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Home My WebLink About201-067 STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION 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 ❑ 201-067 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20374-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,ADL 387207 CRU CD2-42 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 13138 feet Plugs measured None feet true vertical 7397 feet Junk measured None feet Effective Depth measured 13138 feet Packer measured 9096 feet true vertical 7397 feet true vertical 7101 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 117' 117' Surface 2545' 9.625" 2581' 2377' Intermediate iCMNNE E juN j 5 016 Production 9599' 7" 9634' 7274' Liner 3534' 4.5" 12965' 7367' Perforation depth Measured Depth: Perf Pups from 9853'- 12920' MD RECEIVED True Vertical Depth: Perf Pups from 7276'-7360'TVD MAY 0 9 2016 Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 9438' MD, 7245'TVD AOG�VVVV `►("� Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 9096' MD, 7101'TVD�J SSSV: WRDP, 2045' MD, 1966'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9634'- 13138' 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: 252 1891 65 900 217 Subsequent to operation: 287 2069 48 652 212 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory❑ Development 2 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 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 Phone 265-6579 Date Mal f; LOU.. 1/7 1_ 5/60//6 Form 10-404 Revised 5/2015 49 fr 4O,/ b RBDMS LL MAY 1 0 2016 Submit Original Only • • CD2-42 Scale Inhibition Treatment 4/05/16—4/06/16 Hybrid Scale Inhibitor Squeeze Job pumped from 20:30 hrs on 4/5/16 to 07:00 hrs on 4/06/16. LRS= Little Red Services - Initial pressure TBG/IA/OA-520/619/505 - LRS pumped 128 bbls Diesel/WAW5206/M209 preflush at 1- 1.9 bpm,TBG/IA/OA-30/457/547 - LRS pumped 128 bbls Seawater/SCW3001 scale inhibitor main treatment at 1.9 bpm,TBG/IA/OA —58/448/565 - LRS pumped 1406 bbls dead crude overflush at 1.6-3 bpm,TBG/IA/OA—136/461/623 Interval treated (MD): 9634'—13138' WNS PROD CD2-42 • GonocoPhillips � well attributes Max Angle&MD TD • Alaska.Inc. wellbore API/UWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(ftKB) cu�oa�wwhlx+, 501032037400 ALPINE PROD 91.23 10,519.00 13,138.0 .°. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD2-02,8/28120149,40,50 AM SSSV:WRDP Last WO: 10/20/2008 43.36 6/2/2001 Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,33.3- ,,(_ Last Tag: Rev Reason:CORRECT OPEN HOLE DEPTH haggea 8/28/2014 ( Casing Strings (E Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread `(jjj}}} IL I A. CONDUCTOR Insulated 16 15.062 43.0 117.0 117.0 62.58 H-40 WELDed 34" Lasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.697 36.8 2,581.4 2,377.0 40.00 L-80 BTC-MOD CONDUCTOR Insulated 34 I I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread 430.117.0 PRODUCTION 7 6.276 35.0 9,633.5 7,273.5 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread OPEN HOLE 61/8 6.125 12,965.2 13,138.0 7,396.9 0 0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread NIPPLE,2,044.8 WRDP;2,045.0 I _ LINER(in open hole) 41/2 3.958 9,430.8 12,965.2 7,366.8 12.60 L-60 )BTM Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 9,430.8 7,243.6 74.87 SLEEVE "HR"Liner Setting Sleeve 5.80"ID(10.11'Inner 5.800 Profile) SURFACE:368.2,581.4 9,443.7 7,246.8 75.80 NIPPLE "RS"Packoft Seal Nipple w/TKC collar(4.25"ID) 4.250 9,447.4 7,247.7 76.01 HANGER Baker Rex Lock D/G Liner Hanger(4.43"ID) 4.430 GAS LIFT;3.9579 9,457.3 7,250.1 76.57 SBE 80-40 SBE 3.960 Tubing Strings GAS LIFT;6,937.5 £ Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibfft) Grade Top Connection 01TUBING WO 'String 41/21 3.958/ 33.31 9,437.51 7,245.31 12.601 L-80 I)BTM Completion Details GAS LIFT;9,026.9 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc)(°) Item Des Com (in) 33.3 33.3 0.00 HANGER FMC 4 1/2"Tbg Hanger 4.500 _._. 2,044.8 1,965.8 36.25 NIPPLE 4 1/2"Camco Bal-0-SSSV w/3.812"Profile 3.812 PACKER;9,096.1 9,096.1 7,101.2 58.76 PACKER 4 1/2"X 7"Baker premier packer 3.870 dEl 9,199.9 7,154.3 59.98 NIPPLE 4 1/2"HES"XN"nipple wl 3.725"ID 3.725 NIPPLE;9199.99,417.0 7,239.9 73.83 LOCATOR Locator sub 6.01"OD-3.97"ID 3.970 LOCATOR;9.4170 9,427.8 7,242.8 74.64 WLEG WLEG 4.93"OD 3.95"ID 3.950 WLEG,9,427.8 111 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc) I Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 2,045.0 1,966.0 36.25 WRDP 3.81"DB LOCK ON WRDP(HSS-130) 4/7/2013 2.125 iE° Perforations&Slots Shot Dens Top(ND) etm(ND) (shots// Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PRODUCTION;35.0.9,633.5 9,853.0 9,858.0 7,276.4 7,276.4 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid 42 liner/pert pups 10,071.0 10,076.0 7,277.7 7,277.7 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid PERFP;9.953.0-9,658.0 { 42 liner/pert pups til 10,293.0 10,297.0 7,278.6 7,278.6 ALPC,CD2- 10/16/2008 1.5 PERFP Altemating solid it 42 liner/pert pups PERFP:10,071.0.10,076 0 10,513.0 10,518.0 7,275.4 7,275.3 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid 42 liner/pert pups 10,733.0 10,738.0 7,273.5 7,273.5 ALPC,CD2- '10/16/2008 1.5 PERFP Alternating solid PERFP;10,2930-10.2970 42 liner/pert pups 10,953.0 10,957.0 7,273.3 7,273.3 ALPC,CD2- 10/16/2008 1.5 PERFP Altemating solid 42 liner/pert pups 11,174.0 11,179.0 7,273.1 7,273.2 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid PERFP;10513.0-12.5100 42 liner/pert pups 11,390.0 11,395.0 7,273.9 7,273.9 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid 42 liner/pert pups PERFP;10,733910.738.0-7 ) 11,610.0 11,616.0 7,274.8 7,274.9 ALPC,CD2- 10/16/2008 1.5 PERFP 'Alternating solid 42 liner/pert pups 11,830.0 11,835.0 7,278.4 7,278.5 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid PERFP;10,953.0-10,9570 [ 42 liner/pert pups 12,047.0 12,052.0 7,279.8 7,279.8 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid 42 liner/pert pups PERFP;11,1]40.11,179.0 12,268.0 12,273.0 7,282.7 7,282.9 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid RE-FRAC;9,653.0 42 liner/pert pups FRAC,9,653.0 12,480.0 12,485.0 7,297.7 7,298.1 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid PERFP;11390.911,39a 42 liner/pert pups 12,695.0 12,700.0 7,325.0 7,325.7 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid 42 liner/pert pups PERFP;118100.11,616.0 12,915.0 12,920.0 7,358.8 7,359.6 ALPC,CD2- 10/16/2008 1.5 PERFP Alternating solid 42 liner/pert pups Stimulations&Treatments PERFP;11.830.0-11,835.0Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 9,853.0 12,920.0 7,276.4 7,359.6 FRAC 2/13/2009 Pumped a total of 510,851#with 9 PPA,16/30 PERFP;12047.0.12.052.0 Badger sand to formation used 4340 bbls of SW and 1934 Gal of L-65 Scale Inhibitor. Flushed 195 bbls to PERFP;12,268.0.12,273.0 completion w/105 bbls SW and 90 bbls of diesel for FP PERFP,12480.0-124850 9,853.0 12,920.0 7,276.4 7,359.6 RE-FRAC 3/21/2013 C-sand fracture treatment using 25#linear/x-linked gel placing 584,100#of 16/20 proppant into formation (100%of design).Well flushed to completion;freeze PERFP;12.695.0-12,700.0 protected with diesel Mandrel Inserts St PERFP;129150.12,920.0 at, a on Top(ND) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Sero Type Type (in) (psi) Run Date m LINER(in open hole);9,430.8- 1 3,957.9 3,392.2 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,754.0 4/1/2013 12,965.2 OPEN HOLE;12.965.2 13,138 0 i; WNS •PROD • CD2-42 ConocoPhillips 0-4 6 Alaska.inc. Cmfiml718�C CO2-42.8/282014 9:40:51 AM Vertical schematw(actual) ............................... HANGER;335- _u '. Mandrel Inserts 1 m { ati C ° Top(TVD) Valve Latch Port Size TRO Run NO Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date 2 6,937.5 5,582.4 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,760.0 4/1/2013 CONDUCTOR Insulated 34": I 3 9,026.9 7,064.4 CAMCO KBG-2 1 GAS LIFT OV BKO3 0.250 0.0 4/1/2013 43 0-117 Notes:General&Safety End Date Annotation 10/29/2008 NOTE:View Schematic wl Alaska Schematic9.0 NIPPLE;2,044.8 WRDP;2.045.0 SURFACE;36.8-2581 4 d. GAS LIFT;3,957.9 GAS LIFT;6,937.5 GAS LIFT;9,026.9 1 4 PACKER;9,096.1 1+1 NIPPLE;9,199.9 I LOCATOR;9,417.0 WLEG;9,42.8 d" PRODUCTION;35.0-9,633.5 PERFP;9,853.0-9,858.0 i PERFP;10,071.0-10,076.0 PERFP;10,293.0-10,297.0 PERFP;10513.0.10518.0 PERFP;10,733.0-10.738.0 PERFP;10,953.0-10,957.0 PERFP;11,174.0-11,179.0 RE-FRAC;9,853.0 FRAC;9,853.0 PERFP;11,390.0-11,395.0 PERFP;11,610.0-11,616.0 PERFP;11.830,0-11,835.0 PERFP;12,047.0-12,052.0 PERFP;12,268.0-12,273.0 PERFP;12,480.0-12,485.0 PERFP;12,695.0-12,700.0 PERFP;12.915.0-12,920.0-1 i LINER(in open hole);5430.8- 12,965.2 OPEN HOLE;12.965.2-13,138.0 2-o k-°col • • 2.2-t� WELL LOG TRANSMITTAL " PROACTIVE DIAgNOSTIC SERVICES, INC. ='h• A. .: ,, DATA LOGGED °I/n"/2015 {, „w rv1.K.BENDER To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) 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: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNEtj 1) Caliper Report 24-Aug-15 CD2-42 CD 50-103-20374-00 2) Signed : /'22A .1*T4AI' to_E;iIzeft Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achwes\MasterTemplatenles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmd docx Imag~ roject Well History' File Cover ~' .~e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~--~-[-0~'~ Well History Fileldentifier Organizing ldo,,~/ [] lot items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA OVERSIZED (Scannable) [] Diskettes, No. [] Maps: BY: [] Other, No/Type [] BEVERLY ROBIN VINCENT SHERY~INDY Other items scannable by large scanner OVERSIZED (Non-Scannable) ~J Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~ WINDY DATE,~/~0~ ~SI Scanning Preparation ',~ x 30 =?(~2 BY: BEVERLY ROBIN VINCENT SHERYL ~WINDY = TOTALPAGES ?/ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES __ NO RESCANNED B~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ao ( O~ 7 FILE # c2-~4- 1-f11JJ I-rlli) To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ¡ 333 W. 7th Ave., Ste. 100 ¡ Anchorage, Alaska 99501 Voice (907) 279-1433 fFax (907) 276-7542 STATE OF ALASKA % , ALA OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS , , 1. Operations Performed: Abandon f Repair w ell [ Plug Perforations f - Perforate E Other j- Alter Casing " Pull Tubing E Stimulate - Frac it Waiver r Time Extension . f Change Approved Program EOperat. Shutdow n E Stimulate - Other E Re -enter Suspended Well E 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j;� Exploratory f — - 201 -067 3. Address: 6. API Number:' P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic f Service f 50 103 20374 - 00 ° 04 / � 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075, 387207 - CD2-42 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 13138 feet Plugs (measured) none true vertical 7397 feet Junk (measured) none Effective Depth measured 13138 feet Packer (measured) 9096 true vertical 7397 feet (true vertical) 7101 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 117 117 SURFACE 2545 9.625 2581 2377 PRODUCTION 9598 7 9633 7274 LINER (IN OPEN 1 3534 4.5 12965 7367 Perforation depth: Measured depth: slotted liner from 9853 - 12920' SCANNED APR 19 2013 True Vertical Depth: 7276 - 7360 Tubing (size, grade, MD, and TVD) 4.5, L - 80, 9438 MD, 7240 TVD Packers & SSSV (type, MD, and TVD) PACKER - 4 1/2" X 7" BAKER PREMIER PACKER @ 9096 MD and 7101 TVD NIPPLE - CAMCO BAL-0 SSSV @ 2045 MD and 1966 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9853' - 12920' MD Treatment descriptions including volumes used and final pressure: ISIP= 1100 psi, 584100# of 16/20 proppant 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 761 3110 44 -- 247 Subsequent to operation 1444 8291 176 -- 273 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory f — Development Ri Service i Stratigraphic E 16. Well Status after work: . Oil RI Gas fl WDSPL E Daily Report of Well Operations XXX GSTOR E WINJ I` WAG E GINJ E SUSP f 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: 313 -060 Contact Robert Blakney Cad 265 -6417 Email Robert.G.Blakney @conocophillips.com Printed Name Ro... Bla Title Completion Engineer Signature i Tr / Phone: 265 -6417 Date f , A, 6 3 RBDMS APR 9 A � VHF '7 .7 6 . - 4 ,1& h 3 Form 10 -404 Revised 10/2012 Submit Original Only a WNS • CD2 -42 Conoc Well Attributes M ax Angle & MD TD Alaska, IOC. Wellbore APW WI Field Name Well Status !nci (°) MD (RKB) Act Btm (ftKB) 501032037400 ALPINE PROD 91.23 10519.00 13,138.0 "' Comment H2S (ppm) Date Annotation End Date KB-Grd ON Rig Release Date "' SSSV: WRDP Last WO: 10/20/2008 43.36 6/2/2001 Well Conric: - CD2 -02, 4!82013 1'55:06 PM Scnemanc -ACwal Annotation Depth (ftKB) End Date Annotation 'Last Mod By End Date +q Last Tag: Rev Reason: FRAC, GLV C/0, Set WRDP osborl 4/7/2013 HANGER. 33 { Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (WD) ... String Wt.. String ... String Top Thrd CONDUCTOR 16 15.062 43.0 117.0 117.0 62.58 H-40 WELDed C Insulated 34" Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (WD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.697 36.8 2,581.4 2,377.1 40.00 L -80 BTC -MOD ii 4.1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR - - - PRODUCTION 7 6276 35.0 9,633.5 7,273.8 26.00 L -80 BTCM 43 -177 Insulat4tl 117 - Casing Description ring 0... String I D ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Pd� o n 9 P OPEN HOLE 61/8 6.125 9,633.0 13,138.0 7,396.9 0 0 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd NIPPLE, 2,045 MIN LINER (in open hole) 4 1/2 3.958 9,430.8 12,965.2 7,366.8 12.60 L -80 IBTM WRDP,2,045 Liner Details Top Depth H (TVD) Topincl Nomi... LJ Top (ftKB) (ftKB) 11 Rem Description Comment ID (in) n 9,430.8 7,243.5 74.87 SLEEVE "HR" Liner Setting Sleeve 5.80" ID (10.11' Inner Profile) 5.800 SURFACE. _ 1 L 9,443.7 7,246.5 75.88 NIPPLE "RS" Packoff Seal Nipple w/ TKC collar(4.25" ID) 4.250 37 9,447.4 7,247.5 76.08 HANGER Baker Flex Lock D / G Liner Hanger (4.43" ID) 4.430 GAS OFT, _ 9,457.3 7,250.0 76.61 SBE 80 -40SBE 3.960 3.958 Tubing Strings GAS LIFT, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 6.936 TUBING WO 4 1/2 3.958 33.3 9,437.5 7,245.3 12.60 L -80 IBTM Completion Details GAS LIFT, Top Depth 9,027 - (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 33.3 33.3 -0.16 HANGER FMC 4 1/2' Tbg Hanger 4.500 PACKER, 9,095 , °� 2,044.8 1,965.8 36.29 NIPPLE 4 1/2" Camco Bal - O - SSSV w /3.812' Profile 3.812 9,096.1 7,101.2 58.76 PACKER 4 1/2" X 7" Baker premier packer 3.870 9,199.9 7,154.0 59.16 NIPPLE 4 1/2" HES" XN" nipple w/ 3.725" ID 3.725 NIPPLE, 9.200 ; I'` 9,417.0 7,239.8 73.83 LOCATOR Locator sub 6.01" OD - 3.97" ID 3.970 LOCATOR. • 9,427.8 7,242.7 74.64 WLEG WLEG 4.93" OD 3.95" ID 3.950 9,417 ` WLEG, 9,428 7 I Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc' I Top (ftKB) (ftKB) ( ° ) Description Comment Run Date ID (in) 2,045.0 1,965.9 36.29 WRDP 3.81" DB LOCK ON WRDP (11SS -130) 4/7/2013 2.125 { Perforations & Slots ( { Shot Top (TVD) Btm (TVD) Dens Top (508) Btm (ftKB) (ftKB) (RKB) Zone Date NM- Type Comment PROOUCT109, 9,853.0 9,858.0 7,276.4 7,276.4 ALPC, CD2 -42 10/16/2008 1.5 PERFP Alternating solid liner /pert pups 35 -9,633 ..A. 10,071.0 10,076.0 7277.7 7277.8 ALPC, CD2 -42 10/16/2008 15 PERFP Altemating solid liner /pert pups PERFP. 10,293.0 10,297.0 7,278.5 7,278.5 ALPC, CD2-42 10/16/2008 1.5 PERFP Altemating solid liner /perf pups 8,853 -9,858 ..• • 10513.0 10,518.0 7275.4 72753 ALPC, CD2-42 10/16/2008 15 PERFP Alternating solid liner /pert pups 10,733.0 10,738.0 7,273.3 7,273.3 ALPC, 002-42 10/16/2008 1.5 PERFP Alternating solid liner /pert pups PERFP, 10,071- 10.076 = 10,953.0 10,957.0 7273.3 7273.3 ALPC, CD2-42 10/16/2008 1.5 PERFP Alternating solid liner /pert pups 11,174.0 11,179.0 7,273.1 7273.2 ALPC, CD2-42 10/16/2008 1.5 PERFP Alternating solid liner /perf pups 11,390.0 11,395.0 7,272.8 7,272.9 ALPC, CD2-42 10/16/2008 1.5 PERFP Altemating solid liner /perf pups 10,29910297 11,610.0 11,616.0 7,275.0 7,275.1 ALPC, CD2 10/16/2008 1.5 PERFP Altemating solid liner /perf pups 11,830.0 11,835.0 7,278.4 7,278.5 ALPC, CD2-42 10/16/2008 1.5 PERFP Altemating solid liner /perf pups 12,047.0 12,052.0 7,282.9 7,282.6 ALPC, CD2-42 10/16/2008 1.5 PERFP Altemating solid liner /perf pups PERFP, 10513 40s1e - 12,268.0 12,273.0 7,282.8 7,283.0 ALPC, CD2-42 10/16/2008 1.5 PERFP Altemating solid liner /perf pups 12,480.0 12,485.0 7,297.9 7,298.3 ALPC, CD2-42 10/16/2008 1.5 PERFP Altemating solid liner /perf pups PERFP, 10.733-1Q736 12,695.0 12,700.0 7,325.2 7,325.8 ALPC, CD2-42 10/16/2008 1.5 PERFP Altemating solid liner /perf pups II 12,915.0 12,920.0 7,358.8 7,359.6 ALPC, CD2-42 10/16/2008 1.5 PERFP Altemating solid liner /perf pups PERFP, _ Stimulations & Treatments 10,953 - 10.957 . >, a - Bottom I' Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) PERFP, : _- (ftKB) (ftKB) (ftKB) (RKB) Type Date Comment 11,174 11.179 9,853.0 12,920.0 7,276.4 7,359.6 FRAC 2/13/2009 Pumped a total of 510,851# with 9 PPA, 16/30 �' "' Badger sand to formation used 4340 bbls of SW and FRAC. 34 RE - FRAC, 1934 Gal of L-65 Scale Inhibitor. Flushed 195 bbls 9 . 8 to completion w/ 105 bbls SW and 90 bbls of diesel PERFP, - for FP 11,390 - 11.395 _ 9,853.0 12,920.0 7,276.4 7,359.6 RE -FRAC 3/21/2013 C -sand fracture treatment using 25# linear /x -linked PERFP, - = gel placing 584,100# of 16/20 proppant Into formation 11,610 11.616 - s (100% of design). Well flushed to completion; freeze protected with diesel Notes: General & Safety PERFP, a End Date Annotation 1183011835 _ 10/29/2008 NOTE View Schematic w/ Alaska Schematic9.0 PERFP, 12,047- 12.052 PERFP, : M 12,268 - 12.273 < ®m PERFP. -- e 12,480 - 12.485 PERFP, A 12,695 - 12.700 L _3 Mandrel Details Top Depth Top Port PERFP, r = S (TVD) Inc! OD Volvo Latch Size TRO Run 12,915 - 1 LINER (In pen - - 5... Top (ftKB) (RKB) (°) Make Model (in) sem Type Type (In) (pal) Run Date Com... hole), " a 1 3,957.9 3,392.2 43.76 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,754.0 4/1/2013 9,431 - 12.965 OPEN HOLE, - L ---'- 2 6,937.5 5,582.5 41.88 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,760.0 4/1/2013 9,833- 13.138 TO (CD2 -42), 13.138 3 9,026.9 7,064.4 56.32 CAMCO KBG-2 1 GAS LIFT OV BKO3 0.250 0.0 4/1/2013 CD2 -42 Frac Work Summary DATE SUMMARY 3/17/2013 GAUGE TBG TO 3.84" TO 2045' RKB. PULLED WRDP -2 (S /N: HSS -130) @ SAME. GAUGE TBG TO 3.77" TO 9200' RKB. SET CAT STANDING VALVE @ 9185' SLM( 9200' RKB). * *NOT HOLDING PRESSURE * *. IN PROGRESS. 3/18/2013 PUMPED 80 BBLS CRUDE. IA TRACKING. PULL OV @ 9027' RKB. * *CHECK IN OV STUCK OPEN**. READY FOR CIRC OUT. 3/18/2013 SET DV @ 9027' RKB. MITT TO 3500 psi. * *PASS * *. MIT -IA TO 3500 psi. * *PASS * *. SET FRAC SLEEVE (OAL= 48 ") © 2045' RKB. * *READY FOR FRAC TREATMENT * *. 3/21/2013 Performed C -sand fracture treatment using 25# linear /x- linked gel placing all 584,100# of 16/20 .ro. •ant o location into formation (100 %of design). Flushed to completion, ell freeze protected wt diesel. Pulled Stinger from well, demobed equipment to allow slickline to perform post -frac during night shift on CD2 -41. Will move rig -up to CD2 -47 in A.M. 3/30/2013 PULLED FRAC SLV @ 2045' RKB. B &F TO XN @ 9200' RKB. PULLED DV @ 9027' RKB. JOB SUSPENDED. 3/31/2013 SET OV(1/4 ") @ 9027' RKB. PULLED DV's @ 6938' & 9027' RKB. UNSUCCESSFUL ATTEMPTS TO SET GLV's @ 6938' & 9027' RKB. IN PROGRESS. 4/1/2013 PULLED OV @ 9027' RKB. SET GLV (TRO =1754 PORT = 3/16 ") @ 3957' RKB. SET GLV (TRO =1760 PORT = 3/16 ") @ 6937' RKB. SET OV (1/4 ") @ 9027' RKB. CONFIRMED GLD INTEGRITY. PULLED SV @ 9200' RKB. SET FRAC SLV @ 2045' RKB. COMPLETE. 4/7/2013 PULLED FRAC SLV @ 2045' RKB. B &F TBG. SET WRPD (HRS -277) @ 2045' RKB. PASSED CLOSURE TEST. REOPENED SSSV. COMPLETE. • • • w\� � j,, • THE STATE Alaska Oil and as ofALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 OR R d 2013, Fax: 907.276.7542 �Ep Robert Blakney Completion Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 '� Or - - 0 61 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -42 Sundry Number: 313 -060 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, II I Cathy P. F erster Chair DATED this PT day of February, 2013. Encl. A ` , RECEIVED • STATE OF ALASKA FEB 0 6 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION D7-S /1e3 APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1. Type of Request: Abandon E Rug for Redre f - Perforate New Fool E Repair w ell r Change Approved Program I __ Suspend (-" Rug Perforations r Perforate E Pull Tubing r Tine Extension r Operational Shutdown r Re -enter Susp. Well I-- Stimulate IV Alter casing I-" Other: I 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development w Exploratory r 201-067 3. Address: Stratigraphic E Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20374 - 00 7.1f perforating. What 8. Well Name and Number: Regulation or Conservation Order governs well spacing In this pool? Will planned perforations require spacing exception? Yes r No " P CD2 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 380075, 387207 ColvNie River Field / Alpine Oil Pool 11. P RESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13138 7397 13138' 7397' none none Casing Length Size MD WD Burst Collapse CONDUCTOR 83 16 117' 117' SURFACE 2545 9.625 2581' 2377' PRODUCTION 95!, 7 9633' 7274' LINER ON OPEN HOLE 3534 4.5 12965' 7367' Perforation Depth MO (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 9853 12920' 7276 - 7360 4.5 L 9438 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - 4 1/2" X 7" BAKER PREMIER PACKER MD= 9096 TVD= 7101 SSSV - CAMCO BAL-O SSSV MD= 2045 TVD=1966 12. Attachments: Description Summary of Proposal W 13. Welt Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory F Stratigraphic r Development W Service (" 14. Estknated Dale for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 Oil i,7 Gas ly WDSPL f Suspended r 16. Verbal Approval: Date: VVINJ r GINJ r WAG r Abandoned f" Commission Representative: GSTOR l SPLUG r 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact: Robert Blakney 0 265 -6417 Email: Robert.G.Blaknev(conocoohillit Printed Name ; *1. : t : i Title: Completion Engineer Signature • � '� Phone: 265 -6417 Date 1 IS" /13 Commission Use Only Sundry Number. 3) 3- r/wV Conditions of approval: Notify Commission so that a representative may witness J!!J v Plug Integrity f BOP Test r Mechanical Integrity Test r Location Clearance E 1, RBDMS FEB 15 2013 Other Spacing Exception Required? Yes ❑ No (J Subsequent Form Required: / G _ //, ,/ APPROVED BY Approved by: _ ro lication is vagl Mt giths from th I val, Date: Z " /�- -- /) ��iP � pp Farm 10 -403 (Revised 10/2012) 1/ " G Submit Form and Attachments in Duplicate ORIGINAL 2113//3 1 1 • • CD2-42 Sundry Application CD2 -42 was completed in June of 2001 targeting the Alpine C formation. The well was completed with 4.5" tubing. Initially hydraulically fractured in February 2008, —510,000#'s of 16/30 Badger Sand was placed. We intend to re- stimulate the Alpine C formation with a 4 stage treatment utilizing Bioballs for fluid diversion. If the stimulation is successful we intend to place —580,000#'s of 16/20 Carbolite and anticipate an increased production of 275 bpd in 2013. Proposed Procedure: Schlumberger Pumping Services: (Alpine C Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' ND. 3. Ensure the 10 -403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 11 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 4950 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 240 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 40bpm with a maximum expected treating pressure of 3700 psi. Stage 1 • 360 bbls YF125ST Pad • 147 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 255 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 179 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 306 bbls YF125ST w/ 7 ppa 16/20 Carbolite • 30 bbl Bioball diversion Stage 2 • 280 bbls YF125ST Pad • 147 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 255 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 85 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 229 bbls YF125ST w/ 7 ppa 16/20 Carbolite RB • • 30 bbl Bioball diversion Stage 3 • 280 bbls YF125ST Pad • 147 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 255 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 85 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 229 bbls YF125ST w/ 7 ppa 16/20 Carbolite • 30 bbl Bioball diversion Stage 4 • 280 bbls YF125ST Pad • 147 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 255 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 85 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 229 bbls YF125ST w/ 7 ppa 16/20 Carbolite • Flush with 149 bbls of linear fluid (WF125) and freeze p rotect • Total Sand: Approx. 580,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Cement Evaluation of CD2-42 and wells within 1 /4 mile of CD2 -42 CD2 - 42: 7" Casing cement job was pumped on 5/26/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.9 ppg mud. The plug was bumped and floats held. CD2 - 47: 7" Casing cement job was pumped on 11/11/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg brine. The plug was bumped and floats held. A pressure test was performed at 3500 psi and held for 30 min. CD2 - 55: 7" Casing cement job was pumped on 7/25/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 8.8 ppg brine. The plug was bumped to 1400 psi and floats held. CD2 - 60: 7" Casing cement job was pumped on 6/30/2005 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg mud. The plug was bumped to 1550 psi and floats held. RB • • CD2 - 43: 7" Casing cement job was pumped on 1/9/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1500 psi and floats held. CD2 - 40: 7" Casing cement job was pumped on 8/20/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1260 psi and floats held. Full returns were observed throughout the job. CD2 - 05: 7" Casing cement job was pumped on 8/9/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1200 psi and floats held. Full returns were observed during the job. CD2 - 467: 7 5/8" Casing cement job was pumped on 7/25/2008 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 960 psi and floats held. Full returns were observed during the job. CD2 - 30: 7" Casing cement job was pumped on 9/3/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement. The plug was bumped to 1500 psi and floats held. CD2 - 56: 7" Casing cement job was pumped on 9/23/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1150 psi and floats held. Full returns were observed during the job. CD2 - 33: 7" Casing cement job was pumped on 8/24/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement. The plug was bumped to 1200 psi and floats held. Returns were observed during the job. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a 1/4 mile radius or any other nearby well. RB • Stimulation Surface Rig -Up Mond Tattle '1\ 'Ewe Tar .-<>4 � F ' E ' y To er: y • Minimum pressure rating on all surface treating lines 10,000 psi `x • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. m y fi k s . n rtul &dud ti Pop Off Tarn a, itt Pop-3n Tank Pump Truck N C n- F J V N j Ll Frac Pump r l Frac Pump Frac Pump Frac PLrlp L Frac Purrp r-.41 7f, •J Frac Pump RB 0 0 Stimulation Tree Saver OPEN POSITION CLOSED POSITION FRAC 1RCTN t ONNE r r . , At MA I. VALVE r.�` i „, ,..AANUAL OPERATED 1 MASTER VALVE F A ,, Nv Stinger Stinger \ �.. .... __ _ — NaAt+sizREt. .. ,d ,µ. _. , / L.... \ ...,.... _ . . .... 1 . , fi t / " VENT W a ,� rtow TEE AND !I, C> VENT VALVE WE LIHIA rr % VAC.VE`,. OPEN N / - - ■ . JIELLH Aat VALVCS "� 3 WI QUAD PACKOT r ' ASSE AAEtt IN P LACE IN nt NNG ` ' t '1,11 $I , 1 i . s ,.. ; ^ � t a E d: • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB :.;;:::: ',: 1~+44 4t C CD i 25' •: 6p1 32P61 D217 \ 2:32 ...>•:-•••••••.• � 0336 2: ••. •. ' • C.D2 -30 CD2 = 24$9: =i•.' .'i '. • • t18i • • .,,,:. .... i. »:.r.. •.,� �: �! CD2 -34PB1 '.. • : :;: ~ , � . r ° . � .: ✓ t � . '''.. 15�1,-44PB1 • CD2 29 f { $Q 2 -32PB1 a 50P6 }:: Z;D2 -34 , T T ... • • CD2 -05 '.. f1l,PINE 1 CD2 -19 .. 0.2 -26 • • • • • • Cb2 d2P: ` •CD +PB1 • Cl }2-46 CE12 -39PB1 Legend ' Well • 1,.. �3P61 \ • • - Ti ' D2 -50 . Suspended • C © z ` 49 • + P +A • • • '• ALPINE 1E + Service • • • ` . • Producer A Observation • • • • A Injection: SW • CD C 1`e ♦ Injection: SAPW • 1 -33A CD2 -39 • Injection: PW T CD2- 467PB1 4 D2 -464 S ♦ Injection: MWAG + ACTIVE, INJ, MG III • • ACTIVE, INJ, IWAG CD2 -38 ACTIVE, INJ, GAS • CD2 470 ' C D2 41 * • ACTIVE, INJ, DG • NEVE • 1 ACTIVE, INJ, <Null> • • • `•CD2 -467 CD2-48 � 4 Disposal • r A . 1/4 Mile Radius • • • • • : � D2 -56 Cpl -55 02 47 = 'CD2 -56L1 �" • • �: ConocOPhillip5 D2 -60P61 CD2-42 Fracture Radius •,.CD2 -43 N CONFIDENTIAL : • CD2 -56L1 • C D4 -304 CD4 -16 •, o o.2s o.s • • • n .. •.••. {, I E Miles • i • • FracProAram2013.mcd CSR 1 -10 -2012 • • 0 • fi 7 WNS CD2 -42 ConocoPhillips :r ° a Well Attributes Max Angle & MD TD Alaska,llx:. e`y� '' Weliba W eAPWI Field Name Well Status Inc!(') 010 (RKB) Act atm(RKB) F Cnsw7ffNl a Y ; r 501032037400 ALPINE PROD 91.23 10,519.00 13,138.0 "' Comment H2S (ppm) Date Annotation End Date KS (R) Rig Release Date wan Gonna. , 046.32012 a m.al u3 SSSV: WRDP Last WO: 10/20/2008 43.36 6/2/2001 5c/ornate - soon Annotation Depth (6658) End Date Annotation Last Mod ... End Data Last Tag: Rev Reason: RESET WRDP ninam 8'16/2012 HAIIGER,33 - Casing Strings ti Casing Description String 0... String m. Top (OKs) Set Depth (f... Set Depth(TOD) ... String WI.. String... String Top Thrd ; �; CONDUCTOR 16 15.062 34.0 117.0 117.0 6258 H-40 WELD y Casing Description String 0.. String ID.. Top MB) Sat Depth (r... Set Depth (TVD)._ String Wt ... String ... String Top Thrd 3 pp SURFACE 958 8.697 368 2,581.4 2,377.1 40.00 L - 80 ETC - MOD Casing Description String 0... String ID... Top IRKS) Set Depth (f_. Sat Depth MVP)._ String Wt... String ... String lop Thrd ... , - ; PRODUCTION 7 6.276 35.0 06315 7,273.8 2900 L - 80 ETCM CONDUCTOR, ' Casing Description String 0... String ID ... Top (RKB) Sot Depth p... Sal Depth (IVO)... String Wt... String ... String Top Thrd 3x•117 OPEN HOLE 61/8 6.125 9,633.0 13,138.0 7,396.9 0 0 Casing Description String 0 .. Siring 10... Top (RKS) Set Depth (1... Set Depth MVO) ". String Wt... String._ String Top Thrd N. LINER (in open hole) 4 1/2 3.958 9,430.8 12965.2 7,366.8 12.60 L -80 IBTM N17710 a04s� Liner Details WeOP.2.045 - ' Top Depth IWO) Top not Nord... T op IRKS) (7158) ( ") Item Description Comment ID (In) 9,430.8 7,243.5 74.87 SLEEVE "HR" Liner Setting Sleeve 5.80' ID (10.11' Inner Profile) • 5.800 L. 9,443.7 7,246.5 75.88 NIPPLE 'RS' Packoff Seal Nipple w/ TKC collar(4.25" ID) 4250 suRFacE. 9,447.4 7,247.5 7608 HANGER Baker Flex Lock D /0 Liner Hanger (4.43" ID) 4230 37.2.581 9.457.3 2250.0 76.61 SBE 80-40 SBE 3.960 GA S LOT, max 3000 Mk Tubing Strings M* Tubing Description String 0... String ID... Top (ROB) Set Depth (f... Set Depth (TVD)... String Wt.., String... String Top Thrd = TUBING I 41/2 3.958 ( 33.3 9,437.5 7,2453 12.60 I L - 80 IBTM GAS LIFT, a °• °� �® Completion Details IIIIII Top Depth GAS OFT, (TVD) Top Intl Nomi... 9,027 Top MKS) RO a) 1 Item Description Comment ID (!n) 33. 33.3 -0 .16 HANGER FMC 4 1/2' Tbg Hanger 4.500 MIN 2,044.8 1,965.8 36.29 NIPPLE 4 112' Cameo Bal -O- SSSV w/3.812" Prole 3.812 PACY,ER.9,o96 -- .,. 9,099.1 7,101.2 58.76 PACKER 4 1/2' X 7' Baker premier packer 3.870 MEI - 9,199.9 7,154.0 59.18 NIPPLE 4 1Y2' HES' XN' nipple w1 3.725' ID (original completion) 3.725 MIL NIPPLE. 9,200 - ; 9,417.0 7,239.8 73.83 LOCATOR Locator sub 6.01'00 - 3.97" ID (original completion) 3.970 9,427.8 7,242.7 74.64 WLEG WLEG 4.93' OD 3.95" ID (original completion) 3.950 MI it LOCATOR, e.4iT 11 Other In Hole ireiine retrievable plugs, valves, pumps, fish, etc.) PJLEG. 9.426 Top Depth () Top Inc! UP 3 (!IXe (SOB) 1') Description Comment Run Data ID (in) I - 2,04 1,965.9 36.29 WRDP 3.81 DB LOCK ON MOP (HSS -130) 7/25/2012 2.125 P erforations & Slots Shot Top (0/D) aim (ND) Dens Top (RIM otm (ORB) (ROE) (NAB) zone Dale Oh-- Type Comment 1 9,853 9,858 7,276.4 7,276.4 ALPC, CO2-42 10/16/2008 1.5 PERFP Altemating solid liner /pert pups PRODUCTION, _ A 10,071 10,076 7,277.7 7,277.8 ALPC, CD2.42 10/16/2008 1.5 PERFP Alternating solid finer /pert pups 355,032 I 10,293 10,297 7,278.5 7,278.5 ALPC, CD2 -42 10/1612006 1.5 PERFP Alternating solid liner /pert pups 8.6519,657{ PEPFP, II 4 10.513 10,518 7,275.4 7,275.3 ALPC, CD2 -42 10/16/2008 1.5 PERFP Alternating so1W liner /pert pups 1 I 3 e 10,733 10,738 7,273.3 7,273.3 ALPC, CD2-42 10/16/2008 1.5 PERFP Alternating solid linet/perf pups PERFP, I 10,953 10,957 7,273.3 7,273.3 ALPC, CD2-42 10116'2008 1.5 PERFP Alternating said liner /pert pups 16.oT1 -w.o2a a I 11,174 11,179 7,273.1 7,273.2 ALPO, CD2 -42 10/116/2006 1.5 PERFP ARemating solid liner /pert pups 11,390 11395 7,272.8 7,272.9 ALPO, CD2-42 10/16/2008 1.5 PERFP Alternating solid kner /per( pups PERFP, • • Y 11,610 11,616 7.275.0 7,275.1 ALPC, CD2 -42 10/16/2008 1.5 PERFP Alternating solid liner/ped pups to,2m-tazel I. a9 ' ' 11,830 11,835 7,278.4 7,278.5 ALPC, CD2-42 10/1 82008 1.5 PERFP Alternating solid iiner/perf pups ■ 3 12,047 12,052 7,282.9 7,282.6 ALPC, CD2 -42 10/16/2008 1.5 PERFP Alternating solid liner /pert pups 70677, e I 12,268 12,273 7,282.8 7,283.0 ALPO, CD2-42 10/16/2008 1.5 PERFP Ntorati nng solid liner /port pups 10,513.7,;,,,7i i � c 12,480 12,485 7,297.9 7,298.3 ALPC, CD2 -42 10'16/2008 1.5 PERFP Alternating solid liner/per( pups � - Ij 12,695 12,700 7,325.2 7,325.8 ALPC, CO2-42 10/1672008 1.5 PERFP Alternating solid liner /pert pups PERFP, b 19,73340138 ° 12915 12,920 7,358.8 7,359.6 ALPC, CD2-42 10/1612008 1.5 PERFP Alternating solid liner /pert pups e I t� i Stimulations & Treatments j Bottom PERFP, i - I.fln Tap Ftas Blm Top Oaplh Depth 10.95340.957 11 -8 Depth Depth (TOD) (WO) l' 9 (Mai) MB) IRKS) (055) Type Date Comment 9 ,853.0 12,920.0 7,276.4 7,359.6 FRAC 2/13/2009 Pumped a total of 510,85111 with 9 PPA, 16/30 I 1 171 ER 1i P 9' I °Ei e 1 Badger sand to formation used 4340 bbls of SW and tt S� 1934 Gal of L -65 Scale inhibitor. Flushed 195 bbis t FRAC, 9653 a to completion w/ 105 bas SW and 90 buts of desel for FP PERFP, 1 ,,39au.3ss I 1 t Notes: General & Safety t End Date Annotation PERFP, i i- 10/29/2008 NOTE: View Schematic w/ Alaska Schemalic9.0 11,61041,816 l ei I I F 1 a PERFP. ( Mandrel Details 11.9304 1.635 s Top Depth Cep Pan (TVO) Ind OD Valve Latch aloe TRO Run PERFP, i 3 Stn Top NIKO) MK 8 1 I'1 Make Model (in) Sere Typo Typo 90 (poll Run Date Con._ !2.04742,052 1 3,957.9 3,392.2 43.76 CAMCO KBG -2 1 GAS LIFT DI'AY 8EK -5 0.000 0.0 101182008 12,aaa- ia,273 PERFP, I i , lit I p � 1 2 6,937.5 5,582.5 41.88 CAMCO KBG -2 1 GAS LIFT DMY BEK -5 0.000 0.0 10/18/2008 ( ib P 3 9,026.9 7,064.4 56.32 CAMCO KBG -2 ( GAS LIFT OV BK 0.250 0.0 2/15/2009 PRFP, r = ss'+.. 12,4001E2,455 In PERFP, E" 12.695- 72.103 f L, PERFP, I 12,01540,520 e 011ER tin open a e q [ L hole). ad3142,9as OPEN HOLE, „/ 0,633-134 38 TO(CO2.47). , 73,+36 CD2 -42 Alpine C Frac Model • 4 stage stimulation • F rac Design 1 stage Job Description Step Pump Fluid Name Step Gel Prop. Prop. Name Rate Fluid Conc. Type and Mesh Conc. • (bbl /min) Volume (Ib /mgal) (PPA) (gal) PAD 40.0 YF125ST 15120 25.0 0.00 2.0 PPA 40.0 YF125ST 6179 25.0 CarboLite 16/20 2.00 4.0 PPA 40.0 YF125ST 10723 25.0 CarboLite 16/20 4.00 4.0 PPA 40.0 YF125ST 7149 25.0 CarboLite 16/20 4.00 7.0 PPA 40.0 YF125ST 12860 25.0 CarboLite 16/20 7.00 For all stages Fluid Totals 181314 gal of YF130ST • 11760 gal Of WF 125 Proppant Totals 584,267 lb of CarboLite 16/20 Model Results Initial Fracture Top TVD - 7260.0 ft Initial Fracture Bottom TVD - 7377.0 ft Propped Fracture Half- Length - 205.9 ft • EOJ Hyd Height at Well - 147.7 ft Average Propped Width - 0.334 in • Disclaimer Notice: — This model was generated using vendor supplied modeling • software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. • STATE OF ALASKA • FEB 2 7 2009 REPORT OF SUNDRYSWELL OPEIRA IT Ok~~~` `'~s ~o"s• commission ~-„_~_ 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 ^ 201-067 3. Address: Stratigraphic ^ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20374-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 52' CD2-42 - 8. Property Designation: 10. Field/Pool(s): , ADL 380075 ` Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 13138' - feet true vertical 7397' - feet Plugs (measured; Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16" 114' 114' SURFACE 2544' 9-5/8" 2581' 2376' PRODUCTION 9596' 7" 9633' 7273' LINER 3528' 4-1/2" 12965' 7367' Perforation depth: Measured depth: Slotted Liner from 9853' - 12920' true vertical depth: 7276' - 7359' Tubing (size, grade, and measured depth) 4-1/2" L-80 at 9438' MD Packers &SSSV (type & measured depth) Baker Premier Packer ~ 9096' Camco SSSV @ 2045' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : f ,.,; , 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 213 168 51 809 247 Subsequent to operation 4111 4667 331 1124 327 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Expioratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: C~ - Ga~ 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: 309-014 contact Tim Schneider Printed Name Tim hne' er .Title Production Engineer ~'Z r ~ Signature Phone o ° 265-6859 Date ~ ~ Pre amd b Jeanne L. Haas 263-0470 Form 10-404 Revised 04/2006 ~~Z Submit Original Only r 1~ • • CD2-42 Stimulation results: Summary of stimulation job: 2-13-09: Pump frac in four stages: Utilized a four stage design with 90 - 7/8" bio-balls for diversion. Pumped a total of 510,851# of 16/30 badger sand to formation with 4 - 2 to 9 PPA ramps, using 4340 bbls of SW and 1934 gallons of L-65 scale inhibitor. Flushed 195 bbls to completion with 105 bbls SW and 90 bbls of diesel for freeze protect. AIR-30 BPM, AIP-2600 psi, ISIP-2100 psi. Well test: 2/22/09: 4111 bopd, 331 bwpd, 4.7 mmcfpd, 327 WHP CONDUCTOR, _) 34117 NIPPLE. 2,045 WRDP, 2,045 SURFACE. 342.581 GAS LIFT, 3,958 GAS LIFT, 8 938 GA8 LIFT. 9,027 PACKER, 9,098 NIPPLE, 9,200 LOCATOR, 9.417 WLEG, 9.428 PRODUCTION, ~ 349.833 I PERFP. - 9,683-9.858 =e =e PERFP, e~i 10.071-10,076 PERFP, :~~ 10.293-10,297 I ~, PERFP, I 10,513-10,518 PERFP, =_ 70.733-10,738 = PERFP, 70.983-10.957 ~, PERFP, ~I 71,77417,179 FRAC. 8.853 I ~2 PERFP, 11,390-11,395 -iI PERFP, _ 11.810-11,816 I PERFP, -e I 11,830-11,838 PERFP, ~ 12,268-12,273 i PERFP, 72,480-12.465 ~ ' ~ WNS CD2-42 Well Attributes Maz An le 8 MD TD Wellbore API/UWI 501032037400 Field Name ALPINE Well Status ProMnj Type Incl (°) MD (ftKB) PRODUCING 91.23 10,519 Act Btm (ftNB) 13,138 Commem SSSV: WRDP H25 (ppm) Dale Annrtrtion End Drte Last WO: 1020/2008 KB-0rd (R) 43.36 Rig Release Date 6/2/2001 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason. PULL FRAC SLEEVE, SET WRDP End Date 2/23/2009 Casin Strin s Casing Description CONDUCTOR String 0... 16 String ID ... 15.062 Top (ftKB) 34 Set Depth (f... 117 Set Depth (TV D) ... 117,0 String Wt... 62.58 String ... H-40 String Top Thrtl WELD Casing Description SURFACE String 0... 95/8 String ID ... 8.697 Top (ftNB) 34 Set Depth (f... 2,581 Set Depth (ND) ... 2,376.7 String WL.. 40.00 String ... L-80 String Top Thrd BTC-MOD Casing DescripROn PRODUCTION String 0... 7 String ID ... 6.151 Top (ftKB) 34 Set Depth (f... 9,633 Set Depth (ND) ... 7,273.8 String Wt... 26.00 String ... L-SO String Top Thrtl BTCM Casing Description OPEN HOLE String 0... 61/8 String ID ... 6.125 Top (ftKB) 9,633 Set Depth (f... 13,138 Set Depth (ND) ... 7,396.9 String Wt... String ... 0 String Top Thrd 0 Casing Description LINER (in open hole) String 0... 4 1/2 String ID ... 3.958 Top (ftKB) 9,431 Set Depth (f... 12,965 Set Depth (ND) ... 7,366.8 String Wt... 12.60 String ... L-80 String Top Thrd IBTM Liner Details Top (ftKB) Top Depth (ND) (ftKB) Top Incl (°) ttem Descriptio n Comment ID (in) 9,431 7,243.5 74.87 HA NGER "HR" Liner Setting Sleeve 5.80" ID (10.11' Inner Profile) 5.800 9,444 7,246.5 75.88 NIP PLE "RS" Packoff Seal Nipple w/ TKC collar(4.25" ID) 4.250 9,447 7,247.5 76.08 HA NGER Baker Flex lock D / G Liner Hanger (4.43" ID) 4.430 9,457 7,250.0 76.61 SBE 80-40 SBE 3.960 Tubin Strin s Tubing Description TUBING String 0... 41/2 String ID ... Top (ftKB) 3.958 33 Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top ThrO 9,438 7.245 12.60 L-80 IBTM Run Date I ID Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftNB) Tvve Date Comment sand to formation used 4340 bbls of SW and 31 of L-65 Scale Inhibitor. Flushed 195 bbls detion w/ 105 bbls SW and 90 bbls of diesel IStnl Too lftK8ll (ftKB) I(°)I Make Motlel I ON I Serv TYPe I Type I IIN TRP Unl Run Date Comm... PERFP, ~e 12,920 e (in open hole). I-12.965 J HOLE, WNS • CD2-42 ConocoF'hillips Alaska- inr- KBGrd (R) Rig Release Oa 34117 NIPPLE. 2,048 WRDP, 2,045 SURFACE, 342,581 GAS LIFT. 3.958 GAS LIFT, 8,938 GAS LIFT. 9,027 PACKER, 9,096 NIPPLE. 8,200 LOCATOR, 9,411 WLEG, 9.428 PRODUCTION. 349,633 -a PERFP, ~~. 1o.m1-1o.ws ~~ PERFP, °~ 10.293-10,297 ~~ PERFP, 10.513-10.518 PERFP, 70.733-10.738 PERFP. 10,953-10,957 PERFP, 11.774-11.179 FRAC. 9.853 PERFP, 11.390-11,395 PERFP, 11.610-11.616 PERFP, 11.830-11.835 PERFP, 12.047-12 052 PERFP, 12.268-72.273 PERFP, 12.480-12.485 PERFP. 12,695-12,700 ~m TD • • ~ h ~ i ~~ ~ ~ ~~ ~ ,, f ~ ~ j ~ ~^' ~ ~ 1 ~ ~ f~ ~ ~ ~ ` ~ x ... ; r }} a ~ , ~.~ 9 1 ~ l 1 ~ ~ . , ~ ~ ' ~ ~ ~ ~' r ~ ~ '~ % ~ L ~ i J ~ ~ SARAH PALlN, GOVERNOR _ , _ . , ...- ., ._ . . . ~r ~~ ~~ ~~ ~~++ ~ 7~~~ ~ ~ ~+ t~ i~t1•~7~ QIL t~1si / ~ 333 W. 7th AVENUE, SUITE 100 ~~TT~+ ~~1v 1~T a7 ` C01s5~Ii R'sA~Ots C~~II 7'~''I01` ANCHORAGE, ALASKA 99501-3539 ~ r' PHONE (907) 279-1433 FAX (907) 276-7542 Tim Schneider Production Engineer ConocoPhillips Alaska Inc. , PO Box 100360 Anchorage AK 99510 Re: Colville River Field, Alpine Oil Pool, .CD2-42 ~ ~ ~- Sundry Number: 309-~~~~ Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Sea-nount, Jr. Chair ~t DATED thisZ i day of January, 2009 Encl. ~~ ~ ~' ~ STATE OF ALASKA ~~, ~~~ ~ ~, ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ZGQ~ ~,ti~ APPLICATION FOR SUNDRY APPRO~iRNa~iI ~~ ~~~,~ ~~~~~~~~~~ 20 AAC 25.280 anchn~e..,, 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate 0 ' Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^~ Exploratory ^ 201-067 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-2037400 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Required? YeS NO ~ CD2-42 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075 RKB 52' Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13138' 7397' Easing Length Size MD TVD Burst Collapse CONDUCTOR 77~ 16' 114' 114' SURFACE 2544' 9-5/8" 2581' 2376' PRODUCTION. 9596' 7" 9633' 7273 LINER 3528' 4-1 /2" 12965' 7367' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 9438' Packers and SSSV Type: Packers and SSSV MD (ft) 4 1/2" X 7" Baker premier packer Packer = 9096' 4 1/2" Camco Bal-O SSSV SSSV = 2045' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 24, Zoos Oil Q ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name Tim Schneider Title: Production Engineer Signature f Phone 265-6859 Date l'/r-!~ej Commission Use Onl Sundry Number: O~L~ J~ Conditions of approval: Notify Commission so that a representative may witness ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~1~~ 6. #~~~ ~ ~ t~1~G APPROVED BY ~' Approved by: COMMISSIONER THE COMMISSION Date: Form 10-4(~3 Revised 06/006 /""~ ['g ~ ~ ~ ! /~ ~ ~ Submit in u~c~a~o~ t~.d3 Eta' ~ \VI H ~~ l ~© Overview: ; CD2-42: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU at least ten clean insulated frac tanks. Load tanks with Seawater from CD2 injection manifold. (approximately 4500 bbls are required for the treatment) 2. Rig up Schlumberger pumping services equipment and stab the 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 9000 psi 4. Pump the 550 bbl Breakdown with YF125ST fluid with L-65 Scale inhibitor (50 gpt). Bring pumps up to maximum rate ASAP. SD and obtain ISIP & Pc. a. Pump Schlumberger's schedule at 40-50 BPM with a maximum pressure of 7000 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment using Little Red's pump truck. b. 4 Stages of 2,4,7 PPA ramped containing: • 1260 bbls dirty YF125ST dropping to 1170 bbls for the remaining three stages (3510 bbls) • 611 Mlbs. -16/30 white sand • 30 bio-balls via the ball drop after each 7 ppa stage (90 balls total) • Flush with 50 bbls YF125ST; 50 bbls WF125, and 76 bbls diesel (177 bbls tubing volume to mid liner depth) " ~ WNS ~ CD2-42 CQCIQ~Q1-1 i~1~1p5 { `~ Well Attributes ... _ _ _ Max Mgle 8 MD STD .l „~ t Wellbore APl/UWI Fieltl Name Well Status Pratl/Inj Typo ~Incl (°) MD (ftK6) Act Btm (ftK6) 501032037400 ALPINE ~/ 'PROD 91.23 10,51900 13,138.0 COmment M25 (ppm) !Dale Annotation (End Date KB-Grd (ft) (Rig Release Dal ... ___,SSSV: WRDP ( Last WO 10!20/2008 43.36 6/22001 .. - - $OMvnat5 A :Annotation iDepth (NKB) '. End Date Annotation End Date last Tag: i ( Rev Reason WORKOVER, GLV C/O, PULL HHC!PLUG 1029/2008 HANGER 33 ° Casin~trings 'C g Descnption ? (String O String ID .Top (ftK8) Sat Depth ((.. Set Depth (ND) . Str g Wt... Str g ...' St mg Top Thrd , ~ ~ CONDUC fOR 16 15 062 0.0 111.0 117 0 62.58 H-00 WELD CONDUCTOR, r Casing Descnption String O String ID .Top (ftK6) Sat Depth (i... Set Depth (ND) .. String Wt... (Str g ... String Top Thrd onn SURFACE 95/8 8.697 0.0 2,581.0 2,376.7 40.00 L-80 BTC-MOD •' Casing Description String 0... String ID ... Top (ftK6) Sat Depth (i... Set Depth (ND) ... String Wl... String ... _ String Top Thrtl NIPPLE, z.ws - ,PRODUCTION 7 6.151 0.0 9.633.0 7 273.8 26.00 L-80 BTCM -_ Casin Descri g ption g g p( ) p ( p ( ) (String Wt... String... Stria 0... Stria ID ... To ftK6 Set De th i... Set De [h ND _ Stang TOp Thrd su of sa O 0 0 _ z i ~ DO t Str g .. Btr ~~ D)... Stria wl.., g String ... -~- Bet ~ Te $e String Top Thrd . cnsuFT, INER Ide C o en 4 2 3-958 12965.2 7,3668 9A30.8 12.60 L-80 IBTM 3.558 hole) cns uFT, 6 538 M iLner Details.. Top Depth - _ -_.- , (ND) Top Inc! GAS LIFT Top (NKB) (ftK6) (°) Item D pt Comment ~ - ID Sin , a9z] 9,430.8 7,243.5 74 87 HANGER ~"HR" Liner Semng Sleeve 5.80" ID (10.11' Inner Prof e) 5.8C ~ 9,443.7 7,246.5 ~ I 75.88iNIPPLE ~"RS" Packoff Seal Nipple w/ TKC collar(4.25" ID) 1 4.25 PACKER, 9.056 - - ~ 9,447.4 7,247 5 _ _ ~ 76.08 (HANGER Baker Flex Lock D / G Liner Hanger (4.43" ID) - _ 14.43 9,457 31 7,250 0' ' 76.61 SBE '80-00" SBE 5.00" ODx4.00" ID W/ XO Bushing 5 1/2" BTC X 4 1/2" IBT ~ 3.9E NIPPLE. s,2oo -- - - I (3.96" ID) ocATDR I - Tubing Strings . L , gptT Tubing Des ph . (String 0... I Str ng ID _.. Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... String ... _ String T p Thrd WLEG 9 x28 f. G 41/2 3958 I _ 0.0 I 9,437.5 I 7,245.3 i 1260 I L-80 - I IBTM - , , _ p COm IetlOn De Top Depth all$ t _. _ _. - - - (ND) ToP Inc! ~, PRODUCTION, )f I ~ ~ -'--- - -'--'--I ~ __.._ ~ .._. ~_ .._. _-_ 0-9633 9,199.9 7.154.0 59.16 NIPPLE .41/2 HES "XN'nipple w/3725"ID (original completion) 372` 9.417.0 7,239.8 73.83 LOCATOR Locator suh 6.01 OD - 3 9T ID (original completion) 3 97C ~„ . ,,,,, 9.427 8 /242.7 74.64 WLEG WLEG 4.93" OU 3.95" IU (onglnal completion) 3.96C °- - - Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) __ __ _ _ Top Depth' I >i Pfi• __ eP ~ (TVD) ToP Intl - up~° lo,u~r; ~TOp (ftK8) (fiKe) (°) Description Comment Run Dat ID (in) ~~` ~ 2.045.0 1.965.91 3629'WRDP 13.812"WRDP (HPS-315) - - 12/11/2008.12125 Pertorations _ - _ --.- _ ~I.. n 'snm: I ,- i., ~ ', ToP (TVDI Btm (TVD) Dens' Top (flKe) Btm (flKB) (ftK8) (ftK8) Zone Date (sh ~~ Type Comment _ ~' 9 853 0 9,858 0 7,276.4 7,276 4 ALPC CD2-02 ~ 10/16/2008 1 S PERFP Altemating solid liner/pert pups 10,0/1.0 10,076 0 7 277.7 7,277.8 ALPC, CD2-02 10/16/2008 1.5 PERFP 'Alternating solid liner/pert pups rLel '. 10,293.0 10,297.0 7,278.5 7,278.5 ALPC, CD2-02 10/16/2008 t5 PERFP ,Altemating solid liner/pert pups 10513 '(. ~'.. _ 10,513.0 10,518 0 7,275.4 7,275.3 ALPC, CD2-02 10/16/2008 i t5 PERFP 'Altemating solid liner/pert pups 10,733.0 10,738.0 7,273.3 7 273.3iALPC, CD2-02 10/16/2008 15PERFP :Altemating solid liner/pert pups ~~.,,, ~~., ,,, - i 10,953.0 10,957.0 7,273.3 7,273.3 ALPC, CD2-02 10/1620081 1.5 PERFP Altemating solid liner/pert pups - 111,174.0 11,179.0 7,273.1 7,273.2ALPC, CD2-02 10/16/2008 t5 PERFP Altemating solid liner/ped pups 11,390.0 11,395.0 7,272.8 7,272.9iALPC, CD2-02 10/16/2008 1.5 PERFP Altemating solid liner/ped pups E 11,610-0 11,616.0 7,275.0 7 275-1'iALPC, CD2-02 110/16/2008 1-5 PERFP Altemating solid liner/ped pups s3 u. ~... ~ ~ 11,830.0 11,835.0 7,278.4 7,278.SLALPC. CD2-02 10/16/2008 LS PERFP Altemating solid liner/ped pups 12,047.0 12,052.0 7,282.9 7,282.6~',ALPC, CD2-02 ~ 10/16!2008 1.5 PERFP Altemating solitl liner/ped pups 12,268.0 12,273.0 7,282.8 7,283.OIALPC, CD2-02 10/162008 1.5 PERFP (Altemating solid liner/ped pups " >s ~' - 12,480.0 12,485.0 7 297 9 7,298.3 ALPC, CD2-02 10/162008 tS,PERFP ',Altemating solid liner/ped pups 12,695 0 12.700.0' 7,325.2 7,325.8 ALPC, CD2-42 10/162008 i LS PERFP Altemating solid liner/ped pups - - 12915 O 12.920.0: 7,358.8 /,359.6 ALPC, CD2-02 10/16/2008 ] 1.5 PERFP Altemating solid liner/pert pups ° ^' Notes: General & Safety ~~ End Data - Annotation 10/29/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 ~_~r~t u a ., .. ~I - 4~ ,~ i y _- _ _ _ IMandrelDetatls_ __ - Top Depth Top I Port ' (TV D) Inc! OD Valve Latch Size TRO Run 2 a] ~u5:~ ~ ' .Stn Top (ftK8) lftKei (°) Make Model (in) Srxv TYPe Type (in) (Psi) Run Data Comm... 1 3,951.9 3,392.2 43J6 CAMCOKBG-2 1 PROD DMY BEK-5 0 00 10!182008 PERFP, - " 1z.z6e-12,273 ° ~ 2 6,937.5 5,582.5 41.88 CAMCO KBG-2 1 PROD DMY BEK-5 0 0.0 10/18/2008 _ __ 3 9,026.9 7,064.4 56.32 CAMCO KBG-2 1 PROD OV BK 1/4 0.0 10/2312008 PERFP. _ - _ I _- 12660-12.685 F= r:. •~~ 12,695-'~. [.>uu - PERFP,_ ~. 12,915-12.92u - - '_ LINGER (inside pen hole), ~ 9,631-12,565 ~ . OPEN HOLE. ' 9.63313.136 \ - TD(CD212), ~~ - t3.138 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~ i REPORT OF SUNDRY WELL OPERATf~~VS 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. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ~ - Exploratory ^ 201-067 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20374-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 52' AMSL ' CD2-42 8. Property Designation: 10. Field/Pool(s): ADL 380075 Colville River Field /Alpine Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 13138' ~ feet true vertical 7397' feet Plugs (measured) Effective Depth measured 13138' feet Junk (measured) true vertical 7397' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 77' 16" 114' 114' SURFACE 2544' 9-5/8" 2581' 2376' PRODUCTION 9596' 7" 9633' 7273' LINER 3528 4.5" 12965' 7367' ((~~ ] ~ (` ~~ ~ ( ~ ~ ~ $1 ~ p ` ~ C_ `~ ~ 9853'-98a 1' 6' 10293'-10297', 10513'-10518', 10733'-10738', 10953'-10957', 11174'-11179', 11390'-11395', 11610'- ~ ~' ` Perforation depth: Measured depth: 11616', 11830'-11835', 12047'-12052', 12268'-12273', 12480'-12485', 12695'-12700', 12915'-12920' true vertical depth: 7276'-7276', 7277'-7277', 7278'-7278', 7275'-7275', 7273'-7273', 7273'-7273', 7273'-7273', 7273'-7273', 7275'-7275', 7278'-7278', 7283'-7283', 7283'-7283', 7298'-7298', 7325'-7326', 7359'-7360' Tubing (size, grade, and measured depth) 4.5", L-80, 9437.5' MD. , {1{y~,3ry~y ~~ j,{, 7~~+ 7j ff~'/~` "1 A ' ~ ~ ~ ~ .:~ .` •~i Rb ~~ ,~ I'Ii 2 a.~ a/ l-V Packers &SSSV (type 8~ measured depth) BAKER Premier pkr @ 9096' Camco SSSV @ 2045' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1183 ~ 1801 9 269 Subsequent to operation 45 1517 422 - 234 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 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: 308-330 Contact Liz Galiunas @ 265-6247 Printed Name Liz Galiun Title Alpine Drilling Engineer Signature Phone: 265-6247 Date Pre aced b Sharon All u Drake 263-4612 Form 10-404 Revised 04/2006 ' ~ I r ~ ~ ''`~~' ~~• ~ ` ~~ '~ ~~Q~ V :>..~:.. y ,, . ' ,,. ... -.. ,..,ry. ~~. /3 , cg Submit Original Only ~~~'~ .-. ConocoPhilGps NIPPLE, W ROP, GAS LIFT. 3,958 GAS LIFT, - _- _- 6.938 GAS LIFT. 9,02] PACKER, 9,096 NIPPLE. 9.200 LOCATOR, 9,617 wLEG, s,a26 PRODUCTION, 0-9.633 ~a a2 ~r w - t I toll o ~ u 7» ~n EPF' ~ - I u sa-a.9si ~ t ,F, - 74 ~ . nv -, .. PERFP, 11,390-11,395 PERFP, 11.610.11.616 PERFP, 11.830-11.835 PERFP, tz.on-tz.osz PERFP, 12.266-12.273 PERFP, tz,4so-12.4es PERFP, 12,695-12,]00 WNS ! CD2-42 Last Tag: ~ ~ Rev Reason' WORKOVER, GLV C/O, PULL RHC/PLUG 10/29/2008 Casing Strings Casing Description 'String O... String lD ...TOp (ftK8) ( Set Depth(f...Set Dopth (TVD)... ', Siring Wl...5tring ... String TOp ThM CONDUCTOR 16 15.062 I 0.0 1170 1170 G258 H-40 WELD Casing Description String 0... String ID ... ~'~TOp (ftK8) Sat Depth (t... Set Depth (7VD)... String Wt... String ._ Skiing Top Thrd SURFACE 9 5/8 8.697 0 0 1 2,581.0 '~ 2,376.7 i~ 40.00 L-80 BTC-MOD 'on 'String 0... 51 ... (Top (ftK8) S 6 Set Deplh (i... Set Depth (ND) ... String WI... String ... _ String Top Thrd PRO DUCTION 0 0 .1 9,633.0 7,273.8 26.00 L-80 BTCM Casio Descd g ption (String 0... String ID ... _ Top (ftK8) Set Depth (T... Set Depth (ND) ... String W1... String ... String Top Thrtl (OPEN HOLE ~ 61/8 6.125 9,633.0 13,138.0 7,3969 0 0 '.Casing Description String 0... String ID ... Top (ftK8) Set Depth (i... Sat Depth (ND) ... Siring Wt... String ... Siring Top Thrd LINER (lnslde open 41/2 3.958 9,430.8 12,965.2 7,366.8 12.60 L-80 IBTM hole) - - _. -..-~. _- !Liner Details Top Depth, -- -_.--.__--._- _ _._-__._- (ND) Top Top (ftK8) ~ (ftK6) Incl (°) Kem Description Comment ID (in) 9,430.8 7,243.5 74.87 HANGER "HR" Liner Setting Sleeve 5.80" ID (10.11' Inner Profile) 5.800 9,443.7 7,246.5 75.88 NIPPLE "RS" Packoff Seal Nipple w/ TKC collar(4.25" ID) 4.250 9,447.4 7,247.5 76.08 HANGER Baker Flex Lock D / G Liner Hanger (4.43" ID) 4.430 9,457.3, 7,250.01 76.61 SBE "80-00" SBE 5.00" ODx4.00" ID W/ XO Bushing 5 1/2" BTC X 4 1/2" IBT 3.960 ' (3.96"ID) Tubing Strings String Top ThM T bing Des iption (String 0... Str g ID ...' ,Top (ftK8) Set Depth (f... iSet Depih (ND) . 1St ng Wt... St log ... ( I ( I , Tubing-Production 41/2 3958 0.0 94375 1 7,245.3 11 1260 L-80 IBTM _ Completion Detaits ~TOp Depth _ (ND) Top Top (fiKB) 1HK8) Incl (°1 kam Description _ Cammant -_-. __ -_ (D(in) 33.3 33.3. -0.16 HANGER FMC 4 1/2" Tbg Hanger 4.500 2,044.8 1,965.8- 36.29 NIPPLE 4 1/2" Camco Bal -O- SSSV w/3.812" Profile 2.812 9,096.1 7,101.21 58.76 ~ PACKER - __ 4 1/2" X 7" Baker premier packer 3.870 9,199.9 7,154.0 1 59.16 NIPPLE 4 1/2" HES"XN" nipple w/ 3.725" ID (original completion) ~ 3.725 9,417.01 7239.8 ~' 73.83 LOCATOR Locator sub 6.01" OD - 3 97" ID (original completion) 3.970! 9,427.8 7,242.7 74.64 WLEG _ WLEG 4.93" OU 3.95" ID (original completion) 3.950 Other to Hole ireline retrievable plugswalves, pumps, fish, etc. rpp oepm (FVD) Top Top (ftK8) (ftK6) Incl (°) Description Comment Run Date ID (in) ~ 2 045.0 1,965.9 10/24/2008 2.125 3629 WRDP 3.812" WRDP-2 (KISS-243) Perfora tions -~ I _ - Shot l - - _- ----- - - ~ ~ ~ Dens Top (TVD) Btm (ND), TOp (ftK6) Btm (ftK6) (ftK6) (ftK6) Zone Date (ski.,. Type Comment _ 4 9,853.0 9,858 0 1,276.4 ALPC, CD2-02 10/16/2008 ~ i5 PERFP Alternating solid liner/pert pups 7,276 10,071.0 10,076.0 1 7 277.7 7,277.8 ALPC, CD2-02 10/16/2008 t5 PERFP Alternating solid liner/pert pups I 10,293.0 10,297.0 _ ~, 7,278.5 7,278.5 ALPC, CD2-02 110/16/2008 1.5 PERFP Alternating solid liner/pert pups 10,513.0 10,518.0 11 7 275.4 7,275.3 ALPC, CD2-02 110/162008 1.5 PERFP Alternating solid liner/pert pups 10,733.0 10,738.0 1 7,273.31 7,273.3; ALPC, CD2-02 ~ 10/162008 1.5 PERFP Alternating solid liner/pert pups 10,953.0 10,957.0 1 7,273.3' 7,273.3 ALPC, CD2-02 ~~ 10/162008 t5 PERFP Alternating solid liner/pert pups 11,174.0 11,179.0 1 7,273.11 7,273.2 ALPC,CD2-02 10/16/2008 1.SPERFP Alternating solid liner/pert pups 11,390.0 11,395.0 7,272.8 7,272.9 ALPC, CD2-02 10/16/2008 1.5 PERFP Alternating soliA liner/pert pups 11,610.0 11 816.0 7,275.0 7,275.1 ALPC, CD2-02 10/16/2008 1.5 PERFP Alternating solid liner/pert pups 11,830.0 11,835.0 7,278.4 7,278.5 ALPC, CD2-02 110/16/2008 1.5 PERFP Altemating solitl liner/pert pups 12,047.0 12,052.0 7,282 9 7,282.6 ALPC, CD2-02 ~. 10/16/2008 1.5 PERFP Alternating solid liner/pert pups 12,268.0 1 12,273 0 ' 7,28281 7,283.0 ALPC, CD2-02 10/16/2008 1.5 PERFP Alternating solid liner/pert pups 12,480.0 ~ 12485.0 1 7,297.9 7,298.3 ALPC, CD2-02 10/1612008 1 i.SPERFP - Alternating solid liner/pert pups 12,695.0 12,700.0 1 7,325.2 7,325.8 ALPC, CD2-02 10/16/2008 1 tSiPERFP Alternating solid linerlperf pups 12,915.0 12,920.0 1 7 358 8, 7,359.6 ALPC, CD2-02 10/1612008 ~' 1.SIPERFP Alternating solid liner/pert pups Notes: General & Safe Entl Dale Annotation 10/2912008 I NOTE: VIEW SCHEMATIC wlAlaska Schemafic9 0 -_..__-. Mandrel Details -- ,_ Top Depth Top 'i Port (NDI Incl OD Valve latch Size ':TRO Run 15[n Top (ftK8) (ftK6) (~) Maka Model (in) Serv Type Type (in) (psi) Run Date Comment 1 3,957.9 3,392.2 43.761CAMC0 KBG-2 1 PROD DMY BEK-5 0 0.0 10/18/20... 2 6,937.5 5.5825,41 88 CAMCO i KBG-2 1 PROD DMY BEK-5 0 0.0 10/18/20... 3 9,026.9 7,064.4156.32 CAMCO -._. ~ _-. KBG-2 1 _ PROD OV _ BK 1/4 I _ 10/23/20... PERFP, _ 12,915-12,920 ~~~-- " LINER (made open hole), 9 43112.965 ~ I I oPEN RaE, ~_ - Page 1 of 1 Maunder, Thomas E (DOA) From: Allsup-Drake, Sharon K [Sharon.K.Allsup-Drake@conocophillips.com] Sent: Monday, December 08, 2008 11:05 AM To: Maunder, Thomas E (DOA) Cc: Galiunas, Elizabeth C; Anderson, Nina M Subject: RE: CD2-42 (201-067) Attachments: cd2-42 workover.xls Tom - Attached is the pre and post rig workover information you requested. Let us know if there is anything else we can help with. Thank you, Sharon 263-4612 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, November 16, 2008 12:17 PM To: Galiunas, Elizabeth C; Allsup-Drake, Sharon K Subject: CD2-42 (201-067) Liz and Sharon, t am reviewing the 404 recently submitted for this well. The pre and post rig information was not included. Would you please submit that information? Email is fine. Tom Maunder, PE AOGCC 12/24/2008 • CD2-42 Pre and Post Rig Workover Summary DATE SUMMARY 9/3/08 PULL 3.812 WRDP @ 2046' RKB!/VRDP GOT STUCK @ 147' SLM WORK ~LS BY HAND WRDP MOVED TO 143' SLM, CONFER WITH CWG, CALL FOR LRS, LRS PUMP 20 BBLS HOT ABLE TO WORK WRDP FREE, PARAFFIN PACKED AROUND BOTTOM SET OF PACKING, LDFN JOB IN PROGRESS 9/4/08 TAG RHC P.~,DG BODY IN X NIP ~ 9Q7T SLM / 9089' RKB BEAT RHC PLUG BODY DOWN TO 9084' SLM, JOB POSTP©NED FOR HIGHER PRIORITY JOB, MOVE TO CD2- 467 9/9/08 RAN 3" BAIT SUB, 3' x 1.875" STEM & 1.39" BULL NOSE. BEAT RHC PLUG BODY FROM 9084' TO 9123' SLM. IN PROGRESS. 9/10/08 DROVE RHC PLUG FROM 9123' TO 9187' SLM. SET WRDP-2 (S/N: HPS-375) @ 2046' SLM / 2046' RKB. GOOD CLOSURE TEST. COMPLETE. 9/24/08 PULLED WRDP FROM 2046' RKB. ENCOUNTERED PARAFFIN @ 150'. BRUSHED TUBING TO X NIPPLE @ 9098' RKB. SET 3.81" XX PLUG_~ 9098' RKB. IN PROGRESS. 9/25/08 CONFIRMED GOOD SET ON XX PLUG @ 9098' RKB. PULLED OV FROM 8993' RKB AND GLV @ 7086' RKB. SET DV @ 7086' RKB. LOADED TUBING AND IA W/ SEAWATER AND 2500' DIESEL CAP. OMIT TO 2500 PSI PASSED. ATTEMPTED TO EQUALIZE XX PLUG, NO SUCCESS. SUSPECT SCALE. IN PROGRESS. 9/26/08 BAILED ON AND ATTEMPTED TO EQUALIZE XX PLUG @ 9098' RKB. BLOWN DOWN HOLE AND LOST TOOLSTRING WHILE ATTEMPTING TO PULL XX PLUG. RECOVERED TOOLSTRING AND ~3' OF WIRE. XX PLUG IS ON TOP OF RHC PLUG BODY CcD_ 9212' RKB. IN PROGRESS. ----°----~--~~~ M._._~ 9/26/08 MOBILIZE TO ALPINE. PREP UNIT AND CHEMICAL CUTTER. 9/27/08 DRIFTED TUBING TO XX PLUG @ 9188' SLM W! WIRE GRAB. NO WIRE FOUND. ATTEMPTED TO EQUALIZED XX PLUG, NO SUCCESS. RIG DOWN FOR E-LINE. 9/27/08 STRING SHOT TUBING FROM 9141-9153'. TUBING PUNCH TUBING TAIL FROM 9162- 9164 . ._ 9/28/08 DRIFTED TUBING TO XX PLUG @ 9188' SLM W/ 3.625" LIB. COMPLETE. 9/28/08 CHEMICAL CUT 4.5" TUBING AT 9152.5'. TUBING PRESSURE 250 PSl BEFORE CUTTING AND 200 PSI AFTER CUTTING. ADJUSTABLE BOTTOM CENTRALIZER ARMS REMOVED BY CHEMICAL AND LEFT IN HOLE. 9!29/08 ASSIS FMC IN SETTING BPV. COMPLETE. 10/23/08 RUN 2" PULLING TOOL & 3.42" BELL GUIDE, SIT DOWN @ 2014' SLM UNABLE TO WORK PAST, CONFER W/ CWG RUN 3.625" LIB, LIB SHOWS FISHING NECK„PULL 3.813" BLANKING SLEEVE, PULL BALL 8~ ROD FROM RHC PLUG BODY~~9187' SLMSLM, MEASURED BHP @ 9175' RKB MAX (PSI 2459.39 /TEMP 145.75), PULLED 1" SOV @ 9027' RKB, SET 1" OV @ 9027' RKB W/ (1/4" PORT), LDFN JOB IN PROGRESS 10/24/08 PULLED RHC PLUG BODY .@ 9200' RKB. SET 3.812 WRDP-2 ~SER# HSS243) @ 2045' RKB. GOOD PRESSURE ON CONTROL LINE BUT BL DID NOT TRACK. PUMP DOWN BL 8~ GET COMMUNICATION BUT UNABLE TO PURGE ALL THE WAY AROUND. WELL PSI TOO LOW FOR CLOSURE TEST, JOB COMPLETE. 12/4/08 GAUGED TBG TO 3.85" TO WRDP-2 @ 2045' RKB. PULLED 3.812 WRDP-2 FROM HAL- O NIPPLE @ 2045' RKB. GAUGED TBG TO 3.805" TO XN NIPPLE @ 9192' SLM / 9200' RKB, NO OBSTRUCTIONS. RUN 3.65" CENT & 1-3/4" SAMPLE BAILER; SIT DOWN @ 9361' SLM, WORK TOOLS TO 9371' SLM. NO SAMPLE RECOVERED. RETURN WELL TO OPNS FOR EVALUATION. 12/7/08 DRIFTED TBG WITH 3.65" CENT 8~ 1-3/4" SAMPLE BAILER. TOOLS STOPPED FALLING @ 9505' SLM / 9513' RKB (80 DEG); NO OBSTRUCTIONS IN TBG. COMPLETE. ~~ i ConocaPhi[ips Time Log & Summary. WelNiew LYeb ReA°Kfng Report Well Name: CD2-42 Rig Name: DOYON 19 Job Type: RECOMPLETION Rig Accept: 10/4/2008 5:00:00 PM Rig Release: 10/19/2008 8:00:00 AM Time Lomas __ _ __ 'i D~te___ From To Dur_ S Depth E Depth Phase Code Subcode T Comment 10/04/2008 24 hr Summary Moved rig from CD2-466 and RU on CD2-42, ACCEPTED RIG @ 17:00 hrs. Load pipe shed with 75 jts 4" DP & 8 4 3/4" DC's. RU to take on produced water & blow down tank. PU & stood back 25 stds of 4" DP. Began to RU circ. manifold. 00:00 17:00 17.00 0 0 MIRU MOVE DMOB P Move rig f/CD2-466 to CD2-42 - Move motor complex -Move pit complex (change tire on complex) Move sub off of CD2-466 (remove lower section of cellar wind wall - Move pit complex & mate up with motor complex -Move sub to CD2-42 -Spot rig over well & level rig -lower support feet -jack floor into drilling postion. ACCEPTED RIG @ 17:00 hrs. 17:00 21:00 4.00 0 0 COMPZ RPCOM RURD P RU service lines, air, water and steam. Loaded pipe shed with 75 jts 4" DP and 8 4 3/4" DC's. RU lines from well to Tiger tank. RU line from CD2-44 to take on seawater and PT both lines. 21:00 23:30 2.50 0 0 COMPZ RPCOM PULD P PU and stood back 25 stds of 4" DP. Began to take on seawater into the its at 22:30 hrs. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Began to RU circ manifold on rig floor. NOTE: Prior to RU on well, FMC tested 7" packoff to 5,000 psi for 30 min. and tested ok. SITP 450 psi, IA 450 psi, OA 550 si. 10/05/2008 Cont. RU for well kill, killed well by bleeding tbg & annulus to -0- then pumped 450 bbls of 8.4 ppg SW around. Recovered 245 bbls for 54% returns. Monitored well 1 hr w/No press. Est circ & took 94 bbls to fill hole, Set BPV, ND tree & installed blanking plug, NU BOPE. Tested BOP's 250/3,500 psi & annular 250/2,500 si. John Cris W/AOGCC witnessed test. RU to ull 4 1/2" tb ave 90 b h losses . 00:00 01:45 1.75 0 0 COMPZ RPCOM RURD P Continue to RU for well kill - MU FMC lubricator & test to 5000 psi - Pull BPV - RD lubricator 01:45 02:30 0.75 0 0 COMPZ RPCOM SFTY P PJSM - Disscuss pressure bleed down & well kill -Well statis - Tbg pressure 450 psi - IA 450 psi - OA 550 si ~ -- _ ~~. ~;~• ; caf ~2 Time Loss __ _ _ _~ __ Date From To Dur S De th E. De th Phase Code Subcode T Comment 02:30 07:30 5.00 0 0 COMPZ WELCTL KLWL P Test lines to 2500 psi -Bleed down tbg & IA f/ 450 psi to 0 psi -Begin pumping down tbg w/ 50 bbls Safe Surf O -followed by 400 bbls 8.4 ppg seawater @ 2 bbls/min 20 psi - taking returns f/ IA to tank -Shut down pumps - 245 bbls recovered in tank f/ total of 450 bbbls pumped 54% returns 07:30 08:45 1.25 0 0 COMPZ WELCTL OWFF P Blow down lines -Monitor well for 1 hr.- Tb & IA 0 si after 1 hr 08:45 10:00 1.25 0 0 COMPZ RPCOM CIRC P Open well & pump seawater down tbg to establish static loss rate - Observed returns to tank @ 94 bbls pumped -Static loss rate 90 bbls/hr - Blow down lines & RD lines -Hook up line to IA to keep hole full -Set BPV - Be in seawater down IA 10:00 11:30 1.50 0 0 COMPZ RPCOM NUND P ND tree -pull control & balance lines for SSSV back through wellhead - Install FMC blankin lu 11:30 16:00 4.50 0 0 COMPZ RPCOM NUND P NU BOPE and drain lines. Had to modi itcher ni le. 16:00 22:00 6.00 0 0 COMPZ WELCTL BOPE P Tested BOPE tested rams, valves and manifold 250 psi low and 3,500 psi high, tested annular to 250/2,500 psi. Performed koomey test, tested with 4 1/2" test jt. Note: John Crisp with AOGCC witnessed the test. 22:00 00:00 2.00 0 0 COMPZ RPCOM RURD P RU to LD 4 1/2" completion, elevators, tongs and control line s ool. Ave 90 b h I 10/06/2008 Pulled BPV, PU on 4 1/2" Comp to 260K & pulled tbg free, LD hanger & cont. to POOH f/9,151' LD 4 1/2" comp. Installed test plug & tested rams & annular w/4" test jt, 250/3,500 psi on rams, 250/2,500 psi annular. MU Baker packer fishing/milling assembly & RIH, attempted to get grapple to latch onto pkr w/no success, be an millin on kr at 9,151' 00:00 01:15 1.25 9,151 9,151 COMPZ RPCOM PULD P MU landing jt - MU into tbg hanger - Back out lock down screws -Work tb string free -pulled 260 k -string wt. when landed was 170 k - Pull tbg han er to ri floor -PU wt. 163 k 01:15 12:30 11.25 9,151 0 COMPZ RPCOM PULD P Pull & LD 4 1/2" com_ pletion -SSSV - 3 GLM - X nipple - 207 jts 4 1/2' tbg & 8.51' of tbg pup f/chemical cut of string -Recovered 51 SS bands & 65 thermal centralizers - All tbg looked to be in ood condition - RD & LD tb a ui ment. 12:30 13:15 0.75 0 0 COMPZ WELCTL BOPE P RU and tested rams and annular with 4" test jt, tested rams 250/3,500 psi and annular to 250/2,500 si. 13:15 13:45 0.50 0 0 COMPZ RPCOM OTHR P Installed wear bushing 13:45 14:30 0.75 0 0 COMPZ FISH RURD P Installed mousehole and PU fishing BHA to ri floor. ~~t~e ~ taf'S~ l Time Low _ _ I Date From To Dur S. De th E. De th Ph se Code Subcode T Comment 14:30 17:15 2.75 0 308 COMPZ FISH PULD P MU Fishin BHA #1 RIH to 308'. 3 1/8" PRT spear (pkr ret. tool), 3.925" grapple with extensions, metal muncher rotary shoe, boot baskets, bumper sub, oil jars, 8-4 3/4" DC's with intensifier jars and pump out sub. 17:15 22:15 5.00 308 9,003 COMPZ FISH TRIP P RIH with BHA #1 from 308' to 22:15 22:45 0.50 9,003 9,151 COMPZ FISH CIRC P Washed down from 9,003' to OF at 9,151' 22:45 23:15 0.50 9,151 9,151 COMPZ FISH OTHR P Attempted to get 3.925" grapple on PRT Packer ret. tool) to latch onto kr with no success. 23:15 00:00 0.75 9,151 9,151 COMPZ FISH MILL P Be an to mill on packer at 9,151', 5-7K wob, 210 gpm, 1,100 psi, 80 rpm's with 10K ft-Ibs torque. rot wt 180K, up wt 205K, so wt 180'. Ave 70 b h losses. 10/07/2008 Mill on packer -lost torque & pump pressure while working string -POOH -Fishing tool string parted leaving 2 PRT extenstions & spear in tbg fish - MU Fishing Assembly # 2 (over shot w/grapple to catch packer body) RIH & Tag Fish @ 9156' MD -Latched On to Fish and POOH t/ 2000' MD -Sea Water Lost for Past 24 Hours = 927 Bbls, Total for Hole 4104 Bbls 00:00 04:15 4.25 9,151 9,151 COMPZ FISH MILL P Millin~on packer Cad 9151' - 3, bbls/min 430 si 04:15 05:00 0.75 9,151 -9,151 COMPZ FISH FISH T Lost torque & pump pressure while working string -attempt to engage fish - No ood 05:00 09:30 4.50 9,151 306 COMPZ FISH TRIP T POOH w/ DP & fishing /milling assembl 09:30 12:00 2.50 306 0 COMPZ FISH PULD T Handle BHA -Std back DC's -break down fishing /milling assembly - Observed 1 PRT extension had arted in the thread - leavin 2 PTR extensions & s ear inside of acker & tail i e 12:00 12:30 0.50 0 0 COMPZ FISH OTHR T Clean boot bskts Clear floor of tools - PU over shot 12:30 13:30 1.00 0 290 COMPZ FISH PULD T PJSM - MU fishin assembl #2 - over shot - MU DC's 13:30 18:00 4.50 290 8,791 COMPZ FISH TRIP T Change over to 4" DP elevators -RIH w/ fishing assembly # 2 on 4" DP f/ 290' to 8791' MD; Fill Pipe Every 20 Stds 18:00 18:15 0.25 8,791 9,156 COMPZ FISH WASH T P/U Single & Wash Down t! Fish [a) 9156' MD' 200 GPM 540 Psi 18:15 18:45 0.50 9,156 9,156 COMPZ FISH FISH T Latch on t/ Fish @ 9156' MD; P/U 275, S/O 160' Work Fish Lo 18:45 00:00 5.25 9,156 2,000 COMPZ FISH TRIP P POOH w/ Fish f/ 9156' - 2000' MD 10/08/2008 Continued to POOH w/ Fish; UD DC's, Break Out & L/D Overshot, Spear, 2 PRT Extensions, 7" Packer, Tubing, XN Nipple, RHC Plug, Gauge Package, and WLEG; R/U & Run 7" Casing Scraper; Worked Through Debris at 9067' & 9618' MD; POOH w/Scraper; R/U & Ran 4 1/2" Liner per Detail t/ 2378' MD; Sea Water Lost in Past 24 hrs = 1560 Bbls; Cumulative for Hole = 6417 Bbls 00:00 01:00 1.00 2,000 290 COMPZ FISH TRIP P Cont. POOH w/ fish f/ 2000' to 290' - --_- -°_ _ - r- i?~~e 3 of 12 i Time~co s_ - - - -- -- Date From To Dur 5 Depth E. Depth Phase Code Subcode T Comment 01:00 04:15 3.25 290 0 COMPZ FISH PULD P LD DC's -Break & LD fish & fishing too{s -Recovered the spear & 2 PRT extensions lost on milling run - Recovered acker & all of tail i e below packer (10.15' pup jt - 44.14' jt. 4 1/2" tbg - XN nipple (with RHC plug in XN nipple & gauge package screwed into btm of RHC) 2 pup jts 9.65'&5.72')&1.35'WLEG- assuming XX plug inside jt of tbg above RHC lu 04:15 04:45 0.50 0 0 COMPZ RPCOM OTHR P PU & Std back 3 std of 4" DP 04:45 06:00 1.25 0 0 COMPZ RPCOM OTHR P PU liner equpiment to rig floor - RU to run 4 1/2" liner 06:00 06:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM on running liner 06:15 07:30 1.25 0 885 COMPZ CASING RUNL P Ran 20 jt 4 1/2" liner as per detail to 880' 07:30 09:45 2.25 885 0 COMPZ CASING PUTB NP Descision made to make scraper run - POOH & LD 20 'ts liner 09:45 10:30 0.75 0 192 COMPZ RPCOM OTHR P MU scraper BHA to 192' 10:30 15:15 4.75 192 9,618 COMPZ RPCOM OTHR P RIH w/ 7" csg scraper f/ 192' to 9618' - Strin took wt. ~ 9067' & 9187' MD. - worked scra er throu h s of - OK 15:15 20:15 5.00 9,618 0 COMPZ RPCOM OTHR P POOH on TT f/9618' - 0' ; UD BHA # 3 20:15 20:30 0.25 0 0 COMPZ CASING SFTY P PJSM on Running 4 1/2" Liner w/ 5' Perforae Pu s 20:30 21:15 0.75 0 0 COMPZ CASING RURD P R/U t/ Run 4 1/2" Liner 21:15 00:00 2.75 0 2,378 COMPZ CASING RUNL P Run Liner w/ Centralizers and Perforated Pups per Detail t/ 2378' MD; P/u 95, S/O 95 10/09/2008 Continued to RIH w/ 4 1/2" Liner U 3641' MD; R/U & Ran 2 7/8" Inner String U 3558' MD; P/U Liner Hanger and Safety Release Screws Sheared During Make Up; Arranged Air Lift of Hanger U Deadhourse for Redress; Aircraft Broke in Deadhorse; Waited for Second Aircraft from Fairbanks to Deliver Hanger to Alpine; Hanger Delivered at 2330; Total Sea Water Lost for Previous 24 Hours = 1200 Bbls, Total for Well 7617 Bbls 00:00 00:45 0.75 2,378 3,641 COMPZ CASING RUNL P Continue RIH w/ 4 1/2" Liner f/ 2378' - 3641' MD 00:45 01:45 1.00 3,641 3,641 COMPZ CASING RURD P R/U t/ Run 2 7/8" Inner Strin 01:45 02:00 0.25 3,641 3,641 COMPZ CASING SFTY P PJSM on Running 2 7/8" Tubing 02:00 09:15 7.25 3,641 3,641 COMPZ CASING OTHR P RIH w/Slick Stick & 2 7/8" Tubing t/ 3558' MD (Tubing Ran Inside of 4 112" Liner 09:15 09:30 0.25 3,641 3,641 COMPZ CASING SFTY P PJSM on P/U Liner Hanger 09:30 10:00 0.50 3,641 3,641 COMPZ CASING RUNL P M/U Liner Hanger -- Hanger "Safetied Off' During Make Up Tor uin 10:00 12:00 2.00 3,641 3,641 COMPZ CASING OTHR T PJSM; UD Liner Hanger Arrange for and Trasport t/ Deadhorse for Repair - Install Canfield Bushing and TIW valve f/ Well Control Time Logs _ Date_ From To Dur S. Depth__E. Depth Phase Code Subcode_ T Comment 12:00 23:30 11.50 3,641 3,641 COMPZ CASING WOEQ T Wait On Liner Hanger f/ Dead Horse; Aircraft Broke and Antoher had to be Flown in From Fairbanks to Deliver Han er f/ Deadhorse 23:30 00:00 0.50 3,641 3,641 COMPZ CASING OTHR T UD Canfield Bushing and TIW Valve; P/U Liner Hanger & M/U Inner String Cu Ass 10/10/2008 M/U Liner Hanger and RIH on 4" DP f/ 3641' - 11823' MD; Rotated Liner while Pumping f/ 11823' - 12325' MD; Pumped 40 Bbl Hi-Vis -Lubricated Sweep w/ 50% Increase in Cuttings; Attempted to Rotate in Hole w/ Pumps but Could Not Go Down; Rotated in Hole w! Pumps Off Establishing Circulation Every Stand U 12515' MD; Hole Packed Off @ 12,515' MD; POOH & Established Circulation @ 12492' MD; Washed Down t/ 12515' MD& Circulated Hole Clean; Sea Water Lost to Hole f/ Previous 24 Hours = 1200 Bbls; Total for Hole 8817 Bbls 00:00 01:30 1.50 3,641 3,641 COMPZ CASING RUNL P MU liner han er - Mix u Pal mix & fill liner tieback -wait 30 mins. 01:30 08:45 7.25 3,641 11,351 COMPZ CASING RUNL P RIH w/ 4 1/2" liner on 4" DP f/ 3641' to 11,351' - took wt. 08:45 12:00 3.25 11,351 11,823 COMPZ CASING RUNL P Continue RIH w/ liner f/ 11,351' to 11,823' - w/ 30 rpm w/ 11,500 ft/Ibs torque -Rotated & pumped down f/ 11,813' to 11,823' - 2 bbls/min @370 si w/ 30 r m 12,000 fUlbs for ue 12:00 19:00 7.00 11,823 12,325 COMPZ CASING RUNL P Continue RIH w/ liner on 4" DP rotating & pumping f/ 11823 - 12325' + MD-30-40RPM-2 -5bbls/ min @ 370 - 1000 psi wl 12 - 13 k ft/Ibs for ue w/ < 50 % returns 19:00 20:00 1.00 12,325 12,325 COMPZ CASING CIRC P Pump 40 Bbl Hi Vis /Lubricated Sweep Staging Pumps Up t/ 6 BPM @ 1500 Psi; Sweep Returned Cuttin s In 20:00 20:45 0.75 12,325 12,325 COMPZ CASING RUNL P Attempt to Rotate in hole w/ Liner @ 3 BPM - 400 Psi; Could Not go Down w/ Pum s On 20:45 22:00 1.25 12,325 12,515 COMPZ CASING RUNL P Rotate Liner in Hole f/ 12325 - 12515' MD W/O Pumps Keeping Hole Full via Hole Fill Pump; Torque 12.5, RPM 40, WOB 3-5; Established Circulation at Each Stand; Hole Packed Off 12515' MD 22:00 22:45 0.75 12,515 12,515 COMPZ CASING OTHR T POOH t/ Establish Circulation @ 12492' MD; Wash Down U 12515' MD Staging Pumps Up t/ 5 1/2 BPM 1500 Psi 22:45 00:00 1.25 12,515 12,515 COMPZ CASING CIRC P Circulate Hole Clean @ 12515' MD; Worked Liner Hanger Through Dirty S ot; 5 1/2 BPM 1550 Psi 10!11!2008 Continued to RIH w/ Liner, Made Connection @ 12968' MD and Liner Stuck; Worked Pipe Free & Noted 15K Less Rotating Weight and 2K Less Torque -Suspect Liner Hanger Released or Parted String; Dropped Ball to Set Liner Hanger; P/U t/ 275K to Confirm Hanger Release -Not Released; P/U t/ 100K Overpull to Shear Release Hanger; POOH U 3790' MD -Hanger and Liner Still Attached; UD Hanger; Attempt to Pull 2 7/8" Inner String but String Pulls Against Something in 4 1/2" Liner; Pull 4 1/2" Liner w/ 2 7!8" Tubing Concurrently - Breaking Out 4 1/2" Liner and Cutting 2 7/8" Tubing then UD Both; Sea Water Lost To Formation for Previous 24 Hours = 960 Bbls; Total Sea Water Lost to Hole 9777 Bbls ~ Page 5 of ~ 2 Time Logs _ _ _ ___ Date From To Dur 5 D th E. De th Phase Code Subcode T Comment __ 00:00 04:45 4.75 12,515 _ 12,968 COMPZ CASING RUNL P _ Cont. RIH w/ 4 1/2" liner on 4" DP - rotating @ 40 rpm's w/ 11 k ft/Ibs torque & pumping @ 4 bbls/min @ 790 psi -Made connection @ 12,968' - Unable to rotate - i e stu k 04:45 08:15 3.50 12,968 12,968 COMPZ CASING OTHR T Work pipe free - 15 k less rotating wt. & 2 k fUlbs less torque -Trouble shoot -String either parted or liner runnin tool released- Notified en ineers in town 08:15 09:45 1.50 12,968 12,968 COMPZ CASING OTHR T Drop liner hanger setting ball & pumped down -Pressure up to 2600 psi to set liner han er -slack off w/ 75 k to set slips -Take pull on string -pulled up to 275 k to confirm that liner hanger running tool had not released -assuming string has arted below liner han er 09:45 12:00 2.25 12,968 11,478 COMPZ CASING OTHR T Pulled 100 k over PU wt. to shear release liner hanger - POOH f/ 12,968'to 11,478' 12:00 17:00 5.00 11,478 3,790 COMPZ CASING OTHR T POOH on TT f/ 11478' - 3790' MD; Liner Hanger and Liner Attached; P/U 130, S/O 90 17:00 17:15 0.25 3,790 3,790 COMPZ CASING SFTY T PJSM on UD Liner Hanger Assembly - Inner strrng of 2 7/8" Fox stuck inside 4 1/2" liner 17:15 18:30 1.25 3,790 3,758 COMPZ CASING OTHR T UD Liner Hanger 18:30 20:45 2.25 3,758 3,758 COMPZ CASING OTHR T Tried to Pull 2 7/8" Inner String; Tubing Hung Up Down Hole; Attempted to Rotate and Pull - No Fix; Called Town and Discussed O tions 20:45 21:00 0.25 3,758 3,758 COMPZ CASING OTHR T PJSM on Pulling 4 1/2" Liner and 2 7/8" Liner Simultaneously then Cuttin 2 7/8" Tubin to UD Liner 21:00 00:00 3.00 3,758 3,375 COMPZ CASING OTHR T Pull 4 1/2" Liner and 2 7/8" Liner; Breaking 4 1/2" Liner Joints Pulling Up and Cutting 2 7/8" Tubing to UD Tubin and Liner 10/12/2008 POOH LD 4 1/2" liner & 2 7/8" inner string (18 jts 4 12P' w/ 2 7/8" inner string inside) -Inner string came free - Pullled & LD 67 jts 2 7/8" inner string -Unable to pull inner string -Cont. to pull 4 1/2" & cutting 2 7/8" inner string & LD -Pulled 4 1/2" Liner Freely After inner String UD -Recovered 82 Jts 4 1/2" Liner, Packoff Nipple & Drill in Shoe -Cleared Rig Floor of Tubing/Liner Equipment -Pulled Wear Ring -Started BOPE Test w/ Annular Preventer t/ 250 / 2500 Psi and Choke & IBOP t/ 250 / 3500 Psi -Total Sea Water Lost to Hole f/ Previous 24 Hours = 840 Bbls; Total for Hole 10617 Bbls 00:00 05:30 5.50 3,375 2,830 COMPZ CASING OTHR T Cont. to pull 4 1/2" liner -cutting 2 7/8" inner string & laying down 4 1/2" w/ 2 7/8" inner string inside (18 jts.) Inner string came free Note: found 2 torque rings badly dama e 05:30 11:00 5.50 2,830 2,830 COMPZ CASING OTHR T RU -Pull & LD 67 jts. of 2 7/8' inner string f/ 2830' to 744' -Inner string stuck a ain -unable to work free page ~ of 12 J Time Logs _~ _ Date From To Dur S De th E De th Phase Code Subcode T Comment 11:00 17:00 6.00 2,830 2,100 COMPZ CASING OTHR T Cont. to pull 4 1/2' liner & cutting 2 7/8" inner string & LD together f/ 2830' to 2100' (LD 33 jts total of 4 1/2" line w/ 2 7/8" cut off inner string inside 17:00 20:15 3.25 2,100 0 COMPZ CASING OTHR T POOH on TT w/ 4 1/2" Liner, Packoff Nipple, and Drill In Shoe; All Liner Comonents Present 20:15 21:30 1.25 0 0 COMPZ CASING OTHR T P/U & Break Out Liner Swivel and Canfield Bushing f/ 1st Joint of Liner then UD 2 7/8" Inner String from Inside Liner Joint 21:30 22:00 0.50 0 0 COMPZ CASING OTHR T Clean & Clear Rig Foor of 15 Perforated Pup Joints, 25 Centralizers, Casing Tongs, and Elevators 22:00 22:30 0.50 0 0 COMPZ WELCTL SFTY P PJSM on BOPE Test 22:30 23:00 0.50 0 0 COMPZ WELCTL OTHR P Pull Wear Ring; Set Test Plug & R/U t/ Fill Hole from Backside During BOPE Test 23:00 00:00 1.00 0 0 COMPZ WELCTL BODE P Test BOPE -Annular Preventer 2501 2500 Psi; Test Choke and IBOP's t/ 250 / 3500 Psi 10/13/2008 Completed BOPE Test; M/U & RIH w/ BHA #4 (Clean Out) t/ 13048 -Packed Off; Circulated Bottoms Up @ 3150', 6006', & 11337' MD; Pumped Hi-Vis Sweeps @ 9620' & 12767' MD; Pumped Out of Hole t110956' MD - Worked Thorugh Tight Spots @ 11900', 11130', & 11040' MD; Total Sea Water Lost to Formaion for Previous 24 hours = 840 Bbsl; Total for Hole 11457 Bbls Chuck Scheve of AOGCC Waived Witnessin Test 00:00 03:00 3.00 0 0 COMPZ WELCTL BOPE P Continue to Test BOPE as Follows; Choke Valves 1-16, Auto & Manual IBOP, Dart, TIW, HRC & Manual Choke & Kill Valves; 4" Kill Valve; Blind Rams & Upper and Lower Variable Rams w/ 4" & 4 1 /2" Teat Joints t/ 250 / 3500 Psi; Performed Koomey Test - 30 Sec f/ 200 Psi / 2:42 for Full Chage; John Crisp of AOGCC Waived Witnessin the Test 03:00 03:30 0.50 0 0 COMPZ WELCTL OTHR P Remove Test Joint & Install Wear Rin 03:30 04:30 1.00 0 293 COMPZ RPCOM RURD T P/U & M/U Clean Out BHA as Follws; Bit, Bit Sub, IBS, NMFDC, IBS, 2 - NMFDC's, XO, 1 Stand HWDP, Jars, 2 Jts HWDP 04:30 06:45 2.25 293 3,150 COMPZ RPCOM TRIP T Single in Hole d/ 4' DP f/Shed U 3150' MD 06:45 07:15 0.50 3,150 3,150 COMPZ RPCOM CIRC T Circ @ 3150' MD; 227 GPM @ 370 Psi 07:15 09:00 1.75 3,150 6,006 COMPZ RPCOM TRIP T Coninue to RIH w/ DP f/Shed then Derrick t/ 6006' MD 09:00 09:30 0.50 6,006 6,006 COMPZ RPCOM CIRC T Circ @ 6006' MD; 227 GPM @ 520 Psi 09:30 11:00 1.50 6,006 9,620 COMPZ RPCOM TRIP T RIH w/ Dp f/ Derrick t/ 9620' MD P~~;e 7 0# 12 Time Logs. _ ~ ~- ---- Date From To Dur S De th E. th Phase Code Subcode T Comment 11:00 12:30 1.50 9,620 9,620 COMPZ RPCOM CIRC T Pump 40 Bbl Hi-viscosity Sweep @ 9620' MD; 227 GPM @ 700 Psi w/ 80 RPM 12:30 14:30 2.00 9,620 9,620 COMPZ RIGMNT SVRG P Slip & Cut 60' Drill Line; Service Top Drive, Ad~ust Draw Works Brakes 14:30 15:30 1.00 9,620 11,337 COMPZ RPCOM TRIP T RIH in Open Hole t/ 11337' MD; P/U 255, S/O 150 15:30 17:00 1.50 11,337 11,337 COMPZ RPCOM CIRC T Circ @ 11337' MD; 225 GPM @ 720 Psi; RPM = 80; Torque = 12; P/U 250, S/O 150, Rot 175 17:00 18:00 1.00 11,337 13,048 COMPZ RPCOM TRIP T Rlh w/ 4" DP f/ Derrick t/ 13030' MD - Lost Down Weight -Established Circulation and Worked Down t/ 1 ' MD - Packe ff 18:00 20:15 2.25 13,048 12,767 COMPZ RPCOM CIRC T Circ 45 Bbl Hi-Vis Sweep @ 13030' MD; 225 GPm @ 830 Psi; RPM = 80; Stand Back 1 Stad Every 45 minutes 20:15 23:00 2.75 12,767 11,051 COMPZ RPCOM TRIP T Pump Out of Hole f/ 12767' - 11051' MD; 126 GPM @ 290 Psi; P/U 255, S/O 140 Work Throu h Ti ht S ots 11900' 11130'MD 23:00 00:00 1.00 11,051 10,956 COMPZ RPCOM CIRC T Circ 20 Bbl Sweep & Work Pipe f/ 11051' -10956' MD; Worked through Tight Spot @ 111040' MD; 225 GPM @ 630 Psi; RPM = 70; Torque = 12; P/U 255, S/O 140, Rot 170 10/14/2008 Completed Circualting Hi-Vis Sweep and Pumped Out of Hole to 7" Casing Shoe; Circulated Hi-Vis Sweep and POOH on Trip Tank t! the Clean Out BHA; UD Clean Out BHA; Rigged Up and Ran 4 112" Liner w! Perf Pus er Detail t/ 11623' MD 00:00 00:30 0.50 10,956 10,956 COMPZ RPCOM CIRC T Coninue to Circulate 40 Bbl Hi-Vis Sweep - 227 GPM @ 600 Psi; RPM = 70 00:30 03:00 2.50 10,956 9,620 COMPZ RPCOM TRIP T OWFF (Hole Taking Fluid); Pump Ou of Hole f/ 10956' - 9620' MD - 189 GPM 400 Psi 03:00 04:15 1.25 9,620 9,620 COMPZ RPCOM CIRC T Circ 40 Bbl Hi-Vis Sweep - 227 GPM 550 Psi; RPM = 80 04:15 08:30 4.25 9,620 293 COMPZ RPCOM TRIP T OWFF (Taking Fluid); Drop Rabbit and POOH on TT f/ 9620' - 293' MD 08:30 09:00 0.50 293 0 COMPZ RPCOM PULD T Stand Back HWDP, NMFDC's, & UD Raminder of Clean Out BHA 09:00 10:00 1.00 0 0 COMPZ CASING RURD T Bring Perf Pups to Rig Floor; R/U t/ Run 4 1/2" Liner 10:00 10:15 0.25 0 0 COMPZ CASING SFTY T PJSM on Running 4 1/2" Liner 10:15 17:30 7.25 0 3,512 COMPZ CASING RUNL T RIH w/ 80 Jts of 4 1/2" Blank Liner and 15 Perf Pu s t/ 3512' MD 17:30 19:00 1.50 3,512 3,532 COMPZ CASING OTHR T P/U and M/U Liner Hanger; Mix Pal Mix and Cure; P/U 105, S/O 105, Rot 105; Torque 3500 @ 30 RPM; Circ 168 GPM 40 Psi 19:00 22:30 3.50 3,532 9,620 COMPZ CASING RUNL T RIH w/ 4 1/2" Liner on DP f/ Derrick t/ 9620' MD; P/U 195, S/O 150, Rot 170; Tor ue 6500 30 RPM E.._.-. Page ~ ~,~ ~2 i • Time Logs _ _ __ _ Date From To Dur 5. De th E. De th Phase Code Subcode T Comment 22:30 00:00 1.50 9,620 11,623 _ COMPZ CASING RUNL T RIH w/ 4 1/2" Liner on DP t/ 11623' MD; fill Pipe Every 20 Stands; P/U 212, S/O 150 10/15/2008 RIH & Land Liner @ 12965' MD; Drop Ball and Set Hanger; Attempt to Release Liner Hanger -Pressured up and Liner Released as Designed; Attempt to Pull Liner Work String -String Stuck at RS Packoff Nipple; Received Permission from Town to Overpull & Fail Work String; Applied 160K Overpull and Inner String Would not Release -Applied 16K Torque, Pulled 160K Over and Liner Hanger Released w/ Liner Still Attached; POOH w/ Liner Hanger and Liner - UD Liner Hanger; Cut Clam Shell Piece to Open RS Nipple and Determine Failure -Failed Due to Junk Behind RS Packoff Assembly; After Discussions w/ BOT & CPAI Reps Decided to Send New Liner Han er back to Prudhoe Sho for Reconfi uration 00:00 00:45 0.75 11,623 12,193 COMPZ CASING RUNL T Continue to RIH w/ Liner on DP f/ 11623' - 12193' MD 00:45 02:00 1.25 12,193 12,965 COMPZ CASING RUNL T Work & Rotate Liner Down Through Ti ht Spots f/ 12193' - 12478' MD & 12573' - 12669' MD; Then RIH w/ Liner on Elevators t/ Set Depth of 12965' MD Drill Pi a Measurement 02:00 02:45 0.75 12,965 12,965 COMPZ CASING RUNL T Pum Down Ball to Set Liner Hance - Pressure Up U 2600 Psi to Set Hanger Slips then Pressure Up to 4000 Psi to Release Han er 02:45 06:00 3.25 12,965 12,965 COMPZ CASING OTHR T Attempt to Pull Free of Hanger by Pulling 50 K Over and Working Pipe for Entire Stroke Length -Unable to Pull Out of Hanger; Liner Hanger Work String Pack-Off (Stuffing Box) Han in U Inside Liner 06:00 09:00 3.00 12,965 12,965 COMPZ CASING WOOR T Waitng on Decision from Anchorage Before Proceedin 09:00 14:00 5.00 12,965 12,965 COMPZ CASING OTHR T Attempt to Pull liner Running Tool Through Liner; Work Up and Down w/o Rotating Pulling Up to 160K Overpull - No Effect; Applied 16K Ri ht Hand Torque to String and Pulled A ain -Han er Released 14:00 19:00 5.00 12,965 3,533 COMPZ CASING OTHR T POOH w/ DP and Liner t/ 3533' MD; Hanger Appears to Still Be En aged w/ Liner Weight Indicator Indicated 35K Over Drill Pipe Weight & Matches Liner Runnin Numbers 19:00 19:45 0.75 3,533 3,525 COMPZ CASING OTHR T Change to 3 1/2" Elevators and Pull Liner Hanger Above RKB; Liner Running Tool String Still Lodged in Liner b "RS" Retrievable to ing Box Retractable "Dogs" -All Liner Han er Parts re u o e o e 19:45 23:00 3.25 3,525 3,525 COMPZ CASING WOOR T Cut Clamshell Section o Pack Off Nipple to Determine Failure Mode; Liner Hanger failed due to Junk Behind RS Pack Off Assembly - Discussed Findings with Anchorage Based Engineers and BOT Reps; Decision Made to Reconfigure Liner Hanger w/ 4" PBR w/ Packoff and Solid Float -Send New Hanger to Prudhoe for Reconfi Time Logs _ _ Date From To D _ ur S De th E. De th Phase Code Subcode T Comment _ 23:00 00:00 _ 1.00 3,525 3,525 COMPZ CASING WOEO T Transport Hanger to Prudhoe via DC-6; Wait for Hanger to Return - Estimated Turn Time 12 hours 10/16/2008 Waited on Liner Hanger Reconfiguring and Transport Back to Alpine -Monitored Hole on the Trip Tank - Taking 25 Bbls/hr; Ran In Hole w/ Reconfigured Liner Hanger and Set Liner w/ Tail @ 12965' MD -Top of Liner @ 9430' MD (DP Measurement); Pumped Ball and Released Hanger; Pull Liner Hanger Work String Through Liner; Sea Water Lost to Hole for Previous 24 Hours is 587 Bbls -Total for hole is 13471 Bbls 00:00 15:00 15.00 3,525 3,525 COMPZ CASING WOEQ T Wait On Liner Hanger Reconfigure - 15:00 15:15. 0.25 3,525 3,525 COMPZ CASING SFTY T PJSM for M/U & Running Liner Han er and Liner 15:15 16:15 1.00 3,525 3,541 COMPZ CASING OTHR T P/U and M/U New Liner Hanger; Mix and Apply Pal-Mix and Cure f/ 30 Minutes 16:15 20:45 4.50 3,541 9,632 COMPZ CASING RUNL T RIH w/ 4 1/2" Liner on DP Filling Pipe Every 20 Stands; Take Base Line Torque and Drag Numbers at Shoe - P/U 195, S/O 145, Rot 170 - Torque @ 30 RPM = 6500; Circ 3 BPM 240 Psi 20:45 23:00 2.25 9,632 12,965 COMPZ CASING RUNL T Run Liner in Open Hole t/ Set Depth of 12965' MD' Worked Through Sticky Spot @ 11347' MD; P/U 215, S/O 145 23:00 00:00 1.00 12,965 9,440 COMPZ CASING OTHR T Circulate Ball Down and Set Liner Hanger in Tension w/ 2600 Psi -Set Down to Block Weight and Pulled Up t/ 250 K to Set Slips; Increase Pressure t/ 3700 Psi to Release RS Setting Tool -Circ Sub Released at Same Pressure; Liner Set w/ Tail @ Depth of 12965' MD and Top @ 9430' MD Drill Pi a Measurement 10/17/2008 POOH w/ Liner Running Tool; P/U & RIH w/ Fishing Tools t! 9426' MD; Circulate Hi-Vis Sepp to Clean Casin ;Cut & Sli Drill Line; POOH w/ Fishin Tools; RIH w/ 4 1/2" Com letion Tubin er Detail 00:00 04:00 4.00 9,440 0 COMPZ CASING OTHR P POOH on TT w! liner Running Tool 04:00 05:00 1.00 0 0 COMPZ FISH PULD X PJSM & P/U Fishing String as Follows; Bit, Boot Basket, Bit Sub, Magnet, Double Pin, Boot Basket, 7" Casing Scraper, Bit Sub, Magnet, XO 05:00 07:45 2.75 0 9,371 COMPZ FISH TRIP P RIH w/ Fishing BHA U 9371' MD 07:45 09:00 1.25 9,371 9,426 COMPZ FISH WASH P Wash Down t/ 9426' MD; Pump Hi-Vis Swee 420 GPM 2150 Psi 09:00 10:30 1.50 9,426 9,426 COMPZ RIGMNT SVRG P Cut & Slip 60' Drill Line & Service To Drive 10:30 15:00 4.50 9,426 0 COMPZ FISH TRIP P POOH on Trip Tank w/ Fishing BHA 15:00 15:30 0.50 0 0 COMPZ FISH PULD P UD Fishing BHA 15:30 16:00 0.50 0 0 COMPZ FISH OTHR X Clean Clear Rig Floor of Fishing Tools 16:00 16:30 0.50 0 0 COMPZ RPCOM RURD P Pull Wear Ring and Set Tubing Wear Rin 16:30 17:15 0.75 0 0 COMPZ RPCOM RURD P P/U & R/U Tubing Tongs, Elevators, Sli s, Floor Safet Valve, etc. ~~ge 1~ csf 1~ Time Logs _ ___ _ _ __ `Date From To Dur S De th E. D th Phase Code Subcode T Comment 17:15 _ 17:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM on Running Upper Completion 17:30 23:30 6.00 0 7,408 COMPZ RPCOM RCST P RIH w/ 169 Jts 4 1/2" Tubing, Wire Line Entry Guide, XN Nipple~Premier Packer, 1-GLM w/ DCK Shear Valve, 2-GLM's w/ Dummy Vavles & M/U SSSV to Strin ; P/U 147, S/O 122 23:30 00:00 0.50 7,408 7,408 COMPZ RPCOM RURD P P/U SLB SSSV Control Line Spools and R/U to Test & Run 10/18/2008 M/U SSSV & Control Lines the Test t/ 5000 Psi; RIH & Space Out Completion Tubing - No Go Spaced Out 3.4' Above Liner Hanger w/ Tail @ 9437.5' MD; Land Tubing in Spool; Nipple Down BOPE Stack and Nipple Up Tree; Terminate Control Lines Through Well Head; Test Tree t/ 5000 psi; Spot Inhibited Brine Across Packer t/ Lower GLM; Set Packer; Test Tubing t/ 4000 Psi f/ 30 minutes (Good); Test Packer & 7" Casing t/ 3500 Psi f/ 30 Minutes (Good); Shear Open GLM; Displace Well Fluids w/ 136 Bbls of Inhibited Brine Followed by 169 Bbls of Diesel; Set TWC; Total Sea Water Lost to Formation for Previous 24 Hours = 624 Bbls -Total Lost to Hole thi Well = 14,815 Bbls 00:00 01:00 1.00 7,408 7,408 COMPZ RPCOM DHEQ P M/U SSSV Control Lines & Test t/ 5000 Psi f/ 10 Minutes 01:00 03:15 2.25 7,408 9,321 COMPZ RPCOM RCST P Continue to Run Completion Tubing w/ Dual Control Lines and 51 Stainless Steel Bands U 9321' MD; P/U 175, S/O 130 03:15 04:00 0.75 9,321 9,430 COMPZ RPCOM HOSO P P!U 4" DP Elevators and M/U Crossover and 2 Stands of 4" DP; Tag TOL @ 9430' MD; Stand Back DP and Change Elevators; Calculate S ace Out 04:00 04:30 0.50 9,430 9,430 COMPZ RPCOM RCST P M/U 4 1/2" Pup Jts & 1 Full Jt of Tubin 04:30 04:45 0.25 9,430 9,430 COMPZ RPCOM SFTY P PJSM on Pulling Wear Ring and Landin Tubin 04:45 05:30 0.75 9,430 9,430 COMPZ RPCOM RCST P Change Elevators; P/U Landing Joint "B' ;Pull Wear Ring; Change Elevators and RIH w/ Final Tubin Jt 05:30 08:00 2.50 9,430 9,430 COMPZ RPCOM DHEO P M/U Tubing Hanger and Terminate Control Lines & Test t/ 5000 Psi; Drain Stack; Blow Down Choke & Kill Lines; Land Tubing and RILDS; Tubin Tail 9437.50 08:00 09:45 1.75 9,430 9,430 COMPZ RPCOM DHEO P Install TWC / R/U and Test Hanger t/ 5000 Psi; R/D Test E ui ment 09:45 10:00 0.25 9,430 9,430 COMPZ WELCTI OTHR P UD Mouse Hole 10:00 10:15 0.25 9,430 9,430 COMPZ WELCTL SFTY P PJSM on N/D BOPE Stack 10:15 12:00 1.75 9,430 9,430 COMPZ WELCTI NUND P N/D BOPE Stack; Terminate Control Lines Throu h Well Head 12:00 16:15 4.25 9,430 0 COMPZ RPCOM SFEO P N/U Tree; Test Tree Seals t/ 5000 Psi; Found Leak on Top Swab Valve (Change Out) Test Tree t/ 5000 Psi Good 16:15 17:00 0.75 0 0 COMPZ WELCTI OTHR P Pull TWC 17:00 17:30 0.50 0 0 COMPZ RPCOM RURD P R/U t/ Displace Well 17:30 17:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM on Displacement ~ P~rta 1 `I rai 12 ~ l ~ r1 Time Logs Date From i To __ Dur 5 D e th E. De th Ph e Code Subcode T Comment 17:45 19:00 1.25 _ 0 0 COMPZ RPCOM CIRC P Pressure Test Lines U 2500 Psi; Pumped 30 Bbls Inhibited Brine w/ Dowell @ 3 BPM & 350 Psi; Then Pump 144 Bbls Sea water w/ Rig Pum s 3 BPM & 240 Psi 19:00 19:15 0.25 0 0 COMPZ RPCOM SFEO P R/U Lubricator and Drop 1 7/8" Ball & Rod 19:15 19:30 0.25 0 0 COMPZ RPCOM SFEQ P Pressure Test Surface Lines U 4500 Psi 19:30 19:45 0.25 0 0 COMPZ RPCOM PACK P Pressure Up U 4000 Psi U Set Packer 19:45 20:15 0.50 0 0 COMPZ RPCOM DHEQ P Complete Tubing Test; Hole 4,000 Psi f/ 30 Minutes Good 20:15 21:15 1.00 0 0 COMPZ RPCOM DHEQ P Bleed Pressure Across Manifold U Annulus to Drop Tubing Pressure U 2000 Psi; Line Up & Pump Down Annulus U 3500 Psi and Hold f/ 30 Minutes to Test Packer (Good); Bleed Down Annulus and Tubing to 0 Psi; Pressure Up Annulus U 2500 Psi to Shear Open GLM (Good); Bleed Down Tubing /Annulus & Line U to Dis lace Well 21:15 23:00 1.75 0 0 COMPZ RPCOM CIRC P Circulate Conventionally to Displace Well Bore Fluids w/ 136 Bbls Inhibited Brine Pumped @ 3 BPM & 940 Psi followed by 169 Bbls of Diesel Pumped @ 3.5 BPM & 1150 Psi for Freeze Protectin 23:00 23:30 0.50 0 0 COMPZ RPCOM RURD P Purge & Blow Down Lines ; R/D Dis lacement Manifold 23:30 00:00 0.50 0 0 COMPZ WELCTL OTHR P R/U Lubricaor & Set BPV .~ 10/19/2008 UD 4" DP for Move U CD2-465; Install Wind Walls; Release Rig @ 0800 00:00 08:00 8.00 0 0 DEMOB MOVE DMOB P UD 4" DP f/ Move -Install Wind Walls -Disconnect High Line Power - Release Ri 0800 Psge 1 ~ ~f ~ 2 • ~LASS~ OII, A1QD Gds co~s~RV~r~ox cornr~ssaoH Liz Galiunas Drilling Team Lead ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 °-' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~ ~~ Re: Colville River Field, Alpine Oil Pool, CD2-42 Sundry Number: 308-330 ~d Dear Mr. Galiunas: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Daniel T. Seamount, Jr. ~~~ (` Chair DATED this ~~ day of September, 2008 Encl. STATE OF ALASKA AJ ~~ ~~"°~ ~~"~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~'%~ ~'~ ~~4 ~'~; ~ f APPLICATION FOR SUNDRY APPROVAL "°~'~,,, f4 `~~~p~ 20 AAC 25.280 -~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver '~,-., `C1l~s-Other ^ ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ f'dsa fi4'~~f Time Extension ^ i"1/1 Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 201-067 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20374-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S NO ~ CD2-42 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): 380075 RKB 52' AMSL Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13138' 7397 918T Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16" 114 114 SURFACE 2544 9-5/8" 2581 2376 PRODUCTION 9596 7" 9633 7273 OPEN HOLE 9192 4-1/2" 8229 7169 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 sz2s' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER'S3' PACKER pkr- 9153' no SSSV no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat September 28, 2008 Oil 0 Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Represeritative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: L. Galiunas 265-6247 Printed Name Chi Alvord Title: Drlling Team Lead Signature Phone 265-6021 Date p9_~~-,Q g ~, jo Co mmission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ,,,~~ ~.33~>~' Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ ~~ ~ S ( 1~~ ~ S'~` G~z p `GR \ S BFI. ~F~ ~ ~ ~aoa Subsequent Form Required: APPROVED BY ~~~~ A~*nve~ ~y: MISSIONER THE COMMISSION Date: Form 10-403 R~sed 06/2006 U ~ ~ ~ V ~ ~ ~ f ~ ~.. Submit in Duplicate • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing Repair well ~ ~ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^~ Peroorate New Pool ^ Re-enter Susg~nded Well ^ 2. Operator Name: 4. Current Well Class: 5. Pe it to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 201-067, 301-142 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20374 ' 7. KB Elevation (ft): 9. Well Name nd Number: 15.9' MSL & 52.3' RKB AMSL CD2-42 ' 8. Property Designation: 10. Field! ools(s): 380075 Alpine Oil Pool ' PRESENT WELL CONDIT IONS MMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): ffective Depth TVD (ft): Plu (measured) Jun .'~ /~ 13138. 7346 13138 7346 10 Casing Length Size MD ND t Collapse Structural Conductor 77 16" 114 114 ~~~ ska Dli ~ ~~~ ion • Gammission Surface 2544 9.625" 2 1 2376 nC 5r~~ 2020 .Intermediate 9596 7" 9633 7273 Production 9192 4.5" 9229 7169 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 L-80 9192 Packers and SSSV Type: Packers nd SSSV MD (ft) : S3 Permanent & WRDP-2 SSSV S3: 9 3' MD &SSSV: 2046' MD 12. Attachments: Description Summary of Proposal Q 13. ell Class after proposed work: Detailed Operations Program Q BOP Sketch ^ E !oratory ^ Develo ent ~ Service ^ 14. Estimated Date for .Well Status after proposed work: Commencing Operations: 9!30/2008 Oil 0 Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my nowledge. Contact L. G 'unas Printed Name C. AlVOrd Alpine Drilling Team Leader Signature Phone 265-6120 Date fs_~ 5 jl z~iOMMISSION USE ONLY Conditions of approval: Notify Commission so that a r presentative may witness Sundry Numb ~~~ ~ ~ ~• Plug Integrity ^ BOP Test ^ Mech ical Integr y~~qt ^ a C~"L`dt1 ~ ce ` / ^ Other: ~ _~~.._~~_,~~•, ~ ___.. _ .__. Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: li ~,~ ~ ~ Q~IGE[~AL ~~'/,,i I~ Form 10-403 Revi 7/2005 ~ SU6MIT IN A1%E • Workover Procedure Pre_rig 1. Coil Tubing attempt to move fish down to packer or below. (work completed as of 9-15-08) 2. Dummy GLM's. Load IA w/ seawater & PT IA 2500 psi. 3. Pull DV @ 8993' RKB. 4. Since fish moved downhole to packer, chem cut tubing @ 9148' RKB. Middle of 10' pup joint. 5. Install BPV prior to MIRU. Procedure with Doyon 19 1. MIRU Doyon 19 2. Pull BPV. Kill well with seawater, taking returns to tank. Set BPV. 3. ND wellhead. NU BOPE. Perfrom standard BOPE Test to 3500 psi. 4. Pull and lay down 4-1/2" tubing. 5. RIH with 6.125" smooth OD x 4.875" ID burn shoe, 5.75" 18# wash pipe, boot baskets, 4.75" DC's and pump-out sub on workstring. Mill down through collars, if necessary, and top slips of S-3 packer. POOH. 6. RIH w/ guide shoe, overshot w/ grapple &packoff, bumper jar, oil jar, DC's, accelerator & pump-out sub on workstring. Engage tubing stub. Pull & jar as necessary to remove fish. POOH, lay down fish. 7. RIH w/ 4.5" shoe, shoe joint and packoff bushing on 4000' of 4.5"IBTM liner w/ pert subs spaced 200' apart. Hang liner on slips. 8. RIH w/ 20' seal stick on 2.875" Hydril 511 inner string and stab into packoff bushing. 9. PU Flex-lock hanger & setting tool and make-up to inner string & liner. 10. RIH w/ liner assembly on workstring to TD @ 13130' MD. Set Flex-lock hanger. POOH, lay down 2.875" workstring. 11. RIH w/ WLEG, 3.813" XN nipple w/ RHC plug, Premier packer, GLM's w/ SOV & SVLN on 4-1/2" production tubing. 12. Tag WLEG in Flex-lock hanger. Space out and land completion. Displace IA w/ seawater containing corrosion inhibitor. ~ 3. Drop ball/rod & s ren- 14. ND BOP. NU and press 15. Freeze protect well w/ dig 16. F~DMO Doyon packer. PT 00 psi. Shear SOV. ~ ~Qj c ~ tes eflhead. ~~SC S~QS V~UCsL'C~~ ~~~~~~ • Current well Schematic: Colville River Field CD2-42 Production Well Completion Plan 16" Conductor to 114' Updated 9-15-08 Post SL work 4-1 /2" Camco BAL-O SSSV Nipple (3.812" ID) at 2000' TVD=2081' 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 @ 2581' MD / 2376' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) Packer Fluid mix: 9.6 apo KCI Brine with 2000' TVD diesel cap Tubing Suoended with diesel to lowest GLM Comaletion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 2076' 1991" 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 3940' 3379' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7068' 5680' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 8994' 7046' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 9098' 7102' 4-1/2" tubing joint (1) Baker S3 Packer 9154' 7131' 4-1/2" tubing joint (1) HES "XN" (3.725" ID)-63.6 deg 9211' 7159' 4-1/2" 10' pup joint WEG (+/- 64.1 deg) 9228' 7168' KBG-2 GLM (3.909" ID) Fish at 9187- RCH & ~ gauge package TOC @ +/- 8872' MD {500' MD above top Alpine) ., ~, Baker S3 Packer at +/- 9154' Top Alpine at 9372' MD / 7256' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9633' MD / 7273' TVD @ 87.9° Well TD at 13138' MD / 7397' TVD ac79.2° inc ° Planned Post Workover Completion Schematic: Colville River Field CD2-42 Production Well Completion Plan 16" Conductor to 114' Updated 9-15-08 4-1 /2" Camco BAL-O SSSV Nipple (3.812" ID) at 2000' TVD=2081' 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 @ 2581' MD / 2376' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) 1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) KBG-2 GLM (3.909" ID) (500' MD above top Alpine) 'lliilii Baker S3 Packer at +/- 9125' Top Alpine at 9372' MD / 7256' TVD Packer Fluid mix: 9.6 oog KCI Brine with 2000' TVD diesel cap Upa er Completion MD TVD 1) Tubing Hanger 32' 32' 2) 4 ''/i' 12.6 #/ft IBT-Mod Tubing (2) 3) 4'/:" 12.6 #/ft IBT-Mod SPACE OUT PUPS 5) 4-'/z" 12.6#/ft L-80 IBTM Tubing 6) Camco BAL-O SSSV (3.812") 2046' 1967' 7) 4?/z" 12.6#/ft L-80 IBTM Tubing 8) Camco KBG GLM (3.938" ID) w/dummy 3969' 3400' 9) 4?'/z" 12.6#/ft L-80 IBTM Tubing 10) Camco KBG GLM (3.938" ID) w/dummy 6961' 5600' 11) 4'/z" 12.6#/ft L-80 IBTM Tubing 12) Camco KBG GLM (3.938" ID) w/DCK2 shear 9075' 7090' 13) 4?/2" 12.6#/ft L-80 IBTM Tubing (1) 14) Baker 4.5" X 7" Premier Packer 9125' 7115' 15) 4 ''/z" 12.6#/ft L-80 IBTM Tubing (2) 16) HES "XN" (2.75" min ID) Cal 68° 9225' 7166' 17) 4?/z" 12.6#/ft L-80 IBTM Tubing (6) 18) 4-'/," 12.6#/ft L-80 IBTM with mule shoe WLEG sub 9465' 7251' bottom, 3' above Top of liner @ 9480' Lower Completion: Top MD TVD 19) Baker 5"x7" Flexlock Liner Hanger w/setting sleeve (150' up from shoe) 9483 7255' 20) 4 '/z" 12.6#/ft L-80 IBTM Tubing with Torque rings 21) 4-''/z" 12.6#/ft L-80 IBTM Tubing with 5' Perforated pups 1 every 4 joints. (with torque rings) 22) Security Drill Shoe 13128' 7346' 7" 26 ppf L-80 BTC Mod Production Casing @ 9633' MD / 7273' TVD @ 87.9° Well TD at 13138' MD / 7397' TVD @79.2° inc .~~ • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 15, 2008 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit for Workover Operations, CD2-42 Dear Sir or Madam: • ~Qt"lOC ~"11~~1 5 p ConocoPhillips Alaska, Inc. hereby applies for a Sundry permit for well workover operations. It is intended that Doyon 19 move to CD2-42 +/- September 29, 2008. CD2-42 (PTD#:201-067) has a fish at 9187' MD (below the top of the S3 packer). The fish is a RHC and a gauge package that has been lodged below the X nipple since the well was completed in 2001. The workover plan includes cutting and pulling the current completion and ~` re-completing with perforated pups and blank liner. This will set CD2-42 up to be frac'ed this ~ winter. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION for Sundry Approval (20 ACC 25.280) 2. Proposed operational procedure. 3. Proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Liz Galiunas at 265-6247, Pat Reilly at 265-6048 or Chip Alvord at 265-6120. Sincerely, ~, :• Liz Ga ~~ nas Drilling Engineer ~EtiEI V G~ SEP ~ ~ 2Q~8 Attachments cc: CD2-42 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Pat Reilly ATO 1584 Alaska Oil & Gas Cons. Cammissinn Anchorage Page 1 of 2 Maunder, Thomas E {D~7-A) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Thursday, September 18, 2008 11:56 AM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; Reilly, Patrick J; Chambers, Mark A Subject: RE: CD2-42 (201-067) Tom, The plan was incorrect in the sundry as you noted. The plan is as follows post installing and testing the wellhead and displacing the well over to inhibited brine: 1. While holding pressure on the SSSV, drop the RHC ball and rod (to set in the RHC profile in the 3.813" XN nipple). Set packer with the pressure recorded earlier + 3500 psi. Test the tubing to 3500 psi for 30 min. 2. Line up on the annulus and pressure test to 35QO~si / 30 min. while balding 2000 psi on the tubing. 3. Bleed off the annulus and the tubing. Pressure up on annulus to +/-3000 psi to shear DCK-2 valve (to achieve 2500 psi down hole). If the valve sleeve does not shear, cycle the annular pressure up to 4000 psi, then 0 psi several times, while allowing the tubing to bleed pressure. 4. Circulate diesel freeze protection for the tubing and annulus through the GLM if it hasn't been done already. 5. Shut in the well on both the tubing and annulus sides. R/U the FMC lubricator and install the BPV in the lower'Cameron' profile. Ensure all surface valves are in the closed position. Prepare the handover form. 6, RDMO Doyan 19. Thank you for confirming the procedure. Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-441-4$71 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, September 18, 2008 11:42 AM To: Galiunas, Elizabeth C Cc: Alvord, Chip; Reifly, Patrick ~; Chambers, Mark A Subject: CD2-42 (201-067) I_iz, et al, I am reviewing the proposed warkover procedure. I note that a pressure test of the tubing is nat mentioned, although I presume that will occur when the new packer is set. Also, it is stated that it is planned to test the IA to 2500 psi. This is less than the pressure value normally applied when the wells are originally completed. Could you please comment on these paints? 9/18/2008 . . ~ ConocoPhillips Alaska :"/! ù J~ Î~ ; !- \.1 f' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ,,;].ii .%å ;.M ,~DlI,s. !¡;;MtU~lli! Q!f .~. ¡;ifi) C"l'J!ii). ¡;mr!Ì!r~$3!O!1 ,føælNl March 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tÌ1 Avenue, Suite 100 Anchorage, AK 99501 ~ ""Þ<~ '21»7\\\\1 . "~;~' \ ... D 10 '1 ." ~() Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from 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 respectively was coated with a corrosion inhibiter, RG2401 engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on March 21st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21 st - 22n , 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, CZ7¢ ¡C Arend· ConocoPhillips Well Integrity Field Supervisor ~ Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name pro # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTO # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al e e r~ ....... '.....-. .t¡,.,__, "'"II,.. "t~f~;,_':;-__-~_" \\; ~\" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFichc\CvrPgs _ Inserts\Microfilm _ Marker. doc ---) ) FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Schneider Staff Development Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 ~o 1- ofo7 ~ Re: Colville River Field, CDt-42 306-038 ~ç^NNE~) f£.H Ü ~ LDUD Dear Mr. Schneider: 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, ~/~ Cathy P. Foerster Commissioner J5f DATED this-.L day of February 2006 Encl. --1 J Tim Schneider Staff Production Engineer Alpine Engineering ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 January 31,2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED FEB 0 1 AI,ska Oil & 2006 Gas Cons. C . Anchorage Dnlrni8$ion Subject: Application for Sundry Approval for CD2-42 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Alpine well CD2-42. We are planning to perform a stimulation treatment on this well. If you have any questions regarding this matter, please contact me at 265-6859. Sincerely, 11Md T. Schneider Staff Production Engineer CPAI Alpine Engineering TSS/skad o R ~ h 1 ~\~ ....~ ~_ --l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION "- ---J APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational Shutdown D Plug Perforations D Perforate New Pool D 1. Type of Request: o o o Suspend 0 o o Abandon Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 36.8' Pull Tubing 8. Property Designation: ADL 380075 & 387207 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 13138' 7397' 13138' Casing Length Size CONDUCTOR SURFACE PRODUCTION OPEN HOLE 16" 117' 2544' 9596' 3505' 9-5/8" 7" 6-1/8" Perforation Depth MD (ft): open hole completion Packers and SSSV Type: pkr= BAKER 'S3' SSSV WRDP-2 @ 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for February 5, 2006 Date: Signature Perforate 0 o Stimulate h" Waiver o o o Other 0 Re-enter Suspended Well Time Extension 5. Permit to Drill NjW1ber: 201-067 V 50~'1~;~;~:::~0 ,/ 9. Well Name and Number: CD2-42 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D 10. Field/Pool(s): Colville River Field / Alpine Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7397' 9168' 9167' MD TVD Burst 117' 117' 2581' 2377' 7273'n 7297' C~l::/VEn FEe () 1 2006 Alasksa Ojl & G Perforation Depth TVD (ft): Tubing Size: (It-GÐumm;ss" Tubing MD (ft): open hole completion 4-1 /2"Anrhorage L-80 IOJ 9229' Packers and SSSV MD (ft) pkr= 9153' 2046' Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim Schneider .~~~ 9633' 13138' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Contact: Title: Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Location Clearance 0 Plug Integrity 0 BOP Test D Mechanical Integrity Test D Other: Subsequent Form Required: 1-tC) L.\ Approved by (}IL I ~ Form 10-4~3 ~sed 7/2005 Collapse Service 0 Plugged 0 WINJ D Abandoned 0 WDSPL 0 Tim Schneider @ 265-6859 Staff Development Engineer Date )- /- tJ (" sundry30cr~ 0 3~ RBDMS BFL FEB It i 7.006 COMMISSIONER APPROVED BY THE COMMISSION nR\G\NA\ Date: 2 -/.. () ~ Submit in Duplicate 5. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up t~~ maximum rate ASAP. ..,. \"')'-'\'~W ~~~~ \~\"'.>'\ 6. Pump the following schedule at 30 BPM with a maximum pressure of 9000 psi, add breaker Ç}\50J1)..t- as per lab results. Maintain 3000 psi on the IA during the treatment. D f - ~ þ~e~~ ð(( -) -] CD2-42 Stimulation procedure: Procedure: 1. RU coiled tubing and run step mill to remove fish. Note: If fishing operations are successful, prep well for fracture stimulation and then follow with the steps noted below: 2. 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) 3. 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). 4. Pressure test surface lines to 9500 psi · 300 bbls YF125ST Pad 240 bbls YF125ST w/2 ppa 16/30 White Sand 480 bbls YF125ST w/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,OOOlbs. 7. 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. 8. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location FCC if required with slick diesel ConocoPhUUps Ala~~, Inc. TUBING (0-9229, 00:4.500, 10:3.958) SURFACE (0-2581, 00:9.625, Wt:40.00) ~ROOUCTION (0-9633, 00:7.000, Wt:26.00) Gas Lift MandrelNalve 2 (7068-7069, Gas Lift MandrelNalve 3 (8993-8994, NIP (9098-9099, 00:5.000) XN NIPPLE (91 3M 1 ~3, 00:3.500) Cf\/Q Î ( PKR (9153-9154, 00:5.970) PLUG (9168-9169, 00:3.725) NIP (9212-9213, 00:5.000) GAUGE (9215-9216, 00:3.000) OPEN HOLE - (9633-13138, 00:6.125) x I,'..,';:,:.,. .:"'0.10_0:.",.".,0:", :". 'I' t·· t a CD2-42 API: 501032037400 SSSV Type: WRDP Annular Fluid: Reference Log: Last Tag: Last Taç¡ Date: Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 OPEN HOLE 6.125 Tubing String - TUBING Size I Top 4.500 0 Sâ$·.·.l3iftlVlån.dtêl$/~åIVe$ St MD TVD Man Mfr Man Type 1 3940 3379 CAMCO KBG-2 2 7068 5680 CAMCO KBG-2 3 8993 7045 CAMCO KBG-2 Other ~plugs, equip., etc.) - JEWELRY Depth TVD Type 2046 1967 SSSV 9098 7102 NIP 9153 7131 PKR 9168 7138 PLUG --ìALPINE Well Type: PROD Orig Completion: 6/2/2001 Last W/O: Ref Log Date: TD: 13138 ftKB Max Hole Angle: 91 deg @ 10519 Top o o o 9633 Bottom 117 2581 9633 13138 CD2-42 Angle @ TS: deg @ Angle @ TD: 79 deg @ 13138 Rev Reason: TAG NIPPLE, set WRDP Last Update: 12/31/2005 TVD 117 2377 7273 13138 Grade H-40 L-80 L-80 o Wt 62.58 40.00 26.00 0.00 Thread WELD BTC-MOD BTCM o Bottom 9229 V Mfr V Type GLV GLV OV V OD Latch BK BK BK Port TRO Date Run 0.188 1696 10/25/2001 0.188 1721 2/17/2002 0.188 0 2/11/2002 1.0 1.0 1.0 Description SSSV WRDP-2 w/10' PRONG, SN #HYS-271 set 12/16/2005 HES 'X' NIPPLE BAKER 'S3' PACKER RHC PLUG STUCK ABOVE XN NIPPLE W/SPARTEC GAUGES BELOW NIPPLE 10/25/02 HES 'XN' NIPPLE GAUGES SITTING BELOW STUCK RHC PLUG SINCE 3/27/02 9212 7160 NIP 9215 7162 GAUGE 9229 7169 WLEG FiSh-EI$t:f Depth I Description ~L XN NIPPLE (11 &7 I f-IL'J) ~ Vlv Cmnt ID 3.812 3.813 3.875 0.000 3.725 0.000 3.875 I Comment XN NIPPLE LOST 12/15/2005 Permit to Drill 2010670 MD 13138 -- TVD DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. COLVILLE RIV UNIT CD2-42 Operator CONOCOPHILLIPS ALASKA INC 7397 --' Completion Dat 6/1/2001 f Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__~o Sample No Directional Survey N~-~L - DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~ Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments ~E" L L,~ L E-~' L E'~ L L W--e-~l Co'~'es/Samples Information: J~'Ctional Survey FINAL D/re~tional Survey FINAL ~iD Resistivity --- 2/5 FINAL C~D Resistivity ~ 2/5 FINAL _.J~D Den. Neu --" 2/5 FINAL -'I'VD Den. Neu -~ 5 FINAL ,4~2'~6 FINAL ~88 FINAL ~I~ID Resistivity /~/~ ! 2/5 FINAL ~,~TVD .Resistivity J~/'~ I 2/5 FINAL 'I~'D Density Neutron ~/~,/2/5 FINAL ,.~TVD Density Neutron ~,~,~/5 FINAL ~3~388 FINAL 8500 114 114 114 9644 9644 8500 114 114 114 2582 2582 8500 13138 9507 13138 13138 13045 13045 13138 9507 9507 9507 9507 9507 13136 Open 9/14/2001 (.t.0286 8500-13138 Open 8/15/2001 ~1'~0288 114-9507 OH 6/14/2001 Directional Survey, Paper Copy OH 6/14/2001 Directional Survey, Paper Copy OH 9/14/2001 114-13138 BL, Sepia OH 9/14/2001 114-13138 BL, Sepia OH 9/14/2001 9644-13045 BL, Sepia OH 9/14/2001 9644-13045 BL, Sepia ' OH 9/14/2001 ~1,0286 8500-13138 digital data OH 8/21/2001 ~!.~)288 114-9507 digital data OH 8/21/2001 114-9507 BL, Sepia OH 8/21/2001 114-9507 BL, Sepia OH 8/21/2001 2582-9507 BL, Sepia OH 8/21/2001 2582-9507 BL, Sepia OH 10/16/2001 ~0388-~'8500-13136 Digital Data Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2010670 DATA SUBMITTAL COMPLIANCE REPORT 6~4~2003 Well Name/No. COLVILLE RIV UNIT CD2-42 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-20374-00-00 MD 13138 TVD 7397 Well Cored? Y/~ Chips Received? ~ Analysis .~(.~- Rm.r.m. ived ? Completion Dat 6/1/2001 Completion Statu 1-OIL Current Status Daily History Received? ~/N Formation Tops ~_~ N 1-OIL UIC N Comments: Compliance Reviewed By: Date: Annular Disposal during the second quarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-15 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2o02 June 2002 CD2-48, CD2-46 1D-11 32102 100 0 32202 235 0 32437 May 2002 June 2002 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June.2002 CD2-19, CD2-41 1C-18 4176 100 0 4276 379 0 4655 June 2002 June 2002 1C-104 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2002: Freeze Pi~otect To~al Volume r Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 1J-09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 1J-10 1C-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 1C-133, 1C-121, 1C- 123, 1C-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- 2001 15 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 1C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 1C-127, lC-117, 1C- 111, 1C-123 Annular Dis 9osal durin ,uarter of 2001: h(1) 2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 ~ 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 oct20Ol Nov 2001 1C-109 2P-438 30331 100 0 30431 212 0 30643 oct 20Ol Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 371 NA* N^* *Freeze protect CD2-15 only ~ CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 Total Volumes rote Annult for wtuclt Dtsposat ttumortzatton l~x~otrea aurtng tne fourtn ~'uarter ztnt~ : Freeze Protect Total Volume " Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 ]' 1D-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CD1-31 6698 100 ' 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 · 2N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect ~ volumes only 1D-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dee 2000 ID-32, 1D40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... 1D-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 IT1 I'ri PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001; as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kupamk Team Leader RT/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files To: AOGCC 3001 Porcupine Dr. Anchorage, AK 99501 Attn: Steve Davies Record Of Shipment Of ~,,' Confidential Information From: Phillips Alaska, Inc. IDistrict: Alaska P. O. Box 100360 Anchorage, Alaska 99510-0360 Attn: Jeanne L. Haas (907) 263-4470 ( x ) Enclosed Subject: ( )Under separate cover ()via Quantity 1 log 1 log Description Sperry-Sun Drilling Services Rig Monitoring TVD log dated 07-04-01 for well CD2-42 PH Sperry-Sun Drilling Services Rig Monitoring MD log dated 07-03-01 for well CD2-42 PH Note - Please verify and acknowledge receipt by signing and returning this transmittal or faxing it. Fax number 265-1515 Signed by Jeanne L. Haas Received by Remarks: Date Date 11/19/O 1 Annular Disposal during the third 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-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, lC-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 ~ ' 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 z CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2001: 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 CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 ~ 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1 D-36, 1 D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. Annular Di, ~osal durin ~ the fourth quarter of 2001: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 I00 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 IC-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD247 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD245, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 Oct2001 Nov2001 1C-109 -' 2P-438 30331 100 0 30431 212 0 30643 oct 2001 Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 t otat votumes into annutt for wntcn ~nsposat ~utnortzatton tzxptrea aurtnl$ tne(Iourtn t,uarter zttct~: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 i , ID-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CI) 1-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 .... -2"N'-305" 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect ............. ~. volumes only 11)-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 ID-32, 1D-40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... I !')-42 32040 I00 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1516 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD2-39 PB1 21399 PEX/DSl 09109101 CD2-39 PB1 21399 DSI 09109101 CD2-39 PB1 21399 PEX DENSITY/NEUTRON 09109101 CD2-39 PB1 21399 PEX TVD 09109/01 CD2-42 (REDO) 21290 LWD ARC & IMPULSE 05/13101 , DATE: RECEIVED UUI I oc.uv, Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. T~k~& Gas Cons. Commi~ior~ Anchorage 10/09101 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1403 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD2-42 21290 LWD IMPULSE,ARC,ADN (PDC) 05113101 1 CD2-42 21290 MD VISION RESISTIVITY 05/13/01 I 1 CD2-42 21290 TVD VISION RESISTIVITY 05/13101 1 1 CD2-42 21290 MD VISION DENSITY NEUTRON 05113101 1 1 CD2-42 21290 TVD VISION DENSITY NEUTRON 05113101 1 1 08/24/01] RECEIVED DATE: ---- S£P 1 4 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8~7~i~n~ ~.CoiIS. Commission Anchorage 8/15/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1372 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD2-42 PB1 21291 CDR,ADN,ARC,Mt0 (PDC) 06121101 CD2-42 PBI 2129t MD VISION RESISTIVITY 05121101 t 1 CD2-42 PB1 21291 TVD RESISTIVITY 05121101 t CD2-42 PB1 21291 MD VISION DENSITY NEUTRON 05/21101 1 t CD2-42 PBI 2t 291 TVD VISION DENSITY NEUTRON 05/21/01 1 CD2-24 PB1 21324 IMPULSE & ADN 06113/01 CD2-24 PBI 21324 MD VISION RESISTIVITY 06113101 CD2-24 PB1 21324 TVD RESISTIVITY 06113101 I 1 CD2-24 PB1 21324 MD VISION DENSITY NEUTRON 06113101 CD2-24 PB1 21324 TVD VISION DENSITY NEUTRON 06113/01 1 I DATE: RECEIVED Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-831 ,~.all~l~¥~of~as Corls. Commi~on Anchorage PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 August 22, 2001 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-42 (201-067 / 301-142) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-42. ~\ (/rlf you have, any questions regarding this matter, please contact me at~265-612~or Scott Reynolds ,265-6253/ at Sincerely, G. C. Alvord Alpine Drilling Team Leader PAI Drilling GCA/skad RECEIVED ,AUG 24 2001 Alaska 0/I & Bas Cons. Commission Anchorage 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 ~=1 Gas D Suspended O Abandoned D Service O 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 201-087 /301-142 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0380 50-103-20374-00 / 50-103-20374-70 ~ ....... ~ 9. Unit or Lease Name 4. Location of well at surface 1984' FNL, 1513' FEL, Sec. 2, T11N, R4E, UM (ASP: 371725, 5974373)~ '~'FE Colville River Unit At Top Producing Interval ~ .~.~ ~; 10. Well Number 29' FNL, 419' FEL, Sec. 10, T11 N, R4E, UM (ASP: 367485, 5971121 . CD2-42 & CD2-42 PB1 2043' FSL, 1319' FWL, Sec. 11, T11N, R4E, UM (ASP: 369171,5967884) Colville River Field 5. Elevation~in feet (Indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36.8' feetI ADL380075 & 387207 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions May 13, 2001 May 29, 2001 June 1,2001I 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 13138' MD / 7397' TVD 13138' MD / 7397' TVD YES I~l No IIII 2076' feet MD 1625' MD 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 BOll'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 40# L-80 Surface 2581' 12.25" 380 sx AS III Lite, 230 sx Class G 7" 26# L-80 Surface 9633' 8.5" 117 sx Class G CD2-42 PB1 cement plug dressed off to 8553' to start CD2-42 sidetrack 24. Pedorations 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" 9230' 9154' open hole completion from 9633' - 13138' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9507'-8904' Plug #1:258 sx 15.8 ppg Class G 8904'-8522' Plug #2:165 sx 17 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Pedod > 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 Alaska 011 & a~s Cons. ~;ommission Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. CD2-42 PB1 Top Alpine D 9182' 7229' Top Alpine 9210' 7250' Base Alpine 9338' 7344' CD2-42 Top Alpine D 9398' 7234' Top Alpine 9476' 7254' TD 13138' 7397' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed _7~L~. d. ~ Title Alpine Drillin.q Team Leader Date ~'fZ',/.O, Chip Alvord Prepared by Sharon AIIsup-Dral~e INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 pertinent 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. Item 28: If no cores taken, indicate "none". Form 10-407 Operations Summary CD2-42 Rpt Date 05/12/01 12:00 AM 05/13/01 12:00 AM 05/14/01 12:00 AM 05/15/01 12:00 AM Comments PJSM. Prepare rig for move, separate modules and move subbase off well. PJSM with Peak, RU tow bars to cats. Stage pipeshed, motor complex and pit module to gaurd shack on ice road. Move motor and pit modules onto CD2 pad, move subbase from CD1 pad to CD2 pad. Spot subbase over well CD2-42, move in pits and motor complexes, spot pipe shed and rig up. Accepted rig at 2200 hours. NU riser and flowline, take on mud in pits. NU riser, modify splash guard for pad hieght. Load drill pipe in shed, take on spud mud. PU and stand back 29 joints of hwdp and 52 joints of 5" drill pipe. MU BHA # 1. Held Pre-Spud meeting with rig team. Performed Divertor Test, Chuck Scheve waived witnessing test. Filled conductor and checked for leaks. Pressure tested standpipe to 2500 psi. Held Evacuation drill with rig team. Spud well, drill from 114' to 1960'. ART=3.4 AST=4.4 Drill from 1960' to 2590'. ART--4.2 AST=I.0 Circ hole clean, condition mud, monitor well, static. Wipe hole to 1389', worked through several tight spots from 1987' to 1675', 20-30k over.. RIH, no problems. Unable to MU top drive (would not rotate), ru circ hose. Pump high vis sweep and circ hole clean, reciprocate pipe throughout. Monitor well for trip, static. POH to BHA, worked through numerous tight spots from 1160' to 750', 30-50k over. Handle BHA, LD MWD and motor, clear tools from floor. RU to run surface casing, held PJSM with crew. Run 9-5/8" casing to 1125', push last 60', observed diminished returns. Established circ (lost 15 bbls) staged pumps up to 7 bpm with full returns. Reciprocate casing and ¢irc hole clean. Continue to run 9-5/8" casing. 1195' @ midnight. Run casing to 1360', pushed last 40', displacement returns diminished. Staged pumps up to 7 bpm and circ with full returns. Run casing, MU LJ and land casing with shoe @ 2581', FC @ 2492'. LD Fill up tool and MU cement head. Staged pumps up to 9 bpm, cir¢ and condition mud, PJSM with Dowell. Pumped 40 bbls of viscosified FW with nutplug marker, line up to cementers, test lines to 2600 psi. Pumped 50 bbls of 10.5 ppg spacer, 300 bbls of lead and 48 bbls of tail cement. Displaced with 20 bbls of FW and 169.8 bbls of mud @ 8 bpm. Bumped plugs to RD cement head and flush conductor. LD LJ, MU wash tool and flush annular preventor, driller functioned divertor with out disabling knife valve resulting in 3 bbl spill on pad. Initiate spill response and establish containment. ND Divertor system, install Unihead and test M/M seal to 1000 psi for 10 min. NU BOPE - change drive sub on Top Drive to 4". Install test plug - test BOP's choke manifold and surface safety valves to 250/5000 psi. Annular Preventor 250/3500 psi. Install wear bushing Chuck Scheve (AOGCC) waived witnessing tests. Install mousehole and second annulus gate valve on wellhead. Slip and cut drilling line - service Top Drive. Operations Summary CD2-42 05/16/01 12:00 AM 05/17/01 12:00 AM 05/18/01 12:00 AM 05/19/01 12:00 AM 05/20/01 12:00 AM 05/21/01 12:00 AM PJSM. Grant-Prideco Rep. spoke to crew on the new drill pipe issues. Begin picking up drill pipe. PJSM. Prideco Rep. discussed handling and MU issues of new XT 39 drill pipe. PU 4" drill pipe and stand back in derrick, 270 joints total. Install 4" stabbing guide on TD, test new blower motor installation. Attempted to make up TD at floor, drive sub tagging face of joint in rotary table. Modify stabbing guide and install centering assist ring on grabber, continued to tag face of tool joint in rotary table. MU BHA #2, install source in LWD and shallow test tools @ 203'. RIH with hwdp. Electrician installed new temperature sensor in TD motor. Calibrate temperature sensor on Top Drive. RIH, tagged cement @ 2472'. Circ and cond cement contaminated mud. RU and test 9-5/8" casing to 2500 psi, 30 min, blow down lines. Clean out cement and float equipment from 2472' to 2590', drilled 20' of new hole to 2610'. Circ hole clean, balance mud wt. in/out. RU and perform FIT to 16.0 ppg EMW. Blow down lines and equipment. Drill from 2610' to 4256', ART=6.3 AST=0.3 Changed over to new LSND mud while drilling first 50' of hole Pump high vis sweep and circ hole clean - monitor well static. Begin wiper trip to shoe. POH to shoe. Service Top Drive and Blocks. Change out Top Drive blower motor. RIH to 4256', precautionary wash last 90', no problems. Drill from 4256' to 4447', swivel packing leaking. Change out swivel washpipe and packing. Drill from 4447' to 6261', ART=10.2 AST=0.5, Pumped wt. sweeps every 300 - 400'. Pump high vis sweep and circ hole for wiper trip. Cir¢ hole clean, monitor well, static. Wipe hole to 4066', no problems. RIH to 6261', precautionary ream last stand. Drill from 6261' to 7120'. ART--5.1 AST-0.2 Change out 2 pistons and 1 liner on #1 mud pump, circ hole @ 10 bpm with #2 mud pump. Drill from 7120' to 8075'. ART=5.6 AST=0.5 Pumped 11.6 ppg high vis sweep, circ and cond mud. Circ hole clean, monitor well, static. Pump dry job. Wipe hole to 6166', no problems, max overpull 15k. RIH, precautionary ream last 90'. Drill from 8075' to 9507'. ART=9.0 AST-0.5 Top of Alpine @ 9209' MD / 7250' TVD. Pump 11.3 ppg high vis sweep and circ hole clean. Monitor well, static. Pump out from 9507' to 9030', pump dry job. POH to BHA, no problems. Monitored well @ shoe 10 min, static. Stand back hwdp, remove source from LWD, LD BHA and clear tools from floor. MU 30 jts. of 3-1/2" tbg tail, RIH with 4" drill pipe to 9507'. Circ and cond mud for cementing, PJSM. RU and test cement lines to 3500 psi. Plugged back 8-1/2" open hole from 9507' with 258 sxs of 15.8 ppg G cement, displaced to equalization. CIP @ 1120 hrs, ETOC @ 8904'. Operations Summary CD2-42 05/22/01 12:00 AM 05/23/01 12:00 AM 05/24/01 12:00 AM 05/25/01 12:00 AM Pulled to 8904', circ to clear drill pipe. RU and test cement lines to 3500 psi. Plugged back 8-1/2" open hole from 8904' with 165 sxs of 17.0 ppg G cement, displaced to equalization. CIP @ 1314 hrs, ETOC @ 8554', pulled to 8522'. CBU, dumped 180 bbls of cement contaminated mud, circ and cond mud, monitor well, static. POH, lay down 3-1/2" tubing. Pull wear bushing and install test plug. Test upper and lower pipe rams, blind rams, choke manifold and surface safety valves to 250/5000 psi. Test annular preventor 250/3500 psi. John Crisp (AOGCC) waived witnessing test. Tested Blind rams, floor safety valves and TD valves 250/5000 psi. Pulled test plug and install wear bushing. MU BHA #3, shallow test tools. RIH to 2580'. Slip and cut drilling line. RIH, fill pipe every 2000', tagged cement @ 8531' Pump 12.0 ppg high vis sweep and circ hole clean. Clean out cement from 8531' to 8553'. Time drill off of cement plug from 8553' to 8603'. Drill from 8603' to 9005'. ART=2.1 AST=6.5 Drill f/9005' to 9405' 7236' TVD - ADT-8.3 AST-5.4 Drill f/9405' to 9519' Repair bumper hose on mud pump #1 Drill f/9519' to 9644' - 7274' TVD - TD- 8 1/2" hole ADT- 4.5 AST - 4.0 Pump weighted hi vis sweep - Circ hole clean for shortr trip - add Lub-tex & bump mud wt. to 9.9 ppg Monitor well - static - Pump out f/9644' to 9179' - 5 stds., continue POOH Continue wiper trip f/9179' to 7269' - RIH to 9549' - wash & ream f/9549' to 9644' Pump weep & circ hole clean POOH to run 7" csg - pump out 5 stds to 9179' - monitor well - static - Pump dry job - POOH to BHA Lay down BHA P/U stack washer & wash stack - pull wear bushing - set test plug - change top pipe rams to 7" - body test BOP - pull test plug - set thin wall wear bushing Rig up to run 7" csg PJSM - running csg Ran 62 jts. 7" 26# L-80 MBTC to 2564' Circ csg volume & btms up f/9 5/8" shoe Continue running 7" csg - Ran 235 its total - 7" 26# L-80 MBTC csg w/shoe @ 9633' FC @ 9549' - landed csg w/fluted mandrel hanger Install cmt head Circ and condition mud for cmt job Cmt 7" csg - test lines to 3000 psi - Pump 20 bbls Arco wash @ 8.3 ppg - 50 bbls Acro spacer @ 12.5 ppg - drop btm plug - mix & pump 117 Sacks Class G 24 bbls @ 15.8 ppg - drop top plug w/20 bbls water f/Dowell - switch to rig pump & displace w/345 bbl Rig down cmt head & csg tools - pull thin wall wear bushing - set & test pack-off to 5000 psi Change top pipe rams f/7" to 3 1/2" x 6" Set test plug - Test BOPE - pipe rams, blind rams, kill & choke line valves, choke manifold valves, floor valves, top drive valves to 250 psi Iow & 5000 psi high - Hydril to 250 psi Iow & 3500 psi high - accumulator closure test - gas detectors - Test wi i,~ Operations Summary CD2-42 05/26/01 12:00 AM 05/27/01 12:00 AM 05/28/01 12:00 AM 05/29/01 12:00 AM 05/30/01 12:00 AM M/U BHA # 4 - RIH to 361' w/BHA RIH picking up 4" DP f/pipe shed to 738' - Test MWD - Continue RIH picking up 4" DP to 4080' - fill pipe RIH w/BHA #4 w/DP f/derrick to 9494' - took wt. Break circ - clean out cmt stringers to 9522' Circ btms up and condition for casing test Circ & condition mud Rig up to test csg - test 7" csg to 3500 psi for 30 mins. Drill cmt - float collar @ 9549' - cmt to float shoe - drill out shoe @ 9633' - clean out rat hole to 9644' - Drill 20' new hole to 9664' Circ hole clean for LOT Rig up for LOT- perform F.I.T. to 12.5 ppg EMW w/9.9 ppg mud - rig down Held PJSM - change well over to 9.2 ppg FIo-Pro Drill 6 1/8" hole f/9664' to 9807' - 7276' TVD - ADT 2,4 Drill f/9807' to 10,540' - 7275' TVD - ADT- 8.8 - AST- .30 Drill 6 1/8" hole f/10,540' to 11,690' - 7272' TVD - ADT - 16.1 AST- 2.6 Drill f/11690' to 11,805' Drilling break - flow decrease - hole taking mud - observed well - static w/pumps off - circ @ reduced pump rate - mix & pump LCM pill - loss rate 50 b/h - drill to 11,813' - spot LCM pill # 2 - observe well -static Drill f/11,813' to 11,868' - loss rate 200 b/h Mix & pump LCM pills 3,4 &5 - last pill 44.5 ppb - spot on btm - pull 1 std.- observed well - well flowing - shut in - SIDPP - 0 SICP - 0 - down squeez LCM pill w/200 psi for 5 mins - open & observe well - slight flow Drill f/11,868' to 12,065' - 7279' TVD - hole still taking fluid @ 45 b/h Drill & slide f/12,065' to 12,300' - hole still taking fluid & slight breathing on connections -loss rate 30 b/h - Perform Exhale test - SIDPP - 610 psi SICP- 340 psi - bleed well through choke for 2 mins.- SIDPP - 500 psi $1CP - 300 psi Lost signal from MWD - trouble shoot - regain signal Drill & slide f/12.300' to 12,400' - 7290 TVD - hole still taking fluid - Total fluid loss past 24 hrs. 734 bbls - 30 b/h average Drill 6 1/8" hole f/12,400' to 12,797' 7340' TVD - ADT - 7.8 AST - 2.4 - hole taking fluid @ 27 b/h aver. loss rate - well breathing on connections Drill 6 1/8" hole f/12,797' to 13,138' - 7397' TVD - ADT - 6.8 AST - .9 - hole taking fluid @ 24 b/h aver. loss rate - breathing on connections - TOTAL LOSSES PAST 24 HRS. 613 BBL - TOTAL ACCUMLATED LOSSES 1,347 BBLS. Pump sweep and circ hole clean for wiper trip Circ hole clean for wiper trip Monitor well - well breathing flow back 15 bbls in 15 mins. well static - pump out f/ 13,138' to 9590' Monitor well - static - circ btms up f/7" csg shoe Cut & slip drill line - Service top drive RIH f/9590' to 13,054' - safety wash & ream f/13,054 to 13,138' Circ btms up Change well over to 9.2 ppg brine @ 4.5 b/m @ 1770 psi - final 4.5 b/m @ 1210 psi - shut down - monitor well - well static- clean up under shakers POOH to 10,285' - inital losses 10 B/H Spot Hi-vis pill Continue POOH to 9331' - monitor well @ 7" shoe - POOH to 8376' - Pump dry job 05/31/01 12:00 AM Monitor well @ 8376' - Pump dry job - Continue POOH to 4650' racking 4" DP in derrick Operations Summary CD2-42 Pull and lay down 134 jts. 4" drill pipe & 5 jts. 4" HWDP Flush BHA w/fresh water - L/D fex collars - remove RA source f/MWD - L/D remaining BHA Pull wear bushing - rig up to run 4 1/2" completion -held PJSM Run 4 1/2" completion - WLEG - (2) 4 1/2" pup jts - XN nipple w/RHC plug & gauges - 1 jt. 4 1/2" 12.6# L-80 IBT tbg - Baker S-3 packer - 1 jt 4 1/2" 12.6# L-80 IBT tbg - X nipple - 2 jts. 4 1/2" 12.6# L-80 IBT tbg - Camco GLM w/DCK shear valve - 44 jts P/U Camco SSSV - connect control lines & test to 5000 psi Continue RIH w/4 1/2" completion - Ran 47 jts 4 1/2", 12.6#, L-80 IBT tbg w/dual control line - M/U tbg hanger & connect control lines - test to 5000 psi - Land tbg string in wellhead - Run in lock down screws - test seals to 500 psi - L/D landing jt 06/01/01 12:00 AM Install landing jt. B - test metal to metal seals on tbg hanger to 5000 psi - L/D landing jt. B Change upper pipe rams to 4" x 7" - change bub in top drive to 4 1/2" IF N/D BOPE & flow line - terminate control line for SSSV through wellhead - Install tree & test to 5000 psi - pull two way check valve Drop packer setting ball & rod - rig up lines to tbg and annulus - test line to 4000 psi - pressure up on tbg to 3500 psi to set packer and test tbg for 30 mins. - bleed tbg down to 2500 psi - pressure test tbg annulus to 3500 psi for 30 mins. Pump 40 bbls 9.6 Brine followed by 158 bbls 9.6 inhibited brine followed by 174 bbls diesel for freeze protection - shut in well Pull down line w/hydrocarbon truck - rig down lines and maniflod - set BPV Pull fluid from mud pits and GIS - Release Rig @ 16:30 hrs 6/1/01 2 291,0~. 3 4 ,~ie~O0 5 654.00 7 .834.00 9 1015~0O 10 11 12 .1300200 13 1~o~ 14 1'~0~00 16 1681,00 18 19 ', t9~6~0O 20 26~,05 21 2166,~0 22 '...ms!',0o 23 234?:00 ..... 24 .244~,.00 25 . 2505.84 26 :' ~657.0O 27 ' 2754,0~ 28 . 2848..00 29 2944,Q0 3O 3349.0O 31 ~.0O 32 '3229.0O 34 3422.00 35 3517.00 36 37 3705',0O 38 39 3899.0O 4O 399~;00 41 .498~,0~ 42 : 4!eS~0o 43 4280.00 44 4375.00 45 .. 46 4565.00 47 4661 48 475'7;00 49 4851,0~) 50 4947.00 51 6043.0O 52 5139200 53 5235.00 54 5330,0G 55 5427.(X) 56 ~.0O 57 5617.00 58 .' $713,00 59 5808.,0O 60 5'90420O 61 5998.00 62 609~.0O 8ie~.0o 64 .6285.00 65 6380,00 66 6478.00 67 . 6571.05 68 6668~00 69 6761 70 .5956-0O 71 8052~00 72 7048~05 73 7143.05 74 "7259°00 75 .7334°00 76 7429~00 77 7525~00 78 7921,0O 79 = 80 · 7m~'i0o 81 7907.0O 82 '~,0o 85 8289,00 86 '8333.0O 87 8480214 88 8548.0O 0.36, 2122.74 0.70.· ,.~__~-~_ ~ 0.77 .', 1.21 1.s1: ,.'~.~ 2.51 :, 226~ 4.05 :': 6.14 . . lO.3~:: ',.~!e. 12.95 '.' 14.38 - ... 17.00. ': 20.33 22.93'' 24.44 : 27.14 :'.: :.234. ~., 30.00.. 33.33 .:.: :236~74 36.81' ':..:237,,~0 4o.11.: 40.70 .: 40.71... :239°64, 40.33" ,.," 23 ,t~. 1: 40.21 ,.: 239,42 39.98 "" 40.56 ..' 41.27 . 42.50 : ' 23~'.~,7 42.39': .23E.56 42.69 '236,99 42.88. '.i'.237';.16 42.96'. 237.O5 42.98, 43.26. 235.65 43.27 , . 23~25 43.33 236-58 43.31 ' ;':.i. 43.65, ~36-~ 43.85' '~.4~ 44.40 ' 44.82 ': '~t7'..1~ 44.18 ':' ~.8~ 43.98"/.. 44.23 . 230.65' 44.36 · 236.92 43.74 .'.. '238~31. 42,58 ' 235.94. 42.65 235.33 42.83 '. 235.48 42.66 ' 236,3~ 42.77 .: 235.86 42.86 235,72 42.78 '{ 233.22 43.03 233.8$ 42.50 ' 23`5.~W, 42.18 "236.4~ 42.10. ' 237.6~1 42.17 . '"'237,48' 42.14 237.23 42.03 297.60 42.03 ":' 41.88 :. 237:61. 41.83. 237.43 41.56 '=' 236.73 41.12 ,=, 236.07 40.73 : "'E~6~ 40.77 ": 23,5.48 40.42 :' 236.0,3 41.89 ". 237.93 41.95 ' ' 238.4:,5 42.08' 237.68 42.03 42.28 236-89 42.19 236.8~ 41.88 236.94 41.59 .,.. 235~2 42.82: ' ', 236.46 43.53 43.71 .:.' 237.0,5 43.77 . 237.75 43.61 . 236.69 43.76 ". 237.0~ 43.76 236.02 43.95' · 235.87 43.95 234.64 43.93 , 235.37 114.00..": '62100 371724.81 6974373~1 291.oo ' 2223~.00 371724.50 473.99 !':., ~2:~.89 371723.26 59~43~1~5 562.98 :.",~10,~ 371722.45 653.97 :601.97 371721.62.5974359,64 742.94::"?~;~4 371720.65 587' ,4~', .'~ 833.89 :. 78J289 371718.67 5974365.3~ 921.74 '""L'8~9.74, 371714.47 1012.38 ' .',:960.38 371707.09 5ETf1359237 1106.35", ,10~.38 371694.70 1200.40 , i:l~. 371677.49 1293.68 ':?1E41':58 371657.65' 597,1,933.88 1385.13. = 13~,~ 371635.46 687~4~4 1475.12' .'.14~3~12 371609.40 1553.42 '.::151:L43 371579.58. 0.00 :, ·: .,0,00 -.0.47. ~'. -0,,30 -1.59" -2.39 , -3.73: -5.62': -8.09.. .' ,.6.01. -10.86 -14.25 ', -17.49 -20·07 ' ': -23.78 -29.26' ' -46,84 -40.571' -53.88 .' :::' ~88,43 -69.96'.: :-1 i4,26 -8a.81 .' .2!,i3.'~6 1651 34.,'. 1599,,34 371547.41. 5974235.79 -110.60':. ';173.57 1736.87:'::;HJ8~'..~.: 371513.42'~4~2,20 -134.68 1819.41.:.1767:41 371476.16:5974,317,07 -160.44 -245.99' 1901.11 "..1849.'11~ 371433.82 5974189.73' -188.45': ' ,;287.87 1978.03':."!9'~,:03 371388.02:59'74~61,1,6 -217.84 2053.19..'2001'd9 371337.14. 5974129~95 -249.90 ; ,,383.54 2125.53. :'20'~/3':,~3. 371284.32 '59~ -282.45' '=~1~.~1' 2198.31.'. 2146.,31 371230.09 5674067.03 -314.63 .-489,51. 2270.53 : :'22118.53 371176.41 '6874036~58 -345.98 ": .-542~68 231924:2267.34 371140.55 597461~.,16 ..367.01 .. 2434.87!: ~:67 371056.29'S~;/3~,42 -417.17 2508.891:::,:2~56.~ 371002.40 5~79936-37 -450.13 '-714.03- 2579.92.:: 2522.92 370949.94 5~730O3J8 -483.20 .: -766-88 2651.39 2599.39 370895.53 597'3869.3t. -517.99 -820.71 2722.23.. 26~0,23 370840.93 5979834;45 -553.77 ': -874.72 2791.49 '. 27~...49 370787.75:5973799.,86 -589.46 ': .;92?.;30 2861.21 :'. 2803.2T' 370733.31' 5973765,03 -625.01 '. -931.18 2931.52 '2879,52 370677.83 5973790,,1~7 -660.51 1-1036.03 3002.49. 2950.49 370622.21 5973694.74 -697.18 .-109.1,06 3071.84. 3319.8't 370567.70 597335~.45 -733.38 -`1'144.97 3141.02" 3089,0~ 370513.16 5979923~ -769.83 .-1198.91 3210.88 3159.88. 370458.02 5973587.95 -806.74 -1258.4,3 3280.00 ~3-23~2~(X~ 370403.29:597956~59 -843.03 3349.66 . 3297.58 370347.97 59735`16.48 -880.06 -1362.27 3417.56: 33~.56 370293.33 597348'!.28 -916.18'" -1418.3'! 3486.65 .:94,,."44.65 370237.18.5973449,3~ -953.04., -147'1.65 3555.37 '3503.37 370180.77 597340~,16 -990.20 -`1527.64 3622.95' '3570.~5 370124.35 597'33~.48 -1026.83 -~583.46 3690.71 3638.71 370067.94 593'3,338.1.1 -1063.15 .-1639.27 3759.67 . 37D7,87 370011.64 5979~.21 -1100.00 . o'~694.36 3827.17 . 3775,'`17~ 369956.49 5~79267.02 -1136.12 -1749.51 3895.88:3843.88 369899.79 5973231.~;,5 -1172.85 o1565.60 3964.88:39,12,88 369843.45 '59'7519~48 -1209.57: -1581.33 4033.45: . 398{,43 369789.47' 5973160.55 -1245.41 -1914.72 4104.10:' 4052.10 369735.21:5973124.78 -1282.10 -1968.37' 4174.60. 4122250 369680.96 5973088.'~0 -1319.09 -2022.00 4245.10.· 4193,10 369626.40= 591305~.09 -1355.62 '.°2076-96 4315.64.. 4263.64 369571.76 5979~`17.68 -1391.95 .-2`130.00 4385.33= .'43:[3,23 369517.76 597258~.29 -1428.25 '-2183.40 4456.48 :., ,I,l~t,~,~ 369463.48' 5972944.90 -1466.56:' 4526.07~ 44~'4.07 369410.83 5972907.35 -1505.00 -2269.05 4595.81 ' 4543.81. 369357.47 59728'71,12 -1542.12 :-2341.B0 4666.77.. 4~!4,7'/369303.19 5972838.~1' -1578.15 i-2~,95.49 4737.22= . 4~65.2'~ 369249.13 5972802,25 -1612.83 ', -2448,97 4808.41 .' .4756.41:369194.20 5972788.64 -1647.36 "-2503.33 4878.094826,09 369140.52 5972795:.5f -1681.40. ;~566.44 4950.084398.08 369085.16 5872701,43 -1716.41 -~611:2~ 5019.90' 4967..90 369031.50 5972668.56 -1750.19 -256'4,33 5091.30.., 50,,39.30 368976.77 5972~3~,04 -1784.63 .'.-2718.48 5162.06.. 6~10.0~ 368922.74 5972601.91 -1818.67'...2771.93' 5232.99 5180.99 368869.12 '5972568.47 -1853.01" -2825.0~ 5305.07 . 5253`07 368815.73 5972,534,28 -1888.10:3877.52 5376.85: 5~24.~ 368763.66 59~500,21 -1923.05' .-2929.30 5448.82., 53~6-92 368711.95 5972,;465.99 -1958.15 -2930.43 5520.20 546~.20 368660.82'587243~,43 -1992.57"-303D.99 5593.23.. ' 5541.23 368606.71 5972398.56 -2027.34 -3084.52 5664.66 :' 5812..56 368551.65 5972365.70 -2061.14 .-3139.02 5735.24"..5883.24 368497.14.5972932.~8 -2094.78.'-3192.98 5806.54'".5754.54 368442.40 597~299.28 -2129.41 -3247..15 5876.99 ' 5824.93 368388.36 5972265,48 -2164.11 .. 5947.32' 5~95,32 368334.38 5972231;38 -2199.13 ~.01 6018.63' "5966.63 368280.03 5972197,07 -2234.35' :..340~.77 6090.26 '" 6038,26 368226.23 5972162,51~ -2269.74 !-3460.99 6160.63., 6'~0~,&.,.,.3 368172.65 59,'~127.94 -2305.29 6230.65... '6.178,65 368116.76 5972993.4,,5 -2340.73 ..-3589.21~ 6299.42 . 6247,42 368060.83 5972059.31 -2375.81.' -3624.64 6368.78. 63~6.78 368004.32 5972(~24.50 -2411.57 .,,3680.56 6437.47,"' 8385.4'7:367948.56 5971989.92 -2447.10 .,,3735.73' 6506.17: 6454,17 367893.02 5971954,99 -2482.96 .: -3790,68' 6575.51' "6523.51 367837.02, 5971919.32 -2519.57. -384.6,06 6643.29" 6591;29 367782.46.5971893.7? -2556.04: -,"~00.02 6713.23 6661.23 367726.43 5971646.30 -2594.46. -3955,42 6762.09:: 67.10:09 367687.41 59'71819,95 -2621.47 '-3993.99 0.20 ~ .... "' :0,27 0.21 ": 0.30 .' ." 1.01 0.50. . .. t.81 0.36 ' ' ".: '~0,~ 1.37' :: · 4.,,30 2.02 "" :" : '4.79 ,. 2.34 ... 4.31.: 4.46" :::. ';3,65: 2.78 ..'.: .' 3,7`1' 1.50 . .!'i.= 4.42, 2.80 . :' ' · :.'.6-79 3.51 ...: :"7.81' 2.78 :'" :.' 10.$1i 1.87. ,.,: '. 14.73 2.84.. ::.' :..'. 20,11i 3.12 · i ~$,45 3.52 ":i'=' 30.411 3.72 :.:..: 3·45 ..: : 39,48:: 0.81 : ..' "' 43.521 0.79 .:.' ' 46-59~ 0.46' ": ,.. :' 43,14~ 0.22 '.:'.= :. = '56.641 0.40 "' "' $$.82~ .. O.69 ' ·59.73i 1.05 :' : 64.41 · 1.30. '' 69,7~ 1.12 75.77 0.39'... 82.44 .. . 0.86 .' 65.3~ 0.11 · ' 9'3,81i 1.03 .. 100.19i 0.82 ~ '., 108.69{ 1,01,::. · 113`40~ 0.94 ".. 120.23i 0.57 ,,i .:~;:': 126.61 0.40 '. 133.5~ 0.38 .: 13,9.91:~ 0.26 :.:'.":': 146,222 0.41 '.' .152.58~ 0.78' ' i58.65 0.77 ". =='~ 164.361 0.33 <= 170.$9i 0.36. 176.71 0.24 '" '182.84i 0.78','."188'.74! 1.26 19'5.162 0.44 · , 202.21~ 0.22 . 209.54i 0.62 .' .. 216.30~ 0.34' . 222.8! 0.14 ", 229,58~ 1.75. :,,~ 238.1(] 0.52 :: .. ,247.521 1,55 .: 255.381 O.SO . . 26i.84i o.91 ~ '=,.267.1~ o.18 · , ' 272.0oi 0.17: '' '276.9~ 0.28. : 282.0(~ 0.09i 286.74 0.18· . 291 0.14 L:~6.37i 0.57 301 0.65 .:: ::.,. 307'.67~ 0.53 ' '.' 314.2t 0.09 ... ='.a2~,O~ 0.53 . 327.54 1.99 ' ': .332.65~ · . 0.37' '. 337.08i 0.56.." ' 341.272 · 0.39. ' 346.26; 0.34 '' 351.65i 0.23.. "357.341 0.40 ' '3~.05i 0.83 '," 369.15 1.37 "1,375,5~i 1.46. ~ :'..'~380.87-- 0.87 ':..' 385.50' 0.51 · '.3~0.67~ 0.79 ' : 395.97 0.31401 0.74407.84 0.23' 414.55 0.88422.31 0.75. 427..93 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 TD 43.93 :.:ii.'23.5i37' 43.81'. 234.45 .. 43.9 ,:i' 230.53 44.91 ii':" i~.; ,..E~3 46.96" "", 223.02: 49.21 :..'.'219.41' 51.21 :':.?,i'~i:6~1~; 6893.37 '.'6841;,.37- 53.01 ',.::;2!'2~',751 6914.87 53.84 .?,210:06. 6933.94 6861:;~ 53.76 .:i 'i2~;~' 6952.84"': 53.59 :i i;::120~;.~..': 6971.2 i;: ?:i,69,1.,,~..2 53.57 .,:.:, 207.'..15. 6991.39 ..6939;39 53.67 '~.i'",i.'~21~..,~.821 7009.19'~ :"695771'¢j: 6762.091 ' = 67~ 367687.41 : 5971.819..9.51 -2621.47 -3~93,99 6785.16: , 6733,16~ 367669.05 59~1807,51' -2634.22 · -4012,14' 6808.24 6756~.4:367651.24 5971794~2 -2647.71 .~29.72' 6830.39: '677&39 367634.79 5971780,..20; -2662.11 6854.74,' 68~,74:367616.83 597;1762;61i -2680 ':i 6875.45, ..,6t~...4~, 367601.36'597~?.45.~52i -2697.35 :'-4078.78' 367587.80 ', 597~1728'-'82! -2714.28" ~4(J92.05, 367571.671597.i7~06,~1i -2736.96 1. 4!07;8: 367557.92: 59.'~!.,:,68~..?~1! -2758.89 ,, 367544.69 5971662.5~:-2781.29 4134.04! 367532.18 ,..597~,92! -2803.11 :~146:t~: 367518.99. 597!6!6:95; -2827.3" ~1'~;96! 367508.43 ".59'~595;25; -2849.18 "'"-4159;t6' 54.36 .':"' i ~ ~ ~:~' 7029.76I ' ' ' 6~2~ 367497'74 :,59~.'i156~'031 '2875'58 !'~."i'~;41,: 55.35 ".::.;;:,i~)4:~69; 7048.18I . I6{)~;,i8:' 367489.60 i: :5,971i~;18' -2900.57 '~187:.1'2i; 56.33 ' I:~ ~ '.~ 7064.47: '7~.~? 367483.94 ~97!520.57.,: -2923.97 -4192.38~ 58.17'.~",188,58 7082.87 7,030,87' 367478.69..597'1'492;77 -2952.16 58.97 ~.:: ' :.,,'.ll~:~:J 59.2 '~' i'; ~ 85.99: 59.58 · ".i.::.1,85.'4,7., 60.68 ".... :.:. 1 .84~44. 63.3 ', :." ;1180,69:. 65.16. ;: '.178~22' 67.12 :~'; !i. '175~16 70.92 · .'::t71~.5: 73.22 .., 75.64 ..'; "167,12 · . .. . 77.47 ?'' 164.67~ 79.21 ...'.161'.65;. 81.56 ' , 159:54~ 85.54.:,.i ::'155.01" ..... 89.14 .. '~.149.21 89.38 . 149.25, 89.52 ::'~:'""' !~';:~'~.~1~' 89.69 "'.""': 1150;83:. 89.69: ',':" 150:07! 89.62 %: .' 150~42:! 89.76 .~..' 150.85 90.69' . ... 90.82..,'151:91.~ 91.23 .....: ~151..93 90.21 .... 1'52;74: 90.38 ': 153.23 90 "': :151:51: 89.97 ,.. 1.51.23 90.14 :~ :!50.67 90.24 .:.:;'1'i50.67.. 89.35 '151.57 89.86' "': '.. 1.5i .35. 90.17 '.::;'i' 151':8' 89.49". :, ,15i,37; 89.97 :.' . 152;4 , 88.8 .:':. ~,: .152i41: 89.07 '..: .1~3~06: 89.38....151:69. ...... 89.73 '.' ".' '152,49 89.83'"" :':152.33. 89.97 .ii.. 152;69' 88.15. ~: ." 150.61. 86.36..' .:' 149.77,. 85.3.'~' i50.3t' 83.51 -: 150.32'; 81.88.'" 150.38.: 82.02 .('::: :.150;24'. 80.78 '? .~'.i'..'1:50;!?~ 80.81 .." · 150.~Z" 80.92 ";: 1151.49: 80.25 i' '.' "15i~.57 79.23".. 151.69 79.23 ' "'151:69, .. 7099.61 ~' 7047~61~. 7115.13" :/7063.13: 7130.031:.' '707~:,~: 7148.87 :", 7,096.8~ 7163.81 7;1~11~81i 7179.31 iii ,712'.7,~ii 7192.35' ' 7i40.35' 7204.49~. ',"71,52,4~ 7217.151' ',TI65;i15" 7227.73.1!.' TI75:73~ 7237.58 .: `7185.58: 7246.17 ~' 7194~i71 7253.61;' 720i'.6i... 7260.08 ,' 7208,08 7265.42 . 7213.42': 7270.71:..' 7218.7. 7274.23=.7222,23; 7275.46' 7223.46, 7276.38. "!i ~;3~~ 7277.04" 7225,04~' 7277.55. '7225.55' 7278.131 .7226~13~ 7278.64 7226;64 7278.27='' 7226.;27' 367474.67 ,'5971~t65~80i -2979.2 .-4200:72~ 367471.69..5971-44030i -3004.74 ,.-4203.28 367468.89 .. :597i.;~,1.'5,58! -3029.51 -4205.66 367465.17 · 597!;383:95; -3061.19'!i '~'~'08.84;, 367462.49 =,' 59~1358.08) -3087.11 '~21.1.08! 367460.711 597,f32{~i0i~ -3116.21 ";-42i2.37i 367460.51 5971302~00~ -3143.22: -42i2~11'? 367461.641.59'7127,.'.4~60; -3170.6 ..:'421 367464.43. '5971243117[ -3201.981 ;' :,4~07,~2:. 367467.94'5~;1'~'i'4;25i -3230.84: :;'-4203.2} 367472.55:5971.184,16:: -3260.85' '-4198,09. 367478.371597;1153.901 -3291.01 . -4191.75: 367485.44 :, '5971'1.23.60! -3321.19:',-4184.1 367494.01= ,5971093.461 -3351.18' -4175.09~ 367504.25' 5971063.63: -3380.84 · -4164.34; 367521.94' 5971020143: -3423.74, .'4145-93: 367556.29 ' 5970952.781 -3490.8 ;" '4110,47 367603.5015970870.36} -3572.42 '-4061,83' 367650.54 ;'$~:{~'i: -3655.29 i!:' 367695.95,. 5970703.26" -3737.95'.-3966.57: 367741.87' 5970618.97' -3821.46 '; '"-3919,22i 367787.61 :,. 5970535:.71'; -3903.93:,...-3873.07.:. 367832.79. 5970452,15 -3986.72 ,,73825.49.! 367876.95' $~70~.'05: -4070.07 -3779.91 7273.29. 7221'~29 7273.31 7221.31, 7273.22 7221:.22~ 7272.91'" 7273.25;. 7221.25. 7273.92 7273.891 '~ 7221'[89: 7274.181. '..7222.18: 7274.62 .722~,~2' 7275.67 722~;67: 7277.411 ' 7225.41:. 7278.71 '. '"'7226171 7279.45 ', ' · "722~[45' 7279.81 '. 7227,8~1~ 7279.98~ .7227~98'~ 7281.56:' · 7229.56, 7286.15' 7234~'15: 7293.13"' .: 7~;~,1 7302.2 7250~2 7314.66~' 7262.66: 7327.97'.; !. ~275197. 7357.22,, 7305122 7372.3: '..7320.3 7276.99: 7224.99:. 367921.23,597028,~;77i -4155.6 i: r3734.17. 7275.29~ 7223,~9', 367964.52 i. 5970!97'23 -4239.41 '.. -3689.46; 7274.11 7222;11' 368006.74 '5970113.26' -4322.65-3645,82 7273.61' .7221.6' 368049.77 ~ 5970025;23 -4409.96 ' -3601.31: 368092.39 5969940.34 -4494.12"-3557.25' 368136.95~ 5969855.32 -4578.38 r3511.25 368181.67 'i 5969~7!..51~ -4661.43 -3465.12 368226.321 5969688~80:-4743.38 r34~9.08: 368271.25'5969603.97; -4827.44 -3372,72 368315.68 ==' 5§695!.8;89':~ -4911.77 ' -3326.85: 368359.48 5969434.59i -4995.32 .-3281".63i 368403.72 =.i 5969349A1;. -5079.75 :' -3235.95.' 368447.06 5969264.88:-5163.54 -3191,18; 368490.53'..5969178.1.8~ -5249.5= '-3146.25: 368532.16" 5969093.93'. -5333.04 ~31'03,2 368575.22" 5969008~i5· -5418.08 -3058.69 368618.26"i ~968923~'~'7" -5502.03 ;3014,.22! 368660.82: 5968838.55, -5586.23 -2970,~3' 368703.69= 5968752.66; -5671.39 -2925,91[ 368747.82=5968667.44~ -5755.86. -288(~.34. 368794.07 5968583.46; -5839.05 -2832.67~ 368840.47: 5,.q~841~9.72; -5922 '. '-2784186 368884.94 5968418.55' -6002.41:" -2739.02' 368931.59 5968333.29" -6086.88? -2690~94 368976.78 i: 59.68250.80': -6168.6 ::-2644,35 369021.59 "5~169i~; -6249.25: ':'-2,5..'~ ,~:,1.6, 369066.46: 5968087;05: -6330.83 ,'-255io91:. 369110.38..' 59~.8004.18 -6412.95 1-2506.59. 7377.71 .'..7325,7.,' 369125,42 5967975.3i, -6441.56 -2491!.07 7386.61, ' 7334.61. 369148.06 ii 5967931.63. -6484.85 '-2467.69 7396.88 "'."7344;88 369172.87"5967883.64' -6532.42 ='-~442.06 0.75 ' ~' ' 427~9~ 2.03" "430~61!' 8.49, :.,i::.! 434,22 10.09 '~'.':' 439;27! 8.92, ,.:/. i446;7i' 11.30' !;.'". 454,86 10.56 ;:' 7.23 i,i !~i,:,~.: 489~12 1.06 .... .;:{,:,502;,81' 2.94 ii:. , ,.- ,. 3.29. :' :.' .':' ;531.63 11.62 ::.': ~t'::' .... 7.61 'i': ?,"":~ ,564;5~' 13.02 ;.' ""'" 582.95' 11.90 ,;.:iii:::,1 60!~11i 7.52. ,:',;';": 623,71.. 6.00 .i' :::'.. :~,i 645,87 4.18,': =,:'~.!,' 1'66'7,2, 3.06 ",,'~' 68~.91; 1.59: ;.',.,.: ~'. :?11~;~ 4.72 i'::~,'. ~..' 736,15i .. 12.79 .'.,'.': ",.76i.19, 9.66...='~ 11.39 ":.. ?,~ :,i':': 810,031 8.92 .i i",~' ';. 83912Z,! 6.8oi':. !:;i~: ':: 9.98 ~.' 895,48: 9.76 · : .,'= 925;06' 9.39~,/ .: '. 955.25~ 10.72'i., 'i;'".." 985;9~i 12.07.' "1017,2:' 11.291: :'. 1:1063,71 8.97 ;;. ': · 1139,59~ 0.26';" '.:: 1234.48 0.92 :i'~' i =. '~ii ~": ~3§~;4 0.771 :,. ':.:. 1425~37. 0.79 "!: ...: !52i 0.38'..' ;. 1616.3: =... , . 0.48.." ..17!1.28 1.41 "":.1806;27:' 0.171" .1903.26 0.43~....~ .. 1998.25 1.39"i.'"' '2092;23: 0.53 '2190.21' 1.85: . ' '2285.21. 0.29:,..' ':'"=. 2381 0.62 ='....: .: '2476.19' 0.11. ":2570~i7: 1.32" ~ .:' '2666116!' 0.581:' ~;. ':2762.15 0.58 .:':". "2857,15. 0.84 !..' , 2953;15 1.20. ".;.':."3048,1.5. 1.21 .;':~. 3145.1~ 0.751, ;! .32~9;i 1.46:, :..'3335,09' 0.92 ~';....:'i':..' 3~130;09~ 0.20/...' 3525.08. 0.40 !~,'... '3621.08 2.88 '... ",:3717,05' 2.06 :'",: '.' 3812'.9' 1.24' .'3908.5b 1.92: ,. 4001,11. 1.66" · =.4098,28. 0.21" .' '.4192,31 1.32 ': .,'./==..4285.21~; 0.57 ,: :'i:; 0.81 ii '~: ."i.:. 4472,75. 2.05 .~' .. 4505.3 2.05'.',.':: '4554,5' :... .. . .. 0.00= ':. 4608.53 . .. = · . ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD2-42 API number ............... : 50-103-20374-00 Engineer ................. : St. Amour COUNTY: .................. : 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 ....... : 15.90 ft KB above permanent ....... : 52.05 ft DF above permanent ....... : 52.05 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: 151.86 degrees 29-May-2001 22:50:52 Page 1 of 7 Spud date ................ : 13-May-01 Last survey date ......... : 29-May-01 Total accepted surveys...: 159 MD of first survey ....... : 0.00 ft MD of last survey ........ : 13138.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 16-May-2001 Magnetic field strength..: 1147.15 HCNT Magnetic dec (+E/W-) ..... : 25.36 degrees Magnetic dip ............. : 80.53 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.15 HCNT Reference Dip ............ : 80.53 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.37 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.37 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 3 291.00 0.36 212.74 177.00 4 474.00 0.70 235.23 183.00 5 563.00 0.77 215.06 89.00 6 654.00 1.21 208.87 7 743.00 1.51 204.40 8 834.00 2.51 226.35 9 922.00 4.05 242.31 10 1013.00 6.14 247.15 11 1108.00 10.34 243.19 12 1204.00 12.95 240.46 13 1300.00 14.38 239.73 14 1395.00 17.00 238.00 15 1490.00 20.33 238.11 16 1585.00 22.93 236.82 17 1681.00 24.44 234.42 18 1776.00 27.14 234.33 19 1870.00 30.00 235.66 20 1966.00 33.33 236.74 21 2060.00 36.81 237.30 22 2156.00 40.11 237.71 23 2251.00 40.70 238.48 24 2347.00 40.71 239.64 25 2442.00 40.33 239.31 91.00 89.00 91.00 88.00 91.00 95.00 96.00 96.00' 95.00 95.00 95.00 96.00 95.00 94.00 96.00 94.00 96.00 95.00 96.00 95.00 26 2505.84 40.21 239.42 63.84 27 2657.00 39.98 238.55 151.16 28 2754.00 40.56 238.03 97.00 29 2848.00 41.27 236.98 94.00 30 2944.00 42.50 237.27 96.00 TVD depth (ft) 0.00 114.00 291.00 473.99 562.98 653.97 742.94 833.89 921.74 1012.38 1106.38 1200.40 1293.68 1385.13 1475.12 1563.42 1651.34 1736.87 1819.41 1901.11 1978.03 2053.19 2125.53 2198.31 2270.53 2319.24 2434.87 2508.89 2579.92 2651.39 29-May-2001 22:50:52 Page 2 of 7 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 0.00 0.00 0 0.00 0.00 0 0.27 -0.47 -0 0.68 -1.59 -1 1.01 -2.39 -2 .0O .00 .30 .53 .32 1.81 -3.73 -3 3.04 -5.62 -4 4.30 -8.09 -6 4.79 -10.86 -10 4.31 -14.25 -17 .14 .07 .01 .16 .49 3.65 -20.07 -29 3.71 -29.26 -46 4.42 -40.57 -66 5.79 -53.88 -88 7.81 -69.96 -114 .78 .84 .49 .46 .26 10.51 -88.81 -143.76 14.73 -110.60 -175.57 20.11 -134.68 -209.16 25.46 -160.44 -245.99 30.41 -188.45 -287.87 0.00 0.00 0.56 2.21 3.33 4.87 6.94 10.08 14.87 22.56 35.91 55.22 77.89 103.58 133.97 168.98 207.50 248.77 293.69 344.07 398.07 457.77 519.33 581.91 643.59 0.00 0.00 212.74 223.92 224.17 220.05 215.93 216.62 223.08 230.83 236.03 238.01 238.61 238.66 238.52 238.29 237.79 237.22 236.89 236.79 236.82 236.91 237.05 237.27 237.48 34.95 -217.84 -333.18 39.48 -249.90 -383.54 43.52 -282.45 -435.81 46.58 -314.63 -489.51 49.14 -345.98 -542.68 50.94 -367.01 -578.19 684.83 237.59 55.82 -417.17 -661.62 782.16 237.77 59.73 -450.13 -714.96 844.86 237.81 64.41 -483.20 -766.88 906.42 237.79 69.69 -517.99 -820.71 970.51 237.74 0.00 0.00 0.20 0.21 0.30 0.50 0.36 1.37 2.02 2.34 4.46 2.78 1.50 2.80 3.51 2.78 1.87 2.84 3.12 3.52 3.72 3.45 0.81 0.79 0.46 0.22 0.40 0.69 1.05 1.30 TIP MWD MWD MWD MWD MWD MWD lVi~D MWD Fi~D lVlWD 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 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 29-May-2001 22:50:52 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 31 3040.00 42.39 235.68 96.00 2722.23 32 3134.00 42.69 235.99 94.00 2791.49 33 3229.00 42.88 237.16 95.00 2861.21 34 3325.00 42.96 237.05 96.00 2931.52 35 3422.00 42.98 235.58 97.00 3002.49 95.00 95.00 96.00 95.00 96.00 94.00 96.00 96.00 95.00 95.00 96.00 94.00 96.00 96.00 94.00 36 3517.00 43.26 236.65 37 3612.00 43.27 235.25 38 3708.00 43.33 236.56 39 3803.00 43.31 235.77 40 3899.00 43.65 236.03 41 3993.00 43.85 236.46 42 4089.00 44.10 236.40 43 4185.00 44.48 236.26 44 4280.00 44.82 237.19 45 4375.00 44.18 236.69 3071.84 3141.02 3210.88 3280.00 3349.66 3417.56 3486.65 3555.37 3622.95 3690.71 3759.67 3827.17 3895.88 3964.88 4033.45 4104.10 4174.60 4245.10 4315.64 4385.33 46 4471.00 43.98 236.33 47 4565.00 44.23 236.65 48 4661.00 44.36 236.92 49 4757.00 43.74 236.31 50 4851.00 42.58 235.94 51 4947.00 42.65 235.33 96.00 52 5043.00 42.83 235.48 96.00 53 5139.00 42.66 236.32 96.00 54 5235.00 42.77 235.86 96.00 55 5330.00 42.86 235.72 95.00 75.77 -553.77 -874.72 82.44 -589.46 -927.30 88.39 -625.01 -981.16 93.81 -660.51 -1036.05 100.19 -697.18 -1091.06 106.69 113.40 120.23 126.69 133.55 -733.38 -1144.97 -769.83 -1198.91 -806.74 -1253.43 -843.03 -1307.57 -880.06 -1362.27 139.91 -916.18 -1416.31 146.22 -953.04 -1471.85 152~.68 -990.20 -1527.64 158.65 -1026.83 -1583.46 164.36 -1063.15 -1639.27 170.59 -1100.00 -1694.96 176.71 -1.136.12 -1749.51 182.64 -1172.85 -1805.60 188.74 -1209.57 -1861.33 195.16 -1245.41 -1914.72 202.21 -1282.10 -1968.37 209.54 -1319.09 -2022.00 216.30 -1355.62 -2075.96 222.85 -1391.95 -2130.00 229.68 -1428.25 -2183.40 238.15 -1466.56 -2237.05 247.52 -1505.00 -2289.06 255.38 -1542.12 -2341.80 261.83 -1578.15 -2395.49 267.18 -1612.83 -2448.97 56 5427.00 42.78 233.22 97.00 4456.48 57 5522.00 43.03 233.85 95.00 4526.07 58 5617.00 42.50 235.87 95.00 4595.81 59 5713.00 42.18 236.40 96.00 4666.77 60 5808.00 42.10 237.69 95.00 4737.22 1035.28 1098.80 1163.32 1228.69 1294.79 237.66 237.56 237.50 237.48 237.42 1359.71 1424.79 1490.61 1555.78 1621.82 1686.81 1753.46 1820.49 1887.26 1953.84 2020.62 2086.04 2153.08 2219.83 2284.12 237.36 237.30 237.23 237.19 237.14 237.10 237.08 237.05 237.04 237.03 237.02 237.00 236.99 236.98 236.96 2349.10 2414.23 2479.38 2544.49 2609.05 236.92 236.88 236.86 236.84 236.81 2674.91 2739.49 2803.95 2868.61 2932.34 236.75 236.68 236.63 236.62 236.63 3 of 7 DLS (deg/ 100f) 1.12 0.39 0.86 0.11 1.03 0.82 1.01 0.94 0.57 0.40 0.38 0.26 0.41 0.78 0.77 0.33 0.36 0.24 0.78 1.26 0.44 0.22 0.62 0.34 0.14 1.75 0.52 1.55 0.50 0.91 Srvy tool type MWD MWD MWD MWD MWD MWD M-WD 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 SCHLUI~BERGER Survey Report 29-May-2001 22:50:52 Page 4 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5904.00 42.17 237.46 62 5998.00 42.14 237.23 63 6095.00 42.03 237.60 64 6189.00 42.03 237.48 65 6285.00 41.88 237.61 66 6380.00 41.83 237.43 67 6475.00 41.56 236.73 68 6571.00 41.12 236.07 69 6666.00 40.73 235.59 70 6761.00 40.77 235.48 96.00 94.00 97.00 94.00 96.00 95.00 95.00 96.00 95.00 95.00 TVI) Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg (ft) (ft) (ft) (ft) (ft) (deg) 100f 4808.41 4878.09 4950.08 5019.91 5091.30 5162.06 5232.99 5305.07 5376.85 5448.82 71 6855.00 40.42 236.03 94.00 5520.19 72 6952.00 41.89 237.93 97.00 5593.23 73 7048.00 41.95 238.45 96.00 5664.66 74 7143.00 42.08 237.68 95.00 5735.24 75 7239.00 42.00 237.13 96.00 5806.54 76 7334.00 42.28 236.89 95.00 5876.98 77 7429.00 42.19 236.60 95.00 5947.32 78 7525.00 41.88 236.94 96.00 6018.63 79 7621.00 41.59 235.82 96.00 6090.26 80 7716.00 42.82 236.46 95.00 6160.63 96.00 95.00 96.00 95.00 95.O0 81 7812.00 43.53 238.22 82 7907.00 43.71 237.05 83 8003.00 43.77 237.75 84 8098.00 43.61 236.69 85 8193.00 43.76 237.05 86 8289.00 43.76 236.02 87 8383.00 43.95 235.87 88 8480.14 43.95 234.64 89 8548.00 43.93 235.37 90 8580.00 43.81 234.45 96.00 94.00 97.14 67.86 32.00 6230.65 6299.42 6368.78 6437.47 6506.17 6575.51 6643.29 6713.23 6762.09 6785.16 272.00 -1647.36 -2503.33 276.96 -1681.40 -2556.44 282.00 -1716.41 -2611.22 286.74 -1750.19 -2664.33 291.57 -1784.63 -2718.48 296.37 -1818.67 -2771.96 301.63 -1853.01 -2825.00 307.66 -1888.10 -2877.82 314.20 -1923.05 -2929.30 321.03 -1958.15 -2980.43 327.54 -1992.57 -3030.99 332.95 -2027.33 -3084.52 337.06 -2061.14 -3139.02 341.27 -2094.78 -3192.98 346.26 -2129.41 -3247.14 351.65 -2164.11 -3300.61 357.34 -2199.13 -3354.01 363.05 -2234.35 -3407.77 369.15 -2269.73 -3460.99 375.50 -2305.29 -3513.99 380.67 -2340.73 -3569.29 385.50 -2375.81 -3624.64 390.66 -2411.57 -3680.56 395.97 -2447110 -3735.73 401.68 -2482.96 -3790.68 407.84 -2519.57 -3846.06 414.55 -2556.04 -3900.02 422.31 -2594.46 -3955.42 427.93 -2621.47 -3993.99 430.61 -2634.21 -4012.14 2996.74 3059.82 3124.83 3187.76 3251.93 Srvy Tool / tool qual ) type type 3315.31 3378.50 3441.91 3504.13 3566.13 236.65 0.18 MWD 236.67 0.17 MWD 236.68 0.28 MWD 236.70 0.09 MWD 236.72 0.18 MWD 3627.29 3691.12 3755.23 3818.80 3883.08 236.73 0.14 MWD 236.74 0.57 MWD 236.73 0.65 MWD 236.72 0.53 MWD 236.70 0.09 MWD 3946.82 4010.68 4074.96 4138.86 4202.67 236.68 0.53 MWD 236.68 1.99 MWD 236.71 0.37 MWD 236.73 0.56 MWD 236.74 0.39 MWD 4268.35 4333.88 4400.24 4465.86 4531.48 236.75 0.34 MWD 236.75 0.23 MWD 236.75 0.40 MWD 236.74 0.83 MWD 236 . 73 1.37 MWD 4597.87 4662.99 4730.39 4777.45 4799.62 236.74 1.46 MWD 236.76 0.87 MWD 236.77 0.51 MWD 236.77 0.79 MWD 236.77 0.31 MWD 236.77 0.74 MWD 236.76 0.23 MWD 236.74 0.88 MWD 236.72 0.75 MWD 236.71 2.03 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 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) Course length (ft) TVD depth (ft) 91 8612.00 43.90 230.53 32.00 6808.24 92 8643.00 44.91 226.30 31.00 6830.39 93 8678.00 46.96 223.02 35.00 6854.74 94 8709.00 49.21 219.41 31.00 6875.45 95 8737.00 51.21 216.84 28.00 6893.37 35.00 32.00 32.00 31.00 34.00 96 8772.00 53.01 212.75 97 8804.00 53.84 210.06 98 8836.00 53.76 209.65 99 8867.00 53.59 208.54 100 8901.00 53.57 207.15 6914.87 6933.94 6952.84 6971.20 6991.39 101 8931.00 53.67 202.82 30.00 7009.19 102 8966.00 54.36 199.64 35.00 7029.76 103 8998.00 55.35 194.69 32.00 7048.18 104 9027.00 56.33 190.69 29.00 7064.47 105 9061.00 58.17 188.58 34.00 7082.87 106 9093.00 58.74 186.43 107 9123.00 58.97 184.99 108 9152.00 59.20 185.99 109 9189.00 59.58 185.47 110 9219.00 60.68 184.44 32.00 30.00 29.00 37.00 30.00 111 9252.00 63.30 180.69 33.00 112 9282.00 65.16 178.22 30.00 113 9312.00 67.12 175.16 30.00 114 9346.00 69.17 172.75 34.00 115 9377.00 70.92 171.50 31.00 7099.61 7115.13 7130.03 7148.87 7163.81 7179.31 7192.35 7204.49 7217.15 7227.73 116 9409.00 73.22 169.17 32.00 7237.58 117 9441.00 75.64 167.12 32.00 7246.17 118 9473.00 77.47 164.67 32.00 7253.61 119 9505.00 79.21 161.65 32.00 7260.08 120 9537.00 81.56 158.54 32.00 7265.42 29-May-2001 22:50:52 __ Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 434.22 -2647.71 -4029.72 439.27 -2662.11 -4045.93 446.71 -2680.00 -4063.59 454.86 -2697.35 -4078.77 463.52 -2714.28 -4092.05 476 489 502 516 531 .09 -2736.96 -4107.79 .12 -2758.89 -4121.18 .81 -2781.29 -4134.04 .32 -2803.11 -4146.18 .63 -2827.30 -4158.96 546 564 582 601 623 .11 -2849.18 -4169.16 .55 -2875.58 -4179.41 .95 -2900.57 -4187.12 .11 -2923.97 -4192.38 .71 -2952.16 -4197.16 645 667 687 714 736 .87 -2979.20 -4200.72 .19 -3004.74 -4203.28 .91 -3029.51 -4205.66 .35 -3061.19 -4208.84 .14 -3087.11 -4211.08 761 785 810 839 866 .19 -3116.21 -4212.37 .13 -3143.22 -4212.11 .03 -3170.60 -4210.52 .27 -3201.98 -4207.20 .60 -3230.84 -4203.20 895.47 -3260.85 -4198.09 925.06 -3291.01 -4191.75 955.25 -3321.19 -4184.17 985.98 -3351.18 -4175.09 1017.20 -3380.84 -4164.34 Page Total displ (ft) At Azim (deg) 4821.72 4843.17 4867.77 4890.00 4910.41 4936.08 4959.40 4982.55 5004.82 5028.97 5049.72 5073.10 5093.65 5111.33 5131.42 5149.92 5166.82 5183.19 5204.35 5221.44 5239.74 5255.64 5270.79 5287.07 5301.44 5315.74 5329.31 5342.06 5353.67 5363.94 236.69 236.66 236.59 236.52 236.44 236.33 236.20 236.07 235.94 235.79 235.65 235.47 235.29 235.11 234.88 234.66 234.44 234.23 233.97 233.76 233.51 233.27 233.02 232.73 232.45 232.16 231.86 231.56 231.25 230.93 5 of 7 DLS (deg/ 100f) 8.49 10.09 8.92 11.30 10.04 10.56 7.23 1.06 2.94 3.29 11.62 7.61 13.02 11.90 7.52 6.00 4.18 3.06 1.59 4.72 12.79 9.66 11.39 8.92 6.80 9.98 9.76 9.39 10.72 12.07 Srvy tool type 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 ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 121 9584.00 85.54 155.01 122 9660.00 89.14 149.21 123 9755.00 89.38 149.25 124 9851.00 89.52 150.12 125 9946.00 89.69 150.83 126 10042.00 89.69 150.07 127 10137.00 89.62 150.42 128 10232.00 89.76 150.85 129 10327.00 90.69 151.81 130 10424.00 90.82 151.91 131 10519.00 91.23 151.93 132 10613.00 90.21 152.74 133 10711.00 90.38 153.23 134 10806.00 90.00 151.51 135 10902.00 89.97 151.23 136 10997.00 90.14 150.67 137 11091.00 90.24 150.67 138 11187.00 89.35 151.57 139 11283.00 89.86 151.35 140 11378.00 90.17 151.80 141 11474.00 89.49 151.37 142 11569.00 89.97 152.40 143 11666.00 88.80 152.41 144 11760.00 89.07 153.06 145 11856.00 89.38 151.69 146 11951.00 89.73 152.49 147 12046.00 89.83 152.33 148 12142.00 89.97 152.69 149 12238.00 88.15 150.61 150 12334.00 86.36 149.77 47.00 76.00 95.00 96.00 95.00 96.00 95.00 95.00 95.00 97.00 95.00 94.00 98.00 95.00 96.00 95.00 94.00 96.00 96.00 95.00 96.00 95.00 97.00 94.00 96.00 95.00 95.00 96.00 96.00 96.00 depth (ft) 7270.70 7274.23 7275.46 7276.38 7277.03 7277.55 7278.13 7278.64 7278.27 7276.99 7275.29 7274.11 7273.60 7273.29 7273.31 7273.22 7272.91 7273.25 7273.92 7273.89 7274.18 7274.62 7275.66 7277.41 7278.71 7279.45 7279.81 7279.98 7281.56 7286.15 29-May-2001 22:50:52 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) 1063.71 -3423.74 -4145.93 5376.87 1139.58 -3490.80 -4110.43 5392.71 1234.48 -3572.42 -4061.83 5409.31 1330.40 -3655.29 -4013.38 5428.48 1425.37 -3737.95 -3966.57 5450.31 1521.34 -3821.46 -3919.22 5473.92 1616.30 -3903.93 -3872.07 5498.51 1711.28 -3986.72 -3825.49 5525.25 1806.27 -4070.07 -3779.91 5554.57 1903.26 -4155.60 -3734.17 5586.86 1998.25 -4239.40 -3689.46 5620.02 2092.23 -4322.65 -3645.82 5654.85 2190.21 -4409.96 -3601.31 5693.60 2285.20 -4494.12 -3557.25 5731.59 2381.20 -4578.38 -3511.25 5769.79 2476.19 -4661.43 -3465.12 5808.27 2570.17 -4743.38 -3419.08 5847.20 2666.16 -4827.44 -3372.72 5888.92 2762.15 -4911.77 -3326.85 5932.40 2857.15 -4995.32 -3281.63 5976.81 2953.15 -5079.75 -3235.95 6022.89 3048.14 -5163.54 -3191.18 6070.07 3145.13 -5249.50 -3146.25 6120.14 3239.10 -5333.04 -3103.20 6170.18 3335.09 -5418.08 -3058.69 6221.83 3430.09 -5502.03 -3014.22 6273.59 3525.08 -5586.23 -2970.23 6326.78 3621.07 -5671.39 -2925.91 6381.66 3717.05 -5755.85 -2880.34 6436.32 3812.90 -5839.05 -2832.67 6489.88 Page At Azim (deg) 230.45 229.66 228.67 227.67 226.70 225.72 224.77 223.82 222.88 221.94 221.03 220.15 219.24 218.36 217.49 216.63 215.78 214.94 214.11 213.30 212.50 211.72 210.94 210.19 209.45 208.72 208.00 207.29 206.58 205.88 6 of 7 DLS (deg/ i00f) 11.29 8.97 0.26 0.92 0.77 0.79 0.38 0.48 1.41 0.17 0.43 1.39 0.53 1.85 0.29 0.62 0.11 1.32 0.58 0.58 0.84 1.20 1.21 0.75 1.46 0.92 O.20 0.40 2.88 2.06 Srvy tool type MWD IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP 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 29-May-2001 22:50:52 Page 7 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 151 12430.00 85.30 150.31 152 12523.00 83.51 150.32 153 12621.00 81.88 150.38 154 12716.00 82.02 150.24 155 12810.00 80.78 150.17 156 12905.00 80.81 150.72 157 13000.00 80.92 151.49 158 13083.00 79.23 151.69 Projected To TD of 13138.00 159 13138.00 79.23 151.69 96.00 93.00 98.00 95.00 94.00 95.00 95.00 83.00 55.00 TV/D Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 7293.13 7302.20 7314.66 7327.96 7342.02 7357.22 7372.30 7386.60 7396.88 3908.59 -5922.00 -2784.86 4001.11 -6002.41 -2739.02 4098.28 -6086.88 -2690.94 4192.31 -6168.60 -2644.35 4285.21 -6249.25 -2598.16 4378.96 -6330.83 -2551.91 4472.74 -6412.94 -2506.59 4554.50 -6484'.85 -2467.69 4608.53 -6532.42 -2442.06 6544.12 6597.81 6655.17 6711.49 6767.84 6825.80 6885.41 6938.50 Srvy tool type 205 . 19 1 . 24 IMP 204 . 53 1 . 92 IMP 203 . 85 1.66 IMP 203 . 20 0 . 21 IMP 202 . 58 1 . 32 IMP 201.95 0.57 IMP 201.35 0.81 IMP 200.83 2.05 IMP 0.00 6973.97 200.50 Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Projected ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD2-42PH API number ............... : 50-103-20374-70 Engineer ................. : St. Amour COUNTY: .................. : 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 ....... : 15.90 ft KB above permanent ....... : DF above permanent ....... : 52.05 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: 236.90 degrees 20-May-2001 19:20:25 Page 1 of 5 Spud date ................ : 13-May-01 Last survey date ......... : 20-May-01 Total accepted surveys...: 99 MD of first survey ....... : 0.00 ft MD of last survey ........ : 9507.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 16-May-2001 Magnetic field strength..: 1147.15 HCNT Magnetic dec (+E/W-) ..... : 25.36 degrees Magnetic dip ............. : 80.53 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.15 HCNT Reference Dip ............ : 80.53 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.37 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.37 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 2ol-0 '7 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 20-May-2001 19:20:25 Page 2 of 5 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 3 291.00 0.36 212.74 4 474.00 0.70 235.23 5 563.00 0.77 215.06 6 654.00 1.21 208.87 7 743.00 1.51 204.40 8 834.00 2.51 226.35 9 922.00 4.05 242.31 10 1013.00 6.14 247.15 11 1108.00 10.34 243.19 12 1204.00 12.95 240.46 13 1300.00 14.38 239.73 14 1395.00 17.00 238.00 15 1490.00 20.33 238.11 16 1585.00 22.93 236.82 17 1681.00 24.44 234.42 18 1776.00 27.14 234.33 19 1870.00 30.00 235.66 20 1966.00 33.33 236.74 21 2060.00 36.81 237.30 22 2156.00 40.11 237.71 23 2251.00 40.70 238.48 24 2347.00 40.71 239.64 25 2442.00 40.33 239.31 26 2505.84 40.21 239.42 27 2657.00 39.98 238.55 28 2754.00 40.56 238.03 29 2848.00 41.27 236.98 30 2944.00 42.50 237.27 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 0.00 0.00 0.00 0.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 177.00 291.00 0.51 -0.47 -0.30 0.56 183.00 473.99 2.15 -1.59 -1.53 2.21 89.00 562.98 3.25 -2.39 -2.32 3.33 91.00 653.97 4.66 -3.73 -3.14 4.87 89.00 742.94 6.48 -5.62 -4.07 6.94 91.00 833.89 9.45 -8.09 -6.01 10.08 88.00 921.74 14.44 -10.86 -10.16 14.87 91.00 1012.38 22.43 -14.25 -17.49 22.56 95.00 1106.38 35.91 -20.07 -29.78 35.91 96.00 1200.40 55.21 -29.26 -46.84 55.22 96.00 1293.68 77.86 -40.57 -66.49 77.89 95.00 1385.13 103.53 -53.88 -88.46 103.58 95.00 1475.12 133.92 -69.96 -114.26 133.97 95.00 96.00 95.00 94.00 96.00 94.00 96.00 95.00 96.00 95.00 63.84 151.16 97.00 94.00 96.00 1563.42 1651.34 1736.87 1819.41 1901.11 1978.03 2053.19 2125.53 2198.31 2270.53 2319.24 2434.87 2508.89 2579.92 2651.39 168.93 -88.81 -143.76 168.98 207.48 -110.60 -175.57 207.50 248.77 -134.68 -209.16 248.77 293.69 -160.44 -245.99 293.69 344.07 -188.45 -287.87 344.07 398.07 -217.84 -333.18 457.77 -249.90 -383.54 519.33 -282.45 -435.81 581.89 -314.63 -489.51 643.55 -345.98 -542.68 684.78 -367.01 -578.19 782.07 -417.17 -661.62 844.75 -450.13 -714.96 906.31 -483.20 -766.88 970.40 -517.99 -820.71 0.00 0.00 212.74 223.92 224.17 220.05 215.93 216.62 223.08 230.83 236 03 238.01 238 61 238.66 238 52 238 29 237.79 237 22 236.89 236 79 398.07 457.77 519.33 581.91 643.59 236.82 236.91 237.05 237.27 237.48 684.83 782.16 844.86 906.42 970.51 237.59 237.77 237.81 237.79 237.74 DLS (deg/ 100f) 0.00 0.00 0.20 0.21 0.30 0.50 0.36 1.37 2.02 2.34 4.46 2.78 1.50 2.80 3.51 2.78 1.87 2.84 3.12 3.52 3.72 3.45 0.81 0.79 0.46 0.22 0.40 0.69 1.05 1.30 Srvy tool type TIP 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 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 3040.00 42.39 235.68 32 3134.00 42.69 235.99 33 3229.00 42.88 237.16 34 3325.00 42.96 237.05 35 3422.00 42.98 235.58 36 3517.00 43.26 236.65 37 3612.00 43.27 235.25 38 3708.00 43.33 236.56 39 3803.00 43.31 235.77 40 3899.00 43.65 236.03 41 3993.00 43.85 236.46 42 4089.00 44.10 236.40 43 4185.00 44.48 236.26 44 4280.00 44.82 237.19 45 4375.00 44.18 236.69 96.00 94.00 95.00 96.00 97.00 95.00 95.00 96.00 95.00 96.00 94.00 96.00 96.00 95.00 95.00 20-May-2001 19:20:25 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 2722.23 2791.49 2861.21 2931.52 3002.49 3071.84 3141.02 3210.88 3280.00 3349.66 3417.56 3486.65 3555.37 3622.95 3690.71 Page 3 of 5 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 1035.18 -553.77 -874.72 1035.28 237.66 1098.73 -589.46 -927.30 1098.80 237.56 1163.25 -625.01 -981.16 1163.32 237.50 1228.62 -660.51 -1036.05 1228.69 237.48 1294.73 -697.18 -1091.06 1294.79 237.42 1359.66 -733.38 -1144.97 1359.71 237.36 1424.76 -769.83 -1198.91 1424.79 237.30 1490.59 -806.74 -1253.43 1490.61 237.23 1555.76 -843.03 -1307.57 1555.78 237.19 1621.80 -880.06 -1362.27 1621.82 237.14 1686.80 -916.18 -1416.31 1686.81 237.10 1753.46 -953.04 -1471.85 1753.46 237.08 1820.49 -990.20 -1527.64 1820.49 237.05 1887.25 -1026.83 -1583.46 1887.26 237.04 1953.84 -1063.15 -1639.27 1953.84 237.03 -1694.96 2020.62 237.02 -1749.51 2086.04 237.00 -1805.60 2153.08 236.99 -1861.33 2219.83 236.98 -1914.72 2284.12 236.96 46 4471.00 43.98 236.33 96.00 3759.67 2020.62 -1100.00 47 4565.00 44.23 236.65 94.00 3827.17 2086.04 -1136.12 48 4661.00 44.36 236.92 96.00 3895.88 2153.08 -1172.85 49 4757.00 43.74 236.31 96.00 3964.88 2219.82 -1209.57 50 4851.00 42.58 235.94 94.00 4033.45 2284.12 -1245.41 2349.10 -1282.10 -1968.37 2349.10 236.92 2414.23 -1319.09 -2022.00 2414.23 236.88 2479.38 -1355.62 -2075.96 2479.38 236.86 2544.49 -1391.95 -2130.00 2544.49 236.84 2609.04 -1428.25 -2183.40 2609.05 236.81 51 4947.00 42.65 235.33 96.00 4104.10 52 5043.00 42.83 235.48 96.00 4174.60 53 5139.00 42.66 236.32 96.00 4245.10 54 5235.00 42.77 235.86 96.00 4315.64 55 5330.00 42.86 235.72 95.00 4385.33 56 5427.00 42.78 233.22 97.00 4456.48 57 5522.00 43.03 233.85 95.00 4526.07 58 5617.00 42.50 235.87 95.00 4595.81 59 5713.00 42.18 236.40 96.00 4666.77 60 5808.00 42.10 237.69 95.00 4737.22 2674.90 -1466.56 -2237.05 2674.91 236.75 2739.47 -1505.00 -2289.06 2739.49 236.68 2803.92 -1542.12 -2341.80 2803.95 236.63 2868.58 -1578.15 -2395.49 2868.61 236.62 2932.31 -1612.83 -2448.97 2932.34 236.63 1.12 0.39 0.86 0.11 1.03 0.82 1.01 0.94 0.57 0.40 0.38 0.26 0.41 0.78 0.77 0.33 0.36 0.24 0.78 1.26 0.44 0.22 0.62 0.34 0.14 1.75 0.52 1.55 0.50 0.91 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD lVfWD 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 6-axis 6-axis 6-axis 6-axis [ (c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 20-May-2001 19:20:25 Page 4 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5904.00 42.17 237.46 62 5998.00 42.14 237.23 63 6095.00 42.03 237.60 64 6189.00 42.03 237.48 65 6285.00 41.88 237.61 66 6380.00 41.83 237.43 67 6475.00 41.56 236.73 68 6571.00 41.12 236.07 69 6666.00 40.73 235.59 70 6761.00 40.77 235.48 96.00 94.00 97.00 94.00 96.00 95.00 95.00 96.00 95.00 95.00 71 6855.00 40.42 236.03 94.00 72 6952.00 41.89 237.93 97.00 73 7048.00 41.95 238.45 96.00 74 7143.00 42.08 237.68 95.00 75 7239.00 42.00 237.13 96.00 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 4808.41 4878.09 4950.08 5019.91 5091.30 5162.06 5232.99 5305.07 5376.85 5448.82 5520.19 5593.23 5664.66 5735.24 5806.54 76 7334.00 42.28 236.89 95.00 5876.98 77 7429.00 42.19 236.60 95.00 5947.32 78 7525.00 41.88 236.94 96.00 6018.63 79 7621.00 41.59 235.82 96.00 6090.26 80 7716.00 42.82 236.46 95.00 6160.63 81 7812.00 43.53 238.22 82 7907.00 43.71 237.05 83 8003.00 43.77 237.75 84 8098.00 43.61 236.69 85 8193.00 43.76 237.05 86 8289.00 43.76 236.02 87 8383.00 43.95 235.87 88 8480.14 43.95 234.64 89 8574.00 43.46 236.39 90 8670.00 43.08 237.49 96.00 95.00 96.00 95.00 95.00 96.00 94.00 97.14 93.86 96.00 6230.65 6299.42 6368.78 6437.47 6506.17 6575.51 6643.29 6713.23 6781.08 6850.98 2996.71 -1647.36 3059.80 -1681.40 3124.81 -1716.41 3187.74 -1750.19 3251.91 -1784.63 -2503.33 -2556.44 -2611.22 -2664.33 -2718.48 3315.30 -1818.67 3378.49 -1853.01 3441.90 -1888.10 3504.12 -1923.05 3566.11 -1958.15 -2771.96 -2825.00 -2877.82 -2929.30 -2980.43 3627.26 -1992.57 3691.09 -2027.33 3755.21 -2061.14 3818.78 -2094.78 3883.07 -2129.41 -3030.99 -3084.52 -3139.02 -3192.98 -3247.14 3946.81 -2164.11 4010.66 -2199.13 4074.94 -2234.35 4138.84 -2269.73 4202.65 -2305.29 -3300.61 -3354.01 -3407.77 -3460.99 -3513.99 4268.33 -2340.73 4333.86 -2375.81 4400.23 -2411.57 4465.85 -2447.10 4531.47 -2482.96 -3569.29 -3624.64 -3680.56 -3735.73 -3790.68 4597.86 -2519.57 4662.98 -2556.04 4730.37 -2594.46 4795.19 -2631.18 4860.99 -2667.08 -3846.06 -3900.02 -3955.42 -4008.86 -4064.01 2996.74 3059.82 3124.83 3187.76 3251.93 236.65 236.67 236.68 236.70 236.72 3315.31 3378.50 3441.91 3504.13 3566.13 236.73 236.74 236.73 236.72 236.70 3627.29 3691.12 3755.23 3818.80 3883.08 236.68 236.68 236.71 236.73 236.74 3946.82 4010.68 4074.96 4138.86 4202.67 236.75 236.75 236.75 236.74 236.73 4268.35 4333.88 4400.24 4465.86 4531.48 236.74 236.76 236.77 236.77 236.77 4597.87 4662.99 4730.39 4795.22 4861.02 236.77 236.76 236.74 236.72 236.72 DLS (deg/ 100f) 0.18 0.17 0.28 0.09 0.18 0.14 0.57 0.65 0.53 0.09 0.53 1.99 0.37 0.56 0.39 0.34 0.23 0.40 0.83 1.37 1.46 0.87 0.51 0.79 0.31 0.74 0.23 0.88 1.39 0.88 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 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 20-May-2001 19:20:25 Page 5 of 5 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) Vertical Displ Displ Total At section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (deg) DLS Srvy Tool (deg/ tool qual 100f) type type 91 8766.00 42.44 239.20 96.00 6921.47 4926.15 -2701.29 -4119.48 4926.16 236.75 1.38 92 8861.00 42.49 238.75 95.00 6991.55 4990.24 -2734.34 -4174.45 4990.25 236.77 0.32 93 8958.00 42.37 239.26 97.00 7063.15 5055.64 -2768.04 -4230.55 5055.65 236.80 0.38 94 9053.00 42.37 239.85 95.00 7133.33 5119.59 -2800.48 -4285.74 5119.60 236.84 0.42 95 9148.00 41.78 239.04 95.00 7203.85 5183.19 -2832.84 -4340.56 5183.19 236.87 0.84 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 96 9244.00 42.19 240.05 96.00 7275.21 5247.34 -2865.39 -4395.92 5247.34 236.90 0.82 97 9339.00 43.26 239.66 95.00 7345.00 5311.71 -2897.76 -4451.65 5311.71 236.94 1.16 98 9434.00 43.76 240.45 95.00 7413.90 5377.01 -2930.41 -4508.33 5377.02 236.98 0.78 MWD 6-axis MWD 6-axis MWD 6-axis Final Survey Projected to ?D of 9507 ft: 99 9507.00 43.76 240.45 73.00 7466.62 5427.40 -2955.31 -4552.25 5427.41 237.01 0.00 MWD [(c)2001 Anadrill IDEAL ID6_iC_08] MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD2-42 Date Dispatche 11-Jun-01 Installation/Rig Doyen 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Received By: ~ Please sign and return to: v,ll Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD2-42PH Date Dispatche 10-Jun-01 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 /.olo Received By:~ .~.~_..12~.,~ Please sign and return .to: ~' Anadfill LWD Division 3940 Amtic Blvd, Suite 300 Anchorage; Alaska 99503 nrosel @ sib.com Fax: 907-561-8417 ,. LWD Loci Deliver)/V1.1, Dec '97 , 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: Kuparuk 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 Disposal durin the second uarter 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, IC-12I, 1C-I23, 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, lJ-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 '13-o45 Total Volumes into Annuli ~or which Disposal Authorization Expired during the second quarter 2001: 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, cD'1- 2000 35, CD 1-32, CD 1-24, 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 Zoo -oi :/ 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 RECEIVED PM/skad JUL 1 9 2001 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 Alaska 0il & Gas Cons. Commission Anchorage Annular Dis vosal durin the second ,uarter 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, 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 1J-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 for which Disposal Authorization Expired during the second quarter 2001: 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, CDI-40, CD1- 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, CDI~NQ1 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 30, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Extendincl Well Depth on CD2-42 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests approval for drilling CD2-42 499 ft measured depth past its original permitted total depth. The well was originally permitted to drill to 12639 ft measured depth, the revised depth is 13138 ft measured depth. Due to Iow resistivity in the area, and the need to determine the thickness of the zone, additional footage was required for LWD tools to cross the base of the reservoir. Verbal approval to drill 400 ft past the original permit depth was granted by Julie Heusser on May 27, 2001. The reservoir was thicker than anticipated, so in order to Icg the bottom of the formation with LWD tools, additional footage was needed. Verbal approval to drill more than 400 ft extra was granted by Steve Davies on May 30, 2001. Please find attached form 10-403. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Vern Johnson Drilling Engineer CC: CD2-42 Well File Chip Alvord Scott Reynolds Nancy Lambert Sharon AIIsup-Drake ATO-868 ATO-838 Anadarko ATO- 1530 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 _ Variance _X Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1984' FNL, 1513' FEL, Sec. 2 T11N, R4E, UM At top of productive interval 106' FNL, 359' FEL, Sec. 10, TllN, R4E, UM At effective depth At total depth 2043' FSL, 1321' FWL, Sec. 11, T11 N, R4E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Coleville River Unit 8. Well number CD2-42 9. Permitnumber/approvalnumber 201-067 10. APInumber 50-103-20374 11. Field / Pool Coleville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measu red true vertical Effective depth: measured true vertical Casing Length Conductor 1 14' Surface 2544' Production 9596' 13138' 7397' 13138' 7397' Size 16" 9-5/8" 7" feet Plugs (measured) feet feet Junk (measured) feet Cemented 10 yds portland $ ready mix cmt 380 Sx AS Ill L & 230 Sx 15.8 class G 117' Sx 15.8 class G Measured Depth True vertical Depth 108' 108' 2581' 2377' 9633' 7273' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4.5" 12.6#, L-80 @ +/- 9229' MD (PLANNED) 7" Baker S-3 Permanent Packer, +/- 9154' MD (PLANNED) Alaska 0il & Gas C{;ns. C0~fissi0~ Anchorage 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation May 29, 2001 16. If proposal was verbally approved Julie Heusser/Steve Davies 27-May-2001 /30-May-01 Name of approver Date approved Oil __X Gas __ Suspended Service __ 17. I hereby cert~,,t~at the~ing is~ue and correct to the best of my knowledge. Signed ~ ~'0~,.C~lt~ j~LlJl)-~ Title: Alpine Drilling Team Leader Chip Alvord FOR COMMISSION USE ONLY Questions? Carl Vern Johnson 265-6081 Date ~' ~(~ "~1~1 Prepared by Vern Johnson Conditions of approval: Notify Commission so representative may witness Approval no., '~ I } ~)/),~ Plug integrity__ BOP Test _ Location clearance__ _ _ Mechanical Integrity Test_ Subsequent form required 10- HO Approved by order of the Commission Commissioner Date ' _ .... Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 25, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD2-42 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that CD2-42 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. This is the first permit for annular disposal of drilling waste on CD2 pad. Provided that approval is granted, it is intended to begin annular injection on CD2-42 while drilling the 6-1/8" hole section of CD2-42, approximately May 26, 2001. Please find attached form 10-403 and other pertinent information as follows: 1. Form 10-403 2. Annulur Disposal Transmittal Form 3. Pressure Calculations for Annular Disposal 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report 10. Formation LOT on 9-5/8" x 7" casing annulus. If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. ly, Vern Johnson Drilling Engineer CC: CD2-42 Well File Chip Alvord Scott Reynolds Nancy Lambert Sharon AIIsup-Drake ATO-868 ATO-838 Anadarko ATO-153O RECEIVED MAY 2 5 Z001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL NOTE TO FILE PPCo Application for Annular Disposal Alpine CD2-42... PTD 201-067 Phillips has made application requesting approval for annular disposal (AD) on their first new CD 2 well CD2-42. Phillips has provided information regarding the cementing and subsequent LOT information as required by the regulations. The casing and cementing information indicates that the casing was successfully run and cemented. It is noted that 117 bbls of cement was returned to surface. The casing test prior to drillout was successful. The initial leak off test did not break down at 16.0 EMW. There is a slight pressure drop during the observation period of 60 psi. On the subsequent LOT, the pressure builds steadily to nearly 700 psi when it breaks and declines approximately 90 psi while pumping 3 additional barrels. When pumping ceased, the pressure declines about 150 psi in the first minute and an additional 100 during the remainder of the observation period. I have examined other Alpine LOTs and the behavior is similar to what has been experienced at CD 1. As noted, this is the first new well on the CD 2 pad. As part of their application, PPCo has supplied a spider plot locating the current wells on the pad (not many) and the planned wells on the pad (a lot). According to the planned plot, there ultimately will be 2 wells with about 200' lateral distance to CD2-42. Due to small print, I am unable to determine the well numbers. As the development continues on CD 2, the proximity of additional wells is something that should be monitored. I will contact the drilling engineer and request that future well proximity to the disposal shoe be noted in upcoming well plans. I recommend that PPCo's request for annular disposal in CD2-42 be approved. Tom Maunder, PE Petroleum Engineer AOGCC 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 _ Variance _ Perforate _ Other _X Annular Disposal 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1984' FNL, 1513' FEL, Sec. 2 T11 N, R4E, UM At top of productive interval 106' FNL, 359' FEL, Sec. 10, T11N, R4F, UM At effective depth At total depth 2530' FSL, 1054' FWL, Sec. 11, T11 N, R4E, UM 5. Type of Well: Development _X Exploratory __ Stratigraphic _ Service _ 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Collevile River Unit 8. Well number CD2-42 9. Permit number / approval number 201-067 10. APl number 50-103-20374 11. Field / Pool Coleville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measu red true vertical Effective depth: measu red true vertical Casing Length Conductor 114' Surface 2544' Production 9596' 12639' (planned) feet Plugs (measured) 7134' (planned) feet 12639' (planned) feet Junk (measured) 7134' (planned) feet Size Cemented 16" 10 yds portland 3 ready mix cmt 9-5/8" 380 Sx AS III L & 230 Sx 15.8 class G 7" 117' Sx 15.8 class G Measured Depth Truevertical Depth 108' 108' 2581' 2377' 9633' 7273' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4.5" 12.6#, L-80 @ 9292' MD (PLANNED) 7" Baker S-3 Permanent Packer, 9224' MD (PLANNED) RECEIVED MAY ;8 5 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __X 15. Status of well classification as: 14. Estimated date for commencing operatio_n¢<~" May 2~, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~~,...~' ~ Title: Alpine Drilling Team Leader Chip Alvord FOR COMMISSION USE ONLY Questions? Call Vern Johnson 265-6081 Date ~[2-~(o( Prepared by Vern Johnson Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form required Approved by order of the Commission .,J. M. Heusser I Approval no. Commissioner Date ' Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. b. The depth to the base of freshwater aquifers and permafrost, if present. c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. f. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. h! Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission to confirm containment of drilling wastes. CD2-42 There are no USDW aquifers in the Coleville River Unit. Base of Permafrost = 732' TVD (RKB) The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating one well within 1/4 mile, CD2-35. There are no water wells within 1 mile. Types of fluids can be mud, diesel, cement, and water. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 1908 psi. See attached calculation page. See attached cementing reports, LOT/FIT reports, and casing reports. See attached casing summary sheet and calculation page. DETAILS: CD2-42- Pressure Calculations for Annular Disposal ~9-5/8" 36 Ib/ft, J-55 BTC casing @ 2581 ft MD (2377 ft TVD) Pburst: 3520 psi, @ 85%: Pburst85% = 2992 psi TOC Top of Cement @ 6978 ft TVD ~7" 26 Ib/ft, L-80, BTC casing @ 9639 ft MD (7314 ft TVD) Pcollapse = 5410 psi, @ 85%: Pcollapse85% = 4598 psi ~4-1/2" 12.6 Ib/ft L-80 tubing ASSUMPTIONS: · Maximum injection pressure, PApplied = 1500 psi · Maximum density of injection fluid is 12.0 ppg. · Pore pressure at 9-5/8" is 0.4525 psi/ft · Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic -I- PApplied ' PFormation Pmax = 12.0 (0.052)(2377)+1500- 0.4525 (2377) Pmax = 1908 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% - PHydrostatic + PApplied ' PFormation 2992 = MWmax (0.052) (2377) + 1500- 0.4525 (2377) MWmax = 20.8 ppg Maximum Fluid Density to Collapse 7" Casing: Pcollapse85%: PHydrostatic + PApplied- PGasGradient - PHeader 4598 = MWmax (0.052) (6978) + 1500 - (0.1) (6978)- 2000 MWmax = 16.0 ppg -'- ~'"~'-'--'='-'--:~'t"= I Phillips Alaska, Inc. .~,,~.~.----.~.=~=~ Structure: CD~2 Well: 42 ~eld : Alpine ~eld Loa~lon: No~ Slope, Aloska -~e,t~eef~ (:feet) ~cQ~e 1 1.c~ - 400 ft West [ ~ ~ Ph~lhps Alaska, Inc. Casing Detail Well: CD2-42 9 5/8" Surface Casing Date: 2/15/01 PHILLIPS Alaska Inc. ~--~"/ A Subsidiary of PHILLIPS PETROLI::UM~COMPANY DEPTH Jt Number Num of Jts COMPLETE DESORIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 FIKB to LDS 36.80 FMC Gen V Hanger 2.19! 36.80 Jts 3 to 62 60 Jts 9-5/8" 40# L-80 BTC Csg 2453.48 38.99 Davis Lynch Float Collar 1.52 2492.47 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 85.70 2493.99 Davis Lynch Float Shoe 1.75 2579.69 2581.44 TD 12 1/4" Surface Hole 2590.00 RUN TOTAL 36 BOWSPFIlNG CENTFlALIZEFlS - I per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52,54,56,58,60. Last 11 jts, stay out # 63 to # 73 Use Best-o-Life 2000 pipe dope Remarks: Up Wt -155 k Dn Wt -148 k Block Wt - 70 Supervisor: DA VID BURLEY Phillips Alaska Drilling Cementing Details Well Name: CD2-42 Report Date: 05/15/2001 Report Number. 4 Rig Name: Doyon 19 AFC No.: 998D04 Field: Alpine Casing Size 9.625 H°le Diameter. I Angle thru KRU: 12.25 Sh°e Depth:I 2581 LC Depth:I 2492 % washout: Centralizers State type used, intervals covered and spacing Comments: Ran 36 9-5/8" x 12-1/4" bow spring centralizers, 1 per joint on #'s 1-12 and every other joint #'s 14-60. Mud Weight: PV(pdor cond): PV(after cond): I YP(pdor cond): YP(affer cond): Comments: 9.7 15 16I 27 18 Gels before: Gels after. Total Volume Circulated: 11/26/35 6/10/14 880 bbls Wash 0 Type: Volume: Weight: Comments: Water 40 8.4 Vlscoslfied & nutplug for marker Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 10.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: ASLite 70 380 10.7 4.44 300 bbls Additives: 30% D053, 0.6% D046, 1.5% D079, 1.5% S001, 50% D124, 9% BWOW D044. Tall Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: GI 70 230 15.8 1.17 48 bbls Additives: 0.2% D046, 0.3% D065,1% S001. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments:: 8 bpm 6 bpm 155 Reciprocation length: Reciprocation speed: Str. Wt. Down: 25' 20 fpm 148 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 189.6 bbls 189.8 bbls Calculated top of cement: CP: Bumped plug: Floats held: Had 117 bbls of 10.7 ppg cement to surface. Date:5/15/01 YES YES Time:0655 hrs. Remarks:Had full returns untlll last 22 bbls of displacement, conductor stood full after blugs bumped. Cement Company: Rig Contractor: ! Approved By: Dowell DOYON J. David Burley Phillips Alaska Drilling Daily Drilling Report AFC No. Date Rpt No Rig Accept - hrs Days Since Accept/Est: 3.1 / 3 998D04 05/15/2001 4 05/12/2001 10:00:00 Rig Relase- hrs: PM Well: CD2-42 Depth (MD/TVD) 2590/2384 Prev Depth MD: 2590 Progress: 0 Contractor. DOYON Daily Cost $165732 Cum Cost $ 629155 Est Cost To Date $ 652000 Rig Name: Doyon 19 Last Csg: 16" @ 114' Next Csg: 9-5/8" @ 2615' Shoe Test: Operation At 0600: Picking up 4" drill pipe. Upcoming Operations: MU BHA #2, test casing, clean out cement, LOT, drill ahead. MUD DATA DRILLING DATA BIT DATA EH&S DRILL~/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. 'ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD ¥ TST 05/14/2001 05/13/2001 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.7ppg Doyon 05/01/2001 04/25/2001 VISCOSITY PU WI' MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 58sqc ¥ SPACE 05/03/2001 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 116 / 18 Mud GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 1250 B/10/14 126 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER 580 12 05/1 5/2001 USED - BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 102 mi/30 rain INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 7.5% CD1-19 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 16 179bbl I I I / / CD2-42 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 3 )h LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 30° 8.8 5.51611 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 16.00 ..9% 7.1741 I 0 PIT VOL GPM 2 JETS JETS PHILLIPS 1 40~ 572111 IIIII I1111 0 PERSONNEL 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 25 III 0 PERSONNEL $6476 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $20736 III III III o COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 M~ III III III PERSONNEL TOTAL 44 DESCRIPTION ~BIT, MLC@1.4, XO, NMDC, NMSTAB, GRSUB, MWD, 2 NMDC, NMSTAB, NMDC, XO, 3 HWDP, JARS, 26 HWDP. BHA NO I OD ID ',¥EIGH ;' GRAI.3i£ CO%~ECTIO". CLASS 2 LE'..GTH D~ IA LE%GTII 1104.09 5 4.26 19.5 G105 4-1/2 iF Prem DATE LAST INSPECTED: HOURS ON JARS: 115.2 :::TIME: END: :HOURS :::OpS CODE:ii :HOLE SECT: IpHASEOPS I i :OPERATIONS FROM:0000;O000: 12:00 AM 12:15 AM 0.25 CASG SURF Casing and Run casing to 1360', pushed last 40', displacement returns Cementing diminished. 12:15 AM 12:45 AM 0.50 ClRC SURF Casing and Staged pumps up to 7 bpm and clrc with full returns. Cementing 12:45 AM 03:00 AM 2.25 CASG SURF Casing and Run casing, MU LJ and land casing with shoe @ 2581', FC Cementing @ 2492'. LD Fill up tool and MU cement head. 03:00 AM 05:00 AM 2.00 CASG SURF Casing and Staged pumps up to 9 bpm, cftc and condition mud, PJSM Cementing with Dowell. 05:00 AM 07:00 AM 2.00 CASG SURF Casing and Pumped 40 bbls of vlscoslfied FW with nutplug marker, line Cementing up to cementers, test lines to 2600 psi. Pumped 50 bbls of 10.5 ppg spacer, 300 bbls of lead and 48 bbls of tail cement. Displaced with 20 bbls of FW and 169.8 bbls of mud @ 8 bpm. Bumped plugs to 1000 psi, floats held, ClP @ 0655 hrs. 07:00 AM 09:00 AM 2.00 CASG SURF Casing and RD cement head and flush conductor. LD LJ, MU wash tool Cementing and flush annular preventor, driller functioned dlvertor with out disabling knife valve resulting In 3 bbl spill on pad. 09:00 AM 09:30 AM 0.50 OTHER SURF Casing and Initiate spill response and establish containment. Daily Drilling Report: CD2-42 05/15/2001 Cementing Page 09:30 AM 12:30 PM 3.00 CASG 12:30 PM 03:00 PM 2.50 NU_ND 03:00 PM 08:30 PM 5.50 BOPE 08:30 PM 09:00 PM 0.50 OTHER 09:00 PM 10:30 PM 1.50 RIGS 10:30 PM 12:00 AM 1.50 OTHER 24.00 SURF SURF SURF SURF SURF SURF Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Other Other ND Dlvertor . ..~m, Install Unihead and test M/M seal to 1000 psi for 10 min. NU BOPE - change drive sub on Top Drive to 4". Install test plug - test BOP's choke manifold and surface safety valves to 25G/5000 psi. Annular Preventor 250/3500 psi. Install wear bushing Chuck Scheve (AOGCC) waived witnessing tests. Install mousehole and second annulus gate valve on wellhead. Slip and cut drilling line - service Top Drive. PJSM. Grant-Prideco Rep. spoke to crew on the new drill pipe issues. Begin picking up drill pipe. Supervisor: DAVID BURLEY Daily Drilling Report: CD2-42 05/15/2001 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-42 Reason(s) for test: Date: 5/16/01 Supervisor: D. Burley [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 4Off, L-80, BTC CSG Casing Setting Depth: 2,581' TMD 2,376' TVD Mud Weight: 9.6 PP~I Length of Open Hole Section: Hole Depth: 2,610'TMD 2,399' TVD 29' EMW = Leak-off Press. + Mud Weight -- 790 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,376' EMW for open hole section -- 16.0 ppg Used cement unit NO Pump output = 0.0997 bps Fluid Pumped = 0.5 bbls Ri.q pump used if 2 Fluid Bled Back = 0.4 bbls 2,860 psi I I I I II I I iI I I II I II I I I II I I II-I I II I I II I I II I I II I I I 2,6C0 I .............................................. ............. ~_, ,., :,:, .,.,,., ,,: .................. _ _ _ ,.. _ ._ _ ,. _----.4. _- ._. 2..,4O0 p~t Z000 ~ ON[ MINUIE lICKS 1,8~ Psi j I ~ 1,(~0 psi / ~ LEAK-OFF TEST / ~ ,=~--CASING TEST ~,~,, ~o pa -~>-- LOT SHUT IN TIME ~ 1,2oo ¢ / -' CASING TEST SHUT IN TIME ~.mo pa / I TIME LINE Opsl~, .............................................. o s ,o ~s m ~ STR~KES ~ ~0 ~ m NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above PHILLIPS Alaska, Inc. A Subsidiary ot PHILLIPS PETROLEUM CONIPANY LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE 1.0 200 psi .~,,~ 2 stks i 340 psi ..................... -~,':B ......... '~iii:i-/,~i" .',, q? ................ i-;¥~"'f---~'~-~_;Fi,' ..................... '~':'~ ......... '.~ii~"~,;i'"~-~P ................ i~';i'~;---!-'-ii~'~'p_'~,T'i ................ i, ................................ 4.0 670 psi -~ ~ ~- ............... ,r, ............... 8 stks ;: ............... 1,080 psi ................ ~ ..... 'E~ ........ ~ii~"~'~i--~-~ ................ ~'~-'~ii~;'-i-'{,~-~-'~i"i,, ................................................... i- .............................. r .................................................................... ! .~__s_ !~.s___[_.k~__o__._.s.L..i ................................. L ................ ! i i.. .............. .f ....................... i ......................... , , i'---~:Y~ih'--! ............... i .... ~,-~-~,'~i .... 1- ............... '~ ............... ",- ................ 1.0min [ i T7Opsi '--~'/~ih---'~ ............... ,,r'--~b";~;i--- ::::::::::::::::::::::::::::::::::::::::::::: 4.0min , ,: 750 psi i- ............... -i ............... .~- ................ ,0m~n i : 750 psi 6.0min : ! 740 psi [---~:y,~h---l ............... ,i---~iis¢-~r-- .......... r .... , ............... I- ................ i i 8.0m~n , , 740 psi · i i i i 9.0m~n , , 730 psi i- .............................. -~- ................ j.P:2_.m_Ln..j ............... L_J~P.£_s.! .... ................... _a__t ~.~._?:_~_.o.~_~ Li i i i ................................ i ................ i.- ................................ !. ................ --, i i- ............... · ............................... [ i i ................ · ............... · ................ -i I SHUT IN TIME SHUT IN PRESSURE ................ · ............... r ................ ..._O_._O...m.L.n_._ 2,530 psi 1.0 min 2,520 p_si -"~75-~i'K ..................... -~'7~6 ~i" ....3_.9._.m. Ln_ .................... ..2:.s..2.9.p.?.L.' ____4_:.0_._m_i__n. ..................... ..2_,.5_ _1..0. p. _s_ b ~___s_._o...m. Ln_ ..................... ._2:.s.!.°..P.?.L_ ~ 6.0 min 2,510p_si 8.0 min 2,500 psi i- ............................... · ................ 9.0 min 2,500 psi ~.j.p.._.0..m..Ln.._[ ................. ._a:~.~.9. 15.0 min : 2,480 ~si j F ........... :'---f ............... · ............... , ~ 20.0 m~n [ 2,470 psi 25.0 min , .___2.,_4_.6_.5_~.s.!.j '--§6~'6-~-B-'" ............... 2,48s p_.s~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scol1 Reynolds Casing Detail Well: CD2-42 PHILLIPS Alaska, Inc. 7"Intermediate Casinq Date: 5/24/01 A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 35.00 FMC 11" X 7" Hanger 2.27 35.00 Jts 3 to 235 233 Jts 7" 26# L-80 BTCM Csg 9512.13 37.27 , . 7" Davis Lynch Float Collar 1.40 9549.40 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 80.95 9550.80 ,.. 7" Davis Lynch Float Shoe 1,72 9631.75 9633.47 I straight blade centralizer per jt #1 - #18 I straight blade centralizer every other jt #172 - #232 ,, Total - 49 centralizers ,, ,, Use Best-o-Life 2000 pipe dope Remarks: Up Wt- ???k ,,, Dn Wt - ???k ,, , Supervisor:Don Mickey Phillips Alaska Drilling Cementing Details Well Name: CD2-42 Report Date: 05/24/2001 Repor~ Number: 13 Rig Name: Doyen 19 AFC No.: 998D04 Field: Alpine Casing Size Hole Diameter: A~gle thru KRU: Shoe Depth: I LC Depth: I % washout: 7" 81/2" 42 9633'I 9549'I 40 Centralizers State type used, intervals covered and spacing Comments: Slip on straight blade stand-offs - 1 per jt on first 18its. then every other jt. f/# 172 to # 232 - 49 total Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.9 10 9 22 17 Gels before: Gels after: Total Volume Circulated: 8/10/12 7/8/11 660 bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.3 ppg Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 bbls 12.5 ppg Lead Cement 0 Type: I Mixwtrtemp: No. of Sacks:I Weight: Yield: Comments: G 70 117 15.8 ppg 1.15 Additives: 0.2% DO-46 antifoamer, 0.25% DO65 dispersant, 0.25% D800 retarder, .018% D167 fluid loss Tail Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: I Yield: Comments: I Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6.5 b/m 5.5 b/m Reciprocation length: Reciprocation speed: Str. Wt. Down: 6 ' 10' / min Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 365.7 bbls 364.7 Calculated top of cement: CP: Bumped plug: Floats held: 8975' Date:5/25/01 Yes Yes Time:0345 hrs. :~emarks:Full returns during job. Unable to reciprocate pipe after 15 mlns. Into circulating up wt 350 K -dn wt 150 K Cement Company: Rig Contractor: Approved By: Dowell DOYEN Don Mickey CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-42 Date: 5/25/01 Reason(s) for test: Supervisor: Don Mickey [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# L-80 BTC CSG X Casing Setting Depth: 2,581' TMD 2,376' TVD 7" 26# L-80 BTCM CSG Mud Weight: 9.9 PP~I TOC Hole Depth: 8,975' TMD 7,O35' TVD Length of Open Hole: 6,394'l 687 psi -- = + 9.9 ppg ) 0.052 x 2,376' / EMW = 15.5 ppg ~ $~ ~ / Press EMW = .052 X TVD + Mud Weight Pump output = .020 BPS ..... Used cement unit Fluid Pumped = 15.0 bbl BLED BACK = 8O0 psi LOT SHUT N T ME I ~ psi 5C0 psi M,I MJ 3O0 100 psi 0 ps] 0.0 1.0 2.0 3.0 4_0 5_0 6.0 7.0 8.0 9.0 10.0 11.0 12_0 13.0 14.0 15.0 16.0 17_0 18.0 t9.0 20.0 21.0 22.0 23.0 24.0 25.0 bbts WC~I:~ls b,bb ~ bt:~ bbbt~c~s bb~b,b~ D,~S t:~D,~ b~ts D4:~ t:~-_.~ L:d~S ~ ~ ~ b,bls t::d~ [:::~Dts ~ blD,~ Dt:~ ~ · BBI.$ LEAK-OFF DATA MINUlES LOT BBLS PRESSURE .................. r ................. r ............... ~ r .............. ~ .............. i i i i ! i ................. -P ................ -1- ............... ~ r .............. r .............. i 0.0bbls .[ 0psi i" " " " i i i i i i f 1.0bbls , 20psi .,~,~t , , , ................. -P ................ -r ......................... -~,i l~-'r~-~ I- .............. I I ~I I I I I , 20bbls 136 si .... ..........................................., · ,' ......................................... , , , , ROhhl.~ , 9RRn~i i ~.~ ~.~ i --~ r'~. , i i i r ................ .-r i ................ -r.i .......................... -~ ~l;41d[ ~. r i .............. i i i i i , 4.0bbls , 424 psi,,~c ..... i i d I ! l i i i i i . , 50bbls , 550 si , ,~ , , , ........................................... . P-L__,':'¢ t,.3_ ........................................... i i I I I i ! i , I I , 6.0bb15 , 587p~i~~ , , , i i i -- , i i i , , 7.0bbls , 676psi ~..1c-~.) , , , ................ ~ ................ ~ .............. ~ r~ ..........~ .............. ? ............... "? i i i 80bbls , 626 si , , , i i ~.P i i i ........................................... , - B...~..~.~.~. ......................................... I I i '~," ~ , I i , ~FIhhl.~ , R(I1 n~i4 , , , , I ....... I ------ r'--- i i i r ................................. -I- ............... ~ r .............. ~ .............. i i i i i , i i i i i i r ............................................................................. .................................. 'T ............... i[ .............. T .............. , ! .................................. "T ............... ' ' SHUT IN TIME SHUT IN PRESSURE .o._. p___m.L~. ................... 2_._?.o.!._p..s.L.i ._.&.o...m. Ln_ .................... [...~..4.~!..1 ____2_._9...m_Ln_ ................... _[," ._~..~.~..*_!_j ___~..o...m_Ln. ................... 2-.~J-.*-~!--J .._.4_._o_.m. Ln_ ................... _L...~..4_e~!__i .................... ...~_.p...m.!.n. .................... r .............. !' .............. ! ............... i i i i r .............. r .............. · ............... i i i i i i i [ ,,' T , i i i i i i i i i r .............. [ .............. T ............... ,r .............. i' .............. i ............... i i P .............. r .............. T ............. , i , ! , i i r .............. ~ .............. · ............... i i i i I i i , i i r .............. ~ .............. ? ............... i i i i i r .............. ~ .............. · ............... i i I ! ! i i ! i i r .............. · .............. · ............... ! i i i i i i i i i i i i i i l i , i i r .............. · .............. ? ............... 7 0 min s .... · i i I i ~ .............................................. r .............. L 369p i i .... 8 0 min s .... · i i r ................ -P ................................ r .............. ! i i i 9.0min } 364 psi j, , , , , ................................. ... ................ ....,mn n,-,,, ,.,,.=_~__:::,::_. .................. _,_.':::-._._:::..,,.- . .............. ., ............ . . ., ............ __. ., NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ALASKA OIL AND GAS CONSERVA~ION COP~ISSION Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Unit CD2-42 Phillips Alaska, Inc. Permit No: 201-067 Sur Loc: 1984' FNL, 1513' FEL, Sec. 2, T1 IN, R4E, UM Btmhole Loc. 2530' FSL, 1054' FWL, Sec. 11, TllN, R4E, UM Dear Mr. Alvord: Enclosed is the approved appliCatiOn for permit to drill the above referenced well. The permit to drill does not exempt you from Obtaining additional Permits required bylaw 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 any CQLs must be submitted to the Commission for approval on form. 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD 2 pad must comply with the 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 space of a single well or to use that well for disposal purposes for a period longer than one year. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and AP1 number (50- - -70) from records, data and logs acquired for well (name on permit). Colville River Unit CD2-42 April 1 25, 2001 Page 2 of 2 Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035: Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to wimess a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this ~_.S ~ day of April 2001 jjc/Enclosures CCi Department of Fish & Game, Habitat Section w/o encl. Department of EnVironmental Conservation w/o encl. Re: [Fwd: CD2-42 logging] Subject: Re: [Fwd: CD2-42 logging] Date: Fri, .20 Apr 2001 16:13:29 -0800 From: Julie Heusser <julie_heusser@admin.state.ak.us> To: Tom Maunder <tom_maunder@admin.state.ak.us> Thanks Tom, If you haven't done so already, please cc the well file. Thanks Julie Tom Maunder wrote: Julie, Bob and I talked with Vem et al regarding logging for the upcoming Alpine CD2 wells. This is the summary of the conversation. I will include their note in the well file. Tom mmmmmmm#mmmm.mmmmm~wmmmmmmmmm~mm~mm#~m~mmmmmmmmmmm~mmmmmmmmm#mmmmmmmm Subject: CD2-42 logging Date: Fd, 20 Apr 2001 09:10:58 -0800 From: "Vernon T Johnson" <vjohnso l @ppco. com> To: Tom Maunder <torn_maunder~.admin.state. ak. us>, bob_crandall@ adm in. state, ak. us CC: "Chip Alvord" <calvord@ppco. com>, "Scott D Reynolds" <sreynol2@ppco. com>, "Meg C Kremer" <mkremer@ppco. com>, Tom Maunder <tom_maunder@admin. state.ak, us> Bob, Based on our conversation yesterday afternoon, we have set up the logging program for CD2-42 as follows: 12.1/4" hole 2615' MD/2400' TVD : LWD: GP,/Res, surface logging: gas chromatograph 8-1/2" Pilot hole 9525' MD/7477' TVD: LWD: GR/Res/Density/Porosity, Surface logging: gas chromatograph 8-1/2' kickoff/landing 9639' MD/7298' TVD: LWD: GR/res 6-1/8" horizontal '12639' MD/7314' TVD: LWD: GR/Res The pilot hole extends through the Alpine, and is drilled for data gathering purposes. The above program is typical of what we have been doing on wells with pilot holes at Alpine, except we do not normally run any surface logging, and we do not normally run any LWD logs in the 12-1/4" hole. It is my understanding that this is acceptable and fulfills the Alpine Pool Rules requirement; rule 4. d. If this is not acceptable please contact me and we can discuss it. If we are not required to log the 12-1/4" hole section or use the gas chromatograph for any hole sections p/ease/et me know. 1 of 2 4/25/01 10:30 AM Re: [Fwd: CD2-42 logging] Vem Johnson 907-265-6081 (w) 907-265-6274 (fax) 907-242-8157 (Cell) 907-267-0566 (pgr) Tom Maunder <torn_maunder~admin. state, ak. us> Petroleum Engineer Alaska Oil and Gas Conservation Commission > Tom Maunder > Petroleum Engineer <tom_maunder~admin.state. ak. us> > Alaska Oil and Gas Conservation Commission > 3001 Porcupine Dr. Fax: 907 276-7542 > Anchorage Work: 907 793-1250 > AK Conference Software Address > 99501 > USA > Additional Information: > Last Name Maunder > First Name Tom > Version 2.1 2 of 2 4/25/01 10:30 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' feet Colville River Field 3. Address 6. Prop esi nation ,~'~ ~.~¢~,~ ~ )'.2-.-¢,7 Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 AD~'&~ADI-~ .,,~,~¢". 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1984' FNL, 1513' FEL, Sec.2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 106' FNL, 359' FEL, Sec.~, T11 N, R4E, UM CD2-42 #59-52-180 At total depth f~' ~¢. 9. Approximate spud date Amount 2530' FSL, 1054' FWL, Sec./Id', T11 N, R4E, UM 04/24/2001 $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 CD2-35 12639 MD 106 FNL T11N feet 59' at 875' Feet 2560 7262 TVD feet R4E 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 89.7° Maximum surface 2572 psig At total depth (TVD) 3262 at psig 721 O' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing 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 2578' 37' 37' 2615' 2400' 399 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9602' 37' 37' 9639' 9298' 134 sx Class G N/A 4.5" 12.6# L-80 IBT-M 9209' 32' 32' 9241' 7207' 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 R EC E I VTr~'~ Casing Length Size Cemented Measured depth ical depth Structural ConductorAPR 0 4 2001 Surface Intermediate Production Alaska 0il & Gas Cons.C0rnrnlssJor' Liner Anchorage Perforation depth: measured true vertical 20. Attachments Firing 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 certify that the foregoing is true and correct to the best of my knowledge Signed ~ .~ (~4 Title Drilling Team Leader Date / Commission Use Only . Permit Number I APl number Approval date /~...~Z' ~,~..~ /'~ / See cover letter for ~o/-- O ~' 7, 50-/'~,,~ --- 2. 0 3' '~ ~' I "/~'2'~../' 6.// I Other requirements Conditions of approval Samples required~ Yes /~ Mudlo~lre~luired~ Yes Hydrogen sulfide measures Yes /~N'~-,,) ~ Directional survey required //' Yes,,~ No v Required working pressure for BORE 2M 3M 5M 10M 15M _'~ ~(~)~ ~),~ ~_,_~ ~-- Other: Approved by OI~IGINAL 816NED BY by order of ~ ~, r, ~ ....... Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate CD2-42 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casinq Interval Event Risk' ~.evel Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision None N/A Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, Iow mud temperatures Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps, run gravel isolation # · ' string. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Iow density cement slurries 8-1/2" Hole / 7" Casinq Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Iow BOPE drills, Keep mud weight above 10.4 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Iow Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole/Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 9.3 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers ED OtR1GINt- L APR 04 2001 Alaska Oil & Gas Cons. Commissior~ Anchorage Alpine: CD2-42PH (Pilot Hole) & CD2-42 Procedure . . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Install diverter. Move on Doyon 19. Function test diverter. 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 Y2" hole to a point +/- 100' TVD below the base of the Alpine Sand. Set 600 ft cement plug #1 from TD to +/- 8925'. Set 350 ft cement plug #2 from +/- 8925' to +/- 8575', RIH with drilling assembly. Dress off plug #2. Kick off at +/- 6583' 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 Y2, 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. Set BPV and secure well. Move rig off. RECEIVED APR 04 2001 ~aska 0il & Gas Co~m, Comrnissi0r: Anchorage Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-35 will be the closest well to CD2-42, 59' at 875' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 52' at 875' MD. Drilling 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. 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 CD2-42 will be injected into the permitted class 2 disposal well on CD1 pad until a well on CD2 pad is permitted for annular disposal. The CD2-42 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 CD2-42 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 below 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 RECEIVED APR 04 2001 Alaska 0il & Gas Cons. Commission Anchorage CD2-42 & CD2-42 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 1/2" Section - 6 1/8" point- 12 IA" 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 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowiine 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 Dual-FIo starch will be used for viscosity and fluid loss control respectively. RECEIVED APR 04 2001 0it & ~as Cons. Commissior~ Anchorage 10 Colville River Field CD2-42PH Pilot Hole - Prior to Sidetracking RKB - GL = 37' Updated 03/19/2001 II 9.8 ppg drilling mud in hole Top Alpine Reservoir at 9224' MD / 7256' TVD Pilot Hole TD at 9525' MD / 7477' TVD (+/- 42.71° inc.) Cement Plug , Wellhead 1 ," Conductor to 114' !il9-5/8 36 ppf J-55 BTC Surface Casing 2615' MD / 2400' TVD cemented to surface Plu.q #2: 350'~ 17 pp.q to cover the HRZ when in place (top at +/-8575') Top of cement plug dressed off to 8679' MD / 6855' TVD (+/- 42.71 _o inc.) -Top of Cement Plug #1 at +/- 8925' 6OO ft 'i RECEIVED APR 04 ~001 Alaska Oil & Gas Cons. C0mmissiol~ Anchorage 11.0 Colville River Field CD2-42 Production Well Completion Plan -5/8 36 ppf J-55 BTC ~ I I I ~*;,, 11 I ~ Surface Casing @ 2615' MD / 2400' TVD cemented to surface 16" Conductor to 114' Updated 03/29/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 2000' TVD=2081' 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 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. R3 tubing run with Jet Lube Run'n'Seal pipe dope WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM TOC @ +/- 8872' MD (500' MD above top Alpine) Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 2000 psi Completion Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple End thermal centralizers 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. (1 per joint) Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2" tubing joints (2) (R3) HES "X" (3.813" ID) 4-1/2" tubing joint (1) (R3) Baker S3 Packer 4-1/2" tubing joint (1) (R2) MD TVD Top Alpine at 9372' MD / 7256' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9639' MD / 7298' TVD @ 89.7 deg 32' 32' 2081' 2000" 2651' 2400' 3976' 3400' 5473' 4500' 6426' 5200' 9080' 7126' 9140' 7159' 9172' 7175' et 2 joints above the X landing nipple HES "XN" (3.725" ID)-63.6 deg 9230' 7202' 4-1/2" 10' pup joint WEG (+/- 64.1 deg) 9241' 7207' ~ ~:iii~.:.~.aker S3 Packer at +/-9172' t ~'~- 12639 MD / i ECEIVED APR 04 2001 "\l~lska 0ii & (~,s Cc, ns, CommissJ,: .Anchorage Colville River Field CD2-42 Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 .N,,o-Go Lock (3.812" OD) with dual 1/4 x 0.049" s/s control line @ 2000' TVD Surface Casing @ 2615' 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. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Updated 03/29/00 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - 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) - Muleshoe / Entry Guide (C) Open Hole Brid(~e Pluq Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe TOC @ +/- 8872' MD (500' MD above top Alpine) Camco KBG-2 GLM (3.909" ID) RECEIVED & 1" Camco DCK-2 Shear Valve -- -' ---~~X.r'is~ejfoi°~t.~aaS~)gveSitc~%~leaanrdi~n;"n0,~.?i APR 04 2007 ~~~ , '~.~.".~.ra.qe ,,,~V I TD _at ~~i'":"'-Baker S3 Packer s et at +/-9172 12639' MD / % % ~?..?:,, 7314' TVD .... ........ fE-LE- E ....... ..... _E. ........ : 7" 26 ppf L-80 BTC Mod Production Casing @ 9639' MD/7298' TVD @ 89.7deg CD2-42 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 2615 / 2400 14.5 1086 1532 7" 9639 / 7298 16.0 3302 2572 N/A 12639 / 7314 16.0 3309 N/A · NOTE: The 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-(0.1 x D) Where; FPP - Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP- (0.1 x D) = 1086 - (0.1 x 2401') = 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) - 3174 - (0.1 x 7298') = 2572 psi 3. Drilling below intermediate casing (7") ASP - FPP - (0.1 x D) = 3184 - (0.1 x 7298') = 2572 psi Alpine, CD1-21PH Cementing Requirements CD1-21PH Cement Plug #1: 9525' MD to 8925' 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 => 235 Sx @ 1.16 ft3/sk CD1-21PH Cement Plug #2: 8925' MD to 8575' MD = 350'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 350' X 0.3941 ft3/ft X 1.1 5 (15% excess) = 158.6 ft3 => 159 sx @ 1.00 ft3/sk Alpine, CD2-42 Well Cementinq Requirements 9 5/8" Surface Casing run to 2615 MD / 2400' TVD. Cement from 2615' MD to 2115' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2115' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2115'-993') X 0.3132 ft3/ft X 1.5 (50% excess) = 527.1 ft3 below permafrost 993' X 0.3132 ft3/ft X 4 (300% excess) = 1244.0 ft3 above permafrost Total volume = 527.1 + 1244.0 = 1771.1 ft3 => 399 Sx @ 4.44 ft3/sk System: Tail slurry: System: 399 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% BWOW1 D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (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 ft~ => 230 Sx @ 1.17 ft3/sk 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft~/sk 7" Intermediate Casing run to 9039 MD / 7046' TVD Cement from 9639' MD to +/- 8872' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9639'- 8872'), X 0.1268 f¢/ft X 1.4 (40% excess) = 136.2 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft° shoe joint volume Total volume - 136.2 + 17.2 = 153.4 ft3 -> 134 Sx @ 1.15 ft3/sk System: o o o 134 Sx Class G + 0.2 Ye D046 antifoamer, 0.25 Ye D065 dispersant, 0.25 Ye D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 fta/sk ~ By Weight Of mix Water, all other additives are BWOCement ~a~I Created by bm~chael ~'or: ¥ Joh~sozz · ' 'l Dole plowed: 14-Mar-2001 Plot Reference is CD2-~-2 PH Versj~3. Coord;nc~es ore ;n feet reference slot True Vedicel Depths ere r:fermr~ence £stimeted RKB. iPhillips Alaska, Inc. Structure : CD#2 Well : 42PH Field : Alpine Field Location : North Slope, Alaska ATTACHMENT 5 Point IKOP PeFmmfFost West Sink Build 5/100 EOC C-40 9 5/8 Cosing Pt C-50 C-20 K-5 K-2 Albian-97 Albion-96 HRZ JAIpine D PROFIL MD Inc 700.00 0,00 7,52.00 0.64 992.51 5.85 1 200.00 10,00 2290,56 42.71 2545.78 42.71 2615.25 42.71 2617.97 42.71 5080.69 42.71 4577.75 42.71 4897.55 42.71 6707.60 42.71 7578.60 42.71 8714.98 42.71 8879.66 42,71 9002.14 42.71 9172.26 42.71 9192.67 42.71 9225.98 42.71 9524.74 42.71 E COMMENT DATA Dir TVD North East 256.90 700.00 0.00 0.00 256.90 752.00 -0.1 0 -0.15 256.90 992.00 -8.15 - 12.50 256.90 1197.47 -2,5.77 -,56.46 236.90 21 61.28 -284.54 -436.47 236.90 2202.00 -305.07 -467.96 256.90 2400.00 -404.89 -621.08 236.90 2402.00 -405.90 -622.62 236.90 2742.00 -577.50 -885.55 256.90 3842.00 -1131.85 -1756.19 2,56.90 4077.00 -1250.52 -1917.92 236.90 5407.00 -1920.82 -2946.42 236.90 6047.00 -2243.47 -5441.54 236.90 6882.00 -2664.42 -4087.05 236.90 7003.00 -2725.42 -41 80.62 236,90 7095.00 -2770.79 -4250.22 256.90 7218.00 -2855,81 -4546.88 256.90 7233.00 -2841.57 -4558.48 256.90 7256.00 -2852.97 -4576.27 256.90 7477.00 -2964.`58 -4547.17 V. Sect 0.00 018 1492 45 52 521 03 558 62 741 40 743.25 1057.11 2072.54 2289.48 5517.25 4108.05 4878.84 4990.54 5073.62 5189.01 5202.86 5224.09 5428.10 Deg/1 O0 0.00 2.00 2.00 2.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ATTACHMENT 5 Creoted by bmichosl For: V Johnson Dote plotted: 14-Mar-2001 Plot Reference is CD2-42 Vers~on~JS. Coord~naJ~ ore ;n ~eet reference slo[ T~e VeHicel Depths ore~reference Estimated ! Phillips Alaska, Inc., Slrucfure : CD#2 Well : 42 'J Field : Alpine Field Locofion : Norfh Slope, Al~skoI Point Begin Final BId/Trn HRZ K-1 LCU Miluveach A Alpine D Alpine t- EOC - Csg Pt PROFILE MD Inc 8678.84 42.71 871 5.06 43.01 8885.08 46.87 9023.84 52.52 9266.01 65.71 9504.20 68.04 9571.95 72.27 9658.95 89.69 COMMENT DATA Dir 7VD North East 256.90 6855.44 -2651.03 -4066.51 232.15 6882.00 -2665.52 -4086.56 211.09 7005.00 -2754.59 -4164.85 196.45 7093.00 -2851.15 -4206.73 176.11 7218.00 -3055.88 -4226.70 175.56 7235.00 -5090.85 -4225.47 1 68.69 7256.00 -5153.73 -4215.50 151.86 7298.00 -5599.77 -4124.28 V. Sect Deg/lO0 419.79 0.00 422.94 9.00 464.74 9.00 530.11 9.00 701.24 9.00 733.60 9.00 795.75 9.0O 1052.79 9.00 ,TD - Csg Pt 126.39.32 89.69 151.86 7514.00 -6045.45 -2709.24 4055.12 0.00 ATTACHMENT 5 Date plotted: 14-V~f-2001 Plot Reference ~s CD2-42 PH Vem~-3. Cootd~natee ore ~n feet reference ~lot ~2. Tr~e vert~al Depths at~ reference ~t~ted flKB.[ Phillips Alaska, Inc.i Structure : CD#2 Well : 42PH Field : Alpine Field Loccflion : North Slope, AloskaI <- West (feet) 5600 5200 4800 `t`tO0 4000 3600 3200 2800 2`tO0 2000 1600 1200 800 `tOO 0 ,tO0 236.90 AZIMUTH 5438' (TO PILOT HOLE TD) *,**Plane of Proposal*** TRUE ESTIMATED PILOT HOLE TD LOCATION: 329' FSL, 782' FEL SEC. 5, T11N, R4E ESTIMATED SURFACE KOP LOCATION .~h Permafrost 1984' FNL, 1513' FEL ....... SEC. 2 T11N R4E ,,.,,, ~uHa ,~/ ~uu ' ' ~ .~."" EOC .-*'C-40 ¢~ :. ,..¢. ,... ,, .~,~ ............... ~Z? ..... '*~ Albian-97 ..... ~"~,lbian-9 6 K ~Z ..... ~'Begin Final Bid/Tm Ip 17TF~ ] Milu.veach A TD ~ ~"A'f¢'i.ne D ~ Alpine ESTIMATED TOT LOCATION: ,, . ~06' FNL, 359' FEL ",, SEC. ~ T~N, R4E ESTIMATED TD LOCATION: 2550' FSL, 1054' FWL SEC. 11, T11N, R4E %. TD - Csg Pt 400 400 800 200 600 2000 2400 2800 3200 3600 I 4ooo V 4400 4800 5200 5600 6O00 6400 6800 7200 ATTACHMENT 5 4OO 400 800 1200 1600 20O0 240O (D 2800 t- 3200 3600 "~ 4000 (D 4400 I 4800 V 52OO 5600 6000 64OO 6800 72OO 76OO 8000 4OO .........................................................................................................................................................................................Structure : CD#2 Well : 42PH Field : Alpine Field Location : North Slope, AlaskaI KOP Permafrost 2.00 4.00 DLS: 2.00 deg per 100 ft 6.00 West Sak 8.00 Build 3/1 O0 13.00 1 6.00 ?19.00 DLS: 3.00 deg per 100 ft ~ 22.00 ~, 25.00 ~ 28.00 ~31.00 .~ 34.00 40.00E0c *% 0-40 "~ 9C5Z¢0 Casing Pt C-20 TANGENT ANGLE 43.71 DEG 236.90 AZIMUTH 5428' (TO PILOT HOLE TD) ***Plane of Proposal*** K -3 ~.,,, K-2 Dote plotted: 14-Mcr-2001 Pict Reference is CD2-42 PH V¢~3. Coorcfinate~ ore In feet reference slot ~42. t Vert~al Deplhs am re.ronco ~tlmat~d RKB.~ TARGET ANGLE 89.69 DEG Albian-97 RECEIVED APR 04 2001 Alaska Oil & (]as Cons. Commission Anchorage Albion-96 HRZ '"'",~, ~-,'o~'%. Miluveach A ~, Alpine ~D '~ ..... TD ~ i i 400 i i i i i [ i i L i t i i L i ~ i ~ 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 Verfical Section (feet) -> Azimuth 236.90 with reference 0.00 N, 0.00 W from slot #42 4800 5200 5600 ATTACHMENT 5 Created by bmichoel ~'Or: V Jo}~3.so'n Dote plotted: 14-Mar-2001 Plot Reference )s CD2-42 VersionS3. Coorc~motes ore in feet reference slot ~42. iTrue Veftlool Depths ale reference Estlrnoted EKB.i INI~Q Phillips Alaska, Inc.[ Structure : CD#2 Well : 42 Field : Alpine Field Location : North Slope, AlaskaI J 6 600 6800 ~ 7000 7200 .+._ 7400 7600 v 7800 151.86 AZIMUTH 4053' (TO TD) ***Plane of Proposal*** i Beg~in Final Bid/Tm HRZ ~42'8H6RZ DLS: 9.00 deg per 100 ft ~44.45 K-1 ~_ 47.59K-1 _ LCU ~ '"'% 51.42 LCU oo~ / i ~ 56.31 .o~q) ~_0cJ Idiluveach A L -x...~61.82 AIp. ine D ~ Alpine TD~ TANGENT/TARGET ANGLE 89.69 DEG TD - Csg Pt 2 0 4 0 600 800 1000 1200 1 0 I 1800 2000 2200 2400 2600 2800 ~000 ;5200 ,:3400 3600 .3800 4000 4200 4400 Vertical Section (feet) -> Azimuth 151.86 with reference 0.00 N, 0.00 E from slot #42 ATTACHMENT 5 Created by bm~chael EOT-' V Johnson Dote plotted : 14-MQr-2001 Plot Reference is CD2-42 VersionS3. Coordinates are In feet reference slot ~42. T~e Ve~Jcal Depth~ a~ re~erence [s[imated RKB.~ l~'~ [ ......................................................................................................... ~Phillips Alaska, Inc.' ! Structure : CD#2 Well : 42 Field : Alpine Field Location : North Slope, Alaskai 2O (D 5O · *- 60 0 7O I v 8O 9O 1 aa 11o 120 130 14O <- West (feet) 110 1 O0 90 80 70 60 50 4-0 30 20 10 0 10 20 d~ ¢:¢ ~3oo , · . '" ,,4'1 O0 ,.'500 ,~."1'~00 ........... , ......... ],.,.~ ~'6'o .... .,~'o :"'":: ........ , ............ ..~ 300 ............. ~r000 300 ,,,.~ oo ............ / .... ,,, .soo .......... ...~oo ............ ,,.'~bo ............... ..... ,..<ooo / ,,...,~" e,~oo ........... / . ,.,"700 ............... ., 500 ............. /~oo ..... .,,. ........... % ,..~'"i'~o / ~ .......... ,oo'o .... ~ //400 ,,,,:: ~,.' .... e:oo / ~'"1200 ,,,,,50'0 / .... '~ / __,,,,,~6o ~3oo / ~3o ,..:,, ............. ,..,7oo /~oo ~o ?o'~ ....... . ~oo ~;'o "~°~' '"'"'~'~'°~°° ,, ,,.. ~ 5500 ,...~66" ~3oo ....... ,,,// ,,,,sd~ ,'"~oo .......... , .~,"~'oo .,,..'~'~oo ,V':/oo ~' 5600 ............. .,,,, 1'300 ,/' ,i ~:~ I'''~''' 6 00 ' ' ~ ' 9'0 ' 8'0 ' 110 100 .... ' .... ,,.'1'~00 /' z,. ,? ,,, ~'"5800 ," / 7'0 ' 6'0 ' 5'0 ' 4'0 ~ 3'0 ' 2'0 ' <- West (feet) ~'"'~00 ...... "',., 700 /; .... :o o2 .,""900 .... ~ ,~'I~ 000 ....... ~ O0 ~,~oo ¢ ~oo 1'0 ' ~1 ' 1~0 i 2'0 4O 5O E -~ 7O I v 9O lOO 11o 120 130 140 RECEIVED ~,t,l~ska OJi & G~.~s Cons,, Commissi¢ A~tchorage ATTACHMENT 5 Date plottefl: 14-MQ¢-2001 Plm Reference is CD2-42 Vem~niS. Coordinates ore in feet re.fence slot ~42. Phillips Alaska, Inc. Structure: CD#2 Well : 42 Field : Alpine Field Location : North Slope, Alaska 20 4O 60 80 · ~ 100 120 ..i-.. 0 140 I V 160 <- West (feet) 360 340 320 300 280 260 240 220 200 180 160 140 120 1 O0 80 , "~ .::.::::,;';:'.i 2 ,.,.~,~,.~,,¢zoo ~ 20 ' ' ............... ,,,1' ~ 60 ..............,," .. ............... ,,~'~'~ ................ ' .......... ~ ............ ~ ~o ,,.,,,vZ',~T&.,,~o'oo .,.~,,.'~'~oo~oo ca ..,., 1 ";~'00 .-4- 180 2OO 220 240 ,,,~,,~.;; ....... , .............. . ......... .,~'"~,o,,o' , '1';~oo ......... .,," I I .......... 1 .......... ' / b 160 V ...... ' ..... ,," 800 ~"1200 L / ...... ...... ~.,~':;~'o ............. ' ..... r ........... ~,."1"~00 /'"' //~t 20O .......... '" ?'1300 2900,,/~t ..... .,,~'&o .......... , ..... ,/ .,.,,,,'"'~,,°'~°~ t ~o ~ "1' ~00 ....... .... ..... . ........... , ,,.',~'~ oo ¢" 6.1"bo .... // ...... /' .,"" 240 ........ .,..~,.'21 O0 260 .......... ,,¢"~oo ,. ............. ' ....... 280 .....~,.2~'Oo 300 ~ , , ~ , ~ ~ ~ , , , 360 340 320 300 280 260 ?~,, .... ./ / ,.,,.~':~;o ..... / : '" " ,./ ~ 6200 ........ /" "1 3~" ........ ~ , ~ , ~ , , , 240 220 200 180 1 0 1 0 1 0 <- West (feet) 260 28O 300 f [CEIVED APR 04 2001 -~, ~.,,.,a i..hi & ,;,a, Con,. Commb~.',:.,. Aacht~rage ATTACHMENT 5 l-~:%ot~ by bm;e~oe~ ~or' V ,fohnson Date plettecl: 14-~er-2001 Plot Reference is CD2-42 Vets[onlY3, Coordinates are in feet reference slot True Vert;cal Dep~s are ~ce ['st;mated RKB. Phillips Alaska, Inc. Structure : CD#2' Well: 42 Field : Alpine Field Location : North Slope, Aloska <- West (feet) 1500 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 300 200 100 I I I I I I I I I I I I I I I I I I II I I I I II I ! 100 6800 0 0 .,..2.400 .................. * 367..::::::::::' ...... 0 ........... 2800 .................. ," ,': ..... ' ..................... ,'"' , ..... 1600 ...... 4000 ........ :::: ....... ,,, ~,.,,,':,': 1 oo .......... ::j:..,:::: ......... .................. '<'~ooo,,., >L i oo 4400 ............ : ........... , ................... ,~ .""':9"'( ............. ~.:,,2~6'~ 2~9,~ ...................... ' ~5""Z_ ....... 200 ............ , ........... , ............ ~'000 .... '""~00,D''<' ,"Lk 200 ,,~8'~'~ ,.:.:,,:.'.'""'"" .... ~~ i: .....~o< 300 ............ . ........... ...~oo ........... ~ <..'/;< ...-~, ~oo .......... ....~oo. ............. ....:..:.,...>:,.~ ................ ~ ,.::.>i~;; ~.~o~ .......... . ,,,,. ':: ...... zuuu ...... / .,.. ~:"' ,. ," 400 5'6'~ ....,..,'2'400 , .,.,~2'60 ...... . ......'~'"~2"400 ~ /'. <~,/" 400 ....... / yg.'/ .............. , ....... ....,ooo ....... .'<" q. .................. ,., ......... :::::.,::: .......... ' <.,'. '~...:<,~';'oo ............... .......... / ,,.'"'~ ......... . ................... ::::::.::': ................. . .............. ~ ::::::::::::::::::::::::: ...... ...,'~'~ ...... ..,,"/. J~ i ~" ~oo/~,..... .............. 240 C~( ........... .,..."~2800 ,, .<'::P' , .......... ., .... / ~' 6800 600 700 ............. 'J ~~, .'"4'[~00 ..... ,~' 20~)'0 700 ~' ;:~,~:~:::::::::::: ..... ... ............. ,...~ooo ;<< ..<<; ....... :::: ...... ~..5200 ,,,"'/ ,," i ,,," ~" 2000 I 1 ooo 1100 12oo 1300 1400 1500 1600 ,,,,, .,./~' 2400 / / / /' ,,' ~ 400 ~,"'~40~ / / .,' ,.. I i I i I i I i I i i i i i i i i i i i I I I i 1500 1 400 1500 1200 11 O0 1000 900 800 700 600 500 400 <- West (feet) 4000 lOOO 11oo 12oo 1300 1400 1500 WED APR 04 2.001 ATTACHMENT 5 Dote plotted: 1,~-Mor-2001 ' Plo, Ref ...... W CD2-42 Version,~. Coofdi~t~ ~m in feet red.nc= ~tot ~2. Ve~l Dep~h~ otc reference Esi;mo[ed RKB.[ I r ,Phillips Alaska, Inc. I Structure : CD#2 Well : 42 [ Field : Alpine Field Locotion : North Slope, Alosko 3OO 4OO 5OO 6OO 700 <- West (feet) 2600 2500 2400 2300 2200 21 O0 2000 1900 1800 1700 1600 1500 1400 1300 I [ I f I / I I I I I I [ I [ I I I I I [ I I I 7200 ,. ....... ..6000 .~..62'00 ,..64'~'~' ...... '.,.7000 ,.6660 ................ .......................... ,.,680~ 30 8OO 900 .... ~I~0 ............... ~,,52'00 .......... ,...5'.~d ............. 1000 ..,,~.6.~:::~"'~'~72,¢'2'6'~ ~,~"~ .........., .......... 1' ,',,' ~...4~00 1200 V 130O O0 1400 1500 1600 300 400 5O0 600 7OO O0 800 900 lOOO 0 ....... ............ =,,,I- .......... ,...S2~ .,..'4.i ~ 1 oo ,4¢0'0 .... .... o ....... .... .,6"~oo o .......... .."3000 ..~ 1200 .,,..,"'"'~6°° ,...'5~00 ..... /" 1400 ~ 7000 1500 I 1600 \ ..... · %;'o ~oo ,,.~'~o,~ ,. .................. ,,. 1700 ,.. 6'0'00'""c "; 7200 1700 1800 ,. '"' '" '"", 1800 19 O0 '",, 19 O0 2000 , ~ , ~ , ~ , , , , , , , , , ~ , , , , ~ ~ , , , ~ 2000 2600 2500 2400 2300 2200 2100<__ 2000West 1900(feet)lB00 1700 1600 1500 1400 CEIVED APR 04 2001 ATTACHMENT 5 Creoted by bmichoel ~"OT: V ~'O'["t~SOTt Date plotte~: 14-Mot-2001 Plot Reference im C02-42 Ve~liOntS. Coordinotes ore in feet reference slot §42. !True Verticol Depths ore reference ~[icnoted RKB, , ........................................................................................................... 1500 1800 2100 2400 % 2700 3000 3300 Q) 3600 -~- 3900 0 4200 I v 4500 l~'"' 4800 5100 5400 5700 60CC 6300 <- West (feet) 6300 6000 5700 5400 5100 4800 4500 4200 3900 3600 3300 3000 2700 2400 56OO 7200 ,,...6~0 ............. O0 ....... "* .' ~.,5'~oo ............................ 6000 .~ ..... il,' .,. 6400 ~ ....... 7200 ¢ 6800 ,....," ....,.,6/~00 .,"" ............ 7298 /. .... ,,. ...... ~..' 6400 ~. 7200 .............. ~ ..,,.~;o ..~.,,4800 ,,:,60'bo 64~0.,:.'.5'~; 440%. 7200 .... ~ . 6800,..:.':,':':,: .... ..... 5200 ....... 4400i ',~ 4000 I I I I I I I ~ I I I ~ I I I I I I I I 6300 6000 5700 5400 51 O0 4800 4500 4200 3900 3600 <- West (feet) 1500 1800 .2100 2400 2700 , ",,,, 3000 ,, ,, '~I, 3300 % 3600 3900 4200 ,,, i 4800 ,¢ 0 ;. ,," ~/5600 '/I~ 60Or" t'~ ~'~ 6000 , ,,e4oo 3300 3000 2700 2 0 APR 04 2001 Oi~ & ~as Cons, Comrn/ssi¢ 4nchorage ATTACHMENT 5 iCt~otacl ~), bm;c~oel For: V Johnson Dote pIotte~: Plot Reference ~ CD2-~2 Ve~ion~3. ~ Coo~in~tes ~ ~n feet ~fe~nce stat Phillips Alaska, Inc. S~rucfure : CD#2 Well : 42 Field : Alpine Field Locofion : North Slope, Alosko 310 320 540 330 70 30 40 300 60 2904:::i~ .......... 280 70 27O 90 260 25O 24O 230 220 100 .... .d?110 120 210 .............. ........ .,,"riot 200 ..... ~ ~ 30 .................. 1'""40 .,..900 ................. ~50 160 RECEIVED Normal Plane Travelling Cylinder- Feet APR 04 2001 All depths shown are Measured depths on Refer~W~l~O~L~li~asCons. Commissim A~c,h0mg~ ATTACHMENT 5 P~t Ra~*ence ~ CD2-42 Vam~n~3. T~ Ve~col ~pth~ are reference Eatim~ted RKB.~ Phillips Alaska, Inc. Sfructure : CD#2 Well : 42 Field : Alpine Field Location : Norfh Slope, Alaska TRUE NORTH .... ' 340 ".?000"..,,7o'6' ~: ~goo''~z°° ,%0020 ............ ',::350 ..... 3~.c~."3,® .... ,.:': ..... :::,:~.~'6; 320 '" ' .... 310 300 60 29O 280 270 2 700 26O ~ 70 8O 250 ............ l::~) 110 ~,.,T'~oc 240 120 1300 230 1 )00 , i ",~ 1000 .... (:~" 210 '!, ,,, / , ",, x .... ........ 1 50 200 ~,,%~¢o /' " ",~!, 60 ' ....... ~ ~/",190 ~/1 80 l"~qooox~% ' ...... C E IV E D Normal Plane Travelling Cylinder - Feet APR 04 2001 All depths shown are Measured depths on Referen~a~V~?lnlil&gasOons. Oommissior'''-~'''''' A~chorage ATTACHMENT 5 Phillips Alaska, Inc. CD~2 42PH slot #42 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD2-42 PH Vers#3 Our ref : prop4293 License : Date printed : 14-Mar-2001 Date created : 15-Nov-2000 Last revised : 13-Mar-2001 Field is centred on nT0 20 37.1~0,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 17.591,w151 2 27.114 Slot Grid coordinates are N 5974373.313, E 371724.813 Slot local coordinates are 1983.52 S 1511.20 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-11984'>,,35,CD#2 PMSS <0-7170'>,,Neve #l,Neve #1 PMSS <1876-9940'>,,AlplA,Alpine #1 PMSS <1868-8850'>,,AlplB,Alpine ~1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 15-Nov-2000 59.0 875.0 875.0 16-Dec-1999 6826.0 9524.7 9524.7 21-Sep-1999 3880.2 2188.9 2188.9 21-Sep-1999 4182.5 0.0 710.7 RECEIVED APR 04 2001 ATTACHMENT 5 Phillips Alaska, Inc. CD#2 42 slot #42 Alpine Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : CD2-42 Version#3 Our ref : prop4134 License : Date printed : 14-Mar-2001 Date created : Il-Oct-2000 Last revised : 13-Mar-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 17.591,w151 2 27.114 Slot Grid coordinates are N 5974373.313, E 371724.813 Slot local coordinates are 1983.52 S 1511.20 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-11984'>,,35,CD~2 PMSS <0-7170'>,,Neve ~l,Neve #1 PMSS <1876-9940'>,,AlplA,Alpine ~1 PMSS <1868-8850'>,,AlplB,Alpine #1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 15-Nov-2000 59.0 875.0 10120.0 16-Dec-1999 3244.7 12639.3 12639.3 21-Sep-1999 3880.2 2188.9 2188.9 21-Sep-1999 4182.5 0.0 12639.3 APR 04 2001 41aska Oil & (las Corm,, Commissir~? Anchorage ATTACHMENT5 Phillips Alaska, Inc. CD~2 42PH slot #42 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : CD2-42 PM Vers#3 Our ref : prop4293 License : Date printed : 14-Mar-2001 Date created : 15-Nov-2000 Last revised : 13-Mar-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is nT0 20 17.591,w151 2 27.114 Slot Grid coordinates are N 5974373.313, E 371724.813 Slot local coordinates are 1983.52 S 1511.20 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath CD2-51 Vers$6, 51-81,CD$2 CD2-52 Vers#5, 52-124,CD$2 CD2-53 Vers#5, 53-95,CD#2 CD2-54 Vers$5, 54-128,CD$2 CD2-55 Vers$3, 55-127,CD#2 CD2-20 VersionS5 ,20-69,CD#2 CD2-24 Vers$6, 24-76,CD$2 CD2-25 VersionS3 ,25-43,CD#2 CD2-32 Vers$4, 32-50,CD$2 CD2-19 Vers#4, 19-46,CD#2 CD2-9 Vers#4, 9-136,CD~2 CD2-5 Vers94, 5-84,CD$2 CD2-18 Vers#4, 18-65,CD#2 CD2-11 Vers#5, 11-89,CD$2 CD2-6 Vers$4, 6-70,CD#2 CD2-57 Vers$3, 57-96,CD$2 CD2-58 Vers#3, 58-97,CD$2 CD2-7 VersionS3, 7-137,CD$2 CD2-12 Version#3 ,12-68,CD#2 CD2-10 VersionS3 ,10-71,CD$2 CD2-22 VersionS3 ,22-42,CD#2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 2-Feb-2001 2-Feb-2001 17-Jan-2001 5-Feb-2001 17-Jan-2001 22-Jan-2001 23-Jan-2001 23-Jan-2001 25-Jan-2001 22-Jan-2001 17-Jan-2001 17-Jan-2001 22-Jan-2001 16-Jan-2001 17-Jan-2001 5-Feb-2001 17-Jan-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 )88 0 )96 3 108 2 118 0 128 1 216 4 176 9 148 9 )66.1 224 7 327 7 368 1 237 5 308 2 358 1 147 5 158 2 348.0 294.7 318.0 197.6 3OO 5OO 3OO 300 30O 5OO 5O0 1112 1577 745 4OO 300 4O0 3OO 300 4O0 3O0 300 745 300 4O0 0 3OO 0 500 0 300 0 300 0 300 0 500 0 500 .5 1112 .8 1577 6 745 0 57O0 0 300 0 4OO 0 300 0 300 0 400 0 300 .0 4580 .6 745 .0 300 .0 6180 RECEIVED APR 04 2001 Oil & (~,~s {k,~.~s. ~;o~nmJ.ssm~ ATTACHMENT 5 CD2-37 Version~3,,37-52,CD~2 CD2-56 Version~2,,56-125,CD~2 CD2-47 Version#3,,47-126,CD~2 CD2-48 Version~3,,48-57,CD~2 CD2-49 Vers~5,,49-53,CD~2 CD2-46 Version~5,,46-49,CD~2 CD2-16 Versiong5,,16-38,CD~2 CD2-17 Version~3,,17-40,CD~2 CD2-13 Version~3,,13-73,CD~2 CD2-8 Vers#4,,8-72,CD~2 CD2-23 Vers#8,,23-67,CDg2 CD2-15 Vers~4,,15-66,CD~2 CD2-41 Vers#5,,41-58,CDg2 CD2-38 Version~3,,38-59,CD~2 CD2-31 Vers#5,,31-134,CDg2 CD2-45 Vers#4,,45-62,CD~2 CD2-44 Vers~4,,44-63,CD#2 CD2-27 Vers#6,,27-135,CD#2 CD2-29 Version#3,,29-45,CD~2 CD2-50 Vers#7,,50-51,CD~2 CD2-28 Versg6,,28-39,CD#2 CD2-39 Vers~8,,39-60,CD#2 CD2-35A Vers. #2,,35A-61,CD#2 PMSS <0-11984'>,,35,CD~2 CD2-14 Version~3,,14-41,CD#2 CD2-26 Version~4,,26-47,CD~2 CD2-30 Vers#5,,30-55,CD#2 CD2-40 Version#3,,40-56,CD#2 CD2-43 Leg#l Vers#2,,43-130,CD#2 CD2-34 Vers~5,,34-48,CD#2 CD2-42 Version~3,,42,CD~2 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 7-Feb-2001 23-Jan-2001 19-Jan-2001 8-Feb-2001 8-Feb-2001 25-Jan-2001 2-Feb-2001 1-Feb-2001 21-Feb-2001 8-Feb-2001 8-Feb-2001 24-Jan-2001 8-Feb-2001 8-Feb-2001 15-Nov-2000 8-Feb-2001 23-Jan-2001 24-Jan-2001 8-Feb-2001 9-Mar-2001 7-Mar-2001 13-Mar-2001 )41.8 )138.0 )48.0 )56.3 )47.4 )21.5 )257.0 )244.7 )287.0 )338.1 )185.1 )266.3 )5.4 )36.4 )104.7 )27.9 )17.9 ) 146.4 ) 125.8 )77.1 )137.9 )24.1 )6605.1 )52.3 )277.1 )155.6 )116.7 )13.4 )8.0 )73.6 )o.o 786.4 300.0 300.0 500.0 1500.0 1200.0 500 0 732 0 500 0 300 0 700 0 500 0 600.0 500.0 745.6 300.0 300.0 500.0 600.0 400.0 300.0 600.0 4600.0 913.2 500.0 700.0 500.0 500.0 300.0 700.0 9040.0 2600.0 300.0 300.0 500.0 1500.0 6300.0 500.0 732.0 500.0 300.0 700.0 500.0 600.0 500.0 745.6 300.0 300.0 500.0 600.0 1622 .2 300.0 600.0 4600.0 913.2 500.0 700.0 500.0 500.0 300.0 700.0 9040.0 ATTACHMENT 5 Phillips Alaska, Inc. CD~2 42 slot #42 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : CD2-42 Version#3 Our ref : prop4134 License : Date printed : 14-Mar-2001 Date created : il-Oct-2000 Last revised : 13-Mar-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is nT0 20 17.591,w151 2 27.114 Slot Grid coordinates are N 5974373.313, E 371724.813 Slot local coordinates are 1983.52 S 1511.20 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath CD2-51 Vers~6, 51-81,CDg2 CD2-52 Vers~5, 52-124,CD#2 CD2-53 Verst5, 53-95,CD#2 CD2-54 Vers#5, 54-128,CD#2 CD2-55 Verst3, 55-127,CD#2 CD2-20 VersionS5 ,20-69,CD~2 CD2-24 Verst6, 24-76,CD#2 CD2-25 Version#3 ,25-43,CD~2 CD2-32 Vers~4, 32-50,CD#2 CD2-19 Vers~4, 19-46,CD#2 CD2-9 Vers~4, 9-136,CD~2 CD2-5 Vers~4, 5-84,CD#2 CD2-18 Vers#4, 18-65,CD#2 CD2-11 Vers~5, 11-89,CD~2 CD2-6 Vers~4, 6-70,CD~2 CD2-57 Vers~3, 57-96,CD~2 CD2-58 Vers~3, 58-97,CD#2 CD2-7 VersionS3, 7-137,CD~2 CD2-12 VersionS3 ,12-68,CD~2 CD2-10 Version#3 ,10-71,CD#2 CD2-22 Version#3 ,22-42,CD~2 Closest approach with 3-D Minimum Distance method Last revised Distance 2-Feb-2001 2-Feb-2001 17-Jan-2001 5-Feb-2001 17-Jan-2001 22-Jan-2001 23-Jan-2001 23-Jan-2001 25-Jan-2001 22-Jan-2001 17-Jan-2001 17-Jan-2001 22-Jan-2001 16-Jan-2001 17-Jan-2001 5-Feb-2001 17-Jan~2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 )88.0 )96.3 )108.2 )118 0 )128 1 )216 4 )176 9 )148 9 )66 1 )224 7 )327 7 )368 1 )237 5 )308 2 )358 1 )147 5 )158 2 )348 0 )294 7 )318 0 )197 6 M.D. 300.0 500.0 300.0 300.0 300.0 500.0 500.0 1112.5 1577.8 750.0 400.0 300.0 400.0 300.0 300 0 400 0 300 0 300 0 750 0 300 0 400 0 Diverging from M.D. 10240 11960 12639 12639 12639 5OO 5OO 1112 1577 75O 5700 30O 400 300 300 12639 12639 3OO 75O 3OO 6180 0 0 3 3 3 0 0 5 8 0 0 0 0 0 0 3 3 0 0 0 °R[CE' VF.D ATTACHMENT 5 CD2-37 Version~3,,37-52,CD~2 CD2-56 Version~2,,56-125,CD~2 CD2-47 Version#3,,47-126,CD~2 CD2-48 Version~3,,48-57,CD~2 CD2-49 Vers~5,,49-53,CDg2 CD2-46 Version#5,,46-49,CD#2 CD2-16 Version~5,,16-38,CD#2 CD2-17 Version~3,,17-40,CD~2 CD2-13 Version~3,,13-73,CD#2 CD2-8 Versg4,,8-72,CD~2 CD2-23 Vers~8,,23-67,CD~2 CD2-15 Vers~4,,15-66,CD#2 CD2-41 Vers#5,,41-58,CD#2 CD2-38 Version#3,,38-59,CD#2 CD2-31 Vers#5,,31-134,CD~2 CD2-45 Vers#4,,45-62,CDg2 CD2-44 Versg4,,44-63,CD#2 CD2-27 Vers~6,,27-135,CD#2 CD2-29 Version~3,,29-45,CD#2 CD2-50 Vers#7,,50-51,CD~2 CD2-28 Vers#6,,28-39,CD#2 CD2-39 Vers~8,,39-60,CD#2 CD2-35A Vers. #2,,35A-61,CD~2 PMSS <0-11984'>,,35,CD#2 CD2-14 Version#3,,14-41,CD#2 CD2-26 Versiong4,,26-47,CD~2 CD2-30 Vers~5,,30-55,CD#2 CD2-40 Version~3,,40-56,CD~2 CD2-43 Leg#l Vers#2,,43-130,CD#2 CD2-34 Vers~5,,34-48,CDg2 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 8-Feb-2001 7-Feb-2001 23-Jan-2001 19-Jan-2001 8-Feb-2001 8-Feb-2001 25-Jan-2001 2-Feb-2001 1-Feb-2001 21-Feb-2001 8-Feb-2001 8-Feb-2001 24-Jan-2001 8-Feb-2001 8-Feb-2001 15-Nov-2000 8-Feb-2001 23-Jan-2001 24-Jan-2001 8-Feb-2001 9-Mar-2001 7-Mar-2001 )41.8 )138.0 )48.0 )56.3 )47.4 )21.5 ) 257.0 )244.7 )287.0 )338.1 ) 185.1 )266.3 )5.4 )36.4 104.7 )27.9 )17.9 146.4 125.8 )77.1( 137.9( )24 1( ) 6605 1 ( )52 3( )277 1( )155 6( )116 7( )13 4( )8 0( )73 6( 775.0 300.0 300.0 500.0 1500.0 1200.0 500.0 725.0 500.0 300.0 700.0 500.0 600.0 500.0 750.0 300.0 300.0 500.0 600.0 400.0 300.0 600.0 4600.0 925.0 500.0 700.0 500.0 500.0 300.0 7O0.O 2600.0 12639.3 12639.3 12639.3 12639.3 12639.3 500.0 725.0 500.0 8890.1 700.0 500.0 12639.3 12639.3 75O.0 10620.0 11120.0 500.0 600.0 12639.3 300.0 12639.3 12639.3 11440.0 500.0 700.0 500.0 12639.3 12639.3 12639.3 RECEIVED APR 04 2.001 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 30, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-42 (& CD2-42 PH) Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is April 24,2001. It is intended that Doyon Rig 19 be used to drill the well. The CD2-42 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 42.7°. 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 the completion of well work and facilities work that will allow the well to be put on production. 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). CD2-42 Pilot Hole Cementing Requirements. 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. RECEIVED APR 04 2001 Alaska Oil & Gas Cons. Commission Anchorage If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip AIvord at 265-6120. Sincerely, Veto Johnson Drilling Engineer Attachments CC: CD2-42 Well File / Sharon AIIsup Drake Chip Alvord Cliff Crabtree Meg Kremer G racie Stefanescu Lanston Chin ATe 153O ATe 8698 ATe 848 ATe 844 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com RECEIVED APR 04 ~001 Oi]& Gas Oons. ^n¢~orage American Express® ...... ., :~'..~; :': ~ ..'.~. - Cash Advance Draft 124 PAY TO 1 / . ~ ' ~ ' .... DOLLARS I~ued by In~ P~n= Sys~m, In~ EndOwS, ~mdo NOT VALID FOR A~OUNT OVER $1~ PERIOD ENDING , .~,)~ ~:~ ,, /~. _..:~~., ,~. ~/_~, ':~0~00~00~:~5 '"0~750005 FIELD & POOL ADMINISTRATION ENGINEERING DATE WELL NAME 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 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 ........... PROGRAM: exp dev ~ redrll serv wellbore sag ,,. GEOL AREA ~' ~ UNIT# ~ ,5'0 .~=, ~ · 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 '~-~,,) ' 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y ann. disposal para req ON/OFF SHORE' GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ~YY N_~//~, ~.. 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. AP, E.R DATE 33. Seabed condition survey (if off-shore) .............. /.,,~.~ g///..~f~,! 34. Contact name/phone for weekly progress reports [explorat~,'~nly] Y N Wi~oper cementing records, this plan (A) will contain waste in asuitable receivingzonei ....... ~ N ,,~Z_\k .k-~ ~.-\¢a~,~%.~..,,.w_\\ ~_~--~;) ~, ~ ~:,9,o¢:.~%7' ~,t::)PiLoV'/%.L ~"~3---. IIAPPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; ~,'J ~ '~tt[:,l.ol (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. ~ N GEOLOGY: ENGINEERING: UIC/Annular WM COMMISSION: Ts '"",~./..Y. r, JM~j~d'~ O Z O ITl Z --I 'r- c:\msoffice\wordian\diana\checklist (rev. 11/01//00)