 100 352 ` 32007 35 (bbls): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. /' Signature: Date: ~~ (~ r/o ') Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate +., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~ Alaska Oil ~ Gas ~~~~;~. Gcrmmissi0n ~cl~;s~r~~m 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 0 ~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ ~ Exploratory ^ 206-032 '" 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20527-00 - 7. KB Elevation (ft): 9. Well Name and. Number: RKB - 36.8' / CD3-112 8. Property Designation: ~ 10. Field/Pool(s): ADL 372105, 364471, 384215 Colville River Field / Fiord Ne ik Oil Pool ` 11. Present Well Condition Summary: .~.1~.~7 Total Depth measured 16021' " feet true vertical 6946' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2677' 9-5/8" 2726' PRODUCTION 8524' 7" 8573' OPEN HOLE 7448' 6 1/8" 16021' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4 1/2" 12.6# IBTM tubi ng = 8096' MD Packers &SSSV (type & measured depth) Baker Premier Packer set at 8023' BAL-O / 4.5" SSSV - 2169' 12. Stimulation or cement squeeze summary: Inter al tre ted m d ~~' ~U~ ~ v ( easure s a ) 31QD7 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 8345 ° 1309 1160 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAGQ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-019 Contact Brian Barreda Printed Name ian Bad- a Title Production Engineer Signature Phone 263-6036 Date ~`~Z/d, ~~ Pre ared b Jeanne Haas 263-4470 Form 10-404 Revised 04/2004 1 1 ~ ~ G ~ ~ A L ~~~ d~~~' '~~?~Q~ubmit Original Only ~.r CD3-112 Daily Report of Well Operations Start Water Injection 8/8/06 Shut-in Well for Conversion 1/17/07 Obtain SBHP 1/22/07 Set A-1 Injection Valve 2/9/07 Complete Conversion & Start WI 4/1/07 ~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 206-03~ ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-112 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20527-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final [] 307-002 1/11/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352" 352 totals (bbls): CD3-107 CD3-113 CD3-112 2007 / 1st 31555 100 0 31655 35 1/12/2007 3/20/2007 , , , CD3-302, CD3-114 2007 / 2nd 0 0 0 0 0 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume 31555 100 352* 32007 35 (bbls>: of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Descriptions>: freeze protect volumes 1 hereby certify that the foregoing is tr~ n d correct to the best of my knowledge. o ` -7 ~~ ~~, \ ~`~~ a - D Si t gna ure: ate: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~J ~' Date OS-09-2007 Transmittal Number:92890 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below, If you have any questions, please contact me in the PDC ar 5hd_d(191 SW Name Date Contractor Log Run Top De th Bottom De th Lo T e NS34 01-18-2007 SCH ULTRASONIC CORRfSION EVALUATION LOG NS34 01-18-2007 SCH COMPOSITE CEMENT EVALUATION LOG NS09 12-22-2006 SCH PRODUCTION PROFILE NS09 08-05-2006 SCH PERFORATION RECORD WITH GAMMA RAY o,~ Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Cheryl Ploegstra Doug Chromanski Kristin Dirks Christine Mahnken Ignacio Herrera ~~ -~~a .~ _ -. ... ~ ~~y~~' ~ ~~ ~~~~ :~ _.~, Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 iV1~1V1(lKA1VllUM TO: Jim Regg ~ ._ t ~ ..., P.I. Supervisor ~`1~~ ! ~~ 7 ~ ~' FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commi~ DATE: Thursday, May 03, 2007 SCBJECT: Ntecnanical Integrity Tests CONOCOPHILLIPS ALASIC;a I~iC CD3-1 t2 COLV[I,LE Ri V FiGRD CD3-~ 12 Src: Inspector NON-CONFIDENTIAL, Reviewed Bv~~: Comm Well Name: COLVILLE RN FIORD CD3-1 12 API Well Number ~o-to3-20527-00-0o Inspector Name' John Crisp Insp Num: mitJCr070~02122~31 Permit Number: zo6-o3z-o Inspection Date• 4;z8izoo7 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - Well ~ CD3al~ f'j' a In'. I w TVD Yp , ' 6770 IA zzls r 810 ! zn6 2179 i YP 2050320 - ~ SPT ! P.T.DI IT eTest ; Test psi ____ ,__.. 169z s i OA j _ 569 ats ' ~ _ _-- - -- 766 7ss Interval INITAL p/F P / Tubin -15as g 1645 6 NOtes: 1.9 bbl pumped for test Thursday, bfay 03, 2007 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 206-~32 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-112 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20527-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ~ or Continuation ^ or Final ^ 307-002 1/11/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352* 352 totals (bbls): CD3-107, CD3-113, CD3-112, 2007 / 1st 31555 100 0 31655 35 1/12/2007 3/20/2007 CD3-302, CD3-114 2007 / 2nd 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume 31555 100 352* 32007 35 (bbls>: of the month following the final month of the quarter. Ex: July 20 for the second quarter Apri120 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~~ ~ ~~=~' -- °----~ Date: ~l l3 l~7 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • SARAH PALIN, GOVERNOR r1Waa~7~1~ OIL ~ ~ 333 W. 7th AVENUE, SUITE 100 C011TSER~A7'IO1~T COl~'II~'IISSI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Brian Barreda Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-112 Sundry Number: 307-019 Dear Mr. Barreda: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of February, 2007 Encl. STATE OF ALASKA o~` ~aN 1 I ZQO7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVca Oil & Gas Cons. Commission 20 AAC 25.280 Anchora~o 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ C~S~/~ Change approved program Q . Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well . ^ ~° W/Q4~~ u 2. Operator Name: 4, Current Well Class: 5. Permit to Drill Numbe . ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 206-032 /~ y3• 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20527-00 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Required? YeS ^ NO ~ CD3-112 ' 9. Property Designation:. 10. KB Elevation (ft): 11. Field/Pool(s): ADL 372105, 364471, 384215 RKB 49' Fiord-Nechelik 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16021' ~i9.2'1' 104(0 Casing Length ~. •~ Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2677 9-5/8" 2726' PRODUCTION 8524' 7" _ 8573'... OPEN HOLE 7448' 6-1/8" 16021' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 8096' Packers and SSSV Type: Packers and SSSV MD (ft) BakerPremier Packer Packer set at 8023' SSSV: BAL-O 4.5" DB Profile SSSV= 2169' 13. Attachments: Description Summary of P roposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true a nd correct to the best of my knowledge. Contact: Brian Barreda @ 265-6036 Printed Name Br B reda Title: Production Engineer Signature ~ Phone 265-6036 Date ` - 1(~'" ~ ~` Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ~- Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other. Subsequent Form Required: ~~ ~ ~ ~~'~ ~~~ ~ ~ ~oo~ APPROVED BY ,~ ~ D ~ / Approved by: MISSION THE CO MISSION Date: Form 10-403 Revised 06/200 ("'~ ~ ~ c~7~~`-~ 1 ~~~~~/~~ '~I , I ~~] Submit in Du licat • _~ I~'C:3ANICAL INTEGRITY REPORT ~ ~ ~~ ~?UD D:_.~ : ~ ~.Ia(o OSo QPER ~ FZELD ~,~~~ ~O~~l~~`Ct \C.~,JCY' -_c ~~~~~~.. ~~~~-off ;,ALL Nvr~~R ~~~- 1~~-- .N ~ LL DAT e TD : ~~0~~ ?~.. ~p~t'E~ TVD ; P BTD : -~- ?ID T~ID Casing : ~~~ Shoe : ~~ t~ ~~(7 ~ ~ liV ; ~-' '-~ --' T~~i --=:~e= . Shoe . '~ T`~ ~ =C^P . ?•~ f _ _','D _ ~ ~ i - ~ ~ ~ 17 ? z c ~c e r l~~ ~~~~1 W T'`T~i ; Set e t ~~ w ole S=~e ~$3~G1 and ~ Perf~ ~ ~~._ to ~~~ ~C'r'~?~?C~.T, ZNTEGRZTV - PART # 1 ?_nr;ulus Press Test: _? Car.~ents . 15 min ~0 min i '~'CHPNZCr..L ZNTEGRTT`~ - PART # 2 y~~tS ~~ ~~ g ~~ ~s Cement Voles: Amt. Liner Csg~S~ DV Cr.t -rol to cover oers ~ 3C~Zc~ ~5 a-~i ~~t~ s~~`c`~~e~~ ~o c.avct~-~~pc,,~~~ ~` ~o ~ - _ =eoretical TOC ~ 3~~ ~ =~~o~ 3<~G r o ~ v Cement Bond Log (Yes or No)_; In AOGCC File CC-~ CBL Evaluation, gone ebove perks v.9 ~~. ~ ' r~~ ~ES~~ ~S ~.~ EG-~c~ ~~ ~ ~ Production Log: Ty-ne_ CONGLJS~ONS: ?art r 1 ?art 1~: ~~~ iH c Evaluation ry'y~-~~ • WELL LOG TRANSMITTAL To: State of Alaska June 15, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7t'' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-112, AK-MW-4295099 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal Letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20527-00. _>, C.(~~ ~ ~ to ~_ ,~ °~ a r CD3-112 Sundry Daily Work Log • • Subject: CD3-112 Sundry Daily Work Log From: "Ban-eda, Brian B" <Brian.B.Barreda@conocophillips.com> Date: Wed, 17 Jan 2007 10:28:36 -0900 To: bob fleckcnstcin(a.admin.slate.ak.us CD3-112 Date Event 8/8/06 Put on production 9/15/06 Start Lift Gas 1/17/07 Shut-in well and start demo work TBD Static bottom-hole pressure TBD Start Water Injection Brian Barreda Cc~nc~coPhillips Alaska lnc. Alpine Productiran ,Engineer ATC - / 738 tJffice: (907} 265 - 6036 Cell: X907) 830 - 0284 1 of 1 1/17/2007 12:12 PM • ConocoPhillips January 8, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • Brian Barreda Production Engineer ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 phone 907-265-6036 ~~~ JAN ~ 1 2~Q7 Alaslt;a Oil & 8~s ~;~arr~. Ctxnmissio ~nc~~r~g~ Re: Report of Sundry Well Operations for Sundry No. 306-244 And Request for Sundry Approvals Colville River Field, Fiord Oil Pool, Weli CD3-112 Dear Ghairman Norman: ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River unit requested and received approval to temporarily produce the well CD3-112 originally permitted as a service well intended for WAG injector in the Fiord Oil Pool. The production period has been concluded for CD3-112. Enclosed is a 10-404 report for the CD3-112 pre- production. Approximately 568,652 STBO were produced from CD3-112 from August 8, 2006 through January 8, 2007. ,/ Also enclosed is a 10-403 form for conversion of CD3-112 from production back to its originally permitted service as a WAG injector. A cement quality log run. in CD3-112 on March 25, 2006 indicated injection fluids will be isolated in the approved injection .~ interval. Please call me at 265-6036 if you have questions. ~~ Brian Barreda Production Engineer ConocoPhillips Alaska, Inc. • ~ Brian Barreda Production Engineer ConocoPhillips Alaska P.O.Box 100360 ~~~~~~~~ ~ ~ ~ ~ ~~ Anchorage, AK 99510-0360 phone 907-265-6036 January 8, 2007 Mr. John Norman, Chair - Alaska Oil and Gas Conservation Commission _ 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Report of Sundry Well Operations for Sundry No. 306-244 And Request for Sundry Approvals Colville River Field, Fiord Oil Pool, Well CD3-112 Dear Chairman Norman: ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River unit requested and received approval to temporarily produce the well CD3-112 originally permitted as a service well intended for WAG injector in the Fiord Oil Pool. The production period has been concluded for CD3-112. Enclosed is a 10-404 report for the CD3-112 pre- production. Approximately 568,652 STBO were produced from CD3-112 from August 8, 2006 through January 8, 2007. V Also enclosed is a 10-403 form for conversion of CD3-112 from production back to its originally permitted service as a WAG injector. A cement quality log run in CD3-112 on March 25, 2006 indicated injection fluids will be isolated in the approved injection interval Please call me at 265-6036 if you have questions. J~~, ~°,~ Brian Barreda Production Engineer ConocoPhillips Alaska,. Inc. ~~~~~ STATE OF ALASKA ~ ~~~ ~ ~ ~~~1 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska ~jj ~ Gas ~flt1S. ~~mt11j3~jOft REPORT OF SUNDRY WELL OPERATIONS A~1t;hara~a 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ' ^ , .Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ~ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development^ Exploratory ^ 206-032 / 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20527-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 49' CD3-112 8. Property Designation: 10. Field/Pool(s)' ADL 372105, 364471, 384215 Fiord-Nechelik 11. Present Well Condition Summary: Total Depth .measured 16021' feet true vertical 6921' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD 'I'VD Burst : - Collapse ,_ , Structural CONDUCTOR .114' 16" 114' SURFACE 267T 9-518" 2726' PRODUCTION 8524' 7" .8573' OPEN HOLE 7448' 6-1/8" 16021' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8096' M0. Packers &SSSV (type & measured depth) Baker Premier Packer set at 8023' SSSV: BAL-O 4.5" DB Profi le set at 2169' 12. Stimulation or cement squeeze summary: .. ~_ ,6A[V ~ '~ 2007 Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation 3,692 2.367 7 1441 255 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _ 1 Well Status after proposed work' ~ Oil ~ ~ as^ WAGLJ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number orN/A if C.O. Exempt: 306-244 contact Brian Barreda Printed Name B ~ n Ba da Title Production Engineer i Signature ~ Phone ~ / `/Q~ 265-6036 Date Pre ared b Jeanne L. Haas 263-4470 v' ~% Form 10-404 Revised 04/2004 ~ ~ ~~ ~RI~°" .b~ ~ /• /6-~7 Su O i n Only f~;~~~T Note to File CD3-112 (206-032...307-002) Colville River Unit (Fiord-Nechelik) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 95 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 57% XS of the calculated hole volume. --On the initial leak off test, there are two pressure slopes. The inflection occurs at about 15.1 EMW. With continued pumping an ultimate FIT of 18.0 EMW was reached. Two slopes are not unusual and have been seen on other CD3 wells. Minimal fluid was pumped in. The pressure declined during the observation period to about 14.8 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. Sufficient cement was pumped to place cement above the shallower Kuparuk sand. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 14.9 EMW, only slightly less than the inflection point on the initial test. The pressure declined with additional pumping to 14.6 EMW. During the observation period, the pressure declined to 13.5 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/ mile radius of CD3-112. The surface shoe of CD3-111 is about 530' distant. An examination of the cementing and pumping information for this well did not reveal any problem that would preclude granting CPAI's request for CD3-112. The nearest other well is CD3-110 some 1200' distant. Based on examination of the submitted ConocoPhillips' request for the subject well. Tom Maunder, PE Sr. Petroleum Engineer January 11, 2007 information, I recommend approval of G:\common\tommaunder\Well Information\By Subject\Annular Disposal\070111--CD3-112.doc a • Note to File CRU CD3-112 (PTD 2060320) January 11, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD3-112 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of Colville River Unit ("CRU") well CD3-112. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set at a true vertical depth subsea ("TVDSS") of about 2,450', near the base of a 400 to 500-foot thick claystone and siltstone interval that persists throughout the area This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone, sandy siltstone, and silty sandstone open to the annulus of CD3-112 to accept the proposed injected fluids. 3. The lower confining layers are sufficiently thick (at least 50' aggregate thickness) and laterally persistent to ensure injected waste materials remain within the proposed disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. There are no potential oil or gas reservoirs in the proposed disposal injection intervals. Discussion CPAI's application was reviewed along with records from nearby wells Nechelik No. 1 ("Nechelik 1 "), CD3-111, CD3-108, and Fiord No. 5 ("Fiord 5"). The discussion that follows is based on well logs from these wells and on mud logs recorded in Nechelik 1 and Fiord 5. An index map and a structural cross- section are provided, below. Careful analysis is warranted because this proposed disposal injection operation will occur within the environmentally sensitive Colville River Delta near the northern coastline of Alaska. The proposed injection interval in CD3-112 lies in the Seabee formation near the center of Section 5, T12N, RSE, UM, which is about 2-1/2 miles from the current boundary of the CRU. The 9-5/8" surface casing shoe of CD3-112 lies at a depth of about 2,726' measured depth (about 2,450' TVDSS), near the base of a 400' to 500' thick interval that is dominated by claystone and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to be at about 7,588' measured depth (about 6,525' TVDSS). The most likely portion of the open annulus that will accept injected waste is a 28' thick interval of silty sandstone that lies between 2,503' and 2,531' TVDSS, which is just below the surface casing shoe. Density and sonic measurements were not recorded in CD3-112, but within the nearby CD3- 111 well these measurements indicate that this silty sandstone has a porosity of about 30%. This sandstone is part of a 173' thick interval of siltstone, sandy siltstone and silty sandstone interval that extends from 2,487' to 2,660' TVDSS. Two underlying siltstone and sandy siltstone zones may also accept some of the injected fluids. These zones lie between 2,722' and 2,825' TVDSS and 2,838' and CRU CD3-112 ~ ~ Janu 11 2007 m'Y Note to File Page 2 of 5 3,021' TVDSS. The aggregate thickness of all of these potential injection zones is about 460'. These three injection zones are separated by two claystone intervals that are, in descending order, 62' and 13' thick. Beneath the injection zones are thick intervals of thinly interbedded siltstone and claystone, including three prominent layers of claystone that range in thickness from 6' to 24', appear to be continuous throughout the area, and have an aggregate thickness of about 50'. The thick interbedded siltstone and claystone intervals and the three prominent claystone layers will provide lower confinement for any injected wastes. i Unlt I CD3-109 C0 ~ Q~'.'1`T`' J[7 boon ~ ~ CD3-108 1 CD3- 10 to CD3~111 1 CONF -' "~~ -- CD3-11 CONF C 112 ONF SP5 ~ ~ I ~. Fiord 5 ~~ ~ ,..CD's-11~ ~, ~' D3-302 CD}302 D}302 PB7 IA I `~ l / CD3-112 = '~ 08 ~~ Injection Interval ~1 L~ Nechelik 1 L Index Map The operator's application reports the base of permafrost occurs at about 1,600' TVDSS in this area. My inspection of the well logs from Nechelik 1 and Fiord 5 indicates that precise determination of the base of permafrost is difficult here. The geologic section is frozen through about 1,100' TVDSS in Nechelik 1, which lies 2-1/2 miles southwest, and about 1,400' TVDSS in Fiord 5, which lies 1-1/2 miles northeast. The base of permafrost lies more than 1,100' above the top of the proposed injection intervals. The shallow geologic section in the area surrounding CD3-112 likely contains methane gas. The mud logs from Nechelik 1 and Fiord 5 indicate that traces of methane were first measured 245' and 80' TVDSS, respectively. Both wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (range: 9.7 to 10.2 pounds per gallon). The shallowest occurrence of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were 890' and 1,325' TVDSS, respectively. So, the entire proposed disposal zone likely contains methane gas. Supporting documentation to ConocoPhillips' annular disposal application states "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area injection Order No. 30, which governs the Fiord Oil Pool, states "There are no underground sources of drinking water beneath the permafrost within the proposed affected area" which includes the area that will be influenced by annular disposal operations in CD3-112. CRU CD3-112 ~ ~ Janu 11, 2007 ~' Note to File Page 3 of 5 4" 4 ~ I -__ - III: -_ iI f - - _ -_- -- - ..Fa~r°o~t ost Likely Zone Surface - snoW ~ 5~ ~ f f 1\ ect~~ . Csg Shoe I _ J Southwest to Northeast Structural Cross-section No mud logs have yet been recorded in wells drilled from the CD3 Pad. There are, however, mud logs available from the Nechelik 1 and Fiord 5 exploratory wells. The shallowest oil shows occur in Fiord 5 from about 4,000' to 4,080' TVDSS and from 4,130' to 4,250' TVDSS, well below the likely injection zones for any 4,075' to 4,350' TVDSS. In Nechelik 1, the shallowest oil show was encountered at about 2,330' TVDSS, and it was rated as fair by the mud-logging geologist. Additional trace amounts of oil CRU CD3-112 ~ ~ January 11, 2007 Note to File Page 4 of 5 were observed at about 2,725,' 3,000,' 3,375' to 3,575,' 3,800' to 3,875,' 3,950' to 4,000,' and 4,075' to 4,350' TVDSS. These mud logs suggest that trace amounts of residual oil may be present in the geologic section below the surface casing shoe of CD3-112. However, examination of well logs from Nechelik 1, CD3-112, CD3-111, CD3-108 and Fiord 5 do not indicate the presence of commercial oil or gas reservoirs in the intervals that will be influenced by the proposed annular disposal operations. The following chart provides an estimate of the affected area surrounding the CD3-112 wellbore. Assuming a 28' thick injection zone with 30% porosity, and a maximum of 35,000 barrels of injected waste, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of about 85' from the wellbore. A worksheet documenting these calculations is attached. Injected Fluid vs Affected Distance from CD3-112 Wellbore (assumes 28' thick zone having 30% porosity) 100 d d d 0 a m E 0 w 50 m v c a D v m v v Q Amount of Injected Fluid (barrels) The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 1,000' of permafrost, and is bounded above and below by continuous layers of claystone. There are no freshwater aquifers present, nor are there any potential commercial hydrocarbon accumulations. The proposed injection zone lies inside the CRU, well away from any external property lines, so correlative rights will not be a concern. I recommend approval of this annular disposal project. Steve Davies Senior Petroleum Geologist k ~~~ ~/ ~CS P~vO, N ~ y~ A~e^ ~ 5,000 10,000 15,000 20,000 25,000 30,000 35,000 CRU CD3-112 Note to File • w January 11, 2007 Page 5 of 5 2oso32o CRU CD3-112 Injected Fluid vs Affected Distance from CD3-112 Wellbore Known 28.0 injection interval thickness in feet 0.30 average porosity 35,000 bbls of fluid to be disposed 5.62 cubic ft per barrel Storage space in annulus: 7 inch casing 0.27 volume of casing (cubic ft per foot of casing) 8.5 inch hole 0.39 volume of hole (cubic ft per foot of hole) 0.13 cubic fl of storage space per foot of annulus 7,588 MD of base of annulus (ft) 2,726 MD of casing shoe (ft) 4,862 feet of annulus 617 cubic fl of storage space available within annulus 110 bbls can be stored in annulus (5.62 bbls/cubic ft) 27 bbls stored in annulus assuming 25% displacement efficiency Affected area around borehole: 34,973 bbls of fluid to be injected 196,371 cubic ft of fluid 654,570 cubic ft of affected rock assuming average porosity above 86 ft radius of affected rock assuming injection interval thickness above Affected area around borehole for various cases: bbls bbls Inj fluid (ft^3) rock (ft^3) radius (fl) 0 0 0 0 0 2,500 2,473 13,883 46,278 23 5,000 4,973 27,921 93,070 33 7,500 7,473 41,958 139,861 40 10,000 9,973 55,996 186,653 46 12,500 12,473 70,033 233,445 52 15,000 14,973 84,071 280,236 56 17,500 17,473 98,108 327,028 61 20,000 19,973 112,146 373,820 65 22,500 22,473 126,183 420,611 69 25,000 24,973 140,221 467,403 73 27,500 27,473 154,258 514,195 76 30,000 29,973 168,296 560,986 80 32,500 32,473. 182,333 607,778 83 35,000 34,973 196,371 654,570 86 r., ~, ~~.~, ~ ~ n ti, ~, _~ - - - ~SS~ ®IL ~D Gr~S COI~TSER~P~TIOI~T COl-TiDIISSI®1~T Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage, AK Re: Colville River Field, Fiord Oil Pool, CD3-112 Sundry Number: 307-002 Dear Mr. Alvord: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision Superior Court unless rehearing has been requested. /' Chairman DATED this ~~ day of January, ~~ ~-o 07 Encl. ~vS 1/~~l~ STATE OF ALASKA ~~~C ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~ ,,; ~~ ~ 2007 ANNULAR DISPOSAL APPLICATION ~~ ' ~_ ~ `„~s ~ 20 AAC 25.oso ~mmissiorr ~ r~,flr~r;~~~, 1. Operator 3. Permit to Drill Name: Number: 206-032 ConoCOPhillips Alaska 4. API Number. 50-103-20527-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3-112 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD3-110, CD3-111 Torok and Seabee formation, shale, siltstone and sandstone ~S~Oy ` `~~'~ ®~ b) Waste receiving zone: b) water wells within one mile: C~-~"~n`'t`+~S`<1~~pr~~.i~~ISU~ Sand layers below the C30 marker in the Seabee formation i ^ ~~Cc c~s~~~=.vcc None ~~ ~~ ~`,C c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1664' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2326 PSI 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- diesel formation fluids associated with the contaminated drilling mud completion fluids 16. Estimated start date: , , , act of drilling a well, drill rig wash fluids, domestic waste water, any added water 20-Jan-07 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well. 17. Attachments: Well Schematic (Include MD and TVD) ^ Cement Bond Log (if required) ^ FIT Records w/LOT Graph ^ Surf. Casing Cementing Data ^ Other ^ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1 Signature: ~~j Title: ~~ w- ~~d, ~~'-A- t-~-.~c ~ Printed Phone t ~ ~I~ ~ Name: Chip Alvord Number: 265-6120 Date: ~ Commission Use Only t~ Conditions of approval: r~~~ Cpw~~`~t~~Cw / a-"S ~~ LOT review and approval: i~1 "0 Subsequent form required: {vim- `~~ Approval number: ,~~~ ~ ~~ o~ APPROVED BY Appro d by: COMMISSIONER THE COMMISSION Date: /~ ~~. ~1j .. io • r,7 ~~~ :_ Form 1 -4 / 004 ~,~ ~ l I TRIJCTIONS ON RE ERSE 0 R 1 G 1 ~ A ~ubmit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ~,,,onocoPh i I I i ps Telephone 907-276-1215 January 3, 2007 (~~~~ Alaska Oil and Gas Conservation Commission ,.~Q fqi ~ ~ ~ ~ Q 333 West 7th Avenue, Suite 100 ~lasica Oj~ & Anchorage, Alaska 99501-3539 Oi~s Gdns. C~~,rtt;~issto~ Rnch~ra~r Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3-112 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3-112 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD3-112 approximately January 20, 2007. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within '/ mile radius at AOGCC: CD3-111 12. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations. The initial annular LOT (15.1 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.0 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. Sin y, ~~3 ~? c_.--- . Vern Johnson Drilling Engineer cc: CD3-112 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 ORIGINAL • C7 Annulus Disposal Transmittal Form -Well CD3-112 AOGCC Reeulations. 20 AAC 25.080 (bl 1 Desi ation of the well or wells to receive drillin wastes: CD3-112 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste maybe drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2326 psi.. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD3-107, CD3-302, CD3-113, CD3-301, CD3-115, CD3-114 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why coin liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. ORIGINAL • • Well CD3- Date_ 12/29/ 112 2006 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of Maximum density of the injection fluid is ,500 12.0 version l.0-Jan'OS psi ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/fr Gas/Fluid Gradient in tubing/casing annulus 0.3952 psi/fr Header Pressure (for wells on gas lift) 0 psi w, Maximum Fluid Density to avoid Burst of Surface Casing U Pburst85% - PHydrostatic +PApplied - PFormation _ 2,992 = ( 2,485 * 0.052 *MWmax ) + 1500 - ( 0.4337 * 2,485 ) N MWmax = 19.9 PPg 2,485 TVD Surface Casing String Size 9.625 in ~ ~ Weight 36 ppf d d Grade J 55 bu ~ 9 rbursU00% 3,520 psi ~~ P ° 2,992 burst85 /o psi U Depth of Shoe 2,485 fr FIT/LOT @ Shoe 18 ppg or 2,326 psi = FIT/LOT for Annulus 15. I ppg c Max Surf. Pressure 1,500 psi TOC Est. (w, 7,588' MD 6,560' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85°/ - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 6,560 * 0.052 *MWmax ) + 1,500 - ( 0.3952 * 6,560) - 0 MWmax = 16.7 PPg a.s "Tubing 2nd Casing String Size 7 in 6,920 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85°/n 4,599 psi Top of Cement 6,560 fr Gas Gradient 0.3952 psi/fr Max Surf. Pressure 1,500 psi Header Press 0 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax avowable -Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,485 * .052 * 18 ) Pmax allowable - 2,326 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". ORIGINAL ConocoPhilli 5 Casing Detail 9 5/8"Surface Casing Well: CD3-112 Date: 3/28/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.45 FMC Gen V Hanger 2.19 36.45 Jts 3 to 69 67 Jts 9-5/8" 40# L-80 BTC Csg 2606.67 38.64 Halliburton Float Collar 1.20 2645.31 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 77.26 2646.51 Ray Oil Tools "Silver Bullet" Float Shoe 2.20 2723.77 2725.97 TD 12 1/4" Surface Hole 2735.97 12-1/4" Hole @ 2736' MD / 2493' TVD 9-5/8" Shoe @ 2726' MD / 2485' TVD RUN TOTAL 40 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8~ 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68 77 joints in the pipe shed. Run 69 joints - 8 joints stay out Use Best-o-Life 2000 i e do e MU torgue - 9000 ft/Ibs Remarks: Up Wt - 180k Dn Wt - 155k Block Wt - 75k Supervisor: D. Lutrick / L. Hill ORIGINAL ~ Cement Detail Report CD3-112 Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL & INITIAL COMPLETION DRILLING 10105575 3/25/2006 3/26/2006 4/13/2006 -- ___ Cement Details __ Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/28/2006 13:15 3/28/2006 14:49 CD3-112 Comment Cement Stages - -- - --- - - ---_ Sta a#1 Description Objective Top (ftKB) Bottom (ftK6) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Primary cement 36.0 2,726.0 `Yes 95.0 Yes Yes Q (start) (bbl/min) O (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 7 640.0 1,150.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out o (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8 Additives __~ ___ _ - i Fluid _ Fluid Type Fluid Description _ __ Estimated Top (ftKB) Est Btm (ftK8) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.0 2,226.0 360 ASL 285.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 4.45 20.72 10.70 Additives Additive Type Concentration Conc Unit label ,_---- (Fluid - _ - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,226.0 2,726.0 233 G 49.9 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label a~~~~~AL Page 1/8 Report Printed: 12128/2006 Security Level: Development Daily Drilling Report CD3-112 Report Number: 4 ., , Rig: DOYON 19 Report Date: 3/28/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD3-112 Development FIORD NECHELIK 3/26/2006 2.69 2,736.0 2,736.0 0.00 AFE / RFE / Maint# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10105575 5,780.80 39,734.12 444,942.80 841,963.12 5,455,715.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,726.OftKB Ops and Depth @ Morning Report 24hr Forecast PU 4" DP Finish testing BOPE - PU 4" DP - MU BHA #2 - CO shoe track -FIT - Drill Last 24hr Summary POOH - LD BHA - RU & Ran 9 5/8" csg to 2726' - Circ & cmted csg - ND riser - NU wellhead & BOPE -Begin testing BOPE General Remarks Weather Head Count -201-45 WC / SE@ 4 mph 47.0 _ Supervisor _ _.__ ~ - _ - -- -. _ -. _._.__. Tttle Contact Name?> Larry Hill Rig Supervisor Time Loq ,at C ~ ~ D,, Tin -- F C~~HhSt.it Dr:~hE^.r. i~.r i i ir: (hrs) i ---~ Phase ..._..- p 0 Code 0 Sub-Co. P . P-N T Tmi (.cJ~ lrbl Class_ ftK8) rth~.C~ CommlQperat(on 00:00 02:30 2.50 SURFAC DRILL - PULD __ P 349.0 0.0 _._ - Std back HWDP and 1 std of DC's. LD BHA #1. Clear floor. 02:30 04:15 1.75 SURFAC CASING RURD P 0.0 0.0 RU 9 5/8" csg equipment. 04:15 04:30 0.25 SURFAC CASING SFTY P 0.0 0.0 PJSM on running csg with all/ personnel. 04:30 08:00 3.50 SURFAC CASING RNCS P 0.0 1,367.0 RIH w/ 9 5/8" 40# L-80 BTC csg to 1367'. 08:00 08:30 0.50 SURFAC CASING CIRC P 1,367.0 1,367.0 Circ 1 csg volume at 4 bpm - 160 psi. 08:30 10:30 2.00 SURFAC CASING RNCS P 1,367.0 2,736.0 RIH w/ 9 5/8" 40# L-80 BTC csg from 1367' to 2687'. MU landing jt and land csg at 2726'. 10:30 11:00 0.50 SURFAC CEMENT RURD P 2,726.0 2,736.0 RD Franks fill up tool. RU cement head and lines. 11:00 13:00 2.00 SURFAC CEMENT CIRC P 2,736.0 2,736.0 Circ and condition mud for cement job. Stage pumps from 2 - 7 bpm at 360 psi ICP - 270 FCP 13:00 15:00 2.00 SURFAC CEMENT DISP P 2,736.0 2,736.0 Cmted 9 518" csg as follows: pumped 40 bbls Biozan water w/ nut plug as marker -tested lines to 2500 psi - Drop btm plug -Pumped 50 bbls Mudpush @ 10.5 ppg - Mixed & pumped 285 bbls lead slurry ASL @ 10.7 ppg - Observed nut plug marker @ sharkers -Switched to tail slurry -Pumped 49 bbls (G) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Displaced w/ 9.8 ppg mud -bumped plug -Full re&~rns through out job w/ 95 bbls cmt to surface - CIP @ 14:49 hrs. 15:00 16:00 1.00 SURFAC CEMENT OTHR P 2,736.0 2,736.0 RU & test csg to 2500 psi for 30 mins. 16:00 17:30 1.50 SURFAC CEMENT RURD P 2,736.0 2,736.0 RD cmt head & lines - LD landing jt. - LD csg equipment 17:30 19:00 1.50 SURFAC DRILL RURD P 2,736.0 2,736.0 ND surface riser -Change TD saver sub 19:00 20:00 1.00 SURFAC DRILL RURD P 2,736.0 2,736.0 NU FMC wellhead -test seals to 1000 psi 20:00 21:30 1.50 SURFAC WELCTL NUND P 2,736.0 2,736.0 NU BOPE 21:30 00:00 2.50 SURFAC WELCTL BOPE P 2,736.0 2,736.0 RU for BOP test -Held PJSM -Test annular to 250 & 3500 psi -Test choke maniflod valves 1,2,14,15,16,17,7,13 - TD IBOP's - HCR kill -upper pipe rams to 250 & 5000 psi - _._ - Mud Check Data ~ - - _ ~ _ YP C2 , GeI (10s,~ ~ __ Get (1 ~c~'~ ~3e1 (3(. H i HP f '. ~ Density Temp h.~, Corr. ~ Type Water DE rh~liKC' '~ Den I ~~I'~ V° ~~t '. F/i d 2,736.0 9.90 62 o cpl 12.0 i, r;H (°F) ;'l) ilbf/10C-'! pbf1100ft=; {}bft9.Jfl=: ilbfMOC ~. MBTQ6/hbl) i rL~rrr. 24.000 8.000 24.000 32.000 27.5 8.8 9.5 Based Mud Water 2,736.0 10.00 284 13.0 81.000 70.000 71.000 78.000 30.0 8.8 10.0 Based Mud In'ection Fluid Flmd S _: ~e I i ~r L~,ase (bt,l ~~ D~ t ~b~-n-. __.. _.__ N~re Cementing Fl uids 593.0 CD3-112 to CD3-109 Latest BOP Test Data Date - - Comment Page 1/2 Report Printed: 12/28/2006 I Security Level: Development Daily Drilling Report CD3-112 Report Number: 4 Rig: DOYON 19 Report Date: 3/28/2006 In'ection Fluid __ Flue" ~, a „_ From Lease (bb'~; De=tination Nate Other 45.0- CD3-112 to GD3-109 Water 150.0 CD3-112 to CD3-109 Water Based Mud 1447.0 CD3-112 to CD3-109 Wellbores __ --- --- Wellbore Name Wellbore API/UWI CD3-112 501032052700 c.ectir~ Size (In) Ad Tyr (ffK89 Act 8tm (ftKB) ~... -- - ' ~ "e End Date COND1 24 _ 0.0 114.0 3/6/2006 _.__ _ 3/6/2006 SURFAC 12 1/4 114.0 2,736.0 3/26/2006 3/27/2006 INTRMI 8 3/4 2,736.0 8,583.0 3/29/2006 4/1/2006 PROD1 6 1/8 8,583.0 16,021.0 4/4/2006 4/10/2006 _-_ Casing Strinc,~s _ -- - - - - - - _ _ _ Casing Descnp'.~m 6 .r I>>to 'iD (in) Wl I~~l;ti i Grace ~ _ C~ ~ h YI F.hi ~',or-nr~en' Surface 'I2o 2006 9 5/8 40.00 L-80 2726.0 ~i __ ''Cement _ _ Surface Casin Cement -Started 3/28/2006 Type Wellbore String Cement Evaluation Results casing CD3-112 Surface, 2,726.OftKB Pressure tested to 2500 psi for 30 mins. Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.0 2,726.0 4 640.0 .:.,.7 i„css Amount (sa ~ r .,c~~. ~ Density (iblgat} Yield (ft'/sack; - G_~t Top {ftKB) Est Btm (ftKB) Lead Cement ASL 285.0 10.70 4.45 360 36.0 2,226.0 Tail Cement G 233 49.9 15.80 1.17 2,226.0 2,726.0 Page 2/2 Report Printed: 12/28/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-112 Rig: Doyon 19 Date: I 3/29/2006 I Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: D. Lutrick / D. Mickey Pump used: #2 Mud Pump _ ~ Strokes ~ 0.1000 Bbls/Strk ~ 0.8 Bbl/min ~ P i d Type of Test: Casing Shoe Test LOT/FIT ~ ump ng own annulus and DP. ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe Depth Hole De th Pumpin Shut-in Pum in Shut-in RKB-CHF: 36.5 Ft 2,726 Ft-MD 2,485 Ft-TVD 2,756 Ft-MD 2,510 Ft-TVD Strks si Min psi Strks psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 30 0 2550 0 50 0 1100 Casin Test Pressure Inte rit Test 2 200 1 2550 1 100 0.25 Mud Weight: 9.9 ppg Mud Weight: 9.5 ppg 4 475 2 2540 2 150 0.5 Mud 10 min Gel: 22.0 Lb/100 Ft2 Mud 10 min Gel: 22.0 Lb/100 Ft2 6 725 3 2535 3 ~ 325 1 Test Pressure: 2,500 psi Rotating Weight: 135,000 Lbs 8 935 4 2535 4 ~ , 490 1.5 Rotating Weight: 130,000 Lbs BlocksJTop Drive Weight: 74,000 Lbs 10 1140 5 2535 5 ~ 590 2 Blocks/Top Drive Weight: 74,000 Lbs Desired PIT EMW: 18.0 ppg 12 1330 6 2530 6 . ,''' 690 2.5 Estimates for Test: 1.7 bbls -- Estimates for Test: 1098 psi 0.8 bbls 14 1540 7 2530 7 720 3 ~ ~ 16 1725 8 2530 8 790 3.5 _ _ EMW = -Leak-off Pressure + Mud Weight _ 1100 PIT 15 Second 18 1970 9 2530 9 ~ 820 4 + 9.5 0.052 x TVD 0.052 x 2485 f Shut-in Pressure, psi 20 2175 10 2530 10 _ 890 4.5 EMW at 2726 Ft-MD (2485 Ft-ND ) = 18.0 ppg__ _ 1075 22 2405 15 2525 11 940 5 sooo ' --• ^` -- ~. ~-~-- •--• `-'~ ^^^' 23 2550 20 2525 12 1000 5.5 25 2525 13 100 6 30 2525 14 6.5 2soo 15 7 16 7.5 8 w 2000 8.5 ~ g N isoo 9.5 w 10 a ~ooo ® ~ ' - soo ^ V J .,_"' o 0 t 2 3 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Vol ume Vol (CASING TEST tLEAK-OFF TEST O PIT Point Pum ed Bled Back Pum ed Bled s s s omments: Tested 9 5/8" csg to 2500 psi after bumping plug on cmt job ume • ConocoPhilli s p Casing Detail 7" Casing .7 Well: CD3-112 Date: 4/2/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.20 FMC Gen V Hanger 2.60 34.20 Jts 3 to 199 197 Jts 7" 26# L-80 BTCM Csg 8446.19 36.80 Halliburton Super Seal Float Collar .96 8482.99 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.53 8483.95 Ray Oil Tools "Silver Bullet" Float Shoe 2.10 8570.48 8572.58 TD 8 3/4" Hole 8583.00 8-3/4" Hole TD @ 8583 ' MD / 6921 'TVD 7" Shoe @ 8572.58 ' MD / 6920 'TVD Total Centralizers: 47 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt jts. # 135,136,137 Straight blade centralizer one per jt on every other joint Starting @ # 139 to 197 Top Nechelik - 8475 ' MD 6911 'TVD 220 joints in shed - 199 total jts. to run Last 21 jts. out Use Run & Seal i e do e Remarks: U p W t- 350 k Dn Wt-180k Block Wt - 75k Supervisor: D. Lutrick / D. Mickey ORIGINAL ~ Cement Detail Report CD3-112 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL & INITIAL COMPLETION DRILLING 10105575 3/25/2006 3/26/2006 4/13/2006 Cement Details __ Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 4/2/2006 19:53 4/2/2006 21:15 CD3-112 Comment Cement Stages - _ _ _ Sta e # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing primary cmt job 7,588.0 8,573.0 Yes Yes Yes Cement O (start) (bbllmin) Q (end) (bbllmin) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 450.0 950.0 Yes 1 5.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out 70 (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8 Additives - __ __ Fluid Fluid Type Fluid Oescription _ Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 7,588.0 8,573.0 200 G 41.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label OR~OI~AL Page 1/8 Report Printed: 12/28/2006 Security Level: Development ` \ Daily Drilling Report CD3-112 Report Number: 9 Rig: DOYON 19 Report Date: 4/2/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD3-112 Development FIORD NECHELIK 3/26/2006 7.69 8,583.0 8,583.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10105575 4,088.05 181,220.38 345,562.05 2,037,958.38 5,455,715.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 8,572.6ffKB Ops and Depth @ Morning Report 24hr Forecast RIH w/ BHA #4 RIH -test csg - C/O shoe track -FIT -Drill 6 118" hole Last 24hr Summary Finish RU to run 7" csg -Ran 7" csg to 8573' -Circ & cmt 7" csg w/ 200 sxs G - RD cmt &csg equipment -Set & test pack- off - Begin to change upper pipe rams General Remarks Weather Head Count 2?/2? ENE @ 3 mph 49.0 ---- -- - <Contact Name7> -- Larry Hill Rig Supervisor Time Loq '~ Time i Time ~ s~ ~ ~ ;e tip ~_~, 1 UF;_cb-Co... F'r ime P-N-I ! ~ Trbl Code - [i ;+. i U~ctn End Trbl CI=5s tth Di "h:6) ~rJOneration -- _ 00:00 02:00 2.00 INTRMI WELCTL NUND P 0.0 0.0 _.. Finish changing upper rams to 7". Test same to 250-5000 psi. 02:00 03:00 1.00 INTRMI CASING OTHR P 0.0 0.0 Daylight Saving Time Change 03:00 03:30 0.50 INTRM1 CASING OTHR P 0.0 0.0 Install thin wear bushing. 03:30 04:00 0.50 INTRM1 CASING RURD P 0.0 0.0 RU 7" csg equipment. 04:00 04:15 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM with all personnel on running 7" csg. 04:15 08:15 4.00 INTRM1 CASING RNCS P 0.0 2,744.0 Run 7" 26# L-80 MBTC csg as follows: FS(Ray Oil Tools silver bullet) 2 jts. - FC (Halliburton suprer seal) 2 jts (first 4 connections made up w/BakerLoc -filled pipe & checked floats) 60 ts.(64 jts total) to 2743' 08:15 08:45 0.50 INTRMI CASING CIRC P 2,744.0 2,744.0 Circ and condition mud at 4 bpm. Circulate 1 csg volume. ICP - 350 psi FCP - 270 psi 08:45 11:15 2.50 INTRM1 CASING RNCS P 2,744.0 5,200.0 Continue running 7" 26# L-80 BTCM csg f/ 2743' to 5200'. 57 jts (121 total) PU wt. 180 SO wt 150 11:15 12:00 0.75 INTRMI CASING CIRC P 5,200.0 5,200.0 Circulate and condition mud at 4 bpm. Circulate total of 190 bbls. ICP - 540 psi FCP - 340 PSI 12:00 15:00 3.00 INTRM1 CASING RNCS P 5,200.0 7,630.0 Continue running 7" 26# L-80 BTCM csg f/ 5200' to 7630' - 57jts.(178 jts total) 15:00 16:30 1.50 INTRM1 CASING CIRC P 7,630.0 7,630.0 Circulate and condition mud at 4 bpm. btms up + ICP - 540 psi FCP - 420 psi 16:30 17:30 1.00 INTRM1 CASING RNCS P 7,630.0 8,535.0 Finish running 7" 26# L-80 MBTC csg f/ 7630' to 8535' - 21 jts. (199 jts total) 17:30 18:30 1.00 INTRMI CASING RNCS P 8,535.0 8,573.0 PU landing jt. &csg hanger -land 7" csg w/ FS @ 8572.58' - FC @ 8482.99' - PU wt. 315k SO wt. 180 - LD fill up tool -blow down TD - RU cmt head & lines 18:30 20:00 1.50 INTRMI CEMENT CIRC P 8,573.0 8,573.0 Establish circ -stage pumps to 6 BPM -Circ & condition for cmtjob -ICP 530 psi FCP 450 psi - Held pre job safety meeting on cmt procedures w/ crew ~~ Latesf BOP Test Data _ - _---- Date - - Comment 3/29/2006 Tested H dril to 250 & 3500 si -All other a ui ment to 250 & 5000 si Page 1/2 Report Printed: 12/28/2006 Time Lo -- - 9-- Sffi : 'i E*.. '~ Tin i:r~~n 120:00 121:30 tig: DOYON 19 (nr=, Phase I Oo Code 1.501 INTRM1 ICEMEN ~ ~ Security Level: Development Daily Drilling Report CD3-112 Report Number: 9 Report Date: 4/2/2006 __ Time Depth Start DepLr G i __ - -N-T Trbl Cooc T L (.less (ftK_Bt =tF:Bj ,,,-rl~jp~idt~or~ P 8,573.0 8,573.0 Cement 7" casing as follows: Pumped 5 bbls CW-100 - Test lines to 3600 psi -Pumped 15 bbls CW-100 - Mixed & pumped 30 bbls 10.5 ppg MudPush @ 5.2 BPM @ 350 psi - Dropped btm plug -Mixed & pumped 41 bbls (200 sxs Class G w/additives) @ 15.8 ppg tail slurry @ 5.5 BPM @ 300 psi -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced cmt w/ 304.4 bbls 9.8 ppg LSND mud @ 7 BPM - Slowed pumps to 3.5 BPM for last 9 bbls of dispalcement -Bumped plug w/ 950 psi (pre bump pressure 450 psi) CIP @ 2116 hrs. -Check floats (held OK) Full circulation throughout job. 21:30 22:30 1.00 INTRM1 CEMENT RURD P 8,573.0 8,573.0 Attempt to test csg - cmt head leaking - RD cmt lines & head - LD landing jt. 22:30 23:30 1.00 INTRM1 DRILL OTHR P 8,573.0 8,573.0 Pull thin wall wear bushing -Set & test pack -off to 5200 psi for 10 mins. 23:30 00:00 0.50 INTRM1 WELCTL EORP P 8,573.0 8,573.0 Close blind rams ~ begin changing top pipe rams ---_ ,t1Rud Check Data rP Cs,l~ ;el '~ ~s GeI (10m) C N ,~ i~~ HTHI' I,, i Da sdy Te inp l J~ Ccrr T~;n=_ Depth(ftKB) ~DensQblgal) Vis{slgt) rvr,,._n, i I_nt'JC4t 'It,tl100ft~) (1bf110DfS') I~1_:_", MBT{IbJbbl) (mll.,_rinl off (°F) (` ~ ~~~ Water 8,583.0 9.85 40 8.0 20.000 7.000 9.000 10.000 16.0 7.6 9.0 8.5 Based Mud Water 8,583.0 9.80 44 10.0 25.000 10.000 13.000 14.000 17.5 7.2 9.2 9.0 Based Mud In'ection Fluid _ _ _ __ - _- --- - __ Flula ~ Source From Leese {bbQ D~sBnation Note _- _ __ (Other 10.0 Freeze protect dteliel CD3-149 I Wellbores Wellbore Name Wellbore API/UWI CD3-112 501032052700 5~>ct(on See i m ~ AG Top (ftK8) Act BLn,{ftK6) S t:~t pate ~ End Date C©ND1 24 0.0 114.0 3/6/2006 3/6/2006 SURFAC 12 1/4 114.0 2,736.0 3/26/2006 3/27/2006 INTRM1 8 3/4 2,736.0 8,583.0 3/29/2006 4/1/2006 PROD1 6 1/8 8.583.0 16,021.0 4/4/2006 4/10/2006 Casing Strings ~ ~ -n n- ~ ~~tion R~ Da[e G: CAD n bv~~ I ,). ; a~ net Depth (ftKB) ~, - - - -- - r~ n~nr _ Intermediate, 4/2!2006 - __ r 26 00 L 80 I 8,572.6; _ _ I Cement Intermediate Casin Cement -Started 4/2/2006 Type Wellbore String Cement Evaluation Results casing CD3-112 Intermediate, 8,572.6ftKB Pressure tested to 3500 psi for 30 mins. Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 7,588.0 8,573.0 4 450.0 I~rnd ~ Clas. - Amount(sacks) V{t~b~~ DensityQb/gal) Yield{frlsa'ck) EstTop;jftK6) _ EstBtm(ftK8) _ Tail Cement G 200 41.0 15.80 1.16 7,588.0 8,573.0' ~1L Page 2/2 Report Printed: 12/28/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-112 Rig: Doyon 19 Date: 4/3/2006 Volume Inpu , Drilling Supervisor: Lutrick /Mickey Pump used: Cement Unit - ~ ~ Barrels ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Cas Hole Size: 8-3/4" ~ Casin Shoe Depth Hole Depth Pumoina RKB-CHF: 36.2 Ft 2726.0 Ft-MD 2393.0 Ft-TVD 7588.0 Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC Chan es for Annular Ade uac Test Pressure In1 Enter outer casing shoe test results in comments Mud Weight: Casing description references outer casing string. Inner casing OD: Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Desired PIT EMW: Estimates for Test: fEMW =Leak-off Pressure + Mud Weight = 665 -- - 0.052 x TVD 0.052 x 2393 + 8 ~~~__ EMW at 2726 Ft-MD (2393 Ft-ND) = 1 ~ ~ l - ~- ~~~ Ft- PP9 In. 647 psi 0.5 bbls PIT 15 Second Shut-in Pressure, psi 571 `l~~ Pump Rate: ~ - -, ~ Bbls/Strk ~ i 0.80 Bbl/min ~ Est Pressure In te rit Test Shut-in Pum in Shut-in lin psi Bbls psi Min si 0 0 85 0.00 625 1 0.5 160 0.25 571 2 1 242 0.50 549 3 1.5 300 1.00 539 4 2 391 1.50 5~ 5 2.5 492 2.00 5' 6 3 558 2.50 52 7 3.5 665 3.00 51 ; 8 4 600 3.50 516 9 4.5 591 4.00 509 10 5 601 4.50 506 15 5.5 613 5.00 501 20 6 617 5.50 499 25 6.5 617 6.00 496 w o. av ~ I ~ 9.00 N aoa 9.50 _- ~ - - 1 ~S E ~ 10.00 a _ -- - -- _... ^_"~ o o , z s a s s ~ s o s ,o ,s zo zs so Volume Volume Volume Vol Barrels Shut-In time, Minutes tCASING TEST f-LEAK-OFF TEST O PIT Point Pum ed Bled Back Pum ed Bled ---~ s s s Co ments: 9 5 8" shoe LOT @ 18.0 ppg Summary WELLPATH DETAILS Philli C ~ onoco p CD3-I 12 Alaska 501032052700 Ref Damn: CD3--112 49.30ft Quarter Mile V-Section Ongin Origin Starting (1320 feet) MALLIBURTON An le +N/-S +E/-W From TVD g a~...y oaxy s«.us. 318.64° 0.00 0.00 36.00 ra ius p of CD3-111 CD3-111 ~~ CD3-110 CD3-110 - - CD3-111 CD3-111L1 CD3-302 Plan: CD3-302 _ ~ 3486 _ - CD3 112 C D3 302 CD3 302PB1 - I - - ) CD3-109 CD3-109 ~~ CD3-302 CD3-302PB2 - 2615 1743 -- s 0 ,-. ~ CD3-307 C D3-307 - 872 ~ ~ - ~ ~ ~ i t 0 - .,- ~ ~ -- -- _- --- 72 ~ ~ ~°--° -4358 -3486 -2615 -1743 -872 0 872 1743 2615 West(-)/East(+) [ftl SURFACE CASING SHOE SEPARATION FROM CD3-112 CD3-112 x r Surface Casino Shoe ASP 4 Coordinates NAD 27: 387406.8 6004382.6 ells Details @ AOGCC Ann. Disp. Permit # ermit Date ource well Ann. Vol. ** tart Date nd Date ~s ante from Object well' Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments CD3-108 1 87 389300.3 6004986.4 17.1 2 t 1&9 not for annular dls at CD3-109 306-020 1/20/2006 CD3-110, CD3-111, CD3-112, CD3-307, CD3-302 60160 1/20/2006 4/27/2006 1562 38J~i / 3 6004780.2 18.0 2414 16.0 CD3-110 12(15 388563.7 6004720.7 16.7 2439 15. CD3-111 n 528 381°~~ 0 6004710.6 17.4 2469 14.6 CD3-112 n 0 387406.8 6004382.6 16.0 24t]S 15.1 CU3-307 n 2225 389627.9 6004245.8 18.2 2479 15.4 Also known as CD3-107 CD3-302 n 1411 388815,4 6004469.9 18.0 2506 na onl sur€ace cos' seY * Lateral distance in feet, between surface casing shoes, in the X-Y plane ** As of Dec. 28 2007 Note that this sheet is not the definitive record for annular disposal volumes .*::Y ., ,. ;. ~.~~~.* • • ~ ~ a ) ~ ~ -^ i ~ ~ ~ ~ FRANK H. MURKOWSK/, GOVERNOR ~~~~ ~~~~++ *_ ~T~+~1 ~ttr~7~~~T Q~ ~ ~ ~ 333 W. 7TM AVENUE, SUITE 100 CO~S~1R~~1i0~ CUMD'I153IU1Q ;° ANCHORAGE, ALASKA 99501-3539 ~~ PHONE (907) 279-1433 FAX (907) 276-7542 Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 95510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-112 Sundry Number: 306-244 Dear Mr. Walker: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907} 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~day of July, 2006 Encl. Ct ~~ - 11vC7 t s ~~~ STATE OF ALASKA ~ 6 ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL REDE~~ED 20 AAC 25.280 ~~ ~,~ ~ U L 1 7 2006 a`~ ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cans. Commission APPLICATION FOR SUNDRY APPROVALS 10-403 (for use w/ NSK & Alpine) AnrhnranP 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^/ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development . ^ Exploratory ^ 206-032 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20527-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ~ CD3-112 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 372105, 364471, 384215 RKB 36.8' Fiord Proposed 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16021' 6946' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' 114' SURFACE 2677 9-5/8" 2726' 2485' PRODUCTION 8524' 7" 8573' 6803' OPEN HOLE 7448' 6-~ l~Yt2° 16021' 6921' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 8096' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer = 7914' SSSV= BAL-O / 4.5" / DB Profile SSSV= 2169' i3. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory Development ~~~~ Servi ~ 15. Estimated Date for 16. Well Statu fter proposed work: Commencing Operations: August 1, 2006 Oil Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WA'°~,~~~~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: R/ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265-6268 Printed. Name- Jack Wa{ker Title: Production Engineer Signature Phone 265-6268. Date 7 i 7~ 6 Commission Use Only Sundr Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ` e ~a OthE i i vi ` 1~55v~ Sv'~~4 ~ ~'~~~ ` . ~ S bse ent For R i i , d 1r~ ~ ~~\~~~ V~~ _ `U l u qu m re -+ equ : ~ J APPROVED BY A / /t !/f d V/~ Approved by: OMMISSIONER THE COMMISSION Date: (/ Form 10-403 Revised 06/2006 ~~ - ORIGINAL BFI JUL 2'12006 ..-~(/~~ Submit in Duplicate • Supplemental Information for 10-403 Application for Sundry Approval for CD3-112 API 50-103-20527-00 Permit to Drill No. 206-032 July 17, 2006 CD3-112 was permitted as a service well because its ultimate service will be injection of water alternating with enriched gas. It was drilled and completed as planned with equipment enabling wireline installation of asurface-controlled subsurface safety valve. A very short flowback was completed after drilling and completion earlier this year. This sundry application seeks approval to temporarily produce CD3-112 to provide additional clean up before injection and to provide additional early production to stakeholders. Injection into CD3-112 is planned after 3 to 6 months of production, and after issuance of an area injection order covering the CD3-112 well. Static pressure measurements are planned before starting production and before starting injection. .~~~ Reservoir simulation shows no effect on ultimate recovery by producing CD3-112 before injection. The future CD3-112 injection profile maybe improved due to increased mud cake clean up from the formation face. T ~ 1 • • Review of Sundry Applications 306-244 and 306-248 ConocoPhillips Alaska, Inc. Wells CD3-112 and CD3-110 AOGCC Permits 206-032 and 205-041 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to pre-produce these MWAG injection wells in the Fiord Oil Pool. Production would be for between 45 days and six months pre CPAI's request. Recommendation: I recommend approval of these Sundry Applications to allow CPAI to pre-produce the wells for up to 6 months. Discussion: CPAI proposes to pre-produce the subject wells prior to conversion to MWAG injection wells in order to provide additional well cleanup prior to injection and to "provide additional early production to stakeholders." While providing additional benefits to the stakeholders is not a compelling reason to allow this activity there is some merit in providing an additional opportunity for well cleanup, which should improve future injectability in these wells. CPAI states that reservoir simulation shows that the proposed activity will not harm ultimate recovery. I talked with Mr. Jack Walker on July 21St and 25th, 2006, to discuss the proposed operations. Mr. Walker stated that their reservoir simulation model indicates a total volume, from all producing wells in the pool not just the two subject wells, of approximately 4 combo will be produced. There will be water and gas injection occurring in the pool during the pre-production period in well CD3-108, and the wo subject wells will also be converted to injection during this period. The injection totals are estimated at 1.6 bcfg and 1.7 mmbw during this six-month period. The original oil in place for the pool is estimated to be between 80 and 190 mmstb. The amount of oil produced during the pre-production period will therefore represent about 2 to 5 percent of the oil in place. Taking into account the total injection volumes also net voidage is reduced to 1 to 2 percent of the original oil in place. Maintaining the reservoir pressure above the minimum miscibility pressure is vital to ensure that the miscible injectant will provide the anticipated benefits. The initial reservoir pressure for the pool is approximately 3,200 psi and the minimum miscibility pressure (MMP) is estimated to be 2,935 psi. Based on the worst-case estimate of a 5 percent voidage the estimated pressure drop would be approximately 150 to 200 psi. The resulting average reservoir pressure would be in the range of 3,000 to 3,050 psi, which is • • above the MMP. This is the worst-case estimate and does not account for the voidage replacement that will also be occurring. The reservoir pressure in the areas immediately adjacent to the pre-produced injection wells will be drawn below the MMP. However, this will represent a small area of the pool and Mr. Walker indicated that the reservoir pressure in this area would be increased to above the MMP through water injection prior to the commencement of the MI injection. Conclusion: CPAI's proposed activities will cause a localized reduction in reservoir pressure to below the MMP, but I believe that average reservoir pressure will remain above MMP and that CPAI is proposing the proper actions to avoid possible harm to the ultimate recovery. Therefore, I recommend approving their request. D.S. Roby Reservoir ngineer July 25, 2006 -~ 7-~~ # i WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 June 15, 2006 RE: MWD Formation Evaluation Logs: CD3-112, AK-MW-4295099 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20527-00. ~l~~.~ `~ ~~ I(ii a~iV;s~;SS~b`'. ~ ~l~ • 06-Jun-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD3-112 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.00' MD Window /Kickoff Survey: 15,982.60' MD (if applicable) Projected Survey: 16,021.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ 7 „~oZO f1 Signed _ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~o cam- ~3~ • • ConocoPhillips May 30, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Subject: Well Completion Report for CD3-112 (APD 206-032) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD3-112. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad • STATE OF ALASKA ~ ~, ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT`~~C~ ~~~ ~ ~" ,..,,sx~i 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ WAG Q 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory ^ Service Q ~ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., f,Y oraband.: Aprilys, 2006 12. Permit to Drill Number: 206-032 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 26, 2006 13. API Number: 50-103-20527-00 4a. Location of Well (Governmental Section): Surface: 3950' FNL, 894' FEL, Sec. 5, T12N, R5E, UM~ 7. Date TD Reached: April 10, 2006 ~ 14. Well Name and Number: CD3-112 - At Top Productive Horizon: 1222' FNL, 932' FWL, Sec. 5, T12N, R5E, UM 8. KB Elevation (ft): 36.8' RKB 15. Field/Pool(s): Colville River Field Total Depth: 362' FNL, 781' FEL, Sec. 36, T13N, R4E, UM 9. Plug Back Depth (MD + ND): 16021' MD / 6946' TVD Fiord Nechelik Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388149 ' y- 6003825 ~ Zone- 4 10. Total Depth (MD + ND): • 16021' MD 16946' TVD 16. Property Designation: - ADL 372105, 364471, 384215 TPI: x- 384729 y- 6006605 Zone- 4 Total Depth: x- 380472 _ - 6012812 - Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: LAS21122 18. Directional Survey: Yes ~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1270' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 84# J-55 36.8' 114' 36.8' 114' 24" 1 o cu yds Portland Type III 9-5/8" 40# L-80 36.8' 2726' 36.8' 2485' 12.25" 360 sx ASLite, 233 sx Class G 7" 26# L-80 36.8' 8573' 36.8' 6920' 8.75" 200 sx Class G 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Injection 4/18/2006 flowback test Method of Operation (Flowing, gas lift, etc.) injector -pre-produced injector ~ Date of Test Hours Tested Production for Test Period --> OIL-BBL 5527 GAS-MCF 1354 WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. 640 psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). ._e_~ .__ .__ _ „, Submit core chips; if none, state "none". ; -'~ ~ ` ` D i NONE BF~ JUN ~ ~+ 2~~6 VEF:IFIE{l Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ (r •1.7•dlo ORIGINAL `~'~~~~i~6 is. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD3-112 Nechelik 8481' 6912' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name Chi Iv rd Title: Alpine Area Drillino Team Leader tt Signature Phone ZV ~ ,, ~ ~ Z~ Date ~ ~ 3~~~.' b INSTRUCTIONS Prepared by Sharon Allsup-Drake 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. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • CD3-112 Well Events Summary • Date Summary 3/25/06 Moved rig to CD3-112 and rigged up. Rig accepted at 0000 hrs 3/26/06. 3/26/06 Nippled up riser. Picked up BHA and spudded well. Drilled form 114' to 1,170'. 3/27/06 Drilled from 1,170' to 2,736'. Circulated hole clean. Short tripped to 889' Back reaming. Circulated hole clean. POOH on TT to 349'. 3/28/06 POOH - LD BHA - RU & Ran 9 5/8" csg to 2726' - Circ & cmted csg - ND riser - NU wellhead & BOPE -Begin testing BOPE 3/29/06 Fin. BOP test - PU 4" DP f/shed - MU BHA -RIH - C/O shoe track -Perform FIT to 18.0 ppg EMW -Drill to 3205' -Circ btms up -POOH to 1871' 3/30/06 POOH on TT -Service GP -Change bit -RIH -wash & ream f/ 2726' to 3205' -Drill to 5671' 3/31/06 Drill 8 3/4" hole f/ 5671' to 8340' 4/1/06 Drill to 8583' TD -Circ btms up -wiper trip to 7574' -RIH -Circ - POOH(spotting tube pill) to 1871' -Handle BHA - LD MWD & GP - RU to run 7" 4/2/06 Finish RU to run 7" csg -Ran 7" csg to 8573' -Circ & cmt 7" csg w/ 200 sxs G - RD cmt & csg equipment -Set & test pack- off - Begin to change upper pipe rams 4/3/06 Fin.chg. rams & test - MU BHA #4 -shallow test tools -PWD failure -POOH to PWD & change tools -RIH to 300' -test tools - RIH to 7580' -MAD pass f/ 7580' to 7910' -RIH to 8126' - S&C drill line -Press. test 7" to 3500 psi 4/4/06 RIH to top of cmt @ 8418' -C/O shoe track -Perform FIT to 12.5 ppg -Change over to 9.2 FloPro -Drill to 9730' 4/5/06 Drill f/ 9730' to 11,266' 4/6/06 Drill f! 11,266' to 12,860' 4/7/06 Drill f/ 12,860' to 14, 377' 4/8/06 Drill f/ 14,377' to 15,070' - GP failure - POOH for BHA 4/9/06 Finish POOH -Chg. BHA -RIH - C&S drill line - W&R f/ 14945' to 15,070 -Circulating btms up -Drill to 15,160' 4/10/06 Drill f/ 15,160' to 16,021' MD 6946' TVD -Circ hole clean pumping out to 15,326' -Change over to 9.4 ppg KCL -Spot LCM pill -Prep to POOH 4/11/06 POOH and laid down DP. RU and ran Completion to 5,938'. PU SSSV. 4/12/06 RIH and landed Completion. ND BOP/NU and tested tree. Freeze protected well. Set and tested packer. Secured well and laid down DP. 4/13/06 Laid down 4" drill pipe -prepare rig for move 4/15/06 Flow back CD3-112 to clean up drilling mud and Brine from well) boar 4/15/06 PULLED 3.81" DUMMY SLEEVE FROM BAL-O-NIPPLE @ 2169' RKB. PULLED BALL & ROD @ 8084' RKB. REPLACED 1" DV @ 7914' RKB W/ 1" X .25" OV. PULLED 3.81" RHC PLUG BODY @ 8084' RKB. WELL IS READY FOR FLOW BACK. 4/26/06 FMC INSTALLED BPV. 30 BBLS DIESEL FREEZE PROTECT PUMPED. • i • • STATE OF ALASKA ALASI'~A OIL AND GAS CONSERVATION COMMISSION ', Mechanical Integrity Test Email to: Jim.. Reaa(a)admin.state.ak.us: Bob FleckensteinCa~admin.state.ak.us OPERATOR: ConocoPhillips FIELD /UNIT /PAD: Fiord /Alpine /CD3 DATE: 4/12/2006 OPERATOR REP: David Burley AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-112 In'. T e N TVD 6,770' Tubin 1,120 1,580 1,610 1,610 Interval I P.T.D. 206-032 Test T e I P Test si 3500 IA 0 3,510 3,440 3,410 P/F P Notes: OA Packer De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Mina Well In'. T pe ' I TVD Tubin Interval I P.T.D. Test T pe ' I Test si IA P/F I Notes: OA Packer De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well In'. T e ' I TVD Tubin Interval I P.T.D. Test T e ' I Test si IA P/F I Notes: ' OA Packer De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well In'. T e ' I TVD Tubin Interval I P.T.D. Test T e I Test si IA P/F I Notes: ' OA Packer De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Mina Well In'. T e I TVD Tubin Interval I P.T.D. Test T e ' I Test si IA P/F I Notes: ' OA MIT Report Form Revised: 03/18!04 CD3-112 MIT.xIs • Halliburton Company Survey Report Company: ConocoPhillipsAlaskalnc. Date: 5/9/2006 'l'ime: 14:53:07 Page: 1 Field: Colville River Unit Co-ordinatc(NE) Reference: We ll: CD3-112, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3-112' 49.3 Well: CD3-112 Section (VS) Referen ce: We II (OAON;O.OOE,318.64Azi) Wellpath: CD3-112 Survey Calttdation M ethod: Min imum Curvature Db: Oracle Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: CD3-112 Slot Name: Alpine CD3 Well Position: +N/-S -66.64 ft Northing : 6003825.22 ft ~ Latitude: 70 25 9.825 N +E/-W -337.88 ft Easting : 388149.29 ft • Longitude: 150 54 40.299 W Position Uncertainty: 0.00 ft Wellpath: CD3-112 Drilled From: Well Ref. Point ' ~ 501032052700 Tie-on Depth: 36.00 ft Current Datum: CD3-112: Height 49.30 ft Above System Datum: Mean Sea Level Magnetic Data: 3/25/2006 Declination: 23.48 deg Field Strength: 57513 nT Mag Dip Angle: 80.72 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.00 0.00 0.00 318.64 Survey Program for Definitive Wellpath Date: 12/2/2004 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 81.00 350.00 CD3-112 gyro (81.00-350.00) CB-GYRO-SS Camera based gyro single shot 433.49 15982.60 CD3-112 (433.49-15982.60) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ MD lncl Azim TVD Sys TVD V'/S EIW MapN MapE Tool j ft deg deg ft ft ft ft ft ft I 5 9 C 169.00 0. 5 122.00 168.99 119.69 0.69 0.92 6003824.5 388150.20 CB-GYRO-SS I 259.00 0.65 310.00 258.99 209.69 -0.68 1.03 6003824.53 388150.31 CB-GYRO-SS i 350.00 2.75 311.00 349.95 300.65 1.09 -1.02 6003826.32 388148.29 CB-GYRO-SS 433.49 3.64 301.98 433.31 384.01 3.80 -4.77 6003829.10 388144.57 MWD+IFR-AK-CAZ-SC ~', 477.13 4.28 311.44 476.84 427.54 5.62 -7.17 6003830.94 388142.20 MWD+IFR-AK-CAZ-SC 569.31 5.65 310.75 568.67 519.37 10.85 -13.19 6003836.27 388136.27 MWD+IFR-AK-CAZ-SC 658.72 5.91 326.35 657.64 608.34 17.56 -19.07 6003843.06 388130.48 MWD+IFR-AK-CAZ-SC '~ I 748.03 7.65 319.77 746.32 697.02 25.93 -25.46 6003851.52 388124.22 MWD+IFR-AK-CAZ-SC I 839.15 8.87 323.38 836.49 787.19 36.20 -33.57 6003861.91 388116.27 MWD+IFR-AK-CAZ-SC 934.23 12.84 313.57 929.86 880.56 49.37 -45.60 6003875.26 388104.44 MWD+IFR-AK-CAZ-SC 1029.65 14.71 310.32 1022.53 973.23 64.52 -62.52 6003890.66 388087.75 MWD+IFR-AK-CAZ-SC 1124.75 17.92 304.55 1113.80 1064.50 80.63 -83.78 6003907.09 388066.73 MWD+IFR-AK-CAZ-SC 1219.74 18.28 305.82 1204.09 1154.79 97.64 -107.90 6003924.45 388042.87 MWD+IFR-AK-CAZ-SC 1315.10 21.55 305.15 1293.73 1244.43 116.48 -134.35 6003943.69 388016.71 MWD+IFR-AK-CAZ-SC ~'I 1410.00 26.11 307.38 1380.52 1331.22 139.20 -165.22 6003966.87 387986.19 MWD+IFR-AK-CAZ-SC 1504.84 30.09 308.83 1464.17 1414.87 166.79 -200.33 6003994.98 387951.49 MWD+IFR-AK-CAZ-SC 1600.09 31.04 308.77 1546.18 1496.88 197.14 -238.08 6004025.89 387914.21 MWD+IFR-AK-CAZ-SC 1694.50 33.59 307.96 1625.96 1576.66 228.45 -277.66 6004057.79 387875.11 MWD+IFR-AK-CAZ-SC I 1789.68 34.57 305.19 1704.80 1655.50 260.21 -320.49 6004090.18 387832.76 MWD+IFR-AK-CAZ-SC ! 1884.68 33.83 302.66 1783.38 1734.08 290.02 -364.78 6004120.64 387788.93 MWD+IFR-AK-CAZ-SC 1979.80 32.94 302.86 1862.80 1813.50 318.34 -408.80 6004149.62 387745.34 MWD+IFR-AK-CAZ-SC '' 2074.72 34.24 303.98 1941.87 1892.57 347.27 -452.62 6004179.20 387701.96 MWD+IFR-AK-CAZ-SC 2169.93 33.01 301.39 2021.15 1971.85 375.75 -496.97 6004208.34 387658.04 MWD+IFR-AK-CAZ-SC i ', 2265.19 32.14 302.14 2101.42 2052.12 402.74 -540.58 6004235.98 387614.85 MWD+IFR-AK-CAZ-SC 2360.52 32.54 301.81 2181.97 2132.67 429.75 -583.84 6004263.63 387572.00 MWD+IFR-AK-CAZ-SC 2455.67 33.93 304.93 2261.56 2212.26 458.44 -627.36 6004292.97 387528.92 MWD+IFR-AK-CAZ-SC '' 2550.97 34.71 306.88 2340.27 2290.97 489.96 -670.88 6004325.13 387485.89 MWD+IFR-AK-CAZ-SC - • Halliburton Company Survey Report Company: ConocoPhiflips Alaska inc. - Field:. Colville River Unit Site: Alpine CD3 Well: CD3-112 Wellpath: CD3-112 Survey NID Incl Azim ft deg deg 2646.07 33.72 304.33 2 2688.40 33.78 304.72 2 2788.28 33.48 304.61 2 2883.45 32.86 305.69 2 2978.60 32.41 306.66 2 ~~ 3073.59 32.32 308.37 2 i 3168.58 31.68 308.37 2 3264.47 31.54 308.26 2 I 3359.86 31.04 308.25 3 I 3454.62 30.78 307.85 3 3549.84 30.15 308.19 3 3645.06 29.48 307.62 3 3740.35 29.18 308.31 3 3835.34 28.73 308.50 3 3929.74 28.82 308.76 3 4024.72 30.02 308.32 3 4119.76 29.89 308.12 3 4214.92 28.92 307.85 3 4309.90 28.03 307.70 3 4404.95 29.04 305.56 3 4499.94 31.49 304.34 4 4595.17 35.74 305.95 4 4690.27 38.99 309.72 4 4785.29 39.45 305.48 4 4880.36 39.10 303.54 4 4975.71 37.59 301.87 4 II 5070.77 36.79 302.07 4 5165.82 36.07 302.02 4 5259.16 36.82 302.43 4 5356.06 36.00 302.42 4 5451.00 35.45 304.50 4 5546.17 37.12 305.10 4 5641.26 36.18 305.84 4 5736.48 35.48 304.85 5 5831.73 34.85 302.13 5 I~ 5926.96 35.68 304.16 5 6021.83 35.84 304.30 5 6117.28 36.62 304.58 5 6212.42 35.09 305.84 5 6307.56 35.37 304.73 5 6402.48 35.61 305.35 5 6497.82 34.69 304.56 5 6592.83 35.80 304.27 5 6688.03 34.92 304.95 5 6783.08 34.75 305.40 5 6878.20 34.65 305.40 5 Date:. 5/9/2006 Time: 14:53:07 Page: 2 Co-ordinate(NE) Reference: Well: CD3-112, True North Vertical (TYD) Reference: CD3-112: 49.3 Section (VS) Reference: Well (O.OON,0.00E,318.64Azi) Survey CatculationMethod: Minimum Curvature Db: Oracle VD Sys TVD N/S ElW Diapr ft ft ft ft ft 418 -- .91 -- 2369 .61 521. 10 -714. 34 6004356. 92 454 .11 2404 .81 534. 43 -733. 71 6004370. 53 537 .27 2487 .97 565. 89 -779. 21 6004402. 67 616 .93 2567 .63 595. 86 -821. 78 6004433. 28 697 .06 2647 .76 626. 15 -863. 20 6004464. 18 777 .30 2728 .00 657. 11 -903. 53 6004495. 74 857 .85 2808 .55 688. 35 -943. 00 6004527. 57 939 .52 2890 .22 719. 51 -982. 43 6004559. 31 021 .03 2971 .73 750. 19 -1021. 34 6004590. 56 02 .33 3053 .03 780. 19 -1059. 67 6004621. 13 84 .41 3135 .11 809. 93 -1097. 70 6004651. 43 267 .02 3217 .72 839. 01 -1135. 06 6004681. 07 350 .10 3300 .80 867. 73 -1171. 86 6004710. 33 433 .21 3383 .91 896. 29 -1207. 89 6004739. 43 515 .96 3466 .66 924. 66 -1243. 39 6004768. 33 598 .69 3549 .39 953. 73 -1279. 88 6004797. 93 681 .03 3631 .73 983. 09 -1317. 17 6004827. 85 763 .93 3714 .63 1011. 84 -1353. 99 6004857. 15 847 .42 3798 .12 1039. 58 -1389. 78 6004885. 42 930 .93 3881 .63 1066. 66 -1426. 22 6004913. 04 012 .96 3963 .66 1094. 07 -1465. 47 6004941. 03 092 .25 4042 .95 1124. 44 -1508. 54 6004972. 04 67 .84 4118. 54 1159. 88 -1554. 06 6005008. 15 241 .46 4192 .16 1196. 51 -1601. 64 6005045. 49 315 .06 4265. 76 1230. 60 -1651. 23 6005080. 32 389 .84 4340. 54 1262. 58 -1700. 99 6005113. 03 465 .57 4416. 27 1293. 00 -1749. 73 6005144. 18 542 .05 4492. 75 1322. 95 -1797. 58 6005174. 84 617 .13 4567. 83 1352. 52 -1844. 48 6005205. 10 695 .12 4645. 82 1383. 36 -1893. 03 6005236. 66 772 .19 4722. 89 1413. 91 -1939. 28 6005267. 90 848 .91 4799. 61 1446. 06 -1985. 52 6005300. 74 925 .20 4875. 90 1478. 99 -2031. 75 6005334. 36 002 .40 4953. 10 1511. 24 -2077. 21 6005367. 28 080 .27 5030. 97 1541. 51 -2122. 95 6005398. 23 58 .02 5108. 72 1571. 58 -2168. 97 6005428. 98 35. 01 5185. 71 1602. 76 -2214. 81 6005460. 85 312. 00 5262. 70 1634. 67 -2261. 33 6005493. 44 389. 11 5339. 81 1666. 79 -2306. 87 6005526. 24 66. 83 5417. 53 1698. 49 -2351. 67 6005558. 60 44. 11 5494. 81 1730. 13 -2396. 78 6005590. 91 22. 07 5572. 77 1761. 58 -2441. 77 6005623. 03 99. 66 5650. 36 1792. 56 -2487. 00 6005654. 69 77. 30 5728 .00 1823. 85 -2532. 34 6005686. 65 855 .31 5806 .01 1855. 13 -2576. 72 6005718. 59 933 .52 5884 .22 1886. 50 -2620. 86 6005750. T 1 1 1 1 2 4 5 6 6 7 61 1apE __ __Tool __ ft __ 387442.90 MWD+IFR-AK-CAZ-SC 387423.73 MWD+IFR-AK-CAZ-SC 387378.71 MWD+IFR-AK-CAZ-SC 387336.60 MWD+IFR-AK-CAZ-SC 387295.64 MWD+IFR-AK-CAZ-SC 387255.78 MWD+IFR-AK-CAZ-SC 387216.79 MWD+IFR-AK-CAZ-SC 387177.83 MWD+IFR-AK-CAZ-SC 387139.39 MWD+IFR-AK-CAZ-SC 387101.52 MWD+IFR-AK-CAZ-SC 387063.94 MWD+IFR-AK-CAZ-SC 387027.03 MWD+IFR-AK-CAZ-SC ~ 386990.67 MWD+IFR-AK-CAZ-SC 386955.07 MWD+IFR-AK-CAZ-SC 386920.00 MWD+IFR-AK-CAZ-SC 386883.95 MWD+IFR-AK-CAZ-SC 386847.11 MWD+IFR-AK-CAZ-SC 386810.73 MWD+IFR-AK-CAZ-SC 386775.36 MWD+IFR-AK-CAZ-SC 386739.33 MWD+IFR-AK-CA2-SC 386700.50 MWD+IFR-AK-CAZ-SC 386657.89 MWD+IFR-AK-CAZ-SC 386612.92 MWD+IFR-AK-CAZ-SC 386565.89 MWD+IFR-AK-CAZ-SC 386516.83 MWD+IFR-AK-CAZ-SC 386467.55 MWD+IFR-AK-CAZ-SC 386419.27 MWD+IFR-AK-CAZ-SC 386371.89 MWD+IFR-AK-CAZ-SC 386325.44 MWD+IFR-AK-CAZ-SC 386277.36 MWD+IFR-AK-CAZ-SC 386231.58 MWD+IFR-AK-CAZ-SC 386185.83 MWD+IFR-AK-CAZ-SC 386140.10 MWD+IFR-AK-CAZ-SC 386095.13 MWD+IFR-AK-CAZ-SC 386049.86 MWD+IFR-AK-CAZ-SC 386004.29 MWD+IFR-AK-CAZ-SC 385958.93 MWD+IFR-AK-CAZ-SC 385912.90 MWD+IFR-AK-CAZ-SC I 385867.85 MWD+IFR-AK-CAZ-SC ~~ 385823.54 MWD+IFR-AK-CAZ-SC i, 385778.90 MWD+IFR-AK-CAZ-SC 385734.40 MWD+IFR-AK-GAZ-SC 385689.64 MWD+IFR-AK-CAZ-SC 385644.77 MWD+IFR-AK-CAZ-SC 385600.87 MWD+IFR-AK-CAZ-SC 385557.21 MWD+IFR-AK-CAZ-SC 385513.72 MWD+IFR-AK-CAZ-SC 385470.12 MWD+IFR-AK-CAZ-SC 385427.32 MWD+IFR-AK-CAZ-SC 385385.69 MWD+IFR-AK-CAZ-SC 385343.96 MWD+IFR-AK-CAZ-SC 385300.34 MWD+IFR-AK-CAZ-SC ', 6973.26 34. 77 305. 93 6011.66 5962. 36 1918. 06 -2664. 84 6005782. 82 7068.44 35. 35 306. 56 6089.57 6040. 27 1950. 38 -2708. 93 6005815. 80 7163.58 33. 33 305. 92 6168.12 6118. 82 1982. 11 -2752. 21 6005848. 18 7258.74 34. 35 308. 72 6247.17 6197. 87 2014. 25 -2794. 33 6005880. 93 7353.88 36. 19 310. 63 6324.84 6275. 54 2049. 33 -2836. 60 6005916. 64 7448.78 40. 29 311. 65 6399.36 6350 .06 2087. 98 -2880. 81 6005955. 95 - ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska lne. Date: 5/9/2006 .Time: 14:53:07 Page: 3 - Field: Co lville River Unit Co-ordinate(NE) Reference: Well: CD3-112 , True North Site: Alpine CD3 Vertical (TVD) Reference: CD3-112: 49.3 Well: CD3-112 Section (VS) Reference: Well (O.OON,O. OOE,318.64Az) Wellpath: C03-112 Survey Calculation Method: Mi nimum Curv ature llb: Oracle Survey ', AiD [ncl Azim TVD ~ S ~sT~'D N/S FJVV p, eta 1' ;~IapE ___ Tool ', ft deg deg ft ft ft ft ft ft 7543 .88 42. 72 311. 11 6470. 58 6421. 28 2129.64 -2928.09 6005998 .30 385253. 68 MWD+IFR-AK-CAZ-SC 7638 .99 45. 17 310. 59 6539. 05 6489. 75 2172.80 -2978.02 6006042 .21 385204. 41 MWD+IFR-AK-CAZ-SC 7733 .86 48. 56 315. 17 6603. 93 6554. 63 2219.93 -3028.67 6006090 .09 385154. 48 MWD+IFR-AK-CAZ-SC ~~ 7828 .93 52. 49 317. 79 6664. 36 6615. 06 2273.16 -3079.15 6006144 .06 385104. 81 MWD+IFR-AK-GAZ-SC ~ 7923. 99 56. 84 319. 75 6719 .33 6670 .03 2331.49 -3130.22 6006203 .14 385054. 63 MWD+IFR-AK-CAZ-SC 8018 .99 61 .19 321. 06 6768 .23 6718 .93 2394.24 -3182.09 6006266 .66 385003. 70 MWD+IFR-AK-CAZ-SC 8114 .07 65 .00 319. 59 6811 .25 6761 .95 2459.47 -3236.23 6006332 .69 384950. 55 MWD+IFR-AK-CAZ-SC j 8209 .30 69. 93 318. 85 6847 .73 6798 .43 2526.05 -3293.67 6006400 .12 384894. 12 MWD+IFR-AK-CAZ-SC 8304 .56 74 .60 320. 18 6876 .74 6827 .44 2595.05 -3352.55 6006469 .98 384836. 29 MWD+IFR-AK-CAZ-SC 8399 .43 78. 46 320. 52 6898 .84 6849. 54 2666.07 -3411.41 6006541 .88 384778. 50 MWD+IFR-AK-CAZ-SC 8492 .57 83. 16 321. 36 6913 .71 6864. 41 2737.45 -3469.32 6006614 .10 384721. 67 MWD+IFR-AK-CAZ-SC 8549 .17 85. 95 321. 64 6919 .08 6869. 78 2781.54 -3504.39 6006658 .71 384687. 26 MWD+IFR-AK-CAZ-SC 8660 .32 86. 67 324. 01 6926 .23 6876. 93 2869.91 -3571.41 6006748 .07 384621. 58 MWD+IFR-AK-CAZ-SC 8755 .37 88. 58 325. 19 6930 .17 6880. 87 2947.32 -3626.42 6006826 .29 384567. 74 MWD+IFR-AK-CAZ-SC 8850 .71 86. 97 325. 22 6933 .87 6884. 57 3025.55 -3680.78 6006905 .32 384514. 57 MWD+IFR-AK-CAZ-SC 8945 .78 87. 41 322. 89 6938 .54 6889. 24 3102.42 -3736.52 6006983 .01 384459. 99 MWD+IFR-AK-CAZ-SC 9041 .17 89. 07 322. 80 6941 .47 6892. 17 3178.41 -3794.10 6007059 .84 384403. 56 MWD+IFR-AK-CAZ-SC i 9136 .44 90. 93 323. 01 6941 .47 6892. 17 3254.40 -3851.56 6007136 .68 384347. 25 MWD+IFR-AK-CAZ-SC '~ 9231 .82 92. 22 322. 78 6938 .84 6889. 54 3330.43 -3909.08 6007213 .56 384290. 88 MWD+IFR-AK-CAZ-SC 9326 .81 91. 73 322. 53 6935. 57 6886. 27 3405.91 -3966.67 6007289 .88 384234. 44 MWD+IFR-AK-CAZ-SC 9421 .93 92. 34 322. 95 6932 .19 6882. 89 3481.56 -4024.22 6007366 .39 384178. 03 MWD+IFR-AK-CAZ-SC ' 9517 .08 92. 53 324. 27 6928. 15 6878. 85 3558.09 -4080.62 6007443 .74 384122. 79 MWD+IFR-AK-CAZ-SC 9612 .31 91. 98 323. 89 6924. 40 6875. 10 3635.15 -4136.44 6007521 .62 384068. 13 MWD+IFR-AK-CAZ-SC 9706 .69 92. 47 323. 44 6920. 74 6871. 44 3711.12 -4192.32 6007598 .42 384013. 40 MWD+IFR-AK-CAZ-SC ~ 9802. 82 90. 62 321. 92 6918. 15 6868. 85 3787.53 -4250.57 6007675 .69 383956. 30 MWD+IFR-AK-CAZ-SC '~ 9898. 04 91. 54 321. 53 6916. 35 6867. 05 3862.27 -4309.55 6007751 .29 383898. 46 MWD+IFR-AK-CAZ-SC i 9993. 54 90. 86 322. 71 6914. 35 6865. 05 3937.63 -4368.17 6007827 .52 383840. 98 MWD+IFR-AK-CAZ-SC 10088. 74 91. 61 324. 46 6912. 30 6863. 00 4014.22 -4424.67 6007904 .94 383785. 64 MWD+IFR-AK-CAZ-SC 10181. 17 90. 99 328. 04 6910. 20 6860. 90 4091.04 -4476.00 6007982 .51 383735. 47 MWD+IFR-AK-CAZ-SC 10277. 57 92. 84 328. 53 6906. 98 6857. 68 4173.00 -4526.64 6008065 .21 383686. 06 MWD+IFR-AK-CAZ-SC 10372. 79 91. 23 325. 62 6903. 60 6854. 30 4252.86 -4578.36 6008145 .83 383635. 55 MWD+IFR-AK-CAZ-SC 10464. 45 91. 05 325. 85 6901. 78 6852. 48 4328.60 -4629.96 6008222 .33 383585. 10 MWD+IFR-AK-CAZ-SC 10562. 58 90. 43 325. 33 6900. 51 6851. 21 4409.55 -4685.41 6008304 .09 383530. 88 MWD+IFR-AK-CAZ-SC 10657. 49 92. 10 326. 36 6898. 41 6849. 11 4488.07 -4738.68 6008383 .39 383478. 79 MWD+IFR-AK-CAZ-SC ~! 10752. 78 89. 07 325. 14 6897. 44 6848. 14 4566.82 -4792.30 6008462 .93 383426. 36 MWD+IFR-AK-CAZ-SC ~ 10848. 01 91. 05 323. 56 6897. 34 6848. 04 4644.19 -4847.79 6008541 .12 383372. 04 MWD+IFR-AK-CAZ-SC 10943. 29 88. 33 322. 89 6897. 86 6848. 56 4720.50 -4904.83 6008618 .27 383316. 16 MWD+IFR-AK-CAZ-SC ~ 11038. 20 87. 65 322. 11 6901. 18 6851. 88 4795.75 -4962.57 6008694 .37 383259. 55 MWD+IFR-AK-CAZ-SC '~ 11133. 79 89. 51 321. 81 6903. 55 6854. 25 4871.01 -5021.45 6008770 .50 383201. 81 MWD+IFR-AK-CAZ-SC ~I i, 11229 .24 88. 09 320. 98 6905. 55 6856. 25 4945.58 -5080.99 6008845 .95 383143. 40 MWD+IFR-AK-CAZ-SC 11324 .31 88. 64 323. 38 6908. 27 6858. 97 5020.65 -5139.26 6008921 .87 383086. 27 MWD+IFR-AK-CAZ-SC ! 11419 .26 89. 38 329. 17 6909. 91 6860. 61 5099.57 -5191.95 6009001 .57 383034. 77 MWD+IFR-AK-CAZ-SC 11512 .26 90. 55 330. 69 6909. 96 6860. 66 5180.05 -5238.54 6009082 .73 382989. 39 MWD+IFR-AK-CAZ-SC 11609. 02 91. 05 328. 89 6908. 61 6859. 31 5263.66 -5287.22 6009167 .05 382941. 98 MWD+IFR-AK-CAZ-SC 11704. 35. 89. 69 328. 97 6908. 00 6858. 70 5345.31 -5336.42 6009249 .42 382894. 01 MWD+IFR-AK-CAZ-SC 11798. 25 91. 85 328. 12 6906. 74 6857. 44 5425.40 -5385.41 6009330 .23 382846. 23 MWD+IFR-AK-CAZ-SC 11894. 50 90. 55 326. 71 6904. 72 6855. 42 5506.48 -5437.23 6009412 .07 382795. 63 MWD+IFR-AK-CAZ-SC j 11989. 59 89. 81 325. 72 6904. 42 6855. 12 5585.51 -5490.11 6009491 .87 382743. 95 MWD+IFR-AK-CAZ-SC 12084. 29 90. 25 324. 48 6904. 37 6855. 07 5663.17 -5544.29 6009570 .34 382690. 95 MWD+IFR-AK-CAZ-SC ', 12178. 84 90. 19 323. 21 6904. 01 6854. 71 5739.51 -5600.07 6009647 .50 382636. 32 MWD+IFR-AK-CAZ-SC 12273. 86 90. 25 323. 93 6903. 64 6854. 34 5815.96 -5656.50 6009724 .78 382581. 05 MWD+IFR-AK-CAZ-SC 12369. 55 89. 51 323. 88 6903. 84 6854. 54 5893.28 -5712.87 6009802 .93 382525. 85 MWD+IFR-AK-CAZ-SC 12464. 40 89. 38 322. 93 6904. 76 6855. 46 5969.43 -5769.41 6009879 .91 382470. 46 MWD+IFR-AK-CAZ-SC i Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 5!9/2006 Time: 14 :53:07 Page: 4 Field: Co lville River Unit Co-ordinate(NE) Re ference: Well: CD3-112, Tru e North , Site: Alpine CD3 Vertical (TVD) Refe rence: CD3- 112: 49.3 Weli: CD3-112 Section (VS) Refere nce: Well (O.OON,O.OOE,31$.64Azi) Wellpath: CD3-112 Survey Calculation Method: Minimum Curvature. Db: Oracle Survcv - _ ___ tiiD Incl Azim TVD Sys T~'D ~!S E/yy' i11apN ivlapE Tool ft deg deg ft ft ft ft ft ft 12559.80 90. 92 324. 19 6904. 51 6855. 21 6046.17 -5826.07 6009957 .49 382414.96 MWD+IFR-AK-CAZ-SC I 12654.90 90. 31 323. 84 6903. 49 6854. 19 6123.12 -5881.95 6010035 .25 382360.24 MWD+IFR-AK-CAZ-SC 12749.84 89. 94 323. 98 6903. 28 6853. 98 6199.84 -5937.87 6010112 .80 382305.48 MWD+IFR-AK-CAZ-SC 12845.15 89. 75 324. 54 6903. 54 6854. 24 6277.20 -5993.54 6010190 .98 382250.98 MWD+IFR-AK-CAZ-SC ', i 12940.44 89. 75 323. 88 6903 .96 6854. 66 6354.50 -6049.27 6010269 .09 382196.42 MWD+IFR-AK-CAZ-SC 13034.27 89. 20 324. 32 6904 .82 6855. 52 6430.50 -6104.29 6010345 .90 382142.56 MWD+IFR-AK-CAZ-SC 13130.89 90. 74 324. 96 6904 .87 6855. 57 6509.29 -6160.20 6010425 .52 382087.83 MWD+IFR-AK-CAZ-SC 13226.01 91. 42 325. 31 6903 .08 6853. 78 6587.33 -6214.56 6010504 .35 382034.65 MWD+IFR-AK-CAZ-SC 13321.22 90. 55 323. 10 6901 .44 6852. 14 6664.53 -6270.24 6010582 .38 381980.14 MWD+IFR-AK-CAZ-SC '; 13416.57 90. 86 321. 43 6900 .27 6850. 97 6739.93 -6328.59 6010658 .64 381922.93 MWD+IFR-AK-CAZ-SC ': 13511.46 90. 00 323. 38 6899 .55 6850. 25 6815.11 -6386.47 6010734 .67 381866.19 MWD+IFR-AK-CAZ-SC 13606.56 90. 37 323. 69 6899 .25 6849. 95 6891.59 -6442.99 6010811 .98 381810.82 MWD+IFR-AK-CAZ-SC ~ 13698.98 89. 57 323. 79 6899. 29 6849. 99 6966.11 -6497.66 6010887 .30 381757.29 MWD+IFR-AK-CAZ-SC 13795.24 90. 62 325. 68 6899. 14 6849. 84 7044.71 -6553.23 6010966 .71 381702.90 MWD+IFR-AK-CAZ-SC 13889.30 91. 73 325. 98 6897 .21 6847. 91 7122.51 -6606.05 6011045 .29 381651.26 MWD+IFR-AK-CAZ-SC 13985.86 90. 12 325. 32 6895. 65 6846. 35 7202.22 -6660.52 6011125 .80 381597.99 MWD+IFR-AK-CAZ-SC 14080.97 90. 68 322. 31 6894. 98 6845. 68 7278.97 -6716.66 6011203 .38 381543.01 MWD+IFR-AK-CAZ-SC 14174.31 90. 86 321. 57 6893. 73 6844. 43 7352.46 -6774.20 6011277 .71 381486.59 MWD+IFR-AK-CAZ-SC 14270.44 89. 26 321. 75 6893. 63 6844. 33 7427.85 -6833.83 6011353 .99 381428.10 MWD+IFR-AK-CAZ-SC ~ 14366.44 89. 88 325. 01 6894. 35 6845. 05 7504.89 -6891.09 6011431 .87 381372.01 MWD+IFR-AK-CAZ-SC ~ 14461.31 88. 70 327. 46 6895. 52 6846. 22 7583.74 -6943.81 6011511 .50 381320.48 MWD+IFR-AK-CAZ-SC I;~ 14556.51 89. 07 328. 18 6897. 38 6848. 08 7664.30 -6994.50 6011592 .80 381271.01 MWD+IFR-AK-CAZ-SC 14651.39 90. 86 329. 68 6897. 44 6848. 14 7745.57 -7043.46 6011674 .78 381223.27 MWD+IFR-AK-CAZ-SC 14746.74 90. 18 328. 57 6896. 57 6847. 27 7827.40 -7092.39 6011757 .33 381175.58 MWD+IFR-AK-CAZ-SC 14840.60 90. 12 327. 63 6896. 32 6847. 02 7907.08 -7141.99 6011837 .74 381127.18 MWD+IFR-AK-CAZ-SC 14937.78 89. 69 327. 83 6896. 49 6847. 19 7989.25 -7193.87 6011920 .67 381076.54 MWD+IFR-AK-CAZ-SC 15030.46 88. 95 327. 46 6897. 59 6848. 29 8067.54 -7243.47 6011999 .68 381028.13 MWD+IFR-AK-CAZ-SC II 15093.76 91. 23 327. 58 6897. 49 6848. 19 8120.93 -7277.46 6012053 .58 380994.95 MWD+IFR-AK-CAZ-SC i 15194.20 92. 34 326. 01 6894. 36 6845. 06 8204.93 -7332.43 6012138 .38 380941.24 MWD+IFR-AK-CAZ-SC 15288.99 91. 66 324. 51 6891. 05 6841. 75 8282.77 -7386.41 6012217 .02 380888.43 MWD+IFR-AK-CAZ-SC ~, 15384.42 90. 73 324. 12 6889. 06 6839. 76 8360.26 -7442.07 6012295. 33 380833.95 MWD+IFR-AK-CAZ-SC 15479.65 91. 29 324. 64 6887. 38 6838. 08 8437.66 -7497.52 6012373. 54 380779.67 MWD+IFR-AK-CAZ-SC 15572.11 88. 02 325. 57 6887. 94 6838. 64 8513.49 -7550.41 6012450. 14 380727.93 MWD+IFR-AK-CAZ-SC ; 15668.89 88. 45 325. 81 6890. 92 6841. 62 8593.39 -7604.93 6012530. 85 380674.61 MWD+IFR-AK-CAZ-SC 15762.22 83. 50 324. 18 6897. 47 6848. 17 8669.62 -7658.32 6012607. 87 380622.38 MWD+IFR-AK-CAZ-SC '; II 15858.35 80. 70 323. 16 6910. 68 6861. 38 8746.33 -7714.72 6012685. 40 380567.14 MWD+IFR-AK-CAZ-SC I ~, 15954.90 76. 73 322. 22 6929. 57 6880. 27 8821.62 -7772.09 6012761. 54 380510.90 MWD+IFR-AK-CAZ-SC j 15982.60 75. 22 321. 51 6936. 28 6886. 98 8842.76 -7788.69 6012782 .92 380494.63 MWD+IFR-AK-CAZ-SC 16021.00 75. 22 321. 51 6946. 08 6896. 78 8871.82 -7811.79 6012812 .32 • 380471.96 ~ PROJECTED to TD STATE OF ALASKA 1/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim ~~e~~;~r)adr~:in.state.ak.~~~~ Uaq~^~r~.Er#~ae br:~ ~~d:~n.state.Uk.~s bole €eckensten:~~adn:in.state.ak.i~~- Contractor: Doyon Rig No.: 19 DATE: 3/29/2006 Rig Rep.: Krupa/Welsh Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Lutrick/Mickey Field/Unit & Well No.: Colville Rv CD3-112 PTD # 206-032 Operation: Drlg: x Test: Initial: x Test Pressure:. Rams: 250!5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kilt Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Workover: Explor.: Weekly: Bi-Weekly Annular: 250/3500 Valves: 250/5000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test R P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P inside BOP 1 P Test Results CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 3000 P Pressure After Closure 1550 P 200 psi Attained 31 P Full Pressure Attained 2 min 30 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2050 psi Number of Failures: 0 Test Time: 5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ~ir:3 req~~; )~adrr:in.stUte.ak.us~ Remarks: Good test. No problems. 24 HOUR NOTICE GIVEN YES X NO Date 03/27/06 Time 8:OOam Test start 9:30pm Finish Waived By Jeff Jones Witness BOP Test (for rigs} BFL 11/09/04 Doyon19 3-29-06 CD3-112-1.xls ~ ~ ~ , "~ ~~ ~a ~ v r r a ~ ~ 1 ~ 4 t j. ~ j !S?~ ~~ ' ~ ~ ~ , ~~ i ~ '~ ~ ~:s + ~', °~, ;1 ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~+ oalL~-7~ Day ~ ~S 3~'~ 333 W. T" AVENUE, SUITE 100 CO1~T-7ERQA1'I011T CUMI~'I153IU1~T ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit, CD3-112 ConocoPhillips Alaska, Inc. Permit No: 206-032 Surface Location: 3950' FNL, 894' FEL, Sec. 5, T12N, RSE, UM Bottomhole Location: 22' FNL, 1027' FEL, Sec. 36, T13N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this Zb day of February, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 23, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-112 Dear Sir or Madam: • Car~aco hilli s ~~~~~~ FEB 2 4 2006 Alaska Oil ~ Cas ~cr~s. ~rx~missi~r! Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector~well from the Fiord CD3 drilling pad. The intended spud date for this well is 3/28/06 It is intended that Doyon Rig 19 be used to drill the well. CD3-112 will be a horizontal open hole injector in the Nechelik reservoir. CD3-112 will be pre-produced for an extended period of time next winter season, anywhere from 3-6 months.- The time will vary based on the reservoir pressure and the production results. The well will be completed with a surface controlled SSSV as is typically used on production wells. It is also requested that the packer placement requirement be relaxed to place the completion packer +/- 200 ft TVD above the Nechelik formation. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. A waiver for the diverter requirement is requested. This will be the 6th well on the Fiord pad and there has been no indication of gas or shallow gas hydrates. 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. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. 4. A proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. 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 is: 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. Riser setup If you have any questions or require further information, please contact Liz Galiunas at 265-6247, or Chip Alvord at 265-6120. ORI~IiVgL • ~ Sincerely, ~` Liz Galiu as Drilling Engineer Attachments cc: CD3-111 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Liz Galiunas ATO 1704 Vern Johnson ATO 1702 Jack Walker ATO 1740 Jordan Wiess ATO-1782 Lanston Chin Kuukpik Corporation STATE OF ALASKA ~~~EI V ~D A OIL AND GAS CONSERVATION COMMI~N ~ 246 ._ FEB 2 PERMIT TO DRILL ~/~~ 20 AAC 25.005 _,-_ ~:~ Q. r_~~ r„n~ Cnrrunission 1a. Type of Work: 1b. Current Well Class: Exploratory ^ Development Oil ^ 1c. Specify if wel r: Drill Q - Redrill ^ Stratigraphic Test ^ Service Q Development Gas ^ nn,,,,,,..~~,, Coalbed Methane ^ ~t~4~d~s ^ Re-entry ^ Multiple Zone ^ Single Zone Q Shale Gas ^ 2. Operator Name: 5. Bond: Blanket Q Single Well ^ 11. Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 59-52-,'698'• ~A, Zv.c ~ CD3-112 • 3. Address: 6. Proposed Depth: 12. field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16429. ND: 6887 c i le River Unit 4a. Location of Well (Governmental Section): 7. Property Designation: ~S~ ~~~Z Fiord Nechelik Pool ' Surface: 3950' FNL, 894' FEL, Sec 5, T12N, R5E, UM . ; ADL 372105, 36447T, §843'ISZ.Lc+ ~: Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 879' FNL, 4633' FEL Sec 5, T12N, R5E, UM LAS21122 3/28/2006 ' Total Depth: 9. Acres in Property: 14. Distance to N~ar est ~~ z 22' FNL, 1027 FEL Sec 36, T13N, R4E, UM ~ 2560 ~ Property Zil~e,'~69''i/RU boundary 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 388149 ' 6003824.8 ~ Zone- 4 Y- (Height above GL): 36.7 feet Within Po~l~ CD3-110 4169' at 11800' v fgX~t"3 -~', ~ 3 ~ i//` MD 11 z-~' 16. Deviated wells: Kickoff depth: 350 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90.7 - degrees Downhole: 3162 ' surface: 2429 ' 18. Casing Program: Specifications Top -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" 9.625" 40# L-80 BTC-Mod 2707 37 37 - 2744 ~ 2500 462 sx AS Lite & 230 LiteCrete 8.5" 7" 26# L-80 BTC-Mod 8891 37 37 ~ 8928 6989 242 sx 15.8 ppg G 6.125" 4.5" 12.6# L-80 IBT-Mod 8120 32 32 8152 6823 --~"~;,,,ji~y~~, ,.f:i'~ 2 ~~'-c: a~~ 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee Q BOP Sketch ^ Drilling Program Q Time v. Depth Plot ^ Shallow Hazard Analysis^ Property Plat ^ Diverter SketcF^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements^~ 21. Verbal Approval: Commission Representative: Date 2/22/2006 22. I hereby certify that the foregoing is true and correct. Contact L. Galiunas 265-6247 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature , ~ ~~ Phone 265-6120 Date 2/22/2006 • Commission Use Only Permit to Drill / Z~6 ~ b3 2 API Number: /~3" ~ OS Permit A proval ~ See cover letter for other Number: - 50- UQ Z Z~ 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 sh~~ .'" other: M iT" ~ (.CL~t+.~4V(~`.~~ ~0~, ~c ~~ +~~~~-~~ a'~ ~~~~ ~ Samples req'd: Yes^ No []'+ Mud log req'd: Ye~ No©f HZS measures: Yes^ No Q' Directional svy req'd: Ye~° No ^ ~~n ~ccc~ ~ ~ ~ ~L L ~c-1fi S t ~ "Q ~ ~~~ „ ^ ~ 2 ~~ y~~ C.~35~0 ~S<~ri~~ ,1-~~.~V{>Sl W"~\i~iMVi"~ ~ ~~'~' ~~\jQ~-lL~'vJG~a1~G' ~~~A C , per. c.,~cc,r~ ~ ~p$-h c~~~-c,.~~t~ ~v 4 ta,C~ ~ ,'-~So C~~ _ ~/ APPROVED BY THE COMMISSION ~ ~~ COMMISSIONER , DATE: Form 10-401 Revised 12/2005 Submit in Duplicate ~~ ': 4 r ~ CD3-112 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low ~ Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low , Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strat Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations ~ Check for flow during connections and if needed, >2000' ND increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low ~ HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips .Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low ~ HzS drills, detection systems, alarms, standard well ' control ractices, mud scaven ers OR161NAL Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. • 3. Drill 12 '/<" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 9-5/8" surface casing. 5. Install and test BOPE to 5000 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test.' 8. Pick up and run in hole with 8-3/4" drilling BHA: 9. Drill 8-3/4" hole to intermediate casing point in the Nechelik~reservoir sand. (LWD Program: GR/RES/PWD) 10. Run and cement 7" casing as per program. 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 casin . 11. BOPE test to 5000 psi. ~,~~~~~ ~v4~~~`r.. ~ ~ ~'1~C~ r ~ ~ ~~~~ 12. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). ~~~~ 13. Circulate the hole clean and pull out of hole. 14. Run 4-'/2, 12.6#, L-80 IBT-Mod tubing with BAL-O landing nipple, gas lift mandrel, packer XN nipple, and wireline entry guide. Land hanger. 15. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 16. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 17. Circulate tubing to diesel and install freeze protection in the annulus. 18. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 19. Set BPV and secure well. Move rig off. ORIGINAL • r Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-110 is the nearest existing well to the CD3-112 plan at 41' well to well separation at 323' MD. Including planned wells, CD3-113 is the closest with well to well separation of 21' at 601' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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: Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-112 will be injected into the permitted annulus CD3-109 or the class 2 disposal well on CD1 pad. The CD3-112 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1500' TVD. The only significant hydrocarbon zones are the Nechelik and Kuparuk reservoirs and there will be more than 500' of cement fill above the top of the Kuparuk as per regulations. Upon completion of CD3-112 form 10-403, Application for Sundry Operations -Annular Disposal, will 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. 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 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing Intermediate hole to 7" casing point - 8'/z" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 12 - 14 cc/30 min 160 8.5-9.0 9.0-10.0 9.0-9.5 PH 6 KCL Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Nechelik is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL • • CD3-112 Completion Schematic 16" Conductor to 114' ~ 2141'MD 4-1 /2" Camco SSSV: BAL-O w/ DB Profile -dual line (Min ID 3.812") 4-1/2" 12.6 ppf IBT M tubing run with Jet Lube Run'n'Seal pipe dope 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 2744' MD / 2500' TVD cemented to surface , Completion MD TVD Tubing Hanger 32' 32' 4 '/2" 12.6 #/ft IBT-Mod Tubing Camco BAL-O landing nipple (3.812" ID) 2141' 2000' 4-Yz" 12.6 #/ft IBT-Mod Tubing Camco KBG-2 GLM (3.833" ID) 7982' 6742' . _ _ 4-%:" tubing joints (2) /" Baker Premier Packer t 8082'792' 4-''/i' tubing 1 joint `~•. ----° HES XN 3.813" (3.725" NoGo)-64° inc 8142' 6819' 4-1/2" 10' pup joint WEG 8152' 6823' Camco KBG-2 GLM (3.833" DRIFT ID) w/ dummy TOC Isolated @ +/ 7680' MD / 6562' TVD (500'bode top Kuparuk C)~ \'~ Top Kuparuk C ~t 8180' M~ / 6835' TVD Top Nechelik at 8679' MD / 6974' TVD - 7" 26 ppf L-80 BTC Mod Casing @ 8928' / 6989' TVD @+/- 90° Well TD at i 16429' MD / i 6887' TVD ORIGINAL • • PRESSURE INFORMATION (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 Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2744 / 2500 14.5 1131 1635 7" 8928 / 6989 16.0 3162 2429 N/A 16429 / 6887 16.0 3116 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. 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 Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1131 - (0.1 x 2500') = 881 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2500 = 1635 psi OR ASP =FPP - (0.1 x D) = 3162 = (0.1 x 6989) = 2463 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3116 - (0.1 x 6887'} = 2427 psi ORIGINAL • • Cementing Program: 9 5/8" Surface Casing run to 2744' MD / 2500' TVD. Cement from 2744' MD to 2244' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2244' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1273' MD). Lead slurry: (2244'-1273') X 0.3132 ft3/ft X 1.5 (50% excess) = 456.2 ft3 below permafrost 1273' X 0.3132 ft3/ft X 4 (300% excess) = 1594.8 ft3 above permafrost Total volume = 456.2 + 1594.8 = 2051 ft3 => 462 Sx @ 4.45 ft3/sk System: 462 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8928' MD / 6989' TVD Cement from 8928' MD to 7680+/-' MD (minimum 500' MD above top of Kuparuk C reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (8928' -7680') X 0.1503 ft3/ft X 1.4 (40% excess) = 262.6 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 262.6 + 17.2 = 279.8 ft3 => 242 Sx @ 1.16 ft3/sk System: 242 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant, 0.07% B 155 retarder and 0.4% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ('~!GINAL i ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-112 Plan: CD3-112 Plan: GD3-112wp02 Proposal Report 22 February, 2006 ~~.~ :~perr~ riig er~-i+~+ ORIGINAL ~`{ "` Calwlation MM#gd: MinimunL~ahre Error System: ISCVJSA ~~ ( ~q~y~~~ F ~G L.V! Ni.V' 11 1.~.7 Sean Mettad: Trav. Cylialer North Colville River Unit l~laska Erta Swiace: EINPtical Cmic Werning Method: Rules Based C~eodea'c oahrm: NAD 1977 (NPDCON CONUB) Al pl ne CD3 '~°~~"~~ 005 Plan: CD3-112 CD3-112wp02 til~LLIBtJP~TC1!61I ~~~""~~~~~~~"""~-~~~"~"~~~~~~~~~~~"'-~~'~~~~~~~'~~~~~~~~~~~ Ground Level: 13.30 Plan: CD3-112 Spergrurt~~S~rvicus RKB: Planned Doyon l9 (d 49.60ft (Doyon l9 (36.3+13.3)) Northing(ASPY: 6003824.75 CD3-112wpO2 4 1/2" Tbg Hole 6 1/8" i ~ Target (Toe); 16429' MD, 6887' ND, 22' FNL & 1027' FEL; Sec36-T13N-R04E ' .-. 7500 . _..----.. _..__....-----......_.._......__.. --------._ ........._. c _ 0 0 N 5000 . -----.._ + _.. ..._.. .- _ 0 z i~ ~ i Target (Heel); 8927' MD, 6989' ND - .. ~ "Csg-83/4"Hole --- _ _ -- 2500 7" Csg Pt; 89 7' MD, 6989' TVD; 879' NL & 4633' FEL; Sec05- 12N-R05E ~ (n Continue Dir; 3.5 DLS, 22.91° TFO, 7241' D, 6232' TVD- - - Start Sail; 33.9° I C, 1769' MD, 1691' ND 9 5/8" Csg - 12 1 /4" Hole - -' 9-5/8" Csg Pt; 2743' MD, 2500' TVD Continue Dir, 2.5° DL , -22.5° TFO, 600' M0, 5 9' TVD - - - - _ _ _ - Kick-off Point; 2° DLS, 3 5° TFO, 350' MD, 350' - - - - - _ - -~ - - 0 - ~~.- - - - e -~ , zl~ats -12500 -10000 -7500 -5000 -2500 0 2500 West(-)/East(+) (2500 ft/in) 0 $HL; 3950' FNL & 894' FEL; Sec05-T12N-ROSE - - - -Kick-off Point; 2° DLS, 325° TFO, 350' MD, 350' ND ^ ~ 1 -- Continue Dir; 2.5° DLS, -22.5° TFO, 600' MD, 599' TVD Q Base Permafrost Start Sail; 33.9° INC, 1769' MD, 1691' TVD O ~ 9 5/8" Csg - 12 1 /4" Hole 2500 __ _ ____.. " ' ' ..... - - - 9-5/8 Csg Pt; 2743 TVD MD, 2500 a~ r -~ C-30 -- -- Q C-20 0 Target (Toe); 16429' MD, 6887 TVD, 22' FNL & 1027 FEL; Sec36-T13N-R04E U K-2 Basal ` :~ 5000 Continue Dir; 3.5° DLS, 22.91° TFO, 7241' MD, 6232' ND ` ' ~ , > ', ~ _._..._. .......................__...................... ` ...................._.._...._ _ ,' 7„ Csg - 8 3/4" Hole ~' ,~ ~ Albian 97 ... ' Alblan 96 _ _.. ~' 7" Csg Pt; 8927' MD, 6989' ND; 879' FNL & 4633' FEL; Sec05-T12N-R05E ~ 4 1/2" Tbg - 6 1/8" Open Hole - ` ,, \ ,, \ ___ -.. - .. ~ O ro _.O -.-__ __ 7500 Top Nechelik" ^ `° °i Target (Heel); 8927' MD,6989' TVD o w 0 2500 5000 7500 10000 N 0 500 N • • Sperry Drilling Services . ' ' ~~~~~~~~ ~~~ ~C~t ~t)Ct~ 11~~1~35 p~ Planning Report -Geographic -- ----- - ---~ Alaska Sperry DritEtng Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-112 Company: ~onocoPhillips Alaska Inc. ND Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3}} Project: Colville River Unit MD Reference: ' ' Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 North Reference: i '-True Well: Plan: CD3-112 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-112 Design: CD3-112wp02 •oject Colville River Unit, North Slope Alaska, United States ap System: US State Plane 1927 (Exact solution)' System Datum: Mean Sea Level eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ap Zone: Alaska Zone 04 Using geodetic scale factor Weil Plan: CD3-112 Welt Position +N/-S 0.00 ft Northing: 6,003,824.75 ft Latitude: 70° 25' 09.821" N +E/-W 0.00 ft Easting: 388,149.36 ft ' Longitude: 150° 54' 40.296" W Position Uncertai nty 0.00 ft Wellhead E levation: ft Ground Level: 13.30ft Wellhore i Plan: CD3-112 Magnetics Model Name Sampie Date Declination Dip Angle Field Strength BGGM2005 2/22/2006 23.51 80.72 57,512 Design CD3-112wp02 -~ - - - - - - Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (TVD} +NI-S +E/-W Direction (ft) (ft) (ft) (~~ 36.30 0.00 0.00 ?4 00 Plan Summary Measured Vertical Dogleg Build Turn Deptfi In clination Azimuth Depth +N/-S +FJ-W Rate Rate Rate TFO (ft) (°) (°) (ft) lft) lft) (°/100ft) (°1100ft) (°1100ft) (`) 36.30 0.00 0,00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 5.00 325.00 599.68 8.93 -6.25 2.00 2.00 0.00 325.00 1,769.21 33.90 305.43 1,691.07 244.84 -307.71 2.50 2.47 -1.67 -22.49 7,241.00 33.90 305.43 6,232.77 2,014.17 -2,794.25 0.00 0.00 0.00 0.00 8,927.96 90.78 324.94 6,989.60 3,072.66 -3,747.96 3.50 3.37 1.16 22.91 16,429.49 90.78 324.94 6,887.60 9,212.52 -8,056.63 0.00 0.00 0.00 0.00 222/2006 2:20:48PM Page 2 of 8 COMPASS 2003.11 Build 50 ~~~ ~r~~cphili~s F1i3ska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-112 Wellbore: Plan: CD3-112 Design: CD3-112wp02 Planned Survey __ _ __ CD3-112wp02 Sperry Drilling Services Planning Report -Geographic Local Go-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: MD lnciination Azimuth TVD SSTVD +N/-S (ftl (°) l°) lft} (ft) lft) 36.30 0.00 0.00 36.30 -13.30 0.00 SHL; 3950' FNL $, 894' FEL; Sec05-T72N-R05E 100.00 0.00 0.00 100.00 50.40 0.00 200.00 0.00 0.00 200.00 150.40 0.00 350.00 0.00 0.00 350.00 300.40 0.00 Kick-off Point; 2° DLS , 325° TFO, 350' MD, 350' TVD 400.00 1.00 325.00 400.00 350.40 0.36 500.00 3.00 325.00 499.93 450.33 3.22 600.00 5.00 325.00 599.68 550.08 8.93 Continue Dir; 2.5° DLS, -22.5° TFO, 600' MD, 599' TVD 700.00 7.37 317.53 699.10 649.50 17.23 800.00 9.81 313.71 797.97 748.37 27.85 900.00 12.27 311.41 896.11 846.51 40.77 1,000.00 14.74 309.87 993.34 943.74 55.96 1,100.00 17.22 308.77 1,089.46 1,039.86 73.39 1,200.00 19.71 307.93 1,184.31 1,134.71 93.03 1,269.75 21.45 307.46 1,249.60 1,200.00 108.01 Base Permafrost 1,300.00 22.20 307.28 1,277.69 1,228.09 114.84 1,400.00 24.69 306.75 1,369.42 1,319.82 138.78 1,500.00 27.18 306.31 1,459.34 1,409.74 164.81 1,600.00 29.68 305.94 1,547.28 1,497.68 192.87 1,700.00 32.17 305.63 1,633.05 1,583.45 222.92 1,769.21 33.90 305.43 1,691.07 1,641.47 244.84 Start Sail; 33.9° INC, 1 769' MD, 1691' TVD 1,800.00 33.90 305.43 1,716.63 1,667.03 254.80 1,900.00 33.90 305.43 1,799.63 1,750.03 287.13 2,000.00 33.90 305.43 1,882.63 1,833.03 319.47 2,100.00 33.90 305.43 1,965.63 1,916.03 351.80 2,200.00 33.90 305.43 2,048.64 1,999.04 384.14 2,300.00 33.90 305.43 2,131.64 2,082.04 416.48 2,400.00 33.90 305.43 2,214.64 2,165.04 448.81 2,500.00 33.90 305.43 2,297.64 2,248.04 481.15 2,550.55 33.90 305.43 2,339.60 2,290.00 497.49 C-40 2,600.00 33.90 305.43 2,380.64 2,331.04 513.48 2,700.00 33.90 305.43 2,463.65 2,414.05 545.82 2,740.91 33.90 305.43 2,497.60 2,448.00 559.04 C-30 2,743.80 33.90 305.43 2,500.00 2,450.40 559.98 9-5/8" Csg Pt; 2743' MD, 2500' ND - 9 5/8" Csg -121/4" Hole 2,800.00 33.90 305.43 2,546.65 2,497.05 578.15 2,900.00 33.90 305.43 2,629.65 2,580.05 610.49 3,000.00 33.90 305.43 2,712.65 2,663.05 642.82 3,100.00 33.90 305.43 2,795.65 2,746.05 675.16 3.200.00 33.90 305.43 2.878.66 2,829.06 707.50 ~~141~I~~~A~I~N .Sperry Drilling Services Well Plan: CD3-112 Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) True Minimum Curvature Map Map +E1_W Northing Easting DLSEV Vert Section (ft} (ft) (ft) (°l100ft} (ftl 0.00 6,003,824.75 388,149.36 0.00 0.00 0.00 6,003,824.75 388,149.36 0.00 0.00 0.00 6,003,824.75 388,149.36 0.00 0.00 0.00 6,003,824.75 388,149.36 0.00 0.00 -0.25 6,003,825.12 388,149.12 2.00 0.44 -2.25 6,003,828.00 388,147.16 2.00 3.93 -6.25 6,003,833.78 388,143.24 2.00 10.90 -13.09 6,003,842.18 388,136.54 2.50 21.63 -23.57 6,003,852.95 388,126.21 2.50 36.39 -37.70 6,003,866.08 388,112.28 2.50 55.14 -55.44 6,003,881.53 388,094.77 2.50 77.86 -76.75 6,003,899.28 388,073.72 2.50 104.48 -101.60 6,003,919.28 388,049.17 2.50 134.98 -121.00 6,003,934.56 388,030.00 2.50 158.51 -129.94 6,003,941.52 388,021.17 2.50 169.28 -161.71 6,003,965.93 387,989.76 2.50 207.33 -196.86 6,003,992.48 387,955.01 2.50 249.04 -235.31 6,004,021.11 387,916.98 2.50 294.35 -277.00 6,004,051.78 387,875.75 2.50 343.16 -307.71 6,004,074.16 387,845.38 2.50 378.95 -321.70 6,004,084.32 387,831.54 0.00 395.23 -367.14 6,004,117.33 387,786.59 0.00 448.10 -412.58 6,004,150.34 387,741.64 0.00 500.97 -458.03 6,004,183.35 387,696.69 0.00 553.84 -503.47 6,004,216.36 387,651.75 0.00 606.71 -548.91 6,004,249.37 387,606.80 0.00 659.58 -594.36 6,004,282.38 387,561.85 0.00 712.45 -639.80 6,004,315.39 387,516.90 0.00 765.32 -662.77 6,004,332.08 387,494.17 0.00 792.05 -685.24 6,004,348.40 387,471.95 0.00 818.19 -730.69 6,004,381.41 387,427.00 0.00 871.06 -749.28 6,004,394.91 387,408.61 0.00 892.69 -750.59 6,004,395.87 387,407.31 0.00 894.22 -776.13 6,004,414.42 387,382.05 0.00 923.93 -821.57 6,004,447.43 387,337.10 0.00 976.80 -867.02 6,004,480.44 387,292.15 0.00 1,029.67 -912.46 6,004,513.45 387,247.20 0.00 1,082.55 -957.90 6,004,546.46 387,202.25 0.00 1,135.42 2222006 2:20:48PM Page 3 of 8 COMPASS 2003.11 Build 50 ORfGINAL C~ CCC~Ph~tips Alaska • Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: `Colville River Unit Site• Alpine CD3 Well: Plan: CD3-112 Wellbore: Plan: CD3-112 Design; CD3-112vdp02 Planned Survey CD3-112wp02 MD {ft) 3,207.16 C-20 3,300.00 3,400.00 3,500.00 3,600.00 3,700.00 3,800.00 3,900.00 4,000.00 4,100.00 4,200.00 4,300.00 4,400.00 4,430.02 K-3 4,500.00 4,600.00 4,607.13 K-3 Basal 4,644.47 K-2 4,700.00 4,770.98 K-2 Basal 4,800.00 4,900.00 5,000.00 5,100.00 5,200.00 5,300.00 5,400.00 5,500.00 5,600.00 5,700.00 5,800.00 5,900.00 6,000.00 6,100.00 6,200.00 6,300.00 6,400.00 6,500.00 6,600.00 6,616.71 Albian 97 6,700.00 Inclination Azimuth ND 33.90 305.43 2,884.60 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: :J ~L~t~~~-~-~nd ____ _ Sperry Dr'slling Services Well Plan: CD3-112 Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) True Minimum Curvature Map Map SSTVD +N/-S +E/-yV Northing Easting DLSEV Vert Section Ift) 1ft) {ft) (ft) (ft) {°/100ft) (ftl 2,835.00 709.81 -961.15 6,004,548.82 387,199.03 0.00 1,139.20 33.90 305.43 2,961.66 2,912.06 739.83 -1,003.34 6,004,579.47 387,157.30 0.00 1,188.29 33.90 305.43 3,044.66 2,995.06 772.17 -1,048.79 6,004,612.48 387,112.35 0.00 1,241.16 33.90 305.43 3,127.66 3,078.06 804.50 -1,094.23 6,004,645.49 387,067.40 0.00 1,294.03 33.90 305.43 3,210.67 3,161.07 836.84 -1,139.67 6,004,678.50 387,022.45 0.00 1,346.90 33.90 305.43 3,293.67 3,244.07 869.17 -1,185.12 6,004,711.51 386,977.50 0.00 1,399.77 33.90 305.43 3,376.67 3,327.07 901.51 -1,230.56 6,004,744.52 386,932.55 0.00 1,452.64 33.90 305.43 3,459.67 3,410.07 933.84 -1,276.00 6,004,777.53 386,887.60 0.00 1,505.51 33.90 305.43 3,542.67 3,493.07 966.18 -1,321.45 6,004,810.54 386,842.65 0.00 1,558.38 33.90 305.43 3,625.68 3,576.08 998.52 -1,366.89 6,004,843.55 386,797.70 0.00 1,611.25 33.90 305.43 3,708.68 3,659.08 1,030.85 -1,412.33 6,004,876.56 386,752.75 0.00 1,664.12 33.90 305.43 3,791.68 3,742.08 1,063.19 -1,457.77 6,004,909.57 386,707.80 0.00 1,716.99 33.90 305.43 3,874.68 3,825.08 1,095.52 -1,503.22 6,004,942.58 386,662.85 0.00 1,769.86 33.90 305.43 3,899.60 3,850.00 1,105.23 -1,516.86 6,004,952.49 386,649.36 0.00 1,785.74 33.90 305.43 3,957.68 3,908.08 1,127.86 -1,548.66 6,004,975.59 386,617.91 0.00 1,822.74 33.90 305.43 4,040.69 3,991.09 1,160.19 -1,594.10 6,005,008.60 386,572.96 0.00 1,875.61 33.90 305.43 4,046.60 3,997.00 1,162.50 -1,597.34 6,005,010.95 386,569.75 0.00 1,879.37 33.90 305.43 4,077.60 4,028.00 1,174.57 -1,614.31 6,005,023.28 386,552.96 0.00 1,899.12 33.90 305.43 4,123.69 4,074.09 1,192.53 -1,639.55 6,005,041.61 386,528.01 0.00 1,928.48 33.90 305.43 4,182.60 4,133.00 1,215.48 -1,671.80 6,005,065.04 386,496.10 0.00 1,966.00 33.90 305.43 4,206.69 4,157.09 1,224.86 -1,684.99 6,005,074.62 386,483.06 0.00 1,981.35 33.90 305.43 4,289.69 4,240.09 1,257.20 -1,730.43 6,005,107.63 386,438.11 0.00 2,034.22 33.90 305.43 4,372.69 4,323.09 1,289.53 -1,775.88 6,005,140.64 386,393.16 0.00 2,087.09 33.90 305.43 4,455.70 4,406.10 1,321.87 -1,821.32 6,005,173.65 386,348.21 0.00 2,139.96 33.90 305.43 4,538.70 4,489.10 1,354.21 -1,866.76 6,005,206.66 386,303.26 0.00 2,192.83 33.90 305.43 4,621.70 4,572.10 1,386.54 -1,912.20 6,005,239.67 386,258.31 0.00 2,245,70 33.90 305.43 4,704.70 4,655.10 1,418.88 -1,957.65 6,005,272.68 386,213.36 0.00 2,298.57 33.90 305.43 4,787.70 4,738.10 1,451.21 -2,003.09 6,005,305.69 386,168.41 0.00 2,351.44 33.90 305.43 4,870.71 4,821.11 1,483.55 -2,048.53 6,005,338.70 386,123.46 0.00 2,404.31 33.90 305.43 4,953.71 4,904.11 1,515.88 -2,093.98 6,005,371.71 386,078.51 0.00 2,457.18 33.90 305.43 5,036.71 4,987.11 1,548.22 -2,139.42 6,005,404.72 386,033.56 0.00 2,510.06 33.90 305.43 5,119.71 5,070.11 1,580.55 -2,184.86 6,005,437.73 385,988.61 0.00 2,562.93 33.90 305.43 5,202.72 5,153.12 1,612.89 -2,230.31 6,005,470.74 385,943.66 0.00 2,615.80 33.90 305.43 5,285.72 5,236.12 1,645.23 -2,275.75 6,005,503.75 385,898.71 0.00 2,668.67 33.90 305.43 5,368.72 5,319.12 1,677.56 -2,321.19 6,005,536.76 385,853.76 0.00 2,721.54 33.90 305.43 5,451.72 5,402.12 1,709.90 -2,366.63 6,005,569.77 385,808.81 0.00 2,774.41 33.90 305.43 5,534.72 5,485.12 1,742.23 -2,412.08 6,005,602.78 385,763.86 0.00 2,827.28 33.90 305.43 5,617.73 5,568.13 1,774.57 -2,457.52 6,005,635.79 385,718.91 0.00 2,880.15 33.90 305.43 5,700.73 5,651.13 1,806.90 -2,502.96 6,005,668.80 385,673.96 0.00 2,933.02 33.90 305.43 5,714.60 5,665.00 1,812.31 -2,510.56 6,005,674.32 385,666.45 0.00 2,941.86 33.90 305.43 5,783.73 5,734.13 1,839.24 -2,548.41 6,005,701.81 385,629.01 0.00 2,985.89 222/2006 2:20:48PM Page 4 of 8 COMPASS 2003.11 Build 50 ORIGINAL Sperry Drilling Services ~.~ Cc»COF'h111pS Planning Report -Geographic p}~ SAsrrJ- ttrilfi;eg Sr~rvices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-112 Company: ConocoPhillips Alaska Inc. ND Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 North Reference: True Well: Plan: CD3-112 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-112 Design: CD3-112vrp02 Planned Survey CD3-112wp02 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section j Ift) E°) j°) (ft) (ftl jft) (ft) jft) Zft) (°I100ft) (ft) I 6,800.00 33.90 305.43 5,866.73 5,817.13 1,871.57 -2,593.85 6,005,734.82 385,584.07 0.00 3,038.76 6,900.00 33.90 305.43 5,949.73 5,900.13 1,903.91 -2,639.29 6,005,767.83 385,539.12 0.00 3,091.63 6,923.93 33.90 305.43 5,969.60 5,920.00 1,911.65 -2,650.17 6,005,775.73 385,528.36 0.00 3,104.29 Albian 96 7,000.00 33.90 305.43 6,032.74 5,983.14 1,936.25 -2,684.74 6,005,800.84 385,494.17 0.00 3,144.50 7,100.00 33.90 305.43 6,115.74 6,066.14 1,968.58 -2,730.18 6,005,833.85 385,449.22 0.00 3,197.37 7,200.00 33.90 305.43 6,198.74 6,149.14 2,000.92 -2,775.62 6,005,866.86 385,404.27 0.00 3,250.25 7,241.00 33.90 305.43 6,232.77 6,183.17 2,014.17 -2,794.25 6,005,880.39 385,385.84 0.00 3,271.92 Continue Dir; 3.5° DLS, 22.91° TF O, 7241' MD, 6232' TVD 7,300.00 35.81 306.81 6,281.19 6,231.59 2,034.06 -2,821.48 6,005,900.68 385,358.91 3.50 3,304.01 7,400.00 39.08 308.87 6,360.57 6,310.97 2,071.37 -2,869.46 6,005,938.71 385,311.50 3.50 3,362.40 7,500.00 42.38 310.66 6,436.35 6,386.75 2,113.12 -2,919.58 6,005,981.20 385,262.02 3.50 3,425.64 7,600.00 45.70 312.23 6,508.22 6,458.62 2,159.15 -2,971.66 6,006,027.99 385,210.64 3.50 3,493.49 7,675.28 48.22 313.30 6,559.60 6,510.00 2,196.51 -3,012.04 6,006,065.96 385,170.82 3.50 3,547.45 Top HRZ 7,700.00 49.05 313.64 6,575.94 6,526.34 2,209.27 -3,025.51 6,006,078.92 385,157.55 3.50 3,565.69 7,800.00 52.40 314.90 6,639.23 6,589.63 2,263.32 -3,080.91 6,006,133.78 385,102.97 3.50 3,641.98 7,900.00 55.78 316.06 6,697.87 6,648.27 2,321.07 -3,137.68 6,006,192.38 385,047.08 3.50 3,722.07 7,917.43 56.37 316.26 6,707.60 6,658.00 2,331.50 -3,147.69 6,006,202.95 385,037.22 3.51 3,736.39 Base HRZ 8,000.00 59.16 317.13 6,751.64 6,702.04 2,382.33 -3,195.59 6,006,254.49 384,990.10 3.50 3,805.66 8,001.87 59.22 317.15 6,752.60 6,703.00 2,383.51 -3,196.68 6,006,255.68 384,989.03 3.56 3,807.26 K-1 8,087.64 62.13 318.01 6,794.60 6,745.00 2,438.71 -3,247.10 6,006,311.63 384,939.44 3.50 3,881.56 Top Kuparuk D 8,100.00 62.55 318.13 6,800.34 6,750.74 2,446.86 -3,254.42 6,006,319.89 384,932.24 3.49 3,892.45 8,180.19 65.27 318.89 6,835.60 6,786.00 2,500.80 -3,302.12 6,006,374.53 384,885.36 3.50 3,964.13 Top Kuparuk C 8,189.81 65.60 318.98 6,839.60 6,790.00 2,507.40 -3,307.87 6,006,381.21 384,879.71 3.50 3,972.85 LCU -Top Nu iqsut 8,200.00 65.95 319.07 6,843.78 6,794.18 2,514.41 -3,313.97 6,006,388.32 384,873.72 3.49 3,982.11 8,300.00 69.35 319.96 6,881.81 6,832.21 2,584.75 -3,374.00 6,006,459.54 384,814.75 3.50 4,074.29 8,349.55 71.04 320.38 6,898.60 6,849.00 2,620.55 -3,403.86 6,006,495.79 384,785.44 3.50 4,120.81 Base Nuiqsut 8,400.00 72.75 320.81 6,914.28 6,864.68 2,657.60 -3,434.30 6,006,533.28 384,755.56 3.50 4,168.67 8,500.00 76.16 321.63 6,941.06 6,891.46 2,732.70 -3,494.63 6,006,609.27 384,696.37 3.50 4,264.89 8,600.00 79.58. 322.42 6,962.07 6,912.47 2,809.75 -3,554.78 6,006,687.21 384,637.39 3.50 4,362.58 8,679.52 82.29 323.04 6,974.60 6,925.00 2,872.24 -3,602.32 6,006,750.40 384,590.79 3.50. 4,441.08 Top Nechelik 8,700.00 82.99 323.20 6,977.22 6,927.62 2,888.49 -3,614.51 6,006,766.82 384,578.84 3.49 4,461.39 8,800.00 86.41 323.97 6,986.46 6,936.86 2,968.60 -3,673.61 6,006,847.81 384,520.95 3.50 4,560.95 8,900.00 89.82 324.73 6,989.75 6,940.15 3,049.81 -3,731.86 6,006,929.87 384,463.94 3.50 4,660.87 8,927.96 90.78 324.94 6,989.60 6,940.00 3,072.66 -3,747.96 6,006,952.96 384,448.18 3.50 4,688.83 7" Csg Pt; 8927' MD, 6989' TVD; 879' FNL & 4633' FEL; Sec05-T12N-R05E -Target (Heel); 8927' MD, 6989' TVD - 7" Csh - 8 3/4" Hole -CD3-1 222/2006 2:20:48PM Page 5 of 8 COMPASS 2003.11 Build 50 ^R161NAL • ~~~ Phillips. Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-112 Wellbore: Plan: CD3-112 Design: CD3-112wp02 • Sperry Drilling Services ~~~~~~~~-~-~ Planning Report -Geographic Sperry Drii~fing $~ local Co-ordinate Reference: Well Plan: CD3-112 ND Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey CD3-112wp02 Map Map MD Inclination Azimuth ND SSTVD +N/-S +E(.yy Northing Easting DLSEV Vert Section 9,000.00 90.78 324.94 6,988.62 6,939.02 3,131.63 -3,789.34 6,007,012.53 384,407.69 0.00 4,760.85 9,100.00 90.78 324.94 6,987.26 6,937.66 3,213.47 -3,846.77 6,007,095.22 384,351.49 0.00 4,860.83 9,200.00 90.78 324.94 6,985.90 6,936.30 3,295.32 -3,904.21 6,007,177.92 384,295.29 0.00 4,960.81 9,300.00 90.78 324.94 6,984.54 6,934.94 3,377.17 -3,961.65 6,007,260.61 384,239.09 0.00 5,060.79 9,400.00 90.78 324.94 6,983.18 6,933.58 3,459.02 -4,019.09 6,007,343.30 384,182.90 0.00 5,160.76 9,500.00 90.78 324.94 6,981.82 6,932.22 3,540.87 -4,076.52 6,007,425.99 384,126.70 0.00 5,260.74 9,600.00 90.78 324.94 6,980.46 6,930.86 3,622.71 -4,133.96 6,007,508.69 384,070.50 0.00 5,360.72 9,700.00 90.78 324.94 6,979.10 6,929.50 3,704.56 -4,191.40 6,007,591.38 384,014.30 0.00 5,460.70 9,800.00 90.78 324.94 6,977.74 6,928.14 3,786.41 -4,248.83 6,007,674.07 383,958.10 0.00 5,560.67 9,900.00 90.78 324.94 6,976.38 6,926.78 3,868.26 -4,306.27 6,007,756.76 383,901.90 0.00 5,660.65 10,000.00 90.78 324.94 6,975.02 6,925.42 3,950.11 -4,363.71 6,007,839.46 383,845.70 0.00 5,760.63 10,100.00 90.78 324.94 6,973.66 6,924.06 4,031.95 -4,421.15 6,007,922.15 383,789.50 0.00 5,860.60 10,200.00 90.78 324.94 6,972.30 6,922.70 4,113.80 -4,478.58 6,008,004.84 383,733.30 0.00 5,960.58 10,300.00 90.78 324.94 6,970.94 6,921.34 4,195.65 -4,536.02 6,008,087.53 383,677.10 0.00 6,060.56 10,400.00 90.78 324.94 6,969.58 6,919.98 4,277.50 -4,593.46 6,008,170.23 383,620.90 0.00 6,160.54 10,500.00 90.78 324.94 6,968.22 6,918.62 4,359.35 -4,650.89 6,008,252.92 383,564.70 0.00 6,260.51 10,600.00 90.78 324.94 6,966.86 6,917.26 4,441.20 -4,708.33 6,008,335.61 383,508.50 0.00 6,360.49 10,700.00 90.78 324.94 6,965.51 6,915.91 4,523.04 -4,765.77 6,008,418.30 383,452.30 0.00 6,460.47 10,800.00 90.78 324.94 6,964.15 6,914.55 4,604.89 -4,823.21 6,008,501.00 383,396.10 0.00 6,560.45 10,900.00 90.78 324.94 6,962.79 6,913.19 4,686.74 -4,880.64 6,008,583.69 383,339.90 0.00 6,660.42 11,000.00 90.78 324.94 6,961.43 6,911.83 4,768.59 -4,938.08 6,008,666.38 383,283.70 0.00 6,760.40 11,100.00 90.78 324.94 6,960.07 6,910.47 4,850.44 -4,995.52 6,008,749.07 383,227.50 0.00 6,860.38 11,200.00 90.78 324.94 6,958.71 6,909.11 4,932.28 -5,052.96 6,008,831.77 383,171.30 0.00 6,960.35 11,300.00 90.78 324.94 6,957.35 6,907.75 5,014.13 -5,110.39 6,008,914.46 383,115.10 0.00 7,060.33 11,400.00 90.78 324.94 6,955.99 6,906.39 5,095.98 -5,167.83 6,008,997.15 383,058.90 0.00 7,160.31 11,500.00 90.78 324.94 6,954.63 6,905.03 5,177.83 -5,225.27 6,009,079.84 383,002.70 0.00 7,260.29 11,600.00 90.78 324.94 6,953.27 6,903.67 5,259.68 -5,282.70 6,009,162.54 382,946.50 0.00 7,360.26 11,700.00 90.78 324.94 6,951.91 6,902.31 5,341.52 -5,340.14 6,009,245.23 382,890.30 0.00 7,460.24 11,800.00 90.78 324.94 6,950.55 6,900.95 5,423.37 -5,397.58 6,009,327.92 382,834.11 0.00 7,560.22 11,900.00 90.78 324.94 6,949.19 6,899.59 5,505.22 -5,455.02 6,009,410.61 382,777.91 0.00 7,660.20 12,000.00 90.78 324.94 6,947.83 6,898.23 5,587.07 -5,512.45 6,009,493.31 382,721.71 0.00 7,760.17 12,100.00 90.78 324.94 6,946.47 6,896.87 5,668.92 -5,569.89 6,009,576.00 382,665.51 0.00 7,860.15 12,200.00 90.78 324.94 6,945.11 6,895.51 5,750.77 -5,627.33 6,009,658.69 382,609.31 0.00 7,960.13 12,300.00 90.78 324.94 6,943.75 6,894.15 5,832.61 -5,684.77 6,009,741.38 382,553.11 0.00 8,060.10 12,400.00 90.78 324.94 6,942.39 6,892.79 5,914.46 -5,742.20 6,009,824.08 382,496.91 0.00 8,160.08 12,500.00 90.78 324.94 6,941.03 6,891.43 5,996.31 -5,799.64 6,009,906.77 382,440.71 0.00 8,260.06 12,600.00 90.78 324.94 6,939.67 6,890.07 6,078.16 -5,857.08 6,009,989.46 382,384.51 0.00 8,360.04 12,700.00 90.78 324.94 6,938.31 6,888.71 6,160.01 -5,914.51 6,010,072.15 382,328.31 0.00 8,460.01 12,800.00 90.78 324.94 6,936.95 6,887.35 6,241.85 -5,971.95 6,010,154.84 382,272.11 0.00 8,559.99 12,900.00 90.78 324.94 6,935.59 6,885.99 6,323.70 -6,029.39 6,010,237.54 382,215.91 0.00 8,659.97 13,000.00 90.78 324.94 6,934.23 6,884.63 6,405.55 -6,086.83 6,010,320.23 382,159.71 0.00 8,759.95 13,100.00 90.78 324.94 6,932.87 6,883.27 6,487.40 -6,144.26 6,010,402.92 382,103.51 0.00 8,859.92 13,200.00 90.78 324.94 6,931.51 6,881.91 6,569.25 -6,201.70 6,010,485.61 382,047.31 0.00 8,959.90 13,300.00 90.78 324.94 6,930.15 6,880.55 6,651.09 -6,259.14 6,010,568.31 381,991.11 0.00 9,059.88 13,400.00 90.78 324.94 6,928.79 6,879.19 6,732.94 -6,316.57 6,010,651.00 381,934.91 0.00 9,159.85 13,500.00 90.78 324.94 6,927.43 6,877.83 6,814.79 -6,374.01 6,010,733.69 381,878.71 0.00 9,259.83 13,600.00 90.78 324.94 6,926.07 6,876.47 6,896.64 -6,431.45 6,010,816.38 381,822.51 0.00 9,359.81 13,700.00 90.78 324.94 6,924.71 6,875.11 6,978.49 -6,488.89 6,010,899.08 381,766.31 0.00 9,459.79 13,800.00 90.78 324.94 6,923.35 6,873.75 7,060.34 -6,546.32 6,010,981.77 381,710.11 0.00 9,559.76 13,900.00 90.78 324.94 6,921.99 6,872.39 7,142.18 -6,603.76 6,011,064.46 381,653.91 0.00 9,659.74 14,000.00 90.78 324.94 6,920.63 6,871.03 7,224.03 -6,661.20 6,011,147.15 381,597.71 0.00 9,759.72 222/2006 2:20:48PM Page 6 of 8 COMPASS 2003.11 Build 50 • • Sperry Drilling Services ~~~~~~~~~~ ~!~~~ ~~~~~ Planning Report - GeograpFlic ~ ~ Serv Alaska ~~ ~ "~~ ices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-112 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 North Reference: 'True Well: Plan: CD3-112 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-112 Design: CD3-112wp02 Planned Survey CD3-112wp02 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section {ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ("1100ft} (ft) 14,100.00 90.78 324.94 6,919.27 6,869.67 7,305.88 -6,718.64 6,011,229.85 381,541.51 0.00 9,859.70 14,200.00 90.78 324.94 6,917.91 6,868.31 7,387.73 -6,776.07 6,011,312.54 381,485.31 0.00 9,959.67 14,300.00 90.78 324.94 6,916.56 6,866.96 7,469.58 -6,833.51. 6,011,395.23 381,429.12 0.00 10,059.65 14,400.00 90.78 324.94 6,915.20 6,865.60 7,551.42 -6,890.95 6,011,477.92 381,372.92 0.00 10,159.63 14,500.00 90.78 324.94 6,913.84 6,864.24 7,633.27 -6,948.38 6,011,560.62 381,316.72 0.00 10,259.60 14,600.00 90.78 324.94 6,912.48 6,862.88 7,715.12 -7,005.82 6,011,643.31 381,260.52 0.00 10,359.58 14,700.00 90.78 324.94 6,911.12 6,861.52 7,796.97 -7,063.26 6,011,726.00 381,204.32 0.00 10,459.56 14,800.00 90.78 324.94 6,909.76 6,860.16 7,878.82 -7,120.70 6,011,808.69 381,148.12 0.00 10,559.54 14,900.00 90.78 324.94 6,908.40 6,858.80 7,960.66 -7,178.13 6,011,891.39 381,091.92 0.00 10,659.51 15,000.00 90.78 324.94 6,907.04 6,857.44 8,042.51 -7,235.57 6,011,974.08 381,035.72 0.00 10,759.49 15,100.00 90.78 324.94 6,905.68 6,856.08 8,124.36 -7,293.01 6,012,056.77 380,979.52 0.00 10,859.47 15,200.00 90.78 324.94 6,904.32 6,854.72 8,206.21 -7,350.44 6,012,139.46 380,923.32 0.00 10,959.45 15,300.00 90.78 324.94 6,902.96 6,853.36 8,288.06 -7,407.88 6,012,222.16 380,867.12 0.00 11,059.42 15,400.00 90.78 324.94 6,901.60 6,852.00 8,369.91 -7,465.32 6,012,304.85 380,810.92 0.00 11,159.40 15,500.00 90.78 324.94 6,900.24 6,850.64 8,451.75 -7,522.76 6,012,387.54 380,754.72 0.00 11,259.38 15,600.00 90.78 324.94 6,898.88 6,849.28 8,533.60 -7,580.19 6,012,470.23 380,698.52 0.00 11,359.35 15,700.00 90.78 324.94 6,897.52 6,847.92 8,615.45 -7,637.63 6,012,552.93 380,642.32 0.00 11,459.33 15,800.00 90.78 324.94 6,896.16 6,846.56 8,697.30 -7,695.07 6,012,635.62 380,586.12 0.00 11,559.31 15,900.00 90.78 324.94 6,894.80 6,845.20 8,779.15 -7,752.51 6,012,718.31 380,529.92 0.00 11,659.29 16,000.00 90.78 324.94 6,893.44 6,843.84 8,860.99 -7,809.94 6,012,801.00 380,473.72 0.00 11,759.26 16,100.00 90.78 324.94 6,892.08 6,842.48 8,942.84 -7,867.38 6,012,883.70 380,417.52 0.00 11,859.24 16,200.00 90.78 324.94 6,890.72 6,841.12 9,024.69 -7,924.82 6,012,966.39 380,361.32 0.00 11,959.22 16,300.00 90.78 324.94 6,889.36 6,839.76 9,106.54 -7,982.25 6,013,049.08 380,305.12 0.00 12,059.20 16,400.00 90.78 324.94 6,888.00 6,838.40 9,188.39 -8,039.69 6,013,131.77 380,248.92 0.00 12,159.17 16,429.49 90.78 324.94 6,887.60 6,838.00 9,212.52 -8,056.63 6,013,156.16 380,232.35 0.00 12,188.66 Target (Toe); 16429' MD, 6887' TVD, 22' FNL & 1027' FEL; Sec38-T13N- R04E - 4112" Tbg - 6 1/8" Open Hole -CD3-112wp02 Toe /I Geologic Targets Plan: CD3-112 TVD Target Name (ft) - ShaAc 6,989.60 CD3-112wp02 Heel - Point 6,887.60 CD3-112wp02 Toe - Point Prognosed Casing Points Measured Verticai Depth Depth (ft) (ft) 2,743.80 2,500.00 8,927.96 6,989.60 16,429.48 6,887.60 Casing Diameter (") 9-5/8 7 4-1/2 +N/-S +E/-W Northing ft ft (ft) 3,072.66 -3,747.96 6,006,952.96 9,212.52 -8,056.63 6,013,156.16 Note Diameter f7 12-1 /4 8-3/4 6-1/8 Fasting (ft) 384,448.18 380,232.35 222/2006 2:20:48PM Page 7 of 8 COMPASS 2003.11 8ui/d 50 ORIGINAL ~' Sperry Drilling Services ~-I~.te_L~1~t~~-~-~ C+~t1QCC3 PI"1t~It~S Planning Report -Geographic -- - - Alaska Sperry Qrilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-112 Company: ConocoPhillips Alaska Inc. ND Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 Narth Reference: True .Well: Plan: CD3-112 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-112 Design: CD3-112v/p02 Prognosed Forrnation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°1 {ft) fft) (ft) Name 1,265.75 21.45 307.46 1,245.60 108.01 -121.00 Base Permafrost 2,550.55 33.90 305.43 2,339.60 497.49 -662.77 G~10 2,740.91 33.90 305.43 2,497.60 559.04 -749.28 C-30 3,207.16 33.90 305.43 2,884.60 709.81 -961.15 C-20 4,430.02 33.90 305.43 3,899.60 1,105.23 -1,516.86 K-3 4,607.13 33.90 305.43 4,046.60 1,162.50 -1,597.34 K-3 Basal 4,644.47 33.90 305.43 4,077.60 1,174.57 -1,614.31 K-2 4,770.98 33.90 305.43 4,182.60 1,215.48 -1,671.80 K-2 Basal 6,616.71 33.90 305.43 5,714.60 1,812.31 -2,510.56 Albian 97 6,923.93 33.90 305.43 5,969.60 1,911.65 -2,650.17 Albian 96 7,&75.28 48.22 313.30 6,559.60 2,196.51 -3,012.04 Top HRZ 7,917.43 56.37 316.26 6,707.60 2,331.50 -3,147.69 Base HRZ 8,001.87 59.22 317.15 6,752.60 2,383.51 -3,196.68 K-1 8,087.64 62.13 318.01 6,794.60 2,438.71 -3,247.10 Top Kuparuk D 8,180.19 65.27 318.89 6,835.60 2,500.80 -3,302.12 Top Kuparuk C 8,189.81 65.60 318.98 6,839.60 2,507.40 -3,307.87 LCU 8,189.81 65.60 318.98 6,839.60 2,507.40 -3,307.87 Top Nuiqsut 8,349.55 71.04 320.38 6,898.60 2,620.55 -3,403.86 Base Nuigsut 8,679.52. 82.29 323.04 6,974.60 2,872.24 -3,602.32 Top Nechelik 222/2006 2:20:48PM Page 8 of 8 COMPASS 2003.11 Build 50 ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-112 Plan: CD3-112 CD3-112wp02 Anticollision Report 22 February, 2006 ~~ Sperry D!rillnr~ r~rvc~s ORIGINAL ANTI-COLLtS ION 8ETI.NGS 1C! ~/ti~~/e~ ~1~~~ InterpoWhon McMOd MD Interval: 26Stations Cakulatlon Method: Mlnlmum Curvature ~ RA fir, lii wl Depth RanOe F'om: 78.70 TO 18429.49 Error Model: ISG WSA p r~,.,5.'~,. Manimum Range: 7BSB.1191107186] Error Surface: EI Otic I'COnloNwlfi Referanoe Well: plan: CD7-112wp02 Warning Method: Rules Based -j~(~~,~~~~'~'~{" ~ STIR\'NY PR OGRA!11 $piTf~/ O~(~Aa ~BfV(~~ ! . Da[e'. 21N16a12.15'Ilr)~IHi:lln Valide[ed: Yes V'°rxWn- Peptli Fran Depth To S'ui~ee/Pf an Tod h 36.39 ABU IH1 CDJ-112wpU2 CB-GYROSS o-. ---° - B~N1.99 Ifi~29.49 CD3-112wp112 N1WD+IFR-AhCAZ S(' Cc-noc°Pfiiao~Aaska MC. --- ~--- R°ject'. Ge Nilb RNerUnr Sia Aprte GD3 tYCe Plan. CD3-112 Pennl,W e VJeNCare PYn: G~J-113 .~e~: ~+m ge..le.:Fw w.,i?arr°~e.n"nmm'w~,araa.vau ~:e} rt.~IO~n,else a.,aaB =m..a,,.~.. a _ _ %?~Bo-------~ l a ,,tr < 9'als_..e -30/339-' ~ -_- --.._..~~~80 --- -_ -~D Prom Colour To MD ::-~-----~i<., -are +~ea-~---- ev-s -rav t+^sa- Critical Issues: ~ . ~ -~ 160 A ~,, .1ltvmoz r j --' _ 140 - ~ _ ~ ~ CD]-111wp02 - ~ -- - X 120 V~ ~ i ~p~y / , ~ ~ lea,,./ -60 / 300 ~ % ~ - _ - ~ ~ 100 v~ S ~~ -90 / ~ ~ / I i / -~, , ~ ` ! '',, '• ' D2.1 t0 Rla Sutvoye x 1 / 1 60' ~~ t ~ ~` Plan: CD7.707 (wp01) w..w'aa~e i ' c r / ' / ~ i ~ % ~ \ ~ t - ~' lan: DDb-108 (wp01) ~~ww•a~~yy / / ! 60 { } , ~ CDb-108 Ri Surve s V j ~ / ~ \ i y\ ,ak ~ g y _ ~+.r i 40 ' ~ coaaoawpa - ~ ~ j ~ 1 / ~ - -coaaaapelwpoa c ~ I ~ j I I j ' ~. ODD•108Wp10 I J I ~ nDa•ta9 RIO 9urvays - 901270 __ ~.__ II ~ ~ }- I I-_-.. _.. 90 CDb-bOdwp08 I t t i I / ' l~ ' Pbn: CD7a06 (vryo21 ' Plan: CDb•1U (w pOt) t , +.. / /~ } '- + ,. 1 0 i ~ ' i Travellingy Cc lurder Azimuth ('FFOt AZIJ (°] vs C entre to C entre Sep amtbn (5 Nina ` , / / } '/ SECTION DETAILS -120/24 ' ~ ~ 100- '120 Sac MD Ioc Azl TVD +N/S +E/-W DLeg TFece VSe< Target ~ ~ Plan: CDb-117 (wp01 '~ 1 . ~~ -' , ~~ ,~ ~ ," ~ ~ -:, ~ 1 2 36.30 350.00 0.00 0.00 0.00 0.00 36.30 350.00 0.011 0.00 O.ql 0.011 0.00 0.00 0.00 0.00 0.00 0.00 \ - 120 - t ~ ~ ~ / f f ~ ~ t { 1 ~ ~ 3 4 600.1p 17fi9.21 724Lg1 5.00 33.90 33 90 325.00 305.43 30 599.68 1691.07 fi132 77 6.93 244.84 2014 17 fi.25 J07.71 479 2.00 1.50 0 00 325.00 -22.49 000 10.90 378.95 3271 Pqn: CDb-118 (wp02 ~ - `~ '- 1_40 ~- r~* ; ~ `ti~ 1 ~ ~,~ 3V ' / 5 6 7 6927.96 49 16429 . 90.78 90 78 5.43 324.94 324 94 . 6989.60 6887 60 . 7073.66 9212 52 435 9747.96 -8056 61 . 3.50 0 00 2391 0 00 .93 4688.83 CD3-112wp02 Heel 12188 66 CD31/2w 02 Tce _ ~ 0 . . . , . . . . p . ~\ ~ I ,,~ ~. ~ Plan: CDb-116 (rry00 -150/21D ~~ / ~~~ ~'' 16D - F„(8U Plan:coa-1latwpoll ~ \ g.X ~. ~ '~~ ~ - - ~1y v ~ i ~ -180 / 180 i Plan: CDb-114 (wp01j NoN: NEGATNE TFO+Azi values from the Survey Editor or Travelling Oylinder Report should be pbttad on the loft sido of the Travelling T,ta}ellin Cylinder. Cylinder azimuth lTFO~+,~Zi sCentre to Centre Se aratien OfVin K ~ (°~ r P ~2 ( 2/22/2006 12:54 PM • Sperry Drilling Services ' ~~~~~ ~~CC)~ 11~~p5 Anticollision Report ~~ ---°~-- Alaska S~ssrry prfllfng 5e~css Company: ConocoPhillips Alaska Inc. Local Co-ordinate Reference: Well Plan: CD3-112 Project: Colville River Unit TVD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Reference Site: Alpine CD3 MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site Error: O.OOft North Reference: True Reference Well: Plan: CD3-112 'Survey Calculation Method: Minimum Curvature Well Error. O.OOft Output errors are at 1.00 sigma Reference Wellbore Plan: CD3-112 Database: EDM 2003.11 Single User Db Reference Design: CD3-112wp02 Reference CD3-112wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refers Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,839.32ft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Offset TVD Reference: '' Offset Datum Survey Too! Program From To (ft) (ft) Date 2x2212006 Survey (Wellbore) Tool Name Description 36.30 800.OU CD3-112wp02 (Plan: CD3-112) CB-GYRO-S5 Camera based gyro single shot 800.00 16,429.49 CD3-112wp02 (Plan: CD3-112) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning ~ Site Name Depth Depth Distance (ft) fromaPlan Offset Well-.Wellbore -Design (ff) (ft) (ft) (ff)` Alpine CD3 CD3-108 -Rig: CD3-108 -CD3-108 Rig Surveys 275.98 275.00 81.62 5.10 76.53 Pass -Major Risk CD3-109 -Plan: CD3-109 -CD3-109 Rig Surveys 399.45 400.00 61.38 8.49 52.90 Pass -Major Risk CD3-109 -Plan: CD3-109 -CD3-109wp10 399.45 400.00 61.38 8.49 52.90 Pass -Major Risk CD3-109 -Rig: CD3-109 -CD3-109 Rig Surveys 399.45 400.00 61.38 8.49 52.90 Pass -Major Risk CD3-110 -Rig 2: CD3-110 -CD3-110 Rig Survey: 323.70 325.00 41.59 6.74 34.85. Pass -Major Risk CD3-110 -Rig: CD3-110 -CD3-110 Rig Surveys 323.70 325.00 41.59 6.74 34.85 Pass -Major Risk CD3-302 -CD3-302PB1 -CD3-302P61 Rig Surve 248.80 250.00 200.63 5.22 195.41 Pass -Major Risk CD3-302 -Plan: CD3-302 -CD3-302 Rig Surveys 248.80 250.00 200.63 5.22 195.41 Pass -Major Risk CD3-302 -Plan: CD3-302 -CD3-302wp06 248.80 250.00 200.63 5.22 195.41 Pass -Major Risk Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 (~ 250.99 250.00 120.64 5.19 115.45 Pass -Major Risk Plan: CD3-107 -Plan: CD3-107 -Plan: CD3-107 (~ 250.99 250.00 100.60 4.66 95.95 Pass -Major Risk Plan: CD3-111 -Plan: CD3-111 -CD3-111wp02 624.01 625.00 23.19 13.33 9.87 Pass -Major Risk Plan: CD3-113 -Plan: CD3-113 -Plan: CD3-113 (~ 600.99 600.00 19.04 11.23 7.81 Pass -Major Risk Plan: CD3-114 -Plan: CD3-114 -Plan: CD3-114 (~ 651.74 650.00 37.74 12.18 25.56 Pass -Major Risk Plan: CD3-115 -Plan: CD3-115 -Plan: CD3-115 (~ 451.73 450.00 60.03 8.41 51.62 Pass -Major Risk Plan: CD3-116 -Plan: CD3-116 -Plan: CD3-116 (~ 226.00 225.00 80.17 4.18 75.99 Pass -Major Risk Plan: CD3-117 -Plan: CD3-117 -Plan: CD3-117 (~ 226.00 225.00 100.15 4.18 95.96 Pass -Major Risk Plan: CD3-301 -Plan: CD3-301 -CD3-301 (wp01) 375.29 375.00 220.51 6.99 213.52 Pass -Major Risk Plan: CD3-303 -Plan: CD3-303 -CD3-303wp04 348.80 350.00 180.51 7.32 173.19 Pass -Major Risk Plan: CD3-303 -Plan: CD3-303P61 -CD3-303P6 349.90 350.00 180.53 7.35 173.19 Pass -Major Risk Pian: CD3-304 -Plan: CD3-304 -CD3-304wp06 350.00 350.00 160.29 7.35 152.94 Pass -Major Risk Plan: CD3-305 -Plan: CD3-305 -Plan: CD3-305 (~ 250.99 250.00 140.50 4.65 135.85 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 222/2006 12:36:39PM Page 2 of 2 COMPASS 2003.118ui1d 50 ORIGINAL "!"`~ Project: Colville River Unit ~ ~~~~~~~~~~~~ Site: Alpine Cb3 ~ - w Well: Plan: CD3-112 ~ v # ~ ~~k~ Wellbore: Plan: CD3.112 ' Plan: CD3-112wp02 - ` ,,- .. _ .~riNIMTj~ O~~~i(A~ ~trf'V~C!!S Ground l.e'+ei: 19.70 RKB: Planned UOyon 19~49.90tt {Cfoyon i9 (36.3 ~+17.71} NorthinglASP Y: 600792&.75 ® • • • • . EastinglASP K: 389'140.:tb ,.. 450 (f~'"i~''~) ~~r/ P ~VO a-. O c,.~ c~ __.. d C CD3-302 ,~ CD3-112wp02 ,~ • CD3-108 OpaMar: ConeeoPMWq AbRkc MC. Orb Camcllon: -0.36 Job NO: NN/A Fl.ld: CeIWIN Riv.r Unfl MopneNe De<Iinaflon: ]3.61 AFE Nc: NN/A Welk ODS-113wpOR dp: B0.y4 API No: NN/A RIO: NN/A Do0ie0 Par 100 it SyW.m (1V01 Aal.ren<a: Menn Sec level axone mermen Orlglnal VS Plane: 324.00 Px.nt w.m Plan: CD3d 13 X: Sfl31N9.36 it VIEW VS PIQnE: 324.00 RNR XeIphF. 49.60 fl Y: dOD3330.y3 D Unfl SyWSm: APl Bored/FPS Secllon (VS)Relxenne: SIO1 `~ ~ Comments: Plan View S ~ w ~ ao ° M ~ M ~ m M ~ M M M M ~ M M M M M M 0 t z° - + -CD3-112wp02 Plan -CD3-110 Rig MW D Section View ~-CD3-109 Rig IFR -F-CD3-108 Rig IFR r N O t 0 E 0 a n 6018000 6017000 6016000 6015000 6014000 6013000 6012000 6011000 6010000 6009000 6008000 6007000 6006000 6005000 6004000 6003000 ____ 4000 5000 6000 7000 8000 n n n n n n M M M M M M M M M M M M M M M M M M M n n n n n n N N N N N N N N N N N N N N N N N N N ~O ~0 ~O ~O ~O ~O M M M M M M M M M M M M M M M M M M M ~ V M N ~ ~ N M 7 h ~ n W D` O N M V u1 ~ n W Vertical Section abng "Yew VS Plane" Combo Preview Page 1 of 1 (Toolboxt.xls) 2/22/2006 2:17 PM Closest in POOL 4 ~' '~ d ~";~~' ~° ~~ Closest A roach: Reference Well : CD3-1 12w 02 Plan Offset Well: CD3-110 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS MIn. Dlst. De th Incl. An le TRUE Azi. TVD E + /W - 324° Comments De th Incl. Angle TRUE Azi. TVD E + /W - (324° Comments m is ante in is ante (4169.58 ft) in POOL (4169.58 ft) in POOL (6835 - 7065 Subsea (6835 - 7065 Subsea TVD) to CD3-110 Rig TVD) to CD3- 4169.58 10600 90.78 324.94 6917.192 6008336 383508 6360.483 MWD 11800 91.43 324.87 6924.045 6010682 386955.1 6294.682 112wp02 Plan Closest A roach: Reference Well : CD3-1 12w 02 Plan Offset Well: C D3-109 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' ': Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Mln. Dlst. De th Incl. An le TRUE Azi. TVD E + /W - 324° Comments Depth Incl. An le TRUE Azi. TVD E + /W - (324°) Comments in is ante in is ante (6191.86 ft) in POOL (6191.86 ft) in POOL (6835 - 7065 Subsea (6835 - 7065 Subsea TVD) to CD3-109 Rig TVD) to CD3- 6191.86 10950 90.78 324.94 6912.427 6008625 383311.3 6710.403 IFR 13925 90.6 325.3 6911.762 6012111 388428.8 6615.38 112wp02 Plan Closest A roach: Reference Well : CD3-1 12w 02 Plan Offset Well: CD3-108 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS MIn. Dlst. De th Incl. An le TRUE Azi. TVD E + /W(- (324° Comments De th Incl. An le TRUE Azi. TVD E + /W -) 324°) Comments in is ante in is ante (8343.99 ft) in POOL (8343.99 ft) in POOL (6835 - 7065 Subsea (6835 - 7065 Subsea TVD) to CD3-108 Rig TVD) to CD3- 8344.0 8316.64 69.91 320.1 6637.948 6006472 384804.5 4089.85 IFR 12800 89.59 327.69 6948.974 6011518 391448.4 4392.659 112wp02 Plan POOL Summaryl.xls 2/22/2006 2:29 PM • • • . CD3-112wp02 Surface Location FNL ~ 3950.2090 ~FEL ~ 894.12978 CD3-112 starting Cnordinal ins Point T ransfom~ Transform Quit Help • • (?R~GINAL ~. • i a • O ~ o ~ ~' ~ ,~ ~n Donc~rn -i F r- O 3 O sco 3 \ m..~ 11j1\ '0p no 02 DZ~ =~ r.. N ~. ~ Om _ ~-+t)1~~ n Oc]~ s y w opZ _. r W n ~ '" r ? ~ ~ r ~" y C D~ ~ ~ ^• LIl fp ~~~ O ~ =~ ``1 D m r ~\ r ~ ~ Q ~ .a ~ .. f1J i ~ ~ ~ i p~ a ~ r C ~ i ~ ~ W ' o ° n j ~ ~ m o ~ N ° ~ C ,~ o n N ~~ ~~ m g I j _ P m ~~ ~ A • • TRANSMITTAL LETTER CHECKLIST WELL NAME C,; /C~~ C~-y ~ -"/ PTD# ~~ ~ - C~~ ~-- Development ~~Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing we(1 (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. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of welll until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl i st • • ^^ ~ y ~ y , ~ •o ~ y N, m L' N ~ V M' C' •- _; ~, ~ ~ ~ ~ ~ a a of a' v VA ~ N. ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ Q N. O. f0, Y' Q~ O ~ c •~ ~ ~ ., ~ 00 o ~ , v. a. a> c ~ ~, ~' m Q ~ Z. 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J J Q E, E = a, `' ,c, c E ' ' ~ c~' m o ° c' 3 c ~ ~, F- ,., c o cef ~' c ~ c w a~, ar °n ni .c y ~, a c c o ~ f Y ~ ~ ~, ~ ° o o a ,~ ~ ~' c. o a ° °, m '~ ~ L o ° >` c°O 0 ~ ~ a V .4 ~ ~ ~, ~ ~, .~ o. ~i o Q ~ia m' ~ y o a o. ~ ~ T ~c ~ ~ Z ~ 3 ~ • U Q m. °' °' m a a' ~ m. ~ ~, ~_, ~_ ~ ~ ~~ ° ~ -° ~ S °- i a~' a °, %, -=, a i ~ a u i' °' n 3' ° o ~ ° 3. c E ~ . c. a. . -°~ c m. ~ `~ `~ ~m a~ o~ . ~, 3; 3 a a~ y ~ a. N , .., ~y, ~ a~ :a ~ '~, .°-~, c 3 ~ ~ M, °~ y ~ o, a m y ~, ~ 4 ~ y ~.-~ o~ o, ~ ~ m' ~ 3. L w W o U Q a ` ~ _ a ~ ' ' ° a Y. -° ' ' a~, ° o rn c. ' a, y u~, a J J f6, N a. a N a N s°, N N U. o. N N 7 O ° °. ° C ° ~ ~ U' U' ° w Q O $ ° Y ° i a -° N ~ O y m N - ° N ~ O ~ L-. O, O (/~ • N p' .~ O c O y C O ~ = L~ f]. N. ~ U. f6, ~~ N 4 fll ~ ~~ ~, O. O. ~' N .~~ p1 ~ ° y y' U). N, fl. (6 ~~ ~ ~ N, r-~ ~ C. °~ _ Q m , ~~ ~ ~ ~~ ~~ -_ ~ N. f0• 01 y fD~ ° N' ~ N' ~~ ~ d • C. T 3~ N ~~ U. -°~ ~ _. C• y. °~ y' c. ~ O. a' L• 4 p '° a~' ~, ~, a a ~~ y' ~ ~ °~ o, ~ 3. ~, .a~ ~ ` ~' ar ar ~, c ~, ~~ 9~ n ~ ~~ ~, o. ~ o' o ' U °~ ~~ >, ~_' ~~ IL U p' ,a~ _~ a~ ' ~, ~, ~, a~ a• U. •- a~ u~, m ~ C~ N• o s, Q, 9~ c c _ -°~ ~ w' N• ~ U `a ' ' N~ 'y. ca ` N N. "d a >~ ° ' .~ ~~ y ' .c. ~ , 3; ~-° y~ o N •'= U ~ o, ~ m a~ c (6 C~ c a~ c, o ~~ m ~_ O a~ m. °, 3. m. m. m. a> ° ° U E ca. 3 ° c LL o, v, m; m' ~ a~ ~ - _ ~?, ~ ` a. ~ m' _, c .v, ~ o, y m U, c OQ ~_ p ~' ~ °' o' o' o' •°~' f0' ~' ~ ~' ' o o' `~' °' ' ~ a~, ° U o, o, > > 3' m, rn ° . m, v ° ~, rn vi. a m c ~, •3. y' m' v -o, U n o ~ ~ Y ~, a~ aoi •~ °~ ' °~ °~ ~, ~ ' 4 4 a~ ~, ' ~ ~ 3, ~, U'. ' o; ~, ~', ~; ~', m; v. ~ ~; v =' ' O, O, t; °' °" ~ ' ' ' y, ~, ~m af6i o p c a J ~, ~ , ~; ~ , cn O, O, a a U s; ¢; a ¢, U cn, U, U, U, U, ¢, _ ¢, o , m m ~ U, ~ , N a, o cn, cn, , ~, fli f~ W a ° ~ N M V ~ C° I~ M O O N ~ M a- et .- ~ t0 a0 Q~ r ___ O N N N N M ~ N N if) CO I~ O N N N N O O N M r` N M V M M M M ~ (O f~ a0 M M_ M M -- O M U U ~ o o o a~ O C +.' N +O' N w N U O . ~ 11 M O r ~ a0 N 6Y 0 a0 N 0 a0 N O •y ° y ~ ~ a O M N ` N N ~ J O N C i d ~ Ur ~ p /-~ L~\ W o E `c. ~ I ~ a g ~ o a m U J ~ ~ a a ~ w a ~ ~ a~ • • Wel4 History File APPENDIX Information of detailed nature that is not particularly gem~ane to the Well Permitting Process but is part of the history file. To improve the readability of the Wel{ Nistory 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. T Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 15 08:00:32 2006 Reel Header Service name .............LISTPE Date .....................06/06/15 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/15 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF au~ -~~~ at ~ Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Colville River (Fiord) MWD/MAD LOGS WELL NAME: CD3-112 API NUMBER: 501032052700 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 14-JUN-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 5 JOB NUMBER: W-0004295099 W-0004295099 W-0004295099 LOGGING ENGINEER: M. HANIK M. HANIK R. KRELL OPERATOR WITNESS: D. LUTRICK D. LUTRICK D. LUTRICK MWD RUN 6 JOB NUMBER: W-0004295099 LOGGING ENGINEER: R. KRELL OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: FSL: 1330 FEL: 894 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 49.30 GROUND LEVEL: 13.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT S~ (IN) SIZE (IN) DEPTH (FT) IST STRING 8.500 9.625 2726.0 2ND STRING 6.125 7.000 8573.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3,5,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP). NO PROGRESS WAS MADE ON MWD RUN 4. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-3,5,6 REPRESENT WELL CD3-112 WITH API#: 50-103-20527-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16021'MD/6946'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 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 TH STOP DEPTH GR 2699.0 15964.0 RPD 2710.0 15971.0 RPS 2710.0 15971.0 RPM 2710.0 15971.0 FET 2710.0 15971.0 RPX 2710.0 15971.0 ROP 2736.5 16021.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2699.0 3205.0. 3 3205.0 8583.0 5 8583.0 15070.0 6 15070.0 16021.0 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 .lIN 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2699 16021 9360 26645 2699 16021 RPD MWD OHMM 0.04 2000 17.7655 26523 2710 15971 RPM MWD OHMM O.OEi 2000 14.0676 .26523 2710 15971 RPS MWD OHMM 0.1_°i 1607.11 11.8639 26523 2710 15971 RPX MWD OHMM 0.13 1856.9 10.5958 26523 2710 15971 FET MWD HOUR 0.16 77.21 1.16702 26523 2710 15971 GR MWD API 26.37 379.24 77.8881 26531 2699 15964 ROP MWD FT/H 0.27 385.28 143.115 26570 2736.5 16021 First Reading For Entire File..........2699 Last Reading For Entire File...........16021 File Trailer Service name........... ~SLIB.001 • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 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.......06/06/15 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 GR 2699.0 RPD 2710.0 RPM 2710.0 RPX 2710.0 RPS 2710.0 FET 2710.0 ROP 2736.5 LOG HEADER DATA 'DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 3168.0 3160.5 3160.5 3160.5 3160.5 3160.5 3205.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 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): 29-MAR-06 Insite 66.37 Memory 3205.0 2736.0 3205.0 31.7 33.5 TOOL NUMBER 132482 66259 8.500 2726.0 Fresh Water Gel 9.60 37.0 ~ • MUD PH: 9.8 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3) 9.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.200 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 78.8 MUD FILTRATE AT MT: 3.200 74.0 MUD CAKE AT MT: 2.800 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Cha nnel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Ns am Reading Reading DEPT FT 2699 3205 2952 1 013 2699 3205 RPD MWD020 OHMM 0.04 2000 65.7021 902 2710 3160.5 RPM MWD020 OHMM 0.06 1856.1 7.81553 902 2710 3160.5 RPS MWD020 OHMM 0.15 1360.37 5.64929 902 2710 3160.5 RPX MWD020 OHMM 0.13 1856.9 7.47573 902 2710 3160.5 FET MWD020 HOUR 0.19 51.51 3.58156 902 2710 3160.5 GR MWD020 API 61.88 175.03 114.945 939 2699 3168 ROP MWD020 FT/H 11.66 299.11 209.796 938 2736.5 3205 First Reading For Entire File..........2699 Last Reading For Entire File...........3205 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER • FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY , VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 3161.0 8537.5 FET 3161.0 8537.5 RPM 3161.0 8537.5 RPD 3161.0 8537.5 RPS 3161.0 8537.5 GR 3168.5 8545.5 ROP 3205.5 8583.0 LOG HEADER DATA DATE LOGGED: O1-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8583.0 TOP LOG INTERVAL (FT) 3205.0 BOTTOM LOG INTERVAL (FT) 8583.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 28.0 MAXIMUM ANGLE: 86.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2726.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.70 MUD VISCOSITY (S) 37.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 7.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.200 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.310 129.2 MUD FILTRATE AT MT: 3.200 74.0 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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 2 ..800 ~0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3161 8583 5872 10845 3161 8583 RPD MWD030 OHMM 1.39 24.85 5.18488 10754 3161 8537.5 RPM MWD030 OHMM 1.33 27.58 4.95 10754 3161 8537.5 RPS MWD030 OHMM 1.2 38.51 4.93275 10754 3161 8537.5 RPX MWD030 OHMM 1.23 51.15 4.96911 10754 3161 8537.5 FET MWD030 HOUR 0.16 9.73 0.46245 10754 3161 8537.5 GR MWD030 API 33.72 379.24 113.729 10755 3168.5 8545.5 ROP MWD030 FT/H 0.74 320.5 201.407 10756 3205.5 8583 First Reading For Entire File..........3161 Last Reading For Entire File...........8583 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name. Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header. data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 8538.0 15019.5 FET 8538.0 15019.5 RPM 8538.0 15019.5 RPX 8538.0 15019.5 RPD 8538.0 15019.5 GR 8546.0 15012.5 ROP 8583.5 15070.0 LOG HEADER DATA DATE LOGGED: 08-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15070.0 TOP LOG INTERVAL (FT) 8583.0 BOTTOM LOG INTERVAL (FT) 15070.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8573.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.25 MUD VISCOSITY (S) 45.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 34000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .160 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 167.0 MUD FILTRATE AT MT: .140 70.0 MUD CAKE AT MT: .260 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN 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 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8538 15070 11804 13065 8538 15070 RPD MWD050 OHMM 7.77 2000 25.1019 12964 8538 15019.5 RPM MWD050 OHMM 0.59 2000 21.9516 12964 8538 15019.5 RPS MWD050 OHMM 0.19 1607.11 17.8555 12964 8538 15019.5 RPX MWD050 OHMM 0.17 1275.4 15.4363 12964 8538 15019.5 FET MWD050 HOUR 0.32 77.21 1.31303 12964 8538 15019.5 GR MWD050 API 26.37 86.5 47.14 12934 8546 15012.5 ROP MWD050 FT/H 3.22 385.28 98.9861 12974 8583.5 15070 First Reading For Entire File..........8538 Last Reading For Entire File...........15070 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 • Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 15013.0 15964.0 RPM 15020.0 15971.0 RPX 15020.0 15971.0 RPS 15020.0 15971.0 RPD 15020.0 15971.0 FET 15020.0 15971.0 ROP 15070.5 16021.0 LOG HEADER DATA DATE LOGGED: 10-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16021.0 TOP LOG INTERVAL (FT) 15070.0 BOTTOM LOG INTERVAL (FT) 16021.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.2 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8573.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 45.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 40000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .120 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .060 169.0 MUD FILTRATE AT MT: .140 75.0 MUD CAKE AT MT: .160 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type....... • .......0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN 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 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD60 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15013 16021 15517 2017 15013 16021 RPD MWD060 OHMM 5.67 31.02 16.1596 1903 15020 15971 RPM MWD060 OHMM 4.65 33.89 14.8462 1903 15020 15971 RPS MWD060 OHMM 3.8 55.88 13.1611 1903 15020 15971 RPX MWD060 OHMM 3.04 43.67 10.8961 1903 15020 15971 FET MWD060 HOUR 0.43 36.85 3.00952 1903 15020 15971 GR MWD060 API 33.78 167.22 66.0251 1903 15013 15964 ROP MWD60 FT/H 0.27 148.38 81.6026 1902 15070.5 16021 First Reading For Entire File..........15013 Last Reading For Entire File...........16021 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/15 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................06/06/15 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Writing Library. Scientific Technical Services Comments ...............~5 LIS Writing Library. Scient~c Technical Services Physical EOF Physical EOF End Of LIS File • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 15 08:00:32 2006 Reel Header Service name .............LISTPE Date .....................06/06/15 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/06/15 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 (Fiord) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004295099 LOGGING ENGINEER: M. HANIK OPERATOR WITNESS: D. LUTRICK MWD RUN 6 JOB NUMBER: W-0004295099 LOGGING ENGINEER: R. KRELL OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: ' FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD L' RECEIVED JAN 2 9 2001 a ~7~~,i, ~~,~,,~• ~fNSS1O11 ~MM~ Scientific Technical Services Scientific Technical Services CD3-112 501032052700 ConocoPhillips Alaska, Inc. Sperry Drilling Services 14-JUN-06 MWD RUN 3 MWD RUN 5 W-0004295099 W-0004295099 M. HANIK R. KRELL D. LUTRICK D. LUTRICK 5 12N SE 1330 894 49.30 13.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 2726.0 2ND STRING 6.125 7.000 8573.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. UTC- ~ -b3a ~ ~~t3c~-t • • THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3,5,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP) NO PROGRESS WAS MADE ON MWD RUN 4. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-3,5,6 REPRESENT WELL CD3-112 WITH API#: 50-103-20527-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16021'MD/6946'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 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 GR 2699.0 15964.0 RPD 2710.0 15971.0 RPS 2710.0 15971.0 RPM 2710.0 15971.0 FET 2710.0 15971.0 RPX 2710.0 15971.0 ROP 2736.5 16021.0 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 2699.0 3205.0 MWD 3 3205.0 8583.0 MWD 5 8583.0 15070.0 MWD 6 15070.0 16021.0 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2699 16021 9360 26645 2699 16021 RPD MWD OHMM 0.04 2000 17.7655 26523 2710 15971 RPM MWD OHMM 0.06 2000 14.0676 26523 2710 15971 RPS MWD OHMM 0.15 1607.11 11.8639 26523 2710 15971 RPX MWD OHMM 0.13 1856.9 10.5958 26523 2710 15971 FET MWD HOUR 0.16 77.21 1.16702 26523 2710 15971 GR MWD API 26.37 379.24 77.8881 26531 2699 .15964 ROP MWD FT/H 0.27 385.28 143.115 26570 2736.5 16021 First Reading For Entire File..........2699 Last Reading For Entire File...........16021 File Trailer Service name ........... ..STSLIB.001 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/06/15 Maximum Physical Record ..65535 File Type .............. ..L0 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.......06/06/15 Maximum Physical Record..65535 File Type ................L0 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 GR 2699.0 3168.0 RPD 2710.0 3160.5 RPM 2710.0 3160.5 RPX 2710.0 3160.5 RPS 2710.0 3160.5 FET 2710.0 3160.5 ROP 2736.5 3205.0 LOG HEADER DATA DATE LOGGED: 29-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3205.0 TOP LOG INTERVAL (FT) 2736.0 BOTTOM LOG INTERVAL (FT) 3205.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.7 MAXIMUM ANGLE: 33.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 2726.0 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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Fresh Water Gel 9.60 37.0 9.8 900 9.2 2.200 74.0 .000 78.8 3.200 74.0 2.800 74.0 • • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2699 3205 2952 1013 2699 3205 RPD MWD020 OHMM 0.04 2000 65.7021 902 2710 3160.5 RPM MWD020 OHMM 0.06 1856.1 7.81553 902 2710 3160.5 RPS MWD020 OHMM 0.15 1360.37 5.64929 902 2710 3160.5 RPX MWD020 OHMM 0.13 1856.9 7.47573 902 2710 3160.5 FET MWD020 HOUR 0.19 51.51 3.58156 902 2710 3160.5 GR MWD020 API 61.88 175.03 114.945 939 2699 3168 ROP MWD020 FT/H 11.66 299.11 209.796 938 2736.5 3205 First Reading For Entire File..........2699 Last Reading For Entire File...........3205 File Trailer Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/06/15 Maximum Physical Record..65535 File Type .............. ..LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 3161.0 8537.5 FET 3161.0 8537.5 RPM 3161.0 8537.5 RPD 3161.0 8537.5 RPS 3161.0 8537.5 GR 3168.5 8545.5 ROP 3205.5 8583.0 LOG HEADER DATA DATE LOGGED: O1-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8583.0 • TOP LOG INTERVAL (FT) 3205.0 BOTTOM LOG INTERVAL (FT} 8583.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 28.0 MAXIMUM ANGLE: 86.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 66259 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: 8.750 2726.0 • Fresh Water Gel 9.70 37.0 8.8 800 7.8 2.200 74.0 1.310 129.2 3.200 74.0 2.800 74.0 Data Format Specification Re cord Data Record Type ......... .... .....0 Data Specification Block Type ...,.0 Logging Direction ........ .... .....Down Optical log depth units.. .... ...,.Feet Data Reference Point ..... .... .....Undefined Frame Spacing ............ .... .....60 .lIN Max frames per record .... .... .....Undefined Absent value ............. .... .....-999 Depth Units .............. .... ..... Datum Specification Block sub -type...0 Name Service Order Units Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3161 8583 5872 10845 3161 8583 RPD MWD030 OHMM 1.39 24.85 5.18488 10754 3161 8537.5 RPM MWD030 OHMM 1.33 27.58 4.95 10754 3161 8537.5 RPS MWD030 OHMM 1.2 38.51 4.93275 10754 3161 8537.5 RPX MWD030 OHMM 1.23 51.15 4.96911 10754 3161 8537.5 FET MWD030 HOUR 0.16 9.73 0.46245 10754 3161 8537.5 GR MWD030 API 33.72 379.24 113.729 10755 3168.5 8545.5 ROP MWD030 FT/H 0.74 320.5 201.407 10756 3205.5 8583 • • First Reading For Entire File..........3161 Last Reading For Entire File...........8583 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 8538.0 15019.5 FET 8538.0 15019.5 RPM 8538.0 15019.5 RPX 8538.0 15019.5 RPD 8538.0 15019.5 GR 8546.0 15012.5 ROP 8583.5 15070.0 LOG HEADER DATA DATE LOGGED: 08-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15070.0 TOP LOG INTERVAL (FT) 8583.0 BOTTOM LOG INTERVAL (FT) 15070.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8573.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.25 MUD VISCOSITY (S) 45.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 34000 • • FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .160 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 167.0 MUD FILTRATE AT MT: .140 70.0 MUD CAKE AT MT: .260 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN 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 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8538 15070 11804 13065 8538 15070 RPD MWDO50 OHMM 7.77 2000 25.1019 12964 8538 15019.5 RPM MWDO50 OHMM 0.59 2000 21.9516 12964 8538 15019.5 RPS MWDO50 OHMM 0.19 1607.11 17.8555 12964 8538 15019.5 RPX MWDO50 OHMM 0.17 1275.4 15.4363 12964 8538 15019.5 FET MWDO50 HOUR 0.32 77.21 1.31303 12964 8538 15019.5 GR MWDO50 API 26.37 86.5 47.14 12934 8546 15012.5 ROP MWDO50 FT/H 3.22 385.28 98.9861 12974 8583.5 15070 First Reading For Entire File..........8538 Last Reading For Entire File...........15070 File Trailer Service name ............ .STSLIB.004 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .06/06/15 Maximum Physical Record. .65535 File Type ............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/15 • • Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 15013.0 15964.0 RPM 15020.0 15971.0 RPX 15020.0 15971.0 RPS 15020.0 15971.0 RPD 15020.0 15971.0 FET 15020.0 15971.0 ROP 15070.5 16021.0 LOG HEADER DATA DATE LOGGED: 10-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16021.0 TOP LOG INTERVAL (FT) 15070.0 BOTTOM LOG INTERVAL (FT) 16021.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.2 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8573.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 45.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 40000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .120 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .060 169.0 MUD FILTRATE AT MT: .140 75.0 MUD CAKE AT MT: .160 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet • • Data Reference Point ..... .........Undefined Frame Spacing . ........... ..... ....60 .lIN Max frames per record .... ..... ....Undefined Absent value .. ........... ..... ....-999 Depth Units ... ........... ..... .... Datum Specification Block sub-type...0 Name Service Order Units Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD60 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15013 16021 15517 2017 15013 16021 RPD MWD060 OHMM 5.67 31.02 16.1596 1903 15020 15971 RPM MWD060 OHMM 4.65 33.89 14.8462 1903 15020 15971 RPS MWD060 OHMM 3.8 55.88 13.1611 1903 15020 15971 RPX MWD060 OHMM 3.04 43.67 10.8961 1903 15020 15971 FET MWD060 HOUR 0.43 36.85 3.00952 1903 15020 15971 GR MWD060 API 33.78 167.22 66.0251 1903 15013 15964 ROP MWD60 FT/H 0.27 148.38 81.6026 1902 15070.5 16021 First Reading For Entire File..........15013 Last Reading For Entire File...........16021 File Trailer Service name .......... ...STSLIB.005 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/06/15 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/15 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/06/15 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF • • End Of LIS File