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Home My WebLink About200-028 Ima~ Project Well History' File Cove~i' 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. ~ ~-2'C-~ ~"Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERL~INCENT SHERYL MARIA WINDY Project Proofing [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: ,_ ~-. BY: BEVERL~INCENT SHERYL MARIA WINDY Scanning Preparation / X 30 = If..___....~~+ BY: BEVERL~OBIN ~,NCENT SHERYL MARIA WINDY m~,-'/~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ BY: Stage 2 BY: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: '~f' YES ~ NO IF NO ~N STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES ~ NO BEVERL~VINCENT SHERYL MARIA WINDY DATE:/~-~.-.~,~S/~.~ (SCANNING IS coMPLETE AT THIS POINT UNLESS'SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) RESCANNEDB?': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is/ General Notes or Comments about this file: Quality Checked 12/lO/02Rev3NOTScanned.wpd F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ALASKA OIL AND GAS CONSERVATION COMMISSION 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 4~4~0O Schh berger NO. 121346 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine (Cased Hole) Color Well Job # Log Description Date BL Prints Sepia CD lqc~, I ~. ~ CD1-03 O., ~.L-. 20127 SCUT 000313 1 CD1-03 ) 20127 JEWELRY LOG 000313 I 1 CD 1-05 I 20128 SCUT 000313 1 !CD1-05 20128 JEWELRY LOG 000313 I 1 CD1-36 20122 SCUT 000311 1 CD1-36 20122 JEWELRY LOG 000311 I 1 CD1-37 20123 SCUT 000311 1 CD1-37 20123 JEWELRY LOG 000311 I 1 CD1-39 20124 SCUT 000311 1 CD1-39 20124 JEWELRY LOG 000311 I 1 CD1-42 20125 SCMT 000312 1 CD1-42 20125 JEWELRY LOG 000312 I 1 CD1-45 20126 SCUT 000312 1 CD1-45 '*" 20126 JEWELRY LOG 000312 1 1 ~ ~_1-1 V PIJ S,G.E~ ~/~~, ~ D^TE: APR 102000 Alaska 0ii & Gas C0,~s. ~ommissi0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~l~.rage Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: Colville Riv Unit CD2-39 Permit # 200-028 April 5,2001 Re: Cancelled Permit Action Colville Riv Unit CD2-39 XX API# 103-20331-95 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. Steve ~nc~na~ns ~ Statistical Technician 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.state.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 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IISSION Doug Chestcr. Drilling Tcam Leader ARCO Alaska. Inc. P O Box 100360 Anchorage. AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1z133 FAX: (907) 276-7542 ac~ Coivillc River Unit CD2-39 ARCO Alaska. Inc. Permit No: 200-028 Sur. Loc. 1954'FNL. 1516'FEL. Sec. 02. TI IN, R4E. UM Btmhole Loc. 2530'FSL. 1054'FWL, Sec. ! 1, TI IN. R4E. UM Dear Mr. Chester: Enclosed is the approved application for permit to the abovc rcferenccd well. 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 (CD2-39PH) and APl numbcr (50-103-20331-70) from records, data and logs acquircd for well CD2-39. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting detcrminations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submittcd to ensure that thc rcquircmcnts of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Ccmcnting records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that anv disposal of fluids generated from this drilling opcration which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 drilling pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through thc annular spacc of a single well or to usc that well for disposal purposcs for a period longer than one vcar. Blowout prevcntion equipment (BOPE) must bc tcstcd 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 by contacting the Commission petroleum field inspector on thc North Slope pager at 659-3607. Robert N. Christcnson. P.E. Chair BY ORDER OF TI-I[.E_VOMMISSION DATED this ~ ~ '~"~ day of March, ;~000 dlffEnclosures cc; Depamnent of Fish & Game. Habitat Section w/o encl. Department of Environmental Conserwition w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 40' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380075& 387207 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1954' FNL, 1516' FEL, Sec.2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 106' FNL, 359' FEL, Sec. 10, T11 N, R4E, UM CD2-39 #U-630610 At total depth 9. Approximate spud date Amount 2530' FSL, 1054' FWL, Sec. 11, T11N, R4E, UM 03/10/2000 $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 12,539' MD Crosses Sec 10 to feet 37.6' @ 478' Feet 2560 7,300' TVD feet 11, T11N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 90° Maximum surface 2571 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 Couplinc, i Len~lth MD TVD MD TVD (include sta~le data) 42" 16" 62.5# H-40 Weld 76' 17' 17' 99' 99' Pre-installed 12.25" 9.625" 36# J-55 BTC 2731' 17' 17' 2748' 2400' 524 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9522' 17' 17' 9539' 7295' 137 sx Class G N/A 4.5" 12.6# L-80 I BT-M 9007' 17' 17' 9024' 7144' 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: true measured vertical feet feet Junk (measured) RECEIVED Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor .... [~ 2 9 2-000 Surface Intermediate Production depth: measured 0RIGINAL Perforatio~iner true vertical 20. Attachments Filing fee X Property plat BOP Sketch X DiverterSketch X Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21, I hereby ce~that thesigned ~'~~ foregoing~AP~l n m ~er'~is true and correct to the best of my knowledgecommissionTitleuse Only Drilling Team Leader Date ~~7/~ Permit Number ~.~:~ I 50. ~,~:~ ?.2 .. ~ ~ ~/....~(~:) I Approval date ~,~.... ~C~,._ ~ I See cover letter for ~ -- ~ ethel_requirements ,, Conditions of approval Samples required Yes o/~o '"~ Mud log required Yes ("'~'o'"'). Hydrogen sulfide measures Yes /"~0"'"')~ectional survey required ~) No ~,..............,.~ Required working pressure for BOPE~2M 3M ~ 10M 15M "~..~(..~~ ~;:~ ~-~,"~" Other: ORIGINAL SIGNED BY Robert N. Chfistenson by order of "~ ~_(~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate V Sca " ' ~ ICINITY MAP le: 1 = 1 M~le I Not Refer to Shee~ 2 for No~es ~ LocaUon Information i AHCO Alaska, I~c. ~ ~b~s ~b s~s c~-~ ~ PROPOSED WELL CONDUCTOR LOCATIONS Subsidiary of Atlantic R~c~fleld Company PERMIT EXHIBIT LK66¢D1 ALL CONDUCTORS ARE LOCATED iN PROTRACTED SEC 2, T 11 N, R 4- E, UMIAT MERIDIAN , Sec Line O/S Plan Well Y' 'X' Lat, (N) FNL FEE (;nd Pad CD2-3 5,974,761,14 371,683,64- 70'20'21,398" 151'02' 28,510" 1,597' !,560' 8,8'15,9' CD2-4 5,974,751.20 371,684.70 70'20'21.300" 151'02' 28,475" 1,607' 1,559' 8.7'15.9' CD2-6 5,974,731,31 371,686,81 70'20'21,105" 151'02' 28,403" 1,627' !,556' 8,7'15,9' CD2-7 5,974,721,36 371,687,86 70'20' 21,007" 151'02' 28,367" 1,637' 1.555' 8,7'15,9' CD2-8 5,974-,711.~2 371,688.92 70'20'20.910" 151'02' 28,332" 1,647' !,554' 8.7'15.9' CD2-9 5,974,701.48 371,689.98 70'20'20.812" 151'02' 28.296" 1,657' 1,553' 8.7'15.9' CD2-105,974,691,55 371,691,03 70'20' 20,715" 151'02' 28,260" 1,666' !,552' 8,7'15,9' CD2-115,974,681,59 371,692,09 70'20' 20,617" 151' 02' 28,224" 1,676' i,550' 8,7'15,9' CD2-125,974,671,64 371,69;5,14 70'20' 20,519" 151'02' 28,188" 1,686' i,549' 8,7'15,9' C92-135,974,661.70 371,694.20 70'20' 20.422" 151'02' 28.153" 1,696' i,548' 8.7'15.9' CD2-145,974,651,75 371,695,25 70'20'20,324" 151'02' 28,117" 1,706' !,547' 8,7'15,9' CD2-155,974,641,81 371,696,31 70' 20' 20,276" 151' 02' 28.081" 1,716' 1,545' 8,7'15,9' CD2-165,974,631,87 571,697,37 70'20' 20,129" 151'02' 28,045" 1,726' !,544' 8,7'15,9' CD2-175,974,621.92 371,698.4-2 70'20' 20.0.51" 151'02' 28.009" 1,736' 1,543' 8.7'15.9' CD2-185,974,611.98 371,699,48 70'20'19,934" 151'02' 27,974" 1,746' 1,542' 8,7'15,9' CD2-195,974,602,0`5 ;571,700,5`5 70' 20' 19,8`56" 151' 02'27.9,58" 1,756' 1,54.1' 8,7'15,9' CD2-205,974-,592,09 ;571,701,59 70' 20' 19,738" 151' 02' 27,902" 1,766' !,5;59' 8,7'15,9' CD2-215,974,582.14 371,702.64- 70'20' 19.64-1" 151' 02' 27.866" 1,776' !,538' 8.7'15.9' CD2-225,974,572,20 ;571,703,70 70"20' 19,54.5" 151'02' 27,830" 1,786' !,537' 8,7'15,9' CD2-2`5 5,974,562,26 571,704,76 70' 20' 19,446" 151' 02' 27,795" 1,795' 1,5;56' 8,7'15,9' CD2-24- 5,974-,552,51 ;571,705,81 70'20' 19,348" 151'02' 27,759" 1,805' !,535' 8,7'15,9' CD2-255,974-,542.37 371,706.87 70'20' 19.250" 151'02' 27.725" 1,815' !,53.3' 8.7'15.9' CD2-265,974,532,42 371,707,92 70' 20' 19,153" 151' 02' 27,687" 1,825' !,5.32' 8,7'15,9' CD2-275,97¢,522,48 ;571,708,98 70' 20' 19,055" 151' 02' 27,651" 1,8.35' 1,531' 8,7'15,9' CD2-285,974,512,53 371,710,03 70' 20' 18,957" 151' 02' 27,616" 1,845' !,530' 8,8'15,9' CD2-295,974,502.59 371,711.09 70' 20' 18.860" 151' 02' 27,580" 1,855' !,528' 8.8'15.9' CD2-305,974,492,64 ;571,712,14 70' 20' 18,762" 151' 02' 27,544" 1,865' 1,527' 8,8'15,9' CD2-$15,974,482,70 ;571,71`5,20 70' 20' 18,665" 151' 02' 27,508" 1,875' 1,526' 8,8'15,9' CD2-325,974,472,76 371,714,26 70' 20' 18,570" 151' 02' 27,472" 1,885' 1,525' 8,8'15,9' CD2-335,974.462.81 ;571.715.;51 70' 20' 18.470" 151' 02' 27,437" 1,895' !.524' 8.8'15.9' CD2-34- 5,974-,452.87 571,716.57 70' 20' 18..372" 151' 02' 27.401" 1,905' !,522' 8.8'15.9' iOD2-`55 5,974,442,90 ;571,717,49 70' 20' 18,274" 151' 02' 27,363" 1,915' 1,521' 8,8'15,9' CD2-365,974,432,98 371,718,48 70' 20' 18,177" 151' 02' 27,329" 1,924' 1,520' 8,7'15,9' CD2-375,974.423.0`5 ;571.719.5.5 70' 20' 18.079" 151' 02' 27,293" 1,934' 1.519' 8.7'15.9' CD2-385,974,413.09 ;571.720.59 70' 20' 17.981" 151' 02' 27.258" 1,944' 1,517' 8.7'15.9' CD2-395,974,403,15 ;571,721,65 70' 20' 17,884" 151' 02' 27,222" 1,954' 1,516' 8,7'15,9' CD2-4-0 5,974,393,20 ;571,722,70 70' 20' 17,786" 151' 02' 27,186" 1,964' 1,515' 8,7'15,9' CD2-415,974-,383,26 ;571,72:5,76 70' 20' 17,688" 151' 02' 27,150" 1,974' i,514' 8,7'15,9' CD2-4`5 5,974,36.3,37 ;571,725,87 70" 20' 17,49`5" 151' 02' 27,079" 1,994' 1,511' 8,7'15,9' ,CD2-44 5,974,353,42 571,726,92 70'20' 17,396" 151' 02' 27,045" 2,004' 1,510' 8,6'15,9' CD2-4-5 5,974,343,48 ;571,727,98 70' 20' 17,298" 151' 02' 27,007" 2,014' 1,509' 8,6'15,9' C~):Z-,-~ 5,~'~.333.5' 3~.~9..'~ '~' 20' ~.2e~" ~5~' ~2' 26.97~" 2.~2.r ~.5.s' s.~'~5.g' CD~-.7~,~)7..,323,5~) 37~,730,09 70'20' ~7,~03" ~s~' 02' 2~,93~" ~,.3,r ~,s~7' s,~'~5,g' CD2-485,974,`51`5,65 ;571,7;51,15 70' 20' 17,005" 151' 02' 26,900" 2,044' 1,505' 8,6'15,9' CD2-495,g74,303,70 371,7;52,20 70' 20' 16,907" 151' 02' 26,864" 2,854' 1,504' 8,5'15,9' CD2-505,974,293.76 371,733.26 70'20' 16.810" 151' 02' 26.828" 2,66;5' 1,503' 8.5'15.9' CD2-515,974,283,81 ;571,7;54,.31 70'20' 16,712" 151' 02' 26,792" 2,073' 1,502' 8,5'15,9' ....CD_2._--_52__5,974,27`5,87 ;571,7;55,`57 70'20' 16,615" 151' 02' 26,756" 2,08;5' 1,500' 8,5'15,9' ,NOTES; 1. COORD]NATES SHOWN ARE ALASKA STATE PLANE, ARCO Alaska, Inc. Subsidiory of Atlontic Richfield Company · i'1 ii ~,~. ,, ALPi'NE DR[LL S~TE CB-2 PROPOSED WELL CONDUCTOR LOCAT[ONS PERMIT EXHIBIT CADD FILE NO, I DRAW[NC NO: ]SHEET: IREV: LK664D1 2/08/0~1 NSK 6,64-dl 2 OF 2 e Alpine · CD2-39PH (Pilot Hole) [ .,D2-39 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. Rig up and run electric line logs to TD (GR/Res/Dens/Neut). 4. Run and cement 9 5/8 surface casing. 5. Install and test BOPE to 3500 psi. 6. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. 7. Drill 8 Y~" hole to a point +/- 120' below the base of the Alpine Sand. 8. Set 500 ft cement plug #1 from TD to +/- 8842'. Set 400 ft cement plug #2 from +/- 8842' to +/- 8442'. 9. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 8577' 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. ¢!: ~ ...... !~: 1%, '? 2nd Rig Visit (Year 2001- most likely with Doyon 19) 16. R/U over CD2-39 and test BOPE equipment to 3500 psi. 17. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform for~t~tegnty 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 TM. 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. 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 CD2-39 (37.6' at 478' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 35.0' at 511' 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. A large fault (up to 35' throw) is prognosed approximately 200' from the 7" casing point. 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~ Operations: Incidental fluids developed from drilling operations on well CD2-39 will be injected into the annulus of well CD2-35 (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 CD2-39 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 CD2-39 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 ,h~;tl~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 CD2-39 & CD2-39 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 rain 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 Configuration · 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 CD2-39PH Pilot Hole- Prior to Sidetracking Assumes RKB - MSL = 40' therefore, RKB - GL = 22' Wellhead Updated 02/23/00 16" Conductor to 99' 9.8 ppg drilling mud in hole Top Alpine Reservoir at 9112' MD / 7245' TVD._ Pilot Hole TI:) at 9342' MD / 7420' TVD (+/- 40 deg inc.) Cement Plug ,i i. .... ...... Plug ,#1 ~ 5oo ft 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2748 ' MD / 2400' TVD cemented to surface Top of cement plug dressed off to sidetrack point at 8577' MD / 6838' TVD (+/- 40 deg inc.) Top of Cement Plug #1 at +/~ 8842' t Colville River Fiel~ CD2-39 Temporary Suspension Schematic Diesel Freeze Protection in casing and annulus to 2000' TVD. [ Wellhead installed with tubing hanger and BPV set and pressure tested to 3500 psi 1 jt tubing with WEG. 16" Conductor to 99' Updated 02/24/00 Assumes' RKB = MSL = 4O' RKB - GL = 22' 9.8 ppg drilling mud in annulus 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2748' MD / 2400' TVD cemented to surface 9.6 ppg brine with diesel freeze protection to 2000' TVD. TOC at 8749' MD (500' MD above top Alpine Casing pressure tested to 3500 psi on plug bt ~. 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 9539' MD / 7295' TVD @ 90 deg Colville River Field CD2-39 Production Well Completion Plan 16" Conductor to 99' Updated 02/24/00 Assumes RKB - MSL = 40' therefore RKB - GL = 22' 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 @ 2748' 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 MD, TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 2000 psi set 2 joints above the X landing nipple Tubing Hanger 17' 17' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1828' 1700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4061' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 6426' 5200' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 8923' 7084' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 8992' 7126' 4-1/2" tubing joint (1) Baker S3 Packer 9024' 7144' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 9089' 7178' 4-1/2" 10' pup joint WEG (+/- 62 deg) 9100' 7184' Cd2-39PH - cement kick off plug at 8577' MD Note: solid body aluminum centralizers installed between 2400' TVD (=2748') and 4500' TVD (=5506') Baker S3 Packer at +/- 9024' TOC @ +/- 8749' MD (500' MD above top Alpine) Well TD at ........ . ..... .... !..i.-i~ -,.' ,:-. ::1,~2~,3~' MD / .............. · : : ~:':..¢ ~:~t),¢" TVD Top Alpine at 9249' MD/7245' TVD ................................. ~ ,,~. ~'/¢1~ ~,,~ 7" 26 ppf L-80 BTC Mod Production Casing @ 9539' MD / 7295' TVD @ i ii',' Colville River Field CD2-39 Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 99' Updated 02/07~00 RKB - MSL = 40' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" s/s control line @ 1700' TVD = 1828' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2748' 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 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) Muleshoe / Entry Guide (C) Open Hole Bridqe Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe TOC @ +/- 8749' MD (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 .... ' ~.',, Well TD at ~ ....... P 12539' Baker S3 acker set at +/- 9024' MD / , ~ ........... 7300' TVD ~ -T ................. ~ ............... .............. lqo P .... ' ...... ~ ~ ~i~ ~';~li~ii i i. ~ 7" 26 ppf L-80 BTC Mod Production Casing @ 9539' MD / 7295' TVD @ 90 deg CD2-39 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 99 / 99 10.9 52 53 .... 9 5/8 2748 / 2400 14.2 1086 1532 7" 9539 / 7295 16.0 3300 2571 N/A 12539 / 7300 16.0 3303 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 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 = -- ASP = [(FG x 0.052) - 0.1} D [(14.2 x 0.052) - 0.1] x 2400 -- 1532 psi OR FPP - (0.1 x D) 3300 - (0.1 x 7295') = 2571 psi Drilling below intermediate casing (7") ASP = -- FPP - (0.1 x D) 3300 - (0.1 x 7295') = 2571 psi Alpine CD2-39 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -500 -1500 -2500 ~ -3500 ~ P£ -4500 -5500 -6500 -7500 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT ARCO Alaska, Inc. Doyon 141 Diverter Schematic 21¼" 2,000 psi wP DRILLING SPOOL w/16" Outlet Flowline ~ 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE / 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 J 1 F I I 3" 5,000 psi WP OCT i-l MANUAL GATE V KILL. LINE ~r~ 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / DSA 13-5/8"5,000 psi WP x 11" 5,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple 3" 5,000 psi WP Shaffer GATE VALVE ~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL '~'~ w/two 3" 5M Dsi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom Alpine, CD~..,9PH & CD2-39 Well Cementinq F~.~uirements 9 5/8" Surface Casing run to 2748 MD / 2400' TVD. Cement from 2748' MD to 2248' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2248' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2248'-1622') X 0.3132 ft3/ft X 1.5 (50% excess) = 294.1 ft3 below permafrost 1622' X 0.3132 ft3/ft X 4 (300% excess) = 2032.0 ft3 above permafrost Total volume = 294.1 + 2032.0 -- 2326.1 ft3 -> 524 Sx @ 4.44 ft3/sk System: Tail slurry: 524 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% BWOW~ D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft~ shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 -> 230 Sx @ 1.17 ft~/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 9539' MD / 7295' TVD Cement from 9539' MD to +/- 8749' MD (500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9539'- 8749')o X 0.1268 ft3/ft X 1.4 (40% excess) = 140.2 ft3 annular volume 80' X 0.2148 ft"/ft = 17.2 ft3 shoe joint volume Total volume = 140.2 + 17.2 = 157.4 ft3 => 137 Sx @ 1.15 ft3/sk System: o o o 137 Sx Class G + 0.2 Yo D046 antifoamer, 0.25 Yo D065 dispersant, 0.25 Yo D800 retarder o 3 and 0.18 Yo D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft/sk CD2-39PH Cement Plug #1: 9342' MD to 8842' MD = 500'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft~/ft X 1.15 (15% excess) = 226.6 ft3 => 197 Sx @ 1.15 ft3/sk CD2-39PH Cement Plug #2: 8842' MD to 8442' MD = 400'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 400'X 0.3941 ft~/ft X 1.15 (15% excess) = 181.3 ft~ => 182 sx @ 1.00 ft~/sk ~ By Weight Of mix Water, all other additives are BWOCement ARCO Alaska, Inc. Structure: CD#2 Well: 59PB1 Field : Alpine Field Location: North Slope, Alaska 40o 800 1200 1600 2OOO 2400 2800 c' 5200 5600 12 4000 ~ 4400 I 4800 x/ 520O 5600 6000 6400 6800 7200 7600 ESTIMATED RKB ELEVATION: 40' KOP 5.00 6.00 9.00 DLS: 5.00 decj per 100 fl: 12.00 i. O0 18.00 ~ 21.00" Sok 24.00 27.00 30.00 55.00 Permafrost 59.00 EOC C40 9 5/8 Cosing C50 C20 230.23 AZIMUTH 5347' (TO TO) ***Plane of Proposal*** AVERAGE ANGLE 40.42 DEG K-5 K-2 Albion-97 Albion -96 HRZ K-1 LCU Miluveoch A Alpine D Alpine TD KOP - Sidetrack Pt I I I I I I [ I I I I i ] I [ I [ I [ I[ I I I 400 800 1200 1600 2000 2400 2800 3200 5600 4000 4400 4800 5200 5600 6000 Vertical Section (feet) -> Azimuth 2/50.25 with reference 0.00 N, 0.00 ir from ARCO Alaska, Inc. Sfruoture: CD#2 Well: 59 Field: Alpine Field Loootion : Norlh Slope, Alaska Crooked by finch For: B Robe~'taon Dote plotted: 25-Dec-199g I I P~ot Reference 18 C02-39 VerBlon I Coord[no[ .... in 6660 6840 7020 7200 7580 7560 151 .§6 AZIMUTH 40§1' (T0 TD) ***Plone of Proposol*** HRZ K-1 LCU Miluveoch A AIp.[n~ D Alpme Bose Alpine TD TARGET ANGLE 89.9 DEG TD i i i I i i i i i i i i i i i i ! i i i I i i ii i ii ! i i i i i i i i i i i i i i i i i i O 180 360 540 720 900 1080 1260 1440 1620 1800 1980 2160 2340 2520 2700 2880 5060 3240 5420 5600 5780 5960 4140 VerfTcolSection (feet)-> Azimuth 151.86 with reference 0.00 N, 0.00 E from slot #59 ARCO Alaska, In'c Structurs: CD#2 Wall: ~9 / Field : Alpine Field kooofion: North Slope, Aka 550 700 1050 1400 1750 2100 2450 '-I-- Q) 2800 · +- 3150 0 5500 I v 3850 4200 4550 4900 5250 5600 5950 6500 <- West (feet) 4900 4550 4200 3850 5500 3150 2800 2450 21 O0 1750 1400 1050 700 550 0 550 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 ESTIMATED SURFACE LOCATION: W Sok 1954' FNL, 1516' FEL Perm~frost SEC. 2, T11N, R4E EOC C20 C40 C50 9 5/8 Casing CD2-59PB1 TD LOCATION: 363' FSL, 7.31' FEL SEC. 3, T11N, R4E K-3 K-2 Albion-97 Albion -96 HRZ K-1 LCU Miluveoch K- 1 - Sidetrock Pt E~oS~ TD LCU Miluveach A pipe D ~pme TARGET/EOC/CSG PT CD2-39 TGT - CSG PT LOCATION: 106' FNL, 559' FEL SEC. 10, T1 1N, R4E TD CD2-59 TD LOCATION: 2530' FSL, 1054' FWL SEC. 11, Tll, R4E i i i i i i i i i i i i i i i ii i iI i i i i i i i i i i 4900 4550 4200 3850 3500 3150 2800 2450 21 O0 1750 1400 1050 700 350 0 350 <- West (feet) 550 7O0 1050 1400 1750 2100 56O0 5950 6300 525O 4900 4550 4200 5850 2450 0 2800 r" ..+. 3150 '-~ ---I- 3500 I v Creoted by finchFor: B Robertson Date plotted: 22-Dec-1999 Plot Reference ;s CD2-59PB! Version ill. I Coardinates are in [eet reference slat ~159. [ True Vertical Depths ~n~e [*tlm~l ~B.I ARCO Alaska, Inc. Structure: CD~2 Field : Alpine Field Well: 5gPB1 Looation: North Slope, Alaska Point KOP W Sak Permafrost EOC C40 C50 9 5/8 C20 K-3 K-2 Albion-97 Albion-96 HRZ K-1 LCU Miluveach A Alpine D Alpine Base Alpine TD Casing Po;nt PROFILE COMMENT DATA MD Inc Dir TVD North 400.00 0.00 0.00 400.00 0.00 1052.63 19.58 236.62 1040.00 -60.75 1 621.61 36.65 236.62 1540.00 -207.75 1747.42 40.42 256.62 1 658.59 -250.84 2458.86 40.42 236.62 2180.00 -504.65 2728.15 40.42 236.62 2385.00 -600.72 2747.85 40.42 236.62 2400.00 -607.75 5194.47 40.42 236.62 2740.00 -767.08 4634.14 40.42 236.62 3836.00 - 1280.69 4928.39 40.42 236.62 4060.00 - 1585.66 6675.44 40.42 236.62 5390.00 -2008.93 7509.56 40.42 256.62 6025.00 -2306.50 8593.26 40.42 236.62 6850.00 -2693.12 8829.70 40.42 236.62 7030.00 -2777.47 8947.92 40.42 236.62 7120.00 -2819.64 9058.26 40.42 236.62 7204.00 -2859.01 9081.91 40.42 236.62 7222.00 -2867.44 9112.12 40.42 236.62 7245.00 -2878.22 9213.27 40.42 236.62 7322.00 -2914.31 9342.00 40.42 236.62 7420.00 -2960.23 East 0.00 -92.21 -515.27 -580.71 -765.95 -911.75 -922.4O - 11 64.25 - 1943.75 -2103.07 -3049.03 -5500.67 -4087.45 -4215.48 -4279.49 -4539.23 -4552.04 -4368.59 -4425.16 -4492.86 V. Sect 0.00 109.74 375.21 455.08 911.54 1085.06 1097.76 1585.55 2315.27 2502.88 5628.67 4166.17 4864.50 5016.86 5095.04 5164.14 5179.38 5198.85 5264.05 5546.98 b.dO 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0~00 O.dO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Created by finch For: B Robertson Dote plotted: 22-DOc-1999 Plot Reference is CD2-39 Vergon ~12. True%rrtd;:~t~e;;; in feat refernc?~_s~lmOto[ ARCO Alaska, Inc. Strunfure: CD#2 Reid : Alpine Reid Well : 59 Looallon: North Slope, Alaska PROF Point MD KOP - Sidetrack Pt 8577.26 HRZ 8593.25 K-1 8840.22 LCU 8981.86 Miluveoch A 9143.96 Alpine D 9186.47 Alpine 9248.61 TAROET/EOC/CSO PT 9558.73 LIE [nc 40.42 40.54 47.20 54.11 65.61 66.29 70.30 89.90 COMMENT DATA Dir TVD North East 236.62 6837.83 -2687.42 -4078.76 254,41 6850.00 -2695.30 -4087,51 203.54 7030.00 -2824.73 -4190.07 189.65 7120.00 -2929.56 -4220.57 176.67 7204.00 -3067.53 -4227.59 173.66 7222.00 -3105.68 -4224.14 169.46 7244.99 -5162.77 -4215.64 151.86 7295.00 -3429.57 -4120.60 V. Sect Deg/lO0 446.11 0.00 447.26 9.00 51 4.69 9.00 592.57 ,c~='O 711.01 9.00 746.37 9.00 800.71 9.OO 1080.80 9.00 TD 12539.05 89.90 151.86 7500.00 -6075.25 -2705.56 4081.12 0.00 ARCO Alaska, Ine Structure: CD#2 Well: 59PB1 Field: Alpine Field Location : Norlh Slope, 40 30 20 10 10 (D ~1 20 -~- 50 0 40 I V 50 6O 80 go <- West (feet)' East (feet) -> 80 70 60 50 40 50 20 10 0 10 20 50 40 ,50 60 70 I I I I I I I I I I I I I I I I r I I I I I I I I I I I I I I 500 500 600 700 800 900 1000 1200 1400 1600 ~-~0 ',,,. ~ ~oo 600~ ~2~oo 90~0/ 800 ~' 700,~ / lO0 110 120 ~o ' ~'o ' ~'o ' io ' ;o ' <- West (feet)' East (feet) -> 80 50 10 20 r- 30 ~ ---!- I V 50 60 70 80 90 1 O0 110 120 ARCO Alaska. Inc. CD~2 39 slot #39 A1 pi ne Fi el d North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : CD2-39 Version #2 Our ref : prop3714 License : Date printed : 23-Dec-1999 Date created : lO-Nov-1999 Last revised : 22-Dec-1999 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w1511 42.976 Slot location is n70 20 17.884,w151 2 27.222 Slot Grid coordinates are N 5974403.146, E 371721.646 Slot local coordinates are 1953.74 S 1514.88 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-11984'>,,35,CD~2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 28-Sep-1999 37.6 477.8 10040.0 ARCO Alaska, Inc~' Post Office box 100350 Anchorage, Alaska 99510-0360 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 CD2-39 (& CD2-39 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 10, 2000. It is intended that Doyon Rig 141 be used to drill the well. It is intended 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. CD2-39PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 40°. 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 CD2-39 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 FEB 2 9 If you have any questi~l,o or require further information, pleaset~..,ntact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Senior Drilling Engineer Attachments CD2-39 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin G racie Stefanescu Lanston Chin ATe 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tom my_Thom pson @ anadarko.com PA:'-YAB~ES.:-..:- ?:-...:::~:: ..:..?. _?::.:. .~:::~.: ~:'::-~ .'_:"?.. :::.::::" '-:.'- :-.-.--. .:-;~ :'" ' .. .-:~.~..~::..~-~ ,~:. ?~?-:,~-.~..~- -~::~.:...--~:.~:~:~. ~?.--._.~.~.- .~:.~: ~:~:-.~:- c~-~...~.~ ~o'~.'o~3:~ 76'~":~.- .'- -.. '.:.:~ · :'?~'~'~8:~8~, AK 99519.2776 '" "-:'?:-~:-~' "~-?.-'.'-?.t_.:-?' .?.. ~_:: ~.-).::: -/:: : -:':-:. .. .:-::-:'-' :-:::- -:-:.. ':"?::' ..... ' ":::':':???':"" :"-..:'-::i. tF-':::--.- -._.: .::-:.-.:._.?::.::.... .-"-.: .. --..~ ....... '--:::~%~-'~-'-'-:-~-2~°~~-~-: .... . -. - - :-'-.:-':.:-..:--:.:~,u~,~?:~,:.'~Ooo ..... o~~ Through Republ~c. Bank.' ' .- .- 0 .'. --.. -J ,/ 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 (CD2-39PH) and API number (50-103-20331-70) from records, data and logs acquired for well CD2-39. WELL PERMIT CHECKLIST COMPANY -/~/~,,') WELL NAME ~Z,e'A d62-.-~c) PROGRAM: exp =IELD & POOL / ~__g..~//<~C"~ INIT CLASS '--'~c,/ /'- ~)/c..- GEOL AREA DATE 3-!.C,D ENGINEERING DATE GEOLOGY dev 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number2~ ............... 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 pady ................... 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 ~'C3 (:3 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 ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... v' redrll __ serv __ wellbore seg ~ann. disposal para req ~ UNIT# ~--~ --% ~ ~..~ ON/OFF SHORE N , N 31. Data presented on potential overpressure zones ...... . .j ~ 32. Seismic analysis of shallow gas zones ......... .z~.,"/~ Y DATE 33. Seabed condition survey (if off-shore) ......... i i ~t~.'/") y -.~-//' ~ 34. Contact name/phone for weekly progress reports [exploratory only~_~ ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; ~ .,, ~/~ IO o (C) will not impair mechanical integrity of the well used for disposal; ~ ' ~ (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: 0 Z 0 -.I c:\msoffice\wordian\diana\checklist (rev. 02/17/00)