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Home My WebLink About198-221 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 5 MAIEL) AUG 0 1 2012 Mr. Jim Regg `b `�-- Alaska Oil and Gas Conservation Commission 333 West 7 Avenue } (a Anchorage, Alaska 99501 V' v Subject: Corrosion Inhibitor Treatments of West Beach Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from West Beach that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my altemate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) West Beach Date: 4/26112 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API # cement pumped cement off date inhibitor sealant date ft bbls ft na qal WB-03 2021450 50029223220000 Dust Cover _ NA 0.0 NA NA 4/22/2012 WB-04 1901680 50029221170000 1.0 NA 1.0 NA 8.50 4/26/2012 WB -05B 1981910 50029228170200 1.3 NA 1.3 NA 10.20 4/26/2012 WB -06 1982210 50029229290000 1.7 NA 1.7 NA 12.75 4123/2012 WB-07 1991060 50029229490000 Dust Cover NA NA NA NA 4/25/2012 WBST -03 1760340 50029202080000 Suspended NA NA NA NA NA 4Q2010 Not Operable Injector Report • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, February 19, 2011 2:43 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 4Q2010 Not Operable Injector Report Attachments: Not Operable Injector Report 4Q2010.zip - t_.. M A C 4 .j r ✓ �� Hello Tom, Jim, Phoebe and Guy, W� Attached is the 4Q 2010 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 4Q2010.zip» Notes on wells: Removed from Quarterly Injection Report: B1 -14: Passed AOGCC MITIA with Badami field restart R -13: Furmanite wrap repaired startinghead leak. Added to Quarterly Injection Report: MPF -92: Added until injection is requested. MPF -95: Added until injection is requested. MPL -09: Added until Furmanite clamp is fabricated and installed to mitigate startinghead leak. Z -12: Added until TxIA communication is repaired. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/22/2011 Well WB -06 Injection Plot PlPCCIIrP VC Rate TIO Plot 041. Operated under Sundry #303 - 0 o co Sundry canceled - 02/25/07. Tb 9 IA Last MIT -IA: 4/19/05 OA 0 "F)) o 1) a 'N I a a — 0 N • • Last 90 days • Last Month 0 0 0 1 1 1 6/18/10 9/8/10 11/29/10 2/19/11 Injection Rate, MCFPD k o\S- - D- Volume Injected Tubing Pressure Tbg Press IA Press OA Press — \C.iSk (D'r�k " Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 01/01/11 0 -100 12/31/10 -100 420 320 12/31/10 0 -100 12/30/10 -100 420 320 CD -2 ) 12/30/10 0 -100 12/28/10 -100 420 320 12/29/10 0 -100 12/28/10 -100 420 320 12/28/10 0 -100 12/27/10 -100 440 320 12/27/10 0 -100 12/25/10 -100 440 320 12/26/10 0 -100 12/25/10 -100 440 320 12/25/10 0 -100 12/24/10 -100 440 320 12/24/10 0 -100 12/22/10 -100 440 320 12/23/10 0 -100 12/21/10 -100 440 320 12/22/10 0 -100 12/20/10 -100 440 320 • 12/21/10 0 -100 12/19/10 -100 440 320 12/20/10 0 -100 12/18/10 -100 440 320 12/19/10 0 -100 12/17/10 -100 440 320 12/18/10 0 -100 12/16/10 -100 440 320 12/17/10 0 -100 12/15/10 -100 440 320 12/16/10 0 -100 12/14/10 -100 440 320 12/15/10 0 -100 12/14/10 -100 440 320 12/14/10 0 -100 12/12/10 -100 440 320 12/13/10 0 -100 12/11/10 -100 420 320 12/12/10 0 -100 12/10/10 -100 420 320 12/11/10 0 -100 12/09/10 -100 420 320 12/10/10 0 -100 12/09/10 -100 420 320 12/09/10 0 -100 12/07/10 -100 420 320 12/08/10 0 -100 12/06/10 -100 420 320 12/07/10 0 -100 12/05/10 -100 420 320 12/06/10 0 -100 12/04/10 -100 420 320 12/05/10 0 -100 12/03/10 -100 420 320 12/04/10 0 -100 12/02/10 -100 420 320 12/03/10 0 -100 12/02/10 -100 440 320 12/02/10 0 -100 11/30/10 -100 440 320 . . BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 ë February 22, 2007 RECEIVED· MAR 0 1 2007 Alaska Oil & Gas Cons. Commbir ...~ -1.... Anchorage Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: West Beach Unit well WB-06 (PTD #1982210) Application for Cancellation of Sundry #303-041 Dear Mr. Norman: This request is to cancel Sundry #303-041 for West Beach Unit well WB-06 (PTD #1982210). The Sundry originally issued on 02/11/03 was for continued water injection with tubing by inner annulus communication. The well is shut-in with no plans for injection. Therefore the Administrative Approval is no longer needed and the Application for Sundry Cancellation form 10-404 to cancel sundry #303-041 is attached. If you require any additional information, please contact Anna Dube or Andrea Hughes at (907) 659-5102. Sincerely, ~MAR 022007 Steve Rossberg Wells Program Manager ~ RECt.::i\lED . STATE OF ALASKA ..r..;.ðl M R 1 Z007 ALASKA OIL AND GAS CONSERVATION COMMISSION /l:Ã7í A 0 ). REPORT OF SUNDRY WELL OPERATIONISOiI& Gas Cons. Commission . 1. Operations Performed: v I Abandon 0 Repair WellD Plug PerforationsD Stimulate 0 OtherŒJ 1 0-403 Cane Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD ... Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 198-221 ~ 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratígraphicO serviceŒ 50-029-22929-00-00 .. 7. KB Elevation (ft): 9. Well Name and Number: 52.00 I WB-06 '" 8. Property Designation: 10. Field/Pool(s): ADL-0034629 .j Prudhoe Bay Field 1 West Beach Oil Pool ./ 11. Present Well Condition Summary: Total Depth measured 18212 I feet true vertical 9257.0 I feet Plugs (measured) Effective Depth measured 18112 feet Junk (measured) Fish --- RFT Bolts @ 18111' true vertical 9200.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" 91.5# H-40 38 - 120 38.0 - 120.0 1490 470 SURFACE 7221 13-3/8" 68# L-80 40 - 7261 40.0 - 4709.0 4930 2270 PRODUCTION 16004 9-5/8" 47# L-80 38 - 16042 38.0 - 8195.5 6870 4760 LINER 1099 7" 29# L-80 15814 - 16913 8105.8 8573.2 8160 7020 LINER 1297 7" 29# 13CR-80 16913 - 18210 8573.2 - 9256.2 8160 7020 Perforation depth: Measured depth: 17570-17680,17735-17810,17860-18090 True vertical depth: 8902-8961,8991-9032,9060-9188 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 35 - 17404 Packers & SSSV (type & measured depth): 7" Baker Model S-3 HYDRO Set Packer @ 17309 4-1/2" Cameo TRM-4E TRSSSV @ 2008 12. Stimulation or cement squeeze summary: ,F<BDMS 8Ft MA.tI 0 1 Z007 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaqe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: --- --- Shut-In --- --- Subsequent to operation: --- --- Shut-In --- --- 14. Attachments: 15. Well Class after proposed work: ./ ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run _ 16. Well Status after proposed work: / Daily Report of Well Operations_ ~ OilD GasD WAG 0 GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 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: Contact An ¡¡a Dube / Andrea Hughes 303-041 Printed Name An¡ ~a Dube P.E. ....- r-.. Title Well Integrity Coordinator Signature ( ( )J ^.. J ~ , '..... I J A...J) Phone 659-5102 Date 2/22/07 - . I I ~ 1\ I I Form 10-404 Revised 4/2004 V \J lJ I'J-\L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.28O 1. Type of Request: Abandon [~] Suspend E~ Operation Shutdown r-~ Perforate r"] VarianceE] Annular Disposalr-~ Alter Casing r-~ Repair Well [~ Plu.q Perforations E~] Stimulater-] Time Extension r"] Other[~ Chan.qe Approved Proqram E~ Pull Tubinq D Perforate New Pool r-] Re-enter Suspended Well[-'] , 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 198-2210 Development r-~ Exploratory [~ '3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic E] Service r~ 50-029-22929.00.00 7. KB Elevation (ft): 9. Well Name and Number: 51.80 KB WB-06 /' ~8. Property Designation: 10. Field/Pool(s): ADL-0034629 Prudhoe Bay Field ! W_Beach Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): IEffective Depth MD (ft): IEffective Depth TVD (ft): Plugs (md): Junk (md): 18212 9257.3 18112 9148.5 None 18111 Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 82 20" 91.5# H-40 38 - 120 38.0 - 120.0 1490 470 Liner 2396 7" 29# L-80 15814 - 18210 8105.8 - 9256.2 8160 7020 Production 16004 9-5/8" 47# L-80 38 - 16042 38.0 - 8198.5 6870 4760 Surface 7221 13-3/8" 68# L-80 40 - 7261 40.0 - 4709.2 4930 2270 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 17570 - 17640 8901.96 - 8939.6 4.5" 12.6 # L-80 35 17405 17640 - 17680 8939.63 - 8961.2 17735 - 17770 8991 - 9010.1 17770 - 17810 9010.09 - 9032.0 17860 - 18010 9059.69 - 9143.2 18010 - 18090 9143.18 - 9187.9 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Baker S-3 Hydro Set Packer 17309 4-1/2" TRM-4E SSV 2008 7" Baker ZXP Packer 15824 12. Attachments: Description Summary of Proposal [~ 13. Well Class after proposed work: Detailed Operations Program C~ BOP Sketch r'-] Exploratoryr-~ DevelopmentE~ Servicer'x~ 14. Estimated Date for December 10, 2003 15. Well Status after proposed work: Commencing] Operatic, Oil GasE] PluggedC~ Abandonedn~ 16. Verbal Approval: Date: WAG D GINJD WINJ[~] WDSPLD Commission Representative: Perpared by Garry Catron 564-4657, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Dwight Warner Printed Name ~ Dwi~lht Warner . Title Lead Petroleum En~lineer GPMA S~gnature . ~ C/.,f ~ Phone 564-5359 12/1/03 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r-] BoP Testr~ Mechancial Integrity Test r~ ,oc,tion c,~,,~ ~ ~ !~ r,) Other:subsequent Form Required: ; O "' ¢"~O ~'j- :;':!:i.~'!:'it.'" :"iii'!ii~i ~i"'t.L. ~ ,'~ :"~. !'~ [~EC 2~3' i T Original Signed By BY oN~ke:lNI & Gas Cons. Commission Approved :':., "'~'~: ..... '"~"'; .... ~ Sarah Palin THE COMMISSlO~n~fage I."'~. .... , 2003 Form 10-403 Revised 2/2003 ORIGINAL SUBMIT IN DUPLICATE ,, bp To: G. McBride / J. Smart Well Operations Team Leader From: Howard West SWS Design Engineer Date: Sept. 24, 2003 Subject: WB-06i OA Cement Downsqueeze Procedure WBJWBE006 Est. Cost: $22M IOR: TxlA waiver Please downsqueeze the OA as described in the following procedure. This procedure includes the following steps: Step Type Procedure 1 FB OA cement downsqueeze 2 DHD MITOAto 3000psi The OA casing shoe has been deemed not competent based on a MIT-OA failure on .,,-- 03/03/03. An NFT-T failed on 2/21/03. This is the third in a line of cement programs, the previous two have failed. This procedure will leave -2500' of cement above the OA shoe. The surface casing is 68 #/ft, 13 3/8 L-80 pipe. The calculated internal yield is / 5020 psi. The procedure includes the following major steps: 1. O 2. DHD OA Downsqueeze MITOA. Shoot fluid levels If you have any questions or comments regarding this procedure, please call Howard West at (W) 564-5471, (Cell) 230-6628. CC: w/a: Well File H. West D. Warner w/o: S. Rossberg JOB PLANNING DETAILS: Current OA leak rate- 03/03/03: MIT-OA Failed, 03/09/03 LLR of 2.25 BPM at 2400 psi. Surface Casing = 13-3/8" Production Casing = 9-5/8" Surface Casing Shoe = 7261' OA Annular Capacity=.0597 bbls/ft Volume to shoe=434 bbls 2500' cement= - 150bbls total cement Displacement=434-5 (H20 Spear)-150(CMNT)-5(H20 Flush)= 275 bbls Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 360 bbls of =80 degree F Meth/Water: 20 bbls Crude: (volume needed to load OA) plus Displacement: 150 bbls (30-60 degree F) DS CW101:15 bbls Arctic Set I Cement (15.7 ppg): 150 bbls pumpable (design the pumping time for 2.5+ hrs.) Note: The first 50 barrels of cement are to contain ¼ lb. per sack of celloflake. PREP WORK (pre downsqueeze): DHD: 1. Shoot FLs and record WHPs. 2. The day prior to the downsqueeze, bleed the OAP to +/- 200 psi. CEMENTING OPERATIONS: FB Pumping 1. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. . a) b) c) 15 bbls of CWI01 spacer d) 5 bbls of fresh water spacer Flood lines with warm fresh water and pressure test lines to 3000 psi. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 2000 psi. Note injectivity at pertinent /'' times during the displacement. Current OA leak rate- 2.25 BPM at 2400 psi. 5 bbls of methanol spear 200 barrels of 80o freshwater to flush OA e) 150 barrels of 15.7 ppg Arctic Set 1 cement (mixed on the fly) The first 50 bbls of cement are to contain ¼ lb per sack of celloflake. f) 5 bbls of fresh water flush g) 275 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 265 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. , . Shut down pumps and leave the well SI with the positive WHP trapped on the OA. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 6. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post Squeeze: DHD: 1. MITOA to 3000 psi after 2 days WOC. NOTE: SLICKLINE HUNG UPBELOW SSSV TREE= _-__ WB - 06 FLA PPER. SUSPECT HVY PA RA FFIN WAS ' · KEEPING FLAPPER OPEN- 01/28/00 KB. ELEV = 51.8' *CHROM ELINER* i~oP= i~0~ Max Angle = 69 @ 10979' 17476' i 2008' H CAMCO4-1/2"TRM-4ETRSSSV, ID= 3.81" ....................................... Batum IVD = 8800' SS I 13-3/8" CSG, 6~, L-80, ID= 12.415" H 7261' ~-~ i GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE I 9-5/8"CSG, 47#,L-80,1D=8.681"H 13t~4' I~-~ ~ 1 25~ 2516 34 ~IG RI< 2 7017 4603 64 M~IG RK ! 3 9501 5617 68 IVIVIG RK Minimum ID = 3.725" @ 17393'L 4 12188 6612 67 IVlVlG RE 5 14592 7604 66 IVIVIG RK XN NIPPLE 6 16300 8304 65 KEG-2 BE 7 17231 8726 60 KBG-2 BK I TOPOF 7" LNR H 18814' I I I I 17298' ['-~ 4-1/2"XNIP, ID=3.81"I ' ~; i 17309' I'~ 7"X4.5"BAKERMODELS-3I HYDRO SET PKR, ID = 3.88" I'· I' 17372'I-I~-~'~"x~'~,'~=°.~"l I 4-~,,,~, ~.~,,-~o,o.o~,,~=~.~,. H ~,~o~, I ~ i ~o~. I--t ~-~"~^~'~,,~--~.oo"l. -r PERFORATION SUMM~ RY REF LOG: USIT ON 01/23/99 ANGLEAITOP Ft~RF: 57 @ 17570' Note: Refer to ~oduc~ion DB for his~rical porf da~a SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 17570-17680 O 07/21/99 3-3/8" ~ 6 17640-17680 O 09/15/10 . 3r3/8" 6 17735-17810 O 07/19/99 rz I ~-~,~,, ~ ~o-~o~o o o~,o~,~ I 7"LNR, 29~, 13CR-80,0.0371 bpf, ID=6.184" I~ 18210' I DATE REV BY COMMENTS DATE REV BY I COM~NTS ' WE-~T BEACH UNIT i 02/27/99 ORIGINAL COiVPLETION ! i WELL: WB-06 09/15/00 DKIM REPERF 17640'-17680' i ! PERMIT No: 98-221 11/14/00 SIS-Isl CONVERTED TO CANVAS I APINo: 50-029-22929-00 I 02/23/01 SIS-LG FINAL i I SEC25, T12N, R14E 5012.12 FEL 1030.48 FNL 10/03/01 RN/TP CORRECTIONS I I BP Exploration. (Alas ka) SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 17570-17680 O 07/21/99 3-3/8" 6 17640-17680 O 09/15/10 3r3/8" 6 17735-17810 O 07/19/99 3-3/8" 4 17860-18090 O 03/03/99 DATE REV BY COMMENTS DATE REV BY COMMENTS 02/27/99 ORIGINAL COIVPLETION 09/15/00 DKIM REPERF 17640'-17680' 11/14/00 SIS-Isl CONVERTED TO CANVAS 02/23/01 SIS-LG FINAL 10/03/01 RN/TP CORRECTIONS BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 bp February 3, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: WB-06 (PTD 1982210) Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for well WB-06. This request is for approval to continue produced water injection. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Engineer Attachments: Application for Sundry form 10-403 Description Summary of Proposal Wellbore Schematic RECEIVED FEB 0 200, Alaska 01t & Gas Cons. C. ot,-amiss[o~, Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION " APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate_ Other_ 6. Datum elevation (DF or KB feet) RKB 52.0 feet 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 5210' FNL, 3415' FEL, Sec. 25, T12N, R14E, UM At top of productive interval 1257' FNL, 220' FEL, SEC 29, T12N, R15E, UM At effecbve depth 1070' FNL, 5089' FEL, Sec. 28, T12N, R15E, UM At total depth 1033' FNL, 5015' FEL, Sec 28 T12N, R15E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service.~X (asp's 687781,5982963) (asp's 700995, 5987261) (asp's 701400, 5987459) (asp's 701473, 5987497) 7. Unit or Property name We. st-Bea"~U nit 8. Well number WB-06 ¢" 9. Permit number / approval number 198-221 10. APl number 50-029-22929-00 11. Field / Pool West Beach 12. Present well condition summary Total depth: measured 18212 feet Plugs (measured) true vertical 9257 feet Effective depth: measured 18112 feet Junk (measured) true vertical 9200 feet Casing Length Size Cemented Conductor 120' 20" Driven 1500 sx PF 'e", 898 sx Surface 7221' 13-3/8" 'G', 4218 sx PF'E' Intermediate 16004' 9-5/8" 1120 sx Class 'G' Liner 2362' 7" 320 sx Class 'G' Fish - RFT Bolts @ 18111' Measured Depth TruevedicalDepth 160' 160' 7261' 47O9' 16042' 8198' 15848'-18210' 8120'-9256' Perforation depth: measured Open Perfs 17570'-17680', 17735'-17810', 17860'-18090' true vertical Open Perfs 8902'-8961', 8991'-9032', 9060'-9188' Tubing (size, grade, and measured depth 4-1/2" 12.6# L-80 TBG @ 17404'. Packers & SSSV (type & measured depth) RECEIVED 2005 F'- 7" x 4-1/2" Baker Model 8-3 HYDRO SET Packer @ 17309'JMaMDSka 0it & Gas Cons. C0mi11[$$1_011 · Anchorage 4-1/2" Camco TRM-4E TRSSSV @ 2008' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation February 1,2003 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil _ Gas _ Service WATER INJECTOR Suspended _ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call (~0 A~e~s,~p~~'~ Title: ~AJc/I ~t~'~C:'/~3/,..~,~"/~,,'e,r' Date: zI~io~ Signedjoe E. Prepared by DeWayne R Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no.,.~/-~_,O~_ Plug integrity__ BOP Test __ Location clearance __ ~ , ~ ~ Mechanical Int~rity T~t ., , ~ubse~uept ~rm required 10-. , Approved by order of the ~ommission Commissioner Date M L. Bill ~ ~7 ~ ~ ~ SUBMIT IN TRIPLICATE WB-06 Description Summary of Proposal O2/O3/03 Problem: Injector with Slow TxlA communication Well History and Status Well WB-06 (PTD 1982210) is a water injector that failed an MIT-IA. On /~ 12/15/02, the MITIA failed on pressure stabilization and a leak rate of .35 GPM at a 1500 psi differential pressure was established. A standing valves was set and an MITIA passed to 3000 psi on 1/30/03. Recent events: > 12/15/02: MITIA failed on pressure stabilization w/1500# diff TxIA. LLRT-IC = 0.35 gpm @ 3000 psi > 01/30/03: Set standing valve, CMIT-TxlA passed to 3000 psi, pulled standing valve. This sundry request is to allow for continued injection of water. The following supports the request: · A CMIT-TxIA passed on 1/30/03 to 3000 psi against a standing valve, demonstrating competent production casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · An annual IA leak rate test will be conducted to monitor the leak severity. · A CMIT TxlA against a TTP will be conducted every 4 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only ~njecbon. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rates. 4. Perform an annual IA leak rate test. '/ 5. Perform combination MIT Tubing x IA against a plug every 4 years. 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. TREE= '~ NOTE: SLICKLINE HUNG UPBELOW SSSV · KEPING FLAPPER OPEN- 01/28/00 KB. ELEV = 51 .e' *CHROM ELINER~ MaxAngle= 69@10979' ' 2008' H CAMCO4-1/2"TRrv~4ETRSSSV, ID=3.81" ] DatumrvD: 17476' A I I Datum TVD = 8800' SE I 13-3~,, CSG, 68~, L-80, ID: 12.415" H 726~, i-~ I ~k GAS UFTMANDRELS ST MD 'rVD DEV TYPE VLV LATCH PORT DATE I 9'5/8"CSG'47#'L'80"D=8'68~"I--I 13694' I--'--'~ , 1 2599 2516 34 rvlvIG RK 2 7017 4603 64 MMG RK 3 9501 5617 68 rv'lvlG RK Minimum ID = 5 14592 7604 86 IViMG RK XN NIPPLE 6 16300 8304 65 KBG-2 BK 7 17231 8726 60 KBG-2 BK I 9-5/8"CSG, 47#,L-80, ID=8.681"H 16042' 17208' ~-q 4-1/2" x N~R tD = 3.81"I a?a°~' ~ r'x4's"a^~mu°mcs-3I 7405' I-I rr,O GED02/27/ I PERFORATION SUMI~ RY REF: LOG: U$1T ON 01123/99 I ANGLEATTOP PERF: 57 @ 17570' Note: Refer to Produc~on DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 17570-17680 O 07/21/99 3-3/8" 6 17640-17680 O 09/15/10 3-3/8" 6 17735-17810 O 07/19/99 3-3/8" 4 17860-18090 O 03/03/99 7" LNR, 20#,13CR-80, O.0371 H 18210' DATE REV BY COIVIVIENTS DA-rE REV BY COMMENTS WEST BEACH UNIT 02/27/99 ORIGINAL COMPLETION WB.L: WB-06 09/15/00 DKIM REPERF 17640'-17680' PERMIT No: 98-221 11/14/00 SIS-Isl CONVERTr:n TO CANVAS APINo: 50-029-22929-00 02/23/01 SIS-LG FINAL SEC25, T12N, R14E 5012.12 FEL 1030.48 FNL 10/03/01 RN/TP !CORRECTIONS BP Exploration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 17570-17680 O 07/21/99 3-3/8" 6 17640-17680 O 09/15/10 3-3/8" 6 17735-17810 O 07/19/99 3-3/8" 4 17860-18090 O 03/03/99 UIC Check List Well Name: (~ ~.~-- ~(o Operator: ~--~,5) New Well Conversion Date: PTD: [~'~ - ZZ I Sundry #: '~ O 3-- cD4 ( Order(s): Item Y/N Comments 1. Standard MIT test provided? 2. Notified of pressure communication or leakage? 3. Diagnostics planned/mn? Method? 4. Form 10-403 submitted requesting waiver? 5. Alternate MIT passed? Method? AOGCC witnessed? 6. MIT Part II verified? How? 7. Area or Review examined? Definition of Terms T Tubing IA Inner Annulus (tbg x csg) OA Outer Annulus (csg x csg) MIT Mechanical Integrity Test CMIT Combined test of annular spaces LLRT Leak Loss Rate Test Waiver Assessment (if necessary) Integrity # Barriers Condition Enhanced Operational Restrictions Category Affected / Monitoring Requirements~ d4~ TxlA communication (tu.b_~.. leak; Annual MITL%%LRT~ .,,,"~ ~ ~ 1 packer leak not quantifiable) 4 year CMIT T x IA '~ Water only TxlA communication (tubing leak; 2 year CMIT T x IA (tubing leak) 3 1 packer leak quantifiable) 2 year MIT T (packer leak) Water only Annual CMIT IA x OA 2 1 Production casing leak MIT Tubing - 2 yrs Water only IAxOA communication Annual MITT Water only, Alarm w/injection shutdown on OA. Set point minimum 1000 psi < 1 1 ~ Annual CMIT IA x OA minimum burst strength of outside casing. ~In addition to Monthly Report of Daily Operating Parameters; Annulus Pressure Monitoring Matrix applies to the following well configuration: 1. Conventional completion per regulations; monobore on case by case basis 2. Production casing designed for shut-in tubing pressure USDW exemption or finding of no aquifer waiver chklst.doc:8/l 2/2002 Reviewing Engineer: Recommended Action: Integrity Category: I~1-: I-"l 1.2 {l~UZZlU) W~-U~ Palled Mil IA Subject: Date: From: To: CC: RE: PTD (1982210) WB-06 Failed MIT IA Fri, 31 Jan 2003 17:37:46 -0600 "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Tom Maunder <tom_maunder@admin.state.ak.us> "Dube, Anna T" <Anna. Dube@BP.com>, "- Field Inspectors AOGCC (E-mail)" <AOGCC_Prudhoe_Bay@admin.state.ak.us>, "- Winton Aubert (E-mail) ' 'AOGCC (E-mail)" <Winton_Aubert@admin.state.ak.us>, "- Jim Re§g AOGCC (E-mail)" <Jim_Regg@admin.state.ak.us>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWelIOperationsSupervisor@BP.com>, "Engel, Harry R" <EngelHR@BP.com> Hello Tom. WB-06 passed a CMIT TxlA on 1/30/03 against a TTP. Attached is the completed MIT form. Preparation of the sundry application is in progress, should have ~t out th~s weekend. Please call if you have any questions. Joe ..... Original Message ..... From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, December 16, 2002 10:03 AM To: NSU, ADW Well Integrity Engineer Cc: - Field Inspectors AOGCC (E-mail); - Winton Aubert (E-mail) ' 'AOGCC (E-mail); - Jim Regg AOGCC (E-mail) Subject: Re: PTD (1982210) WB-06 Failed MI-I' ]IA Kevin, This acknowledges receipt of your testing information for the subject well. It appears that your testing does indicate T x IA communication and that the casing appears competent. You have approval to keep the well in water service. We look forward to receiving the sundry in the short term. Are your plans to send the sundry in prior to the holidays?? Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hi Tom,WB-06 failed a MIT IA pressure test yesterday the following information was recorded during the test:T/I/O=2350/2350/150. SI well. MITIA FAILED to 3000 psi. LLRT .35 GPM at 3000 psi. (High lAP). IA FL @ surface. Bled IA from 2350 psi to 600 psi in 1 hour (Gas and Fluid). T/I/O=1450/600/150. PT hose and manifold to 3500 psi. Pressured IA to 3000 psi with 5.5 bbls of methanol. First mins IA lost 250 psi. Re-pressured to 3000 psi with 10.35 gallons. IA lost 150 psi in first 15 mins and 110 psi in second 15rains for a total of 260 psi in 30 mins. Pressured IA back to 3000 psi with 17.38 gallons. IA lost 80 psi in first 15 mins and 150 psi in second 15 mins for a total of 190 psi in 30 mins. Bump pressure back up to 3000 psi with 10.42 gallons. IA lost 100 psi in 15 mins and 100 psi in 15 rains for a total of 200 psi in 30 mins. Re-pressured IA to 3000 psi with 7.53 gallons. IA lost 100 psi in first 15 mins and 100 psi in second 15 rains for a total of 200 psi in 30 mins. Re-pressured with 6.77 gallons. Bled IA down to 600 psi. Pumped a total of 42.1 gallons for average LLRT-IC of .35 GPM at 3000 psi. Total test time 120 minutes. Pumped a total of 6.5 bbls down iA. Put will BOI. Final WHP's=1370/600/150T. he results of the test indicate we have slow tubing by inner annulus communication. We request to be allowed to keep the well on injection while a formal state sundry application is submitted to your office for review and approval. Please let me know if further information is required. Kevin. Joe Anders, P.E. / Kevin Yeager/John Cubbon Well Integrity Engineer, BP Exploration, (Alaska)Inc. ,SCANNED FEB0 &2003 Work:(907) 659-5102 Mobil: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com PBU WB-06 01-30-03.xls Name: MIT PBU WB-06 01-30-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel Encoding: base64 1 of 1 2/3/2003 10:52 AM Re: PTD (1982210)WB-06 Failed MIT IA Subject: Re: PTD (1982210) WB-06 Failed MIT IA Date: Mon, 16 Dec 2002 10:03:27 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "NSU, ADW Well Integrity Engineer" <NSUADVVWelllntegrityEngineer@BP.com> CC: "- Field Inspectors AOGCC (E-mail)" <AOGCC_Prudhoe_Bay@admin.state.ak.us>, "- Winton Aubert (E-mail) ' 'AOGCC (E-mail)" <Winton_Aubert@admin.state.ak.us>, "- Jim Regg AOGCC (E-mail)" <Jim_Regg@admin.state.ak.us> Kevin, This acknowledges receipt of your testing information for the subject well. It appears that your testing does indicate T x IA communication and that the casing appears competent. You have approval to keep the well in water service. We look forward to receiving the sundry in the short term. Are your plans to send the sundry in prior to the holidays?? Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hi Tom,WB-06 failed a MIT IA pressure test yesterday the following information was recorded during the test:T/l/O=2350/2350/150. SI well. MITIA FAILED to 3000 psi. LLRT .35 GPM at 3000 psi. (High lAP). IA FL @ surface. Bled IA from 2350 psi to 600 psi in 1 hour (Gas and Fluid). T/I/O=1450/600/150. PT hose and manifold to 3500 psi. Pressured IA to 3000 psi with 5.5 bbls of methanol. First mins IA lost 250 psi. Re-pressured to 3000 psi with 10.35 gallons. IA lost 150 psi in first 15 mins and 110 psi in second 15mins for a total of 260 psi in 30 mins. Pressured IA back to 3000 psi with 17.38 gallons. IA lost 80 psi in first 15 mins and 150 psi in second 15 mins for a total of 190 psi in 30 rains. Bump pressure back up to 3000 psi with 10.42 gallons. IA lost 100 psi in 15 mins and 100 psi in 15 mins for a total of 200 psi in 30 mins. Re-pressured IA to 3000 psi with 7.53 gallons. IA lost 100 psi in first 15 mins and 100 psi in second 15 mins for a total of 200 psi in 30 mins. Re-pressured with 6.77 gallons. Bled IA down to 600 psi. Pumped a total of 42.1 gallons for average LLRT-IC of .35 GPM at 3000 psi. Total test time 120 minutes. Pumped a total of 6.5 bbls down IA. Put will BOI. Final WHP's=1370/600/150.The results of the test indicate we have slow tubing by inner annulus communication. We request to be allowed to keep the well on injection while a formal state sundry application is submitted to your office for review and approval. Please let me know if further information is required.Kevin. Joe Anders, P.E. / Kevin Yeager / John Cubbon Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work:(907) 659-5102 Mobil: (907) 943-1154 Pager: (907) 659~5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com Tom Maunder <tom maunder~,admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission GANNED DE O 1 9 20D2 I of 1 12/16/2002 10:12 AM • • Page 1 of 2 Maunder, Thomas E (DOA) From: Tom Maunder [tom_maunder @admin.state.ak.us] Sent: Wednesday, October 24, 2001 4:58 PM To: 'Leslie Anders' Subject: Re: INFO: WB -06 (PTD 1982210) Passing MITIA Attachments: tom_maunder.vcf Joe, Thanks for the information. I concur, that continuing to monitor is a good course and I agree the leak is likely the standing valve. I'm not sure what you mean by the tubing tail. Do you mean a connection leak ?? Tom Leslie Anders wrote: Hello Tom. 5titNNED MAR 2.01 On 10/13/01, WB -06 (PTD 1982219) passed an MITIA. Slickline set a standing valve and the well was loaded. The tubing was pressured to 3000 psi and a tubing leak rate of 200 psi /20 min was observed. The IA did not change pressure during this testing. The IA was pressured to 3000 psi and lost 60 psi /15 minutes, another 40 psi the next 15 minutes for a total of 100 psi in 30 minutes. Slickline pulled the standing valve. The well is currently on water injection. Our plan is to continue monitoring the IA pressure for signs of communication. The failing MIT -T is likely due to a leaking standing valve or tubing tail. Let us know if you have any questions. Joe Original Message From: Tom Maunder [mailtotom maunder_ admin.state.ak.us] Sent: Tuesday, October 09,2001 12:27 PM To: NSU, ADW Well Integrity Engineer Subject: Re: WB -06 (PTD 1982210) Failed MITIA Joe /Kevin, Thanks for the notice. Keep us informed of the diagnostic results. Tom "NSU, ADW Well Integrity Engineer" wrote: > Hello Tom. > Injection Well WB -06 (PTD 1982210) failed an MIT -IA due to lack of pressure 2/22/2011 • Page 2 of 2 > stabilization. On 09/28/01, an MIT -IA was attempted to evaluate high IA > pressure. The well was pressured to 3000 psi and a pressure loss of 150 -180 > psi was consistently observed at 15 minute intervals. Calculated leak rate > is .4 GPM @ 3000 psi. The well is currently on water injection. > Our plan is to set a tubing tail plug, pressure test the tubing and > production casing then evaluate submitting a sundry to continue water > injection. We will keep you informed of diagnostic work progress. > Please call if you have any questions. > > Joe > Joe Anders, PE / Kevin Yeager > Well Integrity Engineer > BP Exploration, Alaska Inc. > (907) 659 -5102 - Work > (907) 659 -5100, x1154 - Pager > email: NSUADWWellIntegrityEngineer@bp.com 2/22/2011 3o-oi 198-221-0 PRUDHOE BAY UN WB WB-06 50- 029-22929-00 BP EXPLORATION Roll #1: Start: Stop Roll #2: Start ~.~- Stop (ALASKA) INC MD 18212 TVD 09257 Completion Date: ~/2~99 Completed Status: I-OIL Current: IWINJ T Name Interval C 9243 ~'~- ' 1 SCHLUM GR C 9244 ~ 1 SCHLUM GR/CDR/ADN L ADN-MD t"~'~ FINAL 16040-18174 L ADN-TVD ~- FINAL 8200-9215 L CDR/GR-MD ~'~-~ FINAL 120-18174 L CDR/GR-TVD~FINAL 120-9215 L GR-MD~~''~r FINAL 120-7519 PB1 L RFT '~'~- FINAL 17608-18009 L STAT BHP /r FINAL 0-17806 12/5/99 L STAT BHP ~-~ FINAL 0-17476 L STAT PRES/TEM /FINAL 17170-17934 7/17/99 R SRVY RPT R SRVY RPT S 1003 ~ SCHLUM 0-18138.30 SCHLUM 0-7919.1 PB1 DRY DITCH 7260-18211 Sent Received OH 7/13/99 7/26/99 OH 7/22/99 7/26/99 OH 7/22/99 7/26/99 OH 7/22/99 7/26/99 OH 7/22/99 7/26/99 OH 7/22/99 7/26/99 OH 7/13/99 7/26/99 CH 2/1/99 2/4/99 CH 5 12/14/99 12/29/99 CH 5 7/7/00 7/19/00 CH 5 8/4/99 8/13/99 OH 2/1/99 2/1/99 OH 2/1/99 2/1/99 OH 1/18/99 1/18/99 T/C/D Thursday, February 01, 2001 Page 1 of 1 .... STATE OF ALASKA --_. , ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_X (Conversion) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 5208' FNL, 3413' FEL, Sec. 25, T12N, R14E, UM At top of productive interval 1268' FNL, 214' FEL, SEC. 29, T12N, R15E, UM At effective depth At total depth 1030' FNL, 5012' FEL, Sec. 28, T12N, R15E, UM 5. Type of Well: Development__ Exploratow___ Stratigraphic__ Service~X 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name PRB Unit West Beach PA 8. Well number WB-06i 9. Permit number / approval number 198-221/300-121 signed on May 9, 2000 lO. APl number 50-029-22929 11. Field / Pool West Beach Oil Pool 12. Present well condition summer Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 7209' Intermediate 15990' Liner 2396' Perforation depth: measured true vertical Tubing (size, grade, & measured depth) Packers and SSSV (type & measured depth) 18212 feet 9257 feet Plugs (measured) PBTD tagged @ 18091' MD on 10/15/2000. 18091 feet Junk (measured) 9188.5 feet Size Cemented Measured Depth True vertical Depth 20" Ddven 80' 80' 13-3/8" 5718 Sx PFE & 898 Sx Class G 7261' 4709' 9-5/8" 1120 Sx Class G 1 6042' 81 98' 7" 320 Sx Class G 1 821 0' 9256' 17570'-17680'; 17735'-17810'; 17860'-18090'. 8902'-8961'; 8991'-9032'; 9060'-9188'. 4-1/2",12.6#, L-80 Tbg @ 17405' MD. BAKER 7" X 4.5" MODEL S-3 HYDRO SET PACKER @ 17309' MD. CAMCO 4-1/2" TRM-4E TRSSSV @ 2008' MD. RECEIVED JAN ] ] 2001 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation (6/10/2000) Subsequent to operation OiI-Bbl 597 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 10201 29 6700 Casing Pressure Tubing Pressure 689 22OO 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _._X 16. Status of well classification as: Oil __ Gas __ Suspended __ Service Water lniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ..-.-~(_.~~ .~'~'/'~"~¢J~--..,~. Title West Beach Surveillance Engineer Scott Mattison - Date Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · ORi6!NAL SUBMIT IN DUPLICATE ~ ~ WB-06i .~ DESCRIPTION OF WORK COMPLETED CONVERSION OF PRODUCER TO WATER INJECTOR Date Event Summary 6/15/2000: 6/22/2000: 7/05/2000: 7/08/2000: 7/21/2000: 7/22/2000: 7/23/2000: 7/27/2000 - 7/28/2000: 8/10/2000: 8/1 2/2000: 8/30/2000 - 9/05/2000: 9/07/2000 - 9/12/2000: 9/15/2000: RIH & tagged PBTD @ 17881' MD. RIH & performed SBHP/FBHP Survey. Logged stations @ 17476' 17080' 16644' 16174'. RIH w/CT & performed FCO to 18100' MD using Biozan / N2. RIH & loaded IA w/2% KCL Water & Diesel. MIRU CTU. PT'd equip to 4000 psi. RIH w/CT & tagged 18098'. FCO'd to 18120'. POOH w/CT. Performed injectivity test. Well locked @ 270 bbls KCL Water away. RIH & tagged fill @ 17946'. Cleaned out w/Crude & Biozan to 18127'. POOH w/CT. Performed injectivity test. RIH & FCO'd to 18118'. Reversed out to TD. Injectivity test: 0 bpm @ 2100 psi. POOH w/CT. FP'd well. RD. Pulled GLV's. Dummied GLV's. Performed MITIA to 3000 psi - passed. Injectivity test: 2 bpm @ 4400 psi, 1.5 bpm @ 4275 psi, I bpm @ 4000 psi, & 0.5 bpm @ 3700 psi. RIH & tagged PBTD @ 18107'. MIRU ELU. PT'd equip. RIH w/perf guns & did tie-in. Reperforated 230' f/: 17860'- 18090' MD (Kuparuk Zone) Reference Log: USIT 1/23/1999. Used 3-3/8" carriers and all shots @ 6 SPF. POOH w/guns. ASF. RD. Injectivity test: 0.85 bpm @ 2100 psi, 0.85 bpm @ 3000 psi, & 1.3 bpm @ 4000 psi. MIRU ELU. PT'd equip. RIH w/perf guns & did tie-in. Reperforated 75' f/: 17735' - 17810' MD (Kuparuk Zone) Used 3-3/8" carriers and all shots @ 6 SPF. POOH w/guns. ASF. RD ELU. Performed injectivity test: established 2.1 bpm @ 2300 psi. MIRU ELU. PT'd equip. RIH w/perf guns & did tie-in. Reperforated 40' f/: 17640'- 17680' MD (Kuparuk Zone) Used 3-3/8" carriers and all shots @ 6 SPF. POOH w/guns. ASF. RD ELU. 9/22/2000: Injectivity test: 0.8 bpm @ 3000 psi. Pumped breakdown @ 3.5 bpm @ 4200 psi. Established injection of 1 bpm @ 3500 psi. RECEIVED Page1 JAN J. J- 2001 Alaska 0il & Gas C~s. Commission 'Anchorage WB-06i ( DESCRIPTION OF WORK COMPLETED CONVERSION OF PRODUCER TO WATER INJECTOR Date Event Summary 10/05~2000: 10/09~2000: 10/15/2000: 10/29/2000: 11/26/2000: 12/09/2000: 12/10/2000: 12/25/2000: Pulled station #2 DGLV & replaced w/OGLV. Flowed well back to system to clean up perfs. RIH & tagged PBTD @ 18091'. Injectivity test - ave 4.6 bpm @ 2100 psi. RIH & pulled CA RDO 20 RK f/Sta #2 & set CA RD RK in Sta #2. All downhole pre-injection work is completed. RIH & pulled top sta DGLV. FP'd IA w/Methanol. RIH & installed DGLV in sta #2. Placed WB-06i initially on Cretaceous water injection (supplied f/WB-07) @ 1200 hrs. Obtained representative injection data. Page 2 RECEIVED JAN 1 2001 Alaska O~J & Gas Cons. Commission Anchorage Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-rN: Sherrie NO. 315 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Beach 777/00 Well Job # Log Description Date BL Sepia CD WB-05B STATIC BO'I-rOM HOLE 000621 I 1 WB-06 STATIC B.H. PRESSURE LOG 000622 I I r~ r'r' E !\!r I~ ,, RECEI JUL19 Alaska 0il & t~as Cons. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ (prod -> Water Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Inj Conversion) Change approved program _ Pull tubing _ Variance _ Perforate _ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development~X RKB 52 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ PRB Unit West Beach PA 4. Location of well at surface 8. Well number 5208' FNL, 3413' FEL, Sec. 25, T12N, R14E, UM (asp's 687781, 5982963) WB-06 At top of productive interval 9. Permit number / approval number 1268' FNL, 214' FEL, SEC. 29, T12N, R15E, UM (asp's 701000, 5987249) 198-221 At effective depth 10. APl number 50-029-22929 At total depth 11. Field / Pool 1030' FNL, 5012' FEL, Sec. 28, T12N, R15E, UM (asp's 701474, 5987497) West Beach Oil Pool 12. Present well condition summary Total depth: measured 18212 feet Plugs (measured) Tagged PBTD @ 17877' on 1/29/2000. true vertical 9257 feet Effective depth: measured 17877 feet Junk (measured) true vertical 9069 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" Driven 80' 80' Surface 7209' 13-3/8" 5718 Sx PFE & 898 Sx Class G 7261' 4709' Intermediate 15990' 9-5/8" 112o Sx C~ass G 16042' 8198' Liner 2396' 7" 32o Sx C~ass G 18210' 9256' Perforation depth: measured 17570'-17680'; 17735'-17810'; 17860'-18090'. true vertical 8902' - 8961'; 8991' - 9032'; 9060' - 9188'. ~ ~,.~.... . ,. ~.~-_~ ' ~ '~,~ ~ ,~.~,~._ Tubing(size, grade, and measured depth 4-1/2", 12.6#,L-80Tbg @ 17405'MD. ~J[~Y 0,5 200~ [Packers & SSSV (type & measured depth) BAKER 7" X 4.5" MODEL S-3 HYDRO SET PACKER @ 17309' MD. CAMCO 4-1/2" TRM-4E TRSSSV @ 2008' MD. 13. Attachments Description summary of proposal __X Detailed operations program ~ BOP sketch ___X 14. Estimated date for commencing operation 15. Status of well classificaUon as: May 20, 2000 16. If proposal was verbally approved Oil __X Gas__ Suspended Name of approver Date approved Service 17. I hereby ce~ng is true and correct to the best of my knowledge. Questions? Call Mike Morgan @ 263-4332 Signed ~,,-~~ Title: Phillips Alaska Engineering Supervisor Date Erin Oba Prepared by Pau/ Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity __ BOP Test__ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10-~O{-~. · .-~i~IGINAL SIGNED-BY Approved by order of the Commission ~r~bert N. ChristensQn Commissioner Date !~pp~owed 0o~3¥ · Retu~r~e~o- u '~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 4, 2000 Mr. Robert N. Christenson, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 Dear Mr. Christenson: Re: Sundry Notice for WB-06 Conversion from Producer to Water Iniection Service Consistent with Conservation Order 311B and Area Injection Order 4C Phillips Alaska Inc. requests permission to convert West Beach 06 (WB-06) to water injection service. The conversion of WB-06 will enhance recovery from the West Beach Oil Pool supporting production from both WB-04 and WB-05B. WB-06 was drilled, cased, cemented and tested according to the requirements of 20 AAC 25.005. These applications and completion records are on file at the AOGCC. The well will be tested according to 20 AAC 25.412 prior to initiation of water injection. An exception to 20 AAC 25.412(b), requiring the packer within 200' MD of the top perforation, is requested. The packer in the well is 261' MD above the top perforation and within the upper confining zone of the West Beach Oil Pool. All well work will be conducted in accordance with the requirements of AAC 20 25.280 and consistent with current Phillips Alaska, Inc. Prudhoe Bay Unit standard wellwork practices. Below is a summary of the planned procedure: (1) Record static pressure survey and tag current PBTD. (2) Perform coil tubing cleanout if necessary. (3) Notify AOGCC representative of plans and timing of pressure test. (4) Pull gas lift valves, load annulus with inhibited brine and freeze protect cap. (5) Perform mechanical integrity pressure tests per 20 ACC 25.412(c). (6) Place WB-06 in injection service. If additional data or scheduling information is needed, please call Mike R. Morgan at 263-4332.. MAY 0,5 200 Subject: [Fwd: FW: WB-06 Status] Date: Mon, 18 Sep 2000 09:39:56 -0800 From: Jack Hartz <jack hartz~admin.state.ak.us> Organization: AOGCC To: Blair Wondzell <blair_wondzell~admin.state.ak.us>, Thomas E Maunder <tom_maunder~admin. state.ak.us>, Robert Crandall <bob_crandall@admin. state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us> CC: Lori Taylor <lori_taylor~admin. state.ak.us> FYI, updated WB-06 well work to establish injectivity. Lori, Please make copy for WB-06 (198-221) file. Thanks, Jack Subject: FW: WB-06 Status Date: Wed, 13 Sep 2000 18:30:31 +0100 From: "Taylor, Paul J" <TaylorPJ~BP.com> To: "Jack Hartz (E-mail)" <Jack_Hartz~admin. state.ak.us> Jack; here's a nice summary of where we're at on the conversion of WB-06. In short, we're planning to reperf one more interval sometime later this weekand hope to have the injector operating shortly thereafter. Paul Taylor Prudhoe/GPMA Reservoir Engineer BP Exploration (907) 564-4068 taylorpj~bp.com > ..... Original Message ..... > From: Mattison, Scott A > Sent: Tuesday, September 12, 2000 3:46 PM > To: Frazier, Randy B > Cc: Taylor, Paul J > Subject: WB-06 Status > > Randy, > > WB-06 is being converted from production to injection as part of the start > up of the West Beach Waterflood. The lower perforated interval was Frac'd > in May of 1999 with just under 125,000 pounds of 20/40 Proppant behind > pipe. The well was pre-produced post Frac with an initial rate of 3,000 > bopd, declining to 1,000 bopd by July. Two upper intervals were AdPerf'd > in July increasing the rate to 2,000 bopd. > > The well locked up at 270 barrels away during an injectivity test post FCO > on 7/21/00 and failed to 'Break Down' during an HPBD with crude on > 8/10/00. Injectivity was 2 BPM at 4,400 psi and 0.5 BPM at 3,700 psi > during the HPBD. The well was Drifted to 18,107' (17' RH) with a 3.50" > CENT on 8/12/00. The conclusion from all of the above is that the perf > tunnels were plugged during the injectivity test. > > RePerf'ing 150' of the deepest interval in the well established an > Injectivity of approximately 1 bpm at 2100 psi on 9/6/00. RePeri'ing 75' > of the middle Perfinterval increased injectivity to 2.3 bpm post Break > Down on 9/12/00. This revised procedure calls for RePerfSng 40' of the > upper Perf interval with the objective of increasing Injectivity to 3+ bpm > at 2100 psi. This Revision of the Perf Procedure reduces the amount of > the upper interval being RePerf'd to optimize conformance between > intervals. An Injectivity Test with crude should be mn post RePerf (take > to 4,000 psi to 'Break Down' Perfs if necessary). > > Scott A. Mattison > Petroleum Engineer, GPMA > MB 5-3/551 > Bus Ph: (907) 564-4362 > Cell Ph: (907) 244-9164 > <<Scott Mattison (E-mail).vcf>> [15wd: West Beach Update] Subject: [Fwd: West Beach Update] Date: Wed, 04 Oct 2000 16:32:12 -0800 From: Jack Hartz <jack_hartz~admin. state.ak.us> Internal Organization: AOGCC To: Blair Wondzell <blair_wondzell~admin.state.ak.us>, Thomas E Maunder <torn_maunder~admin.state.ak.us> CC: Lori Taylor <lori_taylor~admin. state.ak.us> Blair, Tom - This is an update on WB-06 injection conversion. Looks like a headache but they are making some progress Jack Lori, Please copy to WB-06 ptd 198-221. Thx, Jack Subject: West Beach Update Date: Tue, 3 Oct 2000 03:11:29 +0100 From: "Taylor, Paul J" <TaylorPJ~BP.com> To: "Jack Hartz (E-mail)" <Jack_Hartz~admin.state.ak.us> CC: "Mattison, Scott A" <MattisSA~BP.com>, "Frazier, Randy B" <FrazieRB~BP.com> Jack; here's an update on what is happening at the WB-06 conversion attempt. Throughout September, we've continued to add perforations with mixed results ultimately ending up with a completion that is still unsatisfactory for adequate injection rates. At the bottom of this note is a collection of drillsite reports that summarize the work. The plan forward is to attempt to produce the well again for a short term test. If production is low relative to its former rates, we plan to design and pump an acid stimulation° If production is the same, we will try another nitrogen clean out and test for injectivity. I realize we're still operating WB-04 under a verbal waiver and want to put this procedure behind us as soon as possible. However, we are still being frustrated with operational problems may take us a week or two more sort out. Please let me know if you have any comments or concerns (e.g., we could curtail WB-04 or get a BHP at WB-05B just to see if we're drawing things down too much...). Paul Taylor Prudhoe/GPMA Reservoir Engineer BP Exploration (907) 564-4068 taylorpj@bp.com 8/31/00 WB-06 PROD REPERF FROM 17,970' TO 18,010' ELM (IN-PROGRESS) / LORENTZ 10/5/00 9:34 AM [15~wd: West Beach Update] PERF(REPERF) .PERFORATED: 17970' - 18010', 6 SPF, 3 3/8" POWERJET AFE # 2D0087 Daily $13930 Cum $18368 9/2/00 WB-06 PROD 3 3/8" HSD, 6 SPF POWERJET PERFORATE / LORENTZ PERF(REPERF) .PERFORATED: 17900' - 17930', 6 SPF 3 3/8"POWERJET AFE # 2D0087 Daily $16085 Cum $54966 9/3/00 WB-06 PROD 3 3/8" HSD, 6 SPF POWERJET PERFORATE / LORENTZ PERF(REPERF) .PERFORATED: 17860' - 17900' 6 SPF POWERJET , AFE # 2D0087 Daily $18342 Cum $73308 9/7/00 WB-06 PROD 09/05/00: INJECTIVITY TEST / PERF(REPERF).ESTABLISH LORENTZ INJECTIVITY RATE 0.85 BBPM @ 2100 PSI, 0.85 BPM @ 3000 PSI, 1.3 BPM @ 4000 PSI. AFE ~ 2D0087 Daily $990 Cum $74298 9/8/00 WB-06 PROD 3 3/8" HSD, 6SPF POWERJET / PERF(REPERF) .PERFORATED: 17770' LORENTZ - 17810', 6 SPF POWERJET AFE ~ 2D0087 Daily $18493 Cum $92791 9/12/00 WB-06 PROD PERFORATING / PERF(REPERF) .PERF FROM 17735' TO 17770' 3 LORENTZ 3/8'' POWERJET 6 SPF AFE ~ 2D0087 Daily $17373 Cum $110164 9/15/oo WB-06 PROD / PERF(REPERF) .Perforated 17,640' - 17,680' MD. KIM AFE # 2D0087 Daily $0 Cum $112014 9/16/00 WB-06 PROD PERFORATE 17640-17680 FT MD - 3 3/8" HSD PJ3406 @ KIM 6 SPF / PERF(REPERF) .PERFORATE 17640 - 17680 WITH 2 RIHS - 3 3/8" HSD WITH PJ3406 CHARGES @ 6 SPF. AFE ~ F58WBE06 Daily $12275 Cum $12275 9/23/00 WB-06 PROD INJECTIVITY TEST (POST-PERF) / PERF(REPERF).iST INJ TEST: CISMOSKI 0.8 BPM AT 3000 PSI, 90 BBLS CRUDE PUMPED. RD & RETURNED WITH FULL LOAD. PUMPED BREAKDOWN @ 3.5 BPM, 4200 PSI. REDUCED ~TE A/~D ESTABLISHED 2ND INJ TEST <<<<< 1 BPM @ 3500 PSI >>>>> AFE # 2D0057 Daily $2112 Cum $126401 10/5/00 9:34 AM [F~wd: West Beach Update] Paul Taylor Prudhoe/GPMA Reservoir Engineer BP Exploration (907) 564-4068 taylorpj@bp.com Jack Hartz <jack hartz~admin.state.ak.us> Sr. Petroleum Reservoir Engineer Alaska Oil & Gas Conservation Commission 3 of 3 10/5/00 9:34 AM Subject: FW: WB06 Injectivity Test post Flow Back Date: Tue, 24 Oct 2000 00:00:14 +0100 From: "Taylor, Paul J" <TaylorPJ~BP.com> To: "Jack Hartz (E-mail)" <Jack_Hartz@admin. state.ak.us> CC: "Frazier, Randy B" <FrazieRB@BP.com> Jack; just a heads up that we're going to attempt to establish water injection in WB-06 soon, probably sometime this week. See the attachment for a summary of what we have done to date. If rates are reasonably close to our target, we might commence injection and put a temporary booster pump (truck) in series with the source well and monitor progress as the colder water establishes thermal fracs. Once established, we may be able to supply water via the source well alone. If this fails, we plan to take a step back and re-evaluate. We will consult with you if this happens so we can be in agreement on what to do next. Thanks again for working with us on this, Jack. Paul Taylor Prudhoe/GPMA Reservoir Engineer BP Exploration (907) 564-4068 taylorpj~bp.com > ..... Original Message ..... > From: Mattison, Scott A > Sent: Thursday, October 19, 2000 12:34 PM > To: G ANC Wellwork Program > Cc: Frazier, Randy B; LPC DS Lead; Taylor, Paul J; Kidd, Gordon A; > Barnes, Thomas J > Subject: WB06 Injectivity Test post Flow Back > > Please conduct an Injectivity Test on well WB-06 following the enclosed Procedure. > > <<WB-06 Inj Test 10-00.doc>> > > Scott A. Mattison > Petroleum Engineer, GPMA > MB 5-3/551 > Bus Ph: (907) 564-4362 > Cell Ph: (907) 244-91 64 > Home Ph: (907) 338-9320 > <<Scott Mattison (E-mail).vcf>> bp To: Gary McBride/John Smart, GPB Well Ops TL From: Scott A. Mattison, GPMA PE Date: October 19, 2000 Subject: WB-06 Iniectivity Test Post Flowback AFC: F 58 WBE Please test for Injectivity with 2% KCI water Post Flow Back. Est. Cost: $5M IOR: State Required Type Procedure Comment O Injectivity Test Establish stable Injection Rates at 2,300 psi, 3,000 psi, 3,500 psi and 4,000 psi using 2% KCI in fresh water. Pump a minimum of 400 bbl. Last injectivity: Max Deviation: Avg Hole Angle: Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: 0.8 BPM at 3,000 psi on 9/22/00. 69 deg at 10,979' 64 deg 3.725" @ XN at 17,393'MD Drifted to 18,091' md corrected on 10/15/00 D&T 21 ppm This well is being converted from production to injection as part of the start up of the West Beach Waterflood. The lower perforated interval was Frac'd in May of 1999 with just under 125,000 pounds of 20/40 Propant behind pipe. The well was pre-produced post Frac with an initial rate of 3,000 bopd, declining to 1,000 bopd by July. Two upper intervals were AdPerf'd in July increasing the rate to 2,000 bopd. The well locked up at 270 barrels away during an injectivity test post FCO on 7/21/00 and failed to 'Break Down' during an HPBD with crude on 8/10/00. Injectivity was 2 BPM at 4,400 psi and 0.5 BPM at 3,700 psi during the HPBD. The well was Drifted to 18,107' (17' RH) with a 3.50" CENT on 8/12/00. The well was RePerfd in several steps in late August and September. Injectivity after the last RePerf was 0.8 bpm at 3,000 psi. The well was Flowed back to the system on 10/09/00 in an attempt to clear possible plugged Perfs and evaluate the possibility that the formation has been damaged. Production was measured at 1,300 bopd during this flow back compared to it's normal 2,500 to 3,000 bopd initial rate. A Drift & Tag found a soft bottom at 18,091' md (corrected) on 10/15/00. A sample bailer was run but no sample was collected. Page 1 of 2 WB-06 RePerf Continued production at West Beach is dependant on starting pressure support with the West Beach Waterflood. We are now beyond the deadline (from the state) for S/U of water injection, and WB-05 is currently being produced under verbal waiver. If you have any questions or comments regarding this procedure, please call Scott Mattison at (W) 564-4362, (H) 338-9320, (Cell) 244-9164. CC: w/a: Well File Paul Taylor w/o: Steve Rossberg R. Frazier G. Kidd Subject: [Fwd: FW: WB-06 Status] Date: Mon, 18 Sep 2000 09:39:56 -0800 From: Jack Hartz <jack_hartz~admin.state.ak.us> Organization: AOGCC To: Blair Wondzell <blair_wondzell~admin.state.ak.us>, Thomas E Maunder <tom_maunder~admin. state.ak.us>, Robert Crandall <bob_crandall~admin. state.ak.us>, Stephen F Davies <steve_davies~admin. state.ak.us> CC: Lori Taylor <lori_taylor~admin. state.ak.us> FYI, updated WB-06 well work to establish injectivity. Lori, Please make copy for WB-06 (198-221) file. Thanks, Jack Subject: FW: WB-06 Status Date: Wed, 13 Sep 2000 18:30:31 +0100 From: "Taylor, Paul J" <TaylorPJ~BP.com> To: "Jack Hartz (E-mail)" <Jack_Hartz~admin.state.ak.us> Jack; here's a nice summary of where we're at on the conversion of WB-06. In short, we're planning to reperf one more interval sometime later this weekand hope to have the injector operating shortly thereafter. Paul Taylor Prudhoe/GPMA Reservoir Engineer BP Exploration (907) 564-4068 taylorpj@bp.com > ..... Original Message ..... > From: Mattison, Scott A > Sent: Tuesday, September 12, 2000 3:46 PM > To: Frazier, Randy B > Cc: Taylor, Paul J > Subject: WB-06 Status > > Randy, > > WB-06 is being converted from production to injection as part of the start > up of the West Beach Waterflood. The lower perforated interval was Frac'd > in May of 1999 with just under 125,000 pounds of 20/40 Proppant behind > pipe. The well was pre-produced post Frac with an initial rate of 3,000 > bopd, declining to 1,000 bopd by July. Two upper intervals were AdPerf'd > in July increasing the rate to 2,000 bopd. > > The well locked up at 270 barrels away during an injectivity test post FCO > on 7/21/00 and failed to 'Break Down' during an HPBD with crude on > 8/10/00. Injectivity was 2 BPM at 4,400 psi and 0.5 BPM at 3,700 psi > during the HPBD. The well was Drifted to 18,107' (17' RH) with a 3.50" > CENT on 8/12/00. The conclusion from all of the above is that the perf > tunnels were plugged during the injectivity test. > > RePeri~ing 150' of the deepest interval in the well established an > Injectivity of approximately 1 bpm at 2100 psi on 9/6/00. RePeri'ing 75' > of the middle Perf interval increased injectivity to 2.3 bpm post Break > Down on 9/12/00. This revised procedure calls for RePert~ing 40' of the > upper Perf interval with the objective of increasing Injectivity to 3+ bpm > at 2100 psi. This Revision of the PerfProcedure reduces the amount of > the upper interval being RePerf'd to optimize conformance between > intervals. An Injectivity Test with crude should be mn post RePerf (take > to 4,000 psi to 'Break Down' Perfs if necessary). > Scott A. Mattison > Petroleum Engineer, GPMA > MB 5-3/551 > Bus Ph: (907) 564-4362 > Cell Ph: (907) 244-9164 > <<Scott Mattison (E-mail).vcf>> Subject: [Fwd: FW: WB-06 Injectivity Test] Date: Mon, 30 Oct 2000 12:28:09-0900 From: Jack Hartz <jack_hartz@admin.state.ak.us> Organization: AOGCC To: Blair Wondzell <blair_wondzell@admin.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Lori Taylor <lori__taylor@admin.state.ak.us> It appears that WB-06 is doing much better. Lori, please file in WB-06 well file (198-221). Jack Subject: FW: WB-06 Injectivity Test Date: Mon, 30 Oct 2000 18:42:19-0000 From: "Taylor, Paul J" <TaylorPJ@BP.com> To: "Jack Hartz (E-mail)" <Jack_Hartz.@admin.state.ak.us> Injection appears to be imminent. Thanks for your patience, Jack. Paul Taylor Prudhoe/GPMA Reservoir Engineer BP Exploration (907) 564-4068 taylorpj@bp.com > ..... Original Message ..... > From: Mattison, Scott A > Sent: Monday, October 30, 2000 9:27 AM > To: Barnes, Thomas J > Cc: Taylor, Paul J; LPC DS Lead; Frazier, Randy B; Mike R. Johnson > (E-mail); Limb, H Gary (Phillips) > Subject: WB-06 Injectivity Test > > BruceFFJ, > > The Wells Group ran an Injectivity Test on WB-06 using water yesterday > (10/29/00) and got between 3.5 and 4.5 BPM at 2300 psi. They pumped a > total of 310 bbl of KCl water and the well was still taking 2 bpm at 1000 > psi when they shut down, so it looks like we are ready to Start-up WB-07 > and put WB-06 on Injection. > Please let Paul and I know when you think you may be ready to start > injection so we can advise the State. > Scott A. Mattison > Petroleum Engineer, GPMA > MB 5-3/551 > Bus Ph: (907) 564-4362 > Cell Ph: (907) 244-9164 > <<Scott Mattison (E-mail).vcf>> Scott Mattison (E-mail) <MattisSA@BP.com> Staff Petroleum Engineer BP Exploration Alaska GPB~GPMA Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121017 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Beach (Open Hole) Well Job # Log Description Date BL Sepia CD WB-05B STATIC BOTTOM HOLE 12/7/99 I 1 WB-06 STATIC BOTTOM HOLE 12/5/99 I 1 ,_.. _ _. ~t.~,C_.I V 12/14/99 SIGNED: ~1(~.~ DATE: t.,i:':,. <". 2 9 1999 Alaska Oil & Gas Cons. COlnmissio~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317~ou. 8/4/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12728 Company: Alaska Oil & Gas Cons Comm ¢ Attn: Lori Taylor I 3001 Porcupine Drive Anchorage, AK 99501 Field: Point Mclntyre Floppy LIS Well Job # Log Description Date Blueline Sepia Disk Tape WB-06 STATIC PRESS/I'EMP 990717 I 1 P1-05 PRODUCTION PROFILE 990704 1 1 P1-09 EXI~ PRODUCTION PROFILE 990705 1 P2-37 PRODUCTION PROFILE/DEFT 990706 1 1 SIGN DATE: ~,,t~,ska TM '" '""""' "'"" .... "'"'"'""'"" ' Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Tliank¥/ou. Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12684 Company: Alaska Oil & Gas Cons Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Beach (Open Hole) Well Job if Log Description Date BL Sepia CD WB-06PB1 99221 MDREALTIMEGR ~ ~_u~'~ 981209 I I 1 ~,, SIGNE DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (007) 561-0317. 7/13/99 7/22/99 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12698 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Beach (Open Hole) Well Job # Log Description Date BL Sepia CD wa-06 ,~ ~c~ ~ 99222 MWD GPJCDR/ADN 990108 1 wa-06 99222 CDR-GR 990108 I 1 wa-os 99222 CDR-GE TVD 990108 I 1 wa-06 99222 ADN 990108 I 1 wa-06 99222 ADN TVD 990108 I 1 SIGNE DATE: ~-'E-E,.. Please sign and return one-copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. · . :~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [] Gas [] Suspended [] Abandoned [] Service ,,, 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 98-221 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22929 4. Location of well at surface !'~'i~.;i,;:i;"'i~'_!i ~.~i.i.:" 1~ 9. Unit or Lease Name 69' NSL, 3415' WEL, SEC. 25, T12N, R14E, UM:.~....../ , , West Beach At top of productive interval --~¢--':!~~2"~ ' 10. Well Number 4023'NSL, 5060'EWL, SEC. 29, T12N, R15E, UM ? ,..~,~..,~..,, ~i ~ WB-06 At total depth ~:_i~ t 11. Field and Pool 4260' NSL, 260' EWL, SEC. 28, T12N, R15E, UM ,,._~%%. ....... .~..:'; West Beach 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. DF = 51.80'I ADL 034629 12. Date Spudded12/3/98 113' Date T'D' Reached I 14' Date C°mp" Susp" °r AbanO'115' Water depth' if °fish°re 116' N°' °f C°mpleti°nsl/7/99 2/27/99 N/A MSL One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth whore SSSV sot 121. Thickness of Permafrost 18212 9257 FTI 18112 9200 FTI [~Yes l-iNs 2008' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, CDR, PWD, DWOB, DTOQ, ADN, RFT, USIT, Gyro 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FI-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 120' 30" Driven 13-3/8" 68# L-80 40' 7261' 16" 1500 sx PF 'E', 898 sx 'G', 4218 sx PF 'E' 9-5/8" 47# L-80 38' 16042' 12-1/4" i1120 sx Class 'G' 7" 29# L-80 / 13Cr80 15848' 18210' 8-3/4" 320 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) ,.. SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 17405' 17309' MD TVD MD TVD 17860' ~ 17890' 9060' - 9076' 17890' - 17950' 9076' - 9110' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 17950' - 18010' 9110' - 9143' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED 18010' - 18070' 9143' - 9177' 18070' - 18090' 9177' - 9188' Freeze Protect with 445 Bbls of Diesel * See Post Rig Summary for Frac Treatments 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 5, 1999I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA .. ,, Brief descripti°n °f lith°l°gy' P°r°sity' fractures' apparent dips and presence °f °il' gas °r water' ~~ _c~ 1 ~P~ D Refer to recorded mud log. .... 0ii & Oas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate L;UNI'IUI:Nil/I . , 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. T-8 (SV5) 4718' 3587' SV4 4908' 3678' %5 (SV3) 5530' 3959' SV2 5923' 4132' T-3 (SV1) 6878' 4542' K-15 7964' 4998' Colville Group 12961' 6927' West Sak Sand 12961' 6927' West Sak Seismic 12979' 6934' K-12 13160' 7009' HRZ 17514' 8872' Kalubik 17532' 8882' Kuparuk 17570' 8902' Miluveach 18092' 9189' 31. List of Attachments Summary of Daily Drilling Reports, Post Rig Summary, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~"~""~¢, ~~ Title TechnicalAssistantlll Date · . WB-06 98-221 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 CONFIDENTIAL West Beach 06 Post-Rig Completion Work ARCO and Exxon request that the information provided below be kept confidential to the fullest extent allowed or required by law, including AS 31.05.035(d), AS 38.05.035(a)(9) and AS 43.05.230. 10-407 Attachment, Section 27. Well Name: WB-06 Permit Number: 98-221 APl Number: 50-029-22929 West Beach 06 Well Tests DATE CHOKE TEMP FTP OIL WATER TOTAL GAS GLG % WC GOR GLR 21 -Jun-99 100° 58° 617 1139 79 5439 0 7 4775 4465 Comment 18-Jun-99 100° 59° 579 1205 90 5040 0 7 4183 3892 16-Jun-99 100° 60° 583 1318 105 4841 0 7 3673 3402 15-Jun-99 100° 61° 602 1322 105 4658 0 7 3523 3264 15-Jun-99 100° 60° 604 1372 114 4625 0 8 3371 3112 12-Jun-99 100° 58° 641 1974 199 4166 0 9 2111 1917 10-Jun-99 100° 61° 581 1619 152 3685 0 9 2276 2081 10-Jun-99 100° 60° 595 1688 157 3448 0 9 2042 1869 09-Jun-99 100° 60° 595 1681 149 3465 0 8 2061 1893 09-Jun-99 110° 58° 595 1811 189 6228 2412 9 2107 3114 Metered Gas Lift Gas 08-Jun-99 110° 58° 630 2122 248 6660 3474 11 1501 2810 Metered Gas Lift Gas 07-Jun-99 110° 59° 662 2487 341 5425 3600 12 734 1918 Metered Gas Lift Gas 05-Jun-99 110° 62° 705 2406 705 4246 3050 23 497 1365 Metered Gas Lift Gas 30-Apr-99 90° 29° 647 380 0 298 0 0 784 784 WB-04 Raw Lift 29-Apr-99 90° 34° 655 947 0 760 0 0 803 803 WB-04 Raw Lift 19-Apr-99 90° 36° 650 840 71 590 0 8 702 648 WB-04 Raw Lift 18-Apr-99 90° 45° 600 900 350 1000 0 28 1111 800 WB-04 Raw Lift 25-Mar-99 30° 40° 100 5 95 0 0 95 0 0 To Tank Page 1/1 Operator ARCO Performance Enquiry Report Date 02:48, 11 Feb 99 Formation Integrity Test for WB-06 Page The analysis is from - 04:00, 23 Dec 98 - to - 15:00, 05 Jan 99 Programs in Result Table: WB-06 Drill and Complete Well Type WB-06 Event WB-06 Event Time From Time To Duration Description E.M.W.(ecluivalent mud weight) 04:00, 23 Dec 98 04:00, 23 Dec 98 0 hr 0 min Obtained leak off 13.5 15:00, 05 Jan 99 15:00, 05 Jan 99 0 hr 0 min Obtained required level of integrity 13.0 Depth MDR 7450.0 16763.0 Hole Size MDR 12-1/4 8-1/2 CD Z -11 m z Facility West BeaCh Well WB-06 Page 1 Rig POOL 7 Date 12 July 99 Date/Time 02 Dec 98 03 Dec 98 07:30-19:30 07:30-10:00 10:00 10:00-13:00 13:00 13:00-14:00 14:00 14:00-16:00 16:00 16:00-18:00 18:00 18:00-19:30 19:30 19:30-01:30 19:30-01:30 01:30 01'30-06:00 01'30-06:00 01:30-06:00 06:00-06:30 06:00-06:30 06:30 06:30-07:30 06:30-07:30 07:30 07:30-10:30 07:30-10:30 10:30 10:30-17:00 10:30-13:30 13:30 13:30-14:00 Duration 12hr 2-1/2 hr 3 hr 1 hr 2 hr 2 hr 1-1/2 hr 6 hr 6 hr 4-1/2 hr 4-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 3hr 3 hr 6-1/2 hr 3 hr 1/2 hr Activity Move rig Rigged up Drillfloor / Derrick PJSM. Skid rig floor. Raise cellar walls and foot. Equipment work completed Rig moved 100.00 % Move rig and spot over WB-06. At well location - Cellar Rigged up Drillfloor / Derrick Lower foot and cellar walls. Equipment work completed Skid rig Skid floor over hole. Take on diesel. Spot reserve tank. At well location - Cellar Rigged up Fluid system rig up - spot #3 pump and shop buildings .... Equipment work completed Rigged up Drillfloor / Derrick RU section on man lift, trolly in pipe shed, rock over tank. Equipment work completed Nipple up Divertor Rigged up Divertor Nipple up diverter, fill pits with water, fill pipe shed with drill pipe / BHA. Accept rig @ 1930 hrs 12-2-98. Equipment work completed Run Drillpipe, 5-1/2in O.D. Singled in drill pipe to 4500.0 ft PU 5 1/2" drill pipe and stand back in derrick. Singled in drill pipe to 4500.0 ft PU 5 1/2" drill pipe and stand back in derrick - mix spud mud. Spill drill @ 0530 hrs - 3 min. Run Drillpipe, 5-1/2in O.D. (cont...) Singled in drill pipe to 5000.0 ft (cont...) PU 5 1/2" drill pipe and stand back in derrick - mix spud mud. Spill drill @ 0530 hrs - 3 min. Stopped · To test equipment Test well control equipment Functioned Divertor Function test diverter ( 35 sec) - test witness waived by John Spalding with AOGCC. Equipment work completed Run Drillpipe, 5in O.D. Ran Drillpipe to 7000.0 ft (5-1/2in OD) Finished picking up 5 1/2" drill pipe and HWDP. Stopped · To pick up/lay out tubulars BHA run no. 1 Made up BHA no. 1 PU drill collars, stab, and jars - stand back in derrick. Began precautionary measures Held safety meeting Held pre-spud saftey / operations meeting - spill Facility Date/Time 04 Dec 98 05 Dec 98 West Beach 14:00 14:00-17:00 17:00 17:00-17:30 17:00-17:30 17:30 17:30-06:00 17:30-21:30 21:30 21:30-23:00 23:00 23:00-03:00 03:00 03:00-04:00 04:00 04:00-05:00 05:00 05:00-05:30 05:30 05:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-06:00 06:30-06:00 06:00-14:00 06:00-11:00 11:00 11:00-12:00 Progress Report Well WB-06 Page 2 Rig POOL7 Date 12 July 99 Duration Activity 3 hr 1/2 hr 1/2 hr 12-1/2 hr 4 hr 1-1/2 hr 4 hr 1 hr 1 hr 1/2 hr 1/2 hr 24 hr 1/2 hr 23-1/2 hr 23-1/2 hr 8 hr 5 hr 1 hr Completed operations Made up BHA no. 1 Make up BHA - 9 5/8" adj motor - 1.83 deg. Orient tools. Tagged up at 91' .Fill hole and check for leaks - test mud line. Mud shakers failed - Change operation Repair Repaired Mud shakers Repair scalper shaker by-pass. Equipment work completed BHA run no. 1 Drilled to 1000.0 ft Clean out conductor. Drill f/120' - 300'. ART=2 3/4 hrs. Stopped: To take survey Took Gyro survey at 269.0 ft RU Schlumberger - Ran gyro - orient. Acceptable survey obtained at 269.0 ft Drilled to 493.0 ft Drill from 300' - 493'. AST 2 hrs. Survey and gyro @conns. Unable to build angle. Build rate unacceptable - BHA Pulled out of hole to 0.0 ft POOH to adjust motor. At BHA Pulled BHA Set motor bent to 2.38 deg. Orient tools. Completed operations R.I.H. to 493.0 ft On bottom Took Gyro survey at 420.0 ft Run gyro - orient. Acceptable survey obtained at 420.0 ft BHA run no. 1 (cont...) Set tool face PJSM. Reboot anadril computer. Completed operations Drilled to 1800.0 ft Drill from 1,490' - 1,950'. ART= 1 1/2 hrs, AST= 2 hrs. Drilled to 1800.0 ft Drill from 493' - 1,490'. ART = 6 hrs, AST = 8.5 hrs. Gyro surveys @ 518', 636', 727', 820', 885', 979', and 1,072'. Fire drill @ 0430 hrs - 2 min. BHA run no. 1 (cont...) Drilled to 1800.0 ft (cont...) Drill from 493' - 1,490'. ART = 6 hrs, AST = 8.5 hrs. Gyro surveys @ 518', 636', 727', 820', 885', 979', and 1,072'. Fire drill @ 0430 hrs - 2 min. Reached planned end of run - Directional objective met Trip to change bend in motor. Circulated at 1950.0 ft Circ hole clean. Slug drill pipe. Facility Date/Time 06 Dec 98 07 Dec 98 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 3 Rig POOL7 Date 12 July 99 12:00 12:00-12:30 12:30 12:30-14:00 14:00 14:00-06:00 14:00-15:30 15:30 15:30-16:30 16:30 16:30-18:00 Duration 1/2 hr 1-1/2 hr 16hr 1-1/2 hr 1 hr 1-1/2 hr Activity Obtained bottoms up (100% annulus volume) Pulled out of hole to 1020.0 ft POOH to change BHA. No problems. At BHA Pulled BHA Pulled BHA - bit o.k. BHA Stood back BHA run no. 3 Made up BHA no. 3 Adjust motor bent to 1 1/2 deg, change out MWD, orient tools. Surface test. BHA no. 3 made up R.I.H. to 1940.0 ft Observed loss of 20.00 klb string weight Had 10' fill. Drilled to 3100.0 ft Drill from 1,950' - 2,101'. Hole tight on connections. 18:00 18:00-18:30 18:30 18:30-06:00 18:30-06:00 06:00-06:00 06:00-14:30 14:30 14:30-16:00 16:00 16:00-18:00 18:00 18:00-19:15 19:15 19:15-06:00 19:15-06:00 06:00-06:00 06:00-06:00 1/2 hr 11-1/2 hr 11-1/2 hr 24 hr 8-1/2 hr 1-1/2 hr 2 hr 1-1/4 hr 10-3/4 hr 10-3/4 hr 24 hr 24 hr Stopped: To circulate Circulated at 2101.0 ft Raise viscosity. Obtained req. fluid properties - 100.00 %, hole vol. Drilled to 3350.0 ft Drill from 2,101' - 3,350'. ART= 4 hrs, AST= 7 1/4 hrs. Spill drill at 0430 hrs. Drilled to 3350.0 ft Drilled from 3,350' - 4,110'. ART = 3.75 hrs, AST = 2.75 hrs. Spill drill @ 0730 hrs - 2.5 min. BHA run no. 3 (cont...) Drilled to 3350.0 ft (cont...) Drilled from 3,350' - 4,110'. ART = 3.75 hrs, AST = 2.75 hrs. Spill drill @ 0730 hrs - 2.5 min. Started scheduled wiper trip: due to Footage drilled Circulated at 4110.0 ft Circ hole clean for short trip. Obtained clean returns - 200.00 % hole volume Pulled out of hole to 1727.0 ft POOH to 1,727'. Hole tight at 2,738' and from 2,139' - 1,950'. Pumped out one joint DP f/2,139' - 2,107'. At top of check trip interval R.I.H. to 4110.0 ft RIH. Washed thru tight spot from 2,765' - 2,795'. On bottom Drilled to 5000.0 ft Drill from 4,110' - 5,400'. ART = 6.75 hrs, AST = 1.5 hrs. H2S drill @ 0400 hrs - 3 min. Drilled to 5000.0 ft ART= 12-3/4 hrs, AST= 3-3/4hrs FIRE DRILL @ 0830 HRS, 3 MINS FIRE DRILL @ 0130 HRS, 3 MINS BHA run no. 3 (cont...) Drilled to 7189.0 ft (cont...) ART Facility Date/Time 08 Dec 98 09 Dec 98 West Beach Progress Report CONFIDENll ,L Well WB-06 Page 4 Rig POOL 7 Date 12 July 99 06:00-05:00 06:00-10:30 10:30 10:30-16:00 16:00 16:00-19:00 19:00 19:00-21:30 21:30 21:30-22:15 22:15 22:15-01:00 01:00 01:00-02:00 02:00 02:00-04:00 04:00 04:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00-00:00 06:00-07:00 07:00 07:00-07:30 07:30 07:30-09:30 09:30 09:30-11:30 11:30 11:30-15:00 15:00 15:00-16:00 Duration 23 hr 4-1/2 hr 5-1/2 hr 3 hr 2-1/2 hr 3/4 hr 2-3/4 hr 1 hr 2 hr 1 hr 1 hr 1 hr 18hr 1 hr 1/2 hr 2 hr 2 hr 3-1/2 hr 1 hr Activity FIRE DRILL @ 0830 HRS, 3 MINS BHA run no. 3 (cont...) Drilled to 7519.0 ft ART- 3 hrs, AST= 0 hrs Reached planned end of run - Section / well T.D. Circulated at 7519.0 ft Circ & condition mud. Mud coming back very thin, running sand / pea gravel. Try to increase viscosity. Began precautionary measures Pulled out of hole to 3510.0 ft Observed 100.00 klb overpull Backreamed to 2600.0 ft Began precautionary measures Circulated at 2600.0 ft Obtained bottoms up (100% annulus volume) Backreamed to 1950.0 ft Very tight, torque up, no packoff Began precautionary measures Circulated at 1950.0 ft Obtained clean returns - 225.00 % hole volume Pulled out of hole to 215.0 ft Pull to surface to ck bit & motor. Tight f/800' to 600' D3 DIVERTER DRILL @ 03:30 HRS, 3 MINS At BHA Pulled BHA L/D motor, bearings bad BHA Stood back BHA run no. 4 Made up BHA no. 4 P/U new motor, same bit BHA run no. 4 (cont...) Made up BHA no. 4 Orient, Surface test BHA no. 4 made up R.I.H. to 2566.0 ft Observed 30.00 klb resistance Washed to 3168.0 ft Orient and slide through a previous slide section 2607' to 2680', Wash and rotate f/2680' to 2980' & 3092' to 3168'. No further resistance R.I.H. to 7519.0 ft Work through a spot that was a little tight at 5551'. On bottom Circulated at 7519.0 ft Set back a std every 45 mins. Conditioning mud and cleaning up the hole. Got about 1-1/2 BU. D3 DIVERTER DRILL @ 1130 HRS, 4 MINS Pressure changed from 2800.0 psi to 2400.0 psi in 0.33 hr - Downhol~ washout Tested Fluid system CIl~.,~.-~. Facility West Beach Date/Time 16:00 16:00-21:30 21:30 21:30-23:30 23:30 23:30-00:00 10Dec98 00:00 00:00-06:00 00:00-03:00 03:00 03:00-04:30 04:30 04:30-06:00 06:00-03:15 06:00-06:30 06:30 06:30-07:30 07:30 07:30-08:30 08:30 08:30-10:00 10:00 10:00-11:30 11:30 11:30-12:30 12:30 12:30-13:00 13:00 13:00-14:30 Progress Report CONFIDENTIAL Well WB-06 Page 5 Rig POOL 7 Date 12 July 99 Duration Activity 5-1/2 hr 2 hr 1/2 hr 6 hr 3 hr 1-1/2 hr 1-1/2 hr 21-1/4 hr 1/2 hr 1 hr 1 hr 1-1/2 hr 1-1/2 hr 1 hr 1/2 hr 1 ~ 1/2 hr Function test completed satisfactorily Pulled out of hole to 3707.0 ft POOH, tight hole f/5740' to 5608'. Worked pipe through, 100K overpull. Tight again at 5373' to 5330' and 20 to 40K drag from 5229' to 4600'. Pulled free to 3707'. Pulled into tight spot at 3707', With 60K overpull pipe parted. Observed loss of 100.00 klb string weight Pulled out of hole to 0.0 ft Came out with all the DP and 13 jts Hwt DP. The pipe parted on the box of a jt of Hwt DP just below the hard band. Left in hole 13 jts Hwt, Jars, 3 DCs, 2 LDCs, 2 Stabs, MWD, Motor and Bit = 622 ft. Fish at surface Serviced Drillfloor / Derrick Clean rig floor Equipment work completed BHA run no. 5 Made up BHA no. 5 Put DCs in pipe shed. P/U fishing BHA to rig floor. M/U fishing BHA. Stopped: To service drilling equipment Serviced Drillfloor / Derrick Service Drawworks and blocks, Change oil in Top drive. Build stop in overshot catch. Equipment work completed Made up BHA no. 5 M/U Fishing BHA, P/U DCs BHA run no. 5 (cont...) Made up BHA no. 5 Fishing BHA BHA no. 5 made up R.I.H. to 2550.0 ft Began precautionary measures Stopped to circulate down to fish. Worked toolstring at 2550.0 ft Fill pipe. Drill string plugged. Attempted to clear by rotating surged w/pressures to 4000 psi. Completed operations Unable to clear pipe. Pulled out of hole to 588.0 ft At BHA Pulled BHA Clean sand and gravel out of BHA & Hwt DP BHA Stood back Made up BHA no. 5 M/U BHA, Hwt DP and 1 std of DP BHA no. 5 made up Circulated at 650.0 ft Try to circulate, string plugged. Began precautionary measures Pulled BHA Pull '-" ~' .... ,T ~ Facility West Beach Date/Time 14:30 14:30-18:00 18:00 18:00-19:00 19:00 19:00-20:00 20:00 20:00-21:30 21:30 21:30-00:00 llDec98 00:00 00:00-00:30 00:30 00:30-02:00 02:00 02:00-03:15 03:15 03:15-06:00 03:15-04:30 04:30 04:30-06:00 06:00-12:00 06:00-09:00 09:00 09:00-10:00 10:00 Progress Report CONFIDENTIAL Well WB-06 Page 6 Rig POOL 7 Date 12 July 99 Duration Activity 3-1/2 hr 1 hr 1 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1-1/4 hr 2-3/4 hr 1-1/4 hr 1-1/2 hr 6 hr 3 hr 1 hr BHA Stood back R.I.H. to 3115.0 ft RIH, circulate every stand of BHA and DP down. Tag fish at 3115' (30' deeper than where we left it.) Observed 10.00 klb resistance Worked toolstring at 3080.0 ft Work pipe, attempt to pull fish up hole. Jarred w/ 100K over, Free going down. Began precautionary measures Washed to 3809.0 ft Circulating through the Overshot at the top of the fish. RIH and wash down 7 stds, through area where stabilizers were tight. No further resistance Pumped out of hole to 2950.0 ft Washing hole while pulling out. Observed 50.00 klb overpull Gained about 130 ft. past where we had been. Worked toolstring at 2950.0 ft Work and jar pipe w/175K over. Free travel going down 60'. Try to RIH to circ and wipe again. Stopped at 3015'. Pull back to 2950' travel down restricted. Aborted attempts to work Downhole tools free at 2950.0 ft Circulated at 2950.0 ft Clean rig floor, Remove csg equipment. Wait on Schlumberger for backoff. Stopped: To change handling equipment Rigged up Handling equipment P/U and M/U subs required for wireline backoff. Equipment work completed Rigged up Wireline units R/U Schlumberger Equipment work completed Electric wireline work Conducted electric cable operations RIH w/weight bar and collar locator, stopped at XOs at 2735'. POOH w/wireline. Observed 0.00 klb resistance Conducted electric cable operations Change out sinker bar. RIH w/new weight tool and collar locator. Got past XOs and into fish to 3415'. Logged collars to fishing assy. POOH to PFU stringshot. Electric wireline work (cont...) Conducted electric cable operations PJSM, RFU stringshot, RIH w/Wireline to 3103' WLM SPILL DRILL @ 08:00 HRS, 3 MINS Stopped to work torque into string Worked toolstring at 3103.0 ft Put LH tq into drill string, 1-1/2 tums. Fire string shot. Work pipe to backoff. Pipe came free Facility Date/Time West Beach Duration 2 hr 10:00-12:00 12:00 12:00-17:30 12:00-14:00 14:00 14:00-15:00 15:00 15:00-17:30 17:30 17:30-06:00 5-1/2 hr 2 hr 1 hr 2-1/2 hr 12-1/2 hr 17:30-18:00 18:00 18:00-21:00 21:00 1/2 hr 3 hr 3-1/2 hr 21:00-00:30 1-1/2 hr 1 hr 12 Dec 98 00:30 00:30-02:00 02:00 02:00-03:00 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 03:00 03:00-05:30 05:30 05:30-06:00 06:00-06:30 06:00-06:30 15-1/2 hr 2-1/2 hr Progress Report 06:30 06:30-22:00 06:30-09:00 Well WB-06 Rig POOL 7 09:00 09:00-11:30 11:30 11:30-12:30 12:30 12:30-16:00 16:00 16:00-17:00 17:00 2-1/2 hr 1 hr 3-1/2 hr 1 hr CONFIDENTIAL Page 7 Date 12 July 99 Activity Rigged down Wireline units POOH w/wireline. Rig down Schlumberger. Equipment work completed BHA run no. 5 Pulled out of hole to 218.0 ft At BHA Pulled BHA Fish at surface Laid down fish L/D 5 jts Hwt DP, 152.19'. Remove OS from fish. Complete fish recovered BHA run no. 6 Serviced Draw works Equipment work completed Made up BHA no. 6 MFU screw in sub w/Cut lip guide shoe. Wash each std of BHA into hole. BHA no. 6 made up FIRE DRILL @ 21:00 HRS, 2-1/2 MINS R.I.H. to 3056.0 ft Wash each stand down. Began precautionary measures Circulated at 3056.0 ft Obtained clean returns - 200.00 % hole volume Worked stuck pipe at 3108.0 ft Attempt to work over fish with cut lip guide. Couldn't get guide over tool joint box. Aborted attempts to work Downhole tools free at 3108.0 ft Pulled out of hole to 218.0 ft At BHA Pulled BHA BHA run no. 6 (cont...) Pulled BHA L/D Jars, Bumper sub, Guide shoe & screw in sub. BHA Stood back BHA run no. 7 Made up BHA no. 7 P/U Hwt jt w/cut lip pin, 6"fishing jars & bumper sub, 4 XOs, Accelerator jars. BHA no. 7 made up R.I.H. to 3108.0 ft At Top offish: 3108.0 ft Worked toolstring at 3108.0 ft Engage fish, Unable to pump. Jar up, Bump down, Work torque into string and bump down, Broke free & rotating, no up or down travel. Pipe came free Backreamed to 2494.0 ft Backream up without pumps, extreamly tight for the first 180' No further resistance Pulled out of hole to 1077.0 ft At BHA At top of the fishing assembly. Facility Date/Time West Beach 17:00-19:00 Duration 2 hr 19:00 19:00-22:00 3 hr 22:00 22:00-01:00 22:00-01:00 13 Dec 98 01:00 01:00-06:00 01:00-06:00 3 hr 3 hr 5 hr 5 hr 06:00-07:00 06:00-07:00 1 hr 1 hr 07:00 07:00-09:00 07:00-09:00 09:00 09:00-06:00 09:00-10:30 10:30 10:30-13:45 13:45 13:45-14:15 2 hr 2 hr 21 hr 1-1/2 hr 3-1/4 hr 1/2 hr 1 hr 2-1/2 hr Progress Report CONFIDENTIAL 14:15 14:15-15:15 15:15 15:15-17:45 Well WB-06 Page 8 Rig POOL 7 Date 12 July 99 17:45 17:45-18:30 18:30 18:30-19:00 19:00 19:00-19:30 3/4hr 1/2 hr 1/2 hr Activity Pulled BHA Pulled and stood back fishing assy, Hwt DP, Accelerator jars and steel DCs f/fishing assy. L/D Oil jars, Bumper sub & Jt of Hwt DP w/ cut lip. BHA Stood back Laid down fish Pull Hwt, Jars & DCs, ck for gravel and stand back. Pull MWD, stab & motor, Break bit, L/D motor and send to Anadrill's shop for inspection. L/D 2 LDCs, stab, MWD. Clear floor of fishing tools & misc BHA pieces. Complete fish recovered Derrick management Laid down 950.0 ft of Drill collar L/D fish. Jars, 3 NMDCs, Stab, and 8 jts Hwt DP. L/D remaining fishing BHA, 6-8" DCs, 12 jts Hwt DP, Accelerator jars. Send all Hwt off for inspection. Completed operations BHA run no. 8 Made up BHA no. 8 P/U 328" DCs, Stab and stand back. P/U motor, Bit, 2 LDCs, stab and MWD, Orient. Run in DCs, P/U jars and Six 6-1/2" DCs to replace the Hwt. BHA run no. 8 (cont...) Made up BHA no. 8 Orient motor/MWD, P/U 6-1/2" DCs BHA no. 8 made up Repair Cleared Mud pumps Attempt to surface test MWD, mud line frozen. Thaw out mud lines. Equipment work completed BHA run no. 8 R.I.H. to 2980.0 ft Began precautionary measures Reamed to 3870.0 ft Ream stuck pipe section plus a couple of hundred feet where we met resistance. Completed precautionary measures Circulated at 3'870.0 ft Clean up hole Obtained bottoms up (100% annulus volume) R.I.H. to 5300.0 ft Observed 20.00 klb resistance Reamed to 5842.0 ft Clean up tight area. Completed precautionary measures Circulated at 5842.0 ft Obtained bottoms up (100% annulus volume) R.I.H. to 7100.0 ft Observed 30.00 klb resistance Reamed to 7148.0 ft Ream f/7060' to 7148' Facility Date/Time West Beach 19:30 19:30-20:00 20:00 20:00-23:30 Duration 1/2 hr 3-1/2 hr 23:30 23:30-02:30 3 hr 14 Dec 98 02:30 02:30-05:00 05:00 05:00-06:00 06:00 06:00-18:00 06:00-07:30 07:30 07:30-09:30 2-1/2 hr 1 hr 12 hr 1-1/2 hr 2 hr 09:30 09:30-13:00 3-1/2 hr 13:00 13:00-16:00 16:00 16:00-17:00 17:00 17:00-18:00 3 hr 1 hr 1 hr 18:00 18:00-06:00 18:00-22:30 12hr 4-1/2 hr 22:30 22:30-00:00 1-1/2 hr 15 Dec 98 00:00 00:00-04:30 4-1/2 hr 3/4 hr Progress Report CONFIDENTIAL 04:30 04:30-05:15 05:15 Well WB-06 Page 9 Rig POOL7 Date 12July99 Activity Completed precautionary measures R.I.H. to 7519.0 ft On bottom Circulated at 7519.0 ft Circulate hole clean. Condition mud for casing job. Set std back every 45 rains. Obtained clean returns - 200.00 % hole volume Pulled out of hole to 4260.0 ft Pull 2 stds. wet, pump dry job, blow down Top drive. POOH Observed 25.00 klb overpull Backreamed to 2931.0 ft Wash to 3960', Backream to 2931', Some tight, mostly precautionary Stopped: To circulate Circulated at 2931.0 ft Obtained clean returns - 150.00 % hole volume BHA run no. 8 (cont...) Pulled out of hole to 2260.0 ft Backreamed tight hole f/2839' to 2462' Began precautionary measures R.I.H. to 3310.0 ft Wash from 3060' to 3310' Observed 30.00 klb resistance Reamed to 4095.0 ft Ream from 3310', Took weight at 4095' and wouldn't drill off. Observed 40.00 klb resistance Pulled out of hole to 404.0 ft At BHA Pulled BHA BHA Stood back Serviced Handling equipment Ck bit, Clean floor, Get new stabs and bit to rig floor. Equipment work completed BHA run no. 9 Made up BHA no. 9 P/U new bit, 2 new stabs, change blades, Orient, P/U six 6-1/2" DCs, Surface test MWD at 670' BHA no. 9 made up R.I.H. to 4093.0 ft Orient high side. FIRE DRILL @ 23:30 HRS, 2-1/2 MINS Observed 30.00 klb resistance Reamed to 4232.0 ft Work pipe, slide from 4093' at 45L trying to stay in old hole. AST= 2-1/2 hrs Completed precautionary measures Lost old hole. Sidetracked. Reamed to 4232.0 ft Ream and clean up sidetracked area from 3960' Completed precautionary measures Facility Date/Time 16 Dec 98 17 Dec 98 18 Dec 98 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 10 Rig POOL 7 Date 12 July 99 05:15-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-07:30 07:30 07:30-10:00 10:00 10:00-11:30 11:30 11:30-12:00 12:00 12:00-18:45 18:45 18:45-20:15 20:15 20:15-06:00 06:00-06:00 06:00-08:30 08:30 08:30-11:30 11:30 11:30-17:30 17:30 17:30-20:00 20:00 20:00-01:00 01:00 01:00-02:00 Duration 3/4 hr 24 hr 24 hr 24 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 6-3/4 hr 1-1/2 hr 9-3/4 hr 24 hr 2-1/2 hr 3 hr 6 hr 2-1/2 hr 5 hr 1 hr Activity Drilled to 4300.0 ft ART= 1/2 hr BHA run no. 9 (cont...) Drilled to 5934.0 ft ART= 11-1/2 hrs, AST= 6-1/2 hrs Had bit balling problems from 06:30 to 07:30 hrs FIRE DRILL @ 10:00 HRS, 2 MINS SPILL DRILL @ 20:30 HRS, 3 MINS BHA run no. 9 (cont...) Drilled to 6119.0 ft ART= 1 hr, AST= 0 hrs Started scheduled wiper trip: due to Footage drilled Circulated at 6119.0 ft Obtained clean returns - 200.00 % hole volume Pulled out of hole to 4047.0 ft Work through tight spot at 4242' At top of check trip interval R.I.H. to 6119.0 ft On bottom No problems RIH D3 DIVERTER DRILL @ 12:00 HRS, 3 MINS Drilled to 6681.0 ft ART= 4-1/4 hrs, AST= 1/2 hr Observed 50.00 klb drag on connections Reamed to 6681.0 ft Circulate and work toolstring. Completed precautionary measures Drilled to 7121.0 ft ART= 7-1/2 hrs, AST= 0 hrs SPILL DRILL @ 21:00 HRS, 2-1/2 MINS BHA run no. 9 (cont...) Drilled to 7275.0 ft ART= 2 hrs, AST= 0 hrs Reached planned end of run - Section / well T.D. Circulated at 7275.0 ft Condition mud. Lighten mud weight. SPILL DRILL @ 10:00 HRS, 2-1/2 MINS Obtained clean returns - 200.00 % hole volume Pulled out of hole to 1700.0 ft Sticky from 7275' to 6400'. T-3 sands trying to differentially stick us. Pumped the last 17 stands out to change over 9.7 mud in hole for conditioned 9.3 mud in the pits. At top of check trip interval R.I.H. to 7275.0 ft Hole in pretty good shape. On bottom Circulated at 7275.0 ft Cut MW to 9.3 in and 9.4 out. Add Barofiber and Pac-L to cut fluid loss. Set back 1 std every hr. FIRE DRILL @ 20:30 HRS, 3 MINS Obtained req. fluid properties - 300.00 %, hole vol. Circulated at 7275.0 ft Run 4 stds back in hole. Spot Barofiber pill from 7275' to 6000' Facility Date/Time 19 Dec 98 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 11 Rig POOL7 Date 12July99 Duration Activity 02:00 02:00-06:00 06:00-13:00 06:00-07:30 07:30 07:30-11:30 11:30 11:30-13:00 13:00 13:00-06:00 13:00-16:00 16:00 16:00-21:30 21:30 21:30-22:30 22:30 22:30-00:00 00:00 00:00-00:30 00:30 00:30-02:00 02:00 02:00-03:30 03:30 03:30-05:15 05:15 05:15-05:45 05:45 05:45-06:00 06:00-21:00 06:00-07:00 07:00 07:00-09:30 09:30 09:30-12:00 12:00 12:00-14:00 4 hr 7 hr 1-1/2 hr 4 hr 1-1/2 hr 17hr 3 hr 5-1/2 hr 1 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-3/4 hr 1/2 hr 1/4 hr 15hr 1 hr 2-1/2 hr 2-1/2 hr 2 hr LCM spotted downhole Pulled out of hole to 1575.0 ft POOH wet. Hole looked prety good. BHA run no. 9 (cont...) Pulled out of hole to 590.0 ft At BHA Pulled BHA BHA Laid out Serviced Block line Clean floor, Cut drlg line Line slipped and cut Run Casing, 13-3/8in O.D. Rigged up Casing handling equipment Equipment work completed Ran Casing to 2040.0 ft (13-3/8in OD) Hold PJSM, P/U float jts and circulate to test. Run casing. Began precautionary measures Circulated at 2040.0 ft 10 bpm, 1150 psi Obtained req. fluid properties - 200.00 %, hole vol. Mud real thick coming back. Ran Casing to 3213.0 ft (13-3/8in OD) Began precautionary measures Circulated at 3213.0 ft Obtained req. fluid properties - 150.00 %, hole vol. Ran Casing to 4393.0 ft (13-3/8in OD) Observed 50.00 klb resistance 50K drag down. 120K over to break free picking up. Circulated at 4393.0 ft Hole cleaned up, P/U and S/O back to normal. Obtained req. fluid properties - 150.00 %, hole vol. Ran Casing to 5093.0 ft (13-3/8in OD) Stopped: To pick up/lay out tubulars Installed DV collar PFLI ES cementer, Baker Lock cementer and jts above and below, Install centralizers above and below, Cement baskets below. Equipment work completed Circulated at 5220.0 ft Run Casing, 13-3/8in O.D. (cont...) Circulated at 5220.0 ft 10 bpm, 1250 psi, P/U wt 375K, S/O wt 195K Obtained req. fluid properties - 150.00 %, hole vol. Ran Casing to 6058.0 ft (13-3/8in OD) Began precautionary measures Circulated at 6058.0 ft 10 bpm, 1100 psi, P/U wt 400K, S/O wt 200K R/U Hanger, R/U Landing jt, Hold PJSM - getting casing past sands quickly. Obtained req. fluid properties - 200.00 %, hole vol. Ran Casing to 7260.0 ft (13-3/8in OD) Run csg to bottom. M/U hgr & landing jt, Land csg. Facility Date/Time West Beach Duration 14:00 14:00-15:00 1 hr 15:00 15:00-17:00 2 hr 17:00 17:00-21:00 4 hr 21:00 21:00-06:00 9 hr 21:00-23:30 2-1/2 hr 23:30 23:30-01:15 1-3/4 hr 20 Dec 98 01:15 01:15-02:00 3/4 hr 02:00 02:00-04:45 2-3/4 hr 04:45 04:45-06:00 1-1/4 hr Progress Report 06:00-12:00 6 hr 06:00-08:45 2-3/4 hr Well WB-06 Rig POOL 7 08:45 08:45-09:30 3/4 hr CONFIDENTIAL Page 12 Date 12 July 99 Activity Hanger landed Circulated at 7260.0 ft Obtained bottoms up (100% annulus volume) Rigged up Cement head R/D 'Franks' fill up tool. R/U Halliburton cementing head. O-rings cut on cmt tool, replace and R/U head again. Equipment work completed Circulated at 7250.0 ft Condition mud for surface cement job. 1.4 full circulations at 13 bpm, 1000 psi. Hold PJSM with rig hands, cementers and truck drivers. Obtained req. fluid properties - 400.00 %, hole vol. When we shut down to pump cement- MW 9.3 ppg in, 9.4 ppg out Visc. 43 in, 200 out Cement: Casing cement Mixed and pumped slurry - 750.000 bbl Test lines to 3000 psi, Drop bottom plug, Pump 50 bbl water spacer, Pump 580 bbls of lead slurry, 184 bbls of tail slurry. Drop 1st stage shut off plug. Cement pumped Displaced slurry - 1074.000 bbl Clear lines w/10 bbls water, displace w/rig at 12 bpm. Visc out, 122 at start of displacement. Plug bumped Floats held Functioned DV collar Load closing plug, Pressure to 3000 psi, ES cementer only partially opened. Pull closing plug, Drop bomb, shear open DV with 400 psi. Equipment work completed Circulated at 2165.0 ft Circulate annulus clean from the ES cementer to surface. Got contaminated mud back after pumping 760 bbls, cement back after 880 bbls. Hole cleaned up after pumping 1700 bbls. Obtained req. fluid properties - 1700.00 %, hole vol. Continued to pump until mud coming back was treated and we had enough water and Vac trucks back to do 2nd stage cement job. Pumped a total of 2800 bbls. Mixed and pumped slurry - 490.000 bbl Pumped 490 bbls by 06:00 hrs. Will continue to pump until cement back to surface. Cement: Casing cement (cont...) Mixed and pumped slurry - 1630.000 bbl Pump 1630 bbls of Permafrost 'E' cement. Drop closing plug, Clear lines w/10 bbls water. Cement pumped Displaced slurry - 314.000 bbl Displace w! rig at 10 bpm, 800 psi. Got 12.0 ppg ~,,~,,. to~,,,.,~,~ ,~..,.,_, oul .... ~ to pump. Facility Date/Time 21 Dec 98 West Beach 09:30 09:30-12:00 12:00 12:00-17:00 12:00-17:00 17:00 17:00-20:30 17:00-20:30 20:30 20:30-04:00 20:30-03:30 03:30 03:30-04:00 04:00 04:00-06:00 04:00-06:00 06:00-10:30 06:00-08:30 08:30 08:30-09:00 09:00 09:00-10:30 10:30 10:30-18:00 10:30-11:00 11:00 11:00-18:00 18:00 18:00-23:30 18:00-19:00 19:00 Progress Report CONFIDENTIAL Well WB-06 Page 13 Rig POOL 7 Date 12 July 99 Duration 2-1/2 hr 5 hr 5 hr 3-1/2 hr 3-1/2 hr 7-1/2 hr 7 hr 1/2 hr 2 hr 2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 7-1/2 hr 1/2 hr 7 hr 5-1/2 hr 1 hr Activity Bump plug, pressure to 2000 psi and close the ES Plug bumped Rigged down Handling equipment Rig down Halliburton. L/D casing Elevators, Spyders and tongs. L/D Landing joint. Drain and flush cement out of stack. Flush out mud lines, mud manifold and blow down. Clean out under shakers and auger. Equipment work completed Nipple down Divertor Removed Well control Rig down Bell nipple, flow line, diverter line. Wash cement out of surface Hydril chambers. N/D Hydril, Spacer spool and Knife valves. Equipment work completed Wellhead work Installed Casing head PFU and set Split Speedhead, P/U and set BOP stack, Test metal to metal seal to 1000 psi for 10 mins. Equipment work completed Nipple up BOP stack Rigged up Well control N/U BOPE Equipment work completed Rigged down Handling equipment B/O XO out of Franks circulating head, L/D head Equipment work completed Test well control equipment Tested Well control M/U test jt and set test plug, Test BOPE, Witnessing of test waived by State man Larry Wade Test well control equipment (cont...) Tested Well control Test BOP's as per SSD policy to 250 psi low and 5,000 psi high. Hydrill to 3,000 psi. ACCumulator drill. Began precautionary measures Held safety meeting Saftey meeting. Completed operations Tested BOP stack Test BOP's - Upper IBOP leaked Suspended pressure test on Internal BOPs, observed leak Repair Held safety meeting PJSM - change out upper IBOP. Completed operations Repaired Kelly cocks Change out upper IBOP ~ test to 250 psi low and 5,000 psi high. Equipment work completed BHA run no. 10 Rigged up Drillstring handling equipment Bails, elevators, ect. Equipment work completed Facility Date/Time West Beach 19:00-19:30 Duration 1/2 hr 1/4 hr 19:30 19:30-19:45 19:45 19:45-23:30 3-3/4 hr 1 hr 1 hr 23:30 23:30-00:30 23:30-00:30 5-1/2 hr 2-1/2 hr 22 Dec 98 00:30 00:30-06:00 00:30-03:00 1 hr 03:00 03:00-04:00 2 hr 04:00 04:00-06:00 06:00 06:00-17:30 06:00-14:30 14:30 14:30-15:00 11-1/2 hr 8-1/2 hr 1/2 hr 1/2 hr 15:00 15:00-15:30 15:30 15:30-17:00 1-1/2 hr 1/2 hr 17:00 17:00-17:30 1-1/2 hr 1-1/2 hr Progress Report CONFIDENTIAL 17:30 17:30-19:00 17:30-19:00 Well WB-06 Page 14 Rig POOL 7 Date 12 July 99 19:00 19:00-01:45 6-3/4 hr Activity Serviced Other sub-surface equipment Set wear ring and blow down choke and kill lines. Equipment work completed Held safety meeting PJSM - make up BHA. Completed operations Made up BHA no. 10 Make up BHA - 12 1/4" mill tooth bit, 9 5/8" adj motor - 1.15 deg, MWD / CDR. Orient tools. BHA no. 10 made up Repair Rigged down Top drive Change out saver sub. Equipment work completed BHA run no. 10 R.I.H. to 2129.0 ft RIH picking up 26 jts 5 1/2" HWDP and 37 jts 5 1/2" DP Began precautionary measures Circulated at 2168.0 ft Fill pipe. Surface test MWD - wash down and tagged ES cementer @ 2,168'. Observed 10.00 klb resistance Drilled cement to 2171.0 ft Drill out ES cementer @ 2,168' and rotate down to 2,370'. Blow down top drive. Completed operations BHA run no. 10 (cont...) R.I.H. to 6800.0 ft RIH picking up 5 1/2" DP to 5,250'. Circ / push junk from ES cementer ahead of bit. RIH with DP out of derrick to 6,800'. Began precautionary measures Held drill (Kick (well kill)) Circ - SPR's - D2 drill followed well kill drill. Drill abandoned R.I.H. to 7150.0 ft Blow down kill line - RIH to 7,150'. Observed 40.00 klb resistance Drilled cement to 7160.0 ft Drill on loose junk from ES cementer - high torque - rotary / motor stalling - 50 - 90K drag up and down. Stopped to test casing Circulated at 7160.0 ft Circ and condition mud for csg test. Obtained clean returns - 100.00 % hole volume Perform integrity test Tested Casing Test 13 3/8" csg to 3,000 psi. ( 13 bbls). Lost 200 psi in 30 min. Pressure test completed successfully - 2800.000 psi BHA run no. 10 Facility West Beach Date/Time 19:00-23:15 23:15 23:15-23:45 23:45 23:45-01:45 23 Dec 98 01:45 01:45-04:00 01:45-04:00 04:00 04:00-06:00 04:00-06:00 04:00-06:00 06:00-06:00 06:00-16:00 16:00 16:00-16:30 16:30 16:30-18:00 18:00 18:00-19:00 19:00 19:00-22:30 22:30 22:30-00:30 24 Dec 98 00:30 00:30-01:00 01:00 01:00-04:00 04:00 04:00-05:00 Progress Report CONFlUENT!AL Well WB-06 Page 15 Rig POOL7 Date 12July99 Duration 4-1/4 hr 1/2 hr 2 hr 2-1/4 hr 2-1/4 hr 2 hr 2 hr 2 hr 24 hr 10 hr 1/2 hr 1-1/2 hr 1 hr 3-1/2 hr 2 hr 1/2 hr 3 hr 1 hr Activity Drilled cement to 7260.0 ft Drill up loose junk from ES cementer, plugs, and landing collar, @ 7,171', cement, FC @ 7,214', and shoe @ 7,256'. CO open hole to 7,275'.D2 drill @ 2145 - 3 min. At 13-3/8in casing shoe Drilled to 7295.0 ft Drill new formation f/7,275' - 7,295'. Stopped: To circulate Circulated at 7295.0 ft Displace hole with 8.6 ppg LSND mud - Condition mud for LOT. Hole displaced with Water based mud - 100.00 % displaced Perform integrity test Performed formation integrity test Ran LOT @ .6 BPM and 1.2 BPM. Obtained leak off 13.5 ppg EMW BHA run no. 10 Drilled to 7450.0 ft Drill from 7,275' - 7,450'. ART - 1 hrs. Drilled to 7450.0 ft Drill from 7,450' - 8,140'. ART= 4 hrs, AST= 2 3/4 hrs. BHA run no. 10 (cont...) Drilled to 8140.0 ft (cont...) Drill from 7,450' - 8,140'. ART= 4 hrs, AST= 2 3/4 hrs. Stopped: To service drilling equipment Serviced Draw works Lubricate - adjust brakes. Equipment work completed Drilled to 8245.0 ft Drill from 8,140' - 8,245'. ART=I/2hr, AST-- 1/2 hr. Began precautionary measures Circulated at 8245.0 ft Circ / clean up hole. Obtained clean returns - 100.00 % hole volume Drilled to 8625.0 ft Drlg from 8,245' - 8,625'. ART= 1 3/4hrs, AST= 0 hrs. D 1 drill @ 2050 hrs - 3 min. Stopped: To service drilling equipment Installed Mud shakers Circ and clean up hole- loosing mud over shakers - change screens. Equipment work completed Circulated at 8625.0 ft Pump low / high sweep. Hi-Vis mud spotted downhole Drilled to 8851.0 ft Drill from 8,625' - 8,851'. ART=I hr, AST = 1 hr. Stopped: To service drilling equipment Serviced Mud shakers Change screens on derrick shaker and rock-over shaker. Facility Date/Time 25 Dec 98 · West Beach Progress Report Well WB-06 Rig POOL 7 CONFIDENTIAL Page 16 Date 12 July 99 05:00 05:00-06:00 06:00 06:00-16:00 06:00-08:00 08:00 08:00-12:00 12:00 12:00-13:00 13:00 13:00-13:30 13:30 13:30-14:00 14:00 14:00-16:00 16:00 16:00-22:15 16:00-18:00 18:00 18:00-22:15 22:15 22:15-06:00 22:15-06:00 22:15-06:00 06:00-06:00 06:00-17:00 17:00 17:00-18:30 18:30 18:30-00:00 Duration 1 hr 10hr 2 hr 4 hr 1 hr 1/2 hr 1/2 hr 2 hr 6-1/4 hr 2 hr 4-1/4 hr 7-3/4 hr 7-3/4 hr 7-3/4hr 24 hr llhr 1-1/2 hr 5-1/2 hr Activity Equipment work completed Drilled to 8901.0 ft Drill from 8,851' - 8,901'. AST= 3/4 hr. Started scheduled wiper trip: due to Time elapsed BHA run no. 10 (cont...) Circulated at 8901.0 ft PJSM. Circ & condition mud and hole for short trip. Pump 50 bbls weighted barafiber sweep around. Obtained req. fluid properties - 200.00 %, hole vol. Pulled out of hole to 7250.0 ft POOH to 7,250'. Hole swabbing - pump out 10 stands. At top of check trip interval Held safety meeting PJSM - Hang/W. L. sheave in derrick. Completed operations Serviced Top drive Equipment work completed R.I.H. to 8820.0 ft RIH to 8,820' - no problems. Wash 81' to bottom. D1 drill @ 1330 hrs - 2.5 min. On bottom Circulated at 8901.0 ft Circ hole clean. Obtained clean returns - 200.00 % hole volume Wellbore survey Rigged up Gyro survey instruments PJSM. RU Schlumberger / Gyro Data. Equipment work completed Took Gyro multi-shot w/line survey Ran IHR Gyro thru DP to 8,750'. RD Schlumberger. Acceptable survey obtained at 8750.0 fl BHA run no. 10 Drilled to 9520.0 ft Drill from 8,901' - 9,520'. ART = 4 hrs, AST = 1 1/4 hrs.D2 drill @ 2350 hrs - 3 min. Drilled to 9520.0 ft PJSM. Drilled from 9,520' - 10,213'. ART--4 3/4 hrs, AST = 1 hr. Spill drill @ 0810 hrs - 3 min. Coal continuosly coming over shakers. Shaker screens blinding - BHA run no. 10 (cont...) Drilled to 10213.0 ft (cont...) PJSM. Drilled from 9,520' - 10,213'. ART--4 3/4 hrs, AST = 1 hr. Spill drill @ 0810 hrs - 3 min. Coal continuosly coming over shakers. Shaker screens blinding - Started scheduled wiper trip: due to Footage drilled Circulated at 10213.0 ft Circ to clean up hole - pump low / high vis sweep around. Shaker screens plugged off w/EP mud lube - valve leaked in pits. Obtained bottoms up (100% annulus volume) Pulled out of hole to 7213.0 ft POOH to 9,730'--dragging 30K-40K over and starting Facility West Beach Duration 1-1/2 hr Date/Time 26 Dec 98 00:00 00:00-01:30 01:30 01:30-02:00 1/2 hr 1/2 hr 02:00 02:00-04:30 04:30 04:30-06:00 1-1/2 hr 1-1/2 hr 04:30-06:00 24 hr 1/2 hr 06:00-06:00 06:00-06:30 2 hr 06:30 06:30-08:30 19hr 08:30 08:30-03:30 27 Dec 98 03:30 03:30-05:30 05:30 05:30-06:00 2 hr 1/2 hr 1/2 hr 05:30-06:00 10hr 6-1/2 hr 06:00-16:00 06:00-12:30 12:30 12:30-16:00 3-1/2hr 5-1/2 hr 1 hr 16:00 16:00-21:30 16:00-17:00 4-1/2hr 17:00 17:00-21:30 Progress Report CONFIDENTIAL Well WB-06 Page 17 Rig POOL 7 Date 12 July 99 Activity Stop and circ 30 min twice - not much help. Packed At top of check trip interval Installed Mud shakers Change screen on all shakers - plugged w/EP mud lube. Equipment work completed Serviced Top drive Service top drive. Equipment work completed Installed Mud shakers Circ - new screens blinded off immediately. Change to bigger screens. Equipment work completed Circulated at 7213.0 ft Circ - treat mud system with lubricants. Circulated at 7213.0 ft Circ - treat mud system with lubricate. Hole unloading coal. BHA run no. 10 (cont...) Circulated at 7213.0 ft (cont...) Circ - treat mud system with lubricate. Hole unloading coal. Obtained req. fluid properties - 200.00 %, hole vol. R.I.H. to 10213.0 ft RIH to 10,125'. No problems hole in good shape running in. Wash to bottom @ 10,213'. On bottom Drilled to 11526.0 ft Drill from 10,213' - 11,526'. ART = 12.75 hrs, AST = 1.5 hrs. Fire drill @ 2230 hrs - 3 min. ROP dropped from 180.0 ft/hr to 80.0 fi/hr - Bit quit Circulated at 11526.0 ft Pump low / high vis sweep around - circ hole clean. Obtained clean returns - 250.00 % hole volume Pulled out of hole to 11526.0 ft Start POOH for bit / BHA change. Pulled out of hole to 11526.0 ft POOH for bit / BHA change. Hole in good shape. D1 drill @ 0900 hrs o 2.5 min. BHA run no. 10 (cont...) Pulled out of hole to 1029.0 ft (cont...) POOH for bit / BHA change. Hole in good shape. D1 drill @ 0900 hrs - 2.5 min. At BHA Pulled BHA LD BHA. Clear floor. BHA Laid out Test well control equipment Installed BOP test plug assembly Pulled wear ring and set test plug. RU to test BOP's. Equipment work completed Tested BOP stack Test BOP's as per SSD policy to 250 psi low and 5,000 psi high. Hydril to 3,500 psi. Accumulator Facility Date/Time 28 Dec 98 Duration West Beach 21:30 21:30-06:00 8-1/2 hr 21 '30-00:00 2-1/2 hr 00:00 00:00-04:00 4 hr 04:00 04:00-04:30 1/2 hr 04:30 04:30-06:00 1-1/2 hr 06:00 06:00-04:00 22 hr 06:00-08:30 2-1/2 hr 08:30 08:30-11:30 3 hr 11:30 11:30-12:00 1/2 hr 12:00 12:00-04:00 16 hr 29 Dec 98 04:00 04:00-04:30 1/2 hr 04:00-04:30 1/2 hr 04:30 04:30-06:00 1-1/2 hr 04:30-06:00 1-1/2 hr 04:30-06:00 1-1/2 hr 06:00-06:00 24 hr 06:00-01 '30 19-1/2 hr Progress Report CONFIDENTIAL 30 Dec 98 01:30 01:30-04:30 3 hr Well WB-06 Page 18 Rig POOL 7 Date 12 July 99 04:30 04:30-06:00 1-1/2 hr Activity AOGCC. Blow down and set wear bushing. Pressure test completed successfully - 5000.000 psi BHA run no. 11 Made up BHA no. 11 Make up BHA, PDC bit, 9 5/8" OD adj motor - .78 deg, ADJ Stablizer, CDR, MWD, ect. Orient tools. Surface test motor. BHA no. 11 made up R.I.H. to 5200.0 ft RIH picking up 132jts 5 1/2" drill pipe. Began precautionary measures Serviced Top drive Service top drive - fill drill pipe. Equipment work completed R.I.H. to 8427.0 ft D 1 drill @ 0530 hrs - 2.5 min. Stopped: To take survey BHA run no. 11 (cont...) Took MWD survey at 8260.0 ft Take MWD IHR check shots @ 8,353' - unacceptable. Take check shots @ 8,260'. Acceptable survey obtained at 8260.0 ft R.I.H. to 11526.0 ft No problems. Washed 180' to bottom. On bottom Functioned downhole tools at 11526.0 ft Set Andergage stablizer to full gage. Equipment work completed Drilled to 12505.0 ft Drill f/11526' - 12,505'. ART = 12 hrs, AST = 1 1/2 hrs. Mud pumps failed - Circulate Repair Repaired Mud pump fluid end Change swabs in two pumps. Equipment work completed BHA run no. 11 Drilled to 12520.0 ft Drill from 12,505' - 12,520'. 04:30-06:00 1-1/2 hr Drilled to 12520.0 ft Drill from 12,520' - 13,404'. ART = 8.5 hrs, AST = 7.5 hrs. Spill drill @ 2345 hrs - 4.5 min. BHA run no. 11 (cont...) Drilled to 12520.0 ft (cont...) Drill from 12,520' - 13,404'. ART = 8.5 hfs, AST - 7.5 hrs. Spill drill @ 2345 hrs - 4.5 min. Started scheduled wiper trip: due to Time elapsed Circulated at 13403.0 ft Circ hole clean for short trip. Obtained clean returns - 275.00 % hole volume Pulled out of hole to 11900.0 ft Observe well. Slug DP. POOH to 11,900'. No problems. Pulled out of hole to 11900.0 ft Progress Report CONFIDENTIAL Facility West Beach Well WB-06 Page 19 Rig POOL 7 Date 12 July 99 Date/Time 06:00-06:00 06:00-06:15 06:15 06:15-07:00 07:00 07:00-09:30 09:30 09:30-10:30 10:30 10:30-11:00 11:00 11:00-12:00 12:00 12:00-23:00 23:00 23:00-00:00 31Dec98 00:00 00:00-06:00 00:00-06:00 06:00-06:00 06:00-04:30 01 Jan 99 04:30 04:30-06:00 04:30-06:00 06:00-15:30 06:00-08:30 Duration 24 hr 1/4 hr 3/4 hr 2-1/2 hr 1 hr 1/2 hr 1 hr 11 hr 1 hr 6 hr 6 hr 24 hr 22-1/2 hr 1-1/2 hr 1-1/2 hr 9-1/2 hr 2-1/2 hr Activity 11,980' -11,970'. BHA run no. 11 (cont...) Pulled out of hole to 11445.0 ft (cont...) Short tripped to 11,445'. Had 30K over pull from 11,980' -11,970'. At top of check trip interval R.I.H. to 13403.0 ft PJSM - RIH -30K down drag from 12,455 -12,465'. Hole in good shape. On bottom Circulated at 13403.0 ft Circ and condition mud and hole. Observe well - sluged drill pipe. Obtained clean returns - 200.00 % hole volume Pulled out of hole to 12281.0 ft Start POOH to run RFT's. D1 drill @ 1030 hrs - 2 min. Stopped · To service drilling equipment Arco made decison to not run RFT' s. Serviced Swivel Changed swivel packing. Equipment work completed R.I.H. to 13403.0 ft RIH - Set andergage stablizer. On bottom Drilled to 14500.0 ff Drill from 13,403' -14,157'. ART=8.25 HRS, AST= 1.25 HRS. Slight increase in torque and drag picking up to make connection. Began precautionary measures Circulated at 14157.0 ft Circ - pump sweep around and clean up hole. Hole swept with slug - 100.00 % hole volume Drilled to 14577.0 ft Drill from 14,157' - 14,577'. ART = 4.25 hrs, AST -- .25 hrs. Fire drill @ 0315 hrs - 4 min. Drilled to 14577.0 ft Drilled from 14,577' - 16,042'. ART = 13.5 hrs, AST = 0 hrs. D2 drill @ 0800 hrs - 3 min, D2 drill @ 2330 hrs - 3.5 min. Cut mud wt from 9.7 ppg to 9.4 ppg. Dilute with a lot of water and new mud. BHA run no. 11 (cont...) Drilled to 14577.0 ft (cont...) Drilled from 14,577' - 16,042'. ART = 13.5 hrs, AST = 0 hrs. D2 drill @ 0800 hrs - 3 min, D2 drill @ 2330 hrs - 3.5 min. Cut mud wt from 9.7 ppg to 9.4 ppg. Dilute with a lot of water and new mud. Reached planned end of run - Section / well T.D. Circulated at 16042.0 ft Circ and condition mud and hole for short trip. Circulated at 16042.0 ft Circ and cond mud and hole for short trip. Observe well. BHA run no. 11 (cont...) Circulated at 16042.0 ft (cont...) ":-~ and cond ......... '- for ..... hip '-'~- IIUIU )tlUI t ~11 ~,, 111 I~u. Facility Date/Time 02 Jan 99 03 Jan 99 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 20 Rig POOL 7 Date 12 July 99 08:30 08:30-15:00 15:00 15:00-15:30 15:30 15:30-16:30 15:30-16:30 16:30 16:30-06:00 16:30-20:00 20:00 20:00-20:30 20:30 20:30-00:00 00:00 00:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00-14:00 06:00-11:30 11:30 11:30-14:00 14:00 14:00-06:00 14:00-15:30 15:30 15:30-17:00 17:00 17:00-01:00 01:00 01:00-01:30 01:30 01:30-02:00 02:00 Duration 6-1/2 hr 1/2 hr 1 hr 1 hr 13-1/2 hr 3-1/2 hr 1/2 hr 3-1/2 hr 4 hr 2 hr 2 hr 8 hr 5-1/2 hr 2-1/2 hr 16hr 1-1/2 hr 1-1/2 hr 8 hr 1/2 hr 1/2 hr Activity well. Obtained clean returns - 250.00 % hole volume Pulled out of hole to 7250.0 ft POOH to 13 3/8" shoe. No problems. At top of check trip interval Held safety meeting Completed operations Repair Repaired Bell nipple Change out bell nipple boot. Equipment work completed BHA run no. 11 Serviced Block line String up new drilling line. Equipment work completed Serviced Top drive Equipment work completed R.I.H. to 16042.0 ft RIH - wash 60' to bottom. No problems. On bottom Circulated at 16042.0 ft Circ and conditon mud and hole to run 9 5/8" csg. Mud wt. out 9.7 - 10.1+. Dilute with water and premix mud / lubtex. Obtained req. fluid properties - 300.00 %, hole vol. Pulled out of hole to 13000.0 ft Start POOH to run 9 5/8" csg. Pulled out of hole to 13000.0 ft POOH to run 9 5/8" casing. D1 drill @ 1130 hrs - 2 min. BHA run no. 11 (cont...) Pulled out of hole to 1026.0 ft (cont...) POOH to run 9 5/8" casing. D1 drill @ 1130 hrs - 2 min. At BHA Pulled BHA BHA Laid out Run Casing, 9-5/8in O.D. Rigged up Top ram Pulled wear bushing. Changed top rams to 9 5/8". Set test plug. Test doors seals to 3,500 psi. Equipment work completed Rigged up Casing handling equipment R. U. casers. Equipment work completed Ran Casing to 6700.0 ft (9-5/8in OD) PJSM. Ran 165 jts 9 5/8" csg. High pressure lines failed - Abort operation Serviced High pressure lines Dry lock failure on hydrolic line. Replace drylock connection. Equipment work completed Ran Casing to 7225.0 ft (9-5/8in OD) Ran total 178 jts 9 5/8" csg. Began precautionary measures Facility Date/Time 04 Jan 99 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 21 Rig POOL 7 Date 12 July 99 02:00-03:00 03:00 03:00-06:00 03:00-06:00 06:00-19:30 06:00-09:30 09:30 09:30-17:30 17:30 17:30-19:30 19:30 19:30-00:00 19:30-21:00 21:00 21:00-22:45 22:45 22:45-00:00 00:00 00:00-06:00 00:00-01:30 01'30 06:00-06:30 06:00-06:30 06:30 06:30-08:30 06:30-07:30 Duration 1 hr 3 hr 3 hr 13-1/2 hr 3-1/2 hr 8 hr 2 hr 4-1/2 hr 1-1/2 hr 1-3/4 hr 1-1/4 hr 6 hr 1-1/2 hr 1/2 hr 1/2 hr 2 hr 1 hr Activity Circulated at 7225.0 ft Circ @ 13 3/8" shoe- cleared 9 5/8" csg - 130 spm- 1200 psi. Obtained bottoms up (100% annulus volume) Ran Casing to 11190.0 ft (9-5/8in OD) Run 9 5/8" csg - 275 its in hole @ 0600 hrs. Ran Casing to 11190.0 ft (9-5/8in OD) RIH w/361 its 9 5/8" csg to 14,700'. Hole tight. Circ bottoms up and recipicate csg. Run Casing, 9-5/8in O.D. (cont...) Ran Casing to 14700.0 ft (9-5/8in OD) (cont...) RIH w/361 jts 9 5/8" csg to 14,700'. Hole tight. Circ bottoms up and recipicate csg. Observed 140.00 ldb resistance Unable to run pipe after circulating. Washed to 16042.0 ft Wash 9 5/8" csg down from 14,700' - 16,042'. Pulling Max 725K up to move csg - 140K down drag. No problem circulating - acts like we are pushing something ahead of shoe and rubble around pipe - nothing over shakers. On bottom Circulated at 16.0 ft Cftc and condition mud and hole for cement job. Recipicate pipe pulling 650K up - 250K down. Full returns. Obtained req. fluid properties - 150.00 %, hole vol. Cement: Casing cement Mixed and pumped slurry - 354.000 bbl Test lines to 3,500 psi. Howco cemented 9 5/8" csg @ 16,042' pumping 20 bbl water, 70 bbls alpha spacer @ 1 lppg, 193 bbls "G" econolite slurry @ 11.0 ppg, 161 bbls "G" @ 15.8 ppg. Tail cement pumped Displaced slurry - 1158.000 bbl Displace cement @ 12 bpm with rig pumps - recipicated pipe - full returns. Plug did not bump. CIP @ 2240 hrs. Annulus static. String displaced with Water based mud - 100.00 % displaced Floats held. Rigged down High pressure lines Rig down cement lines and cement head. Equipment work completed Wellhead work Removed Tubing head spool PU stack and tubing head. Landed 9 5/8" casing with 450K on slips. Equipment work completed Wellhead work (cont...) Tested Seal assembly Test Seal assy to 3800 psi for 15 mins Pressure test completed successfully - 3800.000 psi Nipple up BOP stack Installed BOP stack Facility Date/Time 05 Jan 99 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 22 Rig POOL 7 Date 12 July 99 07:30 07:30-08:30 08:30 08:30-13:30 08:30-12:30 12:30 12:30-13:30 13:30 13:30-06:00 13:30-17:00 17:00 17:00-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-20:30 20:30 20:30 20:30-21:30 21:30 21:30-00:00 00:00 00:00-04:00 04:00 04:00-04:30 04:30 04:30-05:30 05:30 05:30-06:00 06:00 06:00-14:30 Duration 1 hr 5 hr 4 hr 1 hr 16-1/2 hr 3-1/2 hr 1 hr 1/2 hr 1/2 hr 1-1/2 hr 1 hr 2-1/2 hr 4 hr 1/2 hr 1 hr 1/2 hr 8-1/2 hr Activity Equipment work completed Serviced Pipe ram Change rams Equipment work completed Test well control equipment Tested Well control Tested Hydril to 250/3500 psi. Tested Rams, HCR & manual choke and kill line valves, Choke manifold, Upper & lower IBOPs and Floor valves to 250/5000 psi. Pressure test completed successfully - 5000.000 psi Test witnessed by State man Lou Gramaldi Installed Wear bushing Pull test plug, Set wear bushing, Blow down choke & kill lines Equipment work completed BHA run no. 12 Made up BHA no. 12 P/U BHA, Program M~q2) tool, Orient, Load source. BHA no. 12 made up Held safety meeting Hold Safety stand down with daylight crew. Completed operations Functioned downhole tools at 457.0 ft PTSM, Test MWD, did not get test Equipment work completed R.I.H. to 1030.0 ft Run Hwt DP in hole Stopped: To pick up/lay out tubulars Laid down 574.0 ft of 5-1/2in OD drill pipe Test MWD no test, L/D 19 its of Hwt drill pipe, Test MWD again, no test. 19 joints laid out At BHA Pulled BHA Change computer settings, retest MWD-ok Stopped: To test equipment Singled in drill pipe to 3000.0 ft 87 joints picked up R.I.H. to 14700.0 ft Stopped: To test equipment Tested Casing - Via annulus and string Pressure up to test 9-5/8" casing to 3500 psi at 9 spm. Pressure test completed successfully - 3500.000 psi Held safety meeting Hold Rig safety stand down while holding pressure on casing test. Completed operations R.I.H. to 15920.0 ft Tag cement 38' above Landing collar. At Top of cement: 15920.0 ft No rotation at 37K ft/lbs BHA run no. 12 (cont...) Facility Date/Time 06 Jan 99 07 Jan 99 Progress Report CONFiDENTiAL West Beach Well WB-06 Page 23 Rig POOL7 Date 12 July 99 06:00-07:00 07:00 07:00-09:30 09:30 09:30-10:00 10:00 10:00-11:45 11:45 11:45-12:45 12:45 12:45-14:30 14:30 14:30-15:00 14:30-15:00 15:00 15:00-06:00 15:00-06:00 06:00-06:00 06:00-23:00 23:00 23:00-00:30 00:30 00:30-02:00 02:00 02:00-02:30 02:30 02:30-03:00 03:00 03:00-03:30 03:30 03:30-06:00 06:00-06:00 06:00-23:00 Duration 1 hr 2-1/2 hr 1/2 hr 1-3/4 hr 1 hr 1-3/4 hr 1/2 hr 1/2 hr 15 hr 15hr 24 hr 17hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 24 hr 17hr Activity Serviced Drillfloor / Derrick Service Top drive and rig. Spot vac trucks, crew coming on tower check out trucks, hoses, mud lines Equipment work completed Circulated at 15920.0 ft PJSM with truck drivers & crew Displace hole with GEM mud. Before disp- P/U 380, S/O 250, Rot 250, Tq 37K After disp- P/U 320, S/O 210, Rot 240, Tq 17K Hole displaced with Water based mud - 100.00 % displaced Cleared Mud shakers Clean possum belly, under shakers, flowline, hose out sand trap & mud cleaner pit. Pressure to 3500 psi on casing to get baseline for LOT with 10.5 ppg mud Equipment work completed Drilled cement to 16042.0 ft Drill cement, LC,FC,FS At 9-5/8in casing shoe Drilled to 16072.0 ft ART= 1 hr Stopped · To perform FIT Circulated at 16072.0 ft CBU, set a stand back, Pull into shoe. Obtained bottoms up (100% annulus volume) Perform integrity test Performed formation integrity test Obtained required level of integrity - 13.0 ppg EMW BHA run no. 12 Drilled to 16763.0 ft ART = 12-3/4 hrs, AST= 0 hrs FIRE DRILL @ 23:40 HRS, 4 MINS BHA run no. 12 (cont...) Drilled to 17715.0 ft ART= 14-1/2 hrs, AST= 0 hrs D2 DRILL @ 17:30 HRS, 2 MINS Started scheduled wiper trip: due to Footage drilled Circulated at 17715.0 ft Obtained clean returns - 150.00 % hole volume Pulled out of hole to 16000.0 ft At 9-5/8in casing shoe Hole in good shape Serviced Block line Line slipped and cut Serviced Top drive Equipment work completed R.I.H. to 17715.0 ft On bottom Drilled to 17816.0 ft ART= 2-1/4 hrs, AST= 0 hrs D2 DRILL @ 03:30 HRS, 4 MINS BHA run no. 12 (cont...) Drilled to 18212.0 ft ART= 15-1/2 hrs, AST= 0 hrs Facility Date/Time 08 Jan 99 09 Jan 99 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 24 Rig POOL 7 Date 12 July 99 Duration Activity 23:00 23:00-01:00 01:00 01:00-06:00 06:00-12:30 06:00-10:00 10:00 10:00-12:30 12:30 12:30-23:15 12:30-14:00 14:00 14:00-21:30 21:30 21:30-23:15 23:15 23:15-23:45 23'15-23:45 23:45 23:45-06:00 23:45-00:00 00:00 00:00-04:00 04:00 04:00-05:30 05:30 05:30-06:00 06:00-16:30 06:00-07:00 07:00 07:00-08:30 08:30 08:30-10:00 2hr 5 hr 6-1/2 hr 4 hr 2-1/2 hr 10-3/4 hr 1-1/2 hr 7-1/2 hr 1-3/4 hr 1/2 hr 1/2 hr 6-1/4 hr 1/4 hr 4 hr 1-1/2 hr 1/2 hr 10-1/2 hr 1 hr 1-1/2 hr 1-1/2 hr Reached planned end of run - Section / well T.D. Circulated at 18212.0 ft Obtained clean returns - 150.00 % hole volume Pulled out of hole to 9500.0 ft Monitor well, Pull 10 stds wet, Pump dry job, Blow down Top drive, POOH BHA run no. 12 (cont...) Pulled out of hole to 458.0 ft D1 DRILL @ 09:00 HRS, 2-1/2 MINS At BHA Pulled BHA BHA Laid out Tubular conveyed wireline work Rigged up Logging/braided cable equipment P/U Schlumberger RFT logging tool. Function test tool. Equipment work completed Ran logs on tubulars RIH with logging tool at 1 min per stand. At 9-5/8in casing shoe D1 DRILL @ 21:30 HRS, 2-1/2 MINS Rigged up Logging/braided cable equipment PJSM, R/U wireline sheaves in derrick, side entry sub, Circulate pipe while rigging up. Logging/braided cable equipment failed - Circulate Repair Repaired Logging/braided cable equipment Thaw out frozen solenoid on wireline unit. Equipment work completed Tubular conveyed wireline work Rigged up Logging/braided cable equipment Finish rig up Equipment work completed Conducted electric cable operations Run wireline in drill pipe and latch up logging tool. Synchronize tools, set tension on wire at side entry sub, Blow down Top drive. On bottom Ran logs on tubulars RIH, Log down from 16365', Lost signal from wet connect at 17587' Logging/braided cable equipment failed - Change operation Circulated at 17587.0 ft Circulate trying to clear tool and relatch Tubular conveyed wireline work (cont...) Worked toolstring at 17595.0 ft Packed off while circulating. Tried to move pipe, hung up, Work pipe pulling no more than 30K over, Gain a little each time, Free at 17540' Pipe came free Pulled out of hole to 15940.0 ft At 9-5/8in casing shoe Rigged down Logging/braided cable equipment U[ Uu.L Facility Date/Time 10 Jan 99 11 Jan 99 West Beach 10:00 10:00-16:00 16:00 16:00-16:30 16:30 16:30-06:00 16:30-18:30 18:30 18:30-01:30 01:30 01:30-06:00 06:00-06:00 06:00-15:00 15:00 15:00-21:00 21:00 21:00-21:30 21:30 21:30-06:00 06:00-05:00 06:00-09:30 09:30 09:30-14:30 14:30 14:30-17:30 17:30 17:30-20:00 Progress Report CONFiDENTiAL Well WB-06 Page 25 Rig POOL7 Date 12 July 99 Duration 6 hr 1/2 hr 13-1/2 hr 2 hr 7 hr 4-1/2 hr 24 hr 9 hr 6 hr 1/2 hr 8-1/2 hr 23 hr 3-1/2 hr 5 hr 3 hr 2-1/2hr Activity down side entry sub and W/L sheaves. Equipment work completed Pulled out of hole to 55.0 ft Pump dry job at the shoe, POOH to logging tool. At Surface ' 0.0 ft Rigged down Logging/braided cable equipment Plug into RFT tool and function test- ok. L/D tool in pipe shed Work completed, equipment laid out BHA run no. 13 Made up BHA no. 13 P/U clean out assy, 3 DCs, NB stab, 2 string stabs, Bit. BHA no. 13 made up R.I.H. to 16118.0 ft D1 DRILL @ 20:10 HRS, 2-1/2 MINS Observed 30.00 klb resistance Took weight 1 st stand out of shoe. Worked toolstring at 17260.0 ft Work through and ream tight spots f/16118' to 16683'. Ream every std f/16683'. Weight up mud system to 11.0 ppg BHA run no. 13 (cont...) Reamed to 17567.0 ft Ream and work down from 16683' to 17567'. Packed off, pulled back to 17465' before getting circulation and free rotation. Bad spot in HRZ is from 17475' to 17485' Pressure changed from 1500.0 psi to 1700.0 psi in 0.02 hr - Hole deteriorated Reamed to 17625.0 ft Bit and NB Stab are 58' into KUP No further resistance R.I.H. to 18089.0 ft Observed 30.00 klb resistance Reamed to 18164.0 ft Working our way to bottom through the Kingak Adding 1.5% GEM and 6.25 ppb Baratrol (asphalt) FIRE DRILL @ 22:20 HRS, 3 MINS BHA run no. 13 (cont...) Reamed to 18212.0 ft Ream f/18164' to bottom @ 18212' On bottom Circulated at 18212.0 ft Condition mud. Add Baratrol & GEM. Get MW back to 11.0 ppg. Pump Barofibre sweep around. Obtained req. fluid properties - 200.00 %, hole vol. Pulled out of hole to 16040.0 ft Backream out f/18106' to 17932', Tight at 17664', 17421', 16580' At 9-5/8in casing shoe D1 DRILL @ 1730 HRS, 3 MINS R.I.H. to 18212.0 ft Ream through tight spots f/17340 to 17350, 17532 to 17553. Packed off once. RIH to bottom. Facility West Beach Progress Report Well WB-06 Rig POOL 7 Page 26 Date 12 July 99 Date/Time Duration Activity 12 Jan 99 13 Jan 99 20:00 20:00-01:30 01:30 01:30-04:00 04:00 04:00-05:00 05:00 05:00-06:00 05:00-05:30 05:30 05:30-06:00 06:00-11:30 06:00-10:00 10:00 10:00-11:30 11:30 11:30-06:00 11:30-13:00 13:00 13:00-15:00 15:00 15:00-16:00 16:00 16:00-22:30 22:30 22:30-06:00 06:00-09:00 5-1/2 hr 2-1/2 hr 1 hr 1 hr 1/2 hr 1/2 hr 5-1/2 hr 4 hr 1-1/2 hr 18-1/2 hr 1-1/2 hr 2 hr 1 hr 6-1/2 hr 7-1/2 hr 3 hr On bottom Circulated at 18212.0 ft Weight up system to 11.2 ppg. Circulate Barofibre sweep around. Pump dry job. SPILL DRILL @ 2100 HRS, 2-1/2 MINS Obtained req. fluid properties - 250.00 %, hole vol. Pulled out of hole to 15835.0 ft Hole in good shape. Stopped: To test equipment Set Retrievable packer at 57.0 ft with 0.0 psi P/U RTrs and attach to drillstring, set at 57', bit at 15900' Equipment work completed Test well control equipment Installed BOP test plug assembly P/U test joint, Pull wear bushing, Set test plug. Equipment work completed Tested Well control Test well control equipment (cont...) Tested Well control Test Hydril to 250/3500 psi. Test Rams, Choke and Kill line manual & HCR valves, Choke manifold, Top drive valves & floor valves to 250/5000 psi. Test Accumulator system. Pressure test completed successfully - 5000.000 psi Witnessing of test waived by State man Chuck Scheve. Rigged down Well control Pull and lay down RTTS. Some rubber off the test plug was in the threads, had to wash out before we could stab into RTrS. Equipment work completed BHA run no. 13 R.I.H. to 17573.0 ft Ledge at formation change, top of KUP. Observed 80.00 klb resistance Reamed to 17573.0 ft Ream stand from 17530' to 17621' until we were able to work by the ledge without pumping or rotating. No pack off problems. No further resistance R.I.H. to 18212.0 ft On bottom Circulated at 18212.0 ft Circulate and condition mud. Add 2.3 ppb Soltex, 1% GEM to system. Spot 2% GEM and 1% Lubtex pill in open hole. Pump dry job. Blow down Top drive. SPILL DRILL @ 17:00 HRS, 2-1/2 MINS D2 DRILL @ 19:50 HRS, 3 MINS Obtained req. fluid properties - 300.00 %, hole vol. Pulled out of hole to 4500.0 ft Take torque & drag readings coming out. BHA run no. 13 (cont...) Facility Date/Time 14 Jan 99 Progress Report CONFiDENTIaL West Beach Well WB-06 Page 27 Rig POOL 7 Date 12 July 99 06:00-07:30 07:30 07:30-09:00 09:00 09:00-05:30 09:00-10:00 10:00 10:00-16:00 16:00 16:00-17:30 17:30 17:30-18:30 18:30 18:30-04:00 04:00 04:00-05:00 05:00 05:00-05:30 05:30 06:00-11:30 06:00-07:00 07:00 07:00-08:00 08:00 08:00-09:00 09:00 09:00-10:00 10:00 10:00~ 11:30 Duration 1-1/2 hr 1-1/2 hr 20-1/2 hr 1 hr 6 hr 1-1/2 hr 1 hr 9-1/2 hr 1 hr 1/2 hr 5-1/2 hr 1 hr 1 hr 1 hr 1 hr 1-1/2 hr Activity Pulled out of hole to 457.0 ft At BHA Pulled BHA BHA Laid out Run Liner, 7in O.D. Rigged up Casing handling equipment Work completed - Casing handling equipment in position Ran Liner to 2402.0 ft (7in OD) Run 2 jts L80 BTC, 30 jts NSCC 13Cr, 25 jts L80 Hydril 563, 3 XO jts, Baker 9-5/8" Liner Hgr/Pkr Stopped: To change handling equipment Rigged down Casing handling equipment R/D casing equip, Put Tembloc pill in pkr tie back sleeve. Change Elevators, Hook up kelly hose. Equipment work completed Circulated at 2586.0 ft Change Elevator bales, Circulate liner, P/U wt 135K, S/O wt 140K, 25 rpm, 3000 fobs tq Obtained req. fluid properties - 300.00 %, hole vol. Ran Drillpipe in stands to 15715.0 ft SPILL DRILL @ 2130 HRS, 3 MINS At 9-5/8in casing shoe Rigged up Casing handling equipment MFU Baker plug dropping tool and swivel on dbl, Stand back in derrick. Equipment work completed Circulated at 15715.0 ft Circulate hole, Check pump pressures, P/U, S/O, rotating wt & torque Obtained req. fluid properties - 25.00 %, hole vol. Run Liner, 7in O.D. Ran Drillpipe in stands to 16555.0 ft Started having a lot of drag almost as soon as we left the csg shoe. Observed 80.00 klb resistance Circulated at 16555.0 ft Began precautionary measures Circulate and rotate liner to clean up hole. Ran Liner on landing string to 16825.0 ft RIH to 16780', 100K drag, Rotate & circulate 3 liner annulus volumes. Try and circulate down. Got to 16825' hole trying to packoff if circulating while moving down. Began precautionary measures Circulated at 16825.0 ft Rotate and circulate to clean up hole. Began precautionary measures Circulate 10 liner annulus volumes. Ran Liner on landing string to 17397.0 ft RIH, Stopped at 17100', circulate and rotate, Run in to 17397' Try to circulate, packed off. Try to rotate, torque too high for liner. P/U to work pipe, 100K overpull before we got pipe to move. Facility Date/Time 15 Jan 99 16 Jan 99 West Beach Progress Report Well WB-06 Rig POOL 7 CONFiDENTiAL Page 28 Date 12 July 99 11:30 11:30-06:00 11:30-13:00 13:00 13:00-14:00 14:00 14:00-22:00 22:00 22:00-22:30 22:30 22:30-06:00 06:00-08:00 06:00-07:00 07:00 07:00-08:00 08:00 08:00-06:00 08:00-10:00 10:00 10:00-18:45 18:45 18:45-20:30 20:30 20:30-21:30 21:30 21:30-00:00 00:00 00:00-01:00 01:00 01:00-06:00 06:00-09:00 06:00-09:00 09:00 09:00-11:00 09:00-09:30 09:30 09:30-10:30 Duration 18-1/2 hr 1-1/2 hr 1 hr 8 hr 1/2 hr 7-1/2hr 2 hr 1 hr 1 hr 22 hr 2 hr 8-3/4 hr 1-3/4hr 1 hr 2-1/2 hr 1 hr 5 hr 3 hr 3 hr 2 hr 1/2 hr 1 hr Activity Observed 110.00 klb resistance Pull Liner, 7in O.D. Pulled Drillpipe in stands to 15950.0 ft At 9-5/8in casing shoe Serviced Block line Line slipped and cut Pulled Drillpipe in stands to 2402.0 ft D 1 DRILL @ 1530 HRS, 2-1/2 MINS D 1 DRILL @ 1930 HRS, 3 MINS Stopped · To change handling equipment Rigged up Casing handling equipment Rig up to L/D 7" liner. Remove Kelly hose. Equipment work completed Laid down 2402.0 ft of Liner L/D liner hanger, PJSM, L/D liner, Had some shale packed on turbolators. Cutting Baker locked jt at landing collar. Pull Liner, 7in O.D. (cont...) Laid down 2400.0 ft of Liner Cut apart and L/D Liner float jts 59 joints laid out Rigged down Casing handling equipment Equipment work completed BHA run no. 14 Made up BHA no. 14 BHA no. 14 made up R.I.H. to 16021.0 ft At 9-5/8in casing shoe Circulated at 16021.0 ft Add B aronex for HTHP Obtained req. fluid properties - 150.00 %, hole vol. R.I.H. to 17209.0 ft Observed 80.00 klb resistance Try to circulate at 17209' Packing off. Pull back to 17149' Reamed to 17245.0 ft Rotate & circulate, work stand and clean up hole from 17149' to 17245' No further resistance Worked toolstring at 17480.0 ft RIH to 17480' took weight. Start to ream, packed off. Pull back to 17361' Began precautionary measures Reamed to 17465.0 fl Ream from 17361' Packed off and backed up a couple of times. Deepest point 17487' BHA run no. 14 (cont...) Reamed to 17490.0 ft Washpipe failed - Change operation Repair Pulled out of hole to 17123.0 ft Swivel packing out. Pull back to good hole. Began precautionary measures Repaired Washpipe Facility Datefrime 17 Jan 99 18 Jan 99 Progress Report ONFiBENTI L West Beach Well WB-06 Page 29 Rig POOL 7 Date 12 July 99 10:30 10:30-11:00 11:00 11:00-06:00 11:00-00:00 00:00 00:00-00:15 00:15 00:15-02:00 02:00 02:00-06:00 06:00-13:30 06:00-07:30 07:30 07:30-11:30 11:30 11:30-13:30 13:30 13:30-14:00 13:30-14:00 14:00 14:00-06:00 14:00-14:30 14:30 14:30-16:00 16:00 16:00-18:00 18:00 18:00-05:00 05:00 Duration 1/2 hr 19hr 13hr 1/4 hr 1-3/4 hr 4 hr 7-1/2 hr 1-1/2 hr 4 hr 2 hr 1/2 hr 1/2 hr 16hr 1/2 hr 1-1/2hr 2 hr llhr Activity packing, test same. Equipment work completed R.I.H. to 17490.0 ft Began precautionary measures BHA run no. 14 Reamed to 17618.0 ft Ream and clean up HRZ. Packed off many times. Pump Barofibre sweeps every 4 hrs. FIRE DRILL @ 19:00 HRS, 2-1/2 MINS No further resistance R.I.H. to 17991.0 ft At Bottom of reservoir: 18000.0 ft Near top of the Kingak Worked toolstring at 18084.0 ft Packing off above us in the HRZ, work pipe and establish circulation and rotation. Completed operations Good circulation from 18084' Reamed to 18123.0 ft Working to bottom through the Kingak. Packing off, torque high BHA run no. 14 (cont...) Reamed to 18212.0 ft Ream through Kingak, packing off. Got it cleaned up. On bottom Circulated at 18212.0 ft Pump weighted Barofibre sweep around. Clean up hole Obtained clean returns - 250.00 % hole volume Pulled out of hole to 16025.0 ft Short trip to shoe. Overpulls- 40K @ 18010', 100K @ 17570', 80K @ 17545', 100K @ 17365' At 9-5/8in casing shoe Repair Repaired Swivel Change out Gooseneck on swivel Equipment work completed BHA run no. 14 Serviced Drillfloor / Derrick Service Drawworks and Top drive Equipment work completed R.I.H. to 18082.0 ft Tight at 17355' 17475' and 17515', Reamed through these tight spots Began precautionary measures Reamed to 18212.0 ft Precautionary ream to bottom. On bottom Circulated at 18212.0 ft Pump 2 weighted Barofibre sweeps. Add 4 ppb Baratrol (Asphalt). Weight up to 11.5 ppg FIRE DRILL @ 2400 HRS, 3 MINS Obtained req. fluid properties - 5.00 %, hole vol. Facility Date/Time 19 Jan 99 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 30 Rig POOL 7 Date 12 July 99 05:00-06:00 06:00-06:00 06:00-07:00 07:00 07:00-08:30 08:30 08:30-09:00 09:00 09:00-17:00 17:00 17:00-18:30 18:30 18:30-18:45 18:45 18:45-05:00 05:00 05:00-06:00 06:00 06:00-07:00 06:00-06:15 06:15 06:15-07:00 07:00 07:00-06:00 07:00-08:00 08:00 08:00-08:15 08:15 08:15-12:30 Duration 1 hr 24 hr 1 hr 1-1/2 hr 1/2 hr 8 hr 1-1/2 hr 1/4 hr 10-1/4 hr 1 hr 1 hr 1/4 hr 3/4 hr 23 hr 1 hr 1/4 hr 4-1/4 hr Activity Pulled out of hole to 17600.0 ft Pump dry job. Blow down Top drive. BHA run no. 14 (cont...) Pulled out of hole to 16025.0 ft Continue short trip to 9-5/8" casing shoe. Pulled 50K over at 17,575' and 70K over at 17,365' No further resistance. At 9-5/8in casing shoe R.I.H. to 18088.0 ft Light wash (50 rpm, 2 bpm) through 17,475-17,510' and 17,545-17,580'. Began precautionary measures Washed to 18211.0 ft Precautionary ream to bottom. On bottom Circulated at 18211.0 ft Pump weighted Barofiber sweep (13 ppg) @ 10 bpm, 110 rpm, reciprocating and racking back at regular intervals. No appreciable cuttings returned, sweep returned on calculated strokes. Raised MW from 11.5 ppg to 11.7 ppg. Obtained req. fluid properties - 100.00 %, hole vol. Circulated at 18211.0 ft Spot 3% Lubetex/Gem pill in openhole, pump dry job. Lo-vis mud spotted downhole Held safety meeting PTSM all hands: tripping pipe, skate safety. Completed operations Pulled out of hole to 453.0 ft Pulled 70K over at 17,573' and at 17,538'. No further resistance. Record weights and torque each 5 stds in OH and 10 stds in casing. At BHA Pulled BHA Stand back HWDP, lay down all other. Stopped · To hold safety meeting BHA run no. 14 (cont...) Held safety meeting PTSM on LD BHA Completed operations Pulled BHA Bit and stabilizer 1/16 out, same as in. 2 stands HWDP stood back. BHA Laid out Run Liner, 7in O.D. Rigged up Casing handling equipment Equipment work completed Held safety meeting PJSM on running liner. Completed operations Ran Liner to 2309.0 ft (7in OD) Made up 59 joints 7" 29#/ft plus 2 each, 20' markers, first 32joints NSCC 13-Cr, top 17 joints L-80 Hydril 563. Baker locked shoe joints, II[,.,L,I~.t IIKJClL lUllk.,tlkJll..L'k,ILII ~t'lL, ll 3tlO~l~tlt-tJllil. U~ Facility Date/Time 20 Jan 99 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 31 Rig POOL7 Date 12 July 99 12:30 12:30-13:00 13:00 13:00-13:30 13:30 13:30-14:00 14:00 14:00-14:30 14:30 14:30-00:00 00:00 00:00-02:00 02:00 02:00-04:45 04:45 04:45-06:00 04:45-06:00 06:00-08:00 06:00-07:00 07:00 07:00-08:00 08:00 08:00-15:30 08:00-10:30 Duration 1/2 hr 1/2 hr 1/2 hr 1/2 hr 9-1/2 hr 2 hr 2-3/4 hr 1-1/4 hr 1-1/4 hr 2 hr 1 hr 1 hr 7-1/2 hr 2-1/2 hr Activity ridgid centralizers 17,345' - 17,189'. Stopped: At sub-assembly Installed Liner hanger RS Nipple, 9-5/8" x 7" Baker Flex-Lock hanger, ZXP packer. Equipment work completed Ran Drillpipe in stands to 186.0 ft Ran liner on 2 stands HWDP. Stopped: To circulate Circulated at 2495.0 ft Circulated 100 bbls @ 8.5 bpm, 350 psi. PUW 140, SOW 135. Obtained bottoms up (100% annulus volume) Rigged down Casing handling equipment Equipment work completed Ran Drillpipe in stands to 15998.0 ft 60 seconds per stand as per Baker recommendation. At 9-5/8in casing shoe Circulated at 15998.0 ft Circulate 500 bbls @ 8 bpm, 900 psi. PUW =300K, SOW = 205K, RTW -- 245K, TQ=20K @ 50 rpm. Obtained bottoms up (100% annulus volume) Ran Drillpipe in stands to 18212.0 ft No resistance first -1150'. Up to 50K drag down until 17,512'. Worked through tight spots from 17,512' 17,639' w/rotary at 50 rpm and pump at 2.5 bpm. Torque 23-27K. No packing off. Ran free to TD, picked up last stand w/cmt head. Tag TD @ 18,211' On bottom Circulated at 18211.0 ft Continue rotation and circulation at TD: 50 rpm, 24-26K ft-lbs torque, 7.3 bpm, 1100 psi. 800 bbls pumped total. No packing off or downhole losses. Circulated at 18211.0 ft Position shoe 1' off bottom, initiate circulation at 2.5 bpm, 550 psi. At OH annulus volume pumped, initiate rotation 40 rpm, 24K ft-lbs, increase pump to 7.3 bpm 1100 psi at 06:00. Run Liner, 7in O.D. (cont...) Circulated at 18211.0 ft (cont...) Position shoe 1' off bottom, initiate circulation at 2.5 bpm, 550 psi. At OH annulus volume pumped, initiate rotation 40 rpm, 24K ft-lbs, increase pump to 7.3 bpm 1100 psi at 06:00. Obtained bottoms up (100% annulus volume) Set Liner hanger at 15823.0 ft with 2000.0 psi Drop LC ball and circulate to LC, set hanger w/ shoe 2' off bottom. Set down 100K lbs. Equipment work completed Cement: Liner cement Circulated at 18210.0 ft Continue circulation. Increase rate to 9.3 bpm, 1350 psi. Continue rotation. Begin batch mixing at 09:10 hrs. Facility Date/Time 21 Jan 99 West Beach 10:30 10:30-11'15 11:15 11:15-12:15 12:15 12:15-12:30 12:30 12:30-14:30 14:30 14:30-15:30 15:30 15:30-23:30 15:30-23:30 23:30 23:30-06:00 23:30-05:30 05:30 05:30-06:00 06:00 06:00-15:00 06:00-06:30 06:30 06:30-12:30 Progress Report CONFIDEN Well WB-06 Page 32 Rig POOL7 Date 12 July 99 Duration 3/4 hr 1 hr 1/4 hr 2 hr 1 hr 8 hr 8 hr 6-1/2 hr 6 hr 1/2 hr 9 hr 1/2 hr 6 hr Activity Obtained bottoms up (100% annulus volume) Second bottoms' up reached. Slurry batch mixed. Mixed and pumped slurry ~ 68.000 bbl Held safety meeting, pumped 2 bbls 3%KC1, tested Halliburton lines to 3500 psi, Pumped 70 bbls of 12.5 ppg Alpha spacer, followed by 68 bbls 15.6 ppg Latex slurry at 5.5 bpm. Dropped DP wiper dart and kicked out w/5 bbls 3% KC1. Cement pumped Displaced slurry - 419.000 bbl Switch to rig pumps (down 13 minutes to thaw surface line). Caught cement in 29 bbls pumped, continue displacement at 9.3 bpm, 1400 psi. Latched up wiper plug 40 strokes early, bumped on re-calculated strokes. Plug bumped CIP at 12:20. Pressure increase consistent w/ proper cement placement. Rotation continued until torque approached 30K ft-lbs (12 bbls shy of bump). Functioned Liner hanger Confirm bump w/1000 psi over final displacement pressure. Bleed off, check floats - okay. Set down 50K over rotating weight. Pressure up to 4000 psi to release hanger. Bleed off to 1000 psi, release running tool and initiate circulation. Equipment work completed Circulated at 15810.0 ft Circulated 30 bbls to clear liner top of cement, set down 60K lbs 3 times while rotating 20 rpm to set liner top packer. Continue circulating @ 10.5 bpm, rotating, 1000 bbls. Obtained clean returns - 150.00 % hole volume No indcation of cement or spacer in returns Cleared Cement head Equipment work completed Pull Drillpipe, 5-1/2in O.D. Pulled Drillpipe in stands to 0.0 ft Lay down 6 jts HWDP and liner runbning tool. Tool check conEmned packer set. Completed run with Setting tools to 15823.0 ft Test well control equipment Tested BOP stack Pull wear ting, install test joint, test annular 250/3500 psi, all other rams and components to 5000 psi. Test witness waived by Larry Wade, AOGCC. Pressure test completed successfully - 5000.000 psi Installed Wear bushing Pull test joint, install wear bushing. Equipment work completed BHA run no. 15 Held safety meeting Hold safety meeting on MU BHA. Clear rig floor. Completed operations Made up BHA no. 15 Facility Date/Time 22 Jan 99 Progress Report West Beach Well WB-06 Page 33 Rig POOL7 Date 12 July 99 12:30 12:30-15:00 15:00 15:00-17:00 15:00-17:00 17:00 17:00-06:00 17:00-01:00 01:00 01:00-02:00 02:00 02:00-04:00 04:00 04:00-04:30 04:30 04:30-06:00 04:30-06:00 06:00-09:30 06:00-09:30 09:30 09:30-10:30 09:30-09:45 09:45 09:45-10:30 10:30 Duration 2-1/2 hr 2 hr 2 hr 13hr 8 hr 1 hr 2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 3-1/2 hr 1 hr 1/4 hr 3/4 hr Activity to space out 9-5/8" casing scraper to 20' above BHA no. 15 made up Laid down 2350.0 ft of 5-1/2in OD drill pipe Lay down extra stands of DP from derrick. 75 joints laid out Repair Repaired Casing scraper Replace faulty 9-5/8" casing scraper (partially stuck blade prevented entry into casing at wellhead). Equipment work completed BHA run no. 15 R.I.H. to 18067.0 ft RIH on 5-1/2" DP. No indication of cement at top of liner or stringers in liner. At Top of cement: 18067.0 ft Tagged TOC 135' above LC. Drilled cement to 18112.0 ft Drilled medium-firm cement at 3 fpm, 5-1 OK lbs, 19K ft-lbs. Tagged LC 11' high to liner tally. Tagged Landing collar Circulated at 18112.0 ft 10.5 bpm, 3150 psi, rotating/reciprocating. Obtained bottoms up (100% annulus volume) Tested Casing - Via string Hold PJSM on pressure testing procedures. 5-minute test to 3500 psi - solid (30-minute test after displacement to SW). 12.4 bbls to pressure up. Pressure test completed successfully ~ 3500.000 psi Circulated at 18112.0 ft Continue circulation (while rotating/reciprocating pipe) w/seawater, 1700 bbls total. Final: 2300 psi @ 10.5 bpm. Circulated at 18112.0 ft Pump 25 bbls fresh water, 50 bbls caustic water, 20 bbls SW, 50 bbls Dirt Magnet pill, 50 bbls n-Vis pill. Chase w/SW at 10 bpm, 2950 psi, rotating / reciprocating. BHA run no. 15 (cont...) Circulated at 18112.0 ft (cont...) Pump 25 bbls fresh water, 50 bbls caustic water, 20 bbls SW, 50 bbls Dirt Magnet pill, 50 bbls n-Vis pill. Chase w/SW at 10 bpm, 2950 psi, rotating / reciprocating. Obtained clean returns - 250.00 % hole volume Perform integrity test Held safety meeting PJSM on testing procedures, high pressure hazards, spill potential. Completed operations Tested Liner Open outer annulus, close lower pipe rams, pressure test casing and liner to 3500 psi / 30 minutes. No bleed off, test recorded on chart. Pressure test completed successfully ~ 3500.000 psi Facility Date/Time 23 Jan 99 Progress Report CONFIDENTIAL West Beach Well WB-06 Page 34 Rig POOL7 Date 12 July 99 10:30-19:30 10:30-14:30 14:30 14:30-17:00 17:00 17:00-19:30 19:30 19:30-06:00 19:30-19:45 19:45 19:45-06:00 06:00 06:00-14:00 06:00-06:15 06:15 06:15-11:00 11:00 11:00-13:30 13:30 13:30-14:00 14:00 14:00-06:00 14:00-14:15 14:15 14:15-14:45 14:45 14:45-19:30 19:30 19:30-20:30 20:30 20:30-21:00 Duration 9 hr 4 hr 2-1/2 hr 2-1/2 hr 10-1/2 hr 1/4 hr 10-1/4 hr 8 hr 1/4 hr 4-3/4 hr 2-1/2 hr 1/2 hr 16hr 1/4 hr 1/2 hr 4-3/4 hr 1 hr 1/2 hr Activity Fluid system Fill pits with Brine Clean and fill pits and rockovers w/9.8 ppg NaC1 brine. Completed operations Circulated at 18112.0 ft Displace well w/9.8 ppg brine at 10.5 bpm. 1250 bbls pump total. Hole displaced with Brine - 100.00 % displaced 200 ntu's on final ruturn. Cleared Kelly/top drive hose Blow down top drive, clean trip tank and fill same w/9.8 ppg brine. Clean under shakers and 'possum belly. Equipment work completed BHA run no. 15 Held safety meeting PJSM on tripping procedures, checking equipment, proper footing and PPE. Completed operations Laid down 11400.0 ft of 5-1/2in OD drill pipe At 6700' at 06:00. Stopped · To hold safety meeting BHA run no. 15 (cont...) Held safety meeting PTSM on pipe handling and skate safety. Completed operations Laid down 2400.0 ft of 5-1/2in OD drill pipe At BHA Pulled BHA Change handling eq. to 3-1/2", Lay down BHA #15. BHA Laid out Rigged down Drillstring handling equipment Equipment work completed Electric wireline work Held safety meeting PJSM w/all hands and Schlumberger: wireline safety and pinch points. Completed operations Rigged up sub-surface equipment ~ Downhole measurement tools Make up USIT. Equipment work completed Conducted electric cable operations RIH w/USIT on e-line. No difficulty RIH nor indication of liner top. Log from PBTD (TD not tagged for tool sensitivity) to 7" liner top. Field interp: Excellent cement below 17,550', questionable to non-existent above. RD logging tools. Completed run with Downhole measurement tools from 18070.0 ft to 15823.0 ft Rigged up Lubricator ND bell nipple, NU shooting flange. Equipment work completed Held safety meeting Facility Date/Time 24 Jan 99 West Beach Progress Report Well WB-06 Rig POOL 7 CONFIDENTIAL Page 35 Date 12 July 99 21:00 21:00-22:30 22:30 22:30-03:30 03:30 03:30-06:00 03:30-06:00 06:00-22:30 06:00-21:30 21:30 21:30-22:30 22:30 22:30-06:00 22:30-22:45 22:45 22:45-23:15 23:15 23:15-23:30 23:30 23:30-06:00 Duration 1-1/2 hr 5 hr 2-1/2 hr 2-1/2 hr 16-1/2 hr 15-1/2 hr 1 hr 7-1/2 hr 1/4 hr 1/2 hr 1/4 hr 6-1/2 hr Activity radio silence. Completed operations Rigged up sub-surface equipment - Downhole measurement tools RU cased-hole RFT tool. Run checks and surface test unit. Install firing head / sample port. Equipment work completed Conducted electric cable operations RIH w/cased-hole RFT. Log up from PBTD, tie-in. Position tool at 17,608' (uppermost point requested) fire shot and collect pressure data: 3825 psi @ 8870' TVDss (8.3 ppg EMW). Re-position @ lowermost point 18,006'. Shoot sample: data unusable, POH. Completed run with Downhole measurement tools from 17608.0 ft to 18006.0 ft Conducted electric cable operations Re-dress firing/sample head, RIH to re-shoot lowermost point. Conducted electric cable operations Complete 5 runs total w/wireline, fired 9 of 10 RFT points, collected good data from 3 points: 17,608' MD / 8871' TVDss: 3825 psi (8.3 ppg EMW) 17,760' MD / 8953' TVDss: 3881 psi (8.3+ ppg EMW) 18,009' MD / 9090' TVDss: 3927 psi (8.3 ppg EMW) RD SOS Electric wireline work (cont...) Conducted electric cable operations (cont...) Complete 5 runs total w/wireline, fired 9 of 10 RFT points, collected good data from 3 points: 17,608' MD / 8871' TVDss: 3825 psi (8.3 ppg EMW) 17,760' MD / 8953' TVDss: 3881 psi (8.3+ ppg EMW) 18,009' MD / 9090' TVDss: 3927 psi (8.3 ppg EMW) RD SOS Completed logging run with RFT from 18009.0 ft to 17608.0 ft Points 1, 2, & 4 of the six requested are useable data. Other attempts failed due to, a) unable to obtain seal prior to shot (1 each) b) seal apparently broke during shot (2 each) c) plugged flow tube, no pressure response (4) Rigged up Bell nipple Discontinue radio silence, ND shooting flange, NU bell nipple, release Schlumberger. Equipment work completed Run Gas lift completion, 4-1/2in O.D. Retrieved Wear bushing Equipment work completed Rigged up Tubing handling equipment Doyon casing running services w/integral back-up tongs and Torque-Turn system. Equipment work completed Held safety meeting PJSM w/all hands: tubing running potential hazards and planned ops. Completed operations Ran Tubing to 5000.0 ft (4-1/2in OD) Baker-lock shoe jt, RIH w/7" x 4.5" Baker S-3 packer, 3 of 7}~,,~,,,,,,~,-' .... ~' ,~,l~,'~T "~~-..~ ~ .... ,~..,,~ ~r, it .....,-,-o,, Facility Date/Time 25 Jan 99 26 Jan 99 Progress Report CONFiOE, !!AL West Beach Well WB-06 Page 36 Rig POOL 7 Date 12 July 99 06:00 06:00-06:00 06:00-06:15 06:15 06:15-16:00 16:00 16:00-17:00 17:00 17:00-18:00 18:00 18:00-18:15 18:15 18:15-23:00 23:00 23:00-06:00 06:00 06:00-11:00 06:00-06:30 06:30 06:30-11:00 11:00 11:00-13:00 11:00-13:00 13:00 13:00-23:30 13:00-16:30 Duration 24 hr 1/4 hr 9-3/4 hr 1 hr 1 hr 1/4 hr 4-3/4 hr 7 hr 5 hr 1/2 hr 4-1/2 hr 2 hr 2 hr 10-1/2 hr 3-1/2 hr Activity IBT-mod tubing. 120joints of 417 in hole at Stopped · To hold safety meeting Run Gas lift completion, 4-1/2in O.D. (cont...) Held safety meeting PTSM on running tubing. Completed operations Ran Tubing to 15390.0 ft (4-1/2in OD) Continue running 4-1/2" 12.6g/ft, L-80 IBT-Mod tubing: 369 jts to SSSV. Stopped · At sub-assembly Installed SCSSSV Install 4-1/2" Camco TRM-4E flapper valve. RU Camco control line (single, bare), test to 5000 psi / 15 minutes. Equipment work completed Ran Tubing to 16210.0 ft (4-1/2in OD) Continue RIH, SS bands each joint. No indication of liner top at packer entry. Stopped · To hold safety meeting Held safety meeting PTSM on tubing running. Completed operations Ran Tubing to 17405.0 ft (4-1/2in OD) Ran 417 joint 4-1/2" 12.6~/ft, L-80 IBT-mod + 2 each 4-1/2" x 1" GLMs, 5 each 4-1/2" x 1-1/2" GLMs, 7" x 4-1/2" Baker S-3 permanent packer, 4-1/2" Camco TRSSSV, control line + 53 SS bands. Installed tbg hgr & landing joint. MU Contol line / test 5000. Hanger landed PUW = 215, SOW = 135 (including 70K top drive weight). RILDS. Note: Torque-mm revealed make-up to mark had torque ranging from 3K-5K ft-lbs. Reverse circulated at 17405.0 ft 300 bbls SW followed by 900 bbls SW inhibited w/25 gal/100-bbl Corexit. 3.0 bpm (Baker recommended maximum) 350 psi. Hole displaced with Seawater - 100.00 % displaced Prepare to drop ball, set packer. Run Gas lift completion, 4-1/2in O.D. (cont...) Rigged up High pressure lines PTSM, RU to circulate. Equipment work completed Circulated at 17405.0 ft Drop 2" / 1.38 sg shear-out sub ball. Displace @ 3.0 bpm, 200 bbls. Hesitate 30-minute intervals, followed by 8 bbl circ at 6.0 bpm 3 times, while call out slickline. Began precautionary measures Suspend operations Rig waited · Service personnel Waited on slickline unit arrival. Resumed operations Slickline wireline work Conducted slickline operations on Slickline equipment - Tool run RIII w/3.6" gaugc to 'l", ,~,~,A' ~, o~,..°T ~ · Tag ......... Facility Date/Time 27 Jan 99 Progress Report CONFiQE!X/iaL West Beach Well WB-06 Page 37 Rig POOL 7 Date 12 July 99 Duration Activity 16:30 16:30-17:00 17:00 17:00-20:00 20:00 20:00-23:30 23:30 23:30-01:00 23:30-00:00 00:00 00:00-01:00 01:00 O1:00-06:00 O1:00-05:00 05:00 05:00-05:15 05:15 05:15-06:00 05:15-06:00 06:00-07:30 06:00-07:30 07:30 07:30-09:00 07:30-09:00 09:00 09:00-15:30 09:00-15:30 1/2 hr 3 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1 hr 5 hr 4 hr 1/4 hr 3/4 hr 3/4 hr 1-1/2 hr 1-1/2- hr 1-1/2 hr 1-1/2hr 6-1/2 hr 6-1/2hr Completed run with Drift from 0.0 ft to 17415.0 ft Circulated at 17405.0 ft Re-attempt to pressure up, 10 bbls pumped at 6 bpm, pressure bleeding off to annulus. Began precautionary measures Rigged up sub-surface equipment - Slickline / braided cable RU 7" Otis Quick-Connect to landing joint, slickline packoff and cat standing valve. Equipment work completed Conducted slickline operations on Slickline equipment - Setting run RIH, set cat standing valve in XN profile at 17393'. Completed run with Slickline / braided cable from 0.0 ft to 17393.0 fl Perform integrity test Functioned Permanent packer Pressure up to 3000 psi to set packer. Pressure bleeding rapidly. Bump up to 3000 psi, monitor. 1000 psi loss in 20 minutes: 0.1 bpm flow to annulus. Began precautionary measures Tested Permanent packer - Via annulus Bleed tubing to zero, pressure annulus to 2500 psi. Attempt release from cat standing valve. Monitor pressure while POH w/slickline: 300 psi loss in 1 hr. Flow to tubing - 0.1 bpm. Suspended test, observed returns from wellbore Slickline wireline work Conducted slickline operations on Slickline equipment - Tool run Call out Schulmberger spinner/temp. At surface w/ slickline: cat standing valve still on tool. Redress valve, RIH, set in XN profile. Completed run with Slickline / braided cable from 0.0 ft to 17393.0 ft Tested Nipple plug - Via string Re-test tubing and cat standing valve prior to POH, same leak off result. Suspended pressure test on Sub-surface equipment, observed leak Retrieved Running tool POH w/cat standing valve running tool. Retrieved Running tool Continue POH w/cat standing valve running tool. RD Halliburton. Slickline wireline work (cont...) Retrieved Running tool (cont...) Continue POH w/cat standing valve running tool. RD Halliburton. Completed operations Perform integrity test Tested Permanent packer - Via annulus and string Confirm packer integrity w/2500 psi on tubing and casing. Pressures tracked and stabilized. Pressure test completed successfully ~ 2500.000 psi Electric wireline work Conducted electric cable operations r~ Facility Date/Time 28 Jan 99 i ! West Beach Progress Report Well WB-06 Rig POOL 7 CONFIDENTIAL Page 38 Date 12 July 99 15:30 15:30-01:30 15:30-01:30 01:30 01:30-03:00 01:30-03:00 03:00 03:00-06:00 03:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00-16:00 06:00-09:30 09:30 09:30-11:30 11:30 11:30-16:00 16:00 16:00-18:00 16:00-17:00 17:00 17:00-18:00 18:00 18:00-19:00 18:00-18:15 18:15 18:15-19:00 Duration lOhr lOhr 1-1/2 hr 1-1/2 hr 3 hr 2 hr 1 hr 1 hr 10hr 3-1/2 hr 2 hr 4-1/2 hr 2 hr 1 hr 1 hr 1 hr 1/4 hr 3/4 hr Activity spinner/temp/CCL. RIH to 10,000: tool failure, POH. Tool Completed misrun with Spinner to 10000.0 ft Slickline wireline work Conducted slickline operations on Slickline equipment - Retrival run RU Halliburton, retrieve RP shear valve at 17,230' after two failed attempts. Completed run with Side pocket valve from 17230.0 ft to 0.0 ft Fluid system Reverse circulated at 17.0 ft Displace 9.8 brine in tubing (excess pumped in attempt to set packer) from tubing w/300 bbls inhibited SW. Hole displaced with Seawater - 100.00 % displaced Slickline wireline work Conducted slickline operations on Slickline equipment - Setting run RIH w/1" dummy valve, hung up in GLM #6 at 7017'. POH, check and redress tool. Completed misrun with Side pocket valve to 7017.0 ft Conducted slickline operations on Slickline equipment - Setting mn Re-run dummy GLV. Conducted slickline operations on Slickline equipment - Setting run Re-run dummy GLV to lowermost GLM at 17,230'. Attempt to set valve, POH, valve not set. Slickline wireline work (cont...) Conducted slickline operations on Slickline equipment - Setting mn (con' ...) Re-run dummy GLV to lowermost GLM at 17,230'. Attempt to set valve, POH, valve not set. Completed misrun with Side pocket valve to 17230.0 ft Conducted slickline operations on Slickline equipment - Setting run Check tool and re-dress dummy valve. RIH to 3000' w/high drag, POH check tool. Completed misrun with Side pocket valve to 3000.0 ft No obvious reason for high drag. Conducted slickline operations on Slickline equipment - Setting run Re-mn dummy GLV (slow RIH first 7000' due to high drag). Set GLV in mandrel, POH. Completed run with Side pocket valve to 17230.0 ft Perform integrity test Tested Tubing Pressure test tubing to 3500 psi / 30-minutes. <100 psi bleed off. Pressure test completed successfully - 3500.000 psi Note: RP valve disassmbly and inspection revealed a failed O-ring and markings where wash-out had occurred. Tested Permanent packer Test annulus to 3500 psi / 30-minutes: <50psi bleed off. Pressure test completed successfully - 3500.000 psi Wellhead work Held safety meeting PTSM on ND procedures and safety. Completed operations Installed BOP test plug assembly Install TWC, test same to 500 psi from top side. Facility Date/Time 29 Jan 99 30 Jan 99 .. ! Progress Report CONFIDENTIAL West Beach Well WB-06 Page 39 Rig POOL7 Date 12July99 19:00 19:00-06:00 19:00-06:00 19:00-06:00 06:00-12:00 06:00-12:00 12:00 12:00-18:30 12:00-17:00 17:00 17:00-18:30 18:30 18:30-23:30 18:30-19:30 19:30 19:30-23:30 23:30 23:30-05:00 23:30-01:00 01:00 01:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 Duration llhr llhr llhr 6 hr 6 hr 6-1/2 hr 5 hr 1-1/2 hr 5 hr 1 hr 4 hr 5-1/2 hr 1-1/2 hr 4 hr 1 hr 1 hr Activity Equipment work completed Nipple down BOP stack Rigged down BOP stack Flush choke line. Disassemble rams; clean and inspect same. ND annular preventor and dual rams. Grease same for de-mob storage. Rigged down BOP stack PJSM w/day tour on ND procedures and cold weather safety. ND choke & kills, Hydril, double ram mud cross, single ram, manuals and HCR. Nipple down BOP stack (cont...) Rigged down BOP stack (cont...) PJSM w/day tour on ND procedures and cold weather safety. ND choke & kills, Hydril, double ram mud cross, single ram, manuals and HCR. Equipment work completed Wellhead work Installed Xmas tree NU adapter flange and tree. Test tubing hanger, tree, and 9-5/8" packoff to 5000 psi. Equipment work completed Removed Hanger plug Pull TWC, some difficulty due to ice. Equipment work completed Slickline wireline work Conducted slickline operations on Slickline equipment - Retrival run Start in hole w/GLV kick over tool, ice at wellhead. Pick up gage drift, RIH to 2000'. Completed run with Drift from 0.0 ft to 2000.0 ft Conducted slickline operations on Slickline equipment - Retrival run RIH w/GLV retrieving tool to 2nd GLM at 7017'. Very slow RIH from 4000-7000' due to inclination (-50 fpm). Pull dummy GLV, POH. Completed run with Kickover tool from 0.0 ft to 7017.0 ft GLV recovered. Fluid system Freeze protect well - 135.000 bbl of Diesel RD Halliburton slickline. Freeze protect 13-3/8" x 9-5/8" annulus to 2200' TVD w/135 bbls Diesel at 80 F. Pumped at 3.0 bpm, final pressure: 850 psi. Completed operations Freeze protect well - 310.000 bbl of Diesel Pumped 310 bbls 80 F diesel down 9-5/8" x 4-1/2" annulus at 3.0 bpm. U-tube to tubing side for freeze protection to 4500' MD / 3500' TVD, tubing and inner annulus. Completed operations Wellhead work Installed Hanger plug Install BPV, Secure tree. OAP = 0, IAP = 0, TBG = 0. Began precautionary measures RIG RELEASED: 17:00 hrs 1/29/99. (Release time backed out 13 hrs for ND BOPs in components which required 13 hrs longer than thc benchmark 4.0 Facility West Beach Progress Report Well WB-06 Rig POOL 7 CONFIDENTIAL Page 40 Date 12 July 99 Date/Time Duration Activity hrs). Begin de-mob to West Dock Staging Area. CONFIDENTIAL West Beach 06 Post-Rig Completion Work Chronology ARCO and Exxon request that the information provided below be kept confidential to the fullest extent allowed or required by law, including AS 31.05.035(d), AS 38.05.035(a)(9) and AS 43.05.230. The work summarized below has been conducted in accordance with the requirements of AAC 20 25.280 and consistent with ARCO Alaska, Inc. Prudhoe Bay Unit standard wellwork practices. Detail reports can be furnished upon request. Date 1/30/99 2/4/99 2/5/99 2/27/99 2/27/99 2/28/99 3/1/99 3/2/99 3/3/99 3/4/99 3/5/99 3/6/99 3/7/99 3/9/99 3/12/99 3/13/99 3/14/99 3/15/99 Activity Description Pool 7 rig released from well Pool 7 rig and equipment off pad Pipeline construction and road crossings in progress; no wellwork allowed on pad. Pipeline pad construction work complete Initial perforation work initiated (depths reference Schlumberger USIT dated 1/23/99): Shot: 18,070' to 18,090' MD, 4 SPF, 60° phasing using 3 3/8" guns, 4lB charges. Initial perforation work continued (depths reference Schlumberger USIT dated 1/23/99): Shot: 18,010' to 18,070' MD, 4 SPF, 60° phasing using 3 3/8" guns, 4lB charges Initial perforation work continued (depths reference Schlumberger USIT dated 1/23/99): Shot: 17,950' to 18,010' MD, 4 SPF, 60° phasing using 3 3/8" guns, 4lB charges Initial perforation work continued (depths reference Schlumberger USIT dated 1/23/99): Shot: 17,890' to 17,950' MD, 4 SPF, 60° phasing using 3 3/8" guns, 4lB charges Initial perforation work completed (depths reference Schlumberger USIT dated 1/23/99): Shot: 17,860' to 17,890' MD, 4 SPF, 60° phasing using 3 3/8" guns, 4lB charges Static Bottomhole Pressure Survey; pressure at 8800' SS datum = 3777 psi (17,476' MD); BHT = 176° F; tubing pressure 450 psi, casing pressure 1000 psi. Attempt to set SSSV isolation sleeve, tight spot at 330'. Swedge tight spot, run SSSV isolation sleeve at 1973' in preparation for frac. Treatment. Hydraulic fracture treatment attempt #1. Initial tubing pressure 801 psi, casing pressure 1000 psi. · Pumped 550 bbl. perforation breakdown treatment at 25 bpm, 7650 psi. Initial shut-in pressure 3048 psi, frac gradient 0.77 psi/ft. · Pumped 500 bbl. datafrac with 50 ppt. gel loading. Treating pressure 6450 psi at 25 bpm. Initial shut-in pressure 3580 psi, fluid efficiency estimated at 19%. · Pumped hydraulic fracture treatment as follows: 600 bbl. pad (50 ppt. gel loading, subsequent stages 40 ppt. gel loading), 70 bbl. 1 ppg 20/40 Carbolite, 100 bbls. 3 ppg 20/40, ramped to 12 ppg. over next 390 bbls. While treating, several pumps went off line dropping rate from 25 to 20 bpm and spiking concentration, which caused a near well screenout when high proppant concentration hit perforations. Placed 30,066 lbs. 20/40 Carbolite in formation out of 102,759 lbs. pumped. Perform coiled tubing fill cleanout to 18,075' MD Drift to 4080', tag proppant fill. Pull SSSV isolation sleeve. Attempt coiled tubing fill cleanout. Pump failed. Rig down. Perform coiled tubing fill cleanout to 17,520' MD in prep. to refrac, the well. Drift and tag at 17,967'. Set SSSV isolation sleeve at 1975'. Page 1/3 CONFIE)ENTI L West Beach 06 Post-Rig Completion Work Chronology ARCO and Exxon request that the information provided below be kept confidential to the fullest extent allowed or required by law, including AS 31.05.035(d), AS 38.05.035(a)(9) and AS 43.05.230. 3/17/99 3/18/99 3/19/99 3/20/99 3/22/99 3/23/99 3/24/99 3/30/99 4/1/99 4/12/99 4/13/99 4/14/99 4/15/99 4/16/99 4/18/99 4/23/99 4/25/99 4/26/99 4/27/99 4/28/99 5/2/99 5/14/99 5/15/99 5/16/99 Hydraulic fracture treatment attempt #2. Initial tubing pressure 65 psi, casing pressure 0 psi. · Pumped 740 bbl. perforation breakdown treatment at 25 bpm, 5100 to 5900 psi. Initial shut-in pressure 2613 psi, frac gradient 0.72 psi/ft. · Pumped 500 bbl. datafrac with 50 ppt. gel loading. Treating pressure 5500 psi at 25 bpm. Initial shut-in pressure 2362 psi, fluid efficiency estimated at 21%. · Pumped hydraulic fracture treatment as follows: 600 bbl. pad (50 ppt. gel loading), 1 ppg. 20/40 Carbolite ramped linearly to 10 ppg max. concentration. While treating with 6 ppg on perforations, lost suction on pumps for approximately 2 minutes. Screened out early due to mechanical/operational problems. Placed 38,395 lbs. 20/40 Carbolite in formation out of 111,477 lbs. pumped. Perform coiled tubing fill cleanout to 9500'. Continue coiled tubing fill cleanout reversing out frac sand from 9500' to 18,090'. Drift tubing and tag top of fill at 18,071' Pull SSSV isolation sleeve; set catcher sub at 7560', attempt to pull station #2 DGLV (6990'); mandrel packed with frae. Sand. Brush station #2 mandrel at 6990', pull station #2 DGLV. Set ¼" OGLV in station #2 mandrel, pull catcher sub. Begin raw lift operations utilizing West Beach 04 (WB-04) as source well. Install LGLV in station #1 at 2575' to allow well to unload using WB-04. Drift tubing for hydrates/paraffins and tag fill at 18,033' MD Rig up to move OGLV to deeper station and run memory pressure gauge; found ice at 2827'. Hot oil tubing with 145 bbls crude. Post hot oil drift to 17360'. Tag fill at 18037', set catcher sub at 17360'. Pull station #7 DGLV (17,201 ') and run side pocket mandrel memory gauge in station #7, pull station #20GLV (6990') Pull station #4 DGLV (12,168'), run ¼" OGLV in station #4, run LGLV in station #2 (6990'), pull catcher sub at 17,360'. Restart gas lift operations using WB-04 as gas source well. Well flowing at low rates and very cold, can not sustain production, plan to refrac, the interval. (refer to test summary below). Pre-frae drift and tag hit paraffin at 2050' work to 2370'. Rig down. Hot oil tubing to remove hydrates and paraffin, pumped 250 bbls. hot crude. Run catcher sub, set at 17362'. Pull memory gauge from station #7 at 17211', run DGLV in station #7. Pull catcher sub at 17,362'. Drift and tag at 18,039'. Set catcher sub at 17,372' in prep. for GLV change-out (pre-frac). Pull station #40GLV (12,164'), station #2 LGLV (6,994'), station #1 LGLV (2572'); place DGLVs in stations #1 & #2, RDMO Load 9-5/8" with 650 bbls. crude, set DGLV in station #4 @ 12,164'. Pressure test 9-5/8" to 3000 psi with 1500 psi on tubing. Pull catcher sub, tag fill at 18,037'. Set SSSV isolation sleeve at 1976'. Page 2/3 CONFIEIENTI/ L West Beach 06 Post-Rig Completion Work Chronology ARCO and Exxon request that the information provided below be kept confidential to the fullest extent allowed or required by law, including AS 31.05.035(d), AS 38.05.035(a)(9) and AS 43.05.230. 5/19/99 5/21/99 5/23/99 5/24/99 5/25/99 5/26/99 5/27/99 5/28/99 5/29/99 5/30/99 6/3/99 6/5/99 6/11/99 Hydraulic fracture treatment attempt g3. Initial tubing pressure 860 psi, casing pressure 0 psi. · Pumped 400 bbl. Pre-pad of 20 ppt gel at 25 to 35 bpm with pressures ranging from 5900 to 8200 psi. Initial shut-in pressure 1492 psi, frac gradient 0.6 psi/ft. · Pump 500 bbl. Breakdown with 2 ppg scour stage. Max. rate 28 bpm. Good reduction in near well friction losses. Initial shut-in pressure 1615 psi, frac. gradient 0.61 psi/fi. · Pumped 500 bbl. datafrac with 50 ppt. gel loading at 25 bpm. Initial shut-in pressure 1725 psi, fluid efficiency estimated at 12%. · Pumped hydraulic fracture treatment as follows: 600 bbl. pad (50 ppt. gel loading), 1 ppg. 20/40 Carbolite ramped linearly to 10 ppg max. concentration. Placed 124,655 lbs. 20/40 Carbolite in formation out of 127,167 lbs. pumped. Perform coiled tubing fill cleanout to 18,076'; freeze protect to 4500' with crude Pull SSSV isolation sleeve, fish tree saver rubber and metal; tag at 18,090', set catcher sub at17,375' Pull station g7 DGLV @ 17,221', pull station g6 DGLV @ 16,291', pull station g5 DGLV @ 14,584'. LDFN Pull station g3 DGLV @ 9492', pull station gl DGLV @ 2572', run LGLV station gl, run LGLV station g3, run LGLV station g5, LDFN Place memory pressure gauge in station #6 @ 16,291, attempt to set OGLV in station #7, RDMO Brush station g7 @ 17221', set ~,4" OGLV in station #7. Pull catcher sub at 17,375'. Begin unloading well with dry gas! Will not unload below station gl, suspect bad LGLV. Drift/Tag .... hydrates at 822'. RDMO Jet out hydrates with coiled tubing from 850' to 1200'; tag fill at 17979', reverse out to 18,100', displace well to crude; position nozzle at 17,300' and begin lifting to tank using nitrogen. Well returning approximately 1200 BFPD. Drift and tag at 17,899', set catcher sub at 2680', pull station gl (2572') LGLV, run station gl DGLV, pull catcher sub. RD. First Test: 2406 STBOPD, 705 BWPD, 497 scf/stbo GOR. (refer to test summary). Rig up to pull memory gauge at 16,291', tagged fill at 15,964'; RDMO Construction crews on pad; all wellwork is on hold pending completion of manifold installation; estimated completion date July 7, 1999 Below are planned additional initial perforation intervals which have not been completed. ARCO Alaska, Inc.will file a Report of Sundry Well Operations (Form 10-404) within 30 days after completion of the perforating listed below; all depths reference Schlumberger MWD CDR/AND recorded 1/3/99 to 1/8/99: 17,570' MD to 17,680' MD (8850' SS to 8909' SS) 17,735' MD to 17,810' MD (8939' SS to 8980' SS) Page 3/3 Anadrill/Schlumberger Survey Report WELL INFORMATION TD Date: Run 8 Client: Fid& Well Name: Permanent datum: Depth measured from: Elevation of kelly bushing: Elevation of rig floor: Elevation of ground level: Magtetic Declination: Grid Convergence: Total Correction: TIE IN POINT Measured Depth: True Vertical Depth: Inclination: Azimuth: N/S displacement: E/W displacement: Azimuth from rotory table to target: 9 January, 1999 ARCO Alaska Inc. West Beach WB-06 Mean Sea Level RKB 0.00 51.80 11.10 .27.98 0.00 26.05 (IHR) 0.00 0.00 0.00 0.00 0.00 0.00 73.2 ORIGINAL RECEIVED FEB 01 1999 Alaska Off & Gas C°ns. Commission Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Survey depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ Type (ft) (deg) (deg) (ft) (It) (ft) (fi) (It) (ft) (de<j) 1000 0 0.00 0 0 0 0 0 100 0.16 108.1 100.00 100.00 0.11 -0.04 200 0.30 67.5 100.00 200.00 0.49.. 0.0.1 300 0.88 43.0 100.00 299.99 1.41 0.68 400 1.06 55.8 100.00 399.98 2.96 1.76 5O0 1.59 57.4 600 2.20 50.1 7O0 4.7O 43.4 800 5.77 42.9 900 6.06 44.7 1000 6.81 51.5 1100 7.51 55.2 1200 7.88 62.2 1300 8.59 68.8 1400 9.93 70.2 1500 11.22 69.9 1600 11.68 71.2 0 0.13 0.51 1.27 2.56 0 0.14 0.51 1.44 3.11 0 0 TIP 108.10 0.16 MWD M 88.48 0.21 MWD M 62.06 0.62 MWD M 55.56 0.28 MWD M 100.00 499.95 5.18 3.02 4.50 5.42 56.07 0.53 MWD_M 100.00 599.90 8.28 5.01 7.13 8.72 54.95 0.66 MWD_M 100.00 699.71 13.60 9.22 11.42 14.68 51.10 2.53 MWD_M 100.00 799.29 21.50 15.88 17.66 23.75 48.04 1.07 MWD_M 100.00 898.76 30.48 23.31 24.79 34.03 46.76 0.34 MVVD_M 998.13 40.63 30.75 33.15 45.21 47.14 1.07 MWD_M 1097.35 52.36 38.17 43.15 57.61 48.50 0.84 MWD_M 1196.45 65.31 45.10 54.58 70.80 50.43 1.01 MWD_M 1295.42 79.48 51.00 67.61 84.69 52.97 1.18 MWD_M 1394.11 95.54 56.62 82.68 100.21 55.60 1.36 MWD_M 100.00 100.00 100.00 100.00 100.00 100.00 100.00 1492.41 113.87 62.88 99.93 118.07 57.82 1.29 MWD_M 1590.42 133.70 69.49 118.65 137.50 59.64 0.53 MWD_M Page 1 Measured depth fit) 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 330O 3350 3400 3450 3500 355O 3600 3650 3700 3750 3800 Incl angle (deg) 12.00 13.28 13.71 14.13 14.48 15.14 16.06 16.66 17.68 19.12 20.24 22.59 24.23 26.31 28.12 29.28 30.91 31.70 32.87 33.97 35.50 37.70 39.48 41.06 43.13 44.62 46.50 48.21 49.70 51.69 53.44 55.29 56.98 58.58 60.59 62.43 63.86 65.20 65.45 65.76 65.20 65.10 65.88 66.22 Azimuth angle (deg) 72.2 75.8 78.4 79.1 79.0 78.4 78.6 77.8 76.6 75.7 74.3 72.4 71.4 70.3 70.1 70.2 70.6 71.0 71.9 72.4 72.5 72.4 71.8 71.7 71.8 72.0 73.1 74.0 74.3 74.5 74.6 75.0 75.9 76.3 76.3 76.2 76.5 76.6 77.0 77.9 78.8 78.9 78.4 77.9 Course length 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 5O.O0 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth fit) 1639.36 1688.15 1736.77 1785.30 1833.75 1882.09 1930.25 1978.22 2025.99 2073.43 2120.51 2167.06 2212.94 2258.15 2302.62 2346.47 2389.73 2432.45 2474.72 2516.45 2557.54 2597.68 2636.76 2674.91 2712.01 2748.05 2783.06 2816.93 2849.76 2881.43 2911.83 2940.96 2968.82 2995.47 3020.79 3044.64 3067.22 3088.72 3109.60 3130.25 3151.00 3172.01 3192.75 3213.05 Vertical section fit) 143.95 154.89 166.52 178.49 190.78 203.50 216.89 230.92 245.65 261.41 278.23 296.49 316.35 337.67 360.50 384.48 409.52 435.48 462,17 489.71 518.19 548.00 579.18 611.49 645.00 679.64 715.33 752.11 789.81 828.49 868.18 908.80 950.28 992.53 1035.58 1079.46 1124.00 1169.06 1214.40 1259.81 1305.11 1350.26 1395.54 1441.06 Displ +NIS- fit) 72.71 75.71 78.31 80.65 83.00 85.52 88.21 91.09 94.36 98.15 102.51 107.75 113.93 120.94 128.69 136.84 145.25 153.81 162.33 170.77 179.36 188.34 197.93 208.05 218.55 229.31 240.01 250.42 260.72 271.13 281.70 292.39 302.85 313.01 323.22 333.67 344.19 354.69 365.07 374.96 384.15 392.92 401.87 411.26 Displ fit) 128.39 138.91 150.28 162.08 174.21 186.74 199.91 213.70 228.09 243.41 259.67 277.15 296.03 316.19 337.71 360.29 383.91 408.44 433.75 459.96 487.12 515.54 545.22 575.91 607.74 640.68 674.74 710.01 746.28 783.55 821.81 861.02 901.19 942.25 984.14 1026.83 1070.17 1114.08 1158.31 1202.76 1247.31 1291.82 1336.43 1381.15 Total displ (ft) 147.55 158.20 169.46 181.04 192.97 205.39 218.51 232.30 246.84 262.45 279.17 297.36 317.20 338.53 361.39 385.40 410.47 436.44 463.13 490.64 519.09 548.87 580.04 612.34 645.84 680.48 716.15 752.88 790.52 829.13 868.75 909.31 95O.72 992.88 1035.86 1079.68 1124.16 1169.18 1214.48 1259.85 1305.13 1350.26 1395.54 1441.08 (deg) 60.48 61.41 62.48 63.54 64.52 65.39 66.19 66.91 67.52 68.04 68.46 68.75 68.95 69.07 69.14 69.20 69.28 69.36 69.48 69.63 69.79 69.93 70.05 70.14 70.22 70.31 70.42 70.57 70.74 70.91 71.08 71.24 71.42 71.62 71.82 72.00 72.17 72.34 72.51 72.69 72.88 73.08 73.26 73.42 DLS (deg/ lOOt) Survey Type 0.76 MWD_M 3.00 MVVD M 1.49 MWD M 0.90 MVVD M 0.70 MWD M 1.37 MVVD_M 1.85 MWD M 1.28 MWD M 2.16 MWD M 2.94 MVVD M 2.43 MWD M 4.90 MVVD M 3.37 MWD_M 4.26 MWD M 3.62 MWD M 2.32 MWD M 3.28 MWD M 1.61 MVVD M 2.57 MVVD M 2.27 MWD M 3.06 MWD M 4.40 MWD M 3.64 MWD M 3.16 MWD M 4.14 MWD_M 2.99 MWD M 4.O7 MWD M 3.67 MWD M 3.01 MWD M 3.99 MWD M 3.50 MWD M 3.73 MWD M 3.77 MWD M 3.27 MWD M 4.02 MWD M 3.68 MWD M 2.91 MWD M 2.69 MWD M 0.88 MWD M 1.75 MWD M 1.98 MWD_M 0.27 MWD M 1.81 MWD_M 1.14 MWD M Page 2 Measured depth (ft) 3850 3900 3950 4000 4O50 4100 4150 4200 4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 5200 5250 53OO 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850 5900 5950 6000 IncI angle (deg) 66.34 65.79 65.57 65.45 64.77 64.81 65.70 67.44 67.97 67.76 67.88 67.25 66.70 66.07 65.37 64.99 64.31 63.38 61.70 6O.36 61.07 61.34 61.81 62.25 62.69 63.35 63.29 63.31 63.09 63.24 64.13 63.89 63.52 63.28 63.14 64.06 64.20 64.O0 63.93 64.04 64.48 63.62 63.74 63.80 Azimuth Course TVD Vertical Displ Displ Total At DLS Survey angle length depth section +N/S- +E/tN- displ Azim (deg/ Type (deg) (ft) (It) (fl) (ft) (it) (ft) (deg) 1000 78.0 50.00 3233.16 1486.68 420.81 1425.92 1486.72 78.2 50.00 3253.45 1532.21 430.24 1470.63 1532.28 78.5 50.00 3274.04 1577.59 439.44 1515.26 1577.69 79.3 50.00 3294.77 1622.86 448.24 1559.90 1623.02 79.2 50.00 3315.81 1667.97 456.74 1604.45 1668.20 79.4 50.00 3337.11 1712.95 465.17 1648.90 1713.26 78.4 50.00 3358.04 1758.13 473.96 1693.45 1758.52 76.7 50.00 3377.92 1803.87 483.85 1738.24 1804.33 76.0 50.00 3396.89 1850.06 494.77 1783.20 1850.56 75.8 75.9 76.1 76.5 76.6 50.00 50.00 50.00 50.00 50.00 3415.73 1896.33 506.09 1828.11 1896.87 3434.60 1942.58 517.45 1872.99 1943.15 3453.69 1988.74 528.63 1917.83 1989.36 3473.24 2034.68 539.53 1962.54 2035.35 3493.27 2080.42 550.18 2007.10 2081.14 76.6 50.00 3513.83 2125.91 560.75 2051.43 2126.69 76.9 50.00 3534.82 2171.20 571.15 2095.61 2172.04 77.0 50.00 3556.23 2216.29 581.35 2139.62 2217.20 77.4 50.00 3578.27 2261.06 591.29 2183.39 2262.04 78.0 50.00 3601.32 2305.28 600.75 2226.73 2306.35 78.4 50.00 3625.54 2348.86 609.69 2269.55 2350.02 78.3 50.00 3650.00 2392.29 618.50 2312.26 2393.56 77.8 50.00 3674.08 2435.95 627.57 2355.13 2437.31 77.3 50.00 3697.88 2479.79 637.05 2398.07 2481.24 77,0 50.00 3721.33 2523.84 646.87 2441.12 2525.38 50.00 50.00 50.00 50.00 50.00 76.7 76.6 76.3 76.3 76.3 3744.44 3767.13 3789.58 3812.04 3834.59 2568.09 2612.56 2657.17 2701.77 2746.33 656.96 2484.30 2569.70 667.25 2527.65 2614.24 677.72 2571.08 2658.91 688.30 2614.48 2703.57 698.87 2657.84 2748.19 76.3 50.00 3857.16 2790.88 709.43 2701.19 2792.80 76.5 50.00 3879.32 2835.62 719.97 2744.75 2837.61 76.6 50.00 3901.23 2880.49 730.43 2788.46 2882.54 76.7 50.00 3923.38 2925.23 740.78 2832.08 2927.35 76.9 50.00 3945.77 2969.85 750.98 2875.60 2972.05 77.1 50.00 3968.31 3014.38 761.02 2919.09 3016.66 77.1 50.00 3990.54 3059.06 771.02 2962.75 3061.43 77.5 50.00 4012.36 3103.93 780.91 3006.63 3106.39 77.7 50.00 4034.20 3148.78 790.57 3050.56 3151.34 77.9 50.00 4056.14 3193.55 800.07 3094.47 3196.23 77.8 50.00 4078.07 3238.34 809.52 3138.40 3241.13 77.7 50.00 4099.79 3283.23 819.08 3182.42 3286.13 77.7 50.00 4121.67 3328.05 828.66 3226.34 3331.06 77.8 50.00 4143.83 3372.72 838.17 3270.14 3375.84 78.0 50.00 4165.93 3417.42 847.61 3313.98 3420.66 73.56 73.69 73.83 73.97 74.11 74.25 74.36 74.45 74.49 74.53 74.56 74.59 74.63 74.67 74.71 74.75 74.80 74.85 74.90 74.96 75.02 75.08 75.12 75.16 75.19 75.21 75.23 75.25 75.27 75.28 75.30 75.32 75.34 75.36 75.39 75.41 75.44 75.47 75.50 75.54 75.57 75.60 75.62 75.65 0.30 MWD M 1.16 MWD M 0.70 MWD M 1.30 MWD M 1.36 MWD M 0.20 MWD M 2.42 MWD_M 4.67 MWD M 1.67 MWD M 0.70 MWD M 0.44 MWD._M 1.31 MWD_M 1.32 MWD M 1.27 MWD M 1.40 MWD M 0.93 MWD M 1.37 MWD M 1.99 MWD M 3.52 MWD M 2.77 MWD M 1.43 MWD M 1.03 MWD M 1.29 MWD M 1.03 MWD M 1.03 MWD M 1.33 MWD M 0.55 MWD M 0.04 MWD M 0.44 MWD_M 0.30 MWD M 1.82 MWD M 0.51 MWD M 0.76 MWD M 0.60 MWD M 0.45 MVVD M 1.84 MWD M 0.77 MWD M 0.54 MWD M 0.39 MWD M 0.28 MVVD M 0.90 MWD M 1.72 MWD_M 0.30 MWD M 0.22 MWD M Page 3 Measured depth 605O 6100 6150 6200 6250 63OO 6350 6400 6450 6500 6550 6600 6650 6700 6750 6800 6850 6900 6950 7000 705O 7100 7150 7200 7250 7300 7350 7400 7450 7500 755O 7600 7650 7700 775O 78O0 7850 7900 7950 8000 8050 8100 8150 8200 8250 IncI angle (deg) 63.64 64.15 63.89 64.30 64.84 65.16 65.55 65.64 65.98 65.80 65,36 65.29 64.75 64.47 63.65 63,68 63.75 63.57 63.76 63.81 63.70 64.35 64.45 64.38 64.35 63.53 64.00 63.44 64.72 63.80 65.04 65.36 67.09 67.29 66.61 66.94 68.31 67.86 67.51 67.42 65.69 65.58 64.59 64.98 64.77 Azimuth angle (deg) 78.0 78.3 78.5 78.6 78.6 78.7 78.9 78.9 79.0 79.2 79.2 79.5 79.3 79.1 79.4 79.4 79.8 80.0 80.1 80.3 80.5 80.8 81.0 81.3 79.3 79.2 79.1 78.8 78.6 78.7 78.9 78.9 78.7 78.4 78.2 77.8 77.5 77.3 77.3 77.3 77.3 77.5 77.3 77.3 77.4 Course length (ft) 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50,00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 4188.07 4210.07 4231.98 4253.82 4275.29 4296.42 4317.27 4337,93 4358.42 4378.84 4399.51 4420.39 4441.50 4462.94 4484.81 4506.99 4529.13 4551.32 4573.50 4595.59 4617.70 4639.60 4661.20 4682.79 4704.43 4726.39 4748.50 4770.63 4792.49 4814.20 4835.79 4856.76 4876.92 4896.31 4915.88 4935.60 4954.63 4973.29 4992.28 5011.44 5031.33 5051.96 5073.02 5094.33 5115.55 Vertical section (fi) 3462.10 3506.83 3551.59 3596.36 3641.32 3686.42 3731.65 3776.95 3822.33 3867.73 3913.01 3958.18 4003.24 4048.16 4092.87 4137.41 4181.96 4226.46 4270.95 4315.47 4359.96 4404.53 4449.21 4493.88 4538.60 4583.27 4627.87 4672.47 4717.23 4762.O6 4806.94 4852.11 4897.65 4943.54 4989.36 5035.15 5081.24 5127.50 5173.64 5219.70 5265.45 5310.87 5356.10 540!21 5446.36 Displ +NIS- (ff) 856.97 866.19 875.22 884.15 893.08 902.00 910.82 919.59 928.37 937.04 945.57 954.00 962.38 970.84 979.23 987.47 995.57 1003.46 1011.24 1018.88 1026.36 1033.66 1040.83 1047.81 1055.40 1063.78 1072.22 1080.82 1089.63 1098.49 1107.25 1116.03 1124.95 1134.14 1143.51 1153.07 1162.95 1173.07 1183.28 1193.47 1203.56 1213.49 1223.39 1233~33 1243.24 Displ +E/W- (ff) 3357.83 3401.77 3445.80 3489.88 3534.15 3578.57 3623.15 3667.84 3712.59 3757.40 3802.12 3846.76 3891.31 3935.68 3979.85 4023.90 4067.99 4112.10 4156.23 4200.43 4244.65 4289.00 4333.52 4378.07 4422.50 4466.63 4510.68 4554.68 4598.77 4642.93 4687.17 4731.70 4776.58 4821.74 4866.79 4911.73 4956.90 5002.17 5047.28 5092.32 5137.07 5181.52 5225.78 5269.90 5314.07 Total displ (ft) 3465.46 3510.32 3555.22 3600.14 3645.24 3690.50 3735.89 3781.36 3826.91 3872.48 3917.93 3963.30 4008.55 4O53.65 4098.55 4143.29 4188.04 4232.76 4277.48 4322.24 4366.97 4411.80 4456.76 4501.71 4546.69 4591.56 4636.36 4681.16 4726.10 4771.11 4816.18 4861.54 4907.26 4953.33 4999.32 5045.26 5091.49 5137.88 5184.13 5230.31 5276.18 5321.72 5367.07 5412.30 5457.57 (deg) 75.68 75.71 75.75 75.78 75.82 75.85 75.89 75.93 75.96 76.00 76.03 76.07 76.11 76.14 76.18 76.21 76.25 76.29 76.33 76.37 76.41 76.45 76.49 76.54 76.58 76.60 76.63 76.65 76.67 76.69 76.71 76.73 76.75 76.76 76.78 76.79 76.8O 76.80 76.81 76.81 76.81 76.82 76.82 76.83 76.83 DLS (deg/ ioof) Survey Type 0.37 MWD M 1.15 MWD M 0.63 MWD M 0.84 MVVD M 1.08 MWD M 0.67 MWD M 0.86 MWD M 0.18 MWD M 0.68 MWD M 0,66 MWD M 0.88 MWD M 0.39 MWD M 1.10 MWD M 0.67 MWD M 1.73 MWD M 0.06 MWD M 0.73 MWD M 0.40 MWD M 0.52 MWD M 0.37 MWD M 0.42 MWD_M 1.41 MWD M 0.27 MWD M 0.74 MVVD M 3.61 MWD M 1.65 MWD M 0.96 MWD M 1.24 MWD M 2.59 MWD M 1.85 MWD M 2.51 MWD M 0.67 MWD M 3.46 MWD M O.84 MWD M 1.37 MWD M 0.99 MWD M 2.80 MWD M 0.97 MWD M 0.72 MWD M 0.26 MWD M 3.46 MWD M 0.43 MWD M 2.01 MWD M 0.78 MWD M 0.46 MWD M Page 4 Measured Incl Azimuth Course TVD Vertical Displ Displ Total At depth angle angle length depth section +N/S- +E/W- displ Azim (fi:) (deg) (deg) (fl:) (ft) (ft) (fi:) (ft) (ft) (deg) DLS Survey (deg/ Type lOOf) 8300 65.15 8350 65.03 840O 64.91 8450 64.74 8500 64.92 8550 64.54 860O 64.93 865O 64.57 8700 64.50 8750 64.38 8825.90 65.26 8915.97 67.87 9010.29 67.46 9101.31 67.07 9192.60 68.27 9288.06 68.45 9383.62 68.03 9478.49 67.63 9573.56 67.61 9668.63 67.28 9761.67 67.31 9857.31 68.42 9941.32 67.77 10043.10 67.04 10136.68 66.54 10232.72 67.92 10326.42 67,80 10422.15 68.21 10518.36 68.76 10610.13 68.66 10703.12 68.58 10795.93 68.83 10886.95 69.17 10978.96 69,19 11072.56 68.98 11164.18 68.94 11261.04 69.06 11355.15 68.47 11447.29 69.09 11547.46 68.97 11641.03 68.92 11731.59 68.49 11827.92 68.48 11924.42 68.21 77.3 50,00 5136,72 5491.54 1253,17 5358,28 5502,87 76.84 77.1 50,00 5157,78 5536.78 1263,21 5402,50 5548,21 76.84 77.0 50,00 5178,93 5581.98 1273.37 5446,65 5593.52 76.84 76.8 50.00 5200.20 5627,13 1283,62 5490,72 5638.77 76.84 77.2 50,00 5221,47 5672,28 1293,80 5534,81 5684.02 76.84 77.7 50.00 5242.81 5717.37 1303.63 5578.95 5729.23 76.85 77.8 50.00 5264.15 5762.45 1313.26 5623.13 5774.45 76.85 78.2 50.00 5285.48 5807.51 1322.70 5667.35 5819.66 76.86 78.1 50.00 5306.98 5852.48 1331.97 5711.53 5864.79 76.87 78.5 50.00 5328.55 5897.41 1341.12 5755.70 5909.88 76.88 79.6 75,90 5360.84 5965,73 1354,16 5823,14 5978,52 76.91 78.4 90,10 5396.67 6047.96 1369,94 5904,28 6061.13 76.94 79,1 94,30 5432,51 6134.77 1386,96 5989,83 6148.31 76.96 79.9 91,00 5467,68 6218,19 1402,25 6072,35 6232.15 77.00 78.5 91,30 5502~7. 63D2,17. 1418,Q8. 615.5_3D. 6316,54 77.03 78.4 95.50 5537.59 6390.56 1435.86 6242.27 6405.28 77.05 77.9 95.50 5572.99 6478.92 1454.07 6329.08 6493.96 77.06 77.8 94.90 5608.81 6566.50 1472.57 6414.99 6581.84 77.07 78.4 95.10 5645.03 6654.11 1490.70 6501.03 6669.75 77.09 78.0 95.00 5681.47 6741.50 1508.64 6586.91 6757.47 77.10 78.6 93.10 5717.40 682~04. 1.526_06... 66Z1,Q1. 6843.34 77.11 78.4 95.60 5753.42 6915.21 1543.71 6757.79 6931.86 77.13 78.2 84.00 5784.76 6992.83 1559.51 6834.10 7009.78 77.15 78.1 101.80 5823.87 7086.46 1578.81 6926.09 7103.75 77.16 78.6 93.60 5860,76 7172._13.. 1596.19.~ 7010.34 7189.76 77.17 78.8 96.00 5897.92 7260.24 1613.53 7097.14 7278.25 77.19 78.7 93.70 5933.23 7346.61 1630.46 7182.26 7365.01 77.21 77.9 95.80 5969.11 7435.08 1648.48 7269.24 7453.82 77.22 77.0 96.20 6004.39 7524.33 1667.92 7356.60 7543.31 77.23 77.6 91.70 6037.69 7609.55 1686.71 7439.95 7628.75 77.23 77.2 93.00 6071.59 7695.91 1705.60 7524.46 7715.35 77.23 77.7 92.80 6105.29 7782.13 1724.39 7608.86 7801.81 77.23 78.1 91.10 6137.94 7866.89., 1742~.. 7692.02 7886.86 77.24 77.8 92.00 6170.64 7952.58 1760.17 7776.12 7972.84 77.25 77.0 93.60 6204.05 8039.77 1779.24 7861.45 8060.27 77.25 76.5 91.60 6236.94 8125.10 1798.83 7944.66 8145.76 77.24 76.4 96.80 6271.63 8215.32 1820.01 8032.52 8236.13 77.23 76.5 94.20 6305.75 8302.98 1840.58 8117.88 8323.92 77.23 76.1 92.10 6339.08 8388.71 1860.99 8201.27 8409.76 77.22 76.6 100.20 6374.94 8482_13. 1883...14,. 8292.37 8503.32 77.21 77.3 93.50 6408.53 8569.20 1902.85 8377.18 8590.57 77.20 77.5 90.60 6441.44 8653.38 1921.26 8459.56 8674.98 77.20 77.6 96.30 6476.75 8742.71 1940.58 8547.04 8764.57 77.21 77.8 96.50 6512.37 8832.11 1959.68 8634.67 8854.26 77.21 0.78 MWD M 0.43 MWD M 0.30 MWD M 0.50 MWD M 0.81 MWD M 1.18 MWD M 0.78 MWD M 1.16 MWD M 0.23 MWD M 0.76 MWD M 1.75 MWD M 3.14 MWD M 0.81 MWD M 0.92 MWD M 1.93 MWD 0.21 MWD 0.66 MWD O.44 MVVD 0.58 MWD O.52 MWD 0.60 MWD 1.18 MWD 0.80 MWD O.72 MWD 0.73 MVVD 1.45 MWD 0.16 MVVD 0.88 MWD 1.04 MWD 0.62 MWD 0.41 MWD O.57 MWD 0.55 MWD 0.31 MWD O.83 MWD 0.51 MWD 0.16 MWD O.63 MWD 0.84 MWD M 0.57 MWD 0.70 MWD 0.52 MWD 0.10 MWD 0.34 MWD Page 5 Measured Incl Azimuth Course TVD Vertical Displ DispI Total At depth angle angle length depth section +N/S- +E/W- dispI Azim (fi:) (deg) (deg) (It) (fi:) (fl:) (fi:) (ft) (fi) (deg) 12016.99 68.08 77.1 92.60 6546.84 8917.82 1978.36 8718.56 8940.20 77.22 12110.47 67.59 12205.35 67.13 12299.53 66.58 12382.47 65.92 12489.28 65.70 77.2 93.50 6582.11 9004.20 1997.62 8802.98 9026.79 77.21 77.8 94.80 6618.60 9091.44 2016.55 8888.40 9114.29 77.22 77.7 94.20 6655.63 9177.78 2034.93 8973.05 9200.90 77.22 78.9 83.00 6689.06 9253.44 2050.34 9047.44 9276.85 77.23 76.9 100.80 6732.83 9350.53 2070.76 9142.69 9374.26 77.24 12584.24 65.58 12675.66 65.95 12764.91 65.77 12858.96 65.62 12951.90 65.62 75.7 94.90 6771.97 9436.85 2091.23 9226.68 9460.70 77.23 76.0 91.50 6809.53 9520.19 2111.63 9307.58 9544.11 77.22 74.1 89.20 6846.01 9601.54 2132.63 9386.22 9625.45 77.20 72.2 94.10 6884.75 9687.29 2157.48 9468.30 9710.99 77.16 70.1 92.90 6923.10 9771.85 2184.82 9548.37 9795.14 77.11 13046.01 65.73 13138.92 65.84 13231.47 66.05 13321.87 66.44 13422.79 66.08 66.8 94.10 6961.87 9857.29 2216.31 9628.10 9879.90 77.04 67.6 92.90 6999.97 9941.56 2249.14 9706.21 9963.39 76.95 67.2 92.60 7037.72 10025.69 2281.64 9784.27 10046.79 76.87 67.2 90.40 7074.13 10107.98 2313.70 9860.55 10128.36 76.79 66.6 100.90 7114.75 10199.79 2349.94 9945.51 10219.36 76.71 13519.70 65.86 13608.51 65.64 13700.05 65.26 13796.41 64.70 13889.71 64.64 67.2 66.9 67.3 65.3 65.9 96.90 7154.21 10287.77 2384.66 10026.91 10306.58 76.62 88.80 7190.68 10368.27 2416.23 10101.47 10386.42 76.55 91.60 7228.74 10451.13 2448.65 10178.22 10468.62 76.47 96.30 7269.47 10537.76 2483.72 10258.12 10554.52 76.39 93.30 7309.39 10621.36 2518.56 10334.92 10637.37 76.30 13984.90 64.75 14081.84 64.83 14171.31 65.06 14265.20 65.11 14360.14 65.36 65.9 95.20 7350.08 10706.73 2553.70 10413.48 10722.03 76.22 65.3 96.90 7391.36 10793.64 2589.92 10493.32 10808.21 76.14 65.1 89.50 7429.26 10873.93 2623.93 10566.92 10887.83 76.05 65.5 93.90 7468.82 10958.30 2659.51 10644.29 10971.50 75.97 65.6 94.90 7508.57 11043.71 2695.18 10722.73 11056.26 75.89 14454.14 65.59 14554.59 65.77 14649.35 65.96 14741.05 66.10 14835.42 66.34 64.4 94.00 7547.59 11128.36 2731.32 10800.24 11140.25 75.81 64.5 100.50 7588.98 11218.89 2770.82 10882.86 11230.06 75.72 65.6 94.70 7627.70 11304.44 2807.27 10961.22 11315.00 75.63 64.1 91.80 7665.00 11387.44 2842.92 11037.15 11397.40 75.56 64.7 94.30 7703.02 11472.73 2880.21 11114.97 11482.08 75.47 14925.16 66.51 15022.54 66.52 15113.56 66.14 15208.46 65.71 15296.35 65.55 15392147 65.14 15484.62 65.09 15578.46 65.08 15670.73 65.29 15765.69 65.58 15858.70 65.88 15952.38 66.02 16047.54 66.35 65.4 89.80 7738.94 11554.21 2914.92 11189.59 11563.04 75.40 65.3 97.30 7777.71 11642.62 2952.14 11270.70 11650.92 75.32 62.6 91.10 7814.29 11724.97 2988.78 11345.65 11732.72 75.24 64.3 94.90 7853.01 11810.37 3027.51 11423.16 11817.54 75.16 65.5 87.80 7889.24 11889.52 3061.43 11495.58 11896.25 75.09 65.2 96.20 7929.37 11976.14 3097.90 11575.04 11982.43 75.02 65.7 92.10 7968.12 12058.93 3132.61 11651.04 12064.82 74.95 65.1 93.90 8007.68 12143.31 3168.06 11728.47 12148.81 74.88 64.5 92.20 8046.38 12226.11 3203.69 11804.19 12231.21 74.82 64.7 95.00 8085.87 12311.55 3240.75 11882.24 12316.25 74.74 65.4 93.00 8124.10 12395.48 3276.52 11959.11 12399.83 74.68 64.4 93.70 8162.28 12480.16 3312.81 12036.59 12484.16 74.61 63.5 95.10 8200.68 12566.03 3351.02 12114.75 12569.67 74.54 . Page 6 .. , DLS Survey (deg/ Type lOO0 0.72 MWD O.53 MWD 0.76 MWD M 0.59 MWD 1.54 MWD 1.72 MWD 1.16 MWD 0.50 MWD 1.95 MWD 1.85 MWD 2.06 MVVD 3.20 MVVD 0.79 MWD 0.46 MWD 0.43 MWD 0.65 MWD 0.61 MWD 0.40 MWD 0.57 MWD 1.97 MWD 0.58 MWD 0.12 MWD 0.57 MWD O.33 MWD 0.39 MWD 0.28 MWD 1.19 MWD O.2O MWD 1.08 MWD 1.50 MWD 0.64 MWD 0.74 MWD 0.09 MWD 2.75 MWD 1.70 MWD 1.26 MWD 0.51 MVVD 0.50 MWD 0.58 MWD 0.63 MWD 0.36 MWD 0.76 MWD 0.99 MWD 0.93 MWD_M Measured Incl Azimuth Course TVD Vertical Displ DispI depth angle angle length depth section +N/S- +EtW- (ft) (deg) (deg) (ft) (ft) (ft) (ft) (fi) Total displ (ft) 16144.45 66.14 62.6 16235.02 65.68 63.0 96.90 8239.72 12653.35 3391.22 12193.81 12656.60 90.60 8276.70 12734.71 3429.02 12267.37 12737.61 16327.62 65.27 63.4 16422.12 64.60 63.8 16515.92 64.25 63.6 16611.18 63.86 64.0 16709.44 63.53 63.4 92.60 8315.14 12817.68 3467,01 12342.57 12820.26 94.50 8355.17 12902.09 3505.07 12419.24 12904.38 93.80 8395.66 12985.55 3542,56 12495.09 12987.57 95.30 8437.36 13070.10 3580.39 12571.98 13071.88 98.20 8480.88 13156.94 3619,39 12650.90 13158.47 16805.21 63.06 63.6 16897.09 62.59 63.2 16990.86 61.94 63.4 17083.73 61.27 63.7 17178.92 60.31 63.8 95.80 8523.93 1_3241~.0.._ ~65~..5.8..12~27.49 13242.62 91.90 8565.90 13321.88 3694.19 12800.59 13322.99 93.80 8609.55 13403.67 3731.49 12874.76 13404.61 92.80 8653.68 13484.16 3767.85 12947.85 13484.94 95.20 870,0_14_ 1356~_14. ~804~Q...13022.38,.13566,77 17271.61 59.81 63.5 17365.45 59.17 63.6 17454.53 58.20 63.1 17548.98 57.43 63.4 17640.41 57.44 63.6 17733139 57.09 63.4 17831.55 56.43 63.7 17924.20 56.08 63.6 18017.52 56.28 63.9 18108.99 55.60 64.3 92.70 8746.41 13645.36 3840,26 13094.36 13645.87 93.90 8794.08 13725.13 3876.29 13166;79 13725.52 89.00 8840.34 13800.05 3910,39 13234.75 13800.35 94.50 8890.67 13878.83 3946.39 13306.16 13879.05 91.40 8939.87 13954.77 3980.76 13375.10 13954.92 93.00 8990.16 14031.89 4015.67 13445.11 14031.99 98.20 9043.99 14112.87 4052.25 13518.65 14112.92 92.60 9095.42~.14188~8~, 4086,4~._1358~.64. 14188.83 93.30 9147.35 14265.28 4120.71 13657.16 14265.29 91.50 9198.60 14340.14 4153.82 13725.35 14340.14 18138.30 55.15 64.1 29.30 9215.25 14363.95 4164.32 13747.06 14363.95 At DLS Survey Azim (deg/ Type (deg) lOOf) 74.46 74.38 74.31 74.24 74.17 74.10 74.03 73.97 73.90 73.84 73.77 73.71 73.65 73.60 73.54 73.48 73.43 73.37 73.31 73.26 73.21 73.16 73.15 0.88 MWD 0.65 MWD 0.59 MWD 0.81 MWD 0.42 MWD 0.56 MWD 0.64 MWD 0.52 MWD 0.64 MWD 0.72 MWD 0.78 MWD 1.01 MWD 0.61 MWD 0.69 MWD 1.19 MWD 0.86 MWD 0.18 MWD 0.42 MWD 0.72 MWD 0.39 MWD 0.34 MVVD 0.83 MWD 1.64 MWD Page 7 Date: Well Name: Company: API Number: Location: Field: Rig: Anaddll Alaska - Prudhoe Bay o'o sws Pouch 340130 (907) 659-2487 16-Dec-98 WB-06PB 1 ARCO Alaska Inc. 5002922929 North Slope, Alaska West Beach Pool Arctic Alaska 7 Anadrill Personnel Field Crew: Cell Managers: Cell Engineers: Lwd Engineers: Nathan Rose Mark St. Amour Daniel Guay Felix Seminaro SERVICES PROVIDED Alaska District Manager: Martin Varco Field Service Manager: Joey LeBlanc ORIGINAL Service Directional Survey Service (DSS) DWOB/DTOR (IWOB) Gamma Ray (GR) Service Dates 16 Oct-98 - 09 Dec-98 16 Oct-98 - 24 Oct-98 16 Oct-98 - 24 Oct-98 Depth Imerval 120' - 7519.1' 120' -7519.1' 120' -7519.1' OPERATING STATISTICS Total MWD Pumping Hours: 112.8 Total MWD Below Rotary Hours: 248.15 Total MWD Footage: 7396.1 Total MWD Runs: 5 JOB PERFORMANCE DIRECTIONAL RECEIVED FEB 01 1999 Alall o a sCo s. ion Surveys (DSS) were provided over the entire well. The final surv~ point was at 7447.65' with an inclination of 64.97 degrees and an azimuth of 77.9 degrees. This survey was projected to TD, giving the final bottom hole location: Measured Depth: 7519.1' True Vertical Depth: 4702.27' Latitude: 1126.87 N Departure: 4715.10 E Displacement at Azimuth: 4847.85' at 76.56 deg FORMATION EVALUATION Real-time GR was used for lithology identification; specifically, to evaluate and pick the casing point. Real-time logs, DLIS files and ASCII data were faxed/mailed in a timely manner. DRILLING MECHANICS The downhole measurements were monitored by the driller on the rig floor, as well as the Anadrill engineer on location. DWOB and DTOR was used to monitor and help in the drilling procedures. SHOCK No shocks were monitored. WASHOUT DETECTION Washouts can be seen from MWD turbine rpm, pump pressure, and flow. A washout was detected after it was noticed on the drill floor. The MWD turbine rpm was used to confirm the washout. EXPLANATION OF PLUG BACKS WB-06 PB 1 was side tracked when during a wiper trip it was impossible to get back to bottom. LESSONS LEARNED Using a frequency of 24 hz and 6 bit per second gives a very. good signal for the MWD. Make to monitor the MWD turbine rpm, so you can see washouts. Anadrill appreciates the opportunity to provide BP Exploration and Shared Services Drilling with M3YD and LWD services. Sincerely, Joev Leblanc Field Service Manager Mark St. Amour Field Cell Manager Anadriil/Schlumberger Survey Report WELL INFORMATION TD Date: 9 December 1998 Client: ARCO Alaska Inc. Field: West Beach Well Name: WB-06PB1 Permanent datum: Mean Sea Level Depth measured from: RKB Elevation of kelly bushing: 0.00 Elevation of rig floor: 51.80 Elevation of ground level: 11.10 Magnetic Declination: 27.98 Grid Convergence: 0.00 Total Correction: 27.98 TIE IN POINT Measured Depth: 0.00 True Vertical Depth: 0.00 Inclination: 0.00 Azimuth: 0.00 N/S displacement: 0.00 E/W displacement: 0.00 Azimuth from rotory table to target: 73.2 Measured Incl Azimuth Course TVD depth angle angle length depth (ft) (deg) (deg) (ft) (ft) 0 0 0 0 0 100 0.05 88.2 100 100 180 0.08 149.5 80 180 269 0.08 46.2 89 269 359 0.23 78.8 90 359 390 0.28 56.9 31 390 420 0.31 63.3 30 420 518 1.45 56.9 98 517.99 636 4.01 49.2 118 635.84 727 6.53 41.1 91 726.45 Vertical section (ft) 0 0.04 0.09 0.16 0.39 0.53 0.68 2.13 7.34 14.63 Displ +N/S- (ft) 0 0 -0.05 -0.06 0.02 0.08 0.15 0.95 4.46 10.44 Displ +F_/VV- (ft) 0 0.04 0.11 0.18 0.41 0.53 0.66 1.94 6.31 12.13 Total displ (ft) 0 0.04 0.12 0.19 0.41 0.54 0.68 2.16 7.73 16 Azim (deg) 0 '88.2 113.1 107.1 86.84 81.86 77.08 63.94 54.76 49.27 DLS (deg/ toof) 0 0.05 0.09 0.14 0.19 0.35 0.15 1.17 2.19 2.88 Survey Type TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD Page 1 Measured depth (ft) 820 885 979 1072 1128.42 1222.92 1316,79 1411.67 1507.45 1603.88 1692.9 1786.95 1877.28 1968.89 2059.73 2154.98 2250,57 2345,76 2436,56 2528,08 2621.1 2717.57 2813.81 2906.2 2998.56 3095.4 3191.35 3284.49 3380.96 3470.94 3565.19 3659.66 3754.76 3846.28 3940.52 Incl angle (deg) 5.86 5.97 6.9 7.76 7,54 8.55 8.57 10.16 12.18 11.49 13.46 13.76 14,9 16.37 17.94 20.59 24.21 27.71 30.64 32.54 34.88 38.55 41.71 45.19 48.28 51.43 55.44 58.5 62.06 65.09 65.67 65,25 66.37 66.28 65.87 Azimuth Course TVD angle length depth (deg) (ft) (ft) 41.7 93 818.91 42.5 65 883.56 48.5 94 976.97 54.9 93 1069.21 56.9 56.4 1125.11 64.9 94.5 1218.68 71.9 93.9 1311.54 71.4 94.9 1405.17 68.9 95.7 1499.05 68 96.5 1593.5 74.9 89 1680.4 78 94.1 1771.86 77.4 90.3 1859.35 78.2 91.6 1947.56 75.7 90.8 2034.31 74.9 95.3 2124.27 71.3 95.6 2212.65 69.7 95.2 2298.23 69.6 90.8 2377.5 71.9 91.5 2455.44 72.9 93 2532.8 72.9 96.5 2610.14 70.7 96.2 2683.69 72.2 92.4 2750.76 74.6 92.4 2814.09 74 96.8 2876,49 74.7 96 2933,67 76.3 93.1 2984.41 76,3 96.5 3032.24 76.1 89.9 3072.25 76,9 94.3 3111.53 78,7 94.5 3150.78 77,7 95.1 3189.75 77.8 91.5 3226.49 78.3 94.2 3264.7 Vertical section (ft) 23.16 28.9 38.23 49.27 56.44 69.34 83.24 98.68 117.19 136.91 156.1 178.19 200.47 225.08 251.8 283.21 319.62 361.24 405.41 453.29 504.9 562.58 624.55 688.05 755.32 829.29 906.36 984.34 1068 1148.39 1233.97 1319.65 1406.06 1489.59 1575.38 Displ +NIS- (ft) 17.97 22.94 30.29 37.61 41.82 48.18 53.32 58.18 64.51 71.78 77.8 82.98 87.74 92.95 99.02 107.01 117.68 131,62 147.02 162.79 178.38 195.34 214.74 234.93 254.11 274.14 294.92 314.45 334.29 353.49 373.51 391.67 409.42 427.2 445.02 Displ +E/W- (ft) 18.76 23.25 30.77 40.09 46.31 57.86 70.84 85.49 102.91 121.32 139.54 161.06 182.9 207.03 233.11 263.51 298.32 337.58 379.08 424.33 473.53 528.66 587.53 647.77 712.25 783.47 857.7 933.26 1014.7 1092.8 1176.2 1260.2 1345.1 1427 1511.3 Total displ (ft) 25.98 32.66 43.18 54.97 62.4 75.3 88.66 103.41 121.46 140.96 159.76 181.18 202.86 226.94 253.27 284.41 320.7 362.34 406.59 454.49 506.01 563.59 625.55 689.06 756.22 830.05 906.99 984.81 1068.32 1148.59 1234.08 1319.68 1406.06 1489.59 1575.42 Azim (deg) 46.23 45.38 45.45 46.83 47.92 50.22 53.03 55.76 57.92 59.39 60.86 62.74 64.37 65.82 66.98 67.9 68,47 68.7 68.8 69,01 69.36 69.72 69.92 70.07 70.36 70.71 71.02 71.38 71.77 72.08 72.38 72.73 73.07 73,33 73.59 DLS (degl ioof) 0.72 0.2 1.23 1.27 0.61 1.59 1.11 1.68 2.17 0.74 2.77 0.84 1.27 1.62 1.91 2,79 4.05 3.75 3.23 2.46 2.59 3,8 3.6 3.93 3.84 3.29 4.22 3.59 3.69 3.38 0.99 1.79 1.52 0.14 0.65 Survey Type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Page 2 Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Survey depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ Type (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) 4037.87 64,81 78.6 97.4 3305.33 1663.52 462.75 1598 1663.64 73.85 1.12 MWD 4131.06 66.47 77.9 93.2 3343.78 1748.08 480.04 1681.1 1748.3 74.06 1.91 MWD 4226.52 68.59 76.9 95.4 3380.24 1835.99 499.28 1767.1 1836.31 74.22 2.42 MWD 4320.99 67.78 77.5 94.5 3415.35 1923.51 518.71 1852.7 1923.93 74.36 1.04 MWD 4411.85 68.04 77.8 90.9 3449.54 2007.47 536.73 1935 2008.02 74.5 0.42 MWD 4507.29 67.57 78.3 95.4 3485.58 2095.48 555.02 2021.4 2096.19 74.65 0.69 MWD 4601.51 66.94 77.6 94.2 3522 2182.05 573.15 2106.3 2182.92 74.78 0.96 MWD 4695,02 65.53 76.2 93.5 3559.68 2267.44 592.54 2189.7 2268.43 74.86 2.04 MWD 4788.94 64.55 76.4 93.9 3599.3 2352.44 612.7 2272.4 2353.54 74.91 1.06 MVVD 4880.63 65.43 77.3 91.7 3638.07 2435.37 631.61 2353.3 2436.59 74.98 1.31 MWD 4973.12 65.73 77.8 92.5 3676.31 2519.34 649.76 2435.6 2520.73 75.06 0.59 MWD 5066.92 65.91 78 93.8 3714.73 2604.62 667.7 2519.2 2606.2 75.16 0.27 MWD 5162.06 65.75 78,1 95.2 3753.71 2691.16 685.69 2604.2 2692.95 75.25 0.19 MWD 5253.34 64.87 78.4 91.2 3791.81 2773.69 702.56 2685.3 2775.7 75.34 1.01 MWD 5348.16 64.39 77.9 94.9 3832.47 2859.12 720.17 2769.2 2861.35 75.42 0.69 MWD 5440.78 65.53 77.9 92.6 3871.66 2942.73 737.75 2851.3 2945.17 75.49 1.23 MWD 5532.59 65 77.8 91.8 3910.07 3025.82 755.3 2932.8 3028.48 75.56 0.59 MVVD 5632.35 66.32 78.4 99.8 3951.2 3116.41 774.05 3021.8 3119.32 75.63 1.43 MWD 5722.61 67.74 78.7 90.2 3986.4 3199.09 790.53 3103.1 3202.26 75.71 1.6 MWD 5812.51 68.49 79.4 89.9 4019.91 3282.07 806.38 3185 3285.54 75.79 1.1 MWD 5908.05 68.48 79.6 95.6 4054.97 3370.46 822.59 3272.5 3374.3 75.89 0.19 MWD 6002.73 67.6 80.1 94.6 4090.35 3457.6 838.05 3358.9 3461.83 75.99 1.05 MWD 6097.22 67.5 80 94.5 4126.44 3544.31 853.14 3444.9 3548.95 76.09 0.14 MWD 6193.02 68.15 80 95.8 4162.59 3632.39 868.54 3532.3 3637.46 76.19 0.68 MWD 6288.73 67.71 79.1 95.7 4198.55 3720.53 884.63 3619.5 3726 76.27 0.99 MWD 6380.8 67.77 79.2 92.1 4233.44 3805.3 900.67 3703.2 3811.13 76.33 0.12 MWD 6476.94 68.06 79.5 96.1 4269.57 3893.83 917.13 3790.7 3900.06 76.4 0.42 MWD 6566.97 67.09 77.9 90.1 4303.95 3976.72 933.45 3872.4 3983.27 76.45 1.96 MWD 6666.92 66.93 77.5 99.9 4342.96 4068.4 953.04 3962.2 4075.22 76.48 0.4 MWD 6754.51 66.02 76.9 87.6 4377.93 4148.52 970.83 4040.5 4155.53 76.49 1.21 MWD 6849.08 65.64 77 94.6 4416.66 4234.63 990.32 4124.6 4241.83 76.5 0.41 MWD 6940.16 64.62 76.4 91.1 4454.98 4317.13 1009.33 4205.1 4324.48 76.5 1.27 MWD 7036.04 64.34 77.1 95.8 4496.25 4403.41 1029.15 4289.2 4410.93 76.51 0.72 MWD 7129.39 64.06 76.7 93.4 4536.9 4487.32 1048.2 4371.1 4495.02 76.51 0.49 MWD 7223.12 64.63 76.4 93.7 4577.47 4571.63 1067.85 4453.2 4579.48 76.52 0.67 MWD 7314.1 65.2 77 91 4616.05 4653.89 1086.81 4533.5 4661.9 76.52 0.87 MWD 7408.85 65.29 77.5 94.7 4655.7 4739.67 1105.79 4617.3 4747.89 76.53 0.49 MWD 7447.65 64.97 77.9 38.8 4672.02 4774.76 1113.29 4651.7 4783.08 76.54 1.25 MWD Projected to TD 7519.1 64.97 77.9 71.5 4702.27 4839.32 1126.87 4715.1 4847:85 76.56 0 Projected Page 3 Date: Well Name: Company: API Number: Location: Field: Rig: Anaddll Alaska - Pmdhoe Bay c/o SV~ Pouch 340130 Pmdhoe Bay, AK 99734 (907)659-2487 10-Jan-99 WB-06 ARCO Alaska Inc. 5002922929 North Slope, Alaska West Beach Pool Arctic Alaska 7 Anadrill Personnel Field Crew: Cell Managers: Cell Engineers: LWD Engineers: Nathan Rose/Mark St. Amour Ray Whitmm~an Guay/Felix Seminario Nathan Rose/Mark St. Amour Field Support: Alaska District Manager: Martin Varco Field Service Manager: Joey LeBlanc SERVICES PROVIDED Service Directional Survey Service (DSS) DWOB/DTOR (IWOB) Gamma Ray (GR) Compensated Dual Resistivity (CDR) Pressure While Drilling (PWD) Azimuthal Density Neutron Service Dates 03-Dec-98 - 08-Jan-99 14-Dec-98 - 08-Jan-99 14-Dec-98 - 08-Jan-99 21-Dec-98 - 08-Jan-99 27-Dec-98 -08-Jan-99 04-Jan-99 - 08-Jan-99 Depth Interval 120' -18211' 4093' -18211' 4093' -18211' 7275' -18211' 11527 -18211' 16042'-18211' OPERATING STATISTICS Total MWD Pumping Hours: Total MWD Below Rotary Hours: Total MWD Footage: Total MWD Runs: Total LWD Pumping Hours: Total LWD Below Rotary Hours: Total LWD Footage CDR: Total LWD Runs: CDR: Total LWD Footage ADN: Total LWD Runs: ADN: 416.2 583.3 18211 7 266.4 364 10963 3 10963 1 ORI61NAL RECEIVED FEB 01 JOB PERFORMANCE DIRECTIONAL Surveys (DSS) were provided over the entire well. The final survey point was at 18138.3 with an inclination of 55.15 degrees and an azimuth of 64.1 degrees. Measured Depth: North/South Displacement: Displacement at Azimuth: 18211.78 4164.32 N 14363.95 at 73.16 deg True Vertical Depth: 9215.25' East/West Displacement: 13747 E FORMATION EVALUATION Real-time GR and Resistivity were used for lithology identification; specifically, to evaluate the zone of interest. Azimuthal Density Neutron was used in Run 9 for density and porosity determination. The Ultrasonic caliper measurement on the ADN failed during Run 9. DRILLING MECHANICS The downhole measurements were monitored by the driller on the rig floor, as well as the Anadrill engineer on location. Equivalent Circulating Density was monitored and controlled below the maximum rate throughout the well. The APWD sensor was successfully run in the 8.25 in. CDR for the first time in Alaska. SHOCK Shock was monitored and remained low throughout most of the well. WASHOUT DETECTION Washouts can be seen from MWD turbine rpm, pump pressure, and flow. On mn 4 a clean-out mn was made with 8 ~¼ in. M10 and motor assembly. A shallow hole test was performed at surface and the tools were tripped to bottom. At approximately 12:30 on 12-9-98 while circulating on bottom a 300 psi pressure drop was noticed as well as a corresponding drop in turbine RPM. It was determined to be a washout above the MWD. The BHA was tripped to surface, unfortunately the hole was fight while tripping out in several places. The pumps were used for approximately. 3 hours to facilitate tripping out after a washout was determined. This caused the BHA to part in the HWDP at 2961 fi (top of fish) while trying to back ream out of the hole. The BI-IA parted with an overpull of approximately 150,000 lbs. EXPLANATION OF PLUG BACKS WB-06 consisted of one plug back. PB 1 consisted of MWD runs 1 and 5. The well WB-06, was then drilled out of the shoe at 13807 ft and drilled to 14971 ft, with MWD runs 3,4,5, and 6. W13-05B was open hole sidetracked at 14721', and achieved a TD of 16100' with MWD runs 1,3,4,5,7,11 and 12. LESSONS LEARNED Pulsation dampeners at the shallow hole test should be checked. Deflating the pulsation dampeners sometimes helps to acquire a good shallow hole due to low pressures. Do not pump if at all possibly after a washout has been determined to have occurred. An 8 ~¼ M10 was mn successfully to a depth of 16042 ft using 24hz at 6 bits/second demodulation rate for the first time on this rig resulting in a better quality realtime log as well as faster tool face update rates. Anadrill appreciates the opportunity to provide Arco Alaska, Inc. and Shared Services Drilling with MWD and LWD services. Sincerely, Joey Leblanc Field Service Manager Mark St. Amour Field Cell Manager [Fwd: West Beach State #5 and #6] Subject: [Fwd: West Beach State #5 and #6] Date: Wed, 17 Feb 1999 09:00:07 -0900 From: Jack Hartz <jack hartz~admin.state.ak.us> ~r~ter~ml Organization: Alaska Oil & Gas Conservation Commission To: Blair Wondzell <blair_wondzell~admin.state.ak.us>, Robert Crandall <bob_crandall~admin.state.ak.us> CC: Lori Taylor <lori_taylor~admin.state.ak.us> A note from Mike Morgan at AAI on the hookups for WB-05A and WB-06. Lori, please print a copy to each well file. Thanks, Jack Subject: West Beach State #5 and #6 Date: Wed, 17 Feb 1999 08:33:14 -1000 From: "Mike R Morgan" <MMORGAN~mail.aai.arco.com> To: jack_hartz~admin, state.ak.us Hello Jack, We've finally got the wells hooked up to the system, and we'll begin the initial completion work. I'I1 keep you posted on our progress and results. Mike Morgan ...................... Forwarded by Mike R Morgan/AAI/ARCO on 02/17/99 08:31 AM (Embedded Mike R Morgan image moved 02/17/99 08:30 AM to file: (Embedded image moved to file: pic 16934.pcx) pic09612.pcx) To: Paul J Taylor/AAI/ARCO~ARCO, stuart.w.holland~exxon.com, dalton.lockman~exxon.com, karen.d.hagedorn~exxon.com, Donald W Ince/AAI/ARCO@ARCO, Paul Daggett/AAI/ARCO~ARCO, Ed Westergaard/AAI/ARCO~ARCO cc: Subject: West Beach State #5 and #6 FYI - Completed well tie-in work this weekend (see attached photos). Procedures are in-place for initial completion work on both WB-05B and WB-06. Additionally, post-frac flow testing and sampling of NPB#3 is scheduled for later this week; consequently, we're bringing WB-04 on-line to warm up the lines. Mike ...................... Forwarded by Mike R Morgan/AAI/ARCO on 02/17/99 08:27 AM 1 of 3 2/17/99 9:03 AM [Fwd: West Beach State #5 and #6] B everly&Wangstrom 02/16/99 06:31 PM To' Raymond J Eastlack/AAI/ARCO~ARCO, Mike R Morgan/AAI/ARCO~ARCO cc: Charles Sauer/AAI/ARCO~ARCO, Don S McLean/AAI/ARCO~ARCO Subject: West Beach State #5 and #6 Folks, Just to let you know, we turned over well #5 and #6 to GPMA Operations on Monday, February 15. (See attached file: WBS#5&6.jpg)(See attached file: WBS#5&6HeaderDetail.jpg) Peak started their work on the West Beach State pipelines road crossings today. Per. ~ Name: pic16934.pcx i! [~pic 16934.pcx Type: PCX Image (application/x-unknown-content-type-pcxfile) Encoding: base64 ii Name: pic09612.pcx ~,ii ~pic09612.pcx i! Type: PCX Image (application/x-unknown-content-type-pcxfile) i i Encoding: base64 Name: WBS#5&6.jpg , Type: JPEG Image (image/jpeg) ~ WBS#5&6.jpg Encoding: base64 i Description: JPEG File Interchange Name: WBS#5 &6HeaderDetail.jpg Type: JPEG Image (image/jpeg) ~ WBS#5&6HeaderDetail.jpg Encoding: base64 ~ Description: JPEG File Interchange Jack Hartz <jack hartz~admin.state.ak.us> Petroleum Reservoir Engineer Alaska Oil and Gas Conservation Commission 2 of 3 2/17/99 9:03 AM [Fwd: West Beach State #5 and #6] 3 of 3 2/17/99 9:03 AM ~PIIIII~ .$ · ~ ~ ' · t".':'~' uii~:! ."~' .~ ........... ":.,' .... . '~ '"~"~! '~! ': ...... . . .. ............. . ...... =......: ..... ~,-.,~=,~' ,~.~T,'" "' · .~ ~" ~,~ ~ ~'" ' · · · ~ , " '.' ,.= ,~, · .... ' · · · "'"" ..?.~.'~'., .~..,., ,,.,,...,..:" · ", ~ = ~1111~_' · ' ' - ......... ~,,.,,.~ ~.!...~...~ .......... "~Ti:... :~_.. . ~ .... . ,,~ ..... ..~,,,. ........... · .: '... · ·. .... · · '~ : r.. 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'. 2:1.:': ~ :~. :~'~ ?":':"~ ' ~ ~ ~ ".~.~. ~:..:'~i '? ...i ': .': .'..': ~...¥ :: ~. ~.~ .' .' :: .' ~...: :. · . '. . .... ~. · ~ ': · .' .~":.'"':" · . .' '.~.~ ~'...'~ ~i .: '.~..".' ~..~ . : i. '. · ......i... ~i. :' ' ': .. '. ~.:" "."' .~: ~. ': .' ~ . " ..: . . '....: .. :' 'i. '.... ' ' . ~.. ' "'~ 2/1/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al'tN: Sherrie NO. 12299 Companl Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Beach Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape WB-06 CH RFT 990123 1 1 SIGN DATE: .,t,~ a~ka Oil & Ga~ i3ons. C~.r~an~ion Please sign and return one copy of this trans~iffal lo Sherrie at lhe above address or fax to (~07) 562-6521. ~hank ~ ALASKA O" AND GAS CONSERVATION COMMISS"-' ~ REPORT. 'SUNDRY WELL OPERATI~.~--~S 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate ~ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5208' FNL, 3412' FEL, Sec. 25, T12N, R14E At top of production interval 0. At effective depth At total depth 1030' FNL, 5012' FEL, Sec. 28, T12N, R15E 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) 51.8 feet 7. Unit or Property name WEST BEACH 8. Well number WB-06 9. Permit number/approval number 98-221 / 10. APl number 500292292900 11. Field/Pool West Beach 12. Present well condition summary Total Depth: measured: Effective Depth: Casing Conductor Surface Intermediate true vertical: measured: true vertical: Length 80' 7261' Liner Perforation depth: Size 20" 13 3/8" 13694' 9 5/8" 18700 feet Plugs (measured) 9257 feet 17939 feet Junk (measured) 9104 feet Cemented Driven 1500 sx PF 'E', 898 sx 'G', 4218 sx PF 'E' · 1120 sx Class 'G' 1297' 7" 320 sx Class 'G' measured 17570-17680', 17735-17810', 17860-18090', true vertical 8902-8961 ', 8991-9032', 9060-9188' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# L-80 @ 0-17405' MD Packers and SSSV (type and measured depth) None. RFT PARTS @ 18111' Measured depth True vertical depth 80' 80' 7261' 4709' 13694' 7226' 18210' 9256' RECEIVED ORIGIItI 3 7/8 x 6 PKR @ 17309' MD, 3 4/5 x 4 1/2 SSSV @ 2008' MD 13. Stimulation or cement squeeze summary Please refer to the attached Anohom~ Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 1771 7094 64 621 Subsequent to operation 2026 11613 108 618 15. Attachments 16. Status of well classification as: Tubing Pressure 622 652 Oil ~ Gas __ Suspended Service Copies of Logs and Surveys run __ j Daily Report of Well Operations ~V~ 17. ~,,~y c~f~h at y~/a,,n¢o to~ rrect he best of my knowledge. .~,gnC~e~/..J~ ,//C,:(r~.//_~_,,/Title Sr. Engineer Form 10-4u,~ Rev 06/15/88 Date SUBMIT IN DUPLICATE ,.~est Beach 06 Completion Work Ch~-~oloay ARCO and Exxon request that the information provided below be kept confidential to the fullest extent allowed or required by law, including AS 31.05.035(d), AS 38.05.035(a)(9) and AS 43.05.230. The work summarized below has been conducted in accordance with the requirements of AAC 20 25.280 and consistent with ARCO Alaska, Inc. Prudhoe Bay Unit standard wellwork practices. Detail reports can be furnished upon request. Date 6/12/99 6/24/99 7/3/99 7/4/99 7/5/99 7/8/99 7/15/99 7/16/99 7/17/99 7/18/99 7/19/99 7/20/99 7/21/99 Activity Description RU Slickline, drift tubing to 16,213'SLM, tag proppant with 3" bailier. RDMO. Wellwork shutdown on pad pending installation of new manifold skid and tie-ins. WB-06 Shut-In in preparation for well tie-in and static pressure survey. RU Coil tubing, perform fill cleanout to 17,793' CTM. RDMO RU Slickline, drift to 17,575' with 3.55" dummy gun. Deepest add perf at 17,810' MD. Set catcher sub at 17,378' SLM in XN nipple. RDMO/ RU slickline, pull side pocket memory pressure gauge at 16,295' SLM, run DGLV in Station 6 at 16,295' SLM, pull catcher sub at 17.378' SLM. Inner annulus pressure at 2525 psi. RDMO RU slickline, record memory static pressure survey. Tag bottom at 17808' corrected SLM. Pressure stops recorded at 17,791' MD, 17,476' MD, 17,080' MD, 16,644' MD, 16,174' MD and 15,684' MD. Tubing pressure 1500 psi, inner annulus pressure @ 2450 psi. RDMO. Pressure at 8800' SS/17,476' MD was 4401 psi. Initial reservoir pressure in the well was 3777 psi @ 8800' SS (3/4/99). Tubing/casing had not equalized due to fill in liner over perforations. Pressure data does not reflect reservoir pressure. RU Coil Tubing, load well with 2% KC1 water, tag top of fill at 17,891', reverse out proppant to 17,916' CTM, leave well loaded with crude for add perfs. RDMO RU Slickline, drift tubing with 3.20" dummy and tag top of fill at 17,939' corrected SLM. Deepest add perf. At 17,810' MD, RDMO. RU E-line. Record SBHP survey (pressure at 8800'SS @ 4586 psi, tubing = 1500 psi, casing pressure = 2300 psi). Pressure suspect as initial well pressure was 3777 psi @ 8800' SS. RU E-line and perforate: 17,750' to 17,810' MD, 6 SPF, 60 degree phasing, (Depths reference Schlumberger USIT dated 1/23/99.) Perforate: 17,640' to 17,680' MD and 17,735' to17,750'MD, all 6 SPF, 60 degree phasing. Left gun in hole on last run. (Depths reference Schlumberger USIT dated 1/23/99.) RDMO location. RU Slickline to fish gun. Latch and retrieve fish at 17,879' SLM. RDMO. RU E-line and perforate: 17600' MD to 17640' MD, 6 SPF, 60 degree phasing. (Depths reference Schlumberger USIT dated 1/23/99.) Perforate: 17,570' MD to 17,600' MD, 6 SPF, 60 degree phasing. RDMO. (Depths reference Schlumberger USIT dated 1/23/99.) Page 1/2 _~_ est Beach 06 Completion Work Ch~-~olo~y ARCO and Exxon request that the information provided below be kept confidential to the fullest extent allowed or required by law, including AS 31.05.035(d), AS 38.05.035(a)(9) and AS 43.05.230. Below is a summary of well tests for WB-06: TEST SEP DATE LENGTH CHK TEMP FTP SEP PRES OIL WTR TOTAL GAS GLG % WC GOR GLR 13-Aug-99 12.0 176 62 635 619 897 47 10329 0 5 11515 10942 09-Aug-99 12.0 176 63 640 623 984 54 9964 0 5 10126 9599 08-Aug-99 12.0 176 62 650 636 998 53 9765 0 5 9785 9291 31-Ju1-99 6.0 176 63 643 632 1232 66 8541 0 5 6932 6580 26-Ju1-99 9.0 176 55 632 632 1438 78 11242 3199 5 5593 7416 25-Jul-99 0.0 176 69 588 612 1682 87 11368 3100 5 4916 6426 24-Jul-99 0.0 176 67 590 618 1807 I 15496 0 0 8576 8571 23-Jul-99 6.0 176 58 642 619 1830 49 10955 0 3 5986 5830 22-Jul-99 2.0 176 56 632 618 2026 108 11613 0 5 5732 5442 Additional Perforations shot 7/18/99 throuigh 7/21/99 14-Jul-99 12.0 176 59 618 621 1771 64 7094 0 4 4006 3866 13-Jul-99 0.7 97 52 622 625 2103 57 8394 0 3 3991 3886 23-Jun-99 23.0 100 59 591 591 1102 77 5813 0 7 5275 4930 21-Jun-99 23.0 100 58 617 616 1139 79 5439 0 7 4775 4465 18-Jun-99 24.0 100 59 579 578 1205 90 5040 0 7 4183 3892 16-Jun-99 16.0 100 60 583 581 1318 105 4841 0 7 3673 3402 15-Jun-99 10.0 100 61 602 600 1322 105 4658 0 7 3523 3254 15-Jun-99 5.3 100 60 604 603 1372 114 4625 0 8 3371 3112 12-Jun-99 2.0 100 58 641 630 1974 199 4166 0 9 2111 1917 10-Jun-99 6.0 100 61 581 568 1619 152 3685 0 9 2276 2081 10-Jun-99 6.0 100 60 595 585 1688 157 3448 0 9 2042 1869 09-Jun-99 6.0 100 60 595 584 1681 149 3465 0 8 2061 1893 09-Jun-99 6.0 110 58 595 568 1811 189 6228 2412 9 2107 3114 08-Jun-99 12.0 110 58 630 583 2122 248 6660 3474 11 1501 2810 07-Jun-99 6.0 110 59 662 640 2487 341 5425 3600 12 734 1918 05-Jun-99 0.0 110 62 705 630 2406 705 4246 3050 23 497 1365 Page 2/2 Well: WB-06 SSSV-- NIPPLE PKR NIPPLE NIPPLE TT FRAC FRAC FRAC RFT PARTS GPMA WEB Date: 8/16/99 WB-06 ] APl: 500292292900 SSSV Type: CAT I Annular Fluid: Diesel & Seawater Reference Log: Last Tag: 17939' SLM-CORR Last Tag Date: 7/16/99 Well Type: PROD Orig Compltn: 2~27~99 Last W/O: Ref Log Date: TD: 18700 ftKB Max Hole 69 deg @ 10979 Angle: Angle @ TS: deg @ Angle @ TD: 55 deg @ 18212 Rev Reason: ADD PERF Last Update: 7/22/99 Notes Date Note 2/2/99 Minimum ID = 3.725" at XN nipple 17393' MD. 3/16/99 Frac Sleeve 2.9" ID 49' long set on 3/14/99 (~ 1975' SLM General NOteS ] Date Note 1/24/99 In additions to the IPERFs on 3/3/99, there was also 9 shots taken between 17608-18006 during a SWS RFT. Fish FISH ] Depth Description Comment 18111 RFT PARTS RFT BOLTS -JEWELRY Depth 2008 17298 17309 17372 17393 17404 TVD Type Description ID 1986 SSSV CAMCO 4-1/2" TRM-4E TRSSSV 3.810 8760 NIPPLE X NIPPLE 3.810 8765 PKR BAKER 7" X 4.5" MODEL S-3 HYDRO SET PACKER 3.880 8797 NIPPLE X NIPPLE 3.810 8808 NIPPLE XN NIPPLE (w/C-SUB ran 5/23/99) 3.720 8814 TT BAKER WLEG, 17405' ELMD 4.000 S - All / J Size Weight Grade Top Btm Feet Description 13.380 68.00 L-80 0 7261 7261 Surface 9.630 47.00 L-80 0 13694 13694 Intermediate 9.630 47.00 L-80 13694 16042 2348 Intermediate 7.000 29.00 L-80 15814 16913 1099 Production 7.000 29.00 13CR-80 16913 18210 1297 Production Size Weight Grade Top Btm- Feet Des(~ri'pti(~n 4.500 12.60 L-80 0 17405 17405 Tubing lan:drelSNalves :: Stn MD TVD Man Man VMfr VType VOD Latch pOrt TRO Date VIv Mfr Type 1 2599 2516 CAMCO MMG CAMCO DMY 2 7017 4603 CAMCO MMG CAMCO DMY 3 9501 5617 CAMCO MMG CAMCO GLV 4 12188 6612CAMCO MMG CAMCO DMY 5 14592 7604 CAMCO MMG CAMCO GLV 6 16300 8304 CAMCO KBG-2 CAMCO DV 7 17231 8726 CAMCO KBG-2 CAMCO OV Run 1.5 RK 0.000 0 6/3/99 1.5 RK 0.000 0 5/15/99 1.5 RK 0.250 2496 5/25/99 1.5 RK 0.000 0 5/16/99 1.5 RK 0.000 2471 5/25/99 1.0 BK 0.000 0 7/5/99 1.0 BK 0.250 0 5~27/99 Comment Interval TVD Zone Status Feet SPF Date Type Comment 17570 - 8902 - 8961 O 110 6 7/21/9~ APERF 3-3/8" Powerjet 17680 17735 - 8991 - 9032 O 75 6 7/19/9S APERF 3-3/8" Powerjet 17810 17860 - 9060 - 9188 O 230 4 3/3/99 IPERF 60 deg phasing 18090 Stimulations & Treatments Interval Date Type 17860-18090 3/6/99 FRAC 17860-17967 3/17/99 FRAC 17860-17967 5/19/99 FRAC Comment 30,000 lbs of 20/40 LWP 38,400 lbs of 20/40LWP 124,655 lbs or 20/40 LWP TO: AOGCC 3001 PORCUPINE ANCHORAGE, AK. OPERATOR: AAI SAMPLE TYPE: DRY DITCH SAMPLE TRANSMITTAL DATE: JANUARY 18, 1999 AIR BILL: AFT:09-01-18-01 CHARGE CODE: NAME: West Beach #6 APl NO: NUMBER OF BOXES: 9 SAMPLES SENT: DRIES (1 SET EACH) SENT BY: D. L. PRZYWOJSKI 7260'-18,211' UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPA,%'CIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED: CC: ARCO BAYVIEW GEOLOGICAL FACILITY 619 EAST SHIP CREEK AVE SUITE 102 ANCHORAGE, AK. 99510 DAN PRZYWOJSKI ABV100 E. WESTERGUARD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman DATE: January 4, 1999 THRU' Blair Wondzell, ~ FILE NO: P. I. Supervisor ~tf,~(,)~) FROM' Lou Grimaldi,'/~,~,-~ SUBJECT: Petroleum Inspector AE1JADGE.DOC BOPE Test Pool 7 ARCO / West Beach State WB-06 Prudhoe Oil Pool PTD 98-0221 Monday, January 4, 1999: I traveled to Arco's West Beach State location to witness the weekly BOPE test on Pool rig 7. The test lasted 4 hours with no observed failures. All BOP equipment operated properly. Jon West (Pool Toolpusher) was on hand for the test. The rig was in good condition and the area around the rig was clean with good access. SUMMARY: I witnessed the initial BOPE test on Pool rig 7, ARCO well WB-06. No failures observed. Attachment: AE1JADGE.XLS Non-Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DATE: 1/4/99 Pool Rig No. 7 PTD # 98-0221 Rig Ph.# 659-4815 Arco Alaska Rep.: Les Peak WB-06 Rig Rep.: John West Set @ Location: Sec. 25 T. 12N R. 14E Meridian Umiat Weekly X Other MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Quart. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve N/A I Well Sign P Drl. Rig P Hazard Sec. P Test Press. P/F 250/3500 P 250/5,000 P 250/5,000 P 250/5,000 P 250/5, 000 P 250/5,000 P 250/5,000 P 250/5, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5,000 P 250/5,000 P 250/5,000 P 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 16 250/5,000 P 38 250/5,000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 6 Bottles 1900 Average 2,900 P 1,900 P minutes 45 sec. minutes 0 sec. P Remote: P Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test, No failures. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES Yes NO 24 HOUR NOTICE GIVEN YES Yes NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev.12/94) AE1JADGE~s TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 4. 1998 Lowell Crane ARCO Alaska, Inc. Engineering Supervisor POBox 196612 Anchorage, AK 99519-6612 Re~ West Beach WB-0~ ARCO Alaska. Inc. Permit No: 98-221 Sur Loc: 69'NSL. 3415'WEL, Sec. 25. T12N. R14E. UM Btmhole Loc. 4297'NSL, 4462'WEL. Sec. 28; T12N, RI5E, UM Dear Mr. Crane: Encloscd is thc approved application for permit to drill the above refercnccd wcll. Thc permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be givcn by c~ Icum field inspector on thc North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures CC~ Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. , STATE OF ALASKA A ASKA,. ,. CO S .VAT,O CONFIOENTI L PERMIT TO DRILL 20 AAC 25.005 ¢~, la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test J~ Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 51.8' West Beach State 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034629`/ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 69' NSL, 3415' WEL, SEC. 25, T12N, R14E, UM West Beach At top of productive interval 8. Well Number Number U-630610 4056' NSL, 14' WEL, SEC. 29, T12N, R15E, UM WB-06 At total depth 9. Approximate spud date Amount $200,000.00 4297' NSL, 4462' WEL, SEC. 28, T12N, R15E, UM 11/06/98 12. Distance to nearest pr°perty line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034628, 818'I WB-04, 36' at 906' MD 2560 18527' MD / 9465' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' Maximum Hole Angle 64° Maximum surface 3422 psig, At total depth (TVD) 8480' / 4270 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 WLD 80' Surface Surface 120' 120' Driven 16" 13-3/8" 68# L-80 BTC 7651' Surface Surface 7692' 4687' 3915 sx PF 'E', 825 sx Class 'G' 12-1/4" 9-5/8" 40# L-80 BTC-M 15754' Surface Surface 15795' 8202' 685 sx Class 'G' 8-3/4" 7" 26# 13CR-80 NSCC 2877' 15650' 8139' 18527' 9465' 395 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface nrtoe iu%etid ante R Er E iV E D Liner 0 R I Gl NAL 0c.T Perforation depth: measured .~P.~ka Oil & (~aS COl'iS. Commission Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diver[er Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Bill Isaacson, 564-5521 ~5'{. Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby certify that the foj~going is true and correct to the best of my knowledge Signed n~~ ~'~'/f./ Ti"- Low,, Cra ...... ~ ...... nng Supervisor Date Commission Use Only Permit Number I AP. Number J Approv.al D..ate/~ I See cover letter - for other requirements ¢/~¢ ~,;~ 50- o,t~-. 2 2. ~ ~f 11 -"¢- ¥ ~ Conditions of Approval: Samples Required []Yes J~No Mud Log Required []Yes [~No Hydrogen Sulfide Measures []Yes ~No Directional Survey Required ~'Yes []No Required Working Pressure for BOPE []2K; []3K; []4K; ]~5K; [] 10K; [] 15K Other: Original Signed By by order of Approved By D~vJ(;J W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate WB-06 Well Plan WB-06 Well Plan Summary Surface Location: 69' FSL 3415' FEL Sec 25 T12N R14E Target Location: 4056' FSL 14' FEL Sec 29 T12N R15E Bottom Hole Location: 4297' FSL 4462' FEL Sec 28 T12N R15E I AFENumber: I 2D0064 I Rig: I Pool#7 I Estimated Start Date: I 11-6-98 I Operating days: I 36 I MD: [ 18,527' [TVD: I 9,465' I ]KBE: I 51.8' Type of Well (producer or injector): I Pre-Produced Injector I Well Design (conventional, slimhole, etc.): I Big Bore with Liner Formation Markers: (all depths RKB) Measured True Vertical Formation Mud Formation Tops Depth, ft Depth, ft Gradient, ppg Weight1, ppg Base Permafrost 1900 1852 8.552 8.8 T8 (SV-4) 5122 3572 8.55 9.2 T5 (SV-3) 5987 3947 8.55 9.2 T3 (SV- 1) 7347 4537 8.55 9.2 Ugnu (K- 15) 8303 4952 8.8 9.4 West Sak 12,418 6737 8.8 9.4 Colville (K-12) 13,059 7015 8.8 9.4 Shale Wall (K- 10) 17,166 8805 8.8 10.6 Cabana 16,141 8350 9.7 10.6 to 16,830 to 8650 HRZ 17,454 8945 9.4 10.63 Kupamk 17,536 8985 8.0 10.6 Kingak (Base Kup) 18,327 9368 8.2 10.6 1 Unless otherwise noted, the mud weights are based on a minimum: 125 psi overbalance, if the depth <5000' ss; and 150 psi overbalance, if the depth >5000' ss. 2 Seawater gradient assumed through the SV sands. 3 10.6 ppg is a result coming from Wellbore Stability Study. Value may change depending on ECD Considerations from Hydraulics and PWD. Desired Static Bottomhole EMW is 10.8 ppg Version 1 10-21-98mWSI WB-06 Well Plan Casing/Tubing Program: (all depths feet RKB) Hole Size Csg]Tbg Wt/Ft Grade Conn. Length Top Btm OD MDfrVD MDfrVD 30" 20" 94# H-40 WLD 80 GL 120/120 16" 13 3/8" 68# L-80 BTC 7651 GL 7692/4687 12 IA" 9 5/8" 40# L-80 BTC-M 15,754 GL 15,795/8202 8 ~" 7" 26# 13CR-80 NSCC 2877 15,650/8139 18,527/9465 Tubing 4 V2" 12.6# L-80 IBT-Mod 17,296 GL 17,337/8888 Mud Pro~ram: -- Surface Hole (0-7692'): Fresh Water Surface Hole Mud Interval Density Viscosity YP LSR YP Gel-10 sec Fluid (ppg) (seconds) Loss Initial 8.6-9.2 300-200 70-50 30-40 35-55 12-15 T8 (SV-4) 8.9-9.4 120-200 40-25 18-11 20-35 6-8 Interval TD 9.0-9.4 60-80 20-35 8-15 20-35 6-8 Intermediate Hole (7692'-15,795'): Low Solids Non-Dispersed Interval Density Viscosity YP LSR YP pH Fluid (ppg) (seconds) Loss Initial 8.6-8.8 42-48 8-14 4-7 10.5-9.0 12-8 Ugnu 9.2-9.4 48-60 18-25 8-12 9.0-10.0 8-6 West Sak 9.2-9.4 48-60 18-25 8-12 9.0-10.0 8-6 Colville 9.2-9.4 48-60 18-25 8-12 9.0-10.0 +4 Production Hole (15,795'-18,527'): 3% KCI / Polymer / 5% GEM Interval Density Viscosity YP Tau 0 API/ HPHT Chlorides (ppg) (seconds) Fluid Loss Initial 10.5-10.6 40-50 15 - 25 3 - 6 <5 / <10 cc 14-19K Shale Wall 10.6 40-50 15 - 25 3 - 6 <5 / <10 cc 14-19K HRZ 10.6 40-50 15 - 25 3 - 6 <5 / <10 cc 14-19K Kuparuk 10.6 40-50 15 - 25 3 - 6 <5/<10 cc 14-19K Logging/Formation Evaluation Program: Surface MWD/GR ........... ........................ ..................... Production MWD/GR; CDR/PWD; ADN; DWOB/DTOQ (entire hole section) Wireline / DP: Schlumberger RFT Cased Hole Logs: Schlumberger USIT Version 1 10-21-98--WSI WB-06 Well Plan Directional KOP: 500' Begin gradual build using 1°/100' to 3°/100' DLS until reaching an inclination of -64° and azimuth of -73° at -3160' MD. Max Hole -64° In Tangent Interval -3160' to 16,835' Angle: Close Approach Minimum Normal Distance~Survey-to-Survey Wells: WB-01 15' @ Surface WB-03 89' @ 1532' MD WB-04 36' @ 906' MD WB-05 69' @ 1745' MD Survey Surface - TD MWD surveys as drilling each interval. Program: Version 1 10-21-98--WSI WB-06 Well Plan Cementing Program Hole Category Casing VolumeI Type of Cement Properties2 Size/Depth Surface First Stage 13 3/8" @ Lead3 Lead Lead 7,692' 1205 sx Permafrost "E" Den 12.0 ppg 466 bbls Yield 2.17 ft 3/sx Water 11.6 gps TI' 4.0 hrs Tail4 Tail Tail 825 sx Class "G" w/ Den 15.8 ppg 169 bbls 0.2 % CFR-3, Yield 1.15 ft 3/sx 0.2 % Halad 344 Water 5.0 gps TI' 4.0 hrs Second Stage Stage collar Lead5 Lead Lead @ 2,150' 2710 sx Permafrost "E" Same as above 1047 bbls Intermediate 9 5/8" @ 685 sx6 Class "G" w/ Den 15.8 ppg 15,795' 140 bbls 0.2 % CFR-3 Yield 1.15 ft 3/sx 0.2 % Halad 344 Water 5.0 gps (as required) % HR-5 TT Batch mix + 4.5 hrs Temp BHST 165° / CT 145° Production 7" @ 395 sx7 Class "G" w/ Den 15.6 ppg 18,527' 84 bbls 2.0 gps Latex Yield 1.19 ft 3/sx 0.36 gps 434B Water 3.48 gps 0.05 gps D-Air 3 TI' Batch mix + 5.0 hrs 1.0 % Gel 0.4 % CFR-3 Temp BHST 180° / CT 150° (as required) % HR-5 1 Rounded up to the nearest 5 sacks. 2 Thickening Time; actual times should be based on job requirements and lab tests. 3 Open hole volume from top of tail slurry to stage collar + 50% excess. 4 600' TVD open hole volume + 50% excess + 80' shoe joint. 5 Open hole volume from stage collar to surface + 350% excess + casing capacity to stage collar. 6 1600' open hole volume (12 1/4" x 9 5/8") + 50% excess + 80' shoe joint 7 To 1000' above Kuparuk +50% excess + 80 ft shoe joint (Base actual volume on ADN Caliper). .Alaska 0il & Gas Cons. Commission Anchorage Version 1 10-21-98--WSI WB-06 Well Plan Drilling Hazards/Risks Reservoir Pressure In November 1997, RFT's were run as part of drilling operations on WB-05 and pressures were obtained from both the Kupamk and Cabana Sands. The Kupamk reservoir was under-pressured in the area, with the equivalent mud weight measuring between 7.5 to 8.0 ppg (3550 psi @ 8950' TVD). The Cabana Sands were measured with an equivalent mud weight measuring approximately 9.7 ppg (4270 psi @ 8480' TVD). Lost Circulation/Faults The suspect lost circulation zones in the area are the SV, Ugnu, and West Sak sands. The WB- 06 well design allows these intervals to be drilled and cased in very low mud weights, reducing the chance for losses and differential sticking. However, always use best practices to avoid differential sticking and monitor fluid levels closely to understand losses to these formations. Also, the potential for fluid losses in the Kuparuk interval is high due to the low reservoir pressure in this area. Close Approaches Close approach issues are of minimal concern due to the limited number of wells in the area. The current directional plan passes all appropriate anti-collision rules. Formations Expect to have full sections of the Shale Wall and HRZ. Both formations have shown hole instability potential in the past. Closely monitor mud weight and ECD's at all times. Controlling and understanding these is the key to preventing a destabilized wellbore. Also, since we will be drilling these formations in the intermediate hole section, the increase in mud weight introduces the potential for differential sticking in the West Sak and Ugnu sands. Well Control Well control equipment consisting of 5000 psi WP pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE, and mud fluid system schematics on file with AOGCC. Maximum anticipated surface pressure is estimated at 3422 psi and is calculated using a gas column to surface. This is calculated using an expected formation pressure in the Cabana of 4270 psi and a gas gradient of 0.1 psi/ft. Disposal Haul all drilling and completion fluids and other Class Il wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. All cuttings from drilling operations will be hauled to CC- 2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. Version 1 10-21-98--WSI WB-06 Well Plan Drill and Complete Summary 1. Move in / rig up Pool Rig #7. NU and test Diverter system. Notify AOGCC 24 hours in advance. 2. Directionally drill 16" surface hole to section TD at 7692' MD. 3. Run and cement 13-3/8" surface casing with 2 stage job. E_nsure ce_ment to surface 4. ND diverter NU BOP's and test. Notify AOGCC 24 hours in advance to witness test. 5. Pressure test 13-3/8" surface casing. Drill out and perform leak-off test. 6. Drill 12 lA" hole to section TD at 15,795' MD. 7. Run and cement 9 5/8" intermediate casing. 8. Pressure test 9-5/8" casing. Drill out and perform formation integrity test. 9. Drill 8 3A" hole to well TD at 18,527' MD. 10. Run open hole logs. 11. Run and cement 7" liner. Set liner hanger and liner top packer. 12. Run cased hole logs. 13. Pressure test casing and liner lap. 14. Run 4 V2" single completion, setting production packer in 7" liner. 15. ND B OPE. NU and test tree. 16. Secure well; RDMO Pool Rig #7. Post Rig Work 1. Perforate as per asset requirements. Version 1 10-21-98--WSI Tree: 4 "- 5M CIW Non-Chrome Wellhead: FMC 13-5/8" x 5M psi Actuator: Baker W -06 Proposed Completi °n RT-GL = 40.7' GL-SL = 11.1' I. 4-1/2" 5M psi FMC Tubing Hanger with pup. H. 4-1/2" 12.6# L-80, IBTC-Mod Tbg to surface with SSSV control line banded to pipe OD. G. 4-1/2" Camco TR SSSV set at +/-2000' MD/TVD, with 10' handling pups installed above and below. 13-3/8", 68 #, L-80, BTC I 7,692' F. 4-1/2" 12.6# L-80, IBTC-Mod Tbg to SSSV with Camco 4-1/2" x 1-1/2" 'MMG' GLM's spaced out as below. 10' handling pups installed above and below each GLM. GAS LIFT MANDRELS TVD Type Valve 1 TBD DV 2 TBD DV 3 TBD DV 4 TBD DV 5 TBD DV i i 7" Liner Top at: I 15,650' I 6' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC Hanger ~ 9-5/8", 40 #, L-80, BTC-Mod I 15'795'1 E. 4-1/2" 'X' Landing Nipple with 3.813" seal bore. D. 7" x 4-1/2" Baker 'S-3' Production Packer with 10' handling pups above and below. C. 4-1/2" 'X' Landing Nipple with 3.813" seal bore. B. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. A. Baker 4-1/2" Wireline entry guide with tubing tail +/-200' above top of Kuparuk. 7", 26 #, '13CR-80, NSCC I 18'527'1 Total Depth Date 10/21/9 8 Rev By WSI Comments Proposed Completion [ 18,527' MD ] 9,465' TVD J West Beach WELL: WB-06 APl NO: 50-029-????? Shared Services Drilling AnadriL[ Schlumberger Alaska District 3940 Arctic Blvd, Anchor&ge. AK 99S03 (907} 273-1700 Fax 561-8537 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... Field ........ .. Prudho~ Bay, ~est Beach Pad Computation.. : Ninim~m Curv-ature Uoi~s ........ : FEET Surface La~.. : 70.35825364 Surface Loag.: 14E.47471586 begal Description Suwface ...... : 69 FSL 3415 FEL Target ....... : 4056 FSL 14 FEL B}{L .......... : 4297 FSL 4462 FEL ITDCATIONS - ALASKA Zone: 4 X-Coor~ Y-Coord S25 T[SN 214E UM 687981,91 5982962.85 S29 T12N R15E I/M 701~00, O0 5987308.00 828 TiRN R15~ L%! 70~02~.8l 5987563.34 PROPOSED ~LL PROFILE STATIO~¢ MEASURED [NCLN [DE~IFICATION DEPTH ANGLE KB 0.00 KOP BUILD L/~00 500,00 BU]hD 1.5/LO~ 600.00 1.0~ BUILD 2/100 700.00 2.50 BUILD 2.!~//00 800.00 4.50 DIRECTION VERTICAL-DEPTHS AZ[[~r~TB T~D SUB-SEA 0.00 0.00 -81,80 0.00 500.00 44~,20 0.00 599,99 548,19 0.00 699.95 642.15 O.00 799.75 747.95 SECTION DEPART o.00 0.00 0,25 1,13 2,87 Prepared ..... : 19 OcC 1998 Vert sect az.: 73.35 KB elavation.: ~1.80 ft ~agnetic Dcin: +2S.017 (El Scale Factor.: 0.99994006 ConYersence..: +1.43657053 ~,r,.~ .~, r:l'.,'~ ~ AKA-DPC i ~.'~,.I..'~".,: 'U C F :,A. I !LiTY PLAN NOT A? P[<OVED FOR [XECUTION COORDiNATES-FROM ALASKA Zo6e 4 WELLH~AD X 0.00 N O.OO E 657981.$1 5982962.85 0.00 N 0.00 E 687781,S[ 598296~.85 0,87 N O.00 E 687781,49 5982963.72 3.93 N 0.00 E 687781.4~ 5982966.78 10,03 N 0.00 E 687781.26 5982972.88 900.00 5.43 .. 1000.00 7.15 Il00.00 9.24 1200.00 ~1.49 1300.00 13.83 27. lB 43 53 .67 59 -76 63 -85 899.39 . 647.59 998.79 946,99 1097.77 1045.97 1196.14 1144 34 1293.70 1241 90 7,28 18.16 ~ 2.16 15,98 26.86 N 8-6~ 28.96 36.[0 N 19.~3 46,21 45,88.1t 34.51 67.65 56.[6 N 53-84 FACE 100 HS 0.00 ~ 0.00 H~ 1.00 H8 1.50 27R 2.00 687783.22 5982981.06 5SR 2.50 687789.~8 5982989.92 39R 2.50 687800.~3 5982999,43 29R 2.50 687814.85 5983009,58 23R 2.50 687833.92 5983020,34 19R 2.50 [400.00 ]6,21 1500.00 18.62 66.76 68.94 1390.28 1.338 1485.69 1433 48 93.33 6f.9~ N 77.40 E $9 123.12 78.18 N 105,13 E 68785'7.20 5983031,70 1.SR 2,50 687884.64 5983043.64 Z4R 2.50 l> (Anadrill (c)98 WB06P4 3.2C S:0B P?,I P) h3 STATION [DSMTIPICAT[ON DEPTH ANGLE E)~ 2.5/ZOD BUILD ~UILD 3/]00 L600.00 21,06 !700,00 23.50 1800,00 25.96 1865.00 27.$6 1899,59 27-56 1935.00 27.56 2000.00 29.51 2100.00 32.51 2200.00 35.51 2300.00 38.51 PROPOSED W~LL PROFILE DrRECTIO~ VERTICAL- BE PTKS AZ I ~¢JTH TVD SU~-SEA 19 Oct L998 70.6~ L579.75 1527.95 71.99 2672,27 1620.47 73.11 ~763,09 1711.29 73.~3 I821.13 1769.33 73,73 1851,80 ]800.00 SECTIOR ODORDI~ETES-FROM DEPART [~ELL~IEAD LS?.00 89.88 ~ 136.98 /94.88 102.00 ~ 172.90 236.7[ 114.53 N 212.$/ 265.98 122.88 ~ 240.86 281.98 127.36 ~ 256.23 73.73 1883.[9 1831.39 298,36 ~31.95 N 27T.96 73,73 1940.29 1888.49 329,4Z X40.65 N 30X.76 73,73 2025.99 1974.~9 380.92 ~55.08 N 35~.21 73.73 2108.87 20~7.07 436.85 [70.75 N 4~4.90 73.73 2188.71 2136.91 497.04 187.62 N 462.68 Page 2 ALASKA Zone 4 TOOL DL/ X Y FACE 100 ~8~916.19 5983056.13 L2K 2.50 683952.39 $983069.15 llR 2.50 687991.37 5983082.67 10R ~.50 6880[9,20 5983091.?2 HS 2.50 688034.4S 5983096.S9 HS 0.00 688050.06 5983101.57 HS 0.O0 688079.63 5983111.01 688128.70 5983126.68 ES 3.00 688181.98 5983143.69 HS 3.00 688239-31 5983161.99 BS 3.00 CO BND 3/100 BUILD T-8 2400.00 4[.51 2500.00 44.51 2600.00 47.51 2700.00 50.~1 2800,00 53.51 2900,00 56.51 3000,00 59.51 3~O0,00 62.51 3~59.32 6~.29 5122.13 64.29 T- 5 5986.56 64 ,29 T-.3 7346 .59 64 .19 13-'3/8'1 CSO PT <1 I.> 7692.36 64.29 K-15 8303.23 64 ,29 ~gES% SILK 12417.90 64.29 K-t2 13058 .~3 64 .29 9.5/8" CSG PT ..1[> t5'/94 .94 64 ,29 CTkB:\NA 16140 . 71 64 . 29 {Anadrill <c)98 MS,D6B4 3.2C 5:0~ PM 73.73 2265.30 2213.50 561.32 73.73 2338.41 2286.61 629.53 73.73 2407.85 2356.05 701.47 73.73 2473.44 2421.6~ 776.9~ 73.73 2534.98 2483.R8 855.74 73.73 2592.32 2548.52 937.65 73.73 26~5.29 2593.4~ 1022.46 73.73 2693.75 2641,95 1~D9.92 73.73 2720.31 2668,~1 116~.95 73.73 3571.80 3520,00 2931.41 205.63 N 524.39 224.74 M 589.,87 244.89 N 658.92 266,04 N ~31.37 288,11 N 807,02 311,06 N 885.66 334,82 N 967.07 359,33 ~ 1051.03 374,19 ~ I101.94 869,67 N 2799.6~ 73.73 3946,80 3895.00 3710.25 1087.88 N 3547.27 73.73 4536,80 ~485,00 4935.62 1431.~9 N 6723.59 73.73 4686.80 4635.00 5247.15 1518.48 N 5022.65 73.73 4951,$D 4900,00 579$.53 1672.68 if 5551.O0 73.73 6736.88 6685,00 9504.78 2711.36 N 9109.86 73.73 ~03.4.80 6963,00 i008~16 73.73 8281,80 8:tSfl.O0 12547.43 73.73 8351,80 8300.00 ~858,96 688300.55 5983/8[.55 HS 3,00 688365.52 5983202.29 HS 3.00 688434.05 5983224.~7 HS 3.00 688505.9~ 5983247.I2 HS 3.OO 68858~.05 5983271.09 H,S 3-00 ,, 688659.0~ 5983296.0~ ~S 3.00 688739.82 5983321.79 HS 3.00 688823.13 5983348.39 }tS 3.00 6888?3.65 5983364.52 HB 3.00 690558.27 5983902,38 HS O.O0 691300.18 $984139.25 692467,46 5984511.93 692764.22 5984606,68 693288.51 5984774,07 696820,01 5985901 58 H8 0.00 HS 0.00 H$ 0.00 HS o.00 KS 0.00 2873.13 H 9664.13 3563.84 tf 12030.72 3651.12 R 1232! 69737(].01 5986077 18 HS 0.00 699718,41 5986~26 97 I{S 0.0(I ~.~ 3 ~__ IE _.7_9_9.Cl 15..,_]..,%_53_~. 6_9_2.1 ,~7_2 ..... I{ $ 0.0 o rL~ !"," ."~ C', .,.'? .' · . ...... . ..... .,, LI_ A ~ .'...., ' : ,.~ NOT .... E><ECUTION PI A -U PROPOSED ~'~ELL PROFILE STATION ~&EASURED INCLN DIR~CTIO~ VERT]CAL-~EPTHS IDENTIFICATION DEPTH ANGLE AZIMUTH T'VD SUB-SEA ==.~==~= ............ =====_~= ....................... -- DRO? ~/100 !6~36.48 64_29 73.73 8653.63 8601.83 16900.00 63.66 $3.73 8681.5L 8629.71 17000,00 62,66 73.73 87~6.66 8674.86 17L00.00 61.66 7~.73 8773.37 8721.87 EiND 1/100 D~OP 17i65,50 61,00 73.73 ~$04.80 8753.00 K-10 ~7165.50 6~.00 73.73 8804.80 8753.00 H,qZ <<<<<<<<<<<<<<<< ~7454.28 61.00 73.75 8944,80 8893.00 TARGET ****~******** [7536.78 61.00 73.73 8984,80 8933.00 TOP K~,ARUK 17536.78 6l.~G 73.73 8984.80 8933.00 K[NGA}~ 1832~.78 6L.~G 73.73 9~67,80 9516.00 TD 7" LlfR PT <Il> 18526.78 61.80 73.73 9464.76 9412.96 TO? ~VISHAK 1055/.80 IOSOO.O0 SECTIO14 DEPART 13485.84 13542.9~ ~3632.~4 13720.56 13778.03 13778.03 14030.59 14102,78 14793,68 14968.68 ~90c= 1998 COORDINATES-FROM WELLHEAD 3526.76 N 12931.57 3842.75 ~ ~2986.36 3867.74 N [3072,01 3892.$2 ~ I3156,89 3908.62 N 13212.86 390~.62 N 13~12.06 3979.58 1~13%$4.51 3999.6(] N 13523.78 3999.6(3 N 13523.78 4193.18 N 14187.06 42~2.19 N 1435~.95 E Page 9 ....... ==== .... Zone 4 TOOL DL/ Y FACE 100 700612.34 5987112,38 g00666.71 5987129.73 LS 1.00 700751.70 5987156.67 LS 700835.93 5987183.76 LS 1,00 700~90.67 598020L.24 HS 1.00 700890.67 598720~.24 MS 1.00 70~3~,26 5987278.0~ ~S 0.00 70~900,00 5987300,00 HS 0.00 701200,00 5987500,00 HS 0.00 701858.18 5987510,14 HS 0.00 702024.81 5987563.34 0.00 ~,~,~'....... ,,_.~.' l L AKA-D?C >. I TY PLA'Iq NOT -- ...... O FOR EXECUTION PLAN (A.qadri'll (c)98 WBg6P4 3.2C 5:08 PM P) .... S'HAR'Eb "SERVZdES 'DRtLL't[N6' ' i · ii iii iii ii i iii ii iii i i i i iiiij i i i Anadr i ] ] Sch]umberger i iiii ii i ii i , ...... i i i i · 18-06 (P4A) VERTICAL SECTION VIEW ,Section at'. 73.35 (KB> 100 800( ,1:'-'~::-,'~ ~:'~LITY PLAN , ...... -: .... i:..- -,, : :TVD Scale ' ~ inch: 2000 feet NO~ APPROVED FOR ~: - ~ ................. ~ IOra~n ..... : ~9 Oct 19~8 - ~-~,m~h~r-,~ C] BUILfl ].5/100 600 BO0 O D] BUZLD 2/t00 700 700 1 2.5 .. E) BUILD 2.51100 800 BDO 3 H ~ F) END 2.5/~00 BUZLD 1865 ~B21 266 27.~ - ~ B) GUILD 3/~0Q 1935 ~883 298 27.~ H) ENB 3/100 BUILD 3&59 2720 t163 64.2 I) 13-3/8' 6S6 PT <I1> 7892 4687 5247 'T~"- ~ ............ ~ J) ~-5/8" 6~ PT <1~ > J5795 8202 ~254Z 64.2 - ~:~- ~r4r ' ' ' ' -- ' ...... K) D~P ~/tOO ~6806 8654 ~34~ 64 ff:3-'~0% ................................ ~l TARGET ~~ ~7~37 B~ ~g3 ~ , .............. ,, I~~ ,,, ,,,, .... l ...... , .... ......... .-- ~-~--~ -~-~.. , ~ ............ ~ ...... ........... ,, , , ~ , ,, ,, ,,, 0 dO00 2000 3000 4000 5000 5000 7000 8000 9000 tO000 !iOOO J2000 ~3000 ~4000 1.5000 JBOOO !7000 Section_ Dep. arture .......... ", ............. mao:.~] "i~l .~ ,eo~p,' 5'.~c ~:~ ~'m ............. AnadrJ 1 ] Sch ]umberger . _ ii i i i ii i · ii i · im I III PLAN VIEW II Ii I ]LOSURE ..... : 14969 feet at Azimuth 73.54 ]ECL[NAT]ON.: +28.0t7 (E) BCALE. ' 1 inch = 2000 feet )RAVIN ....... : I9 Oct 1998 S' AR "D' SE'jblV T C'F_"S I Il mil i · ~eker tdent ~ f icon,on ~3 )O/S E/W A) KB O 0 N 0 E B) i<OP BgILD l/tOO 500 0 N 0 E C) BUILD 1.5/lO0 600 ! ~t 0 E D) BUILD 2/t00 700 4 N 0 E E) BUILD 2.5/100 800 lO I( O E F) END 2.5/I00 BUILD ~865 123 N 241 E G) BUILD 3/100 lg35 132 N 272 E H) END 3/100 BUILD 3359 374 N ~02 E I) 33-3/8' CSG PT <l I> 7692 3518 N 5023 E J] 9-5/8" CSG PI <l I> 15795 3564 N 12031 E K) DROP l/iO0 16B36 3827 N 12932 E L) END 1/I00 DROP ~7156 3909 N 132~2 E M) lARGEr ,~x~,~,~ ~7537 4000 N 13.924 E N) 11] 7' LNR PT <l I> ~8527 4242 N · 14355 E DR"ILLI'NG IIII III I · ii ii m 40{ 3OO 200 iQO0 0 tO00 2000 3000 4000 5000 6000 7000 8000 9000 10000 J~OQO 12000 ~3000 14000 15000 16000 170DO <- ~EST' EAST ~> ' I DATE I CHECK NO. H 14 3 0 G 3 ~o/~/?~ oo~ 4 VENDOR .AL ASK. AST 14 DATE INVOICE / CREDll' MEMO DESCRIPTION GROSS DISCOUNT NET · 092198 CK092198 !00. 00 !00.00 HANDL!N,-= I.~:, S/H CAROL WTTHEY~ .~_41t~_ ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. = itl f:lll ~ i OO. Or:.~v ir~n=~ =. ~,r,c:~ FIEf D & POOl ADMINISTRATION WELL PERMIT CHECKI.,IST AI?I q,~ I)All. ,; ENGINEERING APPI~ DA I'E GE_OL_O_GY APl >l't I.)AI I;'f ANNULAR DISPOSAL APIq,~ I)AI l'.' I 2 3 4 5 6 7 8 9 10 11. 12 13. 14. 15. 16 17 18, 19. 20. 21 22. 23 24. 25, 26. 27. 28. 29. 30. 31. 32 33 34 COMPANY _..~ ~,, C_..._0. ......... WEll NAMF. '~/V' ~ - O 0 PROGRAM: exp [J dev I7~edrll [TI serv [:1 wellbore segll ann. disposal para Y N Y N Y N Y N I~elndl fee attached ............ I ease ~mmber appropriate ........ Ulli(lue well name and ntm~bel Well Iocaled in a defined pool ........... We. II Iocaled proper dislance flora dlilling unil botuMa~y Well Iocaled proper distance from other wells ...... Sidticienl acreage available in drilling trail . . If devialed, is wellbore plal included ............ Operalor only affected pady ............... Operalor has appropriale bond in force ............. Permil can be issued wilhoul conse~ation order ........ t~ellnil can be issued wilhoul administralive appioval ..... Ca~ permil be approved before 15-day wait ........... Conduclor string provided ................ Stuface casing protects all known USDWs ......... CM 1' vol adequale to circulate on conductor & surf csg .... CMI vol adequate to tie-in long string to stuf csg ........ CMI will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adeqt~ate lankage or reserve pit ................ Ii a ~e-dlill, has a 10-403 for abandonme~d bee~l approved. Adequate wellbore separation proposed ............. If diveder required, does il meet regulations .......... Drilling fluid program schematic & equip list ade(luale .... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to _,,~5'ooo psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is p~esence of H2S gas probable ................. I'~ernfit can be issued w/o hydrogen sulfide ~neasures. . ~ Dala presenled on potenlial overpresst~._z~... Seismic analysis of shallow~gas~cmes.---"~ .... ' Seabed co n~~(i f"'~' "'off-shore) ............. Cr)nta¢.-f~/phon.e .for weekly progress repolls ..... ---J~ploratory only] ON/OFF SI-lORE ... (~..~ (A) will contain waste in a suitable receiving z~e; ....... Y N (1~) will not conlaminale fl'esti'~ater; or c¢"drilling waste . Y N Io stuface; ~. / (C) will ~lol impair mechanical int~.~of th.e wel! used for disposal; Y N (I)) will not damage pro~~~l)air ~ecovery from a Y N pool; and [_._.(E] will nol circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Qg(.)l 0GY: _E_N_G_ LN_E_ E.R_!. _N...G.: .................. ~' COMMISSIQ..N.: I:]1 '(~:~ JDII~ ...... RNC ............... '; ~ M r:h¢!ldml I,'v ()h/2r)/fiH Corn merits/Instructions: