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Home My WebLink About198-153&44C� BI -z';- Regg, James B (CED) rTn I% 0530 From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRe bp.com> Sent: Saturday, June 8, 2019 11:02 AM�`� To: Regg, James B (CED) Cc: Bixby, Brian D (CED); AK, OPS FF Well Ops Comp Rep Subject: RE: B1-25 Information Jim/Brian Be advised that the B1-25 well sign was delivered to the expeditor for delivery to Badami Thursday pm. I spoke with Wayne Kuykendall and he said he would get it installed when it arrived. Regards, Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony — 7187 (Alternate: Vince Pokryfki) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Wednesday, May 29, 2019 2:04 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Bixby, Brian D (CED) <brian.bixby@alaska.gov>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@ bp.com> Subject: RE: B1-25 Information !qin, I will get a sign ordered and arrange to have it delivered to Savant at Badami. Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony — 7187 (Alternate: Vince Pokryfki) From: Regg, James B (CED) <jim.retg@alaska.aov> Sent: Wednesday, May 29, 2019 12:53 PM To: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Cc: Bixby, Brian D (CED) <brian.bixby@alaska.gov> Subject: RE: 131-25 Information Vince/Lee — I am following up on Brian Bixby's inquiry about Badami B1-25 — see email below. The well sign that was hung on the well (photo attached) — by Savant? — is not correct. The 2 laterals (131-251-1 and -251-2) were canceled in 1998 according to our records. Please make arrangements for a correct sign on the well. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or ilm.regg@alaska.eov. From: Bixby, Brian D (CED) Sent: Tuesday, May 28, 2019 2:09 PM To: Regg, lames B (CED) <lim.reeg@alaska.gov> Subject: FW: B1-25 Information Jim, While out at Badami witnessing SVS tests I noticed there was no sign on one well. After talking with Stave Sage out there he said that the well belongs to BP. I reached out to Vince and you can read his email below. Not sure if this well is suspended or what. You can see from the pictures there is no wellhouse and no flow lines. The tubing and casing are cut and a couple CIB set. The guys there found the sign in the shop and hung it for me. Just thought I would pass on to you. Thanks, Brian Bixby Petroleum Inspector Cell 509-998-3683 brian.bixbv@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at (907) 279-1433 or brian.bixby@alaska.gov. From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Saturday, May 25, 2019 6:46 PM To: Bixby, Brian D (CED) <brian.bixbv@alasl<a.gov> Subject: B1-25 Information Subject: B1-25 Information Brian, Got your message about not needing the sign but this is the info I dug up on 131-25. Learn something new every day. • Per e-mail dated January 17, 2012 from our Legal Department: "As of January 7 all Badami wells except B1-25 were transferred to Savant and ASRC. B1-25 is a Retained Well and we remain responsible for it. At the cessation of production, up to five additional production wells (131-11A, 61-14, 81-15, B1-16 AND 81-28) will become Retained Wells if they are not modified by Savant and ASRC. At the cessation of production we will also reacquire the disposal well B1-01". • We receive B1-25 IA and OA readings from the Badami Control Room Operator, to ensure they remain at 0 psi. The Well Integrity folks in GWO receive the reads, not our position. • Wellbore schematic attached, which includes the required information for the sign. • The well is not suspended. Vince Vince Pokryfki GPB Pipeline and Well Ops Compliance BP Exploration (Alaska) Inc. PBOC — B103 Office (907) 659-5332 Cell (907) 354-1352 Harmony — 7187 Alternate: Lee Hulme MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg N"-- 5P41'J DATE: 5/28/2019 P. I. Supervisor /('/ FROM: Brian Bixby SUBJECT: Well Inspection Petroleum Inspector Badami B1-25 BPXA PTD 1981530 - 5/25/2019: While out at Badami witnessing SVS tests, I noticed there was no sign on one well. I discussed with Steve Sage (Savant) and he said that the well belongs to BPXA. I reached out to Vince Pokryfki (BPXA Greater Prudhoe Bay Pipeline and Well Ops Compliance representative) about the well. In January 2012 all Badami wells except B1-25 were transferred to Savant. The well had no wellhouse, no flow lines, and no well sign. Savant located the well sign in the Badami shop and hung it on the well. Attachments: Photos (4) - 5/25/2019 Email Well Schematic Inspection Supervisor's Note: Badami B1-25 is shown in RBDMS as 1 -Oil completion with a long-term shut-in status, having been secured with a downhole plug effective 4/8/2005 as approved in Sundry 305-022. The well sign incorrectly references 2 laterals (B1-251-1 and -251-2) which were never drilled (shown in RBDMS as canceled effective 10-9-1998). 2019-0525_W ell_Badami_B 1-25_bb.docx Pagel of 3 ,.l l.....■■..i of/ 19112152180 �� uuunu ii i ILI luuuunr� rr i � ��uuu.urr i Well sign incorrectly references 2laterals (Bl-25LI and Bl - 25L2) that were never drilled (canceled 10/9/1998) 2019-0525_Well_Badami_B I-25_bb.docx Page 3 of 3 Py� ng) 530 Regg, James B (CED) From: Bixby, Brian D (CED) Sent: Tuesday, May 28, 2019 2:09 PM To: Regg, James B (CED) Subject: FW: B1-25 Information Attachments: 81-25.pdf; 190525 B1-25 at Badami 3.JPG; 190525 B1-25 at Badami 4.JPG; 190525 Bt -25 at Badami 1.JPG; 190525 B1-25 at Badami 2.1PG Jim, While out at Badami witnessing SVS tests I noticed there was no sign on one well. After talking with Stave Sage out there he said that the well belongs to BP. I reached out to Vince and you can read his email below. Not sure if this well is suspended or what. You can see from the pictures there is no wellhouse and no flow lines. The tubing and casing are cut and a couple CIB set. The guys there found the sign in the shop and hung it for me. Just thought I would pass on to you. Thanks, Brian Brian Bixby Petroleum Inspector Cell 509-998-3683 brig n. bixby@a laska.eov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at (907) 279-1433 or brian.bixbv@alaska.gov. From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Saturday, May 25, 2019 6:46 PM To: Bixby, Brian D (CED) <brian.bixby@alaska.gov> Subject: B1-25 Information Subject: B1-25 Information Brian, Got your message about not needing the sign but this is the info I dug up on 81-25. Learn something new every day. Per e-mail dated January 17, 2012 from our Legal Department: "As of January 7 all Badami wells except B1-25 were transferred to Savant and ASRC. B1-25 is a Retained Well and we remain responsible for it. At the cessation of production, up to five additional production wells (131-11A, B1-14, B1-15, 81-16 AND 131-28) will become Retained Wells if they are not modified by Savant and ASRC. At the cessation of production we will also reacquire the disposal well 131-01". • We receive B1-25 IA and OA readings from the Badami Control Room Operator, to ensure they remain at 0 psi. The Well Integrity folks in GWO receive the reads, not our position. • Wellbore schematic attached, which includes the required information for the sign. • The well is not suspended. Vince Vince Pokryfki GPB Pipeline and Well Ops Compliance BP Exploration (Alaska) Inc. PBOC — B103 Office (907) 659-5332 Cell (907)354-1352 Harmony — 7187 Alternate: Lee Hulme I'EKt VKA I IUN JVMNIAKT I REF LOG: ANGLE AT TOP PERF: Note: R eter to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 4-1/2" SL TD 11980 - 12750 C 04/10/05 PBTD 12749' 4-1/2" LNR, 12.6#, L -80, !n 12750' , .0152 bpf, ID = 3.958" DATE REV BY I COMMENTS DATE REV BY COMMENTS 11/22/98 N28E ORIGINAL COMPLETION 04/08/05 N4ES P&A 04/14/09 /SV DRLG DRAFT CORRECTIONS 06116/09 MAS/TLH DRLG FINAL CORRECTIONS 02/21/11 MB/JMD ADDED SSSV SAFETY NOTE BADAMI WELL: B1-25 PERMIT No: X1981530 API No: 50-029-22906-00 SECS , T9N, R20E, 1423' FNL & 17' FEL RP Fvnlnrafinn lAlaclr al DATE REV BY I COMMENTS DATE REV BY COMMENTS 11/22/98 N28E ORIGINAL COMPLETION 04/08/05 N4ES P&A 04/14/09 /SV DRLG DRAFT CORRECTIONS 06116/09 MAS/TLH DRLG FINAL CORRECTIONS 02/21/11 MB/JMD ADDED SSSV SAFETY NOTE BADAMI WELL: B1-25 PERMIT No: X1981530 API No: 50-029-22906-00 SECS , T9N, R20E, 1423' FNL & 17' FEL RP Fvnlnrafinn lAlaclr al BADAMI WELL: B1-25 PERMIT No: X1981530 API No: 50-029-22906-00 SECS , T9N, R20E, 1423' FNL & 17' FEL RP Fvnlnrafinn lAlaclr al STATE OF ALASKA CECE~V ALASKA t AND GAS CONSERVATION CO~_)ISSIO~' ".:~. ED REPORT OF SUNDRY WELL OPERATIONS 1 2 Z005 1. Operations Performed: D Abandon D Alter Casing D Change Approved Program 181 Repair Well D Plug Perforations D Stimulate D Pull Tubing D Perforate New Pool D Waiver D Operation Shutdown D Perforate D Re-Enter Suspended Well Alaska Oil & GlIlS GorIS. CommissiQo ~fitJ!::; q~~._.__._--_._-_._- D Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: 181 Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number: 198-153 6. API Number: 50-029-22906-00-00 99519-6612 54.80' 9. Well Name and Number: Badami B1-25 8. Property Designation: 10. Field / Pool(s): ADL 365533 Badami 11. Present well condition summary Total depth: measured 12750 feet true vertical 10596 feet Plugs (measured) 2450' & 2347' Effective depth: measured 2347 feet Junk (measured) None true vertical 2347 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 110' 110' 1490 470 Surface 4490' 9-5/8" 4524' 4523' 5750 3090 Intermediate Production 10862' 7" 2501' - 10895' 2500' - 9050' 11220 8510 Liner 2053' 4-1/2" 10697' - 12750' 8901' - 10596' 8430 7500 SCANNED MAY 2 () 2005 Perforation Depth MD (ft): Perforation Depth TVD (ft): Slotted 12225' - 12477' Slotted 10125' - 10349' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", 12.6# 4-1/2", 12.6# Baker S-3 Perm Packer HES THB Perm Packer & Perm L-80 L-80 Surface - 2280' 4465' - 8229' 8127' 8183' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation: Subsequent to operation: 14. Attachments: D Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: D Exploratory 181 Development D Service 16. Well Status after proposed work: 181 Oil D Gas D WAG D GINJ D WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem,564-5743 _~"-:OJJ-30~2 /<ÞL:/ Printed Name Sondra Stewman Sign~ Form 10-404 ReviSéd 04/2004 Title Technical Assistant O'R I G 1f\t~ L Prepared By Name/Number: Dateffi-- l2~OSSondra Stewman, 564-4750 Submit Original Only .1 TREE: 4-1/16" / 5000 psi' ~ WELLHEAD: 13-5/8"/ 100l ,li / FMC RT. ELEV = 54.8' BF. ELEV = 19.5 MAX. DEV. = 58 @ 8100' MD SAFETY NOTES: EST. ~\.' OUTSIDE 7"@989S' ***TxIAxOA eOMM*** J ***POSSIBLE MILLED HOLE IN 7" eSG@4504'*** B1-25 DRLG DRAFT 4 1/2" L·BO 1ST MOD l J ·12.6#/ftTubing -j 1 WLEG @r......".~:~?":,J ~::!¡C s.~ Hal!itl?url~n~~ 51/8" EZSV ...,.., ^ ^ ,.. 2.;A7 TOP OF T~G 50' Arctìc Set 1 cmt :I:::::ìBG ~-~-:l:::~::r Fasdrill L-80, BTC. CSG. ~ '::> ':> ,¿ ¿ .. 2501' I 4524' I ~ Gas Lift Summary Camco 1" KBG-2-LS GLM MD TVD DEV ß: 41/2" L-80 IBT MOD 12.6#/ft Tubing . 4474 I I 81621 Unique Overshot 7.5' Assy w/o seals stabbed over 12' of 4.5" L-80 tubing z z ) , ~ Z U z Z] 41/2" L-80 IBT Solid Liner .. ... ~ HES X Nipple 10 (3.813") 1 2051 I 2 5923 5886 30 1 8061 7209 57 Baker S-3 18127 1 Permanent Packer HES XN Nipple 9CR I 81461 ID (3.725") HES THB I 81831 Permanent Packer HES X Nipple 9CR I 81971 10 (3.813") HES XN Nipple 9CR 182171 10 (3.725") WLEG 18229 I ELMO 182201 7" X 4 1/2" Liner 1106971 Hanger Packer ~ 7" 29#/ft P11 0 BTC CSG Shoe 1108951 Top of Slotted Liner 1119801 PBTD 12749 Casing Shoe 12750 DATE REV. BY COMMENTS BADAMI WELL B1-25 3-30-99 JTP Update Information PERMIT # 98-153 9-16-04 JLA/TLH Collapsed Tubing 2-8-05 RO/TLH SSSV & Tbg Correct API # 50-029-22906 4-2-05 JRA/TLH JET CUT (3/27/05) BP EXPLORATION, INC. ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B1-25 B1-25 TEMP ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 4/1/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: End: 4/8/2005 Date'· From-ro' Hours Task Code ···NPT Phase De.scri ptiortof Qperations· · 4/1/2005 12:00 - 23:00 11.00 PRE Rig down off DS9-20i & prep for move to Badami B1-25. Wait on trucks - Nabors 27E move at Kuparuk. 23:00 - 00:00 1.00 PRE Trucks arrive, start hooking up to rig modules. 4/2/2005 00:00 - 01 :30 1.50 MOB P PRE RID Prepare to move to Badami B1-25. 01 :30 - 05:30 4.00 MOB P PRE Move off os 9-20 onto Endicott access road. 05:30 - 09:30 4.00 MOB P PRE Move down Badami ice road. Blew tire. 09:30 - 13:30 4.00 MOB N RREP PRE Replace blown tire on left outboard side. 13:30 - 21 :00 7.50 MOB N PRE Con't to move down Badami ice road to Badami Pad. 21 :00 - 22:00 1.00 MOB N PRE Prepare well for MORU. Lay down Herculite & spot in matting boards. 22:00 - 00:00 2.00 MOB N PRE Spot in rig sub over B 1-25 well. Spot pits & pipe shed. Begin R/U modules. 4/3/2005 00:00 - 02:00 2.00 MOB P PRE Spot camp. R/U rig & equip. ( DST Move clock ahead 1 hr) 02:00 - 06:00 4.00 RIGU P INTERV Con' t to R/U equip. Raise & scope up derrick. ACCEPTED RIG @ 03:00 Hrs. 06:00 - 08:00 2.00 RIGU P INTERV Take on seawater. Line up tree for kill operations. 08:00 - 08:30 0.50 KILL P INTERV Hold PJSM & Pre-Spud meeting wlall hands. Test kill lines to 250/3500 psi. 08:30 - 10:30 2.00 KILL P INTERV Open well. SITP 20 psi, SICP 90 psi. Circulate well wI 120 degree seawater & kill well. pumped 3 BPM @ 350 psi, increased to 4 BPM @ 350 psi. Pumped 250 Bbls. SID. Monitor well, well dead. 10:30 - 12:00 1.50 WHSUR P INTERV Set TWC. Test to 3500 psi. Blow down & RID lines from kill operations. 12:00 - 16:00 4.00 WHSUR P INTERV Bleed off hanger void. N/D tree & adapter. 16:00 - 19:30 3.50 BOPSUR P INTERV Install 1 OM x 5M DSA & N/U BOPE. 19:30 - 00:00 4.50 BOPSUF P INTERV Pressure test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Jeff Jones wI AOGCC. 4/4/2005 00:00 - 00:30 0.50 BOPSUR P INTERV Finish testing BOPE. RID test equip. Test witnessed by Company Man & Tool Pusher. 00:30 - 01 :30 1.00 WHSUR P INTERV R/U lubricator. Pull TWC. UD lubricator. 01 :30 - 02:30 1.00 PULL P INTERV M/U landing it. BOLDS. Pull hanger to floor wI 56K. UD hanger & landing it. 02:30 - 03:00 0.50 PULL P INTERV R/U spooling unit & tools to UD 41/2" tubing. 03:00 - 06:00 3.00 PULL P INTERV POOH & UD 4 1/2" tubing. Pull 11 its & tubing pulled tight. 35K overpull. Work pipe. Control line bird-nested. Pull control line wI tugger & work pipe. Estimated 1200' of control line out presently. RU to circulate hot seawater to clean up paraffin on controlline/tubing. 06:00 - 10:00 4.00 PULL P INTERV Continue to work pipe up to 100K. Order out drum of EP-Iube. Discuss way forward wI Anchorage Engineering. Periodically circulate hot seawater while working pipe. 10:00 - 10:30 0.50 PULL P INTERV Mix up 30-bbl EP-Iube pill. Line up to reverse circulate. Spot pill down to -1700' on the backside. Work pipe. On 2nd P/U started moving pipe at 75K, once ball of control line gets past 7" casing collar, weight drops back to 50K. 10:30 - 12:30 2.00 PULL P INTERV Continue POH with 4-1/2" tubing. See weight bobbles up to 75K but diminishing at each casing collar. 12:30 - 13:00 0.50 PULL P INTERV Observe wadded up controlline/bands wrapped around the handling pup -3-4 feet above 5.62" OD HXO ball valve. Recovered -21 bands out of 52. Cut out mangled control lines. Printed: 4/11/2005 10:10:34 AM ) ) BPEXPLORATION O:perati ons ··SlJmrn~rY.·.:Ff~pprt Päge20f 4 Legal Well Name: B1-25 Common Well Name: B1-25 Spud Date: Event Name: TEMP ABANDON Start: 4/1/2005 End: 4/8/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/8/2005 Rig Name: NABORS 4ES Rig Number: HOlJrs T~sk Code NPT Phäse .' Description of Operédiómf. 4/4/2005 12:30 - 13:00 0.50 PULL P INTERV UD ball valve and handling pups. 23 jts to pull before top GLM (5.99" OD) reaches the floor. 13:00 - 17:00 4.00 PULL P INTERV Continue POH with 4-1/2" tubing down to the jet cut. Observed mass of control line and bands riding on top of GLM #2. Hand fished 13 bands out then lost all downhole once the belly of the GLM came out of the 7" casing. 17:00 - 18:00 1.00 PULL P INTERV RID tubing tools. Clear & clean rig floor. 18:00 - 18:30 0.50 FISH P INTERV R/U tools to P/U BHA & DP. 18:30 - 19:00 0.50 FISH P INTERV Install Wear Bushing. 19:00 - 20:00 1.00 FISH P INTERV M/U BHA # 1 as follows to fish control lines. Spear, Bumper Sub, Oil Jars, 9 * 4 3/4" DCs, Accelerator. TL 314.89'. 20:00 - 23:30 3.50 FISH P INTERV P/U 31/2" DP 1 x1 & RIH wI BHA #1. 23:30 - 00:00 0.50 FISH P INTERV Tag up @ 4466', 25' in on jt # 131. Slo wI 5K. Put 6 turns to right in string & P/U wI 5K overpull. P/U 70K. SIO 70K. Prep to POOH. 4/5/2005 00:00 - 01 :30 1.50 FISH P INTERV POOH wI BHA #1. Stand back 3 1/2" DP & BHA. 01 :30 - 02:00 0.50 FISH P INTERV Recovered 1 SS band. Bottom 2' of spear showed signs of being inside tubing stub. Top of Tubing stub @ 4464'. UD spear. 02:00 - 03:30 1.50 FISH P INTERV M/U BHA #2 as follows to washover collapsed tubing. 6" x 5" MM Shoe, 2 jts * 5 3/4" Wash Pipe, XO Bushing, Washover Boot Basket, Bumper Sub, Oil Jars, 9 * 4 3/4" DCs, Accelerator Jar. TL = 384.71 03:30 - 04:30 1.00 FISH P INTERV RIH wI BHA #2 w/3 1/2" DP. Had small amount of fluid flow up DCs from TIH wI washpipe. Circulated & blew hole clean. Reported to Spill Hotline, Jack Bowland @ 0430 hrs. Cleaned rig floor. Checked outside around rig, no discolored snow. 04:30 - 09:30 5.00 FISH P INTERV Con't to RIH wi BHA #2 very slowly to avoid displacement flow up the drill pipe. Load 65 joints of 4.5" 12.6#/ft L-80 IBT tubing in the pipe shed. 09:30 - 13:00 3.50 FISH P INTERV PJSM. Establish parameters. Up wt 75K, Down wt 75K, Rotating wt 75K. 3 1/2 bpm @ 400 psi. Tag top of 41/2" tbg stub @ 4465' DPM. Milled over stub 7 tagged collar @ 4484'. Milled collar & went on down to 4511'. Tagged 8 milled to 4514' wI 3-5K WOB. Milled @ 4514' wI 10K WOB, no progress after (2) hrs of milling. 13:00 - 16:30 3.50 FISH P INTERV PJSM. POOH wI milling BHA. 16:30 - 17:30 1.00 FISH P INTERV UD milling BHA. Clear I Clean rig floor. 17:30 - 18:30 1.00 FISH P INTERV M/U BHA # 3 as follows to cut 7". 5-1/2" Baker multi-cutter, 3-1/2" X/O, 6" stabelizer, 9 * 4-3/4" DCs. TL = 285.85'. 18:30 - 20:00 1.50 FISH P INTERV RIH wI BHA # 3 wi 3-1/2" DP to 2500' 20:00 - 20:15 0.25 FISH P INTERV Bleed 7" x 9-5/8" annulus 240 psi differential pressure 6 bbls to zero. establish communication before cut. 20:15 - 20:45 0.50 FISH P INTERV On depth at 2500' with Baker multi cutter, cut 7" csg. See visual indication of cut...picked up & slacked off wI blades extended, took weight @ 2501', indicating 7" dropped after cut. 20:45 - 22:00 1.25 FISH P INTERV POOH wI BHA # 3, leaving 25 stds DP in derrick & lay down 54 singles 22:00 - 23:00 1.00 FISH P INTERV UD BHA # 3. Clear I Clean rig floor 23:00 - 00:00 1.00 FISH P INTERV PJSM. Pull wear bushing, install test plug. 4/6/2005 00:00 - 01 :00 1.00 FISH P INTERV CIO VBRs to 7", Body test 250 psi low I 3500 psi high Pull test plug 01 :00 - 03:00 2.00 FISH P INTERV R/U Circulate out freeze project 7' x 9-5/8" 4 BPM at 250 psi Printed: 4/11/2005 10:10:34 AM ) ) BPEXPLORATION ·ºpe~ations.. ·Sulnl'1'1ary.·:Re·port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B1-25 B1-25 TEMP ABANDON NABORS ALASKA DRILLING I NABORS 4ES Date From- To ··Hours 4/6/2005 01 :00 - 03:00 2.00 FISH P 03:00 - 03:30 0.50 FISH P 03:30 - 04:00 0.50 FISH P 04:00 - 06:00 2.00 FISH P 06:00 - 09:00 3.00 FISH P NPT Phèsè INTERV INTERV INTERV INTERV INTERV INTERV INTERV INTERV INTERV INTERV INTERV INTERV ABAN ABAN ABAN ASAN ASAN ABAN ABAN ABAN ABAN ASAN ABAN ABAN ABAN ABAN ASAN ASAN ABAN ABAN ASAN ASAN ASAN 09:00 - 10:00 10:00 - 12:00 1.00 FISH P 2.00 FISH P 0.50 FISH P 0.50 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 3.00 CLEAN P 1.00 T A P 12:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 15:30 15:30 - 18:30 18:30 - 19:30 19:30 - 20:30 1.00 T A P 20:30 - 21 :30 1.00 T A P 4/7/2005 21 :30 - 00:00 00:00 - 02:00 P P 2.50 T A 2.00 TA 02:00 - 03:00 1.00 T A P 03:00 - 04:30 1.50 T A 04:30 - 05:00 0.50 T A 05:00 - 07:00 2.00 TA 07:00 - 08:00 1.00 T A 08:00 - 09:30 1.50 TA 09:30 - 10:30 1.00 T A 10:30 - 11 :30 1.00 T A 11 :30 - 12:00 0.50 T A 12:00 - 13:00 1.00 T A 13:00 - 15:30 2.50 T A 15:30 - 16:30 1.00 T A 16:30 - 19:00 2.50 T A 19:00 - 21 :30 2.50 T A 21 :30 - 00:00 2.50 T A 4/8/2005 00:00 - 03:00 3.00 TA P P P P P P P P P P P P P P Page3Òf.4 Start: 4/1/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: End: 4/8/2005 Døscriptionof Operation$ returns of 120 bbls Set test plug. P/U 7" test jt. test 250 psi low 13500 psi high UD &' test jt., Pull test plug. PJSM. BOLDs. Pull pack off wI 17K, lay down same. M/U BHA # 3 RIH latch and pull 7" wI 70K up wt. Continue to POOH & UD 7", 29#, P11 0 casing. Recovered (59) full joints & (38.33') of cut off joint. No visible indications of any holes in casing that was laid down. Rig down casing equipment. R/U to run DP. PJSM. Set test plug. CIO Plrams to 31/2" X 6" variables. PT same @ 250 I 3500 psi, OK. Pull test plug. Clear I clean rig floor. PJSM. Pick up 9 5/8" scraper SHA #5 RIH wi scraper assembly to top of 7" stub @ 2501'. PJSM. Circulate hole clean wI 15 bbls Hi Vis sweep. Circulate around @ 5 1/2 bpm @ 600 psi to clean returns. PJSM. POOH w/3 1/2" DP & clean out SHA. PJSM M/U BHA # 5 Halliburton Fas Drill 9-5/8" Sridge Plug, setting tool, and 9* 4-3/4" DC TIH with 3-1/2" DP set Fasdrill 9-5/8" plug at 2450" with 55K overpull. Pressure test 9-5/8" Fasdrill plug at 2450' with 1500psi good test TOH with 3-1/2 DP, SIB collars, Lay down setting tool TIH with open ended DP just above plug @ 2450' R/U to cement and catch returns PJSM R/U cementers, pressure test lines, spot 10 bbls 15.8 ppg Arctic Set 1 cement on top of Fasdrill @ 2450'. P/U to 2395' reverse out leaving 50' on top of Fasdrill plug TOH with 3-1/2" DP M/U SHA # 6 Halliburton EZSV cast-iron bridge-plug. RIH wI Halliburton 9 5/8" bridge plug. PJSM. Set Halliburton cast iron bridge plug @ 2347' DPM. Shear off wI 95K, OK. Set 20K on it to verify set, OK. PJSM. POOH w/3 1/2" DP. UD collars & setting tool. PJSM. RIH w/3 1/2" DP, open ended. (1) hour safety stand down wi Herb Williams, John Haynes & Tim Worthington. Discussed recent incident & ways to mitigate that risk. PJSM. Pump 5 bbls water ahead & PT lines, OK. Pump (10) bbls 15.8 ppg Arctic Set 1 & displace wi 12 bbls water. Pick up to 2290'. PJSM. Reverse circulate (3) DP volumes @ 5112 bpm I 600 psi. PJSM. POOH & LDDP. WI (20) jts out, pick up kelly & break connections. Continue OOH. Clear Iclean rig floor. Rig up to run 4 1/2" kill string. PJSM. RIH w/4 1/2", 12.6#, IST-M kill string. Land Tbg. hanger, test, Set TWC, test Nipple down S.O.P.E. Remove lines Nipple up adaptor flange and tree. Test to 5000psi PJSM R/U hot oiler pump truck test lines 1000 psi. Displace Printed: 4/11/2005 10:10:34 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) SP'EXPLORATION QperåtiqnsSul1'Imary ·.Rep.ort.. B1-25 B1-25 TEMP ABANDON NABORS ALASKA DRILLING I NABORS 4ES Date FrÖrTl~ TO Hours Task CodeNPT 4/8/2005 00:00 - 03:00 03:00 - 06:00 3.00 T A 3.00 TA Start: 4/1/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: End: 4/8/2005 Dešcripti()r1 of. Operations ASAN ASAN sea water with diesel 170 bbls. Clean pits, secure well and ready for move. Release Rig @ 06:00 hrs, 04/08/2005. Printed: 4/11/2005 10:10:34 AM ) /Cf ¿f- /5 ~ ') syÞJe~t:$~~åri1i~1~~$$q¿,p~~b~h~~:: ...i-.·..·.·.·..·..····.·...·.·..·.·.....·.··.··..·.·.·· .......................... ....... Fr9(nr~inton.I1HÞ~rt<\J\lint()n';¿~lub~~@.~drnimstat<?;ak~u.s?···· . Øðtè:Tl.Jé/05A\. ·t2005QQ:'t4-::3().lQ8QO········ Dave, AOGCC hereby approves changes to proposed operations (Sundry App. No. 305-022) on well B 1-25 (PTO 198-153), as described below. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Hinkel, Lee M (Orbis) wrote: Winton, as we discussed on the phone here is our proposed change of scope for Badami well 81-25: 1) the 7" casing will be mechanically cut at -2500'md. This casing will be pulled from the wellbore. 2) a 9-5/8" composite bridge-plug will be set in the 9-5/8" surface casing at -2450'md. This plug will be pressure tested to 1500 psi. 3) a 50' plug of cement will be spotted on top of the bridge-plug leaving top of cement at -2400'md. 4) a 9-5/8" cast iron bridge-plug will be set at -2350'md. 5) a 4.5" kill string will be installed with the end of tubing at -2300'md. Please call me at 659-1201 if further clarifications are required. Thank you for your prompt attention to theis scope change. Dave Reem ~·.·iI'-·":' ~'.k\.~Ië::Y'i .f\ tbWp 'J .i 2.0D5 .:;t../,)~n!n\'!~,~.;' n f\. -. ... ') ~i&\rŒ lID~ !Æl!Æ~~!Æ ) A.,ASHA. OIL AND GAS CONSERVATION COJDDSSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 'PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David C. Reem Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage,AJ( 99519-6612 Re: Badami BI-25 305-022 ,"~ ,..",~.!J Cl"''' ,,7 \....C.k<. ". :~.. \;: ,0'~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least'twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following' the date of this letter, or the next working day if the 23rd day falls~o. n a :iday or weekend. Aperson may not appeal a Commission decision to Superior our. unless rehearing has been requested. é r:~ C~ y, I ~ i.No / 'Chait~. \.. DATED thisft.day of February 2005 Enc!. SC.ANNE.D FES 11 2005 ) ') Subject: Badami B 1-25 Cement Volumes From: "Reem, David C" <ReemDC@BP.com> Date: Wed, 02 Feb 2005 10:15:15 -0900 To: winton_aubert@admin.state.ak.us Winton, the planned volumes for the cement to be set on the two bridge plugs are thus: On the 7" plug (set at -4450'md) we plan on laying in - 5 bbls of class "G" cement and will reverse off the excess leaving a clean cement top at - 4400'md in the 7" casing. On the 9-5/8" plug (set at -2490'md) we plan on laying in - 7 bbls of Arctic Set 1 cement and will reverse off the excess leaving a clean cement top at - 2440'md in the 9-5/8" casing. Please call or return an e-mail if further details are required for your evaluation of the proposal for 81-25. Thanks. Dave Reem Wells/Workover Engineer 564-5743 (w) 632-2128 (c) \ì..J CJ I\: zl 1,12 OOS ÐrS G(ð IS ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 'J 0 1 2005 1. Type of Request: 0 Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well AJ~¿;~~f¡ o¡¡ J~c~fè1~¡t~ !buf~ w mH¡;s~¡(m II Other A!1ch!Jí~ge 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 54.80' 8. Property Designation: ADL 365533 4. Current Well Class: / III Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number 198-153~ VJGAr 6. API Number: 50- 029-22906-00-00 9. Well Name and Number: / Badami B1-25 10. Field / Pool(s): Badami , ' PRES~NT.\Ni:L~,C<)NDIT'QN.,$l,JMMARy,I' , Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10596 12750 10596 None Length S'iie .. MP . TVD. 'BÙrst 20" 110' 110' 9-5/8" 4524' 4523' 7" 10895' 9050' 4-1/2" 10697' - 12750' 8901' - 10596' 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17.. ;::~:::}Ej~gë~S.t¡:cttothe.:::n:D~~I~~;:7: , Commission Us~Ol1ly 11: , Total Depth MD (ft): 12750 Casing. Structural Conductor Surface Intermediate Production Liner 74' 4490' 10862' 2053' Perforation Depth MD (ft): Perforation Depth TVD (ft): Packers and SSSV Type: Baker S-3 Perm Packer HES THB Perm Packer & Perm 12. Attachments: III Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program , / Maféh .,P: 2005 Nte: Junk (measured): None Collapse 1490 5750 470 3090 11220 8430 8510 7500 Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 8127 8183 Tubing MD (ft): 8229 13. Well Class after proposed work: /' 0 Exploratory III Development 0 Service 15. Well Status after proposed work: / III Oil 0 Gas 0 WAG DGINJ 0 Plugged DWINJ 0 Abandoned 0 WDSPL Contact David Reem, 564-5743 Prepared By Name/Number: Date 1- 31-Q 5. Sondra Stewman, 564-4750 I Sundry Number: 300"-Odd- 0 Plug Integrity 0 BOP Test Conditions of approval: Notify Commission so that a representative may witness 0 Location Clearance 0 Mechanical Integrity Test Other: T ~ ~-t- ~Sc:90 pi; , RBDMS 8Ft FEB 0 8 2005 ORIGINAL Date ~/OS Submit In Duplicate COMMISSIONER APPROVED BY THE COMMISSION ) ') Badami Bl-25 Secure/Safe-out Procedure Problem: Well has Tubing x Inner Annulus x Outer Annulus communication /' 1. Slickline drift to the collapsed section of 4.5" tubing. E-line chemically cut the 4.5" tubing in the middle of the 1 st full joint above the collapse. 2. 3. Circulate the well to seawater with diesel freeze protect. 4. MIRU Nabors 4ES. Circulate the well to warm seawater. ND tree (BPV installed and tested prior to rig up) and NU BOPE. Test BOPE to 250 psi (low pressure test) and 3500 psi (high pressure test) per BP/AOGCC regulations. / 5. Recover 4.5" tubing and control lines down to the cut. 6. Set 7" composite bridge-plug just above 4.5" tubing stub. Set 50' cement plug on top of 7" bridge-plug. PT plug to 1500 psi. ~ b b Is Cvv\ t, ~t.:A- 7. Mechanically cut the 7" casing at -2500'md and pull the casing down to the cut. 8. Set 9-5/8" composite bridge-plug just above the cut 7" stub. Set 50' cement plug on top of 9-5/8" bridge-plug. PT the plug to 1500 psi. 1 b6ls ~{, W4/'r' 9. Run 4.5" kill string with "X" profile nipple to within 50' of cement top. Land tubing and test tubing hanger to 5000 psi. Circ in freeze-protect fluids. 10. Set BPV in tubing hanger and test. ND BOPE. NU and test tree to 5000 psi. 11. RDMO. IREE =..4-1/16" 5M CIW WELLHEAD:; 13-5/8" 10M FMC KB. ELEV = 54.8' SF ELEV = 19.5' MAX DEV= 58 @ 8100' KOP= I ') B 1-25 Current ') 8 2051' I-iHES HXO SSSV NIP, 3.813" ID 19-5/8", 40#/ft, L-80 BTC CASING H 4524' ~ )I<~ 4504' l-i COLLAPSED 4.5" TUBING L GAS LIFT I\AANDRELS ST MD lVD TYPE 4 3029 2995 KBG-2-LS 3 4032 3998 KBG-2-LS 2 5923 5886 KBG-2-LS 1 8061 7209 KBG-2-LS Minimum ID = 3.725" @ 8146' 14-1/2", 12.6#/ft, L-80 IBT-MTUBING H 8162' 1 z Z 8127' l-i Baker S-3 Perm Packer C j 8146' l-i HES "XN", 3.725" ID 8162' l-i Unique Machine Overshot, no seals Z Z---1 8183' l-i HES "THB" Perm Packer I . 8197' l-i HES "X" NIP, 3.813" ID ~ 8217' I-iHES "XN", 3.725" ID 8229' l-i WLEG z Z -I 10697' I-iT' x 4.5" Liner Top Hanger/Packer I TOP OF SLOTS H 11980' 1 17", 29#/ft, P-110 CASING H 10895' 1 j ~ 1/1 12750' 1- 4.5", 12.6#/ft, L-80 IBT-M BOTTOM OF SLOlTED LINER H 12749' 1 I PBTD H 12749' 1 l DA TE REV BY COMMENTS ORIGINAL COM PLETION DA TE REV BY COMMENTS ENDICOTT UNrr WELL: 0-00/0-00 PERMrr No: 0000000 API No: 50-000-00000-00 SEe T N R E BP Exploration (Alaska) IREE,=A-1/16" 5M CIW WELLHEAD =; 13-5/8" 10M FMC KB. ËLEV = 54.8' BF ELEV = 19.5' MAX DEV = 58 @ 8100' KOP= ' ) 19-5/8", 40#/ft, L-80 BTC CASING H 4524' ~ Minimum ID = 3.725" @ 8146' 14-1/2", 12.6#/ft, L-80 IBT-MTUBING H 8162' 1- ITOP OF SLOTS H 11980' 1 17", 29#/ft, P-110 CASING H 10895' 1 1 BOTTOM OF SLOTIEDLlNER H 12749' 1 I PBTD H 12749' 1 B 1-25 Proposed ) ~ ~----- 4.5" Kill string w/"X" nipple ~ --- 9-5/8" Bridge-plug w/50' cement cap BP set @ -2490' ~ )C~ L z z [ J z Z~ I I . ~- z 7" Bridge-plug w/50' cement cap BP set @ -4450' 4504' 1-1 COLLAPSED 4.5" TUBING GAS LIFT MANDRELS ST MD lVD TYÆ 2 5923 5886 KBG-2-LS 1 8061 7209 KBG-2-LS 8127' 1-1 Baker S-3 Perm Packer 8146' I-IHES "XN", 3.725" ID 8162' 1-1 Unique Machine Overshot, no seals 8183' 1-1 HES "THB" Perm Packer 8197' 1-1 HES "X" NIP, 3.813" ID 8217' 1-1 HES "XN", 3.725" ID 8229' 1-1 WLEG Z -I 10697' 1-17" x 4.5" Liner Top Hanger/Packer ~ ~ 1/1 DA TE REV BY COMMENTS ORIGINAL COM PLETION DATE REV BY COMMENTS 12750' 1- 4.5", 12,6#/ft, L-80 IBT-M ENDICOTT UNIT W8..L: 0-00/0-00 ÆRMIT No: 0000000 API No: 50-000-00000-00 SEC T N R E BP Exploration (Alaska) \I~(j/~ l' '1-.." I ~C'C4- t' t~~'~' {) rlS 7 / .¿ I / a- ',1 STATE OF ALASKA' w "~. ,~'- :- I ~ I ~ ALASKA OIL AND GAS CONSERVATION COMMISSION 'r - APPLICATION FOR SUNDRY APPROVA-¡~~ ~ 20 AAC 25.280 ' -", ì ~L, 1. Type of Request: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: Suspend 0 Repair Well D Pull Tubing D Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD WaiverD Annular DisposalD StimulateD Time ExtensionD OtherŒJ Re-enter Suspended Well D Secure Well . 5. Permit to Dnll Number' 198-1530 /' BP Exploration (Alaska), Inc. Length Development ŒJ " Exploratory D StratigraphicD Service D 9. Well Name and Number: B1-25 / 10. Field/Pool(s): Badami Oil Field / Badami Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 12750 10541.2 MD TVD 6. API Number 50-029-22906-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 54.80 KB 8. Property Designation: ADL-365533 11. Total Depth MD (ft): 12750 Casing Total Depth TVD (ft): 10596.0 Plugs (md): Junk (md): Size None Burst None Collapse top bottom top bottom Conductor 74 20" 91.5# H-40 35 109 35.0 109.0 1490 470 Liner 2053 4-1/2" 12.6# L-80 10697 12750 8901.0 10596.0 8430 7500 Production 10863 7" 29# P-11 0 32 10895 32.0 9049.8 11220 8510 Surface 4490 9-5/8" 40# L-80 34 4524 34.0 4522.5 5750 3090 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # L-80 30 8229 Packers and SSSV Type: 4-112" Baker 5-3 Hydro Set Packer 4-1/2" Baker ZXP Packer 4-1/2" Howco THB Packer Packers and SSSV MD (ft): 8127 10697 8183 12. Attachments: Description Summary of Proposal D Detailed Operations Program Œ! BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Date: 13. Well Class after proposed work: ExploratoryD DevelopmentŒ! "./ ServiceD 15. Well Status after proposed work: Oil Œ] GasD WAG D GINJD Plugged D Abandoned D WINJD WDSPLD Prepared by Sharmalne Copeland 56-1--1-12-1. August 2, 2004 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John McMullen P~inted Name ?cohn M I~- ~ ø// .£ Title Signature 1.~- /(,~ ~l Phone - Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sr Production Engineer 564-4711 7/20/04 Sundry Number: 30 cf -¿;-g;;- l-- Plug In~e~r¡ty D . ~Ç>P TestD Mechan~iallntegrity ~est D I Location ?Iearance ~q I J t. Other: If,' ZC AJK 2.5" .~¡ I L (c \ J (£ ¡He",- t pI{ 1 {. c¡ ,...:: IV l'.Ll ¡'I'd Jr',' L~(j j { q IJ (¡; H di . J'ot ú Il . Subsequent FQqu¡red: l C - 404 ,)¡;// / ~ BY ORDER OF ( ( Approved by: o/~~ THE COMMISSION Date: I 2-/ LJ-- _Bfl III 2 1 100'* .oHIGINAL Form 10-403 Revised 06/2004 SUBMIT IN DUPLICATE ó Current Status: Last TO tag: Latest Drift: Min 10: Integrity Issues: lVlax Deviation: SOUP: 828: PROCEDURE: Badami BI-25 Application for Sundry Approval Proposed Procedure to Secure July 20, 2004 SI gas lifted producer. TIIIO = 1150/1900/0 psi. / 12216' ELMO 12/19/98. None recent. Significant paraffin and asphaltene buildup in tubing. 3.725" ID thru XN. . Confirmed T x lA communication 1/3/2004. Location of leak unknown. .,/' 58 deg at 8100'. 4/99 -7 5567 psi @ 10500' SSTVD; 4/02 -7 3150 psi @ 10000' SSTVD. 0 ppm during 2003 production. I. RU coil tubing unit. PT BOPE. 2. Liquid pack IA and tubing. 3. Using diesel/xylene or other hot fluids, clean-out tubing and liner with 3.65" drift nozzle to 11000' MD. POOH. 4. MU and RIH with a cast iron bridge plug. Set at 10,875' MD. Stack weight to confirm holding. ,/ POOH. Freeze protect well. 5. CMIT T x lA to 2500 psi. 6. RDMO. BADAMI WELL B1-25 API # 50-029-22906 ~ r-' ~ ~ r-' : Top Canning Shale . --~ : 10,215'MD;8560'TVD . , . ! Top Badami Sand ; ~' i 10 950' MD; 9090. TVO ~ ' Production Packer 18183& MD: 7275' TVD I Z -41/2" Liner Top Packer 110.697' MD; 8900' TVD I -- Top of Slotted Liner h 1.980' MD: 9915' TVD I TO 12,750' MD~ 10,596' TVD RT. 8...EV = 548' EF. ELEV = 19.5' MAX. DEV. = 58 @ 810()' MO TREE: 4-1116"' 5000 psi , CIW WELl.HEAO: 13-518-'10000 psi' FMC B1-25 13-3/8" 68#tft l-æ. BTC.CSG. I 4524 I .~ ... I HE5 HXO Safety I 20511 Valve Nipple ID (3.813-) Gas UI Slmmary U: Canco 1" KBG-2-LS GLM MD TVO OEV 4 ~:i!9 :i!99:> U 4 112~ L-80 IBT MOO ~ 3 4032 3998 0 12.6#1ft Tuting 2 5923 5886 30 1 8061 7209 fil '~ Z Baker 5-3 181 27 I Pennanent Packer I ' HE5 XN Nipple OCR 1 81461 Uniqœ Ovashot ID (3.725") I 8162 I 7.5' Assy wlo seals i HE5 THB stabbed o..er 1 Z of Z I 81831 4.5" l-80 tubing Pennanent Packer ¡ J HE5 X Nipple 9CR 1 81971 ID (3.813") HE5 XN Nipple 9CR 18217 I ID (3.725") ~ WLEG 182291 ELMD 18220 I Zt ~ T' X 4 1/2" Uner 1106971 Hanger Packer 4 1'2- L-80 IBT ~ Solid linEr' ~ T 29#1ft P11 0 1108951 ...' BTC CSG Shoe Top of Slotted Uner 1119801 ~ PBm 12749 Casing Shoe 12750 DATE REV. BY I COMMENTS BADAMI WELL B1-25 PERMIT # 98-153 API # 50-029-22906 I BP EXPLORATION, INC. '" 3-30-99 JTP Update Infoonation 7 -20-04 JCMITLH Depth Corrections .. 198-153-0 Roll #1: Start: Stop Roll #2: Start Stop (ALASKA) INC MD 12750 TVD 10596 Completion Date: 11/21/98 Completed Status: 1-OIL Current: Name D 8804 D 9122 L CCL ~.,,,,2 8004-8238 L CCL/TBNG CUTT t"/2 8070-8231 L COMBO GAS LG-MD v,;'PINAL 10565-12750 L COMBO GAS LG-TV ~J~INAL 8850-10550 L DGR/EWR4-MD L DGR/EWR4-TVD L FMT L GAS LIFT L JWL Interval Sent Received T/C/D ~ 1 BPX FMT /'4-6 SPERRY MPT/GR/EWR4 v/FINAL 6571-12750 FINAL 6363-10596 /~1 12026-12650 ~'~::INAL I00-12715 tv/FINAL I00-12715 L PROD-SPIN/TEM/ /,,'FINAL PRES 1000-12715 OH 12/1/98 12/3/98 OH 3/31/99 4/2/99 CH' 5 12/1/98 12/3/98 CH 5 12/1/98 12/3/98 OH 1 12/8/98 OH 1 12/8/98 OH 3/31/99 4/2/99 OH 3/31/99 4/2/99 CH 12/1/98 12/3/98 CH 5 1/14/99 1/21/99 CH 5 1/14/99 1/21/99 CH 5 1/14/99 1/21/99 Tuesday, January 09, 2001 Page 1 of 1 BP EXPLORATION Memorandum To: Blair Wondzell fm' Anna Dube March 29, 2000 Re' 10-404 for Xylene/Diesel Stimulation on Badami B1-25 Blair, Please find attached the 10-404 report for your records for the xylene/diesel stimulation job on Badami B1-11A which was completed February 10th. Included are a summary of the wellwork with well test information, a copy of the wellwork telex, and a current plot of well test data. If you have any questions on the information provided, please feel free to give me a call. Regards, Anna Dube Petroleum Engineer Eastern North Slope 564-5230 STATE OF ALASKA ALASK,~ '_ AND GAS CONSERVATION COMI SION RE~-ORT OF SUNDRY WELL OPERATION~' 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. 'Datum Elevation'('DF or KB) ...... BP Exploration (Alaska) Inc. [] Development KBE = 54.8' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Badami Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3857' NSL, 17' WEL, SEC. 8, T9N, R20E, UM B1-25 At top of productive interval 9. Permit Number / Approval No. 198-153 300-029 5192' NSL, 4531' EWL, SEC. 9, T9N, R20E, UM 16'. APl Number At effective depth 50-029-22906-00 41' NSL, 4767' EWL, SEC. 4, T9N, R20E, UM 11. Field and Pool At total depth Badami 41' NSL, 4767' EWL, SEC. 4, T9N, R20E, UM 12. Present well condition summary Total depth: measured 12750 feet Plugs (measured) true vertical 10596 feet Effective depth: measured 12750 feet Junk (measured) true vertical 10596 feet Casing Length Size Cemented M D TVD Structural Conductor 74' 20" 260 sx Arctic Set (Approx.) 110' 110' Surface 4490' 9-5/8" 2408 sx PF 'E', 391 sx Class 'G' 4524' 4522' Intermediate 10862' 7" 200 sx Class 'G' 10895' 9050' Production Liner 2053' 4-1/2" Uncemented Slotted Liner 10697' - 12750' 8901' - 10596' Perforation depth: measured 12225'- 12477' ORIGINAL . true vertical 10125' - 10349' ' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 2051'~-,..;~,;~,4~ ..... '~ ........... ~'.'.;u Packers and SSSV (type and measured depth) 4-1/2" Baker 'S-3' hydroset packer at 8127'; 4-1/2" Howco 'THB' packer at 8183'; 4-1/2" HES 'HXO' SSSV Landing Nipple at 2051' 13. Stimulation or cement squeeze summary Xylene / Diesel Stimulation 02/10/00 Intervals treated (measured) 12225'- 12477' Treatment description including volumes used and final pressure Bullheaded 68 bbls of 20/80 xylene/diesel down tubing and displaced with 232 bbls of diesel. Left well shut in to soak for two weeks with well head pressure reading 750 psig. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 359 bopd Subsequent to operation: 607 bopd ............... 15. Attachments ......... 16'. status' of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that t,.h~he/~going is true a~l'~correct to the best of my knowledge ~/24:~/~ ~ Signed Anna D~./~,ct...,,~ ~,~ Title Petroleum Engineer, ENS Date 0 ........ : Pr'eparedByName/Number: AnnaDube'~64"523~ kl ~orm 10-404 Rev. 06/15/88 Submit In Duplicate Summary of Xylene/Diesel Stimulation Wellwork on B:L-25 The xylene/diesel stimulation wellwork on B1-25 was completed February 10th, 2000. The job consisted of bullheading 68 bbls of 20/80 xylene/diesel followed by 232 bbls of hot diesel to displace the tubing and stimulate the near wellbore reservoir. A pressure decrease was observed after pumping 240 bbls which is believed to be indicative of removal of paraffin and/or asphaltenes in the perforations. The well was pressured up with gas lift and left shut-in for approximately two weeks to soak. On February 4th, B1-25 tested at 359 bopd with a gas lift rate of 1.8 mmscfd. We believe the well work resulted in an increase in productivity when considering the rates at which the well came on-line. The well was brought on line on February 22th and initially tested at 707 bopd with a gas lift rate of 2.7 mmscfd. The next day the well tested at 607 bopd with a gas lift rate of 1.8 mmscfd. After a month of production, the well is still producing over 400 bopd. Below is a summary of the well tests since the well was placed back on production on February 22th, 2000. Data Oil Rate (bopd) Gas Lift Rate 2/22/00 707 2.7 2/23/00 607 1.8 2/25/00 545 1.8 2/29/00 585 2.0 3/3/00 522 1.9 3/6/00 496 1.9 3/12/00 433 1.9 3/16/00 363 1.9 3/22/00 487 2.0 3/26/00 413 2.1 (mmscfd) DATE: 2/10/00 WELL N°: B1-25 BP EXPLORATION REP: Powers SERVICE COMPANY: HB&R DATE/TIME OPERATIONS SUMMARY 2/10/00 1700 SI gaslift. 1845 SI wing valve and PT lines. 1850 Begin pumping 68 bbls of 20/80 xylene/diesel at 70 degrees, SIWHP--300, lAP-700. 1940 SD to load more diesel. 68 bbls away, injectivity 1400 psig @ lbpm 2033 Resume pumping. WHP=0 psig, lAP=900 psig 2302 SD to load more diesel. 135 total bbls away, injectivity 2350 psig @ 1.5 bpm 2355 Resume pumping. WHP--0 psig, lAP=900 psig 2035 SD to load more diesel. 202 total bbls away, injectivity 2550 psig @ 1.5 bpm 2/11 148 Resume pumping. WHP-0 psig, IAP=1000 psig 200 Start seeing small injectivity break 2200 psig @ 1.5 bpm 240 bbls away. 231 SD to load more diesel. 269 total bbls away, injectivity 1700 psig @ 1.5 bpm 300 Resume pumping. WHP=200 psig, lAP-1000 psig 324 300 total bbls away. Final injectivity was 1500 psig @ 1.5 BPM. lAP -1000 psig 330 RDMO. SIWHP--750 psig. lAP-1000 psig. Leave well SI. SUMMARY: Bullheaded 68 bbls of 20/80 xylene/diesel down tubing and displaced with 232 bbls of diesel. Left well SI to soak. BP EXPLORATION Memorandum To: Blair Wondzell fm: Anna Dube Re: 10-403 for Stimulation of Badami B1-25 February 1, 2000 Blair, Please find attached the ::[0-403 application for your approval for stimulating B1-25 with a diesel wash which we would like to carry out early next week. We are investigating whether this will improve Well performance by removing paraffins from the reservoir in the near well bore region. If you have any questions regarding the program please give me a call. Regards, Anna Dube Petroleum Engineer Eastern North Slope 564-5230 RECEIVED FEB 01 2000 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ..... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) [] Development KBE = 54.8' BP Exploration (Alaska) Inc. i--I Exploratory 7. Unit or Property Name 3. Address []Stratigraphic Badami Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [--I Service 4. Location of well at surface 3857' NSL, 17' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 5192' NSL, 4531' EWL, SEC. 9, T9N, R20E, UM At effective depth 41' NSL, 4767' EWL, SEC. 4, T9N, R20E, UM At total depth 41' NSL, 4767' EWL, SEC. 4, T9N, R20E, UM 8. Well Number B1-25 9. Permit Number 198-153 10. APl Number 50- 029-22906-00 11. Field and Pool Badami 12. Present well condition summary Total depth: measured 12750 true vertical 10596 Effective depth: measured 12750 true vertical 10596 Casing Length Structural Conductor 74' Surface 4490' Intermediate 10862' Production Liner 2053' feet feet feet feet Size 20" 9-5/8" 7' 4-1/2" Plugs (measured) Junk (measured) OR! G!!xJ,& L Cemented 260 sx Arctic Set (Approx.) 2408 sx PF 'E', 391 sx Class 'G' 200 sx Class 'G' Uncemented Slotted Liner MD TVD 110' 110' 4524' 4522' 10895' 9050' 10697'-12750' 8901'-10596' Perforation depth: measured 12225' - 12477' true vertical 10125' - 10349' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 2051' Packers and SSSV (type and measured depth) RECEIVED FEB 0 1 200O Alaska 0il & Gas Cons. Commission Anchorage 4-1/2" Baker 'S-3' hydroset packer at 8127'; 4-1/2" Howc~o 'THB' packer at 8183'; 4;1/2" HES 'HXO' SSSV Landing Nipple at 2051' 13. Attachments [~ Description summary of proposal i--I Detailed operations program i--I BOP sketch 14. Estimated date for commencing operation February 7, 2000 16. If proposal was verbally approved Name of approver Date approved Contact £ngineer Name/Number: Anna Dube, 564-5230 17. I hereby certify th true and correct to the best of my knowledge Signed _ Bill Tumbull ~ ~ Commission Use Only 15. Status of well classifications as: [~ Oil I--I Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 Title Senior Petroleum Engineer, ENS Date Conditions of Approval: Notify Commission so representative may witness I Approval N o ¥.~~ Plug integrity_ BOP Test __ Location clearance __ I Mechanical Integrity Test Subsequent form requir..,e .~,~ L~C) ~. -3~IGINAL SIGNED BY ~, aet~e~ ~pproved by order of the Commission Robe~ N. Ohristenson o zfhr) ~missioner Date ~/~3 -"~ Form 10-403 Bev. 0~/15/88 ~ Submit In Tdplicate BP EXPLORATION Memorandum To' J. Powers/J. Eckstein January 31,2000 fm: A. Dube Re' Stimulation of Well B1-25 Please run a diesel/xylene stimulation job on Badami well B1-25. The objective of this job is to improve productivity by dissolving paraffin and asphaltenes in the near wellbore section of the reservoir. Historically B1-25 has been a steady producer with lower GOR. Currently B1-25 is being cycled to balance the production cycles from B1-11A. Please displace the tubing with approximately 200 bbls of diesel/xylene and then add another 60 bbls of diesel (approximately one truck Icad) to stimulate the near wellbore . .. reservoir. Any questions or comments may be directed to Anna Dube (x5230). xc: B1-25 Well File RECEIVED Alaska 0il & 6as Ceos. Commission Anchorage · Zone F4 & F5 uni-lateral producer · Producer - currently shut-in for pressure build-up B1-25 ..C..u..m..u.l.a..U.'.v..e..(.M..b.b. ts...o.r...M.M.S..C..E)...th m..1.L1.7/..q.o.:. Total Oil 332.8 Water 0 Gas 146.8 ..0..~...r.a..ti.q.n..a.I..H..ig.h. Jig.hts.; 11-20-98 12-6-98 12-29-98 4-1-99 4-8-99 4-11-99 Completed. Run DH gauges for PBU. FBHP = 1900 psig but no PBU initiated. Production Icg. 60% of flow from F4, 40% from F5. FBHP = 2000 psi Static. 5567 psi @ 10500 ft tvdss Brush and flush with slickline installed new gas lift design GLM//2 MD (BKB) = 5923 Valve type = LGLV Port size (64ths) = 16 TRO = 2450 This well is a possible candidate for cycling. RECEIVED FEB 0 1 000 Alaska 0ii & Gas Cons. Commission Anchorage Well Test Plot WELL: B1-25/BADAMI Dates from 08/24, 1998 to 03/28,2000 lWT CPE Vl.S.04 Gross Fluid Oil Rate G.O.R. Gas Lift [ Man, Pressure Man, Temp, Choke WC Def/Meas. Kelly bushing to wellhead/GL (ft) 35.3 Wellhead to sea level (ft) 19.5 F5 F4 Sheetl Conductor 20.000 19.124 91.5 115 60 0.0 Production Tubing 4.500 3.958 12.6 HES "HXO" Safety Valve Landing Nipple 5.620 3.813 2051 1995 0.0 Surface Casing 9.625 8.681 40 4524 4468 0.0 Camco 4 1/2· x 1· GLM 3029 2980 0.0 Camco 4 1/2" x 1' GLM 4031 3975 0.0 Camco 4 1/2· x 1" GLM 5923 5836 25.0 Camco 4 1/2' x 1" GLM 8061 7185 52.8 Baker "So3' Hydroset Packer 5.970 3.875 23-29 8127 7225 52.7 HES "XN" Landing Nipple 4.500 3.725 8146 7237 52.6 Overshot guide 5.88 4.750 8163 7247~ 52.6 Howco 'Ti:lB':Packer 5.870 3.~75 -8183 7259 52.5 IHES "X" Landing Nipple 4.500 3.813 -8197. 7268.' 52.5 :' ' 'i HES "XN· Landing Nipple 4.500 3..7.25 8217 7280' 52.5 . Wireline Entry Guide 5.250 3.958 8229 7287 52.4 7· x 4 1/2" Liner Hanger / Packer 10697 8909 43.5 Intermediate Casing 7.000 6.184 29 10904 9064 41.1 Solid Liner 4.500 3.958 12.6 11980 9941 31.0 Top F4 sand 12320 10239 27.6 Slotted Liner 4.500 3.958 12.6 12750 10609 23.6 Date Rev by Comments 9/-//1998 P.Collins Initial design ~###.##. M. Sauve Updated with tubing & liner tally R£C iV£D :EB 01 7.000 :.:__;....,,.:; ~. n,...,,. ~'n'n.u_... .... C, nmmissi0rl Page I Aiask~ :' : :? ::: :i Pr°ducer-unilaterai :.'::::;i: STATE OF ALASKA .__.. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: [] Development I--I Exploratory I--I Stratigraphic [--I Service 4. Location of well at surface 3857' NSL, 17' WEL, SEC. 8, T9N, R2OE, UM At top of productive interval 5192' NSL, 4531' EWL, SEC. 9, T9N, R2OE, UM At effective depth 41' NSL, 4767' EWL, SEC. 4, T9N, R2OE, UM At total depth 41' NSL, 4767' EWL, SEC. 4, T9N, R2OE, UM 6. Datum Elevation (DF or KB) KBE = 54.8' 7. Unit or Property Name Badami Unit 8. Well Number B1-25 9. Permit Number 198-153 10. APl Number 50- 029-22906-00 11. Field and Pool Badami 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12750 feet 10596 feet 12750 feet 10596 feet Length Size 74' 20" 4490' 9-5/8" 10862' 7" 2053' 4-1~" Plugs(measured) Junk(measured) Cemented 260 sx Arctic Set (Approx.) 2408 sx PF 'E', 391 sx Class 'G' 200 sx Class 'G' Uncemented Slotted Liner MD TVD 110' 110' 4524' 4522' 10895' 9O5O' 10697'-12750' 8901'-10596' Perforation depth: measured 12225'-12477' true vertical 10125'-10349' RECEIVED FEB 01 2000 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 2051' ~daska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 4-1/2" Baker 'S-3' hydroset packer at 8127'; 4-1/2" Howc~o 'THB' packer at 8183'; 4,1/2" HES 'HXO' SSSV Landing Nipple at 2051' 13. Attachments [] Description summary of proposal [-] Detailed operations program [--'] BOP sketch 14. Estimated date for commencing operation February 7, 2000 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Date approved Anna Dube, 564-5230 15. Status of well classifications as: i--I Gas []] Suspended ~;~] Oil Service Prepared By Name/Number: 17.Signedl hereby certify tha~true and correct to the best of my knowledge BilITurnbull Title Senior Petroleum Engineer, ENS Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance Terrie Hubble, 564-4628 Date I Approval No. _~) '" O C~i Mechanical Integrity Test Subsequent form ORIGINAL SIGNED'BY .., ~i~(~q.~...C, orflmissioner iApproved by order of the Commission Robert N. Christen~ur, Form 10-403 Rev. 06/15/88 Submit In Triplicate BP EXPLORATION Memorandum To: J. Powers/J. Eckstein January 31, 2000 fm: A. Dube Re: Stimulation of Well B1-25 Please run a diesel/xylene stimulation job on Badami well B1-25. The objective of this job is to improve productivity by dissolving paraffin and asphaltenes in the near wellbore section of the reservoir. Historically B1-25 has been a steady producer with lower GOR. Currently B1-25 is being cycled to balance the production cycles from B1-1 lA. Please displace the tubing with approximately 200 bbls of diesel/xylene and then add another 60 bbls of diesel (approximately one truck Icad) to stimulate the near wellbore . .. reservoir. Any questions or comments may be directed to Anna Dube (x5230). xc: B1-25 Well File RECEIVED FEB 0 1 2000 ~,~s,~,~ Oil & Gas Cons. Commission Anchorage · Zone F4 & F5 uni-lateral producer · Producer - currently shut-in for pressure build-up B1-25 ..C..u. mu. ta..tj.v..e..(.M.b.b, ts...o.r. M M.s...c.E).~ m. !!!7ZQQi Total Oil 332.8 Water 0 Gas 146.8 ..o..~.. r.a..t!.o..n..aJ..H..i.¢Jigb, ts.; 11-20-98 12-6-98 12-29-98 4-1-99 4-8-99 4-11-99 Completed. Run DH gauges for PBU. FBHP = 1900 psig but no PBU initiated. Production Icg. 60% of flow from F4, 40% from F5. FBHP = 2000 psi Static. 5567 psi @ 10500 ft tvdss Brush and flush with slickline installed new gas lift design GLM #2 MD (BKB) = 5923 Valve type = LGLV Port size (64ths) = 16 TRO = 2450 ..C..u..rr.e..n.t..P,..~.o. mm.e..n..d..~.....A..c.U.'.o..n.; This well is a possible candidate for cycling. Gas Cons. Commission A~chomge fromm...08/28/1998 to 01/17/2000 W[~-,! Test Plot WELL: B1-25/B~AMI Dates 0[,'- S -' -- O M 5000 ~; r -- 4000 ............; ................. ~ ...... ' 1000 8OO 700 600 500 ........ 400 ......... ' 300 ~ .....~ - - ~, ............. 200 ', , ., -- ;. - - ~- ........ -r'" , 7" ' 10 gA S 0 N D 1998 , , , , A aaka Oil a 'fi' i f .': .; Jf .;:; f:f :'/' f--: f:: ..... - ....... '~ ........ : ......... J/_ :.L '- ........ ~--- f- .......................................... 4-L..~ ...... ', ....... Z- i-~ ................ ', , _ ......',_ ~_.~ ..... { ....... r--~ ........ , .........~ ......... , __, ................... ~- .., . ~,,~,¢-~,~ .,. 1. : , ~', ', , _..~_w_~_.,,. ~, ....... ~ - -"~ ~' .... ~ - - - -. '~-~.9~_' ..... ~ ......... " ....... _,_'_: ........ . .................... ~ ,~ ', ~= ~,,-~ ,, - -i ...............'-- -": ~'- -' ...................... " .........I ......... ;- - ~ ...... , .................. ·, ........... .J ......... ~ ................ .... ' ................... , .... ~', .... , .... '' ........... ' , _ ....... , ......... L ........ ~l ..... ' , ~ _t ..... - - -, ......... ~ .......... "- - ....... ,- , , I ~ ~ .... , ....................... , .... ~ ............. - .......... % , e ee . . ,~,~--. .... , ' ~ ................ t - -i-{ ......... ._.__.L. ..u.---- J A $ 0 N D F M A M J 999 J 2000 Janun~ 17 2000 CPE V1,2.03 S O 1998 F M A 1999 Gross Fluid I~lOil Rate --- ~ - · G.O.R. ,, ..... [Gas Lift Man. Pressure IMam Temp. '~, ' Choke ~[WC Def/Meas, Kelly bushing to wellhead/GL (ft) 35.3 Wellhead to sea level (ft) 19.5 F5 F4 Sheetl Conductor 20.000 19.124 91.5 115 60 0.0 Production Tubing 4.500 3.958 12.6 HES "HXO" Safety Valve Landing Nipple 5.620 3.813 2051 1995 0.0 Sur[ace Casing 9.625 8.681 40 4524 4468 0.0 Camco 4 1/2" x 1" GLM 3029 2980 0.0 Camco 4 1/2" x 1' GLM 4031 3975 0.0 Camco 4 1/'2" x 1' GLM 5923 5836 25.0 Camco 4 1/2' x 1" GLM 8061 7185 52.8 Baker 'S-3" Hydroset Packer 5.970 3.875 23-29 8127 7225 52.7 HES "XN" Landing Nipple 4.500 3.725 8146 7237 52.6 Overshot guide 5.88 4.750 8163 7247 52.6 Howco 'Tt~B' iPacke[ 5.870 3.~7_5 - 8183 7259 52.5 ~-,. : ~ ~,..:~ -, -.~ HES "X" Landing Nipple 4.500 '3.~t'3- 8197, 7261~ 52.5 HES "XN" Landing Nipple 4.500 /3.~25 8217 7280 52.5 . . Wireline Entry Guide 5.250 3.958 8229 7287 52.4 7" x 4 1/2" Liner Hanger / Packer 10697 8909 43.5 Intermediate Casing 7.000 6.184 29 10904 9064 41.1 Solid Liner 4.500 3.958 12.6 11980 9941 31.0 Top F4 sand 12320 10239 27.6 Slotted Liner 4.500 3.958 12.6 12750 10609 23.6 Date9/7/1998 Revby Comments -- VEb P.Collins Initial design [~ E C ~,~ i #~##~ M. Sauve Updated with tubing & liner tally FEB 0 1 2000 Alaska 0il & Gas Cons. C0mmissi~ ~n~_hnra0e ::i:i Produce? ~:Unilateral Page I BP EXPLORATION Date: 3-31-99 Transf~04'12 BP/Badami OPEN HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name Rec TyPe Rec Date Company Code Comments B1-25 OH 5-Nov-98 SPERRY MWD, ROP, DGR, EWR4 B1-25 OH 5-Nov-98 SPERRY MWD, DGR, EWR4 Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center OH LOGS Madellyn Millholland MB 7-1 AOGCC FINA DNR F EC IVF APR 02 19~i Oil& Gas Co~s COmmi~ion Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99619.6612 BP EXPLORATION Date: 3-31-99 Trans#90412 BP/Badami OPEN HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name Rec Type Rec Date Company Code ;Comments B1-25 OH 5-Nov-98 SPERRY 'MWD, ROP, DGR, EWR4 B1-25 OH 5-Nov-98 SPERRY MWD, DGR, EWR4 Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center OH LOGS Madellyn Millholland MB 7-1 AOGCC FINA DNR RECEIVED Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION Date: 3-31-99 Trans#90405 BP/Badami OPEN HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw NametRec TypelRec Date ICompany Code Comments B1-25 IDISKJ 12-Nov-981SPERRY MWD, MPT, GR, EWR4, ROP Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center OH LOGS AOGCC FINA DNR Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 01-14-99 Trans# 90151 BADAMI LOG DATA Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name RecType Rec Date Company Code Comments B1-25 CH 29-Dec-98 BAKER GAS LIFT SUF~VEY, OTHER SERV- SPINNER/TEMP/PRES B1-25 CH 29-Dec-98 BAKER JEWELRY LOG B1-25 CH 29-Dec-98 BAKER SPINNER/TEMP/PRESSURE B1-11A CH 29-Dec-98 BAKER SPINNEFVTEMP/PRESSURE- JEWELRY LOG B1-11A CH 29-Dec-98 BAKER GAS LIFT SURVEY Please sign and return one copy of this transmittal to: Carla H. Mclntosh Petrotechnical Data Center LOG DATA AOGCC-1 bluelinell sepia PETROFINA-1 blueline/1 sepia DNR - 1 blueline BP- - 1 blueline Howard Oakland Mike Engle Tim Ryherd Dave Goodwin MB 7-2 RECEIVED JAN 2 t 1999 Alaska 0il & Gas Cons. Commission Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 ALASKA OIL AND GAS CONSERVATION COMMISSION dC~ I z~ 1999 WELL COMPLETION OR RECOMPLETION REPORT AND ,i & 6~.~___ Cons . Oommissior~ 1. Status of Well Classifical~o~'~Serv~l~gB [~ Oil I-~ Gas [~ Suspended F-] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 9~/,.~ 398-293 ~ 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22906 4. Location of well at surface !:. ~ .. :.~'. ', i~ ~ ~ '. 9. Unit or Lease Name' 38571NSL, 17' WEL, SEC. 8, TeN, R20E, UM,_/'~/_~ ~ ~: r ' 10. Badami UnJtWell Number At top of productive interval lt. .% ~ ~ 5192' NSL, 4531' EWL, SEC. 9, T9N, R20E, UM ;:_ ..~$~:.-.[~?~. :_ ! ;;.~--...¢.~_~~...~! B1-25 At total depth /"~. ............. ""'~"" ' ': ~-:_-_.:!.'~.~~,:' 11. Field and Pool 41' NSL, 4767' EWL, SEC.~, TgN, R20E, UM _i Badami 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 54.8'] ADL365533 f4~ 12. Date Spudded ]13. Date T.D. Reached I 14. Date Comp., Susp., orAbanddl5. Water depth, if offshore 116. No. of Completions 10/25/98I 11/12/98I 1472-4/98 l,/~,,/,~lOj N/A MSLI One 17. Total Depth (MD+TVD) J18. Plug Back Depth (MD+-I-VD)J19. Directional Survey 20. Depth where SSS,V, set J21. Thicknes,s, of Permafrost 12750 10596 FTJ 12750 10596 FTJ ~]Yes E~No 2051 MD J 1900 (Approx.) .. 22. Type Electric or Other Logs Run 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 36' 110' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 4524' 12-1/4" 2408 sx PF 'E', 391 sx Class 'G' 7" 29# P110 33' 10895' 8-1/2" 200 sx Class 'G' 4-1/2" 12.6# L-80 10697' 12750' 6" Uncemented slotted liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 2051' 8126' MD TVD MD TVD 12225' - 12477' 10125' - 10349' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 55 bbls Diesel 27. PRODUCTION TEST 0R[~~ : Date NovemberFirst prOduction24, 1998II Met'h°dGas Lift°f Operation (Flowing, gas lift, etc.) iii;' ~-i/~' b Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD 1 Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lith°logy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 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. Top Badami Sands 'F4' 12150' 10060' Base Badami Sands 'F4' 12353' 10238' Base Badami Sands 'F5' 12530' 10396' 31. List of Attachments Summary of Daily Drilling Reports, Surveys ,, 32.1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Mike E. Mille Title Badami Drilling Team Leader Date B1-25 98-155 398-293 Prepared By Name/Number: Carol Withey, 564-4114 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 Performance Enquiry Report Operator BP Exploration Date 00:42, 09 Jan 99 Page 1 The analysis is from - 07:00, 31 Oct 98 - to - 07:00, 31 Oct 98 Programs in Result Table: Well Type Time From Time To Duration Event 07:00, 31 Oct 98 07:00, 31 Oct 98 Description E.M.W.(equivalent mud weight) Obtained leak off 12.5 Hole Size MDR 8-1/2 Progress Report Facility Badami CPF Well B 1-25 Rig Nabors 28E Page 1 Date 08 January 99 Date/Time 23 Oct 98 17:30-18:00 18:00-00:00 24 Oct 98 00:00-00:30 00:30-06:00 06:00-10:30 10:30-12:00 12:00-12:15 12:15-14:00 14:00-17:00 17:00-20:00 20:00-21:00 21:00-00:00 25 Oct 98 00:00-00:30 00:30-02:00 02:00-02:15 02:15-06:00 06:00-06:15 06:15-06:30 06:30-07:45 07:45-09:30 09:30-11:00 11:00-06:00 26 Oct 98 06:00-06:30 06:30-08:00 08:00-08:15 08:15-10:00 10:00-12:00 12:00-12:45 12:45-14:15 14:15-15:00 15:00-18:15 18:15-18:45 18:45-19:15 19:15-20:00 20:00-06:00 27 Oct 98 06:00-16:45 16:45-18:30 18:30-20:45 20:45-22:00 22:00-23:00 23:00-00:45 28 Oct 98 00:45-01:00 01:00-01:15 01:15-06:00 06:00-16:15 16:15-17:45 17:45-20:15 20:15-00:15 29 Oct 98 00:15-01:30 01:30-04:00 04:00-06:00 06:00-06:15 06:15-07:15 07:15-07:30 Duration 1/2 hr 6 hr 1/2 hr 5-1/2 hr 4-1/2 hr 1-1/2 hr 1/4 hr 1-3/4 hr 3 hr 3 hr 1 hr 3 hr 1/2 hr 1-1/2 hr 1/4 hr 3-3/4 hr 1/4 hr 1/4 hr 1-1/4 hr 1-3/4 hr 1-1/2 hr 19hr 1/2 hr 1-1/2 hr 1/4 hr 1-3/4 hr 2 hr 3/4 hr 1-1/2 hr 3/4 hr 3-1/4 hr 1/2 hr 1/2 hr 3/4 hr 10hr 10-3/4 hr 1-3/4 hr 2-1/4 hr 1-1/4 hr 1 hr 1-3/4 hr 1/4 hr 1/4 hr 4-3/4 hr 10-1/4 hr 1-1/2 hr 2-1/2 hr 4 hr 1-1/4 hr 2-1/2 hr 2 hr 1/4 hr 1 hr 1/4 hr Activity Held safety meeting Rig moved 65.00 % Held safety meeting Rig moved 90.00 % Rig moved 100.00 % Installed Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Prepare mouse/rat hole Rigged up Fluid system Functioned Additional services Installed Fluid system Held safety meeting Installed Fluid system Held safety meeting Fill pits with Water based mud Fill pits with Water based mud Made up BHA no. 1 Drilled to 118.0 ft - Drilled to 226.0 ft Made up BHA no. 1 Drilled to 1200.0 ft Drilled to 1210.0 ft Serviced Fluid system Drilled to 1220.0 ft Serviced Fluid system Drilled to 1232.0 ft Serviced Fluid system Drilled to 1370.0 ft Cleared Sand traps Drilled to 1544.0 ft Cleared Sand traps Drilled to 1575.0 ft Serviced Fluid system Drilled to 2420.0 ft Drilled to 3421.0 ft Circulated at 3421.0 ft Pulled out of hole to 655.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 3375.0 ft Reamed to 3421.0 ft Took MWD survey at 3421.0 ft Drilled to 3822.0 ft Drilled to 4540.0 ft Circulated at 4540.0 ft Pulled out of hole to 655.0 ft R.I.H. to 4540.0 ft Circulated at 4540.0 ft Pulled out of hole to 655.0 ft Pulled BHA Held safety meeting Rigged up Casing handling equipment Held safety meeting Facility Date/Time 30 Oct 98 31 Oct 98 01 Nov 98 02 Nov 98 03 Nov 98 04 Nov 98 05 Nov 98 Progress Report Badami CPF Well B 1-25 Rig Nabors 28E Page 2 Date 08 January 99 07:30-14:00 14:00-17:00 17:00-17:15 17:15-17:30 17:30-17:45 17:45-18:00 18:00-19:00 19:00-21:30 21:30-21:45 21:45-22:00 22:00-01:00 01:00-01:45 01:45-02:15 02:15-03:00 03:00-04:30 04:30-06:00 06:00-14:00 14:00-15:00 15:00-16:00 16:00-20:00 20:00-20:30 20:30-01:00 01:00-01:30 01:30-02:30 02:30-03:30 03:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-06:00 06:00-10:00 10:00-10:45 10:45-14:00 14:00-15:30 15:30-16:00 16:00-17:30 17:30-19:45 06:00-04:15 04:15-04:45 04:45-05:00 05:00-06:00 06:00-07:15 07:15-06:00 06:00-21:30 21:30-22:45 22:45-00:00 00:00-01:00 01:00-03:30 03:30-06:00 06:00-10:00 10:00-10:30 10:30-12:30 12:30-13:30 Duration 6-1/2 hr 3 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 1 hr 2-1/2 hr 1/4 hr 1/4 hr 3 hr 3/4 hr 1/2 hr 3/4 hr 1-1/2 hr 1-1/2 hr 8 hr 1 hr 1 hr 4 hr 1/2 hr 4-1/2 hr 1/2 hr 1 hr 1 hr 1 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 23 hr 4 hr 3/4 hr 3-1/4 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2-1/4 hr 22-1/4 hr 1/2 hr 1/4 hr 1 hr 1-1/4 hr 22-3/4 hr 15-1/2 hr 1-1/4 hr 1-1/4 hr 1 hr 2-1/2 hr 2-1/2 hr 4 hr 1/2 hr 2 hr 1 hr Activity Ran Casing to 4524.0 ft (9~5/8in OD) Circulated at 4524.0 ft Held safety meeting Pumped Water based mud spacers - volume 90.000 bbl Mixed and pumped slurry - 99.000 bbl Mixed and pumped slurry - 80.000 bbl Displaced slurry - 337.000 bbl Circulated at 2207.0 ft Held safety meeting Pumped Water based mud spacers - volume 40.000 bbl Mixed and pumped slurry - 830.000 bbl Displaced slurry - 168.000 bbl Circulated at 34.0 fi Rigged down Cement head Rigged down Bell nipple Installed Casing head Installed BOP stack Serviced Block line Rigged up High pressure lines Tested All functions Installed Wear bushing Made up BHA no. 3 R.I.H. to 2207.0 ft Drilled installed equipment - DV collar R.I.H. to 4405.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Float shoe Drilled to 4560.0 ft Circulated at 5460.0 ft Performed formation integrity test Drilled to 6320.0 ft Drilled to 6569.0 ft Circulated at 6569.0 ft Pulled out of hole to 648.0 ft Pulled BHA Serviced Wear bushing Made up BHA no. 4 R.I.H. to 6569.0 ft Drilled to 8729.0 ft Circulated at 8729.0 ft Flow check Pulled out of hole to 6350.0 ft R.I.H. to 8729.0 ft Drilled to 10110.0 ft Drilled to 10904.0 ft Circulated at 10904.0 ft Pulled out of hole to 8342.0 ft R.I.H. to 10904.0 ft Circulated at 10904.0 ft Laid down 3000.0 ft of 5in OD drill pipe Laid down 5500.0 ft of 5in OD drill pipe Rigged down Kelly Laid down 2400.0 ft of 5in OD drill pipe Serviced Pipe ram Facility Date/Time 06 Nov 98 07 Nov 98 08 Nov 98 B adami CPF ) - Progress Report Well B 1-25 Page 3 Rig Nabors 28E Date 08 January 99 13:30-15:30 15:30-16:30 16:30-17:45 17:45-18:00 18:00-01:00 01:00-01:30 01:30-04:30 04:30-04:45 04:45-06:00 06:00-07:00 07:00-07:15 07:15-08:45 08:45-09:00 09:00-10:30 10:30-11:00 11:00-11:45 11:45-12:30 12:30-13:00 13:00-14:00 14:00-14:15 14:15-15:15 15:15-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-06:00 06:00-06:45 06:45-07:30 07:30-07:45 07:45-08:30 08:30-09:00 09:00-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-15:00 15:00-00:00 00:00-00:15 00:15-01:00 01:00-01:45 01:45-02:15 02:15-03:00 03:00-06:00 06:00-06:45 06:45-07:30 07:30-12:00 Duration 2 hr 1 hr 1-1/4 hr 1/4 hr 7 hr 1/2 hr 3 hr 1/4 hr 1-1/4 hr 1 hr 1/4 hr 1-1/2 hr 1/4 hr 1-1/2 hr 1/2 hr 3/4 hr 3/4 hr 1/2 hr 1 hr 1/4 hr 1 hr 1-1/4 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1 hr 1 hr 1 hr 1 hr 1/2 hr 1/2 hr 5 hr 3/4 hr 3/4 hr 1/4 hr 3/4 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr 1/2 hr 1 hr 9 hr 1/4 hr 3/4 hr 3/4 hr 1/2 hr 3/4 hr 3 hr 3/4 hr 3/4 hr 4-1/2 hr Activity Pulled BHA Tested Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 4510.0 ft (7in OD) Circulated at 4510.0 ft Ran Casing to 6900.0 ft (7in OD) Circulated at 6900.0 ft Ran Casing to 7900.0 ft (7in OD) Ran Casing to 8879.0 ft (7in OD) Circulated at 8879.0 ft Ran Casing to 9864.0 ft (7in OD) Circulated at 9864.0 ft Ran Casing to 10857.0 ft (7in OD) Circulated at 10857.0 ft Rigged up Cement head Circulated at 10894.0 ft Held safety meeting Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 41.000 bbl Displaced slurry - 401.000 bbl Rigged down Cement head Installed Seal assembly Rigged up Kelly Serviced Top ram Serviced Kelly Installed Kelly Installed Internal BOPs Installed Kelly cocks Held safety meeting Rigged up Instrument lines Tested All functions Tested Kelly/top drive hose Worked on BOP - Choke manifold Installed Wear bushing Ran Drillpipe to 27.0 ft (3-1/2in OD) Removed Drillfloor / Derrick Serviced Wear bushing running tool Functioned BOP stack Ran HWDP to 454.0 ft (3-1/2in OD) Held safety meeting Ran Drillpipe to 625.0 ft (3-1/2in OD) Pulled HWDP in stands to 0.0 ft Made up BHA no. 5 R.I.H. to 10040.0 ft Held safety meeting R.I.H. to 10600.0 ft Washed to 10749.0 ft Circulated at 10749.0 ft Circulated at 10749.0 ft Pulled out of hole to 3187.0 ft Pulled out of hole to 475.0 ft (cont...) Pulled BHA Made up BHA no. 6 Facility Date/Time 09 Nov 98 10 Nov 98 11 Nov 98 12 Nov 98 13 Nov 98 14 Nov 98 15 Nov 98 16 Nov 98 Badami CPF Progress Report Well B 1-25 Page 4 Rig Nabors 28E Date 08 January 99 Duration Activity 12:00-12:30 12:30-13:30 13:30-18:00 18:00-18:30 18:30-19:45 19:45-20:45 20:45-21:00 21:00-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-06:00 06:00-08:45 08:45-10:00 10:00-10:45 10:45-11:00 11:00-15:30 15:30-17:00 17:00-19:30 19:30-00:15 00:15-06:00 06:00-06:00 06:00-17:30 17:30-19:00 19:00-23:15 23:15-01:30 01:30-03:30 03:30-03:45 03:45-05:15 05:15-06:00 06:00-08:00 08:00-15:30 15:30-17:45 17:45-18:15 18:15-02:45 02:45-03:00 03:00-03:45 03:45-04:15 04:15-06:00 06:00-08:45 08:45-15:15 15:15-16:45 16:45-01:45 01:45-04:45 04:45-05:15 05:15-05:45 05:45-06:00 06:00-06:15 06:15-06:45 06:45-17:45 17:45-21:45 21:45-00:00 00:00-06:00 06:00-09:00 1/2 hr 1 hr 4-1/2 hr 1/2 hr 1-1/4 hr 1 hr 1/4 hr 3 hr 1/2 hr 1-1/2 hr 4 hr 24 hr 2-3/4 hr 1-1/4 hr 3/4 hr 1/4 hr 4-1/2 hr 1-1/2 hr 2-1/2 hr 4-3/4 hr 5-3/4 hr 24 hr 11-1/2 hr 1-1/2 hr 4-1/4 hr 2-1/4 hr 2 hr 1/4 hr 1-1/2 hr 3/4 hr 2 hr 7-1/2 hr 2~ 1/4 hr 1/2 hr 8-1/2 hr 1/4 hr 3/4 hr 1/2 hr 1-3/4 hr 2-3/4 hr 6-1/2 hr 1-1/2 hr 9 hr 3 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr llhr 4 hr 2-1/4 hr 6 hr 3 hr Held safety meeting Serviced Block line R.I.H. to 10750.0 ft Serviced Kelly Circulated at 10750.0 ft Tested Casing - Via string Held drill (Kick (well kill)) Drilled cement to 10904.0 ft Drilled to 10924.0 ft Circulated at 10924.0 ft Drilled to 11010.0 ft Drilled to 11440.0 ft (cont...) Drilled to 11489.0 ft Circulated at 11489.0 ft Pulled out of hole to 10984.0 ft Circulated at 10984.0 ft Pulled out of hole to 645.0 ft Pulled BHA Made up BHA no. 7 R.I.H. to 11489.0 ft Drilled to 11655.0 ft Drilled to 12325.0 ft Drilled to 12630.0 ft Circulated at 12630.0 ft Drilled to 12750.0 ft Circulated at 12750.0 ft Pulled out of hole to 10986.0 ft R.I.H. to 11453.0 ft Reamed to 11589.0 ft R.I.H. to 12750.0 ft Circulated at 12750.0 ft Pulled out of hole to 638.0 ft Pulled BHA Held safety meeting Conducted electric cable operations Held safety meeting Rigged down sub-surface equipment - Formation logs Held safety meeting Ran Liner to 320.0 ft (4-1/2in OD) Ran Liner to 2065.0 ft (4-1/2in OD) Ran Drillpipe on landing string to 12750.0 ft Functioned Liner hanger Laid down 10690.0 ft of 3-1/2in OD drill pipe Laid down 2060.0 ft of Drillpipe Removed Wear bushing Held safety meeting Installed Completion string handling equipment Installed Completion string handling equipment Installed Permanent packer Ran Tubing to 8146.0 ft (4-1/2in OD) Packer worked at 8146.0 ft Installed Logging/braided cable equipment Rig waited · Materials Rig waited · Materials Facility Date/Time 17 Nov 98 18 Nov 98 19 Nov 98 20 Nov 98 Progress Report Badami CPF Well B 1-25 Page 5 Rig Nabors 28E Date 08 January 99 09:00-09:30 09:30-10:30 10:30-13:00 13:00-14:15 14:15-18:00 18:00-03:30 03:30-04:00 04:00-06:00 06:00-08:30 08:30-09:00 09:00-09:15 09:15-09:45 09:45-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-00:00 00:00-00:30 00:30-06:00 06:00-09:45 09:45-10:45 10:45-11:00 11:00-11:15 11:15-12:00 12:00-13:00 13:00-13:45 13:45-14:00 14:00-15:45 15:45-20:00 20:00-21:00 21:00-01:00 01:00-01:30 01:30-01:45 01:45-02:45 02:45-05:45 05:45-06:00 06:00-08:00 08:00-08:30 08:30-09:30 09:30-12:00 12:00-13:00 13:00-14:00 14:00-14:30 14:30-15:30 15:30-16:30 16:30-17:30 17:30-18:00 18:00-00:00 00:00-03:15 03:15-05:00 05:00-06:00 06:00-09:30 09:30-11:30 Duration 1/2 hr 1 hr 2-1/2 hr 1-1/4 hr 3-3/4 hr 9-1/2 hr 1/2 hr 2 hr 2-1/2 hr 1/2 hr 1/4 hr 1/2 hr 1-3/4 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 10 hr 1/2 hr 5-1/2 hr 3-3/4 hr 1 hr 1/4 hr 1/4 hr 3/4 hr 1 hr 3/4 hr 1/4 hr 1-3/4 hr 4-1/4 hr 1 hr 4 hr 1/2 hr 1/4 hr 1 hr 3 hr 1/4 hr 2 hr 1/2 hr 1 hr 2-1/2 hr 1 hr 1 hr 1/2 hr 1 hr 1 hr 1 hr 1/2 hr 6 hr 3-1/4 hr 1-3/4 hr 1 hr 3-1/2 hr 2 hr Activity Held safety meeting Installed Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Circulated at 8176.0 ft Laid down 8176.0 ft of Tubing Installed BOP test plug assembly Tested BOP stack Tested BOP stack Installed Wear bushing Held safety meeting Installed Logging/braided cable equipment Conducted electric cable operations Rigged down Wireline units Retrieved Wear bushing Held safety meeting Installed Permanent packer Ran Tubing to 6178.0 ft (4-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 8100.0 ft (4-1/2in OD) Space out tubulars Installed SCSSSV control line Installed Tubing hanger Held safety meeting Installed Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Installed Hanger plug Serviced Drillfloor / Derrick Rigged down BOP stack Serviced Block line Installed Tubing on landing string Retrieved Hanger plug Held safety meeting Installed Slickline unit Installed High pressure lines Held safety meeting Circulated at 8229.0 ft Held safety meeting Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Held safety meeting Functioned Permanent packer Tested Tubing - Via annulus Functioned Other sub-surface equipment Circulated at 8061.0 ft Conducted slickline operations on Slickline equipment - Retrival run Circulated at 8061.0 ft Circulated at 8060.0 ft Circulated at 2100.0 ft Circulated at 8061.0 ft Conducted slickline operations on Slickline equipment - Setting run Facility Badami CPF Progress Report Well B 1-25 Page 6 Rig Nabors 28E Date 08 January 99 Date/Time 21 Nov 98 11:30-12:00 12:00-12:30 12:30-13:00 13:00-15:00 15:00-16:30 16:30-18:45 18:45-19:15 19:15-20:15 20:15-20:45 20:45-21:15 21:15-21:30 21:30-23:00 23:00-05:30 05:30-06:00 06:00-07:15 07:15-08:30 08:30-10:15 10:15-10:30 10:30-12:00 12:00-13:00 13:00-13:30 13:30-14:30 14:30-15:30 15:30-18:00 Duration 1/2 hr 1/2 hr 1/2 hr 2 hr 1-1/2 hr 2-1/4 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/4 hr 1-1/2 hr 6-1/2 hr 1/2 hr 1-1/4 hr 1-1/4 hr 1-3/4 hr 1/4 hr 1-1/2 hr 1 hr 1/2 hr 1 hr 1 hr 2-1/2 hr Activity Held safety meeting Tested Casing - Via annulus Tested Tubing - Via string Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Setting run Tested Tubing - Via string Conducted slickline operations on Slickline equipment - Setting run Tested Tubing - Via annulus and string Tested Casing - Via annulus Conducted slickline operations on Slickline equipment - Retrival run Held safety meeting Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Serviced Slickline unit Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Held safety meeting Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Monitor wellbore pressures Installed Hanger plug Serviced High pressure lines Rigged down Drillfloor / Derrick Badami Alaska State Plane Zone 3 Badami CPF, Slot B1-25 B1.25 Job No. AKVCS0417, Surveyed: 5 November, 1998 RECEIVED DEC 0 9 '1998 BPXA PDC ORIGINAL S UR VEY REPORT 1 December, 1998 Your Ref: AP1-500292290600 KBE - 54.8' MWD Survey Instrument Surface Coordinates: 5906424.70 N, 363995.48 E (70° 09' 08.0322" N, 147° 05' 37.1954" W) :..~aj~__..i-~i-~'~,j'- ~l_lrl nRILL, IH{~ SERVICES Survey Reh svy661 Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No. AKVC80417, Surveyed: 5 November, ~998 Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -54.80 0.00 35.30 0.000 0.000 -19.50 35.30 96.98 0.360 48.070 42.18 96.98 191.62 0.140 337.920 136.82 191.62 287.61 0.380 29.970 232.81 287.61 381.69 0.460 1.580 326.89 381.69 470.69 0.570 27.110 415.88 470.68 556.96 1.240 21.470 502.14 556.94 650.84 2.380 15.970 595.97 650.77 745.27 3.830 8.830 690.26 745.06 838.57 4.320 6.150 783.33 838.13 932.65 4.420 9.400 877.13 931.93 1026.63 4.510 10.810 970.83 1025.63 1120.06 2.710 13.830 1064.07 1118.87 1212.21 2.270 10.160 1156.13 1210.93 1305.69 0.830 15.920 1249.57 1304.37 1400.90 0.220 89.460 1344.78 1399.58 1494.69 0.370 90.120 1438.57 1493.37 1588.26 0.590 127.000 1532.14 1586.94 1681.55 1.000 124.180 1625.42 1680.22 1775.15 1.020 137.160 1719.00 1773.80 1868.61 0.630 178.490 1812.45 1867.25 1962.88 0.980 205.270 1906.71 1961.51 2057.18 0.960 201.380 2001.00 2055.80 2149.91 1.130 202.690 2093.71 2148.51 Local Coordinates Global Coordinates Northings Eastings Northlngs Eastlngs (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5906424.70 N 363995.48 E 0.00 N 0.00 E 5906424.70 N 363995.48 E 0.13 N 0.14 E 5906424.83 N 363995.63 E 0.44 N 0.32 E 5906425.13 N 363995,81 E 0.82 N 0.44 E 5906425.51 N 363995.93 E 1.47 N 0.60 E 5906426.16 N 363996.11 E 2.22 N 0.81 E 5906426.90 N 363996.33 E 3.47 N 1.35 E 5906428.14 N 363996.89 E 6,29 N 2.26 E 5906430.95 N 363997.85 E 11.29 N 3.28 E 5906435.93 N 363998,97 E 17.86 N 4.14 E 5906442.49 N 363999.94 E 24.96 N 5.11 E 5906449.57 N 364001.04 E 32.17 N 6.39 E 5906456.75 N 364002.45 E 37.92 N 7.61 E 5906462.48 N 364003.77 E 41.83 N 8.45 E 5906466.37 N 364004.68 E 44.30 N 8.97 E 5906468.84 N 364005.24 E 44.97 N 9.34 E 5906469.49 N 364005.62 E 44.97 N 9.82 E 5906469.49 N 364006.11 E 44.68 N 10.51 E 5906469.18 N 364006.79 E 43.93 N 11.57 E 5906468.42 N 364007.83 E 42.86 N 12.81 E 5906467.33 N 364009.06 E 41.74 N 13.39 E 5906466.19 N 364009.61 E 40.49 N 13.06 E 5906464.95 N 364009.26 E 39.03 N 12.42 E 5906463.50 N 364008.60 E 37.46 N 11.79 E 5906461.94 N 364007.94 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/'lOOft) (ft) Comment 0.00 0.000 0.00 0.584 0.17 0.358 0.43 0.327 0.65 0.234 1.00 0.283 1.41 0.783 2.28 1.227 3.95 1.586 6.36 0.563 9.04 0.284 11.99 0.151 15.27 1.937 18.07 0.508 19.99 1.547 21.18 0.836 21.73 0.160 22.19 0.394 22.77 0.441 23.57 0.245 24.45 0.735 24.69 0.536 24.02 0.073 23.00 0.185 21.94 Continued... 1 December, 1998 - 17:06 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: AP1-5~,0292290600 Job No. AKVC80417, Surveyed: 5 November, 1998 Badami Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2244.98 1.460 193.140 2188.76 2243.56 2339.79 0.450 204.170 2283.56 2338.36 2433.77 0.340 287.360 2377.53 2432.33 2527.16 0.650 302.360 2470.92 2525.72 2620.05 0.680 312.230 2563.80 2618.60 2714.77 0.990 307.810 2658.51 2713.31 2807.93 0.650 294.750 2751.67 2806.47 2901.78 0.650 299.770 2845.51 2900.31 2995.60 0.380 292.880 2939.33 2994.13 3089.29 0.520 324.680 3033.01 3087.81 3182.51 0.570 350.780 3126.23 3181.03 3278.55 0.390 70.980 3222.27 3277.07 3369.09 0.520 87.870 3312.80 3367.60 3461.73 0.370 87.240 3405.44 3460.24 3555.67 0.350 90.510 3499.38 3554.18 3649.05 0.470 74.740 3592.76 3647.56 3741.32 0.250 105.810 3685.02 3739.82 3835.14 0.200 119.970 3778.84 3833.64 3929.06 0.230 122.950 3872.76 3927.56 4023.58 0.280 102.600 3967.28 4022.08 4117.27 0.360 109.290 4060.97 4115.77 4210.67 0.300 172.250 4154.37 4209.17 4303.99 0.700 204.720 4247.69 4302.49 4399.41 0.590 213.220 4343.10 4397.90 4461.39 0.650 196.260 4405.08 4459.88 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 35.42 N 11.15 E 5906459,91 N 364007.27 E 33.90 N 10.72 E 5906458.40 N 364006.81 E 33.65 N 10.31 E 5906458.16 N 364006.39 E 34.01 N 9.59 E 5906458.54 N 364005.68 E 34.67 N 8.74 E 5906459.20 N 364004.84 E 35.54 N 7.68 E 5906460.10 N 364003.80 E 36.26 N 6,56 E 5906460.84 N 364002.69 E 36.75 N 5.62 E 5906461.34 N 364001.76 E 37.13 N 4.87 E 5906461.74 N 364001.02 E 37.60 N 4.34 E 5906462.22 N 364000.49 E 38.40 N 4.02 E 5906463.02 N 364000.19 E 38.98 N 4.25 E 5906463.60 N 364000.43 E 39.10 N 4.95 E 5906463.70 N 364001.13 E 39.13 N 5.67 E 5906463.72 N 364001.85 E 39.14 N 6.26 E 5906463.72 N 364002.44 E 39.24 N 6.92 E 5906463.81 N 364003.10 E 39.28 N 7.47 E 5906463.84 N 364003.66 E 39.14 N 7.81 E 5906463.70 N 364004.00 E 38.96 N 8.11 E 5906463.51 N 364004.29 E 38.81 N 8.50 E 5906463.35 N 364004.67 E 38.66 N 9.00 E 5906463.19 N 364005.17 E 38.32 N 9.31 E 5906462.85 N 364005.48 E 37.56 N 9.10 E 5906462.09 N 364005.26 E 36.62 N 8.59 E 5906461.16 N 364004.73 E 36.01 N 8.32 E 5906460.56 N 364004.44 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/'tOOft) (ft) Comment 0.414 20.75 1.078 19.91 0.565 19.44 0.357 18.86 0.127 18.23 0.334 17.46 0.414 16.59 0.061 15.82 0.295 15.21 0.300 14.84 0.269 14.76 0.660 15.15 0.205 15.85 0.162 16.55 0.031 17.12 0.175 17.78 0.311 18.32 0.079 18.61 0.034 18.84 0.109 19.17 0.094 19.61 0.373 19.81 0.509 19.40 0.152 18.64 0.310 18.20 Continued... 1 December, 1998- 17:06 -3- DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, ~998 Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 4525.42 0.830 195.050 4469.10 4523.90 4618.87 0.770 193.560 4562,54 4617.34 4712.91 1.140 176.620 4656.57 4711.37 4805.04 1.240 160.050 4748.68 4803.48 4899.41 1.950 155.850 4843.01 4897.81 4993.97 1.730 158.740 4937.52 4992.32 5087.59 2.010 152.360 5031.09 5085.89 5182.05 3.220 127.820 5125.46 5180.26 5276.64 5.060 104.110 5219.80 5274.60 5369.54 7.340 98.530 5312.15 5366.95 5464.67 11.600 87.510 5405.97 5460.77 5558.18 15.480 81.400 5496.87 5551.67 5652.93 18.730 76.580 5587.42 5642.22 5746.82 23.630 71.710 5674.95 5729.75 5839.92 27.600 71.840 5758.88 5813.68 5933.77 30.370 70.600 5840.97 5895.77 6027.27 34.270 71.190 5919.97 5974.77 6120.96 37.180 71.880 5996.02 6050.82 6215.70 40.820 73.400 6069.64 6124.44 6309.99 44.570 73.130 6138.93 6193.73 6403.60 47.940 73.280 6203.64 6258.44 6498.02 51.790 73.880 6264.50 6319.30 6597.70 53.210 74.190 6325.18 6379.98 6693.87 53.060 73.160 6382.87 6437.67 6786.84 52.770 73.260 6438.93 6493.73 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 35.22 N 8.10 E 5906459.77 N 364004.21 E 33.95 N 7.77 E 5906458.51 N 364003.86 E 32,41 N 7.68 E 5906456.96 N 364003.74 E 30.55 N 8.07 E 5906455.10 N 364004.10 E 28,13 N 9.08 E 5906452.66 N 364005.06 E 25.33 N 10.26 E 5906449.84 N 364006.19 E 22.56 N 11.53 E 5906447.05 N 364007.41 E 19.46 N 14.39 E 5906443.90 N 364010.22 E 16.82 N 20.54 E 5906441.15 N 364016.32 E 14.94 N 30.38 E 5906439.09 N 364026.13 E 14.45 N 45.96 E 5906438.33 N 364041.69 E 16.73 N 67.70 E 5906440.21 N 364063.47 E 22.15 N 95.00 E 5906445.14 N 364090.87 E 31.56 N 127.56 E 5906453.97 N 364123.58 E 44.14 N 165.78 E 5906465.86 N 364162.02 E 58.80 N 208.82 E 5906479.74 N 364205.32 E 75.15 N 256.05 E 5906495.24 N 364252.84 E 92.46 N 307.94 E 5906511.62 N 364305.03 E 110.22 N 364.84 E 5906528.35 N 364362.24 E 128.63 N 426.06 E 5906545.66 N 364423.78 E 148.17 N 490.79 E 5906564.03 N 364488.85 E 168.56 N 560.02 E 5906583.18 N 364558.44 E 190.31 N 636.05 E 5906603.56 N 364634.85 E 211.93 N 709.89 E 5906623.85 N 364709.06 E 233.36 N 780.89 E 5906644.00 N 364780.44 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/'tOOft) Comment 0.282 17.76 0.068 17.10 0.491 16.57 0.387 16.42 0.762 16.69 0.252 17.03 0.372 17.46 1.718 19.33 2.618 24.47 2.536 33.37 4.847 48.17 4.417 69.66 3.739 97.38 5.541 131.27 4.265 171.49 3.020 216.92 4.185 266.85 3.136 321.52 3.972 381.12 3.982 445.05 3.602 512.66 4.106 584.83 1.446 663.91 0.871 740.85 0.324 815.01 Continued... I December, 1998- 17:06 -4- DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Reft API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, 1998 Badami Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6881.30 53.740 73.630 6495.44 6550.24 6974.97 54.410 74.000 6550.40 6605.20 7068.03 55.190 75.340 6604.05 6658.85 7161.85 56.610 76.960 6656.65 6711.45 7254.80 56.390 76.800 6707.95 6762.75 7348.86 56.210 76.490 6760.14 6814.94 7442.98 56.060 76.200 6812.58 6867.38 7536.65 56.050 75.740 6864.89 6919.69 7630.52 56.360 75.340 6917.10 6971.90 7724.23 55.770 75.680 6969.42 7024.22 7818.97 55.930 75.590 7022.60 7077.40 7912.18 57.060 76.540 7074.05 7128.85 8006.00 57.720 75.830 7124.61 7179.41 8100.44 58.000 75.690 7174.85 7229.65 8195.10 57.780 74.830 7225.17 7279.97 8288.39 56.880 74.780 7275.53 7330.33 8382.50 55.780 74.930 7327.70 7382.50 8476.21 54.660 76.330 7381.1 6 7435.96 8570.10 54.440 77.700 7435.62 7490.42 8663.62 54.440 77.030 7490.00 7544.80 8758.88 53.430 77.320 7546.08 7600.88 8852.39 52.450 76.440 7602.44 7657.24 8946.73 51.470 77.280 7660.57 7715.37 9040.71 50.830 78.830 7719.52 7774.32 9135.14 49.710 78.440 7779.88 7834.68 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 254.92 N 276.06 N 296.16 N 314.75 N 332.34 N 350.42 N 368.87 N 387.71 N 407.18 N 426.64 N 446.09 N 464.80 N 483.68 N 503.35 N 523.75 N 544.33 N 564.79 N 583.90 N 601.09 N 617.73 N 634.82 N 651.76 N 668.65 N 683.8O N 698.11 N 853.45 E 5906664.26 N 364853.37 E 926.29 E 5906664.09 N 364926.58 E 999.63 E 5906702.87 N 365000.27 E 1075.06 E 5906720.10 N 365076.01 E 1150.54 E 5906736.33 N 365151.80 E 1226.68 E 5906753.04 N 365228.25 E 1302.62 E 5906770.12 N 365304.52 E 1378.01 E 5906787.60 N 365380.23 E 1453.55 E 5906805.72 N 365456.10 E 1528.82 E 5906823.82 N 365531.72 E 1604.78 E 5906641.91 N 365608.01 E 1680.21 E 5906859.26 N 365683.76 E 1756.95 E 5906876.75 N 365760.83 E 1834.46 E 5906895.03 N 365838.68 E 1912.00 E 5906914.03 N 365916.58 E 1987.79 E 5906933.25 N 365992.72 E 2063.39 E 5906952.36 N 366068.67 E 2137.94 E 5906970.12 N 366143.56 E 2212.47 E 5906985.97 N 366218.38 E 2286.70 E 5907001.27 N 366292.90 E 2361.78 E 5907017.02 N 366368.28 E 2434.46 E 5907032.64 N 366441.24 E 2506.81 E 5907048.24 N 366513.89 E 2578.41 E 5907062.10 N 366585.75 E 2649.61 E 5907075.13 N 366657.19 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/'lOOft) (ft) Comment 1.074 890.70 0.764 966.55 1.445 1042.58 2.082 1120.18 0.277 1197.55 0.334 1275.69 0.301 1353.74 0.408 1431.38 0.464 1509.34 0.698 1587.04 0.186 1665.39 1.481 1743.03 O.949 1821.97 0.322 1901.88 0.804 1982.02 0.966 2060.53 1.176 2138.83 1.713 2215.74 1.212 2292.07 0.583 2367,98 1.088 2444,82 1.289 2519.31 1.253 2593.48 1.454 2666.44 1.228 2738.77 Continued... 1 December, 1998 - 17:06 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Reft API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, 1998 Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 9228.51 49.670 78.340 7840.28 7895,08 9322.94 49.270 79.050 ~7901.65 7956.45 9417.85 49.480 78.340 7963.45 8018.25 9512.10 49.170 77.760 8024.87 8079.67 9604,94 48.240 78.240 8086.14 8140.94 9700.25 48.030 77.580 8149.75 8204.55 9793.48 47.640 77.370 8212.33 8267.13 9887.59 47.770 76.090 8275.67 8330.47 9980.99 47.690 75.760 8338.49 8393.29 10075.04 47.210 74.960 8402.09 8456.89 10169.51 46.060 74.490 8466.96 8521.76 10263.86 44.990 73.460 8533.06 8587.86 10358.13 44.600 72.910 8599.95 8654.75 10451.33 43.840 71.590 8666.75 8721.55 10544.83 43.210 71.130 8734.54 8789.34 10638.28 42.770 69.720 8802.90 8857.70 10731.99 41.790 68.520 8872.23 8927.03 10826.04 40.900 68.330 8942.84 8997.64 10841.26 40.930 67.840 8954.34 9009.14 10938.10 40.830 68.360 9027.56 9082.36 10989.19 40.620 69.560 9066.28 9121.08 11054.34 40.450 69.450 9115,79 9170.59 11148.71 40.580 70.370 9187.54 9242.34 11243.10 39.490 68.100 9259.81 9314.61 11337.98 37.470 67.100 9334,08 9388.88 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 712.44 N 2719.35 E 5907088,20 N 366727.18 E 726.51 N 2789.73 E 5907101,01 N 366797.80 E 740.63 N 2860.37 E 5907113.86 N 366868.68 E 755.43 N 2930.30 E 5907127.40 N 366938.87 E 769.94 N 2998.52 E 5907140.68 N 367007.34 E 784.80 N 3067,93 E 5907154.29 N 367077.00 E 799.79 N 3135.39 E 5907168.07 N 367144.72 E 815,77 N 3203.14 E 5907182.83 N 367212,75 E 832.57 N 3270.18 E 5907198,43 N 367280.08 E 850.08 N 3337.21 E 5907214.73 N 367347.42 E 868.17 N 3403.46 E 5907231.63 N 367413.98 E 886.75 N 3468,17 E 5907249.04 N 367479,01 E 905.97 N 3531.75 E 5907267.11 N 367542.93 E 925.78 N 3593.65 E 5907285,81 N 367605.18 E 946.35 N 3654.67 E 5907305.29 N 367666.55 E 967.70 N 3714.70 E 5907325.55 N 367726.96 E 990.16 N 3773.61 E 5907346.95 N 367786.25 E 1013.01 N 3831.38 E 5907368.76 N 367844.43 E 1016.73 N 3840.63 E 5907372.31 N 367853.74 E 1040.37 N 3899.43 E 5907394.89 N 367912.96 E 1052.33 N 3930.54 E 5907406.30 N 367944,28 E 1067.16 N 3970,20 E 5907420,41 N 367984.20 E 1088.22 N 4027.78 E 5907440.43 N 368042.15 E 1109.73 N 4084.55 E 5907460.92 N 368099.29 E 1132.21 N 4139.13 E 5907482.42 N 368154.27 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/'lOOft) (ft) Comment 0.092 2809.71 0.711 2881.19 0.609 2952.93 0.571 3024.18 1.074 3093.72 0.561 3164.49 0.450 3233.42 1.015 3302.92 0.275 3371.97 0.808 3441.22 1,270 3509.88 1.376 3577.20 0.583 3643.62 1,281 3708.60 0,754 3772.95 1.131 3836,57 1.355 3899.43 0.956 3961.31 2.118 3971.24 0.366 4034.34 1.587 4067.56 0.283 4109.80 0.648 4170.99 1.930 4231.53 2.228 4290.25 Continued,.. 1 December, 1998 - 17:06 - 6 - DrillQuest Sperry. Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, 1998 Badami Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northlngs Eastings Northings Eastings (ft) (ft) (ft) (ft) 11432.06 36.060 63.300 9409.46 9464.26 1155.79 N 4190.24 E 5907505.08 N 368205.80 E 11526.46 36.710 64.580 9485.46 9540.26 1180.39 N 4240.55 E 5907528.77 N 368256.53 E 11621.24 35.760 64.250 9561.90 9616.70 1204.58 N 4291.08 E 5907552.05 N 368307.49 E 11715.54 34.860 63.300 9638.86 9693.66 1228.66 N 4339.97 E 5907575.25 N 368356.81E 11810.04 34.060 63.060 9716.77 9771.57 1252.79 N 4387.69 E 5907598.51N 366404.96 E 11904.77 32.770 63.150 9795.64 9850.64 1276.38 N 4434.21 E 5907621.27 N 368451.90 E 11998.99 31.720 62.970 9875.53 9930.33 1299.16 N 4479.03 E 5907643.23 N 368497.11 E 12093.26 30.810 62.180 9956.11 10010.91 1321.69 N 4522.46 E 5907664.98 N 368540.94 E 12187.78 29.540 62.160 10037.82 10092.62 1343.87 N 4564.47 E 5907686.40 N 368583.34 E 12280.93 28.340 62.120 10119.34 10174.14 1364.93 N 4604.32 E 5907706.75 N 368623.56 E 12376.01 27.150 61.400 10203.48 10258.28 1385.87 N 4643.32 E 5907726.98 N 368662.93 E 12469.95 26.200 60.750 10287.42 10342.22 1406.26 N 4680.23 E 5907746.71N 368700.20 E 12562.40 25.350 60.740 10370.68 10425.48 1425.91N 4715.30 E 5907765.72 N 368735.62 E 12627.67 24.890 61.120 10429.77 10484.57 1439.37 N 4739.52 E 5907778.75 N 368760.08 E 12687.29 24.150 61.110 10484.02 10538.82 1451.32 N 4761.18 E 5907790.31 N 368781.95 E 12750.00 24.150 61.110 10541.24 10596.04 1463.72 N 4783.65 E 5907802.30 N 368804.64E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 28.704° (25-Oct-98) The Dogleg 'Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 73.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12750.00ft., The Bottom Hole Displacement is 5002.58ft., in the Direction of 72.987° (True). Alaska State Plane Zone 3 Badami CPF Dogleg Rate (°/'lOOft) Vertical Section (ft) Comment 2.844 1.059 1.023 1.118 0.859 1.363 1.119 1.059 1.344 1.288 1.300 1.058 0.919 0.747 1.241 0.000 4345.95 4401.17 4456.49 4510.21 4562.82 4614.13 4663.56 4711.60 4758.18 4802.38 4845.71 4886.90 4926.10 4953.15 4977.32 5002.37 Projected Survey Continued... 1 December, 1998- 17:06 - 7- DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, 1998 Badami Alaska State Plane Zone 3 Badami CPF Comments Measured Depth (ft) 0.00 12750.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 10596.04 1463.72 N 4783.65 E Comment Tie-on Survey Projected Survey 1 December, 1998 - 17:06 - 8 - DrillQuest 00~9967 RECENED BPY, A PDC Badami Alaska State Plane Zone 3 Badami CPF, Slot B'/-25 B~-25 Job No. AKVC80417, Surveyed: 5 November, ~998 S UR VEY REPORT December, ~998 Your Reft AP1-500292290600 KBE - 54.8' MWD Survey Instrument Surface Coordinates: 5906424.70 N, 363995.48 E (70° 09' 08.0322' N, ~47° 05' 37. f954' W) DRILLING SERVICES Survey Reft svy66'l Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, 1998 Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -54.80 0.00 35.30 0.000 0.000 -19.50 35.30 96.98 0.360 48.070 42.18 96.98 191.62 0.140 337.920 136.82 191.62 287.61 0.380 29.970 232.81 287.61 381.69 0.460 1.580 326.89 381.69 470.69 0.570 27.110 415.88 470.68 556.96 1.240 21.470 502.14 556.94 650.84 2.380 15.970 595.97 650.77 745.27 3.830 8.830 690.26 745.06 838.57 4.320 6.150 783.33 838.13 932.65 4.420 9.400 877.13 931.93 1026.63 4.510 10.810 970.83 1025.63 1120.06 2.710 13.830 1064.07 1118.87 1212.21 2.270 10.160 1156.13 1210.93 1305.69 0.830 15.920 1249.57 1304.37 1400.90 0.220 89.460 1344.78 1399.58 1494.69 0.370 90.120 1438.57 1493.37 1588.26 0.590 127.000 1532.14 1586.94 1681.55 1.000 124.180 1625.42 1680.22 1775.15 1.020 137.160 1719.00 1773.80 1868.61 0.630 178.490 1812.45 1867.25 1962.88 0.980 205.270 1906.71 1961.51 2057.18 0.960 201.380 2001.00 2055.80 2149.91 1.130 202.690 2093.71 2148.51 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5906424.70 N 363995.48 E 0.00 N 0.00 E 5906424.70 N 363995.48 E 0.13 N 0.14 E 5906424.83 N 363995.63 E 0.44 N 0.32 E 5906425.13 N 363995,81 E 0.82 N 0.44 E 5906425.51 N 363995.93 E 1.47 N 0,60 E 5906426.16 N 363996.11 E 2.22 N 0.81 E 5906426.90 N 363996.33 E 3.47 N 1.35 E 5906428.14 N 363996.89 E 6.29 N 2.26 E 5906430.95 N 363997.85 E 11.29 N 3.28 E 5906435.93 N 363998.97 E 17,86 N 4.14 E 5906442.49 N 363999.94 E 24.96 N 5.11 E 5906449.57 N 364001.04 E 32.17 N 6.39 E 5906456.75 N 364002.45 E 37.92 N 7.61 E 5906462.48 N 364003.77 E 41.83 N 8,45 E 5906466.37 N 364004,68 E 44.30 N 8.97 E 5906468.84 N 364005.24 E 44.97 N 9.34 E 5906469.49 N 364005.62 E 44.97 N 9.82 E 5906469.49 N 364006,11 E 44.68 N 10.51 E 5906469.18 N 364006.79 E 43.93 N 11.57 E 5905468.42 N 364007.83 E 42,86 N 12.81 E 5906467.33 N 364009,06 E 41.74 N 13.39 E 5906466.19 N 364009.61 E 40.49 N 13.06 E 5906464.95 N 364009.26 E 39.03 N 12.42 E 5906463.50 N 364008.60 E 37.46 N 11.79 E 5906461.94 N 364007.94 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/'tOOft) (ft) Comment 0.00 0.000 0.00 0.584 0.17 0.358 0.43 0.327 0.65 0.234 1.00 0.283 1.41 0.783 2.28 1.227 3.95 1.586 6.36 0.563 9.04 0.284 11.99 0.151 15.27 1,937 18.07 0.508 19.99 1.547 21.18 O.836 21.73 0.160 22.19 0.394 22.77 0.441 23.57 0.245 24.45 0.735 24.69 0.536 24.02 0.073 23.00 0.185 21.94 Continued... 1 December, 1998 - 17:06 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No, AKVCS0417, Surveyed: 5 November, 1998 Badami Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2244.98 1.460 193.140 2188.76 2243.56 2339.79 0.450 204.170 2283.56 2338.36 2433.77 0.340 287.360 2377.53 2432.33 2527.16 0.650 302.360 2470.92 2525.72 2620.05 0.680 312.230 2563.80 2618.60 2714.77 0.990 307.810 2658.51 2713.31 2807.93 0.650 294.750 2751.67 2806.47 2901.78 0.650 299.770 2845.51 2900.31 2995.60 0.380 292.880 2939.33 2994.13 3089.29 0.520 324.680 3033.01 3087.81 3182.51 0.570 350.780 3126.23 3181.03 3278.55 0.390 70.980 3222.27 3277.07 3369.09 0.520 87.870 3312.80 3367.60 3461.73 0.370 87.240 3405.44 3460.24 3555.67 0.350 90.510 3499.38 3554.18 3649.05 0.470 74.740 3592.76 3647.56 3741.32 0.250 105.810 3685.02 3739.82 3835.14 0.200 119.970 3778.84 3833.64 3929.06 0.230 122.950 3872.76 3927.56 4023.58 0.280 102.600 3967.28 4022.08 4117.27 0.360 109.290 4060.97 4115.77 4210.67 0.300 172.250 4154.37 4209.17 4303.99 0.700 204.720 4247.69 4302.49 4399.41 0.590 213.220 4343.10 4397.90 4461.39 0.650 196.260 4405.08 4459.88 Local Coordinates Global Coordinates Northings Eastings Northlngs Eastlngs (ft) (ft) (ft) (ft) 35.42 N 11.15 E 5906459.91 N 364007.27 E 33.90 N 10.72 E 5906458.40 N 364006.81 E 33.65 N 10.31 E 5906458.16 N 364006.39 E 34.01 N 9.59 E 5906458.54 N 364005.68 E 34.67 N 8.74 E 5906459.20 N 364004.84 E 35.54 N 7.68 E 5906460.10 N 364003.80 E 36.26 N 6.56 E 5906460.84 N 364002.69 E 36.75 N 5.62 E 5906461.34 N 364001.76 E 37.13 N 4.87 E 5906461.74 N 364001.02 E 37.60 N 4.34 E 5906462.22 N 364000.49 E 38.40 N 4.02 E 5906463.02 N 364000.19 E 38.98 N 4.25 E 5906463.60 N 364000.43 E 39.10 N 4.95 E 5906463.70 N 364001.13 E 39.13 N 5.67 E 5906463.72 N 364001.85 E 39.14 N 6.26 E 5906463.72 N 364002.44 E 39.24 N 6.92 E 5906463.81 N 364003.10 E 39.28 N 7.47 E 5906463.84 N 364003.66 E 39.14 N 7.81 E 5906463.70 N 364064.00 E 38.96 N 8.11 E 5906463.51 N 364004.29 E 38.81 N 8.50 E 5906463.35 N 364004.67 E 38.66 N 9.00 E 5906463.19 N 364005.17 E 38.32 N 9.31 E 5906462.85 N 364005.48 E 37.56 N 9.10 E 5906462.09 N 364005.26 E 36.62 N 8.59 E 5906461.16 N 364004.73 E 36.01 N 8.32 E 5906460.56 N 364004.44 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.414 20.75 1.o78 19.91 0.565 19.44 0.357 18.86 0.127 18.23 0.334 17.46 0.414 16.59 0.061 15.82 0.295 15.21 0.300 14.84 0.269 14.76 0.660 15.15 0.205 15.85 0.162 16.55 0.031 17.12 0.175 17.78 0.311 18.32 0.079 18.61 0.034 18.84 0.109 19.17 0.094 19.61 0.373 19.81 0.509 19.40 0.152 18.64 0.310 18.20 Continued... I December, 1998- 17:06 -3- DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, 1998 Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 4525.42 0.830 195.050 4469.10 4523.90 4618.87 0.770 193.560 4562.54 4617.34 4712.91 1.140 176.620 4656.57 4711.37 4805.04 1.240 160.050 4748.68 4803.48 4899.41 1.950 155.850 4843.01 4897.81 4993.97 1.730 158.740 4937.52 4992.32 5087.59 2.010 152.360 5031.09 5085.89 5182.05 3.220 127.820 5125.46 5180.26 5276.64 5.060 104.110 5219.80 5274.60 5369.54 7.340 98.530 5312.15 5366.95 5464.67 11.600 87.510 5405.97 5460.77 5558.18 15.480 81.400 5496.87 5551.67 5652.93 18.730 76.580 5587.42 5642.22 5746.82 23.630 71.710 5674.95 5729.75 5839.92 27.600 71.840 5758.88 5813.68 5933.77 30.370 70.600 5840.97 5895.77 6027.27 34.270 71.190 5919.97 5974.77 6120.96 37.180 71.880 5996.02 6050.82 6215.70 40.820 73.400 6069.64 6124.44 6309.99 44.570 73.130 6138.93 6193.73 6403.60 47.940 73.280 6203.64 6258.44 6498.02 51.790 73.880 6264.50 6319.30 6597.70 53.210 74.190 6325.18 6379.98 6693.87 53.060 73.160 6382.87 6437.67 6786.84 52.770 73.260 6438.93 6493.73 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 35.22 N 8.10 E 5906459.77 N 364004.21 E 33.95 N 7.77 E 5906458.51 N 364003.86 E 32.41 N 7.68 E 5906456.96 N 364003.74 E 30.55 N 8.07 E 5906455.10 N 364004.10 E 28.13 N 9.08 E 5906452.66 N 364005.06 E 25.33 N 10.26 E 5906449.84 N 364006.19 E 22.56 N 11.53 E 5906447.05 N 364007.41 E 19.46 N 14.39 E 5906443.90 N 364010.22 E 16.82 N 20.54 E 5906441.15 N 364016.32 E 14.94 N 30.38 E 5906439.09 N 364026.13 E 14.45 N 45.96 E 5906438.33 N 364041.69 E 16.73 N 67.70 E 5906440.21 N 364063.47 E 22.15 N 95.00 E 5906445.14 N 364090.87 E 31.56 N 127.56 E 5906453.97 N 364123.58 E 44.14 N 165.78 E 5906465.86 N 364162.02 E 58.80 N 208.82 E 5906479.74 N 364205.32 E 75.15 N 256.05 E 5906495.24 N 364252.84 E 92.46 N 307.94 E 5906511.62 N 364305.03 E 110.22 N 364.84 E 5906528.35 N 364362.24 E 128.63 N 426.06 E 5906545.66 N 364423.78 E 148.17 N 490.79 E 5906564.03 N 364488.85 E 168.56 N 560.02 E 5906583.18 N 364558.44 E 190.31 N 636.05 E 5906603.56 N 364634.85 E 211.93 N 709.89 E 5906623.85 N 364709.06 E 233.36 N 780.89 E 5906644.00 N 364780.44 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/'tOOft) (ft) Comment 0.282 17.76 0.068 17.10 0.491 16.57 0.387 16.42 0.762 16.69 0.252 17.03 0.372 17.46 1.718 19.33 2.618 24.47 2.536 33.37 4.847 48.17 4.417 69.66 3.739 97.38 5.541 131.27 4.265 171.49 3.020 216.92 4.185 266.85 3.136 321.52 3.972 381.12 3.982 445.05 3.602 512.66 4.106 584.83 1.446 663.91 0.871 740.85 0.324 815.01 Continued... 1 December, 1998- 17:06 -4- DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, ~998 Badami Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6881.30 53.740 73.630 6495.44 6550.24 6974.97 54.410 74.000 6550.40 6605.20 7068.03 55.190 75.340 6604.05 6658.85 7161.85 56.610 76.960 6656.65 6711.45 7254.80 56.390 76.800 6707.95 6762.75 7348.86 56.210 76.490 6760.14 6814.94 7442.98 56.060 76.200 6812.58 6867.38 7536.65 56.050 75.740 6864.89 6919.69 7630.52 56.360 75.340 6917.10 6971.90 7724.23 55.770 75.680 6969.42 7024.22 7818.97 55.930 75.590 7022.60 7077.40 7912.18 57.060 76.540 7074.05 7128.85 8006.00 57.720 75.830 7124.61 7179.41 8100.44 58.000 75.690 7174.85 7229.65 8195.10 57.780 74.830 7225.17 7279.97 8288.39 56.880 74.780 7275.53 7330.33 8382.50 55.780 74.930 7327.70 7382.50 8476.21 54.660 76.330 7381.16 7435.96 8570.10 54.440 77.700 7435.62 7490.42 8663.62 54.440 77.030 7490.00 7544.80 8758.88 53.430 77.320 7546.08 7600.88 8852.39 52.450 76.440 7602.44 7657.24 8946.73 51.470 77.280 7660.57 7715.37 9040.71 50.830 78.830 7719.52 7774.32 9135.14 49.710 78.440 7779.88 7834.68 Local Coordinates Global Coordinates Northings Eastings Northlngs Eastings (ft) (ft) (ft) (ft) 254.92 N 853.45 E 5906664.26 N 364853.37 E 276.06 N 926.29 E 5906684.09 N ' 364926.58 E 296.16 N 999.63 E 5906702.87 N 365000.27 E 314.75 N 1075.06 E 5906720.10 N 365076.01E 332.34 N 1150.54E 5906736.33 N 365151.80 E 350.42 N 1226.68 E 5906753.04 N 365228.25 E 368.87 N 1302.62 E 5906770.12 N 365304.52 E 387.71 N 1378.01E 5906787.60 N 365380.23 E 407.18 N 1453.55 E 5906805.72 N 365456.10 E 426.64 N 1528.82 E 5906823.82 N 365531.72 E 446.09 N 1604.78 E 5906841.91N 365608.01E 464.80 N 1680.21E 5906859.26 N 365683.76 E 483.68 N 1756.95 E 5906876.75 N 365760.83 E 503.35 N 1834.46 E 5906895.03 N 365838.68 E 523.75 N 1912.00 E 5906914.03 N 365916.58 E 544.33 N 1987.79 E 5906933.25 N 365992.72 E 564.79 N 2063.39 E 5906952.36 N 366068.67 E 583.90 N 2137.94E 5906970.12 N 366143.56 E 601.09 N 2212.47 E 5906985.97 N 366218.38 E 617.73 N 2286.70 E 5907001.27 N 366292.90 E 634.82 N 2361.78 E 5907017.02 N 366368.28 E 651.76 N 2434.46 E 5907032.64N 366441.24 E 668.65 N 2506.81 E 5907048.24 N 366513.89 E 683.80 N 2578.41E 5907062.10 N 366585.75 E 698.11N 2649.61E 5907075.13 N 366657.19 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/lOOft) (fl:) Comment 1.074 890.70 0.784 966.55 1.445 1042.58 2.082 1120.18 0.277 1197.55 0.334 1275.69 0.301 1353.74 0.408 1431.38 0.464 1509.34 0.698 1587.04 0.186 1665.39 1.481 1743.03 0.949 1821.97 0.322 1901.88 0.804 1982.o2 0.966 2060.53 1.176 2138.83 1.713 2215.74 1.212 2292.07 0.583 2367.98 1.088 2444.82 1.289 2519.31 1.253 2593.48 1.454 2666.44 1.228 2738.77 Continued... 1 December, 1998 - 17:06 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for BI-25 Your Ref: API-500292290600 Job No, AKVCS0417, Surveyed: 5 November, 1998 Badami Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9228.51 49,670 78.340 7840.28 7895.08 9322.94 49,270 79.050 7901.65 7956.45 9417.85 49.480 78.340 7963.45 8018.25 9512.10 49.170 77.760 8024.87 8079.67 9604.94 48.240 78.240 8086.14 8140.94 9700.25 48.030 77.580 8149.75 8204.55 9793.48 47.640 77.370 8212.33 8267.13 9887.59 47.770 76.090 8275.67 8330.47 9980.99 47.690 75.760 8338,49 8393.29 10075.04 47.210 74.960 8402.09 8456.89 10169.51 46.060 74.490 8466,96 8521.76 10263.86 44.990 73.460 8533,06 8587,86 10358.13 44.600 72.910 8599,95 8654,75 10451.33 43.840 71.590 8666.75 8721,55 10544.83 43.210 71.130 8734.54 8789,34 10638.28 42.770 69.720 8802.90 8857.70 10731.99 41.790 68.520 8872.23 8927.03 10826.04 40.900 68.330 8942.84 8997.64 10841.26 40.930 67.840 8954.34 9009.14 10938.10 40.830 68.360 9027.56 9082.36 10989.19 40.620 69.560 9066.28 9121.08 11054.34 40.450 69.450 9115.79 9170.59 11148.71 40.580 70.370 9187.54 9242.34 11243.10 39.490 68.100 9259.81 9314.61 11337.98 37.470 67.100 9334.08 9388.88 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 712.44 N 2719.35 E 5907088.20 N 366727.18 E 726.51 N 2789.73 E 5907101.01 N 366797.80 E 740.63 N 2860.37 E 5907113.86 N 366868.68 E 755.43 N 2930.30 E 5907127.40 N 366938.87 E 769.94 N 2998.52 E 5907140.68 N 367007.34 E 784.80 N 3067.93 E 5907154.29 N 367077.00 E 799.79 N 3135.39 E 5907168.07 N 367144.72 E 815.77 N 3203.14 E 5907182.83 N 367212.75 E 832.57 N 3270.18 E 5907198.43 N 367280.08 E 850.08 N 3337.21E 5907214.73 N 367347.42 E 868.17 N 3403,46 E 5907231.63 N 367413.98 E 886.75 N 3468.17 E 5907249.04 N 367479.01E 905.97 N 3531.75 E 5907267.11 N 367542.93 E 925.78 N 3593.65 E 5907285.81N 367605.18 E 946.35 N 3654.67 E 5907305.29 N 367666.55 E 967.70 N 3714.70 E 5907325.55 N 367726.96 E 990.16 N 3773.61E 5907346.95 N 367786.25 E 1013.01N 3831.38 E 5907368.76 N 367844.43 E 1016.73 N 3840.63 E 5907372.31 N 367853.74 E 1040.37 N 3899.43 E 5907394.89 N 367912.96 E 1052.33 N 3930.54E 5907406.30 N 367944.28 E 1067.16 N 3970.20 E 5907420.41N 367984.20 E 1088.22 N 4027.78 E 5907440.43 N 368042.15 E 1109.73 N 4084.55 E 5907460.92 N 368099.29 E 1132.21N 4139.13 E 5907482.42 N 368154.27 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/'t OOft) (ft) Comment 0.092 2809.71 0.711 2881.19 0.609 2952.93 0.571 3024.18 1.074 3093.72 0.561 3164.49 0.450 3233.42 1.015 3302.92 0.275 3371.97 0.808 3441.22 1.270 3509.88 1.376 3577.20 0.583 3643.62 1.281 3708.60 0.754 3772.95 1.131 3836.57 1.355 3899.43 0.956 3961.31 2.118 3971.24 0.366 4034.34 1.587 4067.56 0.283 4109.80 0.648 4170.99 1.930 4231.53 2.228 4290.25 Continued... 1 December, 1998 - 17:06 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Ref: API-500292290600 Job No. AKVCS0417, Surveyed: 5 November, 1998 Badami Measured Sub.Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11432.06 36.060 63.300 9409.46 9464.26 1155.79 N 4190.24 E 5907505.08 N 368205.80 E 11526.46 36.710 64.580 9485.46 9540.26 1180.39 N 4240.55 E 5907528.77 N 368256.53 E 11621.24 35.760 64.250 9561.90 9616.70 1204.58 N 4291.08 E 5907552.05 N 368307.49 E 11715.54 34.860 63.300 9638.86 9693.66 1228.66 N 4339.97 E 5907575.25 N 368356.81 E 11810.04 34.060 63.060 9716.77 9771.57 1252.79 N 4387.69 E 5907598.51 N 368404.96 E 11904.77 32.770 63.150 9795.84 9850.64 1276.38 N 4434.21 E 5907621.27 N 368451.90 E 11998.99 31.720 62.970 9875.53 9930.33 1299.16 N 4479.03 E 5907643.23 N 368497.11 E 12093.26 30.810 62.180 9956.11 10010.91 1321.69 N 4522.46 E 5907664.98 N 368540.94 E 12187.78 29.540 62.160 10037.82 10092.62 1343.87 N 4564.47 E 5907686.40 N 368583.34 E 12280.93 28.340 62.120 10119.34 10174.14 1364.93 N 4604.32 E 5907706.75 N 368623.56 E 12376.01 27.150 61.400 10203.48 10258.28 1385.87 N 4643.32 E 5907726,98 N 368662.93 E 12469.95 26.200 60.750 10287.42 10342.22 1406.26 N 4680.23 E 5907746.71 N 368700.20 E 12562.40 25.350 60.740 10370.68 10425.48 1425.91 N 4715.30 E 5907765.72 N 368735.62 E 12627.67 24.890 61.120 10429.77 10484.57 1439.37 N 4739.52 E 5907778.75 N 368760.08 E 12687.29 24.150 61.110 10484.02 10538.82 1451.32 N 4761.18 E 5907790,31 N 368781.95 E 12750.00 24.150 61.110 10541.24 10596.04 1463.72 N 4783.65 E 5907802,30 N 368804.64E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 28.704° (25-Oct-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 73.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12750.00ft., The Bottom Hole Displacement is 5002.58ft., in the Direction of 72.987° (True). Alaska State Plane Zone 3 Badami CPF Dogleg Rate (°/'tOOft) Vertical Section (ft) Comment 2.844 1.059 1.023 1.118 0.859 1.363 1.119 1.059 1.344 1.288 1.300 1.058 0.919 0.747 1.241 0.000 4345.95 4401.17 4456.49 4510.21 4562.82 4614.13 4663.56 4711.60 4758.18 4802.38 4845.71 4886.90 4926.10 4953.15 4977.32 5002.37 Projected Survey Continued... 1 December, 1998 - 17:06 - 7- DrillQuest Sperry-Sun Drilling Services Survey Report for B1-25 Your Reft AP1-$00292290600 Job No. AKVC80417, Surveyed: 5 November, ~998 Badami Alaska State Plane Zone 3 Badami CPF Comments Measured Depth (~t) 0.00 12750.00 Station Coordinates TVD Northings Eastings Ct) Ct) 0.00 0.00 N 0,00 E 10596.04 1463.72 N 4783.65 E Comment Tie-on Survey Projected Survey 1 December, 1998 - 17:06 - 8 - DrillQuest BP EXPLORATION, Alaska Date: 12-01-98 Trans~ 89929 BADAMI CASED HOLE LOG DATA & DISKS Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Company Code Rec Type Rec Date Comments B1-25 ATLAS CH 16-Nov-98 CASING COLLAR LOCATOR (TUBING CUT RECORD) B1-25 ATLAS CH 14-Nov-98 FORMATION MULTI-TESTER B1-25 ATLAS CH 18-Nov-98 CASING COLLAR LOCATOR B1-25 ATLAS DISK 14-Nov-98 FORMATION MULTI-TESTER · Please sign and return one copy of this transmittal to: Carla H. Mclntosh Petrotechnical Data Center LOG DATA AOGCC- 1 disk/1 blueline/1 sepia PETROFINA- 1 disk/1 blueline/1 sepia DNR- 1 disk/1 blueline BP-- 1 blueline BP ml correlation log blueline Howard Oakland Mike Engle Tim Ryherd Evelyn Raybon Ken Lemley RECEIVED DEC O3 1998 Alaska 0il & Gas Co~s. Commission Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 MEMORANDUM State of Alaska TO: THRU: David Johns_.~~ ,' Chairman~~ Blair Wondzell, P. I. Supervisor '-'..,ir.. Alaska Oil and Gas Conservation Commission DATE: November i 7. 1998 FILE NO: a7rkkqfe.doc FROM: Chuck Scheve, ¢_ .~ SUBJECT: Petroleum Inspector BOPE Test Nabors 28E Badami B1-25 PTD # 98-153 Tuesday November 17, 1998: ! traveled to BPXs Badami B1-25 well and witnessed the weekly BOPE test on Nabors Rig 28E. As the attached AOGCC BOPE test report indicates, the test lasted 4 hours with no failures. The test time was lenghtened due to leaking bleed off valves on the test pump. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary: I witnessed the weekly BOPE on Nabors Rig 28E drilling BPXs Badami B1-25 Well. Nabors 28E, 11/17/98, Test Time 4 hours, no failures Attachment: a7rkkqfe.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential ·" STATE OF ALASKA ...... OIL AND GAS CONSERVATION COMMISSION BOPE Test Report 11/17/98 OPERATION: Drlg: X Workover: DATE: Drlg Contractor: Nabors Rig No. 28E PTD# 98-153 Rig Ph.# Operator: BPX Rep.' Nick Scales Well Name: B1-25 Rig Rep.: Chds Page Casing Size: Set @ Location: Sec. 8 T. 9N R. 20E Meddian Test: Initial Weekly X Other 659-1201 Umiat Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign OK Dd. Rig OK Hazard Sec. Yes' FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 250/5000 P 1 250/5000 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve NA Test Press. P/F 300/3,500 P 1 250/6000 P 1 250/6000 P 1 250/6000 P 1 250/6000 P 2 250/6000 P 1 250~6000 NA P MUD SYSTEM: Visual Alarm Tdp Tank OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK - H2S Gas Detector OK OK . CHOKE MANIFOLD: No. Valves No. Flanges 40 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 17 250/5000 P 250/5000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8@2000 avg. 300 J P 1,400 ~ P minutes 30 sec. minutes 30 sec. X Remote: X Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 29 Repair or Replacement of Failed Equipment will be made within 0 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 retumed by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES × NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-O21 L (Rev. 12/94) a7rkkqfe ¼ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12019 Compan~ Alaska Oil & Gas Cons Corem Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 11/4/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape NOV 06 1998 $1~N DATE: ~ch0rage Please sign and retu~ne copy of this lransmiflal 1o Sher~e at the above address or fax to (907) 562-6521. Thank (~ALASKA~' eared rvices rilling BP Exploration / Arco Alaska Date: To: Attn: November 2, 1998 Alaska Oil & Gas Conservation Commission From: Subject: Kathy Campoamor, Technical Asst. B1-25 Sundry Application, Permit #98-153 Enclosed is an Application For Sundry for Badami well #B1-25. We are requesting to change approved program due to the following: 1. Directional- Ramp section is now being omitted in the latest directional. There is no future intention to lateral off of wellbore, hence the deletion of the ramp section. 2. Slotted Liner - The 4-1/2" slotted liner will be tied back all the way to the 7" intermediate casing with 150'. No "stubby". 3. Sidewall Cores - Were previously planned for surface hole. Will not be run. 4. Logging- Limited to MWD/GR/RES in 6" production hole section. If there are any questions, please contact Mike Cook at 564-5390. Thank you. STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION CO-MMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well []Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3857' NSL, 17' WEL, SEC. 8, T9N, R20E, UM At top of productive interval N/A At effective depth 4190 NSL, 1118' EWL, SEC. 9, TgN R20E, UM At total depth 59' SNL, 685' WEL, SEC. 9, T9N, R20E, UM (Planned) 5. Type of well: [~ Development ~ Exploratory ITM Stratigraphic I--Service 6. Datum Elevation (DF or KB) Plan KBE = 54.8' 7. Unit or Property Name Badami Unit 8. Well Number B1-25 9. Permit Number 98-153 10. APl Number 50-029-22906 11. Field and Pool Badami 12. Present well condition summary Total depth: measured 7240 feet true vertical 6757 feet Effective depth: measured 7240 feet true vertical 6757 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 64' 20" 4490' 9-5/8" Plugs (measured) Junk (measured) Cemented 260 sx Arctic Set (Approx.) 2408 sx PF 'E', 390 sx Class 'G' MD TVD 118' 118' 4524' 4522' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A ORIG 13. Attachments ~ Description summary of proposal I~1 Detailed operations program [~ BOP sketch 14. Estimated date for commencing operation November 5, 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of ;,/ell classifications as: ~ Oil _~ Gas ~ Suspended Service Contact Engineer NamelKumber: Michael Cook, 564-5390 Prepared By NamelNumben Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ( ' Mike E. M, er ~/~ .~'~ ~~------~ Title Badami Drillin9 Team Leader Date Commission Use Only Conditions of Ap. prove '., ,_.,,,.,,~J. Notify Commission so representative may witness , Approval Approvea ~"-'~'~ Plug integrity BOP Test __ Location clearance __ Returned -- · ~ ~.' "~,.,~ Mechanical Integrity Test __ Subsequent form required 10-/,~'/' V Commissioner Date id W J0hnsm", Approved by order of the Commission Da ' ; -": ' ' Form 10-403 Rev. 06/15/88 Submit In Triplicate OCT-19-9t HON 04'17 ph' $13ERRY-SUN RLRSK,q 190756:35754 P, 04/10 SHARED SERVICES DRILLING Well' B1-25 Wp9 0 -- 20O ~ 2400 -- 3600 -- 4800 -- 6000 '--~ 7200 -- 5400 -- 9600 -- ,.. ~,lart DIr ~P J.OO0~/lOOfl '. 300.00fl MD, 300.O01[TVD ,- End Dir: 700,00~ MD, 609.68fl -I'VD "- Slart DIr @ 1,000"/t00fl: 800.00k MO. 799.43R TVD .,. End Dir: 1200,00& MD, 1190,11rITVD 9 518" Casing - 4555.69 MD, 4554,80 TVD ,., Slar~ Dlr @ 4.000"/100fl: 5200.89[! MD. 5200.001l TVD .,. BHA Tendency @ 0,250¥100fl; 6600,89fl MD, 6387.51fl TVD 7000,00 7400.00 DrillQues; Current Well Properties Horizontal Cootdlnales: Reft Global Coordinates: RGI, Geographical Coorainales: RRR Elevation; RKB Calculalion: Nonh Relerence: Uil[ls: Cootdln~le Sy~lem: 5908424.70 N, 3~309fl,48 E 700 0g' 0g.0322' N, 147" 0fi'87,1OG4" W E4.B01t abav0 ~nn SO3 36.30 l{ Rig (ES ~') 19.50 It Wull (CEE) TnJa Noqh NAD2? Ab.~a $1alo Pln_~es, Zone 3, US Foe PLOT DATE: 9/28/98 Approved By: Proposal Target Summary Proposal D-',tn ~or BI-25 Wp0 Men~urod IncL Axlnl.V~nlcat Depth Oep~ I0~ I1! ................................. ~POO,GO 0600.00 · Top Mid flrvolda/t. 71J2, RO I'VP · TOp W~,~'l 3ttk - 7514.6'0 TVD 9400.00 .......................................................... MgO , $/,g,l.l~O 9800.00 . BHA Tendency ~, 1.000°/100f[: 10145,42ff MD, 8574,80f1'l'VD , .. ' ' ~'c/~'~' Wc~l ,Yak (M#$) ' ~i,174.~0 TVD · To/) Canni, g · 1~$74. A'O 7'VD .~m 10 197 9 ,,~,~. ................................................................................... 'I'I'O'~N - ................................ Shullt;wc.~f Bmlumi ,?nnrt · 9 I.f4./~0 TVD 114Oo.0DX s~8oo.oo~l~ , BI-IA ~endency ~ ~.112~/lOOfl: 12342.0BI~ MD, 10~lg.n. .................................................................................................. ~ ........ '." ............... F,r. 997J,8~ TVD ,' ..... , · ~ /'V i0/~ 6'0 '/'VD ........................................................................... · i i i'i ............ ,,.,',,,j ..... ~ '~ ..................... ~ i '. ~ ~ ]' ~ ~i ~'" ~ ~] ~ ......... i '~ ......~ .....~ i ~'"~ ~ ~ Z'b,',.?~4~'~/~'~)] ]' L.-~.T~]' ']" ~ .......... ~,~ ' ,~-,,~.~.. ~.r/4 .................................................. J ],~ ~/~,/0.'~J].,~/) ~'~,~,~,,~1/~ ..... ?~.~' ~,.,.L~ '' 0'' ' ' ' ' ' ' ' ' ~ ' 'dl.~ - JU*DI.3.~L/ ,~ V/,~p ~)l~. ' 1 ~D"I ~I '~ ~ 0 1200 2400 3600 4800 Scale: linch = 120Oft Vertical Section Section Azimuth: 73,499° (True North) Current We[! Properties B1-25 V,'ell: Hor~zo nlzl Coc rdin a:c-s: Eel. ECoI:;Z GocrairaleS: Re[. Geogral:h.~a~ ColOr,ares: RK0 I~e~a§(~: RI.~ Calcul=t ~q: No.'Ih REference: UrJts: C, cordinzle System: S.7,-,C. B42~.7o iq. 363~95.¢9 E 7~ C,,9' C8.CG22' N. ~.:r' 05' 37.[954' W S~.80fl aCove Mean Sca Level 35.30 P, R~g (~8~ N~27 ~ ~ ~ ~ne 3, ~ F~I r Well · B1-25 Wp9 [ l/rtll uest PLOTDATE: Checked By:..~/'(,// Approved By: Proposal Target Summary -~907~ ~ "0 N. L-~C:.567.40 Scale: linch = 600ft 1800 -- §00 -- 0 ~ Easfngs 0 600 1200 1800 2400 3000 3600 4200 4800 4 I~' Oner - 12498.7G M D_I ~54.~ ~D To~ De~h: 124~,7{Q MD. 1~,8~O~ BHATe~n~ 1.112"~: 3~2.~D, ' 7'Casing'10819'F2MD'~S4'80WD X ~_ "~/~ B~Te~e~/~ 0.250~21~: ~.~ff LiD, ~SZZth~ ~ ~Pc=~ ~~_.~~ / ~, ~d ~r: 7~.~ MD, ~9.~ ~D I I I I i I I [ I' 0 600 [ 200 1800 2~ ~ 3600 4200 ~00 Scale: linch = 600~ Ea~ings Reference is T~e No~h -- [800 200 -- 600 -0 g TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 16, 1998 Dave Cocking Drilling Superintendem BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 ae~ Badami Unit B 1-25 BP Exploration (Alaska) Inc. Permit No: 98-153 Sur Loc: 3857'NSL, 17"~VEL, Sec. 8, T9N, R20E, UM Btmhole Loc. 5 i'SNL. 598%VEL, Sec. 9, T9N. R20E. UM Dear Mr. Cocking: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your request for a diverter waiver is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given n the North Slope pager at 659-3607. ._ Chairman BY ORDER OF THE COMMISSION dlffEnclosures C¢~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA , ALASKA O ,,ND GAS CONSERVATION COMk SION PERMIT TO DRILL 20 AAC 25.005 REVISED 10/09/98 la. Type oi work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil ..... [] Re-Entry [] Deepen [-1 Service [] Development Gas [] Single Zone [] Multiple Zone .... ~2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP .Exploration (Alaska) Inc. Plan KBE = 54.8' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL365533 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3857' NSL, 17' WEL, SEC. 8, T9N, R20E, UM Badami Unit ....... At top of productive interval 81" Weil Number ~/~__.. Number 2S100302630-277 94' SNL, 743' WEL, SEC. 9, T9N, R20E, UM B1-25t~!~ At total depth 9. Approximate spud date Amount $200,000.00 51' SNL, 598' WEL, SEC. 9, T9N, R20E, UM 10/20/98 12. Distance to nearest proPerty line113. Distance to nearest well 14. Number of acres in property 15'. Proposed depth (MD and TVD) ADL367011,4682'I B1-16, 13.35' at 2570' MD 5120 12477' MD / 10454' TVD 16. To Be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 500' MD Maximum Hole Angle 56° Maximum surface 4400 psig, At total depth O-VD) 10094' / 6326 psig 18. Casing Program Specifications Setting Depth Size. Top Bottom Quantity of Cemen.! 'lZIole Casing Weight Grade 'Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.). 12-1/4" 9-5/8" 40# L-80 BTC 4521' 35' 35' 4556' 4555' :2755 sx PF 'E', 385 sx Class 'G' 8-1/2" 7" 29# Pl10 BTC-Mod 10428' 33' 33' 10655' 9055' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC 250' 12225' 10236' 12477' 10454' Llncemented slotted liner 119. 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 M D TVD Structural Conductor Surface Intermediate Production Diverter Waiver Reauested Liner Perforation depth: measured ~ ~3S bO~o. (~Olliffli$$Joi'~ true vertical Anchorage 20. Attachments [] Fil'i'ng Fee " [] PrOperty Plat //I~BOP Sketch [] Uiverter Sketch [] Drilling Program [] Drilling Fluid Program []Tirhe vg.C)eDth I~lot: [] I~efraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements '.. , ,Y': '%_..,-,l~ :~- ~ ~ . I ~ Prepared By Name/Number Carol W/the 564 4114 Contact Engineer Name/Number: Michael Cook,~'4-5390~V~,'~/.~ ~.~ I~'~,l.~.// : Y, - 21. I herebY certify that the forego~,f~s/true aCrect to the-~ -best of my knowledge / Signed Dave Cocking l/~ Title Drillin9 Superintendent f //,'7' /,¢ Date /Ljt~' / Commission Use Only / -- Permit Number ~'~/_ J APl Number I ApprovalDate__ See cover letter ~ ~-/~'~3 50- 4:~'.a:~'-- ~,~__~'42'~" /~'"/~,.---,~ for other requirements Conditions of Approval: Samples Required []Yes J~ No Mud Log Required [] Yes ,~_No Hydrogen Sulfide Measures []Yes 'J~ No Directional Survey Required J~Yes [] No Required Working Pressure for BOPE []2K; []3K; []4K; []5K; ~[~.IOK; [] 15K Other: Approved By C~--~"- ~~¢)~' -5"~z"-Cr"¢'~ .. by order of /(',) ,;.. ..... -,~.t qinn~d R',f Commissioner the commission Date ,.,..- ,.¢ Form 10-401 Rev. 12-01-85 0avid W, Johnston Submit In Triplicate STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COb~lSSlON PERMIT TO DRILL 20 AAC 25.005 REVISED 10/09/98 l'a. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory ['-I Stratigraphic Test [~ Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone I--I Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska)Inc. Plan KBE = 54.8' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL365533 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3857' NSL, 17' WEL, SEC. 8, TDN, R20E, UM Badami Unit At top of productive interval 8. Well Number ~/~.. Number 2S100302630-277 94' SNL, 743' WEL, SEC. 9, TDN, R20E, UM B1-2,5,L~ At total depth i9. Approximate spud date Amount $200,000.00 51' SNL, 598' WEL, SEC. 9, TDN, R20E, UM 10/20/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL367011,4682'I B1-16, 13.35' at 2570' MD 5120 12477' MD / 10454' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' MD Maximum Hole Angle 56° Maximum surface 4400 psig, At total depth (TVD) 10094' / 6326 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD 'I-VD (include stage data) 24" 20" 91.1# H-40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4521' 35' 35' 4556' 4555' 2755 sx PF 'E', 385 sx Class 'G' 8-1/2" 7" 29# Pl10 BTC-Mod 10428' 33' 33' 10655' 9055' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC 250' 12225' 10236' 12477' 10454' Uncemented slotted liner 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 Intermediate Production Diverter Waiver Reouested ~ ~'~'~. t V E D. Liner Perforation depth: measured AJ~k~0ii & 6asC0.s. C0Bai si..0 true vertical 20. Attachments [] Filing Fee [] Pr~)perty Plat /~BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Tir~et~._ ..u~ v¢~. el~ I~lgtl [] ~efraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements 21.C°ntactEngineerName/Number'l hereby certify that the'froMiChae/C°°ko g(:¢~ S C°°k's~true atr,-S39°~J~l[~/{/~!e aCrrect to t~~! mC~knowled e '¢' Y g PreparedByName/Number:/' CarolWithey, 564-4114 Signed ,~ / ),~¢~ .. , Oj~3 Dave Cocking t(~ Title Drilling Superintendent ! ~/' 7 /'~ Date ,,¢,- / Commission Use Only Permit Number 4¢¢'~' APl Number Approval Date I See cover letter ~ ~-/-~'3 50- '=:~------~-- ~-' 2-~4:~~' /~-'/~¢,4;;~)~ for other requirements Conditions of Approval: Samples Required []Yes J~"No Mud Log Required []Yes Hydrogen Sulfide Measures []Yes i~]'No Directional Survey Required '~Yes I--INo Required Working Pressure for DOPE 1'-12K; I-'I3K; []4K; []5K; ~,10K; [] 15K Other: ~-~ ~;~/P~Jd ~'(-'-' by order of Approved By r Q tS~' Commissioner the commission Date Form 10-401 Rev. 12-01-85 L)8.VJQ W. dulu~ Submit In Triplicate $ ~ALA~KA~, L,~ BP Exploration / Arco Alaska Date: October 9, 1998 To: Attn: From: Alaska Oil & Gas Conservation Commission Mr. Jack Hartz CaroJ Withey ~ j~~ Technical As~is~lt~t III Shared Servic'e~s Drilling Jack: Per our phone discussion on Monday, October 5, I have attached the revised permit for B1-25L2. The following is a recap of our conversation. B1-25, B1-25L1, and B1-25L2 originally permitted and approved by AOGCC is no longer a multi-lateral well. We plan a single penetration utilizing the B1-25L2 surface, productive interval and bottom hole location coordinates. Drilling operations have been modified accordingly and are attached. We anticipate no changes in the drilling fluid program. We have not begun drilling operations and plan to move to the site within the next 7 days. Additionally, you asked I make the followin,~<equest: , Cancel Permits ~ and B1-25L1 ~uaSS[~Ft *~'"'- DI'~ ADI H~inn~fir,~, tO n~ o~ LI I~ ~, , --~.~ .... lVl i ~ I --~E~ ~ Changc the we!! namer--S2 to B1~ Please contact Michael Cook, the operational drilling engineer at 564-5390 or myself at 564-4114 if you have further questions. Cc: B1-25 Well File REC[iVED Attachments -Revised Permit -Operations Summary -Revised Directional -Well Plan Summary Alaska 0ii & Gas Cons. C0mmissiol~ Anchorage Shared Services Drilling Contact: Mike Cook 564-5390 J Well Name: J B1-25 J Well Plan Summary I Type of Well (producer or injector): Producer- Open hole I Surface Location: 3857' FSL 17' FEL SEC 8, T9N, R20E, UM, AK AFE Number: J880460 J IKBE: 154.8I ,~. }AMSL J J IRig: Nabors 28E I Estimated Start Date: I Oct. 20 1998 I Operating days to complete: I 45 I Well Design: Ultra slimhole- multi-lateral open hole completion w/slotted liner Formation Tops MD TVD (bkb) Remarks base permafrost 2005 2004 Top Middle Brookian (TMBK) 7619 7132 M90 9228 8184 Base West Sak (M85) 9655 8474 Casing/Tubing Program: Hole ~ize Csg'/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD brt 24" 20" 91.1 # H-40 Weld 80 37/37 116/116 12-1/4" 9-5/8" 40# L-80 BTC 4521 35/35 4556/4555 8-1/2" 7" 29# P110 BTC- 10621 33/33 10654/9054 mod IInternal yield pressure of the 7" 29#/ft P110 casing is 11220 psi, which is greater than the maximum anticipated surface pressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/ft, surfac~-~-~~ 0.36 psi/ft, 6570 to 10094' tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. Logging Program: I.open Hole Logs: Surface Intermediate Production Sidewall cores · 30ea. planned ( 2500' md - 4500'md) MWD/GR @ hole section TD MWD/GR/RES HDIL/ZDL/MAC Mud Program: I Special design considerations displace OH to 5% KCL water based muds Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 150 25 20 45 9 10 to to to to to to to 9.8 - 10.0 300 60 30 60 9.5 15 Intermediate Mud Properties: I KCL polymer .... Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to 10.1 55 20 10 25 9.5 4-6 Production Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 12.0 45 10 8 15 8.5 4-5 to to to to to to to 12.4 55 15 10 20 9.5 4-5 Well Control (Secondary): Diverter Waiver Requested Well control equipment consisting of 10,000 psi W.P.(2) pipe rams, (1) blind rams, and 5M WP annular preventer will be installed and is capable of handling maximum potential surface pressures.10 M WP Choke & kill manifold. BOPE and drilling fluid system schematics on file. Waste Manaqement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Annular Injection: No annular injection is planned at this time. DRILLING HAZARDS AND RISKS: Wellbore proximity comments are addressed under each MLOH section. Junk (auger tooth) was encountered in the B1-16 conductor - if junk is encountered, ensure all junk is fished prior to commencing drilling. Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Badami sands are overpressured - normally 12.2ppg mw required at TD. Pressure transition begins just above shallowest sand. Shallow sands typically pressured between normal and the 12.2 ppg required in lower sands. Maintain minimum mud weight and utilize latest techniques to manage lost circulation hazards in shallow sands (flow rates, tapered drill string). Weight up as wellbore pressures dictate, maintaining a 200 psi overbalance throughout. Hazards of well control and stuck pipe are managed by setting 7" casing above shallowest sand, before penetrating the full overpressure. Hazard of lost circulation is managed by proper techniques to maintain Iow ECD - ECD of 13.5 ppg noted to be maximum allowable to prevent lost circulation. Badami Sand F5 Primary tar~let Bottom Hole Location (TD) B1-25 lTD TVDBRT: 110454 I94'FNL 743' EEL SEC 9, T9N, R20E, UM, AK 51' FNL 598' EEL SEC 9, T9N, R20E, UM AK Formation Markers: Formation Tops MD TVD (bkb) Remarks Shallowest Badami Sand 10787 9154 Badami Sand F3 11913 9973 Badami Sand F4 12068 10102 Badami Sand F5 12225 10236 Primary Sand Badami Sand A5 12315 10313 Total Depth 12477 10454 Casing/Tubing Program: Hole ~ize Cs'g/ Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MD/TVD MD/TVD brt 6" 4-1/2" 12.6# L-80 BTC 250 12225/10236 12477/10454 slotted liner NOTE' slotted liner will only be installed if sufficient amalgamated pay exists as determined by logs and petrophysicist. Length of slotted liner will be adjusted to cover an interval from TD to above top of amalgamated pay. If insufficient amalgamated continuous pay exists to warrant the slotted liner, none will be run. Logging Program' Production Hole RFT Cased Hole Logs: MWD GR/Resistivity only none none Directional: KOP: 1 5200' md/tvd Maximum Hole Angle' 56 deg. @ 10983' md thru 11043' md (ramp section) Close Approach Well: B1-16 @ 2570' md (13.30' close approach). B1-16 shut-in. 15. 16. Badami B1-25 Proposed Summary of Operations 1. Weld the starting head on the conductor. 2. Prepare the location for the rig move. 3. MIRU Nabors 28E drilling rig. Build spud mud. A diverter waiver is requested from AOGCC. 4. PU 12-1/4" bha & drill surface hole as per directional plan. Run directional MWD from surface to TD. 5. Run 9-5/8" surface casing and cement to surface in two stages. 6. NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi. 7. RIH with BHA, test casing to 3000 psi. Drill out float equipment and 20' of new formation. Perform a LOT as per SSD Standard Operating Procedure. Contact the Badarni Drilling Team Leader or SSD Superintendent with LOT test results before drilling ahead. 8. Drill 8-1/2" hole to intermediate casing TD as per directional plan, with MWD directional surveys. 9. Run 7" casing and cement as per Cement Procedure (1000' md of cement above shoe). Test BOPE to 6000 psi. 10. RIH w/6" BHA, test 7" 29# P110 csg. to 3500 psi. Drill out float equipment and 20' of new formation. Perform FIT to 13.5 ppg minimum equivalent. 11. Drill 6" hole to targeted BHL as per directional plan with GR/4 phase resistivity MWD. Utilize latest techniques for reducing lost circulation risk (tapered string, flow rate limitations, ECD limits, mud rheology, etc.). 12. Displace open hole to above top of upper most Badami sand with high viscosity/low fluid loss pill - POOH. Run open hole logging surveys. 13. Run 4-1/2" slotted liner from TD to just above the top of the amalgamated pay (exact depths to be determined from logs). Set liner on bottom, release from liner with HES hydraulic setting tool. 14. RIH with 4-1/2" completion assembly open ended. M/U connect 2 ea. %" control lines ( 316 SS Wall thk: 0.049") to WLRSV landing nipple. Line up trip tank to bell nipple. Circulate across the well with returns back to the trip tank while the completion is being run in the hole. Pitwatcher will monitor the fluid level in trip tank as the completion is run in the hole. RIH - position permanent packer to setting depth. Record pick up and slack off weights. M/U control lines to FMC 4-1/16" 10 M tubing hanger. Test control lines to 5000 psi - hold pressure for 10 mins. Land FMC 4-1/16" 10 M tubing hanger and RII.DS (14 ea.) to energize FMC tubing hanger packoff assembly. Test packoff assembly. Set & test two way check. N/D 13-5/8" 10000 WP BOPE. N/U 1 i"-10M x 4 1/16"10M Adaptor & Tree tested to 7000 psi. Pull two way check valve. 17. R/U slickline. N/U 5k psi pump-in sub + BOP's. PU dummy valve pulling tools & ball/rod in lubricator tested to 3k psi on top of swab valve(s). Bleed lubricator off to 1,820 psi. 18. R/U pump truck & manifold per attached schematic. Displace freshwater down 4-1/2" tubing (180 bbls). Maximum rate 2 bbls/min. Slow pump rate to V2 BPM & open swab valve(s) to drop ball & rod. Close swab valve & bleed/drain lubricator. 23. 24. 25. 19. Set Baker S-3 permanent production packer with 5600 psi. tubing surface pressure. After packer setting sequence is complete, maintain pressure at 5600 psi.for 30 minutes and record as tubing test. Note: Baker S-3 packer will require 3500 psi differential pressure to complete its mechanical setting sequence. Total surface estimated pressure requirement will be 3500 + 2100 = 5600 psi. 20. Test 7"x 4-1/2" to 3500 psi for 30 minutes. Reduce tubing pressure from 5600 psi to 4500 psi on 4-1/2" tubing for 7"x 4-1/2" annulus test. Record on Barton Recorder. Maintain 7" x 4-1/2" annulus pressure at 3500 psi. Bleed 4-1/2" tubing from 4500 psi to 2500 psi to create 2900 psi differential pressure from annulus to tubing to shear of SDCK valve. Note: (1) Upon SDCK shear, limit amount of 12.3 #/gal drilling fluid "U" tube to tubing side to prevent barite settling on RHC plug. (2) Tubing pressure should be maintained greater than 1800 psi to ensure ball & rod assembly stays on seat. 21. Pump down 4-1/2" 12.6# L80 tubing and up the 4-1/2" x 7" annulus with freshwater w/25 gals/100bbls of 7726 Corexit corrosion inhibitor. Maximum rate through SDCK valve is 3 bbls/min. Circulate 4-1/2" x 7 until clean. Add dirt magnet as needed. Freeze protect 4-1/2" tubing & 4-1/2" x 7" annulus. 22. Equalize lubricator with tubing & TIH to pull dun-uny ball valve from SVLN. POH, SI swab valve & bleed-off lubricator to recover ball valve. Pull SDCK valve from lower GLM & replace with dummy valve. Pull ball & rod assembly. Pull RHC sub. Install SSSV "BBE" in SVLN. Close "BBE" SSSV. Test "BBE" SSSV by closing valve and bleeding 4-1/2" 12.6# tubing pressure to "0" psi. Monitor tubing for 30 minutes to ensure "BBE" SSSV pressure seal integrity. R/D wireline. Secure well. RD/MO Nabors 28E rig, release rig. Transfer well custody to Badami Operations Install two-way check valve in FMC 4-1/16" 10M hanger profile. N/D 4-1/16" 10M Cameron Adaptor & 10M Xtree. N/U 11" 10 M x 4-1/16" 5M Cameron Adaptor & 5M Xtree. Test Xtree to 5000 psi. Retrieve two-way check valve & replace with BPV. Secure well. RD/MO Nabors 28E rig, release rig. Transfer well custody to Badami Operations Badami B1-25 CASING SIZE: 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON SPACER: 100 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 255 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from 1000' above the casing shoe to the ES cementer at 2200' md, plus 30% excess. Premium 2% calcium chloride 15.8 ppg YIELD:l.15 ft3/sx MIX WATER: 5.0 gal/sk 385 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of fill in the gauge hole plus 30% excess plus 80' shoe joint. SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 2500 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX NO SACKS: To be determined on job x job basis MIX WATER: 11.63 gal/sk INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 7" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 185 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. MULTI-LATERAL WELL ABANDONMENT PROGRAM The following program is to be used at such time as the wellbores below the 7" intermediate casing are to be abandoned. 1. MIRU Rig. 2. Kill Well. 3. Pull tubing, packer, completion. 4. RIH with 7" EZSV cement retainer and set 50-100' inside the 7" intermediate casing and above all perforations in the 7", if any exist. 5. Mix and pump a volume of premium class G cement to fill the 7" casing below the EZSV and the calculated volume to fill the entire hole section of all wellbores below the 7" shoe, plus 10%. 6. Unsting from EZSV. 7. Pressure test the EZSV and cement to 3000 psi. 8. Procedures for the remainder of the wellbore above the EZSV will depend on the future plans for the wellbore (total abandonment, sidetrack, etc.). 00T-07-98 WED 04:45 PIX ?CRRY-$UN ALASKA FAX NO, 19075635754 P, 02 ., · ~r~/-surl SHARED SERVICES DRILLING DrillQ uest" .,.. S~sH DIr O 1.0~°/10~: 300.00~ MD, 800,00h ~O Well: BI-25 40~.~0 Horlzon~l ~ordl~lea: · End DIt ~ 700.~ MD,6gg.68~D R~I. GI~ Co~d~nalas: 5~424.70 N, a63995.48 E ~ ~K8 El~valbn: ~4.8011 above Mean ~a Lovol .... End D~: 1200.00R MD, 1199.~ IR ~DJS ~ RKB Cal~tion: 3S.30 1400 ' No,Ih Ra~erence: Tree 1600,00 ' Uni1~; F~Ct Ceordinale S~[am ~ NAD27 A~a SI~Io Plon0n, Zon~ 3, US Fool ~.~ ......... PLOT DA~: 9~9B ~oo,oo *, ,?.~.~ ............ 2800 -- 2800,00 ' Sail ~ O.000' Inclinallon on 358.971 ~ ~mu~h rroposm marget oumma[~ .............. ' 3200.00 ~ Civic (2~) 3~00.~ -~.,, P~opo;;I ~1; 1o~ B1.2S Wp6 ~ 4~0,00 4200 ~ 44oo,~ ~ L 9 5/8" Ca,lng. 4555,69 MD, 4554.80 TVD ~o~,o,m~. o~o,~,~00~ ................... m ~ ~ Sttt~ Dif ~ 4.0~"/1001t: 5200.891i MD, 52~.O~t~D ~ " o,~ ' ~'~. ........ 3% ..... ~uu vv ~ ~ · r . , O ~ 3~71 . ~.~ 0~ 6400.~ ... ~HATcnduncy O 0.250/l~f[ :6550.agItMD, 63SG.SAII~D { ..................... ~ ........... Trip Mid Rrn~i:m- ?132.A0 TVD 8000,00 ~ ~ e2oo.oo ~ . .................... ~-- -- ~0- 8J84.80 TVD 96~ ~ ~ ~nn -- 96~.~ ~ ~AT~ncy ~ 1.~/t~fl; ggOg.05~ MD 8574.8~t ~ ~o4~.~ 7" Casing - 10654.63 MD, 9054.80 I i I 0 14~ 2~00 Scale: 1 Inch = lao0~ Vertical Section Section Azimulh: 73.484' ~me Nor~) 7" Casino- 10654.~q MD, 9054.80 TVD . End ~1r:'I0654.6~ MD 9054,8011~ VD 10~00.0,~ ~'.,, SlaA Dire G,000~/100I[; 10714,63h MD, 91~,~[1~D ~ . Eno uir; 3o~ua./zlt MD, 9280,581(~ ' ' 39oo.oo ~. 81aA Dir ~ 6.0~"/10~1: 11040,72[t MD, 93~4.13ft~0 ~ ~o0.0o ~.... BHA T~de~ ~ f.112~/100/t: 11310.3~ MD. ~91.~[ ~D 9600 - ~ ~sOO.O0~ ' ~ ~sao.o~ ~ 10400 - Cl~~..,~ ~ ~." Tolal Depth; 12477.10[I MO, 10454,80{i ~D ]~.uJ.,~'u ~'v/~ 4 1/2" Liar - 12477.10 MD, 10454.80 ~D I- - - I I 3Bo~ 4400 5200 9cale'. l ln~h = a00R Vedical Section se~a~n Azimulh; '/3,484' ~me No~) ,.. X Scale: I fnch = lOOft -100 I Eastings SHARED SERVICES DRILLING Well' B1-25 Wp8 O' 109 200 [_ I I I I I -100 0 lO0 2O0 Scale: linch = lli~ft Easfings 3O0 4O0 30O 4O( Refezence Is True North -0 Current Well Properties B1-25 PLOT DATE 5906424,70 N, 3~a3995.48 E 71~ O~ 08.0~322.' t~l, x47~ ~' 37. t954' W 54.601[ ~x~ve Mean Sea Level ~.3~ R~ (ESh ~.5o ~t We~ (C~E-J NAD27 AJas~ State Pl~es. Zme3, US Fo~. I Proposal Target Summary i ~1-~ T~I- I~ 1~3~ i~.~ R ~.~ E ~N. ~.~E S~ale: linch = 500 lO(X) 150~ 2000 · t I I .......... '8HATend, ency ~ O.2.~0:J[(X~,: 65SO.69~ MD, 6358JGf; TVD I I I 50O [O00 150O 2OO0 Scale: linch = 5001t Eastings 2500 ,3000 35~3 ,I ,t I I 25CX) Eastings Circle (200'Rta~'u7) JO31 J.&~72'1/D 4 412' LJner - 12477o10 MD, 10454.80 'I'VD TelaJ Del~: I2477,101tMD, 104~.~t TVD ...... BI-LA Ten<lency ~ 1.000~II(X3fl: 9999.05tt hiD, 857'4.80ft TVD i I I 3500 40~3 4500 5000 Re~erence Is True North Sperry-Sun Drilling Services Proposal Report for B1-25 Wp8 x Badami Measured Depth Incl. Az[m, Su~Sea Depth (~) Vertical Local Coordinates Depth Northings Easfings (ft) (ft) (ft) 0.00 0.000 0.000 -54.80 0.00 300.00 0.000 0,000 245.21) 300.00 400.00 t.O00 8.000 345.19 399.99 500.00 2.000 8.000 445.16 499.96 600.00 3.000 8.000 545,06 599.86 700.00 4.000 8.000 644.88 699.68 800.00 4.000 8.000 744.63 799.43 900.00 3.000 8.000 844.44 899-24 1000.00 2.000 8.000 944.35 99 9.15 1100.00 $.000 8.000 1044.31 1099.11 1200.00 0.000 0.000 1144.31 1199.11 2000.00 0.000 0.000 1944,31 1999.11 2005.69 0.000 0.000 1950.00 2004.80 2877.85 0.000 0.000 2822.15 2876.95 3000.00 0.000 0.000 2944.31 2999.11 4000.00 0.000 0.000 3944.31 3999.11 4555.69 0.000 0.000 4500.00 4554.80 5000.00 0.000 0.000 4944.31 4999.t 1 5200.89 0.000 0.000 5145.20 5200.00 5300.00 3.964 77.900 5244.23 5299.03 5400.00 7.964 77.900 ,5,343.67 5398.47 5500.00 ! 1.964 77.900 5442,14 5496.94 5600.00 15.964 77.900 5,539.16 5593.96 5700.00 19.964 77.900 5634.27 5689.07 5800.00 23.964 77.90a 5726.99 5781.79 5900.00 27.964 77.900 5,816.88 5871.68 6000.00 31.964 77.900 5903.50 5958.30 6100.00 35.964 77.900 5986.42 6041.22 6200.00 39.964 77.900 6,065,24 6120.04 6300.00 4,3.96,4 77.900 6139.58 6194.38 0.00 N 0.(]0 E 0.00 N 0.{30 E 0.86 N 0_12 E 3.46 N 0,49 E 7.78 N 1.09 E 13.82 N 1.94 E 20.73 N 2.91 E 26.77 N 3.76 E 31.09 N 4.37 E 33.69 N 4.73 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 35.27 N 8.21 E 37.45 N 18.36 E 41.07 N 35.28 E 46.13 N 5&87 E 52.59 N 89.02 E 60.43 N 125.59 E 69.61 N 168.39 E 80.08 N 217.2.1 E 91.78 N 271.83 E 104.68 N 331.97 E 118.69 N 397.33 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (.) (°/leo.) (ft) 5906424.70 N 363995.48 E 0.00 5906424.70 N 363995.48 E 0.000 0.00 59064,25.56 N 363995.62 E 1.000 0.36 5906428.15 N 363996.03 E 1.000 1.45 5908432.4,5 N 363996.71 E 1.000 3,26 5906438.48 Iq 363997.67 E 1.000 5.79 5906445.37 N 363998.76 E 0.000 8.69 5906451,40 N 363999.72 E 1.000 11.22 5906455.71 N 364000.41 E 1.000 13,03 5906458.30 N 364000.82 E 1.000 14.12 5906459.16 N 364~000.96 E 1.000 14,4~ 590645,9,16 N 364(i00.96 E 0.000 14.4~ 5906459.16 N 364000.96 E 0.000 14.4~ 5906459.16 N 364000.96 E 0.000 14.48 5906459.16 N 364000.96 E 0.000 14.4~ 5906459.16 N 364000.96 E 0.000 14.45 5906459.16 N 364000.96 E 0.000 14.48 5906459.16 N 364000.96 E 0.000 14.45 5906459.16 N 364000.96 E 0.000 14.45 5906459.82 N 364004.32 E 4.000 17.69 5906461.81 N 364014.51 E 4.000 28.25 5906465.13 N 364031.49 E 4.000 45.50 5906469.77 N 364055.17 E 4.000 69.56 5906475.69 N 364085.43 E 4.000 100.30 5906.482.87 N 364122.13 E 4.000 137.58 5906491 ,:27 N 364165.09 E 4.000 181.23 590650.0.86 N 364214.10 E 4.000 231.01 5906511.59 N 364268.9! E 4.000 286.70 5906523.40 N 364329.27 E 4.000 34,8.03 59065.36.24 N 364394.88 E 4.000 414.68 Alaska State Plane Zone 3 Badami CPF Comment Start Dir @ 1 .(]0i]°/100fl ' 300.O0[t MD, 300.OOR TVD End Dir' 700.OOgt MD, 699.68fl TVD Start D]r @ 1.000°/100ft · 800.OOfl MD, 799.4311 TVD Ertd DIr: 1200.OOtt MD, 1199.1 lft 'I-VD Base Permafrost Sail @ 0.000° Inc]inat~oa on 358.971" Azimulh 9 ~8' C~sin[7 Stad D]r i~ 4.C4}0°/100[t · 5200.89ft MD, 5200.0Oft ']'VD Conlinued.. . 7 October, 1998 - 1¢:5E -1- DriEQuest Sperry-Sun Drilling Services Proposal Report for B 1-25 Wp8 x Badami Measured Depth (fi) Incl. Azim, Sub-Sea Depth Vertical Depth (.) 6400.00 47.964 77.900 6209.08 6263.88 6500,00 57.964 77.900 6273.39 6328.19 6550.89 54.000 77.900 6304.03 6358.83 6600.00 53,885 77.848 6332.94 6387.74 6700.~0 53.650 77.742 6392,04 6446.84 6800.00 53.415 77.635 6451.48 6506.26 6900.00 53.180 77.527 6511.24 6566,04 7000.00 52,946 77.419 6573.34 6626,14 7100.00 52.711 77,310 6631,76 6686,56 7200.00 52.477 77,200 6692,50 6747.30 7300.00 52,243 77.090 6753,57 6808.37 7400.00 52.009 76.979 6814,97 6869.77 7500.00 51.775 76.867 6876.68 6931.48 7600.00 51.54 i 76.755 6938.72 6993.52 7700.00 51.307 76.642 7001.07 7055.87 7800.00 55.073 76.528 7063.75 7118.55 7822.67 51.020 76.502 7078.00 7132.80 7900,00 50.840 76.413 7126.74 71,83.54 8O{10, 04) 50.606 76.298 7190.04 7244.84 81C0.00 50.373 76.181 7253.67 7308.47 8200.00 50.140 76.064 7317.60 7372.40 5300.00 49.906 75,947 7381.85 7436.65 8400.00 49.673 75.626 7446,41 7501.21 8500.00 49.441 75.706 7511,28 7566,08 8600.00 49.208 75.588 7576.46 7631.26 8700.00 48.975 75.467 7641,94 769 6.74 8800.00 48.743 75.345 7707.73 7762.53 8900.00 48.510 75.222 7773.8,3 782.6.63 9000.00 48.278 75.099 78,40.2:3 7895.03 9 ~ 00.00 48.04-6 74.974 7906.93 7961.73 Local Coordinates Northings Eastings (ft) (fi) 133.76 N 467.61 E 149.80 N 542,46 E 158.32 N 582,19 E 166.66 N 621.01 E 183.71 N 699.84 E 200.86 N 778.41 E 218.10 N 856.71 E 235.44 N 934.74 E 252,87 N 1012.49 E 270.39 N 1089.97 E 288,01 N 1167.17 E 305.72 N 1244.10 E 323,52 N 1320.74 E :341.42 N 1397A0 E 359.41 N 1473.48 E 377.49 N 1548.98 E 381.60 N 1566.13 E 395.66 N 1624.49 E 413.92 N 1699.72 E 432.27 N 1774.65 E 450.71 N 1849.30 E 469.24 N 1923.66 E 487.86 N 1997,72 E 506.57 N 2071.49 E 525.37 N 2144.96 E 544.26 N 2218.14 E 563,23 N 2291.02 E 582.30 N 2363.60 E 601.4.5 N 2435.88 E 620.68 N 2507.85 E Global Coordinates Dogleg Vertical Northings Easfings Rale Section (ft) fit) (°/~O0.) (it) 5906550.04 N 364465,42 E 4.000 486.34 5906564.74 Iq 364549.54 E 4.000 5 62.67 5906572.54 N 364580,42 E 4.000 603.18 59'06580.18 N 364619.38 E 0.250 6,42.76 5906595.82 N 364698.51. E 0.250 723.20 59066'~ 1.55 N 36477'7.37 E 0,250 803.40 5906627.39 N 364855.97 E 0.250 883.37 5906643.32 N 364934.30 E 0,250 963.10 5906659.35 N 365012.35 E 0.250 1042.60 5906675.48 N 365090.'[3 E 0,250 112'[.87 5906691.71 N 365167.64 E 0,250 1200.89 5906708,04 N 365244.87 E 0,250 1279.68 5906724.46 N 36532~.82 E 0.250 1358.22 5906740.98 N 365398.49 E 0.250 1436.52 5906757.60 N 365474.88 E 0.250 t514.57 5906774.32 N 365550.99 E 0.250 1592,38 5906776.12 N 365568.21 E 0.250 1609.99 5906791.13 N 365626.81 E 0.250 1669.94 5906808.03 N 365702.35 E 0.250 1747.26 5906625.04 N 365777.61 e 0.250 1824,32 5906842.14 N 365852,57 E 0.250 1901.13 5906859.33 N 365927.25 E 0.250 1977.68 5906876.62 N 366001.64 E 0.250 2053.98 5906894.00 N 366075.73 E 0.250 2130.03 59'069fl.48 N 366349.53 E 0.250 2_205.82 5906929.05 N 366223.03 E 0.250 2_281.34 5906946.71 N 366296,24 E 0,250 2356.61 5906964.4.7 N 366369.15 E 0.250 2431.61 5906982.32 N 3664~ 1,76 E 0.250 2506.36 5907000,26 N 366514.07 E 0.250 2550.83 Alaska State Plane Zone 3 Badami CPF Comment BHA Tendency @ 0.250"1100ft: 6550.89ft MD, 6358.83ft 'rvI) Top Mid Bfook[~ Ccntinued.,. 7October, 7998 - 14:56 -2- DriflQuest Sperry-Sun Drilling Services Proposal Report for B1-25 Wp8 x Badami Measured Depth incl. Azlrrl, Sub-Sea Depth (it) Vertical Local Coordinates Depth Northlngs Eastings (it) (ft) 9200.00 47.814 74. 848 7973.94 8028.74 9300.00 47.582 74.722 8041,24 8096.04 9400.00 47.350 74.595 8108.84 8163.64 9431.21 47.278 74.555 8130.00 8184.80 9500.00 47.119 74.466 8176.74 8231.54 9600,00 45.8~7 74.337 8244.94 8299.74 9700.00 46,656 74.207 8313,43 8368,23 9800.00 46.425 74.075 8352.24 8437,01 9854.75 46.298 74.003 8420.00 8474.80 9900.00 46. f94 73.943 8451.29 8506,09 9999.05 45.965 73.811 8,520.00 8574,~0 10000.00 45.956 73.8C~; 8520.66 8575.46 40100.00 45.018 73.3Z3 8590.76 8645.56 10200.00 44.081 72.823 8662.03 8716.83 10300.00 43.147 72.306 8734.43 8789.23 10400.00 42.215 71.771 8807.94 8862.74 10500.00 41.286 71.217 8882.55 8937.35 10600.00 40.359 70.641 8958.22 9013.02 10~o54.63 39,8,54 70.318 9000.00 9054.80 10714.63 39.854 70.316 9046.06 9100,86 10787.27 44.2.13 70.318 9100.00 9154.80 10800.00 44.977 70,318 9109.07 9163,67 10900.00 50.977 70.318 9175.98 9230,78, 10983.72 56.000 70,318 9225.78 9280,58 11000.00 56.000 70,318 9234.88 9289.66 640.01 N 2579.53 E 659.42 N 2650.90 E 678.91 N 2721.96 E 685.01 N 2744.07 E 698.49 N 2792.71 E 718.16 N 2863.16 E 737,91 N 2933.29 E_ 757.75 N 3003.12 E 768.64 N 3041.21 E 777.67 N 3072.63 E 797,48 N 3141,17 E 797.67 N 3141.82 E 817.84 N 3210.22. E 838.27 N 3277.33 E 858.93 IN 3..343.14 E &79.83 N 3407.63 E 900.97 N 3470.77 E 922.32 N 3532.56 E 934.08 N 3565.72 E 947.03 N 3601.93 E 963,41 N 3647.71 E 966.42 N 3656.13 E 991,43 N 3726.04 F__ 1014.08 N 3789.38 E 1018.63 N 3802.09 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (ft) (°/100~t) (ft) 5907018.29 N 3665R6.08 E 0.250 2655.04 5907036.4:2 N 366657,79 E 0.250 2728.98 5907054.63 N 366729.19 E 0.250 2802.65 5907060.34 N 366751.41 E 0.250 2825.59 5907072.94 N 366800.28 E 0.250 2876.06 5907091.34 N 366871.07 E 0.250 2949.19 5907109.83 N 366941.55 E 0.250 3022.04 5907128.41 N 367011.72 E 0.250 3094.62 5907138.62 N 367050.00 E 0.250 3134.25 5907147.08 N 36708%57 E 0.250 3166.93 5907165.66 N 367150,46 E 0.250 3238,28 5907165.83 N 367151.12 E 1.000 3238.96 5907184.78 N 367219.86 E 1.000 3310.26 5907203.99 N 367287.33 E 1.000 3380.41 5907223.47 N 367353.50 E 1.000 3449.38 5907243.21 N 367418.35 E 1.000 3517.15 5907263.2_1 N 367481.87 E 1.000 3583.70 5907283.45 N 367544.02 E 1.000 3649.00 5907294,61 N 367577.40 E 1.000 3684.15 5907306.91 N 3676~3.83 E 0.000 3722.54 5907322.46 N 367659.90 E 6.000 3771.09 5907325.32 N 367668.37 E 6.000 3780.02 5907349.07 N 367738.72 E 6.000 3854.16 5907370.59 N 367802.46 E 6.000 3921.32 5907374.90 N 367815.24 E 0.000 3934.80 Alaska State Plane Zone 3 Badami CPF Comment Mgo Base West Sak [M85) TBHA..Tend. ency @ 1.000"/100ft: 9999.05tt MD, 8574.80fl TVD op ~anrung End Dir ' 10654.63~t MD, 9054_80ft -['VD 7' Casing Start Dir @ 6.000~'/100rt· 10714.63ft MD, g100.86~t-I-VD Shallowest Badam[ Sand End Dir: 109B3.72f[ MD, 9280.58~t TVD Con h'nued... 7 October, 1~38- ~4:55 ? -3- DrJttQuest Sperry-Sun Drilling Services Proposal Report for B 1-25 Wp8 d x Badami Measured Sub-Sea Vertical Deplh Incl. Azim. Depth Depth (ft) (ft) (fi) Local Coordinates Northir~gs Eastings (ft) 11043.72 56.000 70.318 9259,33 9314,13 1030.84 N 11100.00 52,623 70.318 9292.16 9346.96 1046,23 N 11200.00 46,623 70.318 9355,91 94.11.71 1071,88 N 11300.00 40.623 70.318 9429,26 9484.06 1095.10 N 11310.39 40,000 70.318 9437.19 9491,99 1097.37 N 11400.00 39.099 69.648 9506.28 9561.08 1116.90 N 11500.00 38.098 68.870 9584.43 9639.23 113 8.98 N 11600.00 37.103 68.056 9653.66 9718.46 1161.38 N 11700.00 36.114 67.205 9743.93 9798.73 1184.07 N 11800.00 35. I3! 66.312 9825.22 9880.02 1207.05 N 1 ig00.O0 34.154 65.374 9907.49 9962.29 1230.30 N 11913.89 34.019 65,240 9919.00 9973.80 1233.56 N 12000.00 33.185 64,389 9990.72 10045.52 1253.83 N 12068.19 32,529 63.687 10048.00 t0102.80 1270.02 N 121(]0.00 32,225 63.351 ~0074.86 10129.66 1277.62 N 122(]O.00 31.273 62.257 10159.90 10214.70 1301,66 N 12225.82 31,029 61.965 10182,00 10236.80 1307.91 N 12300.00 30,331 61.'t 02 ~0245.79 10300.59 1325.95 N 12315.29 30.168 60.920 10259.00 10313.80 1329.68 N 12400.00 29.337 60.105 10332.54 10357.34 1350.36 N 12477.10 2~.567 59.326 10400.00 10454.80 1359.19 N 3.836,22 3879,25 3950.95 4015.88 4022.21 4075.$2 4t34.16 4590.92 4246.06 4299.58 4351.45 4358.52 4401.65 4434,91 4450.16 4496.96 E 45O6.77 E 4542.04 E 4548.78 E 4585.39 E 4617.62 E GLobal Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (fi) (°/100ft) (fi) 5907386.50 N 367849.59 E 0.000 3970.99 5907401.12 N 367892.89 E 6.000 4016.62 5907425.47 N 367965~3 E 6.000 4092,65 5907447.53N 366030~7 E 6.000 4161.50 5907449.68 N 368036.74 E 6.000 4168.22 5907468,24N 368090.69 E 1.112 4225.17 5907489.28 N 368149.42 E 1.112 4287,3,8 5907510.65 N 368206.57 £ 1.112 4.348,16 59075,32~5 N 368262.12 E 1.112 4407,48 590755A~6 N 368316.04 E 1.112 4465.33 5907576.68 N 368368.32 E 1.112 4521.66 5907579.81N 368375.45E 1.112 4529.37 5907599.30 N 368¢18,93E 1,112 4576.48 5907614.90 N 368452,48E 1,112 4612,98 5907622.22 N 368467.86 E 1.112 4629.75 5907645.42N 368,515.09 E 1.112 468~.46 5907651.4.5N 368527.00 E 1.112 4694.56 5907668.89 N 368560.59 E 1.t~2 4731.58 5907672.50 N 368567.40 E 1.f$2 473,9.11 5907692.53N 368604~7 E 1.112 4780.08 5907710.77N 368636.93 E 1.112 4~816.:33 Ail data is in feet unless othen,v[se stated. Directions and coordinates are relative to True North. Vertical depths are relative to Weft Reference. Nodhings and Eastings are relative to Well Reference. The Dogleg Severity is [n Degrees per 100ft. Vedica[ Section is from Well Reference and calculated along an Azimuth of 73.484° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12477.10ft., The Bottom Hole Displacement is 4816.33ft., in the Direction of 73.484° (True). Alaska State Plane Zone 3 Badami CPF Comment Start Dir @ 6,000°/100~: 11043,72ft MD, 9314.13ft TVD BHA Tendency @ 1.112°/100ft - 11310,39~t MD, 9491,99ft '[-VD F3 F4 F5 ~get: B1-25 Target(607438), 200.00 R~dius., Dd II e rs Total D .epth - 12477.10,fl. MD, 10454.80ft 'rVD 4 1/2" Uner Conlinu~d... 7' Ocfober~ 1998 - 14:56 -4- DritlQuest Sperry-Sun Drilling Services Proposal Report for B 1-25 Wp8 Badami Alaska State Plane Zone 3 Badami CPF Comments Measured Depth 30o. 0o 70o. 00 800.00 1200.00 2877.85 5200.89 6550.89 9999.05 10654,63 10714.63 10983.72 ! 1043.72 11310.39 12477.10 Formation Tops Measured Depth (fi) 2005.69 7822.67 9431.21 9854.75 9999.05 Stat[on Coordinates TVD ([1) 300.C~) 699.68 799.43 1'~99.11 2876.95 5200.00 6358.83 8574.80 9054.80 91{30.86 9280.58 9314.13 9491.99 10454.80 Northings Eastings (fi) (ft) o.oo N o.oo E 13.82 N 1.94 E 20.73 N 2.91 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 158.32 N 582.19 E 797.48 N 3141.17 E 934.08 N 3565.73 E 947.03 N 3603.93 E 1014.08 N 3789.38 E 1030.84 N 3835.22E 1097.37N 4022.21 E 1369. t9 H 4&17.62 E Ve~[ca! Sub-Sea Depth Depth Nodhings (~) (~) (~) 2004.80 195o.oo 34.55 N 7132.80 7o78.00 381.60 N 8184,80 8~30.00 685.01 N 8,474.80 8420.00 768.64N $574.80 8520.00 797.4~N Comment Start D[r @ 1.000°/100~t: 300.00ft MD, 3CO.O0~t-I'VD End Dlr: 700.0011 MD, 699,68ft TVD Start DIr @ 1.~0,0'~f100ti: 800.O0ft MD, 799.43tt TVD End DIr: 1200.00it MD, 1199.11 [1 TVD S. all@ 0.000° Inclination on 358.971 ° Azimulh Start Dir @ 4.000"/1001t: 5200.89~t MD, 5200.00tt TVD BHA Tendency @ 0.250"/10011: 6550.89~ MD, 6358.83tt 'i'VD BHATendency @ l.O00"/t00~t: 9999.05fl MD, 8574.8011TVD End Dir: 10~54.63ft MD, 9054.80fl '['VD Sta~[ Dir @ 6.000°/100ff: 107t4.63~t MD, 9300.86ff 'J'VD End Dir: 1098,3.72ft MD, 9280.58ft 7'VD Start Dir @ 6.000°/100['t: 11043.72ft MD, 9314.13[t TVD BHA Tendency @ 1.112°/100ft: 11310.39ft MD, 9491.99ft 'rVD Total D~pth: 12477.10ft MD, 10454.8911 'rVD East[rigs Formation Name (ft) 4.86 E Base Permafrost 1566.13 E Top Mid Brook[an 2744.07 E Mg0 3(~41.2~ E Base Wesl Sak 3141.17 E Top Cann[rt[~ CohO'hued... 7October, 1998- 14'.E6 -5- Sperry-Sun Drilling Services Proposal Report for B1-25 Wp8 Badami Measured Vertical Sub-Sea Depth Depth Depth (~) (~) (~) Formation Tops (Continued) 1078727 9154.80 9100.00 11913.89 9973.80 9919.00 12058.19 10102.80 $0048D0 1~725,82 10236.80 10182.00 123t5.29 10313.80 10259.00 Northings 963.41 N 12.33.56 N 1270.02 N 130731 N 1329.68 N EastinGs 3647.71 E 4358.52 E 4434.91 E 4508.77 E 454838 E Formation Name Shallowest Badami Sand F3 F4 F5 A5 Alaska State Plane Zone 3 Badami CPF Casing deta#s From Measured Depth <Surface> <Su dace> <Su trace> Vertical Depth <Surface> <Surface> <Surface> To Measured Depth 4555.69 10854,63 12477.1o Ve~ca[ Depth (fi) 4554.80 9054.80 10454.80 Casing Detail 9 5/8' Ca[sing 7" Cas~r~g 4. 1F2' Lirter Continued... 7 October, 1998- 14:56 -6- Drii~Ques! AL~G-03-98 ~iON 08:54 Shared Services Drilling Mike Cook Mike, The above mentioned well h~s been scanned using sta. ndaxd anti-collision methods via DEAP. i im lira II I il The sc'm was perform~ with th~ following pa.,'arnetet:~: Start Scan Inspection Zone End Scan Inspection Zone Stnrting Scan Raclius Rate o£ Radlu~ Increase (pet' 1000') 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Approved Well Close Approach Review 35.30' 14,329,42' 200.00 ' Anti- Collision Sm-m summary: At the planned KOP th~ Starting Scan Radius ix 98,235' larger than DEAFs default settings of 100' Start Scan Radius increasing at 50' per 1003 'MD for a new-drill well sca. n, thus DEAP's defaults would b~ equal Lo 101.765' at the Start Scan Inspection Zeno as stated above. These numbers axe ~ed to produce a f~n,al scan radius of 1629,412' which is 812.941' larger than DEAP's d~fault value of 8I 6,471' Scan Parameters Comments: · I I __ I I I I ] I lB I I Il i ............ I [ I [ ! I [ [ II [ __ [ l[ [[ [ [ [ [ [ [ Il[[ [ At this ent~gcd r~i~ the following w~lls were detected during the ~can (Based on c~os~t 'Allowable Dcviallon from Plea'Ii .',,'ere: ¢,.ls list may not Include all th~ well.s dat~t~d, or, 17 tho. se of which are of ¢o~eern or ma.~/effect Toler~ec Line drawing! .. Bl-21 B1-21 '- B1.2g Bl.2g _ , , _ .C. omparison Su_blect Well Planned Well Relative Ail0vmble Shut-l~Required? (Secretion notes~ Well: Deoth Severatlo~ Aztmutl1 Devtatfon ('= Di:;~.~ S~O~ (': Well PIw~ MD) (P_ot.! IO ? o!r.t] (T~ Direc/ion) OD_~ro~ TL PI:J2 B 1-01 598.63 'MD 240.45 ' 265,80 ° 234.92 ' No MINOE B 2. ] 1 4 00.45 'MD 140.43 ' 2{}8.06 'o 136.54 ' No MINOR . B t- 14 400.30 'MD 110,78 ' 269,20 ° 106,87 ' No MINOR B1-14 4691,85'MD 166.48 ' 317.70 · 127,38 ' No MINOR ,, , B].ISL1 499.73'MD 100,81 ' 266.50 ° 96,15 ' No MINOrt __ B~I.15L, t 5197,12'MD 124,83 ' 264.10 ° 83,99 ' No MINO~ BI-16PB'--"~'~~ 400,25'MD 92,75" :269,50 ° g~,{5 ' No ~INOR Bl.16PBl 2570,34 'MD 30.07 ' 292,90 ° 13.32 ' No MINOR 131.18 599.79 'MD 69.95 ' 266,60 ' 64.53 ' No MINOR Bl.l$ 5480.20'MD 145,95 ' 214.90 ° 107.60' No MINO~ 200,10'MD 40,17 ' 270.20 ° 38.54 ' No MINOR 3163,86'MD 94,35' 126,20 ° 74,98 ' No ~INOR 599,64 'MD 30,23 ' _ 104.9.__~0 · 25,43 ' No MINOR .__ 2693,29'MD 128,24 ' 143,10 ° 112.34 ' No MINOR · i ......... i I · i I I I L III i I il ~ ...... ill ~ I · IlL I - --I Tolerance Plot required: Yes ~t~qtus as Tested Close Approach Comments: We have a very close approach with B1-16 at the 2400- 3000 MD area, I will talk to our drillers before they Do ur> and have them nudge away from that oreo slightly to avoid any interference yet still remain on our nudc~e oro~rom. mi i m i , mi I I I m Il I , II · Il mi i I j i · ii ii i ii i ii m · i i i Close Approach Scan Performed by: Date: ' C'hecked by: Date: Approved by: Date: B1-2$.xls _ AWD Proximity Review Shared Services Drilling Contact: I Well Name: Type of Well (producer or injector): Mike Cook J B1-25 J Well Plan Summary Producer- Open hole 564-5390 Surface Location: 3857' FSL 17' FEL SEC 8, T9N, R20E, UM, AK AFE Number: I 880460I Estimated Start Date: I Oct. 20 1998 I Well Design: KBE: 54.8 -~ AMSL IRig: INab°rs 28E I Operating days to complete: 145 Ultra slimhole- multi-lateral open hole completion w/slotted liner Formation Tops MD TVD (bkb) Remarks base permafrost 2005 2004 Top Middle Brookian (TMBK) 7619 7132 M90 9228 8184 Base West Sak(M85) 9655 8474 Casing/Tubing Program: Hole ~ize Csg~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDf'i'VD MD/TVD brt 24" 20" 91.1# H-40 Weld 80 37/37 116/116 12-1/4" 9-5/8" 40# L-80 BTC 4521 35/35 4556/4555 8-1/2" 7" 29# P110 BTC- 10621 33/33 10654/9054 mod Internal yield pressure of the 7" 29#/ft P110 casing is 11220 psi, which is greater than the maximum anticipated surface pressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/ft, surface to 6570'; oil, 0.36 psi/ft, 6570 to 10094' tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. Loggin9 Program: Open Hole Logs: Surface Sidewall cores: 30ea. planned ( 2500' md - 4500'md) Intermediate MWD/GR @ hole section TD Production MWD/GR/RES HDIL/ZDL/MAC Mud Program: Special design considerations I displace OH to 5% KCL water based muds Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 150 25 20 45 9 ¢~ ,~, .~. _.1,0 ..... to to to to to to ;~'~ ~ ~ ~o! %jo 9.8 - 10.0 300 60 30 60 9.5 ~'~ Intermediate Mud Properties: '" I KCL polymer '- .... : Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point 9el 9el Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to 10.1 55 20 10 25 9.5 4-6 Production Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point ~lel gel Loss 12.0 45 10 8 15 8.5 4-5 to to to to to to to 12.4 55 15 10 20 9.5 4-5 Well Control (Secondary): Diverter Waiver Requested Well control equipment consisting of 10,000 psi W.P.(2) pipe rams, (1) blind rams, and 5M WP annular preventer will be installed and is capable of handling maximum potential surface pressures.lO M WP Choke & kill manifold. BOPE and drilling fluid system schematics on file. Waste Manaqement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1~01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well 131-01. Annular Injection: No annular injection is planned at this time. DRILLING HAZARDS AND RISKS: Wellbore proximity comments are addressed under each MLOH section. Junk (auger tooth) was encountered in the B1-16 conductor - if junk is encountered, ensure all junk is fished prior to commencing drilling. Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Badami sands are overpressured - normally 12.2ppg mw required at TD. Pressure transition begins just above shallowest sand. Shallow sands typically pressured between normal and the 12.2 ppg required in lower sands. Maintain minimum mud weight and utilize latest techniques to manage lost circulation hazards in shallow sands (flow rates, tapered drill string). Weight up as wellbore pressures dictate, maintaining a 200 psi overbalance throughout. Hazards of well control and stuck pipe are managed by setting 7" casing above shallowest sand, before penetrating the full overpressure. Hazard of lost circulation is managed by proper techniques to maintain Iow ECD - ECD of 13.5 ppg noted to be maximum allowable to prevent lost circulation. ~ B 1-25 I TD MD: I12477 I lTD TVDBRT: 110454 Badami Sand F5 Primary 94'FNL 743' FEL SEC 9, T9N, R20E, UM, AK target Bottom Hole Location (TD) 51' FNL 598' FEL SEC 9, T9N, R20E, UM AK Formation Markers: Formation Tops MD TVD (bkb) Remarks Shallowest Badami Sand 10787 9154 Badami Sand F3 11913 9973 Badami Sand F4 12068 10102 Badami Sand F5 12225 10236 Primary Sand Badami Sand A5 12315 10313 Total Depth 12477 10454 Casing/Tubing Program: Hole'~ize 'Cs'g/ wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD brt 6" 4-1/2" 12.6# L-80 BTC 250 12225/10236 12477~10454 slotted liner NOTE: slotted liner will only be installed if sufficient amalgamated pay exists as determined by logs and petrophysicist. Length of slotted liner will be adjusted to cover an interval from TD to above top of amalgamated pay. If insufficient amalgamated continuous pay exists to warrant the slotted liner, none will be run. Logging Program: Production Hole RFT Cased Hole Logs: MWD GR/Resistivity only none none Directional: KOP: I 5200' md/tvd Maximum Hole Angle: 56 deg. @ 10983' md thru 11043' md (ramp section) Close Approach Well: B1-16 @ 2570' md (13.30' close approach). B1-16 shut-in. ~ Badami B1-25 Proposed Summary of Operations 1. Weld the starting head on the conductor. 2. Prepare the location for the rig move. 3. MIRU Nabors 28E drilling rig. Build spud mud. A diverter waiver is requested from AOGCC. 4. PU 12-1/4" bha & drill surface hole as per directional plan. Run directional MWD from surface to TD. 5. Run 9-5/8" surface casing and cement to surface in two stages. 6. NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi. 7. RIH with BHA, test casing to 3000 psi. Drill out float equipment and 20' of new formation. Perform a LOT as per SSD Standard Operating Procedure. Contact the Badami Drilling Team Leader or SSD Superintendent with LOT test results before drilling ahead. 8. Drill 8-1/2" hole to intermediate casing TD as per directional plan, with MWD directional surveys. 9. Run 7" casing and cement as per Cement Procedure (1000' md of cement above shoe). Test BOPE to 6000 psi. 10. RIH w/6" BHA, test 7" 29# P110 csg. to 3500 psi. Drill out float equipment and 20' of new formation. Perform FIT to 13.5 ppg minimum equivalent. 11. Drill 6" hole to targeted BHL as per directional plan with GR/4 phase resistivity MWD. Utilize latest techniques for reducing lost circulation risk (tapered string, flow rate limitations, ECD limits, mud rheology, etc.). 12. Displace open hole to above top of upper most Badami sand with high viscosity/low fluid loss pill - POOH. Run open hole logging surveys. 13. Run 4-1/2" slotted liner from TD to just above the top of the amalgamated pay (exact depths to be determined from logs). Set liner on bottom, release from liner with HES hydraulic setting tool. 14. RIH with 4-i/2" completion assembly open ended. M/U connect 2 ea. ~,4" control lines ( 316 SS Wall thk: 0.049") to WLRSV landing nipple. Line up trip tank to bell nipple. Circulate across the well with returns back to the trip tank while the completion is being run in the hole. Pitwatcher will monitor the fluid level in trip tank as the completion is run in the hole. 15. RIH - position permanent packer to setting depth. Record pick up and slack off weights. 16. M/U control lines to FMC 4-1/16" 10 M tubing hanger. Test control lines to 5000 psi - hold pressure for 10 mins. Land FMC 4-1/16" 10 M tubing hanger and RILDS (14 ea.) to energize FMC tubing hanger packoff assembly. Test packoff assembly. Set & test two way check. N/D 13-5/8" 10000 WP BOPE. N/U 11"-IOM x 4 1/16"10M Adaptor & Tree tested to 7000 psi. Pull two way check valve. 17. R/U slickline. N/U 5k psi pump-in sub + BOP's. PU dummy valve pulling tools & ball/rod in lubricator tested to 3k psi on top of swab valve(s). Bleed lubricator off to 1,820 psi. 18. R/U pump truck & manifold per attached schematic. Displace freshwater down 4-1/2" tubing (180 bbls). Maximum rate 2 bbls/min. Slow pump rate to V2 BPM & open swab valve(s) to drop ball & rod. Close swab valve & bleed/drain lubricator. 23. 24. 25. 19. Set Baker S-3 permanent production packer with 5600 psi. tubing surface pressure. After packer setting sequence is complete, maintain pressure at 5600 psi.for 30 minutes and record as tubing test. Note: Baker S-3 packer will require 3500 psi differential pressure to complete its mechanical setting sequence. Total surface estimated pressure requirement will be 3500 + 2100 = 5600psi. 20. Test 7"x 4-1/2" to 3500 psi for 30 minutes. Reduce tubing pressure from 5600 psi to 4500 psi on 4-1/2" tubing for 7"x 4-,1/2" annulus test. Record on Barton Recorder. Maintain 7" x 4-1/2" annulus pressure at 3500 psi. Bleed 4-1/2" tubing from 4500 psi to 2500 psi to create 2900 psi differential pressure from annulus to tubing to shear of SDCK valve. Note: (1) Upon SDCK shear, limit amount of 12.3 #/gal drilling fluid "U" tube to tubing side to prevent barite settling on RHC plug. (2) Tubing pressure should be maintained greater than 1800 psi to ensure ball & rod assembly stays on seat. 21. Pump down 4-1/2" 12.6# L80 tubing and up the 4-1/2" x 7" annulus with freshwater w/25 gals/100bbls of 7726 Corexit corrosion inhibitor. Maximum rate through SDCK valve is 3 bbls/min. Circulate 4-1/2" x 7 until clean. Add dirt magnet as needed. Freeze protect 4-1/2" tubing & 4-1/2" x 7" annulus. 22. Equalize lubricator with tubing & TIH to pull dummy ball valve from SVLN. POH, SI swab valve & bleed-off lubricator to recover ball valve. Pull SDCK valve from lower GLM & replace with dummy valve. Pull ball & rod assembly. Pull RHC sub. Install SSSV "BBE" in SVLN. Close "BBE" SSSV. Test "BBE" SSSV by closing valve and bleeding 4-1/2" 12.6# tubing pressure to "0" psi. Monitor tubing for 30 minutes to ensure "BBE" SSSV pressure seal integrity. R/D wireline. Secure well. RD/MO Nabors 28E rig, release rig. Transfer well custody to Badami Operations Install two-way check valve in FMC 4-1/16" 10M hanger profile. N/D 4-1/16" 10M Cameron Adaptor & 10M Xtree. N/U 11" 10 M x 4-1/16" 5M Cameron Adaptor & 5M Xtree. Test Xtree to 5000 psi. Retrieve two-way check valve & replace with BPV. Secure well. RD/MO Nabors 28E rig, release rig. Transfer well custody to Badami Operations Badami B1-25 CASING SIZE: 9-5/8" SPACER: SURFACE CASING CEMENT PROGRAM - HALLIBURTON 100 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.O ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 255 SACKS THICKENING TIME: Greater than 4 hrs at 50© F. Volume based on gauge hole annular capacity from 1000' above the casing shoe to the ES cementer at 2200' md, plus 30% excess. Premium 2% calcium chloride 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 385 SACKS THICKENING TIME: Greater than 4 hrs at 50© F. Volume based on 1000' md of fill in the gauge hole plus 30% excess plus 80' shoe joint. SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.O ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 2500 SACKS THICKENING TIME: Greater than 4 hrs at 50© F. Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: To be determined on job x job basis ~ INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 7" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1 ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 185 SACKS THICKENING TIME' Greater than 4 hrs at 50© F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. MULTI-LATERAL WELL ABANDONMENT PROGRAM The following program is to be used at such time as the wellbores below the 7" intermediate casing are to be abandoned. 1. MIRU Rig. 2. Kill Well. 3. Pull tubing, packer, completion. 4. RIH with 7" EZSV cement retainer and set 50-100' inside the 7" intermediate casing and above all perforations in the 7", if any exist. 5. Mix and pump a volume of premium class G cement to fill the 7" casing below the EZSV and the calculated volume to fill the entire hole section of all wellbores below the 7" shoe, plus 10%. 6. Unsting from EZSV. 7. Pressure test the EZSV and cement to 3000 psi. 8. Procedures for the remainder of the wellbore above the EZSV will depend on the future plans for the wellbore (total abandonment, sidetrack, etc.). ~ 00T-07-98 NED 04:45 Pii SPERRY-SUN ILaSKA FA× NO, 19075635754 P, 02 ~-[:3~=1~/-~LJr3 SHARED SERVICES DRILLING DrillQ uest' 0 , .,.' ~~.~,1 Well '. Current Well I stan PIt t~ 1.000~/i00fl: 300.00~1 MD, 300.00h I'VD : Hor!zonl~l Ooordlnales: EndDlr'.700.O0flMD,69g.6~ftTVO L~ i~ ! · ',;i STaM DIr ~ 1.000('/10O'H: 800.00~1 MD, 799.43.fl TVD ,~ , Rul. Globe1Coorcfrn:',lr:.s: $g0~,,~24.70 N, 263995.4-"- E ReL Geographical Coordinates; 800.00 ' P, KB ~Jev311on: 54.~011 abova Menn Sen Lr~vol .... End Dlr .* 1200.0011 MD. 1 I g9.t ll't TVD RKB C.~l~utation: ,3~.30/~ Rig (EST) 4;'00.00 ' J lO.g0 fl W~:II (CB-c) 1400 J [ Notlh Ra~erence: True North D-.,,;o rcrmarm.~[ · 2(XH.I~0 TVD i C(:ordinate .SysJsm '. NAD27 Alnska SI;~Io -~,(~)o.~ ............ I PLOT DATE: 9/28/9B . Crc~tod By :~-~ ~ ;~,~00,00 ' l¢rleckad ~3y: Appr=uod By: ~,.,~ ~ ..... , .... .~ ,, · .................. 2800 - ~.800.00 ' S~ll ~ o.ooo° Incllnnllon on 358,971~Azimulh Proposal Target summary ..... 3200,00 ' r..l~.l= (2brrR~N,~) 3eO0.O0 4000.00 ' ' .......................... -- 44oo,oo j' L 9 5/8" Casing - 4555.69 MD, 4554.80 TVD ~ o~oa~.o,~:~, o.¢,,,~,, 7200~0 7000- ~auo.0o ~ 8000,00 ~ 8qO~,O0 ~ 9200.00 ~ 9800.00 ~ ~A Tandency ~ 1.~*/~: 9999.0S~ MD, 8574.8~t 10400 ~ 4 · 7" Casing - 10654.~3 MD, 905 .80 I [ I 0 1400 2600 Scale: linch = 14o0~ Vertical Section Section Azimuth: 73.484' ~rua Norih) 7" C~sinw- 10654 63MD, 905a.80TVD lO~OO.O., ~'... St~ Dire G.000~/100[~; 10714,63h MD, 9100.~It ~D 9~00 m~ 1~o0.oo ~BHAT~den~ ~ 1.112°/100,: 11310.3~ MD,~gl.g~I~D -- -- -- ~ .... PI- I0102.8[)1WD ~ ~12100,0~ V 10400 ~ Cl~,lh,.,) ~2400.00 ~%..' Tolal D~pCh: 12477,10[t MO, 10454,80~D 3~0~ 4400 ~200 9cale~ linCh = a0Oll Ve,ical Section Se~lign A=imu~h; 73,484= ~e No~h) ..... SHARED SERVICES DRILLING WeE ' B1-25 Wp8 I DrillQuest' O~ Scale: Ifnch = lO0'f't -100 I I I -100 0 Scale: liech = lO0ft Eastings 100 I I I t00 200 300 Fa$1;llnS Reference Is True North Current Well Properties Well: BI-25 590642.4.70 N. 3ro39<JS.48 E 7O: 09' ~8.O,322.' t4, t<T~ C5' 37.[954' W RKB Et~va~im: 54.60f[ r=bove Mean Sea ~ RKB Calcula~n: 3,5.3o t~ PJ9 (EST) Is.5o tt We~ (C~E") Un/ts: Fee~ _C_,o0~lm Sy~l~'n: NAD2/~ State Pl~ne:5., Zcx~e 3, US Foo~. PLOT DA11~: ~ Proposal Target Summary Itr)~.O:) Ill~l'l.~O &.x29.61l Iq. ~.18.'7'ff E 55417~"2_1CIIq. ~d.e.6'L40E 1250 750 Scale: linch = 5OO~t Eastings 500 IOtXI tSO0 2000 2500 3000 3500 4000 4500 5000 . ..I I I I I I I i I t lOdl J.~O Tl'Vl> 4 1/2' Liner - 12477.10 MD. 10454.80 't'VD ~ -~ ~,,,~-'... 'eH~T~,~,cy e ~.~ot: ~ ~olo~, ~D.~ ~ "~.~ ,~. '- ' ~r I~ 6.(XXI'/'I~fl: !1043.72ff M~D.~14.13flTVO ~ '% ~ ~~ 00It: 10714-~3tt MD, 91C~.~t TVD ~'~o -' 7' Cesin - 10654 63 MD 9054.80 TVD ..~ ~7. BHATendency ¢~ 1.OqXY'/lOOfl:Dggg.05ttl~O, g574.8011'D/D BHATendency ¢~ 1.OqXY'/lOOfl:Dggg.05ttl~O, g574.8011'D/D .............. BHAT~ndenc,/~, O.2.~.O=l[OOf;: 65S0.6~ MD, 63S&~,TVD 1 I I I I I I I I I 500 [OO0 1.500 2000 2500 3000 3500 400) Sca~e: 1 Inch = 50OIt Eastin g$ Re~erence [$ T~e North 250 ~1 Sperry-Sun Drilling Services Proposa/ Report for B1-25 Wp8 Badami Measured Depth (.) Incl. Az[m, Sub-Sea Vertical Local Coordinates DepIh Depth Northings Easfin9s (ft) (ft) (,) (,) 0.00 0.000 0.000 -54.80 0.00 300.00 0.000 0.000 245.20 300.00 400.00 t.00O 8.000 345.19 399.99 500.00 2.000 8.000 445.16 499.96 600.00 3.000 8.000 545.06 599.86 700.00 4.000 8.000 644.88 699.68 800.00 4.000 8.000 744.63 799.43 900.00 3.000 8.000 844.44 899.2.4 1000.00 2.000 8.000 944.35 99 9.15 1100.00 ~.000 8.000 1044.31 ~099.11 1200.00 0.000 0.000 1144.31 1199.11 2000.00 0.000 0.000 1944.31 1999.11 2005.69 0.000 0.000 1950.00 2004.80 2877.85 0.000 0.000 282..2.15 2876.95 3000.00 0.000 0.000 2944.31 2999.11 4000.00 0.000 0.000 3944.31 3999.11 4 555.69 0.000 0_000 4500.00 4554.80 5000.00 0.000 0.000 4944.31 4999.11 5200.89 0.000 0.000 5145.20 5200.00 5300.00 3.964 77.900 5244.23 5299.03 5400.00 7.964 77.900 5343.67 5398.47 5500.00 11.964 77.900 5442.14 5496.94 5600.00 15.964 77.900 5539.16 5593.96 5700.00 19.964 77.900 5634.27 568,9.07 5800.00 23.964 77.900 5726.99 5781.79 5900.00 27.964 77.900 5616.85 5871.68 6000.00 31.964 77.900 5903.50 5958.30 6100.0O 35.964 77.900 5986.42 6041.2.2 6200.00 39.964 77.9'30 6065.24 6120.04 6300.00 4.3.96-4 77.900 6139.58 6194.38 0.00 N 0.00 E 0.00 N 0.00 E 0.86 N 0_12 E 3.46 N 0.49 E 7.78 N 1.09 E 13.82 N 1.94 E 20.73 N 2.91 E 26.77 N 3.76 E 31.09 N 4,37 E 33.69 N 4.73 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 34.55 N 4.86 E 35.27 N 8.21 E 37.45 N 18.36 E 41,07 N L'LS.2.8 E 46.13 N 5~.87 E 52.59 N 89.02 E 6O.43 N 125.59 E 69.61 N 16,5.39 E 80.O8 N 217.2.1 E 91.78 N 271.8,3 E 104.68 N 331.97 E 118.69 N 397.33 E Global Coordinates Dogleg Vertical Northings Eastings Rate Seclion (it) (ti) (°/~OOtt) (tt) 5906424.70 N 363995.48 E 0.00 5906424.70 N 363995.48 E 0.000 0.00 59064-25.56 N 363995.62 E 1.000 0.36 5906428.15 N 363996.03 E 1.000 1.45 59084,32.45 N 363996.7~ E 1.000 3,26 5906438.48 N 363997.67 E 1.000 5.79 5905445.37 N 363998.76 E 0.000 8.69 5906451.40 N 36399,9.72 E 1.000 11.22 5906455.71 N 364000.41 E 1.000 13.03 5906458.30 iq 3640(~0.82 E 1.000 14.12 5906459.16 N 364000.96 E. 1.000 14.48 5906459.16 N 364000.96 E 0.000 14.48 5906459.16 N 364000.96 E 0.000 14.48 5906459.16 N 364000.96 E 0.000 14.48 5906459.16 N 364000.96 E 0.000 14.48 5906459.16 N 364,000.96 E 0.000 14.48 5906459.16 N 364.,000.96 E 0.000 14.48 5906459.16 N 364000.96 E 0.000 14.48 5906459.16 N 364000.96 E 0.000 14.4~ 5906459.82 N 364004.32 E 4.000 17.89 5906461.81 N 364014.51 E 4.000 28.25 5906,465.13 N 364031.49 E 4.000 45.50 5906469.77' N 364055.17 E 4.000 69.56 5906475.69 N 364085.43 E 4.000 100.30 5906482.87 N 364122.13 E 4.000 137.59 5906491.27 N 364165.09 E 4.000 181.23 590650'0.86 N 364214.10 E 4.000 231.01 5906.511.59 N 364268.9! E 4.000 286.70 5906523.40 N 364329.27 E 4.000 343.03 5906536.24 N 364394.88 E 4.000 414.68 Alaska State Plane Zone 3 Badami CPF Comment Start Dir @ 1.000°/1 O0ft · 300.00It MD, 300.00R TVD End Dir' 700.O0[t MD, 699.68fl TVD Start D]r @ 1.000°/100fl · 800.O0fl MD, 799.43tt TVD Ertd Dir: 1200.00fl KiD, 1199.1 lfl TVD Base Permafrost Sail @ 0.000" Inclinal~on on 358.971" Azimu~ 9 ~8' Casin9 Start D]r @ 4.C,00°/100H · 5200.8941 MD, 5200.0~'I-VD Co,,~b'nued... 7 October, I998 - 14:56 -1- DrjttOuest Sperry-Sun Drilling Services Proposal Report for B 1-25 Wp8 x Badam[ Measured Depth Incl_ Azim. Sub-Sea Depth Vertical Depth 6400.00 47,964 77.900 6209.08 6263.88 6500.00 5[.964 77.900 6273.39 6328.19 6550.&9 54.000 77.900 6304.03 6358.83 6600.00 53.~&5 77.848 6332.94 6387.74 6700.G0 53.650 77.742 6392,04 6446.84 6800.00 53.415 77.635 6451.48 6506.28 6900.00 53.180 77.527 6511.24 6566.04 7000.00 52.946 77.419 6571.34 6626.14 7100.00 52.711 77.310 6631.76 6686.56 7200.00 52.477 77.200 6692,50 6747.30 7300.00 52.243 77.090 6753.57 6808.37 7400.00 52.009 76.979 6814.97 6869.77 7500.00 51.7'75 76.867 6876.68 6931.48 7600.00 51.541 76.755 6938.72 6993.52 7700.00 51.307 76.642 7001.07 7055.87 7800.00 51.073 76.528 7063.75 7118.55 7822.67 51.020 76.502 7078.00 7132.80 7900.(~0 50.840 76.413 7126.74 7181.54 8000.00 50.606 76.298 7190.04 7244.84 8100.00 50.373 76.181 7253.67 7308.47 8200.00 50.140 76.064 7317.60 7372.40 15300.00 49.906 75,947 7381.85 7436.65 8400.00 49.673 75.828 7446,41 7501.21 8500.00 49.441 75.7C~ 7511.28 7566.08 8600.00 49.208 75.588 7576.46 7631.26 8700.00 4<3.975 75.467 7641 ,:94 769 6,74 8800.00 4&743 75.345 7707.73 7762.53 8900.00 48.510 75.222 T"/73.8,,3 7828.63 9000.00 48.278 75.099 78.40..,~3 7895.03 9100.00 48.04-6 74.974 7906.93 7961.73 Local Coordinates Northings Easlin§s (fi) 133.76 N 467.61 E 149.80 N 542.46 1::: 158.32 N 582.19 E 166.66 N 621.01 E 183.71 N 699.84 E 200.86 N 778.41 E 218.10 N 856,71 E 235.44 N 934,74 E 252.87 N 1012.49 E 270.39 N 1089.97 E 288.01 N 1167,17 E 305.72 N 1244.10 E 323.52 N 1320.74 E 341.42 N 1397.t0 E 359.41 N 1473.18 E 377.49 N 1548.98 E 381.60 N 1566.13 E 395.66 N 1624.49 E 413.92 N 1699.72 E 432.27 N 1774.65 E 450.71 N 184,9.30 E 469.24 N 1923.66 E 487.86 N 1997,72 E 506.57 N 2071.49 E 525.37 N 2144.96 E 544.26 N 2218.14 E 56323 N 2291.02 E 582.30 N 2363.60 E 601.4.5 N 24,35.88 E 620.68 N 2507.85 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (it) (fi) (°/100tt) (11) 5906550.04 N 364465.42 E 4,000 486.34 5906564.74 N 364549.54 E 4,000 562.b'-'7 5906572.54 Iq 364,580.42 E 4.000 603.18 5906580.18 N 364619.38 E 0.250 642.76 5906595.82 FI 364698.51 E 0,250 723.20 59066~ 1.55 N 36477-/.37 E 0,250 803.40 5906627.39 N 364855.97 E 0,250 883.37 5906643.32 N 364934.30 E 0,250 963.10 5906659.35 N 365012.35 E 0,250 1042.60 5906675.48 N 365090.t3 E 0.250 112f.87 5906691.71 N 365167.64 E 0,250 1200.89 5906708.04 N 365244.87 E 0,250 1279.68 5906724.46 N 36532~.82 £ 0,250 1358.22 5906740.98 N 365398.49 E 0.250 14.36.52 5906757.60 N 365474.88 E 0.250 I514.57 5906774.32 N 365550.99 E 0.250 1592.38 5906778.12 N 365568.21 E 0.250 1609.99 5906791.13 N 365626.81 E 0.250 1669.94 590~08.03 N 365702.35 E 0.250 1747.26 590682.5.04 N 36577"7.61 E 0.250 1824,32 5906842.14 N 365852.57 E 0.250 1901.13 590~859.33 N 365927,25 E 0.250 1977.68 5oJ~6876.62 N 366001.64 E 0.250 2053.98 5?06894.00 N 366075.73 E 0.250 2130.03 59~69f1.48 N 366149.53 E 0.250 2205.82 5906929.05 N 366223.03 E 0.250 2281.34 5906946.71 N 366296.24 E 0.250 2356.61 5906964.47 N 366369.15 E 0.250 2431.61 5906982.32 N 366441.76 E 0.250 2506.36 5907000.26 N 366514.07 E 0.250 2580.83 Alaska State Plane Zone 3 Badami CPF Comment BHA Tendency @ 0,250°1100ft ' 6550,69ft MD, 6358.&3ft ]-VD Top Mid B¢ookiaJn Ccntinued... 7 October, ~99~ - 14:56 -2- Dri#Quest Sperry-Sun Drilling Services Proposal Report for B1-25 Wp8 x <3:: [_t... Badami Measured Depth incl. Azlm. Sub-Sea Depth (It) Vertical Depth 9200.00 47.814 74,848 7973.94 8028.74 9300.00 47.582 74.722 8041.24 8096.04 9400.00 47.350 74.595 8108.84 8163.64 9431.21 47.278 74.555 8130.00 8184.80 9500.00 47.119 74.466 8176.74 8231.54 9600,00 46.667 74.337 8244.94 8299.74 9700.00 46.656 74.207 8313.43 8368,23 9800.00 46.425 74.075 83~2.2~ 8437,01 9854.75 46.298 74.003 8420.00 8474.80 9900.00 46. f94 73.943 8451.29 8506.09 9999,05 45.965 7'3.811 8520.00 8574,80 '[000O.00 45.956 73.8(;'6 8520.6~ 8,575.46 f0100.00 45.018 73.323 8590.76 8645.56 10200.00 44.081 72.823 8662.03 8716.83 10300.00 43.1~,7 72.306 8734.43 8789.23 10400.O0 42.215 71.771 8807.94 8862.74 10500.00 41.286 71.2~7 8882.55 8937.35 10600.00 40.359 70.641 8958.22 9013.02 10654.63 39.&54 70.318 9000.00 9054.80 10714.63 39.85~ 70.318 9046.06 9100,86 10787.27 44.213 70.318 9100.00 9154.80 10800.00 44.977 70.318 9109.07 9163.87 10900-00 50.977 70.318 9175.98 9230.78 10983.72 56.000 70.318 9Z25.78 92~0,51~ 11000.00 56.000 70.318 923 4.88 9289.68, Local Coordinates Northings Eastings (ft) (r~) 640.01 N 2579.53 E 659.42 N 2650.90 E 678.91 N 2721.96 E 685.01 N 2'744.07 E 698.49 N 2792.71 E 718.16 N 2863.16 E. 737,91 N 2933.29 E_ 757.75 N 3003.12 E 768,6.4 N 3041.21 E 777.67 N 3072.63 E 797.48 N 3141,17 E 797.67 N 3141.82 E 817.84 N 3210.22_ E 8.38.27 N 3277.33 E 858.93 N 3343.14 E 879.83 N 3407.63 E 900.97 N 3470.77 E 922.32 N 3532.56 E 934.08 N 3565.72 E 947.03 N 3601.93 E 963.41 N 3647.71 E 966.42 N 3656.13 E 991.43 N 3726.04 E 1014.08 N 3789.38 E ~018.63 N 3802.09 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ri) (ft] (°/100tt) (fi) 5907018.29 N 366586.08 E 0,250 2655.04 5907036.42 N 366657.79 E 0,250 2728.98 5907054.6.3 N 366729.19 E 0.250 2602.65 5907060,34 N 366751.45 E 0.250 2825.59 5907072.94 N 366800.28 E 0.250 :2876.06 5907091.34 N 366871.07 E 0.250 2949.19 5907109.83 N 366941.55 E 0.250 3022.04 5907128.41 N 367011.72 E 0.250 3094.62 5907138.62 N 367050.00 E 0.250 3134.25 59-37147.08 N 367081.57 E 0.250 3166.93 5907165.66 N 367150,46 E 0.250 3238,28 5907165.83 N 367151.12 E 1.000 3238.9(; 5907184.78 Iq 3672.19.86 E 1.000 3310.26 5907203.99 rd 367287.:33 E 1.000 3380.41 5907223.47 N 367353.50 E 1.000 3449.38 5907243.21 N 367418.35 E 1.000 3517.15 5907263.21 N 367481.87 E 1.000 358,3.70 5907283.45 N 367544.02 E 1.000 3649.00 5907294,61 N 367577.40 E 1.000 3684.15 5907306.91 N 3676'13.83 E 0.000 3722.54 5907322.46 N 367659.90 E 6.000 3771.09 5907325.32 N 367668.37 E 6.000 3780.02 5907349.07 N 367738.72 E 6.000 3854.16 5907370.59 N 367802.46 E 6.000 3921.32 5907374.90 N 367815.24 E 0.000 3934.80 Alaska State Plane Zone 3 Badami CPF Comment M90 Base West Sa, k [M85) HA..Tertd, ency @ 1.000°/100~t: 9999.0511 MD, 8574.80ft op uanmng End Bit · 1065,4.1~[t ME), 9~54.80ft TVD 7" Casing Start Dir @ 6.000~11001l · 10714.63ft MD, 9100.86ETVD Sh;tl[owest Badam[ Sand End Dir · 10983.72~ MD, 9280.58~t TVD Con h'rTued... 7 October, 1998- 74:56 -3- D~JtlQues~ Sperry-Sun Drilling Services Proposal Report for B 1-25 Wp8 Badami Measured Sub-Sea Vertical Local Coordinates Deplh Incl. Azirn, Depth Depth Northings Eastings (f0 (.) (fi) (.) (.) 11043.72 56.0-00 70.318 9259.33 9314.13 1030.84 N 3836,22 11100.00 52.623 70.318 9292.16 9346.96 1046.23 N 3879.25 E 11200.00 46.623 70.318 9356,91 94-11.71 1071.88 N 3950.95 IE 11300.00 40.623 70.318 9429.26 9484.06 1095.10 N 4015.88 IE 11310.39 40.000 70.318 9437.19 9491,9-3 '[097.37 N 402:2.21 11400.00 39,099 69.648 9506.28 9561.08 1116.90 N 4075.82 IE 11500.00 38.098 68.870 9584.43 9639.23 1138.98 N 4~34.16 E 11600.00 37.103 68.056 9663.66 9718.46 1161.38 N 4'~90.92 E '[ 1700.00 36.'114 67.205 9743.93 9798.73 1184.07 N 4246.06 E 11800.00 35.13~ 66.312 9825.22 9880.02 1207.05 N 4299.58 E 1 [900.00 34.154. 65.374 9907.49 9962.29 1230.30 N 4351.45 F__ 11913.89 34.019 65.240 9919.00 9973.80 1233.56 N 4358.52 E 12000.00 33.185 64.359 9990.72 10045.52 1253.83 N 4401.65 E 12068.19 32.529 63.687 I0048.00 I0102.80 1270.02 N 4434,91 E 121(~0.00 32.2_25 63.351 t0074.86 t0129.66 1277.62 N 4450.16 E 1226"O.00 31.273 62.257 10159.90 10214.70 1301,66 N 4496.96 E 12225.82 31.029 61.965 10182.00 10236.80 1307.91 N 4506.77 E 12300.00 30.3,31 61,102 10245.79 10300.59 1325.95 N 454Z.04 E 12315.29 30.18~ 60.920 10259.00 10313.80 1329.68 N 4548.78 E 12400.00 29,337 60,105 10332.54 103B7.3,4 1350.38 N 4585.39 E 12477.~0 28,567 59,326 10400.00 1045-4,80 1369.19 N 46f7.62 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (~) (°n00ft) 5907386.50 N 367849.59 E 0,000 3970.99 5907401.1:? N 367892.89 E 6,000 4016.62 5907425.47 N 367965.03 E 6.000 4092.65 5907447,53 N 368030.37 1:: 6.000 4161,50 5907449.68 N 368036,74 E 6,000 4168.22 5907466.24 N 368090.69 E t.112 4225.17 590748.9.28 N 368149.42 E '[.112 4287.38 5907510.65 N 368206.57 I:: 1.112 4348.16 5907532.35 N 368262.12 E 1.112 4407.48 5907554.36 N 368316.04 E 1.112 4465.33 5907576.68 N 368368.32 E 1.112 4521.66 5907579.81 N 368375.45 E 1.112 4529.37 5907599.30 N 368418.93 E 1.112 4576.48 5907614.90 N 368452.48 E 1,112 4612,98 5907622.22 N 388467.86 E 1.112 4629.75 5907645.42 N 388,515.09 E 1.112 4681.46 5907651.4,5 N 36852.7.00 E 1.112 4694.56 5907668.89 N 368560.59 E 1.I ~2 4731.58 5907672.50 N 368567.40 E 1.'['12 4739.11 5907692.53 N 368604.37 E 1.112 4780.08 5907710.77 N 368636.93 F__. 1.112 4816.33 Afl data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vedical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is [n Degrees per 100ft. Vedica[ Section is from Well Reference and calculated along an Azimuth of 73.484° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12477.10ft., The Bottom Hole Displacement is 4816.33ft., [n the Direction of 73.484° (True). Alaska State Plane Zone 3 Badami CPF Comment Stad Dir @ 6.000°/'t00lt: ~ 1043.72tt MD, 9314.13ft TVD BHA Tendency @ 1.~12'/100ff: 11310.391l MD. 9491.99ft TVD F4 F5 A5 Ta:get: B1-25 Targe[(607438), 200.00 Radius., Ddllers Total D .e,pth - 12477.10,'1. MD, 10454.80ft TVD 4 1/2' Liner Conlinued... 7 October, 1998 - 14:56 .4- DritlQuest Sperry-Sun Drilling Services Proposal Report for B 1-25 Wp8 Badami Alaska State Plane Zone 3 Badami CPF z Comments Measured Station Coordinates Depth TVD Norlhings Eastings (ft) (U) (fi) (ft) 300.00 300.00 0.00 N 0.00 E 700.00 699.68 13.82 N 1.94 E 800.00 799.43 20.73 N 2.91 E 1200.00 1199.11 34.55 N 4.86 E 2877.85 2876.95 34.55 N 4.86 E 5200.89 5200.00 34.55 N 4.86 E 6550.89 6358.83 158.32 N 582.19 F: 9999.05 8574.80 797.48 N 3141.17 E 10654.6:3 9054.80 934.05 N 3565.73 E 10714.63 9100.86 947.03 N 3601.93 E 10983.72 9280.56 1014.08 N 3789.38 E 11043.7:2 9314.13 1030.84 N 3835.22 E 11310.39 9491.99 1097.37 N 4022.21 E 12477.10 10454.80 1369.t9 H 4&17.62 E Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings (tt) Ct) (~) (~) 2005.69 2004.80 1950.00 34.55 N 7822.67 7132.80 7078.00 381.60 N 9431.21 8184.80 8t30.00 685.01 N 9854.75 8474.80 8420.00 768.64 N 9999.05 8574.80 8520.00 797.43 N Comment Slari Dir @ 1.000°/100ft: 3O0.00ft MD, 300,O0~t TVD End Dir: 700.0011 MD, 699.68ft TVD Start Dir @ 1.000~/1 0Ott: 800.OOfl MD, 799.43tt 'I'VD End DIr: 1200.001t MD, 1199.1111 TVD Sail @ 0.000° Inclination or~ 358.971" AzimuUi Stad Dir @ 4.000"/100It: 5200.8911 MO, 5200.001t TVD BHA Tendency @ 0_250"/10011: 6550.89,'1 MD, 6358.8311 TVD BHA Tendency @ 1.000°/100~t: 9999.05fl MD, 8574.80tt TVD End Dir: 10654.63ft MD, 9054.80tl 1-VD Star~ Dir @ 6.000°/100ft: 10714.6311 MD, 9100.8§ft ]'VD End Oir: 10983.72>ft MD, 9280.58117VD Stad I}ir @ 6.000°/10011: 1104..3.72ft MD, 9314.1311 'I'VD BHA Tendency' @ 1.! 12°/100ft: 11310.39ft MD, 9491.99ft TVD Total Depth: 12477.1Ott MD, 10454.8011 TVD Eastin§s Formation Name (fi) 4.86 E Base Permafrost 1566.13 E Top Mid Brookian 2744.07 E 3041.2l E Base We.si Sak (M85) 3141.17 E Top Cann[r[[f CohO'hued... October, 1998 - 14:E6 -5- DriltQuest Sperry-Sun Drilling Services Proposal Report for B1-25 Wp8 Badami Measured Vertical Sub-Sea Depth Depth Depth (it) (ft) (ft) Formalion Tops (Continued) 10787~7 9~54.80 9100.00 11913.89 9973.80 9919.00 12068.19 10102.80 $0048~0 12225.82 10236.80 10182.00 123t5.29 10313,80 10259.00 Northings 953.41 N 1233.56 N 1270.02 N 1307.91 N 1329,68 N Eastin[ts (fi) 3647.71 E 4358.52 E 4434.91 E 4508.77 E 4,548.78 E Formation Name Shallowest Badami Sand F3 F4 F5 A5 Alaska Slate Plane Zone 3 Badami CPF Casing details From Measured Depth (ft) <Sue'fa. ce.> <Surface> <Su dace> Vertical Depth <Surface> <Surface> <Surface> To Measured Depth 4555.69 10 ~54,63 12477.10 Vertical Depth 4554.8O 9054.80 10454.80 Casing Detail 9 5/8' Casing 7' Casir~g 4, lf2' Lfrter Continued... 7 October, 1998 - 14;56 -6- DfiflQues! NON 08:54 I~U IbU~O Ibq F, U~_ Shared Services Drilling Mike Cook The above mentioned well h~s been scanned using sta~dazd anti.collision methods via DE.AP, 5631 Siiverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Approved Well Close Approach Review 35.30' 14,329,42' 2(20.00' 103,00' Anti. Collision Scm summnry: At the planned KOP the Starting Sc,~ Radius is 98,235' larger than DEAP's default settings of 103 ' Sea.d, Sc. art Radiu~ incr¢~ing at 50' per 1000 'MD for a new-drill well sca.n, thus DEAP's defaults would bo ~xlual to 101.765' at the Start Scan Inspection Zone as stated above. These numbers axe used to Froduce a final scan radius of 1629,412' which is 812,941' larger than DF. AP's default value of 816.471' Scan Parameters Comments: · , · [ Il I _ I i l[ I [ I Il l At t'hi~ ent~.rged r~i~ the loll'owing w¢ll~ were detected d~ng ~ ~ ~d °n cl~t~AHoW%lc De~ion ~om N'ote: c~Js list may not includ~ all ~ well~ ~t~d, oM~ thee of wMch ge of coa~m ~ m~ eff~ Tolet~ Linc ~0mPadson $~_bJ~ Well Pl~n~ Well Rela~ve ~ Shut-l~R~rM? (Se~radon Wvll: De~th Se~mHon A~mu~ De.~a~oq m ,, ~tntus, as Tested BI-0i 598.63 'MD 240.45 ' 265.80 ° 234.92 ' No MINOR BI.Il BI.14 Bl-14 4691.88 'MD B 1-ISL1 499,73 'MD BI-15LI 5197.12 'MD ~ i~i6PB i ' 400.25'MD BI-16PB1 2570.34 'MD B t-18 599,79 'MD BI.18 5480.20 'MD B1-21 200.10'MD B1-2I 3163,86 'MI) B 1.28 599,64 'MD B1.28 2693,29 'MD 400.45'MD 140.43 ' 268.00 ° 136.54 ' No MINOR MINOR No MINOR No MINOR No MINOR No MINOR No MINOR No MINOR No MINOR No MINOR No MINOR No MINOR No MINOR 403.30'MD 110.78 ' 269,20 ° 106.87 ' No 166.4 8 100,81 124,83 92,75 30.07 69.95 145,95 40,17 94,35 30,23 128,24 317.70 , 266.50 264.10 269,50 292,90 127,38 96,18 83.99 88.15 13,92 64.53 107.60 38,54 74.98 25,43 112.34 266,60 ' 214.90 ° 270.20 · 126,20 ' _ 10~.90 '- _ 143,10 ' , , , I IJ i il i , Il , , il i i · , l lll , il , , i , , ,1 1, Tolerance Plot required: Yes Close Approach Comments: We hove o very close o..pproach with BI-16 at the 2400- 3000 MD oreo, I will talk to our drillers before they, _go up and have them nudge away from that oreo sli,qht,ly to 9void any interference yet s. tlll remain on our nudf~e orofaram. Close Approach Scan Performed by: Date: C'h ecked by: Date: Approved by: Date: Shared Services Approval; i ii Il I I I , al-2$.xls _AWD Proximity Rovlow Date: · WELL PERMIT CHECKLIST FIELD & POOL_ ..... bUl¥1 I--A~i~I ~I --Z~ INIT CLASS ,,,/~ /,--,~,% .......... GEOL AREA ~~, UNITff .......... /~_~_O-.~ ......... ON/OFF SHORE ............................ N N _ N N N N N N Conduclor string provided ................. ~ N .......................... Su~ face casing protects all known USDWs ......... ~..~ N CM f vol adequate to circulate on conduclor & surf csg ..... ~ ..................................................... ........ ~,' N -~-~ .............................................. ~ '~'~-'~ Is presence of H2S ~as probable ................. '~e, nfi~ can be issued w/o hydro~en sulfide meast.'es. . I,)~l~ p~esemed on potential ouerpress~.'e zones ..... Y ScismJc analysis el shallow gas zones. Seabed condition survey (if off-shore) ........ N N ..................... Contact name/phon~ Jor weekly progress ~epo~ts .... ~ Y [explorato~ only] ' ADMINISTRATION i Pelnfit fee attached ....................... 2. lease number appropriate .................. 3 Unique well name and number. 4 Well Iocaled in a defined pool ............. 5 Well Iocaled proper dislance from drilling unit botuMa~y. 6 Well Iocaled proper distance from other wells ..... 7. Stlfficienl acreage available in drilling tl~fil 8 If deviated, is wellbore plat included 9 Operator only affected pady ............. 10 Operator has appropriate bond in force ............. 11 Permit can be issued without conservation order ........ 12 Perlnit can be issued without administrative approval 13. Can permit be approved before 15-day wait ........... ENGINEERING A P I':' !'~, D A,]tE 14. 15. 16. 17 CMl vol adequate to tie-in long string to sLIrf csg ....... 18 CMI will cover all known productive horizons .......... 19. Casing designs adequate for C. T. B & permah'ost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment beel~ approved.. 22. Adequate wellbore separation proposed ............. 23. If diverler required, does il [neet regulations .......... 24. Drilling fluid program schematic & equip list a(:le(luale .... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~,~~.~:> psig. 27. Choke manifold complies w/APl RP-53 (May 84) 28 Work will occur without operation shutdown ........... 29. Y N Y N Y N G_E_O.__koo_Y_ 30 3'1 32 33 !~ I)A,1 I.! ? ...... X~'~X~"'~i§~;'G~Xi 55. ~ii}i proper cementing records, this plan (^) will contain waste in a suitable receiving zone; ....... APPF.~ I)A'I E! (B) will I~ot contaminate freshwater; or caL~se drilling wasle... 1o stir'face; ((;) will l~ol impair mechanical inlegrily of the well ,Jsed for disposal'. (I)) will ~ol damage pro(hming formation ol i~ff)air recovery honl a pool; a~d ..-...-._ ..... _=(F~_wi!/nol ci,'cun]vent~;~ ~;.;;~ 20 AAO 25.252 or 20 AAC 25.412. Y N GEOt. OGY' E_N._G_!H_E_.E B !..N_O.: UlC/.A.n.~]uLar ................. ,JDH M nh,,I,,h!;I I,'v COMMISSION: RNC ...... : ..... ~ co ._~-~].,.._¢. TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 26, 1998 Dan Stoltz Drilling Superintendent BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Badami Unit B 1-25 BP Exploration (Alaska) Inc. Permit No. 98-153 Sur. Loc.: 38572qSL, 17~/'EL. Sec. 8, T9N, R20E, UM Btmhole Loc: 71~NSL. 1883~3JEL, Sec. 4, T9N. R2.0E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your request for a diverter waiver is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035· Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission max, xxstness the test. Notice may be,,gi~y contacting the Commission petroleum field inspector on the North · · BY ORDER OF THE COMMISSION dlf/enclosures cc: Department of Fish & Game. Habitat Section wfo encl. Department of Environmental Conservation w/o encl. , ~ STATE OF ALASKA .~., ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 DIVERTER WAIVER REQUESTED Ila. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] StratigraphiC Test [] Development Oil1 l--IRe-Entry .ElDeepen[ []Service [] Development Gas I-'lSin~lleZone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska)Inc. Plan KBE = 54.8' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL365533 , 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3857' NSL, 17' WEL, SEC. 8, T9N, R20E, UM Badami Unit At top of productive interval 8. Well Number Number 2S100302630-277 16' SNL, 1443' WEL, SEC. 9, T9N, R20E, UM B1-25 At total depth 9. Approximate spud date Amount $200,000.00 71' NSL, 1883' WEL, SEC. 4, T9N, R20E, UM 09/10/98 12. Distance to nearest property line113. Distance to nearest well ;14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 367011,3397' .I 131-28, 25' at 600' MD 5120 12191' MD / 10504' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.0'35 (e) (2)} Kick Off Depth 10780' MD Maximum Hole Angle 49° Maximum surface 4400 psig, At total depth (TVD) 10094' / 6326 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.) , , , 12-1/4" 9-5/8" 40# L-80 BTC 4521' 35' 35' 4556' 4555' 2755 sx PF 'E', 385 sx Class 'G' 8-1/2" 7" 29# Pl10 BTC-Mod 10428' 33' 33' 10461' 9054' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC 2208' 10311' 8935' 12191' 10504' Uncemented slotted liner 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 Intermediate Production Liner ~\ , ~= ~ Perforation depth: measured A~aS~(8 0il & Cas Cons. C0i~r~issior' true vertical Anch0r~ge 20'. Attachments [~ Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis []Seabed Report [] 20 AAC 25.050 Requirements .... , , , Contact Engineer Name/Number: Mike Miller, 564-5066 Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby certify tha¢¢e foregoing is true and correct to the best of my knowledge Signed OanS~"~~f//~~ Title Drilling Superintendent Date y- . . uommms~on Use Only Permit Number J APl Number I A~~'¢%~ I See c°ver letter ~ ¢ - ! .~' ~ 50- 0 & c~ .. ~, ,~, ¢~ 0/~ for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required []Yes [~'No Hydrogen Sulfide Measures I--lYes ~rNo Directional Survey Required ~.Yes ['-INo Required Working Pressure for BOPE []2M; []3M; [~5M; []10M; []15M Other: u~ ,,~,~i'~! bigl!~;tl dy by order of Approved By David W. J0hnst0r~ Commissioner the commission Date Submit In Triplicate , , STATE OF ALASKA ALASIO,, ulL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 DIVERTER WAIVER REQUESTED la. Type of work l~ Drill I--IRedrill Ilb. Typeofwell I--IExploratory I-'lStratigraphicTest [~ Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 54.8' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL365533 / 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3857' NSL, 17' WEL, SEC. 8, T9N, R20E, UM Badami Unit At top of productive interval 8. Well Number Number 2S100302630-277 16' SNL, 1443' WEL, SEC. 9, T9N, R20E, UM B1-25 Attotal depth 9. Approximate spud date Amount $200,000.00 71' NSL, 1883' WEL, SEC. 4, T9N, R20E, UM 09/10/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 367011,3397'I B1-28, 25' at 600' MD 5120 12191' MD / 10504' TVD 1 (J. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 10780' MD Maximum HoleAngle 49° Maxirnumsurface 4400 psig, At total depth (TVD) 10094'/6326psig 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) 24" 20" 91.1# H-40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4521' 35' 35' 4556' 4555' 2755 sx PF 'E', 385 sx Class 'G' 8-1/2" 7" 29# Pl10 BTC-Mod 10428' 33' 33' 10461' 9054' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC 2208' 10311' 8935' 12191' 10504' Uncemented slotted liner 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,_r~ Conductor S u trace Intermediate Liner Production ~\~ECEIVED Perforation depth: measured Naska 0il & Gas Cons. Commission true vertical Anchorage , ,, 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mike Miller, 564-5066 Prepared By Name/Number: Carol Withey, 564-4114 21 I hereby certify tha¢~e . foregoing is true and correct to the best of my knowledge Signed s ' _~~__~..~, ~ Da, Title Drilling Superintendent Date V,~" '~ 'f~ ! I;~ommission Use Only Permit NuEnber I APl Number Approval Date I See cover letter c~ ~. ] ~' 3I 50- 0 ~.~/-.- A ~ oJ (2 re ~_~_~,~_ _..~K___~, for other requirements Conditions of Approval: Samples Required []Yes I~No Mud Log Required I--lYes []No Hydrogen Sulfide Measures []Yes I~ No Directional Survey Required J~Yes F-lNo Required Working Pressure for BOPE []2M; [-13M; 1~SM; I--ll0M; I--I15M Other: d~'!t.j:,i-~: 5igP, Sd [:3y by order of Approved By DO, Vid W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate B 1-25 Producer - Multi-lateral "-- ,- PERMIT B1-25 - HOLE//3 - PRIMARY WELLBORE - Third penetration below intermediate casinu: I TD MD: I12191 I lTD TVDBRT: 110504 I Badami Sand F5 Primary 16'FNL 1443' FEL SEC 9, T9N, R20E, UM, AK target Bottom Hole Location (TD) 71' FSL 1383' FEL SEC 4, T9N, R20E, UM AK Formation Markers: Formation Tops MD TVD (bkb) Remarks Shallowest Badami Sand 9154 10590 Badami Sand F3 9964 11581 Badami Sand F4 10099 11734 Badami Sand F5 10214 11864 Primary Sand Badami Sand A5 10369 12039 Total Depth 10504 12191 Casing/'l'ub lng Program: Hole ~ize Cs'g/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD brt 6" 4-1/2" 12.6# L-80 BTC 2208 10311/8935 12191/10504 slotted liner (7" toTD) Tubing 4-1/2" 12.6# L-80 IBT 11767 33/33 10211/8863 Mod. Logging Program: Production Hole RFT Cased Hole Logs: MWD G R/Resistivity none none Directional: KOP' J 10780'md/9292'tvd @ 49 deg. Maximum Hole Angle: Close Approach Well: 49deg @ kickoff point B1-25 L1 & B1-25 L2 B 1-25 Producer - Multi-lateral PERMIT Badami B1-25 Multi-lateral Proposed Summary of Operations 1. Weld the starting head on the conductor. 2. Prepare the location for the rig move. 3. MIRU Nabors 28E drilling rig. Build spud mud. A diverter waiver is requested from AOGCC. 4. PU 12-1/4" bha& drill surface hole as per directional plan. Run directional MWD from surface to TD. 5. Run 9-5/8" surface casing and cement to surface in two stages. 6. NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi. 7. RIH with BHA, test casing to 3000 psi. Drill out float equipment and 20' of new formation. Perform a LOT as per SSD Standard Operating Procedure. Contact the Badami Drilling Team Leader or SSD Superintendent with LOT test results before drilling ahead. 8. Drill 8-1/2" hole to intermediate casing TD as per directional plan, with MWD directional surveys. 9. Run 7" casing and cement as per Cement Procedure (1000' md of cement above shoe). Test BOPE to 6000 psi. 10. RIH w/6" BHA, test 7" 29# P110 csg. to 3500 psi. Drill out float equipment and 20' of new formation. Perform FIT to 13.5 ppg minimum equivalent. 11. Drill 6" hole to B1-25 L1 - [Hole #1] target TD as per directional plan with GR/Resistivity MWD. Utilize latest techniques for reducing lost circulation risk (tapered string, flow rate limitations, ECD limits, mud rheology, etc.). Run open hole logging surveys: triple combo 12. Displace open hole to above KOP for B 1-25 L2 [Target #2] to kill-weight, hi-vis water based mud w/5% KCL If insufficient interval of amalgamated pay exists as determined by logs, no slotted liner will be run in this hole. If a sufficient interval of amalgamated pay exists as determined by logs and petrophysicist, run 4-1/2" slotted liner from TD to just above the top of the amalgamated pay (exact depths to be determined from logs). [This will leave open hole above top of slotted liner]. Set liner on bottom, release from liner with HES hydraulic setting tool. POOH. 13. RIH with BHA and perform open-hole, low-side kickoff. Use most aggressive BHA design to get off (tricone or PDC sidetrack bit, 2.38 motor housing bend, etc.) Drill to B 1-25 L2 [Hole #2] target TD as per directional plan with GR/Resistivity MWD. 14. Displace open hole to above KOP for B 1-25 [Target #3] to kill-weight, hi-vis water based mud with 5 % KCL. If insufficient interval of amalgamated pay exists as determined by logs, no slotted liner will be run in this hole. If a sufficient interval of amalgamated pay exists as determined by logs and petrophysicist, run 4-1/2" slotted liner from TD to just above the top of the amalgamated pay (exact depths to be determined from logs). Set liner on bottom, release from liner via hydraulic releasing tool. POOH. 15. RIH with BHA and perform open-hole, low-side kickoff. Drill to B1-25 [Hole #3] target TD as per directional plan with GR/Resistivity MWD. This will be designated the primary wellbore. 16. Displace open hole to above KOP for B1-25 [Target #3] to kill-weight, hi-vis water based mud with 5% KCL. Run 4-1/2" slotted liner from TD to above top of shallowest sand, and blank 4-1/2" liner from above top of shallowest sand to 150' inside the 7" intermediate casing. Release from liner via Baker Oil Tools hydraulic releasing tool. POOH. B 1-25 Producer - Multi-lateral -. :, PERMIT 17. RIH with 4-1/2" completion assembly with 3.813" PXN plug in place in "XN" nipple. Fill tubing with 50 bbls of viscosified spacer followed with 8.34# fresh water while running in hole. Position Halliburton "TNT" packer setting depth to +/- 100' md above 4-1/2" liner tieback extension. Record pick up and slack off weights prior to setting HES "TNT" permanent packer. 18. M/U connect 2 ea. 'fi" control lines ( 316 SS 0.049" wt.) to WLRSV landing nipple. M/U control lines to FMC 4-1/16" 10 M tubing hanger. Test control lines to 5000 psi - hold pressure for 10 mins. 19. Land FMC 4-1/16" 10 M tubing hanger and RILDS (14 ea.) to energize FMC tubing hanger packoff assembly. 20. Pressure up tubing to 500 psi. Shut down and monitor pressure for leaks. Pressure tubing to 7000 psi to set HES "TNT" permanent production packer. Reduce pressure to 3500 psi. Hold pressure for 30 minutes and record on Barton recorder chart as 4-1/2" tubing pressure test. Maintain 4-1/2" tubing pressure at 3500 psi and pressure up 4-1/2" x 7" annulus to 3500 psi:. Hold pressure for 30 minutes and record on Barton recorder chart as 4-1/2 "x 7" annular pressure test. Bleed 4-1/2"x7" annulus pressure off prior to bleeding down tubing pressure. 21. Back out and L/D landing joint. Install "two way" check valve in FMC 4-1/16" 10M hanger profile. 22. Nipple down 13-5/8" 10 M Hydril BOPs. Nipple up the FMC 11" 10M x 4-1/16" 5M tubing head adapter and Cameron 4-1/16" 5M tree. Test control line to 5000 psi. Test the tubing head adapter and Cameron 4-1/16" 5M tree to 5000 psi. Pull the "two way" check valve. Orient tree wing valve and S-riser/downcomber as per Badami orientation diagram. 23. Pressure up on 4-1/2" x 7" tbg/csg, annulus - shear RP valve in lower GLM station. RP shear valve requires 2900 psi of differential pressure to shear. Calculated surface annular pressure to shear "open" the RP shear valve is +/- 1200 psi. 24. Pump down 4-1/2" 12.6# IBT L80 tubing to displace mud from the 4-1/2"x 7" annulus. Maximum displacement rate = 3 bpm through RP valve. Freeze protect well with diesel by "U" tubing from annulus side to tubing side. 25. Install BPV. Secure well. RD/MO Nabors 28E rig, release rig. Transfer custody of well to Operations. After rig release: 26. R/U slickline. Pull WLRSV dummy. 27. RIH w/slickline and retrieve RP valve in lower GLM, pooh., RIH w/ slickline w/dummy valve, and locate in lower GLM sidepocket. 28. RIH w/ slickline and pull pressure equalizing prong in "PXN" plug. Pull "PXN" plug body. Caution: Be aware of differential pressure below "PXN" plug during pulling operations - adjust for downhole differential pressure with equal surface pressure. 29. RIH w/ WLRSV and locate in HXO landing nipple. B 1-25 Producer - Multi-lateral PERMIT Badami B1-25 CASING SIZE: 9-5/8" SPACER: SURFACE CASING CEMENT PROGRAM - HALLIBURTON 100 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 255 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from 1000' above the casing shoe to the ES cementer at 2200' md, plus 30% excess. Premium 2% calcium chloride 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 385 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of fill in the gauge hole plus 30% excess plus 80' shoe joint. SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 2500 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX NO SACKS: To be determined on job x job basis MIX WATER: 11.63 gal/sk B 1-25 Producer- Multi-lateral PERMIT INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 7" SPACER' 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 185 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. MULTI-LATERAL WELL ABANDONMENT PROGRAM The following program is to be used at such time as the wellbores below the 7" intermediate casing are to be abandoned. 1. MIRU Rig. 2. Kill Well. 3. Pull tubing, packer, completion. 4. RIH with 7" EZSV cement retainer and set 50-100' inside the 7" intermediate casing and above all perforations in the 7", if any exist. 5. Mix and pump a volume of premium class G cement to fill the 7" casing below the EZSV and the calculated volume to fill the entire hole section of all wellbores below the 7" shoe, plus 10%. 6. Unsting from EZSV. 7. Pressure test the EZSV and cement to 3000 psi. 8. Procedures for the remainder of the wellbore above the EZSV will depend on the future plans for the wellbore (total abandonment, sidetrack, etc.). 10 B 1-25 Producer - Multi-lateral Shared Services Drilling Contact: PERMIT Mike Miller 564-5066 I Well Name: I B1-25 Badami I Well Plan Summary DATA COMMON TO ALL THREE PENETRATIONS (PRIMARY AND BOTH LATERALS): I Type of Well (producer or injector): I Surface Location: Producer- Multi-Lateral Open-Hole 3857' FSL 17' FEL SEC 8, T9N, R20E, UM, AK Estimated Start Date: IKBE: 154.8 I Sept. 10 1998 I I Operating days to complete: 1 45 Well Design: I Ultra slimhole- multi-lateral open hole completion w/slotted liner Formation Tops MD TVD (bkb) Remarks base permafrost 2005 2004 Top Middle Brookian (TMBK) 7619 7132 M90 9228 8184 Base West Sak (M85) 9655 8474 Casing/Tubing Program: Hole §ize Csg) Wt/Ft Grade Conn Length Top Btm Tbg O.D. . MD/I'VD MD/TVD brt 24" 20" 91.1# H-40 Weld 80 37/37 116/116 12-1/4" 9- 5/8" 40# L-80 BTC 4521 35/35 4556/4555 8-1/2" 7" 29# P 110 BTC- 10428 33/33 10461/9054 mod Internal yield pressure of the 7" 29#/ft P110 casing is 11220 psi, which is greater than the maximum anticipated surface ,p, ressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/ft, surface to 6570'; oil, 0.36 psi/fi, 6570 to 10094 tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. Log~ling Program: Open Hole Logs' Surface Sidewall cores · 30ea. planned ( 2500' md - 4500'md) Intermediate MWD/GR @ hole section TD Mud Program: B 1-25 Producer - Multi-lateral PERMIT Special design considerations I displace OH laterals to 5% KCL water based muds Surface Mud Properties: i Density Marsh Yield 10 sec 10 min pH Fluid (PPG) , . Viscosity Point gel gel Loss 8.6 150 25 20 45 9 10 to to to to to to to 9.8 - 10.0 300 60 30 60 9.5 1-5 intermediate Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel geI Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to 1 o. 1 55 20 10 25 9.5 4-6 Production Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 12.0 45 10 8 15 8.5 4-5 to to to to to to to 12.4 55 15 10 20 9.5 4-5 Well Control (Secondary) · Diverter Waiver Requested Well control equipment consisting of 10,000 psi W.P.(2) pipe rams, (1) blind rams, and 5M WP annular preventer will be installed and is capable of handling maximum potential surface pressures.10 M WP Choke & kill manifold. BOPE and drilling fluid system schematics on file. Waste Manaqement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Annular Injection: No annular injection is planned at this time. DRILLING HAZARDS AND RISKS: Wellbore proximity comments are addressed under each MLOH section. Junk (auger tooth) was encountered in the B1-16 conductor - if junk is encountered, ensure all junk is fished prior to commencing drilling. Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Badami sands are overpressured - normally 12.2ppg mw required at TD. Pressure transition begins just above shallowest sand. Shallow sands typically pressured between normal and the 12.2 ppg required in lower sands. Maintain minimum mud weight and utilize latest techniques to manage lost circulation hazards in shallow sands (flow rates, tapered drill string). Weight up as wellbore pressures dictate, maintaining a 200 psi overbalance throughout. - BI-25 Producer- Multi-lateral - PERMIT Hazards of well control and stuck pipe are managed by setting 7" casing above shallowest sand, before penetrating the full overpressure. Hazard of lost circulation is managed by proper techniques to maintain Iow ECD - ECD of 13.5 ppg noted to be maximum allowable to prevent lost circulation. . scale: linch · 400ft . ' Eastings ; . 3200 3800 4000 ' 4400 4800 '1'8oo- I I I I I - 18oo z ! z 1000 ~s~.94ft MD, 0593.35ft 'rVD - ~000 ~ 0 .~ "He-on, Start Dtr ~2 8.000'/~00ft: 10760. Oft MD, 9292.10ft 'I'VD-- ~ 7" Casing - 10481.22 MD, 9054.80 TVD I I I I I 3200 3500 4000 4400 4800 Scale: 'linch - 400ft Eastings Reference i~ True North -: Prel~al Data f~' B1.25 Wp41.2 9000 - 1~o~o~ Casing - 10461.22 MD, 0054.80 TVD - ~ ............. Shallowcst B~dami Sand - 9154.80 'TVD : Proposal Target Summary '-w------- ..... ~.~_-Tle-on, Start Dtr ~} 8.000'/100ft: 10780.00ft MD, 9292.10ft TVD . r.,z~]~-.: ~/D.~ ~ w.~t~,aorr,.,,: ..... '~ itl-25 L2 TI . 10248.00 1030180 1401.62 N, 3848.67 Il 5907163.o0 N, 36786~.8o E 9400 -~ooo.oo~ ' ~.~End mr, Sa, e 27.755':~1~81.04, UO, ~593.35, TVD i SURFACE 'LOCATION- PLOT b-A-~-E-.;- 9800- ' ~4oo.oo~~ - , .,~% ...... ~.--.,o~ ' FOE PERMITTING ONLY - F$ 10214 80TVD 2.80 TVD - 1407.62 N, 3848.67 E ...... 3.5 - 10369.80 TVD ~o6oo - 4 ~12' IJnor - 121~1.8~ MD, 10§04.80 TVD 800 1200 1600 2000 Scale: linch = 400ff Section Azimuth: 358,971' (True North) Vertical Section .. --- Sperry-Sun Drilling Services Proposal Report for B1-25 Wp4 L2 FOR PERMITTING ONLY Badami Measured Depth (ft) 10780.00 10800.00 1O900.00 11000.00 11100.00 11161.94 11200.00 t 1300.00 11400.00 11500.00 11581.68 11600.00 11700.00 11734.23 11800.00 11864.19 11900.00 11963.63 12000.00 12039.34 12100.00 12191.89 Incl. 49.082 47.752 41.316 35.393 30.295 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 27.755 Azim. 70.958 69.770 62.977 54.283 42.873 34.089 34.089 34.089 34.089' .... 34.089 . 34~89 34.089 34.089 34.089 34.089 34.089 34.089 34.089 34.089 34.089 34.089 34.089 Sub-Sea Depth (ft) 9237.30 '9250.57 9321.86 9400.30 9484.37 9538.55 9572.23 9660.73 9749.22 .9837.72 9910.00 9926.21 10014.70 10045.00 10103.20 10160.00 10191.69 10248.00 10280.19 10315.00 10368.68 10450.00 Vertical LOcal Coordinates Depth Northings Eastings (ft) (ft) (ft) 9292.10 93O5.37 9376.66 9455.10 9539.17 9593.35 9627.03 9715.53 9804.02 9892.52 9964.80 9981.01 10069.50 10099.80 10158.00 10214.80 10246.49 10302.80 10334.99 10369.80 10423.48 10504.80 974.75 N 3448.62E 979.78 N 3462.71E 1007.62N 3526.95 E 1039.58N 3579.96E 1075.02 N 3620.69E 1098.43 N 3639.42 E 1113.11N 3649.35 E 1151.68N 3675.45 E 1190.25 N 3701.56E 1228.81N 3727.66E 1260.32 N 3748.98E 1267.38 N 3753.76 E 1305.95 N 3779.86E 1319.15 N 3788.79 E 1344.52 N 3805.96E 1369.27 N 3822.71 E 1383.08 N 3832.06 E 1407.62N 3848.67E 1421.65 N 3858.16 E. 1436.82 N 3868.43 E 1460.22N 3884.26 E 1495.66N 3908.25 E Global Coordinates Dogleg Vertical Northings Eastings 'Rate Section fit) (ft) (°/100ft) fit) R.(~7RRT_RR N RR74R1.134 F 912.C-~ 5907342.15 N 367475.22 E 8.000 917.44 5907368.84 N 367539.95 E 8.000 944.12 5907399.84 N 367593.52 E 8.000 975.12 5907434.55 N' 367634.89 E 8.000 1009.83 5907457.61 N 367654.03 E 8.000 1032.90 5907472.11 N 367664.23 E 0.000 1047.39 5907510.21 N 367691.02 E 0.000 ..1085.49 5907548.30 N 367717.81 E 0.000 1123.58 5907586.39 N 367744.60 E 0.000 1161.67 5907617.51 N 367766.48 E 0.000 1192.79 5907624.48 N 367771.39 E 0.000 1199.77 5907662.58 N 367798.18 E 0.000 1237.86 5907675.62 N 367807.35 E 0.000 1250.90 5907700.67 N 367824.97 E 0.000 1275.95 5907725.12 N 367842.16 E 0.000 1300.40 5907738.76 N 367851.75 E 0.000 1314.04 5907763.00 N 367868.80 E 0.000 1338.28 5907776.86 N 367878.54 E 0.000 1352.14 5907791.84 N 367889.08 E 0.000 1367.12 5907814.95 N 367905.33 E 0.000 1390.23 ,5907849.95 N 367929.95 E 0.000 1425.23 Alaska State Plane Zone 3 Badami CPF Comment Tie-on. Start Dir @ 8.000?/100ft ' 10780.00ft MD: 9292_10fl 'rvl3 · End Dir, Sail @ 27.755°: 11161.94ff MD, 9593.35ft TVD F3 F5 Tar,qet: B1-25 L2..T1,200.00 Radi.u.s., Driller~ A5 Total Depth · 12191.89ft MD, 10504.80ft TVD 7" ~'/'y 4 1/'2~ Liher 30 Jun~ 1998- 11:14 -1- Dr~lQuest Sperry-Sun Drilling Services Proposal Report for B1.25 Wp4 L2 Badami All data is in feet unless Otherwise stated. Directions and coordinates are relative to True North~ Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 358.971 ° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12191.89ft., The: Bottom Hole Displacement is 4184.66ff., in the Direction of 69.058" (True). , FOR PERMITTING ONLY Alaska State Plane Zone 3 Badami CPF 30 June, 1998 - 11:14 -2- DnTIQuest RUG-03-98 NON 08:54 Rl'i SFEt~F,Y-;gUN flLflSttfl Ut" Shared Services Drilling Mike Cook Mike, The above mentioned well h~ been scanned using standaxd anti-collision methods via DEAP. I The sc~'m was performed with the following parametebs: Start Scan Inspection ~one End Scan Inspection Zone Starting Scan Radius l~te o£ Radius Increase (per 1000') 35.30' 14,329.42' 200.00' 100.00 ' 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Approved Well Close Approach Review Badami/B1-28 Wp4 Anti-Collision Scan summary~ At the plannexi KOP the Starting Scan Radius is 98,235' larger than DEAP's default settings of 100' Start Scan Radius increasing at 50' per 1000 'MD for a new-drill well scan, thus DEAP's defaults would be equal to 101.765' at the Start Scan Inspection Zone as stated above. These numbers axe used to ~oduce a final scan radius of 1629,412' which is 812,941' larger than DEAP's default value of 816,471' Scan Parameters Comments: ii ii i i _ i i ii ii At this enlarged radius the following welts Were detected during the scan (Based on closest 'Allowable Deviation from Plan')', Note: this list may not include all the wells detect~d, only those of which are of concern or m~/effe~-'t Tolera.nc~ Line drawing{ Cpmparison S~bJect Well Planned Well Relative ~l]owable, Shut-In Required? (SeperaQon notes~ Status W~]I: Devth ~eoeration Azimutll Devtatlorl as Texted ('= Extslln~ Su~ve~ ('= W¢~ Plan MD) (point lo PenNi (TC Dirtcllon) L4v~rox. TL Dt.q) BI-O1 598,63 'MD 240.45 ' 265.80 ° 234.92 ' No MINOR BI.I 1 400.45'MD 140,43 ' 268.00 ° 136.54 ' No MINOR / B1-14 400,30'MD 110.78 ' 269,20 ° 106.87 ' No MINOR Bl-14 4691.88'MD 166.48 ' 317.70 ° 127.38 ' No MINOR BI-15L1 499,73'MD 100,81 ' 266.50 ° 96,18 ' No MINOR "BI-15L1 5197,12'MD 124,83 ' 264.10 ° 83.99 ' No MINOR BI-16PB 1 400.25 'MD 92,75 ' 269,50 · 88,15' No MINOR ~ BI-16PB1 2570.34'MD 30.07 ' 292.90 ° 13,32 ' No MINOR ~' B1-18 599.79'MD 69.95 ' 266,60 ° 64.53 ' No MINOR Bl-18 5480.20 'MD 145.95 ' 214,90 ° 107.60 ' No MINO~ ~, B1-21 200.10'MD 40,17 ' 270.20 ° 38.54 ' No MINOR B1-21 3163,86 'MD 94,35 ' 126.20 ° 74.98 ' No MINOR ' B1-28 599.64'MD 30.23 ' 104.90 ° 25.43' No MINOR B1,28 2693.29'MD 128.24 ' 143,10 ° 112.34 ' No MINOR i i I i I i i i ii i i i Tolerance Plot required: Yes Close Approach Comments: We have a very close approach with Bl-16 at the 2400 - 3000 MD area, I will talk to our drillers before they go up and have them nudge away from that area siigh,tly to avoid any interference yet still remain on our ,nudge pro~ram. i ii Close Approach Scan Performed by: ii i i i Date: Checked by: Date: Approved by: Date: Shared Services Approval: i I · i I i i Date: i · i B1-25.xls _ AWD Proximity Review 8/3/90 BI-25 Producer- Multi-lateral PERMIT B 1-25 - HOLE//3 - PRIMARY WELLBORE - Third penetration below 7" intermediate casing: I TD MD: I12191 I lTD TVDBRT: }10504 I Badami Sand F5 Primary target Bottom Hole Location {TD) 16'FNL 1443' FEL SEC 9, T9N, R20E, UM, AK 71' FSL 1383' FEL SEC 4, T9N, R20E, UM AK Formation Markers: Formation Tops MD TVD (bkb) Remarks Shallowest Badami Sand 9154 10590 Badami Sand F3 9964 11581 Badami Sand F4 10099 11734 Badami Sand F5 10214 11864 Primary Sand Badami Sand A5 10369 12039 Total Depth 10504 12191 Casing/Tubin9 Program: Hole §ize Cs'g/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. . MD/TVD MD/i'VD brt 6" 4-1/2'" 12.6# L-80 BTC 2208 10311/8935 12191/10504 slotted liner (7" toTD) Tubing 4-1/2" 12.6# L-80 IBT 11767 33/33 10211/8863 Mod. Logging Program: Production Hole RFT Cased Hole Logs: MWD GR/Resistivity none none Directional: KOP: J 10780'md/g292'tvd @ 49 deg. Maximum Hole Angle: J 49deg @ kickoff point Close Approach Well: J B1-25 L1 & B1-25 L2 B 1-25 Producer- Multi-lateral PERMIT Badami B1-25 Multi-lateral Proposed Summary of Operations 1. Weld the starting head on the conductor. 2. Prepare the location for the rig move. 3. MIRU Nabors 28E drilling rig. Build spud mud. A diverter waiver is requested from AOGCC. 4. PU 12-1/4" bha & drill surface hole as per directional plan. Run directional MWD from surface to TD. 5. Run 9-5/8" surface casing and cement to surface in two stages. 6. NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi. 7. RIH with BHA, test casing to 3000 psi. Drill out float equipment and 20' of new formation. Perform a LOT as per SSD Standard Operating Procedure. Contact the Badami Drilling Team Leader or SSD Superintendent with LOT test results before drilling ahead. 8. Drill 8-1/2" hole to intermediate casing TD as per directional plan, with MWD directional surveys. 9. Run 7" casing and cement as per Cement Procedure (1000' md of cement above shoe). Test BOPE to 6000 psi. 10. RIH w/6" BHA, test 7" 29g P110 csg. to 3500 psi. Drill out float equipment and 20' of new formation. Perform FIT to 13.5 ppg minimum equivalent. 11. Drill 6" hole to B1-25 L1 - [Hole gl] target TD as per directional plan with GR/Resistivity MWD. Utilize latest techniques for reducing lost circulation risk (tapered string, flow rate limitations, ECD limits, mud rheology, etc.). Run open hole logging surveys: triple combo 12. Displace open hole to above KOP for B 1-25 L2 [Target g2] to kill-weight, hi-vis water based mud w/5% KCL If insufficient interval of amalgamated pay exists as determined by logs, no slotted liner will be run in this hole. If a sufficient interval of amalgamated pay exists as determined by logs and petrophysicist, run 4-1/2" slotted liner from TD to just above the top of the amalgamated pay (exact depths to be determined from logs). [This will leave open hole above top of slotted liner]. Set liner on bottom, release from liner with HES hydraulic setting tool. POOH. 13. RIH with BHA and perform open-hole, low-side kickoff. Use most aggressive BHA design to get off (tricone or PDC sidetrack bit, 2.38 motor housing bend, etc.) Drill to B 1-25 L2 [Hole g2] target TD as per directional plan with GR/Resistivity MWD. 14. Displace open hole to above KOP for B 1-25 [Target g3] to kill-weight, hi-vis water based mud with 5% KCL. If insufficient interval of amalgamated pay exists as determined by logs, no slotted liner will be run in this hole. If a sufficient interval of amalgamated pay exists as determined by logs and petrophysicist, run 4-1/2" slotted liner from TD to just above the top of the amalgamated pay (exact depths to be determined from logs). Set liner on bottom, release from liner via hydraulic releasing tool. POOH. 15. RIH with BHA and perform open-hole, low-side kickoff. Drill to B1-25 [Hole g3] target TD as per directional plan with GR/Resistivity MWD. This will be designated the primary wellbore. 16. Displace open hole to above KOP for B 1-25 [Target #3] to kill-weight, hi-vis water based mud with 5% KCL. Run 4-1/2" slotted liner from TD to above top of shallowest sand, and blank 4-1/2" liner from above top of shallowest sand to 150' inside the 7" intermediate casing. Release from liner via Baker Oil Tools hydraulic releasing tool. POOH. B1-25 Producer- Multi-lateral PERMIT 17. RIH with 4-1/2" completion assembly with 3.813" PXN plug in place in "XN" nipple. Fill tubing with 50 bbls of viscosified spacer followed with 8.34# fresh water while running in hole. Position Halliburton "TNT" packer setting depth to +/- 100' md above 4-1/2" liner tieback extension. Record pick up and slack off weights prior to setting HES "TNT" permanent packer. 18. M/U connect 2 ea. %" control lines ( 316 SS 0.049" wt.) to WLRSV landing nipple. M/U control lines to FMC 4-I/16" 10 M tubing hanger. Test control lines to 5000 psi - hold pressure for I0 mins. 19. Land FMC 4-1/16" 10 M tubing hanger and RILDS (14 ea.) to energize FMC tubing hanger packoff assembly. 20. Pressure up tubing to 500 psi. Shut down and monitor pressure for leaks. Pressure tubing to 7000 psi to set HES "TNT" permanent production packer. Reduce pressure to 3500 psi. Hold pressure for 30 minutes and record on Barton recorder chart as 4-1/2" tubing pressure test. Maintain 4-1/2" tubing pressure at 3500 psi and pressure up 4-1/2" x 7" annulus to 3500 psi.. Hold pressure for 30 minutes and record on Barton recorder chart as 4-1/2 "x 7" annular pressure test. Bleed 4-1/2"x7" annulus pressure off prior to bleeding down tubing pressure. 21. Back out and L/D landing joint. Install "two way" check valve in FMC 4-1/16" 10M hanger profile. 22. Nipple down 13-5/8" I0 M Hydril BOPs. Nipple up the FMC 11" 10M x 4-i/16" 5M tubing head adapter and Cameron 4-1/16" 5M tree. Test control line to 5000 psi. Test the tubing head adapter and Cameron 4-1/16" 5M tree to 5000 psi. Pull the "two way" check valve. Orient tree wing valve and S-riser/downcomber as per B adami orientation diagram. 23. Pressure up on 4-1/2" x 7" tbg/csg, annulus - shear RP valve in lower GLM station. RP shear valve requires 2900 psi of differential pressure to shear. Calculated surface annular pressure to shear "open" the RP shear valve is +/- 1200 psi. 24. Pump down 4-1/2" 12.6# IBT L80 tubing to displace mud from the 4-1/2"x 7" annulus. Maximum displacement rate = 3 bpm through RP valve. Freeze protect well with diesel by "U" tubing from annulus side to tubing side. 25. Install BPV. Secure well. RD/MO Nabors 28E rig, release rig. Transfer custody of well to Operations. After rig release: 26. R/U slickline. Pull WLRSV dummy. 27. RIH w/slickline and retrieve RP valve in lower GLM, pooh., RIH w/ slickline w/dummy valve, and locate in lower GLM sidepocket. 28. RIH w/ slickline and pull pressure equalizing prong in "PXN" plug. Pull "PXN" plug body. Caution: Be aware of differential pressure below "PXN" plug during pulling operations - adjust for downhole differential pressure with equal surface pressure. 29. RIH w/ WLRSV and locate in HXO landing nipple. B 1-25 Producer - Multi-lateral PERMIT Badami B1-25 CASING SIZE: 9-5/8" SPACER: SURFACE CASING CEMENT PROGRAM- HALLIBURTON 100 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 255 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from 1000' above the casing shoe to the ES cementer at 2200' md, plus 30% excess. Premium 2% calcium chloride 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 385 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of fill in the gauge hole plus 30% excess plus 80' shoe joint. SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 2500 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: To be determined on job x job basis BI-25 Producer- Multi-lateral PERMIT INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 7" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 185 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. MULTI-LATERAL WELL ABANDONMENT PROGRAM The following program is to be used at such time as the weilbores below the 7" intermediate casing are to be abandoned. 1. MIRU Rig. 2. Kill Well. 3. Pull tubing, packer, completion. 4. RIH with 7" EZSV cement retainer and set 50-100' inside the 7" intermediate casing and above all perforations in the 7", if any exist. 5. Mix and pump a volume of premium class G cement to fill the 7" casing below the EZSV and the calculated volume to fill the entire hole section of all wellbores below the 7" shoe, plus 10%. 6. Unsting from EZSV. 7. Pressure test the EZSV and cement to 3000 psi. 8. Procedures for the remainder of the wellbore above the EZSV will depend on the future plans for the wellbore (total abandonment, sidetrack, etc.). 10 1-25 lh'oduccr- Multi-latcral PERMIT Shared Services Drilling Contact: I Well Name: Mike Miller 564-5066 I B1-25 Badami I Weft Plan Summary DA TA COMMON TO ALL THREE PENETRATIONS (PRIMARY AND BOTH LATERALS): Type of Well (producer or injectOr): Producer- Multi-Lateral Open-Hole I Surface Location: 3857' FSL 17' FEL SEC 8, T9N, R20E, UM, AK IAFE Number: 88O46O J I KBE: 154.8 I 28E I Estimated Start Date: I Sept. 10 1998 J I Operating days to complete: 145 Well Design: I Ultra slimhole- multi-lateral open hole completion w/slotted liner Formation Tops MD TVD (bkb) Remarks base permafrost 2005 2004 Top Middle Brookian (TMBK) 7619 7132 M90 9228 8184 'Base West Sak (M85) 9655 8474 Casing/Tub ing Program: Hole §ize Csg~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. . MD/TVD MD/'rVD brt 24" 20" 91.1 # H-40 Weld 80 37/37 116/116 12 - 1/4" 9-5/8" 40# L-80 BTC 4521 35/35 4556/4555 8-1/2" 7" 29# P110 BTC- 10428 33/33 10461/9054 mod Internal yield pressure of the 7" 29#/ft P110 casing is 11220 psi, which is greater than the maximum anticipated surface ,p, ressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/fi, surfac~'~-~~ 0.36 psi/ft, 6570 to 10094 tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. Logging Program: IOpen Hole Lo[Is: Surface Intermediate Sidewall cores · 30ea. planned ( 2500' md - 4500'md) MWD/GR @ hole section TD B 1-25 Producer- Multi-lateral PERMIT Mud Program: Special design considerations [displace OH laterals to 5% KCL water based muds Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 150 25 20 45 9 10 ,, to to to to to to to 9.8 - 10.0 300 60 30 60 9.5 1-5 Intermediate Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel , Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to 10.1 55 20 10 25 9.5 4-6 .... Producti0.n Mud ProPerties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 12.0 45 10 8 15 8.5 4-5 to to to to to to to 12.4 55 15 10 20 9.5 4-5 i Well Control (Secondary) · Diverter Waiver Requested Well control equipment consisting of 10,000 psi W.P.(2) pipe rams, (1) blind rams, and 5M WP annular preventer will be installed and is capable of handling maximum potential surface pressures.10 M WP Choke & kill manifold. BOPE and drilling fluid system schematics on file. Waste Mana.qement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Annular Injection: No annular injection is planned at this time. DRILLING HAZARDS AND RISKS: Wellbore proximity comments are addressed under each MLOH section. Junk (auger tooth) was encountered in the B1-16 conductor ~ if junk is encountered, ensure all junk is fished prior to commencing drilling. Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Badami sands are overpressured - normally 12.2ppg mw required at TD. Pressure transition begins just above shallowest sand. Shallow sands typically pressured between normal and the 12.2 ppg required in lower sands. Maintain minimum mud weight and utilize latest techniques to manage lost circulation hazards in shallow sands (flow rates, tapered drill string). Weight up as wellbore pressures dictate, maintaining a 200 psi overbalance throughout. B I-~.~ Producer - Muld-la[crai PERMIT Hazards of well control and stuck pipe are managed by settin9 7" casin9 above shallowest sand, before penetrating the full overpressure. Hazard of lost circulation is managed by proper techniques to maintain Iow ECD - ECD of 13.5 ppg noted to be maximum allowable to prevent lost circulation. 0-1~ t L. I- IN O I DrillQuesr scale: linch = 40oft Eastlngs 4400 3200 3800 4000 4800 10302 ~D - 1407.62 N, 3848.67 E~ 1000 ~nd Olr, ~11~ 27.755': 11161.~ff MD, 9593.35~t ~O 1000 / 3200 3800 4000 4400 4800 Scale: linch = 400ft Eastlngs Reference Is True North 9000 94O0 9800 10200 10600 Proposal Data for 81-25 WIM. L2 Casing - 10461.22 MD, 9054.80 TVD __-Tie-on, Start [:)ir ~ 8.000'/10Oft: 10780.00ft MD, 9292.10tl TVD · Shdlowcst Bsdami Sand - 9154.80 TVD ProPosal Target S~mary T~,~ Narm: 'P/E~ 'l'V~kt~ ItI*U I..2 TI 1024t.00 IO~01JO 1407.62 N, 314~.07 K OIo~1C~ordi~wle,: $907763.(;~ N, 367868.110 E 11ooo.oo ~End Dtr, Sail O 27.755': 11161.94ft MD, 9593.35ff TVD 11200.00 11400,00 SURFACE-LOCATiON" ' He~eWll~ ~,df:M~ i SGO6434.;'0 N, 3S3~S.48 l mca r. Je,mi~ ~ 1~.~ w,a {~T~) PLOT DATE: 06~30~98 F3 - 9964.80 IWD FOR PERMI'i-rlNG ONLY --F4 - I(XYJ9.$0 T'VD L:,~--,I,7-/Ci~-7-I~72~.~T-F$. 10214.80 TVD '0302.80 TVD . 1407.62 N, 3848.67 E --AS - 103~9.80 TVD 800 Scale: linch = 400ft · . Total h: 12191.89ft MD, 10504.80ft TVD 4 1/2" Liner - 12191.89 MD, 10504.80 TVD I I I 1200 1600 2000 Section Azimuth: 358.971' (True North) Vertical Section Badami Measured Depth (ft) 10780.00 10800.00 1O9O0.00 11000.00 11100.00 11161.94 11200.00 11300.00 11400.00 11500.00 11581.68 11600.00 11700.00 11734.23 11800.00 11864.19 11900.00 11963.63 12000.00 12039.34 , 12100.00 12191.89 Incl. Azim. 49.082 70,958 47.752 69.770 41,316 62,977 35,393 54.283 30,295 42,873 27,755 34,089 27,755 34,089 27.755 34,089 27,755 34,089' 27.755 34,089 27,755 34.089 27.755 34.089, 27,755 34.089 27.755 34.089 27.755 34.089 27.755 34,089 27.755 34,089 27.755 34.089 27.755 34,089 27.755 34,089 27.755 34.089 27.755 34.089 Sub-Sea Depth (ft) 9237.30 9250.57 9321.86 9400.30 9484.37 9538.55 9572.23 9660.73 9749.22 .9837.72 9910.00 9926.21 10014.70 10045.00 10103.20 10160.00 10191.69 10248.00 10280.19 10315.00 10368.68 10450.00 Sperry-Sun Drilling Services Vertical LOcal Coordinates Depth Northings Eastings (ft) (ft) (ft) 9292.10 9305.37 9376.66 9455.10 9539.17 9593.35 9627.03 9715.53 9804.02 9892.52 9964.80 9981.01 10069.50 10158.00 10214.80 10246.49 10302.80 10334.99 10369.80 10423.48 10504.80 Proposal Report for B1-25 Wp4 L2 -- FOR PERMITTING ONLY Alaska State Plane Zone 3 Badami CPF 974.75 N 3448.62E 979.78 N 3462.71E 1007.62 N 3526.95 E 1039.58N 3579.96E 1075.02 N 3620.69 E 1098.43 N 3639.42 E 1113.11N 3649.35 E 1151.68N 3675.45 E 1190.25 N 3701.56E 1228.81N 3727.66E 1260.32 N 3748.98E 1267.38 N 3753.76 E 1305.95 N 3779.86E 1319.15 N 3788.79 E 1344.52 N 3805.96E 1369.27 N 3822.71E 1383.08 N 3832.06 E 1407.62 N 3848.67 E 1421.65 N 3858.16 E 1436.82 N 3868.43 E 1460.22N 3884.26 E 1495.66N 3908.25 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) R.c~37R37_RR N 3674Rl ~t F 912=C-~ 5907342.15 N 367475.22 E 8.000 917.44 5907368.84 N 367539.95 E 8.000 944.12 5907399.84 N 367593.52 E 8.000 975.12 5907434.55 N' 367634.89 E 8.000 1009.83 5907457.61 N 367654.03 E 8.000 1032.90 5907472.11 N 367664.23 E 0.000 1047.39 5907510.21 N 367691.02 E 0.000 1085.49 5907548.30 N 367717.81 E 0.000 1123.58 5907586.39 N 367744.60 E 0.000 1161.67 5907617.51 N 367766.48 E 0.000 1192.79 5907624.48 N 367771.39 E 0.000 1199.77 5907662.58 N 367798.18 E 0.000 1237.86 5907675.62 N 367807.35 E 0,000 1250.90 5907700.67 N 367824.97 E 0,000 1275.95 5907725.12 N 367842.16 E 0,000 1300.40 5907738.76 N 367851.75 E 0.000 1314.04 5907763.00 N 367868,80 E 0,000 1338.28 5907776.86 N 367878.54 E 0,000 1352.14 5907791.84 N 367889.08 E 0.000 1367.12 5907814.95 N 367905.33 E 0,000 1390.23 .5907849.95 N 367929.95 E 0.000 1425.23 Comment Tie-on. Start Dir @ 8.000~/100ft: 10780.00ft MD, 9292.10ft _T~D End Dir, Sail @ 27.755°: 11161.94ft MD, 9593.35ft TVD F3 F4 F5 Target: B1-25 L2 T1,200.00 Radiu. s., Dfiller~ A5 Total Depth- 12191.89fl: MD, 10504.80ft TVD 7' c//~ /~ ~¢2 ~ :~¢t. ~/ 4' ii2- Lirfe[ ~ 30 June, 1998- 11:14 -1- Dr~Quest Badami Sperry-Sun Drilling Services Proposal Report for B1-25 Wp4 L2 FOR PERMITTING ONLY Alaska State Plane Zone 3 Badami CPF All data is in feet unless Otherwise stated. Directions and coordinates are relative to True North~ Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 358.971 ° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12191.89ft., The Bottom Hole Displacement is 4184.66ft., in the Direction of 69.058° (True). -. 30 June, 1998 - 11:14 -2- DnTIQuest hUG-03-98 I10N 08:54 $?ENNY-NUN flLH~KH 1~Htx, HU. ~t~U/bb6b/bq r, Shared Services Drilling Mike Cook Mike, The above mentioned well h~ been scxaned using standard anti-collision methods via DEAP. The sc~'m was performed with the following pa. ra.metem Star Scan Inspection Zone End Scan Ins?eeflon Zone Starting ,..Read Paadlus Rate of Radlu~ Increase (per 1000') 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Approved Well Close Approach Review Badami/B1-28 Wp4 35.30' 14, 329,42' 200.00' Anti-Collision Scan su.mmary~ At the planned KOP the Starting Sca~ Radius is 98.235' larger than DEAF, default setting,~ of 100' Start Scan Radi~ Increasing at 50' per 1000 'MD for a new-drill well scan, thus DEAFs defaults would be equal to 101.765' at the Start Scan Inspection Zone a~ stated above. These numbers are u~ed to produce a final scan radius of 1629,412' which is 812,941' larger than DEAP's default value of 816.471' Scan Parameters Comments: i ii __ i ii ii At this enlarged radiu~ the following wells ~,ere detected during the scan (Based on closest 'Allowable Devialion from Plan'): Note: this list may not include all the wells detected, only tho~e of wkich are of concern or may effect Tolerance Line drawing! Comparison $_ublect Well Planned Well Relative ADowab]e, Shut-in_Required? (Semradon notes'~ Well: Devth Severation Azimuth Devlatloq ('= Eslsttn~, Su~ (': Well Plan MD) fPot, t /o Pot~4} (rCDirectlon) (Awrox. IL Dbl) B1-01 598,63 'MD 240.45 ' 265.80 * 234.92' No MINOR B 1-I 1 400.45 'MD 140,43 ' 268,00 ° 136,54 ' No MINOR · -< Bl-14 400,30'MD 110.78 ' 269,20 * 106.87 ' No MINOR BI-14 4691,88'MD 166.48 ' 317,70 * 127,38 ' No MINOR BI-15L1 499,73'MD 100,81 ' 266.50 * 96.18 ' No MINOR " BI-ISLI 5197,12'MD 124,83' 264.10 * 83,99' No MINOR BI-16PB1 400,25'MD 92,75 ' 269.50 * 88.15 ' No MINOR < BI-16PB1 2570.34 'MD 30.07 ' 292.90 * 13.32 ' No MINOR BI-18 599.79 'MD 69.95 ' 266,60 * 64.53 ' No MINOR BI-18 5480.20'MD 14535 ' 214.90 * 107.60' No MINOR ...13.1-21 200,10'MD 40,17 ' 270.20 ° 38,54 ' No MINOR B1-21 3163,86 'MD 94,35 ' 126.20 ° 74,98 ' No MINOR B 1-28 599.64 'MD 30,23 ' 104.90 * 25.43 ' No MINOR B1.28 2693,29'MD 128,24 ' 143,I0 * 112.34 ' No MINOR ! i i i ii i Tolerance Plot required: Close Approach Comments: Yes Status as Tested We hove a very close approach with Bl-16 at the 2400- 3000 MD area, I wlll talk to our drillers before they go up and have them nudge away fro_m., that area slightly to avoid any interference yet still remain on our nudcle Droclram, i ! Close Approach Scan Performed by: Date: Checked by: Date: Approved by: Date: i Shared Services Approval: Date: · i i i i B1-25,xls _ AWD Proximity Review 8,3/98 · WELL PERMIT CHECKLIST WELL NAME ~¢~ a.,,~ UL~4~'(' DJ -~,,~ PROGRAM: exp [] dev ~'redrll [] serv [] wellbore seg I] ann. disposal para req I! COMPANY FIELD & POOL 0 (~_~ C) ~ ~ 0 INIT CLASS D ):- d I- tj/t. GEOL AREA _~ ~ ~) UNIT# '~, t3 ~2~ 0 ff ON/OFF SHORE ADMINISTRATION Ai~R D&TE ENGINEERING DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .--5~OOO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N N N N GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... ~ N 31.' Data presented on potential overpressure z~.'T'"'~ Y N 32. Seismic analysis of shallo~ ......... Y N 33. Seabedcon~foff-shore) ............. Y N 34. ~~e ogress reports ....... Y N ..... exploratory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving z~~,. ...... (B) will not contaminate freshwater~~se drilling waste... to surface; (C) will not ~ntegrity of the well used for disposal; (D) will not,,,da~~mation or h'npair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N Y N Y N GEOLOGY: RPC_~r~ ENGINEERING: UIC/Annular COMMISSION: co Comments/Instructions: M:chel~lisl rev 05/29/98 dlf. C :\m sr)ffic(;\wor dian\di,aurt\(:h(~r;k li¢;t Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Mar 25 13:10:10 1999 Reel Header Service name ............. LISTPE Date ................ ; .... 99/03/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name.. ...... UNKNQWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/03/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER BADAMI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA . JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RECEIVED APR 02 1999 B1-25 500292290600 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 25-M_A_R-99 MWD RUN 4 MWD RUN 5 MWD RUN 6 AK-VC- 80417 AK-VC- 80417 AK-VC- 80417 J. PANTER M. CADY M. CADY D. MASKELL D. MASKELL N. SCALES 8 09N 20E 3857 17 54.80 53.30 19.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 20.000 116.0 2ND STRING 12.250 9.625 4524.0 3RD STRING 8.500 7.000 10891.0 PRODUCTION STRING 6.000 12750.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 4 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. MWD RUNS 5 AND 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. A CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) OCCURRED AT 10836'MD, 9005'TVD. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DAVE DOUGLAS OF BP EXPLORATION (ALASKA), INC. ON 06 JANUARY, 1999. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12750'MD, 10596'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SM6OTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NI3MBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 6503 0 ROP 6571 0 FET 10890 0 RPD 10890 0 RPM 10890 0 RPS 10890 0 RPX 10890 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 12702 5 12750 5 12709 5 12709 5 12709 5 12709 5 12709 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 4 6571.0 10905.0 5 10905.0 11489.0 6 11489.0 12750.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ~ Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPM MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 RPS MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 6503 12750.5 9626.75 12496 6503 GR 24.6154 147.692 92.4877 12400 6503 Last Reading 12750.5 12702.5 ROP RPM RPX RPS RPD FET 4 9893 0 1287 0 3378 0 1488 0 0722 0 9782 609.375 107.885 12360 2000 13.1092 3640 95.7205 8.99944 3640 2000 10.4752 3640 2000 11.7652 3640 17.8949 1.95079 3640 6571 10890 10890 10890 10890 10890 12750.5 12709.5 12709.5 12709.5 12709.5 12709.5 First Reading For Entire~ File .......... 6503 Last Reading For Entire File ........... 12750.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ~' STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD · Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6503.0 10836.0 ROP 6571.0 10905.0 $ LOG HEADER DATA DATE LOGGED: 04-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWN-HOLE SOFTWARE VERSION: DEP2 2.22A DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10905.0 TOP LOG INTERVA3~ (FT) : ~ 6571.0 BOTTOM LOG INTERVAL (FT) : 10905.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/~GLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURA3~ GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE .(DEGF) MUD AT MEASURED TEMPEP~ATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined At, sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 40.9 58.0 TOOL NUMBER NGP SPC 319 8.500 8.5 GEL-CHEM 9.70 54.0 8.8 1100 6.0 .000 .000 .000 .000 124.8 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 Name Min Max Mean DEPT 6503 10905 8704 GR 24.6154 147.692 90.9689 ROP 5.2226 609.375 137.916 Nsam 8805 8667 8669 First Reading 6503 6503 6571 Last Reading 10905 10836 10905 First Reading For Entire File .......... 6503 Last Reading For Entire .File ........... 10905 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 · Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: START DEPTH STOP DEPTH 10830.0 11448.0 10890.0 11455.0 10890.0 11455.0 10890.0 11455.0 10890.0 11455.0 10890.0 11455.0 10900.0 11489.0 10-NOV-98 ISC 5.06 DEP2 2.22A DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL ~ -MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MEMORY 11489.0 10905.0 11489.0 36.1 40.8 TOOL NUMBER P1064GR4 P1064GR4 6.000 6..0 LSND 10.50 46.0 10.0 5.6 .130 .065 .115 .140 143.0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel , DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHMM 4 1 68 RPD MWD 5 OHMM 4 1 68 ROP MWD 5 FT/H 4 1 68 FET MWD 5 HOLrR 4 1 68 Name Min Max Mean Nsam DEPT 10830 11489 11159.5 1319 GR 47.7637 i22.443 99.1088 1237 RPX 0.3378 11.0662 6.35631 1131 RPS 0.1488 2000 8.3913 1131 RPM 0.1287 2000 16.8665 1131 RPD 0.0722 2000 11.7936 1131 ROP 6.5436 440.931 26.6818 1179 FET 1.2556 3.2278 1.93734 1131 4 8 12 16 20 24 28 First Reading 10830 10830 10890 10890 10890 10890 10900 10890 Last Reading 11489 11448 11455 11455 11455 11455 11489 11455 First Reading For Entire File .......... 10830 Last Reading For Entire File ........... 11489 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/25 Maximum Physical Record..65535 File Type ............. ~ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11441 5 11448 5 11448 5 11448 5 11448 5 11448 5 11490 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12702 5 12709 5 12709 5 12709 5 12709 5 12709 5 12750 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA ILAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REM3LRKS: 12-NOV-98 ISC 5.06 DEP2 2.22A MEMORY 12750.0 11489.0 12750.0 24.2 36.7 TOOL NUMBER P1064GR4 P1064GR4 6.000 6.0 LSND 12.40 98.0 10.4 30000 4.1 .240 .121 · 140 .280 166.0 .6 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record. ............ Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type.. Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 6 API 4 1 68 RPX MWD 6 OHMM 4 1 68 RPS MWD 6 OHMM 4 1 68 RPM MWD 6 OR-MM 4 1 68 RPD MWD 6 OHMM 4 1 68 ROP MWD 6 FT/H 4 1 68 FET MWD 6 HOUR 4 1 68 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 11441.5 12750.5 GR 35.4719 125.449 RPX 4.795 95.7205 RPS 4.9595 135.019 RPM 4.7999 171.46 RPD 4.9811 161J784 ROP 4.9893 208.203 FET 0.9782 17.8949 Mean 12096 94 3548 10 1682 11 3875 11 3864 11 7225 42 9078 2.04408 Nsam 2619 2523 2523 2523 2523 2523 2521 2523 First Reading 11441.5 11441.5 11448.5 11448.5 11448.5 11448.5 11490.5 11448.5 Last Reading 12750.5 12702.5 12709.5 12709.5 12709.5 12709.5 12750.5 12709.5 First Reading For Entire File .......... 11441.5 Last Reading For Entire File ........... 12750.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/03/25 Origin ................... STS Tape Name ................ UNKI~OWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ................. "....99/03/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ..... ~ ...... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File