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Home My WebLink About200-017Originated: Delivered to:8-Sep-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 CD1-33 50-103-20357-00 908071484 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 26-Aug-22 0 12 CD1-35 50-103-20297-00 908071486 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 28-Aug-22 0 13 CD1-41 50-103-20328-00 908072045 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 29-Aug-22 0 14 CD2-02 50-103-20513-00 907988867 Colville River Multi Finger Caliper Field & Processed 12-Jul-22 0 15PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:CD1-33 PTD:200-212 T36990CD1-35 PTD:199-038 T36991CD1-41 PTD:200-017 T36992CD2-02 PTD:205-109 T36993Electromagnetic Pipe3CD1-4150-103-20328-00908072045Colville RiverXaminer Record (EPX-V)Field & Processed29-Aug-2201Kayla JunkeDigitally signed by Kayla Junke Date: 2022.09.09 09:43:03 -08'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Scale Inhibition ConocoPhillips Alaska, Inc. 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 11170 feet None feet true vertical 7082 feet None feet Effective Depth measured 11170 feet 7896 feet true vertical 7082 feet 6948 feet Perforation depth Measured depth 8,333'-11,170' feet True Vertical depth 7102'-7082' feet Tubing (size, grade, measured and true vertical depth)4.5" L-80 7985' MD 6996' TVD Packers and SSSV (type, measured and true vertical depth)Packer: Baker S-3 Packer, 7896' MD, 6948' TVD SSSV: WRDP-2, 1715' MD, 1702' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Mark Shulman Contact Name:Mark Shulman Authorized Title:Senior Production Engineer Contact Email:mark.shulman@cop.com Contact Phone:263-3782 WINJ WAG 1674 Water-Bbl MD 114 2496' 2936 Oil-Bbl measured true vertical Packer 7"8333' PO Box 100360, Anchorage, AK 99510 Colville River Field/Alpine Oil PoolNone measured TVD Tubing Pressure 3201 CRU CD1-41 See attachment. ADL 25559, 25558 8333' - 11170' MD Plugs Junk measured 78' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-017 50-103-20328-00 4. Well Class Before Work:5. Permit to Drill Number:2. Operator Name 3. Address: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 191 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 237 Gas-Mcf 1505 Authorized Signature with date: Authorized Name: 1626 Casing Pressure 1467 208 Representative Daily Average Production or Injection Data 188 2460' 8298' Conductor Surface Intermediate Production Casing Structural 16" 9.625" Length 114 2394' 7102' Senior Engineer:Senior Res. Engineer: CollapseBurst Fra O g g g l g 200 6. A R t G L PG , Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:47 pm, Jun 01, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.06.01 15:26:35 -08'00' VTL 8/4/21 -00 SFD 6/16/2021 SFD 6/16/2021 RBDMS HEW 6/7/2021 DSR-6/2/21 Scale Inhibitor Squeeze Job pumped from 1100 - 2000 hrs on 5/10/21. LRS = Little Red Services ACF = Alpine Central Facility x Initial pressure TBG/IA/OA – 1680/600/20 x LRS pumped 30 bbls WAW5206/Diesel pre-flush at 4.5 bpm x LRS pumped 83 bbls ACPC 19610A at 4.5 bpm x LRS pumped 88 bbls produced water with SCAL 16089A x LRS pumped 1182 bbls Seawater/SCW3001 scale inhibitor main treatment at 3.0 bpm, TBG/IA/OA- 1550/1550/760 x LRS pumped 32 bbls crude over-flush at 3.5 bpm, TBG/IA/OA – 1500/1500/760 Interval treated: 8333’ – 11170’ MD Tubing: 4.5”, L-80, 7985’ MD, 6996’ TVD Packer: Baker S-3 Packer, 7896’ MD, 6948’ TVD SSSV: WRDP-2, 1715' MD, 1702' TVD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: CTMD 4/21/2021 CD1-41 claytg Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set WRDP Post Coil FCO 4/22/2021 CD1-41 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.3 Set Depth (ftKB) 2,496.3 Set Depth (TVD)… 2,393.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC-MOD Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.3 Set Depth (ftKB) 8,332.5 Set Depth (TVD)… 7,102.4 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description OPEN HOLE OD (in) 6 1/8 ID (in)Top (ftKB) 8,332.5 Set Depth (ftKB) 11,170.0 Set Depth (TVD)… 7,082.1 Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 32.3 Set Depth (ft… 7,984.8 Set Depth (TVD) (… 6,996.3 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) 32.332.30.00 HANGER FMC TUBING HANGER 3.900 1,715.21,702.4 18.35 NIPPLE CAMCO BAL-O SSSV 3.812 7,853.5 6,922.0 49.45 NIPPLE HES X NIPPLE 3.813 7,896.1 6,948.3 53.94 PACKER BAKER S-3 PACKER 3.875 7,972.5 6,989.9 58.66 NIPPLE HES XN NIPPLE 3.725 7,983.5 6,995.6 58.93 WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 1,715.2 1,702.5 18.35 WR-SSSV 4.5" WRDP-2 ON 3.812" DB LOCK 4/22/2021 2.125 HSS-129 Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB)Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 OPEN HOLE FRAC 2/13/2006 8,832.5 11,170.0 0.0 0.00 0.00 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 3,654.2 3,389.1 29.98 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/10/2006 2 5,776.0 5,193.2 30.95 Camco KBG-2 1 GAS LIFT GLV BK 0.188 1,974.0 2/18/2006 3 7,773.9 6,867.7 46.25 Camco KBG-2 1 GAS LIFT OVBK 0.188 0.0 10/8/2018 Notes: General & Safety End Date Annotation 8/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 CD1-41, 4/23/2021 5:48:48 AM Vertical schematic (actual) OPEN HOLE; 8,332.5-11,170.0 OPEN HOLE FRAC; 8,832.5 PRODUCTION; 34.3-8,332.5 WLEG; 7,983.5 NIPPLE; 7,972.5 PACKER; 7,896.1 NIPPLE; 7,853.5 GAS LIFT; 7,773.9 GAS LIFT; 5,776.0 GAS LIFT; 3,654.2 SURFACE; 36.3-2,496.3 WR-SSSV; 1,715.2 NIPPLE; 1,715.2 CONDUCTOR; 36.0-114.0 HANGER; 32.3 WNS PROD KB-Grd (ft) 43.50 Rig Release Date 4/1/2000 CD1-41 ... TD Act Btm (ftKB) 11,170.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032032800 Wellbore Status PROD Max Angle & MD Incl (°) 92.27 MD (ftKB) 10,389.01 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: WRDP • STATE OF ALASKA ALI"OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 200-017 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20328-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559, 25558 CRU CD1-41 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 11170 feet Plugs measured None feet true vertical 7082 feet Junk measured None feet Effective Depth measured 11170 feet Packer measured 7896 feet true vertical 7082 feet true vertical 6948 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2460' 9.625" 2496' 2394' SCANNED NOV 0 12012 Intermediate Production 8298' 7" 8333' 7102' Liner RECEIVED Perforation depth Measured Depth: Open Hole Completion 8333'- 11170' AUG 2 8 2017 True Vertical Depth: 7102'-7082' G C Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 7985' MD, 6996'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3 Packer, 7896' MD, 6948'TVD SSSV: WRDP-2, 1715' MD, 1702'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8333'- 11170' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 294 578 1923 1268 178 Subsequent to operation: 292 653 2065 1277 173 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kaylie Plunkett Email Kaylie.B.Plunkett@cop.com Printed Name Kaylie Plunkett Title Production Engineer Signature 1(t-" '/ Phone 265-6450 Date 1--2.1----17 D VTL !o/6,i/-7 Form 10-404 Revised 5/2015 A !'©�[ RBDMS V`� s„vY+ 8 2017 Submit Original Only • • CD1-41 Scale Inhibition Treatment 7/30/17 Aqueous Scale Inhibitor Squeeze Job pumped from 09:28 to 16:28 on 7/30/17. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA= 337/1162/900 - ACF pumped 30 bbls seawater for a tubing flush at .97 bpm,TBG/IA/OA=0/1124/900 - LRS pumped 20.69 bbls EC9610A preflush at .6- .7 bpm while ACF pumped 83 bbls seawater at .83 - .97 bpm,TBG/IA/OA=0/1042/900 - LRS pumped 15.52 bbls EC6089A scale inhibitor main treatment at .4 bpm while ACF pumped 88 bbls seawater at 1.97—2.71 bpm,TBG/IA/OA=0/1014/900 - ACF pumped 1182 bbls seawater overflush at 2.54—3.90 bpm,TBG/IA/OA=0/1030/900 Interval treated: 8,333'—11,170' MD STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMAION ' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 200-017 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20328-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559, 25558 CRU CD1-41 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 11170 feet Plugs measured None feet true vertical 7082 feet Junk measured None feet Effective Depth measured 11170 feet Packer measured 7896 feet true vertical 7082 feet true vertical 6948 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2460' 9.625" 2496' 2394' Intermediate "''� + ► Production 8298' 7" 8333' 7102' RECEIVED Liner JUL. 292016 Perforation depth Measured Depth: Open Hole Completion 8333'- 11170' ��r True Vertical Depth: 7102'-7082' SCAMMED JAN 3 0 12017, AOG C Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 7985' MD, 6996'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3 Packer, 7896' MD, 6948'TVD SSSV: Camco Bal-O SSSV, 1715' MD, 1702'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8333'- 11170' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 348 1051 2065 1230 175 Subsequent to operation: 205 669 1672 1490 460 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development ❑I Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kerry Freedman Email Kerry.C.Freedman@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature It., -7/\,t,.,I1 4 ._ Phone 265-6579 Date 7 (t s , lc, Form 10-404 Revised 5/2015 f �� ` / 3 RBDMS 1,1, A ttf; - 2 2O16Submit Original Only • • CD1-41 Scale Inhibition Treatment 7/2/16—7/3/16 Aqueous Scale Inhibitor Squeeze Job pumped from 16:55 on 7/2/16 to 02:29 on 7/3/16. 1 LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA—160/1207/950 - ACF pumped 30 bbls seawater for a tubing flush at 3.1 bpm,TBG/IA/OA-30/1219/950 - LRS pumped 10.3 bbls WAW5206 preflush at .35 bpm while ACF pumped 93 bbls seawater at 3.1 bpm,TBG/IA/OA- 15/1238/950 - LRS pumped 15.5 bbls SCW4004 scale inhibitor main treatment at .52 bpm while ACF pumped 88 bbls seawater at 3.1—4.3 bpm,TBG/IA/OA—3/1254/950 - ACF pumped 1119 bbls seawater overflush at .6—5.1 bpm,TBG/IA/OA- 151/1311/950 Interval treated: 8,333'—11,170' v,, WNS PROD • CD1-41 • ConocoPhillips F Well Attributes Max Angle&MD TD het Wellbore API(UWI I Field Name Wellbore Status Incl(') MD(ROB) Act Btm(ftKB) • Alaska, 11* Con000RUWps 501032032800 ALPINE PROD 92.27 10,389.01 11,170.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date - SSSV:WRDP Last WO: 43.50 4/1/2000 Well Contig:-CD1-41,.818201311:11.32 AM Schematic.-Actual Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET WRDP osborl 8/8/2013 Casing Strings HANGER.32 r Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(NO)...String Wt...I String..String Top Thrd CONDUCTOR 16 15.062 36.0 114.0 114.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 36.3 2,496.3 2,394.0 36.00 J-55 BTC-MOD Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd kill '.. PRODUCTION 7 6.276 34.3 8,332.5 7,101.7 26.00 L-80 BTCM Casing Description String 0... String ID...Top(RKB) Set Depth p...Set Depth(ND)...String Wt..String...String Top Thrd OPEN HOLE 61/8 6.125 8,332.5 11,170.0 7,082.1 Tubing Strings CONDUCTOR, Tubing Description String 0... String ID...Top(RKB) ISet Depth(1...Set Depth(ND)...String Wt...String.. String Top Thrd 36-114 TUBING 41/2 3.958 I 32.3 7,984.8 I 6,995.9 12.60 L-80 IBTM Completion Details Top Depth! (ND) Top Incl Nomi... Top(RKB) (RKB) 1°) item Description Comment ID(in) NIPPLE,DP.17,715,715 32.3 32.3 -0.54 HANGER FMC TUBING HANGER 4.500 WR 1,715.2 1,702.3 18.35 NIPPLE CAMCO BAL-O SSSV 3.812 7,853.5 6,921.6 49.77 NIPPLE HES X NIPPLE 3.813 INN 7,896.1 6,948.2 54.12 PACKER BAKER S-3 PACKER - 3.875 7,972.5 6,989.9 58.66 NIPPLE HES XN NIPPLE 3.725 7,983.5 6,995.2 57.89 WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole ' ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Mel Top(RKB) (RKB) (°) Description Comment Run Date ID(In) SURFACE, L. 1,715.2 1,702.3 18.35 WRDP 3.81"DB LOCK ON WRDP(HRS-283)OAL=105" 8/7/2013 1.250 36-2,496 INCLUDING LOCK ir Stimulations&Treatments Bottom I Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) III GAS LIFT, (RKB) (RKB) (COB) (RKB) Type Dab Comment 3•�6 8,832.5 11,170.0 7,113.7 7,082.1 OPEN HOLE 2/13/2006 310000#16/30 Badger and YF125-ST XL gel I FRAC Notes:General&Safety End Date Annotation 8/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 I GAS LIFT, 5,776 11 I if GAS UFT, 7,774 I I NIPPLE.7.853 I 1 PACKER 7,896 NIPPLE,7,972 !.- WLEG,7,984 0 „ Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run N...Top(RKB) (ROB) (°) Make Model (in) SeW Type Type lin) (psi) Run Date Com... 1 3,654.2 3,389.1 29.98 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/10/2006 2 5,776.0 5,193.2 30.95 Camco KBG-2 1 GAS LIFT GLV BK 0.188 1,974.0 2/18/2006 3 7,773.9 6,867.7 46.25 Camco KB0-2 1 GAS LIFT OV BK 0.250 0.0 3/21/2010 PRODUCTION, 34-$333 OPEN HOLE FRAC,8,833 I OPEN HOLE, 8,333-17,170 TD(CD1-41), 11,170 STATE OF ALASKA AL ..,KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed Suspend p r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrdl r Perforate New Fbol r Repair Well r Re-enter Susp Well r Other: Scale Inhibitor Treatment . 2 Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 200-017 3 Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20328-00 7 Property Designation(Lease Number): 8.Well Name and Number: ADL 25559,25558 CRU CD1-41 9.Logs(List logs and submit electronic and printed data per 20AAC25 071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 1 11.Present Well Condition Summary: Total Depth measured 11170 feet Plugs(measured) none true vertical 7082 feet Junk(measured) none Effective Depth measured 11170 feet Packer(measured) 7896 true vertical 7082 feet (true vertical) 6948 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2460 9.625 2496 2394 PRODUCTION 8298 7 8333 7102 SCANNED h T. i 1 Zil'� 41� RECEIVED Perforation depth Measured depth: open hole completion 8333-11170 JUL 2 9 215 True Vertical Depth: 7102-7082 AOG^mss^ Tubing(size,grade,MD,and ND) 4.5, L-80, 7985 MD,6996 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER S-3 PACKER @ 7896 MD and 6948 TVD NIPPLE-CAMCO BAL-O SSSV @ 1715 MD and 1702 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8333'-11170' Treatment descriptions including volumes used and final pressure: see attached summary 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 396 _ 1313 1740 968 - 169 Subsequent to operation 384 1297 1972 974 173 14 Attachments(required per 20 AAC 25.070,25 071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development F Service r Stratigraphic r Copies of Logs and Surveys Run r 16 Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt none Contact Kerry Freedman @ 265-6579 Email Kerry.C.Freedman@conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature /J q-we+rrtn�Le.---- Phone:265-6579 Date JJ(1 Z`t)2d IC / If 71- i RBDMS...\W AUG - 2 2015 0 Form 10-404 Revised 5/2015 Submit Original Only CD1-41 Scale Inhibition Treatment 7/01/15 Aqueous Scale Inhibitor Squeeze Job pumped 7/1/15 from 07:12 to 15:25. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA—443/878/740 - ACF pumped 30 bbls produced water tubing flush at 2 bpm,TBG/IA/OA-2/886/740 - LRS pumped 10.3 bbls WAW5206 at.2 bpm while ACF pumped 93 bbls seawater at 2 bpm, TBG/IA/OA-0/986/740 - LRS pumped 15.5 bbls SCW3001 scale inhibitor at .3 bpm while ACF pumped 88 bbls produced water at 2 bpm,TBG/IA/OA—0/999/740 - ACF pumped 1119 bbls produced water overflush at 3 bpm,TBG/IA/OA-0/1101/740 Interval treated: 8333'-11,170' v, I WNS PROD CD1-41 • : ConocoPhillips A Well Attributes Max Angle&MD TD Alaska.lac Wellbore API/UWI Field Name Wellbore Status Incl(') MD(ROB) Act Still(ftKB) CatgccPMBpa 501032032800 ALPINE PROD 9227 10,389.01 11,170.0 "" Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date ••• Well Confq:-CDI41,8/8201311-.11.32AM -SSSV:WRDP Last WO: 43.50 4/1/2000 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET WRDP osbort 8/8/2013 7, HANGER.32 , Casing Strings r Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 114.0 114.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(COB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 95/8 8.921 36.3 2,496.3 2,394.0 36.00 J-55 BTC-MOO Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String WL.String...String Top Thrd 0 a P PRODUCTION 7 6.276 34.3 8,332.5 7,101.7 26.00 L-80 BTCM Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd - ,. OPEN HOLE 6 1/8 6.125 8,332.5 11,170.0 7,082.1 Tubing Strings CONDUCTOR, Tubing Description String 0... String ID...Top(COB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 30-114 TUBING 41/2 3.958 32.3 7,984.8 6,995.9 12.60 L-80 IBTM Completion Details Top Depth (TVD) Top Incl Nomi... NIPPLE,1,775 Top(ftKB) (000) I I Item Description Comment ID(in) WRDP,1,715IrE, 32.3 32.3 -0.54 HANGER FMC TUBING HANGER 4.500 1,715.2 1,702.3 18.35 NIPPLE CAMCO BAL-O SSSV 3.812 7,853.5 6,921.6 49.77 NIPPLE HES X NIPPLE 3.813 7,896.1 6,948.2 54.12 PACKER BAKER S-3 PACKER 3.875 7,972.5 6,989.9 58.66 NIPPLE HES XN NIPPLE 3.725 ( 7,983.5 6,995.2 57.89 WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl Top(RKB) MKS) P) Description Comment Run Date ID(in) ii1 1,715.2 1,702.3 18.35 WRDP 3.81'DB LOCK ON WRDP(HRS-283)OAL=105" 8/7/2013 1.250 SURFACE,6 iINCLUDING LOCK IMF Stimulations&Treatments Bottom ! Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) GAS LIFT, (ROB) (ROB) (ROB) (RKB) Type Date Comment 3• 8,832.5 11,170.0 7,113.7 7,082.1 OPEN HOLE 2/13/2006 3100008 16/30 Badger and YF 125-ST XL gel FRAC Notes:General&Safety '( End Date Annotation 8/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, 5.776 I GAS LIFT, 7,774 ' �6 NIPPLE,7,853 i. i PACKER.7,896011111110' '' i NIPPLE,7,972 I■', MEG.7,984 11 • } Mandrel Details Top Depth Top Port 5--- (ND) Incl OD Valve Latch Size TRO Run N...Top(MB) (RKB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,654.2 3,389.1 29.98 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/10/2006 2 5,776.0 5,193.2 30.95 Camco KBG-2 1 GAS LIFT GLV BK 0.188 1,974.0 2/18/2006 li 3 7,773.9 6,867.7 4625 Camco KBG-2 1 GAS LIFT OV BK 0250 0.03/21/2010 PRODUCTION, I , #8,333 OPEN HOLE a ` FRAC,8,833 OPEN HOLE, i' 8,33311,170 { 0 11,170 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~_~- ~)_/_~ Well History File Identifier Organization (do.e) RESCAN DIGITAL DATA ~'/~'Color items: [] Diskettes, No. ~'"/Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: TOTALPAGES: ~ ? NOTES: ORGANIZED BY: BEVERLY BRE~HERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: 4~--~ ~'? /S/ /6 [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN~ SHERYL MARIA LOWELL Scanned (done) PAGES: SCANNED BY: (at the time of scanning) BEVERLY BREN VINCEN~I~ MARIA LOWELL RESCANNED BY: BEVERLY BRE~HERYL MARIA LOWELL DATE: General Notes or Comments about this file: PAGES: Quality Checked (done) STATE OF ALASKA < AL/ OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other Scale Inhibition Alter Casing Pu Tubing Treatment g j` g r Stimulate - Fr ac �' W r Time Exte J"" Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ^ ConocoPhillips Alaska, Inc. Development 17 Exploratory r 200 -017 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20328 -00 0 0 1 7. Property Designation (Lease Number): 8. Well Name and Number: I ADL 25559, 25558 -• i° ' CD1 - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 11170 feet Plugs (measured) None true vertical 7082 feet Junk (measured) None Effective Depth measured 11170 feet Packer (measured) 7896 true vertical 7082 feet (true vertucal) 6948 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115 115 SURFACE 2460 9.625 2496 2394 PRODUCTION 8298 7 8333 7102 p `. i '4A0c 4 {' - i ' t i ! iq ,. , ! 11 r R E moo/ E I V E D Perforation depth: Measured depth: open hole completion 8330' - 11170' , -- ;- L' f - v . L L_ True Vertical Depth: 7102' -7082' AUG 1 5 2012 Tubing (size, grade, MD, and TVD) 4.5, L -80, 7984 MD, 6996 TVD AOGCC Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 7896 MD and 6948 TVD SSSV - CAMCO BAL -O NIPPLE @ 1715 MD and 1702 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8330' - 11170' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 760 2606 1076 -- 192 Subsequent to operation shut - in for plant turn - around 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development f Service r Stratigraphic r 16. Well Status after work: s Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Michael Dammeyer na. 265 -6548 Printed Name Michael Dammeyer Title Senior Production Engineer Signature --fiA Phone: 265 -6548 Date 5( i d‘C—.-/r) /, F-Z2-• Form 10-404 Revised 11/2011 REI®MS AUG 15 2012 i�� Ie Z-- Submit Original Only WNS CD1-41 p1. 1K , Conac Philii ,,- Well Attributes Max Angle & MO TD Alaska Inc. - ' ,,,, o , Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) tl c «,,,,, s q 501032032800 ALPINE PROD 92.27 10,389.01 11,170.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well Confic - C131 -41, 228/201211.0127 AM SSSV: NIPPLE Last WO: 43.50 4/1/2000 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: RESET WRDP ninam 2/26/2012 Casing Strings Casing Description String O. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd 1 a' P CONDUCTOR 16 15.062 36.0 114.0 114.0 62.58 H - 40 WELDED HANGER, 32 ;; T' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 SURFACE 9 5/8 8.921 36.3 2,496.3 2,394.0 36.00 J - 55 BTC - MOD t Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd '`' PRODUCTION 7 6.276 34.3 8,332.5 7,101.7 26.00 L - 80 BTCM ti1�ra» Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 OPEN HOLE 61/8 6.125 8,333.0 11,170.0 7,082.1 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set 0 epth (TVD) ... String Wt... Str ng ... String Top Thrd e TUBING 4 1/2 I 3.958 I 32.3 7,984.8 6 I 12 L 80 I IBTM CONDUCTOR, Completion Details 36 -114 P Top Depth (TVD) Top Inc! Nom'... at Top (ftKB) (ftKB) (°I Item Description Comment ID (in) 32.3 32.3 -0 .54 HANGER FMC TUBING HANGER 4.500 NIPPLE, 1,715 1,715.2 1,702.3 18.35 NIPPLE CAMCO BALD SSSV 3.812 BE WRDP, 1,715 7,853.5 6,921.6 49.77 NIPPLE HES X NIPPLE 3.813 7,896.1 6,948.2 54.12 PACKER BAKER S-3 PACKER 3.875 ' 7,972.5 6,989.9 58.66 NIPPLE HES XN NIPPLE 3.725 7,983.5 6,995.2 57.89'WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc( Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 1,715 1,702.3 18.35 WRDP 3.81" DB LOCK ON WRDP (HSS- 241) 2/7/2012 1.250 Stimulations & Treatments SURFACE, ■ Bottom 36 -2,496 Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 8,333.0 11,170.0 7,101.8 7,082.1 OPEN HOLE 2/13/2006 310000# 16/30 Badger and YF125 -ST XL gel ♦� }n & Safety FRAC GAS LIFT, Notes: General.& Safety 3,654 End Date Annotation it 8/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1 GAS LIFT, 5,776 ,.... it GAS LIFT, 7,774 IU II al NIPPLE, 7,853 it ir at PACKER, 7,696 t1 . 111U/ It NIPPLE, 7.972 lk WLEG, 7,984 J Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,654.2 3,389.1 29.98 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 2/10/2006 2 5,776.0 5,193.2 30.95 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,974.0 2/18/2006 3 7,773.9 6,867.7 46.25 CAMCO KBG -2 1 GAS LIFT OV BK 0.250 0.0 3/21/2010 PRODUCTION, 34-8,333 OPEN HOLE FRAC, HOLE OPEN HOLE, 8,333- 11,170 i TO(C01 -41), y,; ;Ala 11,170 . - • 0 Scale Inhibition Treatment: CD1 -41, 8/4/2012 Initial pressure TBG/IA/OA — 475/1000/820; Facility pumped 50 bbls SW preflush; LRS pumped 3.5 bbls WAW5206 (147 gal) at 0.4 bpm and facility pumped 32 bbls SW at 4 bpm, 475/1000/820; LRS pumped 35.3 bbls SCW3001WC (1483 gals) at 0.65 bpm and facility pumped 200 bbls of SW at 4.3 bpm, 625/970/840; LRS pumped 3.5 bbls WAW5206 (147 gal) at 0.4 bpm and facility pumped 36 bbls SW at 4 bpm, 2150/1240/750; facility pumped 1094 bbls of SW over - displacement at 4.3 bpm. STATE OF ALASKA ALASKA IAND GAS CONSERVATION COMMISSO ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon f'" Repair w ell ""' Plug Perforations r Stimulate 5C 4 r Alter Casing I- Pull Tubing r Perforate New Pool {" Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p" Exploratory r _ - 200 - 017 3. Address: 6. API Number: Stratigraphic r Service '-" P. O. Box 100360, Anchorage, Alaska 99510 - 50 7. Property Designption (Lease Number): 8. Well Name and Number: ADL 25559, 25558 r CD1 -41 9. Field /Pool(s): _ Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11170 feet Plugs (measured) None true vertical 7082 feet Junk (measured) None Effective Depth measured 11170 feet Packer (measured) 7896 true vertical 7082 feet (true vertucal) 6948 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115 115 SURFACE 2460 9.625 2496 2394 PRODUCTION 8298 7 8333 7102 C, C: r V,":. ' ', :,' r.:: r Perforation depth: Measured depth: open hole completion 8330' - 11170' True Vertical Depth: 7102' -7082' Tubing (size, grade, MD, and TVD) 4.5, L - 80, 7984 MD, 6996 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S - PACKER @ 7896 MD and 6948 TVD SSSV - CAMCO WRDP -2 @ 1715 MD and 1702 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8330' - 11170' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 1017 2609 876 -- 197 Subsequent to operation not available 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 1;7 - Service I Stratigraphic - 15. Well Status after work: - Oil 17 Gas r WDSPL I Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ ;fl SUSP r SPLUG E 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact David Neville @ 265 -6402 Printed Name David Neville Title WNS Production Engineer Signature \ Q Phone: 265 -6402 Date G P-- Z `/ .� 64 vie" /va✓ //! Form 10 -404 Revised 10 /201v'BDMS AUG 04 21)& Submit Original Only 0 • CD1 -41. 7/15/2011: Initial pressure TBG /IA - 738/1097; facility pumped 50 bbls SW preflush; LRS pumped 3.5 bbls WAW5206 (298 gal) at 0.4 bpm and facility pumped 32 bbls SW, 504/1097; LRS pumped 3.9 bbls SCW3001WC (163.8 gal) job not completed due to high tubing pressure (1300 psi). WNS • CD1-41 ConocoPh llhps nom? Well Attributes _ _ Max Angle & MD __ TD AfaSitt ir1C "` Wellborn APIIUWI Field Name 'Well Status Ind () MD (ftKB) Act Btm (ftKB) ts Lrnt , 501032032800 ALPINE PROD 92.27 I 10,389.01 11,170.0 Comment H2S (ppm) Dab "Annotation 1 1,C644 End Dab KB (ft) Rig Release Date _Y1 .Cpidg' _01A1-4.1..312. 2Glg ?t_�4s An+ - SSSV NIPPLE Last WO: 43.50 4/1/2000 _ -_ naIDIa A Date otation Depth (ftKB) End Date Annotation - - Last Mod ... End Da Last Tag: Rev Reason RESET WRDP Imosbor 3/2/2011 Casing Strings Casing Description String O String ID ... Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd I ' a. r CONDUCTOR 16 15062 36.0 114.0 114.0 62.58 H WELDED HANGER, 32 " ; '.� .:. Casing Deserption String 0... String ID. -. Top (HKB) Sat Depth (E.. Set Depth (TVD) ... String Wt... String ... Siring Top Thrd SURFACE 9 5/8 8.921 36.3 2,496.3 2,394.0 36.00 J - 55 BTC - MOD - Casing Description String 0... String ID... Top (ftKB) Set Depth (t... Set Depth (TVD)... String Wt... String ... String Top Thrd ' ` PRODUCTION 7 6 151 34.3 8,332.5 7,101.7 26.00 L BTCM _ _.. Casing Descliption String 0... String ID Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String String Top Thrd OPEN HOLE 6 1/8 6 125 8,333.0 11,170.0 7,082.1 Tubing Strings N! >^.i :�d Tubing Description String 0... String ID ... Top (ftKB) Set Depth (t_. Set Depth (ND) .. String Wt... String ... String Top Thrd TUBING 4 1/2 3.958 32.3 7,984.8 6,9959 12.60 L - 80 IBTM CONDUCTOR, . NDU t Completion Details Top Depth — (TVD) Top Intl NaN... Top ( M KS) (KS) C) Item Description Comment ID(in) ilk 32.3 32.3 -0.54 HANGER FMC TUBING HANGER 4.500 NIPPLE, 1715 z' 1,715.2 1,702.3 18.35 NIPPLE CAMCO BAL -O SSSV 3.812 WRDP, 1,715 7,853.5 6,921.6 49.77 NIPPLE HES X NIPPLE 3.813 7,896.1 6,948.2 54.12 PACKER BAKER S -3 PACKER 3.875 7,972.5 6,989.9 58.66 NIPPLE HES XN NIPPLE 3.725 I. 7,983.5 6,995.2 57.89 WLEG BAKER WI RELI NE GUIDE 3.958 Other In Hole fWireline retrievable plugs�valv�s pumps fish, etc.) _ j Top Dept (TVD) Top 1001 Top (ftKB) (ftKB) ('( Description Comment Run Date ID (in) 1,715.2 1,702.3 18.35 WRDP CAMCO 3.81" WRDP -2 (HSS -128) 3/1/2011 1.250 Stimulations & Treatments SURFACE. -._. Bolcom 36 -2.496 Min Top Mao Btrn Top Depth Depth Depth Depth (ND) (TVD) (ftKB) (ftKB) (ftKB) ( Type Date Comment 5 8,333 0 11,170.0 7,101 8 7,082.1 OPEN HOLE 2/13 /2006 3100006 16/30 Badger and YF125 -ST XL gel FRAC GAS I IFT Notes: General & Safety 3654 End Date Annotation _. 8/19/2010 NOTE: VIEW SCHEMATIC w /Alaska Schemanc9.0 i I GAS LIFT -- 5.776 GAS i I f. 7.774 I NIPPLE, 7,853 PACKER, 7,896 — NIPPLE, 7,972 if ALES, 7,964- - -- ,- Mandrel Details Top Depth Top 1 - 1 Port (TVD) -_ —� 1 3,6542 3,389.129.98 CAMCO KBG-2 OD 1GAS LIFT IDMY BK 0 x00 0 Run Stn Top MKS) (ftKB) ('I Make Model (in) `ere S Type Typ (in) (Pei) Run Date Corn... 0.0 2110/2006 i 2 5,776.0 5,193.2 30.95 CAMCO KBG -2 1 GAS LIFT GLV BK 0.188 1,974.0 2/18/2006 3 7,773.9 6,867.7 46.25 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 321/2010 PRODUCTION, 34 -8,333 OPEN HOLE FRAC, 8,333 OPEN HOLE, 8,333 - 11,170 TO (CDt41), 11,170 STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon "`"" Repair w ell Plug Fbrforations ~"" Stimulate ~" Other "' Alter Casing ~ Pull Tubing ~""' Pbrforate New Pbol Waiver ~ Time Extension r Change Approved Program """ Operat. Shutdown °° Perforate "'" Re-enter Suspended Well ~°` 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~' Exploratory j! 200-017 3. Address: Stratigraphic ~ Service ~°° API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20328-00 7. Property Designation: 8. Well Name and Numbe ADL 25559 CD1-41 9. Field/Pool(s): `~ Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11170 feet Plugs (measured) None true vertical 7082 feet Junk (measured) None Effective Depth measured 11170 feet Packer (measured) 7896 true vertical 7082 feet (true vertucal) 6948 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2460 9.625 2496 2394 PRODUCTION 8299 7 8333 7055 ~~~~ ~J ~® Perforation depth: Measured depth: open hole from 8333'-11170' True Vertical Depth: 7055'-7082' ~~J(~ ~ ~ Z~~l~ Alaska ~ ~ Ga~x Ceti. ~~!'rtission Tubing (size, grade, MD, and TVD) 4.5, L-80, 7985 MD, 6996 TVD ~~~"~~~~~~ Packers & SSSV (type, MD, and TVD) PACKER -BAKER 'S-3' PACKER @ 7896 MD and 6948 TVD WRDP - CAMCO WRDP-2-SCSSSV @ 1715 MD and 1702 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): S@@ attachment ~, ~; ; ; <'° '~ ~'~ ~~~~ t tt ~ ~ ~~ " "~` Treatment descriptions including volumes used and final pressure: "~'`'~` 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1027 1270 621 -- 193 Subsequent to operation 565 577 653 -- 194 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development ~ Service 15. Well Status after work: Oil -~'', Gas """ WDSPL ~°` Daily Report of Well Operations XXX GSTOR °°'` WAG """ GASINJ "` WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. F~cempt: none contact David Neville ~ 265-6402 d Ne ille ~ Title WNS Engineer Printed Name D av i Signature ~~,~^I~PJ Phone: 265-6402 Date ~ ? ~ U~~/ l RBC-IIAS AUG I ~ 1~ ~ // ~° Form 10-404 Revised 7/2009 ~ ~ Submit Original Only ~s~ ~''~® CD1-41 Well Events Summary 7/24/10 Scale squeeze job pumped 8:45 ~ 14:05 hrs on 7/24/2010. Aqueous Squ using SW manifold with slip stream of chemicals addeTby LRS: 50 bbls SW pre-flush from CD1-33 injector followed by 29 bbls SW /WAW 5206 mixture (132 gal. WAW 5206) at 4.4 BPM from the CD1-33 and 0.43 BPM from LRS on a vacuum; then pumped 252 bbls SW /SCW 3001WC mixture (25.8 drums SCW 3001WC) at 4.4 BPM from CD133/0.71 bpm from LRS with tbg on VAC; followed by 29 bbls SW /WAW 5206 mixture (132 gal. WAW 5206) at 4.4/0.43 BPM with tbg on VAC; then over displaced with 1098 bbls S/W at 4.4 BPM from CD1-33 with tbg on VAC. SI for 12 hours and returned to production. 1.8 additional drums (100 gallons) 3001 was pumped due to CD1-33~s water meter (7.5% error). ~'~~ WNS • CD1-41 ~~~~~~I~~p's L Well Attributes ___ _ 'Max Angle & MD TD j „ ~ ~` Wellbore API/UWI ' Field Name Well Status Incl (°) MD (fIKB) ~ Act Btm (ftKB) " ~ a.. .. 501032032800 ALPINE 10,38901 PROD 9227 11,170.0 COmment Date ~,AnnolaLon /End Date KB-Grd (ft) H2S (PPm) _ RigR I Date I SSSV WRDP i ~ Last WO 43.50 L 4/1/2000 _ -° ~pn c, eg coibt, a271zo ~ I Srherna(c_Acwai _ Annotabon Depth (ft KB) End Date Annotation Last Mod By End D to _ Last Tag_ 1 _ ESET WRDP, GLV CIO Imosbor Rev Reason R 3/27/2010 Casin Strin s String OD String ID Set Depth Set Depth (ND) String WI String Casing Description (in) I (in) ~ Top (kK6) (ftKB) (flK6) (Ibs/ft) Grade String Top Thrd OR ~ O ' 15.062 6 8 43.5 114.0 114.0 62.58 H-40 WELDED ~ RFACE SU 8.697 9 0.0 2,496 0 2,393.8 36.00 J-55 BTC-MOD '~ ( _ PRODUCTION 7 6.151 0.0 8,333.0 7,101.8 26.00, L-80 BTCM ,- ,~ OPEN HOLE 61/8 6.125 8.333.0 17,1700 7082.1 ~ ~ _ Tubin Stnn s g g __.. ~ j ~ String OD String ID f Set Depth Set Depth (ND) Strng Wt Str ng I v g ription Tubin D (~n) i (in) Top (ftK81 (ftKB) (ftKB) (Ibs/ft) G de Stnng TOp Thrd 1 cor4DUCroR, 116 ~ TUBING I 41/2; 3.9581 111 0.0 1,985.0 6,996.0 12601E 80 IIBTM 1 Other In Hole (SA I I Jewelry: Tubin & Retrievable, Fish etc. g Run ' ~ ~ Top Depth/ ~ _ ~, (TVDI ToP Incl ~ Top (HKB) kK6 ( I (% Description Comment Run Date _ ID (in) 1,715 1,702.1' 18.35 NIPPLE CAMCO BAL-O NIPPLE 3/31/2000 3.812 NIPPLE. 1.]15 S ., waoP,1,715~- ? ` ~. ___.. 1,715 _ _. 1,702.1 18.35 WRDP _ CAMCO 3 81" WRDP-2 (HRS 65) GOOD CLOSURE TEST - _ -. 3/26/2010 _. - - 1.250 ' g ~ - 3,654 3,385.9 29 98 GAS LIFT CAMCO/KBG-2/1/DMY/BK///Comment: STA 1 2/10/2006 3.938 g 5,776 5193.2 3095 GAS LIFT CAMCO/KBG-2/11GLV/BK/.188/1974/Comment: STA2 2/18/2006 3.938 ~ 7,774 6 867-8 46.25 GAS LIFT CAMCO/KBG-2/1/OV/BK/25//Comment: STA3 3/2172010 3.938 _. 7 7,853 6,921.3 49.73 NIPPLE - _. HES'X'NIPPLE 3131/2000 _ _ 3813 SURFACE._ z.bsfi 7,896 6,948.1 5411 PACKER -- -- BAKER'S-3' PACKER -- 3/31/2000 - 3.875 7,972 6,989.71 58.65 NIPPLE HES'XN' NIPPLE 3/31/2000 3.725 "I JI 7,985 6,996 O 58.00 WLEG --_ _ BAKER WIRELINE RE-ENTRY GUIDE 3/31/2000 __ 3.875 Stimula tions 8 Treat _. __ ments _ __ Bonom Min TOp Max 61m Top Depth Depth ~ I GAS LIFT. Depth Depth (ND) (ND) 3.654 - (ftKB) (ftKB) (ftKB) (ftKB) Type Data Commetrt %I ~~ 8,333.0 11,170.0 7,101.8 7,082.1 OPEN HOLE 2/13/2006 310000# 16/30 Badger and YF725-ST XL gel a: i FRAC I GAS LIFT, _ 5.776 i GAS LIFT, 7 ]74 NIPPLE. 7,853 1 i3 PACKER, 7,89fi 9 I NIPPLE. 7.972- --- ~-~^° ~_ i. , j I j t I i t I i I I, WLEG. 7.9E5 ~;.;~ x:, __ PRODUCTION, 8 333 OPEN HOLE FRAC.8333 ~ OPEN HOLE, • • 11,170 m 11,170 . • Page 1 of 1 Regg, James B (DOA) ,~ ZUO- ~I ~ From: NSK Well Integrity Proj [N1878@conocophillips.com] ~~ ~~z~l~ Sent: Thursday, March 11, 2010 5:23 PM ~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: CD1-41 (PTD200-017) Attachments: CD1-41.pdf Tom/Jim/Guy, Producer CD1-41 (PTD 200-017) exhibited TxIA communication while it was SI earlier this wee. The orifice valve' suspected to be the problem and will be changed out later this week. The well has been added to the weekly SCP report. The TIO and schematic are attached Please let me know if you have any questions. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 3/12/2010 CRU CD1-41 PTD 2000170 3/11/2010 TIO Pressures 1000 900 soo goo soo soo 400 300 200 100 0 TJI/O Plat - CD1-41 Dec-2009 Jan-2010 Feb-2010 Date Mar-2010 1000 9oa soo Boa soo ~ soo t 0 400 v 300 200 100 0 Apr-2010 • STATE OF ALASKA • ~1AR 2 5 2C1Q9 ALASKA OIL AND GAS CONSERVATION COMMISSION ~(8Sk8 OII ~ GaS ~Oli~. ~OIT1Cf11SStu+`x REPORT OF SUNDRY WELL OPERATIONS An~nara~n 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^/ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~' Exploratory ^ 200-017 • 3. Address: - Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20328-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD1-41 8. Property Designation: 10. Field/Pool(s): ADL 25559, ADL 2558 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 11170' feet true vertical 7082' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78' 16" 114' 121' SURFACE 2460' 9-5/8" 2496' 2394' PRODUCTION 8299' 7" 8333' 7055' Perforation depth: Measured depth: Open Hole Completion from 8333' - 11170' true vertical depth: ',, ~ ~?~., ~r'~ ,' .'~- J/tj!s{ ~~~~ Tubing (size, grade, and measured depth) 4.5" L-80 @ 7985' MD Packers &SSSV (type ~ measured depth) Baker S3 Packer @ 7896' Camco SSSV @ 1715' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volume s 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 1912 • 3607 304 660 175 Subsequent to operation 2320 - 4587 316 700 217 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 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: N/A Contact Tim Schneider Printed Name Tim Schneider Title Production Engineer Signature~~j~ Phone 265-6859 Date 3-zZj~`p~J Pre ared b ann L. H 63-4470 ~•~.~:~ Form 10-404 Revised 04/2006 ~ ~ °: _. ~~ lit; h` ;f S 1ij(~4 ~}~ Submit Origin3~l,G~~ t WSR -Well Service Report Well Service Report U rr~A 1r- s ~ W ..- P ~ ~ @r.• A ~' Page 1 of 1 Well Job Scope ~ CPAI Rep CD 1-41 Scale Inhibition Brake, Jared Date Daily Work Unit Number 3/15/2009 Scale Squeeze 44 Initial & ~tartmg ~1~13(i/lA/OA Final 600/575/825 End Field: ALPINE Pressures: 525/600/850 24 hr. Pumped a scale squeeze with total of 1073 bbls of fluid. Summarti~ STARTTIME OPERATION 09:55 PM Start pumping crude 207 bbls 7 bbl/min Pump 12 bbls pre-flush crude w/ SOgal WAW5206 followed by 79 bbls SW w/495g 10:28 PM SCW3001 WC @ 2.5 bbUmin. Flush with 12 bbls Crude w SOgal WAW5206 @ 2.5 bbUmin 11:04 PM Pump 354 bbls Crude 6.3 bbUmin Fluid Type To Well From Well Non- recoverable Note OIL 207 Dead Crude OIL 12 w/50 gal WAW5206 SEAWATER 79 w/ 395 gal SCW3001 WC OIL 12 w/ 50 gal WAW5206 http://akapps. conocophillips.net/alaskawelleventquery/worklog. aspx?ID=AO 8B 829... 3/24/2009 ~,~ Sssv (1715-1716, OD:3.812) NIP (1715-1716, OD:6.062) Gas Lift 3ndrel/Dummy Valve 1 (3654-3655, OD:5.984) Gas Lift MandrelNalve 2 (5776-5777, Gas Lift MandrelNalve 3 (7774-7775, NIP (7853-7854, OD:5.000) TUBING (0-7985, OD:4.500, ID:3.958) PKR (7896-7897, OD:7.000) NIP (7972-7973, OD:5.000) W LEG (7985-7986, OD:5.000) OPEN HOLE FRAC (8333-11170) OPEN HOLE (8333-11170, OD:6.125) ~J Co~oooPhiliP~ Ai~ska, inc: ALPINE CD1-41 . . ~ ConocoPhillips Alaska ,~ ,J::' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 .i!, March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 1 0 2007 dvOO-O 17 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ITom the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 Alpine Field March 31,2007 e ConocJPhillips e Tim Schneider Staff Production Engineer Alpine Engineering P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 March 7, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 ~~ov1 Subject: Report of Sundry Well Operations for CD1-41 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the Alpine well CD1-41. This report will cover the recent stimulation treatment on this well. If you have any questions regarding this matter, please contact me at 265-6859. Sincerely, -¡(¿-iJ) T. Schneider Staff Production Engineer CPAI Alpine Engineering TSS/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION e e RECEIVED MAR 0 8 2006 REPORT OF SUNDRY WELL OPERA TIO nil fl. 1::..." 1""..." - 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate Q Other Anchbrltge Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory 0 200-017 1 306-037 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20328-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD1-41 8. Property Designation: 10. Field/Pool(s): ADL 25559 & 25558 Colville River Field 1 Alpine Oil Pool 11. Present Well Condition Summary: - feet Total Depth measured 11170' true vertical 7082' , feet Plugs (measured) Effective Depth measured 11170' feet Junk (measured) true vertical 7082' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURF CASING 2440' 9-5/8" 2496' 2394' PROD CASING 8277' 7" 8333' 7101' OPEN HOLE 2837' 5-1/2" 11170' 7082' Perforation depth: Measured depth: open hole completion true vertical depth: open hole completion Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7985' MD. RBDMS BFL MAR 0 8 2006 Packers & SSSV (type & measured depth) pkr= BAKER 'S-3' PACKER pkr= 7896' Cameo WRDP SSSV @ 1715' 12. Stimulation or cement squeeze summary: Intervals treated (measured) open hole interval from 8333'-11170' MD Treatment descriptions including volumes used and final pressure: 308,935# ot 16/30 white sand in 2328 bbls total slurry, ISIP=1567 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation \ .~\ ""/bb\ 2206 2235 0 1149 200 Subsequent to operation \ .".~ ~/b"\ 4659 8983 27 917 325 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development Q Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilQ GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt:. , \ ~Ob'- o-s Contact Tim Schneider @ 265-6859 Printed Name ~;27eide~ Title Staff Production Engineer Signature -,0J .d-. Phone Date ~ -7-0" Preoared bv Shamn AII.<un-Drake 263-4612 Form 10-404 Revised 04/2004 Ot~IGlî~AL .~ ./ 7 "c'/ Submit Original Only .> . ~ e e FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Kelli Hanson Alpine Development Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 ~(þ--(){7 Re: Colville River Field, CD 1-41 306-037 ,... ~_'. ......'!1.iE;:, 'C ~~,:\i)'\~~~',v. ' , ;'~ Dear Ms. Hanson: 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, CI4/~ Cathy P. Foerster Commissioner ¡61- DATED this_ day of February 2006 Encl. e e Kelli Hanson Production Engineer Alpine Engineering Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6945 January 31, 2006 RECEIVED FE -B 0 1 2006 AJask<> '~I,'I " f' .. ~, I QI ""'8S C' '"'00$1. en., , . An h .-m1mtsSIúi1 C orage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for CD1-41 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Alpine well CD1-41. We are planning to perform a stimulation treatment on this well. If you have any questions regarding this matter, please contact me at 265-6945. Sincerely, rJ£'/~ Kelli Hanson Production Engineer CPAI Alpine Engineering KH/skad ORIGINAL ~ÇA~ ~. ommíss ¡rlii 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver ~horage Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill~ber: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-017 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20328-00 V 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD1-41 8. Property Designation: 10. Field/Pool(s): ADL 25559 & 25558 Colville River Field 1 Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11170' 7082' 11170' 7082' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' 114' SURF CASING 2440' 9-518" 2496' 2394' PROD CASING 8277' 7" 8333' 7101' OPEN HOLE 2837' 5-1/2" 11170' 7082' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion open hole completion 4-1/2" L-80 7985' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'S-3' PACKER pkr= 7896' Camco WRDP SSSV @ 1715' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 7,2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelli Hanson @ 265-6945 Printed Name Kelli Hanson Title: Alpine Development Engineer Signature j/p.QR¡tl ~ Phone 2r£~~'!'I) Date 1/3// ñln Commission Use Only Conditions of approval: Notify Commission so that a representative may witness sun:~t;:. 0 ~ 7 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS 8Fl FEB 0 2 2006 Subsequent Form Required: ~~ æ /J./l¡; ßd APPROVED BY Date: Z....I-Ð6 Approved by: '" ,I/-)fur COMMISSIONER . ~ . MMISSION Form 10-403 Rev(ed 7/;005 ....., "''-1 .. It I ..--r T\ II I l ,1""\ I L.: / Submit in Duplicate f.. RECEIVED ~/L... ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 1 2006 APPLICATION FOR SUNDRY APPROVAL AlA k O. 20 MC 25 280 ruaS a II & Gas Con' C e STATE OF ALASKA e IGINAL e e Overview: CD1-41: A hydraulic fracture treatment will be performed in the openhole horizontal section to remove formation damage and establish communication between vertical layering in this thick Alpine interval, increasing production rate and reserves. A coil c!eanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU seven clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) 2. Rig up Dowell equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up t~ maximum rate ASAP. L I" \ _ '- ,\" , \ . ~ ~ÙT)"'>~' ~\I--...~ '{)'-'.\~ T 5. :~;~r tl~~ ~~~~~~~g ~~~~~~e3~~~op~ro~ ~i~hl~ ~u~~~~~: ~:::t~~~t~f 9000 psi, add breaker ~(~ p~ ~ · 300 bbls YF125ST Pad ~ ~~( · 240 bbls YF125ST wI 2 ppa 16/30 White Sand · 480 bbls YF125ST wI 4 ppa 16/30 White Sand · 1000 bbls YF125ST wI 7 ppa 16/30 White Sand · Flush with linear YF125ST and freeze protect Total Sand: -310,000Ibs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCC if required with slick diesel. SSSV (1715-1716, OD:3,812) Gas Uft MandrelNalve 1 (3654-3655, OD:5,984) Gas Uft MandrelNalve 2 (577fr5m, OD:5.984) GasUft MandrelNalve 3 (m4-m5, OD:5.984) NIP (7853-7854, OD:5.000) PKR (7896-7897, OD:7.000) NIP [1972-7973, OD:5,OOO) TUBING (()'7985, OD:4,500, ID:3,958) WLEG (7985-7986, OD:5.000) OPEN HOL:, (8333-11170. OD:6 125: ConocoPhilUps Alaska, .. w , , :aðr lþ ~ ,.1 I I " , I · , i , . I I " I I ..oiiiiii . CD1-41 API: 501032032800 SSSV Type: WRDP Annular Fluid: Reference Loa: Last Taa: Last Tag Date: .. ..... e ALPINE i·· Well Tvoe: PROD Orig 4/1/2000 Comoletion: Last W/O: Ref Loa Date: TO: 11170 ftKB Max Hole Angle: 92 deg @ 10389 Size 16.000 9.625 7.000 6.125 TOD o o o 8333 CAMCO CAMCO CAMCO Bottom 114 2496 8333 11170 TVD 114 2394 7101 11170 CD1-41 i Anale (å) TS: dea (å) Angle @ TD: 90 deg @ 11170 Rev Reason: Chanae 7" ID Last Uodate: 11/22/2003 Wt 62.58 36.00 26.00 0.00 TVD 6996 I Wt I Grade 1 I 12.60 I L-80 1 V Type VOD Latch 1.0 1.0 1.0 Port BK BK BK 0.188 1823 0.188 1871 0.156 0 Casino Strino - ALL Description CONDUCTOR SURF CASING PROD CASING OPEN HOLE Tubina Strina - TUBING Size Top I Bottom I 4.500 I 0 I 7985 I Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr Mfr 1 3654 3389 CAMCO KBG-2 2 5776 5193 CAMCO KBG-2 3 7774 6868 CAMCO KBG-2 Other ( luas eauiD. etc.\ - JEWELRY Depth TVD TVDe 1715 1702 NIP 1715 1702 SSSV 7853 6922 NIP 7896 6948 PKR 7972 6990 NIP 7985 6996 WLEG GLV GLV OV DescriDtion CAMCO BAL-O NIPPLE CAMCO WRDP-2-BAL-SSA-S SSSV reset 9/27/2003 HES 'X' NIPPLE BAKER 'S-3' PACKER HES 'XN' NIPPLE BAKER WIRELlNE RE-ENTRY GUIDE Grade H-40 J-55 L-80 Thread WELDED BTC-MOD BTCM Thread IBTM TRO Vlv Cmnt Date Run 1/25/2001 1/25/2001 1/25/2001 ID 3.812 1.250 3.813 3.875 3.725 3.875 '" . . V¡¡:;tf~ k;} c.ør STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well_ Plugging _ Time extension - Stimulate _X Change approved program Pull tubing Variance Perforate Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development _X RKB 56 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic _ Anchorage, AK 99510-0360 Service Colville River Unit 4. Location of well at surface 8. Well number 508' FNL, 2985' FEL, Sec. 5, T11 N, R5E , UM (asp's 385717,5975622) CD1-41 At top of productive interval 9. Permit number / approval number 1130' FNL, 1052' FEL, Sec. 6, T11 N, R5E, UM (asp's 382364, 5975053) 200-017 At effective depth 10. API number 50-103-20328 At total depth 11. Field / Pool 3739' FNL, 2501' FEL, Sec. 31, T12N, R5E , UM (asp's 380948, 5977744) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 11170 feet Plugs (measured) true vertical 7082 feet Effective depth: measured 11170 feet Junk (measured) true vertical 7082 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" 10 cu yds Portland Type 3 114' 114' SURF CASING 2440' 9-5/8" 380 Sx AS III L, 234 sx Class G 2496' 2394' PROD CASING 8277' 7" 129 Sx Class G 8333' 7101' OPEN HOLE 2837' 6.125" 11170' OPEN HOLE SCANNED SEP 1 3 2007 ITEC12/'v. Perforation depth: measured None C:D true vertical None 4ÞR 2 7 Alaska OW lOOT & Gas Tubing (size, grade, and measured depth 4-1/2",12.6#, L-80 Tbg @ 7985' MD. ~. CoI71rniSSior¡ Packers & SSSV (type & measured dep.th) BAKER 'S-3' PACKER @ 7896' MD. CAMCO WRDP-2-Bal SSSV @ 1715' MD. 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: April 9, 2001 16. If proposal was verbally approved Oil _X Gas - Suspended _ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Michael Erwin @ 265-1478. SignedjtA .f). J) Ò~ Title: Alpine Production Engineer Date '-f /"2-& /01 Michael EfW! Î "'- PreDated bv Sharon Allsuo-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness T Approval no. 2:() l -l \ L{ Plug integrity _ BOP Test_ Location clearance - '-\Q'l Mechanical Integrity Test_ Subsequent fonn required 10- ORIGINAL ::);1.;>1\;,- ~ {·Ol Approved bv order of the Commission n T"'\llnr c~<>~, Commissioner Date , Form 10-403 Rev 06/15/88' ORIGINAL SUBMIT IN TRIPLICATE .. . . Stimulation Procedure Colville River Field CDl-41 Conversion operations will commence following ice road construction on or about April 1, 2001. Completion is expected on or about April 15, 2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. --.......... ~ 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot +/-110 bbl. ofDS MudSolv mixed in a 9.2 ppg KCL base fluid in the openhole interval. ~ 3. POOH and RD coil tubing. 4. Allow the breaker to soak for 24 hours. 5. Return the well to production. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _x Plugging _ Perforate - Pull tubing _ Alter casing _ Repair well _ Other - 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development _X RKB 56 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphlc_ Anchorage, AK 99510-0360 Service Colville River Unit 4. Location of well at surface 8. Well number 508' FNL, 2985' FEL, Sec. 5, T11 N, R5E , UM (asp's 385717,5975622) CD1-41 At top of productive interval 9. Permit number 1 approval number 1130' FNL, 1052' FEL, Sec. 6, T11 N, R5E, UM (asp's 382364, 5975053) 200-017/ At effective depth 10. API number 50-103-20328 At total depth 11. Field 1 Pool 3739' FNL, 2501' FEl, Sec. 31, T12N, R5E, UM (asp's 380948, 5977744) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 11170 feet Plugs (measured) true vertical 7082 feet Effective depth: measured 11170 feet Junk (measured) true vertical 7082 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" 10 cu yds Portland Type 3 114' 114' SURF CASING 2440' 9-5/8" 380 Sx AS III L, 234 Sx Class G 2496' 2394' PROD CASING 8277' 7" 129 Sx Class G 8333' 7101' OPEN HOLE 2837' 6.125" 11170' RECEIVt:O Perforation depth: measured None APR 2 7 ~ 2001 true vertical None OW & Gas ~. COfTIrrü . SSlon Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 7985' MD. Packers & SSSV (type & measured depth) BAKER '5-3' PACKER @ 7896' MD. CAMCO WRDP-2-Bal SSSV @ 1715' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Representative Dailv Averaqe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1764 1982 4 - 194 Subsequent to operation 1003 1311 2 - 189 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~~~ 'ì)~ Title Alpine Production Engineer Date ~/2~/1) Michael Erwin Prepared by Sharon Allsup-Drake 263-461~ , ~ Form 10-404 Rev 06/15/88' OR SUBMIT IN DUPLICATE .,. . . CDl-41 Description of Work Completed CT Enzyme Treatment 4/9/01 : CT ENZYME TREATMENT COMPLETED. 1ST TRIP SET DOWN @ 10000' CTM WEATHERFORD FOR FAILED PULLED OUT AND FOUND LARGE CHUNKS OF WHAT APPEARS TO BE FORMATION ROCKS LODGED IN IT & THE CENTRALIZER. THE LARGEST 1-1/4" X 1-1/4" X 1/2" ALL ANGULAR. CHANGED BHA. ON 2ND TRIP CT ENZYME TREATMENT COMPLETED. TREATED OPEN HOLE SECTION FROM 10612' CTM UP TO 8300' CTM USING 126 BBLS OF MUDSOLVE. RETRIEVED ROCKS IN THE CENTRALIZER AGAIN. WELL TO STAY SHUT IN FOR UPCOMING FLOW BACK 4/10/01 : POST ENZYME FLOW BACK TO TANKS USING LIFT GAS @ 1.6MM - 203 BBLS TOTAL FLUID WITH THE LAST ONE GALLON SAMPLE @ 100% OIL [Other Stirn] ..~':"'~'" MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill No. 2000170 MD 11170 TVD DATA SUBMITTAL COMPLIANCE REPORT 8/29/2002 Well Name/No. COLVILLE RIV UNIT CD1-41 Operator PHILLIPS ALASKA INC. 7082 Completion Date 3/31/2000 Completion Status 1-OIL Current Status API No. 50-103-20328-00-00 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples N~o -- Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name Interval Log Log Run OH / Scale Media No Start Stop CH T 2450 11170 Ope (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments 5/19/2000 09656~'"" :~4-56~-~-'~-~1~-- T 8050 10500 Cas 3/13/2001 09971~'/ 8050-10500 T 2400 8166 Ope 5/19/2000 2400-8166 09655,/" T 8200 10618 Cas 3/13/2001 09972~8200-10618 ,L L 2/5 FIELD 2496 11170 OH 5/19/2000 2496-11170 IL L 2/5 FIELD 2400 7100 OH 5/19/2000 2400-7100 ~L L 2/5 FIELD 2506 8122 OH 5/19/2000 2506-8122 PB1 L 2/5 FIELD 2400 7200 OH 5/19/2000 2400-7200 PB1 L L 2/5 FIELD 2325 7200 OH 5/19/2000 2325-7200 PB1 L L 2/5 FINAL 8200 10618 ch 3/13/2001 8200-10618 BL, Sepia ~ --.D.-- FINAL 8200 10618 ch 3/13/2001 ~ 8200-10618 Digital Data L L 2/5 FINAL 8050 10500 ch 3/13/2001 8050-10500 BL, Sepia L L 2/5 FIELD 2506 8122 OH 5/19/2000 2506-8122 PB1 C ..... '-G~ ...... 1 OH 5/19/2000.J;)666-'~ SCHLUM CDR/ADN PB1~ e.~, ~ 1 OH 5/19/2000 9666-- SCHLUM IMP-CDR/ADN/M10 R 'R,'" 114 8166 OH 6/29/2000 BHI 114-8166 PH1 R '1~ 7113 11170 OH 6/29/2000 BHI 7113-11170 R .--R~i, 0 11170 OH 4/10/2000 SCHLUM 0-11170 R ~ 0 8166 OH 4/3/2000 SCHLUM 0-8166 PH ,-'~D~ .... ---'B~ FINAL 8050 10500 ch 3/13/2001 ~ 8050-10500 Digital Data Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Permit to Drill No. 2000170 DATA SUBMITTAL COMPLIANCE REPORT 8/29/2002 Well Name/No. COLVILLE RIV UNIT CD 1-41 Operator PHILLIPS ALASKA INC. MD 11170 TVD 7082 Completion Date 3/31/2000 Completion Status 1-OIL Current Status Well Cored? Y/¢ Dally History Received? Chips Received? ~ Formation Tops Receuived? Analysis Received? AP1 No. 50-103-20328-00-00 I-OIL UIC N Comments: Annular Dis vosaI durin the second quarter o r2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133, 1C-121, 1C-123, 1C-127 :7 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Dis ¢osal Authorization Expired during the second quarter 2001: .............................. j ............. ~.- ..................... · ~ + Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume .Status of Annulus ~' 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 ' 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- / 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attaChed the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup~Drake Annular Dis 9osal durin the second quarter of 2001: h(1) h(2) 'h(3) ' Total for Previous 'New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01' 1C-133, 1(2-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 . Dec 00 Jun 01 2N-302, 2N-314, .... 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May,01 Jun 01 CD2,24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 ..... Lo} Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2001: ' ' Total Voiume ' ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume VOlume Volume Status of Annulus , 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 .... 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down , CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 Zoo. o 4.3 o='o '=' O " -- ~~~ "-s~ ë/,L I STATE OF ALASKA . A SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface Development _X Exploratory _ Stratigraphic _ Service (asp's 385717, 5975622) At total depth 3739' FNL, 2501' FEL, Sec. 31, T12N, R5E , UM 12. Present well condition summary Total depth: measured true vertical (asp's 380948, 5977744) 11170 feet 7082 feet Plugs (measured) Effective depth: measured true vertical Casing Length Size CONDUCTOR 114' 16" SURF CASING 2440' 9-5/8" PROD CASING 8277' 7" OPEN HOLE 2837' 6.125" OPEN HOLE Junk (measured) Cemented Perforation depth: true Tubing (size, grade, and measured depth 4-1/2",12.6#, L-80 Tbg @ 7985' MD. Packers & SSSV (type & measured depth) BAKER 'S-3' PACKER @ 7896' MD. Oil_X Service Colville River Unit 8. Well number CD1-41 9. Permit number / approval number 200-017 10. API number 50-103-20328 11. Field / Pool Colville River Field / Alpine Oil Pool Measured Depth 114' 2496' 8333' 11170' True vertical Depth 114' EIVED JUL 2 0 2001 Alaska Oil & Gas Cons. Commission Anchorage Gas Suspended _ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- "-\0 '4 ORIGINAL SIGNED BY Form 10-403 Rev 06/15/88· ORIGtf\JAL Commissioner Ç;-1'~ '0 \:; \ Date ~ SUBMIT IN TRIPLICATE .. . . Stimulation Procedure Colville River Field CDl-41 Conversion operations will commence on or after August 1,2001. Completion is expected before December 15,2001. This procedure is designed to reduce the residual water saturation (water block) and stimulate a producing well by restoring the initial fluid saturation to the wellbore. 1. RU coil tubing unit. Gill with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot one wellbore volume of 2-3% mutual solvents and surfactants blended into a diesel base fluid in the openhole interval. 3. Pump approximately 1000 bbl. of solvent and diesel at matrix injection rates. 4. POOH and RD coil tubing. 5. Allow the breaker to soak for 24 hours. 6. Return the well to production. Flowback and clean up the well. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17,2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC; Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files RECEIVED JUL Alaska Oil & Gas Cons. Commission Anchorage Annular Dis vosal durin the second quarter o ~ 2001: h(1) h(2) h(3) Total for Previous New start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, 1c-121, 1c-123, 1c-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 H-10 .... CD2-42 16902 100 0 17002 0 17002 ... May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C~127 ,,, Total Volumes into Annuli ¢r which Disposal Authorization Expired during the second quarter 2001: Total Voiume ' Start End' Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ID-II 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 .... , 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, cD1-40, CD12 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- .... 33, CD1-NQ1 o ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave.-Ste. 100 Anchorage, AK 99501-3539 RE' Distribution- Final Print(s) 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' Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE REPORT WELL DATE TYPE OR SEPIA LINE OR CD-ROM FILM PRINT(S) BLUE LINE Open. Hole _1 I 1 CD 1-41 02-20.01 Res. _Eval. CH I I 1 Mech. _CH I Caliper:Survey I Rpt or I Color Signed' Print Name: L.~ ProActive Diagnostic Services,--Inc., Date · RECEIVED l 2001 Naska'Oil & Gas Cons. Commissio~ 310 K Street Suite 20~C~o. fa-ge, AK Phone:(907) 245-8951 Fax:(907) 245-8952 E-mit: ixlsanchorage t~memorylog, com 99501 Website: u,~wv, n~emory, log. corn ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 100 Anchorage, AK 99501.3539 RE' Distribution- Final Print(s) 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' Joey Burton / Jerry Morgan ProActive Diagnostic-Services, Inc. P. O. Box 1369- Stafford, TX 77497 LOG, DIGITAL -MYLAR / BLUE REPORT WELL DATE TYPE OR SEPIA LINE OR CD.ROM .FILM .PRINT(S) BLUE LINE Open:Hole .1 I 1 CD141 02.19.0-1' Res, ~Eval. -CH- _ Mech. CH Caliper-Survey- I Rpt or' t I COt.or Signed' ~~~ Date' I Print Name: ~ ! 5 200] BroActive DiagnoStic Services,-Inc., 3-1.0 K St.~eet Suite ~-68_. Aachor-a~e. A~ 99581 N~ oir& gas ~ns. commissl~ Phone:(~7) 245-8951 F~(~ 245-8952 E.m~t: ~ch~o~~ A~chor~itc: ~v.memo~log.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~'~ Gas E] Suspended F'] Abandoned F~ Service 2. Name of Operator 7. Permit Number Inc. ~ 200-017 Phillips Alaska, 3. Address ~.,~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 , 50-103-20328-00 & 50-103-20328-70 4. Location of well at surfacei[~'~'~'~'-';~?(";0'~ ..... ...... iON t~ [.~.. ~' ,9.Unit or Lease Name 509' FNL, 2293' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385717, 5975622) i DATE ~~ Colville River Unit Producing Interval,J ~ 10. Well Number At Top VERIFIED .~ CD1-41 & CD1-41PH 1130' FNL, 1052' FEL, Sec. 6, T11N, R5E, UM (ASP: 382364, 5975053) At Total Depth~ ..... ~;;;~-.-~~ 11. Field and Pool 1540' FSL, 2509' FEL, Sec. 31, T12N, R5E, UM (ASP: 380947.5, 5977744.5) Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool DF 56 feetI ADL 25559 & 25558 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions March 17, 2000 March 30, 2000 March 31, 2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost YES ['~ No E]I 1715' feetMD 1562' 11170' MD / 7082' TVD 11170' MD / 7082' TVD 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-If'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2496' 12.25" 380 sx AS III L, 234 sx Class G 7" 26# L-80 Surface 8332' 8.5" 129 sx Class G CD1-41 PB1 cement plug dressed off to 7154' to start CD1-41 sidetrack 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 7985' 7896' 6.125" OH completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8166'-7545' Plug #1:48 bbls 15.8#PPG Class G 7545'-7038' Plug #2: Pump 40 bbls 17.0 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL !GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24~Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A c :!,JN 2 9 2000 ORIGINAL Alaska oil & Gas Gons, G0mmission Form 10-407 Rev. 7-1-80 CONTINU ED ON REVERSE SIDE Submit in duplicate 29. NAME CD1-41 Top Alpine TD 0D1-41 PH Top Alpine TD GEOLOGIC MARKERS MEAS. DEPTH 8118' 11170' 7930' 8166' TRUE VERT. DEPTH 7056' 7082' 7055' 7259' 30. FORMATION TESTS Include interval tested, pressure dala, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diese 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby cedify that the following is true and correct to the best of my knowledge. Signed , ,, Title Drilling Team Leader Doug~ster Questions? Call Brian Robertson 265-6034 Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. ~.~,~¢ r~,,, ,~ ~':;'~"' Item 28: If no cores taken, indicate "none". Form 10-407 JUN 2 9 20O0 Alaska Oil & Ga~ Cons, Date: 05/11/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-41 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:03/17/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20328-00 03/17/00 (D1) MW: 8.7 VISC: 300 PV/YP: 11/ 1 APIWL: 16.5 TD/TVD: 176/176 (176) DRILLING SURFACE HOLE ~ 760' SUPV:SCOTT D REYNOLDS Move over to CD1-41. Nil diverter system. Accept rig ~ 16:30 hrs. Function test diverter system. Hold pre-spud meeting. Drill from 115' to 176'. Run gyro survey. 03/18/00 (D2) MW: 9.6 VISC: 135 PV/YP: 6/48 APIWL: 14.6 TD/TVD: 2335/2254 (2159) SHORT TRIP. DIESEL SMELL ON RIG FLOOR - PIT - AND GIS SUPV:SCOTT D REYNOLDS Drill from 176' to 2335' Some packing off while drilling and reaming from 1800' to 2335'. Added soap and nut plug. Pumped 40 bbls coarse nut plug pill to scour bit. 03/19/00 (D3) MW: 9.6 VISC: 49 PV/YP: 11/14 APIWL: 18.0 TD/TVD: 2506/2402 ( 171) TESTING BOPE. SUPV:SCOTT D REYNOLDS Drill from 2335' to 2506' Drilled through ratty formation ~ 2460'. Encountered diesel fumes @ 2480' MD. Pump sweep, circ & condition mud. Continue to get diesel fumes in pits while circulating. Monitor well, static. Short trip to 1000'. Run 9-5/8" casing. PJSM. Pump cement. Bumped plug. Floats held. 03/20/00 (D4) MW: 9.6 VISC: 40 PV/YP: 9/18 APIWL: 10.0 TD/TVD: 3096/2913 (590) DRILLING AHEAD ~ 3639' SUPV:SCOTT D REYNOLDS Remove diverter & flush knife valve. Set stack. NU BOPE and test 250/3500 psi. RIH. Wash and ream thru cement stringers to 2386'. Break circulation & condition mud. Test casing to 2500 psi, good test. Tag plugs ~ 2404' Drill float shoe & 20' new hole. Circulate and condition mud for LOT/FIT. Perform FIT to 16 ppg EMW. Drill from 2526' to 3096' 03/21/00 (D5) MW: 9.6 VISC: 42 PV/YP: 6/25 APIWL: 6.2 TD/TVD: 5761/5181 (2665) PRE-RESERVOIR MEETING. SUPV:SCOTT D REYNOLDS Drill from 3096' to 3571'. Pump hi vis sweep. Circulate hole clean. Monitor well, static. POOH from 3571' to 2506' Drill from 3571' to 5761'. Pump hivis sweep. Circulate hole clean. Monitor well static. POOH from 5761' to 3571' Date: 05/11/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 03/22/00 (D6) MW: 9.7 VISC: 40 PV/YP: 8/21 APIWL: 5.2 TD/TVD: 8090/7194 (2329) TOOH. SUPV:SCOTT D REYNOLDS/PAT REILLY Short trip to 3476' Screw in, establish circ., wash and ream from 5666' to 5761'. Drill from 5761' to 8090' 03/23/00 (D7) MW: 9.7 VISC: 42 PV/YP: 9/21 APIWL: 5.6 TD/TVD: 8166/7259 ( 76) SIDE TRACKING. SUPV:REYNOLDS/REILLY Drilling from 8090' to 8166' Circ/sweep. Short trip to 7697' POH, observe well. RIH. Circ and condition mud. PJSM. Pump cement to balance plug #1. Pull slow to 7545' CBU. Pump cement for plug #2. POH to 7038' 03/24/00 (D8) MW: 9.6 VISC: 41 PV/YP: 11/20 APIWL: 5.4 TD/TVD: 7986/6996 ( 0) SLIDING ~ 8176. SUPV:REYNOLDS/REILLY RIH to 6963'. Wash/ream from 6963' to 7038' Drill cement from 7038' to 7154'. Time drill from 7154' to 7986' 03/25/00 (D9) MW: 9.7 VISC: 43 PV/YP: 10/20 APIWL: 5.4 TD/TVD: 8342/7102 ( 356) RUNNING 7" CASING. SUPV:REYNOLDS/REILLY Drill from 7986' to 8342'. Circ/sweep. Short trip, work various tight spots from 7170'. Continue trip to 6297', monitor well, RIH. Tag up ~ 8060', screw in and work/wash to bottom. Pump sweep, circ and clean, monitor well, POH to 7387'. Monitor well, pump dry job. POH. R/U to run 7" casing. PJSM. Run 7" casing. 03/26/00 (D10) MW: 9.6 VISC: 38 PV/YP: 10/14 APIWL: 6.8 TD/TVD: 8342/7102 ( 0) SLIP & CUT DRLG LINE. SUPV:REYNOLDS/REILLY Run 7" casing. Circ casing volume ~ 5.5 bpm. Continue RIH to 3772 (meth gas alarm) check flow. Circ and condition mud, monitor well. Continue RIH. Run 7" casing. PJSM. Cement casing. Bumped plug, checked float. Set packoff test to 5000 psi. Test BOPE. Perform LOT to 15.4 ppg EMW. Pumped diesel for freeze protection. 03/27/00 (Dll) TD/TVD: 8700/7112 SUPV:SCOTT REYNOLDS MW: 0.0 VISC: 38 PV/YP: 0/ 0 ( 358) DRILLING AHEAD ~ 9040' APIWL: 0.0 RIH tO 8137'. Tag up on cement stringers. Wash and ream cement stringers from 8137' to 8220'. Circulate and condition mud for casing test. Test 7" casing to 3500 psi, OK. Wash and ream cement stringers from 8220' to 8250' Drill float equipment. Drill 20' new hole from 8342' to 8362'. Circulate and condition mud for LOT. Perform LOT to 12.5 ppg EMW. Displace well to 9.2 ppg Flo-Pro mud system. Monitor well, static Drill from 8362' to 87~F% 2000 Date: 05/11/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 03/28/00 (D12) MW: 9.2 VISC: 53 PV/YP: 11/26 APIWL: 4.0 TD/TVD: 9799/7098 (1099) DRILLING AHEAD ~ 10041' SUPV:SCOTT REYNOLDS Drill from 8700' to 9799'. Pump lo vis/hivis sweep. Circulate until hole clean. Pump out to shoe ~ 8332'. No hole problems encountered. 03/29/00 (D13) MW: 9.2 VISC: 53 PV/YP: 13/27 APIWL: 3.9 TD/TVD:10875/7082 (1076) DRILLING AT 11,110' SUPV:DONALD LUTRICK Pump out to shoe. Monitor well. No problems. RIH to TD. CBU. Drilling from 9799' to 10875' 03/30/00 (D14) MW: 9.2 VISC: 0 PV/YP: 0/ 0 TD/TVD:ll170/7082 (295) RIH W/ 4 1/2" COMPLETION SUPV:DONALD LUTRICK APIWL: 0.0 Drilling from 10875' to 11170'. Circ hi vis sweep. Pump out to shoe. No problems. CBU at shoe. RIH to TD. Circ hi vis sweep. Circ until clean. PJSM. Displace well to 9.2 brine. Monitor well. POH to shoe. No problems. Monitor well. 10 bph loss. POH. Pump slug. POH. 03/31/00 (D15) MW: 9.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:ll170/7082 ( 0) LEVEL RIG AT CD1-23 SUPV:DONALD LUTRICK PJSM. RIh w/4.5"completion. RIH w/4.5" tubing. Test packoffs to 5000 psi. ND BOP. NU tree and test to 5000 psi. Freeze protect well. Set BPV. Secure well. Release rig ~ 4/1/00 00:00 hrs. SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00018 Sidetrack No. Page 1 of 4 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD ' Well Name & No. PAD CD#1/41 PH1 / 41 Survey Section Name CD1-41 PH1 MWD BHI Rep. D NEWLON ~NI'TEI~ WELL DATA TargetTVD (F-r) Target Coord. N/S Slot Coord. N/S -509.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ ssE~ Target Description Target Coord. E/W Slot Coord. E/W 2293.00 Magn. Declination 25.860 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft[~ 30mE] 10m~ Vert. Sec. Azim. 251.78 Magn. to Map Corr. 25.860 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F~ (DD) (DD) (FT) (FT) (F-T} (F-T) (Per 100 F'r) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 17-MAR-00 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 9 1/2" M1C 1.4 DEG AKO 18-MAR-00 MWD 189.00 0.50 293.00 75.00 189.00 0.25 0.13 -0.30 0.67 0.67 Gyro Single Shot 18-MAR-00 MWD 368.00 4.25 293.00 179.00 367.81 5.82 3.03 -7.13 2.09 2.09 Gyro Single Shot 18-MAR-00 MWD 475.83 5.78 291 ~86 107.83 475.23 12.98 6.61 -15.85 1.42 1.42 -1.06 18-MAR-00 MWD 564.78 4.64 285.38 88.95 563.81 19.41 9.23 -23.47 1.44 -1.28 18-MAR-00 MWD 654.13 3.44 276.70 89.35 652.94 24.85 10.50 -29.62 1.50 -1.34 18-MAR-00 MWD 737.63 2.71 271.80 83.50 736.32 28.98 10.86 -34.08 0.93 -0.87 18-MAR-00 MWD 826.55 1.62 271.29 88.92 825.17 32.14 10.95 -37.44 1.23 -1.23 18-MAR-00 MWD 915.43 1.18 266.69 88.88 914.02 34.21 10.93 -39.61 0.51 -0.50 18-MAR-00 MWD 1004.57 0.12 184.63 89.14 1003.16 35.13 10.78 -40.53 1.31 -1.19 18- MAR-00 MWD 1100.18 0.41 231.39 95.61 1098.77 35.49 10.47 -40.81 0.35 0.30 18-MAR-00 MWD 1196.43 4.29 245.87 96.25 1194.92 39.39 8.78 -44.36 4.05 4.03 18-MAR-00 MWD ., 1291.73 7.32 246.53 95.30 1289.72 48.99 4.90 -53.19 3.18 3.18 0.69 18-MAR-00 MWD 1387.18 9.53 253.13 95.45 1384.13 62.94 0.19 -66.33 2.52 2.32 6.91 18-MAR-00 MWD 1481.52 12.02 255.44 94.34 1476.80 80.56 -4.55 -83.31 2.68 2.64 2.45 18- MAR-00 MWD 1576.85 14.18 251.56 95.33 1569.65 102.14 -10.74' -104.00 2.45 2.27 -4.07 18-MAR-00 MWD 1671.66 16.98 248.10 94.81 1660.97 127.58 -19.58 -127.87 3.11 2.95 -3.65 18- MAR-00 MWD 1766.58 19.97 251.06 94.92 1750.99 157.62 -30.01 -156.06 3.30 3.15 3.12 18-MAR-00 MWD 1861.89 23.85 251.98 95.31 1839.40 193.18 -41.26 I -189.80 4.09 4.07 0.97 18-MAR-00 MWD 1956.73 28.55 253.14 94.84 1924.47 ! 235.03 -53.77I! -229.74 4.98 4.96 1.22I~ 18-MAR-00 MWD 2051.67 29.65 253.96 94.94 2007.43 281.18 -66.84 -274.02 1.23 1.16 0.86 18-MAR-00 MWD 2147.94 29.51 I 253.07 96.27 2091.1 5 328.68 -80.32 ! -319.59 0.48 -0.15 -0.92 18-MAR-O0 MWD 2242.95 29.45 254.82 95.01 2173.86 375.40 -93.25 -364.52 0.91 -0.06 i 1.84 SURVEY CALCULATION AND FIELD WORKSHEET Job no. 0.50-00o18 S rac No. Page 2 4 Company ARCO ALASKA, INC. Rig Contractor & No..Do_y.o~_.~!!!!?g___C_o._.-___Rig: #19 .......................... Field ALPINE FIELD Well Name & No. PAD CD#1/41 PH1 /41 Survey Section Name CD1-41 PH1 MWD BHI Rep. D NEWLON ~ WELL DATA (F-r) Target Coord. N/S Slot Coord. N/S -509.00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL[~ SS[- =ription Target Coord. E/W Slot Coord. E/W 2293.00 Magn. Declination 25.860 Calculation Method MINIMUM CURVATURE ;tion (DD) Build\Walk\DL per: 100ft~ 30m~ 10m~ Vert. Sec. Azim. 251.78 Magn. to Map Corr. 25.860 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Tool Depth Angle Direction Length 'FVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) MWD 2337.88 29.90 253.30 94.93 2256.34 422.36 -106.16 -409.71 0.92 0.47 -1.60 MWD 2445,02 29.59 251.93 107.14 2349.36 475.51 -122,04 -460.43 0.70 -0.29 -1.28 MWD 2545.00 30.28 251.72 99.98 2436.01 525.40 -137.61 -507.83 0,70 0.69 -0.21 6 3/4" M1/XL 1.2 DEG AKO MWD 2641.00 29.84 .. 250.62 96.00 2519.09 573.48 -153.12 -553.35 0.73 -0.46 -1.15 MWD 2736.00 29.60 249.59 95.00 2601.60 620.56 -169.15 -597.63 0.59 -0,25 -1.08 MWD 2830.00 30.05 251.56 94.00 2683.15 667.29 -184.69 -641.72 1.15 0.48 2.10 MWD 2925.00 30.00 251.96 95.00 2765.40 714.83 -199.57 -686.87 0.22 -0.05 0.42 MWD 3021.00 31.60 252.69 96.00 2847.86 763.98 -214.48 -733.70 1.71 1.67 0.76 MWD 3117.00 32.01 253.56 96.00 2929.44 814.56 -229.17 -782.12 0.64 0.43 0.91 MWD 3212.00 31.99 252.77 95.00 3010.01 864.88 -243.75 -830.30 0.44 -0.02 -0.83 MWD 3306.00 31.61 252.59 94.00 3089.90 914.41 -258.49 -877.59 0.42 -0.40 -0.19 MWD 3401.00 31.18 251.56 95.00 3170.99 963.90 -273.72 -924.67 0.72 -0.45 -1.08 MWD 3495.00 30.61 250.53 94.00 3251.65 1012.16 -289.40 -970.32 0.83 -0.61 -1.10 MWD "3591.00 30.31 249.65 96.00 3334.40 1060.80 -305.97 -1016.08 0.56 -0.31 -0.92 MWD 3686.00 29.81 249.74 95.00 3416.63 1108.36 -322.48 -1060.71 0.53 -0.53 0.09 MWD 3781.00 31.13 250.81 95.00 3498.51 1156.51 -338.73 -1106.05 1.50 1.39 1.13 MWD 3876.00 31.82 252.91 95.00 3579.53 1206.10 -354.16 -1153.19 1.36 0.73 2.21 MWD 3972.00 33.20 252.83 96.00 3660.49 1257.69 -369.36 -1202.49 1.44 1.44 -0.08 MWD 4067.00 33.76 253.60 95.00 3739.72 1310.08 -384.49 -I 252.66 0.74 0.59 0.81 MWD 4163.00 33.91 253.01 96.00 3819.46 1363.51 -399.85 -1303.86 0.38 0.16 -0.61 MWD 4258.00 , 34.12 253.44 95.00 3898.21 1416.64 -415.19 -1354.75 0.34 0.22 i 0.45 MWD 4353.00 33.95 253.01 95.00 3976.94 1469.79 -430.53 -1405.65 0.31 -0.18 i -0.45 MWD 4448.00 33.65 252.72 95.00 4055.88 1522.63 -446.10 -1456.16 0.36 -0.32 -0.31 MWD 4543.00 33.37 252.07 95.00 4135.09 1575.07 -461.96 -1506.15 0.48 -0.29 -0.68 target TVD r'arget Descri~ target Directi Date 19-MAR-00 19-MAR-00 _~0-MAR-00 _~0-MAR-00 _~0-MAR-00 >_0-MAR-00 _~0-MAR-00 _>0-MAR-00 _~1 -MAR-00 ->1 -MAR-00 _>1 -MAR-O0 _>1 -MAR-00- :)1 -MAR-00 ;)1 -MAR-00 ;)1 -MAR-00 21 -MAR-00 21 -MAR-00 21 -MAR-00 21 -MAR-O0 21 -MAR-00 21 -MAR-00 21 -MAR-00 21 -MAR-00 21 -MAR-00 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00018 Sidetrack No. Page 3 of 4 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD '~ Well Name & No. PAD CD#1/41 PH1 / 41 Survey Section Name CD1-41 PH1 MWD BHI Rep. D NEWLON ~'~lrr~l~ WELL DATA target TVD (FT) Target Coord. N/S Slot Coord. N/S -509.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SSI- target Description Target Coord. E/W Slot Coord. E/W 2293.00 Magn. Declination 25.860 Calculation Method MINIMUM CURVATURE ]'arget Direction (DD) Build\Walk\DL per: 100ft[~ 30m~] 10m~ Vert. Sec. Azim. 251.78 Magn. to Map Corr. 25.860 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) :)1 -MAR-00 MWD 4638.00 33.17 251.55 95.00 4214.52 1627.19 -478.23 -1555.66 0.37 -0.21 -0.55 :)1 -MAR-00 MWD 4733.00 32.55 251.47 95.00 4294.32 1678.73 -494.58 -1604.54 0.65 -0.65 -0.08 ..) :)1 -MAR-00 MWD 4828.00 32.00 251.16 95.00 4374.64 1729.46 -510.83 -1652.60 0.60 -0.58 -0.33 _>1 -MAR-00 MWD 4924.00 31.52 .. 251.11 96.00 4456.26 1779.99 -527.17 -1700.42 0.50 -0.50 -0.05 :)1 -MAR-00 MWD 5019.00 31.02 250.75 95.00 4537.46 1829.29 -543.28 -1747.02 0.56 -0.53 -0.38 :)1 -MAR-00 MWD 5114.00 30.60 250.53 95.00 4619.06 1877.94 -559.41 -1792.93 0.46 -0.44 -0.23 :~1 -MAR-00 MWD 5211.00 30.21 249.26 97.00 4702.72 1927.01 -576.28 -1839.03 0.78 -0.40 -1.31 ::)1 -MAR-00 MWD 5306.00 29.80 249.47 95.00 4784.98 1974.47 -593.02 -1883.49 0.45 -0.43 0.22 21 -MAR-00 MWD 5401.00 29.24 248.34 95.00 4867.65 2021.22 -609.86 -1927.16 0.83 -0.59 -1.19 21 -MAR-00 MWD 5496.00 28.86 248.10 95.00 4950.70 2067.26 -626.98 -1969.99 0.42 -0.40 -0.25 21 -MAR-00 MWD 5592.00 29.40 249.87 96.00 5034.56 2113.93 -643.73 -2013.62 1.06 0.56 1.84 21 -MAR-00 MWD 5686.00 30.68 252.14 94.00 5115.93 2160.98 -659.03 -2058.11 1.82 1.36 2.41 22-MAR-O0 MWD 5782.00 30.97 252.51 96.00 5198.37 2210.17 -673.96 -2104.98 0.36 0.30 0.39 22-MAR-00 MWD 5877.00 30.77 252.03 95.00 5279.91 2258.91 -688.80 -2151.41 0.33 -0.21 -0.51 22-MAR-00 MWD 5972.00 30.40 251.32 95.00 5361.70 2307.24 -704.00 -2197.29 0.54 -0.39 -0.75 22-MAR-00 MWD 6068.00 29.80 250.08 96.00 5444.75 2355.38 -719.91 -2242.73 0.90 -0.63 -1.29 22-MAR-00 MWD 6162.00 29.23 250.11 94.00 5526.55 2401.67 -735.67 -2286.27 0.61 -0.61 0.03 22-MAR-00 MWD 6256.00 28.78 249.23 94.00 5608.76 2447.21 -751.51 -2329.01 0.66 -0.48 -0.94 22- MAR-O0 MWD 6351.00 29.84 252.15 95.00 5691.61 2493.70 -766.86 -2372.90 1.87 1.12 3.07 22-MAR-00 MWD 6447.00 29.11 252.50 96.00 5775.18 2540.93 -781.21 -2417.90 0.78 -0.76 0.36 22-MAR-O0 MWD 6542.00 28.57 251.74 95.00 5858.40 2586.76 -795.27 -2461.51 0.69 -0.57 -0.80 22-MAR-O0 MWD 6637.00 30.05 252.38 95.00 5941.23 2633.26 -809.59t -2505.76 1.59 1.56 0.67 22-MAR-OO MWD 6732.00 31.35 253.74 95.00 6022.92 2681.74 -823.71 -2552.15 1.55 1.37 1.43 22-MAR-00 MWD 6828.42 31.19 253.87 96.42 6105.33 2731.76 -837.67 -2600.22 0.18 -0.17 0.13 SURVEY CALCULATION AND FIELD WORKSHEET JobNo. 0450-00010 Sidetrack No. Page 4 of 4 ii-' [I.r~-' I ::~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/41 PH1 /41 Survey Section Name CD1-41 PH1 MWD BHI Rep. D NEWLON IN"r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord, N/S -509.00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL~ SS~ I Target Description Target Coord, E/W Slot Coord, E/VV 2293,00 Magn. Declination 25.860 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec, Azim, 251,78 Magn, to Map Corr. 25,860 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (F-r) (F-T) (FO (FO (Per 400 FO Drop (-) Left (-) 22-MAR-00 MWD 6923.00 30.62 253.06 94.58 6186.48 2780,32 -851.49 -2646.79 0.75 -0,60 -0,86 -.~ 22-MAR-00 MWD 7018,00 29,95 251,51 95,00 6268,52 2828,22 -866,06 -2692,42 1,08 -0,71 -1,63 22-MAR-O0 MWD 7113,00 29.28 ~ 251.30 95.00 6351,11 2875,16 -881,03 -2736,92 0,71 -0,71 -0,22 22-MAR-00 MWD 7208,00 30,17 .. 252,48 95.00 6433,61 2922,27 -895,67 -2781,69 1,12 0,94 1,24 22-MAR-00 MWD 7303.00 30.91 253,59 95.00 6515,43 2970,53 -909,75 -2827,86 0,98 0,78 1,1 7 22-MAR-O0 MWD 7398,00 30,26 253,41 95,00 6597,21 3018,84 -923.48 -2874,21 0,69 -0,68 -0,19 22-MAR-O0 MWD 7494,00 29,71 253,62 96.00 6680,36 3066,80 -937.09 -2920,21 0,58 -0,57 0,22 22-MAR-00 MWD 7591,00 30,61 253,45 97.00 6764,23 3115,51 -950,90 -2966,95 0,93 0,93 -0,18 22-MAR-00 MWD 7685,00 31.21 254.88 94.00 6844,88 3163.75 -964,07 -3013,40 1,01 0,64 1,52 : 22-MAR-O0 MWD 7780,00 30,85 254,92 95,00 6926,29 3212,65 -976,83 -3060,68 0,38 -0,38 0,04 22-MAR-00 MWD 7875,00 30,40 255,89 95.00 7008,04 3260,95 -989,03 -3107,51 0,70 -0,47 1,02 22- MAR-00 MWD 7971,00 30,28 255,40 96,00 7090,89 3309,33 -1001,05 -3154,49 0,29 -0,12 -0,51 22- MAR-O0 MWD 8066.00 30,52 255,31 95,00 7172.83 3357,31 -1013,21 -3201,00 0,26 0,25 -0.09 23-MAR-00 MWD ~ 8091.00 30.41 255.30 25.00 7194.38 3369.96 -1016.42 -3213.26 0.44 -0.44 -0.04 ) , 23-MAR-00 MWD 8166.00 30.41 255.30 75.00 7259.06 3407.85 -1026.05 -3249.98 0,00 0.00 0.00 Projected Data- NO SURVEY I I , F~ ~.-~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00018 Sidetrack No..1_ Page 1_ ~ ::/~-~'_ [I_r~ '_ I Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD · Well Name & No. PAD CD#1/41 PH1 / 41 Survey Section Name CD1-41 MWD BHI Rep. D NEWLON WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord. N/S -509.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~] SS~ Target Description Target Di~ Date 24-MAR-00 24-MAR-00 24-MAR-00 24-MAR-00 24-MAR-00 24-MAR-00 24-MAR-O0 24-MAR-00 24-MAR-00 24-MAR-00 24-MAR-00 24-MAR-O0 24-MAR-00 24-MAR-O0 24-MAR-00 24-MAR-00 24-MAR-00 24-MAR-O0 24-MAR-00 24-MAR-00 24-MAR-O0 24-MAR-00 24-MAR-00 Target Coord. E/W Slot Coord. ENV 2293,00 Magn. Declination 25.860 Calculation Method MINIMUM CURVATURE ~tion (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~] Vert. Sec. Azim. 331.93 Magn. to Map Corr. 25.860 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Tool Depth Angle Direction Length 'FVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'T) (FT) (FT) (F-F) (Per 100 FT) Drop (-) Left (-) MWD 7113.00 29.28 251.30 6351.11 510.54 -881.03 -2736.92 TIE IN POINT MWD 7182.00 30.18 255.72 69.00 6411.03 517.34 -890.72 -2769.71 3.43 1.30 6.41 6 3/4" M1X 1.5 DEG AKO MWD 7214.00 31.29 260.80 32.00 6438.54 521.95 -894.03 -2785.72 8.82 3.47 15.88 MWD 7247.00 32.86 266.36 33.00 6466.51 528.43 -895.97 -2803.11 10.13 4.76 16.85 MWD 7277.00 34.85 271.39 30.00 6491.43 536.01 -896.28 -2819.81 11.45 6.63 16.77 MWD 7310.43 37.14 276.68 33.43 6518.48 546.46 -894.87 -2839.39 11.55 6.85 15.82 MWD 7341.82 38.44 280.15 31.39 6543.29 557.91 -892.05 -2858.41 7.94 4.14 11.05 MWD 7372.00 38.50 278.98 30.18 6566.92 569.37 -888.93 -2876.92 2.42 0.20 -3.88 MWD 7404.00 38.68 280.58 32.00 6591.93 581.62 -885.54 -2896.59 3.17 0.56 5.00 MWD 7436.00 38.82 281.61 32.00 6616.89 594.27 -881.69 -2916.25 2.06 0.44 3.22 MWD 7467.00 38.91 281.90 31.00 6641.03 606.72 -877.72 -2935.29 0.65 0.29 0.94 MWD 7499.00 39.04 282.64 32.00 6665.90 619.75 -873.45 -2954.96 1.51 0.41 2.31 MWD 7531.00 38.83 283.09 32.00 6690.79 632.93 -868.97 -2974.56 1.10 -0.66 1.41 " MWD 7562.00 38.97 283.86 31.00 6714.92 645.84 -864.43 -2993.49 1.62 0.45 2.48 MWD 7594.00 40.32 288.18 32.00 6739.56 660.04 -858.79 -3013.10 9.59 4.22 13.50 MWD 7626.00 42.14 292.73 32.00 6763.64 675.85 -851.41 -3032.85 10.96 5.69 14.22 , MWD 7657.00 43.95 295.87 31.00 6786.29 692.61 -842.70 -3052.12 9.05 5.84 10.13 MWD 7689.00 45.91 299.89 32.00 6808.95 711.33 -832.12 -3072.08 10.78 6.12 12.56 MWD 7721.00 46.21 301.24 32.00 6831.16 731.00 -820.40 -3091.92 3.18 0.94 4.22 MWD 7752.00 46.23 301.21 31.00 6852.61 750.25 -808.80 -3111.06 0.10 0.06 -0.10 MWD 7785.00 46.26 301.34 33.00 6875.43 770.75 -796.43 -3131.43 0.30 0.09 0.39 MWD 7817.00 46.53 301.17 32.00 6897.50 790.68 -784.40 -3151.24 0.93 0.84 -0.53 ' MWD 7847.00 48.74 302.23 30.00 6917.71 809.83 -772.76 -3170.10 7.82 7.37 3.53 MWD 7879.00 52.27 304.75 32.00 6938.06 831.55 -759.12 -3190.68 12.59 11.03 7.87 SURVEY CALCULATION AND FIELD WORKSHEET Job.o. _0~._50-°°°18 SidetraCk N°. 1_ .... Page 2 of 3 COmpany ARCO ALAsKA' INc' Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/41 PH1 / 41 Survey Section Name CD1-41 MWD BHI Rep. D NEWLON ~ WELL DATA (FT) Target Coord. N/S Slot COord. N/S -509.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS[-] :ription Target Coord. E/W Slot Coord. E/W 2293.00 Magn. Declination 25.860 Calculation Method MINIMUM CURVATURE ;tion (DD) Build\Walk\DL per: 100ft[~ 30mi-] lOmr--I Vert. Sec. Azim. 331.93 Magn. to Map Corr. 25.860 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F-T) (FO (FO (FO (Per 100 FO Drop (-) Left (-) MWD 7912.00 55.50 307.13 33.00 6957.51 855.51 -743.47 -3212.25 11.39 9.79 7.21 '~ MWD 7942.00 58.10 309.69 30,00 6973.94 878,53 -727.87 -3231.91 11.23 8.67 8.53 MWD 7975.00 58.71 311.06 33.00 6991.23 904.67 -709.66 -3253.32 3.99 1.85 4.15 MWD 8006.00 59,50 ,, 312,34 31.00 7007.15 929,63 -691.97 -3273,18 4.36 2.55 4.13 MWD 8038.00 61,79 313.89 32.00 7022.83 956.03 -672.90 -3293.54 8.31 7.16 4.84 MWD 8069,00 64.64 315.93 31.00 7036.80 982.49 -653.36 -3313.13 10.91 9.19 6,58 MWD 8102.00 67.58 317.09 33.00 7050.17 1011.57 -631.47 -3333.89 9.47 8.91 3.52 MWD 8132.00 70.52 318.12 30.00 7060.89 1038.71 -610.78 -3352.78 10.31 9.80 3.43 MWD 8166.00 73.98 320.76 34.00 7071.26 1070.32 -586.19 -3373.82 12,58 10,18 7.76 MWD 8198.00 75.82 321,45 32.00 7079.59 1100.66 -562.14 -3393.22 6.12 5.75 2.16 MWD 8228.00 77.59 320.83 30.00 7086.49 1129.34 -539,41 -3411,54 6.23 5.90 -2.07 MWD 8272.00 80.57 323.61 44.00 7094.83 1171,92 -505.26 -3437,99 9.18 6.77 6.32 MWD 8367.00 87.50 330.12 95.00 7104.71 1265.93 -426.22 -3489.55 9,98 7.29 6.85 4 3/4" M1X 1.2 DEG AKO MWD 8429.00 88.05 330.46 62,00 7107.11 1327.86 -372.41 -3520.26 1.04 0.89 0.55 MWD 8527.00 88.63 330.08 98.00 7109.95 1425.77 -287.34 -3568.84 0.71 0.59 -0.39 MWD 8623.00 89.31 330,30 96.00 7111,68 1521.71 -204.06 -3616.55 0.74 0.71 0.23 MWD 8719.00 88.66 330.37 96.00 7113.38 1617.66 -120.66 -3664.06 0,68 -0.68 0.07 MWD 8815.00 90.45 331,94 96.00 7114.12 1713.64 -36,58 -3710.37 2.48 1.86 1,64 MWD 8911.00 90.82 331.41 96.00 7113.06 1809.64 47.92 -3755.91 0.67 0.39 -0.55 MWD 9006.00 91.27 331.56 95.00 7111.33 1904.62 131.39 -3801.26 0.50 0.47 0.16 MWD 9099.00 92.09 331.45 , 93.00 7108.60 1997.57 213.08 -3845.61 0.89 0.88 -0.12 MWD 9190,00 90.75 332.61 91.00 7106,35 2088.54 293.43 -3888.27 1.95 -1,47 1.27 MWD 9283.00 91.37 331.74 93.00 7104,63 2181.52 375.66 -3931.67 1,15 0.67 -0.94 MWD 9377.00 90.86 331.96 94,00 7102.80 2275.50 458.52 -3976.01 0.59 -0.54 0.23 INT 'arget TVD 'arget Descri[ 'arget Direction Date ~4-MAR-00 ~4-MAR-00 ~4-MAR-00 ~5-MAR-00 !5-MAR-00 !5-MAR-00 ~5-MAR-00 !5-MAR-00 .'5-MAR-00 !5-MAR-00 !5-MAR-00 .~5-MAR-00 .~7-MAR-00 .)7-MAR-00 .)7-MAR-00 .~7-MAR-00 )_8-MAR-00 .)8-MAR-00 _~8-MAR-00 ~_8-MAR-00 _~8-MAR-00 _~8-MAR-00 _~8-MAR-00 ~_8-MAR-00 SURVEY CALCULATION AND FIELD WORKSHEET Job No. _04~!8 Sidetrack No. 1 Page 3 of 3 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig' #19 Field ALPINE FIELD Well Name & No. PAD CD#1/41 PH1 / 41 Survey Section Name CD1-41 MWD BHI Rep. D NEWLON IN"J~"~~ WELL DATA 'arget-I-VD (F'r) Target Coord. N/S Slot CoOrd. N/S -509.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS~] *arget Description Target Coord. E/VV Slot Coord. E/W 2293,00 Magn. Declination 25.860 Calculation Method MINIMUM CURVATURE 'arget Direction (DD) Build\Walk\DL per: 100ft~ 30m[~ 10m~ Vert. Sec. Azim, 331.93 Magn. to Map Corr. 25.860 Map North to: OTHER SURVEY DATA Survey SUrvey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (~T) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) :8-MAR-00 MWD 9470.00 90.58 332.47 93.00 7101.63 2368.50 540.79 -4019.36 0,63 -0.30 0.55 '.8- MAR-00 MWD 9563.00 91.20 332.34 93.00 7100.18 2461.48 623.20 -4062.44 0.68 0.67 -0.14 '.8-MAR-00 MWD 9653.00 90.10 331.98 90.00 7099.16 2551.47 702.78 -4104.46 1.29 -1.22 -0.40 '.8-MAR-00 MWD 9746.00 89.79 ..332.16 93.00 7099.25 2644.47 784.95 -4148.02 0.39 -0.33 0.19 !9-MAR-00 MWD 9838.00 90.45 331.06 92.00 7099.06 2736.47 865.88 -4191.77 1.39 0.72 -1.20 !9-MAR-00 MWD 9929.00 91.30 330.75 91.00 7097.67 2827.44 945.39 -4236.01 0.99 0.93 -0.34 !9-MAR-O0 MWD 10021.00 89.93 331.29 92.00 7096.68 2919.42 1025.86 -4280.58 1.60 -1.49 0.59 !9-MAR-00 MWD 10113.00 90.65 331.82 92.00 7096;22 3011.42 1106.75 -4324.40 0.97 0.78 0.58 !9-MAR-00 MWD 10206.00 91.58 330.59 93.00 7094.41 3104.39 1188.24 -4369.19 1.66 1.00 -1.32 !9-MAR-00 MWD 10298.00 92.23 329.92 92.00 7091.35 3196.30 1268.07 -4414.81 1.01 0.71 -0.73 !9-MAR-00 MWD 10389.00 92.27 333.23 91.00 7087.77 3287.22 1348.03 -4458.08 3.63 0.04 3.64 !9-MAR-00 MWD 10480.63 91.27 333.64 91.63 7084.94 3378.77 1429.94 -4499.04 1.18 -1.09 0.45 !9-MAR-00 MWD 10573.00 90.24 334.73 92.37 7083.73 3471.06 1513.08 -4539.26 1.62 -1.12 1.18 !9-MAR-00 MWD 1~0664.00 90.41 332.84 91.00 7083.21 3562.00 1594.72 -4579.46 2.09 0.19 -2.08 !9-MAR-00 MWD 10756.00 90.41 334.79 92.00 7082.55 3653.95 1677.27 -4620.05- 2.12 0.00 2.12 !9-MAR-00 MWD 10849.00 90.17 334.04 93.00 7082.08 3746.86 1761.15 -4660.21 0.85 -0.26 -0.81 ~0-MAR-00 MWD 10939.00 90.07 333.87 90.00 7081.89 3836.80 1842.01 -4699.73 0.22 -0.11 -0.19 t0-MAR-00 MWD 11032.00 89.52 333.68 93.00 7082.23 3929.75 1925.44 -4740.82 0.63 -0.59 -0.20 tO-MAR-O0 MWD 11115.97 90.27 333.91 83.97 7082.38 4013.68 2000.77 -4777.90 0.93 0.89 0.27 tO-MAR-O0 ~ MWD 11170.00 90.27 333.91 54.03 7082.13 4067.67 2049.30 -4801.66 0.00 0.00 0.00 Projected Data - NO SURVEY I [ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 D. Chester Phone (907) 263-4792 Fax: (907) 265-6224 June 22, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for CD 1-41 / CD 1-41 PH(200-017) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the drilling operations on CD1-41 / CD1-41PH. If you have any questions regarding this matter, please contact me at 263-4792 or Brian Robertson at 265-6034. Sinc,~rely' D. ~~8[er ~ Alpine Drilling Team Leader PA1 Drilling DC/skad Scblmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 158 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-41 ~ ~ ~.~( c~ 20164 CDR/ADN/M10/IMPULSE 000331 1 CD1-41 20164 MD VISION475 000331 I 1 CD1-41 20164 TVD VISION475 000331 I 1 .-. RF- EIVED 5/17/00 Naska 0ii & 6as Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~el~.rag0 5/11/00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 124 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-37 UA C_. INJECTION PULSE TEST LOG 000413 I 1 CD2-35 20172 CBL WISCMT 000409 1 CD1-41 PB1 20163 MD CDR 000323 I 1 CD1-41 PB1 20163 TVD CDR 000323 I 1 CD1-41 PB1 20163 MD ADN 000323 1 1 CD1-41 PB1 20163 TVD ADN 000323 I 1 CD1-41 Pa1 20163 CDR/ADN ~ ~L~"~-- 000323 I SIGN DATE: MAY 1 9 2000 Alaska 0il & Gas C~*~, Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank~El&~orage MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Well No CD1-41 c,~OO' OIq Installation/Rig Doyen 19 Dispatched To: AOGCC Date Dispatche 5-Apr-00 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 RECEIVED /~.~ ?, 1 ) ~000 A!aa 0il & Gas C 0os. c0mmi~ 1 Received By Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 rose@anchorage.anadrill.slb.com Fax: 907-561~8417 . _ LWD Log Delivery V1.1, Dec '97 ANADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-41 API number ............... : 50-103-20328-00 Engineer ................. : Dammeyer Rig: ..................... : Doyon 19 State: ................... : Alaska Survey calculation methods ..... Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference - Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 55.80 ft DF above permanent ....... : 55.80 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point .... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.93 degrees 30-Mar-2000 07:12:52 Page 1 of 6 ORIGINAL Spud date ................ : 23-Mar-00 Last survey date ......... : 30-Mar-00 Total accepted surveys...: 142 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11170.00 ft Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date. ........... : 17-Mar-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 25.86 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections - - .Magnetic dec (+E/W-) ..... : 25.86 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.86 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED ,..-i-. i 0 2000 Aiaska Oi~ & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 30-Mar-2000 07:12:52 Page 2 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 189.00 0.50 293.00 4 368.00 4.25 293.00 5 475.83 5.78 291.86 6 564.78 4.64 285.38 7 654.13 3.44 276.70 8 737.63 2.71 271.80 9 826,55 1.62 271.29 10 915.43 1.18 266.69 11 1004.57 0.12 184.63 12 1100.18 0.41 231.39 13 1196.43 4.29 245.87 14 1291.73 7.32 246.53 15 1387.18 9.53 253.13 16 1481.52 12.02 255.44 17 1576.85 14.18 251.56 18 1671.66 16.98 248.10 19 1766.58 19.97 251.06 20 1861.89 23.85 251.98 21 1956.73 28.55 253.14 22 2051.67 29.65 253.96 23 2147.94 29.51 253.07 24 2242.95 29.45 254.82 25 2337.88 29.90 253.30 26 2445.02 29.59 251.93 27 2545.00 30.28 251.72 28 ' 2641.00 29.84 250.62 29 2736.00 29.60 249.59 30 2830.00 30.05 251,56 0.00 114.00 75.00 179.00 107.83 88.95 89.35 83.50 88.92 88.88 89.14 95.61 96.25 95.30 95.45 94.34 95.33 94.81 94.92 95.31 94.84 94.94 96.27 95.01 94.93 107.14 99.98 96.00 95.00 94.00 TVD depth (ft) 0.00 114.00 189.00 367.81 475.23 563.81 652.94 736.32 825.17 914.02 1003.16 1098.77 1194.92 1289.72 1384.13 1476.80 1569.65 1660.97 1750.99 1839.40 1924.47 2007.43 2091.15 2173.86 2256.34 2349.36 2436.01 2519.09 2601.60 2683.15 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 0.00 0.00 0.00 0.00 0.25 0.13 6.02 3.03 13.29 6.61 19.19 9.23 23.20 10.50 25.62 10.86 27.28 10.95 28.28 10.93 28.58 10.78 28.44 10.47 28.62 8.78 29.35 4.90 31.38 0.19 35.19 -4.55 39.46 -10.74 42.89 -19.58 46.96 -30.01 52.90 -41.26 60.66 -53.77 69.96 -66.84 79.51 -80.32 89.24 -93.25 99.11 -106.16 108.97 -122.04 117.54 -137.61 125.27 -153.12 131.96 -169.15 139.00 -184.69 0.00 0.00 0.00 0.00 TIP 0.00 0.00 0.00 0.00 MWD -0.30 0.33 293.00 0.67 GYR -7.13 7.74 293.00 2.09 GYR -15.85 17.17 292.64 1.42 MWD -23.47 -29.62 -34.08 -37.44 -39.61 25.22 291.47 1.44 31.43 289.52 1.50 35.77 287.67 0.93 39.01 286.30 1.23 41.09 285.42 0.51 -40.53 41.94 284.89 1.31 -40.81 42.13 284.39 0.35 -44.36 45.22 281.19 4.05 -53.19 53.41 275.27 3.18 -66.33 66.33 270.16 2.52 -83.31 83.44 266.88 2.68, -104.00 104.55 264.11 2,45 -127.87 129.36 261.30 3.11 -156.06 158.92 259.12 3.30 -189.80 194.23 257.74 4.09 -229.74 235.95 256,83 4.98 -274.02 282.06 256.29 1.23 -319.59 329.53 255.89 0.48 -364.52 376.26 255.65 0.91 -409.71 423.24 255.47 0.92 -460.43 -507.83 -553.35 -597.63 -641.72 476,33 255.15 0.70 526.15 254.84 0.70 574.14 254.53 0.73 621,11 254.20 0.59 667,77 253.94 1.15 RECEIVED ,-, , 't 0 2000 Alaska Oil & Gas Co~s. Commission Anchorage MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Mar-2000 07:12:52 Page 3 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 31 2925.00 30.00 251.96 95.00 32 3021.00 31.60 252.69 96.00 33 3117.00 32.01 253.56 96.00 34 3212.'00 31.99 252.77 95.00 35 3306.00 31.61 252.59 94.00 36 3401.00 31.18 251.56 95.00 37 3495.00 30.61 250.53 94.00 38 3591.00 30.31 249.65 96.00 39 3686.00 29.81 249.74 95.00 40 3781.00 31.13 250.81 95.00 41 3876.00 31.82 252.91 95.00 42 3972.00 33.20 252.83 96.00 43 4067.00 33.76 253.60 95.00 44 4163.00 33.91 253.01 96.00 45 4258.00 34.12 253.44 95.00 46 4353.00 33.95 253.01 47 4448.00 33.65 252.72 48 4543.00 33.37 252.07 49 4638.00 33.17 251.55 50 4733.00 32.55 251.47 51 4828.00 32.00 251.16 52 4924.00 31.52 251.11 53 5019.00 31.02 250.75 54 5114.00 30.60 250.53 55 5211.00 30.21 249.26 56 5306.00 29.80 249.47 57 5401.00 29.24 248.34 58 5496.00 28.86 248.10 59 5592.00 29.40 249.87 60 5686.00 30.68 252.14 95.00 95.00 95.00 95.00 95.00 95.00 96.00 95.00 95.00 97.00 95.00 95.00 95.00 96.00 94.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) I00f) 2765.40 2847.86 2929.44 3010.01 3089.90 3170.99 3251.65 3334.41 3416.63 3498.51 3579.53 3660.49 3739.72 3819.47 3898.21 3976.94 4055.88 4135.09 4214.52 4294.32 4374.64 4456.26 4537.46 4619.06 4702.72 4784.98 4867.65 4950.70 5034.56 5115.93 147.11 -199.57 -686.87 155.99 -214.48 -733.70 165.81 -229.17 -782.12 175.62 -243.75 -830.30 184.86 -258.49 -877.59 193.58 201.23 208.14 214.57 221.57 230.13 239.92 250.18 260.72 271.13 281.54 291.57 301.10 310.04 318.62 326.89 334.98 342.69 350.06 356.86 363.01 368.70 373.75 379.50 386.94 -273.72 -924.67 -289.40 -970.32 -305.97 -1016.08 -322.48 -1060.71 -338.73 -1106.05 -354.16 -1153.19 -369.36 -1202.49 -384.49 -1252.67 -399.85 -1303.86 -415.18 -1354.75 -430.53 -1405.66 -446.10 -1456.16 -461.96 -1506.15 -478.23 -1555.66 -494.58 -1604.54 -510.83 -1652.60 -527.17 -1700.42 -543.28 -1747.02 -559.41 -1792.93 -576.28 -1839.03 -593.02 -1883.49 -609.86 -1927.16 -626.98 -1969.99 -643.73 -2013.62 -659.03 -2058.11 715.27 253.80 0.22 764.41 253.70 1.71 815.00 253.67 0.64 865.34 253.64 0.44 914.87 253.59 0.42 964.34 253.51 0.72 1012.56 253.39 0.83 1061.15 253.24 0.56 1108.65 253.09 0.53 1156.76 252.97 1.50 1206.35 252.93 1.36 1257.94 252.93 1.44 1310.34 252.94 0.74 1363.80 252.95 0.38 1416.94 252.96 0.34 1470.11 252.97 0.31 1522.96 252.97 0.36 1575.40 252.95 0.48 t627.51 252.91 0.37 1679.04 252.87 0.65 1729.75 252.82 0.60 1780.26 252.78 0.50 1829.54 252.73 0.56 1878.17 252.67 0.46 1927.20 252.60 0.78 1974.64 252.52 0.45 2021.35 252.44 0.83 2067.36 252.35 0.42 2114.01 252.27 1.06 2161.05 252.24 1.82 RECEIVED ..,., 10 2000 ~a~a ~1 & Gas Co, ns. Commis~on An~orage Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Mar-2000 07:12:52 Page 4 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) TVD depth /ft/ Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) I00f) type type 61 5782.00 30.97 252.51 62 .5877.00 30.77 252.03 63 5972.00 30.40 251.32 64 6068.00 29.80 250.08 65 6162.00 29.23 250.11 96.00 95.00 95.00 96.00 94.00 5198.37 5279.92 5361.70 5444.75 5526.55 395.81 -673 404.56 -688 412.75 -704 420.09 -719 426.67 -735 .96 -2104.98 .80 -2151.41 .00 .2197.29 .91 -2242.73 .67 -2286.27 2210.24 252.25 0.36 2258.98 252.25 0.33 2307.32 252.23 0.54 2355.44 252.20 0.90 2401.72 252.16 0.61 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 66 6256.00 28.78 249.23 67 6351.00 29.84 252.15 68 6447.00 29.11 252.50 69 6542.00 28.57 251.74 70 6637.00 30.05 252.38 94.00 95.00 96.00 95.00 95.00 5608.76 5691.61 5775.18 5858.40 5941.23 432.81 -751 439.91 -766 448.43 -781 456.54 -795 464.73 -809 .51 -2329.01 · 86 -2372.90 .20 -2417.90 .27 -2461.51 .59 -2505.76 2447.26 252.12 0.66 2493.74 252.09 1.87 2540.97 252.09 0.78 2586.79 252.10 0.69 2633.30 252.09 1.59 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 71 6732.00 31.35 253.74 95.00 72 6828.42 31.19 253.87 96.42 73 6923.00 30.62 253.06 94.58 74 7018.00 29.95 251.51 95.00 75 7113.00 29.28 251.30 95.00 6022.92 6105.33 6186.48 6268.52 6351.11 474.10 -823 484.40 -837 494.11 -851 502.73 -866 510.46 -881 .71 -2552.15 .67 -2600.22 · 49 -2646.79 .06 -2692.42 · 03 -2736.92 2681.79 252.11 1.55 2731.82 252.14 0.18 2780.38 252.17 0.75 2828.28 252.17 1.08 2875.23 252.16 0.71 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 76 7182.00 30.18 255.72 69.00 77 7214.00 31.29 260.80 32.00 78 7247.00 32.86 266.36 33.00 79 7277.00 34.85 271.39 30.00 80 7310.43 37.14 276.68 33.43 6411.03 6438.54 6466.51 6491.43 6518.48 81 7341.82 38.44 280.15 31.39 6543.29 82 7372.00 38.50 278.98 30.18 6566.92 83 7404.00 38.68 280.58 32.00 6591.93 84 7436.00 38.82 281.61 32.00 6616.89 85 7467.00 38.91 281.90 31.00 6641.03 517.34 -890 521.95 -894 528.42 -895 536.01 -896 546.46 -894 557.90 -892 569.37 -888 581.61 -885 594.26 -881 606.72 -877 .72 -2769.71 .03 -2785.71 · 97 -2803.11 .28 -2819.81 .88 -2839.39 .05 -2858.41 · 93 -2876.92 · 54 -2896.59 · 69 -2916.24 .73 -2935.29 2909.41 252.17 3.43 2925.66 252.21 8.82 2942.82 252.27 10.13 2958.82 252.37 11.45 2977.07 252.51 11.55 2994.37 252.67 7.94 3011.12 252.83 2.42 3028.93 253.00 3.17 3046.61 253.18 2.06 3063.71 253.35 0.65 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 86 7499.00 39.04 282.65 87 7531.00 38.83 283.09 88 7562.00 38.97 283.86 89 7594.00 40.32 288.18 90 7626.00 42.14 292.73 32.00 32.00 31.00 32.00 32.00 6665.90 6690.79 6714.92 6739.56 6763.64 619.75 632.92 645.84 660.04 675.84 -873.45 -2954.95 -868.97 -2974.56 -864.43 -2993.49 -858.79 -3013.10 -851.41 -3032.84 3081.34 253.53 1.51 3098.89 253.72 1.10 3115.80 253.89 1.62 3133.10 254.09 9.59 3150.09 254.32 10.96 RECEIVED MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 10 2000 ~amka Oil & Gas C(ms. Commission Anchorage ANADRILL SCHLUMBERGER Suryey Report 30-Mar-2000 07:12:52 Page 5 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 91 7657.00 43.95 295.87 92 7689.00 45.91 299.89 93 7721.00 46.21 301.24 94 7752.00 46.23 301.21 95 7785.00 46.26 301.34 31.00 32.00 32.00 31.00 33.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 6786.29 6808.95 6831.16 6852.61 6875.43 96 7817.00 46.53 301.17 32.00 6897.50 97 7847.00 48.74 302.23 30.00 6917.71 98 7879.00 52.27 304.75 32.00 6938.06 99 7912.00 55.50 307.13 33.00 6957.51 100 7942.00 58.10 309.69 30.00 6973.94 692.60 711.33 731.00 750.24 770.75 790.68 809.83 831.54 855.51 878.52 101 7975.00 58.71 311.06 33.00 6991.23 904.66 102 8006.00 59.50 312.34 31.00 7007.15 929.62 103 8038.00 61.79 313.89 32.00 7022.83 956.02 104 8069.00 64.64 315.93 31.00 7036.80 982.48 105 8102.00 67.58 317.09 33.00 7050.17 1011.56 106 8132.00 70.52 318.12 107 8166.00 73.98 320.76 108 8198.00 75.82 321.45 109 8228.00 77.59 320.83 110 8272.00 80.57 323.61 30.00 34.00 32.00 30.00 44.00 7060.89 7071.26 7079.59 7086.49 7094.83 7104.71 7107.11 7109.95 7111.68 7113.38 7114.12 7113.06 7111.33 7108.60 7106.35 111 8367.00 87.50 330.12 95.00 112 8429.00 88.05 330.46 62.00 113 8527.00 88.63 330.08 98.00 114 8623.00 89.31 330.30 96.00 115 8719.00 88.66 330.37 96.00 116 8815.00 90.45 331.94 96.00 117 8911.00 90.82 331.41 96.00 118 9006.00 91.27 331.56 95.00 119 9099.00 92.09 331.45 93.00 120 9190.00 90.75 332.61 91.00 1038.71 1070.32 1100.66 1129.34 1171.91 1265.92 1327.85 1425.77 1521.71 1617.66 1713.64 1809.63 1904.61 1997.57 2088.54 -842.70 -3052.12 -832.12 -3072.08 -820.41 -3091.92 -808.80 -3111.06 -796.43 -3131.43 -784.41 -3151.24 -772.76 -3170.10 -759.13 -3190.68 -743.47 -3212.25 -727.87 -3231.91 -709.67 -3253.32 -691.97 -3273.18 -672.91 -3293.54 -653.37 -3313.13 -631.48 -3333.89 -610.79 -3352.78 -586.19 -3373.82 -562.14 -3393.22 -539.41 -3411.53 -505.27 -3437.99 -426.22 -3489.55 -372.41 -3520.26 -287.35 -3568.83 -204.06 -3616.55 -120.66 -3664.06 -36.58 -3710.37 47.92 -3755.91 131.38 -3801.26 213.08 -3845.61 293.42 -3888.27 3166.32 ,254.57 9.05 3182.78 254.84 10.78 3198.91 255.14 3.18 3214.48 255.43 0.11 3231.13 255.73 0.32 3247.40 256.02 0.93 3262.92 256.30 7.82 3279.74 256.62 12.59 3297.17 256.97 11.39 3312.86 257.31 11.23 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 3329.82 257.69 3.99 MWD 3345.53 258.06 4.36 MWD 3361.58 258.45 8.31 MWD 3376.94 258.84 10.91 MWD 3393.17 259.27 9.47 MWD 3407.96 259.68 10.31 3424.37 260.14 12.58 3439.47 260.59 6.12 3453.92 261.02 6.23 3474.92 261.64 9.18 MWD MWD MWD MWD MWD 3515.48 263.04 9.98 MWD 3539.90 263.96 1.04 MWD 3580.38 265.40 0.71 MWD 3622.30 266.77 0.74 MWD 3666.04 268.11 0.68 MWD 3710.55 269.44 2.48 MWD 3756.22 270.73 0.67 MWD 3803.53 271.98 0.50 MWD 3851.50 273.17 0.89 MWD 3899.33 274.32 1.95 MWD RECEIVED Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Mar-2000 07:12:52 Page 6 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 9283.00 91.37 331.74 122 9377.00 90.86 331.96 123 9470.00 90.58 332.47 124 9563.00 91.20 332.34 125 9653.00 90.10 331.98 93.00 94.00 93.00 93.00 90.00 126 9746.00 89.79 332.16 93.00 127 9838.00 90.45 331.06 92.00 128 9929.00 91.30 330.75 91.00 129 10021.00 89.93 331.29 92.00 130 10113.00 90.65 331.82 92.00 131 10206.00 91.58 330.59 132 10298.00 92.23 329.92 133 10389.00 92.27 333.23 134 10480.63 91.27 333.64 135 10573.00 90.24 334.73 136 10664.00 90.41 332.84 137 10756.00 90.41 334.79 138 10849.00 90.17 334.04 139 10939.00 90.07 333.87 140 11032.00 89.52 333.68 141 11115.97 90.27 333.91 Survey Projected to TD 11170.00 90.27 333.91 Last 142 93.00 92.00 91.00 91.63 92.37 91.00 92.00 93.00 90.00 93.00 83.97 54.03 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg (ft) (ft) (ft) (ft) (ft) (deg) i00f 7104.62 7102.80 7101.63 7100.18 7099.16 7099.25 7099.06 7097.67 7096.68 7096.22 7094.41 7091.35 7087.77 7084.94 7083.73 7083.21 7082.55 7082.08 7081.89 7082.23 7082.38 7082.13 2181.52 2275.50 2368.49 2461.48 2551.47 2644.47 2736.46 2827.44 2919.42 3011.41 3104.39 3196.30 3287.21 3378.76 3471.05 3562.00 3653.94 3746.85 3836.80 3929.75 4013.67 4067.67 375.65 -3931.67 458.52 -3976.gl 540.79 -4019.36 623.20 -4062.43 702.78 -4104.46 784.94 -4148.02 865.88 -4191.76 945.39 -4236.01 1025.86 -4280.58 1106.75 -4324.40 1188.23 -4369.18 1268.07 -4414.80 1348.02 -4458.08 1429.94 -4499.04 1513.08 -4539.26 1594.72 -4579.45 1677.27 -4620.05 1761.15 -4660.21 1842.01 -4699.73 1925.43 -4740.82 2000.77 -4777.90 2049.30 -4801.66 3949.58 275.46 1.15 4002.36 276.58 0.59 4055.58 277.66 0.63 4109.96 278.72 0.68 4164.19 279.72 1.29 4221.64 280.72 0.39 4280.26 281.67 1.39 4340.22 282.58 0.99 4401.79 283.48 1.60 4463.78 284.36 0.97 4527.88 285.21 1.66 4593.31 286.03 1.01 4657.43 286.82 3.63 4720.81 287.63 1.18 4784.80 288.43 1.62 4849.18 289.20 2.09 4915.09 289.95 2.12 4981.89 290.70 0.85 5047.81 291.40 0.22 5116.90 292.10 0.63 5179.91 292.72 0.93 5220.69 293.11 0.00 Srvy Tool / tool qual ) type type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6 0C 07] RECEIVED 10 000 Alaska Oil & Gas Co s. Commission An~ora~ ANADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-41PH API number ............... : 50-103-20328-70 Engineer ................. : J. Rathert Rig: ..................... : Doyon 19 State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference -- Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : KB above permanent ....... : DF above permanent ....... : Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 19.50 ft 55.80 ft 55.80 ft 0.00 ft 0.00 ft Platform reference point .... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 251.78 degrees 23-Mar-2000 02:41:55 Page 1 of 4 Spud date ................ : 17 Mar 2000 Last survey date ......... : 23-Mar-O0 Total accepted surveys...: 87 MD of first survey ....... : 0.00 ft MD of last survey ........ : 8166.00 ft Geomagnetic data - - - Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 17-Mar-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 25.85 degrees Magnetic dip.... .......... : 80.48 degrees MWD survey Reference Criteria ......... Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections - Magnetic dec (+E/W-) ..... : 25.86 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.86 degrees (Tota~ az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 0C 07] RECEIVED APR ~NADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 189.00 0.50 293.00 4 368.00 4.25' 293.00 5 475.83 5.78 291.86 6 564.78 4.64 285.38 7 654.13 3.44 276.70 8 737.63 2.71 271.80 9 826.55 1.62 271.29 10 915.43 1.18 266.69 11 1004.57 0.12 184.63 12 1100.18 0.41 231.39 13 1196.43 4.29 245.87 14 1291.73 7.32 246.53 15 1387.18 9.53 253.13 16 1481.52 12.02 255.44 17 1576.85 14.18 251.56 18 1671.66 16.98 248.10 19 1766.58 19.97 251.06 20 1861.89 23.85 251.98 21 1956.73 28.55 253.14 22 2051.67 29.65 253.96 23 2.147.94 29.51 253.07 24 2242.95 29.45 254.82 25 2337.88 29.90 253.30 26 2445.02 29.59 251.93 27 2545.00 30.28 251.72 28 2641.00 29.84 250.62 29 2736.00 29.60 249.59 30 2830.00 30.05 251.56 Course length (ft) 0.00 114.00 75.00 179.00 107.83 88.95 89.35 83.50 88.92 88.88 89.14 95.61 96.25 95.30 95.45 94.34 95.33 94.81 94.92 95.31 94.84 94.94 96.27 95.01 94.93 107.14 99.98 96.00 95.00 94.00 [(c)2000 Anadrill IDEAL ID6 0C 07] -- 23-Mar-2000 02:41:55 TVD Vertical Displ depth section +N/S, (ft) (ft) (ft) 0.00 114.00 189.00 367.81 475.23 563.81 652.94 736.32 825.17 914.02 1003.16 1098.77 1194.92 1289.72 1384.13 1476.80 1569.65 1660.97 1750.99 1839.40 1924.47 2007.43 2091.15 2173.86 2256.34 2349.36 2436.01 2519.09 2601.60 2683.15 Page 2 of 4 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 0.00 0.00 0.00 0.00 0.00 0.00 0.25 0.13 -0.30 5.82 3.03 -7.13 12.98 6.61 -15.85 19.41 9.23 -23.47 24.85 10.50 -29.62 28.98 10.86 -34.08 32.14 10.95 -37.44 34.21 10.93 -39.61 0.00 0.00 0.00 TIP 0.00 0.00 0.00 MWD 0.33 293.00 0.67 GYR 7.74 293.00 2.09 GYR 17.17 292.64 1.42 MWD 25.22 291.47 31.43 289.52 35.77 287.67 39.01 286.30 41.09 285.42 1.44 1.50 0.93 1.23 0.51 35.13 10.78 -40.53 35.49 10.47 -40.81 39.39 8.78 -44.36 48.99 4.90 -53.19 62.94 0.19 -66.33 41.94 284.89 1.31 42.13 284.39 0.35 45.22 281.19 '4.05 53.41 275.27 3.18 66.33 270.16 2.52 80.56 -4.55 -83.31 83.44 266.88 2.68 102.14 -10.74 -104.00 104.55 264.11 2.45 127.58 -19.58 -127.87 129.36 261.30 3.11 157.62 -30.01 -156.06 158.92 259.12 3.30 193.18 -41.26 -189.80 194.23 257.74 4.09. 235.03 -53.77. -229.74 281.18 -66.84 -274.02 328.68 -80.32 -319.59 375.40 -93.25 .-364.52 422.36 -106.16 -409.71 235.95 256.83 282.06 256.29 329.53 255.89 376.26 255.65 423.24 255.47 476.33 255.15 526.15 254.84 574.14 254.53 621.11 254.20 667.77 253.94 RECEIVED APR 03 2000 Alaska Oil & Gas Cons. Commission Anchorage 475 525 573 620 667 · 51 -122.04 -460.43 · 40 -137.61 -507.83 .48 -153.12 -553.35 · 56 -169.15 -597.63 · 29 -184.69 -641.72 4.98 1.23 0.48 0.91 0.92 0.70 0.70 0.73 0.59 1.15 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 31 2925.00 30.00 251.96 32 3021.00 31.60 252.69 33 3117.00 32.01 253.56 34 3212.00 31.99 252.77 35 3306.00 31.61 252.59 Course length (ft) 95.00 96.00 96.00 95.00 94.00 TVD depth (ft) 2765.40 2847.86 2929.44 3010.01 3089.9.0 23-Mar-2000 02:41:55 Vertical Displ Displ Total section +N/S- +E/W- displ '(ft) (ft) (ft) (ft) 714.83 -199.57 -686,87 715.27 763.98 -214.48 -733.70 764.41 814.56 -229.17 -782.12 815.00 864.88 -243.75 -830.30 865.34 914.41 -258.49 -877.59 914.87 Page 3 of 4 At DLS Azim (deg/ (deg) I00f) 253.80 0.22 253.70 1.71 253.67 0.64 253.64 0.44 253.59 0.42 S rvy tool type MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 36 3401.00 31.18 251.56 95.00 37 3495.00 30.61 250.53 94.00 38 3591.00 30.31 249.65 96.00 39 3686.00 29.81 249.74 95.00 40 3781.00 31.13 250.81 95.00 3170.99 3251.65 3334.41 3416.63 3498.51 963.90 1012.16 1060.80 1108.36 1156.51 -273.72 -924.67 -289.40 -970.32 -305.97 -1016.08 -322.48 -1060.71 -338.73 -1106.05 964.34 1012.56 1061.15 1108.65 1156.76 253.51 0.72 MWD 253.39 0.83 MWD 253.24 '0.56 MWD 253.09 0.53 MWD 252.97 1.50 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 41 3876.00 31.82 252.91 42 3972.00 33.20 252.83 43 4067.00 33.76 253.60 44 4163.00 33.91 253.0i 45 4258.00 34.12 253.44 95.00 96.00 95.00 96.00 95.00 3579.53 3660.49 3739.72 3819.47 3898.21 1206.10 1257.69 1310.08 1363.51 1416.64 -354.16 -1153.19 -369.36 -1202.49 -384.49 -1252.67 -399.85 -1303.86 -415.18 -1354.75 1206.35 1257.94 1310.34 1363.80 1416.94 252.93 1.36 MWD 252.93 1.-44 MWD 252.94 0.74 MWD 252.95 0.38 MWD 252.96 0.34 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 46 4353.00 33.95 253.01 95.00 3976.94 1469.79 47 4448.00 33.65 252.72 95.00 4055.88 1522.63 48 4543.00 33.37 252.07 95.00 4135.09 1575.07 49 4638.00 33.17 251.55 95.00 4214.52 1627.19 50 4733.00 32.55 251.47 95.00 4294.32 1678.73 -430.53 -1405.66 -446.10 -1456.16 -461.96 -1506.15 -478.23 -1555.66 -494.58 -1604.54 1470.11 1522.96 1575.40 1627.51 1679.04 252.97 0.31 MWD 252.97 0.36 MWD 252.95 0.48 MWD 252.91 0.37 MWD 252.87 0.65 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 51 4828.00 32.00 251.16 52 4924.00 31.52 251.11 53 5019.00 31.02 250.75 54 5114.00 30.60 250.53 55 5211.00 30.21 249.26 95.00 96.00 95.00 95.00 97.00 4374.64 4456.26 4537.46 4619.06 4702.7.2 1729.46 1779.99 1829.29 1877.94 1927.01 -510.83 -1652.60 -527.17 -1700.42 -543.28 -1747.02 -559.41 -1792.93 -576.28 -1839.03 1729.75 1780.26 1829.54 1878.17 1927.20 252.82 0.60 MWD 252.78 0.50 MWD 252.73 0.56 MWD 252.67 0.46 MWD 252.60 0.78 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 56 5306.00 29.80 249.47 57 5401.00 29.24 248.34 58 5496.00 28.86 248.10 59 5592.00 29.40 249.87 60 5686.00 30.68 252.14 [(C)2000 Anadrill IDEAL ID6_0C_07] 95.00 95.00 95.00 96.00. 94.00 4784.98 4867.65 4950.70 5034.56 5115.93 1974.47 2021.22 2067.26 2113.93 2160.98 -593.02 -1883.49 -609.86 -1927.16 -626.98 -1969.99 -643.73 -2013.62 -659.03 -2058.11 1974.64 2021.35 2067.36 2114.01 2161.05 252.52 0.45 252.44 0.83 252.35 0.42 252.27 1.06 252.24 1.82 ECEIVED APR 03 200 Alaska Oil & Gas Cons. Commission Anchorage MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 23-Mar-2000 02:41:55 Page 4 of 4 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 5782.00 30.97 252.51 96.00 62 5877.00 30.77 252.03 95.00 63 5972.00 30.40 251.32 95.00 64 6068.00 29.80 250.08 96.00 65 6162.00 29.23 250.11 94.00 66 6256.00 28.78 249.23 94.00 67 6351.00 29.84 252.15 95.00 68 6447.00 29.11 252.50 96.00 69 6542.00 28.57 251.74' 95.00 70 6637.00 30.05 252.38 95.00 71 6732.00 31.35 253.74 95.00 72 6828.42 31.19 253.87 96.42 73 6923.00 30.62 253.06 94.58 74 7018.00 29.95 251.51 95.00 75 7113.00 29.28 251.30 95.00 76 7208.00 30.17 252.48 95.00 77 7303.00 30.91 253.59 95.00. 78 7398.00 30.26 253.41 95.00 79 7494.00 29.71 253.6-2 96.00 80 7591.00 30.61 253.45 97.00 81 7685.00 31.21 254.88 94.00 82 7780.00 30.85 254.92 95.00 83 7'875.00 30.40 255.89 95.00 84 7971.00 30.28 255.40 96.00 85 8066.00 30.52 255.31 95.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft). (ft) (ft) (ft) (ft) (deg) 100f) 5198.37 5279.92 5361.70 5444.75 5526.55 5608.76 5691.61 5775.18 5858.40 5941.23 6022.92 6105.33 6186.48 6268.52 6351.11 6433.61 6515.43 6597.21 6680.36 6764.2.3 6844.88 6926.29 7008.04 7090.89 7172.83 86 8091.00 30.41 255.30 25.00 7194.38 Survey Projected to Total Depth: 87 8166.00 30.41 255.30 75.00 [(c)2000 Anadrill IDEAL ID6 0C 07] 7259.06 2210.17 2258.91 2307.24 2355.38 2401.67 -673.96 -2104.98 -688.80 -2151.41 -704.00 -2197.29 -719.91 -2242.73 -735.67 -2286.27 2447.21 2493.70 2540.93 2586.76 2633.26 -751.51 -2329.01 -766.86 -2372.90 -781.20 -2417.90 -795.27 -2461.51 -809.59 -2505.76 2681.74 2731.76 2780.32 2828.22 2875.16 -823.71 -2552.15 -837.67 -2600.22 -851.49 -2646.79 -866.06 -2692.42 -881.03 -2736.92 2922.27 2970.53 3018.84 3066.80 3115.51 -895.67 -2781.69 -909.75 -2827.86 -923.47 -2874.21 -937.09 -2920.21 -950.90 -2966.95 3163.75 -964.07 -3013.40 3212.65 -976.83 -3060.68 3260.94 -989.03 -3107.51 3309.33 -1001.05 -3154.49 3357.31 -1013.20 -3201.00 3369.96 -1016.42 -3213.26 3407.85 -1026.05 -3249.98 Srvy tool type 2210.24 252.25 0.36 MWD 2258.98 252.25 0.33 MWD 2307.32 252.23 0.54 MWD 2355.44 252.20 0.90 MWD 2401.72 252.16 0.61 MWD 2447.26 252.12 0.66 MWD 2493.74 252.09 1.87 MWD 2540.97 252.09 0.78 MWD 2586.79 252.10 0.69 MWD 2633.30 252.09 1.59 MWD~ 2681.79 252.~11 1.55 MWD 2731.82 252.14 0.18 MWD 2780.38 252.17 0.75 MWD 2828.28 252.17 1.08 MWD 2875.23 252.16 0.71 MWD 2922.33 252.15 1.12 MWD 2970.59 252.17 0.98 MWD 3018.92 252.19 0.69 MWD 3066.88 252.21 0.58 MWD 3115.60 252.23 0.93 MWD 3163.86 252.26 1.01 MWD 3212.78 252.30 0.38 MWD 3261.10 252.35 0.70 MWD 3309.52 252.39 0.29 MWD 3357.53 252.44 0.26 MWD 3370.19 252.45 0.44 MWD 3408.10 252.48 0.00 RECEIVED APR 2000 Alaska Oil & ~as Cons. Com~ An~~ MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 509' FNL, 2293' FWL, Sec.5, T11N, R5E, UM At target (7" casing point in Alpine)) 960' FNL, 1165' FEL, Sec 6, T11 N, R5E, UM At effective depth At total depth 1533' FSL, 2391' FVVL, Sec.31, T12N, R5E, UM ...... Other _ Annular Injection - X 5. Type of Well: Development _X Exploratory _ Stratigraphic __ Service _ per APD per APD 6. Datum elevation (DF or KB feet) RKB 56' feet 7. unit or Property name Colville River Unit 8. Well number CD1-41 9. Permit number / approval number 200-17 10. APl number 50-103-20328-00 11. Field / Pool Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 1 1170 feet true vertical 7082 feet Effective depth: measured 1 1170 feet true vertical 7082 feet Casing Length Size Cemented Conductor 77' 16" 10 cu.yds, Portland Type 3 Surface 2457' 9.625" 380 sx ASL3, 234 sx Class G Production 8298' 7" 129 sx Class G Measured Depth 114 2496' 8332' CD1-41 is as an open hole production well. It was suspended after being completed with 4-1/2" tubing. It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. True vertical Depth 114 2393' 7101' ORIGINAL 13. Attachments Description summary of proposal __ 14. Estimated date for commencing operation May 31,2000 16. If proposal was verbally approved Name of approver Date approved Detailed operations program 15. Status of well classification as: Oil ~ Gas __ Service __ BOP sketch _ 17. I hereby cert~ that the foregoing is true and correct to the best o! my knowledge. Signed ~.~1~~ .~lr b'~P~'~¢'~/~' Title: Drilling Team Leader Suspended __ Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I n°'30C) ' I0 q Plug integrity_ BOP Test __ Mechanical Integrity Test __ Location clearance __ Subsequent form required 10- /'( ~ Approved by order of the Commission ......... APR 1 9 2000 A~aska 0il 8, Gas Cons. Commission Commissioner Date ;,,pproved Copy Returned Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 18, 200O Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-41 Dear Sirs: ARCO Alaska, Inc. hereby requests that CD1-41 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information as follows: . 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing, Casing and Formation Test Integrity Report (LOT at surface casing shoe). Formation LOT on 9-5/8" x 7" casing annulus. CD1-41 Well Completion Schematic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer CC. CD1-41 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko 0RI$1NAL RECEIVED /'.PR 1 9 2000 Alaska 0il & Gas Co~s. Commission Anchorage ARC(_) Alaska hlc is a Subsidiary <)f AtlanticF!IchfieidCornpany APR 1 9 2000 Alaska 0ii & Gas Co~s. C0mmi&.~n An~0r~e ARCO Alaska, Inc. Casing Detail 9 5/8" Surface Casinq Well: CD1-41 Date: 3/5/00 Subsidiary of Atlm Subsidiary of Atlan~c Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.30 FMC Gen V Hanger 2.43 36.30 Jts 3 to 58 56 Jts 9-5/8" 36# J-55 BTC Csg 2368.16 38.73 Davis Lynch Float Collar 1.52 2406.89 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 86.14 2408.41 Davis Lynch Float Shoe 1.75 2494.55 2496.30 TD 12 1/4" Surface Hole 2506.30 RUN TOTAL 33 BOWSPRING CENTRALIZERS - I per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40 42, 44, 46, 48, 50, 52, 54 7 Jts left in pipe shed #57 - #65 Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 190k Dn Wt -130k Block Wt - 70k Supervisor: Scott D Reynolds ARCO Alaska, Inc. Cementing Details Well Name: CD1-41 Report Date: 03/19/2000 Report Number: 1 Rig Name: Doyon 19 AFC No.: 998C05 Field: ALPINE · . Cehtralizers. State type used, intervals covered and spacing CommentS: U~ed 3319-5/8" bow spring I per jt on Jt #1 -#12 & 1 every other joint to surface. centralizers. I MUd Weight: PV(prior cond): PV(after cond): YP{prior cond): YP(after cond): Comments: 9.6 10 11 45 11 SPud Mud Gels before: Gels after: Total Volume Circulated: : 34/50158 9/25/36 693 bbls i Wash 0 'Type: Volume: Weight: comments: GELH20 40 bbls 8.5 ::Gelled w! Biozan w/6 sx · ;coarse nut plug :Sp~cei; i0 Type: Volume: Weight: ~omments: ARCO Spacer 50 bbls 10.5 LeadCement 0 Type: I Mix wtr temp:No. of Sacks: Weight: Yield: Comments: AS III LiteI 70 380 10.5 4.44 Additives: i 30% D53, 0.6% D46, 1.5% D79, 1.5% S1, 50% D-124, 9% D44 I I I I 'raii Cement: 0 Type: I Mixwtrtemp: I No. ofSacks: I Weight: I Yield: Comments: 70 234 15.8 1.17 G Additives: . . 0.2% D46, 0.3% D65, 1% 51 Disl31acement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6.5 bpm 6.0 bpm 190k Reciprocation length: Reciprocation speed: Str. Wt. Down: 20' 5 fpm 130k Theoretical Displacement: Actual Displacement: Sir. Wt. in mud: 166 bbls 166.7 bbls 76557 lbs Calculated top of cement: CP: Bumped plug: Floats held: SURFACE Date:3-19-2000 YES YES Time:21:15 HRS Remarks:Nut plug in spacer showed up @ surface 20 bbls over estimated pumping volume (for gauge hole). Washout calculated to be 15.6% over gauge hole. Started to get good 10.5 ppg cement back 93 bbls into rig displacement; therefore, estimated good cement returns @ 73 bbls. Had full returns throughout cement job. , Cement Company: IRig Contractor: DOYON Approved By: Scott D Reynolds DS RECEIVED APR 1 9 2000 Alaska 0ii & Gas Cons, Commission Anchorage RECEIVED ,PR 1 9 000 Aiaska 0il & Gas Cons. Commission Anchorage Daily Drilling Report ARCO Alaska, Inc. AFC No. I Date Rpt No Rig Accept - hrs Days Since Accept/Est: 2.31 / 2.5 998C05 ~03/19/2000 3 03/17/2000 04:30:00 Rig Relase - hrs: I PM Well: CD1-41 Depth (MD/TVD) 2506/2402 Prey Depth MD: 2335 Progress: 171 Contractor: DOYEN Daily Cost $169642 Cum Cost $ 440765 Est Cost To Date $ 500000 Ri~ Name: Doyen 19 Last Cs~: 16" @ 115' Next Cs~: 9-5/8" @ 2505' Shoe Test: Operation At 0600: Testing BOPE. Upcoming Operations: PU BHA #2 for drilling 8-1/2" pilot hole. MO~DATA DRI'L~iNGDATA: :: : B~:DATA EH&S DRILLS/BOP DATA MUD TYPE ::)EPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD 2506 I N TST 03/17/2000 03120/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6pp~] 147k 12.25 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 49sqc 142k HTC N SPACE 03/19/2000 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 11 / 14 142k MXC1 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 4605 9 / 25 / 36 5k L82ZF APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1110 18 BBLS HTH P WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 114 mi/30 min 8500 115 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8% 7000 2391 CD1-42 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F -16 362bbl 18o0l I I 19.44/7.02 / CD1-41 MBT PUMP NO WeB 2 WeB 2 RATE (bpm) WIND SPEED 12i 20 1 I 2 I I 10- 20 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 270° 7.5 5.51 61 I 60-147 1025 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -46.03 1.7% 75175{ { .546 Water Base Muds 940 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 1 75 25813141 I 18112i121101 I I llll 60 Other 25 DALLY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $4095 III 11910 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $20906 I I I 2 l si RG I G I I 1025 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 MI I I I E I I I SD lTD I I 3087 PERSONNEL TOTAL 48 : ~i~E: [ EN~ I OPS~ODE [ HO~E SECT IPHASE OPS [ OPERATIONS FROM 0000- 00,00 12:00 AM 04:00 AM 4.00 DRIL SURF Making Hole Drill f/2335' t/2506' (2402' tvd). ART=2.44 hrs; AST=0.20 hrs. Drilled through ratty formation @ 2460'. Encountered diesel fumes @ 2480' md. 04:00 AM 05:00 AM 1.00 ClRC SURF WiperTrip Pump sweep - circ & condition mud. Continue to get diesel fumes in pits while circulating. Monitor well - static. 05:00 AM 06:30 AM 1.50 TRIP_OUT SURF WiperTrip Short trip t/1000' (HWDP). RIH t/2506'. 06:30 AM 07:30 AM 1.00 CIRC SURF WiperTrip Rotate & Reciprocate while pumping HiVis sweep. Observe well - static. 07:30 AM 09:00 AM 1.50 TRIP_OUT SURF Trip Out POOH to BHA. 09:00 AM 10:30 AM 1.50 BHA SURF Trip Out LD BHA #1 (UBHO - mwd - stab - NMC - motor. Stand back collars. 10:30 AM 11:00 AM 0.50 OTHER ~ SURF Casing and Clean & clear rig floor. Cementing 11:00 AM 12:00 PM 1.00 PREP SURF Casing and RU slips - elevators & Franks fill-up tool for running 9-5/8" Cementing casing. 12:00 PM 12:30 PM 0.50 RIGS SURF Casing and Service top drive. Cementing 12:30 PM 04:30 PM 4.00 RUN_CSG SURF Casing and Ran 58 joints of 9-5/8" - 36# csg. (Break circulation @ Cementing 1000'. CBU for 15 minutes.) Daily Drilling Report: CD1-41 03/19/2000 Page 1 04:30 PM 06:00 PM 1.50 ClRC 06:00 PM 06:30 PM 0.50 PREP 06:30 PM 07:30 PM 1.00 CIRC 07:30 PM 09:30 PM 2.00 CEMENT 09:30 PM 10:30 PM 1.00 CEMENT 10:30 PM 11:00 PM 0.50 OTHER 11:00 PM 12:00 AM 1.00 BOPE 24.00 SURF SURF SURF SURF SURF SURF SURF Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Other Stage pumps up to 7 bpm. Circulate & condition mud for cement job. Blow down top drive and MU cement head. Continue to circulate & condition mud. Hold PJSM for cement job. Pump 40 bbls pre-flush & 5 bbls water. Pressure test cmt lines. Drop bottom plug - pump 50 bbls spacer - 300 bbls lead & 46 bbls tail. Drop top plug & chase with 20 bbls wtr - displace with rig. 10.5 ppg cement back 92 bbls into rig displacement. Full returrns throughout job. Bumped plug 0.7 bbls over calculated displ. Floats held. ClP @ 21:15 hrs. Approx. 80 bbls of good lead cement returned to surface. LD cement head - landing joint - bails & elevators. PU 1 jt DP & stack washer. Wash stack. ND Riser - flowline - diverter & diverter line. Supervisor: SCO3'r D REYNOLDS RECEIVED APR 1 9 2000 Alaska 0il & Gas Cons. Commission Anchorage Daily Drilling Report: CD1-41 03/19/2000 Page 2 Well Name: CD1-41 Reason(s) for test: CASING TEST and FORMATION INTEGRITY TEST Date: 2/20100 Supervisor: S. Reynolds [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight APR LEAK,OFF DATA~ DATA Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,496' TMD Hole Depth: 2,393' TVD Mud Weigm: 9.6 ppg Length of Open Hole Section: 2,526' TMD 30' + 9.6 ppg EMW = Leak-off Press. ~- Mud Weight = 810 psi 0.052 x TVD 0.052 x 2~419' EMW for open hole section = 16.0 ppg Used cement unit NO Pump output = 0.0997 bps Fluid Pumped = 1.4 bbls Ri~ pump used # 2 =luid Bled Back = 0.5 bbls ....... ~ LEAK~OFF TEST ~CASING TEST ~ ~"-- LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME ...... ~_ ~ TIME UNE STROPS 71~ psi LOT STROKES PRESSURE CSGTEST ~OK£S PRESSURE 0 0 psi r , 0 stks 0 psi 2.0 180 psi ~ 5 Stks 110 psi fZZZZZ 4.0 I 410 psi I lOStkS 620PSi 6.0 -1' 590 psi , ~' 15stks 1~030 Psi ..... '§:~-'..'~'"710'----p~i'"' ]' ........... T' 20 StOl" ':'~ ..... ...... r ........... 14.0 810 psi 0.0 min , 1.0 min ' 2.0 rain i SHUT IN TIME SHUT IN PRESSURE 810 psi 3.0 min 4.0 min 5.0 min SHUT iN PRESSURE i 2~500 psi 2~500 PS! 0.0 min 1.0 min 2.0 min 3.0 min 690 psi 4.0 min 690 psi 5.0 min 680 psi 6.0 min 7.0 min 8.0 min 9.0 min 10.0 min NOTE: STROKES TURN TO MINUTES DURING SHUT IN TIME :see time line above 680 PSi 680 psi 670 ps! 670 psi 670 psi 6.0 min 7,0 rain 8 0 rain 9,0 rain 10.0 rain 15,0 min 20.0 mi~ ~Z 25;0 NOTE: TO CLEAR DATA, HIGHLIGHT AND 2,475 psi. .2,450 ps.,~_i 2,44.0_._p_s!. _A4_4_o. p_s.L 2,430 Psi Modified by Scott Reynolas CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-41 Date: 3/26100 Supervisor: S.D. Reynolds :leason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 6/8" 36# J-55 BTC CSG X Casing Setting Depth: 2,496' TMD 2;393' TVD 7" 26# L-80 BTCM CSG TOC Hole Depth: 7,618' TMD 6~787' ~D Mud Weight: 9.6 ppg Length of Open Hole Section: 5,122' EMW = Leak-off Press. + Mud Weight = 727 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,393' EMW for open hole section = 15.4 ppg Used cement unit yes Pump output = bbls pumped Fluid Pumped = 10.0 bbls Ri~J pump used # 2 :luid Bled Back = N/A 90O 800 psi ,~, 500 psi ...... ~ ~ psi 0 psi -- 0 10 20 BARRE~ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR FOR LOT BBLS PRESSURE CSGTEST STROKES pRESsuRE ; 0 Ops~ : Ostks = Ops~ / 0.5 ~ 15psi I ~ ~ ............... ! ....... ¥---~-~'/;a-I .............. ............... ~l ..................... 1.5 I 30 psi !, ...............t ';'~1 .... ............... ; ............... ,+ ........ ! ................ ~----''"'""t .......... I 2 , 41 psi , / , .................... '~;g-'",~'-f~f-I ............... t .............. ............... i ...... .3. ......... !33_psi ............ i ...... ----~ ...... ............. ~__..3.:~ ........ ?_o.7...p..s.b i .......... ::~ ~: ......... :~ .... :::::::::::::::::::::::::::::'4 2..si ......... ...... ......... ............ i ..... -~- ......... ~si ~'---i i 6.5 s4o'~';i ........... ----~,' ----~ ~'-~-i ; 6.5 692 psi ' ........~! ....... F'"'"'~F~F', ................ i .............. .........................................................'I ......... ~'~'~'"'"'~ ~ 7.5 500 psi ................ ~ ....... ........ .............. :::::::::::::::::::::::::::: ------- .-~ ,,, -~a~'~a ............. r ................. ~ , ,7--:- ...... ~ .......... -~r~'"[-~' ............. ~ ................................................................. { ~.0 rain [_ ....................... .2 2.0 rain ~ O.Om~n ~ ~ 4~5~s~ 4.0mm ~ 1.0 ~.. , 379 ps 5.0 m~n 1 l' 4.0 mEn ~ ~---~si- 8.0 men 1 ........... ,. , ~ .~-.-~ ........ 5.0mEn , , 359 psi 90mEn , , 6.0mEn i I 353psi 100mEn I ......... ~. ~:~; ...... ~ ........ ~ ...... 7.0m~n ~ , 348psi 15.0mEn [ 9 0 mm ~ / 348 psi 25.0 mln ~ 100mn , , 343psi 300min NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE ~EEETE KEY letion, as buit 4-1/2" Camco BAL-O SSSV Nipple {3,812" iD) at 1715' MD Isolation Sleeve with DB-6 No-Go Lock (3,812" OD) run in profile Dual 1/4" x 0,049~ s/s control lines 9.5/8" 36 ppf J-55 BTC Surface Casing @ 2496' MD / 2393' TVD cemented to surface WRDP-2 SSSV (2A25"ID) w/DB-6 Nc-Go Lock (3,812" OD) - to be installed later Camco KBG-2 GLM (3,909" ID) E Dummy with 1" BK-2 Latch Packer Fluid mix: 9.6 cpo KCI Brine with 2000~ TVD diesel cad 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Tubino Suoended with diesel to lowest GLM Completion M~D Camco KBG-2 GLM {3,909" ID) E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" & 1" Camco DCK-2 Shear Valve ~sheared out) Tubing Hanger 32' 4-1/2", 12,6#/ft, lB%Mod Tubing Camco BAL-O SSSV Nipple 1715' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 3654' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 5776' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 7774' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 7853' 4-1/2" tubing joint (1) Baker S3 Packer 7896' 4-1/2 tubing joint (2) HES "XN" [3,725" ID) 7972' 4-1/2" 10' pup joint WEG t+/- 59 deg) 7985' Cdl-41PH - cement kick off plug at 7154' MD Note: solid body aluminum centralizers astalled between joints 95 and 173 - 79 run. Baker S3 Packer at 7896' TOC @ +/- 7618' MD ReCEiVED 7" 26 ppf L-80 BTC Mod Production Casing @ 6332' MD / 7101' TVD @ 84 deg Well TD at 11170' MD / 7082' TVD MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-41PH C~' © t-- Date Dispatche 30-Mar-00 Installation/Rig Doyen 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 RECEIPTED APR 2)00 /'"-, Alaska0ii & Gas Cons. Commission 'x, Anchorage ~ / Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 rose@anchorage.anadrill.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ALASKA OIL AND GAS CONSERVATION COPlPllSSION Doug Chester Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 ' PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Colville River Unit CD 1-41 ARCO Alaska, Inc. Permit No: 200-017 Sur Loc: 509'FNL. 2293'FWL, Sec. 5, T1 IN, RSE, UM Btmhole Loc. 1533'FSL. 2?91'FWL. Sec. 31, T12N, R5E, UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must bc clearly differentiated in both name (CD 1-4 I PH) and APl number (50-103-20328-70) from records, data and logs acquired for well CD 1-41. The permit to drill does not exempt you from obtaining additional pcrnfits required by lav~' from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and alw CQLs must bc submitted to thc Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling opcration vdfich arc pumpcd down thc surface/production casing annulus of a well approved for mmular disposal on Drill Sitc CD I must comply with thc requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a.volume greater than 35,000 barrels through the annular spacc of a single well or to use that well for disposal purposes for a period longcr than onc vcar. Blowout prevcntion equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficicnt notice (approximately 24 hours) must be given to allow a representative of thc Commission to witncss a test of BOPE installed prior to drilling new hole. Notice may be givcn by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N, Christcnson. P.E. Chair BY ORDER OF THE,~MMISSION DATED this 7-e) ~=' day of February, 2000 dlf/Enclosurcs cc; Department of Fish &Gamc, Habitat Section xv/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 la. Type of Work Drill X Redrill ] lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone "~. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field '3'." Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 & 25558 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 509' FNL, 2293' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 960' FNL, 1165' FEL, Sec. 6, T11N, R5E, UM CD1-41 #U-630610 At total depth 9. Approximate spud date Amount 1533' FSL, 2391' FWL, Sec. 31, T12N, R5E, UM 03/03/2000 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1 - 40 11,170' MD Crosses T11N to feet 8.2' @ 317' Feet 2560 7,057' TVD feet T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1 100' feet Maximum hole angle 91 o Maximum surface 2499 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth , .. size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2468' 37' 37' 2505' 2400' 488 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 8308' 37' 37' 8345' 7091' 128 sx Class G "N/A 4.5" 12.6# L-80 I BT-M 7887' 37' 37' 7924' 6967' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented ~,~, I~i~sb~'.~e~j,~lept~ ~, ~,., t=,~,. True Vertical depth Structural K .L iV D Conductor Surface Intermediate Perforation depth: ~ueeaSvUer~cda,0 RIG IN A L Anchorage 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby ce¢¢ that the foregoing is true and correct to the best of my knowledge Signed ~ Title Drilling Team Leader Date ~'/' Commission Use Only Permit Numb,~er.,,~ ~/',._ , ~ I APl nurobjgr __ -,., ~-,, -~ ~ ,,-",~' ^,*,. I Approval date ~, ~ ~ /m,~ letter for I -? I 50- /o I¢- ISee cover Other re,.quirements Conditions of approval Samples required Yes ~ Mud log required Yes Hydrogen sulfide measures Yes (~'""'"~rectional survey required ~ No Required working pr.,e~,~'r~or BOPE ..... Approved Commissioner the commission Date Form 10-40 Submit in triplicate Alpine · CD1-41PH (Pilot Hole) & ~J1-41 Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 ~" hole to a point +/- 100' TVD below the base of the Alpine Sand. Set 600 ft cement plug #1 from TD to +/- 7549'. Set 500 ft cement plug #2 from +/- 7549' to +/- 7049'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 7160' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet MD above Alpine reservoir. 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. BOPE test to 3500 psi. 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 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency- set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 Ya, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus. 22. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-40 will be the closest well to CD1-41 (8.2' at 317' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 6.6' at 317' MD. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. A large fault (40 - 50' throw) is prognosed approximately 300' East of the pilot hole. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. 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 CD1-41 will be injected into the annulus of a permitted well. The CD1~41 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CDI-4t be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. 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 at the base of the Schrader Bluff Formation (C-30). 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 = 2,998 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: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8"36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-41 & CD1-41 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point- 8 ~" Section - 6 1/8" point- 12 ~" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 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 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <10 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 flowline 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 Alpine 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 Iow 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 FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo~Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. RKB - GL = 37' Co ville River Field CD1-41 PH Pi ot Ho e - Prior to Sid etracking Updated 02/07/00 Wellhead 9.8 ppg drilling mud in hole Cement plug · 16" Conductor to 114' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2505 ' MD / 2400' TVD cemented to surface Top of cement plug dressed off to 7160~ MD / 6380! TVD (+/~ 31 deg !nc;) Top Alpine Reservoir at 7947~ Top of Cement Plug #1 at +/, 7549' Pilot Hole TD at 8149! MD / 7226' TVD (+/- 31 deg incl) 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3,812'~ ID) at 17001TVD = 1712' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines Cdl-41PH - off plug at 7160' MD 9-5/8" 36 ppf J~55 BTC Surface Casing @ 2505' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" 8K~2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM 13.909" IDI at 5200' TVD for E Dummy wlzn 1" 8K-2 Latch Camco KBG-2 GLM 13.909" IDt & 1" Camco DCK-2 Shear Valve ~inned for casing side shear @ +/~ 2000 psi set 2 joints above the X landing nipple 3aker S3 Packer at -.'- 7924 WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go LoCk (3,812" OD) - to be installed later Packer Fluid mix: 9.6 pea KCI Brine with 2000' TVD diesel ceo Tubine Suoended with diesel to lowest GLM Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12,6#/ft. IBT-Mod Tubing Camco BAL-O SSS'V Nioole 1712' 1700' 4-1/2", 12.6#/ft. IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 3674 3400' 4-1/2", 12.6#/11. IBT-Mod Tubing Camco KBG-2 GLM (3,909" IDI 5780' 5200' 4-1/2" 12,6#/ft. IBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 7823' 6907' 4-1/2' tubing joints (2} HES "X" (3.813' ID) 7892' 6950' 4-1/2" tubing joint H, Baker S3 PacKer 7924' 6967' 4-1/2" tubing joint (2) HES XN" (3.725" ID) 7989' 7001' 4-1/2" 10 pup joint WEG [+/- 62 aeg~ 8000' 7006' Note: soi~d body aluminum centralizers installed between 2400' TVD [=2505'} and 4500' TVD (=4961' TOC @ +/- 7614'E (500' MD above top Alpine) Top Alpine at 8114' MD / 7051' TVD 7' 26 ppf L-80 BTC Mod Production Casing @ 8345' MD / 7091' TVD @ 89 deg Well TD at 11170' MD / ' D 7057 TV Colvi le RiverField F0rmhti0n 1 61 ii n 0 ii0n 16" Conductor to 114 4-1/2" Camco BAL-O SSSV Nipp!e (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB;6 No-Go Lock (3,812" OD) with dual 1/4" x 0,049" s/s control line @ 1700' TVD = 1712' MD -5/8" 36 ppf J-55 BTC Surface Casing @ 2505' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seat pipe dope Camco KBG-2 GLM (3.909" tD) at 5200' TVD for E Dummy with 1" BK-2 Latch (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve Baker Payzone ECP (mud inflated) *Landing Collar * 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muloshoe / Entry Guide (C) Open Hole Bridge Pluq Assembly Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Camco KBG-2 GLk/ (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casin§ side shear @ 2000 psi set 2 joints above the X landing nipple TOC @ +/- 7614' MD (500 MD above tOD Alpine) Baker S3 PacKer se[ ar +/~ 7924' Well TD at 11170' MD / 7057' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8345' MD / 7091' TVD @ 89 deg CD1-41 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 Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2505 / 2400 14.2 1086 1532 7" 8345 / 7091 16.0 3208 2499 N/A 11170 / 7057 16.0 3193 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 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 lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1} D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) - 3208 - (0.1 x 7091') = 2499 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3208 - (0.1 x 7091') - 2499 psi ANTICIPATED PORE PRESSURE; MUD WEIGHT, AND FRACTURE GRADIENT -500 -1500 ~2500 -4500 -5500 -6500 -75oo 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT Alpine, CD",-,1PH & CD1-41 Well Cementinq R,..tuirements 9 5/8" Surface caSing run to 2505 MD / 2400' TVD. Cement from 2505' MD to 2005' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2005' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2005'-1562') X 0.3132 ft3/ft X 1.5 (50% excess) = 208.1 ft3 below permafrost 1562' X 0.3132 ft3/ft X 4 (300% excess) = 1956.9 ft3 above permafrost Total volume = 208.1 + 1956.9 = 2165.0 ft3 => 488 Sx @ 4.44 ft3/sk System: 488 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (§0% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft¢ 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% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8345' MD / 7091' TVD Cement from 8345' MD to +/- 7614' MD (500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (8345' - 7614')oX 0.1268 f¢/ft X 1.4 (40% excess) = 129.8 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft° shoe joint volume Total volume = 160.7 + 17.2 = 147.0 ft3 => 128 Sx @ 1.15 ft3/sk System: 128 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 1.15 ft3/sk CD1-41PH Cement Plug #1: 8149' MD to 7549' MD = 600'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 600'X 0.3941 ft3/ft X 1.15 (15% excess) = 271.9 ft3 => 236 Sx @ 1.15 ft3/sk CD1-41PH Cement Plug #2: 7549' MD to 7049' MD = 500'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft3/ft X 1.15 (15% excess) = 226.6 ft3 => 227 sx @ 1.00 ft3/sk 1 By Weight Of mix Water, all other additives are BWOCement 1200 1600 2000 2400 5200 5200 5600 6000 6400 6800 7200 7800 ARCO Alaska, Inc. Sfrucfure: 00#1 Well : 41PH1 Field : Alpine Field Looafion : North Slope, Aldsko 6.00 % \ \ AVERAGE ANGLE2 31.~3 DEG k 251.78 AZIMUTH 34P~2' (TO TD) 4o0 80o ~2oo ~8oo 2oo0 2~oo 2800 ;200 ;800 4ooo Verticot Section (feet) -> Azimuth 251.78 with reference 0.00 S, 0,00 E from slot #41 4400 4800 Alaska, 331.93 AZIMUTH 12~8' (TO TARGET) 595O v 510 680 850 1020 1190 1560 1830 1700 1870 2040 2210 2380 2850 2720 2890 3060 3230 3400 5570 3740 39~0 4080 Vertical Section (feet) -> Azlmufh 351.93 wHh reference 0.00 S, 0,00 W from slot #41 A 2400 2100 1800 1500 1200 90O 6O0 30O 0 500 6O0 90O 1200 ~NTEQ 6000 5700 5400 5100 4~00 ARCO Alaska, Inc. 4-500 4200 3900 3600 <- Wesf (feel) 3,500 3000 2'700 2400 2100 1800 1500 1200 goo 600 300 O TO LOCATION: 1533' FSL, 2391' FWL SEC, 51, Ti2N, RSE TD LOCATION: 1560' F'NL, 967' F£L 6000 5700 5400 5100 4800 4500 4200 2100 1500 1200 go0 500 300 0 1200 Creoted by bm~choml For: B Robertson Dote plotted: ~-Feb-2000 I Plot Reference 19 CD1-4t PH1 VersionS/2. Coordlnotes ore In feet reference slot ~41. Tru. V. rt,oal D.pth ...... i~ RKB (DOYON ARCO Alaska, Inc. Structure : CD#1 Field : Alpine Field Well: 41PH1 Location: North Slope, Alaska 1 Deg/1 0" O.Ou 3.00 2.00 0.00 0.00 5.00 5.00 0.00 0.00 0.00 0.00 0.0~' O.Ou 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Point Begin D'nl Nudge End Angle Build End Angle Drop West So k KOP Permofrost EOC C40 9 5/8 Casing Pt C50 C20 K-5 K-2 Albion-g7 Albian-96 HRZ K-1 LCU Miluveach A Alpine D Alpine Base Alpine TD PROFILE MD 250.00 483.33 833.33 1047.45 11 00.00 1561.94 2141.26 2248.85 2504.98 2507.52 2927.17 4161.00 4418.29 6429.84 7014.59 7459.00 7681.21 7794.65 7888.21 7918.62 7946.69 8035.57 8149.01 COMMENT Inc Dir TVD 0.00 285.00 250.00 7.00 285.00 482.75 0.00 285.00 851.88 0.00 285.00 1046.00 0.00 285.00 1098.55 15.86 251.78 1556.00 51.23 251.78 2089.00 51.25 251.78 2181.00 51.25 251.78 2400.00 31.25 251.78 2402.00 51.25 251.78 2761.00 51.25 251.78 58 t 6.00 31.23 251.78 4036.00 51.23 251.78 5756.00 51.23 251.78 6256.00 51.25 251.78 6656.00 51.23 251.78 6826.00 51.23 251.78 6925.00 31.23 251.78 7005.00 51.25 251.78 7029.00 31.23 251.78 7055.00 31.23 251.78 7129.00 31.23 251.78 7226.00 DATA North East V. Sect 0.00 0.00 0.00 5.68 - 15.75 11.91 9.21 -34.38 29.77 9.21 -34.38 29.77 9.21 -34.38 29.77 -8.17 -87.18 85.36 -77.34 -297.35 306.62 -94.78 -350.34 362.41 -136.30 -476.49 495.22 -136.68 -477.65 496.45 -204.74 -684.44 714.14 -404.75 -1292.14 1355.91 -446.46 -1418.87 1487.52 -772.54 -2409.63 2550.56 -867.54 -2697.64 2835.57 -939.38 -291 6.53 3064.01 -975.40 -3025.97 3179.23 -993.79 -3081.84 3238.06 - 1008.96 -3127.93 3286.57 - 1013.88 -3142.90 3302.34 -1018.43 -3156.73 3316.89 - 1032.84 -3200.51 3362.98 - 1051.23 -3256.38 3421.80 Created by bm|¢hoel For: 1~ Robert. son oat. plotted: 3-Feb-2000 Plot Reference ;. 41 Vere.~g. Coord~not.- nre in f.at reference slot ~41. fru. Vergcal Del~[he ore reference RKB (DQYON i~19), ARCO Alaska, Inc. Structure: CD#1 Field: Alpine Field Well: 41 Looafion : Nor'th Slope, Alaska Point PROFILE MD Inc COMMENT DATA Dir TVD North East V. Sect Deg/lO0 KOP - Sidetrack Pt 71 60.00 31.23 251.78 6380.33 -890.91 -2769.26 516.76 0.00 End Bid & Trn 7330.06 55.30 278.90 6523.29 -897.12 -2860.22 554.07 9.00 HRZ 7468.17 35.30 278.90 6636.00 -884.77 -2959.07 602.07 0.00 Begn Fnl Bid & Trn K-1 7580.55 7703.62 55.50 278.90 6727.70 -874.72 -5003.22 641.12 41.96 293.1 6 6824.00 -852.97 -3076.41 694.75 0.00 9.00 LCU 7844.60 51.18 505.21 6921.00 -802.56 -5164.98 780.90 9.00 Miluvec~ch A 7989.15 61.62 314.57 7001.00 -725.14 -5256.68 892.37 9.00 Alpine D Alpine Tgt - EOC - CsgPt Build 1/100 End 1/100 Build 8048.11 8113.72 8344.86 8344.89 8519.88 66.05 317.83 7027.00 -686.94 -5293.27 943.29 71.04 521.21 7051.00 -640.49 -3352.87 1002.91 89.00 331.93 7091.00 -451.26 -3457.09 1228.33 89.00 331.93 7091.00 -451.25 -5457.10 1228.56 90.75 351.93 7091.58 -296.84 -5559.45 1405.34 9.00 9.00 9.00 1.00 1.00 TD - Cs§ Pt 11170.42 90.75 331.93 7056.76 2041.72 -4786.59 4053.66 0.00 ARCO Alaska, Inc. CDgl 41PH1 slot 941 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-41 PH1 Version#2 Our ref : prop3542 License : Date printed : 2-Feb-2000 Date created : il-Aug-1999 Last revised : 2-Feb-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 32.101,w150 55 38.997 Slot Grid coordinates are N 5975622.395, E 385717.404 Slot local coordinates are 507.94 S 2295.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 'Object wellpath PMSS <0-9236'>,,22,CD#1 PGMS <0-10255'>,,WD2,CD#l PMSS <0-10796'>,,24,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <7755-11134'>,,26,CD#1 PMSS <0-8350'>,,26PH1,CD#l PMSS <0-9357'>,,16PHi,CD#1 PMSS <8393 - 12600'>,,16,CD~1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <472 - 1545'>,,36PHi,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <0-7331'>,,1PHi,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <0-10224'>,,39PHi,CD#1 PMSS <9146 - 13289'>,,39,CD~1 PMSS <0-8844'>,,45PHI,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-10504'>,,5PHi,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <654 - ???'>,,38,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-12055'>,,40,CD#1 CD1-27 Version #7,,27,CD#1 CD1-25 Version#7,,25,CD#1 19A Version#3,,19A,CD#1 PMSS <0-t0548'>,,19,CD~1 Closest approach with 3-D Minimum Distance method Last revised Distance 28-Jun-1999 189.2 28-Jun-1999 28-Jun-1999 28-Jun-1999 15-Ju1-1999 1-Nov-1999 4-Jan-2000 4-Jan-2000 25-0ct-1999 4-Jan-2000 23-Dec-1999 4-Jan-2000 4-Jan-2000 22-Dec-1999 23-Dec-1999 4-Jan-2000 4-Jan-2000 27-Jun-1999 18-Aug-1999 4-Jan-2000 22-Sep-1999 4-Jan-2000 16-Nov-1999 23-Jan-2000 23-Jan-2000 2-Feb-2000 26-Aug-1999 28-Jun-1999 17-Jan-2000 1-Feb-2000 28-Jan-2000 28-Jun-1999 1331.7 169.6 37 6 279 5 149 0 149 0 249 7 249 7 66 6 66 6 35 7 35 7 35 7 10 3 379 5 399 3 399 3 179 6 19 5 19 5 40 2 40 2 358.8 358.8 29.8 39.5 8.2 138.4 159.7 1651.8 219.3 M.D. 261.1 283.3 261.1 1040.0 100.0 283.3 283.3 100 0 100 0 1040 0 1040 0 650 0 650 0 650 0 100 0 250 0 250 0 250 0 100 0 261 1 261 1 200 0 200 0 261.1 261.1 283.3 261.1 316.7 427.8 250.0 1966.7 272.2 Diverging from M.D. 860 283 261 1455 860 283 283 100 100 1040 1040 650.0 2480.0 2480.0 100.0 250.0 250.0 250.0 100.0 261.1 261.1 200.0 200.0 261.1 261.1 283.3 261.1 316.7 427.8 250.0 1966.7 272.2 ARCO Alaska, Inc. CD#i 41 slot #41 Alpine Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 41 Vers.~9 Our ref : prop3650 License : Date printed : 2-Feb-2000 Date created : 11-0ct-1999 Last revised : 2-Feb-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w150 56 46.041 Slot location is n70 20 32.101,w150 55 38.997 Slot Grid coordinates are N 5975622.395, E 385717.404 Slot local coordinates are 507.94 S 2295.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9236'>,,22,CD#1 PGMS <0-10255'>,,WD2,CD#1 PMSS <0-10796'>,,24,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <7755-11134'>,,26,CD#1 PMSS <0-8350'>,,26PHI,CD#1 PMSS <0-9357'>,,16PH1,CD#l PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <472 - 1545'>,,36PH1,CD#l PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <0-7331'>,,1PH1,CD~l PMSS <5946 - 10289'>,,1,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <0-10224'>,,39PHi,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-8844'>,,45PH1,CD#t PMSS <7950-11950'>,,45,CD#1 PMSS <0-10504'>,,SPH1,CD#l PMSS <9499 - 14515'>,,5,CD#1 PMSS <654 - ???'>,,38,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-12055'>,,40,CD#1 CD1-27 Version #7,,27,CD#1 CD1-25 Version#7,,25,CD#1 19A Version#3,,19A,CD#1 PMSS <0-10548'>,,19,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance 28-Jun-1999 28-Jun-1999 28-Jun-1999 28-Jun-1999 15-Ju1-1999 1-Nov-1999 4-Jan-2000 4-Jan-2000 25-Oct-1999 4-Jan-2000 23-Dec-1999 4-Jan-2000 4-Jan-2000 22-Dec-1999 23-Dec-1999 4-Jan-2000 4-Jan-2000 27-Jun-1999 18-Aug-1999 4-Jan-2000 22-Sep-1999 4-Jan-2000 16-Nov-1999 23-Jan-2000 23-Jan-2000 2-Feb-2000 26-Aug-1999 28-Jun-1999 17-Jan-2000 1-Feb-2000 28-Jan-2000 28-Jun-1999 4034.9 4682.5 5720.4 2683.3 5267.6 4954.9 4954.9 5496.4 5496.4 1973.7 1973.7 5558 8 1255 1 1246 5 1057 1 3865 1 3572 1 3572 1 5893 7 3254 5 3254 5 1221 7 1221 7 5678.8 5678.8 3450.9 3814.8 3313.0 4356.5 5456.8 5561.9 5543.0 M.D. 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 10350.0 10350.0 7160.0 7160.0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160 0 7160.0 7160.0 7160.0 7160.0 Diverging from M.D. 7160.0 7160.0 7160.0 9000 7160 7160 7160 7160 7160 10350 10350 7160 7160 11170 10944 7160 7160 11170 7160 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 7160.0 ARCO Alaska, Inc.' Post Office BoX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 February 7, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-41 (& CD1-41 PH) Dear Sirs: RECEIVED , O0 2000 Al~ka 0il & Gas Cons. ARCO Alaska, Inc. hereby applies for a Permit tCbq~~ onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is March 03, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-41 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 31°. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. 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 · . , 5. 6. 7. 8. 9. 10. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). Proposed cementing program and calculations. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer Attachments CC; CD1-41 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1 O54 ANO 382 ANO 384 Anadarko- Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com RECEIVED F[:.B 09 200O ~UJJ:a Oil & Gas Cons. Commission Anchorage The Flr~'t National Bank of Chicago-07'10 Chicago, Illinois ~i. r;! ::*ii ::"::?i-?-iiiii*:!~.e.yable Thri~Jg~?:R. epubU'~;.ilBa.nk :: :.: !..*;,'41~ii.r -...?iiii:: i'?I ...... ii*?;.*:: :: ! :i i i i::?~':::':i;:::? ~':~"?.~'~ACE ~UME~ER!'i':~':;..::::::.!!:24:~'0'0::6§65:i:? :i'? ::;':.[::;!:! i':::?' :'::~'i:i::i. ?i' i' .":.:.':::: i?::.;. ' ' ' i1' ~:ih;"~;~ ~ ~ ~:;~|l~?i::::.i.~OiEII t!i~:~ l,I Text for inclusion in permit approval cover letter: In accordance with 20 AAC 25.005 (f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD 1-41PH) and API number (50-103-20328-70) from records, data and logs acquired for well CD 1-41. FIELD & POOL / 2-0 //O _~ INIT CLASS '~¢_~u-', /O/~- GEOL AREA ADMINISTRATION DATE 1. Permit fee attached ....................... 2. Lease number appropriate. . ',u ............... 3. Unique well name and number2l~; 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... dev ¢/redrll __ serv __ wellbore seg ann. disposal para req __ ON/OFF SHORE (~)N ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to -'z~(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ N *~ 28. Work will occur without operation shutdown ........... ~ 29. Is presence of H2S gas probable ................. Y ~ i~-~.-OEOG¥-- ............... 30~' Permit can be issued w/o hydrogen Sulfide measureS. (~ N 31. Data presented on potential overpressure zones ..... .,~.~ Y N 32. Seismic analysis of shallow gas zones ........... /¢..,¢) Y N R DATE 33. Seabed condition survey (if off-shore) .......... /V'./? Y N · ,2.. -/~ ,~ 34. Contact name/phone for weekly progress reports [exploratory only] GN ANNULAR DISPOSAL 35. APPR DATE w~ 2.1~o12~oo With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... ~) N (B) will not contaminate freshwater; or cause drilling waste... (~ N to surface; (C) will not impair mechanical integrity of the well used for disposal; (~ N (D) will not damage producing formation or impair recovery from a ~ N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. 1~N GEOLOGY: ENGINEERING: UIC/Annular ..w °° RPC ~.,~ SFD.;~ JDH.~ COMMISSION: Comments/Instructions: 0- - c:\msoffice\wordian\diana\checklist (rev. 09/27/99)