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200-027
Ima~ Project Well History' File Cove~ age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ ~~- -~'~ 7 Well History File Identifier RESC/~" DIGITAL DATA OVERSIZED (Scannable) Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERL~NCENT SHERYL MARIA WINDY Project Proofing [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERL'~~NCENT SHERYL MARIA WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY GRAYSCALE OR COLOR IMAGES) NO NO RESCANNEDBt(~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned,wpd MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc OIL AND GAS CONSERVA ION CO I SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chip Alvord Alpine Drilling Team Leader Phillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-1215 April 19, 2001 Dear Mr. Alvord: On March 20, 2000, the Alaska Oil and Gas Conservation Commission (the Commission) approved the application from ARCO Alaska, Inc. for a permit to drill the Colville River Unit CD2-23 well. On April 5, 2001, you sent an email to Mr. Robert Crandall of the Commission stating that CD2-23 had been dropped from the drilling schedule,, and requesting that the permit to drill be canceled. When a permit to drill application is submitted to the Commission, all information submitted must be retained in our files for informational purposes. We realize that sensitive information is contained within every permit to drill application. However,' by regulation, all information submitted to the Commission eventually becomes public information unless justified by the operator. Enclosed is a Request for Confidentiality form that allows you to: . Describe any confidential information contained in, or attached to, the CD2-23 permit to drill application; justify why it should remain Confidential beyond the typical two year period; and suggest a release date for any information that you wish to remain confidential. Please complete this form, and return it to me. If you have any questions, please call.me at 793-1224. SD/jjc/letter6 Sincerely, ( · Steve Davies Petroleum Geologist Request made by: Description of material/information: Conservation Order File No./Other File Name: Basis for confidential request: How long does it need to be kept confidential? If that date is currently unknown, at what date can the need for confidentiality be reassessed? (2 years unless otherwise instructed) Tickle date (90 days before release/reassessment date): Commissioner Date Commissioner Date Commissioner Date Approved at hearing: Signature Date Memorandum To: Well File: Colville Riv Unit CD2-23 Permit # 200-027 Re: Cancelled Permit Action Colville Riv Unit CD2-23 XX API# 103-20330-95 State of Alaska Oil and Gas Conservation Commission April 5,2001 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting redrills and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (wellbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician CD2-42 Drilling Permit ~ AOGCC { Subject: CD2-42 Drilling Permit ~ AOGCC Date: Thu, 5 Apr 2001 14:59:22 -0800 From: "Chip Alvord" <calvord~ppco.com> To: bob_crandall~admin.stat¢.ak.us CC: "Vernon T Johnson" <vjohnso 1 ~ppco.com>, "Sharon Allsup-Drake" <sallsup~ppco.com> Bob, Sorry for the confusion with the drilling permit for CD2-42. Last March (2000) there were two wells (CD2-23 and CD2-39) that got permitted with the hope they could get drilled during the winter drilling season ,however, given exploration priorities and a lack of rig availablity they never got drilled. Since that time the entire development from CD2 pad has been re-planned and we'd like to cancell the two permits previously approved in March 2000. Please cancel the following approved drilling permits: Well # Approver # API# CD2-23 200-027 50-103-20330 CD2-39 200-028 50-103-20331 Once again sorry for the confusion and please call if you need further information. Regards, Chip Alvord G.L. (Chip) Alvord Alpine Drilling Team Leader Phillips Alaska Drilling & Wells (907) 265-6120 Phone (907) 265-1515 Fax (907) 275-4709 Pager calvord@ppco.com CD2 Winter Program: Switch Order of Wells Subject: Date: From: To: CC: CD2 Winter Program: Switch Order of Wells Fri, 17 Mar 2000 09:05:31 -1000 "Brian Robertson" <BROBERT4@mail.aai.arco.com> Tom_maunder@admin.state.ak. us "Douglas K Chester" <DCHESTER@mail.aai.arco.com>, "Renee C Hannon" <RHANNON@mail.aai.aroo.com>, "Douglas G Knock" <DKNOCK@mail.aai.arco.com>, "Mark M Ireland" <MIRELAND@mail.aai.arco.com>, "Thomas A Brockway" <TBROCKW@mail.aai.arco.com> Tom, As per our telecon, we would now like to drill the CD2-23 well before the CD2-39 well. This is in reverse order to the way we submitted the APD's. CD2-23 is the preferred well to have in the ground in the event that rte run out of time due to the ice road going out. I'd now expect that we will be in a position to spud CD2-23 around 5 April. Regards Brian Robertson Alpine Drilling Eng. 1 of I 3/17/00 9:27 AM TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COPl~IISSION Doug Chcstcr. Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage. AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ae~ Colville River Unit CD2-23 ARCO Alaska, Inc. Permit No: 200-027 Sur. Loc. 1796'FNL, 1536'FEL. Scc. 02, T11N. R4E. UM Btmhole Loc. 2548'FSL. 681'FWL. Sec. 34. T12N. R4E, UM Dear Mr. Chester: Enclosed is the approved application for permit to thc above rcfercnccd wcll. In accordance with 20 AAC 25.005(f), all rccords, data and logs acquired for thc pilot hole must be clearlv diffcrcntiatcd in both name (CD2-23PH) and API number (50-103-20330-70) from records, data and logs acquircd for well CD2-23. The permit to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd bv law from other governmental agencies, and docs not authorize conducting drilling operations until all othcr required permitting determinations arc made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will bc contingcnt on obtaining a well cemented surface casing confirmed bra valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to thc start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surfacc/production casing annulus of a well approved for annular disposal on C'D2 drilling pad lnust comply with the requircmcnts and limitations of 20 AAC 25.080. Approval of this permit to drill docs not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular spacc of a singlc well or to usc that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficicnt notice (approximatcly 24 hours) must bc given to allow a rcprcscntative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given by contacting thc Commission petroleum field inspcctor on thc North Slope pagcr at 659-3607. Chair BY ORDER OF THFs~OMMISSION DATED this ~-O ~ day of March, 2000 dlf/Enclosures cc: Departlncnt of Fish & Game. Habitat Scction w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepeni Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 48' feet Colville River Field 3. Address 6. Property Designation ~,,~(3~?,Z,~-~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380075& 387212 .,,~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1796' FNL, 1536' FEL, Sec.2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 96' FNL, 2094' FWL, Sec. 3, T11N, R4E, UM CD2-23 #U-630610 At total depth 9. Approximate spud date Amount 2548' FSL, 681' FWL, Sec. 34, T12N, R4E, UM 03/25/2000 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD2- 35 14,139' MD Crosses Sec 3, feet 120.1'@ 100' Feet 2560 7,273' TVD feet T11N to 11, Sec 4, T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 90° Maximum surface 2563 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD linclude sta~le data) 42" 16" 62.5# H-40 Weld 77' 25' 25' 107' 107' Pre-installed 12.25" 9.625" 36# J-55 BTC 2390' 25' 25' 2415' 2400' 477 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 11114' 25' 25' 11139' 7273' 134 sx Class G N/A 4.5" 12.6# L-80 I BT-M 10499' 25' 25' 10524' 7100' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth StructuralRECEIVED Conductor Surface Intermediate Production Liner [" ~18 2 9 2000 Perforation depth: trmueeaSv~tlcdal 0 RIG IN A L 20. Attachments Filing fee X Property plat BOP Sketch X DiverterSketch X r,,~v-,,~ Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21.Signedl hereby certify~lat,,~ ~"'~/(~!{/, the foregoingc/~_ is true~~and correctl ....... to the best of my knowledge Title Drilling Team Leader Date ,:::~/~ Commission Use Only Permit Number '~'"' ~--"~///~ I API number ... ~ I Approval date~. 50- /~ ~ '- ~ ~ ~ '"~ ~) '"~)/'~ I See cover letter for Other requirements Conditions of appro~1 Samples required Yes ,,,.~ Mud log required - Yes Hydrogen sulfide measures Yes (/~',)~ Directional sa rvey required ~ No Required working pressure for BOPE ~'--'"'"' 2M 3M 10M 15M '~.~(~r.~, ~'~O'~ '~'~.c~-- Other: ORIGINAL SIGNED BY by order of Approved by Robert N,, C';hristeRso~:, Commissioner the commission Dat Form 10-401 Rev. 7-24-89 Submit in triplicate Not To Scale VICINITY MAP DRILL SITE CD-2 el ~2~ .~' .5=.14.· 1~0 .... ,15 20· 22~ ,25 · 25 · 27 28 · · 29 52 · · 55 · 39 &O · · ¢1 42 · · 45 · 4.7 · 4-9 · 5~ 52' Scale' 1"= 1 Mile Refer to Sheet 2 for Notes & Location Information ~ LOUNSBURY ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CADD FILE NO, DRAWING NO: LK664D1 ALPINE DRILL SITE CD-2 PROPOSED WELL CONDUCTOR LOCATIONS PERMIT EXHIBIT SHEET: REV: NSK 6,64-dl 1 or 2 ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC 2, T 11N. R 4 E, UMIAT MERIDIAN Sec Line O/S Plan Well 'Y' 'X' Lat. (N) Lon FNL rm Gnd Pad cD2-1 5,97~,781.03 371,681,53 70'20' ~1,~93' 151' ~2' ~8.~82" 1~:777' i.5~2' 8,1~' CD2-2 5,97~,771.0g 371,682.59 70"20' 21.496" 151'02' 28.546" 1,587' 1,561' 8.8' 15.9' CD2-3 5,97¢,761.1¢ $71,685.64 70'20'21.398' 151'02' 28.510" 1,597' 1,560' 8.8' 15.9' CD2-~ 5,974,751.20 371,684.70 70'20' 21.3~0" 151'~2' 28.475" 1,6~ 1,55g' 8.7' 15.9' cD~-~ ~,~,~.~s ~,~.~ ~e'2e'~.~' ~'~' 2~.~" ~,~ ~,ss~' ~.~ ~.~' CD2-6 5,974,731.31 371,686,81 70'20'21.105' 151'02' 28.403" 1,~27, i,556' s,~ 15,9' CD2-7 5,974,721.36 371,687.86 70' 20' 21.~07" 151'~2' 28.367" 1,637, 1,555' 8.7 15.9' CD2-8 5,974,711.42 371,688.92 70'20'20.910' 151'02' 28.332" 1,647, 1,554' 8.7' 15.9' CD2-9 5,974,701.~ 371,6B9.98 70"20' 20.B!2' 151"02' 28.296" 1,657, 1,553' 8.7, 15.9' CD~-Je s,~7~,6~1.s3 37~,s~.~3 70'20' ~e.7~s' lS1'02' ~s.2se" ~,sss' ~,S~' 8.7' c~2-~ s,~7~,~8~.s9 37~,s~.09 70'20' 2e,s~' ~s~' 02' ~s.224" ~,s~s' ~,sSe' 8.7' ~s.~' CD~-~ S,~7~,~5I.~S 371,S9S.~5 70'2~'~e.3~" ~Sl'e~' 2s.~17" ~,~' ~,s~7' ~.7' ~s.~' CD~-lS S,~7~,~41,81 371,SgS.~1 70'20' ~e.~" lSl'e2' 28.0a~" ~,~lS' 1,5,s' 8,7' lS,~' CD~-JS S,97~,S31.a7 371,S9~.~7 7e'~e' 20.~29' ~s~'e2' ~s.e4s" ~,7~s' ~,5~' ~.7' ~s.9' CD~-~S ~,~7~,~.~ 371,~9.~ 7~' 20' ~.~3,' iS~' 02' ~7.~7~" ~,~' ~,S,~' 8,7' CD2-19 5,97~,602,03 371,700.53 70- 20' 19.836" 151' 02' 27.938" 1,756' 1,5,1' 8,7' 15,9' CD2-2e 5,974,592.09 371,701.59 70' 28' 19.738" 151' 02' 27.902" 1,766' 1,539' 8.7' 15,9' CD2-21 5,97~,582.14 371,7~2.64 70' 20' 19.641" 151' ~2' 27.866" 1,776' 1,538' 8.7' 15.9' CDZ-22 5,97~,572,20 371,703.70 70' 20' 19,543" 151' 02' 27.830" 1,786' 1.5~7' 8,7' 15,9' CD2-23 5,974,562.26 371,704.76 70' 20' 19.~" 151' 02' 27.795" 1,795' 1,536' 8.7, 15.9' CD2-2~ 5,97~,552.31 371,705.81 70' 28' 19,3~" 151' ~2' 27.759" 1,805' 1,535' 8.7, 15.9' CD2-25 5,975,542.37 371,706.87 70' 20' 19.250' 151' ~2' 27.725" 1,815' 1,533' 8.7' 15.9' CD2-26 5,975,532.42 371,707.92 70' 20' 19.153" 151' 02'...27.687" 1,825' 1,532' 8.7' 15.9' CD2-27 5,975,522.~ 371,708,98 70' 20' 19.055' 151' 02' 27.651" 1,835' 1,531' 8,7' 15.9' CD2-28 5,974,512.53 371,710,03 70' 20' 18.957" 151' 02' 27,616" 1,845' !,530' 8,8' 15.9' CD2-29 5,974,502.59 371,711.09 70' 20' 18.860" 151' 02' 27.580" 1,855' 1,5~8' 8.8' 15.9' CD2-3e 5,974,492.64 371,712.14 70' 20' 18.762" 151' 02' .27.544" 1,865' !,527' 8.8' 15.9' CD2-31 5,97&,~2.70 371,71~.20 70' 20' 18.665" 151' ~2' 27.508" 1,875' !,526' 8.8' 15.9' CD2-32 5,974,472,76 371,714.26 70' 20' 18.570" 151' 02' 27.472" 1,885' !,525' 8.8' 15,9' CD2-55 5,974,~2.81 371,715.31 70' 20' 18.470" 151' ~2' 27.4~7" 1,895' 1,524' 8.8' 15.9' CD2-34 5,974,452.87 371,716.37 70' 20' 18.372" 151' ~2' 27.4~!" 1,905' 1,5~' 8.8' 15.9' CD2-35 5,975,~2.90 371,717.49 70' 20' 18.274" 151' 02' 27.363" 1,915' 1,521' 8.8' 15.9' CD2-36 5,974,4~2,98 371,718.~ 70' 20' 18.177" 151' ~2' 27.329" 1,924' 1,520' 8.7, 15.9' CD2-57 5,97~,425.03 371,719.55 70' 2e' 18.079" 151' ~2' 27.293" 1,934' !,519' 8.7' 15.9' CD2-38 5,974,415.09 371,720.59 70' 2~' 17.981" 151" ~2' 27.258" 1,9~' 1,517, 8.7' 15.9' CD2-39 5,97~,~3.15 371,721.65 70' 20' 17.884" 151' 02' 27.222" 1,954' !,516' 8,7' 15.9' CD2-4e 5,97~,393.20 371,722.70 70' 20' 17.786" 151' ~2' 27.186" 1,964' 1,515' 8.7, 15.9' ...CD2-41 5,974,383.26 371,723.76 70' 20' 17.688" 151' ~2' 27.15~" 1,974' 1,514' 8.7' 15.9' CD2-42 5,97~,373.31 371,724.81 7~' 2~' 17.591" 151' ~2' 27.114" 1,984' i,513' 8.7' 15.9' CD2-43 5,974,363.37 371,725.87 70" 2e' 17,493" 151" 02' 27.079" 1,994' 1,511' 8.7' 15.9' CD2-4~ 5,974,353.42 371,726.92 70' 2a' 17.396" 151' 02' 27.043" 2,e04' 1,510' 8,6' 15.9' ~2-45 5,97~,343.~ 371,727,98 70' 20' 17,298' 1.~1' 02' 27.e07" 2,e14' 1,509' 8,6' 15.9' CD2-46 5,974,333.54 371,729.e~ 70' 20' 17.200" 151' ~2' 26.971" ~24' l,seB' 8.6' 15.9' CD2-47 5,974,323,59 371,730.09 70' 20' 17.103" 151' 02' 26.g55" 2,034' 1,507' 8,6' 15,9' CD2-48 5,974,313.65 371,731.15 70' 20' 17.e05" 151' 02' 26.900" 2,044' 1,505' 8.6' 15.9' CD2-49 5,974,303,70 371,732.20 70' 20' 16,907" 151' 02' 26.864" 2,054' 1,504' 8.5' 15,9' .CD2-5e 5,974,293.76 371,733.26 70' 2~' 16.81~" 151' ~2' 26.828" 2,063' 1,503' 8.5' 15.9' CD2-51 5,974,283,81 371,734,31 70' 20' 16,712" 151' 02' 26.792" 2,073' 1,502' 8.5' 15.9' CD~52 5,974,273,87 371,735,37 70' 20' 16,615" 151' 02' 26.756" 2,083' 1,500' 8.5' 15.9' ~ CD2-35 CONDUCTOR WAS AS-BUILT 3/12/98, 1. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2, ELEVATIONS SHOWN ARE B.P,M.S.L. ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CADD FILE NO. _ LK664-D1 2/08//'eeIiDRAW[NG NO.' LOUNSBURY_ ENGINEERS PLANNERS SUBVEYORS ...... " r' ii .? ~,., ,.:i,,,,,. %,~ ,. :Lc:i, ' 'C ALPINE DRILL SITE CB-2 NSK 6,64- d 1 J SHEE'r:2 or 2 J REV: PROPOSED WELL CONDUCTOR LOCATIONS PERMIT EXHIBIT Set 600 ft cement plug #1 from TD to +/- 10489'. Set 600 ft cement plug #2 from +/- 10489' to +/- 9889'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 10027' and drill sidetrack to intermediate casing point in the Alpine Reservoir. 10. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Displace cement with 9.6 ppg brine and enough diesel to provide 2000' TVD of freeze protection 11. Run and set the tubing hanger with joint of tubing. Install 2 way check. 12. Conduct a LOT (using the cement unit) down the 9-5/8" x 7" casing annulus. Freeze protect the casing annulus to 2000' TVD.- use 300 bbls fresh water flush prior to freeze protecting. 13. Nipple down BOP. 14. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check. 15. Set BPV and secure well. Move rig off. i~'% ,~,.~, '., ..... ~ ..... ~ '¥ ~L, ~ .? 2® Rig Visit (Year 2001- most likely with Poyon 19) ., ' , 16. R/U over CD2-23 and test BOPE equipment to 3500 psi. · "~. ~:" .. ;.,~ 17. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and pedorm formatiOn'integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. 18. Drill 6 1/8" horizontal section to well TD. 19. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 20. Displace well to brine and pull out of hole. 21. Run 4 Y~, 12.6 ¢, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. 22. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 23. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 24. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 25. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in annulus. Alpine- CD2-23PH (Pilot Hole) ~ _,.)2-23 Procedure 1. Install diverter. Move on Doyon 141. Function test diverter. 2. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. 3. Run and cement 9 5/8 surface casing. 4. Install and test BOPE to 3500 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Drill 8 1/2" hole to a point +/- 120' below the base of the Alpine Sand. 8. 9. 26. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-35 will be the closest well to CD2-23 (120.1' at 100' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 119.4' at 200' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous CD1 development wells. During the second rig visit, particular care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations on well CD2-23 will be injected into the annulus of well CD2-39 (assuming permit approval is received). Otherwise, incidental fluids will be hauled to the Class II injection facility on 1R pad of the KRU. After the rig returns to drill the 6-1/8" horizontal section it is intended that the incidental fluids be disposed of via an available well annulus (either CD2-23 or another permitted well). The CD2-23 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-23 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2~992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4~599 psi 7,240 psi 6,154 psi CD2-23 & CD2-23 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1/8" point- 12 ¼" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10-25 10-15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at +_ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. Doyon 141: Drillinq Fluid System: 3 - Derrick FIo-Line Cleaners Pioneer Model S2-12 Desander Tri-FIo 'Low Profile' Desilter Alpha-Laval Model DMNX 418 Centrifuge Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor 8 - Brandt pit stirrers Do¥on 141: Pit Confiquration: Capacity (BBLS) Pit 1 (Degasser pit) 83 Pit 2 (Desilter pit) 85 Pit 3 (Desilter pit) 85 Pit 4 (Pill pit) 35.8 Pit 5 (Center pit) 36.4 Pit 6 (Mixing pit) 122.3 Pit 7 (Suction pit) 448 Pit 8 (Sand trap) 64 Pit 9 (Trip tank) 64 Colville River Field CD2-23PH Pilot Hole- Prior to Sidetracking RKB - MSL = 48' RKB - GL: 30' Wellhead Updated 02/28/00 16" Conductor to 107' 9.8 ppg drilling mud in hole Top Alpine Reservoir at 10786' MD / 7238' TVD Pilot Hole TD at 11089' MD / 7398' TVD (+/- 58 deg inc.) Cement Plug I P,lu'g':#'2 ' : ~ , ................ · ,, ', Plug #1 : · , · , ............ · .:, ............. 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2415 ' MD / 2400' TVD cemented to surface Top of cement plug dressed off to sidetrack point at 10027' MD / 6838' TVD (+/- 58 deg inc.) /,,. Top of Cement Plug #1 at +/- 10489' 600 ft Colville River Field CD2-23 Temporary Suspension Schematic Wellhead installed with tubing hanger and BPV set and pressure , tested to 3500 psi 1 jt tubing with WEG. Updated 02/25/00 Diesel Freeze Protection in casing and annulus to 2000' TVD. 16" Conductor to 107' RKB- MSL=48' RKB-GL=30' 9,8 ppg drilling mud in annulus 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2415' MD / 2400' TVD cemented to surface 9.6 ppg brine with diesel freeze protection to 2000' TVD. TOC at 10371' MD (500' MD above top Alpine Casing pressure tested to 3500 psi on plug bL Top of Alpine 10871' MD / 7238' TVD 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 11139' MD / 7273' TVD @ 90 deg Colville River Field CD2-23 Production Well Completion Plan 16" Conductor to 107' Updated 02/25/00 RKB - MSL = 48' RKB - GL = 30' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2415' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCl Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Tubing Supended with diesel to lowest GLM Completion ME) TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Cd2-23PH - cement kick off plug at 10027' TOO @ +/- 10371' M (500' MD above top Alpine) Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 2000 psi set 2 joints above the X landing nipple Top Alpine at 10871' MD / 7238' TVD i'..~ ........ Baker S3 Packer at +/- 10524' Tubing Hanger 25' 25' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1707' 1700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 3567' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 6923' 5200' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 10423' 7047' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 10492' 7083' 4-1/2" tubing joint (1) BakerS3Packer 10524' 7100' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 10589' 7133' 4-1/2" 10' pup joint WEG (+/- 62 deg) 10600' 7138' Note: solid body aluminum centralizers installed between 2400' TVD (=2415') and 4500' TVD (=5596') Well TD at ', 14139' MD / i 7273' TVD " 7" 26 ppf L-80 BTC Mod Production Casing @ 11139' MD / 7273' TVD @ 90 deg Colville River Field CD2-23 Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 107' , 4-1/2" Camco BAL-O SSSV Nip,p, le (3.812' ID), WRDP-2SSSV(2.25 ID,! and DB-6 i,o-eo Lo,c,k (3.812 OD) with dual 1/4',x 0.049 s/s ,c, ontro ne ,,@ 1700 TVD= 1707 MD 9'5/8 36 ppfJ-55BTC Surface Casing @ 2415' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Updated 02~25~00 RKB - MSL = 48' (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi 2 joints above the X landing nipple '~ .~.a..ier S3 Packer set at +/' 10524' ~~ .............. F ................. '~1 TOC @ +/-10371' .:,:i.ii~;/ /.~. - ............. ,,,,:,,,,,,,,,. ........ ........... (500' MD above top ., Alpine) .......... ;... (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Well TD at 14139' MD / 7273' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 11139' MD / 7273' TVD @ 90 deg CD2-23 i' PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 107 / 107 10.9 52 53 9 5/8 2415 / 2400 14.2 1086 1532 7" 11139 / 7273 16.0 3290 2563 N/A 14139 / 7273 16.0 3290 N/A · NOTE: Doyon 141 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) -0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1} D = [(14.2 x 0.052) -0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3290 - (0.1 x 7273') = 2563 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3290 - (0.1 x 7273') = 2563 psi Alpine CD2-23 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -500 -1500 -2500 -3500 P£ PR -4500 -5500 -6500 -7500 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT ARCO Alaska, Inc. Doyon 141 Diverter Schematic Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 77' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L_ I I I 3" 5,000 psi WP OCT [-"J MANUAL GATE V KILL LINE ~r~ 3" 5,000 psi WP Shaffer GATE VALVE ] w/hydraulic actuator / 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE __ ~ hvdraulic actuator CHOKE LINE - 3-5/8" 5,000 psi WP J DSA 13-5/8" 5,000 psi WP x 11" 5,000 psi WP \ DRILLING SPOOL w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams Alpine, CD~ ..3PH & CD2-23 Well Cementing ~'quirements 9 5/8" Surface Casing run to 2415 MD / 2400' TVD. Cement from 2415' MD to 1915' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1915' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (1915'-1555') X 0.3132 ft3/ft X 1.5 (50% excess): 169.1 ft3 below permafrost 1555' X 0.3132 ft3/ft X 4 (300% excess) = 1948.1 ft3 above permafrost Total volume = 169.1 + 1948.1 = 2117.2 ft3 => 477 Sx @ 4.44 ft3/sk System: Tail slurry: 477 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 500' X 0.3132 fts/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 11139' MD / 7273' TVD Cement from 11139' MD to +/- 10371' MD (500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (11139'-1037~1 ') X 0.1268 ft3/ft X 1.4 (40% excess) = 136.3 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft3shoe joint volume Total volume = 136.3 + 17.2 = 153.5 ft3 => 134 Sx @ 1.15 ft3/sk System: 134 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder o 3 and 0.18 Yo D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft/sk CD2-23PH Cement Plug #1: 11089' MD to 10489' MD = 600'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 600' X 0.3941 ft3/ft X 1.15 (15% excess) = 271.9 ft3 => 237 Sx @ 1.15 ft3/sk CD2-23PH Cement Plug #2: 10489' MD to 9889 MD = 600'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 600' X 0.3941 ft3/ft X 1.15 (15% excess) = 271.9 ft3 => 272 sx @ 1.00 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement ARCO Alaska, Inc. Structure: CD#2 Field : Alpine Field Well : 25PH Location : North Slope. Alaska 450 450 9OO 1350 1800 2250 2700 3150 '~ 5600 0 -I.- q~ 4050 -I 4500 I V 4950 5400 585O 6500 675O 7200 7650 450 ESTIMATED RKB ELEVATION: 48' KOP 1.50 5.00 4.50 DLS: 1.50 deg per 100 ft 6.00 7.50 W Sok 9.00 9.50 End of Build 8.02 Drop/Turn to Vert 6.52 5.02 .5.52 Permafrost DLS: 1.50 deg per 100 ft 2.02 0.52 End of Drop 5.00 6.00 9.00 ~,~ C50 DLS: 3.00 deg per 100 ft 283.81 AZIMUTH 7108' (TO TD) ***Plane of Proposal*** ,,~9 5/8 Casing '~'~)=.~a, Begn Fnl Bid/Turn ~4 C20 DLS: 5.00 deg per 100 ft 28.94 34.94 ~ 40.94 ~ 46.93 52.95 EOC HRZ ~ HRZK-I~-dCU Alpine Base Alpine TD e e i i , , i i , i , i , { i m , m i , , i i ~ , m i i i , i i i 0 450 900 1550 1800 2250 2700 ,5150 ,5600 4050 4500 4950 5400 5850 6500 6750 7200 Vertical Section (feet) -> Azimuth 285.81 with reference 0.00 S, 0.00 E from slot #25 Cre~tld I~ f~ch For: It Robertson D<:,Ie pl~ed: 2Z-J*,',-2000 I Plol Re~erence ;a, CD2-2~ Ver~k3n .~5. I I ~.oord;notn ore ;n feet reflr~r~:e Ilot ,~123. J / ~Q ARCO Alaska, Inc. Sfruoture: CD#2 Well: 23 Field: Alpine Flelcl Looaflon : North Slope, Alaska 6300 331.86 AZIMUTH (TO ..... ¢:::~ i)3 C..'> ~,~.,:~.~,~. ~':'.';~ ¢'"'?3. .,:.::':,~ 6480 ;i:sr ~'-~,<~.,~.~ 6840 6660 LCU re M;luveoch A 72ood ....... | Alolne 1 Bose Alpine '~ -- ":-~ I I I I I I I I I I I I I I I I I I I I I I I I I TARGET ANGLE 90 DEG Azimuth ;551.86 with reference 0.00 S, 0.00 E from slot #25 7560 I I I I I I I I I I I I I I I I I I I I I I I I 5600 5780 3960 4140 4320 4500 4680 4660 5040 5220 5400 5580 5760 5940 6120 6500 6480 6660 6640 7020 7200 7360 7560 7740 7920 Vertical Section (feet) -> 4950 4500 4050 5600 5150 A I 2700 2250 800 550 9OO 450 450 900 Creoted ~ finc~ For: B Robert~onI D~te plotted; 20-D~c-1999 Plot ~fe~ce ~ CD2-2~H Vem~on ~5. ~ord;~t ..... ;n f~ r~ ..... lot ~25. ARCO Alaska, Inc. Sfruoture: CD#2 Well : 23PH Field: Alplne Field Loooflon : Norlh Slope, Alosko <- Wesf (feel) 9000 8550 8100 7650 7200 6750 6;500 5B50 5400 4950 4500 4050 5600 5150 2700 2250 1800 1550 900 450 0 450 I I I I I I I I I I I I I I | I I I I I I I I I I I I I I I I I I I I I I I I I I I I CD2-25 TD LOCATION: 2548' FSL, 681' FWL SEC. 54, T12N, R4E ESTIMATED SURFACE LOCATION: 1796' FNL, 1536' FEL SEC. 2, T11N, R4E CD2-25 TARGET LOCATION: 96' FNL, 2094' FWL SEC. 3, T11N, R4E 7 Coslng -iD Tgt-EOC-Cs9 Pt ~ine D A IHRZ CD2-23PH TD LOCATION: 559' FNL, 2060' FWL SEC. 5, T11N, R4E i i i i i i i i ! i i i i i i i i i i i i i i i ii i i i i i i i i i i i i i i i i i 9000 8550 81 O0 7650 7200 6750 5500 5B50 5400 4950 4500 4050 5600 5150 2700 2250 1800 1350 900 450 0 450 <- Wesf (feel) 495O 4500 405O 3600 5150 A 2700 I z 0 2250 --i- 1800 --i- 1550 9OO 450 450 9OO Created by rlnch For: B RoberLson Ooto p~otted: 25-Feb-2000 I Plot F~fer~nce ~ CD2-2~=H Vet=ran ~. I Coordrnat~s are ~n feet reference ~t~ ~2~. I True Vertical Depth~ or~~8 (~o~on t141).I ARCO Alaska, Inc. Sfruafure: CD#2 Field : Alpine Field Well : 25PH Looaflon : North Slope, Alaska PROFILE COMMENT DATA Point KOP W $ok End of Build End Initial Turn Permafrost End Drop/Begin Bid C40 EOC C30 9 5/8 Casing Pt Bgn Fnl BId/Trn [<-2 Albian-97 Albion-96 HRZ K-1 LCU Miluveach A Alpine D Alpine Base Alpine TD MD 500.00 1 049.90 11 66.67 1501.60 1 554.55 1834.94 2196.94 2534.94 2407.96 2415.21 2555.21 2780.56 5974.10 4550.70 4767.68 6824.18 8293.11 10027.59 10555.40 10535.46 10715.52 10747.64 10785.55 10895.48 11088.81 Inc 0.00 8.25 10.00 8.00 4.21 0.00 10.86 15.00 15.00 15.00 15.00 22.55 58.16 58.16 58.16 58.16 58.16 58.16 58.16 58.16 58.16 58.16 58.16 58.16 58.16 Dir TVD North 275.00 500.00 0.00 273.00 1048.00 2.07 275.00 11 65.29 5.04 275.00 1296.55 4.47 275.00 1548.00 6.81 280.00 1828.1 6 7.71 280.00 2188.00 15.65 280.00 2322.46 19.01 280.00 2393.00 22.29 280.00 2400.00 22.62 280.00 2515.92 28.01 280.80 2748.00 42.27 281.91 5644.31 194.40 281.91 5845.00 260.41 281.91 4065.00 555.50 281.91 5148.00 695.98 281.91 5923.00 951.47 281.91 6858.00 1255.47 281.91 7010.00 1512.61 281.91 7105.00 1544.17 281.91 7200.00 1575.74 281.91 7218.00 1581.72 281.91 7238.00 1588.56 281.91 7296.00 1 407.65 281.91 7598.00 1441.52 East 0.00 -59.46 -57.95 -79.01 -105.79 - 11 6.04 - 149.72 -180.13 -198.74 -200.59 -251.17 -508.51 -1051.75 -1564.78 - 1711.39 -3420.78 -4641.77 - 6083 55 - 6354 31 - 6503 98 -6655 65 -6682 01 -6715 52 -6804 90 -6965.60 V. Sect 0.00 58.81 57.00 77.79 104.56 114.52 148.65 179.46 198.31 200.19 251.18 5O9.49 1067.75 1587.49 1741.52 5487.55 4754.71 6207.1 6 6485.95 6656.85 6789.71 6818.67 6850.86 6944.19 7108.54 Deg/lO0. 0.00 1.50 1.50 1.50 3.00 3.00 0.00 0.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0 0 · Creoted by finchFor: B l~obertson Dote pl~tted: 20-Jan-2000 Plot Reference ~a CD2-23 Ver,~an ~5. I Coordinates ore rn feet reference slo~ ITrue Vertrcal Depths are referenc~ eke (Ooyan ~t41).I ARCO Alaska, Inc. Sfruofure: CD#2 Field: Alpine Field Well: 23 Looaflon : North Slope, Alaska PROFILE COMMENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 HRZ 10027.51 58.16 281.91 6838.00 1255.48 -6083.23 3976.10 0.00 K-1 10353.31 58.16 281.91 7010.00 1312.63 -6354.21 4154.29 0.00 LCD 10555.74 59.15 284.46 7105.00 1544.78 -6504.19 4255.58 9.00 Miluveach A 10748.78 68.75 305.22 7200.00 1423.49 -6679.07 4405.26 9.00 Alpine D 10801.63 71.45 307.40 7218.00 1 452.21 -671 9.59 4449.70 9.00 Alpine 1 O871.02 75.08 312.69 7238.00 1494.96 -6770.41 4511.57 9.00 Tgt-EOC-Csg Pt 11158.95 90.00 331.86 7273.00 1703.96 -6931 . 12 4771.45 9.00 TD 14139.27 90.00 551.86 7275.00 4349.64 -8546.16 7771.78 0.00 ^RCO Alaska, Inc / w.,,:l / Field : Alpine Field Location :Norfh Slope, Alaska[ <- West (feet) 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 200 4300 400 500 600 700 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I §00 500 300 200 ~""' --- -.-~ ~500 "- ----- ~.3400 1 O0 '" -.. ,~...3500 ~ ~ 5200 3000 -.-.-..,.... '" --- .~ 2800 '"" ~ .-.. _... 2500 ~ 2200 1500 '""'la... 0 ~ ~ -- -~ 500 O0 ~1~¢00 300 ~ 1900 800 . ~ %2100 1000 "/ -"'~'~ 2500 1100~/'- 1200,-- '%~2.05 1500 ,¢' O0 1400/,¢' / "~2700 1,500/ ~'~"2800 1600 1700 ,.~ 1800 ~ / 500 / / 1900 .. 200%~/ 600 2100 ~/ 2200/0/ 700 2300.~, / 2400/~/' 800 900 1000 1100 1200 i i i i i , i , i i i i i i i i i i i i , i , i i i , i i ~ , 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 200 500 400 500 600 <- West (feet) ~ 1 O0 -I-- v 200 0 500 I V ,~oo 700 60O 500 400 300 ; 200 - 100 100 f.~ 0 r --4- 200 ~- $00 _~ I 4oo V 500 600 700 1200 1100 1000 900 800 ARCO Alaska, Inc. CD#2 23PH slot #23 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD2-23PH Version #3 Our ref : prop3777 License : Date printed : 23-Jan-2000 Date created : 15-Dec-1999 Last revised : 20-Jan-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 19.446,w151 2 27.795 Slot Grid coordinates are N 5974562.255, E 371704.755 Slot local coordinates are 1794.93 S 1534.46 W Projection type: alaska - Zone 4, SDheroid: Clarke - 1866 Reference North is True North Object wellpath CD2-39 Version 93,,39,CD#2 PMSS <0-11984'>,,35,CD92 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 14-Jan-2000 160.0 300.0 300.0 28-Sep-1999 120.1 100.0 100.0 ARCO Alaska, Inc~ Post Office ~ox 100360 Anchorage, Alaska 99510~0350 Telephone 907 276 1215 February 28, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-23 (& CD2-23 PH) Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. The earliest anticipated spud date for this well is March 25, 2000. It is intended that Doyon Rig 141 be used to drill the well. It is intendeds, that operations on this well be split into two distinct phases. The first visit by Doyon Rig 141 will drill the well down to the 7" intermediate casing point. The well will then be suspended and the rig moved onto other operations. At a later date, estimated at April - June 2001, a rig will return and the horizontal reservoir leg will be drilled prior to completion. Upon completion, the well will be brought on production. CD2-23PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 58©. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to horizontally penetrate the Alpine reservoir. 7" casing will be run and cemented and the well suspended. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. Plat, identifying the surface location of the proposed CD2-23 well. 4. A proposed drilling program, including a request for approval of annular pumping operations. 5. A drilling fluids program summary plus a description of the drilling fluids handling system. 6. Proposed pilot hole schematic. 7. Proposed suspension diagram. 8. Proposed completion diagram. 9. Proposed completion diagram with open hole isolation options. 10. Pressure information as required by 20 ACC 25.035 (d)(2). 11. Diagrams of the BOP equipment, diverter equipment for Doyon 141 out as required by 20 ACC 25.035 (a) and (b). 12. Proposed cementing program and calculations. 13. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). RECEIVED "' 2 9 2000 Alaska Oil & Gas Cons. Commi aion Anchorage If you have any questi6,.o or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Ro~ertso~ n~' dy'/ Senior Drilling Engineer Attachments CC: CD2-23 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin G racie Stefanescu Lanston Chin ATO 1 O54 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com ARCO Alaska, Inc, KUPARUK SATELLITE DISBURSEMENT ACCT P.O. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE CHECK NUMBER 2O6O00163 FEBRUARY 23, 2000 VOID AFTER 90 DAYS *** 62-28 311 0927473 EXACTLY ***********100 DOLLARS AND O0 CENTS $***********100.00 The First National Bank of Chicago-0710 Payable Through FCC National Bank Wilmington, Delaware TRACE NUMBER: 206000163 ," 20 F=O00 ;~ F= ~," '.'0 ~ .],.:~-O0 2:~ 3': Oq 27[, WELL PERMIT CHECKLIST COMPANY r FIELD & POOL / ?¢-4~/4:~ INIT CLASS J WELL NAMEg/~¢/-- dPZ-2~PROGRAM: exp_ dev ~,/redrll__ serv__ wellbore seg ~ann. disposal para req ~ ~'~--"Y~.~ GEOL AREA ~~) UNITe O ~} ~ ~ ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate.~ ................. 3. Unique well name and number;z~-~-'~. ............. 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 ........... ENGINEERING _~ DATE . . ~/~<-<:~ 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '&S'L.~L.~ 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 ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... zN ((~N N N N N DATE 32. Seismic analysis of shallow gas zones ........... .,~,..,¢~'~ 33. Seabed condition survey (if off-shore) .......... .,4r'..X".? Y N 34. Contact name/phone for weekly progress reports [exploratory onlY~-~ N ANNULAR DISPOSAL35. With proper cementing records, this plan '(A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: Z O .-I c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Text for inclusion in permit approval cover letter: In accordance with 20 AAC 25.005 (f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD2-23PH) and AP1 number (50-103-20330-70) from records, data and logs acquired for well CD2-23.
