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Home My WebLink About204-167 -~----- . '-'" Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cl 0 y.. - L fa 7 Well History File Identifier Organizing (done) o Two-sided 11I11111111 ""I III o Rescan Needed 11111111"""'111I RESCAN ø&lor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: o Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: D Other:: BY: ..C Maria J I Date: t J . "Lf / (](p /5/ (Mj Project Proofing 111111111111111111 BY: C _ Maria , Date: i I ¡ '/4-/ Ð ~ ~ X 30 = {PO + ~ Date: II , ?If I D{¡; Is! WI,J = TOTAL PAGES In ~ (Count does not include cover sheet) I A A ,"\ /5/ V VVJ Scanning Preparation BY: (" Maria) Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: (12 q (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~aria ,) Date t ( Ilf-(O fo If NO in stage 1 page(s) discrepancies were found: YES NO Isl V\1 0 NO BY: Stage 1 BY: Maria Date: Is/ 11I1111111" 1111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked III 111/1111I" 11111 1 0/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEI VED . ALA•OIL AND GAS CONSERVATION COMMI[ON DEC 4 2 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well • Rug Perforations r Perforate r Other O 3CC Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r 4�VV'' Change Approved Program rOperat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: _4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J ' Exploratory r _ 204-167 . 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-22654-01 . 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25652.ALK 2578 1F-18A . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured ' 9065 feet Plugs(measured) None true vertical 6078 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 6985,6986 true vertical 0 feet (true vertical) 5774, 5774 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121' 0 0 SURFACE 4213 10 4254 3730' 0 0 PRODUCTION 7177 5.5 7208 5940' 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7749'-7845',7858'-88 ;pWINED DU 1 9 2013 True Vertical Depth: 6120'-6099,6096'-6090' Tubing(size,grade,MD,and TVD) 3.5, L-80,6985'MD,5774 TVD Owen 30' Permanent Patch 6915' -6945' Packers&SSSV(type,MD,and TVD) Packer Baker Sable-Liner Packer MD=7000 TVD=5785 SSSV=SSSV nipple profile MD=499 TVD=499 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. - Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development gr Service r Stratigraphic r X 16.Well Status after work: Oil P''. Gas r VVDSPL r Daily Report of Well Operations GSTOR VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt N/A Contact Brent Rogers/Kelly Lyons Email n1617(cf�,cop.com Printed Name Brent Rogers Title Problem Wells Supervisor Signature '�/��/�/ Phone:659-7224 Date 11/24/13/V. ,' LfL C iOt / 0'/ f i !;;Iiit' DEC 13 21 J 2 /t 7/13 Submit Original Form 10-404 Revised 10/2012 ginal Onl y • • 1F-18A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/29/13 RAN 2.715"x 34' DMY PATCH TO 7014' RKB. NO PROBLEMS.SET 2.75"x 1.81" NIPPLE REDUCER IN D-NIP @ 6978' RKB.SET 1.81"AVA CAT SV IN NIPPLE REDUCER @ 6978' RKB. PASSING CMIT-TxIA W/LRS...READY FOR E-LINE 11/17/13ISET 30' PATCH WITH TOP ELEMENT AT 6915' 11/18/13IMITT TBG TO 3000 PSI ( PASS) PULLED SV @ 6978' RKB.JOB COMPLETE. I Summary Set 2.75"x 1.81" Nipple reducer @ 6978'. Set 30' Permanent Patch from 6915'-6945' MITT passed following patch set. ConocoPhillips RECEIVED Alaska DEC 0 2 2013 P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 November 25, 2013 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1F-18A PTD 204-167 tubing patch. A 30' Owens permanent tubing patch was set to repair the tubing. Please call Kelly Lyons or myself at 659-7224 if you have any questions. Sincerely, Brent Rogers ConocoPhillips Problem Well Supervisor Enclosures F KUP PROD 111 1F-18A ConoccPhalips a Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Fold Name Wellbore Status ncl(3 MD(ftKB) Act Btm(ftKB) Coca;rtalnps : 500292265401 KUPARUK RIVER UNIT PROD 103.44 7,654.46 9,080.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1F-18A,11/25/20135:32.53 AM SSSV:NIPPLE 200 8/14/2012 Last WO: 9/29/2004 5/25/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ....._._.____________ __.............. Last Tag: Rev Reason:GLV C/O, PULL CAT SV,SET hipshkf 11/20/2013 PATCH HANGER;278 `;n!. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread t SURFACE 75/8 6.625 41.0 4,253.6 3,730.0 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB( Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 51/2 4.950 31.2 7,207.8 5,939.9 15.50 L-80 LTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread LINER Post S/T 3 1/2 2.992 7,000.2 7.463.1 6.127.7 9.30 L-80 BTC-MOD ,�Liner Details CONDUCTOR;42.0.121.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(3 Item Des Com (in) NIPPLE;498.6 7,000.2 5,784.7 41.04 PACKER BAKER SABL-3 LINER PACKER 2.815 la Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(ND(...WtlLen(I...Grade Top Thread WINDOW AL1 3 1/2 2.992 7,393.0 7,397.0 6,084.0 9.30 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)ND)...WtlLen(I...Grade Top Thread GAS LIFT;2.462.8 - LINER A Top 2 3/8 1.995 7,435.5 7,857.0 6,096.3 4.70 L-80 STL Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(°) Item Des Com (in) 7,435.5 6,111.5 50.08 DEPLOY B/C SAND BAKER DEPLOYMENT SLEEVE, 1.000 CONNECTS TOP&BOTTOM LEG PORTIONS OF LEG A LINER SURFACE;41.0-4,253.6- ' .. 7,845.2 6,098.7 101.88 0-RING BAKER 0-RING SUB 1.000 Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread LINER A Bottom 2 3/8 1.995 7,856.9 8,863.5 6,088.6 4.70 L-80 STL Liner Details GAS LIFT;4,343.1 '4 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc'C) Item Des Com B/C SAND BAKER DEPLOYMENT (in) 7,856.9 6,096.3 101.63 DEPLOY OYMENT SLEEVE, 1.995 CONNECTS TOP&BOTTOM LEG PORTIONS OF LEG A LINER GAS LIFT;5,577.5 8,841.8 6,089.8 92.77 0-RING BAKER 0-RING SUB 1.000 I Tubing Strings Tubing Description String Ma...ID(m) Top(MB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 27.8 7,000.2 5,784.7 9.30 L-80 ABM-EUE GAS LIFT;6,303.6 Completion Details IC Nominal ID illTop(ftKB) Top(ND((ftKB) Top Incl(°) Item Des Com (i n) 27.8 27.8 1.27 HANGER FMC GEN IV TUBING HANGER 3.500 all 498.6 498.5 0.65 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812 PATCH;6,9150 si 6,978.4 5,768.3 40.96 NIPPLE CAMCO D NIPPLE 2.750 GAS LIFT;6,930.5 ! 6,985.4 5,773.6 40.98 LOCATOR BAKER LOCATOR SUB 3.000 6,985.8 5,773.9 40.98 PBR BAKER PBR 3.000 6,999.4 5,784.2 41.04 ANCHOR BAKER ANCHOR 3.000 NIPPLE;69784 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) NIPPLE REDUCER;6,,978.4 Top(ND) Top Inc! Top(ftKB) (ftKB) (°) on Com Run (in) 50 LOCATOR,6.985.4 6,915.0 5,720.3 40.71 PATCH 30'PERMANENT PATCH,TOP ELEMENT @ 6915, 11/17/2013 Date ID 2.2 - OAL-32.46 PBR,6,985.8 ' 6,978.4 5,768.3 40.96 NIPPLE 2.75"x 1.81"NIPPLE REDUCER 10/29/2013 1.810 ANCHOR;6,999.4 I I REDUCER m 7,393.0 6,081.0 39.22 WHIPSTOCK WHIPSTOCK Ay SIDETRACK WINDOW 9/18/2004 7,435.0 6,111.2 49.94 DEPLOY B/C SAND WEATHERFORD AL DEPLOYMENT 9/18/2004 1.000 SLEEVE/OH WHIPSTOCK FROM LATERAL LEG AL I TO LEG A 7,857.0 6,096.3 101.63 DEPLOY B/C SAND BAKER DEPLOYMENT SLEEVE, 9/18/2004 1.995 CONNECTS TOP&BOTTOM LEG PORTIONS OF LEG A LINER PRODUCTION;31.2-7207.8 Perforations&Slots Shot Dens DEPLOY;7,254.0 Top shots/f Bt op(ND) m(ND) LI Top(ftKB( Btm(ftKB) (ftKB) (ftKB) Zone Date t( Type Com 7,749.0 7,845.0 6,119.6 6,098.7 UNIT B,1F- 9/17/2004 8.0 IPERF 3/8"Holes every 3",90 18A deg orient IPERF;7,257.0-9,036.0 7,858.0 8,842.0 6,096.1 6,089.8 UNIT B,C-4, 9/17/2004 8.0 IPERF 3/8"Holes every 3",90 WHIPSTOCK;7,397.0 1F-18A deg orient WINDOW AU;7,393.47,397.0 LINER AL1;7,253.6-9,080.0 Mandrel Inserts WINDOW A;7,429.07,435.0 St ati C on DEPLOY;7,435.0 Top(ND) Valve Latch Port Size TRO Run No Top)ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date m 1 2,462.8 2,384.7 BST AXT 1 GAS LIFT GLV T-1 0.156 1,222.0 2/7/2009 'I 2 4,343.1 3,794.5 BST AXT 1 GAS LIFT GLV T-1 0.156 1,233.0 11/20/2008 3 5,577.5 4,689.1 BST AXT 1 GAS LIFT GLV T-1 0.188 1,270.0 11/20/2008 LINER Pant SIT;7,050,2- 4 6,303.6 5,249.4 BST AXT 1 GAS LIFT OV T-1 0.250 0.0 8/11/2013 7,463.1 I �� 5 6,930.5 5,732.1 BST AXT 1 GAS LIFT DMY T-1 Ext 0.000 0.0 1019/2008 IPERF;7,749.0-7,845.0 ! I Pkg Notes:General&Safety End Date Annotation 9/29/2004 NOTE.1F-18A PRODUCING,BUT"NOT ACCESSIBLE FOR WELLWORK" LINER A Top;7,435.5-7,857.0 9/29/2004 NOTE:Liner 1F-18A in 2 parts 7435'-7857'&7857'-8841'w/connecting deployment sleeve DEPLOY;7,857.0 9/29/2004 NOTE:CTD DUAL SIDETRACK-1F-18A(B/C SANDS),1F-18AL1(NC SANDS) IPERF;7,658.08,842.0 8/25/2008 NOTE:1F-18AL1 S/T off main 1F-18 wellbore;1F-18A S/T off 1F-18AL1(See Attachment) 10/23/2008 NOTE:Install sleeve(9.625"pipe);.375 wall,Surf Csg Patch that straddles collar(OAL 9'6") 9/14/2010 NOTE:View Schematic w/Alaska Schematic9.0 LINER A Bottom;7,856.9- 8,863.5 Con P ' ' oco hsll~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: _~~7 ao~ .~,~f~ ,~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl7, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~~a Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-18A 204-167 15' 5" 2.50 44" 10/30/2008 27.2 11P/2008 1E-16$ 204-200 15" NA 15" NA 3.4 11/7/2008 1 E-17 205-074 13" NA 13" NA 5.53 11 /7/2008 1J-122 207-070 15" NA 15" NA 3.4 11/7/2008 1 J-14 200-200 16" NA 16" NA 1.27 11/7/2008 1J-152' 206-016 3' NA 3' NA 19.55 11/17/2008 1J-158 207-054 6' NA 6' NA 27.2 11/7/2008 1J-162 2 7-080 15" NA 15" NA 2.55 11/7/2008 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1J-168 205-060 10" NA 10" NA 3.82 11/7/2008 1J-170 206-062 8" NA 8" NA 1 11/7/2008 1 J-174 207-143 24" NA 24" NA 17 11 /7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 • ~ ~ ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 26, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~~, . zq~~ ~~~~, `~~~:-' ~~i~`k' 1 ~ ~t~G~ Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 1F-18A (PTD 204-167, Sundry 308-305). The report records the completion of the surface casing excavation, inspection, and repair of Kuparuk well 1 F- 18A. Please call MJ Loveland/Perry Klein at 659-7043 if you have any questions. Sincerely, MJ oveland Well Integrity Project Supervisor 1 F-18A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/05/08 10111/08 10/23/08 Excavated for surface casing repair,set bilge sump,shoring box and stairs.Cut and removed stand plate.T/I/O = SI/0/0. T/I/O = SI/0/0. Removed 15' S" of conductor annulus.Removed cement and cleaned surface casing with wire wheel.Drilled hole out to 1/2" hole.Hole is 3' 1" below O e.Marked for "A" and "B" bands."A" band is 8.75" "B" band is 12" with 8' 10" between top of "A" band and top of "B" band.FL-OA @ 19' 1" below OA valve.FL-OA is ~ 8' 3" below bottom of "B" band.Secured wellhead to shoring box and cleaned off scaffold. SC patch weld -Complete. Purge nitrogen down annulus while welding @ 5 %. Patch Welded as per M.E. specs. Weld collar (8" pipe) 50 3/4" .500 wall (upper) wedding band in no-go style including tie in seal weld on top of wedding band to mandrel hanger and bottom of wedding band to SC coupling. Weld collar (8" pipe) 4" (lower) .500 wall wedding band. Install sleeve (9.625 pipe) .375 wall SC patch that straddles SC collar. Total patch length from bottom of mandrel hanger to lower most wedding band is 9' 6". T/I/O = 0/1/0. 10/24/08 MITOA -PASSED, (Post SC patch weld). Pre MIT T/I/O = SI/3/0 Bleed IA to zero. Pressured OA to 1800 psi with 1.0 bbl diesel. Initial MIT T/I/O = SI/0/1800, started MITOA, 15 min. - T/I/O = SI/0/1775, 30 min - T/I/O = SI/0/1750, 45 min - T/I/O = SI/0/1725, 60 min - T/I/O = SI/0/1725 ,Total loss of 75 psi. Bled OA to zero. T/I/O = SI/0/0. Photo taken of the SC repair. Remove manifolds with gauges & install needle valves for back filling excavation on IA/OA. Install VR plug in IA. Then wrapped SC with Denso wrap. Ready to install conductor. ~ .. `R ~~ 4~ ~ STATE OF ALASKA i ~•.. , ALASKA OIL AND GAS CONSERVATION COM ~ I' ~ `'~' REPORT OF SUNDRY WELL OPERATIOI~~ '' 1. operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other ^ Patch sC 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. Develvprnent 0 Exploratory ^ 204-167 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22654-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 108' 1 F-18A • 8. Property Designation: 10. Field/Pool(s): ADL 25652•ALK 2578 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9065' feet true vertical 6078' ' feet Plugs (measured) Effective Depth measured feet Junk (measured) 7395' Whip stock true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 4146' 7-5/8" 4254' 3730' PRODUCTION 7012' S-1/2" 7208 5940' LINER-ORIG. WE 393' 3-1/2" 7393' 6081' WINDOW forAL1 4' 7397' 6092' Perforation depth: Measured depth: 75$5-7620 true vertical depth: 6236-6265' Tubing (size, grade, and measured depth) 3-1 /2" , L-80, 7000` MD. Packers &SSSV (type & measured depth) Packer Baker Sable- Liner Packer 6999' SS5V= SSSV nippi profile SSSV= 499' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: _ 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 WA if C.O. Exempt: 308-305 contact MJ Loveland/ferry Klein Printed Name MJ Loveland ~ -' Title WI Project Supervisor Signature ~`, f` Phone: 659-7043 Date .10/26/2008 Form 10-404 Revis~o4/2004 ~ ~ ~~ ~ ~ ~ ~~ H L i`~~ ~'', ill"rit °. ~ ~~Q~ <<'`~ '~l/ r~G°'f _ ~~ ~~•~~'j~ ~ r ~ ~ ~ Submit Original Only ~ STATE OF ALASKA AU G 2 7 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV~aslca Oil & Gas Cons• Ca~mmtsslan 20 AAC 25.2so Anchorage 1, Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other Q Altercasing ^ RepairweA Q Plug Perforations ^ Stimulate ^ Time f_xteesion Change approved program ^ Pull Tubing - ^ .Perforate New Pont ^ Re-enter $uspentled Well ^ ~~ SC Patch 2.Operator Name: 4. Current Welt Class:. 5. Permit to DriII Number. ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 204=167 - 3. Address: - ~ - Stratigraphic ^ ~~ • ^ 6. API Number. P. O. Box 1003fi0, Anchorage, Alaska 99510 50-029-22854-01 • . 7. F perforating, closest approach in goof(s) opened by.this. operation to nearest property line 8. Well Name and Number. ' where ownership or landownership changes: ~ ' Spacing Exception Required? . Yps ^. • NO ^ 1 F-18A 9. Property Designation: ~ 10. KB Elevation (ft): 11. FieldlPool(s): ADL 25652 ALK 2578 - ~B 1 Og. • . Kuparuk River Field / tCttparuk Oii Pooi 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Oepth Mo (ft): Effective Depth TVD (ft): Plug§ (measured): Junk (measured): 9065' 6078' ~ 7395' Whip stock Casing Length Size MD ~ TVD Burst Coi(apse CONDUCTOR 121' 16" ~ 121' 121' SURFACE 4146' 7-5/8" 4254' 3730' PROGUCTION 7012' 5-1/2" 7208 5940' !.(NER-ORIG. WELLBOR 393' 3-1/2" 7393' 6081' W W DOW for AL1 4' 739T 6092' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tutting Grade: Tubing. Mb (ft): 7585-7620 6236-6265' 3=112" L-80 7000' Packers and SSSV Type: ~ ~ Packers and SSSV MD (ft) Packer Baker Sable- Liner Packer 6999' SSSV= SSSV nippl profile SSSV= 499' 13. Attachments: Description Summary of Proposal Q 14. Welt 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: - November s, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ . 17. Verbal Approval: ~. Date: ~ WAG [~ _ GIIVJ ^ " WINJ ^ WDSPL ^ Commission Represenfative: 18. i hereby certify that the foregoing is true and correct to the best of my knowledge. ContaeL• Perry Idein/ MJ Loveland ' Printed Name ~ MJ Loveland or Per Klei ~ 'Tttie: WI Project Supervisor Signature Phone: 659-7043 Date ~ ,Zy C> `~ Commission Use Oni ~ ~ - Suridry Nu ber. Conditions of approvaL• Notify Commission so that a representative may witness .~ Plug Integrity ^ BOP Test [] Mechanical Integrity Test ^ Location clearance ^ Other. 3ttbsequent Fonn Required: ~Q. ~(~ ~~ p~~CV'O"'1~~~~~~ 0~~~~ ~. ~ ~~ ~ ` P .:-.. - .. `.: - , . ,. .,.s . .. .. ......... . . . ' .: , PPROVED BY ~ .. • roved bY• ~ - • COMMISSIONER THE COMMISSION _ Date: - _ . Form 10=403 Revised g ' ; ~ ,• .Subinif to DuPUca'te • • l ~gg ~ SARAH PALIN, GOVERNOR ~1 taista-~~ OIL A~D ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5IiRQA1`IOI~T COMbII55ION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland WI Project Supervisor ConocoPhillips Alaska, Inc PO Box 100360 Anchorage AK 99510 O ~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 F-18A Sundry Number: 308-305 Dear Ms. Loveland: ;~~,~NN~~ SAP ~ 208 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 3 day of September, 2008 Encl. • • Conoco~illips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~~ AUG 2 7 2008 August 25, 2008 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Alaska Gil ~ Gas Cc~r~s. ~a~missior~ Anch~ra~a Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1F-18A PTD 204-167 surface casing excavation and repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures ~ ,~~ ~~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~E~~~~~~ ~~ 1 ~~ ~4UG 2 7 2008 ~K t1` APPLICATION FOR SUNDRY APPROVAI~~~~~ oi~ ~ ~~~ ~~~~ k.~~~~~~,~i~ 20 AAC 25.280 ,~r30 ^ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ~ {Vier casing ^ Repair well /^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ External SC Patch Operator Name: 2 4. Current Well Class: 5. Permit to Drill Number: . InC Alaska Development Q Exploratory ^ 204-167 - . , ConocoPhillips I N b 3. Address: Stratigraphic ^ Service ^ er: um 6. AP P. O. Box 1 p9360, Anchorage, Alaska 99510 50-029-22654-01 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 Required? Y@S ^ NO Q 1 F-18A 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25652 ALK 2578 RKB 108' Kuparuk River Field /Kuparuk OiI Pool P RESENT WELL CONDITf ON SUMMARY 12 Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9065' 6078' 7395' Whip stock Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121' SURFACE 4146' 7-5/8" 4254' 3730' PRODUCTION 7012' S-1/2" 72pg 5940' LINER-ORIG. WELLBOR 393' 3-1/2" 7393' 6081' WINDOW for AL1 4' 7397' 6092' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ' 7585-7620 6236-6265' 3-1 /2" L-80 7000 Packers and SSSV Type: Packers and SSSV MD (ft) Packer Baker Sable- Liner Packer 6999 SSSV= SSSV nippl profile SSSV= 499' Attachments: Description Summary of Proposal Q 13 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: d ^ Abandoned ^ ^ Pl ~~ Commencing Operations: November a, Zoos ugge Gas Oil ~ 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: Perry Klein/ MJ Loveland Printed Name MJ Loveland Or Perr ~ KI21 Title: WI Project Supervisor Phone: 659-7043 Date 45' ,2 y ~ `~ Signature Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~ L f i ~ , , ~~~t~t~ O~P~-~E~ ~~\~ ,~ ~~ Q OCv ~ ~~v~ l C~ T APPROVED BY ~ _ CnMMISSInNFR THE COMMISSION Date: ~___ ~, ~ ove° oy~ Form 1 ~~~ SEP 0 ~~ 2DDE r.~it in Duplicate~LD ~~ • ConocoPhillips Alaska, Inc. Kuparuk Well 1F-18A (PTD 204-167) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 24, 2008 This application for Sundry approval for Kuparuk well 1F-18A is for the repair of a surface casing leak. The well is an oil producer and the mother bore 1F-18 was drilled in June 1996. 7 5/8" surface casing was run and cemented as planned. In November 2004 it was coiled tubing side tracked as 1F-18A. In March 2008 a diesel stain was observed around the well head in the gravel. The suspected surface casing leak was reported to AOGCC 3/25/2008. Subsequent testing indicated a leak in the surface casing approximately 9' 2.5" down from the OA valve. With approval, repair of the surface casing will require the following general steps: 1. Shut-in and secure well. Set positive pressure plug @ 6978' and fluid pack the IA as needed to remove all gas. Freeze protect T and IA as needed. PT plug to verify barrier. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. • Cono~coPt~illips Alaska, Inc. '1 i=~18AL1 API: SSSV Type: NIP (499-500, OD:3.500) Annular Fluid: Reference L Last Ta TUBING _ - ~ Last Ta Date: (0-7000, ` in Strin - OD:3.500, Descrl Ion ID:2.992) o~nni Ir- PRODUCTION (0.7208, OD:5.500, wt:1 s.5o> Gas Lift MandrelNalue 3 (55775578, Gas Lift MandrelNaloe a (s3o3~3oa, Gas Lift MantlrelNal~,e 5 (69305931, NIP (69765979, OD:3.500) PBR (69866987, OD:3.500) PACKER (6999-7000, OD:3.500) SLEEVE (7254-7255, OD:2.700) LINER Oltl 1 F-18 (7000-7400, -~ OD:2.375) _._ I Perf (7257-9036) ---- LINER LEG AL1 -_-- I I (7253-9080, -- OD:2.375, --- Wt:4.70) ___ • KRU 1 F-18AL1 Orig 9/30/2004 Angle @ TD: 91 deg @ 9144 Com letion: , _ Last W/O: Rev Reason: FORMAT UPDATE Ref Loa Date: Last Update: ~ 12/27/2007 LINER LEG AL1 2.3 g String -TUB-II, _ Size Top 3.500 0 _ __ rations Summary _____ arval TVD Z - 9036 t 5977 - 6270 C-4 >,A-4 iVa B MD TVD Man Mfr ?463 2385 BST rt Man Ty AXT UNIT 1779 4-4,A-a 8 9/25/2004 ~ V Mfr V Type -- .._ GLV V OD Latc 1.0 T- GLV 1.0 T- _GLV 1.0__ T- _ GLV OV 1.0 T- 1.0 ~ T- lRY __ 'DS' NIPLE Description _ 'D' NO GO NIPPLE PBR JD LINER BAKER SABL-3 LINER PAC JD BAKER DEPLOYMENT SUB FROM I ,, ; ~ ~:s ~ LACK - 1F-18A /B/C SANDSI. 1 F-18AL sis° rlaes every s', 90 dea 1.875 1F-18AL1, Gaslift producer PTD # 204-167, notice of surface casing leak Page 1 of 2 • i Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Wednesday, March 26, 2408 8:30 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: RE: 1 F-18A, Gaslift producer PTD # 204-167, notice of surface casing leak Tom, A recent well test indicates that 1 F-18A will flow unassisted by gaslift. We have shut in and freeze protected the well while we install a pit liner in the cellar and circulate the internal waiver for approval signatures. We plan to have it back on production shortly. The well and waiver will be included in the quarterly SCP report. We plan on excavating and repairing the surface casing. The proper paper work will be submitted for 10-403 sundry approval at a later date. Let me know if you have any questions. Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907} 659-7043 Cell Phone (907) 943-1244 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 25, 2008 10:37 AM To: NSK Well Integrity Proj Cc: Regg, James B (DOA); NSK Problem Well Supv Subject; RE: 1F-18AL1, Gaslift producer PTD # 204-167, notice of surface casing leak Perry, Thanks for the information. Please keep us updated. On item, the correct well name reference should be 1 F-18A. You have the correct PTD number. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, March 25, 2008 10:26 AM To: Maunder, Thomas E (DOA) 8/29/2008 1F-18AL1, Gaslift producer PTD # 204-167, notice of surface casing leak Page 2 of 2 • Cc: Regg, James B (DOA); NSK Problem Well Supv Subject: iF-18ALi, Gaslift producer PTD # 204-167, notice of surface casing leak Tom, 1 F-18AL1, Gaslift producer PTD # 204-167, has a surface casing leak. While attempting an MITOA on 3/24/08 fluid exited the conductor. Initial T/I/O = 200/1175/100 The leak rate is 1/2 cup per minute at 1800 psi. We suspect a shallow surface casing thread leak, possibly from the initial pup joint collar. Final T/1/O = 200/1175/0 1 F-18AL1 passed a TIFL, tubing packoff tesfi, and inner casing pack off tests on 3119/08 Immediate action will be to determine if the well will flow unassisted by lift gas. If it will flow, we plan to internally waiver the well and continue to produce until it can be excavated and repaired. If the well will not flow naturally, it will be shut in until repaired. I've enclosed a 90 day TIO plot and a schematic for your convenience. Let me know if you have any questions. Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cefl Phone (907) 943-1244 For Problem We{Is Supervisor «1 F-18 90 day TIO.jpg» «1 F-18AL1.pdf» 8/29/2008 r1 ~_ - ww~ .. ~ ~7A, .,, ,~ ,; -. , MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc ~q tJŒ ~~ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041670 Well Name/No. KUPARUK RIV UNIT 1F-18A Operator CONOCOPHllLlPS ALASKA INC SRU L 1;( ¥ß'ù'f API No. 50-029-22654-01-00 MD 9065 ~.. TVD 6078 0/ Completion Date 9/29/2004 /'" Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other logs Run: GR / ROP / PRESS Well log Information: log/ Electr Data Digital Dataset log log Run Type Med/Frmt Number Name Scale Media No I Rpt Directional Survey ~c ,. 13804 Gamma Ray 13804 LIS Verification Log Gamma Ray ~ Blu I1D LL:~__ Gamma Ray 25 Blu ìl/ I':, Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? ~ Chips Received? 'H-N- Daily History Received? Formation Tops Analysis Received? "'----"" Y/N - Comments: -- Compliance Reviewed By: ~ Current Status 1-01L UIC N .~~~ Directional Survey Yes ~~-_..- (data taken from Logs Portion of Master Well Data Maint Interval OH/ . Start Stop CH Received Comments 7300 9065 Open 11/8/2004 7395 9065 Open 3/13/2006 GR ROP 7395 9065 Open 3/13/2006 GR ROP 7395 9065 Open 3/13/2006 GR ROP 7395 9065 Open 3/13/2006 GR ROP Sample Set Number Comments @ ~ . ~~~- Date: JJ-ò ~~ 6- . . Transmittal Form '&ill BAKER MUGHU INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: IF-18A Contains the following: -# n ~o'1 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GRlDirectional True Vertical Depth Log LAC Job#: 751636 Sent By: GI/j yorel A .1 / I J Re<eived By: ~ () /A.J Date: March 7, 2006 Date: I) I1M1J~ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 r;.O<{-((¡,7 II . -~-.......,... f __ :::~;~~ J ;~ ~:~ d .-.'" ·'''N I I a'......' -:;::~:~ =-:- ,,:,,'''''i'~~''''... ,,..-:- ·hI.''- ",<'" .". "a _...: ":,".:;M'~10 M1 1'IJi.:-: _...'~- -...",.... . "'" ",j~"p,.,~ ~. _~ STATE OF ALASKA ___ ALAS~ AND GAS CONSERVATION COMWSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandaned 0 Suspended 0 WAG 1b:WeIlClass: 20AAC 25.105 20AAC 25.110 181 Develaprraent 0 Explaratary Na. .of Campletians One Other 0 Stratigraphic 0 Service 5. Date Camp., Susp., .or Aband. 12. Permit ta Drill Number 9/29/2004 I 204-167 6. Date Spudded ¡z.. fP II' 11·£.>:1 13. API Number 91.1ð72004 . 50-029-22654-01-00 7. Date T.o. Reached 14. Well Name and Number: 9/16/2004 ' Kuparuk 1F-18A 8. KB Elevatian (ft): 15. Field / Paal(s): 108' Kuparuk River CASING, LINER AND CEMENTING RECORD Sfrt:rINGD¡:r;rrHMD SemNGDEF'THJVD BOTTOM Top BOTTOM 121' Surface 121' 4254' Surface 3730' 7208' Surface 5940' 7393' 5785' 6081' 8864' 6112' 6089' o GINJ 0 WINJ 0 WDSPL 2. Operatar Name: Canaca Phillips Alaska Inc. 3. Address: c/a P.O. Bax 196612, Ancharage, Alaska 99519-6612 4a. Lacatian .of Well (Gavernmental Sectian): Surface: 792' SNL, 455' WEL, SEC. 19, T11N, R10E, UM Tap .of Productive Harizan: 1867' NSL, 210' WEL, SEC. 18, T11 N, R10E, UM Tatal Depth: 2802' NSL, 1528' EWL, SEC. 17, T11N, R10E, UM 4b. Lacatian .of Well (State Base Plane Caardinates): Surface: x- 539521 " y- 5958733' Zane- ASP4 TPI: x- 539743 y- 5961393 Zane- ASP4 Tatal Depth: x- 541473' y- 5962338' Zane- ASP4 18. Directianal Survey 21. Lags Run: GR/ROP/PRESS 181 Yes DNa 22. 16" 7-5/8" 5-1/2" 3-1/2" 2-3/8" 62.5# 29.7# 15.5# 9.3# 4.7# H-40 L-80 L-80 L-80 L-80 Surface Surface Surface 7000' 7435' 23. Perfaratians aRen ta Praductian (MD + TVD .of TaE and Battam Interval, Size and Number; if nane, state' nane"): 2-3/8" Slatted Sectian MD TVD MD TVD 7449' -7845' 6120' - 6099' 7858' - 8842' 6096' - 6090' 26. Date First Praductian: Octaber 12, 2004 Date .of Test Haurs Tested 10/14/2004 6 Flaw Tubing Casing Pressure Press. 1037 1417 27. PRODUCTION FOR TEST PERIOD ... CALCULATED ....... 24-HoUR RATE"'?" OIL-BsL 591 Nane Farm 10-407 Revised 12/2003 9. Plug Back Depth (MD+ TVD) 9065 + 6078 10. Tatal Depth (MD+TVD) . 9065 + 6078 11. Depth where SSSV set 499' MD 19. Water depth, if affshare N/A MSL Ft Ft 16. Praperty Designatian: ADL 025652 17. Land Use Permit: 20. Thickness .of Permafrast 1380' ss (Apprax.) i/td~ 737'';-/nµ ~682. ry-r<þ 24" 9-7/8" 6-3/4" 4-3/4" 3" SIZE 3-1/2", 9.3#, L-80 DEPTH INTERVAL (MD) GAs-McF 499 WATER-BsL 530 PRODUCTION TEST Method .of Operatian (Flawing, Gas Lift, etc.): Gas Lift OIL-BsL 148 CORE DATA Brief descriptian .of lithalagy, parasity, fractures, apparent dips and presence .of ail, gas .or water (attac:I1§~parate sheet, if necessary). Submit care chips; if nane, state "nane". r ¿{;;i;·:::¡ :6;< ¡ RBDMS BFl NOV 1 7 2004 I c¡ ~~l· d \ ~ "r ~.-,'?' i ì.~"'¡'C·""I. t . .~i , ,~<>. ·l· ---=:;:J .- GAs-McF 1995 WATER-BsL 2121 ORIGINAL CONTINUED ON REVERSE SIDE 230 sx Arcticset I 710 sx AS III, 300 sx Class 'G' 70 sx Class 'G' 99 sx Class 'G' Uncemented Slatted Liner DEPTH SET (MD) 7000' PACKER SET (MD) 6999' AMOUNT & KIND OF MATERIAL USED CHOKE SIZE I GAS-OIL RATIO 54 3377 OIL GRAVITY-API (CORR) 23 cr: 28. GEOLOGIC MARKER.; NAME MD Top B47415 5989' Top B37432 6001' Top 827519 6042' Base B3 7602' Base B4 7803' Base C4 7883' 29. .ORMATION TESTS Include and briefly summarize test results. List intervals tested, TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 5006' None 5015' 5046' 6151' 6108' 6091' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble ~~ ,~Title Technical Assistant Date ll-Od..-()L( Kuparuk 1 F-18A 204-167 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Dan Kara, 564-5667 Permit No. / Approval No. 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. IrEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IrEM 4b: TPI (Top of Producing Interval). IrEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IrEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IrEM 20: True vertical thickness. IrEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IrEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IrEM 27: If no cores taken, indicate "None". IrEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/8/2004 17:00 - 18:00 1.00 MOB P PRE Preparing to move off of 1 D-30a 18:00 - 18:40 0.67 MOB P PRE Safety meeting prior to moving off of location. Review premove checklists. Discuss hazards, such as soft pads, culverts, personnel entering moving rig. Confirm that all pre move checklist items have been completed, including rig move notification to Kuparuk security. 18:40 - 19:10 0.50 MOB P PRE Perform 1 last walk around to ensure the rig is ready to move. 19:10 - 20:10 1.00 MOB P PRE Back rig off well. Move to the end of 1 D pad. Call Kuparuk tool service to confirm the spine road to KOC is blocked to traffic. 20:10 - 00:00 3.83 MOB P PRE Enter the spine road, and begin the move to 1 F pad. Weather conditions for move are poor. It is raining at the present time and the roads are saturated with water. All culvert crossings and other possible soft spots along the spine road are covered by a single layer of rig mats. Location of the rig at midnight is just short of the KOC/CPF1 pad. 9/9/2004 00:00 - 01 :20 1.33 MOB P PRE Continue move from 1 D pad. 01 :20 - 08:00 6.67 MOB P PRE Arrive at KOC/CPF1 pad. Park rig off to the side of the spine road. Wait while Kuparuk tool service shuttles 190 rig mats from the spine road behind the rig, and places them from the end of the KOC/CPF1 pad to the 1 F pad access road, and starting down the access road. 08:00 - 00:00 16.00 MOB N MISC PRE On the move again, Matting 1 FPad access road Stair stepping mats along 1 F Pad access road At midnight, >1/2 mile down 1F access road. 9/10/2004 00:00 - 06:00 6.00 MOB N MISC PRE Moving rig along 1 F-Pad access road. At 0600 hrs the rig approximately 2/3 the way down the access road. Using 4 fork lifts to stair step mats then at midnight, down to 2 because of personnel work time. Back to 4 forklifts at 0600 hrs 06:00 - 16:00 10.00 MOB N MISC PRE Moving along. Notified AOGCC, Chuck Sheve wavered witness the BOP test 16:00 - 18:00 2.00 MOB N MISC PRE Moving mats for the last move to the pad. WiI still need to mat the Pad 18:00 - 00:00 6.00 MOB N MISC PRE 18:00 update. Rig currently about 3/4 of the way down the 1 F pad access road. Continuing to single stack mats, and pull forward on them, then double stack and back up, then repeat. Continuing to inch slowly towards 1 F pad. Raining intermittantly. 9/11/2004 00:00 - 03:00 3.00 MOB N MISC PRE Rig is 1/4 mile short of 1 F pad as of midnight. Continue shuttling mats back and forth, and slowly moving toward the pad. Continuing to rain. 03:00 - 06:00 3.00 MOB N MISC PRE Arrive on 1 F pad. Pull onto pad and stop. Wait for mats to be laid down pad and around to well. Still Raining. 06:00 - 08:00 2.00 MOB P PRE Move rig around pad on mats Held Move over well PJSH and move over well. Conducted Pad inspection Rig accepted at 0800 hrs 9-11-2004 63 hr Pad to Pad rig move. 48 hrs on 1 F Pad access road. 08:00 - 10:15 2.25 MOB P PRE Set in yard and started NU BOP's. AOGCC Chuch Sheave wavered witnessing BOP test Kuparuk Safety and DS Operator approved setting office at different location. NU BOP's WHP = 750 psi Working to get 1 F17 ESD actuator Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/11/2004 08:00 - 10:15 2.25 MOB P PRE panel on rig 10:15 - 14:30 4.25 BOPSUP P PRE PT BOP to 250/3500 psi Hauling fluid and installing reel. 14:30 - 14:50 0.33 BOPSUP P PRE PJSM on pulling reel over pipe shead 14:50 - 15:25 0.58 BOPSUP P PRE Pulling CT over pipe shed. RU actural for ESD on 1 F-17 tree. 15:25 - 17:00 1.58 BOPSUP P PRE Cut CT off, pulled wire out, stab on well and pump fluid Pumped= 44 bbl 17:00 - 18:00 1.00 BOPSUP P PRE Unstab injector, cut CT and fish wire, rehead to BHI 18:00 - 18:30 0.50 BOPSUP P PRE Pre spud safety meeting with all rig hands, SWS Team Leader, Nordic Toolpusher, BP, and 1 APC vac truck driver. Discuss present condition of well, hazards and mitigations to the hazards, and the plan forward for tonights tour. 18:30 - 20:30 2.00 KILL P WEXIT Resume attaching Ecoil head to 2" Coil tubing. 20:30 - 20:45 0.25 KILL P WEXIT Safety meeting prior to making up BHA to RIH and kill well. 20:45 - 21 :20 0.58 KILL P WEXIT MU BHA #1: 2.5" JSN - Blind Sub - BHI DPS - EDC - Powercoms - Ball Valve Sub - LaC - uac - CTC. Stab injector on well. 21 :20 - 21 :55 0.58 KILL P WEXIT Circulate mud down coil to finish slack management. Pumping at 2.0 bpm, 3200 psi. 21 :55 - 22:10 0.25 KILL P WEXIT Pressure test hardline to tiger tank to 1500 psi. Passed ok. Pressure test lubricator to 3500 psi. Passed ok. Bleed off well to 1000 psi, open master valve. 22:10 - 23:30 1.33 KILL P WEXIT Open up well. WHP=975 psi. RIH, bleeding off wellbore fluids to tiger tank thru rig choke. Holding 975 psi on WHo 23:30 - 00:00 0.50 KILL P WEXIT Stop at 7400'. SI pumps and rig choke. Monitor BHA. WHP=975 psi, BHP=3010 psi. Bring pumps on with diesel on the backside, circulating BHP=3100 psi. Holding 975 psi on surface choke. Gradually opening choke as mud gets up around coil. Final BHP while circulating=3475 psi. 9/12/2004 00:00 - 00:15 0.25 KILL P WEXIT Continue to circulate well to mud. 00:15 - 01:30 1.25 KILL P WEXIT POOH following pressure schedule with choke. 01 :30 - 01 :45 0.25 KILL P WEXIT Safety meeting prior to laying down BHA #1. 01 :45 - 02:45 1.00 KILL P WEXIT Lay down BHA #1. 02:45 - 03:15 0.50 KILL N WAIT WEXIT Waiting on Schlumberger hand with pip tags. (He has never been to Kuparuk before and may be lost.) 03:15 - 03:30 0.25 KILL P WEXIT Install RA pip tag into whipstock. 5.67' from top of WS to RA tag. 03:30 - 03:45 0.25 WHIP P WEXIT PJSM re: pressure deployment of WS BHA. 03:45 - 05:30 1.75 WHIP P WEXIT MU BHI MWD BHA in mousehole. PU into lubricator. Distance from no go to MU point is 3.5'. MU WF whipstock in hole. MU MWD to WS. Scribe to high side of tray. PU into lubricator. PT to 1000 psi. Bleed off to WHP. RIH, WHP=700 psi. Tag no go, PU 3.5' and set combis. Bleed off lubricator. MU injector. 05:30 - 06:00 0.50 WHIP P WEXIT PT lub to 500 psi, open combis, O-ring leak on lubicator, PUH and slack off 0.5 ft, shut combies and engerize. 06:00 - 06:15 0.25 WHIP P WEXIT Held PJSM on undeploying BHA to change o-ring. 06:15 - 07:30 1.25 WHIP P WEXIT Set combi, pull tested BHA, Bleed lub pressure, slip chains, and PU lub, close DBV, bleed pressure off CT, Unstab BHA, Change out O-ring. Stab on BHA PT lub 1000 psi. Unlock rams, de- engerize rams, Open Combis. WHP = 377 psi. Need to change packoff following WS setting run. 07:30 - 09:45 2.25 WHIP P WEXIT RIH w/ WS as per schedule 09:45 - 10:35 0.83 WHIP P WEXIT Tie-in from 7200 ft down (Corrected -1 ft) Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/12/2004 10:35 - 11 :20 0.75 WHIP P WEXIT RIH to set WS Tagged CIBP at 7452 ft PUH to 7389' RIH to 7404 ft TOW at 7395 ft, Working at closing EDC. Closed Tray oriented TF to 33R from HS Set at 3350 psi Set 2500 Ib down solid. PUH clean 11 :20 - 12:55 1.58 WHIP P WEXIT POOH following pressure schedule Held Pressure un-dep PJSM Fill across top to keep required WHP when OOH 12:55 - 17:00 4.08 WHIP P WEXIT Tagged up, RIH 0.5 ft Set 2-3/8" Combi's, Depressured above combi's, OK, RU Lub and PT to 600 psi, Equalized pressure, PUH with WS running tools. Closed MV/SV. Change out BHA in mouse hole. Stab in lub and stab on well. PT lub to 600 psi. RIH slow, Falling real slow. Worked down to No/Go Closed combi's. Depressured lub, Un stung, DBV to high for Injector head. Stab back on well. PT to 550 psi, released combi's PUH and greased line. RIH and hit No/Go PU 3.8 ft Set combi's and released pressure. Unstabbed lub and stand back in derrick. Ru lub and injector head 17:00 - 18:20 1.33 WHIP P WEXIT RIH using presssure schedule 18:20 - 19:00 0.67 STWHIP P WEXIT No GR tool in this BHA. No tie in pass made. Tag top of WS at 7398'. Make _3' correction. Up weight = 20 klbs. Kick on pumps. Free spin 3140 psi at 1.55 bpm. BHP=3375 psi. Tag top of whipstock. Confirm depth is still 7395'. Begin window milling. IAP=911 psi, OAP=500 psi. Bleed both down. 19:00 - 20:00 1.00 STWHIP P WEXIT 7395.4', 1.57/1.59/3280 psi. Pit vol=438 bbls. IAP=73 psi, OAP=495 psi. Still bleeding OAP. Getting good motor works and drill offs every 0.1'. 20:00 - 21 :00 1.00 STWHIP P WEXIT 7396.3', 1.57/1.6/3400 psi. Pit vol=436 bbls. IAP=430 psi, OAP=304 psi. 21 :00 - 22:00 1.00 STWHIP P WEXIT 7397.1', 1.57/1.60/3320 psi. Pit vol=436 bbls. IAP=468 psi, OAP=376 psi. Starting to get metal back accross the magnets. 22:00 - 23:00 1.00 STWHIP P WEXIT 7398.2', 1.57/1.59/3230 psi. Pit vol=435 bbls. IAP=497 psi, OAP=426 psi. 23:00 - 23:05 0.08 STWHIP P WEXIT 7399.0', 1.57/1.6/3290 psi. Pit vol=435 bbls. IAP=527 psi, OAP=466 psi. 4.0' milled since start of window. Motor work and WOB suggest that we are in open hole. Attempt to drill ahead. Making hole. Window depth prior to logging correction on next pass is 7395'-7399'. 23:05 - 23:45 0.67 STWHIP P WEXIT Drill 10' of rathole. Getting drill offs. ROP=10-20 fph. Definately in sand. 23:45 - 00:00 0.25 STWHIP P WEXIT 10' of rathole finished. Begin reaming window. 9/13/2004 00:00 - 00: 15 0.25 STWHIP P WEXIT Continue to ream window. 00:15 - 01:30 1.25 STWHIP P WEXIT SI pumps. Dry drift window up and down smooth. POOH for build section BHA. Following pressure schedule while POOH. 01 :30 - 02:00 0.50 STWHIP P WEXIT Tag up at surface. Shut in choke trapping 750 psi on well. Hold PJSM re: pressure undeploy of milling BHA. Discuss proceedure. Review each step on checklist. Discuss hazards and mitigations to hazards. 02:00 - 03:40 1.67 STWHIP P WEXIT Undeploy BHA #3 using the pressure undeploy checklist. Both mills recovered at 2.74" go, 2.73" No-go. Window should be in good shape. Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/13/2004 03:40 - 04:05 0.42 DRILL P PROD1 Safety meeting re: Picking up and pressure deploying build section BHA. 04:05 - 05:20 1.25 DRILL P PROD1 Deploy BHA #4, Build section BHA. MWD tool failed after deploying. 05:20 - 08:25 3.08 DRILL N DFAL PROD1 Undeploy failed MWD tool. change out BHI MWD, pressure deploy 08:25 - 10:00 1.58 DRILL P PROD1 RIH as per pressure schedule 10:00 - 10:15 0.25 DRILL P PROD1 Tie-in at GR development at 7263 ft (Corrected -2.5 ft) Closed choke and EDC. 10:15 - 10:40 0.42 DRILL P PROD1 RIH tagged at 7402 ft PUH and orient TF to 30 R Wash dow to 7409 ft 10:40 - 13:25 2.75 DRILL P PROD1 Drilling TF 33R Qp = 1.55/ 1.51 bpm BHP = 3447 psi = 11.00 ppg EDC Density = 8.85 / 8.89 ppg Vp = 426 bbl at 10:48 hrs Taking 50 ft geo samples 13:25 - 14:05 0.67 DRILL P PROD1 Drilling TF 28R Qp = 1.55/1.55 bpm BHP = 3436 psi = 11.03 ppg EDC Density = 8.85/ 8.89 ppg Vp = 434 bbl at 14:00 hrs Centrifuge airing up the mud 14:05 - 14:25 0.33 DRILL P PROD1 Wiper trip to window Clean 14:25 - 17:45 3.33 DRILL P PROD1 Drilling TF 25R Qp = 1.52/1.53 bpm BHP = 3471 psi = 11.07 ppg EDC Density = 8.85 / 8.89 ppg Vp = 445 bbl at 15:25 hrs 17:45 - 18:00 0.25 DRILL P PROD1 Drill Ahead. 18:00 - 19:45 1.75 DRILL P PROD1 7593', Drilling ahead build section. 1.53/1.59/3540 psi. WHP=50 psi. BHP=3456 psi. IAP=405 psi, OAP=650 psi. Pit vol=444 bbls. ROP=erratic, 2-30 fph. INC=96 deg at bit. TF=60R. 19:45 - 20:00 0.25 DRILL P PROD1 Build and turn section landed as per DD. PUH to make tie in pass prior to POOH for lateral section BHA. Motor work and overpull at 7528' when making wiper trip to window. Keep and eye on this on future runs. 20:00 - 21 :30 1.50 DRILL P PROD1 Log tie in pass over original well gamma marker and RA tag in whipstock. Made -1.8' correction to RA tag. New correlated depths are: Top of window = 7393.2' Bot of window = 7397.2' RA tag = 7399.0' 21 :30 - 22:50 1.33 DRILL P PROD1 POOH with drilling BHA. Choke hand on location to troubleshoot erratic choke. 22:50 - 23:15 0.42 DRILL P PROD1 Tag up at surface. Hold PJSM for BHA undeploy. 23:15 - 00:00 0.75 DRILL P PROD1 Pressure undeploy BHA #5. 9/14/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Continue to lay down build section BHA. 01 :00 - 01 :30 0.50 DRILL P PROD1 Safety meeting prior to picking up lateral section BHA. 01 :30 - 03:30 2.00 DRILL P PROD1 Deploy BHA #6 to drill lateral section using pressure deployment techniques. Pick up new Hycalog bicenter bit as per proceedure. Change out upper and lower check valves as per BHI recommendation. 03:30 - 04:55 1.42 DRILL P PROD1 RIH with BHA #6. 1.0 deg motor, Hycalog DS100 bit. Printed: 10/1/2004 9:09: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/14/2004 04:55 - 05:10 0.25 DRILL P PROD1 Log tie in pass over RA tag. Make -5' correction. 05:10 - 05:45 0.58 DRILL N DPRB PROD1 RIH. Tagged at 7530', worked through, tagged at 7556 ft, worked through. RIH to 7612 ft. PUH pulled tight 34k, PUH above WS, clean above 7535 ft. Above WS open EDC and start mixing KlaGard to inc conc to 12 ppg. Lower B2 shale, fromation top at 7474 ft MD /6025 ft TVD its soft, sticky and troublesome. Qp =2.0 bpm; WHP = 100 psi; BHP = 3452 psi; EDC = 11.27ppg 105:45 - 07:15 1.50 DRILL N DPRB PROD1 At 7300 ft open EDC circulating and mixing KlaGard Bring conc from 6ppb to 12ppb. 07:15 - 07:35 0.33 DRILL N DPRB PROD1 Closed EDC and started cir with 200 psi WHP Qp = 1.53 bpm RIH to 7525 ft slowly BHP = 3666 psi EDC = 11.5ppg 07:35 - 09:05 1.50 DRILL N DPRB PROD1 W IR from 7518ft correct TF Some motor work at 7518 It 1 6042ft TVD Some Motor work at 7530 ft 1 6044 ft TVD Set down 7535 ft, PUH to 7500 ft, little pull at 7525 ft. RIH from 7500 ft, motor work at 7513 ft /6040ft TVD Start of trouble section RIH to 7550ft PUH 24.5k Clean; RIH clean to 7555ft, some motor work at 7556 ft W/R through to 7580ft, took wt and motor work, PUH clean RIH, clean to 7580ft. W/R from 7580ft 6046ft TVD Motor work at 7583 ft down to 7585ft. PUH. Had some motor work from 7585 ft to 7570 ft. pulled tight to 7535ftMD 1 6045 ft TVD. Clean above 7535 ft RIH correct TF to 7605ft PUH to check integrity of upper section All work conducted using EDC = 11.6 ppg 09:05 - 10:00 0.92 DRILL N DPRB PROD1 PUH 28 to 30k to 7588ft Pulled tight and motor work at 7536ft MD 1 6045ft TVD Some motor work 7500ft MD / 6039ft MD RIH , tagged at 7543ftMD TF at 48R PU orient TF to 30R. RIH to 7610ft/6042ft TVD. PUH to 7445ft pulled 33k at 761 Oft to 7580ft . Motor work at 7538ft 1 6045ft TVD. Motor wok at 7480ft MD 1 6028ft TVD RIH and clean to 7610 ft, PUH little pull. PUH to 7520 ft. RIH to corrected TD of 7615 ft MD 10:00 - 10:05 0.08 DRILL P PROD1 W/R to 7615/ 6041ft TVD could be bottom. TF at 60R Drilling TF @ 90R Qp = 1.55/1.55bpm BHP = 3622 psi EDC = 11.56ppg Vp = 435 bbl at 1000 hrs 10:05 - 10:10 0.08 DRILL P PROD1 EDC inc to 12.4ppg, PUH clean to 7593ft, RIH clean 10:10 - 10:35 0.42 DRILL P PROD1 Drilling TF @ 93R Qp = 1.55/1.55bpm BHP = 3642 psi EDC = 11.6 ppg IAlOA = 463/714 psi. WHP = 200 psi ROP 15-33 fph 10:35 - 10:55 0.33 DRILL P PROD1 PUH 15fpm to check hole integrity. Little bobble at 7543ft TF at 90R Little motor at 7499 ftTF still at 90R. Turned around at 7474ft. RIH, down Wt = 5.2k Clean to 7630ft 10:55 - 12:00 1.08 DRILL P PROD1 Drilling TF @ 88R Qp = 1.57/1.55bpm BHP = 36 psi EDC = 11.7 ppg IAlOA = 433/205 psi. WHP = 242 psi ROP 15-33 fph 12:00 - 12:30 0.50 DRILL P PROD1 Drilling ahead. 1.57/1.6/3530 psi. Free spin=3250 psi at 1.57 Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/14/2004 12:00 - 12:30 0.50 DRILL P PROD1 bpm. 200 psi on wellhead. BHP=3690 psi. EMW=11.7 psi. IAP=490 psi, OAP=250 psi. Pit vol=433 bbls. ROP=90 fph. 12:30 - 13:05 0.58 DRILL P PROD1 Make wiper trip to shoe. Clean PU at 23 klbs. Clean thru previous problem area at 7528' both up and down. 13:05 . 15:20 2.25 DRILL P PROD1 Tag bottom, and resume drilling. 1.57/1.6/3700 psi. 200 psi on choke. Pit vol=431 bbls. 15:20 . 16:00 0.67 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 22 klbs. 200 Ibs motor work thru 7528'. Clean when running back thru. 16:00 - 18:10 2.17 DRILL P PROD1 Resume drilling. 1.54/1.62/3700 psi, 200 psi on the wellhead. IAP=600 psi, OAP=340 psi. Pit vol=427 bbls. 18:10-18:45 0.58 DRILL P PROD1 Maker wiper trip to shoe. Clean PU off btm (22k#). 18:45 - 21:10 2.42 DRILL P PROD1 Resume drilling. 1.54/1.42/3250 psi fs, WHP: 200 psi. WOB: 2-3K# BHP: 3680 psi, ECD: 11.9. PVT: 414 bbls. Mostly fast drilling with some hard spots. 21:10 - 21:45 0.58 DRILL P PROD1 Wiper trip to shoe @ 20 fpm. Clean PU off btm, (22K#). No sign of shales at 7528' or 7588'. Some motor work at 7490' 21 :45 - 22:00 0.25 DRILL P PROD1 Log gr tie In outside window. +8' correction. 22:00 - 22:30 0.50 DRILL P PROD1 Complete wiper trip. Hole smooth. 22:30 - 00:00 1.50 DRILL P PROD1 Resume drilling. 1.54/1.42/3250 psi fs, WHP: 200 psi. WOB: 2-3K# BHP: 3740 psi, ECD: 12.1. PVT: 404 bbls. Mostlyfast drilling with some hard spots. 9/15/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Wiper trip to window. Hole smooth. 22k# off btm. 01 :00 - 02:45 1.75 DRILL P PROD1 Resume drilling. 1.54/1.42/3250 psi fs, WHP: 200 psi. WOB: 2-3K# BHP: 3740 psi, ECD: 12.1. PVT: 404 bbls. Mostly fast drilling with some hard spots. 02:45 - 04:30 1.75 DRILL P PROD1 Wiper trip to window. 21 K# PU off btm. Hole smooth. 04:30 - 06:00 1.50 DRILL P PROD1 Drill ahead. 1.56/1.54/3300 psi fs. WHP: 200 psi. ECD: 11.92. PVT: 393 bbls. 06:00 - 09:00 3.00 DRILL P PROD1 Drilling ahead. 1.55/1.53/3430 psi. WHP=200 psi. IAP=420 psi, OAP=450 psi. Pit vol=389 bbls. Drilling ahead with mostly good ROP. with an occasionaly siderite stringer. Appear to be having slight seapage losses to formation. 2-4 bbl/hr. 09:00 - 11:15 2.25 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 23 klbs. 300 Ibs motor work and a 5 klbs overpUII at 7530' when coming up hole. This is the same problem depth observed yesterday. Tagged up and had motor work at 7545' on way down. TF is same as drilled, 15R. PU, made it thru on 2nd attempt. 11:15 - 12:00 0.75 DRILL P PROD1 Resume drilling. 1.59/1.55/3700 psi. 200 psi on WHo Taking mud out of pits to clean pits prior to swapping to new mud. 12:00 - 13:00 1.00 DRILL P PROD1 New mud going downhole. 9.4 ppg. 14 ppb Kla-gard. 13:00 - 13:50 0.83 DRILL P PROD1 New mud around. 1.59/1.55/3900 psi. 0 psi on choke. BHP=3790 psi. IAP=340 psi, OAP=420 psi. Free spin=3800 psi at 1.56 bpm. 13:50 - 17:05 3.25 DRILL P PROD1 Wiper trip to shoe. 5 klbs overpull off bottom. Ratty for first 50'. The new mud appears to be really cleaning the hole. We have about 3 times the amount of cuttings on this wiper trip as opposed to previous trips. Had motor work at 7540', but very little overpull on the way up. Open EDC, and chase cuttings up into 3-1/2" to 6500'. R/H. Set down at 7550'. PU, and got thru ok. Clean to bottom. 17:05 - 18:30 1.42 DRILL P PROD1 Resume drilling. 1.56/1.54/3800 psi. 0 surface choke Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: Rig Release: Rig Number: 9/8/2004 5/31/1996 Spud Date: 5/1/1996 End: 9/29/2004 9/15/2004 17:05 - 18:30 1.42 DRILL P PROD1 pressure. IAP=235 psi, OAP=311 psi. Pit vol=319 bbls. BHP=3710 psi. Drilling break. Lose all returns. 18:30 - 19:30 1.00 DRILL P PROD1 Wiper trip up into casing. Discuss options with town team. Order additonal 8.8 ppg mud from MI. Transfer extra 9.4 mud from tanks on location to pits. 19:30 - 20:00 0.50 DRILL P PROD1 Into csg with no hole problems or overpulls. Cycle EDC. Problems with commands to downhole tools. Re-boot Inteq systems. EDC opened. Attempt to verify proper function. ECD not working. 20:00 - 20:45 0.75 DRILL N DFAL PROD1 POOH to change out MWD tools. Slowly regaining circulation while POOH. Able to hold 200 psi WHP with 90% rtns. 20:45 - 21 :00 0.25 DRILL N DFAL PROD1 At surface. Tag up and position BHA. Shut in well with 300 psi WHP. Hold PJSM to review pressure un-deploy procedure in ops cab. Review entire un-deploy proc line by line. Discuss possibility EDC is not closed. Will get flow back if EDC is open, and double checks are not holding. 21 :00 - 22:30 1.50 DRILL N DFAL PROD1 Undeploy BHA. CHange out float valves and bit (LD Hycalog, PU re-built HTC) 22:30 - 00:00 1.50 DRILL N DFAL PROD1 Review procedure with floor crew. Pressure deploy BHA. Get on tools. Test. OK. Get on well. RIH. 9/16/2004 00:00 - 01:15 1.25 DRILL N DFAL PROD1 RIH with lateral assembly (1.0 deg mtr wi HTC bicenter, BHA #7) 01:15 - 01:30 0.25 DRILL N DFAL PROD1 Log gr from 7400'. Tie into RA tag @ 7399. -6 correction'. 01 :30 - 03:00 1.50 DRILL P PROD1 RIH. Tag up at 7610'. PU. Run through ok. Tag up at 8575'. Ream through, not too difficult. Drilled TF maintained. 1.55 bpm in/1.15 bpm out while circulating in hole. 3500 psi fs. 03:00 - 04:35 1.58 DRILL P PROD1 Drill ahead. 3400 psi fs. 200-400 dpsi. 1.53 in/1.1 0 out, with 9.4 ppg mud. ECD:11.6, BHP:3612 psi. WHP: 0 psi. PVT:225 bbls. 04:35 - 06:00 1.42 DRILL P PROD1 Wiper trip to window. Clean off bottom, and up thru 7528'. Tagged up and fell thru 7540' when RIH. Clean back to bottom. 06:00 - 07:15 1.25 DRILL P PROD1 Continue wiper trip in hole. Had to work it to get from 8650' to TD. Lots of set downs and drag. 07:15 - 08:30 1.25 DRILL P PROD1 Resume drilling. Free spin=3530 psi at 1.55 bpm. Drilling at 1.54/1.2/3620 psi. 0 psi on choke. IAP=70 psi, OAP=103 psi. Pit vol=335 bbls. Mud weight=9.4 ppg. BHP=3670 psi. Getting a significant amount of cuttings over the shaker, and lots of clay out of the centrifuge. 120-15 fph. Drilling good sand with an occasional hard stringer. 08:30 - 08:45 0.25 DRILL P PROD1 312 bbls in the pits. Drilling slowly at 16 fph. Lost 23 bbls in last 1 :15. Or about 17 bbls/hr. 08:45 - 09:15 0.50 DRILL P PROD1 Weight transfer getting difficult. Make 500' wiper, then go back to drilling. Clean PU off bottom at 25 klbs. RIH at 2800 Ibs. Clean back to bottom. Still getting huge cow patties from the centrifuge discharge. It is 90% clay with some fine sand. The most likely source of this clay is the invert section of the well at the heel. The hole is probably washing out or sloughing. 09:15 - 10:25 1.17 DRILL P PROD1 Resume drilling. 297 bbls of 9.4 pg mud in pits. Pump 15 bbl 1 OOklsrv sweep. Drilling at 17 fph. 10:25 - 11 :35 1.17 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. BHP=3677 ECD=11.85 ppg. IAP=78 psi, OAP=160 psi. Pit vol=269 bbls. 7524', had an overpull to 36 klbs, and packing off. Now stuck. Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/16/2004 10:25 - 11 :35 1.17 DRILL P PROD1 Losing returns. Could be cuttings laying in the belly of the well packing off around us. 11 :35 - 11 :50 0.25 DRILL N STUC PROD1 Partially returns. 1.74/0.3/4200 psi. Trying to work back down hole. Returns trending down. Try working pipe down. Got max stacked on it of ·8500 Ibs at surface. WOB=7500 Ibs. downhole. Annular pressure=3320 psi. We are packed off around the BHA below the WOB and Annular pressure sensor. Continue stacking weight and rotating orienter. Not making any footage in hole. Returns now 1.74/0.17/4260 psi. We are just about toast. SI pumps. Open EDC. Pump at max rate. Popped free!!! 11 :50 - 12:45 0.92 DRILL P PROD1 EDC open. Continue wiper trip up into tubing Pumping 2.3/1.77/4450 psi. Annular pressure=3670 psi. Pull this pass up to 6500' to space out cuttings and clean up well. We will need to work the area in the belly of the well. Probably have cuttings and sloughing siltstone laying in washed out/low A V interval here. Still getting huge cow patties down the centrifuge discharge chute. 12:45 - 17:20 4.58 DRILL P PROD1 Run thru window. Shut EDC. RIH at 20 fpm. Tagged up at 7413', and lost returns. Heavy pickup. Chase it to the window. RBIH until we see weight loss and returns dropping off at 7520', and chase it back to the window. Repeat at 7530', 7560',7600',7650',7700'; 7750', 7850', 8000'. Pump High vis sweep on last bite, and chase it up hole. Chase everything up to 6500'. 17:20 - 18:00 0.67 DRILL P PROD1 RIH to log tie in pass across RA tag at 7399'. Add 3' correction. 18:00 - 19:30 1.50 DRILL P PROD1 Wiper trip to verify TD. No set downs or tight spots. Tag TD: corrected depth is 9065'. Pump 15 bbl hi vis sweep. 19:30-21:30 2.00 DRILL P PROD1 Circulate and condition while pulling out Of hole. Clean out tbg to 6500'. Continue to wait on KWF to arrive from MI. 21 :30 - 00:00 2.50 DRILL P PROD1 RIH. Set down at 7398' 3-4 times (btm of window). Finaly bounce through at 10R TF (window drilled at 30R). Continue to RIH to TD. Hole smooth all the way to TD. No set downs, bobbles, motor work at all. 9/17/2004 00:00 . 01 :30 1.50 DRILL P PROD1 POOH from TD, laying in new 9.4 ppg mud. Hole 100% smooth on trip out to window. Swap to 11.7 ppg KWF to coincide with arriving at window depth of 7400'. 01 :30 - 01 :45 0.25 DRILL P PROD1 Displace coil annulus to 11.7 ppg KWF from 7400'. Monitor BHP annular pressure. Initial: 3677 psi @ 1.53 in/1.20 out. Begin losing too much KWF to formation. 01:45 - 03:15 1.50 DRILL P PROD1 POOH at 1:1 (115 fpm @ 1 bpm). Paint EOP flag @ 6000'. Continue to POOH. 03: 15 - 03:45 0.50 DRILL P PROD1 Stop coil at 500'. KWF back to surface. Monitor well for flow. Well on a vac. Fill hole. Took 3.5 bbls to fill after 30 min flow check. Continue to load pits with KWF. 03:45 - 04:30 0.75 DRILL P PROD1 POOH. Tag up. Hold short PJSM. Get off well. Unstab coil. LD tools. 04:30 - 04:45 0.25 RUNCOrvP RUNCMP Hold PJSM to discuss running liner. Verify safety joint readiness. Discuss roles & assignments. 04:45 - 06:00 1.25 RUNCOrvP RUNCMP MU 2-3/8· liner assembly with bent guide shoe. Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/17/2004 06:00 - 06:15 06:15 - 06:35 06:35 - 07:50 07:50 - 09:30 09:30 - 10:50 10:50-12:10 12:10 - 12:40 12:40 - 12:50 12:50 - 13:05 13:05 - 14:30 14:30 - 15:15 15:15 - 15:50 15:50 - 16:15 16:15 - 17:45 17:45 - 19:45 19:45 - 19:00 19:00 - 19:45 0.25 RUNCOrvP 0.33 RUNCOrvP RUNCMP SD running liner for crew change. RUNCMP PJSM for running liner. Discuss hazards and mitigations to hazards while running liner. RUNCMP Resume making up liner. Now on joint 17 of 31. Filled hole. Took 2 bbls. Last filled 35 minutes ago. IAP-67, OAP=O, Pit vol=314. 96 bbls of 11.7 brine in pit 3, 48 bbls left on vac truck. RUNCMP Land 2-3/8" deployment sleeve in slips. Position false table and slip bowl. Begin running 1" CS hydril. Drifting CSH with ball as we pick up the joints. Well continues to take 4 bbls/hr of fluid static. RUNCMP MU pup joints to space out CSH. MU GS spear. MU BHI MWD tools. MWD tools check out ok. MU injector. Stab on well. Establish circulation at minimum rate. RUNCMP RIH with 2-3/8" predrilled liner. BHA length is 1057.04. Slotted interval length is 983.6'. Getting a trickle of returns as we RIH. Should be displacing 3.5 bbls/1000' of pipe RIH. Probably bullheading it all away. 1.25 RUNCOrvP 1.67 RUNCOrvP 1.33 RUNCOrvP 1.33 RUNCOMP 0.50 RUNCOrvP Stop at 6000' EOP flag. Make -6' correction. Make weight check at the window. Up weight=26 klbs. RUNCMP RIH from 7300'. Pumping 0.8 bpm, 2750 psi. 0 returns. Smooth thru window, and thru bad spot at 7528'. Lost a bunch of weight as we started shoving the CTC up hole past the heel of the well. Set down at 8890', PU at 27 klbs. Work it and loosing hole each time we pick up. PU 4 times, and now at 8862'. Bring on pumps. Pumping 1.4 bpm, 4300 psi. PU at 21 klbs. Liner is in the hole. 0.17 RUNCOrvP 0.25 RUNCOrvP Bottom of liner #1 at 8862', top of liner at 7855.5'. (Uncorrected) RUNCMP Drop pumps to 0.5 bpm, 1780 psi. PUH. RUNCMP Log tie in pass accross RA flag. Make + 1.5' correction. 1.42 RUNCOrvP Corrected liner #1 depth is 8863.5-7857.0' RUNCMP POOH, circulating accross the top. Hold PJSM while POOH for standing back CSH. RUNCMP Tag up at surface. Stand back injector. Lay down MWD tool and Baker deployment eq. RUNCMP POH with 15 stands and 1 single of 1" CSH. Standing CSH back in the derrick. RUNCMP Safety meeting Re: Running 2nd string of liner. RUNCMP Make up second liner string for the "A" Ia.teral: Bullet guide shoe with a 1" thru hole, 10' bent pup, o-ring sub, 13 joints of solid liner, WF Aluminum deployment sleeve/OH whipstock, WF G spear, BHI MWD tool. Check MWD tool. Checks ok. Stab on Injector. RUNCMP RIH with liner. Circulate across the top with charge pump. Tie into flag at 7071'. Correct -7 correction. Dn wt: 4.1 k#. Up wt: 20.1k#. RUNCMP Tag liner at 7853'. RIH wt: 4000#. Set -4000# down. Line up to circ down coil. Circ 1.3 bpm @ 3800 psi. PU. RUNCMP Log gr tie in across RA tag. Add 3' correction. Est TOL 7856". 0.75 RUNCOrvP 0.58 RUNCOMP 0.42 RUNCOrvP 1.50 RUNCOrvP 2.00 RUNCOMP 23.25 RUNCOMP 0.75 RUNCOMP Printed: 10/1/2004 9:09: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/17/2004 19:45 - 21 :00 1.25 RUNCOIIiP RUNCMP POOH. Check up WI at 6649'. +1-2k# lighter. Appear to have released from liner. 21:00 - 21:15 0.25 RUNCOIIiP RUNCMP Stop coil at 500'. Flow check well. Lost 1 bbl. Continue to surface. 21:15 - 22:00 0.75 RUNCOIIiP RUNCMP At surface. Get off well. Unstab coil. LD BHA assembly. 22:00 . 23:30 1.50 DRILL P PROD2 Prep to pump slack management. Cut 115' of coil and 85' of e-line. 23:30 . 00:00 0.50 DRILL P PROD2 Install Kendall connector. MU e-line connection. 9/18/2004 00:00 - 01 :15 1.25 STWHIP P PROD2 Continue to MU e-coil head. Pressure, electrical, & pull test same. 01: 15 - 01 :45 0.50 STWHIP P PROD2 Displace KWF from coil at surface. Transfer KWF from pits into upright tank for storage. 01 :45 - 02:30 0.75 STWHIP P PROD2 MU kick off drilling assembly (BHA #9, 2.2 deg mtr wi 2.75" STR-324 bit). Surface test MWD. Stab coil. Get on well. 02:30 - 04:15 1.75 STWHIP P PROD2 RIH. Open EDC. Circulate at 0.6 bpm in/ 0.81 out. Stop at 3500 psi. Get 95% rtns. Continue to RIH. 04:15 - 04:30 0.25 STWHIP P PROD2 Log GR tie in across RA tag at 7399'. Subtract 12' correction. 04:30 - 05:00 0.50 STWHIP P PROD2 Tag liner top billet at 7432'. PU. Close ECD. RIH. 05:00 - 06:00 1.00 STWHIP P PROD2 Begin time milling. 06:00 - 07:30 1.50 STWHIP P PROD2 7429.5', Time milling ramp on WF deployments sleeve/WS at 1 fph. 1.52/1.25/3680 psi. IAP=76 psi, OAP=76 psi. Pit vol=232 bbls. New mud in route from MI. TF=90R. 07:30 - 08:30 1.00 STWHIP P PROD2 7431.0', Begin time milling at 6 fph. 1.55/1.36/3740 psi. 3675 psi BHP, 0 psi on choke. Pit vol=421 bbls. IAP=79 psi, OAP=115 psi. 08:30 - 09:00 0.50 STWHIP P PROD2 7437.0', Begin drilling ahead. ROP=50 fph. Good ROP. Confirmed off the deployment sleeve. It went smooth. Downhole WOB=4500 Ibs. 09:00 - 10:30 1.50 STWHIP P PROD2 POOH attempting to follow the choke pressure schedule, and pumping at full rate with the EDC open. Due to fluid losses to the original lateral, it became more and more difficult to follow the pressure schedule, and still get good returns to surface. Had to compromise by using less choke back pressure. 10:30 - 10:50 0.33 STWHIP P PROD2 Safety meeting prior to undeploying BHA. 10:50 - 12:15 1.42 STWHIP P PROD2 Undeploy BHA #10 12:15 - 12:35 0.33 DRILL P PROD2 Safety meeting prior to deploying BHA #11. 12:35 - 14:15 1.67 DRILL P PROD2 Pressure deploy BHA #11 to drill build section of Lateral L 1. 14:15 - 15:45 1.50 DRILL P PROD2 RIH with BHA #11, following pressure schedule as close as possible. 15:45 - 16:00 0.25 DRILL P PROD2 Log tie in pass at RA tag. Made correction of -10.5'. 16:00 - 16:20 0.33 DRILL P PROD2 Shut EDC. Run to TD. No problems at the window. RIH with pumps down, and set down at the whipstock 2 times. Had correct tool face of 90R. PU, pumps to 0.5 bpm, set down. PU, 0.5 bpm and 5 fpm, and made it thru. 16:20 - 21 :30 5.17 DRILL P PROD2 Kick pumps on, free spin=3700 psi at 1.55 bpm. Pit vol=367 bbls. IAP=71 psi, OAP=61 psi. BHA=3660 psi. Drilling at 1.56/1.24/3880 psi. Losing 18 bbls/hr. TF=85R, ROP=50 fph. Slow drilling from 7520'. Increase rate to 1.75 in/1.50 out. ROP increased slightly, but still erratic and slow. Still no good surveys due to A leg magnetic interference. 21 :30 - 00:00 2.50 DRILL P PROD2 Drilling build. 3750 psi fs. 300-400 dpsi. 1.55 in/1.29 out Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/18/2004 21 :30 - 00:00 2.50 DRILL P PROD2 WOB:3-5k#. ROP:10-30 fph. Tf:60R. PVT:251 bbls. ECD:11.9 ppg, BHP:3707 psi. 9/19/2004 00:00 - 00:20 0.33 DRILL P PROD2 Wiper trip to 7435'. Hole smooth. 00:20 - 04:00 3.67 DRILL P PROD2 Drilling build. 3750 psi fs. 300-400 dpsi. 1.55 in/1.33 out WOB:3-5k#. ROP:10-30 fph. Tf:60R. PVT:247 bbls. ECD:11.9 ppg, BHP:3707 psi. Plan to hold 80 deg inc through A5 interval. Correlation with 1 Y -24 B & A intervals & TVD tops very close. TF: 30L from 7670' 04:00 - 06:00 2.00 DRILL P PROD2 Continue to drill build. Transfer 250 bbls 9.4 mud from uprights to pits. 06:00 - 07:20 1.33 DRILL P PROD2 Well is landed. PU off bottom was clean at 22 klbs. Clean in I build section and thru OH whipstock/deployment sleeve. Clean thru window. POH following choke schedule as much as possible, but had to reduce choke pressure lower than schedule to maintain returns to clean well. Pump at full rate thru an open EDC while POH. 07:20 - 07:40 0.33 DRILL P PROD2 Tag up at surface. Hold PJSM prior to undeploying BHA. 07:40 - 09:00 1.33 DRILL P PROD2 Pressure undeploy BHA #11 following proceedure checklist. Bit in good shape, and graded 1,1. 09:00 - 10:05 1.08 DRILL P PROD2 Adjust motor bend to 1.0 deg. Change out lower checks, and lower quck connect. ReRun same bit. Pressure deploy BHA following procedure checklist. 10:05 - 10:50 0.75 DRILL P PROD2 RIH Started getting gas cut returns at 1500'. Swap from drilling choke to rig choke and run thru the gas buster. Sure be nice to be able to use the Swaco choke and gas buster at the same time. Not possible with current rig choke configuration. 10:50 - 11:45 0.92 DRILL P PROD2 Flowing thru gas buster, taking returns to pit 1. Getting crude cut returns to pit 1. Continue RIH. 11 :45 - 12:05 0.33 DRILL P PROD2 Log tie in pass over RA collar. EDC open. Make -6.5' correction. Shut down pumps, Shut EDC, holding WHP with choke. 12:05 - 13:10 1.08 DRILL P PROD2 RIH to resume drilling. Pumps down, TF 15 R, set down at 7430', top of whipstock. Kick pumps on 0.2 bpm, set down. 0.5 bpm and got thru ok. Continue to bottom. Tagged up at 7560'. PU, TF is correct at 30R. RIH again and made it thru. Set down at 7583'. PU, and made it to 7591',7599'. Getting motor work at each set down. We've played this game before on this well. Continue working it to bottom. Had to ream all the way to 7700'. These Band A6 shales are not very friendly. 13:10 - 13:30 0.33 DRILL P PROD2 Swap back to Swaco choke. Kick on pumps. Free spin=3750 psi at 1.44 bpm. Pit vol=373 bbls. IAP=80 psi, OAP=32 psi. Surface choke pressure=O psi. BHP=3880 psi. ROP=90 fph. Drilling at 1.45/1.3/3770. 13:30-15:10 1.67 DRILL P PROD2 Got another kick. Gas alarms and crude in the mud. Swaped back to the gas buster. Don't have a return MM again. This well is really trying to flow. Hard to believe that the original lateral is flowing when our BHP is 3830 psi. 15:10 - 15:50 0.67 DRILL P PROD2 Wiper trip to shoe. Clean PU at 24klbs. PUH at 20 fph to avoid surging shales in build section. Drop rate when pulling thru OH whipstock. No problems up thru whipstock to shoe. RIH to resume drilling. Weight bobbles at 7613'. 15:50 - 16:05 0.25 DRILL P PROD2 Resume drilling. Pit vol=367 bbls. Free spin=3650 @1.5 bpm. Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/19/2004 15:50 - 16:05 0.25 DRILL P PROD2 Drilling at 1.5/?/3760 psi. IAP=287 psi, OAP=145 psi. Tried swapping back to the pits, still have gas in returns. Continue drilling on Triflo choke. WHP using triflow choke is 90 psi. 16:05 - 17:00 0.92 DRILL P PROD2 Pit vol now 372 bbls. No MM meter to monitor out flow rate. Probably bringing in formation fluid from "A" lateral. BHP=3720 psi. Formation pressure=3010 psi. It is possible we are venturi'ing in formation fluid from the "A" lateral. Adjust choke back pressure to hold an additional 200 psi BHP to help contain bottom hole flow if that is the case. Circulate bottoms up 2 x, and don't see any evidence of a 5 bbl gain in fluid. Continue to have constant traces of crude in mud. 17:00 - 18:00 1.00 DRILL P PROD2 Wiper trip to shoe. Clean PU off bottom at 25 klbs. Clean in open hole up to window. Open EDC. Circulate and chase cuttings up to 6500'. 18:00 - 18:30 0.50 DRILL P PROD2 Shut in well. Monitor BHP & WHP. WHP increased to 840 psi (there is crude on the back side). BHP at 5900 TVD: 3710 psi. This is 12.1 ppg. Looks like the A sand has a higher formation pressure than C sand. 18:30 - 19:30 1.00 DRILL P PROD2 Attempt to circulate back side to clean mud. 1.5 bpm. Losing about 90% rtns. with 700 psi WHP. 19:30 - 19:50 0.33 DRILL P PROD2 RIH. Through window at min rate at 20 fpm. Never saw billet. Clrc at 1.0 bpm, WHP:500 psi. B interval had several bobbles. Set down at 7710. Adjust TF to 90R. RIH. 19:50 - 20:30 0.67 DRILL P PROD2 Drill ahead. 3850 psi@ 1.52 bpm. WHP: 330 psi. Unable to bring rtns inside due to crude & gas. Trico choke unable to hold constant pressure. Cannot drill ahead with rig choke & gas buster. Will fill gas buster with sand or worse. 20:30 - 21 :00 0.50 DRILL P PROD2 POOH above window. 21 :00 - 00:00 3.00 DRILL P PROD2 Circulate above window while waiting on iron to RU to go outside through Swaco choke. This will allow rtns to go outside when too gassed up. Circulate well at 1.0 bpm with 500-600 WHP. ECD: 12.51 ppg, BHA:3800 psi. Try to get good mud in coil annulus. Still too much gas to by pass buster. Test hard line tie-in from Swaco to outside line. Good. 9/20/2004 00:00 - 00:15 0.25 DRILL PROD2 Continue to RU hardline tie in from Swaco to outside line. Test to 500 psi 00:15 - 00:30 0.25 DRILL PROD2 Hold PJSM to discuss procedure for circulating outside, handling rtns, choke operation etc. 00:30 - 01 :00 0.50 DRILL PROD2 Take returns outside to tiger tank. Shut in well close ECD. RIH to resume drilling. Through window ok with HS TF, min rate. Past billet at TF:75R at 0.5 bpm. RIH at 25 fpm, 0.94 bpm. 01 :00 - 04:00 3.00 DRILL PROD2 Drill ahead. 4000 psi @ 1.52 bpm fs. 300-400 dpsi. A mix of hard & fast drilling. Bring rtns inside. OK for 10 minute, then more gas. Take rtns outside.. Plan to watch tank & line full time. Strap tank, and test rtns back inside every 30 minutes. 04:00 - 06:00 2.00 DRILL PROD2 Drill ahead. 3900 psi @ 1.45 bpm fs. Rtns outside. 200-400 dpsi. WHP: 400 psi. ECD: 12.97. BHP: 4131 psi WOB:4k#-6k#. ROP very erratic. Take on more mud from uprights 06:00 - 07:00 1.00 DRILL P PROD2 Wiper trip to shoe. Clean PU off bottom and thru build section. Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/20/2004 06:00 - 07:00 1.00 DRILL P PROD2 No problems at OH whipstock. Wiper back in we set down at 7620', and had to ream it back down 07:00 - 08:05 1.08 DRILL P PROD2 Resume drilling. Holding 400 psi on surface choke. Driling at 1.4/?/3600 psi. ROP=variable. 120 fph, then 5 fph at hard stringers. BHP=3974 psi, 12.5 ppg equivelant. IAP=310 psi, OAP=157 psi. Pit vol=170 bbls, Tiger tank vol=300 bbls. We will wiper trip and SD returns to tiger tank at 350 bbls volume to load a vac truck and transfer it to the pits. 08:05 - 09:00 0.92 DRILL Ip PROD2 320 bbls in the tiger tank. Need to 51 returns to the tiger to allow a safe fluid transfer. Make wiper trip up inside the tubing, and circulate bottoms up to clean up the cuttings enough to 51 returns and trap pressure. 09:00 - 11 :00 2.00 DRILL N DPRB PROD2 Need to determine BHP, and also empty tiger tank. Can't flow to the tiger tank while taking returns to it. 81 returns. Trap 700 psi with choke. Let well pressure stabalize to determine static BHP. WHP built up to 930 psi. BHP stabalized at 3825 psi at 7351' MD,. 5865' TVD. Equivelant mud weight=12.54. 11 :00 - 12:45 1.75 DRILL N DPRB PROD2 Up in liner, pumping new mud. Pump down the coil, taking returns thru the Swaco choke to the tiger tank. Holding choke back pressure to achieve a BHP of 3970 psi, 13.0 ppg EMW. Circulate 1 coil + 1 annular volume to the tiger tank to get rid of contaminated mud. Circulating at 3630 psi, pump pressure, and 850 psi surface choke pressure. 12:45 - 13:15 0.50 DRILL N DPRB PROD2 Continue to circulate, but now saving return to pits after running thru gas buster. Not getting any crude back. BHP=4009 psi, ECD=13.05 ppg, WHP=400 psi. Pumping new 9.4 ppg in, getting 9.0 ppg back. Mud looks gas cut. Continue to circulate, monitoring BHP, and holding 13.0 ECD. 13:15 - 13:30 0.25 DRILL N DPRB PROD2 Continuing to circulate, new 9.4 mud in. Getting 9.2+ ppg mud back at 13:00. Still seems a little gas cut. Out rate seems to be getting a little better with time. Continue to circulate. Getting 1 for 1 returns based on in MM rate, and pit volume total. 13:30 - 13:55 0.42 DRILL N DPRB PROD2 Getting 9.3 ppg back. Continues to improve. 13:55 - 15:30 1.58 DRILL N DPRB PROD2 Swap back to the pits, not going thru the gas buster. Circulating at 1.62/1.14/3890 psi, 410 psi surface choke pressure. 4017 psi Annular BHP, ECD=13.08 ppg. Everything is looking as expected at this depth. The well is cleaned up, no gas or oil returns, and we are loosing returns. Probably to the loss zone in the "A" lateral. Continue circulating bottoms up to ensure the well is stable. 15:30 - 16:00 0.50 DRILL P PROD2 RIH. Slight problem at 7615', but fell thru ok. 16:00 - 17:20 1.33 DRILL N DPRB PROD2 Circulate bottoms up prior to resuming drilling. Got gas alarms and crude to surface. Take outside to tiger tank. Trying to fine tune pressures. At 12.59 ECD we are making gas and crude. At 12.9 ECD the upper lateral is taking 100% fluid. We will try for the happy medium of 12.75 ECD. 17:20 - 18:00 0.67 DRILL P PROD2 Attempt to drill. Free spin 3830 psi at 1.4 bpm. 500 psi choke pressure. 12.7 ECD. Mist release from gas buster. Take rtns outside. 18:00 - 18:15 0.25 DRILL P PROD2 Hold PJSM to discuss flow back & transfer procedures. Strap tank every 30 min. Use buddy system to monitor hand on tank. Bring rtns inside every 30 min to check for gas etc. Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/20/2004 18:15 - 20:00 1.75 DRILL P PROD2 Drill ahead. 3700 pSi@ 1.57 bpm fs. Rtns outside. WHP:560 psi. ECD: 12.96. BHP: 4126 psi. Rtn rate to tiger tank variable. 20:00 - 22:30 2.50 DRILL P PROD2 Drill ahead. 3900 psi @ 1.58 bpm fs. 100-200 dpsi. Returns to tiger tank very close to 1:1 with 12.9 ECD. PU and run into btm to try and stall. Unable to stall. Making no ROP at all. 22:30 - 00:00 1.50 DRILL P PROD2 POOH to check mtr and bit. POOH at 100 fpm (60%) to ensure clean hole. Take rtns inside. Follow BHP schedule for 9.3 mud hold 12.9 ECD on formation 9/21/2004 00:00 - 00:30 0.50 DRILL PROD2 Continue to POOH. Circ at 1.7 bpm at 2000' to clean up any cuttings above BHA. Continue to pull to surface. 00:30 - 00:50 0.33 DRILL PROD2 Hold extensive PJSM to discuss un-deployment procedure. Assign job tasks, discuss hazards. 00:50 - 02:45 1.92 DRILL PROD2 Undeploy lateral drilling assembly. SHut in well with 1250 psi WHP. Bled down to and stabilized at 952 psi just prior to closing master. LD motor. HTC RWD324 bit broken in half. PDC & matrix cutting structure (5" long) left in hole. Polished steel shank w/ pin recovered. 02:45 - 04:00 1.25 DRILL PROD2 Discuss options with town team. 04:00 - 06:00 2.00 STKOH PROD2 Decide to opeh hole sidetrack. MU RST60 bit w/ brass nose on 2.3 deg mtr. Pressure deploy BHA. 06:00 - 08:00 2.00 STKOH N DFAL I PROD2 Continue to pressure deploy Sidetrack BHA. (BHA #13) 08:00 - 10:30 2.50 STKOH N DFAL PROD2 RIH with the sidetracking BHA. This BHA has a 2.3 deg motor, and an R60ST bit with a brass nose to assist in RIH. Made it thru window, top of the "A" lateral deployment sleeve/OH whipstock, and the shales in the heel of the well. A few weight bobbles when RIH thru the shales, but nothing significant. 10:30 -11:10 0.67 STKOH N DFAL PROD2 Start troughing hole for sidetrack at 8065'. Not getting good sliding. Just stacking weight. Make a reaming pass uphole to 7950' to help clean up the hole. 11 :10 - 12:40 1.50 STKOH N DFAL PROD2 Trough hole. Pumping 1.47 bpm, 3865 psi CTP, 500 psi choke pressure. Pit vol=240 bbls. Taking returns to a tiger tank outside. Troughing at 15 fph. Trough to 8055'. 12:40 - 14:00 1.33 STKOH N DFAL PROD2 PU. Drill 2nd trough pass from 8040' to 8055'. 3650 psi @ 1.46 bpm fs. 1.0 to 1.3 bpm out rate. WHP: 505 psi. ECD: 13.2, BHP:4180 psi. PVT: 245. Taking rtns inside. Reduce WHP to 400 psi. ECD: 13.2. 1.45 in/1.30 out. 14:00 - 14:30 0.50 STKOH N DFAL PROD2 Begin time milling at 8055'. Lock brake for 30 min. 3550 psi @ 1.45/1.24 bpm fs. TF: 150L. Inc: 88.5 deg. 14:30 - 16:30 2.00 STKOH N DFAL PROD2 Drill 1 '/hr for 2 hrs. WOB slowly increasing. 3530 psi @ 1.45/1.42 bpm fs. ECD:12.91. BHP: 4100 psi. Drill from 8055 to 8057. 16:30 - 18:30 2.00 STKOH N DFAL PROD2 Continue to time drill from 8057'. 2' / hr for two feet. PVT: 347. INcrease WHP to 350 psi due to bubbling rtns. 18:30 - 19:10 0.67 STKOH N DFAL PROD2 See 85 deg and prior hole was at 89 deg so appear to be off. Clean 'out' MM. Drill ahead to finish KO and get lined out for lateral. Returns are 7.5 ppg, ECD 13.17 ppg w/ 9.2 ppg MW 'in'. Drilled to 8072', but stacking (and having to PU), so call this good, PVT 327 19:10-19:35 0.42 STKOH N DFAL PROD2 Wiper to window. Clean by OH WS and window. 19:35 - 20:00 0.42 STKOH N DFAL PROD2 SI choke to open EDC and WHP=1000 psi. POOH following pressure schedule 1.7/3450 PVT 320. POOH to 5400' and PVT is 324 (have gained 12 bbls due to cyclic Swaco choke Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/21/2004 19:35 - 20:00 0.42 STKOH N DFAL PROD2 operation due to something probably washed out and cutting pressure schedule too close) 20:00 - 20:30 0.50 STKOH N DPRB PROD2 RIH to CBU. Had to take returns outside after too gassy 20:30 - 21 :45 1.25 STKOH N DPRB PROD2 CBU from 7380' 1.8/3740 wI 650 psi whp holding 3940-4000 psi bhp (12.8-13.1 ppg ECD) and taking returns to tiger tank. Switch to manual bypass of SWaco choke and cautiously take 121:45 - 22:10 returns back to pits at 8.8 ppg 0.42 STKOH N DPRB PROD2 CBU 1.5/1.14/3200 from 7380' and gradually reduce WHP to 680 psi while circ'ing out gas cut mud and maintain bhp at 4000 psi wI 13.04 ppg ECD 22: 10 - 00:00 1.83 STKOH N DFAL PROD2 Resume POOH from 7380' following pressure schedule 1.7/3400 Safety mtg re: pressure undeploy I Tag up wI 1250 psi WHP wI closed EDC 9/22/2004 00:00 - 01 :45 1.75 DRILL N DFAL PROD2 Pressure undeploy wI 1055 psi initial. Had trouble breaking out BHI quick connect. Change it out and test. Fin LD BHA. WHP 950 psi 01 :45 - 02:30 0.75 DRILL N DFAL PROD2 Change bit, adjust motor. Change packott Bit was 0-8-1 Had one lost cutter and 3 badly broken (of eight outside cutters) Safety mtg re: pressure deploy 02:30 - 04:00 1.50 DRILL N DFAL PROD2 Pressure deploy BHA wI 950 psi WHP 04:00 - 06:30 2.50 DRILL N DFAL PROD2 RIH wI BHA #14 (new HYC bi bit, 1.1 deg). Have trouble starting to RIH due to injector kickout from preset limits and high WHP. Circ at 0.3/1720 while hold 950 psi WHP and took IDFAL 30 min to get started RIH (new packott too) 06:30 - 07:00 0.50 DRILL N PROD2 Log gr tie in from 7410'. -9' correction. 07:00 - 08:00 1.00 DRILL N DFAL PROD2 Circulate out gas. Load pits with new mud from uprights. 08:00 - 10:30 2.50 DRILL N DFAL PROD2 Drill ahead. 3730 psi @ 1.4 bpm fs. Rtns to tiger. ECD:12.98, BHP:4135 psi. ROP:100+ 10:30 - 11 :45 1.25 DRILL N PROD2 Wiper trip to 7410'. Over pulls through B1 & B2 interval (5-10k#). RIH. Having to work through shales at 7600 to 7700'. Ream and back ream two passes. Cleaned up some, but still bumpy 11 :45 - 13:30 1.75 DRILL P PROD2 Drill ahead. 3350 psi @ 1.42 bpm fs. Rtns to tiger. ECD: 12.2 BHP: 3870 psi. WOB: 1-2K#. ROP: 100-120 fph. 13:30 - 15:00 1.50 DRILL P PROD2 Wiper trip to 6500'. B1 & B2 had some overpulls, better than previous short trip. 15:00 - 16:00 1.00 DRILL N SFAL PROD2 Circulate inside casing while adjusting genset frequency. 16:00 - 17:00 1.00 DRILL P PROD2 Continue to RIH after wiper trip. Rough spots from 7650' to 7775'. 17:00 - 18:00 1.00 DRILL P ! PROD2 Drill ahead to 8420' and find a hard spot. Begin slow drop from 94 deg at 6139' TVD 18:00 - 20:00 2.00 DRILL P PROD2 Took 40 min to get thru 8420', then drill at 100'/hr in 40 api sand wI neg wt 1.67/?/3700/120R wI 530 psi bp, 12.25 ECD taking returns to tiger tank. Attempted to bring returns inside twice, but too gassy. 'In' density varies from 9.00-9.23 ppg and mud looks like 'black magic'. Increase bp to 600 psi to maintain 12.55 ECD (4000 psi bhp) after getting 20 bbl gain over an hour-hard to know return rate when going to tiger tank. Begin vac'ing tank for transfer to pits 20:00 - 22:00 2.00 DRILL P PROD2 Drill ahead in and out of hard streaks and swap to 11 OL. Drilled to 8500' wI 12.55 ECD and gained 10 bbls in last hour. Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: Rig Release: Rig Number: 9/8/2004 5/31/1996 Spud Date: 5/1/1996 End: 9/29/2004 9/22/2004 20:00 - 22:00 2.00 DRILL P PROD2 Incr WHP to 700 psi (12.65 ECD) 22:00 - 22:30 0.50 DRILL P PROD2 Drill ahead in another hard streak at 8500' 1. 75/?/3800/80L wI 710 psi bp, ECD 12.65 (4035 psi bhp) wI -8k surface wt and 2.7k wob and try to stay in lower A4 40 api sand 22:30 - 23:35 1.08 DRILL P PROD2 Incr whp to 900 psi after 7 bbl gain in last 30 min. Initial resultant ECD was 12.9 ppg (4100 psi). Red rate to 1.6/3800 psi to maintain 13.0 ppg ECD after one circ. Begin fluid transfer from tiger tank again. IA has declined from 700 psi to 140 psi and OA from 320 psi to 140 psi over 5 hours-assume a leaking DGLV. Strap a 20 bblloss over last hour-finally gaining on it. "In' density is 8.95 ppg. Drill to 8508' and time to test the water 23:35 - 00:00 0.42 DRILL P PROD2 Wiper to window 1.6/3700 23.4k Had 5-8k overpulls 7650-7700' wI minor MW 9/23/2004 00:00 - 01 :00 1.00 DRILL P PROD2 Fin wiper to 7410' and clean by OH WS. RBIH at 1.4/3500 wI ECD 13.1 and clean by OH WS, shales at 7700' and thru OH sidetrack point. Get to TD wI +1k string wt at 20'/min. Lost 14 bbls on wiper 01 :00 - 02:45 1.75 DRILL P PROD2 Drill from 8508' 1.52/3530/85L wI 800 psi bp, 13.0 ECD and still in a hard spot w/-8.5k wt and 2.85k wob. Losing average 14 bbls/hr. Try to bring returns inside, but still too gassy IA and OA stabilized at 80 psi and 50 psi 02:45 - 04:30 1.75 DRILL P PROD2 Finally get thru a 20' thick hard spot and penetration rate picked back up to 60-120'/hr and GR later showed 100 api rock-should be in vicinity of a fault. Holding 88 deg, but lost some incl in faster drilling (same as first leg at 8569-8600') which was also a guesstimated fault. Cuttings gradually increased ECD to 13.15 ppg wI 800 psi bp. Able to take returns to pits again, but too bubbly to 'see' rate and density thru 'out' MM. Drill to 8647' and had signs of diff sticking, then couldn't get back to TD without setting down from 8620-32'. GR also got back down to 50 api at 8615' 04:30 - 05:45 1.25 DRILL P PROD2 Wiper to 6500' 1.51/3460 wI 800 psi bp, 13.0 ECD. No overpulls anywhere. Open EDC above window and circ 1.6/3400 to 6500'. RBIH to 7420' holding 13.0 ECD 05:45 - 06:15 0.50 DRILL P PROD2 Log tie-in down from 7420'. Add 18.5' correction. 06:15 - 07:00 0.75 DRILL P PROD2 Continue to RIH. Hole much smoother holding 12.8 to 13.0 ECD. 07:00 - 10:00 3.00 DRILL P PROD2 Drill ahead. 3350 psi @ 1.43 bpm fs. 100-200 dpsi. Rtns to tiger. WHP: 900 psi ECD: 12.98 BHP: 4130 psi. ROP: very erratic. 10:00 - 13:30 3.50 DRILL P PROD2 Drill ahead to 8753'. Pump new 9.4 mud around. Slowly reduce WHP to 800 psi with new mud. Drilling still erratic. 1.7K# on bit. 13:30 - 15:15 1.75 DRILL P PROD2 Wiper trip to window. B1 & B2 smooth.a couple of tight spotslset downs between 8500 to 8700. 15:15-18:00 2.75 DRILL P PROD2 Drill ahead. 3700 psi @ 1.46 bpm fs. Rtns to tiger. WHP:800 psi wI 9.4 mud around. ECD: 13.2 BHP: 4237. Continued erratic drilling. Appears to be spotty hard spots. 18:00 - 18:30 0.50 DRILL P PROD2 Adding new 9.4 ppg mud while drill ahead from 8900' 1.45/1.15/3700/90R wI 9.4 ppg 'in', 8.75 ppg 'out' at 13.35 ECD (4233 psi) holding 600 psi bp thru repaired Swaco choke at 60-100'/hr. Take returns to tiger after returns got too gassy Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/23/2004 18:30 - 20:10 1.67 DRILL P PROD2 Wiper to window at 1.45/3800 holding 800 psi bp after getting drilled solids to surface to maintain 13.0 ppg. No overpulls anywhere. Open EDC and circ 1.6 bpm while pull to 6500'. RBIH holding 13.0 ECD while circ 1.4 bpm 20: 10 - 20:25 0.25 DRILL P PROD2 Log tie-in down from 7410' 1.5/2950 thru EDC wi 800 psi bp and 13.1ppg ECD. Corr -2.5'. Take returns back to pits and getting 1/1, but that didn't last too long and go back to tiger tank when alarms went off. Losing fluid when above window, but gaining when tie-ing in at 13.0 ppg both at 1.5 bpm. Bring WHP up to 900 psi to keep ECD at 13.0 ppg 20:25-21:15 0.83 DRILL P PROD2 Wiper back to TD was clean until set down at 8813'. ECD is 12.96 wi 900 psi bp. Acts like we are into something with higher pressure-still adding fresh 9.4 ppg mud 21 :15 - 21 :55 0.67 DRILL P PROD2 Ream at drilled TF to TD and have gained 14 bbls over last hour. Increase WHP to 1000 psi and ECD is 13.2 ppg (4240 psi). Have trouble getting past 8920', but get to TD tagged at 8949.5' 21 :55 - 22:20 0.42 DRILL P PROD2 Wiper back to 8760' 1.47/3560 wI 13.3 ECD wI 1000 psi bp 29.4k. 5k overpull at 8860, 8805' and 8785'. Adding last of new mud on location-have a total of 500 bbls between pits, tiger tank and vac truck. MI mixing 290 bbls 9.4 NaF mud (products just arrived on Slope) Wiper back in hole and had to slow ream 8885-8930' due to low string wt-assume tite rock. Get back to bottom and swap TF to left 22:20 - 23:00 0.67 DRILL P PROD2 Resume drilling wi -5k wt, 1.2k wob 1.47/3750/90L w/1 000 psi bp and watch ECD climb to 13.6 ppg. (4340 psi) Lower WHP to 900 psi after 30 min strap showed a 8 bblloss. Find another hard spot at 8961' 23:00 - 00:00 1.00 DRILL P PROD2 Continue drilling on hard spot Lower WHP to 800 psi after 30 min strap showed a 30 bblloss at 13.6 ECD Lower WHP to 700 psi after 30 min strap showed a 19 bblloss at 13.52 ECD Lower WHP to 650 psi after 30 min strap showed a 10 bblloss at 13.35 ECD 9/24/2004 00:00 - 01 :00 1.00 DRILL P PROD2 Continue drilling in hard spot from 8965' at 1.47/3450/85L wI 650 psi bp at 13.24 ECD continuing slow drop at 86 deg at 6155' TVD. Divert returns back into pits after 15 min strap showed 1/1, but too gassy. Take returns back to tiger tank. Incr WHP to 700 psi and ECD slowly dropped to 13.09 ppg. Incr WHP to 800 psi after 30 min strap showed a 8 bbl gain. Looks like 13.2 ppg ECD is very minimum and 13.25 may be optimum. Incr WHP to 900 psi after 800 psi only showed 13.15 ppg ECD 01 :00 - 02:00 1.00 DRILL P PROD2 Drill ahead in hard spot wI 900 psi WHP at avg 13.25 ppg ECD and lost 1 bbl in 30 min. ECD climbed to 13.4 ppg (as gas was worked out of the system) over the next 30 min and lost 32 bbls. Red WHP to 850 psi to maintain 13.25-13.35 ECD which is new working range 02:00 - 04:00 2.00 DRILL P PROD2 Drill ahead slowly and maintain 13.30-13.35 ECD to minimize large losses and avoid gains. New 9.4 ppg mud has been cut to 9.2 ppg during 3 transfers Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/24/2004 02:00 - 04:00 2.00 DRILL P PROD2 Lost 3 bbl at 13.32 ECD in 30 min wI 825 psi WHP Lost 1 bbl at 13.24 ECD in 30 min wI 840 psi WHP 04:00 - 06:00 2.00 DRILL P PROD2 Continue slow penetration rate and ECD's slowly fell to 13.15 ppg wI 850 psi bp and gained 3 bbls in 30 min. Incr WHP to 900 psi and ECD's stabilized at 13.25 ppg and lost 3 bbls in 30 min. Do a 100' wiper and was clean. Get back to bottom and drill wI 200 psi ditt, -4.5k wt w/1.5k wob and still slow. ECD climbed to 13.45 ppg and lost 19 bbls in 30 min. Reduce WHP to 800 psi 06:00 - 07:00 1.00 DRILL P PROD2 Wiper trip to window. Hole smooth. 07:00 - 08:30 1.50 DRILL P PROD2 Pull out of hole to inspect BHA and perform BOP pressure test. Follow WHP schedule. 08:30 - 08:45 0.25 DRILL P PROD2 Hold PJSM to discuss un-deployment. Discuss jOb assignments, procedure, & hazards. 08:45 - 11 :00 2.25 DRILL P PROD2 Shut in well with 1190 psi WHP. Space out coil. Un-deploy BHA. LD MWD & motor. Bit (Hycalog Bi) nose cuttters in good shape. Several broken andlor missing gauge cutters on wings. Mtr feels good & tight. 11 :00 - 15:30 4.50 BOPSUF P PROD2 Test BOP equipment. Witness waived by AOGCC J. Spaulding. Mixing 580 bbls of 10.0 ppg formate mud at MI. 15:30 - 15:45 0.25 DRILL P PROD2 Hold PJSM before deploying BHA. 15:45 - 18:15 2.50 DRILL P PROD2 Pressure deploy BHA #15. (1.1 deg mtr wI Hycalog DS100 bi-bit). WHP=1220 psi and confirmed wI PWD annular and bore pressure wI assumed 9.20 ppg mud in well bore 18:15 - 19:30 1.25 DRILL P PROD2 RIH wI BHA #15 following pressure schedule 19:30 - 19:45 0.25 DRILL P PROD2 Log tie-in down from 7420' at 1.3 bpm holding 13.35 ECD and losing fluid, corr -7' 19:45 - 21 :05 1.33 DRILL P PROD2 RIH at 35'/min 1.35 bpm holding 13.25-13.35 ECD to 8785' and started losing wt and have motor work. PU and precautionary slow ream probable undergauge hole at Tlmin to TD tagged at 9011.0' wI 13.4 ECD at 900 psi WHP 21 :05 - 21 :35 0.50 DRILL P PROD2 Resume drilling ahead wI 9.23# mud in hard spot 1.54/3600/85L wI 800-900 psi bp thru Swaco choke to hold 13.25-13.35 ECD wI -3.7k wt, 1.82k wob, 200 psi ditt at 86 deg at 6151' TVD while load pits wI 10.0# NaF mud and take returns to tiger tank 21 :35 - 22:20 0.75 DRILL P PROD2 Stall at 9016' and then penetration rate picked back up to 90'/hr w/1.5k wt, 1.4k wob, 100 psi ditto Lost 10 bbls in 30 min wI ECD of 13.45 avg wI 9.2# mud. Purposely staying high on ECD's to keep gas out of system. Transfer last of 9.2# mud directly to pump before swap to 10# mud (while waiting on second vac truck which just left MI) 22:20 - 23:00 0.67 DRILL P PROD2 Drill ahead at 60-90'/hr 1.57/3670/30L and swap to 9.92# mud. Lost 20 bbls in 30 min at 13.46 ECD. Reduce WHP to 850 psi. Found another hard spot at 9100' when new mud was at the bit. Reduce WHP to 825 psi as ECD started to climb due to heavier mud. PU 28k and red pump rate to 1.47/3760 after new mud incr FSp due to LSRV 23:00 - 00:00 1.00 DRILL P PROD2 Continue to drill on hard spot and red WHP in 25 psi increments to try to keep on the slightly losing side while circ new mud up annulus. Didn't do too good of a job tho and lost Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/24/2004 23:00 - 00:00 1.00 DRILL P PROD2 around 40 bbls while getting 9.92# mud back to surface. Bring returns back inside and were okay for 5 min, but then too gassy so send to MT tiger tank. Saw about a 0.5 bpm loss rate on 'out' MM at 13.46 ECD wI 475 psi WHP. Transfer remaining 153 bbls of 9.2 ppg black magic to open top tanks. Lost 13 bbls in last 30 min at 13.43 ECD. Reduced WHP to 425 psi by 0000 hrs 9/25/2004 00:00 - 01 :00 1.00 DRILL P PROD2 Drill ahead from 9105' in hard spot 1.47/3800 w/425 psi bp and 13.38 ECD Lost 9 bbls in 30 min. Bring returns back inside for 15 min and actually see 'mud' (although it was gas cut and sli crude stained) at 1.47/1.33 bpm and had 9.5 ppg initial but declined to 8.0 ppg and eventually alarms went off. Go back to tiger tank and raise bp to 500 psi to maintain 13.40 ECD 01:00 - 02:15 1.25 DRILL P PROD2 Drill ahead from 9112' 1.47/3800/95L w/ 500 psi bp and 13.41 ECD. New target range is 13.40-13.45 ppg ECD which gives an avg loss rate of 25 bph. Stall at 9114' then back to 90'/hr, but that only lasted for 30'. Drill on another hard spot at 9144' for 10 min and turn TF down to 160L to get out of this stuff 02:15 - 03:00 0.75 DRILL P PROD2 Wiper to window was clean. Kept ECD 13.35 and higher so assume true 9.92# mud thru out and a 5 min check of returns showed no gas. Trap 900 psi surface pressure and SI at Swaco choke 03:00 - 03:40 0.67 DRILL P PROD2 Park at 7415' (6097' TVD) to get pressure buildup data Time WHP DHP ECD 0302 900 4142 13.36 0312 900 4114 13.28 0322 900 4108 13.26 0332 900 4107 13.26 Open EDC and begin circ at 1.50 bpm while reduce bp to 450 psi, but had too much gas and MM wouldn't record initially 03:40 - 04:50 1.17 DRILL P PROD2 Circ test at 1.50 bpm PVT Rate Out Density Out 0339 450 4134 13.35 188 0347 450 4135 13.35 186 1.35 9.17 0353 450 4134 13.34 184 1.25 9.86 0405 450 4131 13.34 181 1.25 9.92 Btms up, red whp to 400 0410 400 4121 13.30 177 1.45 9.95 0416 400 4118 13.29 177 1.42 9.96 0424 400 4115 13.28 175 1.42 9.95 0434 400 4111 13.27 175 1.61 8.90 Rate incr and lite mud 0438 400 4110 13.27 175 1.70 7.40 Just before MM quit-gassy 0445 400 4109 13.27 174 Too gassy to measure-end of test Trap 840 psi WHP and DHP=4112 psi. RIH by OH WS while close EDC (Kai lied, used min rate instead) 04:50 - 07:30 2.67 DRILL P PROD2 Wiper back in hole 1.5 bpm w/400 psi to resume drilling holding 13.35 ECD and continue going to pits, but not seeing 'out' MM. Sat down at 8060' in wrong hole. .. Had to take returns to tiger tank at 8600'-too gassy. Lost wt at 9010' and PU, clean 28k. Precautionary ream slowly to TD. Last batch Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: Rig Release: Rig Number: 9/8/2004 5/31/1996 Spud Date: 5/1/1996 End: 9/29/2004 9/25/2004 04:50 - 07:30 2.67 DRILL P PROD2 of 10.0# mud is leaving MI (out of materials to build any more Formate based mud other than that held in reserve for KWF) 07:30 - 09:30 2.00 DRILL P PROD2 Condition hole for liner. Losing 20-40 BPH with 13.5 ECD. wi 650 psiWHP. Reduce WHP to 550 psi @ 1.45 bpm. Hole smooth. 09:30 - 10:00 0.50 DRILL P PROD2 Log gr tie in. -1' correction. 10:00 - 18:30 8.50 DRILL N FLUD PROD2 Pull into csg to get BHP survey while waiting on KWF. 4027 psi @ 6020 TVD: ECD is 12.86 ppg. 18:30 - 19:30 1.00 DRILL N FLUD PROD2 Parked at 7262' and SI wI 1660 psi (3976 psi dhp, 13.11 ECD while wo KWF. Have 450 bbls 10 ppg in pits and vac truck, 290 bbls of 13.4 ppg KWF just arrived. Now sending 210 bbls of prior KWF (12.5 ppg NaBr) to MI for weight up to 13.4 ppg. Will wait for truck to be close to loading before starting displacement and cleanout ops due to probable high fluid losses and safety concerns 19:30 - 23:30 4.00 DRILL N FLUD PROD2 SIP 1740 psi (13.14 ECD). Open EDC and begin pump down CT at min rate wI 150 bbls used 9.2# mud 0.25/1740 to keep CT warm and slow down annular swap Second truck wI KWF left MI at 2330 hrs 23:30 - 23:50 0.33 DRILL N PROD2 SIP 1950 psi (13.25 ECD) pumping 0.25/1550 9.2# mud down CT Advise Kup DSO of venting and field announcement of Pad restrictions were made by Security. Safety mtg re: displace I PROD2 wellbore to mud 23:50 - 00:00 0.17 DRILL N Displace wellbore to used 9.2# mud at 1.5/3200 wi 1600 psi bp and 13.4-13.6 ECD 9/26/2004 00:00 - 00:45 0.75 DRILL N FLUD PROD2 Displace well bore to used 9.2 ppg mud at 1.5/3200 wi 1600 psi bp and 13.4-13.6 ECD using manual choke. Lower WHP in 100 psi stages to maintain 13.53 ECD, but got as high as 13.63 ppg and had minimal returns-sorry, Dan(s). RIH to 7415' to match up from prior day data. Returns were mostly crude, very little gas 00:45 - 01:15 0.50 DRILL N FLUD PROD2 Park at 7415' and circ 1.53/3220 wI 850 psi bp to maintain 13.44 ECD (4157 psi) and swap to recycled 9.8 ppg mud. SI manual choke while close EDC and swap back to Swaco choke. Trap 1090 psi=4119 psi bhp (13.30 ECD) Cancel Pad restrictions 01:15 - 02:15 1.00 DRILL P PROD2 Wiper to TD to condition hole for liner holding 13.4-13.5 ECD. Hole was clean. Tagged TD w/ -2k string wt and confirmed official TD as 9144'. PUH 29.1k Losing avg 12 bbls/hr 02: 15 - 02:50 0.58 DRILL P PROD2 Start fresh, slick 9.95 ppg mud while perform ream/backream 1.513950 from 9100' to TD holding 625 psi. Had trouble reaming last 11' twice, but get back to TD 02:50 - 03:30 0.67 DRILL P PROD2 Wiper back to window leaving fresh mud in OH and start 13.4 ppg KWF (NaFCaC03) down CT maintaining 13.5 ECD. After 10 bbls pumped, red rate to 1.25/4000 due to higher density/viscosity. Take returns back to pits and see 1.29/0.88 at 13.3/9.4 ppg among a few lite spots 03:30 - 03:50 0.33 DRILL P PROD2 Leave 13.4 KWF in open hole from 8200' as POOH and see avg 1.20/0.75 returns 03:50 - 05:30 1.67 DRILL P PROD2 POOH for liner while fin displacement and lower bp accordingly to maintain 13.4 ECD. Fully open choke by 6500', but still have Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/26/2004 03:50 - 05:30 1.67 DRILL P PROD2 sli gas cut returns of 9.4 ppg and 1.2/0.6 pulling 78'/min after 90 total bbls pumped Park at 4700' and monitor and looks like well is taking 0.3 bpm after getting 10.1 ppg returns at surface. Will have to live with some losses so POOH 100'/min 1.15/0.4 and return density slowly increased to 10.3 by 3800', 11.0 by 3100',12.4 at 2000', 13.0 at 500'. Pumped a total of 170 bbls of 13.4 ppg NaF mud, leaving 40 bbls in CT and gaining 27 bbls of 10.35-13.4 ppg. Lost 87 bbls of 13.4 mud 05:30 - 06:00 0.50 DRILL P PROD2 Tag up, monitor well and determine loss rate while have crew change 06:00 - 06:15 0.25 CASE P PROD2 PJSM to discuss getting off well and running liner. Discuss concerns of well fluid stability and need to expedite liner make up. 06:15 - 09:00 2.75 CASE P PROD2 LD BHA. Make 56 joints of 2-3/8" STL, 4.6# liner with deployment sleeve, o-ring sub, bullnose guide shoe. 09:00 - 09:45 0.75 CASE P PROD2 MU coiltrack EDC assembly with GS spear. Stab coil. Get on well. Well begining to flow while stabbing lubricator. 09:45 - 11 :30 1.75 CASE P PROD2 RIH with liner assembly. Cannot circulate due to GS spear. Well taking fluid. Unable to get more than 125 psi WHP. WT check at 7300': 8k# dn, 25k# up. 11 :30 - 13:00 1.50 CASE N DPRB PROD2 Tag up on A-leg liner top. Work pipe, slow, fast, stop & start. Unable to work past 7437'. 13:00 - 14:45 1.75 CASE N DPRB PROD2 POOH to surface. Rig up NaBr KWF truck. 14:45 - 15:45 1.00 CASE N DPRB PROD2 Kill well by displacing down kill line with 13.4 NaBr mud. Bleed WHP from 868 to 700 psi. Pump 10 bbl10ppg formate spacer followed by 130 bbls NaBr kill fluid. Pump at 3.5 bpm, max WHP 1200 psi. Final circ WHP: 1000 psi. 15:45 - 16:30 0.75 CASE N DPRB PROD2 Monitor WHP. Bled to zero quicly. No flow. Check lubricator. No flow. Prep 2" safety joint. 16:30 - 18:20 1.83 CASE N DPRB PROD2 Get off well. Unstab coil. Set back injector on legs. LD BHI mwd tools. Standback liner 18:20 - 20:00 1.67 CASE N DPRB PROD2 Install tree cap and SI well at choke. Well was taking fluid most of trip, but static last 10 min. Nordic crew change today. Not sure of what fluidslwhere at surface-have 3 vac trucks, 4 pits and four tanks with various volumes, weights and additives. Safety mtg, then STOP to weigh fluids and get lined out. Pump 13.4 ppg from CT to pit #4 thru bung hole and replace CT volume wI 9.9 ppg fluid to give 46 bbls 12.7+ NaF in pit #4 and 40 bbls 13.4 ppg fresh NaBr on truck. Assume this would give 13.1 ppg avg and 20 bbls over hole fill, but too close for comfort 20:00 - 21 :00 1.00 CASE N DPRB PROD2 Wellbore starting to show positive pressure, wo more KWF 21 :00 - 23:45 2.75 CASE N DPRB PROD2 SIP=150 psi. Truck is loading at MI 23:45 - 00:00 0.25 CASE N PROD2 Truck on location at 2330 hrs. SIP 700 psi Safety mtg re: well kill before running liner 9/27/2004 00:00 - 02:15 2.25 CASE N DPRB PROD2 SIP 750 psi. Bullhead kill pumping 46 bbls 12.7 ppg NaF, plus 40 bbls 13.4 ppg NaBr off of truck #1, 40 bbls 13.5 NaBr off of truck #2 at avg 3.65 bpm/650 psi and max 900 psi. ISIP 400 psi and bled to 125 psi in 5 min, 95 psi in 10 min, 80 psi in 15 min, 70 psi in 20 min, 60 psi in 30 min, 50 psi in one hour. Discuss. Bleed off trapped gas pressure at surface. Fill hole w/< 0.5 bbls. Remove tree cap and monitor going slowly south Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: Rig Release: Rig Number: 9/8/2004 5/31/1996 Spud Date: 5/1/1996 End: 9/29/2004 9/27/2004 02:15 - 04:00 1.75 CASE N DPRB PROD2 Rerun liner out of derrick while filling wI pinched back charge pump and took 4 bbls. MU BTT locked GS assy. MU BHI assy wlorientor. PU injector, remove legs, add lubs, stab tool, stab injector 04:00 - 05:10 1.17 CASE P PROD2 RIH wI BHA #17 wI well SI and not circ 05:10 - 05:25 0.25 CASE P PROD2 Work to get by 7438' 'A' leg by orienting. No pump, WHP is O. Got by after rotating 210 deg from start 05:25 - 06: 1 0 0.75 CASE P PROD2 RIH wI liner in open hole, but first try went into old hole (where 1/2 of a bit is) and set down at 8256'. PUH wI a few 10k overpulls initially to above OH sidetrack point, orient 90 deg and try it again, repeat, and got by on third attempt 06: 10 - 07:30 1.33 CASE P PROD2 Continue to RIH wI liner. Several set downs. PU wt at 8851: 37k#, 2k# dn wt. Tough spot at 8851'. Work pipe and orient. Unable to get past 2nd spot at 8947'. Work all orientations, speeds. No go. Decide to call it quits. Pump down coil to release from linerlgs spear. 07:30 - 09:00 1.50 CASE N DFAL PROD2 Unable to release from liner. Vary pump rate, orient, vary weight. No good. Discuss options with town team. Order slick seawater and 10 bbls 7% HCL. 09:00 - 09:45 0.75 CASE N DFAL PROD2 Wait on fluids. 09:45 - 11 :30 1.75 CASE N DFAL PROD2 Open ECD. Displace coil to seawater. Close EDC. Circulate at 4600 psi coil pressure at 2.4 bpm. Take rtns to tiger, then shut in well and bull head. Work pipe slowly through up & down wt range. Circulate 40 bbls or more. No go. Had to over pull to 52k# up wt to get liner moving again. 11 :30 - 15:00 3.50 CASE N DFAL PROD2 Wait on acid from SLB in Deadhorse. CPAI designed acid composition to be compatable with KRU reservoir. Move liner every 20 minutes to keep it free. 15:00 - 15:45 0.75 CASE N DFAL PROD2 Spot and RU SLB pumper, acid transport, and vac truck. 15:45 - 16:00 0.25 CASE N DFAL PROD2 Hold PJSM to discuss details of pumping acid. Discuss hazards, procedure, safe area, etc with pump & rig crews. 16:00 - 17:30 1.50 CASE N DFAL PROD2 Pump 5 bbls seawater ahead. Pressure test lines to 4000 psi. Good. Pump 10 bbls 7% HCL with additives into coil using SLB pumpers. Displace with rig pump using seawater. At 40 bbls displacement, slow rate to minimum (0.2 bpm). Displace acid from coil at this rate. Continue to move coil up & down slowly during displacement & spotting process. 17:30-18:15 0.75 CASE N DFAL PROD2 Circulate to try and release GS with seawater. 3800 psi @ 2.07 bpm. Liner went down hole to 9075'. Unable to release. Discuss releasing wI EDC 18:15 - 19:00 0.75 CASE N DFAL PROD2 Pull liner thru open hole continuing to pump SW down CT 0.8/1980 wI 1830 psi WHP wI just a few 5k overpulls 19:00 - 20:00 1.00 CASE N DFAL PROD2 POOH with liner. Displ CT to used 9.9# mud 20:00 - 20:30 0.50 CASE N DFAL PROD2 Park at 200', SD pumping on CT and swap to kill line. SIWHP 1710. Bullhead kill wI 50 bbls 11.4 ppg mixed fluids NaF/NaCIIINaBr/CaC03 followed by 80 bbls 13.5 ppg CaC03 at 4 bpm. Initial/max WHP 1900 psi 20:30 - 21 :40 1.17 CASE N DFAL PROD2 SD pumping at FIR of 4.0/1460 psi. ISIP 800, 5 min 440,30 min 360. Bleed off trapped gas in lub. Fill hole w/4 bbls and static 21 :40 - 22:30 0.83 CASE N DFAL PROD2 Break off inj, LD lub, set inj on legs. LD BHI assyand remove BTT GS and deployment sleeve. Break down GS assy and determine that the bull nose extension with locking device (with Printed: 10/1/2004 9:09: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: Rig Release: Rig Number: 9/8/2004 5/31/1 996 Spud Date: 5/1/1996 End: 9/29/2004 9/27/2004 121 :40 - 22:30 0.83 CASE N DFAL PROD2 two locks) bottoms out at the bottom of the deployment sub when in the stacked position and the GS dogs don't have enough room to release from the top of the deployment sub when they shift up under a differential. Meanwhile BHI change out MWD assy and reposition EDC as low as possible in string in case this is the only way to leave the liner in the hole. Discuss 22:30 - 00:00 1.50 CASE N DFAL PROD2 PU and hang 2" safety it in well in proper position for combi setting if necessary (hole staying full). Remove blocks and PU injector, drop 4' lub. RU and surface test GS assy (without deployment sub) and dogs retracted at 1.75 bpm wi 3/8" orfice (this past run) and 1.0 bpm wI 1/4" orfice. RD test assy. Pull safety jt and LD. MU prior pump off GS assy on deployment sleeve wI shorty BHI assy (checks only). Stab back on well wi injector 9/28/2004 00:00 - 05:00 5.00 CASE N WAIT PROD2 Fill hole from BS and was full. SI well and keep 90 psi charge pump pressure on kill line pumping 13.5 ppg KWF, but well wouldn't take fluid. At 0130 hrs SD charge pump since well pressure was 100 psi. WO BTT to make a tool that works 05:00 - 11 :15 6.25 CASE N WAIT PROD2 Continue to wait on replacement deployment sub from Baker machine shop. WHP: 525 psi and rising. 11: 15 - 11 :30 0.25 CASE N DFAL PROD2 Hold PJSM in ops cab to discuss killing well. 11 :30 - 12:30 1.00 CASE N DFAL PROD2 SI P 1250 psi. Bullhead kill well with 112 bbls 11.4 & 13.5 ppg CaCo fluid at 3.6 bpm/1040 psi. ISIP 600. 5 min 350 psi. Bleed off trapped gas and well was on sli vac 12:30 - 13:20 0.83 CASE N PROD2 Remove injector and set on legs. Remove GS and deployment sub. Install redesigned and longer deployment sub with GS having extended bullnose and 1/4" orfice. MU reconfigured BHI BHA wi orientor on bottom. Stab back on wI injector 13:20 - 14:30 1.17 CASE N PROD2 RIH wi BHA #18 wi well SI and no pump 14:30 - 16:30 2.00 CASE N PROD2 7300' 26.0k. 6k RIH thru window, clean. RIH past leg 'A' wI no wt loss. Sat down in old hole (where 1/2 of bit is at 8251 '). POOH (and was clean) to above OH sidetrack point at 8040' and orient 100 deg. RIH and got in right hole. RIH wi liner at 45'/min at 8300' wI +4k string wt and had +2k st wt just before set down at 8745'. PU, clean 31k and orient 120 deg. Get by and RIH to 8815'. Work for 30 min to get to 8850' and started running clean again. Work from 8970' to 9080' in 30 min. Work for additional 20 min wI clean PU's at 31k and call this good (probably same depth reached as prior run so <70' from actual TD). Fill hole from BS wI 13.5 ppg KWF since WHP is still zero 16:30 - 17:40 1.17 CASE N PROD2 Pump down CT at 1.25/3700 and PUH 23k and were released. TOL at 7254', BOL at 9080'. Filled hole pumping down CT at 0.4/1900 and WHP gradually rose to 500 psi as POH 17:40 - 18:15 0.58 CASE N PROD2 Tag up wI 460 psi. WO crew change to undeploy 18:15 - 18:25 0.17 CASE N PROD2 PJSM review well blowdown attempt. 18:25 - 18:45 0.33 CASE N PROD2 Line up to Tiger Tank. Attempt to bleed-off wellhead pressure but unable to drop pressure. Shut-in well with 490psi. 18:45 - 19:00 0.25 CASE N PROD2 PJSM and review procedures for Pressure Undeployment. 19:00 - 20:30 1.50 CASE N PROD2 Pressure undeploy BHA following guidelines and procedures. No problems. Wellhead pressure 610psi. Printed: 10/1/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 9/28/2004 20:30 - 21 :00 0.50 WHSUR P POST Line-up on wellhead and bullhead 25bbls diesel. Close Master and Swab valves. Final WHP 700 psi. PJSM discuss coil blowdown operations with N2. Slowdown coil with N2. Unstab coil from injector and secure to reel. Prep to remove reel. Same time cleaning mud pits. Lower reel to Veco flatbed. ND SOPE. Installed tree cap and test to 5000psi. Finish cleaning oily mud tanks. 21:00-21:10 I 21 :10 - 22:00 22:00 - 00:00 0.17 WHSUR P 0.83 WHSUR P 2.00 RIGD P POST POST POST 9/29/2004 00:00 - 03:00 3.00 RIGD P POST Rig Released at 0300 hrs 9-29-04 Printed: 10/1/2004 9:09: 13 AM . BP-GDB Baker Hughes INTEQ Survey Report . ..K~ INTE.Q Field: Kuparuk River Unit North Slope UNITED STATES Map System:US Slate Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre bggm2004 Site: KRU 1 F Pad North Slope Site Position: Northing: 5958733.30 ft Latitude: 70 17 53.527 N From: Map Easting: 539521.50 ft Longitude: 149 40 47.811 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.30 deg Well: 1F-18 Slot Name: 1F-18 \ Well Position: +N/-S 0.00 ft Northing: 5958733.30 ft Latitude: 70 17 53.527 N +E/-W 0.00 ft Easting : 539521.50 ft Longitude: 149 40 47.811 W Position Uncertainty: 0.00 ft WeJIpath: 1F-18A 500292265401 Current Datum: 1 F-18 RKB Magnetic Data: 9/14/2004 Field Strength: 57568 nT VerticaJ Section: Depth From (fVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 1F-18 7395.00 ft Mean Sea Level 24.56 deg 80.73 deg Direction deg 87.00 Height 1OS.00 ft Survey Program for Definitive WeJIpath Date: 9/16/2004 Validated: Yes Actual From To Survey ft ft 100.00 7300.00 Gyro (100.00-7800.00) (0) 7395.00 9065.00 MWD (7395.00-9065.00) Version: 4 Toolcode Tool Name GoocUwro MWD Good Gyro MWD - Slandard Annotation 7300.00 7395.00 9065.00 6009.39 6082.48 6077.74 TIP KOP TO Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Slandard Start Date: 9/16/2004 Engineer: Tied-to: From: Definitive Path Survey 7300.00 40.21 13.75 6009.39 5901.39 3438.11 450.70 5962173.40 539954.08 630.02 0.00 7395.00 39.20 14.96 6082.48 5974.48 3496.91 465.74 5962232.26 539968.80 648.12 1.34 7409.96 42.13 15.93 6093.83 5985.83 3506.30 468.34 5962241.67 539971.35 651.21 20.04 7443.44 52.57 25.50 6116.51 6008.51 3529.19 477.18 5962264.60 539980.07 661.23 37.54 7470.19 60.06 33.62 6131.35 6023.35 3548.48 488.20 5962283.95 539990.99 673.24 37.68 7502.33 69.52 40.18 6145.04 6037.04 3571.65 505.68 5962307.21 540008.34 691.91 34.73 7531.40 80.00 43.63 6152.67 6044.67 3592.48 524.40 5962328.13 540026.95 711.70 37.82 7564.44 90.17 50.03 6155.50 6047.50 3614.95 548.37 5962350.73 540050.80 736.81 36.32 7590.33 99.40 53.93 6153.34 6045.34 3630.82 568.67 5962366.71 540071.01 757.91 38.68 7625.82 102.24 65.11 6146.66 6038.66 3648.49 598.65 5962384.53 540100.89 788.77 31.95 7654.46 103.44 68.65 6140.29 6032.29 3659.45 624.32 5962395.62 540126.51 814.99 12.76 . ¡ BP-GDB Baker Hughes INTEQ Survey Report . ..I: INT&Q Survey 7688.45 102.87 64.97 6132.55 6024.55 3672.48 654.74 5962408.81 540156.86 846.05 10.67 7717.22 102.36 67.35 6126.27 6018.27 3683.83 680.42 5962420.29 540182.47 872.28 8.27 7750.83 101.83 71.07 6119.23 6011.23 3695.49 711.14 5962432.12 540213.12 903.57 10.94 7788.74 103.37 76.58 6110.95 6002.95 3705.80 746.65 5962442.61 540248.58 939.58 14.75 7824.72 102.33 81.79 6102.94 5994.94 3712.37 781.09 5962449.37 540282.99 974.31 14.41 7865.27 101.45 85.88 6094.58 5986.58 3716.63 820.54 5962453.83 540322.40 1013.93 10.11 7904.16 99.48 89.87 6087.52 5979.52 3718.05 858.74 5962455.44 540360.60 1052.15 11.29 7936.02 97.15 93.21 6082.91 5974.91 3717.20 890.25 5962454.76 540392.10 1083.57 12.69 7967.15 93.88 94.59 6079.92 5971.92 3715.09 921.16 5962452.81 540423.02 1114.33 11.39 7999.69 90.90 96.24 6078.56 5970.56 3712.02 953.52 5962449.92 540455.39 1146.49 10.47 8031.11 91.73 99.86 6077.84 5969.84 3707.62 984.62 5962445.68 540486.51 1177.31 11.82 8065.42 88.45 102.70 6077.79 5969.79 3700.91 1018.26 5962439.15 540520.18 1210.55 12.64 8098.30 88.97 105.91 6078.53 5970.53 3692.79 1050.10 5962431.20 540552.07 1241.93 9.89 8132.28 90.17 109.34 6078.78 5970.78 3682.50 1082.48 5962421.08 540584.50 1273.73 10.69 8156.62 87.53 111.05 6079.27 5971.27 3674.10 1105.32 5962412.80 540607.38 1296.09 12.92 8187.52 87.19 115.27 6080.69 5972.69 3661.97 1133.69 5962400.82 540635.81 1323.79 13.69 8215.45 89.22 119.11 6081.57 5973.57 3649.21 1158.52 5962388.20 540660.70 1347.92 15.54 8242.81 88.82 123.27 6082.04 5974.04 3635.05 1181.91 5962374.16 540684.17 1370.54 15.27 8277.59 87.81 121.30 6083.06 5975.06 3616.48 1211.30 5962355.75 540713.65 1398.92 6.36 8309.96 89.59 117.79 6083.79 5975.79 3600.53 1239.45 5962339.94 540741.88 1426.19 12.16 8341.95 90.66 114.39 6083.73 5975.73 3586.46 1268.18 5962326.03 540770.68 1454.14 11.14 8381.33 90.84 111.63 6083.21 5975.21 3571.07 1304.42 5962310.83 540806.99 1489.52 7.02 8415.40 90.97 108.52 6082.67 5974.67 3559.38 1336.41 5962299.31 540839.04 1520.86 9.14 8447.03 90.57 105.94 6082.25 5974.25 3550.01 1366.61 5962290.10 540869.29 1550.53 8.25 8477.57 89.98 102.61 6082.10 5974.10 3542.48 1396.21 5962282.73 540898.92 1579.69 11.07 8509.33 88.85 100.16 6082.42 5974.42 3536.21 1427.34 5962276.62 540930.08 1610.45 8.49 8538.74 88.69 95.19 6083.06 5975.06 3532.29 1456.47 5962272.85 540959.23 1639.34 16.90 8569.40 90.02 90.47 6083.40 5975.40 3530.77 1487.08 5962271.50 540989.85 1669.83 15.99 8600.83 84.23 83.52 6084.98 5976.98 3532.41 1518.39 5962273.30 541021.15 1701.19 28.75 8631.73 85.15 80.14 6087.84 5979.84 3536.79 1548.84 5962277.83 541051.57 1731.82 11.29 8660.92 92.88 79.61 6088.34 5980.34 3541.91 1577.55 5962283.11 541080.25 1760.76 26.54 8690.52 88.05 76.98 6088.10 5980.10 3547.92 1606.53 5962289.27 541109.19 1790.01 18.58 8729.32 86.33 158.72 6090.01 5982.01 3559.33 1643.52 5962300.87 541146.12 1827.55 21.72 8764.49 88.42 7022 6091.62 5983.62 3571.65 1676.42 5962313.37 541178.95 1861.05 7.31 8794.36 91.79 73.05 6091.56 5983.56 3581.06 1704.76 5962322.92 541207.24 1889.85 14.73 8825.21 92.19 75.64 6090.49 5982.49 3589.38 1734.45 5962331.40 541236.88 1919.93 8.49 8859.46 93.39 78.44 6088.82 5980.82 3597.05 1767.78 5962339.24 541270.17 1953.62 8.89 8891.97 93.89 82.96 6086.76 5978.76 3602.29 1799.79 5962344.65 541302.15 1985.86 13.96 8921.05 94.90 86.58 6084.53 5976.53 3604.94 1828.66 5962347.45 541331.00 2014.82 12.89 8949.94 92.35 89.91 6082.70 5974.70 3605.82 1857.47 5962348.48 541359.80 2043.64 14.50 8980.81 92.53 93.79 6081.39 5973.39 3604.82 1888.29 5962347.65 541390.63 2074.37 12.57 9010.01 92.47 97.48 6080.11 5972.11 3601.96 1917.32 5962344.94 541419.66 2103.20 12.63 / 9065.00 92.47 97.48 6077.74 / 5969.74 3594.81 1971.79 5962338.07 541474.17 2157.23 0.00 ConocoPhiUips Alaska, Inc. 'Iw/ WELLPATH DETAILS ConocoPhillips 1F·18A 500292265401 Parent Wellpath: 1F·1$ Tie on MD: 7395.00 Rig; Nordic 2 Ref. Datum: 1F·1S RKB 10S.o8ff V.Section Origin Origin Starting Angle +NloS +EI.JN From T\lD S7.00" 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate &!JE) Reference: Vertical . D) Reference: SeQtioo(VS) Reference: Measured Oeþth Reference: CalQulatioo Method: IIIIIIIIII!II Survey: MWD (1F-18/1F-18A) Created By: Briî Patois Date: 10/112004 Azimuths to True North Magnetic North: 24.56" T 1F-18, 1F-18A,Plan *'2 1F-18 (1F-18) 1F~18A MWO $!¡a"" ~Yi:l"n N_ 1F·,Mf>1;IijwmZ- ND .... .55700-_ 1575~ .... .c: 5800-= 1. ~ I» 5850- e:a - ii5900 Co» 1.:595Cf I» >600Cf I» := t:605Cf 3:02 PM 10/1/2004 1500 1550 1600 Vertical Section at 87.000 [50ft/in] NIP (499-500, OD:3.500) TUBING (0-7000, OD:3.500, \D:2.992) SURFACE (0-4254, OD:7.625, Wt:29.70) 'RODUCTION (0-7208, OD:5.500, Wt:15.50) Gas Lift MandrelNal'Je 3 (5577-5578, Gas Lift MandrelNal'Je 4 (6303-6304, Gas Lift MandrelNal'Je 5 (6930-6931, NIP (6978-6979, OD:3.500) PBR (6986-6987, OD:3.500) PACKER (6999-7000, OD:3.500) SLEEVE (7254-7255, OD:2.700) . . , KRU 1F-18AL 1 WINDOW <II (7399-7410, OD:7.625) Perf (7257-9036) ConocoPhillips Alaska, Inc. 1F-18AL1 API: 500292265460 SSSV Type: NIPPLE Well Type: PROD Orig 9/30/2004 Completion: Last W/O: Angle @ TS: deg @ Angle @ TO: deg @ 9144 Rev Reason: CTD SIDETRACK LEG AU, GLV design Last Update: 10/22/2004 Annular Fluid: Reference Log: Last Tag: Last Tag Date: Ref Log Date: TD: 9080 ftKB Max Hole 0 deg @ Angle: CaslngStdng - COMMON STRINGS Description Size CONDUCTOR 16.000 SURFACE 7.625 PRODUCTION 5.500 WINDOW 7.625 Casing String - LINER LEG At 1 Description I Size LINER LEG AL 1 2.375 Tubing String- TUBING Size I Top I Bottom 3.500 0 7000 Perforations Summary Interval I rvD I Zone 7257 - 9036 7257 - 9036 Gas Lift MandrelsNalves St MD rvD Man Man Type V Mfr Mfr 1 2463 2463 BST AXT 2 4343 4343 BST AXT 3 5577 5577 BST AXT 4 6303 6303 BST AXT 5 6930 6930 BST AXT Other (plugs, equIp., etc.) - COMMON JEWELRY· Depth rvD Type 499 499 NIP 6978 6978 NIP 6986 6986 PBR 6999 6999 PACKER 7254 7254 SLEEVE Generà/ Notes Date I Note 9/29/2004 CTO DUAL SIDETRACK - LEG AL 1 Bottom 121 4254 7208 7410 Wt 62.50 29.70 15.50 0.00 Top o o o 7399 rvD 121 4254 7208 7410 Grade Thread Top 7253 Bottom 9080 rvD 7000 V Type VOD Latch GLV 1.0 T-1 GLV 1.0 T-1 GLV 1.0 T-1 GLV 1.0 T-1 OV 1.0 T-1 Description Port TRO Date Vlv Run Cmnt 0.125 1261 10/3/2004 0.156 1295 10/3/2004 0.188 1330 10/3/2004 0.250 1430 10/3/2004 0.250 0 10/3/2004 ID 2.813 2.850 3.000 3.000 1.875 CAMCO 'DS' NIPLE CAMCO 'D' NO GO NIPPLE BAKER PBR BAKER SABL-3 LINER PACKER BAKER DEPLOYMENT SUB FROM MAIN LEG TO LATERAL LEG AL 1 Ke: U-18A e e Hi Jim, I am finally back. The KROP and Wsak spacing revisions are nearly in final form and we would hope to issue next week. Jack, Steve and I have informally discussed the presentation that was made and I am endeavoring to draft a letter. Hopefully we can close that issue as well next week. Respond with any questions. Tom Hand, Jim wrote: Tom, Steve was very responsive to our needs by providing IF-18A well exception the day after the public comment period closed. This allowed us to get the well on line almost immediately following clean-up. We are still waiting for the KROP and Wsak spacing revision but know wells coming up are impacted so we have some time. Thanks for all your help. What is the AOGCC Status on the Kuparuk wells in close proximity to WSak injectors we reviewed a couple weeks ago? Let me know if you need anything else on this issue. Jim -----Original Message----- From: Thomas Maunder [~§J:~_~_t::.C?:_t:C?~_~~~E1_c:ier@admin. state. ak. us] Sent: Tuesday, October 19, 2004 7:14 AM To: Hand, Jim Subject: Re: 1F-18A Steve, Did you send a note back to CPAI?? Tom Hand, Jim wrote: Steve, We have flowed back the 1F-18A well and are ready to go to production. Could you please let me know if we are going to have a hearing on October 12th or if the AOGCC will be able to give us the requested pool rule revision (see attached e-mail) so we may start producing 1F-18A. Your timely consideration would be appreciated. Jim -----Original Message----- lof2 11/7/2005 1:57 PM Re: 1F-18A e e From: Thomas Maunder [maìlto:tom maunder@admìn.state.ak.us] Sent: Wednesday, September 08, 2004 7:11 AM To: Cookson, John Subject: KROP_&_WSak_Spacìng_Notìce_of_Publìc_Hearìng John, Attached ìs the publìc hearìng notìce for the spacìng change. A hearing is tentatively scheduled for October 12, 2004 at 9:00 am. 4:30 pm on October 1, 2004 is when the 30 day public comment period closes. The latest a hearing may be requested is 4:30 pm on September 15, 2004. One thing to remember is that the ultimate decision of whether or not to hold a hearìng is the Commissioners. I hope this information is of help. Give a call and we can discuss. Tom Maunder, PE AOGCC ** 20f2 11/7/2005 1 :57 PM Ke: lFwd: tW: IF-18 Flowback] e James, As we discussed in the meeting - CPAI should go ahead and finish the completion and clean up on the subject well. Taking the gas to the plant should not be an issue since is would be flared or vented otherwise. There is no issue with the gas since there is not a sale involved. Jack Hartz 793-1232 Stephen Davies wrote: Jack, You weren't on the original distrib. list, I don't know why. I can't see a problem with this, as no revenue is involved at this point. Concur? As this lies more in your specialty, do you mind sending a response to Jim Hand? Thanks, Steve D. -------- Original Message -------- FW: 1F-18 Flowback Man, 04 Oct 2004 08:32:17 -0800 Hand, Jim <James. R. Ii9:.!!9c~s:g!!:t2<:.:(?£Þ:.i.}~~E¡;;:C::<?~? tom maunder@admin.state.ak.us, steve davies@admin.state.ak.us Subject: Date: From: To: It was mentioned in our meeting last week that we could go ahead and perf and flowback 1F-18A in advance of receiving the spacing exception or pool rule revisions. I assume we can take the gas to the plant during the flowback? Please let us know so they may proceed with the clean-up. Thanks. Jim Steve - I'll call you later to see if the AOGCC received any public comments and if a hearing is required. -----Original Message----- From: Pysz, Nick P Sent: To: Hand, Jim Subject: FW: 1F-18 Flowback Monday, October 04, 2004 8:25 AM Jim, Is it your understanding that gas from 1F-18 could be sent to the plant since it does not represent a source of revenue for the company? Nick -----Original Message----- From: CPF1 Prod Engr Sent: Saturday, October 02, 2004 2:05 PM To: Pysz, Nick P Cc: Seitz, Brian; CPF1 DS Lead Techs Subject: FW: 1F-18 Flowback Nick- lof2 11/7/2005 1 :59 PM Ke: r W: It'-IS Flowback e n=-,s Þ\ e Jim, Proper disposition of the fluid(s) from the clean up is part of "normal accepted practices". Liquids and gas developed from the clean up may be processed/recycled as appropriate. Tom Maunder, PE AOGCC Hand, Jim wrote: It was mentioned in our meeting last week that we could go ahead and perf and flowback IF-18A in advance of receiving the spacing exception or pool rule revisions. I assume we can take the gas to the plant during the flowback? Please let us know so they may proceed with the clean-up. Thanks. Jim Steve - I'll call you later to see if the AOGCC received any public comments and if a hearing is required. -----Original Message----- From: Pysz, Nick P Sent: Monday, October 04, 2004 8:25 AM To: Hand, Jim Subject: FW: IF-18 Flowback Jim, Is it your understanding that gas from IF-18 could be sent to the plant since it does not represent a source of revenue for the company? Nick -----Original Message----- From: CPFl Prod Engr Sent: Saturday, October 02, 2004 2:05 PM To: Pysz, Nick P Cc: Seitz, Brian; CPFl DS Lead Techs Subject: FW: IF-18 Flowback Nick- I don't think we can just vent the gas to atmosphere (environmental issues & new regulations for planned venting events), and therefore we'll need to pipe the produced gas into our production system. Since we're not supposed to go to sales, and since PTS is and will be tied up many days with west sak flowback, I feel we should schedule this flowback after the lE-166 flowback (-next weekend). Is it OK to produce the gas into our system, since there isn't a revenue stream with it? Ryan Dunn and Mike Timmcke CPFl Production Engineers (907) 659-7493 -----Original Message----- From: Pysz, Nick P Sent: Thursday, September 3D, 2004 8:16 AM lof2 11/7/2005 1 :57 PM Ke: tW: IF-I8 tlowback e e To: CPFl Prod Engr Cc: Hand, Jim; Seitz, Brian Subject: IF-18 Flowback Ryan, Jim spoke to the AOGCC yesterday and they said it would be alright to flow IF-18 back to tanks to clean the well up. We won't be able to go to sales with IF-IS until they issue the Conservation Order. Steve Davies has said he will push the paperwork thru so hopefully it won't take too long to get the CO. Give me a call if you have any questions. Thanks, Nicholas Pysz Drillsite Petroleum Engineering ConocoPhillips Alaska (907) 265-6831 20f2 11/7/2005 1:57 PM e- STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: llr.D...rQfJfl@ª.ºJni.Q.,§.~ªt~Lf!.~Jg~ aoncc _prudhoe _bay@admin.statø.ak.us bob _ fjeGkenstt'j¡ n@admin.state.ak.us Rig No.: 2 DATE: 9/24104 Rig Phone: 659-4398 Rig Fax: 659-4356 Op. Phone: 659-4393 Op. Fax: 659-4356 E-Mail.suADWDRLGNORDIG2TOOLPUSHER@8P.COM PTD # 204-167 Meridian: UM Township: 11 N Range: 10E Workover: Explor.: Weekly: X Other: Annular: 250/2500 Valves: 250/3500 TEST DATA FLOOR SAFETY VALVES: P/F Quantity P/F P Upper Kelly 0 P Lower Kelly 0 P Ball Type 1 Inside BOP 0 Contractor: NORDIC 1 SLB Rig Rep.: Mckeirnan/Olsen Operator: BPX Rep.: Goodrich/Sevcik Well Name: Kuparuk 1F-18A Location: Section: 19 Operation: Drlg: X Test: Initial: Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: P/F P P P P Location Gen.: Housekeeping: PTD On Location Standing Order Posted Well Sign Dr!. Rig Hazard Sec. .e P BOP STACK: Quantity Size/Type P/F MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind / Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A Quantity P/F Choke Ln. Valves 1 31/8" P Inside Reel valves 1 P HCR Valves 2 31/8" PP Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve N/A Time/Pressure P/F System Pressure 3025 CHOKE MANIFOLD: Pressure After Closure 2150 Quantity P/F 200 psi Attained 20 sec No. Valves 14 PIP Full Pressure Attained 1 Min 30 sec Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2100 Test Results Number of Failures: º Test Time: 4.5 Hours Components tested 28 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: llm...rf.}SJfl@ªº-mi.Q.,§M~.tQ:.ft~:.~t~~ Remarks: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector YES 24 HOUR NOTICE GIVEN XXX NO Date Waived By John Spaulding 9/23/04 Time Witness Test start 10:00 Finish 14:30 Coil Tubing BFL 05/29/03 10:00 Nordic 2 BOP 09-24-04..xls -- STATE OF ALASKA e OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: llr.D...rªJJ.ŒmªgxniXJ...§Aª.t§:.ª.t.~g~ aOOGC _p¡l¡dtwe _ bay@adm¡n.statø.ak.us bob _ fj f.1ckenstø¡ n@adrn¡l1.slate,ak,us Rig No.: 2 DATE: 9/11104 Rig Phone: 659-4398 Rig Fax: 659-4356 Op. Phone: 659-4393 Op. Fax: 659-4356 E-Mail SUADWDRLGNORDIC2TOOl.PUSHER@8P.COM PTD # 204-167 Meridian: UM Township: 11N Range: 10E Workover: Explor.: Weekly: Other: Annular: 250/2500 Valves: 250/3500 TEST DATA FLOOR SAFETY VALVES: P/F Quantity P/F P Upper Kelly 0 P Lower Kelly 0 P Ball Type 1 Inside BOP 0 Contractor: NORDIC 1 SLB Rig Rep.: Holmes /Igtanloc Operator: BPX Rep.: Sarber 1 Hildreth Well Name: "Kuparuk 1F·18A Location: Section: 19 Operation: Drlg: XXX Test: Initial: XXX Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: P/F P P P P Location Gen.: Housekeeping: PTD On Location Standing Order Posted Well Sign Dr!. Rig Hazard Sec. P BOP STACK: Quantity SizelType P/F MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind 1 Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A Quantity P/F Choke Ln. Valves 1 31/8" P Inside Reel valves 1 P HCR Valves 2 31/8" PP Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve N/A Time/Pressure P/F System Pressure 2950 CHOKE MANIFOLD: Pressure After Closure 2100 Quantity P/F 200 psi Attained 20 sec No. Valves 14 PIP Full Pressure Attained 1 Min 36 sec Manual Chokes 1 P Blind Switch Covers: All stations XX Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2000 Test Results Number of Failures: º Test Time: 4.5 Hours Components tested 28 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: llm...rºJJiHçgª.ªr.:.1l.t1...§M~.t§:J!}dJ.§ Remarks: Distribution: orig-Well File c - Oper.lRig c - Database c - Trip Rpt File c - Inspector YES 24 HOUR NOTICE GIVEN XXX NO Date Waived By Chuck Sheve 9/10/04 Time Witness David Lancaster Test start 10:00 Finish 14:30 Coil Tubing BFL 05129/03 10:00 Nordic 2 BOP 09-11-04..xls . . FRANK H. MURKOWSKI. GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk IF-18A ConocoPhillips Alaska, Inc. Permit No: 204-167 Surface Location: 792' SNL, 455' WEL, SEC. 19, TIIN, Rl OE, UM Bottomhole Location: 2793' NSL, 2223' EWL, SEC. 17, TIIN, RI0E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips Alaska, Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact th mission's petroleum field inspector at (907) 659-3607 (pager). BY ORDER OF THE COMMISSION DATED thisL day of September, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. o Drill . Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 792' SNL, 455' WEL, SEC. 19, T11N, R10E, UM Top of Productive Horizon: 2693' NSL, 20' EWL, SEC. 17, T11N, R10E, UM Total Depth: 2793' NSL, 2223' EWL, SEC. 17, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): ,¡ ~ Surface: x- 539521 y- 5958733 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 7395 00' feet Maximum Hole Angle: 104 ( degrees . STATE OF ALASKA . A ALASKA OIL AND GAS CONSERVATION COMMISSIO~ECE. rVED. 11 PERMIT TO DRILL K 20 AAC 25.005 AUG 2 72n04 1b. Current Well Class 0 Exploratory . Development Oil 0 Multiple zone. o Stratigraphic Test 0 Service ~~1m<t)ff1ffltßØ C~§!~ion 5. Bond: Ii Blanket 0 Single Well 11. Well Na!OO:ftB~wmber: Bond No. 59-52-180 "KlJp'1~-18A 6. Proposed Depth: ~ 12. Field / Pool(s): MD 9800 '" TVD 5993ss Kuparuk River 7. Property Designation: ADL 025652 " 9. Acres in Property: 2560 13. Approximate Spud Date: September 10, 2004 14. Distance to Nearest Property: 34,500' 8. Land Use Permit: 18. Casing Program: Size Casing 2-3/8" 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 118' feet 791' to 1 F-13 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3200./ Surface: 2583 v' $ettíÍ'19 p~p <:l(Jåºti1YQfCe(oent Top .-.- .\\ (cJ.or sacks) Coupling Length MD TVD MD TVD (includinç¡ stage data) STL 2350' 7450' 6014' 9800' 5993' Uncemented Slotted Liner Hole 3" Weiç¡ht 4.6# Grade L-80 19. PRESENTWELL CONDITION SûMMARY Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 7939 6545 None Structural Conductor 121' 16" 230 sx Arcticset I 121' 121' Surface 4254 7-5/8" 710 sx AS III, 330 sx Class 'G' 4254' 3730' Intermediate 7208' 5-1/2" 70 sx Class 'G' 7208' 5940' Production Liner 929' 3-1/2" 99 sx Class 'G' 7000' - 7929' 5785' - 6536' 20. Attachments Ii Filing Fee, $100 Ii BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 6076' - 6265' Ii Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report Ii Drilling Fluid Program Ii 20 AAC 25.050 Requirements Perforation Depth MD (ft): 7387' - 7620' 21. Verbal Approval: Co~mission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name_ Dan Kara Title CT Drilling Engineer Phone Date: Contact Dan Kara, 564-5667 Permit To Drill__ ,..." I Permit Approval Number: :u /'7 ~ 50- 029-22654-01-00 Date: Conditions of Approval: Samples Required 0 Yes I'2No Mud Log Required Hydrogen Sulfide Measures ~Yes 0 No Directional Survey Required Other: ~Sa()~S\ "'-~~ ~OV \-«.~.\ <>-s.~\o..\'\~~ , See cover letter for other requirements o Yes ~o ~Yes 0 No Approved Bv: Form 10-401 R - ORIGiNAL APPROVED BY THE COMMISSION Oate ?, W,d- 'Iro"':/tI~ 6uPlicate ~\7\ ~, r >£ ~ "",\ \; "RU 1 F-18A & AL 1 Sidetrack - COi'e"Ubing Drilling Summary of Operations: BP operated Coiled tubing drilling will sidetrack ConocoPhillips operated KRU well1F-18 using the dynamically overbalanced coiled tubing drilling (DOCTD) technique (see description below). These horizontal laterals (IF-18A & ALl) will target Kuparuk C Sand and A Sand reserves for production. The Kuparuk A Sand perforations in the existing well will be isolated/abandoned with a CIBP. The window will be milled in the existing Kuparuk C Sand perforations. ,¡ CTD Drill and Complete 1F-18A & ALl program: Planned for September 10, 2004 1. Pre CTD install cast iron bridge plug at 7450' MD to isolate/abandon A Sand perfs. / 2. MIRU Nordic 2. NU 7-1/16" BOPE, test. 3. CTD install mechanical WS at 7395' MD 4. Mill 2.74" window at 7395' md and 10' of openhole. 5. Drill 3" bicenter hole horizontal sidetrack 1F-18A to -9800' TD targeting Kuparuk C4 Sands.'¡ 6. Run and drop a 2-3/8"pre-drilled liner from TD of 9800', up to -7450' md. \ 7. Openhole sidetrack at 7450' from the IF-18A wellbore, above the 2-j/'ô" liner. ~ 8. Drill 3" horizontal sidetrack 1F-18AL1 from open-hole side track to -9800' TD targeting Kuparuk A4 ¡ sand interval. 9. Complete with 2 3/8" pre-drilled liner from the TD of ALl at 9800', up into the 3-112" liner to -7300'. 10. Post CTD; Run GL V s. Bring on production. ~ Mud Program: · Potassium-Formate based Flo-Pro (8.8 ppg) Disposal: · No annular injection on this well. · Class II liquids to KRU 1R Pad Class II disposal well · Class II drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · IF-18A: 2-3/8",4.6#, L-80, STL pre-drilled from 9800' md -7450' md · 1F-18ALl: 2-3/8",4.6#, L-80, STL pre-drilled from 9800' md - 7300' md Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for 1F-18A & ALl · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. ,¡ · Memory resistivity logs may be recorded if hole conditions warrant, MAD pass only. Kara 564-5667 office, 240-8047 cell 1/3 4tRU 1 F-18A & AL 1 Sidetrack - COile"Ubing Drilling Hazards . Several small (10-15') faults in the direction of the well path; lost circulation risk is low, especially while DOCTD. Reservoir pressure is estimated to be 10 ppg. WelllF-18 has a H2S reading of 21 ppm (measured 10/13/03). The highest H2S on IF pad was measured at 65 ppm. IF is classified as an H2S v pad. All H2S monitoring equipment will be operational. Reservoir Pressure / ./ . Reservoir pressure was measured at 3200 psi at 6165' TVD 10 ppg EMW on 8/19/2004. Max. surface pressure with gas (0.1 psi/ft) to surface is 2583 psi. ~. Dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high ./' reservoir pressure and high circulating pressures. Plans are to use 8.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2" rams, see attached BOP configuration), and/or the tested tubing retrievable sub-surface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. At least two times wellbore volume of kill weight fluid will be on location as a contingency. Measured reservoir pressure: 3200 psi at 6165' TVD, 10 ppg EMW. v' Expected annular friction losses while circulating (ECD): 700 psi Planned mud density: 8.8 ppg equates to 2825 psi hydrostatic bottom hole pressure. While circulating 8.8 ppg fluid, bottom hole circulating pressure is estimated to be 3525 psi, or 11 ppg EMW When circulation is stopped, a minimum of 700 psi surface pressure will be applied to maintain the reservoir at 11 ppg EMW. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling. Kara 564-5667 office, 240-8047 cell 2/3 ttRU 1 F-18A & AL 1 Sidetrack - COiJe'Ubing Drilling Kuparuk IF-18A & ALl Potential Drilling Hazards POST ON RIG 1. Please perform pre-job Hazard ill and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S - Well1F-18 has a H2S reading of 21 ppm (measured 10/13/03). The highest H2S on IF pad ./ was measured at 65 ppm. IF is classified as an H2S pad. All H2S monitoring equipment will be operational. H2S procedures must be followed according to the AK Safety Handbook and Shared Services Drilling H2S SOP. All personnel must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in H2S in the pit area. 3. Reservoir pressure - Reservoir pressure was measured at 3200 psi at 6165' TVD 10 ppg EMW on 8/19/2004. Max. surface pressure with gas (0.1 psi/ft) to surface is 2583 psi. Reservoir frac gradient is -0.7 psi/ft or 13.5 EMW, 4315 psi. 4. The Dynamically Overbalanced Coiled Tubing Drilling (DOCTD) technique will be used. Drilling will be done with a less than kill-weight fluid (8.8 ppg Flo-Pro). While drilling and circulating, hydrostatic head from the 8.8 ppg mud (2825 psi), plus 700 psi of annular friction, plus 0 psi choked backpressure held on the return side will provide a 3525 psi BlIP and overbalance the reservoir by -300 psi. However, when circulation is shut down, the reservoir could be underbalanced by 400 psi. Maintain at least 700psi WHP when not circulating to prevent reservoir in-flux and to maintain formation stability by keeping static BlIP close to circulating BHP seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole PWD sub. Increases will occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return-line flow rate and pit volume continuously. If a pit gain has been identified (underbalance event occurred), di vert those returns to an outside tank. 5. No gas saturated intervals are expected. However, always be prepared for the potential for gas influx. Ensure all PVT equipment is fully operational and monitor return-line flow rate and pit volume continuously. 6. Lost circulation is not expected. Several small faults will be encountered along the wellbore trajectory. The faults should not be sealing and lost circulation is considered low risk. If lost circulation occurs plan to control it with adjustments to the DOCTD parameters. Lower circulation rate would be utilized prior to LCM treatments. However, as a contingency ensure that LCM material is on location so that a pill could be mixed quickly if required. Kara 564-5667 office, 240-8047 cell 3/3 NIP (499-500, 00:3.500) TUBING (0-7000, 00:3.500, 10:2.992) Gas Lift MandreINalve 1 (2463-2464. Gas Lift MandrelNalve 2 (4343-4344 . Gas lift MandrelNalve 3 (5577-5578. Gas Lift MandrelNalve 4 (6303-6304, Gas Lift MandrelNalve 5 (6930-6931, NIP (6978-6979. 00:3.500) PBR (6986-6987, 00:3.500) PKR (6999-7000. 00:3.500) PROO. CASING (0-7208, 00:5.500, Wt:15.50) Perf (7585-7620) . ConocoPhmips Alaska, Inc. iF-iS Gas lift MandrelslValvas St MD TVD Man Man Type V Mfr V Type V OD latch Port TRO Mfr 1 2463 2385 eST AXT 2 4343 3794 BST AXT 3 5577 4689 eST AXT 4 6303 5249 eST AXT 5 6930 5732 eST AXT Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 499 499 NIP 6978 5768 NIP 6986 5774 PBR 6999 5784 PKR General Notes Date 1 Note 7122120011 Tag¡:¡ed obstruction @7551' SLM, appears to be something solid (metal). Lost jar action @7553' SLM 10/17/20011 VIDEO LOG SHOWED COLLAPSED LINER @7560' RKB API: 500292265400 SSSV Type: Nipple Annular Fluid: Reference Log: Last Tag: 6360' SLM Last Tag Date: 1/1/2004 CalinQ String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING LINER Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 7387·7402 6076 - 6088 7585 - 7620 6235 . 6265 KRU 1 f..18 Well Type: PROD Orig 3/811996 Completion: LastW/O: Angle@TS: 39 deg @ 7375 Angle@TD: 27 deg @ 7939 Rev Reason: Tag fill, recovered ROCKS Last Update: 31512004 I Ref Log Date: I TD: 7928ftKB I Max Hole Angle: 45 deg @ 4900 Size Top Bottom TVD Wt. Grade Thread 16.000 0 121 121 62.50 H40 7.625 0 4254 3730 29.70 L-80 5.500 0 7208 5940 15.50 L-80 3.500 7000 7928 7928 9.30 L-80 Bottom Grade Thread 7000 L-80 ABM-EUE Zone Status Ft SPF Date Type Comment C4 15 4 11/25/1999 APERF 21/8" Enerjet, 0 deg phase, Orient 0 deg from low side A4 35 4 6/30/1996 IPERF 180 deg Ph; 20 deg CCW Orient, 2.5" Hollow Case GLV GLV GLV GLV OV Date Run 1301 11129/2003 1331 11/29/2003 1320 11/2912003 1342 11129/2003 o 11129/2003 Vlv Cmnt 1.0 1.0 1.0 1.0 1.0 T-1 T-1 T-1 T·1 T-1 0.125 0.156 0.156 0.063 0.188 Description ID 2.813 2.750 3.000 3.000 Cameo'DS' Cameo'D' Nipple NO GO Baker Baker SABL-3 Liner Packer (Stabbed into 3 1/2" C$!".) . KRU 1 F-18A & 1 F-18AL 1 Producer Proposed CTD Sidetracks rLJ f 7-518" 29.7# L·BO i -\ casing @ 42S£..¡ J .. -~ ~ 3.5;~~:Jß @ :l- 5.5" 15.5# L80 @ 7208' MD - 2-3/8" liner top @ +1-7300' MD CIBP plug set +/-7450' MD Fill cleaned out to 7540' RKB ____ A4-Sand Liner collapsed @ 7560' 3.5" 9.3# L·80 @ 7928' MD .... . ConoØPÍ1illips Alaska, Inc. l G. Cameo DS Nipple at 499' MD, 2.813" ID F. 3-1/2" 9.3# L-80 tubing wI 3-1/2" x 1" BST 'AXT' mandrels I B. 3-¥.!" Cameo D nipple with 2.75" ID at 6978' MD (may be milled out to 2.80" for CTD bits) C. Baker 3-1/2' SABL-3 Liner packer at 6999' MD with PBR/seal assembly A. 3-1/2' tubing tail at 7000' MD (stung into 3-1/2" liner) Window in 3.5" 3" openhole Open hole KOP @ 7450' md off wfd alum kick off tool 1F-18A, TO @ 9800' md ,/ 000000000000) o 0 ~ o 000 0 0 0 0 0 0 oi 0000000' 2-3/8" pre-drilled liner Lateral (1F-18AL 1), TO @ 9800' md .¿ - ConocoPhiUips Alaska, WEJ.LP-ATH DETAtLS PhUt#21.F~lIA 500292265401 Pa".fJ~:!":::rM~ ~tJo~oo Rit: Nøßl'k- .2 R.f.Oatu.m;: 11<·18 RKØ 10a.otlfl: V.5oit(!tiOä MgI. n.oo· ~~ ~~:.: f::m~D WID 1M 1. '1':)00<1)0 40.21 13.75 2: 73$:$.00 3&.20 14.$$ $ 1-4is..OO 40,:17 HI.:34 4 7&UlOO 103.50 44.1'1- $ U",OO 1Ð4.0;1: $.» I> 180M» 1Ø4..2& ItJ.04 7 "1aO~ 9S,Ø& $.1.44- 3 $¡:J'l~;-øo &5.$1. 112.64- $' ð2Ø1LßO $(,#Ø 1'v.,28 10 &6ø.oo W:U8 79.37 11 87(11:I;00 -'67 ;ß?$ 1% ~øo _89 100.:51: U &201\.:00 .u..04 73.$0 14 ~OI) &&.In 1Ø-!>1 is $$(I(MNJ $,&,,;W 1'4.47 4¡w.7O' -.,. -.. ...... 811,00 7n-.7-o. ...... 10!HM:& 1H1'.ao i4$S;C7 ,...."" U!lJO.33 """'.. 2$77,8$ :mø5.H ObS T~. TMSilt 0.00 0,00 (Ø(J,oa 1.34 143.04 648.-t~ $.00 30.00 ðS2.U 35.00 $,6.00 i'S4.41 $..00 ee.oo 1104.03- 1.t.øo 81.00 .931'.42 12'.00 Utl.oo- iØž9".Y1 U.OO tUM)O H~ i:t.OO Hit.-oo i:J05.4S 1:t.OO 28$-.1>0 1-6711,01 i~OO %1&.46' 1'114.1"1'- 12.00 $0.00 ~,n 12.* .,.$0,00 2Ml"",) 12.-00 :I.W.$O 291\.76 12.00 27i,MID 2$49.10 Ti\RBfTDETNLS "''' 000 g'¡ =~: 3SO$,2$ 365a.5\J ....... 31@..'17 ....... _... 36241,:37 ::14134.7$ M$3.1& 3$&iA11 :uI03.1!J 35$5.4(f 3$85.44 ANNOTA'fiON$ IU Mþ AR~tÍ(ffl TIP KOP -.!.. mea I bøsm 35- 01.& · .nð 35 01.$1 hvm 12: 0Ui · 7 · · .. 11 .. " -H~_ TO 5700 'i CJ 5800- 1: CÞ 5900 > CÞ 6000 i! ... 6100 ~. LEGEND iF-iS (1F~i8) P!an#21F-18A Plan #2 T Plan: P1an #2 (1 F-18/P!an#2 1 F~ 18A) Created By: Brij Potnis Date: 8/25/2004 _n___,_"_~__,,,,___ Azimuths to True North Magnetic North: 24.5W Magnetic Fieid Strenth: 57566nT D~at~gJj'~!t~ó5; Model: bggm2004 Information 5400 2800 5200 5000 4800 4600 _400 r:: 14200 ~ 4000 ..... +3800 ...... .c: 1:: 3600 o ! 3400 .- ..:;.. .c: 3200 .. :::I o 3000 en 2600·~ 2400 2200 2000· -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 West(-)/East(+) [100ft/in] 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1900 2000 2100 2200 2300 2400 2600 2700 2800 2900 3000 Vertical Section at 87.00· [100ft/in] . . .!IE BP-GDB Baker Hughes INTEQ Planning Report INTRQ r Field: -K~paruk Riv~~Unít North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 U'.eoDatum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level --"-- ~~ Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre bggm2004 -l ~ ----I -~-~ Site: KRU 1 F Pad North Slope Site Position: From: Map Position Uncertainty: Ground Level: Northing: Easting: 5958733.30 ft 539521.50 ft Latitude: 70 17 Longitude: 149 40 North Reference: Grid Convergence: 53.527 N 47.811 W True 0.30 deg 0.00 ft 0.00 ft -~-- --~--"-_.--,- -~~.- _..-J 1;lwell: ---1~~~: - Well Position: +N/-.S +E/-W Position Uncertainty: ---_.~-~~ ~l Slot Name: 0.00 ft Northing: 0.00 ft Easting: 0.00 ft / 5958733.30 ft Latitude: 539521.50 ft v Longitude: 70 17 53.527 N 149 40 47.811 W ~--- -~~ -- ~ I I I I ----_.~._- Wellpath: Plan#21F-18A 500292265401 Current Datum: 1 F-18 RKB Magnetic Data: 8/25/2004 I Field Strength: 57566 nT ~VertiCal Section: Depth :rom (TVD) I 0.00 ____ +N/-S ft ~- 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1F-18 7300.00 ft Mean Sea Level 24.58 deg 80.73 deg Direction deg -- 87.00 ---~- Height 108.00 ft ------. ~~ Targets 1F-18A Polygon2.1 0.00 3697.31 533.00 5962433.00 540035.00 70 18 29.890 N 149 4032.266 W -Polygon 1 0.00 3697.31 533.00 5962433.00 540035.00 70 18 29.890 N 149 4032.266 W -Polygon 2 0.00 3823.62 1047.72 5962562.00 540549.00 70 1831.132 N 149 40 17.254 W -Polygon 3 0.00 3792.63 1425.60 5962533.00 540927.00 70 18 30.826 N 149 40 6.233 W -Polygon 4 0.00 3797.62 1997.69 5962541.00 541499.00 70 18 30.874 N 149 39 49.548 W -Polygon 5 0.00 3812.21 3216.91 5962562.00 542718.00 70 18 31.014 N 149 39 13.989 W -Polygon 6 0.00 3335.02 3243.40 5962085.00 542747.00 70 18 26.320 N 149 39 13.223 W -Polygon 7 0.00 3326.68 2547.28 5962073.00 542051.00 70 18 26.241 N 149 3933.524 W -Polygon 8 0.00 3339.09 1709.25 5962081.00 541213.00 70 18 26.365 N 149 39 57.964 W -Polygon 9 0.00 3470.80 1004.86 5962209.00 540508.00 70 18 27.662 N 149 40 18.506 W -Polygon 10 0.00 3588.95 599.44 5962325.00 540102.00 70 1828.824 N 149 4030.329 W 1F-18A Fault 1 0.00 3823.62 1047.72 5962562.00 540549.00 70 1831.132N 149 40 17.254 W -Polygon 1 0.00 3823.62 1047.72 5962562.00 540549.00 70 1831.132N 149 40 17.254 W -Polygon 2 0.00 3664.72 1024.89 5962403.00 540527.00 70 18 29.569 N 149 40 17.921 W -Polygon 3 0.00 3470.80 1004.86 5962209.00 540508.00 70 18 27.662 N 149 40 18.506 W -Polygon 4 0.00 3664.72 1024.89 5962403.00 540527.00 70 18 29.569 N 149 40 17.921 W 1F-18AFault2 0.00 3792.63 1425.60 5962533.00 540927.00 70 18 30.826 N 149 40 6.233 W -Polygon 1 0.00 3792.63 1425.60 5962533.00 540927.00 70 18 30.826 N 149 40 6.233 W -Polygon 2 0.00 3622.21 1501.72 5962363.00 541004.00 70 1829.150 N 149 40 4.015 W -Polygon 3 0.00 3339.09 1709.25 5962081.00 541213.00 70 1826.365 N 149 39 57.964 W -Polygon 4 0.00 3622.21 1501.72 5962363,00 541004.00 70 18 29.150 N 149 40 4.015 W 1F-18A Fault 3 0.00 3797.62 1997.69 5962541.00 541499.00 70 18 30.874 N 149 3949.548 W -Polygon 1 0.00 3797.62 1997.69 5962541.00 541499.00 70 18 30.874 N 149 39 49.548 W -Polygon 2 0.00 3587.88 2323.63 5962333.00 541826.00 70 18 28.811 N 149 39 40.044 W -Polygon 3 0.00 3326.68 2547.28 5962073.00 542051.00 70 18 26.241 N 149 39 33.524 W -Polygon 4 0.00 3587.88 2323.63 5962333.00 541826.00 70 1828.811 N 149 39 40.044 W --_.~---~- -- . . BP-GDB Baker Hughes INTEQ Planning Report .,a: INTB.Q Annotation 7300.00 7395.00 7415.00 7608.00 7668.00 7803.00 7903.00 8078.00 8208.00 8608.00 8708.00 8983.00 9208.00 9508.00 9800.00 5901.39 5974.48 5989.80 6047.17 6032.74 5999.50 5982.15 5964.67 5958.00 5968.91 5972.82 5978.85 5983.07 5988.41 5993.10 TIP KOP end 9 DLS I begin 35 DLS 4 end 35 DLS I begin 12 DLS 6 7 8 9 10 11 12 13 14 TO ,----------- .-.--- I Plan: Plan #2 Identical to lamar's Plan #2 Principal: Yes ----- ~-,~~~-- Plan Section Information I I I -~ ----~, Date Composed: Version: Tied-to: 8/25/2004 1 From: Definitive Path 0.00 1.34 9.00 35.00 35.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 0.00 0.00 1.27 143.04 6.89 30.00 14.70 30.00 36.04 86.00 12.38 87.00 8.50 135.00 12.06 89.00 11.26 110.00 -11.98 265.60 -11.87 278.40 12.00 90.00 -12.00 -90.00 12.00 90.30 -12.00 270.00 7300.00 40.21 13.75 5901.39 7395.00 39.20 14.96 5974.48 7415.00 40.77 16.34 5989.80 7608.00 103.50 44.71 6047.17 7668.00 104.02 66.33 6032.74 7803.00 104.29 83.04 5999.50 7903.00 95.68 91.54 5982.15 8078.00 95.66 112.64 5964.67 8208.00 90.20 127.28 5958.00 8608.00 86.86 79.37 5968.91 8708.00 88.67 67.50 5972.82 I 8983.00 88.89 100.51 5978.85 9208.00 89.01 73.50 5983.07 L9.508.00 89.02 109.51 5988.41 9800.00 89.20 74.47 5993.10 ----~-~- Survey 3438.11 3496.91 3509.28 3653.55 3686.33 3720.77 3725.32 3689.05 3624.37 3534.75 3563.19 3591.51 3603.16 3595.40 3585.44 450.70 465.74 469.21 564.23 611.95 737.70 835.89 1005.19 1117.30 1495.07 1590.67 1860.33 2082.91 2377.85 2665.11 0.00 -1.06 7.84 32.50 0.87 0.20 -8.61 -0.01 -4.20 -0.83 1.81 0.08 0.05 0.00 0.06 ~~-~-- I I I I I ___--1 7400.00 7415.00 7425.00 7450.00 7475.00 7500.00 7525.00 7550.00 7575.00 7600.00 39.59 40.77 43.83 51.67 59.71 67.86 76.07 84.33 92.60 100.86 7608.00 103.50 7625.00 103.84 15.31 16.34 18.86 24.11 28.32 31.88 35.04 37.99 40.85 43.76 5978.34 5989.80 5997.20 6014.00 6028.09 6039.13 6046.86 6051.11 6051.78 6048.86 3499.97 3509.28 3515.69 3532.87 3551.36 3570.73 3590.53 3610.31 3629.59 3647.94 44.71 6047.17 3653.55 50.83 6043.15 3664.64 466.57 469.21 471.25 478.07 487.21 498.47 511.57 526.22 542.08 558.77 5962235.33 5962244.66 5962251.08 5962268.29 5962286.82 5962306.25 5962326.12 5962345.97 5962365.34 5962383.77 649.11 652.23 654.60 662.31 672.41 539969.62 539972.21 539974.21 539980.94 539989.98 540001.14 540014.14 540028.68 540044.43 540061.03 684.66 698.79 714.45 731.30 748.92 754.67 35.00 767.45 35.00 564.23 5962389.40 540066.45 576.45 5962400.56 540078.61 ~--~- 9.00 9.00 35.00 35.00 35.00 35.00 35.00 35.00 35.00 35.00 TIP MWD MWD MWD KOP 30.00 29.73 30.00 28.13 24.59 22.22 20.64 19.66 19.15 19.08 , MWD i end 9 DLI MWD I MWD MWD I MWD MWD MWD MWD MWD 19.42 4 86.00 MWD . . BP-GDB Baker Hughes INTEQ Planning Report .£ iNTRQ Survey 7650.00 104.06 7668.00 104.02 7675.00 104.06 I I I I I I I i I I I I I I I I I I I 8600.00 86.92 80.33 5968.47 3533.34 1487.20 5962274.07 540989.95 1670.08 12.00 266.70 MWD I 8608.00 86.86 79.37 5968.91 3534.75 1495.07 5962275.52 540997.81 1678.01 12.00 266.85 10 I 8625.00 87.16 77.35 5969.79 3538.17 1511.69 5962279.03 541014.42 1694.79 12.00 278.40 MWD I 8650.00 87.61 74.38 5970.93 3544.27 1535.91 5962285.25 541038.60 1719.29 12.00 278.51 MWD I 8675.00 88.06 71.42 5971.88 3551.62 1559.78 5962292.72 541062.43 1743.52 12.00 278.64 MWD I 8700.00 88.52 68.45 5972.62 3560.19 1583.25 5962301.42 541085.85 1767.41 12.00 278.75 MWD ¡ I 8708.00 88.67 67.50 5972.82 3563.19 1590.67 5962304.46 541093.25 1774.97 12.00 278.84 11U' I 8725.00 88.67 69.54 5973.21 3569.41 1606.48 5962310.76 541109.03 1791.08 12.00 90.00 MWD 8750.00 88.68 72.54 5973.79 3577.53 1630.11 5962319.00 541132.62 1815.11 12.00 89.95 MWD l~775.0~~.as._ 75.54~4.3~_3584.~~~54~~._~~~~26.~~156.62.._1839.47~~!.2.0~~9~""'-\~/D 7700.00 7725.00 7750.00 7775.00 7800.00 7803.00 7825.00 7850.00 7875.00 7900.00 7903.00 7925.00 7950.00 7975.00 8000.00 8025.00 8050.00 8075.00 8078.00 8100.00 8125.00 8150.00 8175.00 8200.00 8208.00 8225.00 8250.00 8275.00 8300.00 8325.00 8350.00 8375.00 8400.00 8425.00 8450.00 8475.00 8500.00 8525.00 8550.00 8575.00 104.19 1 04.27 104.32 104.33 104.29 104.29 102.41 100.27 98.11 95.94 95.68 95.72 95.75 95.76 95.76 95.75 95.71 95.66 95.66 94.75 93.71 92.66 91.60 90.54 90.20 90.04 89.81 89.58 89.35 89.12 88.90 88.68 88.46 88.25 88.04 87.83 87.64 87.45 87.26 87.08 59.84 66.33 67.20 70.29 73.38 76.48 79.58 82.67 83.04 84.95 87.09 89.20 91.29 91.54 94.19 97.21 100.22 103.24 106.25 109.27 112.28 112.64 115.13 117.95 120.77 123.58 126.38 127.28 125.25 122.26 119.27 116.27 113.28 110.29 107.30 104.30 101.31 98.32 95.32 92.33 89.33 86.33 83.33 6037.11 6032.74 6031.04 6024.94 6018.79 6012.61 6006.43 6000.24 5999.50 5994.42 5989.51 5985.51 5982.46 5982.15 5979.97 5977.47 5974.96 5972.45 5969.95 5967.45 5964.97 5964.67 5962.68 5960.84 5959.45 5958.52 5958.05 5958.00 5957.97 5958.00 5958.13 5958.37 5958.70 5959.13 5959.66 5960.28 5961.00 5961.81 5962.71 5963.70 5964.77 5965.93 5967.16 3678.43 3686.33 3689.00 3697.79 3705.34 3711.64 3716.67 3720.40 3720.77 3723.00 3724.70 3725.50 3725.39 3725.32 3724.22 3721.75 3717.98 3712.93 3706.60 3699.01 3690.19 3689.05 3680.18 3669.04 3656.80 3643.50 3629.17 3624.37 3614.32 3600.43 3587.65 3576.00 3565.52 3556.25 3548.20 3541.39 3535.85 3531.60 3528.63 3526.96 3526.60 3527.55 3529.80 596.38 611.95 618.18 640.77 663.80 687.19 710.88 734.81 737.70 758.98 783.43 808.09 832.90 835.89 857.75 882.50 907.08 931.43 955.48 979.17 1002.43 1005.19 1025.22 1047.52 1069.27 1090.42 1110.89 1117.30 1131.00 1151.79 1173.27 1195.38 1218.08 1241.29 1264.95 1288.99 1313.36 1337.97 1362.78 1387.70 1412.67 1437.62 1462.49 5962414.45 5962422.43 5962425.14 5962434.05 5962441.72 5962448.14 5962453.29 5962457.15 5962457.53 5962459.88 5962461.70 5962462.63 5962462.65 5962462.59 5962461.61 5962459.27 5962455.64 5962450.71 5962444.51 5962437.05 5962428.35 5962427.22 5962418.46 5962407.43 5962395.31 5962382.12 5962367.90 5962363.14 5962353.16 5962339.38 5962326.71 5962315.19 5962304.83 5962295.68 5962287.75 5962281.07 5962275.66 5962271.54 5962268.70 5962267.17 5962266.94 5962268.01 5962270.39 540098.47 540113.99 540120.21 540142.76 540165.74 540189.09 540212.75 540236.66 540239.55 540260.82 540285.26 540309.91 540334.72 540337.71 540359.57 540384.33 540408.93 540433.30 540457.39 540481.11 540504.41 540507.18 540527.25 540549.61 540571.42 540592.63 540613.19 540619.62 540633.37 540654.23 540675.77 540697.95 540720.69 540743.95 540767.65 540791.72 540816.12 540840.75 540865.57 540890.50 540915.47 540940.41 540965.26 788.08 804.03 810.40 833.42 856.81 880.50 904.42 928.51 931.42 952.79 977.29 1001.96 1026.73 1029.71 1051.48 1076.07 110D.42 1124.48 1148.16 1171.42 1194.18 1196.88 1216.42 1238.11 1259.19 1279.61 1299.31 1305.45 1318.61 1338.64 1359.42 1380.90 1403.01 1425.71 1448.91 1472.57 1496.61 1520.97 1545.59 1570.39 1595.30 1620.27 1645.22 35.00 35.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 91.02 135.00 135.44 135.86 136.20 136.45 89.00 89.26 89.56 89.87 90.17 90.47 90.77 91.07 110.00 110.23 110.43 110.59 110.69 110.75 265.60 265.60 265.60 265.62 265.64 265.68 265.74 265.80 265.87 265.96 266.06 266.16 266.28 266.41 266.55 87.45 MWD 89.62 end 35 D 87.00 MWD 87.21 87.96 88.72 89.49 90.26 MWD MWD MWD MWD MWD 6 MWD MWD MWD MWD 7 MWD MWD MWD MWD MWD MWD MWD 8 MWD MWD MWD MWD MWD 9 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD . BP-GDB Baker Hughes INTEQ Planning Report . ..E INTEQ Survey 8800.00 88.70 78.54 5974.94 3590.01 1678.49 5962331.73 541180.93 1864.08 12.00 89.81 MWD 8825.00 88.71 81.54 5975.50 3594.33 1703.11 5962336.18 541205.52 1888.89 12.00 89.75 MWD 8850.00 88.73 84.54 5976.06 3597.35 1727.92 5962339.34 541230.31 1913.82 12.00 89.68 MWD 8875.00 88.75 87.55 5976.61 3599.08 1752.85 5962341.19 541255.22 1938.81 12.00 89.61 MWD 8900.00 88.78 90.55 5977.15 3599.49 1777.83 5962341.74 541280.21 1963.78 12.00 89.54 MWD 8925.00 88.81 93.55 5977.68 3598.60 1802.81 5962340.98 541305.19 1988.68 12.00 89.48 MWD 8950.00 88.84 96.55 5978.19 3596.40 1827.71 5962338.91 541330.09 2013.42 12.00 89.42 MWD 8975.00 88.87 99.55 5978.69 3592.90 1852.45 5962335.54 541354.85 2037.95 12.00 89.35 MWD 8983.00 88.89 100.51 5978.85 3591.51 1860.33 5962334.19 541362.74 2045.75 12.00 89.29 12 9000.00 88.89 98.47 5979.18 3588.71 1877.09 5962331.48 541379.51 2062.34 12.00 270.00 MWD 9025.00 88.89 95.47 5979.66 3585.68 1901.90 5962328.58 541404.33 2086.95 12.00 270.04 MWD 9050.00 88.90 92.47 5980.15 3583.95 1926.83 5962326.98 541429.27 2111.76 12.00 270.10 MWD 9075.00 88.91 89.47 5980.63 3583.53 1951.82 5962326.69 541454.26 2136.69 12.00 270.16 MWD 9100.00 88.92 86.47 5981.10 3584.41 1976.80 5962327.71 541479.23 2161.68 12.00 270.21 MWD 9125.00 88.93 83.47 5981.57 3586.61 2001.69 5962330.03 541504.11 2186.66 12.00 270.27 MWD 9150.00 88.95 80.46 5982.03 3590.10 2026.44 5962333.66 541528.84 2211.56 12.00 270.33 MWD 9175.00 88.97 77.46 5982.48 3594.89 2050.97 5962338.57 541553.34 2236.30 12.00 270.38 MWD 9200.00 89.00 74.46 5982.93 3600.95 2075.22 5962344.76 541577.55 2260.83 12.00 270.44 MWD 9208.00 89.01 73.50 5983.07 3603.16 2082.91 5962347.00 541585.23 2268.63 12.00 270.49 13 9225.00 89.00 75.54 5983.36 3607.69 2099.29 5962351.62 541601.58 2285.22 12.00 90.30 MWD I I 9250.00 88.98 78.54 5983.80 3613.29 2123.64 5962357.36 541625.91 2309.84 12.00 90.26 MWD I 9275.00 88.97 81.54 5984.25 3617.61 2148.26 5962361.81 541650.50 2334.65 12.00 90.21 MWD I 9300.00 88.97 84.54 5984.70 3620.64 2173.07 5962364.96 541675.29 2359.58 12.00 90.16 MWD I 9325.00 88.96 87.54 5985.15 3622.37 2198.00 5962366.82 541700.21 2384.57 12.00 90.10 MWD 9350.00 88.96 90.55 5985.60 3622.78 2222.99 5962367.37 541725.19 2409.55 12.00 90.05 MWD I 9375.00 88.96 93.55 5986.05 3621.89 2247.97 5962366.60 541750.17 2434.45 12.00 90.00 MWD i I 9400.00 88.97 96.55 5986.50 3619.69 2272.87 5962364.54 541775.08 2459.19 12.00 89.94 MWD I 9425.00 88.98 99.55 5986.95 3616.19 2297.61 5962361.17 541799.84 2483.72 12.00 89.89 MWD I 9450.00 88.99 102.55 5987.40 3611.40 2322.14 5962356.51 541824.39 2507.97 12.00 89.83 MWD 9475.00 89.00 105.55 5987.84 3605.34 2346.39 5962350.57 541848.67 2531.86 12.00 89.78 MWD I I I 9500.00 89.01 108.55 5988.27 3598.01 2370.29 5962343.37 541872.60 2555.34 12.00 89.73 MWD I 9508.00 89.02 109.51 5988.41 3595.40 2377.85 5962340.80 541880.18 2562.76 12.00 89.68 14 I 9525.00 89.02 107.47 5988.70 3590.01 2393.97 5962335.50 541896.32 2578.57 12.00 270.00 MWD 9550.00 89.02 104.47 5989.13 3583.14 2418.00 5962328.75 541920.38 2602.21 12.00 270.03 MWD I 9575.00 89.03 101.47 5989.55 3577.53 2442.35 5962323.27 541944.76 2626.24 12.00 270.09 MWD I 9600.00 89.04 98.47 5989.97 3573.20 2466.97 5962319.07 541969.40 2650.59 12.00 270.14 MWD ! 9625.00 89.05 95.47 5990.39 3570.17 2491.78 5962316.17 541994.22 2675.21 12.00 270.19 MWD I 9650.00 89.06 92.47 5990.80 3568.44 2516.71 5962314.57 542019.16 2700.02 12.00 270.24 MWD I 9675.00 89.08 89.47 5991.21 3568.02 2541.70 5962314.28 542044.15 2724.95 12.00 270.29 MWD \ 9700.00 89.10 86.47 5991.60 3568.91 2566.68 5962315.30 542069.12 2749.94 12.00 270.34 MWD I 9725.00 89.12 83.47 5991.99 3571.10 2591.58 5962317.63 542094,01 2774.92 12.00 270.38 M~__I 9750.00 89.14 80.47 5992.37 3574.59 2616.33 5962321.25 542118.74 2799.82 12.00 270.43 MWD 9775.00 89.17 77.47 5992.74 3579.38 2640.86 5962326.16 542143.24 2824.57 12.00 270.48 MWD 9800.00 89.20 74.47 5993.10 3585.44 2665.11 5962332.35 542167.45 2849.10 12.00 270.52 TD _._---~-~~~- Well I, ""'" Tree Size I, I, BOP~Tree Rig Floor · · · · I I · ) I, I I IL- I I · . Page 1 From: Sent: To: Subject: Dan, . . Venhaus, Dan E [Dan.E.Venhaus@conocophillips.com] Friday, June 18, 2004 9:36 AM Kara, Danny T Permit authorization This is the standard verbage that we have forwarded to AOGCC in the past authorizing permit delivery to BP: The Kuparuk CTD program starting up in August 2004 consists of 5 wells. The proposed wells are 1C-08A, 1Y-24A, 1D-30A, 1F-18A, #5 TBD and will be drilled with BP's Nordic 2 CTD unit and managed through BP's CT drilling organization. BP's CT drilling services are being provided to the operator, ConocoPhillips, via a Shared Service operation. As such, ConocoPhillips authorizes the delivery of these permits to BP (Terrie Hubble). ConocoPhillips does request that BP provide a copy of the approved permits for COP's files (Sharon Allsup-Drake). If you need anything else, let me know. Dan Venhaus ConocoPhillips AK Wells (907)263-4372 office (907)230-0188 cell KRU 1 F..18A & 1 F..18AL 1 2041670 & 2041680 SFD 9!~~QQ14 17 TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 140 "Mastercard Check" . DATE 08 ~:¿7-Ot¡ ~.ET~FHE~~ ~. ~ ~¿;n~ ,_$__(~~~~__~~_ ~ - 9!O~~ti>,1l ~ DOLLARS First Nationa Bank Alaska Anchorage, AK 99501 ..,¿ . ~ LI ¡J ¿{'/_ MEMO I ç. 18 A- / ¡:;MI.( OJ ·w XJU1-Z 1:.2520001;01:1111 ......11; 2 27..1.551;11- 0....0 . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER V" WELL NAME kRtÆ /r ~/J?/l PTD# Lot! ~ / &, 7 Development Service Exploration Stratigraphic ADD-ONS (OPTIONS) MULTI LATERAL ~'CLUEn CHECK WBA T APPLIES .// (If API number last two (2) digits are between 60-69) The permit is for a new wellbore segment of existing wen' . Permit No, ,. API No. Production, should continue to be reported as a function' of the original API number, stated above. PILOT (PH) HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for tbe pilot hole must be dearly differentiated In both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for we1l (name on permit). SPACING EXCEPTION Tbe permit is approved subject ·to fun compliance with 20 AAC 25.,055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order. app~~~.a spacing· exception. f'r11~w/f~5 (Company Name) assumes tbe liability of liny protest ttfff;e spa. cin g . e~.cePtiP" tba?;l. occur. ~. 4..:1-f4.C', ~. ___ Þ-> ~" All dry ditcb sampl / sets s~ to tbe Commission must be in no greater ,tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample hiter-vals tbrougb target zones. .4-~. liD 17.01 DRY DITCH SAMPLE . . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips Alaska, Inc. assumes the liability of any protest to the spacing exception that may occur. :~~I:L..~E;f:tMIT.Ç~,~~~L~~-'::, Field & Pool__~~!:~_~UK~~~~~~_~~~~_~_R.~_C?I_~~~~~~__n.._._____.._.__.._.____~_.__..___________. Well Name: KUeABU~J=_~I.\lJJ.NIIJE:.t88_______..._____.Program JJEy____..n.____ Well bore seg PTD#: 2041670 Company _Çº-~º_C_Q_P.J::IJLlle.8.)~LA$K8JN.G.__.___.__._.._... .... ___.___ ____ Initial Classrrype _Q~Y_LI?_El~tD_ GeoArea lt9_Q__ Unit JjjJtQ____.______ On/Off Shore .on Annular Disposal Administration 1 p~(n)it.fee attact)e.d _ . . _ _ _ _ _ _ . y~s - _ - - - - . . - . - - - . . 2 .Leas~_nurnber _apRropriat~_ _ . . Y~s . . . - - - - 3 .U.nlqlle well. n_arn~ .and oumb.er _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ - . _ _ - _ - - - - - - . - - - - y~~ - - - - - - . . . . - . - . - - - - - - - - - . - . . -- . - . - - - - - -- . - . . . . . - - - - . - - - - - - - . . . . - - - - - - - - . . - . . . . 4 W~II JQcat~d in.a. define.dpool_ _ . _ _ _ _ _ _ . _ _ _ . _ _ _ y~s . _ _ KUPARUK RIYER, KUPARUKRV 011..:- 490_1 OQ _ . 5 _WelUQcated proper _distance_ from drilling unitb_oundary. Yes - _ - - . - - - - - - - . . - - . - - - - - - - . - . . . - - - - . 6 .W~II JQcat~d pr_oper _d i_stan ce_ from Qtb~r w~l!s_ _ _ _ . . . . _ _ _ _ _ _ Yes. _ SPACING .EXCEPTION HE.o.UJREP _ _ _ 7 _S.ufficient.acr~age_aYail~blein_dJilJiOgunit.... _ _ _ _ _ _ _ _.. _ _ _ _ _ _ N.c_ _ _ _ _. _ .W~llwillbeth~2odVYell_opentp.the.p.coUntheNVV/4of.S..H,TI1N,R10E_ _. - - - -.- 8 Jf.d.eviated, .is_ weJlbQre plaUncJu.ded . _ _ . . Yes - - - - - - - . . - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - . - . - - - - - - - - - - - 9 _Oper.ator onl~ affect~d party. _ . . . _ _ _ _ . _ . . _ . y~s - _ - - - - . . . . - - - - - - - - - - . . . - - . . - - - . . . . . 1 0 _Op~rator bas_apprppriate. b.ond lnJQrç~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ __ _ _ _ _ _ _ . . _ _ _ Ye$ - . . -- - - . . - . - - - - -- . - -- - - - - . - - - . - - - - . . - - - - . -- . . - . - - - - - -- - - - - - - - . - . - . - . - - - - - . . - - . - - 11 Permit c.an be lssued wjtbQut co.nserva.tion order _ . . . _ _ _ . _ _ _ _ _ _ _ _ . No _ _ _ . _ - - - - - - - - - . . - . - - - - - - - - - - . . - . - - - - . - . - - - . . . - - - - - 12 P~rmitcanbeissuedw.itbQutadminist(ative_approvaJ. Yes_ _ _ _ _ _ _ _ -. _ _ -... _ _ _ _ _ - _ - _ - -. - - . - - - - - - -. - -- 9/3/2004 13 Can permit be approved before 15-day wait Yes 14W~IUQcated within area and_strata .authorized by_lojectiolJ Ord~( # (pullO# in_c_oOlm_entsHFor_ NA. _ _ _ . _ - - - . - . . - . . - - - . - - - - - - - . . . - - - - . -. - .. - - - - . - . . 15 _AJlw~IJs_witni.n.1t4_rTJite_ar~a_ofreyi~wid~lJt[fi~d(Fpr~ervjc_ewetlOl1ly). _ _ _ _.. _ _ _ _ _. _. NA_ __ _ _ _ _ _. _. _. _ _. _ _ _. _. _.. - _ - -. - __ - - - - - - -. - -... - - - - -... - - - - - -- - - -.. - - - - - -. - - - -- -- 16 PJ~-prpduçed i[1j~ctor; .duratio.n_of pr~-pro.ductiolJ I~s~ than 3 montbs. (For_s~r:.vice well QnJy) _ _ .NA _ . . . _ . . . _ _ - - - . - - - - . - . . . - - - - - - - - - . . - - - . . - . . . - - - - - - - - - - . . - - - - - - - - - 17 .AGMP.F.inding.ofCQn.si.$t~[1cy-h.asbee-nJ~sued.for.tbispr-oleçt... ... _ _ _..... _ _ _ _NA... _ _ _ _... _ .. - - - -.. -. - - - - - -" - - - -. - - - - - -.. -. -.... -. Appr SFD Date Engineering Appr Date TEM 9/7/2004 ~~(ì -----,.~..._------,._---- Geology Appr SFD Date 9/3/2004 Geologic Commissioner: bf,S [] o - - - - - - - - - - - - - - - - ----_.~-_..- ----------- ----.------.--.------- -------.--.-- - -..-------..---.--.----------,-- 18 .C_o(1du.ctor $tring.PJQv¡d~d _ _ . . . _ .. _ . . . . . _ _ _ _ . . _ . . _ _ . . _ . . .. . _ _ _ _ . _ . _ _ . NA. _ . _ _ . _ _ CQn.ductQr .s~tio origin-al w~lI. 1.F-t8,. . _ _ _ . _ _ . - - . . . - - . - - - - - - - - - - - - - - - - - - - - 19 _S_udac~ _casing pJQtec.ts alLknown USDWs _ _ _ _ _ _ . .. . _ _ _ . _ . _ _ _ _ _ _ _ _ .. . . _ _ _ _ _ NA_ _ _ _ _ _ _ _ All aq_uif~rs. exeIJlPted,A~LC.FR H7J Q2.(b)(3). - -- - - - - - - . .. - - - - . - - . - . - . . 20 .CMT.v_otad~qu.ate.toçirc_utate.o_n.cpnd_uçtor.&$u_rf_c_sg _. _ _ _ _ _. _ _ _. _ _ _ _ _ _ _... _ _ NA. _ _ _ _. _ _Surtaçeca.stng~etjn.Qriginalwell.. - - - _ -. - - -. -. - -.. -. - - - - - - - - - - - -.. 21 .CMT. v.ot ad~qu.ate.to tie-tnJQng .string to_s!..lIf çsg- _ _ . . _ _ . _ . _ _ _ _ . _ . _ . _ NA . _ _ _ _ . __ Prpdu.ctiQn.casiog se.ti.n_oJigiOal w~11.. - - - - - - - - - - - - - - - - - - - . - - - . - . - - - - - - - - - - - - . - - - - - - 22 _CMT.willcoyer_allklJown.pro_duçtiYehQri~Qn_s.. _ _ _.. _ _ _... _ _ _ _ _ _ _ _... _ _... _ No_ _ _. _ _. _Slptte.dJilJer_colTlpleti.onptalJlled.. Origioalpr9ductiQn-Ga~iogçe.mentabpv~aILhYdrpçaJb.ons.- -. 23 _C_asiog d~sig[1s adequa..t~ fpr C,.T., ß .&. perrTJa.fr_ost .. _ - . - - . . - . - - - . - - - - . .. - - . . y~s - - - - - . . - - - . - - - - - - . - - . - - .. .. - - - - - - . - - - . . - .. - . - - - - - - - - . . - . . . . 24 .A.dequ~t.eJan.kage-or re_serye pit _ _ _ . ._ _. . . _ . _ .. _ _ . . . . . . _ _ . _ .. _ . . . _ . . .Y~s _ _ _ _ _ _ _ Rig jSßquippe_d.with .steeLpits. _ No. r~$e_rve_pjt.planoe_d, All wa~te toJ~las.s JlweU(st . . . _ __ - . - . . . . 25 Jf.a_re-.drill.. has_a_ 1.0:-40;3 for ~bandon_me_nt be~1J aRPrQv~d _ _ _ . _ _ _ _ _ _ .. _ _ _ _ _ _ . .. _ .. _ .Y~s _ _ _ _ _ _ . 30A:-3.31 - - - . - . . - - . .. . - - - - - - - .. . . - - - . . . - - - - - - . - . . - . .. - - - . - . - .. 26 _Aøequ~te.we[lbor~ ~epªratio-".proposeø _ _ _ _ __ _ _ . _ .. _ _ _ _ . . . __ .. _ _ . _ .. .. _ _ _ _ .. . . . yes _ _ _ _ _ . . $içjetraçk in r~s~r:.voir. . Ne.are.st weJI Qo.re i..s _aÞan.done.d _s~çti91J of.1f:1.8._ _ _ _ _ _ _ .. . . . . . _ _ _ _ _ _ _ . .. _ .. _ .. 27 Jf.djv~r:ter req_uiJ~d, dQe.s it me~t reguJa.tipns. . _ . . . _ _ _ . . _ . _ . . . _ . _ _ _ _ _ . _ _ _ _ _ _ NA. _ _ _ _ _ _ _ BOP wiJl Þe in_ pJa_c~._ - . - - - - . - - - - - . - . - . . . - . . . . - . . .. . - . - - 28 _DJilJiOg fluid_ pJogJa.m schematjc.& equip Jist.adequate. _ _ . . . _ _ . _ _ . _ _ _ _ _ _ _ _ . . .. Y~s. _ _ . _ . _ Exp~cted BH~ 1 Q.Q EMW.. .Dyoamic ov.erb.ala['lce.tec.hniçu~ planned with. MW.of 8.8 ppg an_d _appli~d bac.k~pre_ssur 29 .BOPEs,_d9 .they me~t r~guJa.tipl) . . _ _ _ _ . . _ _ _ _ _ _ . . _ . . _ . _ _ _ _ _ _ _ _ _ . . . _ _ .Y~s .. - . - - . . . . . - - - . . - . - . .. - . .. . - - - - - - - - - - . . - . - .. . - . - .. - . - - - - .. . - - - - - 30 __BOPE.pr~s$ra.tilJgappropriate;.testto-(pu-tp$igin-comm~nt$)_ _ _ _. _ _ _ _. _ _. _ _ _ _ _ _ _ Ye~_ _ _ _.. _ÇalçuJa.t~d.s.ta.ticMASP_25a3_p_s¡..Galc.ul~teçldyn_ar:njc.MA8.PJO.opsi, 35o.O_p.si.p.lanned.aQ~te~t _ -_ 31 _C.hoke_rTJanifold çQmpJie~ VY/AP'-R~-5~ (May 64).. _ _ _ . . . _ _ . . .. _ . . _ . _ _ . . . . _ . . . _Y~s _ _ . _ _ _ - - . . . .. . . - . - . .. - - . . . - .- . . - - - - -- - - .. . -. - - - - - - . - . - - . . - - - - . - - - - - - - - . - 32 _Wo.rk will OÇCU( vyithOyt.operation.sbutdo.wn. . _ . _ _ _ _ _. ... _ _ _ . . . _ _ _ _ _ . _ . .Y~s - . . . . - - - - - - - - - - .. - - - - - . - - - - - - - - - .. . - - - . .. - - -- .. - - - - - . . . . - - - - . - . - - - - - - - 33 JS.Rre~ence_o.fH2Sgas-prob.abl~-. _.. _ _ _ _ _ _ _ _ _ _ _ _ _.... _ _ _ _ _ _ _ _... _.... Y~s_ _.. _ _ .1F.padJsde_siglJated-as.anH2Spad.-Mud-s-houldpreclud.e.H2S..onrig.-Rig.has.senSQrsand-aJarms.. - -' 34 Meçba.ni.cal.colJdJtlon p{ w~lIs wlthin AOR yerified (For. s_erv.ice w~1J only) _ . .. . . _ _ . . _ _ . . NA. _ _ _ . - . . . - . . . . - . . .. . . - - - . - - -- - . . . - - - . . . - .. - - . - . - . - - -. . . . - . . { ___._.__M'_.__.___._...._________ ---.----. 35 P~rmitca(1 be tssued w!o_ hyd(ogen-s-ulfide meas_ure.s. _ _ _ . . . . _ . _ _ _ _ . _. _ . _ _ _ . . . No_ _ _ _ . _ _ . KRU :11:-:1 a m~aswed21 ppro H2$ OIJ 10./13/2.0.03.. SfD . - - . . .. - - - - - - - . - . - . . . - .. 36 _D_ata.PJes~lJted Qn pote_ntial pvemre~sur~ _zone.s.. . _ . . _ _ _ .. _ _ __ . . .. . _ _ _ _ . . . Y~$ _ . . _ _ . _ ¡;:xp~cted r~$~rvoir .pre.$~wre i.$.1 0 PPG .EMW;.will be.dJilJe_d.dYlJamiçally Ov~rbpl~lJc.eÇ witb Cpil.ed Tubing... 37 _S~i.$mic.analysJs. o.f .sba..llow gas.zolJes- . . . . . _ _ . _ . . . . _ . _ . _ _ _ _ _ . .. . _ _ . .NA. - . - - - - . - . - . . - - . . - - . . . - . . - . - . - - - - - - - - - - - - - - - - - - . -. - - . - - - ... - - - .. - - - . 38 .S~abed .cPr]djtioo survey _(if off-shore) _ _ _ _ _ _ _ _ _ _ _ . . . . . _ _ . _ _ _ _ . _ . _ _.. _ NA . - - - - . . - - . . .. . - - - - - - - . . - . - . - . . . - . - - - . - . - - - - . . . . - - . 39 . GQnta.ct. nametp.honeJQr-'^le~kly pr9gr~~s.reports [eXRIQratory .only]. . ._ _ _ _ .. __ _ . . _NA _ _ _ . . . _. . _ . - - . .- . - . . . . . . . - . . . -- - - - - . . . - . - - - - . . - - . . . . . . - - - . . . - - . - .. - - - - - . - - Date: Engineering Commissioner: 'SIner ~ft~ Date Date 9/7 {1- '--. -- Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, int"ormation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. - --- **** REEL HEADER **** MWD 05/11/23 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/09/16 751636 01 2.375" CTK #/)P6'-f *** LIS COMMENT RECORD ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ~Version Information VERSe WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7396.0000: STOP.FT 9064.5000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- *** Remark File Version 1.000 Extract File: ldwg.las 1.20: NO: C~~S log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska Inc. 1F-18A Kuparuk River Unit 70 deg 17'53.527" N 149 deg 40' 47.811" W North Slope Alaska Baker Hughes INTEQ 2.375 CTK 16-Sep-04 500292265401 ------------------------------ Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSI . 19 I1N 10E MSL o RKB 108 KB 108 N/A N/A 7397 DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Â() L{ -- I ~ 7 '~ "-" ~Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage (5 ) Electrical surface system to log this well. Tools ran in the string included Casing Collar Locater, a Disonnect and Circulation Sub, a Driling Performance Sub (inner and outer downhole pressure), downhole weight on bit, a Gamma and Directional Sub, and a Hydraulic Orienting Sub with a near bit inclination sensor. (6) Data presented here is final and was not adjusted to a PDC (Primary Depth Control). The INTEQ ~m Gamma Ray is the PDC for well 1F- 18A. (7 ) The Side Track was in 3 1/2" Liner. Top of Window Bottom of Window The interval from drilled from 1F-18 through a milled window (8 ) 7393.2' MD (5973.1' SSTVD) 7397.2' MD (5976.2' SSTVD) 9037' to 9065' MD (5970.9' to 5969.7' SSTVD) '!" was not (9) Tied MNEMONICS: GRAX -> ROPA -> TVD -> EOZ END logged due to bit to sensor offset. to 1F-18 at 7263' MD (5873.3' SSTVD). Gamma Ray MWD-API [MWD] (MWD-API units) Rate of Penetration, feet/hour Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1F-18A 5.xtf 150 ConocoPhillips Alaska Inc. 1F-18A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska ">-~ -' instructions, the MVID Gamma Ray ~s the PDC for this borehole. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 40 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7396.000000 9064.500000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 49 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VAl,U -'-- ',,-, -------------------------------- WDFN LCC CN WN FN COUN STAT IF-18A.xtf 150 ConocoPhillips Alaska In IF-18A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX ROPA ---------------------------------------------------- GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 68 68 AAPI P/HR 1 1 4 4 4 4 GRAX ROPA MWD MWD ------- 8 Total Data Records: 80 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7396.000000 9064.500000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 89 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD ~~- 04/09/16 751636 01 **** REEL TRAILER **** MWD 05/11/23 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: ..- 2 records... 132 bytes 132 bytes -~;;,;~ .--- Tape Subfile 1 is type: LIS \._~ _/ Tape Subfile 2 is type: LIS DEPTH GR ROP 7396.0000 -999.2500 1.3000 7396.5000 -999.2500 0.9300 7400.0000 104.4200 7.1700 7500.0000 128.1700 40.8600 7600.0000 134.0800 21.6000 7700.0000 119.2800 118.1300 7800.0000 83.5700 99.9500 7900.0000 93.4167 82.0200 8000.0000 81.1050 168.6100 8100.0000 86.8800 103.9800 8200.0000 95.0967 95.6800 8300.0000 82.6200 132.8200 8400.0000 86.2700 126.1100 8500.0000 88.6300 136.0000 8600.0000 82.2000 39.5800 8700.0000 81.2133 70.5800 8800.0000 94.3600 137.3800 8900.0000 117.6200 131. 7100 9000.0000 98.1700 149.7600 9064.5000 -999.2500 -999.2500 Tape File Start Depth 7396.000000 Tape File End Depth 9064.500000 Tape File Level Spacing 0.500000 Tape File Depth Units feet -~ -' Tape Subfile 3 is type: LIS DEPTH GRAX ROPA 7396.0000 -999.2500 1. 3000 7396.2500 -999.2500 1. 1800 7400.0000 -999.2500 6.3600 7500.0000 128.1300 33.9900 7600.0000 129.9200 20.8100 7700.0000 116.3300 120.1600 7800.0000 82.1100 98.2400 7900.0000 92.7733 54.1400 8000.0000 80.9675 166.2500 8100.0000 84.3500 103.5800 8200.0000 94.4433 95.6800 8300.0000 83.4633 133.2300 8400.0000 85.0000 126.5500 8500.0000 87.4700 136.0600 8600.0000 86.9800 53.5700 8700.0000 82.2967 126.0600 8800.0000 94.2200 138.6700 8900.0000 122.2300 131.4500 9000.0000 93.7200 146.9600 9064.5000 -999.2500 -999.2500 Tape File Start Depth 7396.000000 Tape File End Depth 9064.500000 Tape File Level Spacing 0.250000 Tape File Depth Units feet .~r' .~ Tape Subfile 4 is type: LIS