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Home My WebLink About207-033MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD3-114 COLVILLE RIV UNIT CD3-114 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/12/2023 CD3-114 50-103-20544-00-00 207-033-0 G SPT 6626 2070330 1656 3431 3431 3431 3431 818 906 905 905 INITAL P Austin McLeod 4/12/2023 MITIA after RWO 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD3-114 Inspection Date: Tubing OA Packer Depth 1300 2500 2485 2485IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230412184306 BBL Pumped:1 BBL Returned:1 Friday, May 12, 2023 Page 1 of 1          1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 18042'feet 9513', 9666' feet true vertical 6884' feet None feet Effective Depth measured 9513'feet 9443', 9541', 9618'feet true vertical 6575' feet 6540', 6589', 6626'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 9678' MD 6653' TVD Packers and SSSV (type, measured and true vertical depth) 9443' MD 9541' MD 9618' MD N/A 6540' TVD 6589' TVD 6626' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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 Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2892' 2485' Burst Collapse Open Hole Liner 10592' 7415' Casing 6927' 6884' 10627' 18042' 2856' 150'Conductor Surface Intermediate 16" 9-5/8" 114' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-033 50-103-20544-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL384215, ADL372105, ALD380092 Colville River Field/ Fiord Nechelik Oil Pool CRU CD3-114 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 150' ~ ~~ Injector ~~ ~ 323-037 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: D&L Packer Packer: Baker Premier PackerPacker: Baker Premier Packer SSSV: N/A Sydney Long sydney.long@conocophillips.com (907) 265-6312RWO/CTD Engineer None None Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 3:35 pm, Apr 06, 2023 DTTMSTARTJOBTYP SUMMARYOPS1/19/2023 SUPPORT OTHER OPERATIONS3.814" G-RING TO 2159' RKB. 4.5" GR PT W/EQUAL PRONG TO 2159' RKB. PULL A1-INJ VLV. 3.78" G-RING TO 2679' RKB 3.25" G-RING TO 2679' RKB.1/20/2023 SUPPORT OTHER OPERATIONS3.00" DRIVE DOWN BAILER TO 2679' RKB COME BACK W/HYDRATES. UNABLE TO INJECT PAST HYDRATE PLUG. READY FOR COIL.1/21/2023 SUPPORT OTHER OPERATIONS(PRE RWO) FUNCTION TEST ALL T & IC LDS/GNS (COMPLETE), SBMS (PASSED), T POT (PASSED), T PPPOT (PASSED), LOWER T BODY SEAL POT (FAILED), IC POT (PASSED), IC PPPOT (PASSED), SCLD/ GAS MIT-OA PASSED TO 1210 PSI (PASSED)2/1/2023 SUPPORT OTHER OPERATIONSMILLED ICE PLUG FROM 2665' TO 3230' CTMD, BROKE THROUGH, BULHEADED 100 BBLS OF DIESEL TO TUBING. READY FOR SLICKLINE2/2/2023 SUPPORT OTHER OPERATIONSTAG HYDRATES W/ 3.77" G. RING @ 2685' RKB. RAN CLEAR DRIFT/TBG W/ 2.76" CENT & S. BAILER TO 9700' RKB. MEASURED STATIC & GRADIENT BHP @ 9571' RKB & 9371' RKB - GOOD DATA UPLOADED TO S DRIVE (MAX PSI: 4276, MAX TEMP: 139*). IN PROGRESS.2/3/2023 SUPPORT OTHER OPERATIONSRAN CLEAR DRIFT W/ 3.83" SCRATCHER TO 4000' SLM. TAG XN W/ 3.78" G. RING @ 9666' RKB. ATTEMPT TO SET 3.812" PXN BUT SAT DOWN & LEFT IN GLM @ 9513' RKB. PULLED 3.812" PXN FROM GLM @ 9513' RKB. IN PROGRESS.2/4/2023 SUPPORT OTHER OPERATIONSSET PXN PLUG & BAITED P-PRONG IN XN @ 9666' RKB. LRS PERFORM PASSING CMIT-TxIA TO 2500 PSI. PULL DV FROM GLM AT 9513' RKB. READY FOR ELINE.2/6/2023 ACQUIRE DATA (Pre RWO) T X IA DDT IN PROGRESS2/6/2023 SUPPORT OTHER OPERATIONSPERFORM PRE-RWO TUBING CUT WITH WELLTECH MECHANICAL CUTTER AT 9533' RKB, TOP OF THE FIRST PUP JOINT ABOVE THE PACKER. READY FOR BPV.2/8/2023 ACQUIRE DATA(PRE RWO) T X IA DDT, SET BPV, TEST LOWER ELASTOMER SEAL TO 2534 PSI (COMPLETE)3/4/2023 RECOMPLETION MOVE RIG OFF OF CD3-303. LAY MATS AND SPOT RIG OVER WELL CD3-1143/5/2023 RECOMPLETION RIG UP ON WELL CD3-114. HOOK UP ALL MOD'S. LOAD PITS WITH SEA WATER, SATISFY RIG ACCEPTANCE CHECK LIST. PULL BPV. DISPLACE WELL WITH CLEAN SEA WATER.3/6/2023 RECOMPLETION COMPLETE DISPLACEMENT. COMPLETE BETWEEN WELL MAINTENANCE ON BOP. SET AND TEST BPV. N/D TREE. N/U BOP. TEST BOPE.3/7/2023 RECOMPLETION Test BOPE. Pull hanger to rig floor. L/D 4.5" TS-Blue Tubing.CD3-114 RWO Summary of Operations 3/8/2023 RECOMPLETION Complete Tubing lay down. M/U Baker BHA and single in the hole with 4" DP. Dress off 4.5" stump and circulate hole clean.3/9/2023 RECOMPLETION Circulate hole clean. POOH and Lay down DP. L/D Baker BHA. Process 4.5" Tubing. M/U Packer completion and RIH3/10/2023 RECOMPLETION RIH with 4.5" TS-Blue Packer completion. Space out and land hanger. Test hanger seals, Drop Ball and Rod.3/11/2023 RECOMPLETIONSet Packer, Test tubing, Test Packer at IA, Shear SOV, N/D BOP, N/U Tree and test same. Pump diesel freeze protect. RDMO4/1/2023 SUPPORT OTHER OPERATIONSPULLED BALL AND ROD @ 9510' RKB. JOB IN PROGRESS.4/2/2023 SUPPORT OTHER OPERATIONSPULLED RHC PLUG BODY @ 9513' RKB. PULLED SOV @ 9347' RKB. SET 1' DUMMY VLV ** FRUDENBURG PACKING ** OBTAIN PASSING MITxIA TO 2500 PSI. PULLED PRONG FROM XN LOCK @ 9665' RKB. JOB IN PROGRESS.4/3/2023 SUPPORT OTHER OPERATIONSRAN INTO HYDRATES @ 2317' HOT FLUSHED AND GUAGE TBG 3.77" TO 5000' RKB. PULL XN PLUG BODY @ 9665' RKB. JOB INPROGRESS. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD3-114 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: POST RWO CD3-114 4/4/2023 oberr 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 16 15.25 36.4 150.4 150.4 65.00 H-40 Welded SURFACE 9 5/8 8.83 36.4 2,892.1 2,484.7 40.00 L-80 BTC INTERMEDIATE 7 6.28 34.8 10,627.0 6,927.1 26.00 L-80 BTCM OPEN HOLE 7 6.12 10,627.0 18,042.0 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 34.2 Set Depth 9,539.4 Set Depth 6,588.1 String Ma 4 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection TS Blue 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) 2,171.2 2,028.2 44.55 Nipple - Landing 5.000 HES 3.813'' Landing Nipple "X" HES X Nipple 3.813 9,374.7 6,504.7 58.23 Mandrel GAS LIFT 6.000 4-1/2" KBG-2 GLM (3.86" ID)Camco KBG-2 GLM 3.860 9,442.9 6,540.0 59.40 Packer 5.870 7" x 4½ D & L Packer D&L 0 3.980 9,513.0 6,575.1 60.36 Nipple - Landing 4.967 HES 3.813'' Landing Nipple "X" HES X Nipple 3.813 Top (ftKB) 9,522.7 Set Depth 9,594.5 Set Depth 6,614.7 String Ma 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection TSH Blue 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) 9,540.9 6,588.9 60.72 PACKER 6.276 Baker 7'' x 4.5'' Premier Packer Baker Premier Producti on 3.890 9,571.0 6,603.5 61.21 NIPPLE 5.210 HES 3.813'' X Landing Nipple Halliburt on X nipple 3.813 9,587.4 6,611.3 61.51 OVERSHOT 6.120 Baker PoorBoy Over Shot 6.50' of swallow Spaced 1' off NoGo Baker Poor Boy Oversho t 4.620 Top (ftKB) 9,589.0 Set Depth 9,678.2 Set Depth 6,653.5 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM 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) 9,617.9 6,625.8 62.05 PACKER 5.970 Baker Premier Packer Baker 3.875 9,665.8 6,647.9 63.03 NIPPLE 5.000 3.813" HES XN Nipple (no go)3.725 9,676.9 6,652.9 63.30 WLEG 5.000 Wireline 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) 2,171.2 2,028.3 44.56 INJ VALVE 4.5" MCX on 3.812" X-lock Halliburt on MCX 42816 76-1 4/4/2023 1.570 9,533.0 6,585.0 60.62 CUT WELLTECH MECHANICAL CUTTER CUT 2/6/2023 3.960 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) 9,374.7 6,504.7 58.23 1 DMY BK 1 0.0 4/2/2023 0.000 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) 10,627.0 6,927.1 83.39 OPEN HOLE 7.000 6.125 CD3-114, 4/5/2023 2:31:51 PM Vertical schematic (actual) OPEN HOLE; 10,627.0-18,042.0 OPEN HOLE; 10,627.0-18,042.0 INTERMEDIATE; 34.8-10,627.0 Float Shoe; 10,624.9-10,627.0 Float Collar; 10,537.8-10,538.8 WLEG; 9,676.9 NIPPLE; 9,665.8 PACKER; 9,617.9 OVERSHOT; 9,587.4 NIPPLE; 9,571.0 PACKER; 9,540.8 CUT; 9,533.0 Nipple - Landing; 9,513.0 Packer; 9,442.9 Mandrel GAS LIFT; 9,374.7 Stage Collar; 5,875.5-5,877.9 Annular Fluid - Seawater; 2,100.0-9,539.0; 3/10/2023 Annular Fluid - Seawater; 2,000.0-9,589.0; 3/5/2019 SURFACE; 36.4-2,892.1 Float Shoe ROT Silver Bullet; 2,889.8-2,892.1 Weatherford Float Collar; 2,813.9-2,815.4 INJ VALVE; 2,171.2 Nipple - Landing; 2,171.2 Annular Fluid - Diesel; 35.0- 2,100.0; 3/11/2023 Annular Fluid - Diesel; 31.1- 2,000.0; 3/5/2019 CONDUCTOR Insulated; 36.4- 150.4 Casing Hanger; 36.4-38.6 Casing Hanger; 34.8-36.4 WNS INJ KB-Grd (ft) 42.71 RR Date 4/8/2007 Other Elev CD3-114 ... TD Act Btm (ftKB) 18,042.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032054400 Wellbore Status INJ Max Angle & MD Incl (°) 93.71 MD (ftKB) 11,683.43 WELLNAME WELLBORE Annotation Last WO: End Date 3/11/2023 H2S (ppm)DateComment SSSV: NIPPLE 1 Regg, James B (OGC) From:Rig 142 <rig142@doyondrilling.com> Sent:Tuesday, March 7, 2023 3:00 PM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Cc:Doyon 142 Company Man Subject:Emailing: AOGCC BOP test form 3-7-23.xlsx Attachments:AOGCC BOP test form 3-7-23.xlsx CAUTION: 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. Rig142 3‐7‐23 BOPE test attached, Frank V Carlo III RIG 142 TOOLPUSHER RIG# (907) 670‐6002 RIG CELL# (907) 230‐2585 Personal Cell# (907) 980‐9738 Doyondrilling.com Your message is ready to be sent with the following file or link attachments: AOGCC BOP test form 3‐7‐23.xlsx Note: To protect against computer viruses, e‐mail programs may prevent sending or receiving certain types of file attachments. Check your e‐mail security settings to determine how attachments are handled. CRU CD3-114PTD 2070330 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:142 DATE:3/7/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2070330 Sundry #323-037 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/4500 Annular:250/2500 Valves:250/4500 MASP:4025 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13-5/8" 5M P Pit Level Indicators P P #1 Rams 1 3.5" x 6"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 3.5" x 6"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8" 5M P Time/Pressure Test Result HCR Valves 2 3-1/8" 5M P System Pressure (psi)3000 P Kill Line Valves 1 3-1/8" 5M P Pressure After Closure (psi)1800 P Check Valve 0 NA 200 psi Attained (sec)11 P BOP Misc 0 NA Full Pressure Attained (sec)56 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):#6@2000 P No. Valves 14 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 1 P Annular Preventer 15 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 7 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:7.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/5/23 5:31pm Waived By Test Start Date/Time:3/7/2023 2:00 (date)(time)Witness Test Finish Date/Time:3/7/2022 9:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Doyon Test Annular 250psi-lo, 2500psi-hi w/ 4" test jt. Test Rams #1 & #3 w/ both a 4" & 4.5" test jt. Test 2ea. 4" FOSV & one 4" Dart. All tests 250psi-lo, 4500psi-hi, 5min ea. on chart, with the exception of the manual & Hyd.super choke test to 2000psi. Test H2s & gas alarms, both audio & visual. Test PVT's & flow alarms. All rams functioned from both primary & remote controls. All tests good. F. Carlo / M. Sam CPAI K.Herring /W. Jeardoe CRU CD3-114 Test Pressure (psi): d142cm@conocophillips.com rig142@doyondrilling.com Form 10-424 (Revised 08/2022)2023-0307_BOP_Doyon142_CRU_CD3-114         J. Regg; 6/13/2023 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 18042'None Casing Collapse Structural Conductor Surface Intermediate Open Hole Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Open Hole: 10627-18042' 7415' Open Hole: 6927-6884' 4-1/2" 7" 16" 9-5/8" 114' 2856' Perforation Depth MD (ft): 7"10592' MD 150' 2485' 6927' 150' 2892' 18042' 10627' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6884' 18042' 6884' 4025 psi None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 384215, ADL 372105, ADL 380092 207-033 P.O. Box 100360, Anchorage, AK 99510 50-103-20544-00-00 ConocoPhillips Alaska, Inc. CRU CD3-114 Fiord Nechelik Oil PoolFiord Nechelik Oil PoolColville River Field, N/A Tubing Grade: Tubing MD (ft): 9541' Md and 6589' TVD 9618' MD and 6626' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 9678' 2/28/2023 Packer: Baker Premier PROD Packer Packer: Baker Premier Packer SSSV: None 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 and Digital Signature with Date: AOGCC USE ONLY Sydney Long sydney.long@conocophillips.com (907) 265-6312 RWO/CTD Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 7:08 am, Jan 24, 2023 323-037 10-404X X DLB 01/24/2023VTL 2/3/2023 BOP test to 4500 psig Annular preventer test to 2500 psig X X DSR-1/26/23GCW 02/03/23JLC 2/3/2023 2/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.03 08:52:08 -09'00' RBDMS JSB 020323 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 23, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Sydney Long RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over WNS Injector CD3-114 (PTD# 207-033). Well CD3-114 was drilled in 2007 as an MI injector in the Fiord Nechelik. In 2018, the 4-1/2" tubing was replaced due to a leak. It is currently shut in due to tubing by IA communication and it has become a RWO candidate. If you have any questions or require any further information, please contact me at 907-265-6312 The tubing will be cut and pulled above the current production packer. A new 4.5" completion, with a non-sealing overshot and new packer, will be ran. CD3-114 RWO Procedure Fiord Nechelik Injector Pull and Replace Tubing PTD #207-033 Page 1 of 2 Remaining Pre-Rig Work 1. T&IC-PPPOT and T&IC-POT tests. 2. Set plug in nipple at 9,571’ MD 3. MIT-T, MIT-IA or CMIT 4. Pull GLV for circulation 5. Cut tubing at ~9,500’ MD 6. Prepare well for rig within 48-72 hours of arrival. Rig Work MIRU 1. MIRU Doyon 142 on CD3-114. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/4,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to pre rig cut (~9,500’). Install new 4-½” Tubing 6. MU 4 ½” completion with overshot, nipples, packer, GLM. 7. RIH with completion. Overshot tubing stub. 8. Space out as needed. Land tubing and RILDS. Test pack-offs. 9. Drop ball and rod. 10. Pressure up tubing to set packer 11. Pressure test tubing to 4000 psi for 30 minutes and chart. 12. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 13. Confirm pressure tests, then shear out SOV with pressure differential. 14. Install BPV. Test BPV as needed. 15. ND BOPE. NU tree. 16. Pull BPV, freeze protect well if necessary. 17. RDMO. Post-Rig Work 18. Pull ball and rod 19. Pull RHC plug 20. Pull SOV. Install DV 21. MITT 22. Pull plug set in nipple 23. Install A1 injection valve in shallow nipple 24. Turn over to operations. CD3-114 RWO Procedure Fiord Nechelik Injector Pull and Replace Tubing PTD #207-033 Page 2 of 2 General Well Info: Wellhead type/pressure rating: FMC Horizontal, 5M psi top flange Production Engineer: Mark Shulman Reservoir Development Engineer: Adam Childs Estimated Start Date: 02/28/2023 Workover Engineer: Sydney Long (907.265.6312 / Sydney.Long@conocophillips.com) Current Operations: Shut In Well Type: Injector Scope of Work: Pull the existing 4-1/2” completion from planned pre-rig cut. Run new 4-1/2” completion and stack new packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: CMIT planned pre rig IC POT & PPPOT planned pre rig TBG POT & PPPOT planned pre rig MPSP: 4025 psi using 0.1 psi/ft gradient Static BHP: 4689 psi / 6641 TVD measured on 12/1/2018 CD3-114 Proposed RWO Completion PROPOSED TUBING COMPLETION •4-½" 12.6# L-80 HYD 563 •4-½" DB landing nipple @ ~2,160' MD' (3.813" min ID) •4-½"Camco KBG-2 gas lift mandrel @ ~9,350' MD •D&L Permanent Packer @ ~9,400' MD (4" ID) •4-½" X landing nipple@ ~9,450' MD (3.813" min ID) •4-½"Non-sealing Overshot @ ~9,500' MD REMAINING COMPLETION LEFT IN HOLE •Baker Premier Packer @ 9,540' MD •HES 3.813" X nipple @ 9,571' •Overshot @ 9,587' MD •Baker Premier Packer @ 9,618' MD •HES 3.813" XN Nipple @ 9,666' MD •WLEG @ 6,977' MD 9-5/8" 40# L-80 shoe @ 2,892' MD 7" 26# L-80 shoe @ 10,627' MD 16" 65# H-40 shoe @ 150' MD Openhole 10,627-18,042' RKB Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:CD3-114 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Circ IA to CISW, Set DMY, MIT T 2/11/2022 CD3-114 oberr Casing Strings Casing Description CONDUCTOR Insulated OD (in) 16 ID (in) 15.25 Top (ftKB) 36.4 Set Depth (ftKB) 150.4 Set Depth (TVD)… 150.4 Wt/Len (l… 65.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.4 Set Depth (ftKB) 2,892.1 Set Depth (TVD)… 2,484.7 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.8 Set Depth (ftKB) 10,627.0 Set Depth (TVD)… 6,927.1 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description OPEN HOLE OD (in) 7 ID (in) 6.12 Top (ftKB) 10,627.0 Set Depth (ftKB) 18,042.0 Set Depth (TVD)…Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description Tubing – Production String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.1 Set Depth (ft… 9,594.5 Set Depth (TVD) (… 6,614.7 Wt (lb/ft) 12.60 Grade L-80 Top Connection TSH Blue Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Nominal ID (in) OD Nominal (in)Make Model Com 31.131.10.00 HANGER 3.900 11.000 FMC ALP Gen II FMC Horizontal Gen ll Tubing Hanger 2,159.4 2,019.9 44.14NIPPLE 3.813 5.210 Halliburto n X nipple HES 3.813'' X Nipple 9,513.9 6,575.6 60.37 Mandrel – GAS LIFT 3.860 5.984 Camco KBG-2 Camco 4 1/2'' x 1'' KBG- 2GLM - SOV Ser. # 9,540.96,588.960.72 PACKER 3.890 6.276 Baker Premier Productio n Baker 7'' x 4.5'' Premier Packer 9,571.06,603.5 61.21 NIPPLE 3.813 5.210 Halliburto n X nipple HES 3.813'' X Landing Nipple 9,587.4 6,611.361.51OVERSHOT4.620 6.120 Baker Poor Boy Overshot Baker PoorBoy Over Shot 6.50' of swallow Spaced 1' off NoGo Tubing Description Tubing – Production String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 9,589.0 Set Depth (ft… 9,678.2 Set Depth (TVD) (… 6,653.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Nominal ID (in) OD Nominal (in)Make Model Com 9,617.9 6,625.8 62.05 PACKER 3.875 5.970 Baker Baker Premier Packer 9,665.86,647.963.03 NIPPLE 3.7255.000 3.813" HES XN Nipple (no go) 9,676.96,652.963.30 WLEG3.875 5.000 Wireline Guide Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,159.4 2,019.8 44.14 INJ VALVE INSTALLED A-1 INJ VLV ON 3.81 X LOCK. OAL= 44.5" 4/20/2019 1.250 HYS-442 9,589.0 6,612.1 61.53 TUBING CUT TUBING CUT @ 9589' RKB 2/5/2019 3.958 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 9,513.96,575.660.37 Schlum berger Camco KBG-2 1 INJ DMY BK 0.000 2/5/2022 TPC Packi ng Notes: General & Safety End Date Annotation 4/4/2019 NOTE: VIEW SCHEMATIC w/Alaska Schematic 10.0 3/18/2019 NOTE: Waiver for water-only injection cancelled 3/18/19 post RWO 7/11/2017Note: Waivered for Water-Only Injection due to TxIA on gas 1/25/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 CD3-114, 2/11/2022 7:19:54 PM Vertical schematic (actual) OPEN HOLE; 10,627.0-18,042.0 INTERMEDIATE; 34.8-10,627.0 WLEG; 9,676.9 NIPPLE; 9,665.8 PACKER; 9,617.9 OVERSHOT; 9,587.4 TUBING CUT; 9,589.0 NIPPLE; 9,571.0 PACKER; 9,540.8 Mandrel – GAS LIFT; 9,513.9 Annular Fluid - Seawater; 2,000.0-9,589.0; 3/5/2019 SURFACE; 36.4-2,892.1 INJ VALVE; 2,159.4 NIPPLE; 2,159.4 Annular Fluid - Diesel; 31.1- 2,000.0; 3/5/2019 CONDUCTOR Insulated; 36.4- 150.4 HANGER; 31.1 WNS INJ KB-Grd (ft) 42.71 Rig Release Date 4/8/2007 CD3-114 ... TD Act Btm (ftKB) 18,042.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032054400 Wellbore Status INJ Max Angle & MD Incl (°) 93.71 MD (ftKB) 11,683.43 WELLNAME WELLBORE Annotation Last WO: End Date 3/10/2019 H2S (ppm)DateComment SSSV: NIPPLE CAUTION: 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: CRU CD3-114 (PTD#207-033) Failed 30-day monitor Date:Wednesday, March 2, 2022 12:56:46 PM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, February 23, 2022 3:14 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-114 (PTD#207-033) Failed 30-day monitor Chris— CRU injector CD3-114 (PTD#207-033) was placed on water for a 30-day monitoring period. During monitoring and prep work for an AOGCC-witnessed MITIA, it was determined the IA is still pressurizing during injection. The well has been shut-in and freeze protected. We will attempt further diagnostics and submit proper notification to you when we determine a path forward. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Tuesday, February 15, 2022 8:00 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD3-114 (PTD#207-033) TxIA update Chris— An update on CRU injector CD3-114 (PTD#207-033). Over the past week we pulled the dummy valve and circulated the IA with corrosion inhibited brine and freeze protect. We then set a new high- sealibility dummy valve. The well passed a diagnostic MIT to confirm a good set of the valve. Yesterday the well was brought back on water injection for a 30-day monitoring period. If the well trend is normal during this 30-day monitor we will notify you and pursue a trial period of MI injection as well to determine if the well can be operated as a normal WAG well or if we will need to pursue Administrative Approval for water only injection. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Tuesday, November 23, 2021 12:03 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-114 (PTD#207-033) TxIA update Chris— An update on CRU injector CD3-114 (PTD#207-033). DHD performed testing on the well November 18, 2021 and the tubing packoffs passed as well as a diagnostic MITIA to 3,300 psi. Since then, however, the well has shown what appears to be TxIA communication on water injection. We intend to shut-in the well and freeze protect it the next time Operators are at the CD3 drillsite. Currently this is schedule for this Thursday, November 25th, weather permitting. In the meantime we are managing the IA pressure below the DNE of 2,000 psi. After the well is shut-in our plan is to troubleshoot the dummy valve in the GLM to determine if it is the source of communication. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Tuesday, November 16, 2021 5:03 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-114 (PTD#207-033) TxIA on gas injection Chris— CRU injector CD3-114 (PTD#207-033) was reported by Operations with apparent IA pressurization due to TxIA while on MI injection. The well is currently being WAG’d over to water injection in order to displace the MI from the tubing. Our intent is to place the well on a 30-day monitoring period of water injection as soon as the WAG is completed to determine if the well exhibits TxIA while on water injection. During this time, DHD will perform standard diagnostics including wellhead packoff tests and an MITIA. Once these diagnostics are completed and a path forward determined, we will file the appropriate paperwork to proceed. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com CAUTION: 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: CRU CD3-114 (PTD#207-033) TxIA update Date:Tuesday, February 15, 2022 8:10:38 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, February 15, 2022 8:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD3-114 (PTD#207-033) TxIA update Chris— An update on CRU injector CD3-114 (PTD#207-033). Over the past week we pulled the dummy valve and circulated the IA with corrosion inhibited brine and freeze protect. We then set a new high- sealibility dummy valve. The well passed a diagnostic MIT to confirm a good set of the valve. Yesterday the well was brought back on water injection for a 30-day monitoring period. If the well trend is normal during this 30-day monitor we will notify you and pursue a trial period of MI injection as well to determine if the well can be operated as a normal WAG well or if we will need to pursue Administrative Approval for water only injection. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Tuesday, November 23, 2021 12:03 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-114 (PTD#207-033) TxIA update Chris— An update on CRU injector CD3-114 (PTD#207-033). DHD performed testing on the well November 18, 2021 and the tubing packoffs passed as well as a diagnostic MITIA to 3,300 psi. Since then, however, the well has shown what appears to be TxIA communication on water injection. We intend to shut-in the well and freeze protect it the next time Operators are at the CD3 drillsite. Currently this is schedule for this Thursday, November 25th, weather permitting. In the meantime we are managing the IA pressure below the DNE of 2,000 psi. After the well is shut-in our plan is to troubleshoot the dummy valve in the GLM to determine if it is the source of communication. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Tuesday, November 16, 2021 5:03 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-114 (PTD#207-033) TxIA on gas injection Chris— CRU injector CD3-114 (PTD#207-033) was reported by Operations with apparent IA pressurization due to TxIA while on MI injection. The well is currently being WAG’d over to water injection in order to displace the MI from the tubing. Our intent is to place the well on a 30-day monitoring period of water injection as soon as the WAG is completed to determine if the well exhibits TxIA while on water injection. During this time, DHD will perform standard diagnostics including wellhead packoff tests and an MITIA. Once these diagnostics are completed and a path forward determined, we will file the appropriate paperwork to proceed. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-114 (PTD#207-033) TxIA update Date:Tuesday, November 23, 2021 3:36:26 PM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, November 23, 2021 12:03 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-114 (PTD#207-033) TxIA update Chris— An update on CRU injector CD3-114 (PTD#207-033). DHD performed testing on the well November 18, 2021 and the tubing packoffs passed as well as a diagnostic MITIA to 3,300 psi. Since then, however, the well has shown what appears to be TxIA communication on water injection. We intend to shut-in the well and freeze protect it the next time Operators are at the CD3 drillsite. Currently this is schedule for this Thursday, November 25th, weather permitting. In the meantime we are managing the IA pressure below the DNE of 2,000 psi. After the well is shut-in our plan is to troubleshoot the dummy valve in the GLM to determine if it is the source of communication. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Tuesday, November 16, 2021 5:03 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-114 (PTD#207-033) TxIA on gas injection Chris— CRU injector CD3-114 (PTD#207-033) was reported by Operations with apparent IA pressurization due to TxIA while on MI injection. The well is currently being WAG’d over to water injection in order to displace the MI from the tubing. Our intent is to place the well on a 30-day monitoring period of water injection as soon as the WAG is completed to determine if the well exhibits TxIA while on water injection. During this time, DHD will perform standard diagnostics including wellhead packoff tests and an MITIA. Once these diagnostics are completed and a path forward determined, we will file the appropriate paperwork to proceed. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-114 (PTD#207-033) TxIA on gas injection Date:Thursday, November 18, 2021 10:55:01 AM Attachments:CD3-114 90-day TIO.pdf CD3-114.pdf From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, November 16, 2021 5:03 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-114 (PTD#207-033) TxIA on gas injection Chris— CRU injector CD3-114 (PTD#207-033) was reported by Operations with apparent IA pressurization due to TxIA while on MI injection. The well is currently being WAG’d over to water injection in order to displace the MI from the tubing. Our intent is to place the well on a 30-day monitoring period of water injection as soon as the WAG is completed to determine if the well exhibits TxIA while on water injection. During this time, DHD will perform standard diagnostics including wellhead packoff tests and an MITIA. Once these diagnostics are completed and a path forward determined, we will file the appropriate paperwork to proceed. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CD3-114 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Post RWO NU for Inj 4/20/2019 CD3-114 boehmbh Casing Strings Casing Description CONDUCTOR Insulated OD (in) 16 ID (in) 15.25 Top (ftKB) 36.4 Set Depth (ftKB) 150.4 Set Depth (TVD) … 150.4 Wt/Len (l… 65.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.4 Set Depth (ftKB) 2,892.1 Set Depth (TVD) … 2,484.7 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.8 Set Depth (ftKB) 10,627.0 Set Depth (TVD) … 6,927.1 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description OPEN HOLE OD (in) 7 ID (in) 6.12 Top (ftKB) 10,627.0 Set Depth (ftKB) 18,042.0 Set Depth (TVD) …Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description 4.5" TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.1 Set Depth (ft… 9,594.5 Set Depth (TVD) (… 6,614.7 Wt (lb/ft) 12.60 Grade L-80 Top Connection TSH Blue Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.00 HANGER FMC Horizontal Gen ll Tubing Hanger 3.900 2,159.4 2,019.9 44.14 NIPPLE HES 3.813'' X Nipple 3.813 9,513.9 6,575.6 60.37 INJ Camco 4 1/2'' x 1'' KBG-2GLM - SOV Ser. # 3.680 9,540.9 6,588.9 60.72 PACKER Baker 7'' x 4.5'' Premier Packer 3.890 9,571.0 6,603.5 61.21 NIPPLE HES 3.813'' X Landing Nipple w/ RHC Installed 3.813 9,587.4 6,611.3 61.51 OVERSHOT Baker PoorBoy Over Shot 6.50' of swallow Spaced 1' off NoGo 4.620 Tubing Description TUBING ORIGINAL String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 9,589.0 Set Depth (ft… 9,678.2 Set Depth (TVD) (… 6,653.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,617.9 6,625.8 62.05 PACKER Baker Premier Packer 3.875 9,665.8 6,647.9 63.03 NIPPLE HES XN Nipple (no go) XXN PLUG INSTALLED 3.725 9,676.9 6,652.9 63.30 WLEG Wireline Guide 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,159.0 2,019.6 44.12 WRDP INSTALLED A-1 INJ VLV ON 3.81 X LOCK (S/N: HSS-159, OAL= 46") 4/20/2019 0.000 9,589.0 6,612.1 61.53 TUBING CUT TUBING CUT @ 9589' RKB 2/5/2019 3.958 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 9,513.9 6,575.6 Camco KBG-2 1 INJ DMY 4/14/2019 Notes: General & Safety End Date Annotation 4/4/2019 NOTE: VIEW SCHEMATIC w/Alaska Schematic 10.0 3/18/2019 NOTE: Waiver for water-only injection cancelled 3/18/19 post RWO CD3-114, 5/28/2020 4:15:48 PM Vertical schematic (actual) OPEN HOLE; 10,627.0-18,042.0 INTERMEDIATE; 34.8-10,627.0 WLEG; 9,676.9 NIPPLE; 9,665.8 PACKER; 9,617.9 OVERSHOT; 9,587.4 TUBING CUT; 9,589.0 NIPPLE; 9,571.0 PACKER; 9,540.8 INJ; 9,513.9 Annular Fluid - Seawater; 2,000.0-9,589.0; 3/5/2019 SURFACE; 36.4-2,892.1 NIPPLE; 2,159.4 Annular Fluid - Diesel; 31.1- 2,000.0; 3/5/2019 CONDUCTOR Insulated; 36.4- 150.4 HANGER; 31.1 WNS INJ KB-Grd (ft) 42.71 Rig Release Date 4/8/2007 CD3-114 ... TD Act Btm (ftKB) 18,042.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032054400 Wellbore Status INJ Max Angle & MD Incl (°) 93.71 MD (ftKB) 11,683.43 WELLNAME WELLBORECD3-114 Annotation Last WO: End Date 3/10/2019 H2S (ppm) DateComment SSSV: NIPPLE Annular Communication Surveillance 18-Aug-2021Well Name:CD3-114 Start Date:18-Aug-2021 16-Nov-2021Days:90 End Date:16-Nov-2021 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 3000 3500 4000 18-Aug-2121-Aug-2124-Aug-2127-Aug-2130-Aug-212-Sep-215-Sep-218-Sep-2111-Sep-2114-Sep-2117-Sep-2120-Sep-2123-Sep-2126-Sep-2129-Sep-212-Oct-215-Oct-218-Oct-2111-Oct-2114-Oct-2117-Oct-2120-Oct-2123-Oct-2126-Oct-2129-Oct-211-Nov-214-Nov-217-Nov-2110-Nov-2113-Nov-2116-Nov-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 1000 2000 3000 4000 5000 6000 18-Aug-2121-Aug-2124-Aug-2127-Aug-2130-Aug-212-Sep-215-Sep-218-Sep-2111-Sep-2114-Sep-2117-Sep-2120-Sep-2123-Sep-2126-Sep-2129-Sep-212-Oct-215-Oct-218-Oct-2111-Oct-2114-Oct-2117-Oct-2120-Oct-2123-Oct-2126-Oct-2129-Oct-211-Nov-214-Nov-217-Nov-2110-Nov-2113-Nov-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD MEMORANDUM TO: Jim Regg P.I. Supervisor g Jl 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 -114 COLVILLE RIV FIORD CD3 -114 Ste: Inspector Reviewed By: P.I. Supry c7 NON -CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3 -114 API Well Number 50-103-20544-00-00 Inspector Name: Man Herrera Permit Number: 207-033-0 Inspection Date: 4/28/2019 Insp Num: mitMFH190429053717 Rel Insp Num: Wednesday, May 1, 2019 Page I of 1 Packer retest Initial Depth Pretest 15 Min 30 Min 45 Min 61 u1 Well CD3 -114 TY pe In�j' a 'TVD e<,'v Tubing 198 3199 - 3198 3199 PTD 2070330 ''Type Test] SPT Testpsi 11,96 - IA 675 2010 - 1980 19`0 - BBL Pumped: _--, 1.4 BBL Returned: i - 11 OA 27 127 125 111 Interval INITAL P/F Notes: Initial MIT -IA Post RWO Per Sundry 318_534 IA Pressure testd to 2000 PSI per Operator Wednesday, May 1, 2019 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED APR 0 9 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q Operations shutdown -0 Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program Plug for Redrill ❑ lerforate New Pool ❑ Repair Well Q Reenter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic❑ Exploratory ❑ Service Q 207-033 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20544-00 7. Property Designation (Lease Numb Abandon 8. Well Name and Number: CRU CD3 -114 ADL 384215, ADL 372105 ADL 380092 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 18,042 feet Plugs measured None feet true vertical 6,884 feet Junk measured None feet Effective Depth measured 6,884 feet Packer measured 9541, 9618 feet true vertical 3,734 feet true vertical 6589, 6626 feet Casing Length Size MD TVD Burst Collapse OR INSULATED 114 feet 15 150' MD 150' TVD SURFACE 2,856 feet 9 5/8 " 2,892' MD 2485' TVD INTERMEDIATE 10,592 feet 6 10,627' MD 6927' TVD OPEN HOLE 7,415 feet 6 18,042' MD 6884' TVD Perforation depth: Measured depth: N/A feet True Vertical depth: N/A feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 9,677' MD 6,653' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PACKER 9,541' MD 6,589' TVD PACKER - BAKER PREMIER PACKER 9,618' MD 6,626' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 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: e 4 5000 990 2100 Subsequent to operation: 1e 4 15000 1080 2200 14. Attachments (required per 20 MC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q 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: 3r8 53y ltE, ✓ Contact Name: ,James Hayes Authorized Name: James Hayes Contact Email:james.c.hayes@cop.com AuthorizedTitle: Sr. Wells Engineer Authorized Signature: C Date 7 (� q /1//l Contact Phone: (907) 265-5927 : Form 10-404 Revised 4/2017 NTL // % RBDMS�aPR i 0 2019 Y�0 Submit Original Only ��ry ConomPhillips Kaska. lrtc. WNS INJ NECHELIK NIPPLE WELLNAME C133-114 WELLBORE CD3 -114 WO cpalld, esaoaz'.s4'.m PM Last Tag vahalrtlrreete taaal) An ee- Donato (e) Ena Ooh vaabm 1yr Moa By Last Tag: CO3-114 Ildresdo, Last Rev Reason NHioloved Gno Annahtion End Date Wellbore Lail Money Rev Reason: PULL 8 REPLACE TUBING 14.IU19 1D111'r 'donna Casing Strings C -In. ov-.7on .m OD an) RIBn) Toplm(BI Bepu Mia SM Depen Ovior, worm a.. Grade Top Tbreed CONDUCTOR Insulated 16 15.25 36.4 150.4 1504 65.00 H40 Welded Lasing N-taion OO BnI 10 (in) T" MB) UtDePMMKB) 9e[DepM INDL.. Wtllen ll... Groae Top Thread SURFACE 9518 883 364 2,892.1 2,4843 40D0 L-80 BTC Cuing Deacrlglon oughtlO (in) $MOBN Mada SM oepth tNo)... WIILen B..Grade rwnvhsaf IT.,., INTERMEDIATE ] 6.28 MA 10,62]0 6,92].1 26.00 L-80 8TCM Cuing Oeunpten old(in) Top(KKB) SM "'PaIWO) aN@pth Rvm...WYILen a Gree rIiTMeW Pura OPEN HOLE ] 6.12 10.6270 18,042.0 Tubing Strings Triton, Description stung Ma...ID lin) TDpms) BM DeWh M..set.011(Tool 1... N40b'MI Oraae ropCmnwaon 4.5"TUBING 4112 396 31.1 9,594.5 6,614.7 1260 LA0 TSH Blue CONWCTOR IreJb]; Y.L 150a Completion Details A"'r"br Ph'd"G^t a",.T. ;P10'0'3'SD1a Oval Top lml Naminal Top VistaMKBI (°) Ihm Ou Com ID(ra 31.1 1.1 080 HANGER FMC Horizontal Gen 11 Tubing Hanger 300 2,1594 2,019.9 4414 NIPPLE HES 3813" X Nipple 3813 9,513.9 ,575.6 60.37 INJ Camw4 "X1-KBG2GLM-SOVSer.N 3.680 NIPPLE;2.1%4 9,540.9 ,5889 60,72 PACKER artier ]°x4.5"Frothier Pecker 3,890 791.0 , 035 6121 NIPPLE HES 3.813" X Landing Nipple wl RHC IRslallea 3.813 9,587.4 ,6113 6151 OVERSHOT Baker PoorBoy Over Shot 6.W'of swallow Spaced t' o9NoGo 4620 TobinO rrhl Shing Ma to hie TOPIBKB) Soo opM(R. SM DepM(IVDI(...W Tap Connedbn Now IG, -r,, TUBING ORIGINAL 412 3.96 9,589.0 9982 6,6535 12.60 L-80 IBTM Completion Details Top 1N0) Topincl Nominal TopIMS) IXKB) f) Mm Des Com ID(Inl sURPACE sail.S21 9,689 66258 62.05 PACKER Biker Premier Packer 3.875 fi65 8 a hit a I 63.03 NIPPLE HES AN supple Inc Bol XXN PLUG INSTALLED 3]25 96769 6,652.9 I 6330 IWLEU lWaidne GDide 1 3875 zu6F neo. Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(W[h Topmcl TOPtni, V-14 r) I Dez core Run Dam ID Oni 32.0 32.0 0.00 BPV HP BPV set by FMC 3182019 0.000 9,571.0 6,603.5 6121 R CLU 3162019 0.500 WIBALL 8 ROD 9.5890 6,612.1 61.53 TUBING CUT ITUBING CUT@9589'RKB 1/512019 3958 8.6658 86479 6303 PLUG 381 XXN PLUG WI FILL EXT, OAI:1.W rz 1 0.000 8 W ;a.s1a6 Mandrel Inserts a au PPCYER; B,SIOB m N iaplKKBl TOPVVID w1s) ALke M. OD Phil Yry vaM Tyye lamb TYGe PPNSIto Phil TRO Run Ipa6 Run Dah Cwn 1 9,5139 6,95.6 Carew KBG-2 1 INJ SOV 31612019 Shea rad NIFPLE;9,5N. SOV Notes: General & Safety End Dah AnneNNon ]1111201] Note: Waiveredfor Water -Only Injectiondueto IMAOngas TUBINGCDT.:.1 4142019 NOTE: VIEW HEMATC wIA asks SMematic 100 OVERSHOT,a%74 PACKER. 6.81)9 NIPPLE XB gB. .u.... WLEG: B..9 INTERMEDNTE; 3r.ahRd7 d OPENHOLE', 10.8P.6laNdi) ° • •• Operations Summary (with Timelog Depths) CD3 -114 i Rig: NORDIC 7 Job: RECOMPLETION Time Log Stars Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth ptKB) End Ospm(ftKB) 3/1/2019 3/1/2019 1.00 MIRU MOVE RURD P Prep rig to move off well 0.0 0.0 04:30 05:30 3/1/2019 3/1/2019 4.50 MIRU MOVE RURD P Crew C/O, clean up CD3 -198, while 0.0 0.0 05:30 10:00 pad prep on CD3 -114 was being completed. Lay down Hercufite. Spot in rig mats, line up on mats. 3/1/2019 3/1/2019 0.50 MIRU MOVE RURD P PJSM for moving over well. 0.0 0.0 10:00 1030 3/1/2019 3/1/2019 2.50 MIRU MOVE RURD P MIRU on CD3 -114 spot over well set D.0 0.0 10:30 13:00 down and start shimming rig as required. 3/1/2019 3/1/2019 4.00 MIRU MOVE RURD P Set cuttings tank and Handyberm, 0.0 0.0 13:00 17:00 dike in rig. Check tubing hanger void for pressure, RU to pull adapter and tree. verified 0 psi on annulus. (Well Loaded with seawater and freeze protect. DH and BPV plugs tested prior to moving over well) Accept rig @ 1700 hrs 3/1/2019 3/1/2019 2.00 MIRU WHDBOP NUND P Nipple down tree and adaptor flange, 0.0 0.0 17:00 1900 install blanking plug 3/1/2019 3/2/2019 5.00 MIRU WHDBOP NUND P N/U Stack install HCR Valves 0.0 0.0 19:00 00:00 3/2/2019 3/2/2019 8.50 MIRU MOVE RURD T Continue to rig up BOPE choke/kill 0.0 0.0 00:00 0830 HCRs and high pressure lines, Hook up koomey lines chase lines for proper hook up. 3/2/2019 3/2/2019 9.50 MIRU WHDBOP BOPE T Attempt to test BOP unable to 0.0 0.0 08:30 18:00 maintain high pressure test isolate all surface leak points on surface. Able to maintain test on lower pipe rams, and HCR choke, HCR kill and dart valve. 3/2/2019 3/2/2019 5.00 MIRU WHDBOP BOPE T Continue chasing surface leak 0.0 0.0 18:00 2300 determine upper hanger seal was leaking, Re torque lock down screws, still leaking out IA, Pull blanking plug set HPBPV test dart, IA stopped leaking, High psi test holding against blind rams, install test it and blanking plug retest verify test, good 3/2/2019 3/3/2019 1.00 MIRU WHDBOP BOPE T Test BOP's w/ 4.5" test Jt V 250/4000 0.0 0.0 23:00 0000 Psi State inspector Brian Bixby Waived Witness of test 3/3/2019 3/3/2019 5.50 MIRU WHDBOP BOPE P Continue testing BOPE. to 250/4000 0.0 0.0 00:00 0530 psi for 5 minutes. Test 3: UPR, Man Kill, CMV, 2,6,11 Test 4: UPR, CMV, 1,16,19, Test 5: UPR, CMV 17, Test 6: Choke HCR Test 7: Choke valve manual, Dart valve Test 8: LPR, Test 9: Annular Test 10: Blinds Test 11: Super choke and hand choke 3/3/2019 3/3/2019 0.50 MIRU WHDBOP RURD P RD BOPE testing equipment blow 0.0 0.0 05:30 0600 dodwn and RD test joint pull blanking plug. 3/3/2019 3/3/2019 0.50 COMPZN WHDBOP SFTY P Pre tour Safety meeting/PJSM. on rig 0.0 0.0 06:00 06:30 and crew C/O. 3/3/2019 3/3/2019 0.50 COMPZN WHDBOP MPSP P Pull HP-BPV and lay down T -bar. 0.0 0.0 06:30 07:00 1 Page 114 ReportPrinted: 3/13/2019 . Operations Summary (with Timelog Depths) CD3 -114 Rig: NORDIC 7 Job: RECOMPLETION Time Log Stat Depth StartTme End TMe Dur (Iv) Phaee Op carie A Vdy cope Time P -T -X Operaton (IIKB) End Depth (NKB) 3/3/2019 3/3/2019 0.50 COMPZN WHDBOP RURD P MU landing joint to hanger, BOLDS. 0.0 0.0 07:00 07:30 3/3/2019 3/3/2019 0.50 COMPZN RPCOMP PULL Pull hanger to the floor, PU Wt=107K 0.0 9,589.0 07:30 08:00 RU to circulate hold PJSM for RU and expectations, 3/3/2019 3/3/2019 2.50 COMPZN RPCOMP CIRC Circulate seawater and diesel from 9,564.0 9,564.0 08:00 10:30 well to kill tank, at 8 bpm 3/3/2019 3/3/2019 0.50 COMPZN RPCOMP RURD RD circulating equipment and hold 9,564.0 9,564.0 10:30 11:00 PJSM to lay down tubing, with SLB spooler and rig crew. 3/3/2019 3/3/2019 5.00 COMPZN RPCOMP PULL Start laying down tubing to BALO 9,564.0 7,426.0 11:00 16:00 nipple, recovered 56 bands, all control line. 3/3/2019 3/3/2019 1.00 COMPZN RPCOMP PULL Clear pipe shed and laydown tubing, 7,426.0 7,426.0 16:00 17:00 lay down spooler. 3/3/2019 3/4/2019 7.00 COMPZN RPCOMP PULL Continue to laydown tubing, Gearing 7,426.0 1,215.0 17:00 00:00 tubing out of shed when full @ 4546' continue to lay down tubing to 1215' 3/4/2019 3/4/2019 6.50 COMPZN RPCOMP PULL P Continue to lay down tubing from 1,215.0 0.0 00:00 06:30 1215' to surface. 3/4/2019 3/4/2019 2.50 COMPZN RPCOMP RURD P Unload pipe shed tubing and jewlery 0.0 0.0 06:30 09:00 clean and clear floor. 3/4/2019 3/4/2019 0.50 COMPZN RPCOMP SFTY P Pre tour meeting and crew C/O 0.0 0.0 09:00 09:30 discussed plan forward. 3/4/2019 3/4/2019 2.00 COMPZN RPCOMP RURD P Lay down Nordic power tongs. Pick up 0.0 0.0 09:30 11:30 weatherford power tongs. Prep to load load pipe shed. 3/4/2019 3/5/2019 12.50 COMPZN RPCOMP OTHR P Load pipe shed for tubing run, strap 0.0 0.0 11:30 00:00 and drift completion equipment 3/5/2019 3/5/2019 4.50 COMPZN RPCOMP OTHR P Load pipe shed for tubing run, strap 0.0 0.0 00:00 04:30 and drift completion equipment 3/5/2019 3/5/2019 13.50 COMPZN RPCOMP PUTB P RIH with 4 1/2, 12.6 # L-80 TS blue 0.0 9,594.5 04:30 18:00 completion tubing 3/5/2019 3/5/2019 2.00 COMPZN RPCOMP HOSO P Locate tubing stump with overshot and 9,594.5 9,549.5 18:00 20:00 engage shear screws @ 9,595.50. PU space out and and make up 2 space out pups 1 full joint below hanger. 3/5/2019 3/5/2019 1.00 COMPZN RPCOMP THGR P Make-up hanger to string and mu 9,594.5 9,594.5 20:00 21:00 landing joint to hanger 3/5/2019 3/6/2019 3.00 COMPZN RPCOMP CIRC P PJSM, rig up to pump, pump 250 bbls. 9,594.5 9,594.5 21:00 00:00 1 inhibited seawater 3/6/2019 3/6/2019 COMPZN 9,594.5 00:00 00:00 3/6/2019 3/6/2019 1.50 COMPZN RPCOMP CIRC P Continue pumpig 250 bbls. Inhibited 9,594.5 9,594.5 00:00 01:30 sewater, and 75 bbls seawater. 3/6/2019 3/6/2019 1.00 COMPZN RPCOMP THGR P Drain stack, land tubing 9,594.5 9,594.5 01:30 02:30 3/6/2019 3/6/2019 4.00 COMPZN RPCOMP THGR T RIH T/ land tubing, hanger not setting 9,594.5 9,594.5 02:30 06:30 on depth, pull hanger, found damage by aligment slot, dress up hanger load shoulder. Still not landing out, pull hanger and inspect, found lock pins not engaged on collar, drive pins in, land hanger, run in lock dwns, test hanger seals @ 5k 3/6/2019 3/6/2019 3.50 COMPZN RPCOMP PRTS P PJSM, pressure test tubing @ 4200 9,594.5 9,594.5 06:30 10:00 psi F/ 5 min. bleed down T/ 2000 psi, and test IA @ 3000 psi F/ 30 min. test charted. 3/6/2019 3/6/2019 1.50 COMPZN RPCOMP FRZP P PJSM, Pump 75 obis, diesel down the 9,594.5 9,594.5 10:00 11:30 annulas. Page 214 Report Printed: 3/13/2019 Operations Summary (with Timelog Depths) CD3 -114 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start rime End Time Dur (hr) Phase Op Code Acbvity Code Time P -T -X Operabon Start Depth (MB) End Depth (WS) 3/6/2019 3/6/2019 0.50 COMPZN RPCOMP PRTS P Blow down and rig 9,594.5 9,594.5 11:30 12:00 down test hoses. 3/6/2019 3/6/2019 2.00 COMPZN RPCOMP NUND P PJSM, N/D bops, blow down choke 9,594.5 9,594.5 12:00 14:00 and kill lines, remove choke & kill lines. 3/6/2019 3/6/2019 4.00 COMPZN RPCOMP OTHR T Electrical fire in wiring above MCC 9,594.5 9,594.5 14:00 18:00 room, notify Security and emergency services. 3/6/2019 3/712019 6.00 COMPZN RPCOMP OTHR T Drain and blow down all lines, shut in 9,594.5 9,594.5 18:00 00:00 boilers, clean up water in rig, assess fire damage, 3/7/2019 3/7/2019 2.00 COMPZN WHDBOP EQRP T Continue to Drain and blow down all 9,594.5 9,5F4-5- 00:00 02:00 lines, shut in boilers, clean up water in rig, assess fire damage, 3/7/2019 3/7/2019 2.00 COMPZN WHDBOP FRZP P Hook up lines from annulus to kill line, 9,594.5 9,594.5 02:00 04:00 close blind rams, open annuals and u tube annulus and tubing. 3/7/2019 3!712019 2.00 COMPZN WHDBOP EQRP T Continue to install heater trunks, hook 9,594.5 9,594.5 04:00 06:00 up work lights in rig continue removing fluids from rig. 3/7/2019 3/8/2019 18.00 COMPZN WHDBOP EQRP T Continue rig electrical diagnostic 9,594.5 9,594.5 06:00 00:00 3/8/2019 31812019 6.00 COMPZN WHDBOP EQRP T Continue rig electrical diagnostic. 9,594.5 9,59:F-5- 00:00 06:00 Remove bad wiring, and continue pulling new wires. drill new lugs, install lugs on 636 wire 3/8/2019 3/8/2019 6.00 COMPZN WHDBOP EQRP T Continue installing new wiring, Install 9,594.5 9,594.5 06:00 12:00 new lugs, crimp lugs on 636, land all 3 runs of 636. cables. 3/8/2019 3/9/2019 12.00 COMPZN WHDBOP EQRP T Stat up Gen #2, warm up & start boiler 9,594.5 9,594.5 12:00 00:00 #1, clean up work areas, put #2 generator on lines, put #2 boiler on line, inspec steam system & heaters. wire up charge pump, and test rotation. Start test verifaction on equipment. 3/9/2019 3/912019 6.00 COMPZN WHDBOP EQRP T Replace 3 contactors in SCR 2, 9,594.5 9,594.5 00:00 06:00 continue test verifcation on electrical Equipment 31912019 3/9/2019 8.50 COMPZN WHDBOP EQRP T Continue test verifications, confirm 9,594.5 9,594.5 06:00 14:30 with CPAI electricians theree are no exsisting electrical issues with the compromised wiring that was replaced. Finalize test verifications and start diagnosis of SCR -2. 3/9/2019 3/9/2019 0.50 COMPZN WHDBOP SFTY P PJSM for testing BPV in preparation to 9,594.5 9,594.5 14:30 15:00 1 1 ND BOPE. 3/9/2019 3/9/2019 0.50 COMPZN WHDBOP RURD P Verify BOPE are all in the open 9,594.5 9,594.5 15:00 15:30 position. RU testing lines and test chart. 3/9/2019 31912019 0.50 COMPZN WHDBOP PRTS P Pressure test BPV from below for 10 9,594.5 9,594.5 15:30 16:00 minutes. bleed off pressure 319/2019 3/9/2019 0.50 COMPZN WHDBOP RURD P RD testing equipment 9,594.5 9,594.5 16:00 16:30 3/9/2019 3/9/2019 0.50 COMPZN WHDBOP SFTY P PJSM for ND and NU BOPE 9,594.5 9,594.5 16:30 17:00 3/9/2019 311012019 7.00 COMPZN WHDBOP NUND P ND BOPE and NU adapter and tree as 9,594.5 9,594.5 17:00 00:00 directed by FMC. Test adapter to 5000 for 10 minutes. test tree test bad, remove tree & chang out sbms seal 3/10/2019 3/10/2019 1.50 COMPZN WHDBOP NUND T CHange out SEMS seal on tree, NIU 9,594.5 9,594.5 00:00 01:30 tree. Page 314 ReportPrinted: 3/13120191 , Operations Summary (with Timelog Depths) 1 CD3 -114 Rig: NORDIC 1 Job: RECOMPLETION Time Log StartTime End Time our (hr) Phase Op Cotle Acbvhy Cotle Time P -T -X Operation Stan Depth (RKB) End Depth (MB) 3/10/2019 3/10/2019 5.00 COMPZN WHDBOP PRTS T Attempt to test tree, test failed. Wait 01:30 0630 for FMC rep to arrive on location, personnel on Doyon 142 and no other reps available unable to contact rep servicing Nordicl and Doyon 142. 3/10/2019 3/10/2019 0.50 COMPZN WHDBOP PRTS T Re -torque LDS and attempt to re -test. 06:30 07:00 3/10/2019 3/10/2019 0.50 COMPZN WHDBOP PRTS P Pressrue test tree to 400/4950 psi for 07:00 07:30 1 10 minutes each. 3/10/2019 3/10/2019 1.50 COMPZN WHDBOP RURD P RD testing equipment, secure well and 07:30 0900 dress Wellhead with jewelry, Release rig at 0900 3/10/19 3/10/2019 3/10/2019 COMPZN WHDBOP RURD P RD test pump and hoses secure 09:00 0900 wellhead dress out tree. T=0 psi IA=O psi OA= Page 4/4 Report Printed: 3/13/2019 12FD ao-7—o33 Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Thursday, March 7, 2019 4:59 PM To: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) Cc: Senden, R. Tyler; ALP RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nordic 1 on 3/07/2019 Attachments: CD3 -114 BOPE Letter 3 07 2019.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on CD3 - 114. Please let me know if you have any questions. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 7, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nordic 1 with a written report. Time of BOPE Use: 3/7/2019 at 02:30 hours Well Location: CD3 -114 API Number: 50-103-20544-00 PTD Number: 207-033 Rig Name: Nordic 1 Operator Contact: Dusty Ward. (o) 907-265-6531. (c) 503476-2519. Dusty.Ward@conocophillips.com Operations Summary On 3/6/2019 Nordic 1 had set the packer and tested the Tubing and IA after landing the new completion in CD3 -114. A prejob safety meeting was held for the ND of the BOP operation, at approximately 14:45, smoke and flame was noticed near a cable tray by the MCC room. The fire was extinguished by Rig crews and the Alpine fire department. The Alpine fire department extinguished all sources of ignition and a fire watch was positioned to monitor for any re -ignition. The well has a plug/packer combination downhole as primary barrier. A BPV was set and tested to 1000 psi in the direction of flow in preparation for removing the BOPE. 75 BBL's of diesel was pumped into the IA for freeze protection following the NU. The blind rams were closed at 02:30 hours on 3/7/2019. Diesel from IA to tubing was u -tubed below the blind rams through the BPV. The blind rams will be retested at the start of the next well. The next operational step is to ND the BOPs, and NU the tree. BOPE Used: Blind Reason for BOPE Use: The Blinds were used to provide a flow path for freeze protect to equalize from the IA to the tubing. Due to the lack of power on the rig to remove the BOPE and install the tree the blinds were functioned closed and a hose was connected from the choke side of the BOPE to the inner casing valve to provide a flow path for the freeze protect to equalize between the two strings. Actions To Be Taken: The next operation of the well is to ND the BOPS as soon as the rig can safely do so. The entire BOPE system will be retested on the next well per normal operating procedures. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty Ward Rig Workover Engineer CPAI Drilling and Wells Loepp, Victoria T (DOA) From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Monday, March 4, 2019 6:21 PM To: Loepp, Victoria T (DOA) Subject: Re: [EXTERNAL]Re: CD3 -114 BOPE Testing Issues Follow Up Flag: Follow up Flag Status: Flagged I am sorry Victoria, I never got back with you. We were able to isolate our pressure testing to the lower hanger seals and we were able to get a pressure test on the BOP to 4500 psi. Thanks, James Hayes C: 918.914.9609 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Monday, March 4, 2019 4:37:57 PM To: Hayes, James C Subject: [EXTERNAL]Re: CD3 -114 BOPE Testing Issues James, If the lower hanger seals are leaking then the BOP test pressure can be lowered from 4500 psig to 3300 psig for the first BOP test. Thanx, Victoria Sent from my iPhone On Mar 2, 2019, at 8:46 PM, Hayes, James C <James.C.HavesCa@conocoohillips.com> wrote: Victoria, I am sending this email a bit prematurely because it is still a decent hour. Nordic 1 is having issues testing BOPE's because we have developed a leak in our upper tubing hanger seals. We have a way of isolating the upper hanger seals, however if the lower hanger seals are leaking then we will be unable to test BOPE's without pressuring up the IA, tubing, packer, & plug below the wellhead. We do not feel comfortable testing all of this equipment to our testing pressures of 250 low and 4500 high. if our lower seals are leaking we would like to request a variance from you guys to allow us to go ahead and pull the hanger plus 2 joints of tubing, pick up a storm packer, run it in hole, & set it? This will allow us to pressure test our BOPE's against this barrier. Would you guys allow this? After setting the plug we did pressure test the Tubing & IA and against the packer/plug to 3,300 psi and had a passing test 2/20/19. Thanks, James Hayes COP - Alaska RWO Engineer C: +1918.914.9609 0: +1907.265.6927 Loepp, Victoria T (DOA) From: Regg, James B (DOA) Sent: Monday, March 4, 2019 4:13 PM To: Loepp, Victoria T (DOA) Subject: RE: CD3 -114 BOPE Testing Issues Follow Up Flag: Follow up Flag Status: Flagged Have they confirmed if both upper and lower seals are leaking? From what is stated below they should be able to test as required if the lower hanger seals not leaking. Snce they already tested the tubing and IA (and therefore the packer and plug to 3300 psi), it seems this is just an issue of the test pressure. What about testing to a lower pressure (3000- 3300psi) for the initial test, then back to the 4500psi for subsequent BOPE tests? Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.reee@alaska.gov. From: Loepp, Victoria T (DOA) Sent: Monday, March 4, 2019 3:57 PM To: Regg, James B (DOA) <jim.regg@alaska.gov> Subject: Fwd: CD3 -114 BOPE Testing Issues With a plug in the tubing, this variance looks ok to grant. Are you fine with it? Sent from my iPhone Begin forwarded message: From: "Hayes, James C' <James C Haves@conocophillips.com> Date: March 2, 2019 at 8:46:19 PM AKST To: "Loepp, Victoria T (DOA)" <victoria.loepp@alaska.Rov> Cc: "Senden, R. Tyler" <R Tyler Senden@conocophillips.com> Subject: CD3 -114 BOPE Testing Issues Victoria, I am sending this email a bit prematurely because it is still a decent hour. Nordic 1 is having issues testing BOPE's because we have developed a leak in our upper tubing hanger seals. We have a way of isolating the upper hanger seals, however if the lower hanger seals are leaking then we will be unable to test BOPE's without pressuring up the IA, tubing, packer, & plug below the wellhead. We do not feel comfortable testing all of this equipment to our testing pressures of 250 low and 4500 high. If our lower seals are leaking we would like to request a variance from you guys to allow us to go ahead and pull the hanger plus 2 joints of tubing, pick up a storm packer, run it in hole, & set it? This will allow us to pressure test our BOPE's against this barrier. Would you guys allow this? After setting the plug we did pressure test the Tubing & IA and against the packer/plug to 3,300 psi and had a passing test 2/20/19. Thanks, James Hayes COP - Alaska RWO Engineer C: +1918.914.9609 0: +1907.265.6927 C.&L C63-114 P'M 7,670330 Regg, James B (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Thursday, March 7, 2019 4:59 PM To: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) R�Q 11 liq Cc: Senden, R. Tyler; ALP RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nordic 1 on 3/07/2019 Attachments: CD3 -114 BOPE Letter 3 07 2019.doc Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on CD3 - 114. Please let me know if you have any questions. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 7, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nordic 1 with a written report. Time of BOPE Use: 3/7/2019 at 02:30 hours Well Location: C133-114 API Number: 50-103-20544-00 PTD Number: 207-033 Rig Name: Nordic 1 Operator Contact: Dusty Ward. (o) 907-265-6531. (c) 503-476-2519. Dusty. Ward@conocophillips.com Operations Summary: On 3/6/2019 Nordic 1 had set the packer and tested the Tubing and IA after landing the new completion in CD3 -114. A pre job safety meeting was held for the ND of the BOP operation, at approximately 14:45, smoke and flame was noticed near a cable tray by the MCC room. The fire was extinguished by Rig crews 4±� and the Alpine fire department. The Alpine fire department extinguished all sources of ignition and a fire watch was positioned to monitor for any re -ignition. The well has a plug/packer combination downhole as primary barrier. A BPV was set and tested to 1000 psi in the direction of flow in preparation for removing the BOPE. 75 BBL'S of diesel was pumped into the IA for freeze protection following the NU. The blind rams were closed at 02:30 hours on 3/7/2019. Diesel from IA to tubing was u -tubed below the blind rams through the BPV. The blind rams will be retested at the start of the next well. The next operational step is to ND the BOPS, and NU the tree. BOPE Used: Blind ✓ Reason for BOPE Use: The Blinds were used to provide a flow path for freeze protect to equalize from the IA to the tubing. Due to the lack of power on the rig to remove the BOPE and install the tree the blinds were functioned closed and a hose was connected from the choke side of the BOPE to the inner casing valve to provide a flow path for the freeze protect to equalize between the two strings. Actions To Be Taken: The next operation of the well is to ND the BOPS as soon as the rig can safely do so. The entire BOPE system will be retested on the next well per normal operating procedures. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty Ward Rig Workover Engineer CPAI Drilling and Wells • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 20,2018 TO: Jim Regg P.I.Supervisor Kej I -I Zh( €' SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA,INC. CD3-114 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-1 14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry\_176/2-- NON-CONFIDENTIAL .6/2 — NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-114 API Well Number 50-103-20544-00-00 Inspector Name: Lou Laubenstein Permit Number: 207-033-0 Inspection Date: 2/11/2018 Insp Num: mitLOL180212124321 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-114 Type Inj W 'TVD 6626 ' Tubing 2160 , 2160 - 2160 - 2160 PTD 2070330 - Type Test SPT Test psi 3000 ' IA 900 3320 3260 • 3250 ' BBL Pumped: 2.5 BBL Returned: 2.2 - OA 79 T 256 - 243 - 239 Interval REQVAR - P/F P Notes: MITIA per AIO 30.009 to Maximum anticipated injection pressure SCANNED Tuesday,February 20,2018 Page 1 of 1 37033 Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> IAL'177 Sent: Tuesday,June 27, 2017 1:54 PM C'�� //7 To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, Chris D (DOA) Subject: CRU CD3-114 Diagnostic MIT-IA Attachments: MIT CRU CD3-114 02-28-17.xlsx Hello All— Please see the attached form for a diagnostic MIT-IA performed on CRU CD3-114(PTD#207-033) in February. Please let me know if you have any questions or need more information. Thanks, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED ‘7,.,EP 420i-? • • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoot aalaska.aov AOGCC.InspectorsCrtalaskagov phoebe.brooks(cialaska.gov chns.wallace( alaska.gov OPERATOR: ConocoPhillips Alaska Inc. Rei9 (;(2-711-1 FIELD/UNIT/PAD: Colville River Field/Colville River Unit/CD3 DATE: 02/28/17 OPERATOR REP: SumrallNan Camp AOGCC REP: • Well CD3-114 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2070330• Type Inj W Tubing 1746 - 1747 1748 1746 • Type Test P Packer TVD 6626 ' BBL Pump 4.9 . IA 370 3300 - 3275 - 3275 - Interval 0 Test psi 1657 " BBL Return OA 32 80 78 - 78 - Result P `-'''' • Notes: Diagnostic MITIA WellPressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) 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 Inj Tubing Type Test Packer ND 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 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 In) 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 Inj Tubing Type Test Packer ND 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 Inj Tubing Type Test Packer ND 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 Inj 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 CD3-114 02-28-17 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday,June 20, 2017 4:34 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CD3-114 (PTD#207-033) Chris, Injection well CRU CD3-114(PTD#207-033) has been on MI injection for a limited monitoring period to determine if the well has TxIA communication on gas. The IA pressure has increased and indicated that it does. The 30-day monitoring period will not be completed, and we are working to swap the well back to water injection service. Our intent is to leave the well on water injection and submit to you a proposal for Administrative Approval to continue with water-only injection. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SUMS JUN 2 32.0F. 1 • 111 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, May 9, 2017 11:05 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CRU CD3-114 (PTD#207-033) Monitor update Chris, This is meant to serve as an update on Alpine injector CRU CD3-114(PTD#207-033),which was previously reported for suspect IA pressurization while on MI injection and subsequently WAG'd to water to demonstrate integrity on water injection. The well showed integrity during the water monitor period and has remained on water injection awaiting a circ out prior to starting a 30-day monitor on MI injection. Limited operational access has delayed operations ability to circulate the annulus. However, CPAI plans to initiate the circulation work within the next week or so,and to leave the well on water injection until the circulation and WAG to MI. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED M \! :: 2: 11 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Saturday, April 1, 2017 3:00 PM To: Wallace, Chris D (DOA) Subject: CRU CD3-114 (PTD# 207-033) Attachments: CD3-114 90-Day TIO jpg Hello Chris— Alpine injector CRU CD3-114 (PTD#207-033) has been on water injection for a 30-day monitoring period as part of a diagnostics suite following an observation of high IA pressure while on MI injection. No IA pressure anomalies were seen while on water injection, and the well passed an MITIA and packoff testing as well. We informed you earlier of our intent to circulate the annulus and then perform a 30-day monitoring period on MI injection and it is still our intent to do this. Currently, however, Doyon 19 is blocking access for wireline to CD3-114 and we are unable to perform the circulation. Our intent is to continue water injection in the well until it is operationally possible to access it—and then begin the planned 30-day monitoring period on MI injection. Please let us know if you have any questions or disagree with this plan. Thank you very much, Travis SCANNED APR 1 o 2017 Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 .. 0 • 1::: 1 I lk Sa-k 1 ai u It c 1111 c.- 11144' es = k., ai = us c T- ca _ r..'.. ....7.. :.! . aa es -I To o IL 0 = 1 4 , E E — o o , es— . %.. a, = CI c c 4 tC) 'I v- Ps e- 0 v. 0 IN cckj() U rsi - en R V • . ,.. . r. , ..._. CI a) I 8 8 8 8 8 8 8 c. CI CY I I 0 - - Cd'il MON •L1,).• I 1 3 ,t. .2 isd • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday,January 31, 2017 5:28 PM To: Wallace, Chris D (DOA) Subject: RE:CD3-114 (PTD#207-033) Hello Chris— Alpine injector CRU CD3-114(PTD#207-033) is to undergo diagnostics and a monitoring period to address signs of IA pressurization,see email below. Surface piping work is being performed on the drillsite,and we would like to shut-in CD3-114 for this work prior to beginning the diagnostic work. The shut-in period is expected to be approximately 5 to 7 days,and at its conclusion we propose bringing CD3-114 back online to water injection,allowing it time to stabilize, and then performing the MITIA, DDT,and packoff testing. If this testing passes,we will then commence the 30-day monitoring period on water injection as described below. Please let us know if you have any questions or disagree with this plan. Thank you very much, Travis From: NSK Well Integrity Supv CPF3 and WNS Sent:Sunday,January 29, 2017 4:26 PM To: 'chris.wallace@alaska.gov'<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK DHD Field Supervisor <NSKDHDFieldSupervisor@conocophillips.com> Subject:CD3-114(PTD#207-033) Chris, Alpine injector CRU CD3-114(PTD#207-033) has exhibited signs of IA pressurization while on MI injection. DHD will perform initial diagnostics on the well,which will include an MITIA, DDT,and packoff tests, as soon as reasonably possible. The well will be WAG'd to water injection for a 30-day monitor period to determine if the well has integrity while on water injection, and the annulus will be circulated with clean fluid. If no communication is detected during this monitoring,we will WAG the well to gas injection and monitor for a 30-day period on MI to determine if TxIA communication exists on gas injection. 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, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday,January 29, 2017 4:26 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK DHD Field Supervisor Subject: CD3-114 (PTD#207-033) Attachments: CD3-114.pdf; CD3-114 90-day TIO plot jpg Chris, Alpine injector CRU CD3-114(PTD#207-033) has exhibited signs of IA pressurization while on MI injection. DHD will perform initial diagnostics on the well,which will include an MITIA, DDT,and packoff tests, as soon as reasonably possible. The well will be WAG'd to water injection for a 30-day monitor period to determine if the well has integrity while on water injection, and the annulus will be circulated with clean fluid. If no communication is detected during this monitoring,we will WAG the well to gas injection and monitor for a 30-day period on MI to determine if TxIA communication exists on gas injection. 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, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED 2097 1 • 1 0v ?; `y 0 a0 o (L) - .` 02Z ) U) U ( U) UUnv2UCLIwwMwvaa22zaLaa amara aaamaauraaracao` a' o` acmo: acaamaa! alceam wwwWwwwwwwwwwwwwwwwwwwwwwwwwwwww L Z L D Z L L L - - w_ L - • L c_ 0 O M O V t4) M r tD O O P O P CO r tL) N N M O O sV1 r O c1" O N O1 .n O tD tD wO N tD P O) O N CO N O V t!) N M 4I M M P N tf) tD N M tC? 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~ Well History File Identifier Organizing (done) ^ Two-sided I~I II'I~I II II I II ~II ^ Rescan Needed III II~IN II II III III RESCAN Color Items: DIGITAL DATA Diskettes, No. ~ OVERSIZED (Scannable) ^ M ps: ^ Greyscale Items: ^ Other, No/Type: Other Items Scannable b nner l ~~ l ~ S L ^ Poor Quality Originals: ~R, arge ca a ~- ®~' OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria '' Date: ~~ ~~ ~~ /s/ Project Proofing III II~IIIIIIII VIII BY: Maria Date: #~ /~ ~ ~~ _ /s/ + ~~ =TOTAL PAGES Scanning Preparation x 30 = (Count does not include cover sheet) BY: Maria Date: ~~ l ~ ~ / ~ /s/ Production Scanning Stage 7 Page Count from Scanned File: ~_ (Count does include cov r sheet) Page Count Matches Number in ScannJing Prleparation: YES NO BY: Maria ~ Date: ~/ j`~/ ~ ~ lsl ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO f BY: Maria Date: /si~i~i~iu~i~u i~~i~ Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Comments about this file: Date: /s/ Quality Checked II! !I'~~! ~!) Il~1 Il~ 10!6/2005 Well History File Cover Page.doc 0 0 , a STATE OF ALASKA n7'S 3j21 1 ALASKA OIL AND GAS CONSERVATION COMMISSION ,� ";; 0 013 ANNULAR DISPOSAL APPLICATION AOGCC 20 AAC 25.080 1. Operator 3. Permit to Drill 2 013 Name: MAR 2 2 207 -033 ConocoPhiilips Alaska SCANNE 4. API Number: 50- 103 - 20544 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3 -114 , 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 -111, CD3 -112, CD3 -113, CD3 -118, CD3 -115, CD3 -117, Torok and Seabee formation, shale, siltstone and sandstone CD3 -121, CD3 -122, CD3 -123, CD3 -124, CD3 -125, CD3 -128 CD3 -199, CD3 -127 X i5,c b) Waste receiving zone: lo 1 b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None 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 1658' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 45,773 bbls as of March 4, 2013 densities range from diesel to 12# /gal 2119 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 70,000 bbls. TO � i 7 0 Q�Q� Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- / contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated sta ate: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 22 Mar - 13 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: , :. "' ' _ iP c _, ,) - FIT Records w /LOT Graph 0 Well Schematic (Include MD and TVD) El Cement Bond Log (if required) ❑ fe .r: •I',.t,'- Surf. Casing Cementing Data El Other El previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is correct to the best of my knowledge. ;� Signature: Z ` Title: l L ' ./ 0 Printed Phone Name: Chip Alvord Number: 265 - 6120 Date: j (2,p 13 Commission Use Only Conditions of approval: LOT review and approval: C- L.f ✓ Subsequent form required: / V - 4.23 . Approval number: 17 AP PROVED BY Approved by: / I 9 _„z,..,____ COMMISSIONER TH E COMMISSION Date: 3_2/ — /3 O Ap c� i � i2' J �13MS Ma-24 4 "J 4134013 Submit in Duplicate ` J 1 • • ConocoPhillips Alaska, Inc. RECEIVED Post e Box 100360 Anchorage, Con c Phi 111 Anchoragorage, Alaska ka MAR 99510 -0360 0 6211/3 Telephone 907 - 276 -1215 AOGCC March 6, 2013 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3 -114 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD3 -114 (sundry permit # 312- 088) be re- permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Because of the remote location and limited available annuli on CD3, it is requested that the expiration date limit be extended. CD3 -114 was re- permitted for annular disposal of 70,000 bbls on March 22n 2012 per Sundry #312 -088. As of March 5, 2013 a total volume of 45,773 bbls had been injected into CD3 -114 for annular disposal. The projected volume that will be injected by the expiration date of March 22 is approximately 52,000 bbls which is well below the permitted volume of 70,000 bbls. Due to the short drilling season at CD3, it can be challenging to meet the permitted volume within one year. Until we drill additional wells, this leaves CD3 -114 as one of the only wells on the pad available for annular disposal. Injection pressure has typically been significantly below our original surface casing shoe test pressure. Please find attached form 10 -403AD and other pertinent information as follows: 1. Copy of CD3 -114 annular disposal permit #312 -088. ` • 2. List of wells on CD3 pad and the lateral distance from the surface casing shoe. t �.��` C 3. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, mud and brine pit rinse from mixing operations. Information already at AOGCC from previous sundry: 1. Surface and Intermediate Casing description .r 2. Surface and Intermediate Casing Cementing Report & Daily Drilling Report during cement job ✓° 3. Pressure Calculations for Annular Disposal -/ 4. Casing and Formation Test Integrity Report (LOT at surface casing shoe) ,// 5. Information regarding wells within '/4 mile radius at AOGCC (total of 12 wells): CD3 -111, CD3 -112, CD3 -113, CD3 -118, CD3 -115, CD3 -117, CD -121, CD3 -122, CD3 -123, CD3 -124, CD3 -125, CD3 -128 If you have any questions or require further information, please contact Nina And son at 265 -6403; Rb Stinson can also be reached by calling 263 -4449. ,,A Ct•4Jk Sincerely, F �\\aO Nina Ande cc: Drilling Engineer CD3 -114 Well File Chip Alvord ATO -1570 Sharon Allsup -Drake ATO -1530 Anadarko STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service IS 6. Permit to Drill Number: 207 -033 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD3 -114 I 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20544 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 312 -088 3/22/2012 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 31453 200 347 32000 27 3/4/2010 4/21/2010 CD3 -121, CD3 -301A, CD3 -123, totals (obis): CD3 -302A 2012 /1st 0 0 5 5 0 2012 / 0 0 20 20 0 2nd 2012 / 3rd 0 0 0 0 0 2012 / 4th 0 0 0 0 0 2013 / 1st • Total Ending Report is due on the 20th Volume 31453 200 372 32025 27 (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 SCANNED APR 0 9 2013 Description(s): *freeze protect volumes only, injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. � ` /� Signature: , Date: t(15 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • sifyf SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 f PHONE (907) 279 -1433 0 FAX (907) 276 -7542 Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, CD3 -114 Sundry Number: 312 -088 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval that increases the cumulative volume limit for annular disposal of drilling wastes in the above - referenced well to a total of 70,000 barrels. 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 to Superior Court unless rehearing has been requested. Sincerely, / Cathy / " . F erster Chair DATED this day of March, 2012 Encl. \��I 77� 0 A THE STATE Alaska Oil and Gas qfAL ASKA Conservation Commission c GOVERNOR SEAN PARNELL 333 West Seventh Avenue ' *? • Anchorage, Alaska 99501 -3572 � F ALAS � Main: 907.279.1433 Fax: 907.276.7542 Chip Alvord Alaska Drilling Manager 0 0 3 3 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, CD3 -114 Sundry Number: 313 -117 Dear Mr. Alvord: 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 to Superior Court unless rehearing has been requested. Sincerely, Cathy :. Foerster Chair 7L DATED this 2I day of March, 2012 Encl. • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO MISSION AR 0 2 2012 ANNULAR DISPOSAL APPLICATI • N 20 AAC 25.080 .1 011 & Gas Cons. Commission 1. Operator 3. Permit to Drill ArtGflf'tdye Name: 207- 633 iJ~ ConocoPhillips Alaska 4. API Number: 50 -103- 20544 -00 2. Address: 5. Well P.O, Box 100360, Anchorage, Alaska CD3 - 114 • 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) Al! wells within one - quarter mile: a) Interval exposed to open annulus: CD3 - 111, CD3 - 112, CD3 - 113, CD3 - 118, CD3 - 115, CD3 - 117, Torok and Seabee formation, shale, siltstone and sandstone CD3 -121, CD3 -122, CD3 -123, CD3 -124, CD3 -125, CD3 -128, CD3 -199, CD3 -127 b) Waste receiving zone: b) water wefts within one mile: Sand layers below the C30 marker in the Seabee formation None 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 1658' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: . 32,000 densities range from diesel to 12# /gal 2119 14. Estimated volume to be disposed with this request 15. Fluids to be disposed: 70,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any • 1 - Apr - 12 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) ❑ Cement Bond Log (if required) ❑ FIT Records w /LOT Graph ❑ Surf. Casing Cementing Data ❑ Other El previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ac ak_ Signature: Title: 6�, ttr^6 .,. r - Printed Phone j Name: Chip Alvord Number: 265 -6120. Date: g Z - f Z ©( Commission Use Only Conditions of approval: • LOT review and approval: Subsequent form required: — yZ 3 Approval number . ) �C APPROVED BY pp by: p Date: 3 J} J COMMISSIONER THE COMMISSION Z • Approved b Form 10 -403AD R 6/2004 INSTRUCTIONS ON REVERSE OUP L. Lt bmit in Duplicate Y • • ( �. n; anal ,hannon, „ i fluids f m the' • You. have r equested to o d.i:�Pose c ° new - product Olean `�p ro Lltzids' matultirrcl routine Alpine as well as the clean up mixing Of. Mud and ceme » ". • at A' • . oi? base mud. ' • from cleaning out the to ks at the mud tient in preparation for using The f the 'new pxcX1UCt" clean up • fluids Commission had pTeY�iouv csf+rbved clisnosing °- j uid oral options v annular disposal at CD '1 pad Alpine, Class' 1 an d Class 2 disp Due to the geological setting are rdS>ressor, €i c(�, had established the 1.i.mit ti.4r of lizaitecl. • Phillips' px da � PPPS6 as. opti to pie CoMmi.SSion'.s satisfaction and..annulai diatosal •vras'apY ro'vecl as the , raved practical. and environmental alternative• It these requests the waste fluids are no di.�terent tran previously approved • and, Cleve] opfien�� aztiv activities at Alpine. T the isSio r ta ve o aut b o ou th?a message. By copy of • The Cnnissiariexs. have at�thor3,7s me tq send y this' em i email, Phillips is authorized tt, dispose of cJ.�san up fluids 'as described in . your em il 7.or, . Please call with any , Est Tom Maunder, PD Sr. Pet/ tile= Engineer ACGCC ALP Coord wrote: > D ar Mr. Maunder, ' › A ' noted in the .attached email, Tom Manson previously requested t ion to .dispose of nevi- Product clean up fluids such. as cement > t�tlt.h.ox.i,za., op�ratiana via annular > rii? sate,, and mud, anei. hrite pit rinse from miXing based on the > iO� ap i.ved - sh un dc1. posal at the CD1 Alpine- Drill2Sit.e InJ1999 sit d clo n t tie�3 wr > integral �a}?1'relaat such ionshi p disposal the mu > integral reltp of the facility and the > operation- riificanC. i leaY: > Phil.li s '?a11].ci like to continuing Pursuing this request. ralaarati.an tnx thy. • �rtit of trarilt a . mud mixing facility; m st oCr.ur .>n.:p months. temporary use ofoil based mud products at Alpine in. the he coming > she availability of annular disposal as-an option for tankr sly ne fluids and > siM lar wastes would. g°re�atlY. faci.l.itate this, process. r {' thin large snie beneficially s'eu ed, however, there is a concern th > zation • rinse ia1 quantity f• fluid that • c•ou).d be -gener. ate d during te • • xocess.) > clean up p• > cantairi either new and used mud 7 . pr ods at the mud mixing facility may b injected in D. products. Though ri rinses in contact with used products m > the permitted class 7:'1` disposal a sll. Dnosa7 well t fg2 )"' wherecthe.teuld is > a denfially be raging. to . critical a11. > a diffi.cu�.ty managing soli d . d's content. The class 1 viea:L1].ncati,Qni tor > lifeline fat facility infraetr•uc:ture, being the, dispo. i iocatti n to this Annular disposal 'resents a preferred' waste management > c]oui tic effluent,. and it is a priority to prerent az�.Y > disposal facility. > alternative in this case. • I • • Note to File CD3 -114 ( 207 - 033...310- 037...312- 088...313 -117) Colville River Unit (Fiord Pool) ConocoPhillips Alaska, Inc ConocoPhillips has made application for an extension of time for annular disposal for the subject well. Current total Annular disposal is 45,773 bbls as of March 4, 2013. CPAI did not request a volume increase in their application and so the total allowed remains at 70,000 bbls. This document (as previously created by Guy Schwartz) reviews the pertinent information for the well and recommends approval of ConocoPhillips' request. AOGG should date the approval as March 23, 2013 to give a full year to the existing sundry. -- Surface casing was cemented back to surface. No problems were reported. Approximately 134 bbls of cement was circulated to surface with full circulation during the job. The net cement remaining in the surface hole was 73% XS of the calculated hole volume. Reciprocation was stopped prior to cement reaching the shoe. -- On the initial leak off test, the pressure rises smoothly to 16.4 EMW where it breaks over and flattens out for a easily recognizable break -over. One barrel of fluid was pumped to reach break -over. The pressure declined only slightly during the observation period to about 16.3 EMW. The initial leak off indicates that the surface casing shoe is well cemented. - -No problems were reported drilling the intermediate hole. The 7" casing was run and successfully cemented with a two stage job. The first stage went as planned though returns are not mentioned. The second stage (Qannik) also went as planned with 38 bbls placed in the 7" annulus. ( TOC should be at 4800' md). No mention of reciprocation was noted. - -An injectivity test down 9 -5/8" x 7" annulus was conducted. Pressure steadily increases until a change in slope at 13.6 EMW. The slope increases to 14.2 EMW at break -over. The pressure declined with additional pumping to 13.8 EMW. During the observation period, the pressure declined to 12.7 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 -114. The nearest surface shoe is CD3 -115, about 306' distant which is another annular disposal well (AD # 309 -087). Additional wells in the area include are CD3 -117 at 720 ft away and CD3 -122 is 400 feet away. Additional wells drilled in the area since first starting AD include CD3 -125 and CD3 -128 which are 353' and 468' away at surface shoe respectively. Examination of the cementing information and LOT data did not reveal anything to preclude granting CPAI's request. Chris Wallace, prior reviews by Guy Schwartz Sr Petroleum Eng. AOGCC G:\AOGCC\ Common \tommaunder \Well Information\By Subject\Annular Disposal \130313 -- CD3- 114.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 0 6. Permit to Drill Number: 207 -033 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD3 -114 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG El 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20544 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation Ell or Final ❑ 312 -088 3/22/2012 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 SLA NED JUL 1 8 20! fluids, formation fluids and any necessary water added Previous CD3 -121, CD3 -301A, CD3 -123, totals (bbls): 31453 200 347 32000 27 3/4/2010 4/21/2010 CD3 -302A 2012 / 1st 0 0 5 5 0 2012 / 0 0 20 20 0 2nd 2012 / 3rd 2012 / 4th 2013 / 1st . Total Ending Report is due on the 20th Volume 31453 200 372 32025 27 (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 Description(s): *freeze protect volumes only, injectivit' test I hereby certify that the foregoing is true and � correct to the best of my knowledge. & �� Signature: A r r�'l, Date: — 7( L 00 !z Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate r ' STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 12012 REPORT OF ANNULAR DISPOSAL AOGCC 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 111 6. Permit to Drill Number: 207 -033 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD3 -114 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG El 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20544 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 310 -037 / 312 -088 3/22/2012 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 347* 347 totals (bbls): 2010 / 1st 25703 100 0 25803 21 3/4/2010 3/29/2010 CD3 -121, CD3 -301A 2010 / 5750 100 0 5850 6 4/16/2010 4/21/2010 CD3 -123, CD3 -302A 2nd 2010 / 3rd 0 0 0 0 0 2010 / 4th 0 0 0 0 0 2011 / 1st 0 0 0 0 0 IP Total Ending Report is due on the 20th Volume 31453 200 347 32000 _ 27 (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 Description(s): *freeze protect volumes only dra _ EL) APR 1 1 ZU1 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ylR.-ca,__ Date: C( a( Lo t z_.. Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 12012 REPORT OF ANNULAR DISPOSAL AOGCC 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 111 6. Permit to Drill Number: 207 -033 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD3 -114 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20544 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation Ei or Final ❑ 310 -037 / 312 -088 3/22/2012 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 31453 200 347 32000 27 3/4/2010 4/21/2010 CD3 -121, CD3 -301A, CD3 -123, totals (bbls): CD3 -302A 2012 / 1st 5 5 2012 / 2nd 2012 / 3rd 2012 / 4th 2013 / 1st ill Total Ending Report is due on the 20th Volume 31453 200 352 32005 27 (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 Description(s): *freeze protect volumes only, injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Date: -t 2,,te 2_ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • A "^ •- ei SEAN PARNELL, GOVERNOR J7 l�.a ALASKA OIL AND GAS ` 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1 HSSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 3 3, Re: Colville River Field, CD3 -114 Sundry Number: 312 -088 Dear Mr. Alvord: SclitiiiNED MAR 'I ZO$Z Enclosed is the approved Application for Sundry Approval that increases the cumulative volume limit for annular disposal of drilling wastes in the above - referenced well to a total of 70,000 barrels. 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 to Superior Court unless rehearing has been requested. Sincerely, / Cathy ". F erster • Chair DATED this day of March, 2012 Encl. • • untitled Enclosed is the approved Application for Sundry Approval that increases the cumulative volume limit for annular disposal of drilling wastes in the above - referenced well to a total of 70,000 barrels. Page 1 1 • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 Conoc9Ph i l l i ps Telephone 907 - 276 -1215 D March 2, 2012 1 Alaska Oil and Gas Conservation Commission j 0 2 2012 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 Iaska -1! as Cons. €' , . Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on e l CD3414- -- - - -- - - _ . . Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD3 -114 (sundry permit # 310- 037) be re- permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Because of the remote location and limited available annuli on CD3, it is requested that the volume limit described in 20 -ACC 25.080 d. 1. be raised from 35,000 bbl to 70,000 bbl. Until we drill more new wells, this leaves CD3 -114 as one of the only wells on the pad available for annular disposal. Injection pressure has typically been significantly below our original surface casing shoe test pressure. On 4/10/10 we had disposed of 32,000 bbl of fluid into CD3 -114. We stopped using the annulus for disposal . because of the volume limit per the original sundry. Please find attached form 10 -403AD and other pertinent information as follows: 1. Copy of CD3 -114 annular disposal permit #310 -037. 2. Updated plan view of adjacent wells 3. List of wells on CD3 pad and the lateral distance from the surface casing shoe. • 4. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, mud and brine pit rinse from mixing operations. 5. Information regarding remaining wells within 1 /4 mile radius included in sundry package: CD3 -199, CD3 - 127 Information already at AOGCC from previous sundry: 1. Surface and Intermediate Casing description 2. Surface and Intermediate Casing Cementing Report & Daily Drilling Report during cement job 3. Pressure Calculations for Annular Disposal 4. Casing and Formation Test Integrity Report (LOT at surface casing shoe) 5. Information regarding wells within 1 /4 mile radius at AOGCC (total of 12 wells): CD3 -111, CD3 -112, . CD3 -113, CD3 -118, CD3 -115, CD3 -117, CD -121, CD3 -122, CD3 -123, CD3 -124, CD3 -125, CD3 -128 If you have any questions or require further information, please contact J.G. Samuell at 265 -6309; Chip Alvord can also be reached by calling 265 -6120. Sincerely, t ..2. J. . Samuell cc: Drilling Engineer CD3 -114 Well File Chip Alvord ATO -1570 Sharon Allsup -Drake ATO -1530 Anadarko J 3 - IV s . R IV D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 7 ^r °? ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 !, , , ,. ,.; c -nlis .i: si r, 1. Operator 3. Permit to Drill ,• !t:;' =' Name: 207-033' ConocoPhillips Alaska 4. API Number: 50 -103- 20544 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3 -114 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 -111, CD3 -112, CD3 -113, CD3 -118, CD3 -115, CD3 -117, Torok and Seabee formation, shale, siltstone and sandstone • CD3 -121, CD3 -122, CD3 -123, CD3 -124, CD3 -125, CD3 -128, CD3 -199, CD3 -127 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None 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 1658' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 32,000 • densities range from diesel to 12# /gal 2119 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 70,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 1 - Apr - 12 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) ❑ Cement Bond Log (if required) ❑ FIT Records w /LOT Graph ❑ Surf. Casing Cementing Data ❑ Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ACak Title: Printed Phone Name: Chip Alvord Number: 265 -6120 Date: 3 I Commission Use Only Conditions of approval: �/ LOT review and approval: c Subsequent form required: / 0 - ( Z Approval number: 31 ez._" - o() Q� 8 APPROVED BY Approved by: 01 i / COMMISSIONER THE COMMISSION Date:3_ n ., _ Form 10 403RD Rev. ./2004 � / � STRUCTION V SE ORIGINA1. Submit in 13/0 l� • 0 sc � \ AusE[A\ SEAN PARNELL, GOVERNOR ` ,J + ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Mr. Chip Alvord Alaska Drilling Manager ConocoPhillips P.O. Box 100360 Anchorage, Alaska Re: Colville River Field, Fiord Oil Pool, CD3 -114 Sundry Number: 310 -037 Dear Mr. Alvord: 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 to Superior Court unless rehearing has been requested. Sincer: �� l T. Se: ou•x, Jr. ��"" P) Ch. it ' DATED this!/‘day of February, 2010 RECEIVEbs wH 1 0 2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIOIssa Oil Gas Cents. C liklitli ANNULAR DISPOSAL APPLICATION Anchorage 20 AAC 25.080 1. Operator 3. Permit to Drill Name: 207 -033 • ConocoPhillips Alaska 4. API Number: 50- 103- 20544 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3 - 114 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratlgraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD3 - 111, CD3 - 112, CD3 - 113, CD3 - 118, CD3 - 115, CD3 - 117, Torok and Seabee formation, shale, siitstone and sandstone CD3 - 122 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker In the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albion Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1658' 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 2119 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 - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 22 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) aa Cement Bond Log (if required) E] FIT Records w /LOT Graph Surf. Casing Cementing Data El Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: At_ak Title: [ DA Y tj - 1 ,— M► Printed / , / Phone �\ 1 Name: llii�� /�J wry Chip Alvord Number: 265 -6120 I I F V 1 �/ Commission Use Only Conditions of approval: LOT review and approval: Subsequent form required: 0" 1 4(25 Approval number: ✓` � -0v 7 DLJPLI C ATS M Approved by: COMMISSIONER THE COMMISSION Date: Project: Western North Slope Quarter Mile ConocoPhillips Site: CD3 Fiord Pad IY, h' Well: CD3 -114 t 1320 feet) Wellbore: CD3 -114 Design: CD3 -114 (CD3- 114/CD3 -114) radius Plot Ground Level: 0.00 RKB: CD3.114: 00 50.050 (CO3.114:) Northing /ASP Y: 6003563.04 EastingJASP X: 1526142.21 1 <I CD3 -121 G 3 � 111 1250— _- G O B 1000— - - s 7" 9 5/8" x 12 1/4" • - CD3 -122 95/8" 4 \ ' / 750— _ 1 13 0 95/8 "x121/ A. - C2 <? 500 — c - 9 -518" 9-5/8" : c - 250 — 9 -5/8" x - 0 _ 11b 10 -3/4" x 13 -1/2" Lc) r -250— 127P - _ O GD3 _- _ m 12 - x 9 5/8" x 12 1/4" G 0 , " CD3 - 114 Surf Csg -500— GO312 x 10-3/4" ;13-1/2" 10 9 - • 9 -5/8" x 12 -1/4" -750— 3 LA - G On'1 • -1000 _ 15 CP -1250— _ O � KV' 1 rL1 -1500 I r I l i r i i i i l i i i i -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 West( -) /East( +) (500 ft/in) SURFACE CASING SHOE SEPARATION FROM CD3 -114 CD3 -114 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 387024.7 6003781.8 - - Distance Ann. from Surface csg. Surface Details @ Disp. Object Shoe X Surface csg. Surf LOT casing TVD Annular Wells AOGCC Permit # Permit Date Source well Ann. Vol.** Start Date End Date well Coord. Shoe Y Coord. (ppg) (ft) LOT (ppg) Comments CD3 -108 Y 2575 389300.3 6004986.4 2431 16.9 not for annular disposal CD3 -110, CD3 -111, CD3 -112, CD3 -307, CD3 -109 Y 306 -020 1/20 CD3 -302 1/20/2006 3/4/2007 2140 388917.3 6004780.2 18.0 2414 16.0 Extended to 70000bbl, exp 03/17/07 CD3 -110 Y /-- �._....--------- 1803 388563.7 6004720.7 16.7 2439 15.8 Low surface shoe test CD3 -114, CD3 -111 Y 307 -066 , I71 /7n CD3 -301 26674 3/20/2007 4/20/2007 1223 387821.0 6004710.6 17.4 2469 14.6 CD3 -113, CD3- 107/CD3 • CD3 -112 Y 307 -002 307 32007 1/22/2007 3/16/2007 712 387406.8 6004382.6 18.0 2485 15.1 Also known as CD3 -107, second annlus, CD3 - 107/307 Y 2644 389627.9 6004245.8 18.2 2479 15.3 after cut and pull operations Feb 2007 CD3 -113, CD3 -118, CD3 -303, CD3 -302 Y 308 -036 CD3 -107L1 56647 2/12/2008 1/1/2010 1918 388815.4 6004469.9 18.0 2505 15.0 CD3 -316, CO3 -113 Y 307 -067 CD3 -316A 31964 1/15/2008 3/20/2008 623 387636.7 6003901.1 18.0 2475 16.3 CD3 -114 Y 310 -037 32000 0 387024.7 6003781.8 16.4 2485 14.2 CD3 -301 Y 2300 388541.7 6005510.5 16.2 2493 15.1 Low surface shoe test CD3 -305, CD3 -316A Y 308 -127 CD3 -115 31881 1/11/2009 2/16/2009 1858 388868.2 6003548.0 18.0 2476 15.9 CD3 -303 Y 308 -426 CO3 -117 23833 2/14/2009 3/27/2009 3069 390091.0 6003906.6 18.0 2488 15.9 CD3 -118 Y 671 386456.5 6003425.3 16.6 2489 15.7 Low surface shoe test I. CD3 -305 Y 309 -379 32000 2/1/2010 3182 390145.4 6003158.0 18.0 2471 14.70 CD3 -115 Y 309 -087 CD3 -304 32000 2/1/2010 306 386822.0 6003553.0 18.0 2471 13.30 CD3 -304 Y 309 -380 -.493 4/1/2010 3808 390789.9 6003209.3 18.0 2472 15.20 ..� CD3 -117 Y _- - -__..---------- ____-_ - 721 386471.4 6003320.0 16.2 2447 14.80 CD3 -106 Y 311 -021 31229 1586 388447.6 6004482.6 17.0 2475 15.00 CD3 -121 Y 889 387435.6 6004569.9 16.3 2457 14.90 ---CD3 -122 Y 311 -035 CD3 -128 2/2/2012 2/29/2012 405 387238.8 6004125.0 16.3 2484 14.30 ,fit,CD3-123 Y 405 386932.7 6004176.7 ✓ 2468 15.20 Low surface shoe test 4g4 Y 310 -088 2/1/2010 3/1/2011 1102 386016.2 6003338.3 15.9 2472 14.60 Low surface shoe test !i CD3 -125 Y -111111111 353 386677.0 6003842.4 i 16.5 2459 16.20 / D CD3 -128 N 468 386577.5 6003642.6 2452 Low surface shoe test CD3 -198 N 1748 388580.6 6004577.5 18.1 2455 0 CD3 -199 N 1048 387876.3 6004392.6 16.8 2457 15.70 0 CD3 -127 N CD3 -119 N 2696 388774.1 6005833.1 CD3 -130 N 815 75 387798.5 6003743.7 CD3 -120 N 969 387993.5 6003788.7 Lateral distance in feet, between surface casing shoes, in the X -Y plane ** As of Nov 5, 2009 Note that this sheet is not the definitive record for annular disposal volumes • - . • . . . . • . . . . . . • - . , . . . • — . , . . • • . . . . . . . . ( _ . . - . . TOM an ShannOni . . . You have requested tO diSpohe Cf "new-product' Clear) bp fluids from:the • . .. routine. mixing Of. Mud and cementat Alpite as well as.the clean up fluids resulting . trot ' • cleaning out the tanksat the. mud plat in preparation for using .0i ba6e tud. The CoMmission had preViougy aPPrOv:6d dispOsing tf the 'new pxoduot' clean up • • fluids , . via annular dispoSal at CD 1 pad, . . Due to the geological at Alpine, Class' 1 and Class 2 disposal options are. limited- Phillips' ptodcdessor, A.R.&), had established the limitation of (i.4,0Ppal optiOna to the CoMmlaSicrifs satisf6Ctiou andannblerdiatosalwas as the praCtical and environmental alternative. ' . In he requests the waste fluids are no different than previously approved . are. the result of the .ongoing deVelooMent actiVittes at Alpine. . • The OdmMisSioners. have atthoriZed me to sand you thin meseage- By copy of t,his' . . . email, Phillips is authorized to dispose of 'clean up fldideas described in . your email. . Please call with any gUestions. Comm Maunder, PE Sr. Petrdleum Engineer • . AOGCC . ( . . . Al/P'EnV Coord wrote; Dear Mr, ivlaunder, > , , > Aanoted in the-attached email, Tom Manson previously requested . > authorization to.digpose of new-product clean up fluids such. as cement > rinsate, and mud and. brine pit rinses from miXing operations via annular. > ii6actiOn in perMitted,wells at the-A1pinoCD2 Drill Site AS rioted below, • AOGCC aPpraVed such disposal at the Drill Site In 1999, based on the > integral relationship of the mud mixing facility and the on-site drilling > operation- > . • > PhilliPS vpuld like to Continuing Pursbin h - s request. SignifiCant Olean. . . > out of tanks t theMbd mixing faCilityMust OcCut.in.preParation.for thd. > temporary use Of.oil based mud products at kipine in the months. > The availability of annular disposal as an option for tank -rinse fluids and > similar wastes would. qreatlyfacilitete this procps s. iTypically, routine > rinse are beneficially reused reudr however, there is a concern about the > potential quantity di' fluid that'cbuld be . generated during thin large scale > clean up Process.) . > . • . . > Tanks ac the mud mixing facility may•Contain either new and used mud >products.. Though rinses in contact with used products may be injected in > the permitted class .:11 disposal well (C1:519 ringes,of new products would > potentially ))4 rOutsd to the.cla's*.I. CaisK44: well (WD-.:02, where there is > a.clitfidule2rmanaging solids Cc:intent. The eleit4 1 well is a critical : > lifeline fai faCility inftaStructUrO, being the disposal location for, all, . > domestic effluent, and it is a p4.lorityio compromise to this . > diSpOsal facility. Annular disposal esent preferred waste management > alternative in this. case. . ( > . . . t 11111 . • • • • • • Thsnk yog very Much fpr Yous? ConsideratiOn of thi4 . L - 40eat. Please do not >: hesitate to contac t in ot alternate tia email or phone at (907} 670-4200 > if you have questions or. need Sddiaonal information. .> nnon Donnelly ' • • > Alpine FieldEnvirOnmental CoordinatOr > (907) 610-4200 Forwarded by L? Env CoordiPPCD on. 11/02/01 •1250 PM • > > LIP Env Cord 0E01/01 1.2-: 45 P? • : tOk„g*sittdOrgAdran . cc: sUbject: Reauest to Inject Cement Rinsace at CD 2 • > • Dear Mt. biaunder, • iiijectlion of CW11‘lit dnset nd fluids from mild and brine mixing > operations the Alpine'nmd plant facility into approved annular disposal > operations was by the Alaska Oil And Gas conservation Commission > (AOGCCI. in tbe•March 17,. 19 letter from ADOCC tdDoggThester o! ARCO > Alaska, Ind., now Phillips Alaeka, Inc, (PAI). nle apPti5al•wae granted. tti > PAI specifitallOr Alpins Drill cD1 and authorized-Volumes up to • > 35,000 barrels through the annulat'soace. > ?KT request that this . aoproval be. extended to drilling. operations at Alpine, > Drill Site CD Cement mixing . 45peretions or setting surface conduatprs • > tii. be takingPlate the Grind -and Inject facility whIei is currently > attached to .the drilling rig at C)32% Upon cOmPlecien Of the cementing in • > of the c:ohdilct6e, the lines and tank will haVe to be rinsed and the > rinsate disposed of. PAI request approval to inject tbis rins4te, 4nd other .clean-up ro= el mud and t)rine. mixing onctations into the annual > space -of aPproVed located at Drill Site CD2. > /T yOu have any qUestions please contact n at 67074200. > TO Xanson > Alpine Field Environmental Compliance torn_srfaundervof • • • • • • • • • . Cement Detail Report Aollirw-letrinatzi CD3 -199 ConocoPhilltps String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/7/2011 00:00 Cernent_Det'ails :._ F. Description Cementing Start Date Cementing End Date - Wellbore Name Surface Casing Cement 2/10/2011 21:25 2/10/2011 23:59 CD3 - 199 Comment Pump 90 bbls of 10.0 ppg mud with nut plug marker (5 ppb) at 6 bpm with 330 psi. Next pumped 35 bbls of 8.34 ppg Biozan preflush with nut plug marker(5 ppb) at 5 bpm with 200 psi. Reciprocated 15' to 20'. P/U 122k Ibs and S/O 112k lbs. Dowell pump 5 bbls water and pressure test lines to 3500 psi, good. Bleed off pressure and drop bottom plug. Mix and pump 54.2 bbls Mud Push II spacer (10.5 ppg), pump at 6 bpm w/ 230 psi. Mix and pump 247.3 bbls (308 sx) AS lite lead cement (10.7 ppg, 4.51 cuft/sx, 20.7 gal water /sx), pump at 6.3 bpm with 150 psi. Mix and pump 56.3 bbls (272 sx) Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.105 gal water /sx), pump at 5.8 bpm with 200 psi. Shut down and drop top plug. Dowell kick out top plug w/ 20 bbls water, pump at 5 bpm with 55 psi. Rig displace cement with mud pump #1 and 10.0 ppg mud. Pump at 7 bpm with initial circulating pressure of 300 psi. After pumping 160 bbls at 7 bpm and a final circulating pressure of 700 psi, slowed rate to 3 bpm. ICP at 3 bpm was 500 psi with a FCP of 525 psi. Bump plug at 1750 strokes, 175.8 bbls (calculated displacement of 1755 strokes with 0.1005 bbls /stroke) and pressured up to 1075 psi. Held pressure for 5 minutes. CIP @ 23:59 hrs 2/10/2011. Note: Reciprocated until S/O decreased from 112k lbs to 85k lbs. Landed on hanger at 2345 hrs (landed at 800 strokes into displacement which was 40 bbls before cement returns). Circulated 56.4 bbls of good 10.7 ppg cement to surface. Ogaelif Stages a `z SM Stage # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? • Surface Casing Cement Cement surface casing 26.5 2,673.0 Yes 56.4 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 6 525.0 1,075.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 90 bbls of 10.0 ppg mud with nut plug marker (5 ppb) at 6 bpm with 330 psi. Next pumped 35 bbls of 8.34 ppg Biozan preflush with nut plug marker (5 ppb) at 5 bpm with 200 psi. Reciprocated 15' to 20'. P/U 122k lbs and S/O 112k Ibs. - Dowell pump 5 bbls water and pressure test lines to 3500 psi, good. Bleed off pressure and drop bottom plug. Mix and pump 54.2 bbls Mud Push II spacer (10.5 ppg), pump at 6 bpm w/ 230 psi. Mix and pump 247.3 bbls (308 sx) AS lite lead cement (10.7 ppg, 4.51 cuft/sx, 20.7 gal water /sx), pump at 6.3 bpm with 150 psi. Mix and pump 56.3 bbls (272 sx) Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.105 gal water/sx), pump at 5.8 bpm with 200 psi. Shut down and drop top plug. Dowell kick out top plug w/ 20 bbls water, pump at 5 bpm with 55 psi. Rig displace cement with mud pump #1 and 10.0 ppg mud. Pump at 7 bpm with initial circulating pressure of 300 psi. After pumping 160 bbls at 7 bpm and a final circulating pressure of 700 psi, slowed rate to 3 bpm. ICP at 3 bpm was 500 psi with a FCP of 525 psi. Bump plug at 1750 strokes, 175.8 bbls (calculated displacement of 1755 strokes with 0.1005 bbls /stroke) and pressured up to 1075 psi. Held pressure for 5 minutes. CIP @ 23:59 hrs 2/10/2011. Note: Reciprocated until S/O decreased from 112k Ibs to 85k Ibs. Landed on hanger at 2345 hrs (landed at 800 strokes into displacement which was 40 bbls before cement returns). Circulated 56.4 bbls of good 10.7 ppg cement to surface. Flufd t _ ?: z , sx . Fluid Type Fluid Description . Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Biozan Pre Flush 35.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.00 Additives Additive Type Concentration Conc Unit label Biozan Additive Type Concentration Conc Unit label Fresh Water Additive Type Concentration Conc Unit label Nut Plug .�.! _ Z,� ,� ��:�I�`v� - -y_ f ' - - -- .. �"z...c �_ �..: � � � � .• ��.. �- _ _'3"' - , ._ 'C . - -- �"� - ate.' --'_a k N-.�vi; ' �-8•+. ?�_ r> �� .^`. ��+x."a F ._,_ Y Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 54.2 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Page 1/2 , Report Printed: 2/20/2012 • • • Cement Detail Report CD3 -199 ConocoPhillips ' String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/7/2011 00:00 Additives Additive Type Concentration Conc Unit label Mudpush 11 Cement ° Fluids &.Additives . ' Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) AS Lite Lead 26.5 2,016.4 308 247.3 Yield (ft' /sack) Mix H2O Ratio (gal/sa... Free Water ( %) Density (Ib /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.51 20.70 10.70 Additives Additive Type Concentration Conc Unit label Fluid r Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) G Tail 2,016.4 2,673.0 272 G 56.3 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (Ibigal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.11 15.80 54.9 4.50 Additives Additive Type Concentration Conc Unit label S - 002 accelerator 0.8 %BWOC Additive Type Concentration Conc Unit label D - 046 antifoamer 0.2 %BWOC Additive Type Concentration Conc Unit label D -065 dispersant 0.3 %BWOC Page 2/2 Report Printed: 2/20 /2012 • • Security Level: AK Development l Al <k l Daily Drilling Report r ;a '& l!s • . -� CD3 -199 Report Number: 4 CaanocoPhilli'ps Rig: DOYON 141 Report Date: 2/10/2011 AFEType " £= Network/D# _ __'TotN:AFE }SLp , _ 10296871 7,774,999.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 199 Development FIORD NECHELIK 3.08 4.0 0.00 2,673.0 2,673.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 13, 486.18 49,262.80 432, 363.24 1,011,227.04 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/7/2011 2/7/2011 25.70 23.19 2.51 3/2/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,662.8ftKB Ops and Depth @ Morning Report 24hr Forecast Installing well head Install wellhead and N/U 13 -5/8" BOPE. Test same. P/U 8 -3/4" intermediate drilling BHA. Last 24hr Summary Finish conditioning and circulating mud from 9.6 ppg to 10.0 ppg. POOH on elevators to HWDP at 906' MD (19 stands DP). UD 6 joints of 5" HWDP and rack back remainder of HWDP (6 stands). .Reciprocated through several tight spots between 800' - 600' MD. UD MWD tools and bit. Rig up casing running equipment. M/U 9 -5/8" 40# L -80 BTC -M shoe track and circulate 60 bbls through Frank's fill -up tool. Continue running casing to shoe setting depth of 2662.88' MD. Broke circulation on joints #29 - 30 and #62 - 64 while RIH. Circulated 194 bbls (surface to surface) on joint #35 at 1410' MD. Land hanger and R/U cementing equipment. Establish circulation down 9 -5/8" casing and stage up rate to 7 bpm. Condition and circulate mud to reduce PV/YP in preparation for cementing. PJSM on cementing. Pump 90 bbls of 10.0 ppg mud with nut plug marker followed by 35 bbls of 8.34 ppg Biozan preflush with nut plug marker. Switch over to Dowell and pump 5 bbis water. Pressure test lines to 3500 psi. Drop bottom plug and pump 54.2 bbls Mud Push fl spacer. Pump 247.3 bbls AS lite lead cement followed by 56.3 bbls Alpine tail cement. Drop top plug and kick out with 20 bbls water using Dowell unit. Displace cement with rig mud pump #1 and 10.0 ppg mud. Bump plug at 1750 strokes (175.8 bbls) and pressure up to 1075 psi. Hold pressure for 5 minutes. CIP at 23:59 hrs on 2/10/2011. Landed hanger on landing ring. Circulated 56.4 bbls of good 10.7 ppg cement to surface. General Remarks Weather Head Count No Incidents, No Accidents. Rig & camp on Hi -line. -20° Wind SW @ 10 MPH, Patchy fog and 41.0 flurries Granville Rizek, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer Elmo Cecchetti, Rig Supervisor Rig Supervisor Time Log ° Start End - Dur Time Depth Start, Depth End Tune Time_; 0 (hrs) Phase Op Code '_- Activity Code P T X _" _Trbl Code TtbL Class .. _ E (ftKB) , _ (ftKB) ; Operation P 00:00 00:30 0.50 SURFAC DRILL TRIP P 2,300.0 2,673.0 RIH 4 stands of drill pipe racked back during conditioning and circulating of mud. No fill encountered. 00:30 01:00 0.50 SURFAC DRILL OWFF P 2,673.0 2,673.0 Monitor well on trip tank for flow. 01:00 02:30 1.50 SURFAC DRILL TRIP P 2,673.0 906.0 POOH on elevators from 2673' MD to HWDP at 906' MD (19 stands DP). No hole problems encountered. 02:30 03:30 1.00 SURFAC DRILL PULD P 906.0 170.0 Check well for flow (10 minutes) then UD 6 joints of 5" HWDP. Rack back remainder of HWDP (6 stands). Recorded overpull at 790', 730', 640', and 610' MD. Reciprocated through each spot several times until no drag was observed. 03:30 04:45 1.25 SURFAC DRILL PULD P 170.0 0.0 UD jars and NMFDC. Break bit and drain motor. Small piece of wood found lodged in bit. Bit grade: 1- 2- WT- 2- E- 2 -NO -TD 04:45 06:00 1.25 SURFAC DRILL PULD P 0.0 0.0 Download MWD. Break out and UD MWD tools. 06:00 06:30 0.50 SURFAC - DRILL PULD P 0.0 0.0 Lay down tools from the rig floor. 06:30 07:00 0.50 SURFAC DRILL OTHR P 0.0 0.0 Clean rig floor. Latest BOP Test Data Page 1/5 Report Printed: 2/20/2012 • Security Level: AK Development ' „ Daily Drilling Report CD3 -199 Report Number: 4 ConoccPhi1ltps Rig: DOYON 141 Report Date: 2/10/2011 Time Log , Start Ertl- Dur Time mempiam , Depth Start `Depth E nd K Time Time' Chrs) ; phase °, Op Code , ActiviyyCode p Tx Trbl Codeli TrbY_Class CftKB) _ , (ftKB) Operator 07:00 07:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Pre job safety meeting on rigging up to run casing. 07:15 08:30 1.25 SURFAC CASING RURD P 0.0 0.0 Rig up casing running tools for 9 -5/8" casing (long bales, elevators, slips, tongs). 08:30 08:45 0.25 SURFAC CASING SFTY P 0.0 0.0 Pre job safety meeting on running 9 -5/8" 40 ppf L -80 BTC -m casing. 08:45 09:45 1.00 SURFAC CASING RNCS P 0.0 105.0 M/U 9 -5/8" casing shoe track as per detail: Rays Oil tool float shoe joint, thread lock joint, HES Sure Seal II float collar joint. All baker locked. 09:45 10:00 0:25 SURFAC CASING CIRC P 105.0 115.0 Circulate 60 bbls through float equipment using Franks fill -up tool with 9 -5/8" shoe above conductor shoe at 108'. Circulate 3 bpm, 4 bpm, 5 bpm, and 6 bpm. 10:00 12:00 2.00 SURFAC CASING RNCS P 115.0 1,085.0 Continue running casing to noon depth of 1085' MD (27 joints). Baker lock pin of 4th joint. Make up torque 10,000 ft lbs. Installed centralizers as plan: 10' above shoe on stop ring, collar of joint #1, 10' below box of joint #2 on stop ring. Every collar to joint # 13, then every odd joint to joint # 63. Use Run -N -Seal dope on threads. 12:00 12:30 0.50 SURFAC CASING RNCS P 1,085.0 1,205.0 Circulate joint #29 and #30 in hole with Frank's fill -up tool due to THICK MUD and short displacement volume. Pump 20 bbls each at 2 bpm while running each joint. 12:30 13:00 0.50 SURFAC CASING RNCS P 1,205.0 1,370.0 Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing F/ 1205' T/ 1370' (joint 34 in the hole). 13:00 13:45 0.75 SURFAC CASING CIRC P 1,370.0 1,410.0 Make up joint # 35, stab Frank's fill -up tool. Circulate 194 bbls (surface- surface), reciprocate 20' F/ 1410' T/ 1390', staging up F/ 2 bpm T/ 3.5 bpm. After 70 bbls pumped, increase pump rate to 4 bpm, after 90 bbls increase to 5 bpm, after 120 bbls increase pump rate to 6 bpm w/ 400 psi. 13:45 15:30 1.75 SURFAC CASING RNCS P 1,410.0 2,475.0 Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing F/ 1410' T/ 2475' (jt # 61 in the hole). 15:30 16:15 0.75 SURFAC CASING RNCS P 2,475.0 2,590.0 While running joint # 62, # 63 and #64, stab frank's tool and pump 4 bpm while running each joint f/ 2475' to 2590'. Pumped 97 bbls total. Circulated joints in the hole due to THICK MUD and short displacment volume. 16:15 16:30 0.25 SURFAC CASING RNCS P 2,590.0 2,630.0 Run joint #65 F/ 2590' T/ 2630'. 16:30 16:45 0.25 SURFAC CASING RURD P 2,630.0 2,630.0 Rig down Frank's fill -up tool. Blow down the top drive. Page 2/5 Report Printed: 2/20 /2012 • • Security Level: AK Development Daily Drilling_Report CD3 -199 C4nc�ec�Phdtr Report Number: 4 Rig: DOYON 141 Report Date: 2/10/2011 Time Log Stmt End "= Dur Time Depth _Start ?Depth Tune Tinge_? (firs) - ` Phase'' Op Code Activity Code _ >R T X Trbl Code_' r 1 Class ;__ (ftK8)_ ,a.` (ftKB)` _ Operation 16:45 17:00 0.25 SURFAC CASING RNCS P 2,630.0 2,662.9 Make up FMC hanger and landing joint. Remove casing slips. RIH f/ 2630' to land shoe at 2662.88'. PU wt 132k, SO wt 97k. 17:00 17:30 0.50 SURFAC CEMENT RURD P . 2,662.9 2,662.9 Rig up Dowell /Schlumberger cement head and lines. 17:30 21:00 3.50 SURFAC CEMENT CIRC P 2,662.9 2,662.9 Establish circulation at 3 bpm with 300 psi. Stage pumps up to 7 bpm with 400 psi. Pumped a total of 1015 bbls. Circulate and condition mud to reduce PV/YP from 40/67 to 34/29. Reduce funnel viscosity from 300 sec/qt to 80 sec/qt. Reciprocate F/ 2662' to 2642' during circulation. 21:00 21:15 0.25 SURFAC CEMENT SFTY P 2,662.9 2,662.9 PJSM for cementing 9 -5/8" casing with rig crew, cementers, mud engineers, and truck drivers. 21:15 22:00 0.75 SURFAC CEMENT CIRC P 2,662.9 2,662.9 Pump 90 bbls of 10.0 ppg mud with nut plug marker (5 ppb) at 6 bpm with 330 psi. Next pumped 35 bbls of 8.34 ppg Biozan preflush with nut plug marker (5 ppb) at 5 bpm with 200 psi. Reciprocated 15' to 20'. P/U 122k Ibs and S/O 112k Ibs. 22:00 23:15 1.25 SURFAC CEMENT PUCM P 2,662.9 2,662.9 Dowell pump 5 bbls water and pressure test lines to 3500 psi, good. Bleed off pressure and drop bottom plug. Mix and pump 54.2 bbls Mud Push II spacer (10.5 ppg), pump at 6 bpm w/ 230 psi. Mix and pump 247.3 bbls (308 sx) AS lite lead cement (10.7 ppg, 4.51 cuft/sx, 20.7 gal water /sx), pump at 6.3 bpm with 150 psi. Mix and pump 56.3 bbls (272 sx) Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.105 gal water /sx), pump at 5.8 bpm with 200 psi. Shut down and drop top plug. Page 3/5 Report Printed: 2/20/2012 • • Security Level: AK Development e gigio miaow Daily Drilling Report wag CD3-199 '7,1S7 Report Number: 4 ConocoPhillips Rig: DOYON 141 Report Date: 2/10/2011 7n Start End Dur- Time - Depth Start Depth End Laci6g?-1, 23:15 00:00 0.75 SURFAC CEMENT DISP P 2,662.9 2,662.9 Dowell kick out top plug w/ 20 bbls water, pump at 5 bpm with 55 psi. Rig displace cement with mud pump #1 and 10.0 ppg mud. Pump at 7 bpm with initial circulating pressure of 300 psi. After pumping 160 bbls at 7 bpm and a final circulating pressure of 700 psi, slowed rate to 3 bpm. ICP at 3 bpm was 500 psi with a FCP of 525 psi. Bump plug at 1750 strokes, 175.8 bbls (calculated displacement of 1755 strokes with 0.1005 bbls/stroke) and pressured up to 1075 psi. Held pressure for 5 minutes. CIP @ 23:59 hrs 2/10/2011. Note: Reciprocated until S/0 decreased from 112k lbs to 85k lbs. Landed hanger on landing ring at 2345 hrs (landed at 800 strokes into displacement which was 40 bbls before cement returns). Circulated 56.4 bbls of good 10.7 ppg cement to surface. gOT171PFRU:ii Density Temp :ISqlids,, Corr,: : D6'6 (ii6dat ]: : 00ftDA = FF(MU3OrfigiV Spud Mud 2,673.0 10.00 43.0 83.0 98.000 32.0 8.6 68.0 Spud Mud 2,673.0 10.00 8.0 32.0 38.000 32.0 8.7 64.0 Injection Fluid MlitaitgitinIcagggiSiORASSWilkligMigiattaataitIMigiR:::::::ft.T:SigafJP:43;:0001101.001MENHOP! Drilling Mud WBM CD3-199 200.0 CD1-19 AES 307329 Drilling Mud WBM CD3-199 90.0 CD1-19 AES 307330 Weli bores Wellbore Name Wellbore API/UWI CD3-199 501032063500 SURFAC 12 1/4 0.0 2,673.0 2/7/2011 2/9/2011 I NTRM 1 8 3/4 2,673.0 8,879.0 2/12/2011 2/19/2011 PROD1 6 1/8 8,879.0 15,742.0 2/28/2011 3/6/2011 Page 4/5 Report Printed: 2/20/2012 • • Security Level: AK Development Daily Drilling Report CD3-199 Report Number: 4 ConocoPhiflips Rig: DOYON 141 Report Date: 2/10/2011 CasingStnngs Descritior- Run Date !kflbs./AY'2; Sttirt SURFACE 2/10/2011 9 5/8 40.00 L-80 2,662.8 PJSM on running 9-5/8" 40 ppf L-80 BTC-m casing. M/U 9-5/8 casing shoe track as per detail: Rays Oil tool float shoe joint, thread lock joint, HES Sure Seal II float collar joint. All baker locked. Circulate 60 bbls through float equipment using Franks fill-up tool with 9-5/8" shoe above conductor shoe at 108'. Circulate 3 bpm, 4 bpm, 5 bpm, and 6 bpm. Continue running casing to noon depth of 1085' MD (27 joints). Baker lock pin of 4th joint. Make up torque 10,000 ft lbs. Installed centralizers as plan: 10' above shoe on stop ring, collar of joint #1, 10' below box of joint #2 on stop ring. Every collar to joint # 13, then every odd joint to joint # 63. Use Run-N-Seal dope on threads. Circulate joint #29 and #30 in hole with Frank's fill-up tool due to THICK MUD and short displacement volume. Pump 20 bbls each at 2 bpm while running each joint. Continue to run 9-5/8" 40 ppf L-80 BTC-m casing F/ 1205' T/ 1370' Ooint 34 in the hole). Make up joint # 35, stab Frank's fill-up tool. Circulate 194 bbls (surface-surface), reciprocate 20' F/ 1410' T/ 1390', staging up F/ 2 bpm T/ 3.5 bpm. After 70 bbls pumped, increase pump rate to 4 bpm, after 90 bbls increase to 5 bpm, after 120 bbls increase pump rate to 6 bpm w/ 400 psi. Continue to run 9-5/8" 40 ppf L-80 BTC-m casing F/ 1410' T/ 2475' (jt # 61 in the hole). While running joint # 62, # 63 and #64, stab frank's tool and pump 4 bpm while running each joint f/ 2475' to 2590'. Pumped 97 bbls total. Circulated joints in the hole due to THICK MUD and short displacment volume. Run joint #65 F/ 2590' T/ 2630'. Rig down Frank's fill-up tool. Blow down the top drive. Make up FMC hanger and landing joint. Remove casing slips. RIH f/ 2630' to land shoe at 2662.88'. PU wt 132k, SO wt 97k. Cement .„- Surface Casing Cement - Started A 2/10/2011 Type Wellbore Cemented String Cement Evaluation Results casing CD3 SURFACE, 2,662.8ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 26.5 2,673.0 3 525.0 Fluid Arr:Ittiuht,(Aatks) :.: (lbIgaI) Yield (ftJsack) Est Top; (ftKB) EstBtm (ftKB) Biozan Pre Flush 35.0 10.00 Mud Push 5.4.2 10.50 AS Lite- Lead 308 247.3 10.70 4.51 26.5 2,016.4 G- Tail G 272 56.3 15.80 1.16 2,016.4 2,673.0 Page 5/5 Report Printed: 2/20/2012 �� N�� R �� Security Level: AK Development Daily Drilling Report CD3-199 V" Report Number: 5 ConocoPhiffips , v Report Date: 2/11/2011 DOYON 141 ' 10286871 7.774,999.00 Wellbore Well Type meld Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) co3 Development FIORD NECHELIK 4.08 5.0 0.00 2.673.0 2.673.0 Daily Mud Cos Cumulative Mud Cos Daily Cost Tota Cumulative Cost 26.213.14 75.475.e4 349.0e4.44 1.360.251.48 Actuai Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Day Ahead (days) Projected Job End Date 2/7/2011 2/7/2011 25.70 24.19 1.51 3/3/2011 Last Casing String Next Casing OD (in) Next Ca ing Set Depth (ftKB) SURFACE, 2,662.8ftKB Ops and Depth @ Morning Report 24hr Forecast P/U and rackback 5" DP Finish PIU and rackback 54 stands 5" DP. wvu BHA #a and mH. Test caslng to 3500 ps Drill cement and 20 of new forrnation. Perform LOT to 18 ppg EMW. Drill 8-3/4" intermedate hole section. Last 24hr Summary Bled off pressure to check floats on the 9-5/8" 40 ppf L-80 BTC-m casing, OK. R/D and LJD FMC landing joint, casing, and cementing equipment. N/D riser and FMC starter head. N/U FMC wellhead and test metal-metal seals, OK. N/U13'am^BOPE. Modify drilling riser to fit ri elevation and N/U same. Test BOPE to 250 psi low / 3500 psi high except for annular to 2500 psi high. Bob Noble, AOGCC lnspector witnessed testing. RID BOPE testing equipment and FVUDP handling equipment. P/U and nock600k10 joints nf5^DP. Break operations for all hands to attend Theoretical Maximum Performance (TMP) discussion facilitated by RLG. General Remarks Weather Head Count No lncidents, No Accidents. Rig & camp on Hi-line. '2S^r/vYindcoiU'e4^F. SSW @1uMPH 41.0 Granville Rizek, Rig Supervisor Rig Supervisor Ryan Robertson, DriIHng Engineer Drilling Engineer BmoCocchetti. Rig Supervisor Rig Supervisor figgiONNWRikanalingigelaignanaaaaVAINSOMMONINNtagIENWEIMEWORNI 00:00 00:15 0.25 SURFAC CEMENT . OTHR P 2,662.9 2,662.9 Bled off pressue to check floats on the 9-5/8" 40 ppf L-80 BTC-m casing. Floats holding. 00:15 00:30 0.25 SURFAC CEMENT SFTY P 2.682.9 2.*62.9 PJSM on FVocomendng equipment and landing joint. 00:30 02:00 1.50 SURFAC CEMENT RURD P 2,662.9 U.nR8z Dowell cement head, back out/lay down FMC landing joint. R/O casing tools. Flush riser and lines of cement. 02:00 05:00 3.00 SURFAC WHDBOP NUND P 0.0 0.0 N/D riser and FMC adapter/starter head. Prepare hanger for wellhead installation. 05:00 07:45 2.75 SURFAC WHDBOP NUND P 0.0 0.0 Bring FMC wellhead equipment into cellar. N/U same. 07:45 08:00 0.25 SURFAC WHDBOP PRTS P 0.0 0.0 Tes metal-metal seals m1OOOn10 minutes. Witness of test by rig supervisor. 08:00 09:30 1.50 SURFAC WHDBOP NUND P 0.0 0.0 N/U10-n0''BOPE. 09:30 10:00 0.50 SURFAC RIGMNT SVRG P 0.0 0.0 Service rig. 10:00 12:00 2.00 SURFAC WHDBOP OTHR P 0.0 0.0 Modifydrilling risertofit rig elevation. Add some length. Clean pits. Double valve annulus valve. 12:00 13:00 1.00 SURFAC WHDBOP RURD P 0.0 0.0 N/U riser and flow line. Rig up to test BOPE. 13:00 13:30 0.50 SURFAC WHDBOP OTHR P 0.0 0.0 Fill hole. Flood choke manifold and BOP stack. Check for Ieaks, OK. 13:30 13:45 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 PJSM on testing BOPE. Latest BOP Test Data 2/11/2011 Witness of tes by AOGCC inspector Bob Noble. Page 1/3 Report Printed: 2/20m012 1 • �� NN� �� ' Security Level: AK Development Daily Drilling Report CD3-199 EN:f Report Number 5 Rig: DOYON 141 Report Date: 2/11/2011 13:45 20:15 6.50 SURFAC WHDBOP BOPE 0.0 0.0 Test BOPE. Witness of test by AOGCC inspector Bob Noble. All tests charted for 5 minutes each. Tested annular to 2so psi and zoOO psi. Tested all valves inchokomondb|d.choke|ine.ki|||ina.4" demco valve on mud |ino, floor safety vaive, IBOP, top drive automatic and manual IBOP valves, upper pi (3-1/2^xs''variable boe), blind rams, lower pipe rams (z-7m^xo^variable bore) to 250 psi and 3500 psi Pipe rams and annular tested with s''test joint. Performed accumulator test: initial system pressure was 3000 psi, pressure after closure was 1700 psi. Build up 200 psi in 40 seconds and full pressure in 3 minutes 34 seconds. Nitrogen bottles average 2000 psi. Tested PVT and gas alarms. Choke manifold valves #8.8. and 1O required replacing stem packing. Lower VBR's required retesting. 20:15 20:30 0.25 SURFAC WHDBOP RURD P 0.0 0.0 RID BOPE tes equipment. Install wear ring. BIow down kill line, choke Fne, and choke manifold. 20:30 20:45 0.25 SURFAC DRILL RURD P 0.0 0.0 pnutoP8/ DP via mouse hole. 20:45 21:00 025 SURFAC DRILL SFTY P 0.0 0.0 PJGMonP/U DP. 21:00 21:30 0.50 SURFAC DRILL PULD P 0.0 o.oP8J and M8J18 joints of5'' DP. Rack back same. 21:30 00:00 2.50 SURFAC DRILL OTHR P 0.0 0.0 Break for all hands to attend Theoretical Maximum Performance (TMP) facilitated by RLG. Note: Excellent rtici increase nQ safety during flat time operations. Developed over 50 action items to Feedback provided by crews showed enthusiasm and support for the /Mr purpose. Spud Mud 2,663.0 10.00 8.0 32.0 38.000 32.0 8.7 64.0 Spud Mud 2,663u 10.00 8.0 32.0 88.000 320 8.7 66.0 Cuttings CD3-199 96.4 G & I AES 307338 20 CU YD Cuttings CD3-199 96.4 o&| AES 307339 20 CU YD Drilling Mud vvsM om3-199 290.0 CD1-19 AES 30733e Drilling Mud VVoM CD3-199 280.0 Co1'19 AES 307333 Page 2/3 Report Printed: 2/20/2012 .°°Z • • Security Level: AK Development NA" — Daily Drilling Report ATigAtitztrigiWellsA CD3 -199 Cvt7raccsPtsitlaps ' - Report Number: 5 Rig: DOYON 141 Report Date: 2/11/2011 Arijectton Fluid r =Flwd __ 'Source -From Lease - (bbl)- ' -, Destination`. Vendor Manifest, Number Note Drilling Mud WBM CD3 -199 280.0 CD1 -19 AES 307337 Drilling Mud WBM CD3 -199 275.0 CD1 -19 AES 307331 Drilling Mud WBM CD3 -199 270.0 CD1 -19 AES 307341 Drilling Mud WBM CD3 -199 . 200.0 CD1 -19 AES 307334 Drilling Mud WBM CD3 -199 180.0 CD1 -19 AES 307343 Drilling Mud WBM CD3 -199 130.0 CD1 -19 AES 307340 Drilling Mud WBM CD3 -199 90.0 CD1 -19 AES 307342 Wel l bores Welibore Name Wellbore API /UWI CD3 -199 501032063500 Section a_ Sizei (m) Act=Top (ftKB)'__i ,`Act,Btm (fttB) °Start Date; : :End_Date _. :0:: SURFAC 12 1/4 0.0 2,673.0 2/7/2011 2/9/2011 INTRM1 8 3/4 2,673.0 8,879.0 2/12/2011 2/19/2011 PROD1 6 1/8 8,879.0 15,742.0 2/28/2011 3/6/2011 PressureTest Data _ c:ItemTested.. _ �,. Date : Pres,(psi) ".Detection,: .,Comment - - BOP stack, 2/11/2011 13:45, 2/11/2011 3,500.0 No Witness of test by AOGCC III inspector Bob Noble. Page 3/3 Report Printed: 2/20 /2012 • • CD3-199 9-5/8" Surface Casing Well: CD3 9-5/8 " a ;Int' -80 rrr-rn Ca--sing Date: 2110/2011 :11.tr UnocOPhillio Rig: Doyon Rig 141 AI$ka Depth Jt Number Joints Well Equipment Description and Comments .. . Length Tops Page 1 • • • • • • • •••••••••••••••• .•'••• •••••••••••••••••••••••........... • RKB to Top of Landing Ring 26 . 53 1111NIMMIS FMC 9 5/8" Casing Hanger .21 26,53 9-5/8" Pup in the hanger pin x pin 2.15 26.74 Jts 3 to 65 63 Jts 9 5/8", 40.0#, L BTC Casing 2555.18 28.89 HES 9 5/8" Sure Seal II Float Collar 1.21 2584.07 Jts 1 to 2 2 Jts 9 5/8", 40.0#, L BTC Casing 75.36 2585.28 Ray 011 Tools 9 5/8" Silver Bullet Float Shoe 2.24 2660.64 Shoe depth 2662.88 2662.88 Baker Lock lst 3 joints and pin on 4th joint 2662.88 2662.88 1 Bowspring Centralizer on stop collar 10' above the top of shoe. 2662.88 1 Bowspring Centralizer on stop collar 10' below the box of joint # 2 2662.88 2662.88 Bowspring centralizers on joints # 4 - #13. Then run Bowspring 2662.88 centralizer every other joint #15 to #63. 2662.88 2662.88 Centralizer placement highlighted in yellow on tally sheet. 2662.88 39 total centralizers, 2 stop rings 2662.88 2662.88 5 Joints of 9 casing remain in shed 2662.88 2662.88 TD @ 2673' MD ( 2464.67' TVD) 2662.88 Shoe @ 2662.88' MD ( 2457.01' TVD) 2662.88 Rat hole 10.12'. 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 Remarks: Drifted w/ 8.775" teflon drift Up Wt 125 K Used Jet Lube Run-N-Seal dope. Dn Wt 112 K Torqued to 10,000 Ft Ibs of torque Block Wt 35 K Supervisors:Granville Rizek/ Elmo Cecchetti PRESSURE INTEGRITY TEST , CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 -199 Rig: Doyon Rich 141 Date: 2/12/2011 Volume Input Volume /Stroke Pump Rate: Drilling Supervisor: I Rizek/ Cecchetti Pump used: #2 Mud Pump 1r Strokes NI 0.1005 Bbls/Strk a 5.00 Strk/min ■ Type of Test: Casing Shoe Test LOT /F!T ■ Pumping down annulus and DP. 1r Casing Test Pressure Integrity Test Hole Size: 8 v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 25.OIFt 2662.9IFt -MDR 2457.OIFt -TVD 2693.OIFt -MD . I2480.2IFt -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 9 -5/8" 40 # /Ft L -80 BTC v _ 0 0 0 3730 0 0 0.00 1015 Casing Test Pressure IntegritvTest 1 40 1 3730 2 125 0.25 925 Mud Weight: 9.7 ppg Mud Weight: 9.6 ppg 2 90 2 3730 4 375 0.50 875 Mud 10 min Gel: 20.0 Lb /100 Ft2 Mud 10 min Gel: 12.0 Lb /100 Ft2 3 200 3 3730 6 525 1.00 775 Test Pressure: 3500.0 psi Rotating Weight: 96000.0 Lbs 4 325 4 3730 8 675 1.50 75f • Rotating Weight: 9200.0 Lbs Blocks/Top Drive Weight: 35000.0 Lbs 5 475 5 3730 10 800 2.00 72 Blocks/Top Drive Weight: 35000.0 Lbs Desired PIT EMW: 18.0 ppg 6 625 6 3730 12 925 2.50 700 Estimates for Test: 2.8 bbls Estimates for Test: 1073 psi 0.7 bbls 7 775 7 3730 14 975 3.00 690 ■ ■ 8 875 8 3730 16 1005 3.50 675 EMW = Leak -off Pressure + Mud Weight = 925 + 9 6 PIT 15 Second 9 970 9 3730 18 1015 • 4.00 675 psi 1050 10 3730 4.50 675 0.052 x TVD 0.052 x 2457 Shut-in Pressure, i 10 10.x0 1 37.,11 p 'iii !iii�i :l . ' `I A ' { 'AJ' 0 '.I EMW at 2662.88 Ft -MD (2457.01 Ft-TVD) = 16.8 925 11 1140 15 ;730 5.00 675 ppg 4000 Lost 10 psi Burin test, held 20 3725 5.50 675 p 9 12 1240 0 1 99.7% of test pressure. ,�� 13 1340 25 3720 i _ � is � .. 6.00 675 3500 14 1450 30 3720 6.50 665 15 1540 7. 665 LLI 3000 16 1650 7.50 00 665 e° 18 1870 - 8.,E 2500 20 2140 8.50 00 665 66 _:::: _:.:::...:. 22 2400 9.00 665 9 � 2000 24 26x40 .50 665 N c 10.00 w 26 2930 CL 1500 28 3170 '''' 3O 3 430 ,�2 730 1000 1 f' 3{ 1 6„ A, 1 ... :.__...11..3.{ . {..I 1.. 1.11:,. 500 n. 0 0 1 2 3 4 0 5 10 15 20 25 30 ° ' ° ' "' -' -- Barrels Shut -In time, Minutes V olume Volume Volume Volume tt'CASING TEST -la--LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 3.2 Bbls 3.2IBbis 1.8 Bbls 0.8IBbls Comments: �u.3- I uu our lace uctsing Tebr and Lt.1T z- I z -cu 1 1.xls Summary 0 • - ----“ =,-, AfFq - ILMiliins. Cement Detail Report t:W ., — ,-;,., tiaTc-i CA Aebs CD3-199 --- ,4:izii :ConocoPhillips ...E.,.1., . String: 7".Intermediate casing Job: DRILLING ORIGINAL, 2/7/2011 00:00 tdiiiiiiiI Description Cementing Start Date Cementing End Date Wellbore Name 7" Intermediate casing 2/23/2011 17:00 2/23/2011 21:15 CD3 Corn ment Pump surface volume CW100 pressure test cement line to 3,500 psi, Continue pumping CW100, Drop top plug 25 bbl's CW100 pumped, Pump 5 bbl's CW100 total CW100 pumped 30 bbl's. batch and pump 27 bbl's 11.5 ppg Mudpush 11 spacer, Batch cement and pump 15.8 ppg lead slurry, volume pumped 53 bbl's. Shut down drop top plug chase with 20 bbl's water, Turn over to rig displace at 5 bpm bump plug at 3,104 strokes total mud pumped 314 bbl's. Casing reciprocated 20 stroke length throughout job up wt 245k dn wt 145k, Casing landed on hanger with CIP @ 18:57. final circulating pressure 400 psi, Pressure up 700 psi over FCP held for 5 minutes, bled pressure off checked floats ( Floats Good) Pressure up to 3,400 psi to open stage collar at 5,324' md. Circulate and condition mud for 2nd stage cement job. @ 5 bpm - 300 psi, Increased rate to 6 bpm - 600 psi 2nd stage cement job, Pump 30 bbl's pumped, Pump 28 bbl's 11.5 ppg Mudpush 11 spacer, Mix and pump 48 bbl's 15.5 ppg tail slurry, Drop top plug, Flush cement lines with water turn over to rig displace cement with 184 bbl's mud, Displace at 6 bpm - 270 psi, Bump plug with 1,790 strokes, Pressure up to 1,850 psi close stage collar, (Stage collar @ 5,324' md) pressure up to 2,300 psi hold for 5 minutes, bleed pressure confirm stage collar closed. CIP @ 21:09 Ceiiieiit,StadeadVEMC51:VtrXtMEWSTW:RR:rdR,VEMMRIWIORRWW'VitlianigVig::MRSMNRNNRMN Sta Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? 7" Intermediate casing 1st stage cement job 7,810.0 8,879.0 No 0.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 2 5 4 400.0 1,100.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment "-,CerlieriCntilifi:VAdditilieSitiallgtallAttaillittaniatal:MIRMRAMMOVanterakiNSMONMOMUSWEUMMIE FliifiliEMIVRIkkg: ;:5.V.,40:1RigeNT0.00ftrenaffiPACOPRONSAIMIKIMIRMOi.4 Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 8,867.0 7,810.0 215 G 53.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 5.34 Additives Additive Type Concentration Conc Unit label Retarder B155 0.08 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC tigait4WRONSMINSAMIRMINORWMIMWOMMIRSIONIMMAIMAMIIMMIMUSIWZNERAVOICSitt,SOM • Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? 7" Intermediate casing 2nd stage cement job 4,285.0 5,325.0 No 0.0 Yes No Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 1 2 6 5 270.0 1,850.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Ceitieittl,F,rtiiae&tAdditiiiegNgtMMM #TeiratIggajta nitintAiNtatiaMMISEREa.M.Mtradatatat Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 4,285.0 5,324.0 186 G 48.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.01 15.80 5.03 Additives Additive Type Concentration Conc label Retarder B155 0.08 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label . Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 2/20/2012 � ��/ Security Level: AK Development AW 001110114, Daily Drilling Report CD3~199 red Report Number: 16 ' -- Report 2/22/2011 Rig: DOYON 141 ' 10290871 7.774.98900 Wm/bore Well Type Field Name DFS (days) DOL Depth Progres (ft) Depth Start (ftKB) Depth End (ftKB) CO3'199 Development FIORD NECHELIK 15.08 16.0 0.00 8.87e.0 8.879.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3.495.20 478.328.18 131.68e20 3.389.29716 Actuai Start Date Origrnal Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Day Ahead (days) Projected Job End Date 2/7/2011 2/7/2011 25.70 2718 '1.48 3/6/2011 Last Casing String Next Casing OD (in) Next Ca ing Set Depth (ftKB |wTERMEomTE. Ops and Depth Morning Report 24hr Forecast Running casing @osoo' Run casing & Cement Last 24hr Summary Short trip, Circulate bottoms up, Spot W ll bstrengthening pill @8878' Follow with 104 ppg mud to bit, Monitor well, Pull out spotting WBSP & Cpr @ 2 bpm F/8,879' MD - T/7,790' MD. Trip out of hole on elevators, Monitor at BHA, Rack back HWDP and Jars, Lay down BHA, Flush stack pull and service WB, Clear and clean floor, Cut 78' drill line, Change upper rams to 7" (Sim ops while cutting drill line) Test rams,250 low - 3,500 high. Rig down test equip, Set 10-3/8" Wear ring. PJSM rig up and run 7" casing T/ 2,640' MD. Circulate casing volume staging pumps up to 5 upmw/37s psi. General Remarks Weather Head Count No Incidents, No Accidents. Rig & camp on Hi-line. '18^ Winds South East ©o MPH, Wind Chill 46.0 -28° Fred He,uart, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer Mark Brouillet, Rig Supervisor Rig Supervisor 00:00 00:30 0.50 INTRM1 DRILL WPRT 8,810.0 8,347.0 Short trip f/ 8810' to 8347'. PU wt 205k, So wt 145k. 20k overpull @ 8795' and 10k overpull © 8760'. 00:30 01:00 0.50 INTRM1 DRILL WPRT P 8.347.0 8,879.0 Monitor well- static. RIH, tag bottom @ 8D7S'.no problems. 1Ok drag @88no' and 8045' Wipe f/o7oo'too77o' 01:00 02:00 1.00 INTRM1 DRILL CIRC P 8.879.0 8,879.0 B x circulation rotate 120 rpm w/ 10k ft lbs of torque. Stage pumps up to 600 gpm w/ 1500 psi. Circulate bottoms up while recip f/ 8879' to 8810'. 02:00 02:30 0.50 |wTRM1 DRILL CIRC p 8.87e.0 8.810.0 Pump 10 bbl wellbore sba w/ 90 bbl casing running pill, chase w/ 68 bbl 10.4 ppg mud. Pull up f/ 8879' to 8810' at 25'/min pulling speed, pumping 20 spm w/ 200 psi. Safe Garb 20 5 ppb. Casing running pill: Alpine Beads 5ppg, Lube 776 6%. - 02:30 02:45 0.25 INTRM1 DRILL OWFF P 8,810.0 o,810.0 Monitor well- static. Blow down the top drive. 02:45 03:15 0.50 INTRM1 DRILL TRIP P 8,00.0 8,530.0 Pump and Pull ��30'. Pump 20 spm f/ 75 strokes per stand. Pull 25minute Record PU and wt's. ' Overpull @ 8792 (10k over) 03:15 08:45 0.50 INTRM1 DRILL OWFF P 8.530.0 8,530.0 Monitor well-static. RIH one stand. Determine not lined up right Sucking f/ e strengt fluid), returns to fluid. Line up to suckehd return f/ pit #5. Latest BOP Tes Data 2/11/2011 Witness of test by AOGCC inspector Bob Noble. Page 1/2 Report Printed: 2/20m012 • • Security Level: AK Development Daily Drilling Report } to ;.t CD3 -199 1 Report Number: 16 Co iocoPhi111ps Rig: DOYON 141 Report Dater 2/22/2011 Time Log Start End w Dur Time. Depth Start, Depth End Time Time (hrsj Phase [ Op Code = Activ ty Code -- -_ P T x , `- Trbf Code`: Trtil =Class (ftKB) _ =_ (ftKB) Operation 03:45 05:00 1.25 INTRM1 DRILL TRIP P 8,530.0 7,787.0 Pump and Pull f/ 8530' to 7787' (77 stands in the hole). Pump 20 spm f/ 75 strokes per stand. Pull 25' /minute. Record PU and SO wt's. 05:00 05:15 0.25 INTRM1 DRILL OWFF P 7,787.0 7,787.0 Monitor well- static. 05:15 06:15 1.00 INTRM1 DRILL TRIP P 7,787.0 6,862.0 Pull out on the trip tank f/ 7787' to 6862' 06:15 06:45 0.50 INTRM1 DRILL CIRC P 6,862.0 6,862.0 Pump a dry job. Blow down the top drive. 06:45 12:00 5.25 INTRM1 DRILL TRIP P 6,862.0 659.0 Continue to POOH f/ 6,862' MD to 659' MD 12:00 12:45 0.75 INTRM1 DRILL PULD P 659.0 0.0 Monitor well 20 min, Hold PJSM while monitoring on BHA. Rack back HWDP, Jars. Lay down flex collars, stabilizers and bit. . 12:45 14:00 1.25 INTRM1 DRILL RURD P 0.0 0.0 Flush stack, Pull wear ring, Clear and clean floor 14:00 15:30 1.50 INTRM1 RIGMNT SLPC P 0.0 0.0 Slip and cut 78' drill line. (Sim ops- change upper rams to 7 ") 15:30 16:15 0.75 INTRM1 WHDBOP BOPE P 0.0 0.0 Test upper 7" rams 250 psi low - 3,500 psi high 5 miinute per test. Rig down test equipment. Set 10 -3/8" wear ring. 16:15 18:15 2.00 INTRM1 CASING RURD P 0.0 0.0 PJSM, Rig up to run 7" casing. 18:15 23:00 4.75 INTRM1 CASING RNCS P 0.0 2,640.0 Run 7" casing per detail, Baker lok float equipment, Fill and check floats, (Floats good) Run 64 joints casing to 2640' MD up wt 90k do wt 86k 23:00 00:00 1.00 INTRM1 CASING CIRC P 2,640.0 2,640.0 Circulate casing volume at 2,640' (Shoe) Stage pumps up slowly to 5 bpm 375 psi final circulating pressure. Mud Check'Data YP'Calc Gel?(10sj Gel (10m) Gel (3OmJ HTHP Fdt _ Density Temp Solids Co r' -_ Type Depth (ftKB) : Dens (Ib/gal) V s (s/qt) -PV Calc =(cp) (Ibf /1004) (Ibf /:100Et?) (Ibf /1008 j;_ (Ibf /100R?)" MB7 (Ib/bbl)_ ,:.(mLl30mm)_; Glydril 8,879.0 10.40 9.0 11.0 13.000 15.0 6.4 9.0 93.0 Glydril 8,879.0 10.40 10.0 12.0 13.000 17.5 6.3 9.1 94.0 Infection Fluid 4 _ 5 :: Fluid - - _ Source From Lease (bbl) Destination€ Vendor Manrrfest'Number ,_ Note Truck Rinsate CD3 -199 200.0 CD1 -19 AES 307398 1Nellborest:> Wellbore Name Welibore API /UWI CD3 -199 501032063500 SURFAC 12 1/4 0.0 V 2,673.0 2/7/2011 2/9/2011 INTRM1 8 3/4 2,673.0 8,879.0 2/12/2011 2/19/2011 PROD1 6 1/8 8,879.0 15,742.0 2/28/2011 3/6/2011 Casing Strings _ . StringTOD String Wt € s Casing pescnpbon RunQate -, (n) (Ibs/ft) Strang Grade, :? Set Depth (ftKB), Comment INTERMEDIATE 2/22/2011 7 26.00 L -80 8,870.0 Page 2/2 Report Printed: 2/20 /2012 • • Security Level: AK Development 9.l Daily Drilling Report Ya; We CD3 -199 r Report Number: 17 Conocophiilips Rig: DOYON 141 Report Date: 2/23/2011 AFE Type Networi !ID # - -,:: - ;Total €RFE ±Sup `- 10296871 7,774,999.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 199 Development FIORD NECHELIK 16.08 17.0 0.00 8,879.0 8,879.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total • Cumulative Cost 8,083.51 486,411.68 137,579.27 3,506,876.42 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/7/2011 2/7/2011 25.70 28.18 - 2.48 3/7/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 8,870.0ftKB Ops and Depth @ Morning Report 24hr Forecast Laying down 5" drillpipe Lay down 5" drillpipe, Pick up 4" drillpipe Last 24hr Summary Run 7" casing from 2,640' and to 8,869'. Circulated and conditioned at 4,830' md, 7,016' and and on bottom 8,869' md. Circulating rates staged up from 1 bpm to 5 bpm with final circulating pressure 400 psi. held PJSM, Pressure tested lines, performed 2 stage cement job, 1st stage cement job CIP @ 18:57 2nd stage cement job CIP @ 21:09. Rigged down from cement job. Pulled landing joint, drained stack, set and tested 7" packoff to 5,000 psi. Pressure test witnessed by rig supervisor. Cleared and cleaned floor in preparation for laying down 5" drillpipe. General Remarks Weather Head Count No Incidents, No Accidents. Rig on Hi -line. 22° Wind South @ 26 MPH Wind Chill 4° 46.0 Fred Herbert, Rig Supervisor Rig Supervisor Mark Brouillet, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer Tlme Log Start End _ Dur Time Depth Start Depth -End Time Time (hrs) Phase -_= _ _ Op Code Activity Code _ - P TX ?_Trbf Code_ Trbl Class (ftK6) (ftKB).: Operation 00:00 03:15 3.25 INTRM1 CASING RNCS P 2,640.0 4,830.0 Run 7" casing f/2,640' and - t/ 4,830' md. Obtain up and down weight every 10 joints. 03:15 04:30 1.25 INTRM1 CASING CIRC P 4,830.0 4,830.0 Circulate and condition mud. Very thick dehydrated mud. Mud weight out 10.7 ppg. Lower mud weight to 10.4 ppg. Initial circulating rate 2 bpm - 300 psi, final circulating rate 5 bpm - 450 psi. Circulated over surface to surface volume. up wt 135k down wt 105k 04:30 07:45 3.25 INTRM1 CASING RNCS P 4,830.0 7,016.0 Run 7" casing f/4,830' and - t/ 7,016' md. Obtain up and down weight every 10 joints. 07:45 09:30 1.75 INTRM1 CASING CIRC P 7,016.0 7,016.0 Circulate and condition mud, Break circulation at 2.5 bpm - 350 psi, stage pumps up to 5 bpm - 500 psi. Final circulating pressure at 5 bpm - 450 psi. 09:30 12:15 2.75 INTRM1 CASING RNCS P 7,016.0 8,869.0 Complete running 7" casing, make up landing joint. Total joints run 214. Casing depth 8,869' md. 12:15 12:45 0.50 INTRM1 CEMENT RURD P 8,869.0 8,869.0 Rig down casing tongs, remove slips, rig down Franks fill up tool, Blow down top drive. Rig up cement head. 12:45 17:00 4.25 INTRM1 CEMENT CIRC P 8,869.0 8,869.0 Circulate and condition mud for cement job. Initial circulating rate 1 bpm - 250 psi final circulating rate 5 bpm - 600 psi. Rate staged up 1/2 bpm until final circulating rate reached. Final circulating pressure at 5 bpm - 400 psi. Up wt 245k • do wt 145k. (PJSM for cementing held while circulating.) Latest BOP Test Data Date Comment = 2/11/2011 Witness of test by AOGCC inspector Bob Noble. Page 1/3 Report Printed: 2/20/2012 • � � �� Security Level: AK Development Atig Daily Drilling Report 63:39 CD3-199 _ = Report Number: Number: 17 ccmoo.P`x�s� =^� Report D��' 2/23/2011 Rig: DOYON 141 ' 17:00 19:15 2.25 INTRM1 CEMENT CMNT 8,869.0 8,869.0 Pump surface volume CW100 pressure test cement line to 3,500 psi, Continue pumping CW100, Drop top plug 25 bbl's CW100 pumped, Pump 5 bbl's CW100 total CW100 pumped 30 bbl's. batch and pump 27 bbl's 11.5 ppg Mudpush n spacer, Batch cement and pump 15.8 ppg lead slurry, volume pumped 53 bbl's. Shut down drop top plug chase with 20 bbl's water, Turn over to rig displace at 5 bpm bump plug at 3,104 strokes total mud pumped 314 bbl's. Casing reciprocated 20' stroke length throughout job up wt 245k dn wt 145k, Casing landed on hanger with CIP @ 18:57. final circulating pressure 400 psi, Pressure up 700 psi over FCP held for 5 minutes, bled pressure off checked floats ( Floats Good) Pressure up to 3,400 psi to open stage collar at 5,324' md. 19:15 20:00 0.75 INTRM1 CEMENT CRC 8,869.0 8.809.0 Circulate and condition mud for 2nd stage cement job. @ 5 bpm - 300 psi, Increased rate to 6 bpm 000 psi 20:00 21:15 1.25 INTRM1 CEMENT CMNT P 5.324.0 5.324.0 2nd sta cement job, Pump 30 bbl's pumped, Pump 28 bbl's 11.5 ppg Mudpush 11 spacer, Mix and pump 48 bbl's 15.5 ppg tail slurry, Drop top plug, Flush cement lines with water turn over to rig displace cement with 184 bbl's mud, Displace at 6 bpm 270 psi, Bump plug with 1,790 strokes, Pressure up to 1,850 psi o|osestaQeco||or. (Stage collar @5.324'mu) pressure up.to2.3OOpsi hold for 5 minutes, bleed pressure conflrm stage collar closed. CIP @ 21:09 2115 00:00 2.75 INTRM1 CEMENT RURD P 0.0 0.0 Blow down lines, casing equipment, lay down landing joint, Pull wear bushing, Install 7" packoff, Test packoff to 5,000 psi for 10 minutes, Test witnessed by Conoco rep. Lay down long bales, Prep floor to lay down 5" drillpipe. -MLitt afeCk:Dataiailge; Glydril 8,879.0 10.40 10.0 12.0 14.000 18.7 6.2 9.0 97.0 Glydril 8,8790 10.40 7.0 8.0 9.000 18.7 63 9.0 94.0 Cement Rinsate CD3-199 170.0 CD1-19 AES 348906 Cuttings CD3-199 60001'19 AES 34e904 Drilling Mud WBM Co3489 290.0 Co1'18 AES 348305 Drilling Mud xvsM oD3-19e 280.0 CD1-19 AES 348902 Drilling Mud VVBM CD3-199 270.0 CD1'18 AES 348907 Page 2/3 Report Printed: 2/20/2012 • • Security Level: AK Development .= Daily Drilling Report ' 4 . &WC CD3 -199 cvnQecaPhiut 1,, Report Number: 17 Rig: DOYON 141 Report Date: 2/23/2011 Infection Fluid Fluid _ - = Source - From Lease:(bbl) Destination:: Vendor Manifest Number Note Drilling Mud WBM CD3 -199 265.0 CD1 -19 AES 348903 Drilling Mud WBM CD3 -199 130.0 CD1 -19 AES 307399 Truck Rinsate CD3 -199 200.0 CD1 -19 AES 348908 Weibores Wellbore Name Wellbore API /UWI CD3 -199 501032063500 : ;Section - Size (in) Act Top (ftKB - - Act Btm,(ftKB - ' Start Date;_ End_ Date , SURFAC 12 1/4 _ 0.0 2,673.0 2/7/2011 2/9/2011 INTRM1 8 3/4 2,673.0 8,879.0 2/12/2011 2/19/2011 PROD1 6 1/8 8,879.0 15,742.0 2/28/2011 3/6/2011 Cement 7" Intermediate casing - Started (a7 2/23 /2011 Type Wellbore Cemented String Cement Evaluation Results casing CD3 - 199 INTERMEDIATE, 8,870.0ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbi /... P (final) (psi) 1 7" Intermediate casing 7,810.0 8,879.0 5 400.0 Flpid_ _ :: is Class Amount(sacks) - . ,V (bbl) €?D ensity (Ib /gal) _ € Yield °(feisack) ;EstTop (ftKS) -_ - = Est .Btrn:(ftKB) . -> Intermediate Cement G 215 53.0 15.80 1.16 8,867.0 7,810.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 7" Intermediate casing 4,285.0 5,325.0 6 270.0 Fluid; _ , - =Crass `Amount;(sack - V (bbI) __ � Density (Ib /gal) YFeld'(fNTsadc) :Est Top (ftKB): .. >_::_ Est Btm:(ftKB) <- Intermediate Cement G 186 48.0 15.80 1.16 4,285.0 5,324.0 Page 3/3 Report Printed: 2/20/2012 • • CD3-199 Intermediate Well: CD3 7 26 pof L-80 BTCrn Casing' Date: 2121112010 Conoco Phillips _ Rig: Doyon 141 Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 .•.•.•.•.•.•.•.•...-.•..•.•.-.•.•.•.•.-.•.•.•.•.•.•.•.•.. ...•.•.•.•.•.•.•...-....•.•...•.•.•.•.•...•.•.•.•.•...•.. .•.•.•.•.....•.•...•.•..•.•.•.•.•.•.•.•...•.•.•.....•.•.. -.•.•.•.•.•...•.•.•.•.• •.•.•.•.•.•.•.•.•.•.•.•.•.•.•.-.-. .............. ......... RKB to Casing Flange (Load shoulder .62 below LLDS') (LLDS 24.88') 24 lommostimi FMC 7" Mandrel hanger to the lower lock down screws 1.00 24.88 7", 26#, L-80, BTC-m Casing Pup jt Pin x Pin 2.24 25.88 Jts 87 to 214 128 Jts 7 ", 26#, L BTC Casing 5296.46 28.12 HES 7" Stage Collar 2.43 5324.58 Jts 4 to 86 83 Jts 7", 26#, L BTC Casing 3415.67 5327.01 HES Shut Baffle Collar 1.00 8742.68 Jts 3 to 3 1 Jts 7", 26#, L BTC Casing 40.90 8743.68 HES Sure Seal H Float Collar wi By Baffle Adapter 1.01 8784.58 Jts 1 to 2 2 Jts 7", 26#, L BTC Casing 81.99 8785.59 Ray Oil Tools " Silver Bullet" Float Shoe 2.12 8867.58 Bottom of shoe >» . 8869.70 8-3/4" Hole TD @ 8879' MD / 6953.7 ' TVD, Hole angle 82.57 8869.70 7" Shoe @ 8869.7' MD / 6952.72' TVD/ Hole angle 82.57 deg 8869.70 8869.70 Quannik @ 4786' MD (4061' TVD) 8869.70 8869.70 • 8869.70 Total of 89 Straight Blade centralizers (7" x 8-3/8") - 5 Stop Collars 8869.70 1 Staight Blade centralizer w/ stop 10' above shoe -Jt. #1 8869.70 1 Straight Blade centralizer w/ stop ring 10' below Float Collar jt. #2 8869.70 1 Straight Blade centralizer w/ stop collar 10 below Baffle Adaptor Jt. #3 8869.70 1 Straight Blade centralizer per jt on jts # 4-#30 floating 8869.70 8869.70 1 Straight Blade centralizer w/ stop ring 10' below Stage Collar jt, # 86- below stage collar 8869.70 1 Staight Blade centralizer w/ stop 10' above Stage Collar -Jt. # 87 8869.70 • 1 Straight Blade centralizer per joint floating # 88 thru # 111 8869.70 8869.70 1 on 3 jts Across Shoe jts # 151, # 152 & # 153 8869.70 then 1 every other jt # 155 to # 213--- 2 joints below WH 8869.70 8869.70 Planned: 237 jts in pipe shed / 214 jts to run. 240 jts on location. 8869.70 23 joints left in the shed, plus 3 outside= 26 jts left over 8869.70 8869.70 • 8869.70 Remarks: Drifted w/ 6,151" plastic rabbit Up Wt ??? K Average MU torque= 7800 Ft lbs Dn Wt ?? K Used Run-N-Seal dope Block Wt 35 K Supervisors: Fred Herbert / Granville Rizek / Mark Brouillet PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-199 Rig: DOYON 141 Date: 2/24/2011 Volume Input j Pump Rate: Drilling Supervisor: 1 Fred Herbert/ Mark Brouillet Pump used #2 Mud Pump . Bbl/m in :IIIIIIIIIIIIIIIIIIIIIIIN k 1r 1V ■ Barrels I f r 11:11II;IIIIIIIII:IIIIII Bbls/str ':1::::;F:11:i.:1Z: Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus and DP. ■ - Casing Test Pressure Integrity Test Hole Size: 8-3/4" 1r Casing Shoe Depth Hole Depth Pumping Shut-in , Pumping Shut-in RKB-CHF: 24.9IFt 2662.01Ft-MDI 2457.OIFt 4285.01Ft-MD I 3685.01Ft-TVD Bbls psi Min psi Bbls psi M in psi Casing Size and Description: 7" 26#/Ft 3-55 BTC-MOD v :!ii!lbillilliiiiiii il 0 IllillilliiinVii 0 0 0.00 568 Changes for Annular Adequacy Test Pressure IntegritvTest :.i.!:::1:11:1-14iiii iii!iglig[1:1111: 1 .i'11":11 0.2 155 0.25 563 Enter outer casing shoe test results in comments Mud Weight: 10.4 ppg 2 .;;;:i:1111 0.4 174 0.50 563 Casing description references outer casing string. Inner casing OD: ,....... In. lt 3 jiiiiii11111111111 0.6 215 1.00 558 Hole Size is that drilled below outer casing. ingoolimpill 'i.i.:.'.i 4 0.8 256 :1,51211111115' Use estimated TOC for Hole Depth. 111;iiiiiIi1:111.;i.i..i.;:;:.: • '' ''''''''''''''''' 1 293 2.00 55 Enter inner casing OD at right. Desired PIT EMW :ITIREINE:;:;:; ppg 1: :::11:::::::::: 6 :;:i1:11111 'I 2 325 2.50 554 .„) Estimates for Test: -1329 psi -0.1 bbls 1111:VH)::i 7 11.,:.111::i1;;;i;1 1.4 359 3.00 ,)4 . ■ ::::::::::N:0;1!:;111 811 18 389 3 549 EMW = Leak-off Pressure + Mud Weight = 674 + 10.4 PIT 15 Second ::iiiii!-;Iiiiii!:::[:' - 9 ;:1:: '1.8 412 4.00 549 0.052 x TVD 0.052 x 2457 Shut-in Pressure, psi :l11:1 10 .! 2 444 4.50 549 EMW at 2662 Ft-MD (2457 Ft-TVD) = 15.7 563 : 15 :Eiliiii1i11:1:11:iili 2.2 467 5.00 549 1000 - 4 ' 20 ::;:;:! 2.4 494 5.50 545 25 ::;::':; 2.6 526 6.00 545 30 :i 9 8 545 6.50 545 '-" 577 7.00 545 3.2 604 7.50 545 3.4 627 8.00 540 3.6 645 8.50 540 3.8 674 9.00 540 . ,,,, limuiimmulsomilio 500 11:1;ii;ii.,:iii:1:11111 4 668 9.50 540 „i. . ,,...„....,....,: ,,...,..,..,,..., .... .... 4.2 623 10.00 54110 5 613 , 6 600 .-, 7 604 . 5 1:11111:1111111111111111111111111 ° 0 1 2 3 :4 5 6 7 8 0 5 10 15 20 25 30 •_ ,_ olume Volume Volume Volume V Barrels Shut-In time, Minutes B CASING TEST -ill- LEAK-OFF TEST 0 PIT Point Pumped led Back Pumped Bled Back 0.0 Bbls j1111111,111111Bbls _ 7.0 Bbls :.11:!,11.1,1,:ttilBbls 1 Comments: k..,U.) litlecilvly 1 est z-z4-zu i I .xls Summary H p-Nuirg ,J1111:1,,,,,,,„ e 0 III„ Cement Detail Report I l ' i lil' P 'pi All h II Q A �J I W l i l,I � W�. � lil IIIIII r, 1-, i i ' CD3 -12 1 ortocoPhltlip5 DoI oVl l011 1 String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/9/2011 10:00 Cement Details - Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 2/14/2011 12:00 2/14/2011 17:00 CD3 - 127 Comment Full returns throughout job - no packing off. Reciprocated pipe until 122 bbls before bumping plug - getting sticky so parked on landing ring. Cement Stages Stage # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Cement to surface 36.0 3,239.0 Yes 56.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 8 550.0 1,180.0 Yes 15.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Objective achieved Cement Fluids & Additives Fluid - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 35.9 2,735.0 445 G 356.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.49 20.70 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 2,735.0 3,239.0 280 G 58.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.00 15.80 Additives Additive Type Concentration Conc Unit label Fluid - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/29/2012 • ! Security Level: AK Development Daily Drilling Report I �IW1 14.'- �Ih a � t ► kt ihh d,iui i 0 - _i� CD3 -127 C+coPhutips Report Number: 6 Rig: DOYON 19 Report Date: 2/14/2011 AFE T Network/ 1D # Total AFE +Sup 10299799 9,660,002.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 127 Development FIORD NECHELIK 3.61 6.0 0.00 3,250.0 3,250.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 7,445.33 72,166.87 673, 534.33 1,692,391.87 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/9/2011 2/11/2011 32.80 31.41 1.39 3/12/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 3,239.2ftKB Ops and Depth @ Morning Report 24hr Forecast PU 5" DP. 10 3/4" shoe at 3239' .NU BOPE. PU 5" DP. Test BOPE. MU BHA #2 & RIH. Last 24hr Summary Run 10 3/4" casing to 3239' MD shoe depth. Circ and cond hole. Cement with 445 sx AS Lite lead slurry and 280 sx 15.8 Class G tail slurry. Got back 56 bbls slurry to surface. ND riser. NU wellhead & BOPE. General Remarks Weather Head Count No incidents. No injuries. No spills. -27 deg. Wind WSW @ 9 mph. WC -48 deg. 47.0 Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Dick Maskell, Rig Supervisor Rig Supervisor Time Log Start End Dur Time Depth Start Depth En d Time Time = = -(bra) Phase Op Code Activity Code P T X _ - -- Trbl Code Trbl Class. ` - - ` ;ftKB) MKS) Operation 00:00 01:00 1.00 SURFAC DRILL PULD P 50.0 0.0 Finish LD BHA #1 and download MWD. 01:00 02:00 1.00 SURFAC DRILL PULD P 0.0 0.0 Clear rig floor of BHA components and clean floor. 02:00 03:15 1.25 SURFAC CASING RURD P 0.0 0.0 PJSM. RU casing tools to run 10 3/4" surface casing. 03:15 03:45 0.50 SURFAC CASING SFTY P 0.0 0.0 PJSM with all crew members, mud engr, TP, Co Rep for running 10 3/4" casing. 03:45 06:00 2.25 SURFAC CASING RNCS P 0.0 0.0 MU shoe track. Bakerlock connections on first 3 jts and pin on jt #4. RIH with 10 3/4" casing. 06:00 06:45 0.75 SURFAC CASING CIRC P 1,626.0 1,626.0 Establish circulation - Staged pumps up to 6.0 bpm - Reciprocate casing and condition mud casing PUW 145K SOW 123K FCP =380 psi - Circulated 1.5 X BU - observed mild amount of cuttings across shakers 06:45 09:00 2.25 SURFAC CASING RNCS P 1,626.0 3,239.0 Run 10 3/4" casing from 1626' to 3201' (79 jts. total) MU FMC fluted hanger and landing joint - land casing w/ FS @ 3239' and FC @ 3158' 09:00 09:30 0.50 SURFAC CASING RURD P 3,239.0 3,239.0 Rd casing tongs and scaffold - LD fill -up tool 09:30 09:45 0.25 SURFAC CEMENT RURD P 3,239.0 3,239.0 Ru 10 3/4" cement head and lines 09:45 12:45 3.00 SURFAC CEMENT CIRC P 3,239.0 3,239.0 Establish circulation - Reciprocate and stage pumps up to 7.0 bpm - condition mud and hole for cementing FCP 330 psi - total pumped 1023 bbls - PUW 187K SOW 148K MWT. 10.o ppg PV 22 YP 17 FV 55 10 sec gels 510 min. 11 Held PreJob safety and operations meeting with rig on upcoming cement job Latest BOP Test Data Date = . `, i',Cornment Page 1/3 Report Printed: 2/29/2012 „Ito 4 1 : • • Security Level: AK Development au 'I ° '! Daily Drilling Report -i II { INl ,r:01 IIIIII ��NI.Inp u Illll�i� IWII "�' � II V"� I CD3- 1 2 I �I ' il ! " Report Number: 6 IGonocoPhill ip Rig: DOYON 19 Report Date: 2/14/2011 Time Log' . Start . ,'End out Time s Repfh Start Depth End Time Time (hrs) ' Phase Op Code Activity Code P X _ Trbl Code - -TrbI Class. (ft ) (ftK$1 Operation 12:45 14:30 1.75 SURFAC CEMENT PUCM P 3,239.0 3,239.0 Cemented 10 3/4" casing as follows: Rig pumped 120 bbls of 10.0 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 2 bbls of FW, tested lines to 3200 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 210 psi. Mixed & pumped 446 sxs of 10.7 ppg lead slurry (4.49 cf /sx yield) (ASL) ave. 7.0 bpm at 276 - 190 psi. Observed nut plug marker at shakers w/ 240 bbls lead slurry pumped (pumped down surge can, 357 bbls total) Switched to tail slurry and pumped 280 sxs of 15.8 ppg tail cmt (1.16 cf /sx) 57 bbls (Class G w/ additives) ave.5.0 bpm at 180 psi. . 14:30 15:30 1.00 SURFAC CEMENT DISP P 3,239.0 3,239.0 Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 282 bbls of 10.0 ppg mud ave. 7.0 bpm, ICP 240, FCP 720 psi, slowed pump to 4 bpm at 550 psi (for the last 8.0 bbls of displacement) Bumped plug to 1180 psi. Checked floats OK, CIP @ 1622 hrs. Had full returns throughout job w/ 56 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 122 bbls of displacement (SOW had dropped to 100K). 15:30 17:30 2.00 SURFAC CEMENT RURD P 3,239.0 3,239.0 Bleed off pressure and check floats - OK. RD cement head. LD landing jt. RD and LD casing tools. Install bails and 5: DP elevators. 17:30 19:00 1.50 SURFAC WHDBOP NUND P 0.0 0.0 PJSM. ND and remove riser. 19:00 20:00 1.00 SURFAC WHDBOP NUND P 0.0 0.0 Orient and install FMC wellhead and test metal to metal seal to 1000 psi for 10 min - good test. 20:00 00:00 4.00 SURFAC WHDBOP NUND P 0.0 0.0 PJSM. NU BOPE. Mud Che Data YP Calo Get ( tOs } G e l ( G e F ( HTHP Fitt Density Temp Solids, Corr.' Type .Depth (ftKB} pens (ibigal }, Yis (skit), PV Cai (Cp }I, .(Ibf/1QOtt} (tbf /1 00ft'} (Ibf /1d fk°} ( ibf/100tt } MBT(Ib/bb1J mLi30mir } p (°F) 09 Spud 3,250.0 10.00 55 22.0 17.0 5.0 11.0 18.000 66.0 injection Fluid k F luid Source iiiii From Lease (bbl) Destination Vendor -Manifest Number Note Cementing Fluids CD3 -127 320.0 CD3 -106 Pit Rinsate CD1 -15 28.0 CD3 -106 ASRC 341604 Water CD3 -127 20.0 CD3 -106 Water Based Mud CD3 -127 490.0 CD3 -106 Water Based Mud CD3 -199 290.0 CD3 -106 ASRC 348901 Water Based Mud CD3 -199 290.0 CD3 -106 ASRC 307363 Water Based Mud CD3 -199 285.0 CD3 -106 ASRC 307364 Water Based Mud CD3 -199 280.0 CD3 -106 ASRC 307360 Water Based Mud CD3 -199 280.0 CD3 -106 ASRC 307361 Page 2/3 Report Printed: 2/29/2012 11 q1: 0 ,, • • Security Level: AK Development p l � "�M Daily Drilling Report r "t l' -' 4 pt, ' k+ Ill ,uupul , ' 1 ►, I9�, w III /'� Q J I �4 lioIl1I� ��. CD3-12/ Cc�nCtc l't►illips s Report Number: 6 Rig: DOYON 19 Report Date: 2/14/2011 Injection Fluid - Fluid Source - From Lease (bb) , Destination Vendor, _ Manifest Number' Note Water Based Mud CD3 -127 172.0 CD3 -106 Water Based Mud CD3 -127 161.0 CD3 -106 Water Based Mud CD3 -127 42.0 CD3 -106 Water Based Mud CD3 -127 38.0 CD3 -106 Water Based Mud CD3 -199 24.0 CD3 -106 ASRC Wellbores ` - Wellbore Name Wellbore API/DWI CD3 -127 501032063400 Section _- Size (in) ,•, Act Top (ftKB) Act, Btm (ftKB) - Start Date,;; ° - End; Date COND1 16 37.0 114.0 6/15/2008 6/16/2008 SURFAC 13 1/2 114.0 3,250.0 2/11/2011 2/16/2011 INTRM1 9 7/8 3,250.0 15,261.0 2/16/2011 2/21/2011 PROD1 6 3/4 15,261.0 Casing Strin String, QDr String Wt °- . Casing Description ftun Date -_ (in),, (tbs/ft) - Stri Grade Set Depth (ftKB - Comment = __ - SURFACE 2/14/2011 10 3/4 45.50 L80 3,239.2 No problems runninng casing to bottom 'Cement - - . Surface Casing Cement - Started @ 2/14/2011 Type Wellbore Cemented String Cement Evaluation Results casing CD3 - 127 SURFACE, 3,239.2ftKB Got - 56 bbls cement back to surface Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 36.0 3,239.0 4 550.0 Fluid "i Class Amount (sacks) V (bbl);', _ , Density (lb/gal) . Yield (ftatsack) Est Top (ftKB) - C Est BtmigtKB) Lead Cement G 445 356.0 10.70 4.49 35.9 2,735.0 Tail cement G 280 58.0 15.80 1.16 2,735.0 3,239.0 Page 3/3 Report Printed: 2/29/2012 • • Casing OR Tubing OR Drilling Detail Well: CO3 - 127 s a t ? - •Fx _ -_ ____ • - - - 111.t_ .._ - - - _ Date: 211312011 ConocoPhillips Rig: Doyn 19 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 o FI Strih ' T r a T o f o. RKB to Top of Landing Ring 35.94 i, ;3;i!;i:.;;. 1.1.1i. FMC 10 % " Casing Hanger 2.53 35.94 Jts 3 to 79 77 Jts 10 /a ", 45.5 #, L - 80, Casing 3119.29 38.47 HES 10 3 " Sure Seal Il Float Collar 1.19 3157.76 Jts 1 to 2 2 Jts 10 %", 45.5#, L - 80, Casing 77.95 3158.95 Ray Oil Tools 10 3/4" Silver Bullet Float Shoe 2.32 3236.90 3239.22 3239.22 3239.22 13 - 1/2" Hole TD c 3,250' MD 2,457" TVD 3239.22 3239.22 10 Shoe § 3,239' MD 2,453' TVD 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 Bowspring Centralizers on Joints 1 - 13 & Every Other Joint f/ 15 - 77 3239.22 3239.22 90 Joints in Pipe Shed - Last 11 Stay Out 3239.22 3239.22 Ran 2 stop rings and 46 Bow Spring centralizers 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 3239.22 Remarks: Casing drifted with 9.880" Teflon Rabbit Up Wt 205.00 Average MUT = 11,000 ftllbs Dn Wt 147.00 Run -N -Seal thread compound used on all connections Block Wt 70 K Supervisors: D. Burley / D. Maskell PRESSURE INTEGRITY TEST CONOCOPHILLIPS A laska, Inc. Well Name: CD3 -127 Rig: Doyon 19 Date: 2116/2011 Volume In • ut Volume /Stroke Pum • Rate: Drilling Supervisor: D. Mickey / D. kilaskell Pump used: #2 Mud Pump _ Strokes V t .;1 gcm Bbls /Strk V 9:0 Bbl /min V Type of Test: Casing Shoe Test LOT /FIT ♦ Pumping down annulus and DP. V - Casing Test " Pressure Integrity Test Hole Size: 13-1/2" v I Casing Shoe Depth I ( Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 35.OIFt 1 3.239IFt -MDR 2,453IFt -TVD 3,270IFt -MD 1 2 -TVD Strks psi Min psi Strks psi Min psi Casino Size and Description: 7 10 -3/4" 45.5 # /Ft L -80 BTC v 1 0 0 0 ::3550 :;:;:;:1; :H:::1:19 01:H11020 Casing Test Pressure IntegritvTest 4 100 1 :,:355'0 :; ::' 2::::::::`:75: 0.25 ::;';:;x;-950 Mud Weight: 9.6 ppg Mud Weight: 9.6 ppg 8 ::,400 2 !:3550 3 ::::100: 0.5 ::::::::::850 Mud 10 min Gel: 18.0 Lb /100 Ft2 Mud 10 min Gel: Lb /100 Ft2 : ! 12 x x:775 3 .;:3550 ::::::::::::4 x ;x;150 1 :;:;';:;:770 Test Pressure: 3,500 psi Rotating Weight: Lbs ;'16 ::1200 4 ;'3550 =5 :' 200 1.5 7 Rotating Weight: Lbs Blocks/Top Drive Weight: Lbs :::20 1354 5 `3525 6 2 60: 2 7'.,.. Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 24 ;1:1600 6 ::3525 : x ;:;:;:;: 2.5 :. ;;685 Estimates for Test: 4.5 bbls Estimates for Test: 1071 psi 1.3 bbls :28 :::'1400 7 ::3525: ::::::::::8::':':':'420 3 :::::::::675 • ? ` :::::32 2100 8 ::3525 :::: 9 .:.480: 3.5:;::::.670 EMW = Leak -off Pressure + Mud Weight = 950 PIT 15 Second :;:;:36: !;:2400 9 ::3525 :":: ;:;:;:;:550' 4 ;::665 + 9 0.052 x TVD 0.052 x 2453 6 Shut -in Pressure, psi 40' 2750 10 ;:3525 :x:;:;:;:;1: - - 600: 4.5 :::::;:;;'660 EMW at 3239 Ft -MD (2453 Ft -TVD) = 17.0 ppg 950 :::::,44. ; ;3100 15 :;3525 " :: 12 .: 5 :::::::::660 4000 Lost 25 psi during test, held — ; 48 :;450 20 . 3525 ;!::::13 :::'::::'700 5.5 :: - :x 655 99.3% of test pressure. = iii, 49 .,3550: 25 ;;3526 '14 :..::::750 6 :::::::::650 3500 ■ ka::cxita :::r —ii— —A. 30 "3525 ::::15:::::: 780. 6.5 :::::::: 650 ;;;1:1:1:116 ::: 830: 7:::::::65 0 3000 17: ;:::::x:860: 7.51:1:1:1:1660 ::::18: xx900: 8 :;::::::645 w 2500 ::: "19::::::::: 8.5 ;::;;;;:640 re "20::; 95 0 9 ::::'::::640 2000 ti :::::2:1:::::;;;:;970: 9.5 : ":::64a 22 x >:x 990 10 ::::::::::6' a. 1500 ,. 2 : :: 990 24:::: 1000 - 25 xxx x 1010 : _ 2 6 1 010 ; :27:::1020 500 i 28 11:1'1020 , 0 1 2 3 4 5 6 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume 'CASING TEST — LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 4.9 Bbls x Bbls 2.8 Bbls Bbls Comments: • • Note to File CD3 -114 (207- 033...312 -088) Colville River Unit (Fiord Pool) ConocoPhillips Alaska, Inc ConocoPhillips has made application for an extension of annular disposal for the subject well. Current total Annular disposal is 32p00 bbls. CPAI requests that the total volume allowed for this well be increased to 70,000 bbls. This document reviews the pertinent information for the well and recommends approval of ConocoPhillips' request. - - Surface casing was cemented back to surface. No problems were reported. Approximately 134 bbls of cement was circulated to surface with full circulation during the job. The net cement remaining in the surface hole was 73% XS of the calculated hole volume. Reciprocation was stopped prior to cement reaching the shoe. - - On the initial leak off test, the pressure rises smoothly to 16.4 EMW where it breaks over and flattens out for a easily recognizable break -over. One barrel of fluid was pumped to reach break -over. The pressure declined only slightly during the observation period to about 16.3 EMW. The initial leak off indicates that the surface casing shoe is well cemented. - -No problems were reported drilling the intermediate hole. The 7" casing was run and successfully cemented with a two stage job. The first stage went as planned though returns are not mentioned. The second stage (Qannik) also went as planned with 38 bbls placed in the 7" annulus. ( TOC should be at 4800' md). No mention of reciprocation was noted. - -An injectivity test down 9 -5/8" x 7" annulus was conducted. Pressure steadily increases until a change in slope at 13.6 EMW. The slope increases to 14.2 EMW at break -over. The pressure declined with additional pumping to 13.8 EMW. During the observation period, the pressure declined to 12.7 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 '/4 mile radius of CD3 -114. The nearest surface shoe is CD3 -115, about 306' distant which is another annular disposal well (AD # 309 -087). Additional wells in the area include are CD3 -117 at 720 ft away and CD3 -122 is 400 feet away. Additional wells drilled in the area since first starting AD include CD3 -125 anc CD3 -128 which are 353' and 468' away at surface shoe respectively. Examination of the cementing information and LOT data did not reveal anything to preclude granting CPAI's request. i 1111b Guy Sc - 3/u Sr Petroleum En g. . g G:\AOGCC\ Common \tommaunder \Well Information\By Subject\Annular Disposal \032212 -- CD3- 114.doc • • Note to File CRU CD3 -114 (PTD 2070330) March 16 2012 Re: ConocoPhillips' Application for Sundry Approval for Additional Annular Disposal of Drilling Wastes within Well CD3 -114 Request ConocoPhillips requests approval to increase the volume limit to 70,000 barrels for disposal of waste fluids generated through drilling operations by injection into the 9 -5/8" x 7" annulus within well CD3 - 114. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9 -5/8" surface casing shoe is set in this well at about 2,892' measured depth (- 2,435' true vertical depth subsea, or "TVDSS "), near the base of a 400 -foot thick mudstone 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 silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining mudstone strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. To date, 32,000 barrels of waste have been disposed in the annulus of CD3 -114. The proposed disposal injection of 38,000 additional barrels of waste will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular disposal will be limited to a radius of about 150' from the wellbore. Discussion CPAI's application was reviewed along with well logs from Colville River Unit (CRU) wells CD3 -108, CD3 -114, CD3 -118, CD3 -113, and the Nechelik 1 exploratory well. The mud log from CRU CD3 -114 was also reviewed. An index map is provided in Figure 1, below. All footages presented herein represent measured depth, unless otherwise noted. All thickness footages represent stratigraphic thickness, unless otherwise noted. The CD3 -114 development well was drilled to the Fiord Oil Pool within the CRU. ConocoPhillips, the operator, intends to dispose of drilling wastes utilizing an open annulus within CD3 -114 that extends downward from the 9 -5/8" surface casing shoe, which is set at about 2,892' (- 2,435' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 4,900'( -3,685 TVDSS).' This annulus lies within Section 5 of T12N, R5E, Umiat Meridian (see Figure 1). The annulus is located more than 2- 1/2 miles from the current boundary of the CRU. 1 Top of cement estimate from \ \Doaanco,gcfps01\ Shared \AOGCC \Common \tommaunder \aa2009 0712 Working,- Well Cement Current.xls, worksheet MIT II, PTD 207 -033, column 30% Excess TOC. . • • CD3 - 114 March 16, 2012 Note to File Page 2 of 5 To date, 32,000 barrels of waste have been disposed in the 9 -5/8" x 7" annulus of CD3 -114. ConocoPhillips proposes to inject an additional 38,000 barrels of waste fluids into this same annulus. The section of annulus in CD3 -114 that has accepted injected waste fluids in the past and will most likely continue to accept the additional injected waste fluids (herein termed the most likely receptor interval) is a portion of the Seabee formation that extends from about 2,950 to 3,210' (- 2,470' and - 2,625' TVDSS; see Figure 2, below). This 150 -foot thick interval contains numerous 1- to 2 -foot thick beds of sandy siltstone and silty sandstone that are separated by siltstone, mudstone and shale. The aggregate stratigraphic thickness of the sandy siltstone and silty sandstone beds exposed to the annulus is about 20 feet. On the well log from CD3 -114, the gamma ray curve suggests the presence of a thick, silty sandstone bed at the shoe of the 9 -5/8" surface casing. This apparent silty sandstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 9 -5/8" casing shoe consist of mudstone and siltstone (see Figure 3, below). 7:ai x•17991 ,t �\ CD3 -111 L , \ pCD3 -301 060420 18645 \ � D3-301A i t+ 0� L1 IgaitlitiA CD3 -111 0,,,, 1343e Zg7s; a 10640 19462 aoGOS� 15o7a i • . QCD3 -112 it 07. / `$O 16021 Ilk ' D3- 114 i L70fl0 10 i1 173 3 38 \ ° 0 11 e CD3 -114 07033016001. \ \ \ �� .. 302 '> QCD3 -115 �',, 1 V �. x — 0 50,0o to 090000 20531 \, 2 QCD3.118 • \ � ' �� / D3 ' + -3U 32 2,080250 21450 20 0 98 30PB2 82 GD a CR � D3.1 \V CRU CD3 -114 ? 00 02PB1 , 0� -1 �, emu A A P 2010610 9820 4 4, ', Annulus 2 � ,e' 0040 aa� \ \ \ \ C3 (" ; , _ , ,ry -1 e9a1 ° J � .e.^'_"""'we!«' .3 3 \ :.a CPF 177770 0 Area of Review Most Likely Receptor Surface casing shoe Interval (shaded blue) Cement top (highlighted with red) Figure 1. Index Map (The path of the cross - section shown on Figure 3 is highlighted with a red line) " interval that is dominated b y The 9-5/8" surface casing shoe lies near the base of a 300 -foot thick g mudstone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 50 -foot thick siltstone interval that is also continuous throughout the area. This interval, which lies between about 3,240 and 3,335 (- 2,645' and - 2,700' TVDSS), and three similar, thinner, underlying mudstone intervals will provide additional lower confinement for injected wastes. • • • CD3 - 114 March 16, 2012 Note to File Page 3 of 5 In vicinity of Drill Site CD3, the base of permafrost occurs at about - 1,250' TVDSS, which is about 1,200' shallower than the top of the likely receptor interval. Correlation Depth Resis Porosity OR <MD ResD(RT) RHOB(N /A) _ -10 API 24C 0.2 OHMM 20' .65 2.66 TVDSS> ResM(RPM) - and - Silt - Shale ow Poro 3.2 OHMM 20 SP(N /A) TVD ResS(RPS) NPOR -100 10C 0.2 OHMM 20' .0 C Upper <MD DTCP(NJA) Confining `,91717 -�y Strata ■ Most Likely 3000 Receptor Interval for 3100 Disposed Fluids 3200 - 3300 3404 1110! . � t 11111 Lower EMI Confining ----* 1 �ntuu _ + .- _; l Strata 1; 1111; ' .- 3600 1 �' IL . \ii: 370Q t� _= µ ' qua _ . - - -1- 3800 oi unimi 3900 I LA 9 T 4- t 4000 ! k �. LL + ! = 3 + t -i *--1 4100 ill rt �.._ 4200 n ' 4300 - 4400 Figure 2. CD3 -114 Well Log Displaying Affected Intervals Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the proposed affected area. This well is the only well that was mud logged on Drill Site CD3. In CD3 -114, methane was first encountered at about 1,115' (- 1,050' TVDSS). So, the entire proposed disposal zone likely contains some gas. ; • • CD3 - 114 March 16, 2012 Note to File Page 4 of 5 1811490 2080250 2070330 2070040 2050330 w 501032002000 501032057000 501032054400 501032054100 501032050700 E 12385% 1995 144% -____ 615 ft ■ —0 4 50+110 CONOCOPHILLIPS ALASK CONOCOPHILUPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK NECHELIK 1 COLVILLE RIV UNIT CD3 -118 COLVILLE RIV UNIT CO3114 COLVILLE RIV UNIT CD3 -113 COLVILLE RIV UNITCD3.108 2340 FSL 814 FWL 3978 FNL 1010 FEL 3980 FNL 2703 FEL 3955 FNL 914 FEL 1349 FSL 816 FEL TWP:12 N- Range :5 E- Sec .18 TWP:12 N- Renge:5 E - Sec .5 TWP:12 N- Range :5 E - Sec .5 TWP:12 N- Range :5 E - Sac. 5 TWP:12 N• Range :5 E - Sec .5 .0111111111108M - -- i I - ."' T — v_ Upper - 1 Confining Strata \. 1 - 9 -5/8" Casing Shoe '-'t - - J Likely iii. " f r Receptor _[ n , + 1 ; : - : Interval i —� L ower '� I _ - t fi Conning 7,, { - ` Strata jf TD .10018 y - TD.21450 - _ -..v_ 7 0.18601 - T D =17338 T AI 1 - - - _ 15915 — Figure 3. Structural Cross - section Including CD3 -114 The shallowest oil show encountered in well CD3 -114 was observed at 6,050' (- 4,413' TVDSS), about 1,800' stratigraphically below the most likely receptor beds for the injected material. This show consisted only of 10% dull yellow sample fluorescence and a slow pale yellow sample cut in solvent, and the mud logging geologist rated this show as being of "trace" quality. This instance is judged to represent only small amounts of residual (non- mobile) oil. So, at Drill Site CD3 the likely disposal interval does not contain potentially commercial quantities of oil or gas. The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD3 -114 that will be affected by the proposed additional annular disposal operations. There are about 10' of porous sandy siltstone and silty sandstone beds within the likely waste receptor interval, according to a count using the gamma ray curve from CD3 -114. Neutron and density porosity well logs were run across the proposed disposal interval in nearby well CD3 -108. Inspection of these well logs suggests an average porosity of about 28% for the sandy siltstone and silty sandstone within the likely receptor interval. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 150' from the wellbore, as indicated in the chart below. • • CD3 - 114 March 16, 2012 Note to File Page 5 of 5 Injected Fluid vs Affected Radial Distance CD3 -114 Wellbore (assumes 20' aggregate injection zone thickness and 28% porosity) 300 § 250 0 .0 d 3 200 E 0 0 0 A 150 100 - d 0 d w `¢ 50 0 0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 Amount of Injected Fluid (barrels) Figure 4. Radial Distance Potentially Impacted by CD3 -114 Annular Disposal Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains some gas, is situated beneath about 1,250' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD3. The open annulus that will be used for disposal injection lies inside the CRU, well away from any external property lines, so correlative rights are not a concern. The area most likely affected by the additional proposed waste volume lies within about 150' of the CD3 -114 wellbore. I recommend approval of increasing the volume limit for annular disposal within CD3 -114 from 35,000 barrels to 70,000 barrels. 0 Steve Davies Senior Petroleum Geologist _ e_ oKG ` 4A- ? ,Aj" Gse- .4 rharof 4 4 • Ij Cam' X s-) Pct 1 "; . _ peer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1, Operator: 4a, Well Class: Stratigraphic ❑ Service 77 1 6. Permit to Drill Number: 207 -033 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD3 -114 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG © 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20544 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation ❑ or Final III 310 -037 2/9/2010 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 347* 347 totals (bbls): 2010 / 1st 25703 100 0 25803 21 3/4/2010 3/29/2010 CD3 -121, CD3 -301A 2010 / 5750 100 0 5850 6 4/16/2010 4/21/2010 CD3 -123, CD3 -302A 2nd 2010 / 3rd 0 0 0 0 0 201014th 0 0 0 0 0 , 2011 /1st 0 0 0 0 0 Total Ending Report is clue on the 20th Volume 31453 200 347 32000 27 (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 ❑, ,. AP R 1 zoi' October 20 for the third quarter, and January 20 for the Other (Explain) El fourth quarter. 12, Remarks and Approved Substances Description(s): `freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. { Signature: Aaok. Date: 4 t u V G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • 'iv" • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 3, 2011 b 7- c: p 3 -1 t , Commissioner Dan Seamount 0 - Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 , . 1 '01 Anchorage, AK 99501 9 2,011 ` , 01 - ' " ICls, „si0n o ,.roe 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, fr , , '4 /4 1 / 7 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 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 NA _ 2.55 1/31/2011 CD3 -121 50103206150000 2100220 32" NA 32" 27.2 1/31/2011 CD3 -122 50103206090000 2091530' 74" NA _ 74" _ NA 32.2 1/31/2011 CO3 -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 RIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL :~(~% 41 °~ 201i A(ask~ 0~1 ~ ~s~. Cof~nmission Operator: 1 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 207-033 . ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-114 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20544-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 310-037 2/9/2010 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: reserve pit fluids cuttings fluids and drill rig approved substances (include days Beginning Dates Ending Dates , cement-contaminated domestic waste water descriptions in block 12) disposal ~ ,.;~:a~ ~.~ ,1~~~(€ drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 347* 347 totals (bbls): 2o1o/1st 25703 100 0 25803 21 3/4/2010 3/29/2010 CD3-121, CD3-301A 2010/ 5750 100 0 5850 6 4/16/2010 4/21/2010 CD3-123, CD3-302A 2nd 2010 / 3rd 2010 / 4th Total Ending Report is due on the 20th volume 31453 200 347 32000 27 of the month following the final month of the quarter. Ex: (bbls>: 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 Description(s): '`freeze rotect volumes onl orrect to the best of my knowledge. c I hereby certify that the foregoing is true and (' ~ Signature: ~~~ Date: 2 ~(~ ~Zp ((~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~; Y ~ r:i .; ~~~ .~. .~ .. ... ~ ~~ ~ 'a~~ w ;~~°" ~ ~x ~. ~.`. ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~~~w~EL APR ~. ~ 201a ~ ~Il ~ Gas Cons, Commission 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: 207-033 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-114 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20544-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal Q or Continuation ^ or Final ^ 310-037 2/9/2010 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 drillin mud, com letion occurred ~ fluids, formation fluids and any necessary water added Previous 347* 347 totals (bbls): 2010 / 1st 25703 100 0 25803 21 3/4/2010 3/29/2010 CD3-121, CD3-301 A 2010 / 2nd 2010 / 3rd 2010 / 4th Total Ending Report is due on the 20th volume 25703 100 347 26150 21 (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): "fre@Ze rotect volumes onl I hereby certify that the forego i is t rue and correct to the best of my knowledge. ng // nn ••~~ / ~ Signature: ~G~ 1..~'~ Date: G~(Z(2cs7 0 f Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • MEMORANDUM To: Jim Regg ~ 3f ~( (lo 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 CD3-114 COLVILLE RIV FIORD CD3-114 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: COLVILLE RIV FIORD CD3-114 Insp Num: mitJCr100227175225 Rel Insp Num: API Well Number: 50-103-20544-00-00 Permit Number: 207-033-0 Inspector Name: John Crisp Inspection Date: 2/26!2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WCI~ CD3-114 Type Irij. V/ P.T.~1' 2070330 T pe'I'eSt SPT _ I _~.-- TVD Test psi 662 1656 1529 2546 ~ OA ~ 361 375 2500 i 2497 ~~~ 374 375 Interval aYRTST ~ p~ P ~` Tubing I 1877 i 1876_ 1877 ~ __ 1877 -- - Notes: •9 bbl pumped for test. - --- ,yiy'J~r~~~ m 4st++'' Monday, March O1, 2010 Page 1 of 1 L J • Mr. Chip Alvord Alaska Drilling Manager ConocoPhillips P.O. Box 100360 ~.~+~,,~;'~,~ r F~.k~l ~, `'% Z~l1u Anchorage, Alaska ~~ Re: Colville River Field, Fiord Oil Pool, CD3-114 ~"" Sundry Number: 310-037 Dear Mr. Alvord: 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 to Superior Court unless rehearing has been requested. Jr. DATED this~/~day of February, 2010 r~ u Note to File CD3-114 (207-033...310-037) Colville River Unit (Fiord Pool) ConocoPhillips Alaska, Inc ConocoPhillips 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 back to surface. No problems were reported. Approximately 134 bbls of cement was circulated to surface with full circulation during the job. The net cement remaining in the surface hole was 73% XS of the calculated hole volume. Reciprocation was stopped prior to cement reaching the shoe. -- On the initial leak off test, the pressure rises smoothly to 16.4 EMW where it breaks over and flattens out for a easily recognizable break-over. One barrel of fluid was pumped to reach break-over. The pressure declined only slightly during the observation period to about 16.3 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems were reported drilling the intermediate hole. The 7" casing was run and successfully cemented with a two stage job. The first stage went as planned though returns are not mentioned. The second stage (Qannik) also went as planned with 38 bbls placed in the 7" annulus. (TOC should be at 4800' md). No mention of reciprocation was noted. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until a change in slope at 13.6 EMW. The slope increases to 14.2 EMW at break-over. The pressure declined with additional pumping to 13.8 EMW. During the observation period, the pressure declined to 12.7 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 '/4 mile radius of CD3-114. The nearest surface shoe is CD3-115, about 306' distant which is another annular disposal well (AD # 309-087). Additional wells in the area include are CD3-117 at 720 ft away and CD3-122 is 400 feet away. Examination of the cementing information did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. 77 S Tom Maunder, E Gfay~ Schwartz Sr. Petroleum Engineer Sr. Petroleum Engineer February 23, 2010 G:\AOGCC\Common\tommaunder\Well Information\By Subject\Annular Disposal\100223-- CD3-ll4.doc • i Note to File CRU CD3-114 (PTD 2070330) February 17, 2010 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD3-114 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the 9-5/8" x 7" annulus within well CD3-114. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set in this well at about 2,892' measured depth (-2,435' true vertical depth subsea, or "TVDSS"), near the base of a 400-foot thick mudstone 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 silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining mudstone strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of about 110' from the wellbore. Discussion CPAI's application was reviewed along with well logs from Colville River Unit (CRU) wells CD3-108, CD3-114, CD3-118, CD3-113, and the Nechelik 1 exploratory well. The mud log from CRU CD3-114 was also reviewed. An index map is provided in Figure 1, below. All footages presented herein represent measured depth, unless otherwise noted. All thickness footages represent stratigraphic thickness, unless otherwise noted. The CD3-114 development well was drilled to the Fiord Oil Pool within the CRU. ConocoPhillips, the operator, intends to dispose of drilling wastes utilizing an open annulus within CD3-114 that extends downward from the 9-5/8" surface casing shoe, which is set at about 2,892' (-2,435' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 4,900'(-3,685 TVDSS).' This annulus lies within Section 5 of T12N, RSE, Umiat Meridian (see Figure 1). The annulus is located more than 2- 1/2 miles from the current boundary of the CRU. i Top of cement estimate from \~Doaanco~cfp~01\Shared~AOGCC\Common\tommaunder\aa2009 0712 Workine- Well Cement Current.xls, worksheet MIT II, PTD 207-033, column 30% Excess TOC. • CD3-114 Note to File • February 17, 2010 Page 2 of 5 The section of annulus in CD3-114 that will most likely accept the injected waste fluids (most likely receptor interval) is a portion of the Seabee formation that extends from about 2,950 to 3,210' (-2,470' and -2,625' TVDSS; see Figure 2, below). This 150-foot thick interval contains numerous 1- to 2-foot thick beds of sandy siltstone and silty sandstone that are separated by siltstone, mudstone and shale. The aggregate stratigraphic thickness of the sandy siltstone and silty sandstone beds exposed to the annulus is about 20 feet. On the well log from CD3-114, the gamma ray curve suggests the presence of a thick, silty sandstone bed at the shoe of the 9-5/8" surface casing. This apparent silty sandstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 9-5/8" casing shoe consist of mudstone and siltstone (see Figure 3, below). ~ .-. ~ ;. n, ~ -~4; , -_~ •CD ~-111 L1 r ~~~: D3 - 30i - ~ J CD3 111 'y ~ ~ t 3S'11' ~~D3 X301 A .,,, . ~" ~~ rvu~a~7L - - nio~~,~ ~~ '' .(107 ~ CD3.112 r ; ~ l~~ I CJ~'t~~~' ~ ~.~;01201RU21 ~ I ~ ~: ' 1110>0~ 74'= i i ~~ D,3-114 CZ~fla11 70010'17 ~ 3 338 ~ ~' y ~~ CD3114 'u,ovir teas, ~ ~ ~ - ` Q GD3-115 {o~w;o ~n€3i ' ~` ~ ~ ~~~ ~ \~~ -3nl ~ ,] ~ t- ~ ` ~>uiou i ~~ ~ G1CD3-118~~ ~ ~ ~ti ~ ~~}~,. ~pg ,*~~~ 1 '; ~~~3n~~~113.302PB i N0. 50 11450 ` ~ ~~ \ i 4% ~ 20ii0Y00 v; ..: ~ ~ \ - I ~ ~ CD`s r~ ~?, s ,, ,CR 6t 11Q ~'4Q ~Ipi1 i r,~ E 1 -'?0 '~ ~ .rd~ ~'~ ...~~ CRU CD3-] 14 D3-aozPel ~rt~ioo s~a± . ^ ' ~ Annulus << 0106 1098 <U \ * ~ y~y ~ A - ,~: ^^ I \ ~ -.''~ s C 3- - - - CPF-~ - - -~ ~~ ~'~ - Area of Review Most Likely Receptor Surface casing shoe „ (shaded blue) Interval ' Cement top ~ (highlighted with red) ~- ~; ~~:~~~., Figure 1. Index Map (The path of the cross-section shown on Figure 3 is highlighted with a red line) The 9-5/8" surface casing shoe lies near the base of a 300-foot thick interval that is dominated by mudstone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 50-foot thick siltstone interval that is also continuous throughout the area. This interval, which lies between about 3,240 and 3,335 (-2,645' and -2,700' TVDSS), and three similar, thinner, underlying mudstone intervals will provide additional lower confinement for injected wastes. In vicinity of Drill Site CD3, the base of permafrost occurs at about -1,250' TVDSS, which is about 1,200' shallower than the top of the likely receptor interval. • • CD3-114 Note to File Upper Confining Strata Most Like Receptor Interval fc Disposed Fluids Lower Confining Strata Figure 2. CD3-114 Well Log Displaying Affected Intervals February 17, 2010 Page 3 of 5 Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the proposed affected area. This well is the only well that was mud logged on Drill Site CD3. In CD3-114, methane was first encountered at about l,l 15' (-1,050' TVDSS). So, the entire proposed disposal zone likely contains some gas. • CD3-114 Note to File February 17, 2010 Page 4 of 5 1811490 2080250 2070330 2070610 2050330 W 501032002000 - 501032057000 501032051400 50103205{100 501032050700 Z,` 12365ft 4 199fl ~ 1 1Mfl ~ 1 815h li SOHIO' CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK NECHELIK 1 COLVILLE RIV UNIT CD3-118 COLVILLE RIV UNIT CD3-114 COLVILLE RN UNIT CD3113 COLVILLE RIV UNIT CD&108 2340 FSL 514 FWL 39]8 FNL 1010 FEL 3980 FNL 2703 FEL 3955 FNL 911 FEL 1349 FSL 818 FEL TWP'12 N-Rarpe:5 E-Sec. 18 TWP: 12 N-Range:5 E-Sec.S TWP: 12 N-Re1ge:5 E-Sac.S TWP: 12 N-Ranga:5 E-Sec.S 7NP: 12 N-Range:5 E-Sac.5 ' O - ~ ~iit 0 -O I I, i° " - ~ - { ~~ UPper - -~ - J Confining .. • ~' - 9-5/8" Casing Shoe Strata ~ _ f - _ ' ~{ Likely ~ ~~~-~; r-- ~ ~ } i ~ ~-: f- Receptor ~ ~ ~' Interval ~ !~ ~- -~ ~,~- - : -~ ~ - i Lower ~- _ ~ - ~ - -. ;Confining ~, ~ - _ ~ ~ ~ Strata ~' ~ ~- _ 1 ; - ~f f - t i# __ - '~ 4t i ~{ TDa10018 ~ ~ TD~11450 - TD=18801 TO=17338 TD=18815 Figure 3. Structural Cross-section from Nechelik 1 TO CRU CD3-108 The shallowest oil show encountered in well CD3-114 was observed at 6,050' (-4,413' TVDSS), about 1,800' stratigraphically below the most likely receptor beds for the injected material. This show consisted only of 10°/D dull yellow sample fluorescence and a slow pale yellow sample cut in solvent, and the mud logging geologist rated this show as being of ``trace'' quality. This instance is judged to represent only small amounts of residual (non-mobile) oil. So, at Drill Site CD3 the likely disposal interval does not contain potentially commercial quantities of oil or gas. The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD3-114 that will be affected by the proposed annular disposal operations. There are about 10' of porous sandy siltstone and silty sandstone beds within the likely waste receptor interval, according to a count using the gamma ray curve from CD3-114. Neutron and density porosity well logs were run across the proposed disposal interval in nearby well CD3-108. Inspection of these well logs suggests an average porosity of about 28% for the sandy siltstone and silty sandstone within the likely receptor interval. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 110' from the wellbore, as indicated in the chart below. CD3-114 Note to File • February 17, 2010 Page 5 of 5 Injected Fluid vs Affected Radial Distance CD3-114 Wellbore (assumes 20' aggregate injection zone thickness and 28% porosity) 250 o I a i m ~ 200 i E 0 w d U ~ 150 N R '~ ~ 100 m v Q 50 i~ i 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 4. Radial Distance Potentially Impacted by CD3-114 Annular Disposal Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains some gas, is situated beneath about 1,250' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD3. The open annulus that will be used for disposal injection lies inside the CRU, well away from any external property lines, so correlative rights are not a concern. I recommend pproval of this annular disposal project. ~.-~-~? ~~ Steve Davies Senior Petroleum Geologist ~ ~ Oar C v/'• ~~ ~~~ ,~~ V, ~ y ~vb~ ~~ /I/J ~. L3'~~ 7 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 8, 2010 • ConocoPhilli s R~CEIVED rr~ i o Zoo Alaska Oil and Gas Conservation Commission 333 West 7"' Avenue, Suite 100 Anchorage, Alaska 99501-3539 Alaska ail & Gas Cana. Cam~sion Anchorage , Re• Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3-114 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3-114 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 CD3-114 approximately February 22, 2010. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 9-5/8" x 7" casing annulus 11. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within 1/ mile radius at AOGCC: CD3-111, CD3-112, CD3-113, CD3-118, and CD3-115 13. Information regarding remaining wells within'/ mile radius included in sundry package: CD3-117, CD3-122 14. 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 (14.2 ppg) occurred at a lower equivalent mud weight than the casing shoe test (16.4 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 Ryan Robertson at 265-6318 or Chip Alvord can also be reached by calling 265-6120. Sincer C Ryan Robertson Sharon Allsup-Drake ATO-1530 Drilling Engineer cc: CD3-114 Well File Chip Alvord ATO-1570 ~~~ ~ ~0 ?r'L ~"~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RE~l r r~ ~ 1 0 2 010 ANNULAR DISPOSAL APPLICATION dlaska Oil & Gas Cans.Cssiorl 20 AAC 25.080 Anchorage 1. Operator 3. Permit to Drill Name: 207-033 ' ConocoPhillips Alaska a. API Number: 50-103-20544-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3-114 ' 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: CD3-111, CD3-112, CD3-113, CD3-118, CD3-115, CD3-117, shale, siltstone and sandstone ' Torok and Seabee formation CD3-122 , ~~'d~ L ,a0~.--15 ~ b) Waste receiving zone: ~`~~ b) water wells within one mile: S~~ti ~~ ~ WE`` Sand layers below the C30 marker in the Seabee formation cc ^++ ~-c~~S -~O r'" ~~~IOi~c~~r\ None 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 1658' 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 2119 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- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and other 22-Feb-10 substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) ~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph 0 Surf. Casing Cementing Data ^~ Other ^ g_revious authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Title: ~~~~G Signature: iN-~( - v Printed _ ~ Phone ~ ~~ N b d " ~~'~"~"''~ ~ ~ um 1 er: 265-6120 Name: Chip Alvord Commission Use Onl LOT review and approval: Conditions of approval: ) ~/ roval number: I ~~ ~ 3 A D ~- pp 7 Subsequent form required: ! APPROVED BY OMMISSIONER THE COMMISSION Date: y~ FEB 2 5 2010 ~ Form 10-403RD Rev. 6/2004 I CT NS ON REVERSE p a f ~~ ~d~Submit in Duplicate- ~ ~G~~IQ ((~//~ • • Annulus Disposal Transmittal Form -Well CD3-114 nnr_~~ Uo.,,,l~r;..,,~ ~n e e~ ~~ nQn rho 1 V Desi ation of the well or wells to receive drillin wastes: CD3-114 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 fmding 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 may be 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 equipment after producing drilling/completion fluid (see included note from CD1&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 2119 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 T'he 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 CD3-124, CD3-121, CD3-1.23, CD3-301A, CD3-302A 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 com liance would be im rudent. 16 Any additional data required by the commission to confum N/A containment of drillin waste. • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Well CD3-114 Assumptions Date 2/5/2010 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi Gf? I :F ' Maximum Fluid Density to avoid Burst o ::. f Surface Casi °,' ' Pburst85% - PHydrostatic +PApplied - PFormation '' '' i I . Version 1.0 - Jan'OS 4,888 = ( 2,485 * 0.052 *MWmax ) + 1500 - (0.4337 * 2,485 ) MWmax = 34.6 PPg 2,485 TVD Surface Casing String Size 9.625 in Weight 40 ppf Grade L 80 rbnrstloo°i° 5,750 psi Pburstss% 4,888 psi Depth of Shoe 2,485 ft FIT/LOT @ Shoe 16.4 ppg or 2,119 psi FIT/LOT for Annulus 14.2 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 4,675' MD _ 3,593' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader a.s "Tubing 6,560 TVD 4,599 = ( 3,593 * 0.052 * MWm~ ) + 1,500 - (0.0700 * 3,593) - 1,000 MWmax = 23.3 PPg 2nd Casing String Size 7 in Weight 26 ppf Grade L 80 1'collapsel00% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 3,593 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/I,OT Pmax allowable - (2,485 * .052 * 16.4 ) Pmax allowable - 2,119 psl This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". SURFACE CASING SHOE SEPARATION FROM CD3-114 CD3-114 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: t1 is ante Ann. from Surface csg. Surface Details @ Disp. Ann. Object Shoe X Surface csg. Surf LOT casing TVD Annular Wells AOGCC Permit # Permit Date Source well Vol. ** Start Date End Date well* Coord. Shoe Y Coord. (ppg) (ft) LOT (ppg) Comments z u .. . .._ ~, .. ~, u CD3-110, CD3-111, CD3-112, CD3-109 v 306-020 1/20/2006 CD3-307. CD3-302 64635 1/20/2006 3/4/2007 2140 388917.3 6004780.2 18.0 2414 16.0 Extended to 70000bb1, exp 03/17/07 known as GD3-107, secontl annh cut and Dull operations Feb 2007 6003901.1 shoe test Lateral distance in feet, between surface casing shoes, in the X-Y plane As of Nov 5, 2009 ote that this sheet is not the definitive record for annular disposal volumes • .. Conocol'hillips HALLIBURTON Sperry Grilling 1950 --- C D 3 -114 Name Quarter Mile View ~,\ti O~~ G - - - -- - ~ 11 _li 1 Gpg~ WELLBORE TARGET DETAILS (MAP CO-ORDINATES) IVOSS +N/-S +U-W Northiny Easling ShapeNO wellbore target data is availabl ~~e~ls J ,~ 0 10g `95 1 '~~~~ G~3~106/C~_\ GO~^ G03- ---_- r0~'~0'b x 13 0 0 - - - 5/8" x 121/4" `'. ~~ g S~ x 12 1/4" 011 ~~ 9 5/8" x 12 1/4" 9 5/8" 1 CD3-107L1 ,~0~ C ~' ~ ~t ~ ~ GK'S - ' - G~3.3p1 ~ 0 650 - - 9 5/8" x 12 1/ " 9-5/8" ~ /4" TDr 12 1/ ~ ~~ I ' x 12 1/4" v ~ 9-5/8" x 1/4" TD ~ ~ I .e ~~ ~- ~ w v~ W ~ i I o L 1~a ~ ~ .. x 1 1/4' w o-- ~ G~3, 9 5/8' x 12 P !-- - - _ - - /~ M .. ~ /8'• 9-5/8" o ~ GO ~ ~ ~ o a--~ y M O ~'ll~~ 7r. x 8-3/4" TD ~ ~ t.a -650 ~ _ _ ~ - -- 9-5/8" x 12-1/4" - - - - --- - A GO ~,~ i I / ~ o~ GO~~O~ ~1 ~ ~ C~ 'S' ~e~y ~ - _ - -- - - I o - -------- _.._ -1300 5J i ~1h ~titi ~A G -3900 -3250 -2600 -1950 -1300 -650 0 650 1300 West(-)/East(+) (650 ft/in) ~an~o~c®Phi I I i s Casing Detail 95/8" Surtace Casing Well: CD3-114 Date: 3/20/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.40 FMC Gen V Hanger 2.21 36.40 Jts 3 to 74 72 Jts 9-5/8" 40# L-80 BTC Csg 2775.32 38.61 HOWCO Float Collar 1.43 2813.93 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 74.45 2815.36 Ray Oil Tools "Silver Bullet" Float Shoe 2.27 2889.81 2892.08 'i°~ ~'~ 1i4" ~:iar°<;1•e P°~oie 2902.08 TOTAL BOWSPRING CENTRALIZERS -43 1 per jt on Jt # 1 - # 13 (stop ring on Jt # 1 8 3 ) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67,69, 71,73. 80 joints in the pipe shed. Run 74 joints - 6 joints stay out Easing shoe @ 2892.08' MD/ 248' TVD Hole TD 2902' MD 2491' TVD Use Best-o-Life 2000 pipe dope MU torgue ~ 8600 ft/lbs Remarks l)~, ~f~~t - 170 k Dn Wt - 130h Elo:.~i~ vtlt - 75k Supervisor. D. Burley / L. Hill s ~ - Cement Detail Report ~~' CD3-114 ...• String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/17/200712:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/20/2007 11:15 3/20/2007 13:15 CD3-114 Comment Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls CW 100 w/ Dowell -Tested lines to 2500 psi - Pumped 15 Bbls CW 100 -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 347 bbls lead slurry (ASL) @ 10.7 ppg (* Observed nut plug marker @ shakers w/ 328 bbls lead pumped -pumped down surge can) Pumped 51.5 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 193 bbls 9.8 ppg water base mud -Displaced @ 7.0 bbls/min for first 185 bbls - slowed to 4 bbls/min for last 8 bbls -Bumped plug w/ 1100 psi (pre bump pressure 550 psi) Check float (held OK) CIP @ 1310 hrs. -Full circulation throughout job w/ 134 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until 70 Bbls displaced. Cement Sta es Sta e # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Cement to Surface. 36.4 2,892.0 Yes 134.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) 0 (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 550.0 1,100.0 Yes 20.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Lead Cement 10.7 PPG 437 Sxs. Tail CI G 15.8 PPG 247 Sxs. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.4 2,392.0 437 347.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.77 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,392.0 2,892.0 247 G 51.5 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 Page 1/1 Report Printed: 2/5/2010 ecurity Level: AK Development '~ ~ Daily Drilling Report > o-,.~ -- CD3-114 Report Number: 4 ..• Rig: DOYON 19 - -- Report Date: 3/20/2007 .AFEType = _ _ _: , _; - _ N~iwork/fD# - -' <' --- Tota(AFE+Sup - -- 10165152 7,755,000.00 Wellbore Well Type Field Name DFS (days) DOL. Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-114 Development FIORD NECHELIK 2.98 4.0 0.00 2,902.0 2,902.0 Daily Mud Cost ~_ _ /i, Cumulative Mud Cost :,,. /j Daily Cost Totr~ ~ _ e Cumulative Ci ~~ Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3!17/2007 3/18/2007 23.56 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,892.1ftK6 Ops and Depth @ Morning Report 24hr Forecast RIH w/ 8-3/4" Drill String RIH w/BHA - Cut/Slip DL -Wash t/ shoe - [3rill 20' -FIT -Drill 8-3/4" Last 24hr Summary RIH w/ 9-5/8" csg -land @ 2892'. Cement & test to 2500 psi. ND Riser - NU WH & BOPE -Fill stack & begin testing BOPE. General Remarks Weather Head Count -281 S @ 7m - ph / -47 we 50.0 -- - 'Supervisor __~_ - .TitlA :_.. Don Mickey, Rig Supervisor Rig Supervisor Nina Woods, Rig Supervisor Rig Supervisor Time Lo _ Start End Dur 1 Time ~ Depth Start- _ Depth End -Time Time (hrs) Phase- ~..Op Code Activity Code '~ P-T-X Trbl Code Trbf Class (ftKB) (ftK8) ;. Operation 00:00 01:45 1.75 SURFAC DRILL PULD P 65.0 0.0 Down load MWD - LD BHA -clear tools from rig floor 01:45 03:00 1.25 SURFAC CASING RURD P 0.0 0.0 Rig up to run 9 5/8" casing 03:00 03:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Prejob Safety and Ots meeting with crew 03:15 06:30 3.25 SURFAC CASING RNCS P 0.0 1,732.0 Run 9 5/8" 40# BTC csg as follows: FS(Silver bullet) 2 jts. csg - FC (Weatherford) 2 jts. csg (fill pipe & check floats -first 4 connections made up w/ BakerLoc) 41 jts. csg. for 45 total to 1,732' 06:30 07:00 0.50 SURFAC CASING CIRC P 1,732.0 1,732.0 Stage pumps up to 5.0 bpm - CBU - FCP 240 psi PUW 135K SOW 125K 07:00 08:45 1.75 SURFAC CASING RNCS P 1,732.0 2,892.0 Run 9 5/8" 40# BTC from 1,732' to 2,853'. 29 jts for a total of 74 jts. Made up landing Jt and hanger. Landed. casing @ 2,892'. 08:45 09:15 0.50 SURFAC CASING RURD P 2,892.0 2,892.0 Laid down Franks tool and rigged up cement head. 09:15 11:15 2.00 SURFAC CEMENT CIRC P 2,892.0 2,892.0 Circulated bring pumps up in stages to 7 BPM. Latest BOP Test Data Date Comment - - Page 113 Report Printed: 2/5/2010 Security LeveL• AK Development * 3 I ~`-:.. Daily Drilling Report ,~ y -- - 'c ti ~ . - m CD3-114 ~` Report Number: 4 ~~ • w:' r Rig: DOYON 19 Report Date: 3/20/2007 - Time Lo ~ - __ M__ _ Start End..- Dur ~ Lme Depth Start Depth End "Time Time- (hrs) ~ p!-,a,e Op Code Adrvity Code P T-X Trbl Code Trbl Class. (ft~) ' (ftKB)' Operation 11:15 13:15 2.00 SURFAC CEMENT DISP P 2,892.0 0.0 Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls CW 100 w/ Dowell -Tested lines to 2500 psi - Pumped 15 Bbls CW 100 -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 347 bbls lead slurry (ASL) @ 10.7 ppg (~ Observed nut plug marker @ shakers w/ 328 bbls lead pumped -pumped down surge can) Pumped 51.5 bbls tail slurry (Class G w/ additives) @ 15.8 ppg - _ Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 193 bbls 9.8 ppg water- - base mud -Displaced @ 7.0 bbls/min for first 185 bbls -slowed to 4 bbls/min for last 8 bbls -Bumped plug w/ 1100 psi (pre bump pressure 550 psi) Check float (held OK) CIP @ 1310 Firs. -Full circulation throughout job w/ 134 bbls 10.7 ppg cmt returns to surface - reciprocated pipe while circulating & through cement job until 70 Bbls displaced. 13:15 14:00 0.75 SURFAC CASING DHEQ P 0.0 0.0 RU & Tested casing to 2500 psi for 30 Min. 14:00 15:00 1.00 SURFAC CASING RURD P RD Cement & CSG Equipment, LD _ Bales, landing jt. Clear Floor. PU GeoSpan unit. 15:00 17:15 2.25 SURFAC CASING NUND P ND Riser 17:15 18:15 1.00 SURFAC CASING NUND P Install Wellhead. 18:15 20:30 2.25 SURFAC CASING NUND P NU BOPE 20:30 00:00 3.50 SURFAC WELCTL BOPE P Fill stack -Begin testing BOPE -Tested Annular t/ 250/3000 psi. Tested top rams, valves #1-16, HCR Kill, Choke, Dart, FOSV, Main IBOP, and Auto IBOP. Miad C heck Data - - ~ - _ ~ - - - YP.Calc -. .Gel (tOs) Gel (10m) Gel (30m) NTHP.FiIt -. - Density Temp. :Solids, Corr. - Type Depth (ftKB) Dens (Ib/gal) Vis (s/qt) PV Calz (crj - -(Ibf/100ft') I -'-(Ibf/100ft') (Ibfl100ft'):: (Ibf/100ft') MBT (16/661) (mL/30min) pH : (°F) (%) - Spud Mud 2,902.0 9.90 52 27.0 15.0 5.0 9.0 12.000 25.0 9.0 72.0 In'ection Flu id -Fluid - Source From Lease (bbl) Destination Vendor ManrfestNUmber Note Cementing Fluids 433.0 CD3-112 CD3-114 Diesel 100.0 CD3-112 Water 170.0 CD3-112 Water Based Mud 2054.0 CD3-112 From CD3-114 Drill Strin s: BHA Na 1 - 8" Mud'Mtr4/5 5.3st /Bit Run No. 1 - 12 1/4in Hu hes Christensen , MXL-1 ', 51Q6587 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (1000161] 114.0 2,902.0 0.75 12/16/16/18 4-5-WT-A-E-1-NO-TD 44 Drill Strin Com onents Jts Item Descnptidn OD (in) ID (in) Top Conn Sz (in) Top Thread Cum Lan (ft) = „- Motor with Stabilizer 8 4.947 6 5!8 H 90 31.81 Float Sub 8.08 2.813 6 5/8 H 90 34.39 Stabilizer 8.1 2.813 6 5/8 H 90 39.92 MWD 8 1.920 6 5/8 Reg 66.31 Page 2/3 Report Printed: 2/5/2010 ecurity Level: AK Development Daily Drilling Report - `' CD3-114 ..~ Report Number: 4 Rig: DOYON 19 Report Date: 3/20/2007 Drill Strin Com onents Jts Item Description OD (in) ID (in) Top Conn Sz (in) Top Thread Cum Len (ft) UBHO 8 3.250 6 5/8 H 90 68.90 NMDC 8 2.875 6 5/8 H 90 99.82 NMDC 7 7/8 2.813 6 5/8 H 90 130.78 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 165.35 24 HWDP 5 3.000 41/2 IF 889.83 Drillin Parameters ', Flow Rate ', Sliding (gPm) RPM PU Str Wt Drill Str Wt 50 Str Wt '. Start (ftKB) End (ftKB) Cum Depth (k) Cum Drill Time (hrs) Tlme (hrs) (gPm) WOB (Ib~ (rPm) SPP (psi) (100o1bf) (10001b~ (10001bf) Off Btm Tq Drilt Tq 2,902.0 2,902.0 2,788.00 22.31 600 30.0 50 1,960.0 138 137 133 6,500.0 7,500.0 Wel I bores ~ Wellbore Name Wellbore API/UWI CD3-114. 501032054400 '. Section Size (in) Act Top (ftKB) Act Btm (ftKB) Start Date End Date COND1 18 36.4 150.4 3/12/2007 3/13/2007 SURFAC 12 1/4 150.4 2,902.0 3/18/2007 3/19/2007 INTRM1 8 3/4 2,902.0 10,639.0 3/21/2007 3/25/2007 OPEN HOLE 6 1/8 10,639.0 18,042.0 3/31/2007 4/5/2007 ',Casin Strin s ', String OD String Wt Casing Description Run Date (in) (Ibs/k) String Grade Set Depth (ftKB) Comment (SURFACE 3/20/2007 9 5/8 40.00 L-80 2,892.1 Cement Surface Casin Cement -Started 3/20/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD3-114 SURFACE, 2,892.1ftKB 134 Bbls to surface. Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.4 2,892.0 4 550.0 Fluid Class Amount (sacks) V (bbl) Density (Ib/gal) Yield (ft /sack) Est Top (ftKB) Est Bim (ftKB) Lead Cement 437 347.0 10.70 4.45 36.4 2,392.0 Tail Cement G 247 51.5 15.80 1.17 2,392.0 2,892.0 Page 3/3 Report Printed: 2/5/2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-114 Rig: Doyon 19 Date: 3 /2 012 0 0 7 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: L. Hill / N. Woods Pump used: #z Mud Pump ~ Strokes ~ 0.1000 Bbls/Strk ~ 8.0 Strk/min ~ P i d ~ Type of Test: openhoieTest LOT/Frr ~ ump ng own annulus and DP. CBSIn Test Pressure In te ri Test Hole Size: s-3/4" • Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 36.4 Ft 2,892 Ft-MD 2,485 Ft-TVD 2,922 Ft-MD 2,503 Ft-TVD Strks si Min si Strks si Min si Casing Size and Description: 9-s/s" 40#/Ft L-80 BTC • q 0 0 2600 1 0 0 1050 Casin Test Pressure Int e ri Test 2 100 1 2600 2 40 0.25 850 Mud Weight: 9.8 ppg Mud Weight: 9.8 ppg 4 300 2 2600 3 120 0.5 800 Mud 10 min Gel: 10.0 Lb/100 Ft2 Mud 10 min Gel: 19.0 Lb/100 Ft2 6 575 3 2600 4 300 1 800 Test Pressure: 2,500 psi Rotating Weight: 135,000 Lbs 8 850 4 2600 5 400 1.5 800 Rotating Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 1050 5 2580 6 500 2 80 BlockslTop Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1200 6 2580 7 600 2.5 80 Estimates for Test: 2.1 bbls timates for Test: _1060 si 0.8 bbls E s 14 1375 7 2580 8 700 3 800 _ • _ _ • 16 1550 8 2580 9 800 3.5 800 EMW =Leak-off Pressure + Mud Weight = 850 PIT 15 Second 18 1750 9 2580 10 850 4 800 + 9 8 0.052 x TVD 0.052 x 2485 Shut-in Pressure, si 20 1950 . 10 2580 11 850 4.5 790 EMW at 2892 Ft-MD (2485 Ft-TVD) = 16.4 s5o 22 2150 15 2580 12 850 5 790 L t 20 i i d t t h ld 24 2400 20 2580 13 850 5 5 790 sooo os ps n ur g es , e . 99.2 % of t est pre ssure . 26 2600 25 2580 14 850 6 790 . .. 30 2580 15 850 6 5 790 ,, .~ ,.,,, , . zsoo 16 880 7 790 17 900 7.5 785 18 925 8 785 zooo 19 950 8 5 785 . ~ 20 975 9 785 ~ 21 1000 9.5 785 N 1500 w 22 1020 10 785 23 1040 a ~ " 24 1060 ~ o00 soo 0 1 2 3 0 5 1 0 1 5 2 0 2 5 30 - ~~CASING TEST Barrels -^-L EAK-OFF TEST S hut- O P In tim IT Poin e, M t inute s Volume PUm ed Volume Bled Back Volume PUm ed Volume Bled Back 2.6 s 2.6 Bb s 2.4 Bbls s Comments: Casing tested after bumping plugs on cement job. ~~~~~~~~I~ ~ Casing Detail 7" Casing Well: CD3-114 Date: 3/22/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.70 FMC Gen V Hanger 1.63 34.70 Jts 112 to 248 137 Jts 7" 26# L-80 BTCM Csg 5839.10 36.33 7" Weatherford Stage collar BTCM 2.35 5875.43 Jts 3 to 111 109 Jts 7" 26# L-80 BTCM Csg 4659.96 5877.78 Halliburtan Float Collar .98 10537.74 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.09 10538.72 Ray Oil Tools "Silver BulEet" Float Shoe 2.09 10624.81 10626.90 TD 8 3i4" Hole 105'J9.C10 8-3/4" Hole TD ~ 10,600' MD / 6925' TVD 7" Shoe @' MD /' TVD Total Centralizers: 51 ~.traight t~facle centralizer one ~,er,{t tin jts # 1-14 ~~traic~ht t~iade centralizer e~€baveibeia~~v stg ccll~?~ # 110; 111 vtr~:aight t,i:~civ cer~tr~tlizer or7e perjt jt;.~. #180, 181, 182 Straic ht blade centralizer ane per jt on every rather jcint franc #'s 184 .. 24i7 Top Neohelllt - 1Ck,59C~' I`~lD 6a92t1` T'A'D 258 ~csints ire shed - total 248 jts, tc~ r~ar~ Last 10 jts. cut Use Run & Seal i e do e MU torque - 7800 ft/Ibs Remarks Up Wt - 315 k fin V'v't - 1~5k Black Wt - 75k Supervisor: L. Hill / N. Woods ~~; =~~ ~:. Cement Detail Report ~ . 3 "~'.~ » CD3-114 ... String: Production Casing Cement Job: DRILLING ORIGINAL, 3/17/200712:30 ___ -- - Gement Details _ Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 3/27/2007 00:00 3/27/2007 00:00 CD3-114 Comment Cemented 7" csg as follows: Pumped 10 bbls CW100 -Tested lines to 4000 psi -Pumped 40 bbls CW100 @4 bpm, 400 psi -Mixed & Pumped 40 bbls Mudpush @ 3 bpm, 300 psi -Mix & Pump 51 bbls of 15.8 ppg Tail Slurry (255 sacks) @ 5 bpm, 450 psi. Drop Shut off plug with 20 bbls Water f/ Dowell. Switched to rig pumps & displaced cmt w/ 9.8 ppg mud @ .7 bpm for 375 bbls, 380 - 700 psi. Dropped rate to 3 bpm for 7 bbls -Bumped plug with 850psi (500 psi over 350 pump pressure). 382 bbls total displacement. Checked floats - OK. Cement 2nd stage 7" at Qannik as follows: Pumped 10 bbls CW100 @ 4 bpm, 150p psi. Mixed & pumped 20 bbls mud push 10.5 ppg @ 4 bpm, 150 psi. Mix & pump 38 bbls of 15.8 ppg Class Gcement - 184 sacks - @ 4.5 bpm, 45 psi. Drop closing plug with 10 bbls of water f/ Dowell -Switch to rig pumps & displace w/ 9.8 ppg mud @ 7 bpm pumping 190 - 400 psi. Bump plug @ 213 bbls, pressure increased to 1200# to shear top pins -bumped to 2500# and held. Opened surface valve to confirm sleeve closed. Continued to pressure up, broke over @ 2900psi to 2200 psi and held. Suspect composite plug btm broke. _ _ - - - Cement Sta es z .; - - _ - Sta e # 1 _ - ~~ ~. _ _ Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... lop Plug? Btm Plug'? Production Casing Primary 9,340.0 10,629.0 No Yes No Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? S ke (ft) Rotated? Pipe RPM (rpm) No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out K Drill Out Diameter (in) Comment -- - - - - -- Cement Fluids 8~ Additives - - - - - Fluid _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW-100 50.0 Yield (ft'/sack) Mix H2O Ratio (gaUsa... Free Water (°k) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label Fluid = ,: ,_, - -- - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 40.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi} 10.50 Additives Additive Type Concentration Conc Unit label -Fluid - - - _ - _- - - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl} Tail 9,340.0 10,629.0 255 G 51.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 15.80 Additives Additive Type Concentration Conc Unit label - -- --- _~ - - ;, --- .Fluid . _ :_, - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Water 20.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (ps1) 8.30 Additives Additive Type Concentretion Conc Unit label -- Fluid - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud 382.0 Yield (ft%sack) Mix H2O Ratio (gallsa... Free Water (°k) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 9.80 Page 1/2 Report Printed: 2/5/2010 +~~ -~~ :. Cement Detail Report ,~ ~ , ~~ ~ ~, . ~ ~ ~.. CD3-114. ;~,.. String: Production Casing Cement Job: DRILLING ORIGINAL, 3117/200712:30 Additives Additive Type _. Concentration _ Conc Unit label -- -- Cement Sta es Std ' e # 2 - _ -- -- ,; Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrrrn (... Top Plug? Btm Plug? Production Casing 4,675.0 5,875.0 No Yes No Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (finale(psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped through stage collar @ 5875' ,;~ Cement Fluids & Additives' - "' , ,_ _- ~ __ - - - -- Fluid -- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW-100 10.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label .:Fluid - - - - - -, ;_ -_ - -- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 20.0 Yield (fN/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid - -- - - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail 4,675.0 5,875.0 184 G 38.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 15.80 Additives Additive Type Concentration Conc Unit label Fluid ----- - - _ - Fluid Type Fluid Description Estimated lop (ftKB) Est Btm (ftKB) Amount (sacks). Class Volume Pumped (bbl) Water 10.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (°~) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label Fluid ___ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) ~ Class Volume Pumped (bbl) Mud 214.0 Yield (fPlsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 9.80 Additives Additive Type Concentration Conc Unit label Page 212 Report Printed: 2/5/2010 - - Security Level: AK Development a`a'7 - Daily Drilling Report ~~' - CD3-114 °°_ ' . . - Report Number: 10 Rig: DOYON 19 Report Date:- 3/26/2007 AFEType „_ -- --- - NetworkllD# - TotaLAFE+Sup... -_ _ - -- ---- 10165152 7,755,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-114 Development FIORD NECHELIK 8.98 10.0 0.00 10,639.0 10,639.0 Daily Mud Cost _ ^ ~/ I Cumulative Mud ~^~* ,~~l~l Daily Cost Tots' Cumulative Cc-• ~ _ ~l Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/17/2007 3/18/2007 23.56 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) , INTERMEDIATE, 10,627.OftKB Ops and Depth @ Morning Report 24hr Forecast CO to VBR Rams & Test MU BHA -RIH for Clean out to shoe track - CBU -POOH Last 24hr Summary LD BHA - CO top rams to 7" & Test -RIH w/ 7" Csg & land shoe @ 10,626' MD -Establish Circ -PJSM and begin stage 1 cement job. General Remarks Weather Head Count -18, SW @ 29 mph 50.0 _. ~. -~- Supervisor -'= ::- ..Title _ Don Mickey, Rig Supervisor Rig Supervisor Nina Woods, Rig Supervisor Rig Supervisor Time Lo Start End Dur - -- ~ Tlme - Depth Start Depth End Time '-Time (hrs) Phase- Op Coca !Activity Gode P T X - Trbl Code Trbl Class `. c (ftKB) (ftKB).-: ''Operation 00:00 01:00 1.00 INTRMI DRILL PULD P _ 50.0 0.0 Finished download MWD and lay down. Break Bit. Flow check static. Clear rig floor. 01:00 03:00 2.00 INTRMI WELCTL ROPE P 0.0 0.0 Pulled wear bushing. Changed rams to 7" and tested to 250 / 5000 psi. 03:00 05:15 2.25 INTRMI CASING RURD P 0.0 0.0 Installed thin wear bushing and rigged up to run casing. 05:15 05:30 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM for running casing. 05:30 10:30 5.00 INTRMI CASING RNCS P 0.0 4,275.0 Make up and RIH with 7" 26# L-80 BTCM Csg as follows: Ray Oil Tools Silver Bullett FS - 2 jts - Halliburton FC - 98 jts to 4,275'. Baker Loc 1st 4 jts. Baffle Plate installed in the top of Jt #3. 10:30 11:15 0.75 INTRMI CASING CIRC P 4,275.0 4,275.0 Broke circulation with 2 BPM and worked up to 5 BPM. FCP 440 psi. 11:15 16:00 4.75 INTRMI CASING RNCS P 4,275.0 8,554.0 Continue RIH with 7" 26# L-80 BTCM Csg to 8,554' as follows: 11 jts - Weatherford Stage Collar BTCM - 89 jts. 16:00 17:00 1.00 INTRMI CASING CIRC P 8,554.0 8,554.0 Establish Circulation @ 1.5 bpm @ 430 psi. Stage up to 7 bpm. FCP 630 psi. 17:00 19:30 2.50 INTRMI CASING RNCS P 8,554.0 10,627.0 Cont RIH with 7" 26# L-80 BTCM Csg to 10,627' MD. Landed Shoe @ 10,627' MD, Stage Collar @ 5875' MD. Total of 248 jts run, 51 centralizers. 19:30 20:00 0.50 INTRMI CASING RURD P 10,627.0 10,627.0 Lay Dwn Franks Tool, Blow Down TD, MU Cement Head. 20:00 23:00 3.00 INTRM1 CASING CIRC P 10,627.0 10,627.0 Establish Circulation 1.5 bpm @ 430 psi, Stage up to 7 bpm. FCP 630 psi. 23:00 00:00 1.00 INTRM1 CEMENT CIRC P 10,627.0 10,627.0 PJSM -Begin cementing 1st stage. Mud Check Data - ' - - = YP Calc Gel (10s) ' Get (10m).., Gel (30m) -_. H I NN Filt - ` Density Temp Solids, Corr.. Type -- - Depth (ftKB) - Dens (IWgal) Vis (slgt) PV Calc (cp) Qbfll.OOft') - -(Ibf/100ft~)... (Ibf/t00ft')'.' :'(Ibf/100ft') - MBT (Ib/bbl) '(mV30min) pH- -.. (°F) (%) a LSND 10,639.0 9.80 37 92.0 -64.0 5.0 6.0 10.000 14.0 7.0 9.2 .75.0 In"ection Fluid Fluid Source - From Lease (bbq Destination: Vendor Manifest NNumber Note Diesel 5.0 CD3-111 Water Based Mud 164.0 CD3-111 f/ CD3-114 Latest BOP Test Data Date _- - -- '- Comment 3/21 /2007 250/3500/5000 si 4" & 5" Page 1/2 Report Printed: 2/5/2010 Zig: DOYON 19 Stein s: BHA No. 2 - Geo Pilot 7600-048 f' th In (ftKB). Depth Out (ftKB) TFA 2,902.0 10,639.0 1 Stein Com onents Jts Item-:Descript 1 7600 Geo Pilot 1 Non-Mag GP DM Flex 1 Stabilizer (Non Mag) ILS 1 MWD (Logging) 1 Stabilizer (Non Mag) 1 MWD (Logging) H-Cim 1 MWD (Die & Logging) T-M 1 Float Sub NM 3 NMDC 3 HWDP 1 Drilling Jars -Mechanical 14 HWDP 1 Drill Pipe 1 Ghost Reamers 33 Drill Pipe 1 Ghost Reamer 26 Drill Pipe 1 XO Sub Stein s: BHA No. 3 - 6-1 /8" Rota Ass J th In (ftKB) Depth Out (ftKB) TFA 10,639.0 10,639.0 Daily Drilling Report CD3-114 - %8 0.98 ~ 16/16/16/16/16 OD (in); 6 3/4 6 3/4 6.71 6 3/4 6.78 6.77 6.6 6.64 5 6 1/4 5 5 6.54 5 6.54 5 5 1 /4 - 61 0.70 ~ 13/12/12/12/12/13 rity Level: AK Development Report Number: 10 Report Date: 3/26/2007 2463>;10807513:- _ 3tt Dull String Wt (10001bfl 8-3-LT-N-X-O-BT-TD 84 n) ! Top Conn Sr(n) .r Top Thread c Cum Len (ft)" 1.500 4 1/2 NC 50 21.60 1.920 4 1/2 NC 50 30.80 1.920 4 1/2 NC 50 32.73 1.920 4 1!2 NC 50 53.69 1.920 4 1/2 NC 50 55.88 1.920 4 1/2 NC 50 62.87 1.920 4 1/2 NC 50 72.71 2.813 4 1/2 NC 50 75.11 2.813 4 1/2 NC 50 167.85 3.000 4 1/2 NC 50 258.48 2.250 4 1/2 NC 50 291.29 3.000 4 1/2 NC 50 714.82 4.276 4 1/2 NC 50 746.53 2.875 4 1/2 NC 50 752.59 4.276 4 1/2 NC 50 1,798.85 2.875 4 1/2 NC 50 1,805.80 4.276 4 1/2 NC 50 2,630.89 2.563 4 XT-39 _ - 2,633.39 JT0332 _ IADC Bit Dull String Wt (10001bf) 2-1-CT-CG-X-O-BT-BHA 9 1 Bit Sub 5 2.000 3 1/2 NC 38 2.58 1 Stabilizer (Non Mag) 4.79 2.250 3 1/2 NC 38 7.53 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 38.66 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 69.83 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 101.01 1 XO Sub 5 2.000 4 XT-39 103.98 3 HWDP 4 2.563 4 XT-39 196.01 1 Drilling Jars -Mechanical 4 3/4 2.000 4 XT-39 228.28 2 HWDP 4 2.563 4 XT-39 289.63 Drillin Parameters ' FIowRate - - - Sliding (gPm) RPM-. PU Str Wt '.Drill Str Wt SO Str Wt S_ tart (ftKB) End (ftK6) Cum Depth (ft) - ' Cum DrillTme(h rs) Time(h~s) (gPm) WOB (Ibt1 (~Pm) SPP (psi) --.;(10001bt7 -j100016f) '. ' (10001bf) -0rt Btm Tq - Drill Tq 10,639.0 10,639.0 - - - 625 20.0 125 3,490.0 218 187 155 10,000.0 12,000 D Wellbores _- _ - Wellbore Name Wellbore API/UWI CD3-114 501032054400 Section S¢e (ih) '__-- Ad7op (ftKB)' Act Btm{ftKB) Start Date `° End Date ' COND1 18 36.4 150.4 3/12/2007 3/13!2007 SURFAC 12 1/4 150.4 2,902.0 3/18/2007 3/19/2007 INTRM1 8 3/4 2,902.0 10,639.0 3/21/2007 3!25/2007 OPEN HOLE 6 1/8 10,639.0 18,042.0 3/31/2007 4/5/2007 Casing_Strin s --- String OD String Wt ii --, Casing Qescuption Run Date (in) (Ibs/ft) : SVing Grade ' ~ Set D epth (tiK6) " ~-orr~ me'it _ INTERMEDIATE _ 3/26/2007 7 26.00 L-80 10,627.0 page 2/2 Report Printed: 2/5/20101 ecurity Level: AK Development ' ~~ -~- Daily Drilling Report ~.,,~~ CD3-114 _ Report Number: 11 . . , Rig: DOYON 19 Report Date: 3/27/2007 - AFE T~~: e --- Network/ID #... __ t- Total AFE+Sup =_ 10165152 7,755,000.00 Wellbore Well Type Field Name. DFS (days) DOL Depth Progress (ft) Depth Start (ftK6) Depth End (ftK6) CD3-114 Development FIORD NECHELIK 9.98 11.0 0.00 10,639.0 10,639.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,338.96 316,038.06 200,985.96 3,342,875.05 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/17/2007 3/18/2007 23.56 Last Casing String Next Casing OD (in) Next Casing Set Depth (ttK6) INTERMEDIATE, 10,627.OftKB Ops and Depth ~ Morning Report 24hr Forecast POOH on TT LD BHA - RIH w/PKR to test 7" Csg Last 24hr Summary Pertormed 2 stage cement job on 7" csg - CO to VBR rams & test 4-1/2" jt -Test PO to 5000 psi - MU BHA &RIH -Drill Out cmt @ Stg clr -RIH -Cut & Slip DL General Remarks Weather Head Count -18, SW @ 12 mph 48.0 Supervisor .,_- _, Title Don Mickey, Rig Supervisor Rig Supervisor Nina Woods, Rig Supervisor Rig Supervisor Time Lo "` - _ -Start -- End Dur Time Depth;Start Depth End _ _- .Time Time.;. (hrs) Phase -- -, Op Code Activity Code ~' P T-X Trbl Code TrblClass (ftKB) (ftKB)'.- nperatiorn 00:00 01:00 1.00 INTRMI CEMENT DISP P 10,627.0 10,627.0 Cemented 7" csg as follows: Pumped 10 bbls CW100 -Tested lines to 4000 psi - Pumped 40 bbls CW100 @4 bpm, 400 psi -Mixed & Pumped 40 bbls Mudpush @ 3 bpm, 300- psi -Mix & Pump 51 bbls of 15.8 ppg Tail Slurry (255 sacks) @ 5 bpm, 450 psi. Drop Shut off plug with 20 bbls Water f/ Dowell. Switched to rig pumps & displaced cmt w/ 9.8 ppg mud @ 7 bpm for 375 bbls, 380 - 700 psi. Dropped rate to 3 bpm for 7 bbls - Bumped plug with 850psi (500 psi over 350 pump pressure). 382 bbls total displacement. Checked floats - OK. 01:00 01:30 0.50 INTRM1 CEMENT CIRC P 10,627.0 10,627.0 Pressure up on 7" Csg to 2900 psi to shift stage collar open - ICP 4.5 bpm - Establish circ @ 7 bpm, 300 psi. Circ BU. 01:30 02:30 1.00 INTRMI CEMENT DISP P 10,627.0 10,627.0 Cement 2nd stage 7" at Qannik as follows: Pumped 10 bbls CW100 @ 4 bpm, 150p psi. Mixed & pumped 20 bbls mud push 10.5 ppg @ 4 bpm, 150 psi. Mix & pump 38 bbls of 15.8 ppg Class G cement - 184 sacks - @ 4.5 bpm, 45 psi. Drop closing plug with 10 bbls of water f/ Dowell -Switch to rig pumps 8~ displace w/ 9.8 ppg mud @ 7 bpm pumping 190 - 400 psi. Bump plug @ 213 bbls, pressure increased to 1200# to shear top pins -bumped to 2500# and held. Opened surface valve to confirm sleeve closed. Continued to pressure up, broke over @ 2900psi to 2200 psi and held. Suspect composite plug btm broke. 02:30 04:15 1.75 INTRM1 CEMENT RURD P 0.0 0.0 Blow dwn & RD cmt equip - LD tools - Pull Landing jt. 04:15 04:30 0.25 INTRMI CEMENT OTHR P 0.0 0.0 Pull wear ring -Drain Stack Latest BOP Test Data Date - _ Comment - _ - 3/21 /2007 250/3500/5000 si 4" & 5" Page 1/3 Report Printed: 2/5/2010 Security Level: AK Development "~~~ ~` Daily Drilling Report ~. - CD3-114 Report Number: 11 . . - . Rig: DOYON 19 Report Date: 3/27/2007 Time Lo " Start End - Dur.. - Time. Depth Start Depth-End `Time Tme (hrs) Phase _9p Code __-_ ~ Activity Code P-T X Trbl Gode Trbl Class (ftK6) ; (ftKBj OperaUOn 04:30 05:30 1.00 INTRM1 DRILL OTHR P 0.0 0.0 RIH w/ 7" packoff -Run in LDS's to 450 ftlbs -tested void t/ 5000 psi for 15 min - Good test -Bleed off pressure 05:30 07:15 1.75 INTRM1 WELCTL BOPE P 0.0 0.0 CO 7" Rams to 3-1/2" x 6" Variable -test 250/5000 psi with 4-1 /2" test jt. 07:15 07:45 0.50 INTRM1 CEMENT OTHR P 0.0 0.0 Set Wear Ring - PU 4" Bales & DP Elevators. 07:45 08:45 1.00 INTRM1 CEMENT PULD P 0.0 0.0 MU BHA for Clean out run. 08:45 12:00 3.25 INTRM1 CEMENT TRIP P 0.0 2,673.0 RIH PU DP singles to 2673' 12:00 14:30 2.50 INTRM1 CEMENT TRIP P 2,673.0 5,805.0 Cont PU 4" DP from shed f/ 2673' - 5805'. Tag cement @ 5805'. 14:30 16:30 2.00 INTRM1 CEMENT DRLG P 5,805.0 6,034.0 Wash dwn f/ 5805' t/ 5876' -Tag stg collar -drill collar & cmt t/ 5960' - PU 2 jts V6034'. 16:30 17:00 0.50 INTRM1 CEMENT CIRC P 6,034.0 6,034.0 Circ BU @ 307 GPM, 1100 psi. 17:00 21:00 4.00 INTRM1 CEMENT CIRC P 6,034.0 10,298.0 Cont RIH w/ 4" DP from shed f/ 6034' t/ 10,298' 21:00 23:00 2.00 INTRMI RIGMNT OTHR P 10,298.0 10,298.0 Cut & Slip 120' line -Service TD & Rig 23:00 00:00 1.00 INTRM1 CEMENT TRIP P 10,298.0 10,460.0 Wash dwn f/ 10,298' t/ 10,460' @ 300 gpm, 100 rpm, 1740 psi. Mud Check Data _ - - I ~ YP Calc Gel (1 Os) Gel (10m)>. _.. Gel (30m) - HTHP Filt Density Temp Solids; Corr. -- Type Depth (ftK6) Dens (Ib/gal) -Vis (slgt) PV Calc (cp) (Ibf/100ft') (Ibf/100ft=) (Ibf/100ft') f; "(Ibf/100fN) MBT (Ib/bbl). ' (mLl30min)' pH - ' ('F) (%) LSND 10,629.0 9.80 37 7.0 14.0 14.0 7.0 9.2 78.0 In'ection Fluid ' Fluid Source From Lease (bbl) Destination Vendor Manifest Number Note Diesel 40.0 CD3-111 FP Water 150.0 CD3-111 Flush Water Based Mud 2609.0 CD3-111 f/ CD3-114 Drill Stria s: BHA No. 3 - 6-1/S" Rota Ass /Bit Run No. 3 - 6 1(8in, GeoDiamond M285YPX, JT0332 = Depth In (ftK6) Depth Out (ftK6) TFA (incl Noz) (ins) Nozzles (/32") IADC Bit Duil String Wt (70001b1) 10,639.0 10,639.0 0.70 13/12/12/12/12/13 2-1-CT-CG-X-O-BT-BHA 9 Drill Stria Com onents Jts Item=Description - OD jin) lD ,in,.,,_ T?p.l~onn Sznj ='--Top Thread Cum Len (ft) 1 Bit Sub 5 2.000 3 1/2 NC 38 2.58 1 Stabilizer (Non Mag) 4.79 2.250 3 1/2 NC 38 7.53 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 38.66 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 69.83 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 101.01 1 XO Sub 5 2.000 4 XT-39 103.98 3 HWDP 4 2.563 4 XT-39 196.01 1 Drilling Jars -Mechanical 4 314- 2.000 4 XT-39 228.28 2 HWDP 4 2.563 4 XT-39 289.631 D ritlin Parameters -_ - _ - , Flow Rate . _ ~ Sliding-. " (gPm) RPM - _ PUStr Wt ` Drill Str Wt -..SO SV Wt Start (ftK6)`- End (ftK6)' -Cum D~F fh 'J?"~ Cum Dnll Tme (hrs)' Time (hrs) ' (gPm) WOB(Ibf) (rpm) SPP.(psi) (10001bf) (10001bf) '. . (10001bf) Off Btm-Tq Drill Tq " 1.0,639.0 10,639.0 625 20.0 125 3,490.0 218 187 155 10,000.0 12,000.0 Wellbores Wellbore Name ~ Wellbore API/UWI CD3-114 501032054400 .Section Size'(in) Act Top (ftK8) Act Btm(ftKB) Start Date End.Date COND1 18 36.4 150.4 3/12/2007 3/13/2007 SURFAC 12 1!4 150.4 2,902.0 3/18/2007 3/19/2007 INTRM1 8 3/4 2,902.0 10,639.0 3/21/2007 3/25/2007 OPEN HOLE 6 1/8 10,639.0 18,042.0 3/31/2007 4/5/2007 Page 2/3 Report Printed: 2/5/2010 ,~, ~, ecurity Level: AK Development ~~ .. Dai ly Drilling Re port CD3-114 Report Number: 11 Rig: DOYON 19 Report Date: 3/27/2007 ;Cement Production Casin Cement -Started 3/27/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD3-114 INTERMEDIATE, 10,627.OftK6 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Production Casing Cement 9,340.0 10,629.0 Fluid Class Amount (sacks) V (bbl) Density Q b/galJ Yield (ft°lsack) Est Top (ftKB) Est Btm (ftKB) CW-100 50.0 8.30 Mud Push 40.0 10.50 Tail G 255 51.0 15.80 1.16 9,340.0 10,629.0 Water 20.0 8.30 Mud 382.0 9.80 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 2 Production Casing Cement 4,675.0 5,875.0 FIuId Class Amount (sacks) V (bbf) Density (I b/gal) Yield (ft'lsack) Est Top (ftKB) Est 6tm (ftKB) CW-100 10.0 8.30 Mud Push 20.0 10.50 Tail G 184 38.0 15.80 1.17 4,675.0 5,875.0 Water 10.0 8.30 Mud 214.0 9.80 Page 3/3 Report Printed: 2/5/2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: ~C33-114 Rig: Doyor~ 19 Date: 3f27f2007 Volume In ut Pum Rate: Drilling Supervisor: AtJ4i~key Pump used: Cement Unit ~ Barrels ~ 1 Bbls/Strk ~ ~•$0' Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure In te ri Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 34.2 Ft 2~i90.0 Ft-MD 24135.5 Ft-TVD 10539.0 Ft-MD 656~3.Q Ft-TVD Bbls si Min si Bbls si Min si Casina Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 96 0.00 527 Chan es for Annular Ade uac Test Pressure Int e ri Tes t 1 O.a 172 0.25 464 Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 2fi6 0.50 455 Casing description references outer casing string. Inner casing OD: 7.f5 In. 3 1.5 340 1.00 442 Hole Size is that drilled below outer casing. 4 2 418 1.50 437 Use estimated TOC for Hole Depth. 5 2.5 4805 2.00 42 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 526 2.50 4 Estimates for Test: 672 si 0.7 bbls 7 3.5 556 3.00 41 ~ ~ 8 4 575 3.50 411 EMW =Leak-off Pressure + Mud Weight = 575 PIT 15 Second 9 4.5 549 4.00 404 + 9 8 0.052 x TVD 0.052 x 2485 Shut-in Pressure si 10 5 532 4.50 402 EMW at 2890 Ft-MD 2485 Ft-TVD = 14.2 464 15 ~.~ 536 5.00 397 20 6 542 5 50 394 ~oo0 . 25 6.5 539 6.00 391 30 7 527 6.50 385 7.00 385 7.50 377 8 00 377 . w 8.50 375 ~ 9.00 371 rn 2 '' S P 9.50 37t5 500 w ~ p ~: 10.00 370 a 0 , e z o z e ao o , z Ba a rrels e --~ s ~ s o e S hut- O P ,o In tim i IT P e, M t inute s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back ~~C ASING TE ST ~LEA K-OFF TES T o n 0.0 Bbls Bbls 7.0 Bbls Bbls Comments: 9 St8" casing si~oe I~IT mm 16.4 pl7c~ Summary h ~ ~. ~ t • T'o,;~ and Sh~nnbn, You. haue reC{t~@Qted to dispo:;e of "rietV-produc,L" clean.. t:p ~ltiids from the r~L't 1 n ~ mi~ci,ic3 cf mud arid cerrea~` rat A1.pa.rc~ as *e~cll a~ the le~;1 trp flacis resulta~r~ct from clcaninq but the ta:i'.~cs: at the. muc3 alarit. in F3reY~aration for u.~ng .ail base ~4ud. The Co,.inssio~ you previ:ous:.v ~~.~pravc~d di.znbsirtg of the "rlew pr_cscuct" c:1~un ,a~ Cltzds vi,a arntilar dispersal at ['D 1 pad.. Due to the r~eolr3c~ica. recline: at P.Lpne, ~:I.ass l and Class 2 disposal options are: lix~:ited. t'h. ~,:L.ps' prc~dccc~sor„ ~~C'C?, had esLablisl'ied the Li.mt~:tati.carr bf di. ,posal bptionr; t.o L•Yie Cor~,tnissc~n's s~~t3:sracta,c~tx ax:cl.arir_ular dispr~sal vrds dpT~rc~vecd as the ;~a-<3ctical and canui ronm~-ita1 alterriat_v~. +Ir_these reques L's the vraste f]_uids are no d.~fc,ret:t traz pre~uiau5ly dfa~ira~reel QrYd ~~re`hb r cstalt o` the ongoing clevelopmen: a~:t'iV.iL} ps <~t ~lpinc _ The Gornat~s~ioners hacre author. ~ 7ei1 ms Lo fiu~ Yo's th=. message . By oopY of ~h~S email, Phillips is aiiL'Yzoaized G[, dispose of c:l.ean up fluids as c~escrik~ed its Your e~-~ 1 _ Pleaae cp11 wii~Yt ~•~xiy ~xu~st,.crs _ `Cnm ~lat~ncyczr , P~ Sr. Petrerlecun Eni~xneer ?~CGCC }L.P Enr Goo rd wrote; ~ Fss noted. _t the dCt.aC:hied email, 'i'nm 1Marison px~va,n~lsly requested at~L7or,zatc~:t to cli pase• of new-Product cleat up fluids such.. as cement rirssate, aad rr~ucz arld ox`ii.e pit xi:~s~~ fz'~]iu mixittc~ b~eratior_s uia annular :~ insec~Lion ix: Y~erm.ttPa ~,reJ.l,~ 4~t the ~L~inc CD2 L'ri11 rite. ~~~ rioted Tae low. r i~~C,CG apprs~ved such disposal at the L'D1 Drill Silo '.t7 1~9~, Y~ase~ tin the y integral reiaL°ionship of K:t7e mud rz.xi:ng Loci„l,ity and the on-EZ,ite drillinr~ U}7g~at7.Ot'7l_ Phillips ~aoulcl like t4 cc~t~t,:ntz,~,ng putist;anc3 ±~~ts ruses:. Significat'it dear:. > rtut of tanks at tl>~ mud mixing facility msst occur in pr+eparati:on for the ~ tc€npcsrary use of oil basted mud presatacc~ ~tL' r~lpxne ~.» the cc~mnq months. > ^stle availability of annular c~ispos~a.1. as an opf.i.on for tank rinser fluiCfs and t s~irilar v,::istes wau:ld greatly faca.litatb this prac~ss. {Tyi~ic~:lly, routine > rizises arc beneficially reused, hewe~ae~•, there is ~ concexn mbout thc~ ~ potential cuanlty of fluid Ck~aL' cou7.d kze gener<ated du±-ing thi.^, large ~~ale t clean u~ process.} a 'Finks a the cord ~ixiYiy faulty rtaay Cor2Lair1 eit-he:c ne*a and used mud. products. ihougil ri~lses in co;lact with used p:~caducts may 1•~e in]ected ,z > the parrniL~_ed class ~:''!; dis:~osA]. well,. iCrJ19~+.) , rirsses .of never gradL.c:ts. wc~tt'ld pc,4entally b~ routed to thr->• class I clis;aosal ~a~ll i~-021 , where there is 7 a c3iff`aculty nanaring solids .content. The cla::s I we11 is a critical l,fela.ne for facility. ir~frastr•ur,ture, Y~aing L'k3e dist~os~1. a,ocati.Qrt foY all. ~ dam~stic e~fflv.ent, Grid `~ is a prior~.l.y ttr pr°v'enC ax~~ cgmp~•amise to this 3 disposal facility. Annular disposer], p~eset~rs a }arbferred waste maaiagexttent • ~ alterr~ati've it this case. .. • ~ Tk~an~ }rou ve_`y much for your corx:;ideratiori of this ~.QC,~1~st- ilea.^,~ da not ` > i~ X70-4200 hesitate t,o canCaer sne b' ttty alce~nate -ra etl ar tahone at t30 ~ if ytsu have c~xesta.ors or npeci ac1d~.C:ona1 information. Shanr_on Donnelly ~ ~=dine ^ie_ti Envirorlm~ntal f:oor~.t'xdCQi' y { X07 y 670-427f) :, Hpr*.vaxrl~d ksy A1~P env Ca~arczfPPC:C~ ax 111G2/O1 "-2:50 1'>~7 ~-~:"-- 's ~ TILP En°~~ Coord ~:f3/a1!t}a 12t4~~ LAN . YrtEvander~ admit _ stag _ ac. uu ^r La.~ ~ ~ : i~, ~. { ~7C C Svib~ect: FtecrueSL' Cc3 .lt~~e~:Y C:cmart ^a.nsa~.e at CD2 > Dear 24?-. I+3aurlde~ . > Ir~~~CC5.or1 of. cem~*t~t„ ri~s~te ~.nd glean-up fluids from mud and brine xttixizxc•, op~raf_inns a.t the e~lpine mud plant. facilitlr r.L'o txr~pxc~v~cl annulaY e3is}~osal T operations ~v;as gr.~~z~C.ed by L'tle rslc•~,s'K~ U.J. find Gas ranse_~vatir~n Cgxniit~ssiorl {~}fJGCC} in the Marc]Z 1'7, 1cJ~9 litter prom r~OGC~ Lo Doug {'~ieeter of PR.~Q a F~laslc~t, snd., rc~,a Ptxilli~s Islaska", Ir~.c. {l~,~I} _ ~T`he approval was a=arxted tta ~ Pr'sl sper..{,~~,ra11y fir ~:~.pa.~1~ 1f7ri,_7, Site CDl and autlxc~rizer vo1'um~s up Go ~ 3~, 00[t barx•t;la tix'ou3tx :axe aznal~r svaae. ~ ~~= request that thi:~ apgrcaual be exterxcied i:o dr_i`I,~.a.n~ p;;yf•'-"ations a-_ 1?7.pinc. • ~ Dr~.ll mite ~'DZ. Gernert s7ti~tt:~g: operaCi:ors °~r sett.=ng sur*ace conductors il_L`y w~xic~i i~ ourrenGly t fac d I j i d ~ , ec r_ an n wil.:l. be T..akirxg place at tlxc Gr ~ aLtacrea to CYie drrllirig Tir:7 ak (:p2. I)pUn c~Arfra~,~r.i.cir> nt the cementing in of ttie %o~icluctor.s, hhe l:~es anti mwxi.nct tank will have to be x°izisec~ an:l c:he > x,i.nsare diuposed vi. =AI request apprt~l~a_ t.o itaject tlaa.s r-i,r+.s~tr?, ~ncl other s':lentl~t~p fYo=°; Che. m~aca ux:d l7ra,t~~ m~eing ope_x^ation~, izito tre arxnu~l 3 sp~cc of approve l Svell~ 1 acated tt Dr..ll ~il'~L'r~2, :~ zL` You. l~a~.=~ any c~uegtians ~7lcasc aantGct me ~t G'70-200. ~ To~~~ Nansor, ~ Al}~ixe field Environmental Coripliance torn~naunder.vct • o. Regarding 4 year state witnesse~ITIA's on CD3 pad • Regg, James B (DOA) _ ~ 1'~~~~(_ . 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 ~jle . t.--- ~~ 2.Cs % -u4( _ - ~~ ~ 3~3 2cj~ -- c 2 ~ , 2e%~ ~ ~ t ~, ~;~-~v+l Zpfv' -~ t`t'~ .~ 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 ~' i~~ $. t~:~ war.' '' ~.- ` .~ ,~, t- J L' 333 W.7th Avenue, Suite 100 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. I CD3-110 (PTD 205-041) last tested on 01/12/07 - Ao~ce `"`~~~ ~ l I Z) zki~7 CD3-112 (PTD 206-032) last tested on 04/28/07 ~- !~O~L". cv~~-N~~j ¢~'~~o' ~D3-114 (PTD 207-033) last tested on 04/02/08 - ACC w~-~ess ~(ZJ Z~ CD3-118 (PTD 208-025) last tested on 03/07/09 - ~°~~c w`}'`~ss 3~~~zc7uR CD3-302 (PTD 206-010) last tested on 07/19/07 _ ~G~ce_ W~~-s -n~t~ Z:GJ'J 6I i~~ ~~ CD3-316A (PTD 208-011) last tested on 05/16/08 _. ~6[~~ ~,-h,e~s 5~1 2c%o~ ~ CD3-305 (PTD 208-193) tentatively scheduled to have initial witnessed test on 6/13/09. Please let me know if you have any questions and if this is acceptable. Brent Rogers/Martin Walters 6/10/2009 C~3-IlU -See ~~ei~~ 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 T111Q PIQt -CD3-110 250D 2000 a 1500 1000 500 0 ,, / t J ~ 'yt\,~/ v .~~t of 01-Apr-09 01-May-09 Date 01-Jun-09 200 150 ~. 1as Y O L 50 0 • ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070330 Well Name/No. COLVILLE RIV FIORD CD3-114 Operator CONOCOPHILLIPS ALASKA INC MD 18042 TVD 6884 REQUIRED INFORMATION Completion Date 4/7/2007 Completion Status 1-OIL Current Status WAGIN Mud Log Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name - ---- D C Las 15060~iVlud Log ' pt 15060 Report: Final Well R Samples IVo Log Log Run Scale Media No l og 15060 Mud Log 2 Col / 'Log 15060 Mud Log 2 Col :L~o 15060 Lithology 2 Col .Co~ 15060 Lithology 2 Col 'Log 15060 Mud Log 2 Col ~iog 15060 Mud Log 2 Col ~ D Asc Directional Survey / CED C Lis 15189~nduction/Resistivity Rpt 15189 LIS Verification ~'y Cement Evaluation Col QED C f 791 f~nduction/Resistivity API No. 50-103-20544-00-00 UI ~- Directional Survey Y~~. (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 1 10700 Open 4/20/2007 Mud Data, ROP, PPRS, Oil, Meth Open 4/20/2007 Final Well Report, Table of Contents, Equipment and Crew, Well Details, Drilling Data, Daily Reports, Formation Logs, Drillling Logs 114 10639 Open 4/20/2007 MD Formation Log 114 10639 Open 4/20/2007 TVD Formation Log 114 10639 Open 4/20/2007 LD LWD Lithology 114 10639 Open 4/20/2007 TVD LWD Lithology 114 10639 Open 4/20/2007 MD Drilling Dynamics 114 10639 Open 4/20/2007 TVD Drilling Dynamics 50 18042 Open 5/21/2007 2868 18042 Open 6/12!2007 LIS Veri, GR, ROP w/Graphics 2868 18042 Open 6/1212007 LIS Veri, GR, ROP 9670 10168 Case 3/25/2008 SCMT, Pres, Temp, GR, CCL 7-Mar-2008 0 0 4/23/2009 EWR, CGM and PDS graphics for EWR logs. r, L_J DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070330 Well Name/No. COLVILLE RIV FIORD CD3-114 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20544-00-00 MD 18042 TVD 6884 Completion Date 4/7/2007 og Induction/Resistivity --g Induction/Resistivity __ _ _ _ __ Well Cores/Samples Information: Interval Name Start Stop __ _ __ ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~1ftIQ"' Analysis 'rTRh Received? Completion Status 1-OIL Current Status WAGIN UIC Y 25 Col 114 18042 Case 4/23/2009 MD DGR, EWR, ROP 6- Apr-2007 25 Col 114 6883 Case 4/23/2009 TVD DGR, EWR 6-Apr- 2007 Sample Set Sent Received Number Comments Cores and/or Samples are required to be submitted. This record automatic411y created from Permit to Drill Module on: 3/1212007. ~N Daily History Received? ( N Formation Tops v Comments: _._ - Compliance Reviewed By. _ _ _ ___ - Date: ~_` ~~ • SELL LDG T S1YI1T'TA~, To: State of Alaska Apri16, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-114 AK-MW-4959675 CD3-114 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20544-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20544-00 Digital Log Images: 1 CD Rom 50-103-20544-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com V~~~o~-033 1~`~i~ t __ r Date: Signed: M ~~~~-- • • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: _~ -~ ~_. a.~~:~ AP~ ~ ~oo~ ~SiO~+ ~h~~ ~~~~- d33 L`1~3 _ ~ 1~ Enclosed please fmd 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 Apri15~', 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, r~ ~~~.~ 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 Page 1 of 1 Maunder, Thomas E (DOA) From: Walker, Jack A [Jack.A.Walker@conocophillips.com] Sent: Wednesday, May 07, 2008 5:19 PM To: Maunder, Thomas E (DOA) Cc: Haas, Jeanne L Subject: RE: CD3-114 (207-033) Sorry, Tom. The first injection for CD3-114 was 29-Feb-2008. Jack From: Maunder, Thomas E (DOA) [mailto:tom.maundera~alaska.gov] Sent: Wednesday, May 07, 2008 5:17 PM To: Walker, Jack A Subject: CD3-114 (207-033) Jack, I am reviewing the 404 for the conversion of this well to injector. When was the first date of injection? The date of first injection should be included on future reports such as this. Thanks in advance. Tom Maunder, PE AOGCC 5/7/2008 ~ ~ RECEIVED STATE OF ALASKA MAY 0 2 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPER1~~ Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ her 0 Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Convert to Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ Injection / 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnocoPhillips Alaska, InC. Development ^ Exploratory ^ 207-033 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20544-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB = 36' CD3-114 8. Property Designation: 10. Field/Pool(s): ADL 384215,372105, 380092' Colville River Field/Fjord Oil Pool 11. Present Well Condition Summary: Total Depth measured 18042' feet true vertical 6884' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2842' 9-5/8" 2892' PRODUCTION 10577' 7" 10627' OPEN HOLE 7415' 6 1/8" 18042' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9678' MD. Packers &SSSV (type & measured depth) Baker Premier Packer seE~ Camco BAL-O Nipp le SSSV set at 2132' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 3979 2668 -- 1566 301 Subsequent to operation 6002 844 581 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ' Daily Report of Well Operations _ 16. Well Status after proposed work: Oil^ Gas^ WAG^ 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 G.O. Exempt: 308-051 contact Jack Walker Printed Name Jack Walker ~ ~ ~ Title Pho Production Engnineer D t ~ ~ ~' Signature ., `~~~yG` j , ~~~ ne a e Z.~ c? 265-6268 Form 10-404 Revised 04/2004 ~ l ~ ~ ~ Submit Origina/I ly , . ' ~,,!. _.. CD3-114 ~~~ _~ ~-~ Information s~~~~ A~ ~PP~~c~~~~~Cp3 ~~~~ ~~~~~~ ~,~1~~~,~ • ConocoPhilli S Casing Detail 9 5/8"Surface Casing Well: CD3-114 Date: 3/20/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.40 FMC Gen V Hanger 2.21 36.40 Jts 3 to 74 72 Jts 9-5/8" 40# L-80 BTC Csg 2775.32 38.61 HOWCO Float Collar 1.43 2813.93 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 74.45 2815.36 Ray Oil Tools "Silver Bullet" Float Shoe 2.27 2889.81 2892.08 TD 12 1/4" Surface Hole 2902.08 TOTAL BOWSPRING CENTRALIZERS -43 1 per jt on Jt # 1 - # 13 (stop ring on Jt # 1 & 3 ) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67,69, 71,73. 80 joints in the pipe shed. Run 74 joints - 6 joints stay out Casing shoe @ 2892.08' MD/ 2485' TVD Hole TD 2902' MD 2491' TVD Use Best-o-Life 2000 pipe dope MU torgue - 8600 ft/Ibs Remarks: U p W t- 170 k Dn Wt - 130k Block Wt - 75k Supervisor: D. Burley / L. Hill a n ~. Cement Detail Report :~ r. - CD3-114 .. Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10165152 3/17/2007 3/18/2007 - _ _ ~- - Cement Detai)s' Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3!20!2007 11:15 3/20/2007 13:15 CD3-114 Comment Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls CW 100 w/ Dowell -Tested lines to 2500 psi - Pumped 15 Bbls CW 1-00 -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 347 bbls lead slurry (ASL) @ 10.7 ppg (* Observed nut plug marker @ shakers w/ 328 bbls lead pumped -pumped down surge can) Pumped 51.5 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 193 bbls 9.8 ppg water base mud -Displaced @ 7.0 bbls/min for first 185 bbls - slowed to 4 bbls/min for last 8 bbls -Bumped plug w/ 1100 psi (pre bump pressure 550 psi) Check float (held OK) CIP @ 1310 hrs. -Full circulation throughout job w/ 134 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until 70 Bbls displaced. Cement Stages - --- - ___ - - -- - -- __ Sta e # 1 Description Objective Top (ftK6) 'Bottom (ttKB) Full Retum? Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement Cement to Surface. 36.4 2,892.0 Yes 134.0 Yes Yes Q (start) (bbl/min) Q (end) (bbllmin) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 550.0 1,100.0 Yes 20.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Lead Cement 10.7 PPG 437 Sxs. Tail CI G 15.8 PPG 247 Sxs. __ _ £ement Fluids & Additives - --- - _---- - - - - Fluid ' _ _ _ _ _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.4 2,392.0 437 347.0 Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.77 10.70 Additives Additive Type Concentration Conc Unit label __ _ T -_ - - - -- Fluid __ Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,392.0 2,892.0 247 G 31.5 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/3/2007 r~ ~~ Security Level: Development Daily Drilling Report >, _~ , } :.;_,: CD3-114 Report Number: 4 . . • «_ Rig: DOYON 19 Report Date: 3/20/2007 Welltwre Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD3-114 Development FIORD NECHELIK 3/18/2007 2.98 2,902.0 2,902.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE + Sup Amount 10165152 11,643.32 64,198.02 390,312.06 1,306,976.96 7,862,505.00 Last Casing String Next Casing OD (in) Nett Casing Set Depth (ftK6) Surface, 2,892.1ftKB Ops and Depth @ Morning Report 24hr Forecast RIH w/ 8-3/4" Drill String RIH w/BHA - Cut/Slip DL - Wash U shoe -Drill 20' -FIT -Drill 8-3/4" Last 24hr Summary RIH w/ 9-5/8" csg -land @ 2892'. Cement & test to 2500 psi. ND Riser - NU WH & BOPE -Fill stack & begin testing BOPE. General Remarks Weather Head Count -28 / S @ 7mph / -47 we 50.0 - - _ --- _ Supervisor - - ' Title Don Mickey Rig Supervisor Nina Woods Rig Supervisor Time Lo - -._ ---- _ _ _ __ _ - -- ------ Stag End Dur Tin Depth Sta I Dapth End J ~ c... i P~N- Trbl COIF T, b, ..pass. (itKB) I (ftK6) __. C_~.im/O~- alien Time Time (tics) Phasa .)p Cove ' Op°u^-.; T, _ _ _ _ 00:00 01:45 1.75 SURFAC DRILL PULD P 65.0 0.0 Down load MWD - LD BHA -clear tools from rig floor 01:45 03:00 1.25 SURFAC CASING RURD P 0.0 0.0 Rig up to run 9 518" casing 03:00 03:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Prejob Safety and Ots meeting with crew 03:15 06:30 3.25 SURFAC CASING RNCS P 0.0 1,732.0 Run 9 5/8" 40# BTC csg as follows: FS(Silver bullet) 2 jts. csg - FC (Weatherford) 2 jts. csg (fill pipe 8~ check floats -first 4 connections made up w/ BakerLoc) 41 jts. csg. for 45 total to 1,732' 06:30 07:00 0.50 SURFAC CASING CIRC P 1,732.0 1,732.0 Stage pumps up to 5.0 bpm - CBU - FCP 240 psi PUW 135K SOW 125K 07:00 08:45 1.75 SURFAC CASING RNCS P 1,732.0 2,892.0 Run 9 5/8" 40# BTC from 1,732' to 2,853'. 29 jts for a total of 74 jts. Made up landing Jt and hanger. Landed casing @ 2,892'. 08:45 09:15 0.50 SURFAC CASING RURD P 2,892.0 2,892.0 Laid down Franks tool and rigged up cement head. 09:15 11:15 2.00 SURFAC CEMENT CIRC P 2,892.0 2,892.0 Circulated bring pumps up in stages to 7 BPM. 11:15 13:15 2.00 SURFAC CEMENT DISP P 2,892.0 0.0 Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls CW 100 w/ Dowell -Tested lines to 2500 psi -Pumped 15 Bbls CW 100 -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 347 bbls lead slurry (ASL) @ 10.7 ppg (" Observed nut plug marker @ shakers w/ 328 bbls lead pumped -pumped down surge can) Pumped 51.5 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps 8~ displaced cmt w/ 193 bbls 9.8 ppg water base mud -Displaced @ 7.0 bbls/min for first 185 bbls -slowed to 4 bbls/min for last 8 bbls -Bumped plug w/ 1100 psi (pre bump pressure 550 psi) Check float (held OK) CIP @ 1310 hrs. -Full circulation throughout job w/ 134 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until 70 Bbls displaced. 13:15 14:00 0.75 SURFAC CASING DHEQ P 0.0 0.0 RU & Tested casing to 2500 psi for 30 Min. 14:00 15:00 1.00 SURFAC CASING RURD P RD Cement & CSG Equipment, LD Bales, landing jt. Clear Floor. PU GeoSpan unit. 15:00 17:15 2.25 SURFAC CASING NUND P ND Riser 17:15 18:15 1.00 SURFAC CASING NUND P Install Wellhead. 18:15 20:30 2.25 SURFAC CASING NUND P NU BOPE 20:30 00:00 3.50 SURFAC WELCTL BOPE P Fill stack -Begin testing ROPE -Tested Annular t/ 250/3000 psi. Tested top rams, valves #1-16, HCR Kill, Choke, Dart, FOSV, Main IBOP, and Auto IBOP. Latest BOP Test Data _ _ _ _ _ _ _ _ _ . -- Date Comment I Page 1/2 Report Printed: 4/3/2007 Security Level: Development Daily Drilling Report CD3-114 Report Number: 4 N ~,_ Rig: DOYON 19 Report Date: 3/20/2007 - - Mud. Check Data __ _ __ _ Type ~. Leoth (flKE; Dens (Ibfe~l) V s ,%qt) ':PV Cah lsPj - _ _ _ YP Gai i Gel ('I Osj Gel {10m) GeI (3Am) 'i (HTHP i=1ft ~N Denedy Temp SoI~dS Corr ,Ibf;1Dr' rlbf110[H1') -,. (Ibf1100ft'j (Ibft10oft') MBT Ilt~hbll ! mtl3t)miri) ~i {°F) (,~1 I _ ~ - - Spud Mud 2,902.0 9.90 52 27.0 ~ 15.000 5.000 9.000 12.000 25.0 9.0 72.0 1- - --- - In"ectionf/uid Flwd Source FromLease`{bblj Destination Note Cementing Fluids 433.0 CD3-112 CD3-114 Diesel 100.0 CD3-112 Water 170.0 CD3-112 Water Based Mud 2054.0 CD3-112 From CD3-114 _ Drill Strings: BHA' No. 1 '- 8" Mud Mtr 4/5 5.3 st 1 'Bit Run Na.'-1 - 12 114n, Hu hes Christensen ', 1VIXL-1 .',..5106587_ _ Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles {/32") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 114.0 2,902.0 0.75 12/16/16/18 4-5-WT-A-E-1-NO-TD 44 0 0 Drill Strin Components _ Jts Item Description _ - - : OD {iri) ~ ID (in) Top Conn Sz {in) lop Thread = Cum Len (ft) _ Motor with Stabilizer 4.947 6 5/8 H 90 31.81 8 Float Sub 8.08 2.813 6 5/8 H 90 34.39 Stabilizer 8.1 2.813 6 5/8 H 90 39.92 MWD 8 1.920 6 5/8 Reg 66.31 UBHO 8 3.250 6 5/8 H 90 68.90 NMDC 8 2.875 6 5/8 H 90 99.82 NMDC 7 718 2.813 6 5/8 H 90 130.78 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 165.35 24 HWDP 5 3.000 4 1/2 IF 889.83 ~Drillin Parameters SlidingHrs CumDnll: F ( j ~ Sta2S902).0 En2(902.0 (hrsj CU2 788.00 T~ 22h31 I - Qttlo.tij RPM PUHL RotHL SO HL (C14600~ w0 30 0 ,r;,~50~ SF1,960.0 tlooolb~38 (iooDlt1)J/ (~ooolt'1133 6,500.0 ~ III T~ 1,500.0 WQllbores -- - - - - Wellbore Name Wellbore API/UWI CD3-114 501032054400 Section Size (in) _-__ _ AcETop (ftKB) Ad Btm (ftKB) Start Date s': End Date -- - - PROD1 COND1 0.0 114.0 3/12/2007 3N 3/2007 SURFAC 114.0 2,892.0 3/18/2007 3/19/2007 INTRMI - 2,892.0 10,627.0 3/26/2007 3/27/2007 - - -- Cement Surface Casin Cement -Started 3/20/2007 Type Wellbore String Cement Evaluation Results CD3-114 Surface, 2,892.1 ftK6 134 Bbls to surface. Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.4 2,892.0 4 550.0 Fluid Class Amount (sacks) V (bbl) Density (Ib/gal) Yield. (R'lsacl. i Est T op (ftKB) Est Btm {ftKB) _ _ _ __ _ __ Lead Cement 437 347.0 10.70 4.45 T 36.4 2,392.0 Tail Cement G 247 51.5 15.80 1.17 2,392.0 2,892.0 Page 2/2 Report Printed: 4/3/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-114 Rig: Doyon 19 Date: 3/20/2007 Drilling Supervisor: L. Hill / N. Woods Pump used: #z Mud Pump ~ T f T t ~ P i d Volume Input Strokes ~ Volume/Stroke Pump Rate: 0.1000 Bbls/Strk ~ 8.0 Strk/min ~ ype o es : OpenholeTest LOT/Frr ump ng own annulus and DP. ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe Depth Hole Depth Pumpin Shut-in Pumping Shut-in RKB-CHF: 36.4 Ft 2,892 Ft-MD 2,485 Ft-TVD 2,922 Ft-MD 2,503 Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 9-5/8" 4o#/Ft L-so BTC ~ 0 0 0 2600 1 0 0 1050 Casing Test Pressure Int e rit Test 2 100 1 2600 2 40 0.25 850 Mud Weight: 9.8 ppg Mud Weight: 9.8 ppg 4 300 2 2600 3 120 0.5 800 Mud 10 min Gel: 10.0 Lb/100 Ft2 Mud 10 min Gel: 19.0 Lb/100 Ft2 6 575 3 2600 4 300 1 800 Test Pressure: 2,500 psi Rotating Weight: 135,000 Lbs 8 850 4 2600 5 400 1.5 Rotating Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 1050 5 2580 6 500 2 80 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1200 6 2580 7 600 2.5 800 Estimates for Test: 2.1 bbls Estimates for Test: 1060 psi 0.8 bbls - -_ 14 1375 7 2580 8 700 3 800 ~ ~ 16 1550 8 2580 9 800 3.5 800 _ _ EMW =Leak-off Pressure + Mud Weight = 850 + 9 8 PIT 15 Second 18 1750 9 2580 10 850 4 800 0.052 x TVD 0.052 x 2485 Shut-in Pressure, psi 20 1950 10 2580 11 850 4.5 790 EMW at 2892 Ft-MD (2485_ Ft-ND) = 16.4 `' - -- - - - 850 22 2150 15 2580 12 850 5 790 sooo - - (~ Lost 20 psi during test, held 24 2400 20 2580 13 850 5.5 790 - -- - _ t~ 99.2% of test pressure. 26 2600 25 2580 14 850 6 790 '' ~~ - 30 2580 15 850 6.5 790 zsoo _ - -- 16 880 7 790 - ~ I - 17 900 7.5 785 zooo - 18 925 8 785 -- { - 19 950 8.5 785 ~ - - 11 20 975 9 785 ~ 1500 - 21 1000 9.5 78 w - 22 1020 10 7 ~ a _ - ~ 23 1040 loco - - - ~ 24 1060 - - I 500 I -- - - 0 0 1 2 3 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~~CASING TEST tLEAK-OFF TEST O PIT Point Vol PUm ume ed Vol Bled ume Back Vol PU ume m ed Vol Bled ume Back s s s s Comments: Casing tested after bumping plugs on cement job. ConocoPhilli s p Casing Detail 7" Casing Well: CD3-114 Date: 3/22/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.70 FMC Gen V Hanger 1.63 34.70 Jts 112 to 248 137 Jts 7" 26# L-80 BTCM Csg 5839.10 36.33 7" Weatherford Stage collar BTCM 2.35 5875.43 Jts 3 to 111 109 Jts 7" 26# L-80 BTCM Csg 4659.96 5877.78 Halliburton Float Collar .98 10537.74 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.09 10538.72 Ray Oil Tools "Silver Bullet" Float Shoe 2.09 10624.81 10626.90 TD 8 3/4" Hole 10639.00 8-3/4" Hole TD @ 10,600' MD / 6925' TVD 7" Shoe @ ' MD / 'TVD Total Centralizers: 51 Straight blade centralizer one perjt on jts # 1-14 Straight blade centralizer above/below stg collar # 110, 111 Straight blade centralizer one per jt jts. #180, 181, 182 Straight blade centralizer one per jt on every other joint from #'s 184 - 246 Top Nechelik - 10,590' MD 6,920' TVD 258 joints in shed - total 248 jts. to run Last 10 jts. out Use Run & Seal i e do e MU torque - 7800 ft/Ibs Remarks: Up Wt - 315 k pn Wt-165k Block Wt - 75k Supervisor: L. Hill / N. Woods 1-~ ~ ~ Cement Detail Report CD3-114 r ' s. Production Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10165152 3/17/2007 3/18/2007 Cement Details _ ----- - - --- - - Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 3/27/2007 00:00 3/27/2007 00:00 CD3-114 Comment Cemented 7" csg as follows: Pumped 10 bbls CW100 -Tested lines to 4000 psi -Pumped 40 bbls CW100 @4 bpm, 400 psi -Mixed & Pumped 40 bbls Mudpush @ 3 bpm, 300 psi. -Mix & Pump 51 bbls of 15.8 ppg Tail Slurry (255 sacks) @ 5 bpm, 450 psi. Drop Shut off plug with 20 bbls Water f/ Dowell. Switched to rig pumps & displaced cmt w/ 9.8 ppg mud @ 7 bpm for 375 bbls, 380 - 700 psi. Dropped rate to 3 bpm for 7 bbls -Bumped plug with 850psi (500 psi over 350 pump pressure). 382 bbls total d isplacement. Checked floats - OK. Cement 2nd stage 7" at Qannik as follows: Pumped 10 bbls CW100 @ 4 bpm, 150p psi. Mixed & pumped 20 bbls mud push 10.5 ppg @ 4 bpm, 150 psi. Mix 8 pump 38 bbls of 15.8 ppg Class Gcement - 184 sacks - @ 4.5 bpm, 45 psi. Drop closing plug with 10 bbls of water f/ Dowell -Switch to rig pumps 8~ displace w/ 9.8 ppg mud @ 7 bpm pumping 1 90 - 400 psi. Bump plug @ 213 bbls, pressure increased to 1200# to shear top pins -bumped to 2500# and held. Opened surface valve to confirrn sleeve closed. Continued to pressure up, broke over @ 2900psi to 2200 psi and held. Suspect composite plug btm broke. - --- Cemenf Stages -- -- - - - - - 5ta e # 1 -_ - - Description Objective - Top (ftK6) Bottom (ftKB) Full Return? Gmnt Rtm (... Top Plug? Btm Piug? Production Casing Primary 9,340.0 10,629.0 No Yes No Cement Q (start) (bbl/min) Q (end) (bbllmin) (l (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment ~Cement Fluids'& Additives - - - - _ - -- - ------ Fluid Fluid Type Fluid Description _ _ Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW-100 50.0 Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label - - -- Fluid - - - - - _-- - -- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 40.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label - Fluid - - Fluid Type Fluid Description _ Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail 9,340.0 10,629.0 255 G 51.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 1.16 15.80 Additives Additive Type Concentration Conc Unit label -- - - -- - Fluid.'.. - _ --- _ _ - --- - _ __ _ Fluid Type Fiuid Description __ Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Water 20.0 Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label - - - Fluid - - -- - Fiuid Type Fiuid Description 'Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbQ Mud 382.0 Yield (fY/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 9.80 Page 112 Report Printed: 4/3/2007 - - Cement Detail Report CD3-114 Production Casing Cement Additives Additive Type Concentration Conc Unit label Cement Stages ---- -- Sta a#2 _ Description _ Objective Top (ftK6) Bottom (ftK6) Full Retum? Cmnt Rtm (... Top Plug? Btm Plug? Production Casing 4,675 .0 5,875.0 No Yes No Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Dritl Out Diameter (in) Comment Pumped through stage collar @ 5875' .Cement Fluids 8~ Additives Fluid __ Fluid Type Fluid Description Estimated Top (ftK6) _ Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW-100 10.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label - - Fluid - - - Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Mud Push 20.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity {cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label -- Fluid --- - - Fluid Type Fluid Description Estimated Sop (ftK8) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail 4,675.0 5,875.0 184 G 38.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 15.80 Additives Additive Type Concentration Conc Unit label ,Fluid -- - - --- _ __ __ ___ _ Flu yd 7iFlu pe Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Water 10.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label Fluid - - -- - _ -- Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Mud 214.0 Yield (ft !sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 9.80 Additives Additive Type Concentration Conc Unft label Page 2/2 Report Printed: 4/3/2007 r~ ~ Security Level: Development ` , Daily Drilling Report CD3-114 Report Number: 10 Rig: DOYON 19 Report Date: 3/26/2007 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ftKB) Depth Progress (ft) CD3-114 Development FIORD NECHELIK 3/18/2007 8.98 10,639.0 10,639.0 0.00 AFE / RFE 1 Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummutative Cost Total AFE + Sup Amount 10165152 1,700.00 310,699.10 462,734.50 3,141,889.09 7,862,505.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 10,627.OftKB Ops and Depth @ Morning Report 24hr Forecast CO to VBR Rams 8~ Test MU BHA -RIH for Clean out to shoe track - CBU -POOH Last 24hr Summary LD BHA - CO top rams to 7" 8~ Test -RIH w! 7" Csg & land shoe @ 10,626' MD -Establish Circ -PJSM and begin stage 1 cement job. General Remarks Weather Head Count -18, SW @ 29 mph 50.0 g„F,.,,,.or Title"- ---- Don Mickey Rig Supervisor Nina Woods Rig Supervisor _ _ __ Time Lo __ --- End Dur Tini Start ----- - c'-- P P De th Start De th End ~ F P Time Time (hrs):~ Fha:e ~) ~ Co-~e O~ Sub-Co... P-N I Trp; C.~x1F~ '. lrbl (.la_~ (ftK8) (ftK8) Comrril0 eration --- - __ P 00:00 01:00 1.00 INTRM1 DRILL PULD P 50.0 0.0 Finished download MWD and lay down. Break Bit. Flow check static. Clear rig floor. 01:00 03:00 2.00 INTRM1 WELCTL BOPE P 0.0 0.0 Pulled wear bushing. Changed rams to 7" and tested to 250 ! 5000 psi. 03:00 05:15 2.25 INTRMI CASING RURD P 0.0 0.0 Installed thin wear bushing and rigged up to run casing. 05:15 05:30 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM for running casing. 05:30 10:30 5.00 INTRMI CASING RNCS P 0.0 4,275.0 Make up and RIH with 7" 26# L-80 BTCM Csg as follows: Ray Oil Tools Silver Bullett FS - 2 jts - Halliburton FC - 98 jts to 4,275'. Baker Loc 1st 4 jts. Baffle Plate installed in the top of Jt #3. 10:30 11:15 0.75 INTRMI CASING CIRC P 4,275.0 4,275.0 Broke circulation with 2 BPM and worked up to 5 BPM. FCP 440 psi. 11:15 16:00 4.75 INTRM1 CASING RNCS P 4,275.0 8,554.0 Continue RIH with 7" 26# L-80 BTCM Csg to 8,554' as follows: 11 jts -Weatherford Stage Collar BTCM - 89 jts. 16:00 17:00 1.00 INTRMI CASING CIRC P 8,554.0 8,554.0 Establish Circulation @ 1.5 bpm @ 430 psi. Stage up to 7 bpm. FCP 630 psi. 17:00 19:30 2.50 INTRMI CASING RNCS P 8,554.0 10,627.0 Cont RIH with 7" 26# L-80 BTCM Csg to 10,627' MD. Landed Shoe @ 10,627' MD, Stage Collar @ 5875' MD. Total of 248 jts run, 51 centralizers. 19:30 20:00 0.50 INTRMI CASING RURD P 10,627.0 10,627.0 Lay Dwn Franks Tool, Blow Down TD, MU Cement Head. 20:00 23:00 3.00 INTRMI CASING CIRC P 10,627.0 10,627.0 Establish Circulation 1.5 bpm @ 430 psi, Stage up to 7 bpm. FCP 630 psi. 23:00 00:00 1.00 INTRMI CEMENT CIRC P 10,627.0 10,627.0 PJSM -Begin cementing 1st stage. Mud Check Data _ '. _ _ ~ YP Galc Gel {10s) Gel {3cm) Gel j3Dm) HTHP FiK ~DFmit, Temp ~ u rs, Corr. ~ Type Depth (ftKB) Dens ilb!gal) ;Vic Islr~t)', PV Calc l,cpr ~ ~i (mLf30miri) pH '~ (Fl ~%) :, (br1700rt') (1bfl700(t') Qbf1lDOft?.) libf11i30ft~) MBT.pb2hl) LSND 10,639.0 9.30 37 92.0 -64.000 5.000 6.000 10.000 14.0' 7.0 9 2 75.0 ~ - - - - - Jn'ection Fluid - ---- ~ _ - - Fhud Source _ ( ) - ~ ~ From Lease bbl Destination - Not. ---_-~ Diesel 5.0 CD3-111 Water Based Mud 164.0 CD3-111 f/ CD3-114 Drill Strin s:,BHA No. 3 -tS-1/8" Rota 'Ass !Bit Run No. 3 - 6 1/bin, GeoDamond , M285YPX JT0332 Depth In (ftKB) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (/32") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 10,639.0 10,639.0 0.70 13/12/12/12112/13 2-1-CT-CG-X-O-BT-BHA 9 0 0 Drill Stri~cn Comments -- Jts Item Description _ _- OD {ua) Iq (in) .Top Conn Sz {in) Top Thread Cum Len (ft) 1 Bd Sub 5 2.000 3 1/2 NC 38 2.58 1 Stabilizer (Non Mag) 4.79 2.250 3 1/2 NC 38 7.53 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 38.66 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 69.83 Latest BOP Test Data _ _ __ -- - Date _ __Comment __ ___ __ __ _ 3/21/2007 250/3500/5000 si 4" & 5" Page 1/2 Report Printed: 4/3/2007 Security Level: Development a Daily Drilling Report , CD3-114 Report Number: 10 +' -N . M ' Rig: DOYON 19 Report Date: 3/26/2007 Drill String Components _ _ Jts _ _ _ _ ____ _ __ Item Descnptron OD {m) '. ID (inj; -. Top Conn Sz?(in) Top 7}iread "Cum Len (ft) _ 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 101.01 1 XO Sub 5 2.000 4 XT-39 103.98 3 HWDP 4 2.563 4 XT-39 196.01 1 Drilling Jars -Mechanical 4 3/4 2.000 4 XT-39 228.28 2 HWDP 4 2.563 4 XT-39 289.63 - - -_ Drillin Parameters _ _ - _ 3~Idir gHrs ' ' Dnll _ ~ t p L ~ H 1 1` st ( E ( Cum Depth (ft) T ~~~ ta~' ~I ~ I 5 J ( er 2 (1~It r C 0 (t~Ll` n , ( 1 10 fi 9.U 639.0 10 I lu~ 625~ 20.0 3,490.0 1u - 12,000. 000A - 1 55 10, -- _ Wellbores'- ____ ___ _ Wellbore Name Wellbore APWWI CD3-114 501032 054400 Section Size+(n} Act Top (ftK6) Act Btm (ftK6'~ _ Start Date End Date PROD1 COND1 0.0 114.0 3/12/2007 3/13/2007 SURFAC 114.0 2,892.0 3/18/2007 3/19/2007 INTRMI 2,892.0 10,627.0 3/26/2007 3/27!2007 Page 2/2 Report Printed: 4/3/2007 Security Level: Development ,. Daily Drilling Report CD3-114 Report Number: 11 . . R ig: DOYON 19 Report Date: 3/27/2007 Welltwre Well Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ttK6) Depth Progress (ft) CD3-114 Development FIORD NECHELIK 3/18/2007 9.98 10,639.0 10,639.0 0.00 AFE I RFE I Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE + Sup Amount 10165152 5,338.96 316,038.06 200,985.96 3,342,875.05 7,862,505.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 10,627.OftK6 Ops and Depth ~ Morning Report 24hr Forecast POOH on TT LD BHA -RIH w/PKR to test 7" Csg Last 24hr Summary Performed 2 stage cement job on 7" csg - CO to VBR rams & test 4-1/2" jt -Test PO to 5000 psi - MU BHA &RIH -Drill Out cmt @ Stg clr -RIH -Cut & Slip DL General Remarks Weather Head Count -18, SW @ 12 mph 49.0 -- Supervisor Title Don Mickey Rig Supervisor Nina Woods - - Rig Supervisor -- - - - -- - Time Lo i --- - - -- -- ~ Start End Dur Time Depth'St~,rt Depth End ', .Time Time (hrs) Nh~Se. OpCode OpSub-Co.:. P-N-T TrblCode lrblGass, {f1K6) f,f~hBl ~ CommlOpciatro;~ 00:00 01:00 1.00 INTRMI CEMENT DISP P 10,627.0 10,627.0 Cemented 7" csg as follows: Pumped 10 bbls CW100 - Tested lines to 4000 psi -Pumped 40 bbls CW100 @4 bpm, 400 psi -Mixed & Pumped 40 bbls Mudpush @ 3 bpm, 300 psi -Mix 8~ Pump 51 bbls of 15.8 ppg Tail Slurry (255 sacks) @ 5 bpm, 450 psi. Drop Shut off plug with 20 bbls Water f/ Dowell. Switched to rig pumps & displaced cmt w/ 9.8 ppg mud @ 7 bpm for 375 bbls, 380 - 700 psi. Dropped rate to 3 bpm for 7 bbls - Bumped plug with 850psi (500 psi over 350 pump pressure). 382 bbls total displacement. Checked floats - OK. 01:00 01:30 0.50 INTRMI CEMENT CIRC P 10,627.0 10,627.0 Pressure up on 7" Csg to 2900 psi to shift stage collar open - ICP 4.5 bpm -Establish circ @ 7 bpm, 300 psi. Circ BU. 01:30 02:30 1.00 INTRMI CEMENT DISP P 10,627.0 10,627.0 Cement 2nd stage 7" at Qannik as follows: Pumped 10 bbls CW100 @ 4 bpm, 150p psi. Mixed & pumped 20 bbls mud push 10.5 ppg @ 4 bpm, 150 psi. Mix & pump 38 bbls of 15.8 ppg Class Gcement - 184 sacks - @ 4.5 bpm, 45 psi. Drop closing plug with 10 bbls of water f/ Dowell -Switch to rig pumps & displace w/ 9.8 ppg mud @ 7 bpm pumping 190 - 400 psi. Bump plug @ 213 bbls, pressure increased to 1200# to shear top pins - bumped to 2500# and held. Opened surface valve to confirm sleeve closed. Continued to pressure up, broke over @ 2900psi to 2200 psi and held. Suspect composite plug btm broke. 02:30 04:15 1.75 INTRMI CEMENT RURD P 0.0 0.0 Blow dwn & RD cmt equip - LD tools -Pull Landing jt. 04:15 04:30 0.25 INTRMI CEMENT OTHR P 0.0 0.0 Pull wear ring -Drain Stack 04:30 05:30 1.00 INTRMI DRILL OTHR P 0.0 0.0 RIH w/ 7" packoff -Run in LDS's to 450 ftlbs -tested void t/ 5000 psi for 15 min -Good test -Bleed of( pressure 05:30 07:15 1.75 INTRMI WELCTL BOPE P 0.0 0.0 CO 7" Rams to 3-1/2" x 6" Variable -test 250/5000 psi with 4-1l2" test jt. 07:15 07:45 0.50 INTRMI CEMENT OTHR P 0.0 0.0 Set Wear Ring - PU 4" Bales & DP Elevators. 07:45 08:45 1.00 1NTRM1 CEMENT PULD P 0.0 0.0 MU BHA for Clean out run. 08:45 12:00 3.25 INTRMI CEMENT TRIP P 0.0 2,673.0 RIH PU DP singles to 2673' 12:00 14:30 2.50 INTRM1 CEMENT TRIP P 2,673.0 5,805.0 Cont PU 4" DP from shed f/ 2673' - 5805'. Tag cement @ 5805'. 14:30 16:30 2.00 INTRM1 CEMENT DRLG P 5,805.0 6,034.0 Wash dwn f/ 5805' t! 5876' -Tag stg collar -drill co)lar & cmt t/ 5960' - PU 2 jts t/6034'. Latest BOP Test Data mate Comment X21/2007 1250/3500/5000 psi 4" & 5" ~ Page 113 Report Printed: 4/3/2007 r - - Security Level: Development Daily Drilling Report CD3-114 Report Number: 11 «..• Rig: DOYON 19 Report Date: 3/27/2007 Time Lo Start End Der Time _ _ D-pthSt~ri Depth End Time Time ~h~sl ~. Phase '~ OpCorle :OpSut-Co.. ~t'-N-T , IYbIC 7_ i lrblClass. (`tKE) (ftKB] i~cmrrdOF~r~tinn 'i 16:30 17:00 0.50 INTRMI CEMENT CIRC P 6,034.0 6,034.0 Circ BU @ 307 GPM, 1100 psi. 17:00 21:00 4.00 INTRM1 CEMENT CIRC P 6,034.0 10,298.0 ContRIH w/ 4" DP from shed f/ 6034' t/ 10,298' 21:00 23:00 2.00 INTRM1 RIGMNT OTHR P 10,298.0 10,298.0 Cut & Slip 120' line -Service TD & Rig 23:00 00:00 1.00 INTRM1 CEMENT TRIP P 10,298.0 10,460.0 Wash dwn f/ 10,298' U 10,460' @ 300 gpm, 100 rpm, 1740 psi. - --- - Mud Check Data _ Type Depth(ftK6) Den ~L>Jga!) ~'Vi ~ql; FV~ ~Iclcp~ LSND 10,629.0 9.80 37 7 0' _ _ YP Calc Gel {'IOs) Gel (10m) Gel (30m) '~, - HTHP Filt Density Temp Solids Corr (Ibf1100ft') (Ibf/100ft').. (1bfIt00Ft') (Ibf/1OOft) .ti71j_~ ;fb/bbl) (mLl30min) t,ti (°Fj (%) '. 14.000 ~ ~ 14.0 7.~ 9.2 78.0 ~~ ~ __ ~ _ _ I - - _ _' _- - -~ In'ection Fluid __ ' Fluid Source From Lease bbl); ~ Destination.. td~:.~t-~ Diesel 40.0 CD3-111 FP Water 150.0 CD3-111 Flush Water Based Mud 2609.0 CD3-111 f/ CD3-114 -- _ - - - _ Drill'Strin r. BHA No.-3- 6-118"'Rota Ass /Bit Run No 3 - 6 1/bin, GeoDiamond , M285YPX, JT0332 Depth In (ftKB) Depth Out (ftKB) TFA (foci Noz) (ins) Nozzles (/32") IADG Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 10,639.0 10,639.0 0.70 13/12/12/12/12/13 2-1-CT-CG-X-O-BT-BHA 9 0 0 Drill Strin Components Jts Item Description" OD Qn) ID,(in) Top Conn Sz.(in~ _Top Thread Cum Len (ft) - - 1Bit Sub 5 2.000 3 1/2 NC 38 2.58 1 Stabilizer (Non Mag) 4.79 2.250 3 1/2 NC 38 7.53 1 NMFIexDC 4 3/4 2.250 3 112 NC 38 38.66 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 69.83 1 NMFIexDC 4 3/4 2.250 3 1/2 NC 38 101.01 1 XO Sub 5 2.000 4 XT-39 103.98 3 HWDP 4 2.563 4 XT-39 196.01 1 Drilling Jars -Mechanical 4 3/4 2.000 4 XT-39 228.28 2 HWDP --- 4 2.563 4 XT-39 289.63 _ - __ Drillin Parameters - - _ _ Cum Drill Sliding Hrs ~i HL - PU HL RoF HL RPM O (tl_..-~ ~ Start (ftKB) End (ft1C8) (hrs) Cum Depth (ft) TVme {hrsj 7I - ~ (aF ~1 WOE (ibf) ;([pm) SPP (psi) ( (t00016f) = (10001bf) (7 J~~Ibf! ~ U`f Btm'Tq Unll Tq '~ 1 12 000 0 18 1 000 0 0 ' 10,639.0 10 6~9 C J , . , 55 . 1 490 C 218, 1 , 625 2G 0 125 Wellbores Wellbore Name - - Wellbore API/UWI GD3-114 501032054400 '. Section Size {in) _ Ad Top (ftKB) '9d Btm ((t1Cf3 i ~ Start Data End Date' - - - - _ PROD1 COND1 0.0 114.0 3/12/2007 3/13/2007 SURFAC 114.0 2,892.0 3/18/2007 3/19/2007 INTRMI --- __ 2,892.0 10,627.0 3/26/2007 3/27/2007 T Cement - Production Casio Cement -Started 3/27/2007 Type Wellbore String Cement Evaluation Results CD3-114 Intermediate, 10,627.OftK6 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (Final) (psi) 1 Production Casing Cement 9,340.0 10,629.0 Fluitl ~. Ctass sAmount (sacks) V (bbl) Density,(IWgal) Yield {fN/sack) Est Top (ftKB) Est Btm (ftKB) ;. -- CW-100 50.0 8.30 Mud Push 40.0 10.50 Tail G 255 51.0 15.80 1.16 9,340.0 10,629.0 Water 20.0 8.30 Mud 382.0 9.80 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 2 Production Casing Cement 4,675.0 5,875.0 - - - - - Fluitl.. Class -. Amount {sadks).. V (blil).- " Density(Ib/gaq Yield{ftlsack) L t Top (ftKB) Est 8tm {ftKB). CW-100 10.0 8.30 Mud Push 20.0 10.50 Page 2l3 Report Printed: 4/3/2007 Security Level: Development Daily Drilling Report T } CD3-114 Report Number: 11 Rig: DOYON 19 Report Date: 3/27/2007 ' Ciass Amount{sacks). i V (bbi) Density (Ib7gal) Yleld (ft'/sack) ~ ;1=laid '` - Est Top (ft}:C) Est Btm flVB ~ -- --- _ _ _ `Tail G 184 38.0 15.80 1.17 4,675.0 5,875.0 Water 10.0 8.30 Mud 214.0 9.80 Page 3/3 Report Printed: 4/3/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-114 Rig: Doyon 19 Date: 3/27/2007 Volume Input Pum Rate: Drilling Supervisor: Mickey Pump used: Cement unit ~ Barrels • Bbls/Strk • 0.80' Bbl/min P Type Of Test: Annulus Leak Off Test for Disposal Adequacy • umping down annulus. ~ Casin Test Pressure In te rit Test Hole Size: $-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 34.2 Ft 2890.0 Ft-MD 2485.0 Ft-TVD 10639.0 Ft-MD 6560.0 Ft-TVD Bbls si Min si Bbls si Min si Casi ~ Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 96 0.00 527 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 0.5 172 0.25 464 Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 266 0.50 455 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 340 1.00 442 Hole Size is that drilled below outer casing. 4 2 418 1.50 4 Use estimated TOC for Hole Depth. 5 2.5 480 2.00 4~ Enter inner casing OD at right. Desired PIT EMW: .15.0 ppg 6 3 526 2.50 422 Estimates for Test: 672 si 0.7 bbls 7 3.5 556 3.00 417 ~ ~ 8 4 575 3.50 411 EMW =Leak-off Pressure + Mud Weight = 575 + 9 8 PIT 15 Second 9 4.5 549 4.00 404 0.052 x TVD 0.052 x 2485 Shut-in Pressure, si 10 5 532 4.50 402 EMW at 2890 Ft-MD (2485 Ft-TVD) = 14.2 .~~ 464 15 5.5 536 5.00 397 ~ooo 20 6 542 5 50 394 ~ . ~ 25 6.5 539 6.00 391 30 7 527 6.50 385 7 00 385 ~ . 7.50 377 8 00 377 . w 8.50 375 ~ 9.00 371 eoo `j 9.50 37 ~ w 10.00 3 a i 6 0 o , 2 a s s ~ s o s , 0 1 5 z o 2 5 a o ~~C ASING TE Ba ST rrels -~-BLEAK -OFF TES T Shut-I O P n tim IT Poin e, M t inute s Volu PUm me ed Volume Bled Back Volume PUm ed Volume Bled Back s s s s Comments: 9 5!8" casing shoe PIT = 16.4 ppg t,v~- ~ i4 r-iuiuidi w i .xis Summary ConocoPhillips CRU Initial MIT' ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, March 29, 2008 2:45 PM To: Fleckenstein, Robert J (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv ~~ C ~ (~ `c~ Subject: ConocoPhillips CRU Initial MIT's Attachments: MIT CRU CD3-114 03-26-08.x1s; MIT CRU CD4-17 03-26-08.x1s «MIT CRU CD3-114 03-26-08.x1s» «MIT CRU CD4-17 03-26-08.x1s» Attached for your records are the initial waived State witnessed MITIA's for the CRU CD3-114 and CD4-17 we((s. Please contact me at your convenience if you have questions or comments. Martin Walters ConocoPhillips Alaska, Inc. Problem Wells Supervisor Office 907-659-7224 Cell 907-943-1720 Pager 907-659-7000 #909 4/1/2008 ~U~ _d33 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. ~ ~~ ~ I ~ `©~ FIELD /UNIT /PAD: Alpine /CRU /CD3-114 DATE: 03/26/08 OPERATOR REP: Pat Mize AOGCC REP: Waived Packer De th Pretest Initial 15 Min. 30 Min. Well CD3-114 T e In~. W TVD '6,626' Tubing 1336 1336 1315 1317 Interval I P.T.D. 2070330 T pe test P Test si ~ 1657 Casin 420 2590 2533 2517 P/F P Notes: Initial state witnessed MITIA OA 400 460 453 450 Well Type In'. TVD Tubin Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T etest Test psi Casin P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. Ty e test Test si Casing P!F Notes: OA Well Type In'. TVD Tubin Interval P.T.D. Type test Test si Casin P/F Notes: OA Well T e In~. TVD Tubin Interval P.T.D. T e test Test psi Casing P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT CRU CD3-114 03-26-08.x1s ~~~~~~~ Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job # 03/20/08 N0.4635 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Log Description Date BL Prints CD ;; ~ , Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. Alpine CD3-114 SCMT log ~ • page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, March 10, 2008 1:19 PM ~ ~~ ~~ X01 `~~ To: 'Brake, Jared M'; 'Walker, Jack A' Subject: RE: Alpine CD3-114 SCMT log Disregard part about 10-403 -1 did not realize that one had already been sent. Sundry will be approved today. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: Regg, James B (DOA) Sent: Monday, March 10, 2008 12:08 PM To: 'Brake, Jared M'; Walker, Jack A Subject: RE: Alpine CD3-114 SCMT tog I have reviewed the SCMT log for interval 9,677 ft MD to 10,168 ft MD and agree with your assessment that the log indicates good cement. Based on that and the previously reviewed cement records completed by the Commission after receipt of the Completion Report, you are authorized to place CD3-114 (PTD 207-033) on injection. We will need a '10- 403 to convert the well; please provide a paper copy of the SCMT log with that. Make the appropriate annotations on the sundry form regarding verbal approval (Block 17 of the form). You are also reminded about scheduling an A000C- witnessed MIT after commencing injection and well injection conditions have stabilized. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: Brake, Jared M [mailto:Jared.M.Brake@conocophillips.com] Sent: Friday, March 07, 2008 5:43 PM To: Walker, Jack A Cc: Regg, James B (DOA) Subject: Alpine CD3-114 SCMT log Gentlemen, Here is the copy of the SCMT log from Alpine well CD3-114 performed on 03/07/2008. The log indicates good cement from the tag depth of 10,168' all the way to the tubing tail at 9677'. «CD3 114 SCMTPRINT 7MAR08.PDS» Jared Brake Wells Supervisor ConocoPhillips Alaska, Inc. Office (907) 670-4555 Cell (907) 943-1208 fared. m. brake@conocophillips. com 3/10/2008 s ~ ~.~~ rn~ ~ ~ ~:~ ~ L.a ~ , ,~ s `"' ~ r 1 ~.. o-~~ 1 r I ~~ ~ ~ ~ r ~ ~~ , ~ {.~ ~._.. s i ~ C01~S~RQ~ ATI01•T ~gsjp~ Jack Walker Staff Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510 Re: Colville River Unit Field, Fiord Oil Pool, CD-114 Sundry Number: 308-051 Dear Mr. Walker: 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 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of March, 2008 Encl. ~ ~,~ ~ i~~L1V~ ~~ 3 STATE OF ALASKA ~~~. ~~ ~~: x ~ ~ ~0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVk~a~~&,~as~Cons. 4~ "!~'~°~' 20 AAC 25.280 ~~8 ` '~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Convert Change approved program Q Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ t^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q Exploratory ^ 207-033 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20544-00 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? Y2S ^ NO ^~ CD3-114 9. Property Designation: ~ 10. KB Elevation (ft): 11. Field/Pool(s): ADL 384215, 372105, 380092 ~ ~ RKB 3T Colville River Field / Fiord Oil Pool ' 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18042' 6884' Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2842' 9-5/8" 2892' PRODUCTION 10577' 7" 10627' OPEN HOLE 7415' S-1/2" 18042' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open hole completion Openhole completion 4-1 /2" L-80 9678' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier packer Packer depth = 9618' Wireline retrievable, surface controlled SSSV SSSV= 2132' 13. Attachments: Description Summary of Proposal Q 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 22, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker Printed Name Jack Walker Title: Staff Production Engineer ' ~ ` Signature V~--~ ~--~ Phone 265-6268 Date 2/14/08 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness "©~~ Plug Integrity ^ BOP Test ^ echanical Integrity Test ~ M Location Clearance ^ ~ ^ ,- 't'ip-~ 1.~3a'~sS~~ pJ~~ctC~ ~'~S~~ t `f't'_ J~'L , _ Other: = ~('~ ~~CJ" Q,4Y~1Q+1CQ 1 ~~° ~'+1 `i ~ 'tit,..S ~~Tt!e'~' Subsequent Form Required: APPROVED BY //O / e Approved by: I STONER T MMISSION Dat ` ~~~ Form 10-403~evised 06/2006 ~ V 1 ~ ~ ~ ~'v ~ L ~~~~s~!-x-l~"' ~~ I j ubmit in Duplicate i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 CD3-114 Sundry Approval Application Description Summary of Proposal Febuary 14, 2008 CD3-114 was originally permitted as an injection well under permit to drill 207-033. Before injection, it was converted to a production well under Sundry Approval 307-128. This sundry application seeks approval to r convert CD3-114 to its orginally permitted service as a WAG injection well. A pressure build-up test was conducted at the conclusion of the production period. An MIT and cement quality fog are planned to demonstrate that injection will be confined to the approved interval. Form 10-403 Revised 06/2006 Submit in Duplicate • Page 1 of 1 i Maunder, Th©mas E (DOA) From: Wilson, Chris [Christopher.J.Wilson@conocophiHips_com} Sent: Friday, February 15, 2008 1:49 PM To: Maunder, Thomas E {DOA) Cc: Walker, Jack A Subject: RE: CD3-114 (207-033) Thanks for the note Tom_ As discussed we plan to run the bond log after the rig moves away from CD3-113. We will make this available to you as soon as we can and will convert once we have your permission. Regards Chris From: Maunder, Thomas E {DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 15, 2008 1:41 PM To: Wilson, Chris Subject: FW: CD3-114 (207-033} Here is that request. Thanks. From: Maunder, Thomas E (DOA) Sent: Friday, February 15, 2008 12:36 PM To: 'Walker, Jack A' Subject: CD3-114 (207-033) Jack, I have the sundry for conversion of this well to an injector. Has the bond log been run yet? Please let me know the schedule. Generally, the bond log is available prior to granting the conversion. Call or message with any questions. Tom Maunder, PE AOGCC 2/15/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^~ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhilllps Alaska, InC. Development ~ Exploratory ^ 207-033 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20544-00 7. KB Elevation (ft): 9. Well Name and Number: RKB = 36' CD3-114 8. Property Designation: 10. Field/Pool(s): ADL 384215, 372105, 380092 Colville River Field/Fjord Oil Pool 11. Present Well Condition Summary: Total Depth measured 18042' feet true vertical 6884' 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 2842' 9-5/8" 2892' PRODUCTION 10577' 7" 10627' OPEN HOLE 7415' 5-1/2" 18042' Perforation depth: Measured depth: openhole Completion true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9678' MD. Packers &SSSV (type & measured depth) Baker Premier Packer set at 9618' Camco BAL-O Nipple SSSV set at 2132' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation 3430 2100 0 1434 260 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^O Service ^ Daily Report of Well Operations _ 16. Well Status after proposed work: Oil Gas ^ WAG ^ 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: 307-128 Contact Jack Walker Printed Name Jack Walker Title Production Engineer Signature ~~ Phone 265-6268 Date Z/(~-/C~ ~J v Form 10-404 Revised 04/2004 Submit Original Only ~'EL.I. ~.®G'TR.-~VS~IITT'A~. To: State of Alaska June 4, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-114 AK-MW-4959675 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 CD Rom with verification listing. API#: 5 0-103-20544-00 ~~°~. -033 ~ i st ~ f ~~~ ConocoPhillips May 8, 2007 G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 R~~~~ W ~~ MAY 0 9.2007 Commissioner State of Alaska Alaska Oil & Gas Gans. Cornmissian Alaska Oil & Gas Conservation Commission knchorage 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD3-114 (APD 207-033 / 307-128) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD3-114. 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 t'~G~~"` STATE OF ALASKA MAY 0 9 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ 011 ~ deg Cons. ComrnissioD WELL COMPLETION OR RECOMPLETION REPO ANDAhc6~E 1a. Well Status: Oil O Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, tnc. 5. Date Comp., Susp., orAband.: April 7, 2007 12. Permit to Drill Number: 207-033/ 307-128 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 18, 2007 • 13. API Number: 50-103-20544-00 4a. Location of Well (Governmental Section): Surface: 3960' FNL, 933' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: April 5, 2007 ~ 14. Well Name and Number: CD3-114 Top of Productive Horizon: 1814' FSL, 2072' FWL, Sec. 6, T12N, R5E, UM 8. KB (ft above MSL): 50' AMSL ~ Ground (ft MSL): 13' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 2636' FSL, 949' FWL, Sec. 36, T13N, R4E, UM 9. Plug Back Depth (MD + TVD): 18042' MD / 6884' TVD Fiord Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388110 y- 6003816 Zone- 4 10. Total Depth (MD + TVD): .18042' MD / 6884' TVD 16. Property Designation: ADL 372105, 380092, 384215 TPI: x- 381077 y- 6004419 Zone- 4 Total Depth: x- 376887 ' - 6010588 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 2132' 17. Land Use Permit: 380077 18. Directional Survey: Yes ^~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1250' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" pre-installed 9-5/8" 40# L-80 37' 2892' 37' 2485' 12.25" 437 sx ASLite, 247 sx Class G 7" 26# L-80 37' 10627' 37' 6927' 8.75" 255 sx CI G, 184 sx CI G 23. Open to production or injection? Yes Q No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 9678' 9618' open hole completion from 10627'-18042' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production April 27, 2007 Method of Operation (Flowing, gas lift, etc.) pre-produced injector Date of Test 4/'30/07 Hours Tested 6 hrs Production for Test Period --> OIL-BBL 1212 GAS-MCF 803 WATER-BBL . 0 CHOKE SIZE 95% GAS-OIL RATIO 813 Flow Tubing press. 300 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 4446 • GAS-MCF 3616 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewali Cores Acquired? Yes No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. r NONE ~.~..~~ `' E Y ,~"'~`- O~1 -~p- ~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~ $'.29+Q'7 fl R I G t NA L ~~,,; ~ ~~~ ~ ~ ~~o~ ~~s~~ 7G r~ 28. GEOLOGIC MARKERS (List all formations and mar ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1254' 1250' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 10092' 6814' Nechelik 10575' 6920' N/A CD3-302PB3 TD 9363' 6802' Formation at total depth: Nechelik ,. 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Mechanical Integrity Test 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz Galiunas @ 265-6247 Printed Name /) C ~ Ivord Title: WNS Drilling Team Lead / ~` ~ ` ~' a0 7 1~ Signature ~H-. Phone Z(~S_. (~ ~ LO Date s INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • Conocc~Phliips Time Log Summary WefN7ew V/eb 12eDOrfirrg Well Name: CD3-114 Job Type: DRILLING ORIGINAL -- - - - -- - Time Lois _- _ - __ _ ___ ~ - - - ._ ' Date From To Dur S. Depth E Depth Phase Code Subcode T CONi - --- -- - 03/17/2007 02:30 12:30 10.00 0 0 MIRU MOVE MOB P Moved from CD3-302 to CD3-114 and ri ed u . 12:30 15:45 3.25 0 114 COND1 DRILL RURD P Nippled up riser and flowline. Set mousehole. 15:45 21:30 5.75 114 114 COND1 DRILL PULD P Picked up and stood back 66 jts 5" DP and 24 'ts 5" HWDP. 21:30 23:45 2.25 114 69 COND1 DRILL PULD P Picked up bit and BHA to 69'. Up loaded MWD and held Pre Spud mettin while u loadin . 23:45 00:00 0.25 69 69 COND1 DRILL CIRC P Filled hole and tested surface lines. 03/18/2007 00:00 00:30 0.50 69 69 COND1 DRILL PULD P Test mud lines to 3500 psi - MU 8" flex collars and 'ars 00:30 12:00 11.50 69 889 SURFA DRILL DDRL P Spud well @ 00:30 hrs Drill 12 1/4" hole from 114' to 889' MD 888' TVD ADT= 5.08 hrs ART - 4.22 Hrs AST - 0.86 Hrs WOB 10/20 K RPM 40/50 GPM 400-500 @ 1200 psi String Wt. PU 120K SO 120K RT 120K Torque on/off Btm 6000/3500 fUlbs Ran G ro surve s 12:00 00:00 12.00 889 2,026 SURFA DRILL DDRL P Drill 12 1/4" hole from 889' to 2,026' MD 1920' TVD ADT= 7.32 hrs ART - 3.24 Hrs AST - 4.08 Hrs WOB 10/20 K RPM 50 GPM 500-600 @ 1680 psi String Wt. PU 125 K SO 125 K RT 125 K Torque on/off Btm 6000/5500 ft/Ibs Ran a total of 9 G ro surve s 03/19/2007 00:00 12:00 12.00 2,026 2,836 SURFA DRILL DDRL P Drill 12 1/4" hole from 2,206' to 2836' MD 2450' TVD ADT= 8.98 hrs ART - 7.78 Hrs AST - 1.2 Hrs WOB 20/30 K RPM 50 GPM 600 @ 2040 psi String Wt. PU 138 K SO 133 K RT 1137 K Tor ue on/off Btm 8000/6000 ft/Ibs _ ~~_ ~ a~® ~' ~P,a~~ 'I of ~3 _~ Time Logs Date_ From To Dur S. D~th E Depth Phase Code Subcode__ - - T COM - -- 03/20/2007 11:15 13:15 2.00 2,892 0 SURFA CEME~ DISP P Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/nut plug as marker -Pumped 5 bbls CW 100 w/ Dowell -Tested lines to 2500 psi -Pumped 15 Bbls CW 100 - Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 347 bbls lead slurry (ASL) @ 10.7 ppg (" Observed nut plug marker @ shakers w/ 328 bbls lead pumped - pumped down surge can) Pumped 51.5 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ DoweN - Switched over to rig pumps & displaced cmt w/ 193 bbls 9.8 ppg water base mud -Displaced @ 7.0 bbls/min for first 185 bbls -slowed to 4 bbls/min for last 8 bbls -Bumped plug w/ 1100 psi (pre bump pressure 550 psi) Check float (held OK) CIP @ 1310 hrs. -Full circulation throughout job w/ 134 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until 70 Bbls dis laced. 13:15 14:00 0.75 0 0 SURFA CASIN( DHEQ P RU & Tested casing to 2500 psi for 30 Min. 14:00 15:00 1.00 SURFA CASIN( RURD P RD Cement & CSG Equipment, LD Bales, landing jt. Clear Floor. PU GeoS an unit. 15:00 17:15 2.25 SURFA CASIN NUND P ND Riser 17:15 18:15 1.00 SURFA CASIN NUND P Install Wellhead. 18:15 20:30 2.25 SURFA CASINC NUND P NU BOPE 20:30 00:00 3.50 SURFA WELCT BOPE P Fill stack -Begin testing BOPE - Tested Annular U 250/3000 psi. Tested top rams, valves #1-16, HCR Kill, Choke, Dart, FOSV, Main IBOP, and Auto IBOP. 03/21/2007 00:00 02:45 2.75 0 0 SURFA WELCT BOPE P Finished testing BOP and floor valves 250/5000 psi. Tested closing unit. Pulled test lu . 02:45 03:15 0.50 0 0 SURFA DRILL PULD P Installed wear bushing. 03:15 03:45 0.50 0 0 SURFA DRILL RURD P Picked up bales and elevators. 03:45 06:45 3.00 0 250 SURFA DRILL PULD P Picked up Geopilot BHA and Shallow tested 250'. 06:45 08:15 1.50 250 2,628 SURFA DRILL TRIP P RIH With BHA from 250' to 2,628'. 08:15 09:00 0.75 2,628 2,723 SURFA DRILL REAM P Washed down from 2,628' to 2,723' breakin in bearin son Geo ilot.. 09:00 10:30 1.50 2,723 2,723 SURFA RIGMN SVRG P Slipped and cut drilling line. Serviced To Drive. #e 3 cf 1~ ~°~ ~ ti ._...~......~... ~~ Time Logs _ __ __ Date From To Dur S__De th E Depth Phase_ __Code _ Subcode T COM 03/21/2007 10:30 12:00 1.50 2,723 2,810 SURFA DRILL REAM P Wash & Ream to TOC/Plug @ 2810'. 12:00 15:00 3.00 2,810 2,922 SURFA DRILL DDRL P Drill FC, Shoe track, and shoe. PU Single and drill 20' new hole to 2922' MD. 15:00 15:30 0.50 2,922 2,922 SURFA DRILL CIRC P Circ & cond mud - LD Sgl -Blow down TD. 15:30 16:30 1.00 2,922 2,922 SURFA DRILL LOT P Perform FIT to EMW of 16.5 ppg. 16:30 00:00 7.50 2,922 3,694 INTRM1 DRILL DDRL P Swap over to LSND Mud. Drill 8-3/4" hole w/GP f/ 2922' t/ 3694' MD, 2966' TVD ADT = 4.69 ECD 10.88 WOB = 10/15 K, RPM 120, 600 GPM @ 1900 psi String WT: ROT - 135 K, SO - 127 K, PU-140K Tor ue On/Off Btm - 8000/7000 ft/Ibs 03/22/2007 00:00 12:00 12.00 3,694 4,726 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 3,694' U 4,726' MD, 3,624' TVD ADT = 6.96 ECD 10.88 WOB = 10/20 K, RPM 120, 600 GPM @ 2270 psi String WT: ROT - 146 K, SO - 139 K, PU - 151 K Tor ue On/Off Btm - 9000/7500 ft/Ibs 12:00 00:00 12.00 4,726 6,025 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 4,726' t! 6,025' MD, 4441' TVD ADT = 7.88 ECD 10.71 WOB = 10/20 K, RPM 120, 600 GPM @ 2790 psi String WT: ROT - 155 K, SO - 145 K, PU-170K Torque On/Off Btm - 10,500/8,500 ft/Ibs 03/23/2007 00:00 12:00 12.00 6,025 7,171 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 6025' t/ 7171' MD, 5155' TVD ADT = 8.63 ECD 10.73 WOB = 15/20 K, RPM 120, 600 GPM @ 3050 psi String WT: ROT - 171 K, SO - 147 K, PU - 203 K Torque On/Off Btm - 13,000!12,000 ft/Ibs 12:00 00:00 12.00 7,171 8,526 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 7171' U 8526' MD, 5999' ND ADT = 8.0 ECD 10.72 WOB = 18/22 K, RPM 150, 650 GPM @ 3370 psi String WT: ROT - 179 K, SO - 155 K, PU - 212 K Torque On/Off Btm - 13,000/1.1,500 tt/Ibs s e_ __ ~__ e .®_ _ e. e~ ~~ l~~y~ ~ of 1~t ?... ~__ Time Logs Date From To Dur S De th E De th Phase Code Subcode T COM 03/24/2007 00:00 12:00 12.00 8,526 9,671 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 8,526' t/ 9,671' MD, 6,651' TVD ADT = 8.7 ECD 10.8 WOB = 18/22 K, RPM 150, 650 GPM @ 3620 psi String WT: ROT - 188 K, SO - 170 K, PU - 207 K Torque On/Off Btm - 12,000/9,500 ft/Ibs 12:00 00:00 12.00 9,671 10,421 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 9,671' t/ 10,421' MD, 6895' TVD ADT = 8.7 ECD 10.61 WOB = 18/20 K, RPM 125, 625 GPM @ 3700 psi String WT: ROT - 189 K, SO - 160 K, PU-215K Torque On/Off Btm - 11,500/10,00 ft/Ibs 03/25/2007 00:00 02:45 2.75 10,421 10,639 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 10,421' t/ 10,639' MD, 6928' TVD ADT = 2.1 ECD 10.48 WOB = 15/20 K, RPM 125, 625 GPM @ 3490 psi String WT: ROT - 187 K, SO - 155 K, PU-218K Torque On/Off Btm - 12,000/10,000 ft/Ibs 02:45 06:15 3.50 10,639 10,624 INTRM1 DRILL CIRC P Circulate 3x BU - LD Single, Stand back 1 std/30 mins. 06:15 08:45 2.50 10,624 9,480 INTRM1 DRILL TRIP P Wiper Trip - POH with pump to 9480' 199 s m, 110 r m. Blow down TD. 08:45 09:30 0.75 9,480 10,639 INTRM1 DRILL REAM P RIH to 10,624' PU Sgl -Wash and ream to 10,639' MD. 09:30 11:15 1.75 10,639 10,639 INTRM1 DRILL CIRC P Circulate hole clean w/ 10 ppg mud @ 143 spm - 3450 psi - 140 rpm. Load i e with WSP and CRP. 11:15 12:00 0.75 10,639 10,479 INTRM1 DRILL TRIP P Flow check well -static - POH spotting pills to 10,479' - 3bpm - 400 si. 12:00 13:30 1.50 10,479 9,483 INTRM1 DRILL TRIP P Cont POOH w/pump from 10,479 to 9483' - 3 b m 350 si. 13:30 19:30 6.00 9,483 2,633 INTRM1 DRILL TRIP P Flow check -static -POOH on TT from 9483' - 2633'. Pump dry job @ 9003' 19:30 21:30 2.00 2,633 718 INTRM1 DRILL TRIP P Flow check -static - co to 5" equip - SB 5" to 718'. Flow check -static. 21:30 00:00 2.50 718 50 INTRM1 DRILL PULD P SB HWDP - LD Jars - SB NMFC - Plu in BHA for MWD Data 03/26/2007 00:00 01:00 1.00 50 0 INTRM1 DRILL PULD P Finished download MWD and lay down. Break Bit. Flow check static. Clear ri floor. 01:00 03:00 2.00 0 0 INTRM1 WELC7 BOPE P Pulled wear bushing. Changed rams to 7" and tested to 250 / 5000 si. 03:00 05:15 2.25 0 0 INTRM1 CASIN( RURD P Installed thin wear bushing and rigged u to run casin . 05:15 05:30 0.25 0 0 INTRM1 CASIN SFTY P PJSM for running casing. _. ~~® e ®~ I~a~z; a ~f 1~ ~ Time Logs I_Date From To Dur S De th E. Depth Phase Cod~_____Subcode T COM __ _ _ 03/26/2007 05:30 10:30 5.00 0 4,275 INTRM1 CASINC RNCS P Make up and RIH with 7" 26# L-80 BTCM Csg as follows: Ray Oil Tools Silver Bullett FS - 2 jts - Halliburton FC - 98 jts to 4,275'. Baker Loc 1st 4 jts. Baffle Plate installed in the top of Jt #3. 10:30 11:15 0.75 4,275 4,275 INTRM1 CASIN CIRC P Broke circulation with 2 BPM and worked u to 5 BPM. FCP 440 si. 11:15 16:00 4.75 4,275 8,554 INTRM1 CASINC RNCS P Continue RIH with 7" 26# L-80 BTCM Csg to 8,554' as follows: 11 jts - Weatherford Stage Collar BTCM - 89 'ts. 16:00 17:00 1.00 8,554 8,554 INTRM1 CASINC CIRC P Establish Circulation @ 1.5 bpm @ 430 psi. Stage up to 7 bpm. FCP 630 si. 17:00 19:30 2.50 8,554 10,627 INTRM1 CASINC RNCS P Cont RIH with 7" 26# L-80 BTCM Csg to 10,627' MD. Landed Shoe @ 10,627' MD, Stage Collar @ 5875' MD. Total of 248 ~ts run, 51 centralizers. 19:30 20:00 0.50 10,627 10,627 INTRM1 CASIN RURD P Lay Dwn Franks Tool, Blow Down TD, MU Cement Head. 20:00 23:00 3.00 10,627 10,627 INTRM1 CASINC CIRC P Establish Circulation 1.5 bpm @ 430 si, Sta e u to 7 b m. FCP 630 si. 23:00 00:00 1.00 10,627 10,627 INTRM1 CEME~ CIRC P PJSM -Begin cementing 1st stage. 03/27/2007 00:00 01:00 1.00 10,627 10,627 INTRM1 CEME~ DISP P Cemented 7" csg as follows: Pumped 10 bbls CW100 -Tested lines to 4000 psi -Pumped 40 bbls CW100 @4 bpm, 400 psi -Mixed & Pumped 40 bbls Mudpush @ 3 bpm, 300 psi -Mix & Pump 51 bbls of 15.8 ppg Tail Slurry (255 sacks) @ 5 bpm, 450 psi. Drop Shut off plug with 20 bbls Water f/ Dowell: Switched to rig pumps & displaced cmt w/ 9.8 ppg mud @ 7 bpm for 375 bbls, 380 - 700 psi. Dropped rate to 3 bpm for 7 bbls - Bumped plug with 850psi (500 psi over 350 pump pressure). 382 bbls total dis lacement. Checked floats - OK. 01:00 01:30 0.50 10,627 10,627 INTRM1 CEME~ CIRC P Pressure up on 7" Csg to 2900 psi to shift stage collar open - ICP 4.5 bpm - Establish circ @ 7 bpm, 300 psi. Circ BU. ~- ~ m. ~ ~. ~.e~ F<,~~ ~~ of 1'1 ~ ~~ lime Legs __ __ _ _ I Date From To Dur 5 De th E. De th Phase Code Subcode T COM 03/27!2007 01:30 02:30 1.00 10,627 10,627 INTRM1 CEME DISP P Cement 2nd stage 7" at Qannik as follows: Pumped 10 bbls CW100 @ 4 bpm, 150p psi. Mixed & pumped 20 bbls mud push 10.5 ppg @ 4 bpm, 150 psi. Mix & pump 38 bbls of 15.8 ppg Class Gcement - 184 sacks - @ 4.5 bpm, 45 psi. Drop closing plug with 10 bbls of water f/ Dowell -Switch to rig pumps & displace w/ 9.8 ppg mud @ 7 bpm pumping 190 - 400 psi. Bump plug @ 213 bbls, pressure increased to 1200# to shear top pins - bumped to 2500# and held. Opened surface valve to confirm sleeve closed. Continued to pressure up, broke over @ 2900psi to 2200 psi and held. Sus ect com osite lu btm broke. 02:30 04:15 1.75 0 0 INTRM1 CEME RURD P Blow dwn & RD cmt equip - LD tools - Pull Landin ~t. 04:15 04:30 0.25 0 0 INTRM1 CEME OTHR P Pull wear ring -Drain Stack 04:30 05:30 1.00 0 0 INTRM1 DRILL OTHR P RIH w/ 7" packoff -Run in LDS's to 450 ftlbs -tested void t/ 5000 psi for 15 min -Good test -Bleed off ressure 05:30 07:15 1.75 0 0 INTRM1 WELCT BOPE P CO 7" Rams to 3-1 /2" x 6" Variable - test 250/5000 si with 4-1/2" test 't. 07:15 07:45 0.50 0 0 INTRM1 CEME OTHR P Set Wear Ring - PU 4" Bales & DP Elevators. 07:45 08:45 1.00 0 0 INTRM1 CEME PULD P MU BHA for Clean out run. 08:45 12:00 3.25 0 2,673 INTRM1 CEME TRIP P RIH PU DP singles to 2673' 12:00 14:30 2.50 2,673 5,805 INTRM1 CEME TRIP P Cont PU 4" DP from shed f/ 2673' - 5805'. Ta cement 5805'. 14:30 16:30 2.00 5,805 6,034 INTRMI CEME DRLG P Wash dwn f/ 5805' U 5876' -Tag stg collar -drill collar & cmt U 5960' - PU 2 ~ts U6034'. 16:30 17:00 0.50 6,034 6,034 INTRM1 CEME CIRC P Circ BU @ 307 GPM, 1100 psi. 17:00 21:00 4.00 6,034 10,298 INTRM1 CEME CIRC P Cont RIH w/ 4" DP from shed f/ 6034' t/ 10,298' 21:00 23:00 2.00 10,298 10,298 INTRM1 RIGMN OTHR P Cut & Slip 120' line -Service TD & Rig 23:00 00:00 1.00 10,298 10,460 INTRM1 CEME TRIP P Wash dwn f/ 10,298' t/ 10,460' @ 300 m, 100 r m, 1740 si. 03/28/2007 00:00 01:15 1.25 10,460 10,580 INTRM1 CEME DRLG P Clean out shoe track - Drill wiper plug, insert baffle & cmt to top of FC 10.537'. Drill FC & cmt to 10, 580'. 01:15 02:30 1.25 10,580 10,580 INTRMI CEME CIRC P Circ hole clean for csg pressure test 8.3 BPM 2190 si w/ 100 m's 02:30 03:30 1.00 10,580 10,580 INTRM1 DRILL OTHR P RU to pressure test 7" csg - Pressured up to 1750 psi -pressure bleed down to 850 psi -Checked surface equpiment OK - RD & blow down TD ~~ - -._. ~ -~ ~ e- ~~` ~~~~ y r~~ 1'€ J Time Low - - ._ _ - - Date _ From To Dur S Depth E_ Depth Phase Code Subcode T COM 03/28/2007 03:30 09:00 5.50 10,580 0 INTRM1 DRILL TRIP T Flow ckeck well (static} -POOH on TT -Std back HWDP & NM flex DC's - break off bit 09:00 10:45 1.75 0 0 INTRM1 DRILL OTHR P Pull wear bushing -Install stack washer wear bushing - MU stack washer tool & flush BOP stack - LD stack washer -Pull SW wear bushing - Install drillin wear bushin 10:45 12:00 1.25 0 956 INTRM1 DRILL TRIP T MU Baker packer & RIH to 956' on 4" DP. 12:00 13:30 1.50 956 2,540 INTRM1 DRILL TRIP T Continue to RIH w/ packer f/ 956' to 2540' - strip took 15Kwt. 13:30 15:30 2.00 2,540 0 INTRM1 DRILL TRIP T POOH on TT w/ packer f/2540' - LD pkr -small piece lodged in side of packer -suspect causes drag while POOH. 15:30 18:00 2.50 0 0 INTRM1 RIGMN WOEO T Service Rig 18:00 20:00 2.00 0 300 INTRM1 DRILL PULD T PU and MU Baker Csg scraper, boot baskets, and string mi{I for 2nd cleanout run. 20:00 00:00 4.00 300 5,254 INTRM1 DRILL TRIP T RIH w/4" DP f/ 300' t/ 5254'. 03/29/2007 00:00 03:15 3.25 5,254 10,022 INTRM1 DRILL TRIP T Continue to RIH w/bit & scraper f/ 5254' to 10,022' 03:15 05:15 2.00 10,022 10,022 INTRM1 RIGMN RGRP T Repaired foot throttle for draw works 05:15 05:45 0.50 10,022 10,539 INTRM1 DRILL TRIP T Finish running in w/ bit & scraper f! 10,022' to 10,539' 05:45 06:45 1.00 10,539 10,539 INTRM1 DRILL CIRC T Circ btms up - 8 BPM @ 2060 psi - PU wt. 145 SO wt. 135 -Blow down TD -well static 06:45 08:45 2.00 10,539 9,059 INTRM1 DRILL TRIP T POOH on TT w/ bit & scraper f/ 10,539' to 9059' -hole not taking ro er fill 08:45 09:15 0.50 9,059 9,059 INTRMI DRILL OTHR T Monitor well -static 09:15 17:00 7.75 9,059 300 INTRM1 DRILL TRIP T Continue POOH on TT w/ bit & scra er f/ 9059' to 300'. 17:00 18:00 1.00 300 0 INTRM1 DRILL PULD T Flow Check -Static - SB HWDP - LD & clean out tools. Pieces of rubber & Aluminum found in baskets. 18:00 22:00 4.00 0 6,017 INTRM1 DRILL TRIP T MU BKR Test packer & RIH t/6017' M D. 22:00 23:00 1.00 6,017 6,017 INTRM1 DRILL DHEQ P Set PKR @ 6017' MD & Test CSG from below stg collar to 3500 psi for 15 mins - Verif St Collar closed. 23:00 00:00 1.00 6,017 6,684 INTRM1 DRILL TRIP T Release PKR & continue RIH f/ 6017' - 6684' M D 03/30/2007 00:00 03:30 3.50 6,684 10,530 INTRM1 DRILL TRIP T Continue RIH w! packer f/ 6684' to 10,499' - PU 1 single of DP & run acker to 10,530' - PU 255 SO 140 03:30 04:30 1.00 10,530 10,530 INTRM1 DRILL OTHR T Set packer @ 10,530' -Test 7" casing to 3500 psi for 30 mins -Bleed off ressure -Unseat acker _~ ~ i. ~ w~ s ~~aa~~* ~ ~~ 1~ Time Lois I Date From To__ _ Dur S. Depth E. De th Phase Code Subcode T COM 03/30/2007 04:30 08:00 3.50 10,530 8,036 INTRM1 DRILL TRIP T LD single of DP -Flow ck. Static - POOH on TT to 8036' 08:00 08:15 0.25 8,036 8,036 INTRM1 DRILL OTHR T Monitor well -Static -Install stripping rubber & air sli s 08:15 14:30 6.25 8,036 0 INTRM1 DRILL TRIP T Continue to POOH w/ packer f/ 8036' - LD acker 14:30 15:00 0.50 0 0 INTRM1 WELCT BOPE P Pull wear bushing & set test plug 15:00 21:00 6.00 0 0 INTRM1 WELCT BOPE P Rig up to test BOPE: Tested Annular to 250/3000 psi. Tested upper rams, Valves #1-16, HCR Kill, Man Choke, Dart, FOSV, Man. and auto IBOP, lower rams, & IW to 250/5000 psi. Cummi test. Blow Dwn. 21:00 21:30 0.50 0 0 INTRM1 DRILL OTHR P Install Wear Ring 21:30 00:00 2.50 0 91 INTRM1 DRILL PULD P MU BHA to 91' - GP, Non Mag FC, MWD Tools - Plu in for tool u load. 03/31/2007 00:00 01:30 1.50 91 380 INTRM1 DRILL TRIP P Continue MU BHA & RIH f/ 91' to 380' - Pressure test Geo Span & lines - Shallow test tools - 220 gpm @ 700 si 01:30 07:00 5.50 380 10,483 INTRMI DRILL TRIP P RIH w/ 6 1/8"drilling assembly f/ 380' to 10,483' - fillin i e eve 20 stds 07:00 08:30 1.50 10,483 10,483 INTRM1 RIGMN' SVRG P PJSM -Cut & slip drill line 60' & service TD 08:30 09:00 0.50 10,483 10,580 INTRM1 DRILL TRIP P Establish circ & wash down f/ 10,483' to 10,580' - to of cmt in shoe track 09:00 10:30 1.50 10,580 10,659 INTRM1 CEME~ COCF P Drill cmt f/ 10,580-' to 10,625' -Drill float shoe f/ 10,625' to 10,627' -Clean out rat hole to 10,639' -Drill 20' new hole f/ 10,639' to 10,659' 10:30 11:30 1.00 10,659 10,659 INTRM1 DRILL CIRC P Circ hole clean for FIT @ 220 gpm @ 1400 psi w/ 90 rpm w/ 13,000 ft/Ibs for ue 11:30 12:00 0.50 10,659 10,659 INTRM1 DRILL FIT P RU for FIT -Attempt FIT to 12.5 ppg EMW -Leaked -off @ 865 psi - 11.9 EWM-RD 12:00 13:30 1.50 10,659 10,659 PROD1 DRILL CIRC P Change well over f/ 9.5 ppg LSND mud to 8.9 ppg FloPro @ 220 gpm @ 150 si w/ 90 r m -Monitor well Static 13:30 00:00 10.50 10,659 11,390 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ GP f/ 10,659' to 11,390 MD, 6961' TVD ADT - 7.57 hrs. ECD - 10.58 ppg WOB 9/11 k RPM 120 GPM 220 @ 1760 psi String wt. PU 192 SO 148 Rot 172 Tor ue on/off btm. - 9500/8000 fUlbs 04/01/2007 00:00 12:00 12.00 11,390 12,325 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ GP f/ 11,390' to 12,325' MD 6933' TVD ADT - 9.06 hrs. ECD - 10.57 ppg WOB 6/12 k RPM 120 GPM 220 @ 1850 psi String wt. PU 195 SO 147 Rot 172 Torque on/off btm. - 10,000/9,000 ft./Ibs _~. ~ d F~~n ~ of ~T f Time Lois _ ___ __ Date From _ _To_ Dur S. De th E. Depth Phase Co_d_e__ Sub~od_e T COM ___ 04!01/2007 12:00 00:00 12.00 12,325 13,242 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section f/ 12,325' to 13,242' MD 6930' TVD ADT - 9.36 hrs. ECD - 10.7 ppg WOB 9/12 k RPM 120 GPM 220 @ 1920 psi String wt. PU 200 SO 142 Rot 170 Torque on/off btm. -11,000/9,000 ft./Ibs 04/02/2007 00:00 12:00 12.00 13,242 13,915 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ GP f/ 13,242' to 13,915' MD 6914' TVD ADT - 9.79 hrs ECD - 11.02 ppg WOB 8/12 k RPM 120 GPM 220 @ 2110 psi String wt. PU 200 SO 135 Rot 170 Tor ue on/off btm. 11,000/9,500 ft./Ibs. 12:00 00:00 12.00 13,915 14,805 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ GP f/ 13,915' to 14,805' MD 6902' TVD ADT - 9.31 hrs ECD - 11.13 ppg WOB 8/12 k RPM 120 GPM 220 @ 2270 psi String wt. PU 207 SO 130 Rot 167 Torque on/off btm. 12,000/10,000 ft./Ibs 04/03/2007 00:00 12:00 12.00 14,805 15,502 PROD1 DRILL DDRL P Dril16 1/8" horizontal section w/ GP f/ 14,805' to 15,502' MD 6904' TVD ADT - 9.45 hrs ECD - 11.38 ppg WOB 8/12 k RPM 120 GPM 220 @ 2430 psi String wt. PU 205 SO 125 Rot 167 Torque on/off btm. 12,000/10,500 ft./Ibs 12:00 21:00 9.00 15,502 16,063 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ GP fl 15,502' to 16,063' MD 6892' TVD ADT 6.78 hrs ECD - 11.86 ppg WOB 10/12 k RPM 120 GPM 200 @ 2600 psi String wt. PU 208 SO 115 Rot 165 Torque on/off btm. - 13,000/11,000 ft/Ibs. " Note: PWD tool quit working f/ 15,740' to 15,910' -tool began working 15,910' - ECD's were 11.88 21:00 22:30 1.50 16,063 16,063 PROD1 DRILL WPRT T Due to high ECD's -Made wiper trip f/ 16,063' to 15,525' w! 200 gpm @ 2340 psi w/ 120 rpm's -Flow ck well static - RIH f/ 15,525' to 16,001' 22:30 00:00 1.50 16,063 16,063 PROD1 DRILL CIRC T Wash down f/ 16,001' to 16,063' - Circ btms up @ 200 gpm @ 2360 psi - ECD's 11.35 __ ~.~ ~m _ E~txc;~ ft7 ~_ ~1•~ Time Logs Date TFrom To Dur S. De th E. De th PhaSe Subcode T COM ' Code 04/04/2007 00:00 12:00 12.00 16,063 16,710 __ PROD1 _ DRILL DDRL P Drill 6 1/8" horizontal section w/ GP f/ 16,063' to 16,710' MD 6885' ND ADT 9.0 hrs ECD - 11.43 ppg WOB 10/12 k RPM 120 GPM 210 @ 2360 psi String wt. PU 205 SO 125 Rot 167 Torque onloff btm. - 12,500/11,000 ft/Ibs. 12:00 00:00 12.00 16,710 17,360 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ GP f/ 16,710' to 17,360' MD 6873' ND ADT -7.93 hrs ECD - 11.46 ppg WOB 6/12 k RPM 120 GPM 210 @ 2400 psi String wt. PU 212 SO 115 Rot 165 Torque on/off btm. - 12,500/11,500 ft/Ibs. Hole started taking fluid @ 15 to 20 bbls/hr. -Lost 241 bbls 8.9 FloPro 04/05/2007 00:00 12:00 12.00 17,360 17,920 PROD1 DRILL DDRL P Dril16 1/8" horizontal section w/ GP f/ 17,360' to 17,920' MD 6881' ND ADT - 7.77 hrs ECD - 11.59 ppg WOB 6/15 k RPM 120 GPM 220 @ 2430 psi String wt. PU 207 SO 117 Rot 167 Torque on/off btm. - 13,000/11,500 ft/Ibs. Hole taking fluid @ 20 to 25 bbls/hr. - Lost 267 bbls 8.9 FloPro this tour 12:00 13:15 1.25 17,920 18,042 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ GP f/ 17,920' to 18,042' MD 6884' ND ADT - 1.25 hrs ECD - 11.92 ppg WOB 10/14 k RPM 120 GPM 220 @ 2450 psi String wt. PU 207 SO 110 Rot 165 Torque on/off btm. - 12,500/11,000 ft/Ibs. 13:15 18:30 5.25 18,042 18,003 PROD1 DRILL CIRC P Circulate and condition mud - 220 gpm / 2410 psi / 120 rpm Set back one stand to 18,003' Ready pits for change over to 9.2 KCL/NACL brine 18:30 21:00 2.50 18,003 18,003 PROD1 DRILL CIRC P Change over to 9.2 ppg brine @ 220 m 1680 si w/ 80 r m's 21:00 00:00 3.00 18,003 14,859 PROD1 DRILL TRIP P Flow ck -fluid level dropping in annulus down 3' in 5 mins. -POOH on TT f! 18003' to 14,859' -hole taking 20-25 bblslhr - PU wt. 265 SO wt 110 04/06/2007 00:00 03:30 3.50 14,859 11,530 PROD1 DRILL TRIP P POOH from 14,859' to 11,530' -Hole takin 20 -25 b h 03:30 04:00 0.50 11,530 11,530 PROD1 DRILL CIRC P Pump and displace 35 bbls high vis LCM ill - 210 m / 1150 si 04:00 04:45 0.75 11,530 10,380 PROD1 DRILL TRIP P POOH from 11,530' to 10,380' s~a~c 1 ~ c~~t 1~ L J Time Logs ~I - - - - _ Date ____ _From To Dur S. Depth E Depth Phase Code Subcode T COM -- _ 04/07/2007 07:00 09:15 2.25 0 31 PROD1 RPCO - OTHR __, T _ Strip control lines through hanger - BO & LD hanger - MU new tubing hanger ww/Elastomer seals -strip control lines through hanger MU and test fittings to 5000 psi -land hanger in wellhead 09:15 11:30 2.25 31 0 PROD1 RPCOh OTHR T RILDS - LD LJa -Install TWC - MU LJb -attempt to test Elastomer tubing hanger seals to 5000 psi -slight bleed off observed - LD LJb -Change out TWC valve - MU LJb -Test hanger seals to 5000 si -GOOD! 11:30 12:00 0.50 0 0 PROD1 RPCOh OTHR P LD LJb -Clear tools from rig floor - LD mousehole 12:00 13:30 1.50 0 0 PROD1 RPCOh NUND P Remove flowline and bell nipple - ND BOP stack 13:30 15:00 1.50 0 0 PROD1 RPCOh NUND P Terminate SSSV control lines at wellhead -Install adapter flange and tree -test ada ter flan a to 5000 si. 15:00 15:30 0.50 0 0 PROD1 RPCOh DHEQ P MU FMC lubricator to tree -Test tree and lubricator to 5000 si 15:30 16:00 0.50 0 0 PROD1 RPCOti OTHR P Pull TWC and LD FMC lubricator 16:00 16:30 0.50 0 0 PROD1 RPCOh OTHR P RU hardlines and circulating manifold on ri floor 16:30 16:45 0.25 0 0 PROD1 RPCO SFTY P Prejob safety and Opts meeting with ri team 16:45 19:00 2.25 0 0 PROD1 RPCO FRZP P Pressure test lines to 2000 psi - Displace well w/ 156 bbls - 9.2 ppg inhibited brine followed by 191 bbs diesel (tbg vol + 60 bbls into annulus for freeze rotection 3 BPM 19:00 19:30 0.50 0 0 PROD1 RPCO OTHR P RU lubricator & drop packer setting rod/ball assembly -Retest lines to 5000 si 19:30 21:00 1.50 0 0 PROD1 RPCOI~ PACK P Pressure up on tbg to 4700 psi to set packer & test tbg for 30 mins.- Bleed tbg down to 2500 psi -Pressure up on 4 1/2" X 7" annulus to 3500 psi & test for 30 mins. -Bleed annulus down to 0 psi -Bleed tbg down to 700 psi - Pressure up on 4 1/2" x 7" annulus to 2200 psi & shear out valve in lower GLM -Bleed tbg & annulus to 695 psi - Shut in well 21:00 21:30 0.50 0 0 PROD1 RPCOh RURD P Flush & blow down lines & manifold - RD- 21:30 22:45 1.25 0 0 PROD1 RPCOh OTHR P RU FMc lubricator & set BPV - RD lubricator & secure well 22:45 00:00 1.25 0 0 PROD1 RPCOR PULD P Install mouse hole - LD excess 4" DP f/derrick for rig move Lost 247 bbls 9.2 ppg brine to hole last 24 hrs. ®®~_~ ~ r~a~c: 'f r eit 1~ Time From To bur S. De th E. De th Pha_se Code Subcode___ T COM 00:00 12:00 12.00 0 0 PROD1 RPCOh OTHR P Lay down 4"drill pipe from derrick - 402joints total -Released rig to CD3-301 ~~c~~ 1~ ~af't~G Halliburton Company Survey Report ' Company: CenecoPhillips Alaska Inc. Date: 4/24/2007 Time: 09:26:58 - Pa;;c: 1 Field: Colville River Unit Co-ordinate(NE)Reference: Well: CD3-114, True North Site: Alpine CD3 ~ Ve rtical (TVD) Re ference: CD3-114: 50.1 Well: CD3-114 Section (VS)Reference: _ Well (O.OON,O.OOE,30'1.29Azi) ' Wellpath: CD3-114 Su rvey Cakulatim~ Method: 'Minimum Curvat~ue I)h: Oracle Field: Colville Ri ver 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 S}~stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD3-114 i Slot Name: Well Position: +N /-S -76.60 ft Northing: 6003815.84 ft Latitude: 70 25 9.727 N +E/-W -376.73 ft Easti ng : 388110.30 ft Longitude: 150 54 41.438 W Position Uncertainty: 0.00 ft ~ Wellpath: CD3-114 Drilled From: Well Ref. Point 501032054400 Tie-on Depth: 36.75 ft ~ Current Datum: CD3-114: Height 50.05 ft Above System Datum: Mean Sea Level Magnetic Data: 3/17/2007 Declination: 22.94 deg Field Strength: 57572 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 36.75 0.00 0.00 301.29 Survey Program for Definitive Wellpath ii Date: 3/1 912 0 0 7 Validated: No V ersion: 14 j Actual From To Survey Toolcode Tool Name ft ft 79.00 804.00 CD3-114 gyro (79.00-804.00) C B-GYRO-SS Camera based gyro single shot '~ 880.09 18003.36 CD3-114 (880_09-18003.36) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ ____ I11D Incl Azim TVD tipsTVD N/S E/W MapN VapF fool ft deg deg ft ft ft ft ft h 36.75 0.00 0.00 36.75 -13.30 0.00 0.00 6003815.84 • 388110.30 'TIE LINE j 79.00 0.08 304.65 79.00 28.95 0.02 -0.02 6003815.86 388110.28 CB-GYRO-SS 170.00 0.17 337.51 170.00 119.95 0.18 -0.13 6003816.02 388110.17 CB-GYRO-SS 261.00 0.18 338.82 261.00 210.95 0.44 -0.23 6003816.28 388110.08 CB-GYRO-SS 351.00 0.26 319.17 351.00 300.95 0.72 -0.42 6003816.57 388109.89 CB-GYRO-SS 442.00 0.41 340.84 442.00 391.95 1.19 -0.66 6003817.04 388109.66 CB-GYRO-SS 532.00 0.40 284.66 532.00 481.95 1.57 -1.07 6003817.43 388109.26 CB-GYRO-SS 623.00 0.69 242.38 622.99 572.94 1.40 -1.86 6003817.26 388108.46 CB-GYRO-SS i 715.00 1.75 250.86 714.97 664.92 0.68 -3.68 6003816.57 388106.63 CB-GYRO-SS 804.00 3.49 254.75 803.87 753.82 -0.48 -7.58 6003815.47 388102.72 CB-GYRO-SS 880.09 3.85 251.12 879.81 829.76 -1.92 -12.23 6003814.11 388098.05 MWD+IFR-AK-CAZ-SC 926.86 4.70 261.34 926.45 876.40 -2.71 -15.61 6003813.36 388094.65 MWD+IFR-AK-CAZ-SC 1023.09 6.78 265.97 1022.19 972.14 -3.71 -25.17 6003812.51 388085.08 MWD+IFR-AK-CAZ-SC 1118.46 7.66 263.74 1116.80 1066.75 -4.79 -37.11 6003811.60 388073.13 MWD+IFR-AK-CAZ-SC j 1214.05 10.79 262.49 1211.14 1161.09 -6.66 -52.31 6003809.97 388057.90 MWD+IFR-AK-CAZ-SC 1308.96 17.66 260.97 1303.09 1253.04 -10.08 -75.37 6003806.89 388034.80 MWD+IFR-AK-CAZ-SC 1403.51 22.29 264.30 1391.93 1341.88 -14.12 -107.39 6003803.33 388002.72 MWD+IFR-AK-CAZ-SC 1498.39 26.70 268.02 1478.26 1428.21 -16.64 -146.62 6003801.40 387963.46 MWD+IFR-AK-CAZ-SC 1593.98 29.39 270.85 1562.62 1512.57 -17.04 -191.55 6003801.68 387918.54 MWD+IFR-AK-CAZ-SC 1688.64 31.20 271.09 1644.35 1594.30 -16.23 -239.29 6003803.20 387870.81 MWD+IFR-AK-CAZ-SC 1783.24 33.45 269.24 1724.28 1674.23 -16.11 -289.87 6003804.08 387820.25 MWD+IFR-AK-CAZ-SC 1878.97 35.42 269.17 1803.23 1753.18 -16.86 -343.99 6003804.14 387766.12 MWD+IFR-AK-CAZ-SC 1974.05 37.52 268.73 1879.69 1829.64 -17.90 -400.49 6003803.95 387709.62 MWD+IFR-AK-CAZ-SC 2069.16 40.94 267.43 1953.35 1903.30 -19.94 -460.60 6003802.81 387649.49 MWD+IFR-AK-CAZ-SC 2164.29 44.31 266.33 2023.34 1973.29 -23.46 -524.91 6003800.25 387585.14 MWD+IFR-AK-CAZ-SC 2259.18 47.70 266.36 2089.24 2039.19 -27.81 -593.03 6003796.92 387516.97 MWD+IFR-AK-CAZ-SC 2354.64 50.85 266.94 2151.52 2101.47 -32.03 -665.24 6003793.78 387444.71 MWD+IFR-AK-CAZ-SC 2450.25 51.69 267.17 2211.33 2161.28 -35.86 -739.72 6003791.07 387370.18 MWD+IFR-AK-CAZ-SC 2545.12 51.71 266.60 2270.13 2220.08 -39.91 -814.07 6003788.14 387295.80 MWD+IFR-AK-CAZ-SC r: Halliburton Company Survey Report Compan~~ : ConocoPhillips Alaska Inc. Date: 4/24!2007 Tim c: 09:26.58 Page: Z Field: Colville Rive r Unit Co-ordinaCe (NE) Reference: Well: CD3- 114, True North Site: Alpi ne CD3 Vertical ("CV ll) Keference: CD3-114. 5G.1 Well: CD3 -114 Section (V$) Reference: Well (O.OON .O.OOE,301.29Azi) ~Vell~,arh: __ CD3 -11 4 Survey Cale ulation !Method: Minimum C urva ture I)h: Oracfe __ Gn~ce~ 11U Inc ! Azim TV1) SysTw V{S E/W MapN 11aF~E fool ft deg deg ft ft ft ft ft ft 2640 .32 52 .57 266. 79 2328. 56 2278 .51 -44. 24 -889. 10 6003784. 93 387220. 71 MWD+IFR-AK-CAZ-SC 2735 .47 51 .20 268. 82 2387. 29 2337 .24 -47. 12 -963. 90 6003783. 17 387145. 89 MWD+IFR-AK-CAZ-SC 2830 .54 51. 70 268. 45 2446. 54 2396 .49 -48. 89 -1038. 23 6003782. 52 387071. 54 MWD+IFR-AK-CAZ-SC i 2848. 98 51 .65 268. 33 2457. 97 2407 .92 -49. 30 -1052. 69 6003782. 33 387057. 08 MWD+IFR-AK-CAZ-SC 2887. 27 51. 56 268. 25 2481. 76 2431 .71 -50. 19 -1082. 69 6003781. 88 387027. 08 MWD+IFR-AK-CAZ-SC ~ 2982 .35 52 .25 268. 06 2540. 42 2490 .37 -52. 60 -1157. 47 6003780. 59 386952. 27 MWD+IFR-AK-CAZ-SC ~ 3077. 25 54. 42 268. 85 2597. 08 2547 .03 -54. 65 -1233. 56 6003779. 69 386876. 16 MWD+fFR-AK-CAZ-SC ' 3172. 46 53 .26 269. 28 2653. 26 2603 .21 -55. 91 -1310. 42 6003779. 59 386799. 30 MWD+-FR-AK-CAZ-SC ~ 3267. 55 52 .92 268. 50 2710. 37 2660 .32 -57. 38 -1386. 44 6003779. 25 386723. 28 MWD+IFR-AK-CAZ-SC I 3362 .65 54 .73 270. 32 2766. 50 2716 .45 -58. 15 -1463. 19 6003779. 63 386646. 53 MWD+IFR-AK-CAZ-SC j 3457 .45 53 .39 270. 80 2822. 14 2772 .09 -57. 41 -1539. 94 6003781. 52 386569. 81 MWD+IFR-AK-CAZ-SC ~ 3552 .49 52 .94 270. 12 2879. 12 2829 .07 -56. 79 -1616. 00 6003783. 28 386493. 77 MWD+IFR-AK-CAZ-SC '. ~ 3647. 59 51 .47 267. 72 2937. 40 2887 .35 -58. 19 -1691. 13 6003783. 00 386418. 64 MWD+IFR-AK-CAZ-SC j ~ 3742. 55 50 .73 265. 50 2997. 04 2946 .99 -62. 56 -1764. 89 6003779. 75 386344. 82 MWD+IFR-AK-CAZ-SC j 3837 .72 51 .31 265. 53 3056. 91 3006 .86 -68. 34 -1838. 65 6003775. 07 386270. 99 MWD+IFR-AK-CAZ-SC 3932. 48 52 .47 268. 64 3115. 40 3065 .35 -72. 12 -1913. 09 6003772. 41 386196. 51 MWD+IFR-AK-CAZ-SC 4027. 59 51 .15 268. 34 3174. 20 3124 .15 -74. 08 -1987. 82 6003771. 56 386121. 77 MWD+IFR-AK-CAZ-SC 4123 .50 49 .88 267. 81 3235. 19 3185 .14 -76. 57 -2061. 80 6003770. 19 386047. 76 MWD+IFR-AK-CAZ-SC 4218 .64 49 .19 266. 51 3296. 93 3246 .88 -80. 15 -2134. 09 6003767. 69 385975. 43 MWD+IFR-AK-CAZ-SC 4313 .59 48 .98 266. 24 3359. 12 3309 .07 -84. 69 -2205. 70 6003764. 23 385903. 77 MWD+IFR-AK-CAZ-SC 4408 .54 48 .62 266. 89 3421. 66 3371 .61 -88. 97 -2277. 01 6003761. 02 385832. 41 MWD+IFR-AK-CAZ-SC 4503 .58 49 .51 266. 39 3483. 93 3433 .88 -93. 18 -2348. 68 6003757. 88 385760: 69 MWD+IFR-AK-CAZ-SC 4598 .91 50 .77 267. 22 3545. 03 3494 .98 -97. 25 -2421. 74 6003754. 90 385687. 58 MWD+IFR-AK-CAZ-SC 4694 .01 51 .75 267. 99 3604. 54 3554 .49 -100. 35 -2495. 85 6003752. 92 385613. 44 MWD+IFR-AK-CAZ-SC 4787 .18 51 .51 268. 32 3662. 37 3612 .32 -102. 70 -2568. 86 6003751. 66 385540. 41 MWD+IFR-AK-CAZ-SC 4884 .90 50 .50 267. 07 3723. 87 3673 .82 -105. 75 -2644. 75 6003749. 75 385464. 49 MWD+IFR-AK-CAZ-SC 4977 .65 50 .82 268. 40 3782. 66 3732 .61 -108. 58 -2716. 42 6003747. 99 385392. 79 MWD+IFR-AK-CAZ-SC 5074 .80 49 .71 268. 84 3844. 76 3794 .71 -110. 38 -2791. 10 6003747. 31 385318. 09 MWD+IFR-AK-CAZ-SC 5169 .90 51 .24 268. 01 3905. 29 3855 .24 -112. 40 -2864. 43 6003746 .39 385244. 75 MWD+IFR-AK-CAZ-SC 5261 .34 50 .70 268. 54 3962. 87 3912 .82 -114. 54 -2935. 43 6003745. 31 385173. 74 MWD+IFR-AK-CAZ-SC 5360 .07 51 .02 267. 89 4025. 19 3975 .14 -116. 93 -3011. 97 6003744 .07 385097 .18 MWD+IFR-AK-CAZ-SC I 5454 .93 51 .58 267. 67 4084. 50 4034 .45 -119. 80 -3085. 94 6003742 .32 385023 .17 MWD+IFR-AK-CAZ-SC ~ 5550 .70 51 .69 267. 76 4143. 94 4093 .89 -122. 79 -3160. 97 6003740. 45 384948. 11 MWD+IFR-AK-CAZ-SC 5645 .73 51 .79 267. 57 4202. 79 4152 .74 -125. 83 -3235. 53 6003738. 52 384873 .53 MWD+IFR-AK-CAZ-SC 5740 .64 51 .16 268. 43 4261. 90 4211 .85 -128. 43 -3309. 73 6003737 .04 384799 .30 MWD+IFR-AK-CAZ-SC ' 5835 .83 51 .40 266. 86 4321. 45 4271 .40 -131. 48 -3383. 93 6003735 .10 384725. 07 MWD+IFR-AK-CAZ-SC 5930 .80 50 .83 267. 47 4381. 07 4331 .02 -135. 14 -3457. 77 6003732 .55 384651 .19 MWD+IFR-AK-CAZ-SC 6025 .99 50 .38 268. 35 4441. 48 4391 .43 -137. 82 -3531. 28 6003730 .97 384577 .65 MWD+IFR-AK-CAZ-SC 6121 .28 51 .46 269. 44 4501. 55 4451 .50 -139. 24 -3605. 23 6003730 .66 384503 .69 MWD+IFR-AK-CAZ-SC 6216 .48 51 .63 270. 73 4560. 76 4510 .71 -139. 13 -3679. 78 6003731 .89 384429. 16 MWD+IFR-AK-CAZ-SC 6309 .25 51 .87 269. 85 4618. 19 4568 .14 -138. 76 -3752. 63 6003733 .35 384356 .33 MWD+IFR-AK-CAZ-SC i 6406 .53 51 .39 271. 44 4678. 58 4628 .53 -137. 91 -3828. 89 6003735 .34 384280 .10 MWD+IFR-AK-CAZ-SC ~ 6501 .62 51 .24 271. 16 4738. 01 4687 .96 -136. 22 -3903. 10 6003738 .14 384205 .93 MWD+IFR-AK-CAZ-SC 6596 .63 51 .24 272. 06 4797. 50 4747 .45 -134. 14 -3977. 16 6003741 .33 384131 .92 MWD+IFR-AK-CAZ-SC 6692 .16 51 .49 270. 76 4857. 14 4807 .09 -132. 31 -4051. 75 6003744 .28 384057 .37 MWD+IFR-AK-CAZ-SC 6787 .47 51 .71 269. 84 4916. 35 4866 .30 -131. 92 -4126. 44 6003745 .79 383982 .70 MWD+IFR-AK-CAZ-SC ~ i , 6882 .37 51 .64 269. 10 4975. 20 4925 .15 -132. 61 -4200. 89 6003746 .22 383908 .26 MWD+IFR-AK-CAZ-SC 6977 .59 51 .80 266. 86 5034. 19 4984 .14 -135. 24 -4275. 58 6003744 .70 383833 .54 MWD+IFR-AK-CAZ-SC 7073 .00 51 .25 264. 84 5093. 55 5043 .50 -140. 64 -4350. 07 6003740 .42 383758 .98 MWD+IFR-AK-CAZ-SC 7167 .64 51 .46 265. 40 5152. 66 5102 .61 -146. 93 -4423. 72 6003735 .24 383685 .25 MWD+IFR-AK-CAZ-SC 7262 .65 51 .60 266. 38 5211. 76 5161 .71 -152. 26 -4497. 92 6003731 .02 383610 .99 MWD+IFR-AK-CAZ-SC 7357 .82 51 .43 266. 76 5270. 99 5220 .94 -156. 72 -4572. 28 6003727 .68 383536 .58 MWD+IFR-AK-CAZ-SC ~ i Halliburton Company Survey Report ' Compam: ConocoPhillips Alaska Inc. __ Date: 4124120Q7 Tin,c 09:26:58 __ Ya~c: 3 Field: Colville Rive r Unit Co-o rdinate (NE) Referencr. Well: CD3-1 14, True North ', Site: Alpine CD3 Verti cal (TV D) Reference CD3-114. 5 0.1 ', Nell: CD3-11 4 Section (VS) Reference: Well (QOON .QOOF_,301.29Azi) ,' Wclipath: CD3-11 4 Survey Cak ulationMethod: MiniinumC urvature Dbi-t~racle j Survev ;ViD [nc l Azim TVD Sc~ 1l'D V!S E/~V ~1ap,V ti1apF. Tent ft deg de g ft ft ft ft ft ft 7452. 92 51. 00 266 .72 5330. 56 5280 .51 -160. 93 -4646. 29 6003724. 57 383462. 52 MWD+IFR-AK-CAZ-SC 7548. 46 51. 73 266 .56 5390. 21 5340 .16 -165. 31 -4720. 79 6003721. 32 383387. 97 MWD+IFR-AK-CAZ-SC 7643. 66 51. 63 265 .85 5449. 24 5399 .19 -170. 25 -4795. 32 6003717. 49 383313. 38 MWD+IFR-AK-CAZ-SC 7739. 06 51. 84 266 .88 5508. 32 5458 .27 -175. 00 -4870. 07 6003713. 87 383238. 58 MWD+IFR-AK-CAZ-SC 7834. 23 52. 41 267 .26 5566. 75 5516 .70 -178. 84 -4945. 09 6003711. 15 383163. 51 MWD+IFR-AK-CAZ-SC 7929. 47 52. 16 267 .44 5625. 01 5574 .96 -182. 32 -5020. 35 6003708. 80 383088. 21 MWD+IFR-AK-CAZ-SC 8024. 45 51. 73 268 .24 5683. 56 5633 .51 -185. 14 -5095. 09 6003707. 10 383013. 45 MWD+IFR-AK-CAZ-SC 8119. 51 51. 01 268 .72 5742. 90 5692 .85 -187. 11 -5169. 32 6003706. 24 382939. 20 MWD+IFR-AK-CAZ-SC I~ 8214. 64 50. 93 268 .67 5802. 81 5752 .76 -188. 80 -5243. 20 6003705. 66 382865. 31 MWD+IFR-AK-CAZ-SC 8309. 60 50. 51 269 .17 5862. 93 5812 .88 -190. 18 -5316. 69 6003705. 38 382791. 81 MWD+IFR-AK-CAZ-SC 8404. 66 51. 02 268 .50 5923. 06 5873 .01 -191. 68 -5390. 30 6003704. 98 382718. 19 MWD+IFR-AK-CAZ-SC 8499. 64 51. 25 266 .34 5982. 66 5932 .61 -195. 01 -5464. 17 6003702. 76 382644. 29 MWD+IFR-AK-CAZ-SC I 8594. 78 51. 57 266 .89 6042. 00 5991 .95 -199. 40 -5538. 41 6003699. 48 382570. 00 MWD+IFR-AK-CAZ-SC 8689. 85 52. 37 267 .14 6100. 57 6050 .52 -203. 30 -5613. 19 6003696. 71 382495. 17 MWD+IFR-AK-CAZ-SC j 8785. 26 52. 26 267 .78 6158. 90 6108 .85 -206. 65 -5688. 62 6003694. 49 382419. 71 MWD+IFR-AK-CAZ-SC 8880. 69 52. 18 269 .44 6217. 36 6167 .31 -208. 48 -5764. 02 6003693. 79 382344. 30 MWD+IFR-AK-CAZ-SC 8976. 29 52. 76 273 .22 6275. 62 6225 .57 -206. 71 -5839. 79 6003696. 70 382268. 57 MWD+IFR-AK-CAZ-SC ~ 9071. 65 52. 90 275 .47 6333. 23 6283 .18 -200. 95 -5915. 55 6003703. 59 382192. 91 MWD+IFR-AK-CAZ-SC 9167. 27 54. 53 277 .71 6389. 83 6339 .78 -192. 09 -5992. 11 6003713. 59 382116. 50 MWD+IFR-AK-CAZ-SC 9261. 91 56. 23 281 .09 6443. 60 6393 .55 -179. 35 -6068. 92 6003727. 48 382039. 90 MWD+IFR-AK-CAZ-SC 9357. 22 57. 93 284 .55 6495. 41 6445 .36 -161. 58 -6146. 90 6003746. 42 381962. 19 MWD+IFR-AK-CAZ-SC 9453. 38 59. 58 288 .72 6545. 30 6495 .25 -138. 03 -6225. 64 6003771. 14 381883. 83 MWD+IFR-AK-CAZ-SC 9549. 42 60. 83 292 .67 6593. 04 6542 .99 -108. 57 -6303. 57 6003801. 77 381806. 35 MWD+IFR-AK-CAZ-SC 9644. 33 62. 52 296 .89 6638. 08 6588 .03 -73. 54 -6379. 39 6003837. 92 381731. 07 MWD+IFR-AK-CAZ-SC 9739. 52 64. 80 299 .96 6680. 32 6630 .27 -32. 92 -6454. 38 6003879. 66 381656. 70 MWD+IFR-AK-CAZ-SC 9835. 10 66. 70 303 .75 6719. 59 6669 .54 13. 07 -6528. 37 6003926. 75 381583. 42 MWD+IFR-AK-CAZ-SC 9930. 53 67. 42 306 .28 6756. 79 6706 .74 63. 50 -6600. 34 6003978. 25 381512. 22 MWD+IFR-AK-CAZ-SC 10026. 04 69. 10 308 .58 6792. 17 6742 .12 117. 42 -6670. 77 6004033. 22 381442. 61 MWD+IFR-AK-CAZ-SC 10121. 53 71. 85 310 .35 6824. 08 6774 .03 174. 63 -6740. 23 6004091. 45 381374. 02 MWD+IFR-AK-CAZ-SC 10216. 47 74. 99 313 .49 6851. 18 6801 .13 235. 42 -6807. 91 6004153. 24 381307. 27 MWD+IFR-AK-CAZ-SC 10311. 88 77. 36 315 .93 6873. 98 6823 .93 300. 59 -6873. 73 6004219. 39 381242. 44 MWD+IFR-AK-CAZ-SC 10407. 20 78. 79 319 .10 6893. 68 6843 .63 369. 36 -6936. 71 6004289. 09 381180. 50 MWD+IFR-AK-CAZ-SC 10502. 79 80. 99 320 .21 6910. 46 6860 .41 441. 08 -6997. 62 6004361. 71 381120. 68 MWD+IFR-AK-CAZ-SC 10598. 02 83. 05 323 .30 6923. 68 6873 .63 515. 14 -7055. 98 6004436. 63 381063. 43 MWD+IFR-AK-CAZ-SC 10611. 84 83. 17 323 .62 6925. 34 6875 .29 526. 16 -7064. 15 6004447. 77 381055. 43 MWD+IFR-AK-CAZ-SC 10669. 06 84. 01 326 .53 6931. 73 6881 .68 572. 78 -7096. 70 6004494. 87 381023. 59 MWD+IFR-AK-CAZ-SC 10731. 72 83. 01 326 .65 6938. 81 6888 .76 624. 75 -7130. 98 6004547. 34 380990. 09 MWD+IFR-AK-CAZ-SC 10826. 51 83. 45 325 .51 6949. 99 6899 .94 702. 86 -7183. 51 6004626. 22 380938. 75 MWD+IFR-AK-CAZ-SC 10922. 14 85. 25 324 .57 6959. 40 6909 .35 780. 85 -7238. 04 6004705. 01 380885. 40 MWD+IFR-AK-CAZ-SC ~ 11016. 84 89. 33 325 .36 6963. 88 6913 .83 858. 28 -7292. 33 6004783. 25 380832. 28 MWD+IFR-AK-CAZ-SC 11108. 47 89. 08 327 .85 6965. 15 6915 .10 934. 77 -7342. 75 6004860. 47 380783. 01 MWD+IFR-AK-CAZ-SC 11206. 92 90. 32 326 .85 6965. 66 6915 .61 1017. 66 -7395. 87 6004944. 14 380731. 15 MWD+IFR-AK-CAZ-SC 11302. 04 91. 55 324 .64 6964. 11 6914 .06 1096. 26 -7449. 40 6005023. 53 380678. 81 MWD+IFR-AK-CAZ-SC 11397. 35 93. 28 325 .19 6960. 10 6910 .05 1174. 18 -7504. 13 6005102. 26 380625. 26 MWD+IFR-AK-CAZ-SC 11492. 49 93. 21 325 .33 6954. 71 6904 .66 1252. 24 -7558. 26 6005181. 11 380572. 31 MWD+IFR-AK-CAZ-SC I 11588. 05 93. 59 326 .07 6949. 04 6898 .99 1331. 04 -7612. 01 6005260. 70 380519. 74 MWD+IFR-AK-CAZ-SC j 11683. 42 93. 71 325 .22 6942. 97 6892 .92 1409. 61 -7665. 72 6005340. 06 380467. 22 MWD+IFR-AK-CAZ-SC 11778. 26 92. 97 325 .26 6937. 45 6887 .40 1487. 40 -7719. 70 6005418. 64 380414. 42 MWD+IFR-AK-CAZ-SC I 11873. 92 92. 97 323 .68 6932. 49 6882 .44 1565. 14 -7775. 22 6005497. 20 380360. 08 MWD+IFR-AK-CAZ-SC ~ 11969. 35 89. 76 321 .67 6930. 22 6880 .17 1640. 99 -7833. 05 6005573. 90 380303. 39 MWD+IFR-AK-CAZ-SC 12064. 59 89. 21 321 .48 6931. 07 6881 .02 1715. 60 -7892. 24 6005649. 38 380245. 34 MWD+IFR-AK-CAZ-SC 12160. 04 89. 95 325 .29 6931. 77 6881 .72 1792. 20 -7949. 16 6005726. 82 380189. 58 MWD+IFR-AK-CAZ-SC 12254. 82 89. 45 325 .95 6932. 27 6882 .22 1870. 42 -8002. 68 6005805. 83 380137. 24 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ___ _- Company ConoCOPhiilips P.laska Inc. 1?atei 4/24.'2007 Timr: 09:26:58 Pagc: 4 Field: C~Iville River Unit Co-ordinate(~H:J FtcScrence: 1~leIC CD3-114_ True North Site: Alpine CD3 Vertical (TVU~ Rc(erenee: CD3-114 5C.1 ~~ell: CD3-114 Section (VS) Reference: Well (O.OON O.OOE,301.29Azi) ~~clipaffi: C~3=114 Survey Calculation Method: -MinimumGuivaiure Db: Oracle JUt'l'C~' X111 Jncl Azim TVD Sy, "I~ D i~(S E/~V Map~i '~~SapE Tool ft deg deg ft ft ft ft ft ft r- _ _ _ - _ _- __ 12349.98 89.70 324.71 6932.97 6882.92 1948.68 -8056.81 6005884.88 380084.30 MWD+IFR-AK-CAZ-SC 12444.28 90.32 322.99 6932.96 6882.91 2024.82 -8112.43 6005961.84 380029.82 MWD+IFR-AK-CAZ-SC 12539.76 89.76 323.63 6932.89 6882.84 2101.38 -8169.48 6006039.25 379973.93 MWD+IFR-AK-CAZ-SC ~ 12634.80 90.44 325.85 6932.73 6882.68 2178.98 -8224.34 6006117.65 379920.25 MWD+IFR-AK-CAZ-SC 12729.66 90.56 326.56 6931.90 6881.85 2257.81 -8277.10 6006197.25 379868.68 MWD+IFR-AK-CAZ-SC 12825.33 91.18 327.70 6930.44 6880.39 2338.15 -8329.02 6006278.36 379817.98 MWD+IFR-AK-CAZ-SC i 12921.03 90.38 326.85 6929.14 6879.09 2418.65 -8380.75 6006359.62 379767.46 MWD+IFR-AK-CAZ-SC ~ 13015.91 91.49 327.73 6927.59 6877.54 2498.47 -8432.01 6006440.19 379717.40 MWD+IFR-AK-CAZ-SC 13110.81 89.76 328.71 6926.56 6876.51 2579.14 -8481.99 6006521.59 379668.65 MWD+IFR-AK-CAZ-SC 13205.64 92.61 331.18 6924.60 6874.55 2661.18 -8529.46 6006604.33 379622.41 MWD+IFR-AK-CAZ-SC 13300.97 92.48 331.17 6920.36 6870.31 2744.62 -8575.38 6006688.44 379577.75 MWD+IFR-AK-CAZ-SC 13395.89 92.27 323.81 6916.43 6866.38 2824.54 -8626.32 6006769.11 379528.03 MWD+IFR-AK-CAZ-SC .13490.46 90.32 322.60 6914.29 6864.24 2900.25 -8682.94 6006845.65 379472.55 MWD+IFR-AK-CAZ-SC ~I 13584.92 88.77 320.71 6915.04 6864.99 2974.32 -8741.54 6006920.59 379415.07 MWD+IFR-AK-CAZ-SC 13681.27 89.95 322.48 6916.11 6866.06 3049.82 -8801.38 6006996.96 379356.37 MWD+IFR-AK-CAZ-SC j 13776.44 90.44 322.34 6915.79 6865.74 3125.23 -8859.44 6007073.23 379299.46 MWD+IFR-AK-CAZ-SC '; 13871.45 90.44 322.42 6915.06 6865.01 3200.48 -8917.43 6007149.34 379242.60 MWD+IFR-AK-CAZ-SC ' 13966.50 90.32 324.14 6914.43 6864.38 3276.67 -8974.26 6007226.36 379186.93 MWD+IFR-AK-CAZ-SC 14061.68 90.50 324.51 6913.75 6863.70 3353.98 -9029.77 6007304.49 379132.59 MWD+IFR-AK-CAZ-SC ~ 14157.10 91.49 326.52 6912.09 6862.04 3432.62 -9083.78 6007383.92 379079.77 MWD+IFR-AK-CAZ-SC 14252.40 90.87 327.37 6910.13 6860.08 3512.48 -9135.75 6007464.54 379029.00 MWD+IFR-AK-CAZ-SC j I 14347.52 90.56 325.96 6908.94 6858.89 3591.94 -9188.01 6007544.77 378977.94 MWD+IFR-AK-CAZ-SC 14442.64 91.06 326.19 6907.60 6857.55 3670.86 -9241.10 6007624.47 378926.05 MWD+IFR-AK-CAZ-SC i 14537.81 90.81 325.27 6906.05 6856.00 3749.49 -9294.68 6007703.89 378873.66 MWD+IFR-AK-CAZ-SC 14632.62 90.87 324.28 6904.66 6854.61 3826.93 -9349.36 6007782.14 378820.15 MWD+IFR-AK-CAZ-SC 14727.87 90.93 322.57 6903.16 6853.11 3903.41 -9406.11 6007859.45 378764.56 MWD+IFR-AK-CAZ-SC 14823.01 90.13 321.58 6902.28 6852.23 3978.46 -9464.58 6007935.36 378707.22 MWD+IFR-AK-CAZ-SC 14917.94 90.50 323.67 6901.76 6851.71 4053.89 -9522.20 6008011.64 378650.75 MWD+IFR-AK-CAZ-SG 15013.18 90.32 323.50 6901.08 6851.03 4130.53 -9578.73 6008089.11 378595.37 MWD+IFR-AK-CAZ-SC 15108.36 89.76 322.73 6901.01 6850.96 4206.66 -9635.86 6008166.08 378539.39 MWD+IFR-AK-CAZ-SC ~ 15203.42 89.95 323.45 6901.25 6851.20 4282.67 -9692.95 6008242.93 378483.46 MWD+IFR-AK-CAZ-SC 15298.78 89.70 324.92 6901.54 6851.49 4359.99 -9748.75 6008321.08 378428.83 MWD+IFR-AK-CAZ-SC I 15394.17 89.27 325.25 6902.40 6852.35 4438.21 -9803.35 6008400.10 378375.41 MWD+IFR-AK-CAZ-SC 15489.05 90.13 326.22 6902.90 6852.85 4516.62 -9856.76 6008479.29 378323.18 MWD+IFR-AK-CAZ-SC 15583.94 91.74 326.18 6901.35 6851.30 4595.46 -9909.54 6008558.91 378271.60 MWD+IFR-AK-CAZ-SC 15679.06 90.87 326.19 6899.18 6849.13 4674.47 -9962.46 6008638.69 378219.87 MWD+IFR-AK-CAZ-SC ,I I 15774.18 90.87 322.77 6897.74 6847.69 4751.87 -10017.71 6008716.90 378165.79 MWD+IFR-AK-CAZ-SC 15869.07 91.30 325.25 6895.94 6845.89 4828.62 -10073.46 6008794.48 378111.21 MWD+IFR-AK-CAZ-SC 15964.54 91.24 325.58 6893.82 6843.77 4907.20 -10127.64 6008873.86 378058.22 MWD+IFR-AK-CAZ-SC 16059.72 91.24 324.30 6891.76 6841.71 4985.09 -10182.30 6008952.55 378004.73 MWD+IFR-AK-CAZ-SC 16154.71 90.56 323.30 6890.27 6840.22 5061.74 -10238.39 6009030.02 377949.80 MWD+IFR-AK-CAZ-SC 16250.01 91.12 326.15 6888.87 6838.82 5139.52 -10293.42 6009108.61 377895.95 MWD+IFR-AK-CAZ-SC 16345.12 91.12 326.13 6887.01 6836.96 5218.49 -10346.40 6009188.36 377844.16 MWD+IFR-AK-CAZ-SC i 16440.41 90.44 324.29 6885.72 6835.67 5296.73 -10400.76 6009267.40 377790.99 MWD+IFR-AK-CAZ-SC 16535.88 90.56 324.29 6884.88 6834.83 5374.25 -10456.48 6009345.74 377736.44 MWD+IFR-AK-CAZ-SC 16631.53 89.76 324.39 6884.62 6834.57 5451.96 -10512.24 6009424.27 377681.85 MWD+IFR-AK-CAZ-SC 16727.08 92.29 325.16 6882.91 6832.86 5530.00 -10567.34 6009503.12 377627.93 MWD+IFR-AK-CAZ-SC 16822.35 91.24 325.77 6879.97 6829.92 5608.44 -10621.32 6009582.35 377575.14 MWD+IFR-AK-CAZ-SC 16917.98 90.07 324.84 6878.88 6828.83 5687.06 -10675.75 6009661.77 377521.90 MWD+IFR-AK-CAZ-SC 17013.16 91.12 323.98 6877.89 6827.84 5764.45 -10731.14 6009739.98 377467.68 MWD+IFR-AK-CAZ-SC 17108.52 91.00 325.41 6876.13 6826.08 5842.26 -10786.24 6009818.60 377413.76 MWD+IFR-AK-CAZ-SC 17203.29 90.81 326.88 6874.63 6824.58 5920.95 -10839.03 6009898.07 377362.16 MWD+IFR-AK-CAZ-SC i • Halliburton Company Survey Report ~.ompany: ~.onocornnnps rudsrca mc. Field: Colville Rive r Unit Site: Alpine CD3 Well: GD3-114 N'ellparh: CD3-114.. Survey )'fD Incl 42im TVD Sys T~ U ft deg deg ft ft ~ 17298.69 90.32 322.71 6873.69 6823.64 17393.74 90.56 321.23 6872.96 6822.91 17489.28 90.13 322.40 6872.38 6822.33 17584.71 88.84 321.92 6873.24 6823.19 17680.36 89.21 324.66 6874.87 6824.82 17774.74 88.28 326.34 6876.94 6826.89 17871.11 88.34 327.09 6879.78 6829.73 17966.32 88.84 328.02 6882.12 6832.07 18003.36 88.59 328.67 6882.95 6832.90 • 18042.00 88.59 328.67 6883.90 .6833.85 __--- Date: 4/24/2007 Time: 09:26:58 Page S Co-ordinate(NE} Reference: WeII: CD3-114, True North Vcrticai(TVD) Reference: CD3-114: 50.1 5ection'(VS)Reference: Well (O.OON,O.OOE,301.29Azi) Sur, c~ Caricnlation Method: Minimum Curvature 'r Uh: Oracle N"/S E/W ft ft ____- 5998.88 -10894.01 6073.74 -10952.57 6148.84 -11011.63 6224.20 -11070.17 6300.86 -11127.33 6378.62 -11180.77 6459.14 -11233.64 6539.46 -11284.70 6570.99 -11304.13 6603.98 -11324.22 Stap\ Mapt: Tool ft ft - 6009976.80 __ 377308.35 _-- MWD+IFR-AK-CAZ-SC 6010052.53 377250.93 MWD+IFR-AK-CAZ-SC 6010128.50 377193.01 MWD+IFR-AK-CAZ-SC 6010204.72 377135.61 MWD+IFR-AK-CAZ-SC 6010282.22 377079.61 MWD+IFR-AK-CAZ-SC 6010360.76 377027.34 MWD+IFR-AK-CAZ-SC 6010442.06 376975.70 MWD+IFR-AK-CAZ-SC 6010523.14 376925.85 MWD+IFR-AK-CAZ-SC 6010554.94 376906.89 MWD+IFR-AK-CAZ-SC 6010588.23 376887.30 .PROJECTED to TD • 04-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD3-114 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 50.05' MD Window /Kickoff Survey ' MD (if applicable) Projected Survey: 18,042.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date 2l 'L,4.~ Signed V --~ a ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) • • ~Qr'1~C~~'ll~~l S TRANSMITTAL FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7'h Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: CD3-114 Permit: 207-033 DATE: 04/20/2007 Alpine Field, North Slope, Alaska ;D3-114 OM and hardcopy report Final Well report, Epoch Mudlogging, Inc.; Walker, Duncan, March 25,2007 Equipment and Crew; well details; drilling data; daily reports; formation logs; Color plots: Formation log (MD) and (TVD), LWD Lithology log {MD) and (TVD); Drilling logs: Drilling Dynamics (MD) and (TVD} Please check off each item as received, promptly sign and return the transmittal to address below. To aJl data recipients: A// data /s conf/dentia/until State ofAlaska designated AOGCC re%ase CC: CPAI ine o, -padsite Geologist Receipt: Date: ±~ ~ ~~ GIS-Technical Data Management (ConocoPhillips ~ Anchorage, Alaska ~ Ph: 907.265.6947 Sandra. D. L emkeCa?Conocophil/ips. com Ali; ~# ?~Q7 ~ask~ ail ~ "~~ ~ ~r . Commi~lri®tt f~nwi~ax~ ~~a ao~-o33 ~ i5a~ i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein~admin.state.ak.us; Jim_Regg~admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips FIELD /UNIT /PAD: Alpine / Fiord /CD3 DATE: 04/07/07 OPERATOR REP: Don Mickey AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well CD3-114 Type Inj. W TVD 6,625' Tubing 2,600 3,000 3,000 3,000 Interval I P.T.D. 207-033 Type test P Test psi 3500 Casing 3,525 3,469 3,439 P/F P Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waist G =Gas I =Industrial Waistewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D = Drfferential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1!05 MIT CD3-114.x1s `~ ~~~~/r ,1~~~~ RECEIVED ~ ~ ~ STATE OF ALASKA I i~ APR 1 2 20.01 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 AAC 25.2so Rnchorage 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 ^ 207-033 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20544-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property Tine 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S ^ NO ^~ CD3-114 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 384215, 372105, 380092 ~ RKB 37' Colville River Field/ Fjord Oil Pool ` 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18,042' 6,885' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' 114' SURFACE 2892' 9-5/8" 2892' 2485' PRODUCTION 10,593' 7" 10627' 6927' OPEN HOLE 7415 6-1/8" 18042' 6884' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open Hole open Hole 4-1/2" L-80 9,678' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer: 9,618' BaI-O-Nipple SSSV SSSV: 2,123' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 73, 2007 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker Printed Name Jack Walker _- Title: Production Engineer J ~ ~ Signature ~ V ~ Phone 265-6268 Date // D Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness O~ .. DL Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: 4© APPROVED BY f n ~ ~ V Approved by: COMM ISSION Date: Form 10-403 Revised 06/2006 ~ ~'F{ ~ ~, j~\' /~ ~ ~ S,ubmit ir~Duplicate >~ • Supplemental Information for 10-403 Application for Sundry Approval for CD3-114 API 50-103-20544-00 Permit to Drill No. 207-033 April 11, 2007 CD3-114 was permitted as a service well because its ultimate service will be injection of water alternating with gas. It was drilled and completed as planned with equipment enabling wireline installation of asurface-controlled subsurface safety valve (SCSSSV). Installation operations for a SCSSSV are expected to be complete on April 12, 2007. This sundry application seeks approval to temporarily produce CD3-114 to provide additional clean up before injection and to provide additional early production to stakeholders. Injection into CD3-114 is planned after 12 months of production. Static pressure measurements are planned before starting production and before starting injection. Reservoir simulation shows no effect on ultimate recovery by producing CD3- 114before injection. SARAH PALIN, GOVERNOR ~v ~popau[a~7~7~ ~~ ~D ~7r~ 333 W. 7th AVENUE, SUITE 100 L'Ols-7~1i1s~-~~if CO~IISSI~K ANCHORAGE, ALASKA 99501-3539 -7i'IA jf -7 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Jack Walker Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-114 Sundry Number: 307-128 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 April, 2007 Encl. Sincerely, t Chip Alvord WNS Drilling Team Lead ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Fiord Oil Pool, CD3-114 ConocoPhillips (Alaska), Inc. Permit No: 207-033 Surface Location: 3960' FNL, 933' FEL, Sec. 5, TI2N, RSE, UM Bottomhole Location: 2171' FNL, 4654' 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. The decision as to whether or not the Qannik sandstone contains a significant hydrocarbon accumulation that must be cemented per 20 AAC 25.030(d)(5) must be made in conjunction with AOGCC technical staff. When logging information is available, please have your engineer contact the Commission. The Commission requires that a mudlog and cuttings samples be obtained in one well from each drill site. Our records indicate that no mudlog or cuttings samples have been acquired at Pad CD3. Accordingly, a mud log and cuttings samples must be obtained in well CRU CD3-114. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through Kuparuk target zone and the initial portion of the Nechelik target zone. 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 r ConocoPhillips Well Name: CD3-114 Permit No. 207-033 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 ~ day of March, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~EIVED 3t~ MAR Q 5 2007 • Alaska Oil & Gas Cons. Commission Anchorage 1 a. Type of Work: Drill 0 Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone ^/ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 - 11. Well Name and Number: CD3-114 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 18601' ~ TVD: 6909' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 3960` FNL, 933' FEL,. Sec 5 T12N R5E 7. Property Designation: ADL 384215, 372105, 3 Fiord Oil Pool Top of Productive Horizon: 3433' FNL 2703° FEL, See. 6 T12N R5E 8. Land Use Permit: 07 ALK 380077 ~~~~ 13. Approximate Spud Date: 3118/2007 Total Depth: 2171 ~ FNL 4654' FEL; Sec. 36 T13N R4E r 9. Acres in Property: 2560 14. Distance to f ypp~ ./p C~ Nearest Property:374' FWL Fiord Nechelik PA 7, 4b. Location of Well (State Base Plane Coordinates): Surface: x- 38$110 y- 6003815.8 ° Zane- 4 10. KB Elevation (Height above GL): 3T RKB feet 15. Distance to Nearest Well within Pool: CD3-113 , 2114' ~ 16. Deviated wells: Kickoff depth: 600 - ft. Maximum Hole Angle: 91 ° deg 17. Maximum Anticipated Pressures in psig {see 20 AAC 25.035) Downhole: 3149 psig Surface: 2441 psig' 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 24" 16,t 62.5 N-4f3 Welded 77 37 37 114 114' pre-installed 12.25" 9-518" 40# L-80 BTC 2691 37 37 2728 2400 ~ 523 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 10563 37 37 10600 6925 ' 244sx 15.8G, 2nd stage 184 sx 15.8G 4.5" 12.6# L-80 IBTM 9680 32 32 9712 6674 tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program^ Time v. Depth Plot ^ Shallow Hazard Analysis ~ Properly Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V, Johnson Printed Name C. Alvord Sr Title WNS Drilling Team Lead Signature ~~~`.; (\ ~/~~~ Phone ZGs_ X575 Date ,3~S~p-~ ~k Commission Use Only Permit to Drill Number: ,,~Q~^•~3~ API Number: , / 50- lG/~ "' ~~7` ~ ~ Permit Approval Date: . O ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: ~..` ~~-~i Ctc-d''~CL"~c_~VCs-`~~~b~ Samples req'd: Yes []r No ^ Mud log req'd: Ye~/ No^ Other H2S measures: Yes ^ No Di ction I svy req'd: Yes [/~ No ^ ~~~~ psi 11`x`. r. •~.: ~ ~3~ Q ~-~,~, ~~~~ ~-wcs~: ~ ' a ,~35 L~14~~ v~~~~~ op~~a~~rs~~.~.~,~ ~J ~~~ APPROVED BY THE COMMISSION ~j i DATE: / '~ O ,COMMISSIONER Form 10-401 Revised 12/2005 - 3/7v ubmit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 2, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-114 Dear Sir or Madam: CanocoPhilli s DIVED M~,~ a 5 2ao7 Al~w#r~ (al Gas Cons. CommissiotM Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the CD3 (Fiord) pad. The intended spud date for this well is March 18, 2007. It is intended that Doyon Rig 19 be used to drill the well. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an /open hole injector. At the end of the rig work program, the well will be flowed back for 2-3 days to -' mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin pre-production for a period ending +/- 3~d quarter 2007. It is planned to convert the well from production to injection +/- 3~d quarter 2007. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 8 surface holes drilled at CD3 and there has not been a significant show of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. • • If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. ~i~n~ el ~,~~~ Vern o nson Drilling Engineer Attachments cc: CD3-114 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Liz Galiunas ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation r: • CD3-114 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 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 o 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 densi cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD 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 H2S drills, detection systems, alarms, standard well ~' control ractices, mud scaven ers ORIGINAL • • Fiord Nechelik : CD3-114 Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. 3) Drill 12?/" hole to the surface casing point as per the directional plan. (Directional/MWD/Mud logging). 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 reservoir sand. (LWD Program: GR/RES/PWD & Mud Logging suite) 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 casing. 11) BOPE test to 5000 psi. 12) Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 13) Displace well to Flo-Pro drilling fluid. 14) Drill 6-1 /8" horizontal section to well TD (LWD Program: GR/RES/PWD). 15) Circulate the hole clean and pull out of hole. 16) Run completion: 4-%, 12.6#, L-80 tubing with SCSSSV, gas lift mandrels, packer, landing nipple and wireline entry guide. Land hanger. 17) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 18) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 19) Circulate tubing to diesel and install freeze protection in the annulus. 20) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 21) Set BPV and secure well. Move rig off. ^R!GINAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-113 is the closest well. Well separation is 21.5 @ 500' MD. i Drilling Area Risks: i 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: Incidental fluids developed from drilling operations on well CD3-114 will be injected into a permitted annulus on CD3 pad or the class 2 disposal well on CD1 pad. The CD3-114 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nechelik reservoir, potential Kuparuk reservoir and the Qannik reservoir. There will be 500' of cement fill above the top of the Kuparuk reservoir along with 500' above and below the Qannik reservoir per regulations. Upon completion of CD3-114 form 10-403, Application for Sundry Operations, 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. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 -1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 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 oint-12'/" Intermediate hole to 7" casing point - 8'/2" 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 160 12 - 14 cc/30 min PH 8.5-9.0 9.0-10.0 9.0-9.5 KCL 6 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 reservoir 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 production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 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 • TOC @ +/- 4894' MD / 3745' ND Weatherford Gemoco Stage cementing tool +/- 5917' M D / 4380' TVD Packer TOC Calculated +/- 9340' MD / 6488' ND (300' MD above packer) Top Kuparuk C at 10072' MD / 6807' Top Nechelik at 10535' MD / 6916' TVD • CD3-114 Completion Schematic 16" Conductor to 114' O 2119' 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 @ 2728' MD / 2400' TVD cemented to surface ik interval too +/- 5394' MD ! 4055' TVD Completion: MD TVD Inclination Tubing Hanger 32' 32' 0 degrees 4-'/z" 12.6 #/ft IBT-Mod Tubing 1. Camco BAL-O landing nipple (3.812" ID) 2119' 2000' 42 4'/:" 12.6 #/ft IBT-Mod Tubing 2. Camco KBG-2 GLM w/dummy 4339' 3400' S2 4-'/z" 12.6 #/ft IBT-Mod Tubing 3. Camco KBG-2 GLM w/dummy 7882' 6590' S2 4-'/z' 12.6 #/ft IBT-Mod Tubing 4. Camco KBG-2 GLM w/dummy 9540' 6590' 61 4-'/i' 12.6 #/ft IBT-Mod Tubing 2 jts 5. Baker Premier Packer 9640' 6638' 63 4-'/2' tubing 1 joint `-'~- 6. HES XN 3.813" (3.725" NoGo) 9700' 6665' 64 4-1 /2" 10' pup joint 7. WEG 9712' 6670' 64 - -- - - - - - ---------- -L- - -- - --- - - -- - - Well TD at 18601' MD / i 6909' TVD ------------ - - - 7" 26 ppf L-80 BTC Mod Casing @ 10600' / 6925' TVD @ 83° ORIGINAL ~ • CD3-114 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2728 / 2400 14.5 1086 1570 7" 10600 / 6925 16.0 3133 2441 N/A 18601 / 6909 16.0 3126 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 Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x 114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 3133 - (0.1 x 6925') = 2441 psi ' 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3126 - (0.1 x 6909') = 2435 psi ~21GINAL Cementing Program: 9 5/8" Surface Casing run to 2728' MD / 2400' TVD. Cement from 2728' MD to 2228' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2228' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1633' MD). Lead slurry: (2228'-1633') X 0.3132 ft3/ft X 1.5 (50% excess) = 280 ft3 below permafrost 1633' X 0.3132 ft3/ft X 4 (300% excess) = 2046 ft3 above permafrost Total volume = 280 + 2046 = 2326 ft3 => 523 Sx @ 4.45 ft3/sk System: 523 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% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 10600' MD / 6925' TVD: Cemented in two stages Cement from 10600' MD to 9340' MD (300' MD above the Hacker & minimum 500' MD above ton~£.Ku}~ar~uk reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage• Lead: (10600' -9340' X 0.1503 ft3/ft X 1.4 (40% excess) = 265.1 ft3 annular vol. 80' X 0.2148 ft /ft = 17.2 ft3 shoe joint volume Total volume = 265.1 + 17.2 = 282.3 ft3 => 226 Sx @ 1.16 ft3/sk System: 244 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a stage tool set 500' below the Qannik (K2) interval to +/- 500' above the KZ interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (5917' - 4894') X 0.1503 ft3/ft X 1.4 (40% excess) = 215.3 ft3 annular vol. Total Volume = 215.3 ft3 => 184 Sk @ 1.17 ft3/sk System: 184 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ~~r ~~~~~'"~ ._ .. .. ... E R: M i ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/18/2007 Time: 14:22:27 Page: 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD3-114, True North Site: Alpine CD3 Vertical (TVD) Reference: Plan: CD3-114 49.6 We1L• Plan: CD3-114 Secfion (VS) Reference: Welt (O.OON,O.OOE,301.29Azi) Wellpath: Plan: CD3-114 Survey Calculation Method: Minimum Curvature , Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 1000.00 8.00 267.00 998.70 -1.46 -27.84 2.00 2.00 0.00 267.00 2454.19 51.62 267.93 2230.19 -28.63 -732.94 3.00 3.00 0.06 1.06 8885.77 51.62 267.93 6223.00 -210.43 -5771.76 0.00 0.00 0.00 0.00 10599.39 83.00 324.85 6924.60 529.58 -7051.63 3.50 1.83 3.32 73.85 CD3-114wp02 T1 10615.20 83.55 324.83 6926.45 542.42 -7060.68 3.50 3.50 -0.15 -2.49 10830.02 83.55 324.83 6950.57 716.91 -7183.63 0.00 0.00 0.00 0.00 11000.64 90.38 324.94 6959.60 856.20 -7281.58 4.00 4.00 0.06 0.93 CD3-114wp02 T2 18601.70 90.38 324.94 6909.60 7077.99 -11647.69 0.00 0.00 0.00 0.00 CD3-114wp02 T3 Plan: CD3-114wp02 Date Composed: 1/18/2007 Version: 9 Principal: Yes Tied-to: From Well Ref. Point 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: bggm2006 Site: Alpine CD3 Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.86 deg Well: Plan: CD3-114 Slot Name: Well Position: +N/-S -76.60 ft Northing: 6003815.84 ft ~ .Latitude: 70 25 9.727 N +E/-W -376.73 ft Easting : 388110.30 ft J Longitude: 150 54 41.438 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD3-114 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan: CD3-114 Height 49.60 ft Above System Datum: Mean Sea Level Magnetic Data: 12/2/2004 Declination: 23.88 deg Field Strength: 57515 nT Mag Dip Angle: 80.71 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 301.29 Survey Program for Definitive Wellpath Date: 11/6/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft ~~~~~~~ WELL DETAILS lame +N/-S +E/-W Northing Easting Latitude Longitude Slot 'lan: CD3-114 -76.60 -376.73 6003815.84 388110.30 70°25'09.727N 150°54'41.438W N/A WELLPATH DETAILS Plan: CD3-114 Rig: Doyon 19 Ref. Datum: Plan: CD3-114 49.60ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 301.29° 0.00 0.00 36.30 S a e F T M Azimuths to True North Magnetic North: 23.88° Magnetic Field Strength: 57515nT Dip Angle: 80.71° Date: 12/2/2004 Model: bggm2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 36.30 1000.00 Planned: CD3-114wp02 V9 CB-GYRO-SS 1000.00 18601.70 Planned: CD3-114wp02 V9 MWD+IFR-AK-CAZ-SC 0° o° ' yo ° ' hti o° 1000 0 500 -500 CD3-114 02 o 0 w °o c ° ° 0 0 ° ° -twvv -ivuvu -wuv u wuu West(-)/East(+) [SOOONin] PLAN DETAILS CD3-114wp02 Version 9 1/18/2007 Start Point MD Inc Azi TVD +N/-S +E/-W ° 36.30 0.00 0.00 36.30 0.00 0.00 CD3-114 02 w ~ ~~ ~ o _N H~-L~'B~AT®~ ConocoPhillips sps-ry Dditi+hg servica Alaska REFERENCE INFORMATION ~ Co-ordinate (N/E) Reference: Well Centre: Plan: CD3-114, True North Vertical ('I'VD) Reference: Plan: CD3-114 49.60 -5000 0 5000 10000 15000 20000 Section (VS) Reference: Slot- (O.OON,O.OOE) Measured Depth Reference: Plan: CD3-114 49.60 Vertical Section at 30!.29° (SOOOft/in] n..t....t,..+;,..., wR,.+t.....t. wx :..:.......... n....,,,+...e s ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/18/2007 Time: 14 :22:27 Page: 2 Field: Colville River Un it Co-ordinate(NE) Reference: Well: Plan: CD3-114, True North Site: Alpine CD3 Vertica l (TVD) Reference: Plan: CD3-114 49.6 Well: Plan: C D3-1 14 Section (VS) Reference: Well (O.OON,O.OOE,301 .29Azi) Wellpath: Plan: C D3-1 14 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 36 .30 0. 00 0.00 36. 30 -13. 30 0 .00 0 .00 6003815.84 388110. 30 0.00 0 .00 100 .00 0. 00 0. 00 100. 00 50. 40 0 .00 0. 00 6003815.84 388110. 30 0.00 0 .00 200 .00 0. 00 0. 00 200. 00 150. 40 0 .00 0. 00 6003815.84 388110. 30 0.00 0 .00 300 .00 0. 00 0. 00 300. 00 250. 40 0 .00 0. 00 6003815.84 388110. 30 0.00 0 .00 400 .00 0. 00 0. 00 400. 00 350. 40 0 .00 0. 00 6003815.84 388110. 30 0.00 0 .00 500 .00 0. 00 0. 00 500. 00 450. 40 0 .00 0. 00 6003815.84 388110. 30 0.00 0 .00 600 .00 0. 00 0. 00 600. 00 550. 40 0 .00 0. 00 6003815.84 388110. 30 0.00 0 .00 KOP; 2 DLS ~ 700 .00 2. 00 267. 00 699. 98 650. 38 -0 .09 -1. 74 6003815.77 388108. 56 2.00 1 .44 800 .00 4. 00 267. 00 799. 84 750. 24 -0 .37 -6. 97 6003815.58 388103. 33 2.00 5 .77 900 .00 6. 00 267. 00 899. 45 849. 85 -0 .82 -15. 67 6003815.25 388094. 62 2.00 12 .97 1000 .00 8. 00 267. 00 998. 70 949. 10 -1. 46 -27. 84 6003814.80 388082. 44 2.00 23 .04 Build; 3 DLS 1100 .00 11. 00 267. 29 1097. 32 1047. 72 -2 .27 -44. 32 6003814.23 388065. 95 3.00 36 .70 1200 .00 14. 00 267. 46 1194. 94 1145. 34 -3 .26 -65. 94 6003813.57 388044. 32 3.00 54 .66 1256 .97 15. 71 267. 53 1250. 00 1200. 40 -3 .90 -80. 53 6003813.15 388029. 73 3.00 66 .80 Base Permafrost 1300. 00 17. 00 267. 57 1291. 29 1241. 69 -4. 42 -92. 64 6003812.81 388017. 62 3.00 76 .87 1400. 00 20. 00 267. 64 1386. 11 1336. 51 -5. 74 -124. 33 6003811.96 387985. 90 3.00 103 .27 1500. 00 23. 00 267. 70 1479. 14 1429. 54 -7. 23 -160. 95 6003811.03 387949. 27 3.00 133 .79 1600. 00 26. 00 267. 75 1570. 13 1520. 53 -8. 87 -202. 38 6003810.00 387907. 83 3.00 168 .34 1700. 00 29. 00 267. 78 1658. 82 1609. 22 -10. 67 -248. 51 6003808.89 387861. 68 3.00 206 .83 1800. 00 32. 00 267. 81 1744. 98 1695. 38 -12. 62 -299. 22 6003807.71 387810. 95 3.00 249 .16 1900. 00 35. 00 267. 84 1828. 36 1778. 76 -14. 71 -354. 37 6003806.44 387755. 78 3.00 295 .20 2000 .00 38. 00 267. 86 1908. 73 1859. 13 -16. 94 -413. 80 6003805.10 387696. 33 3.00 344 .83 2100 .00 41. 00 267. 88 1985. 89 1936. 29 -19. 30 -477. 36 6003803.69 387632. 75 3.00 397 .92 2200 .00 44. 00 267. 90 2059. 61 2010. 01 -21. 79 -544. 86 6003802.22 387565. 22 3.00 454 .31 2300 .00 47. 00 267. 91 2129. 69 2080. 09 -24 .40 -616. 13 6003800.68 387493. 93 3.00 513 .86 2400 .00 50. 00 267. 93 2195. 95 2146. 35 -27 .12 -690. 96 6003799.09 387419. 07 3.00 576 .41 2454. 19 51. 62 267. 93 2230. 19 2180. 59 -28 .63 -732. 94 6003798.20 387377. 08 3.00 611 .49 Sail; 52° for 6431 ' 2500. 00 51. 62 267. 93 2258. 63 2209. 03 -29. 93 -768. 83 6003797.44 387341. 18 0.00 641. 49 2600. 00 51. 62 267. 93 2320. 71 2271. 11 -32. 75 -847. 17 6003795.79 387262. 81 0.00 706. 97 2606. 91 51. 62 267. 93 2325. 00 2275. 40 -32. 95 -852. 58 6003795.68 387257. 39 0.00 711. 49 C-40 2700. 00 51. 62 267. 93 2382. 79 2333. 19 -35. 58 -925. 52 6003794.14 387184. 43 0.00 772. 45 2727. 72 51. 62 267. 93 2400. 00 2350. 40 -36. 36 -947. 23 6003793.68 387162. 71 0.00 790. 61 9 5/8" 2800. 00 51. 62 267. 93 2444. 87 2395. 27 -38. 41 -1003. 86 6003792.49 387106. 06 0.00 837: 94 2863. 03 51. 62 267. 93 2484. 00 2434. 40 -40. 19 -1053. 24 6003791.44 387056. 67 0.00 879 .21 C-30 2900. 00 51. 62 267. 93 2506. 95 2457. 35 -41. 23 -1082. 21 6003790.83 387027. 69 0.00 903 .42 3000. 00 51. 62 267. 93 2569. 04 2519. 44 -44. 06 -1160. 55 6003789.18 386949. 32 0.00 968 .91 3100. 00 51. 62 267. 93 2631. 12 2581. 52 -46. 89 -1238. 90 6003787.53 386870. 95 0.00 1034 .39 3200. 00 51. 62 267. 93 2693. 20 2643. 60 -49. 71 -1317. 24 6003785.88 386792. 58 0.00 1099 .88 3300. 00 51. 62 267. 93 2755. 28 2705. 68 -52. 54 -1395. 58 6003784.23 386714. 20 0.00 1165 .36 3400. 00 51. 62 267. 93 2817. 36 2767. 76 -55. 37 -1473. 93 6003782.57 386635. 83 0.00 1230 .85 3483. 18 51. 62 267. 93 2869. 00 2819. 40 -57. 72 -1539. 10 6003781.20 386570. 64 0.00 1285. 32 C-20 3500. 00 51. 62 267. 93 2879. 44 2829. 84 -58. 19 -1552. 27 6003780.92 386557. 46 0.00 1296. 33 3600. 00 51. 62 267. 93 2941. 52 2891. 92 -61. 02 -1630. 62 6003779.27 386479. 09 0.00 1361. 82 3700. 00 51. 62 267. 93 3003. 60 2954. 00 -63. 85 -1708. 96 6003777.62 386400. 72 0.00 1427. 30 3800. 00 51. 62 267. 93 3065. 69 3016. 09 -66. 67 -1787. 31 6003775.97 386322. 35 0.00 1492. 78 3900. 00 51. 62 267. 93 3127. 77 3078. 17 -69. 50 -1865. 65 6003774.32 386243. 97 0.00 1558. 27 4000. 00 51. 62 267. 93 3189. 85 3140. 25 -72. 33 -1944. 00 6003772.66 386165. 60 0.00 1623 .75 4100. 00 51. 62 267. 93 3251. 93 3202. 33 -75. 15 -2022. 34 6003771.01 386087. 23 0.00 1689 .24 4200. 00 51. 62 267. 93 3314. 01 3264. 41 -77. 98 -2100. 69 6003769.36 386008. 86 0.00 1754 .72 4300. 00 51. 62 267. 93 3376. 09 3326. 49 -80. 81 -2179. 03 6003767.71 385930. 49 0.00 1820 .21 4400. 00 51. 62 267. 93 3438. 17 3388. 57 -83. 63 -2257. 38 6003766.06 385852. 11 0.00 1885 .69 4500. 00 51. 62 267. 93 3500. 25 3450. 65 -86. 46 -2335. 72 6003764.41 385773. 74 0.00 1951 .18 4600. 00 51. 62 267. 93 3562. 34 3512. 74 -89. 29 -2414. 07 6003762.75 385695. 37 0.00 2016 .66 ORIGW!1L ConocoPhillips Alaska, Inc. CPAI Report Company: GonocoPhillips Alaska Inc. Date: 1/18!2007 Time: 14:22:27 Page: 3 Field: Colville River Un it Co-ordinate(NE) Re ference: Well: Plan: CD3-114, True North Site: Alpine CD3 Vertica l (TVD) Refe rence: Plan: CD3-114 49.6 Well: Plan: CD3-1 1.4 Sec tion (VS) Reference: Well (O.OON,O.OOE,301 .29Azi) Wellpath: Plan: CD3-1 14 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft d eg deg ft ft ft ft ft ft degl100ft ft 4700 .00 51 .62 267 .93 3624. 42 3574. 82 -92 .11 -2492 .41 6003761. 10 385617. 00 0.00 2082 .15 4800 .00 51 .62 267. 93 3686. 50 3636. 90 -94 .94 -2570 .76 6003759.45 385538. 63 0.00 2147 .63 4900 .00 51 .62 267. 93 3748. 58 3698. 98 -97 .76 -2649 .10 6003757. 80 385460. 26 0.00 2213 .12 5000 .00 51 .62 267. 93 3810. 66 3761. 06 -100 .59 -2727 .45 6003756. 15 385381. 88 0.00 2278 .60 5100 .00 51 .62 267. 93 3872. 74 3823. 14 -103 .42 -2805 .79 6003754. 49 385303. 51 0.00 2344 .08 5124 .58 51 .62 267. 93 3888. 00 3838. 40 -104 .11 -2825 .05 6003754. 09 385284. 25 0.00 2360 .18 K-3 5200 .00 51 .62 267. 93 3934. 82 3885. 22 -106 .24 -2884 .14 6003752. 84 385225. 14 0.00 2409 .57 5300 .00 51 .62 267 .93 3996. 90 3947. 30 -109 .07 -2962 .48 6003751. 19 385146. 77 0.00 2475 .05 5353 .31 51 .62 267. 93 4030. 00 3980. 40 -110 .58 -3004 .25 6003750. 31 385104. 99 0.00 2509 .96 K-3 Basal 5393 .58 51 .62 267 .93 4055. 00 4005. 40 -111 .72 -3035 .80 6003749. 64 385073. 43 0.00 2536 .33 K-2 5400 .00 51 .62 267 .93 4058. 99 4009. 39 -111 .90 -3040 .83 6003749. 54 385068. 40 0.00 2540 .54 5500. 00 51 .62 267. 93 4121. 07 4071. 47 -114 .72 -3119 .17 6003747. 89 384990. 03 0.00 2606 .02 5565 .94 51 .62 267. 93 4162. 00 4112. 40 -116 .59 -3170. 83 6003746. 80 384938. 35 0.00 2649 .20 K-2 Basal 5600 .00 51 .62 267. 93 4183. 15 4133. 55 -117 .55 -3197. 52 6003746. 24 384911. 65 0.00 2671 .51 5700 .00 51 .62 267. 93 4245. 23 4195. 63 -120 .38 -3275. 86 6003744. 58 384833. 28 0.00 2736 .99 5800 .00 51 .62 267. 93 4307. 31 4257. 71 -123 .20 -3354. 21 6003742. 93 384754. 91 0.00 2802 .48 5900 .00 51 .62 267. 93 4369. 39 4319. 79 -126 .03 -3432. 55 6003741. 28 384676. 54 0.00 2867 .96 6000 .00 51 .62 267. 93 4431. 47 4381. 87 -128 .86 -3510. 90 6003739. 63 384598. 17 0.00 2933 .45 6100 .00 51 .62 267. 93 4493. 55 4443. 95 -131 .68 -3589 .24 6003737. 98 384519. 79 0.00 2998 .93 6200 .00 51 .62 267. 93 4555. 64 4506. 04 -134 .51 -3667. 59 6003736. 32 384441. 42 0.00 3064 .41 6300 .00 51 .62 267. 93 4617. 72 4568. 12 -137 .34 -3745 .93 6003734. 67 384363. 05 0.00 3129 .90 6400 .00 51 .62 267. 93 4679. 80 4630. 20 -140 .16 -3824 .28 6003733. 02 384284. 68 0.00 3195 .38 6500 .00 51 .62 267. 93 4741. 88 4692. 28 -142 .99 -3902 .62 6003731. 37 384206. 31 0.00 3260 .87 6600 .00 51 .62 267. 93 4803. 96 4754. 36 -145 .82 -3980 .97 6003729. 72 384127. 94 0.00 3326 .35 6700 .00 51 .62 267. 93 4866. 04 4816. 44 -148 .64 -4059 .31 6003728. 07 384049. 56 0.00 3391 .84 6800 .00 51 .62 267. 93 4928. 12 4878. 52 -151 .47 -4137 .66 6003726. 41 383971. 19 0.00 3457 .32 6900 .00 51 .62 267. 93 4990. 20 4940. 60 -154 .30 -4216 .00 6003724. 76 383892. 82 0.00 3522 .81 7000 .00 51 .62 267. 93 5052. 29 5002. 69 -157 .12 -4294 .35 6003723. 11 383814. 45 0.00 3588 .29 7100. 00 51 .62 267. 93 5114. 37 5064. 77 -159 .95 -4372 .69 6003721. 46 383736. 08 0.00 3653 .78 7200. 00 51 .62 267. 93 5176. 45 5126. 85 -162. 78 -4451. 04 6003719. 81 383657. 70 0.00 3719 .26 7300. 00 51 .62 267. 93 5238. 53 5188. 93 -165. 60 -4529. 38 6003718. 15 383579. 33 0.00 3784 .74 7400. 00 51 .62 267. 93 5300. 61 5251. 01 -168. 43 -4607. 73 6003716. 50 383500. 96 0.00 3850 .23 7500. 00 51 .62 267. 93 5362. 69 5313. 09 -171. 26 -4686. 07 6003714. 85 383422. 59 0.00 3915 .71 7600 .00 51 .62 267. 93 5424. 77 5375. 17 -174. 08 -4764. 42 6003713. 20 383344. 22 0.00 3981 .20 7664 .80 51 .62 267. 93 5465. 00 5415. 40 -175. 91 -4815. 18 6003712. 13 383293. 43 0.00 4023 .63 Albian 97 7700 .00 51 .62 267. 93 5486. 85 5437. 25 -176 .91 -4842. 76 6003711. 55 383265. 85 0.00 4046 .68 7800 .00 51 .62 267. 93 5548. 94 5499. 34 -179 .74 -4921. 11 6003709. 90 383187. 47 0.00 4112 .17 7900 .00 51 .62 267. 93 5611. 02 5561. 42 -182 .56 -4999. 45 6003708. 24 383109. 10 0.00 4177 .65 8000 .00 51 .62 267. 93 5673. 10 5623. 50 -185 .39 -5077. 80 6003706. 59 383030. 73 0.00 4243 .14 8100 .00 51 .62 267. 93 5735. 18 5685. 58 -188 .21 -5156 .14 6003704. 94 382952. 36 0.00 4308 .62 8200 .00 51 .62 267. 93 5797. 26 5747. 66 -191 .04 -5234 .49 6003703. 29 382873. 99 0.00 4374 .11 8300 .00 51 .62 267. 93 5859. 34 5809. 74 -193 .87 -5312. 83 6003701. 64 382795. 62 0.00 4439 .59 8334 .89 51 .62 267. 93 5881. 00 5831. 40 -194 .85 -5340 .16 6003701. 06 382768. 27 0.00 4462 .44 Albian 96 8400 .00 51 .62 267. 93 5921. 42 5871. 82 -196 .69 -5391 .18 6003699. 98 382717. 24 0.00 4505 .08 8500 .00 51 .62 267. 93 5983. 50 5933. 90 -199 .52 -5469 .52 6003698. 33 382638. 87 0.00 4570 .56 8600 .00 51 .62 267 .93 6045. 59 5995. 99 -202 .35 -5547 .87 6003696. 68 382560. 50 0.00 4636 .04 8700. 00 51 .62 267. 93 6107. 67 6058. 07 -205. 17 -5626. 21 6003695. 03 382482. 13 0.00 4701 .53 8800. 00 51 .62 267. 93 6169. 75 6120. 15 -208. 00 -5704. 56 6003693. 38 382403. 76 0.00 4767 .01 8885. 77 51 .62 267. 93 6223. 00 6173. 40 -210. 43 -5771. 76 6003691. 96 382336. 53 0.00 4823 .18 Build; 3.5 DLS 8900. 00 51 .76 268. 54 6231. 82 6182. 22 -210. 77 -5782. 91 6003691. 78 382325. 37 3.50 4832 .54 9000. 00 52 .84 272. 75 6292. 98 6243. 38 -209. 85 -5862. 00 6003693. 89 382246. 32 3.50 4900 .60 9100. 00 54 .05 276. 84 6352. 56 6302. 96 -203. 11 -5942. 01 6003701. 82 382166. 42 3.50 4972 .48 ' f !~'~~ ~' . . ConocoPhillips k In~ Alas a, c. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/18/2007 Time: 14:22:27 Page: 4 Field: Colville River Unit Co-ordinate(NE) Re ferenc e: Well: Plan: CD3-114, True North Site: Alpine CD3 Vertica l (TVD) Reference: P-an: CD3-114 49.6 We1L• Plan: C D3-1 14 Sec tion (VS) Reference: Well (O.OON,O.OOE,301 .29Azi) Wellpath: Plan: C D3-1 14 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DIS VS Comore t ft deg deg ft ft ft ft ft ft deg/100ft ft 9200 .00 55. 40 280 .80 6410. 32 6360. 72 -190 .58 -6022 .66 6003715. 56 382085. 98 3.50 5047 .90 9300 .00 56. 88 284 .62 6466. 05 6416. 45 -172 .29 -6103 .63 6003735. 06 382005. 30 3.50 5126 .60 9400 .00 58. 46 288 .31 6519. 55 6469. 95 -148 .33 -6184 .63 6003760. 23 381924. 67 3.50 5208 .26 9500 .00 60. 15 291 .88 6570. 60 6521. 00 -118 .77 -6265 .35 6003791. 00 381844. 41 3.50 5292 .60 9549 .67 61. 02 293 .60 6595. 00 6545. 40 -102 .04 -6305 .26 6003808. 32 381804. 76 3.50 5335 .39 Top HRZ 9600 .00 61. 93 295 .32 6619. 03 6569. 43 -83 .73 -6345 .50 6003827. 23 381764. 80 3.50 5379 .29 9700 .00 63. 80 298 .65 6664. 65 6615. 05 -43 .33 -6424 .77 6003868. 80 381686. 15 3.50 5468 .01 9732 .86 64. 42 299 .72 6679. 00 6629. 40 -28 .92 -6450 .58 6003883. 61 381660. 56 3.50 5497 .56 Base HRZ 9800 .00 65. 73 301 .87 6707. 29 6657. 69 2 .26 -6502 .87 6003915. 56 381608. 75 3.50 5558 .43 9848 .88 66. 71 303 .41 6727. 00 6677. 40 26 .38 -6540 .53 6003940. 24 381571. 46 3.50 5603 .15 K-1 9900 .00 67. 74 305 .00 6746. 79 6697. 19 52 .88 -6579 .51 6003967. 32 381532. 88 3.50 5650 .22 9954 .64 68. 86 306. 66 6767. 00 6717. 40 82 .60 -6620 .67 6003997. 65 381492. 18 3.50 5700 .83 Top Kuparuk D 10000 .00 69. 80 308. 03 6783. 01 6733. 41 108 .35 -6654. 41 6004023. 90 381458. 54 3.50 5743 .03 10072 .07 71. 32 310. 17 6807. 00 6757. 40 151 .21 -6707. 14 6004067. 54 381406. 75 3.50 5810 .35 Top Kuparuk C 10081 .49 71. 52 310. 44 6810. 00 6760. 40 156 .98 -6713. 95 6004073. 42 381400. 04 3.50 5819 .16 Top Nuigsut 10100 .00 71. 91 310. 98 6815. 81 6766. 21 168 .45 -6727. 27 6004085. 08 381386. 89 3.50 5836 .50 10181 .78 73. 67 313. 35 6840. 00 6790. 40 220 .89 -6785. 16 6004138. 37 381329. 80 3.50 5913 .21 Base Nuiqsut 10200 .00 74. 07 313. 87 6845. 06 6795. 46 232 .96 -6797. 83 6004150. 64 381317. 30 3.50 5930 .31 10300 .00 76. 26 316. 69 6870. 66 6821. 06 301 .64 -6865. 84 6004220. 32 381250. 34 3.50 6024 .09 10400 .00 78. 49 319. 46 6892. 52 6842. 92 374 .24 -6931. 02 6004293. 88 381186. 26 3.50 6117 .50 10500 .00 80. 74 322. 18 6910. 54 6860. 94 450 .48 -6993. 15 6004371. 04 381125. 29 3.50 6210 .18 10535 .43 81. 55 323. 14 6916. 00 6866. 40 478 .31 -7014. 38 6004399. 18 381104. 47 3.50 6242 .78 Top Nechelik 10599 .39 83. 00 324. 85 6924. 60 6875. 00 529 .58 -7051. 63 6004451. 00 381068. 00 3.50 6301 .24 CD3-114wp02 T 10600 .00 83. 02 324 .85 6924. 67 6875. 07 530 .07 -7051. 98 6004451. 50 381067. 66 3.50 6301 .80 10615 .20 83. 55 324. 83 6926. 45 6876. 85 542 .42 -7060. 68 6004463. 97 381059. 15 3.50 6315 .64 10700 .00 83. 55 324 .83 6935. 97 6886. 37 611 .30 -7109. 21 6004533. 56 381011. 66 0.00 6392 .88 10800 .00 83. 55 324 .83 6947. 20 6897. 60 692 .52 -7166 .45 6004615. 63 380955. 65 0.00 6483 .98 10830 .02 83. 55 324 .83 6950. 57 6900. 97 716 .91 -7183 .63 6004640. 27 380938. 84 0.00 6511 .32 10900 .00 86. 35 324 .88 6956. 73 6907. 13 773 .90 -7223 .76 6004697. 85 380899. 57 4.00 6575 .21 11000. 00 90. 35 324. 94 6959. 60 6910. 00 855 .67 -7281 .21 6004780. 47 380843. 36 4.00 6666 .78 11000 .64 90. 38 324. 94 6959. 60 6910. 00 856. 20 -7281. 58 6004781. 00 380843. 00 3.98 6667 .36 CD3-114wp02 T 11100 .00 90. 38 324. 94 6958. 95 6909. 35 937 .53 -7338. 65 6004863. 17 380787. 15 0.00 6758 .37 11200 .00 90. 38 324. 94 6958. 29 6908. 69 1019 .38 -7396. 09 6004945. 87 380730. 95 0.00 6849 .97 11300 .00 90. 38 324. 94 6957. 63 6908. 03 1101 .24 -7453. 53 6005028. 57 380674. 75 0.00 6941 .56 11400 .00 90. 38 324. 94 6956. 97 6907. 37 1183 .09 -7510. 97 6005111. 27 380618. 55 0.00 7033 .16 11500 .00 90. 38 324. 94 6956. 32 6906. 72 1264 .95 -7568. 41 6005193. 97 380562. 34 0.00 7124 .76 11600 .00 90. 38 324. 94 6955. 66 6906. 06 1346 .80 -7625. 86 6005276. 67 380506. 14 0.00 7216 .35 11700 .00 90. 38 324. 94 6955. 00 6905. 40 1428 .65 -7683. 30 6005359. 36 380449. 94 0.00 7307 .95 11800 .00 90. 38 324. 94 6954. 34 6904. 74 1510 .51 -7740. 74 6005442. 06 380393. 74 0.00 7399 .54 11900 .00 90. 38 324. 94 6953. 68 6904. 08 1592 .36 -7798. 18 6005524. 76 380337. 53 0.00 7491 .14 12000 .00 90. 38 324. 94 6953. 03 6903. 43 1674 .22 -7855. 62 6005607. 46 380281. 33 0.00 7582 .74 12100 .00 90. 38 324. 94 6952. 37 6902. 77 1756 .07 -7913. 06 6005690. 16 380225. 13 0.00 7674 .33 12200 .00 90. 38 324. 94 6951. 71 6902. 11 1837 .93 -7970. 50 6005772. 86 380168. 92 0.00 7765 .93 12300 .00 90. 38 324. 94 6951. 05 6901. 45 1919 .78 -8027. 94 6005855. 56 380112. 72 0.00 7857 .52 12400 .00 90. 38 324. 94 6950. 39 6900. 79 2001 .63 -8085. 38 6005938. 26 380056. 52 0.00 7949 .12 12500 .00 90. 38 324 .94 6949. 74 6900. 14 2083 .49 -8142. 82 6006020. 96 380000. 32 0.00 8040 .72 12600 .00 90. 38 324 .94 6949. 08 6899. 48 2165 .34 -8200. 26 6006103. 65 379944. 11 0.00 8132 .31 12700. 00 90. 38 324. 94 6948. 42 6898. 82 2247. 20 -8257. 70 6006186. 35 379887. 91 0.00 8223 .91 12800. 00 90. 38 324. 94 6947. 76 6898. 16 2329. 05 -8315. 15 6006269. 05 379831. 71 0.00 8315. 50 12900. 00 90. 38 324. 94 6947. 11 6897. 51 2410. 91 -8372. 59 6006351. 75 379775. 51 0.00 8407. 10 13000 .00 90. 38 324. 94 6946. 45 6896. 85 2492. 76 -8430. 03 6006434. 45 379719. 30 0.00 8498 .69 13100 .00 90. 38 324. 94 6945. 79 6896. 19 2574 .61 -8487. 47 6006517. 15 379663. 10 0.00 8590 .29 13200 .00 90. 38 324. 94 6945. 13 6895. 53 2656 .47 -8544. 91 6006599. 85 379606. 90 0.00 8681 .89 ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska InC. Date: 1/18/2007 Time: 14 :22:27 Page: 5 Field: Colville River Un it Co-ordinate(NE) Re ference: Well: Plan: CD3-114, True North Site: Alpine CD3 Vertica l (TVD) Reference: P lan: CD3-114 49.6 Well: Plan: C D3-1 14 Section (VS) Reference: Well (O.OON,O .OOE,301 .29Azi) Wellpatb: Plan: C D3-1 14 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 13300 .00 90. 38 324 .94 6944 .47 6894. 87 2738 .32 -8602.35 6006682. 55 379550 .70 0.00 8773 .48 13400 .00 90. 38 324 .94 6943 .82 6894. 22 2820 .18 -8659.79 6006765. 25 379494 .49 0.00 8865 .08 13500 .00 90. 38 324 .94 6943 .16 6893. 56 2902 .03 -8717.23 6006847. 94 379438 .29 0.00 8956 .67 13600 .00 90. 38 324 .94 6942 .50 6892. 90 2983 .89 -8774.67 6006930. 64 379382 .09 0.00 9048 .27 13700 .00 90. 38 324 .94 6941 .84 6892. 24 3065 .74 -8832.11 6007013. 34 379325 .88 0.00 9139 .87 13800 .00 90. 38 324 .94 6941 ,19 6891. 59 3147 .59 -8889.55 6007096. 04 379269 .68 0.00 9231 .46 13900 .00 90. 38 324 .94 6940 .53 6890. 93 3229 .45 -8946.99 6007178. 74 379213 .48 0.00 9323 .06 14000 .00 90. 38 324 .94 6939 .87 6890. 27 3311 .30 -9004.44 6007261. 44 379157 .28 0.00 9414 .65 14100 .00 90. 38 324 .94 6939. 21 6889. 61 3393 .16 -9061.88 6007344. 14 379101 .07 0.00 9506 .25 14200 .00 90. 38 324 .94 6938. 55 6888. 95 3475 .01 -9119.32 6007426. 84 379044. 87 0.00 9597 .85 14300 .00 90. 38 324 .94 6937. 90 6888. 30 3556 .86 -9176.76 6007509. 54 378988. 67 0.00 9689 .44 14400 .00 90. 38 324 .94 6937. 24 6887. 64 3638 .72 -9234.20 6007592. 24 378932. 47 0.00 9781 .04 14500 .00 90. 38 324 .94 6936 .58 6886. 98 3720 .57 -9291.64 6007674. 93 378876. 26 0.00 9872 .63 14600 .00 90. 38 324 .94 6935. 92 6886. 32 3802 .43 -9349.08 6007757. 63 378820. 06 0.00 9964 .23 14700 .00 90. 38 324 .94 6935. 27 6885. 67 3884 .28 -9406.52 6007840. 33 378763. 86 0.00 10055 .83 14800 .00 90. 38 324 .94 6934 .61 6885. 01 3966 .14 -9463.96 6007923. 03 378707. 66 0.00 10147 .42 14900 .00 90. 38 324 .94 6933 .95 6884. 35 4047 .99 -9521.40 6008005. 73 378651. 45 0.00 10239 .02 15000 .00 90. 38 324 .94 6933 .29 6883. 69 4129 .84 -9578.84 6008088. 43 378595. 25 0.00 10330 .61 15100 .00 90. 38 324 .94 6932 .63 6883. 03 4211 .70 -9636.28 6008171. 13 378539 .05 0.00 10422 .21 15200 .00 90. 38 324 .94 6931 .98 6882. 38 4293 .55 -9693.73 6008253. 83 378482 .84 0.00 10513 .80 15300 .00 90. 38 324 .94 6931 .32 6881. 72 4375 .41 -9751.17 6008336. 53 378426 .64 0.00 10605 .40 15400 .00 90. 38 324 .94 6930 .66 6881. 06 4457 .26 -9808.61 6008419. 22 378370 .44 0.00 10697 .00 15500 .00 90. 38 324 .94 6930 .00 6880. 40 4539 .12 -9866.05 6008501. 92 378314 .24 0.00 10788 .59 15600 .00 90. 38 324 .94 6929 .35 6879. 75 4620 .97 -9923.49 6008584. 62 378258 .03 0.00 10880 .19 15700 .00 90. 38 324 .94 6928 .69 6879. 09 4702 .82 -9980.93 6008667. 32 378201 .83 0.00 10971 .78 15800 .00 90. 38 324 .94 6928 .03 6878. 43 4784 .68 -1.Oe04 6008750. 02 378145 .63 0.00 11063 .38 15900 .00 90. 38 324 .94 6927 .37 6877. 77 4866 .53 -1.Oe04 6008832. 72 378089 .43 0.00 11154 .98 16000 .00 90. 38 324 .94 6926 .71 6877. 11 4948 .39 -1.Oe04 6008915. 42 378033 .22 0.00 11246 .57 16100 .00 90. 38 324 .94 6926 .06 6876. 46 5030 .24 -1.Oe04 6008998. 12 377977 .02 0.00 11338 .17 16200 .00 90. 38 324 .94 6925 .40 6875. 80 5112 .10 -1.Oe04 6009080. 82 377920 .82 0.00 11429 .76 16300 .00 90. 38 324 .94 6924 .74 6875. 14 5193 .95 -1.Oe04 6009163. 51 377864 .62 0.00 11521 .36 16400 .00 90. 38 324 .94 6924. 08 6874. 48 5275 .80 -1.Oe04 6009246. 21 377808 .41 0.00 11612 .96 16500 .00 90. 38 324 .94 6923. 43 6873. 83 5357 .66 -1.Oe04 6009328. 91 377752. 21 0.00 11704 .55 16600 .00 90. 38 324 .94 6922. 77 6873. 17 5439 .51 -1.Oe04 6009411. 61 377696. 01 0.00 11796 .15 16700 .00 90. 38 324 .94 6922. 11 6872. 51 5521 .37 -1.Oe04 6009494. 31 377639. 80 0.00 11887 .74 16800 .00 90. 38 324 .94 6921. 45 6871. 85 5603 .22 -1.Oe04 6009577. 01 377583. 60 0.00 11979 .34 16900 .00 90. 38 324 .94 6920. 79 6871. 19 5685 .08 -1.Oe04 6009659. 71 377527. 40 0.00 12070 .94 17000 .00 90. 38 324 .94 6920. 14 6870. 54 5766 .93 -1.Oe04 6009742. 41 377471. 20 0.00 12162 .53 17100 .00 90. 38 324 .94 6919. 48 6869. 88 5848 .78 -1.Oe04 6009825. 11 377414. 99 0.00 12254 .13 17200 .00 90. 38 324 .94 6918. 82 6869. 22 5930 .64 -1.Oe04 6009907. 80 377358. 79 0.00 12345 .72 17300 .00 90. 38 324 .94 6918 .16 6868. 56 6012 .49 -1.Oe04 6009990. 50 377302. 59 0.00 12437 .32 17400 .00 90. 38 324 .94 6917 .50 6867. 90 6094 .35 -1.Oe04 6010073. 20 377246. 39 0.00 12528 .91 17500 .00 90. 38 324 .94 6916 .85 6867. 25 6176 .20 -1.1e04 6010155. 90 377190 .18 0.00 12620 .51 17600 .00 90. 38 324 .94 6916 .19 6866. 59 6258 .06 -1.1 e04 6010238. 60 377133. 98 0.00 12712 .11 17700 .00 90. 38 324 .94 6915 .53 6865. 93 6339 .91 -1.1e04 6010321. 30 377077 .78 0.00 12803 .70 17800 .00 90. 38 324 .94 6914 .87 6865. 27 6421 .76 -1.1e04 6010404. 00 377021 .58 0.00 12895 .30 17900 .00 90. 38 324 .94 6914 .22 6864. 62 6503 .62 -1.1e04 6010486. 70 376965 .37 0.00 12986 .89 18000 .00 90. 38 324 .94 6913 .56 6863. 96 6585 .47 -1.1e04 6010569. 40 376909 .17 0.00 13078 .49 18100 .00 90. 38 324 .94 6912 .90 6863. 30 6667 .33 -1.1e04 6010652. 10 376852 .97 0.00 13170 .09 18200 .00 90. 38 324 .94 6912 .24 6862. 64 6749 .18 -1.1e04 6010734. 79 376796 .76 0.00 13261 .68 18300 .00 90. 38 324 .94 6911 .58 6861. 98 6831 .03 -1.1e04 6010817. 49 376740 .56 0.00 13353 .28 18400 .00 90. 38 324 .94 6910 .93 6861. 33 6912 .89 -1.1e04 6010900. 19 376684 .36 0.00 13444 .87 ~~~~~ ConocoPhillips Al k In~ as a, CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/18/2007 Timer 14:22:27 Page: 6 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD3-114, True North Site: Alpine CD3 Vertical (TVD) Reference: Plan: CD3-114 49.6 Well: Plan: CD3-1 14 Section (VS) Reference: WeII (O.OON,O.OOE,301. 29Azi) Wellpath: Plan: CD3-1 14 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comore t ft deg deg ft ft ft ft ft ft deg/100ft ft 18500.00 90.38 324.94 6910.27 6860.67 6994.74 -1.1e04 6010982.89 376628.16 0.00 13536.47 18600.00 90.38 324.94 6909.61 6860.01 7076.60 -1.1e04 6011065.59 376571.95 0.00 13628.07 18601.70 90.38 324.94 6909.60 6860.00 7077.99 -1.1e04 6011067.00 376571.00 0.00 13629.62 CD3-114wp02 T Targets Map Map <--- Latitude ---> <-- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft CD3-1 14wp02 T3 6909.60 7077.99 -11647.69 6011067.00 376571.00 70 26 19.248 N 151 0 23.313 W CD3-1 14wp02 T1 6924.60 529.58 -7051.63 6004451.00 381068.00 70 25 14.903 N 150 58 8.231 W CD3-1 14wp02 T2 6959.60 856.20 -7281.58 6004781.00 380843.00 70 25 18.113 N 150 58 14.984 W Annotation MD TVD ft ft 600.00 600.00 KOP; 2 DLS 1000.00 998.70 Build; 3 DLS 2454.19 2230.19 Sail; 52° for 6431' 2727.72 2400.00 9 5/8" csg; 2727' MD, 2400' TVD / 8885.77 6222.99 Build; 3.5 DLS 10599.39 6924.60 7" csg; 10600' MD, 6924' TVD 11000.64 6959.60 T2 18601.70 6909.60 TD Casing Points MD TVD Diameter Hole Size Name ft ft in in 2727.72 2400.00 9.625 12.250 9 5/8" 10599.39 6924.60 7.000 8.750 7" 18601.70 6909.60 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction. ft ft deg deg 1256.97 1250.00 Base Permafrost 0.00 0.00 2606.91 2325.00 C-40 0.00 0.00 2863.03 2484.00 C-30 0.00 0.00 3483.18 2869.00 C-20 0.00 0.00 5124.58 3888.00 K-3 0.00 0.00 5353.31 4030.00 K-3 Basal 0.00 0.00 5393.58 4055.00 K-2 0.00 0.00 5565.94 4162.00 K-2 Basal 0.00 0.00 7664.80 5465.00 Albian 97 0.00 0.00 8334.89 5881.00 Albian 96 0.00 0.00 9549.67 6595.00 Top HRZ 0.00 0.00 9732.86 6679.00 Base HRZ 0.00 0.00 9848.88 6727.00 K-1 0.00 0.00 9954.64 6767.00 Top Kuparuk D 0.00 0.00 10072.07 6807.00 Top Kuparuk C 0.00 0.00 10081.49 6810.00 LCU 0.00 0.00 10081.49 6810.00 Top Nuigsut 0.00 0.00 10181.78 6840.00 Base Nuiqsut 0.00 0.00 10535.43 6916.00 Top Nechelik 0.00 0.00 0.00 Base Nechelik 0.00 0.00 ~~~~~~ ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 1/18/2007 Time: 13:59:23 Page: 1 Field: Colville River Unit Reference Site: Alpine CD3 Co-ordinate(NE) Reference: Well: Plan: CD3-114, True North Reference Well: Plan: CD3-114 Vertical (TVD) Reference: Plan: CD3-114 49.6 Reference Wellpath: Plan: CD3-114 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD3-114wp02 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 36.30 to 18601.70 ft Scan Method: Trav Cylinder No rth Maximum Radius: 2056.54 ft Erro r Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 2727.72 2400.00 9.625 12.250 9 5/8" 10599.39 6924.60 7.000 8.750 7" 18601.70 6909.60 4.500 6.125 41/2" Plan: CD3-1 14wp02 Date Composed: 1/ 18/2007 Version: 7 Principal: Yes Tied-to: From Well Ref. Point Summary G___________________ Offset Wellpath -------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD3 CD3-108 CD3-108 V14 273.48 275.00 122.00 5.00 117.00 Pass: Major Risk Alpine CD3 CD3-109 CD3-109 V5 424.93 425.00 101.49 8.45 93.03 Pass: Major Risk Alpine CD3 CD3-110 CD3-110 V11 324.87 325.00 81.71 6.22 75.49 Pass: Major Risk Alpine CD3 CD3-111 CD3-111 V7 624.23 625.00 53.38 11.85 41.53 Pass: Major Risk Alpine CD3 CD3-111 CD3-111 L1 V1 624.23 625.00 53.38 11.85 41.53 Pass: Major Risk Alpine CD3 CD3-112 CD3-112 V3 624.19 625.00 33.08 10.61 22.46 Pass: Major Risk Alpine CD3 CD3-302 CD3-302P61 V11 249.20 250.00 240.71 4.54 236.17 Pass: Major Risk Alpine CD3 CD3-302 CD3-302P62 V6 249.20 250.00 240.71 4.54 236.17 Pass: Major Risk Alpine CD3 CD3-302 Plan: CD3-302 VO Plan: 249.20 250.00 240.71 4.65 236.06 Pass: Major Risk Alpine CD3 CD3-307 CD3-307 V4 375.01 375.00 143.46 7.46 136.00 Pass: Major Risk Alpine CD3 CD3-307 Plan: CD3-107 V4 Plan: 375.01 375.00 143.46 7.57 135.89 Pass: Major Risk Alpine CD3 Plan: CD3-106 Plan: CD3-106 V2 Plan: 250.99 250.00 160.70 5.14 155.57 Pass: Major Risk Alpine CD3 Plan: CD3-113 Plan: CD3-113 V4 Plan: 649.86 650.00 20.14 13.82 6.32 Pass: Major Risk Alpine CD3 Plan: CD3-113 Plan: CD3-113P61 V5 PI 649.86 650.00 20.14 13.82 6.32 Pass: Major Risk Alpine CD3 Plan: CD3-115 Plan: CD3-115 V1 Plan: 426.00 425.00 20.10 7.89 12.21 Pass: Major Risk Alpine CD3 Plan: CD3-116 Plan: CD3-116 V1 Plan: 226.00 225.00 40.10 4.14 35.96 Pass: Major Risk Alpine CD3 Plan: CD3-117 Plan: CD3-117 V1 Plan: 226.00 225.00 60.08 4.14 55.93 Pass: Major Risk Alpine CD3 Plan: CD3-301 Plan: CD3-301 V2 Plan: 424.74 425.00 261.40 8.97 252.43 Pass: Major Risk Alpine CD3 Plan: CD3-301 Plan: CD3-301 P61 V4 PI 424.74 425.00 261.40 8.97 252.43 Pass: Major Risk Alpine CD3 Plan: CD3-303 Plan: CD3-303 V5 Plan: 348.80 350.00 220.54 7.20 213.34 Pass: Major Risk Alpine CD3 Plan: CD3-303 Plan: CD3-303P61 V2 PI 348.80 350.00 220.54 7.09 213.45 Pass: Major Risk Alpine CD3 Plan: CD3-304 Plan: CD3-304 V3 Plan: 348.80 350.00 200.52 7.18 193.34 Pass: Major Risk Alpine CD3 Plan: CD3-305 Plan: CD3-205 V1 Plan: 250.99 250.00 180.57 4.56 176.00 Pass: Major Risk Alpine CD3 Plan: FN-21 Plan: FN-21 VO Plan: F 362.10 325.00 80.20 6.64 73.56 Pass: Major Risk GRAM ORIGINAI- WELL uETAU-S ANTII:OLLISION SETTMGS COMPANY UF:fAILS .N'-S vF/•W NoMing Easing L"Um4e LongimUe Slor Inlerpola(wn MethodMD Interval. 25 00 CrnocuPhillips Alaska Inc. Ihplh Range From 36.30 To IX6UI 70 f'ngi""""g CDI-111 -]6.60 -l]6.7J 6003815 P4 388110.30 7U`25'09.727N ISU`Sd'dl 43tlW N:A Maxrmw3Rwge 205654 Reference Plan CD3-114)rp(12 From Colour To MD 36 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 16000 I assn lawn 75 50 CaIwlaUan Mcrhd. Minimum Curr-amrc Error Swkm ISC WSA Swn Mcrhwl. Tnv CrlinJer Nre16 Err"r Sur(as:c Elhplical ~ Camng Wuming Mclhd. Rulez Basin m: CD3-106) tPD3~s (Plan- fleyW Fm UmN To have> rim tl IadpOx )'I la"9 o" leml r" elma~viluay9z )~ From Colour To MD 36 250 ~Sn 500 7S0 1000 1250 1500 1750 2000 16000 16250 16500 16750 18250 18500 i 18750 19000 25000 'Ian: CD3-113 (Plan: CD3- Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [30fUin] CDi-IOX ICDI-108). Maior Risk CU1-109 (CU1-109), Maior Risk CD3-I 111 (CDI-1101-Myor Rivk CUl-III tC'U3-1117. Major Risk CD3-III (CDI-I I II.I). Melor lLak CD?-1121CD3-112). Major Risk CD3-302 (CDI-?021'HI). Mayor Risk CD3-3U21CD3-lU2PH21. Major Risk CD3-in2 (Plan CD3-302). Myor Risk CD3-3u71CUl-)0]), Maior Rut CD?-307 (Plan l'D3-10'/). Maior Risk Plua..CU3-IOG IPImr CD3-106). Major lLsk Plmrt-D1-113 (PIm. CDI-II?). Mater Risk LEn ET'D Plan CDi-113 (Plan.CD?-11?Pfil). Mayor Rrsk Plan CD3-115 (Plan CDJ-115), Major Risk Plm CD3-116 (PIav.CD3-116). Major Risk PIwCD3-II](Plan .CD3-117), Major Risk Plan CD3-301 (Plan. CD3-?01). Major Risk PImr.CDJ-301 fPlan .CD3-3111 P[31 ), Major Risk PImCDl-30?(Plan CD?-30?). Mepr Risk Plmr'.CU1-303 (Plan. CD3-303PBI). Major Risk Plan CDl-3U4 (Plan l'D1-304). Mayor Risk Plan. CD3-305 (Plan. CU3-205), Major Risk Plan. FN-21 (Plan-. FN-21). Major Rssk Plw. CD3-114 C'DI-114vp02 Sec MU Inc Azi l VD 1 36 30 0 DO 0 00 36.30 z ena on aoo 0 0o Goo no 3 1000.00 R.00 26]00 99%.70 4 2454.19 51 62 26] 93 2230 19 5 NR%5'!7 5162 26793 622300 6 10599 39 83 00 321 85 6924 60 7 IUfi15.20 X155 324.X3 G')2G 45 8 1083002 BJ 55 324 8i 6950 57 9 IIVUU.Gq 9018 12494 6959 G0 10 18601 70 YO 38 124 94 6909 GO 33'Ei)rAm uerws Twl PWcfV3-114 ) Daym 19 ~ "" ~ "~"'~{ ~""- ua. flm'. m?-114 J9.60fl Rd O n 4'$CYan Qryv Ongm g~nv~ef .angk •N's ~E'-M' Fr®1'SD 3012P 000 000 3430 SECTION DETAILS +N'-S ~E'-W DLeg TFme VSce Targct 0 00 U.00 0 00 0.00 0.00 000 0.00 000 OIXI 000 -146 -2'/.R6 2.00 26'/.00 2304 -2863 -]1294 i00 106 GI149 -21043 -5771.]fi OOU U.IXI 4823.Itl S2') 58 -70SI 61 ? 50 73.85 6301 24 CD3-114zvp02 TI 54242 -70G06R 3.SU -2.49 61I5.W ]IG )1 -]18363 000 0.00 651132 SSG 1U -]28158 60U UY3 666736 CU3-I l4xpo2 T2 707]99 -1164]69 0.00 0,00 IIG29 fit CD3-114ap02 T) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75fUin] Closest in POOL Closest Approac h: Reference Well: CD3-114wp02 Plan Offset Well: CD3 -113 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. ! _ Depth Angle TRUE Azi. ND E(+)/W(-) (301.29°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (301.29°) Comments POOL Min Distance POOL Min Distance J (2113.78 ft) in POOL (2113.78 ft) in POOL (10599 - 18601 MD) t (10599 - 18601 MD) t CD3-113 (9318 - CD3-114wp02 Plan 13.78 10599 83 324.8 6875.048 6004447 381067.3 6298.756 9341.67 MD) 9341.67 83.87 328.36 6857.986 6005312 382996 5126.047 (9318 - 9341.67 MD) sest Approac h: Reference Well: CD3-114wp02 Plan Offset Well: CD3 -112 Coords. - Coords. - ASP ASP -D ctr-ctr '. Meas. Incl. Subsea N(+)/S(-) View VS Meas. Ind. Subsea N(+)/S(-) View VS Min. Dist _ Depth Angle TRUE Azi. ND E(+)/W(-) (301.29°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (301.29°) Comments POOL Min Distance POOL Min Distance (4174.68 ft) in POOL (4174.68 ft) in POOL (10599 - 18601 MD) t (10599 - 18601 MD CD3-112 (8511 - CD3-114wp02 Pla 4174.68 16186 90.38 324.9 6875.669 6009064 377924.3 11416.55 16021 MD) 14361 89.84 324.8 6845.162 6011423 381368.4 9755.936 (8511 - 16021 MD) CD3-114wp02 POOLSummary (rev 3-2-07).xls 3!212007 2:28 PM • • ~~~,~, :. ~~',;~ y~ _... ° K , ~~ ~ o o N ~~ ~.:~ F ' ~~` ~ i' - ^Ya c_ j .~s a: ~ s e. 4S . ~ '...~ ~ ~ i ~ ~ ~ ~ a y _ ~_ N i 07 d ~ N O N C!1 n V' I __..... - N ~`D f~N 16 O z o> a - W~i~ O W ~ N ~ ______-_ ._ ......... ..... ....__ ___._. ..__ ......._ ___... . ;_. __. _____._.. O C7 Q O t0 l0 Z ~ - Q °amrn ! fit; i~ (1 N fD tD k~ ~ C ¢~ Q N 0/ O I~ M I~ ~ ~ O O O ......... GI ......_ _.___ ._._ ---~_. __._._.... ......... .. ___- ...... :... ...... .... .......__ ~ O N N O COD = / \~ + T r p P N M C i O I1 n \ ~i W W Z ~ ~ ~ ~ ~ W !~„ , m 0 ~ _. --_ N ~ I . ~ C V C m ~ ~- ~ xa N r r v .........___ - ....._.. ......... .. .......... ....... .__ _____- .... ..... ...____ __- ........._ -- ` ~ MM a rJy yM O O ~ m a m Q N R r w ii ~ a M ~ o ~~ N . ~~~ w m o i v ; ; ~~, ~ ~ O a` ~Y>X - - _ __ .. P _...._ O _- "add ~ ~~ G ~ J ~ j r CR Z ~ ~~-~~ i cNri Y O ~ ~ i.L O ~~ ~ ~ ~ ...._..... ........__ _.. _.._...... ~ ~ ~ I \x j / O i O ~ ~ ~ 0 ° ~ L 0 O 0 O O O O N ~ 0 0 C O V ) ~p ~-) ~p ) ( + 43 43 ~~!/31 OOOZ N/ S ~~~ • • Z 0 0 ~ a0 N N_ ~ ~ O ~ V ~`O f~N t0 ~ In Z rn cT Q ~/~0C4 ?Q OD Lll F-' N O O D (fl U Q O ~ O Z O (D (D ~ ~ O N O Q U N co cfl M 0 ~ O r N W O f~ ~ (O N 000 O ~~ Z ~ N M u: 3S .C ~ ~ N Y y ~ M M Q ¢ >oo0 ~UUU , 3 ° accc .. N N `r { ~~ Qao_ ~ U ~'v~~n c ~wo~ '~°~~ d 0 a ~ a I ~ ~~ai ~ i ~ff~~ 3' ~n ~ z'~ ~/} ~ ~`~ z ~~ ~ °~ ~ o ~' ~ = a W m~ ~OI. i~~, -o ~ ~ - ~~~~ • • ~ SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS AT0 1530 700 G ST. °~ ANCHORAGE AK 99501 _ PAY TO THE ~ "!t"i OI ~ L~S~~ ~~~~ ORDER OF //// , - ~~,p ~ ~ /// - - -- 1175 ~~ 7~ DATE ~ ~/ ~1551i441 ~~~ ~~p miss DOLLARS ~ ~.~a~~ J PMorganCllase ~ ~ Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH MEMO -- ---~---~~'~~~~~- --- ~--- ~:044LL55LL~:528747L90792711•LL75 • '~'12Ai~(S1d~I1~"~'AL ~LDE~/T~'E~ ~t CHECKLIST' `YELL YAIVIE ~~y[ (.dam ~ ~' ~~~ PTD# 20 ~ - t~ 3 3 Development Service Exploratory Stratigraphic Vest Yon-Conventional Wel[ Circle Appropriate Letter /Paragraphs to be Included is Transmittal Letter CHECK I ADD-ONS ! TEXT FOR APPROVAL LETTER Vb'HAT i (OPTIONS) APPLIES ~ ~ ' ' I MliLTt LATERAL ~ ~ ~ The permit is for a new wellbore segment of existing i well ~ (If last two digits in I Permit No. , API No. ~0- - - i API number are I ;between 60-69) Production should continue to be reported as a function of the i original API number stated above. PLOT HOLE --i [n accordance with 20 AAC 25.00~(f), all records, data and logs ~ ;acquired for the pilot hole must be clearly differentiated in both II! ! i ;well name ( PH) and API number f ' (50- - -_~ from records, data and logs ~ ! ~ acquired for well f ~ SPACING The permit is approved subject to full compliance with 20 AAC ~ EXCEPTION ! 2~.0». Approval to perforate and produce /inject is contingent ~ i ; I upon issuance of a conservation order approving a spacing i I exception. assumes the ~ liability of any protest to the spacing exception that may occur. ~ DRY D[TCH ~ AI[ dry ditch sample sets submitted to the Commission must be in i SA!VIPLE i no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j ,' ~ through target zones. ;Please note the following. special condition of this permit: jNon-Conventional i production or production testing of coal bed methane is not allowed ! Well ~ for (name of well) until after (Companv Name) has designed and ! implemented a water well testing program to provide baseline data ! on water quality and quantity. (Companv Name) must contact the ~ Commission to obtain advance approval of such water well testing program. i Rev: 12~r'06 C .^jody~transmittal_checkl ist • ~ ~i n : : N ~, p : _d N O O ~ ~ : a • ~ - N ~: ~ ~ ~, ~ N. 6: Q' C, ° ~ C. m. ~ ~ ~ ~ ~ ~ ~ to o ~ C. o '~ a c ~ ~. , an ~ : , ~ rn I O ~ = o .:: ~ ~ U ~ o N ~ 0 ~ ~ ~ C1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ 0 ~ ~ i c ~ O: C. N w to M -`0 3: o: ~ ~' '~ °o ° ~iu, 3. O ~ E O ~ ~ Q. , U, o ~ O. ~: ~ N v' c ~ ~ I I : ~ ~ ~ o Q n a N~ d -a' M o m o. ~ ~ O ~ °' a o ~, : O a' c' ° N ~ _ ~ ~ : : : ~: : - y O ~ O. ~ ~ ~ ~ ~ ~ ~ ~ N ~ U~ c, O, O ~ ~ ~~ ~ _~ O t d ~ w~ ~~ ~ ~ N N Ul. ~ N O: ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ : O. Q ~ ~ ~ ~ ~ O: T3 N ~ ' ~ ~' t. N. ~ p: U, ~ -O~ ~ d ~~ ~ Or Ul, 'O (6 ~: ~, 3: O: O: ~ ~: i ~ m : ~: O: ~: y: N: Z: ~ M: ~, ~ N' ~~ c V V ~ x ~~ ~ __ O _ O N' C co ~ O ~: ~: ~: n ~ ~ Q. ~: Q, ~: Q rn w: -a: o. ° c a 3' o a ~ o ~: ~ m. '~ ~ ~ ~ r ~ o: c °: .~ d ar upi ~ °o ~ ° ~ a: ~~ ~: ~ ~: -: _ °: 0 ~ ~ ~ o, °: ~: m: ~ =o: ~~ N' °°' ~: ~ 0 y: a: c U ~ O ~ ~ ,~ i ~ o ~: m' ~ , 4 : ~ U d o, °, ~ c: ~ ~~ _ N: ~: ~: : C: : ~~ O C: d ~ ~ G• ~ O: N ~ O1 ~ 41: ' Q N: ~: ~: - y, f6 - ' ,~ Q , ' ~ ~ ~' ' c: i' o mo -o: c ' 3 LL ~ : ~~ m ~ C c U! c M > C~ ~~ ~ ~ ~ ~, ~ ~ ~ o Z.. ~ ~ ~~ O r o ~~ O, ~, N, ~ N: ~ o N, y > ~ Q' J U• ~~ ~ ~ 3 ~ ~ ~ ~ i ~ ~ O' : ' a °~ ~ -o H~ N~ d M: ~ ~~ U' ~; f6. m ~~ O~ Z w C ,. . O- ~ O N~ : N ~ ~ . o. C: ~~ Z. O. ~ N ~ ~ ~ V~ ~ ~~ . v. (6 ~ W ~ ~~ ~~ M~ M: M~ ~ ~' ~ ~~ O U. p. o Q ~ ` O ~ ~ ~ N. O J ~ ~' ~~ p~ O~ O~ L' U N U~ ~. ~' ~ ~ V ~ 0 UJ~ 7~ a0 L~ N O ~ ~ O' ~ ~ ~~ O~ ~ ~ ~ ~ U• N. ~ Q N. , O, N , ~~ ~ N, O' ~ 3~ N ~ ~ W. ~ ~ >. y, ~ ~ ~~ ~ U. ~ O' m. o< ~ 'N, ~ ~ ~ : O: N. ~:i N. O: N~ N Q o ~: c, c: c d -: a~ ~. ~ Q. Q, o: n m, >, 4 '~ : o: m: ° d ui o o, o, o, o. c. ° o. ~ n ~ o ~ °~ ~ E N ~ ~ ~$' J' f6' f0' (6' `p~ N. ~ ~ N~ `~~ ~~ ~ U, ~: ~ ~~ ~ w ~~ ~: ~ ~: ~ T C~ N' d a: U' N tOq ~: ~: : , : : _: O : : O: ~ ~ "6 : ~, ~: ~, ~ : ~' L: : O: tll: O: ~ N ~ ~~ ~ J~ C ~ C ~ C ~ N• -: ~ M ~ O O C "O. a ~ O~ , ~. C N' ~ ~ , X, O, .x: . O U, -: ~, ~ ~, U, Q L' C f6 Z w~ a ~ T ~ (/)~ O' O' U' U' O• U' O' U' ~~ >: N' >: ~ '~ ~ ~ ~ . Q' O' M. ~ i Z~~ N: ~ O ~ Z, __ ~ Q U ~ O) ~~ ~ O: >~ N• d ~~ ~~ Q• N: N' t, ~~ ~: ~ ~, ' O' Z: W X' O, =p~ W~ Z: O O v : ~ : ; ~ ; O y~ N~ N, N, y: N~ N~ N, N, N, N~ N, N~ N, N~ y~ N, N, ~~ N~ N, N, N~ N N, N N• N, y. N~ N, N, Q,i y: ~ N• N, Q, N, ~ O, O, N O, N N, Q N, : f/A N, Q, N, f/D N. N~ N~ O, O N, N, N, N, O O Q Q Q d T ~ r,r r,r,r ; r r r,r, r r r,r r, r,r z r zr z z r r, z r,z r, r,r,r,r zr, r, r, z,z, z A_ '"~ o ~ 1 O - ~C . ~ ~ ~ ~ ~ ~ : : ~~ 3 ~ ~ ~ ~ , U ' ~ qk~ N I ~ ~ ~ : ~ ~ ~ ~ ~ ~ ~ ~ U O N O: O: ~: . >i: p. : p. a~: ~ ~ ~ ~ O: Z: ~: ~: ~I N Q~ ~ O ~ : ~: O: ~ ~: I/~` h\ O I ~ ~ ~ ~ ~ ~ f6. ~: ~ ~ j. N. c N~ N: ~ ~ ~ U ~ : ~ Q ~ N. i0: O. ~ ~ O: O: ~ N: ( ~: ~ ~ O. N: A~U ~ ~ 3 C, 7 O ~ ~ . O: N. ' ~: .N: ~: a: O' y: O: O: O• , ~ t6 c >: : N: W ~, 3: ~~ C o. '~ 3 a a' ° o: ~ ~ o .N: a ~ O o. - ~ a ~ o ~ O a. ~ N > c ~. ~ ~' is ~ >. -o ~ m 4 ' a ° 0' ~ o' ~ m ~ o ~: a, ~ o m M' v' O. ~ r w ; ~ ~ ~, ~ a~' o . . W Z -a o' c: ~ o: , :c . • . s d ~ o. c a~' ~ , 0.' ~ : Q J ~ ~ ~ ~ E~ E, U. ,C, C E~ r f6. N, O M C' C N ~-' ~ c O ~~ w~, ~; c~ ~~ O~ ~' N t Q: p C ~1~ , N '~ '~ ~ ` °: (4 J ~ O i - O~ ~ O: U. 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W n ~ _ ~ O ~- N M V ~ CO I~ W O r O ~ ~ N M ~ ~ V ~ ~ CO f~ ~ ~ ~ O O O r r N ~- N N N M N V N ~ N c0 I~ 00 N N N r m O N M I M M N M M M to M O r 00 M M M O M U U _. _.____~.___. . _ -..__ _. _- __. _.__ __ ~ F- o 0 0 O ~ ~ r O f6 N ' w f0 O _N w O f6 N U ~ N M 0 ~ .. C57 0 O ~ \ O y W O fL6 M ~ C M M p' ~ O N ~ ~O ~'' N i' ~ U O Q ~ ~' ~ Q ~ ;~ 0 O. 0 U a s Q cn ~. ' w a H 0 ~' c7 Q cn Well History Fife APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Wetl History file and to simplify finding information, information of this nature is accurnulaled at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. cd3-114.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed May 30 09:33:03 2007 Reel Header Service name .............LISTPE Date . ...................07/05/30 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/05/30 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Scientific Technical Services scientific Technical services CD3-114 501032054400 ConocoPhillips Alaska, Inc. Sperry Drilling Services 30-MAY-07 MWD RUN 2 MWD RUN 3 W-0004959675 w-0004959675 E. QUAM T. MCGUIRE L. HILL D. MICKEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 5 12 5E 1320 933 50.05 13.30 Page 1 ~~j~ -033 ~' t5t ~s9 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE BIT SIZE (IN) 8.750 6.125 cd3-114.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 2892.0 7.000 10627.0 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 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GEOPILOT ROTARY STEERABLE BHA (GP), AND PRESSURE WHILE DRILLING (PWD). 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 REPRESENT WELL CD3-114 WITH API#: 50-103-20544-00. THIS WELL HAS A TOTAL DEPTH (TD) OF 18042'MD/6884'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 (SEDP). File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER Page 2 • FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD FET RPS RPM RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 2868.0 2880.0 2880.0 2880.0 2880.0 2880.0 2902.0 cd3-114.tapx STOP DEPTH 17985.0 17992.0 17992.0 17992.0 17992.0 17992.0 18042.0 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 2868.0 10639.0 MwD 3 10639.0 18042.0 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 2868 18042 10455 30349 2868 18042 RPD MWD OHMM 0.2 2000 13.3665 30225 2880 17992 RPM MWD OHMM 0.25 2000 11.873 30225 2880 17992 RPS MWD OHMM 0.24 1155.97 10.1964 30225 2880 17992 RPX MWD OHMM 0.31 1152.55 9.32354 30225 2880 17992 FET MWD HOUR 0.15 155.96 1.15492 30225 2880 17992 Page 3 • cd3-114.tapx GR MWD API 22.87 400.08 81.4565 30235 2868 17985 ROP MWD FT/H 0.93 409.7 126.947 30281 2902 18042 First Reading For Entire File..........2868 Last Reading For Entire File...........18042 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/30 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.......07/05/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2868.0 FET 2880.0 RPx 2880.0 RPS 2880.0 RPM 2880.0 RPD 2880.0 RoP 2902.0 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: header data for each bit run in separate files. 2 .5000 STOP DEPTH 10605.0 10597.0 10597.0 10597.0 10597.0 10597.0 10639.0 25-MAR-07 Incite 74.11 Memory 10639.0 2902.0 10639.0 48.6 83.2 Page 4 • TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA ELECTROMAG. BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): cd3-114.tapx RAY RESIS. 4 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 TOOL NUMBER 149206 228269 8.750 2892.0 Fresh water Gel 9.80 37.0 9.2 550 7.7 2.400 72.0 1.230 147.2 2.200 72.0 1.500 72.0 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 2868 10639 6753.5 15543 2868 10639 RPD MWD020 OHMM 0.2 1700.97 6.00095 15435 2880 10597 RPM MWD020 OHMM 0.25 469.68 5.40407 15435 2880 10597 Page 5 • i cd3-11 4.tapx RPS MWD020 OHMM 0.24 106.7 5.15112 15435 2880 10597 RPX MWD020 OHMM 0.31 85.37 5.04946 15435 2880 10597 FET MWD020 HOUR 0.15 52.28 0.612908 15435 2880 10597 GR MWD020 API 36.46 400.08 114.15 15475 2868 10605 ROP MWD020 FT/H 0.93 409.7 159.99 15475 2902 10639 First Reading For Entire File..........2868 Last Reading For Entire File...........10639 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/30 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.......07/05/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 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 10597.5 17992.0 RPD 10597.5 17992.0 RPM 10597.5 17992.0 FET 10597.5 17992.0 RPS 10597.5 17992.0 GR 10605.5 17985.0 RoP 10639.5 18042.0 LOG HEADER DATA DATE LOGGED: 05-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 18042.0 TOP LOG INTERVAL (FT): 10639.0 BOTTOM LOG INTERVAL (FT): 18042.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 6 • • cd3-114.tapx MINIMUM ANGLE: 83.0 MAXIMUM ANGLE: 93.7 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): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 Name Service Order DEPT RPD MWD030 RPM MWD030 RPS MWD030 RPX MWD030 FET MWD030 GR MWD030 ROP MWD030 Name Service Unit TOOL NUMBER 160788 156401 6.125 10627.0 Fresh water Gel 8.90 44.0 9.5 20000 4.6 .270 72.0 .130 158.0 .230 72.0 .400 72.0 units Size Nsam Rep code offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading Page 7 • cd3-114.tapx DEPT FT 10597.5 18042 14319.8 14890 10597.5 18042 RPD MWD030 OHMM 2.18 2000 21.0532 14790 10597.5 17992 RPM MWD030 OHMM 0.43 2000 18.624 14790 10597.5 17992 RPS MWD030 OHMM 0.27 1155.97 15.4617 14790 10597.5 17992 RPX MWD030 OHMM 0.38 1152.55 13.784 14790 10597.5 17992 FET MWD030 HOUR 0.38 155.96 1.72057 14790 10597.5 17992 GR MWD030 API 22.87 65.95 47.1795 14760 10605.5 17985 ROP MWD030 FT/H 2.66 146.08 92.4111 14806 10639.5 18042 First Reading For Entire File..........10597.5 Last Reading For Entire File...........18042 File Trailer service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/30 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.004 Physical EoF Tape Trailer Service name .............LISTPE Date . ...................07/05/30 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................5T5 LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date . ...................07/05/30 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services Page 8 ~ ConocoPhillipsq,a=,,, ~~~1, CJ33 • FINAL WELL REPORT ConocoPhillips Alaska, Inc. CD3-114 Sec 5 - T12N - RSE, UM North Slope, Alaska Approved by: Compiled by: Patrick Walker Jason Duncan March 25, 2007 C~ EPOCH r ~_ C~OCIOGOPh~~pS CD3-114 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT 8< CREW ..................................................................3 1.1 Equipment Summary .......................................................................................... 3 1.2 Crew .....................................................................................................................4 2. GENERAL WELL DETAILS .................................................................................... 5 2.1 Objectives ......................................................................................................... .. 5 2.2 Weil Resume ....................................................................................................... 6 3. DRILLING DATA ..................................................................................................... 8 3.1 Bit Record ........................................................................................................... 8 3.2 Mud Record ....................................................................................................... .. S 4. MORNING REPORTS ........................................................................................... 10 Enclosures: 2"=100' Scale Mudlog . 2"=100' Scale LWD Lithology Log 2"=100' Scale Drilling Dynamics Lag • C~ EPOCH • • COr1000P~~ipS CD3-114 MUDLOGGING EQUIPMENT & CREW 1.1 Eauipment Summary • Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM electric gas trap E-Series Flame Ionization Detection Total Gas and Gas Chromato ra h 0 Rate of enetration ROP Totco WITS Feed 0 Pum stroke counter SPM Totco WITS Feed 0 Hook Load (HLKD} /Weight on bit WOB Totco 1MTS Feed 0 Tor ue RTOQ To Drive Feed 0 To drive rota RPM To Drive Feed 0 Standpipe & casing pressure SPP/CSIP Totco Hydraulic pressure cell 0 Mud flow out FLO Totco Flow Paddle 0 Pit levels x 6 Ball Float sensors in all pits & trip tank 0 Mud logging unit computer system Com ac Pentium V 0 Geologist's workstation Totco workstation 0 Com an Man's workstation Totco workstation 0 Tool usher's workstation Totco workstation 0 Drilter's workstation Totco workstation 0 C~ EPOCH • ~ ~iPs CD3-114 1.2 Crew Unit Type Arctic Unit Number : ML.030 • Mudloggers Years .~ Days Geotechnicians Years Days Technician Days Trainees Days Patrick Walker 1.5 15 Rick Frederic 0.5 15 Steve Forrest 2 Jason Duncan 1.5 15 Daniel Lee 2 15 "' Years experience as Mudlogger "2 Days at wellsite between spud and total depth of well Additional Comments Two spare poly-flow gas lines were run through a heated umbilical to insure nonfreezing for the gas lines and rig air lines to the unit. The QGM gas trap was routinely Leaned of drilling mud and the gas lines blown back with rig air. ~1 EPOCH 4 ~~ COI'1000Ph~~~75 CD3-114 2. GENERAL WELL DETAl~S 2.1 Objectives ConocoPhillips Alaska spudded the CD3-114 on March 18, 2007 as a pre- producing horizontal injector weN targeting the Nechelik Sandstone approximately 2100' west of the offset producer CD3-113. The planned horizontal section was 8000'. The primary objective of the CD3-114 mud log is to fulfill a requirement of the Alaska Oil and Gas Conservation Commission of one complete mud log from surface down to the reservoir interval on the new CD3 Fiord drill site. A secondary objective was to evaluate the Qannik sandstone in the CD3 Fiord area. Mud logs near the CD3 drill site were acquired in the Fiord 5 and Fiord 1 wells. • • ~1 EPOCH 5 ~~~ CD3-114 2.2 Well Resume O erator: ConocoPhi#li s Alaska, Inc. Well Name: CD3-114 Weft T e: Fiord-Nechelik Horizontal In'ector Classification: Devela meat Network Number: 10165152 Field: Alpine Fiord) Location: 3690' FNL, 993' FEL Section 5-T21 N-RSE, UM Coordinates: Boron h: North Slo e State: Alaska Elevations: Pad 13.3' RRT 49.6' API Index: 50-103-20544-00 S ud Date: March 18, 2007 TD Date: Intermediate Hole Section March 25, 2007 Da s Driltin 8 Prima Tar et: Nechelik Secondary Ta et: Quannik T.D. Formation: Nechelik Contractor: Do on Drillin Com an Re resentatives: D. Burle , L. Hill, N. Woods Ri # / T e: 19 Arctic Tri le E~ EPOCH • • • Cor-aaa`PhiN~s cns-~ ~ a L in Unit: ML030 Mud T es: S ud Mud to 2,902' L.S.N.D to 10,639' Casin 16" 114' 9 518" 2,902' 7" 10,631' Hole Sizes 12 '/4 2,902' 8 3l" 10,639' Weti Status: Cam feted as re roducin !n'ector. ~ EPOCH • • • 3. DRILLING DATA 3.1 Bit Record COf1000E~(rpS CD3-114 Bit / Run Make Type Jets t Size Depth In ft Total Footage Bit Hrs Av. ROP ftlhr WOB (klbs) RPM PP (psi) Wear BHA 1 HC MXL-1 1X12, 2X16, 1X 1$ 12.25 114 2788 22.32 124 16 49 1435 4-5-WT-A-E-1-NO-TD #1 2 SDBS FSF2463 5 X 16/ 8.75 2902' 7737 55.75 139 17 118 2868 8-3 MT-10-X-I-BT-TD #2 E~ EPOCH • • • 3.2 Mud Retard Contractor: M-I Swaco Drilling Fluids Mud Type : LSND G0~1000IPIU~IflpS CD3-114 Activity Date Depth MW Vis PV YP Gels API FL Solids Oil/VNater Sand PH CI Ca P/U BHA#1 3/17/07 114 8.8 300 32 83 40/55/75 14.5 4 /96 0 9.3 500 40 Drillin 3/18/07 1836 9.1 300 11 72 66/72/74 13.6 5.5 /94 0 9.1 1000 40 POOH 3/19/07 2902 10.0 300 21 79 78/101/115 9.4 10 1/89 0.25 9.0 950 40 Test BOP's 3120/07 2902 9.9 52 27 15 5/9!12 8.6 9 1/90 0.25 9.0 800 40 Drillin 3/21/07 3400 9.7 38 7 15 7/10/10 11 7 1/92 TRC 10.4 700 52 Drillin 3/22/07 5760 9.8 40 10 17 6/10/12 6 9.5 2/89 TRC 9.5 500 60 Drillin 3/23/07 8333 9.8 37 8 17 7/10/11 7.7 9.5 1/90 TRC 9.2 550 40 Drillin 3124/07 10291 9.9 40 10 24 9/12!15 8.0 9.5 2189 TRC 9.5 600 60 E~ EPOCH • ~~PS CQ3-414 4. MORNING REPORTS Re ort for. D Bur1e L. Hill Time: Date: 3119107 4:76 Current Depth (MD): 2408' Current AM Operations: Current De th D 24 hr Foota a MD : 1906' Drillin Driltina Parameters ROP: Current: 123 Max: 328 To ue: Current: 7.0 Max: 27 WOB: Current 20 kb Max: 29.5 RPM: Current: 54 Max: 80 PP: Current: 1774 Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De h MD/TVD Rv BG : 0 0 t;as Fvenfs De th MD/TVD C1 C2 C3 C41 C4N C51 G5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N 32u 1,883' 6959.56 Gas Sam les No. De th MD/TVD TG C1 G2 C3 C41 G4N G51 C5N Litholo ies: Current: 90% cla stone, 10% sands Last 24 hrs: 75°to cla stone, 25% sands O erational Summa Dritt to 2408. Calibrations: Chromato ra h, THA. Failures: None Daily Cost: $2,790.00 ~ ~S~CH 10 ~~ CD3-114 ConocoPhillips Alaska Inc. CD3-114 Daily Report Re ort for. D. Burle L. Hill Time: Date: 3120/07 4:16 Current Depth {MD): 2902.00' Current Casing AM Operations: Current De th TVD : 2490.87 24 hr Foota a MD : 593' Drillinn Parameters ROP: Current: 0 Max: 621.5 Tor ue: Current: 0 Max: 8 WOB: Current 0 Max: 68 RPM: Current: 0 Max: 58 PP: Current: 0 Max: 2367 La Strokes: 3708 Time: 26.11 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud MW Change: Dep#h: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De th MDtTVD Av BG : 0 0 ryas Fvpnts De th MDITVD C1 C2 C3 C41 C4N C51 C5N Trip Gas 62u Connection Gases None C1 C2 C3 C41 C4N C51 C5N 32u Gas Sam les No. De h MDITVD TG C1 C2 C3 C4i C4N C51 C5N L~hologies: Current: 40°~ Claystone, 20% Sand, 10% Shale, 10% Siltstone, 20% Con lomeratelsand Last 24 hrs: O erational Summa Run Casin Calibrafions: Chromato ra h THA. Failures: None Daily Cost: $2,790.00 ~1 ~:I'OCH 11 • • COt1OC~OPf1~~P5 CD3-114 ConocoPhillips Alaska Inc. CD3-114 Daily Report Re ort for. D. Burle L. Hill Time: Date: 3/21107 4:16 Current Depth {MD); 2902.00' Gurrent Testing B.O.P. AM Operations: Curren# De th TVD : 2490.87 24 hr Foota a MD : 0' ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Surf-Surf; Strokes: Time: ECD: Current: Max: Drillin Parameters Mud MW Change: Depth: From; To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De h MDITVD Av BG : 0 0 Gas Events De th MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas 62u Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 40% Claystone, 20°1° Sand, 10°l0 5hale, 10% Siltstone, 20% Con lomerate/sand Last 24 hrs: O erational Summa : Testin B.O.P. Calibrations: Chromato ra h THA. Failures: None Daily Cost: $2,790.00 12 [~ EPOCH ~ CD3-114 ConocoPhiltips Alaska tnc. CD3-114 Daily Report Re art for: D. Burle L. Hitl Time: Date: 3122/07 3:16 Current Depth (MD): 4069' Current AM Operations: Drilling Current De th D 24 hr Foota a MD : 116T DriHin Parameters ROP: Current: 151 Max: 512 Tor ue: Current: 8.4 Max: 11 WOB; Current 9 Max: 665 RPM: Current: 116 Max: 129 PP: Current: 1765 Max: 2225 La Strokes: 1818 Time: 12.7m Surf-Surf: Strokes: Time: ECD: Current: Max: Mud MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De th MD/TVD Av BG : 26u 1000u 2940 De th MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas None Connection Gases G1 C2 C3 C41 C4N C51 C5N 192u 3419' 64877 2453 1276 334.97 384.25 719.22 268.143 Gas Events Gas Sam les No. De th MDITVD TG C1 C2 C3 C41 G4N C51 C5N Daily Cost: $2,790.00 13 ~ ~ ~H Calibrations: Chromato ra h THA. Failures: None • • ~~PS CD3-114 ConocoPhillips Aiaska inc. CD3-114 Daily Report Re ort for. D. Bur1e L. Hill Time: Date: 3/23/07 3:19 Gurrent Depth {MD): 6295' Current AM Operations: Drilling Current De th D 24 hr Foota a MD : 2226' ROP: Current: 172 Max: 318 Tor ue: Current: 9.6 Max: 21 WOB: Current 14.6 Max: 28 RPM: Current: 119 Max: 139 PP: Current: 2577 Max: 3064 La Strokes: 3091 Time: 21.7m Surf-Surf: Strokes: Time: ECD: Current: Max: Drillin Parameters Mud MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De th MDITVD Av BG : 83u Gas Events Depth C1 C2 C3 C41 C4N G51 G5N MDtCVD Trip Gas None Connection G1 C2 C3 C41 C4N C51 C5N Gases 1313u 5385' 197345.408 10553.274 5456.390 1004.214 2383.75 812.233 1006.887 Gas Sa les No. De th MD/TVD TG C1 C2 C3 C41 G4N C51 C5N Litholo ies: Current: 40% Sandstone, 20% Sand, 20% Siltstone, 10% Cla stone, 10% Shale. Last 24 hrs: O erational Summa Drillin Calibrations: Chromato ra h THA. Failures: None Daily Cost: $2,790.00 14 ~.P(?CH ~ CD3-114 ConocoPhillips Alaska Inc. CD3-114 Daily Report Re ort for. D. Burley L. HiN Time: Date: 3/24107 3:15 Current Depth (MD}: 8886' Current AM Operations: Drilling Current De th D 24 hr Foota a MD : 2591' Driilin Parameters ROP: Current: 163 Max: 333 Tor ue: Current: 12.8 Max: 15 WOB: Current 32 Max: 76 RPM: Current: 143 Max: 156 PP: Current: 3228 Max: 3633 La Strokes: 4694 Time: 30:48m Surf-SurF: Strokes: Time: ECD: Current: Max: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De th MD/TVD Av BG : 60u Gas Events Depth C1 C2 G3 C4l C4N C51 G5N MDITVD Trip Gas None Connection C1 C2 C3 C4l C4N C51 C5N Gases 104u 7098' 14646.190 1060.102 673.978 116.195 213.767 88.114 83.544 Gas Sam les No. De h MDlTVD TG C1 C2 G3 C41 G4N C51 C5N Litholo ies: Current: 30% Sandstone, 30% Sand, 30% Si{tstone, 10% Cla stone. Last 24 hrs: O erational Summa Driilin Calibrations: Chromato ra THA. Failures: None Daily Cost: $2,790.00 15 ~:POCH • Gorwco>~{~Pis CD3-194 ConocoPhillips Alaska Inc. CD3-114 Daily Report Re ort for. D. Burle L. Hill Time: Date: 3125!07 3:57 Current Depth (MD): 10639' Current AM Operations: Ntliper trip. Current De th D : 6925' 24 hr Foota a MD : 1753' Drilling Parameters ROP: Current: Max: 260 To ue: Current: Max: 16 WOB: Current Max: 121 RPM: Current: Max: 157 PP; Current: Max: 3873 La : Strokes: 6398 Time: 41.5m Surf-Surf: Strokes: Time: ECD: Current: Max: Mud MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De h MD/TVD Av BG : 84u 123u 9610'/6616' Gas Events Depth C1 C2 C3 C41 C4N C51 C5N MDlTVD Trip Gas Connection G1 C2 C3 C41 C4N C5( C5N Gases 112u 10530'/^6917' 18120.092 1042.634 689.131 120.800 270.51 91.584 91.555 Gas Sam les No. De th MDCfVD TG C1 C2 C3 C4i C4N C51 C5N Litholo ies: Current: 70% Sand, 20% Shale. Last 24 hrs: O erational Summa : Drill to 10,639' circulate bottoms u , wi r tri . Calibrations: Chromato ra h THA. Failures: None Daily Cost: $2,790.00 F,POCH 16