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Home My WebLink About199-035Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) R,~A'Nlor items: [] Diskettes No. o Maps: ~.~Grayscale items: [3 Other. No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds [] Other TOTAL PAGES: ,~)I NOTES: ORGANIZED BY: BEVERLY BRE~HERYL MARIA LOWELL DATE;¢'~(~ 'S'~ Project Proofing PROOFED BY: BEVERLY [] Staff Proof By Date: BREN ~ SHERYL MARIA LOWELL Scanned (done) PAGES.'~ SCANNED BY. (at the time of scanf~i,',9) BEVERLY BR~SHERYI MARIA LOWELL ReScanned (done) RE SCANNED BY: BEVERLY BREN VINCENT SHERYL~ LOWELL E)ATE General Notes or Comments about this file: ~ ~'~/ PAGES: Quality Checked (done) Rev 1NOTScenned.wPo Memorandum To: Well File: 199-035 State of Alaska Oil and Gas Conservation Commission DATE June 26, 2000 Re.' Cancelled or Expired Permit Action EXAMPLE: Colville River Unit CD1-30XX API# 103-20296-95 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 number for a cancelled or expired permit is modified with an appended XX. CANCELED PERMITS ARE RELEASABLE 2 years from the date on the letter received from the operator requesting the permit canceled.. (Memorandum January 23, 1997 by Dave Johnston, subject: Canceled and Expired Permits) EXPIRED PERMITS ARE RELEASABLE 2 years from the date on the application was issued by the commission, unless the operator ask for extended confidentiality. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 22, 2000 / e ~ - 03 :~ Alaska Oil and Gas Oonservation Oommission- 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill: CD1-30, dated 29 March 1999. Dear Sirs: Please note that well CD1-30, as referenced above, was never drilled and that all plans to drill along this well path have been dropped. Please disregard the previously applied for permit to drill. Well assignments, relating surface locations to bottom hole locations on certain wells were altered after some early development well data was obtained. A future CD1-30 well is planned, and although slot 30 on the pad will be utilized, the well path (and bottom hole location) will actually be different from the that proposed in the earlier application. Included for you reference is a copy of the cover letter and form 10-401 previously submitted. If you have any questions or require further information, please contact Brian Robertson at 265-6034. Sincerely, Brian Robertson Senior Drilling Engineer Attachmentscc: '/~ CD1-30 Well File / Sharon AIIsup Drake Doug Chester ATO 1 O54 ANO 382 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION April 21, 1999 Doug Chester 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 Re: Colville River Unit CD 1-30 ARCO Alaska, Inc. Permit No: 99-35 Sur Loc: 430'FNL, 2370'FWL, Sec. 5, T11N, R5E, UM Btmhole Loc. 908'FSL, 1552'FEL, Sec. 30, TI2N, R5E, UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing 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 any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD 1 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 the annular space of a single 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. 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 conta/ct~the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Chh enson, P.E. Chairman BY ORDER OF THE COMMISSION dlfJEnclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation xv/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen! 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 57' feet Colville River Field 3. Address 6. Property, J~.,es. jg.natipn ~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL~5~,~,~K 4717 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 430' FNL, 2370' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1493' FNL, 280' FEL, Sec. 31, T12N, R5E, UM CD1-30 #U-630610 At total depth 9. Approximate spud date Amount 908' FSL, 1552' FEL, Sec. 30, T12N, R5E, UM 5/15/99 $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 CD1-24 11,634' MD Crosses line feet 58.5' @ 478' feet 2560 6,914' TVD feet (T11N to T12N) 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 93° Maximum surface 2457 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplin~l Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 84' 37' 37' 121' 121' Pre-installed 12.25" 9.625" 36# J-55 BTC 2685' 37' 37' 2722' 2407' 395 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 8874' 37' 37' 8911' 6972' 175 sx Class G N/A 4.5" 12.6# L-80 IBT-M 8824' 37' 37' 8861' 6986' 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 Structural Conductor :~- '.i '; ' ' Surface Intermediate Production Perforatio~i;ee;th: measured 0 RI GIN A L true vertical . i ':: 20. Attachments Filing fee X Property plat X ::: :!Bop';gketch Diverter Sketch Ddlling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby c~ that the foregoing is true and correct to the best of my knowledge Signed ~~,.~ ~4~...~ .~~ ~ Title Drilling Team Leader Date Commission Use Only I//~,~-' I Approvaldate I 50- ~,_C]) ~.,'~ _ ~ _~,~...~:~(:~ cover letter for · Other retirements ConditiOns bf approval Samples required,,,,,~_ Yes N/'~b'"~ Mud log required~ ~(es N~ Hydrogen sulfide measures Yes (N0~,~~irecti°nal survey required ~ No Required working pressure for BOPE 2M 3M 5M 10M 15M Other: ORIGINAL SIGNED. BY Robert N. Christonson by order of q__~.. _C~ Approved by Commissioner the commission Date ......... Form 10-401 Rev. 7-24-89 Submit in tdplic~ te ®~ EXHIBIT "1" ®CONFIDENTIAL Well Name: Alpine CD1-$0 Surface Location: 430' FNL, 2370' FWL,$e¢. 5, T11N, RSE, UM Target Location: 1493' FNL, 280' FEL, Sec. 31, T12N, RSE, UM BoEomhole Location: 908' FSL, 1552' FEL, Sec. 3, T12~, RBE, UM S~le: 1" = 2,000' 3-~-99 99032206A00 ~c~ // '% Location ,7~ ~ g x~-, ~5 Location 7~ ~ L~at~on ~ar-I?-gg ll:ZZam Fro~-^LPI~E APC . +lg0NS0405B T-532 P.03/05 F-003 ~ ' ALPiNE"FAClLi:rY~' "~ ~ICINITY MAP NOT TO SCALE , 3002 .- -.,_o 14 ' 2~ o020 / 23o"22 / 25o°2~ 290°28 31 oO50 % '/ / / 570°~6 ~oo~0 . LEGEND, , *s°°~2 / * EXISTING CONDUCTORS 45 O O~¢ ~ / o NEW CONDUCTOR LOCATION ..... % / Il I I I I Ill I I I I I I I I I IIII . I I I II . II I ARCO Alaekt, Inc. ~ A~INE PROJECT ~ 0D1 ~[ CONDUCTORS Subsidiary of Atlontic Richfield Company .... AS-BUIpT LOCA~ONS :.~ 'c*"""~"°"!.,,.~, .......... ?/.. I""'"~"°;'' ..... 0~-c~0~¢~.~ ' t/lar-l?-99 11:22am From-ALPINE APC 3 per Aggoo1ACS_ +100/'4804066 T-$32 P.04/05 F-O03 ALL CONDUCTORS ARE LOCATED IN SEC 5, T 11 h, R 5 E, UMIAT MERIDIAN Se,~ Line 'Y' 'X' Lei:. Gnd Pad .s,ooo.o 70' =o'°' ss' C01-2 5,975,897.9 385,992.9 20' 34.85" 150' 55' 31.07" 229' 2,565' 13.0' 19.5' CD1 3 5,975,890.9 '385,985.9 .. 70' .... - '' ' .7.0' '20' 34-.78" 1,50' 55' 31.2.7" 2.36' 2,558' 13.1' :'19.5' ...C01-4. 5,975,883,8 385,978.8 70' 20' 34...71" 150' 55' 3,1.4:.1~t" 24,3' .2,551' . 13.2' 1..9.5' C01-.5 5,975,876,7 385.971.7 70' 20' 34-.64," 15.0' 55' 31~6.8': .251,' 2,54,4.' 13.3' 19.5' C01-6, 5,975,869.6 385,964,.6 70' 20' 54.57" 150' 55' $1.83[" 258' 2,537' 13.4.' 19..5' -C01-,7, 5,975,862.6 385,957.6 70' 20':3~..50" 1513' .55' 32..09" 2,65' 2,530' 13.3' 19.5' CD1-8 5,975,.855.5 385,950.5 70' 20' 34.45" 150' 55' 32.2'3" 272' 2,5.25' 13.2' 19.5' Cql-g 5,975,848.4 385,943.,4 70' 20' 34..36" !57 55' 32.,4.g"_._ 279' 2,5!7' 15..1.':19.5' .CDI-IO 5,975,841.34,' 365,936.18 70' 20~ 34.287" .1SO' 55'. 32.7.35" 286' 2,510' 13.0' 19.5' C01-11 5,975,834...3 385'1929.3 70' 20' 34.22" 150' 55' 3.2.99" 294,' 2,503'. 12.9' 19.5' C01-12 5,975,827..2 385~a22.2 70' .20' 34.15" 150' 55' 33.1.{Y' 501' 2,¢96'. 12.a' 19..5' -~01-1.3 5,.975,8.20~_00 385,915.06 7_0' 20' 34.0.7a," 150' 55' 33~..311" 308' 2,4,69' 12.7' 19.5' C01-14 5,975,812,97 38.5i908.00 70' 20' 34..004" 150' 55' 35.5.1~/' 315' 2,4.82' i2.6' 19.5~ C01-15 5,975,806,0 385,901.0 70' 20' 33-95" 150' 55' 55..7_2" 3.22' 2,4,75' 12.5' 19.5' C01-1.6 5,975,798,.86 385,894.08 70',20' 33.865' 150' 55' 33.914." 330' 2,4.68' 12.4,' 19.5' C01-17 5,975,791.81 385,886.84, 70' 20' 33:.793" 150' 55' 34-.12.3" 357' 2,4.61' 12.3' 19.5' C01-.1..8. 5,975,78~;91. 385,879.88 70' 20' 33.724,". 150' 55' 34..32-3" 344' 2,4,54' 12.2' 19.5' C01-19 5,975,777.92 3~5,872.81 70' 20' 33.65¢= 150' 55' 5,4.526" 35.1' 2,4.4,7' 12.1' 19.5' C01-20 5,975,770.7 _ 585,8,65.7 70' 20"33.58" 150' 55' 34.73" 358' 2,440' 12.0'- 19.5' C01-21 5,975,763..6 _585,85.8..6 70' 20' 33.51" 15_0' 55' 34.94.". .. 365' 2.,433'. 11.9' 19.5' · C01-22 5,975,756.4,6 385,8.51.10 70' 20', 33.4,40" 15,0' 55' 34.151" 373' 2,426: 11.9' ..19.'5' C01-23 .5,975,749.4 385,844.4. 70' 20"33.37". 150' 55' 35.5~" 580' 2,419' 12.0' 19.5' C01-24 5,975,7.42.4. 3a5,837.4 70'_20'33.30". 150'55' 35.55.". 387' 2,4.12' 12.2' 19.5' C91.-25 5,975,7'35.3 565,S30.3 7,0' 2.0' 53.23"' _~ .150' 55'.55.75"' -,~,cJ4.' .2,4.05° 1.2.4' 19.5' C01-26 5,975,728.2 385,_823.2 70' 20' 33:16" 1'50' 55'.35.65" 4,01' 2,398',. 12.6' 19.5' C01-27 5,975,721.2 385,816.2 . 70',"20'.';33.09" 150' 55' 36.1.~" :~8' 2,39,1' 12.8' ,.19.5' C01-28 5,975,714..1 385,809.1 70';'20' 33.02' 150' 5.5' 35.5.6." '.4i~-. 2,385;..13.0' .,19.5' C01-29 5,.975,707.0 385,802.0 70' 20' 32.95" 150' 55' .3.6,56" , 4-23' 2,377' 13.2'_ 19.5'_~ C01'30 5,975,699.9 385,794..9 70' 20' 52.88" 150' ~5' 36.77" 4.30'. .2,37(3~ 13.4' 19.5' C01-31 5,975,692.9 385,787.9 70' 20' 32.a0" 150' 55'.36~97" 4.37' __2,365' 15.3'. 19.5' CD1-32 5,975,685,8 385,780.8 70' 20' 32.75" 150' 55' 37.17" 4.4,4,' 2,356' .13.2' 19.5' C01-.~3 5,975,67.8.7 385,773.7 70' 20' 52.66"- 150' 55' 37.2i8" 4,52' 2~.34.9' 15:1' .19.5' C01-3~. 5.975.671..7 385,766.7' 70' 20' 32.59" 150',.55' 57.=.'~8" '-'459' 2,3¢2' 13.0' 19.5' C01-35 5,9-75,664..6 385.759.6 70' 20'. 32.52" 150' 55'-57.78" 4.6.6' 2,355' 12.9' .19.5' '-~:01-36 5,975,657,5 585,752.5 . 70' 20' 32.45" ,1.50' 55' 37.99" 475' .2,328'. 12.8'. 19.5' C01-37 5,'975,65.0.4 385,745.4' 70' 20' 32'38" 150' 55' 38.19" .480' 2,521' 12.7' 19.5' C01-38 5,975,643.4, 385,7.38.4 70' 20' 52...31" 150' 55,,' 3B.,~g" 4.87' !_2,31'4; 12.6' 19.5' i. C01-59 5~975,636.3 385,731.5 70' 20' 32.24," 150' 55' 38.60" · 495' 2,507' 12,5' 19.5' cD1-L40 5,975,629.2 385,724..2 70' 20' .32.17' 150' 55' 38,~i0" 502' 2,500' 12.~' ]..19.5' C01-41 5,975,622..2 585,717.2 -i 70" 20.' 32.10" 150' 55' 39.00" 509' 2,293' 12.3' 19.5' C01-42 5,_975,615.1 585,710.1 70' 20' 32.0-3" 150' .55~ 59.?.1". 516' 2,.2.86' 12.2' 19.5' C01-43 .5,97~5,608.0 585,703;0 70' 20' 51.96" 150' 55~ 59.,~1" 523' 2,27.9' 12.1' .19.5'. C01-44, 5,975,600.9 585,695.9 70' 20' 31.89"' ' 150'.55' 59.61" 53_1/ 2,272'. ~12.0' 1.9.5' C01.-45 5,975,593.9 .385,688.9 70' 20' 31.8.2" 150' 55' .3.9.!~2" 538' 2,265'.i .12.0' 19.5' * C01--22 CONDUCTOR WAS AS-BUILT 2/11//98. ~'-~-LOUNSBURY C/15/ & ASSOCIATES, i ii _-- i ARCO Alaska, Inc. Sub$idlery of Atlonti¢ Richfield Company ALPINE PROJECT CD1 WELL CONDUCTORS' AS-BUILT LOCATIONS -- CE-C010-66501 ._ i SHEET';2,-- OFS, IREV: 1 Uar-l?-gg 11:22am From-ALPINE APC 1 13/5;/99t_ MRTI.. I I I iPer A99001ACS +19074804056 T-$32 P.05/05 F-O03 NOTES 1. THIS DRAWING SHOWS THE LOCATIONS FOR A TOTAL OF 45 CONDUCTORS. CD1-22 WAS INSTALLED AND DRILLED IN MARCH, lg98. 2. CELLARS ARE tN PLACE AT THE TIME OF' THE ISSUANCE OF THIS DRAWING. ASSISTANCE WILL BE GIVEN BY LOUNSBURY & ASSOCIATES IN ALIGNING THE KELLY BAR FOR CONDUCTOR DRILLING OPERATIONS. - ., 3. ALL COORDINAT£S ARE ALASKA STATE PLANE, ..ZONE 4, NAD 27. ¢. ELEVATIONS ARE' BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND'. E. LEVATIONS ARE INTERPOLATED F'ROM MICHAEL BAKER JR. DWG. CE-CD10-~I'OZ, SHT 1, REV. '0. 5. BASIS OF' LOCATION AND ELEVATION ARE TEMPORARY ALPINE MONUMENTS 3 4k 4 BY LOUNS'BURY ~k ASSOCIATES. 6. DATE OF SURVEY: WELL CONDUCTORS 10, 1.3, la, & 16-19 WERE AS-BUILT 3/10/g9, REF. FIELD BOOK L99-20, PAGES 3-11. ARCO Aiaaka, Inc. Subsicliory of Atlantic Richfield Company --CADD FILE NO, { ' I,RA~NG NO: LK663D1, , _ I SURVEYOR'S CF__RTIFICA TE , I HEREBY CERTIFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESE. N TS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERWSION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF ?????????? ----_. i i II ~ LOUNSBURY C/'J5 ~ & ASSOCIATES, INC. ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS '- CE-CD10-66_3D1 i SH,~:3, o~'~ , i Alpine' CD1-30 ~ PROPOSED DRILLING PROGRAM , . 3. 4. 5. 6. 7. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Procedure Move in drilling rig. Install diverter and function test. (16" conductor pre-installed) Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 1/2 hole to the intermediate casing point in the Alpine Reservoir. Note LWD will be run over this section. Run and cement 7 inch casing as per program. Displace cement with brine. Top of cement 500 feet above Alpine reservoir as per Rule 20 AC 25.030. Freeze protect casing annulus and casing. Suspend well and move__off rig:.. -- Move in drilling rig. Install and test BOPE to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test. Drill 6 1/8" horizontal section to well TD. Contingency - set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). - See Note 1. Displace well to weighted brine and pull out of hole. Run liner hanger (without liner) with flapper valve and 2 7/8" displacement string. Displace horizontal section to diesel. POH. Run 4 1/2, 12.6 #, L-80 tubing and sting into liner hanger. Freeze protect completion with diesel. Test tubing and tubing-casing annulus separately to 3500 psi. Nipple down BOP. Nipple up x-tree. Pressure test to 5000 psi. Set BPV and secure well. 21. Move rig off. Note I :The Alpine development wells will have open hole completions. Rock mechanic studies have indicated that there is sufficient rock strength to maintain wellbore stability throughout the life of the well. However this assumes that a. the 6-1/8" horizontal well stays within the sand section over it's full length and b. the well does not cross any weaker formations (e.g. faulted or fractured zones). In the event that the conditions described in either a. or b. are seen while drilling the horizontal section, it will be necessary to cover these sections. The proposed methods for doing this is utilize ECP liner assemblies. The attached drawing shows the various options for formation isolation that are proposed. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-24 will be the closest well to CD1-30 (58.5' at 478' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 55.7' at 500' MD. Note that CD1-24 has not been drilled at the time of this permit application. These figures are based upon direction planning files. Drillinq Area Risks: There are no high-risk events (e.g. overpressured zones) anticipated in well CD1-30. The surface hole is extremely soft and unconsolidated. CD2-35 encountered tight hole problems during a wiper trip at section TD (worst around the base of the West Sak). Drilling practices will be modified to ensure that hole cleaning is optimized. The proposed annular injection zone at 2450' TVD may be gas bearing. On the offset wells, mud weights in the range of 9.6 - 10 ppg have always been sufficient to provide only minor surface gas readings. The mud weight will be 9.6 ppg before drilling out of the shoe. Lost circulation: Mud losses within the Alpine reservoir have been recorded in some offset wells. Faulting within the reservoir is considered to be the most likely reason for these losses having been encountered. A small fault (10 ft of throw) is predicted around 1700' into the 6-1/8" horizontal section. It is not anticipated that this will cause lost circulation. However, it is recognized that other sub-seismic faulting may be present. An addition of loss circulation material to the drilling fluid has cured past losses. Good drilling practices will be stressed to ensure that mechanically induced losses are kept to a minimum. Additional 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. There is potential for differential sticking in the reservoir. The BHA design and 9.2 ppg mud weight have been developed to minimize this potential. However; vigilance through careful adherence to the directional plan will be required to ensure that wellbore geometry does not aggravate the potential for differential sticking. Annular Pum~in_~ Or~erations: Incidental fluids developed from drilling surface and intermediate hole on well CD1-30 will be either b~e hauled to the Class II injection facility q.n. 1R pad of the KRU or injected into the annulus of ~v-e'iis CD1-19 o,r aC~assuming annular injection is permitted by the AOGCC). This decision will be partially driven by the y of road links between Alpine and Kuparuk. 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. The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The CD1-30 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing. 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 CD1-30 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080 (including clean up from mud and brine mixing operations at the Alpine mud plant facility). We also request that cement rinseate be included in the list of permissible injection fluids. 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.c"1~g) * (0.052) * (Surf. Shoe TVD) + 1,500 pm---<. = (12.0 ppg) * (0.052) * (2407') + 1,500 psi - 3,002 psi Pore Pressure = 1,089 psi Therefore Differential - 3002 - 1089 - 1913 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 CD1-30 DRILLING FLUID PROGRAM SPUD to Intermediate hole to Production Hole 9-5/8"surface casing 7" casing point- 8 ~" Section- 6 1/8" point- 12 ¼" Density 9.5 - 9.8 ppg 9.5 - 10.0 ppg 9.2 ppg PV 10-25 12 -18 YP 20 - 60 15 - 25 35 - 45 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 18 - 22 10 minute gels <18 23 - 27 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min HPHT Fluid Loss at 160 8.5 - 9.0 9.0 - 10.0 <10 cc/30 min pH 9.0 - 9.5 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 permafrost and gravel, then reducing to 100-120 sec/qt by casing depth. Pump hi-vis sweeps if needed for supplemental hole cleaning. Maintain mud weight < 9.8 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 maintaining Iow end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 10 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids 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. Colville River Field CD1-30 Temporary Suspension Schematic Wellhead installed with tubing hanger and BPV set and pressure tested to 3500 psi Diesel Freeze Protection in casing and annulus to 1200' TVD, 16" Conductor to 121' 10.0 ppg drilling mud m annulus TOC a[ 7878' MD 6600'TVD 500 MD above top Alpine) 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2722' MD / 2407' TVD cemented to surface 9.2 ppg brine with diesel freeze 9rotection to 1200' TVD. U3dated 3/1 8/99 7" 26 3 BTC-Mod Productia 8911' MD / 6972' TVD i~ 93 eeg Colwlle River Field CD1-30 Production Well Completion Plan 16" Conductor to 121' 4-1/2" Camco TRM-4PE-CF (6,937" OD, 3,812" ID) SSSV and DB-6 Lock (3,812" ID) with single 1/4" x 0,049" s/s control line @ 1,000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2722' MD / 2407~ TVD cemented to surface CamcoKBG-2GLM 3.909" a[ 3400' TVD for E Dumm,~ with 1" BK-5 Top La[ca 4-1/2" 12,6 ppf L~80 IBT Moo. R2 tuning run with Jet Lube Ru@n'SeaJ Packer Fluid mix: 9,2 ppg KCI Brine with 1200' diesel cal; CamcoKBG-2GLM 3,909" a[ 5200' TVD for E DUm~T, with 1" BK-5 Too Latch 4.112" Tailpipe Assembly: (~)- Baker GBH-22 seal assembly f3.958" ID~ with 12' stroke, comoo nltr~le/wton seals TOC 500' MD above A mne @ +/- 7878' MD 6600'TVD Sera[60-65 aug CamcoKBG-2GLM 3,909"fD) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2900 DS BakerPackerse[ Packer Assembly Baker SLZXP Dbl Grip ZX Liner Packer t4.75" IDt with 12' Type 2 Extensmn on top (~)- 4-1/2 joint (1) blank pipe (3,958' ID) (~)- HES "XN" (3.725" ID) landing hippie (~)- 4-1/2 x 10 pup joint w/centralizer (~)- Baker Model 'C' KOIV flapper check (3.81" iD) (~)- 4-112" joint (1) blank pipe (3.958"1D1 (~)- 112 muleshoe .omi TD @ 11634' MD/6914' 7" 26 ppf L-80 BTC Moa =roduction Casing @ 8911' MD 6972' TVD. 93 dug updated 3/~ 8/99 le River Field CD1-30 Production Well Completion Plan (w/ Isolation Options) 16" Conductor to 121' 4-1/2" Camco TRM-4PE-CF (6.937" OD, 3.812" ID) SSSV and DB-6 Lock 3.812" ID! with stogie 1/4 x 0.049" s/s control @ - 000' MD 9-5/8" 36 pef J-55 BTC Surface Casing @ 2722' MD 2407'TVD 6emen[eo to surface Packer FIuio mix: 9.2 ppg KCI Brine with 1200' diesel cap Camco KBG-2 GLM '3.909" DI at 3400' TVD for E Dumm~ with 1" BK~5 Top Latch ,~-~/2" Tubing Tailpipe Assembly; - Baker GBH.22 seal assembJy (3,958" lB) with 12' stroke, combo nitrile/viton seals, 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seal 31pe dope Camco KBG-2GLM 3.909" au 5200' TVD E Dummy with '" BK-5 TOD Lalcr Hydraulics Set Liner Hanger Packer Assembly (~) ~ Baker SLZXP Packer (4 75" D w th 12' Type 2 Extension on top (~) - 4-1/2" joint ~1) blank tub ng (~) - HES "XN" 3.725" ID LE ~) - blank 4-1/~" liner (TBD) (~) - Baker Payzone ECP %- 4-1/2" oints (2! .b, lank tbg - Baker Model C KOIV O ' 4-1/2" joint (1 blank tbg ([~) - wireline entry guide with ECP cement inf,ated TOC +/- 500 MD above Alpine HES "X' f3,813" IDI Set at 60~65 deg Camco KBG-2 GLM f3.909" ID) & '" Camco DCK-2 Shear Valve Pinned for casing sine shear @ 2900 esl set 2 joints above the X landing nipple +/-150' above 7" shoo Open Hole Scab Liner ~)- Baker Payzone ECP -4-1/2" oints TBD blanktbg with centralizers as required (~ - Baker Model XL-IO ECP with ECP s cement inflated Oeen Hole Bridge Plug (~)- Baker Payzone ECP ~)- 4-1/2" joints (TBD) blank mg and centralizers as required (~) - 4-1/23 guide shoe with ECP s cement inflated 1/2 Muleshoe on end of tubing 7" 26 ppf L*80 BTC Mod Productior ~;asing 8911' MD 16972 TVD@ 93 deg IBT Mod, liner MD / 6914' TVD u md 3/18/99 CD1-30 --.- --,.~ 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 the Alpine CD1-30 well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 121 / 121 10.9 52 56 9 5/8 2722 / 2407 14.2 1089 1537 7" 8911 / 6972 16.0 3154 2457 N/A 11634 / 6914 16.0 3128 N/A · NOTE: Doyon 19 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- (0.1x 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 121 = 56 psi OR ASP = FPP - (0.1 x D) = 1089 - (0.1 x 2407') = 848 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 2407 = 1537 psi OR ASP = FPP - (0.1 x D) = 3154 - (0.1 x 6972') = 2457 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3154- (0.1 x 6972') = 2457 psi 5OO Alpine CD1.30 ANTICIPATED PORE PRESSURE; MUD WEIGHT, AND FRACTURE GRADIENT -500 -1500 -2500 -3500 -4500 -5500 -6500 -7500 Alpini~, CD1-30 Well Cementing Requirerr~'nts 9 5~8" Surface Casing run to 2722' MD / 2407' TVD, TAM port Collar @ +/- 1000' MD Cement from 2722' MD to 2222' MD (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2222' MD to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2222' - 899') X 0.3132 ft3/ft X 1.5 (50% excess) = 621.5 ft3 below permafrost 899' X 0.3132 ft3/ft X 4 (300% excess) = 1126.3 ft3 above permafrost Total volume -- 621.5 + 1126.3 = 1747.8 ft3 => 395 Sx @ 4.44 ft3/sk System: 395 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 Tail slurry: 500' X 0.3132 ft3/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 8911' MD / 6972' TVD Cement from 8911' MD to +/- 7878' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (8911'- 7878')o X 0.1268 ft3/ft X 1.4 (40% excess) = 183.4 ft3 annular volume 80' X 0.2148 ft"/ft = 17.2 ft3 shoe joint volume Total volume = 183.4 + 17.2 = 200.6 ft3 => 175 Sx @ 1.15 ft3/sk System: 175 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement c.,~ ~ M~,oe,~. FOR: ROBERTfgON ] Date plotted: 15-Mor-lg99 ] Plot Reference ARCO Alaska, onC. Struofure: CD#I Well : Field: AIimine Field Looaflon: Norfh Slope, A aska 400 400 800 1200 1600 2000 2400 2800 5200 .-- '~ 5600 (D 4000 I 44oo 4800 5200 5600 6000 6400 6800 7200 ~ RKB ELEVATION: 57' KOP 1.50 4.50 7.50 DLS: 5.00 deg per 100 ft 10.50 1,5.50 16.50 19.50 Permofrost 22.50 25.50 West Sak 28.50 ~1.50 54.50 EOC 327.45 AZIMUTH 4988' (TO TARGET) C-40 c~/s cos;.~ Pt C-20 TANGENT ANGLE 35.59 DEG K-5 K-2 TARGET ANGLE 93.3 DEG Albion 97 AIb/an 96 HRZ Begin Bu;Id/Turn to Torc 42.2~-1 LCU DLS: 9.00 deg per 100 ff. Deepest Point ~,~ 60.17~ EOC TARGET-7 Casing Pt-Begin Drop 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 400 0 400 800 1200 1600 2000 2400 2800 5200 5600 4000 4400 4800 5200 Verficol Section (feet) -> Azimuth 527.45 with reference 0.00 S, 0.00 E from slot #50 c~t.-. ~, ~h,,.~ FOR: ROBERTSON Dote plotted: 16-Uor-1999 Plot Reference is CD1-30 Vem~on ~3A. Coordinates ore Tn foot reference slot tl[30. True Vertical Depths ore reference Estimoted RKB. ARCO Alaska, I nc.1 Sfmofum: CD~I W,~ll: F'llid: Alpine Field Loc~llon : North Slope, ~mko/ / 5800 6000 6200 6400 0 6600 ~- 6800 I--- 7000 I 7200 7400 TARGET ANGLE 93.3 DEG 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 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 VerticalSection (feet)-> Azimuth .527.45 with reference 0.00 S, 0.00 E from slot #50 7200 6800 6400 6000 56OO 5200 4800 4400 4000 I ~ 5600 -I-- ~ 5200 0 2800 z 2400 2000 1600 1200 800 400 400 ARCO Alaska, Inc. Sfruofure ; CDi~I Well : 50 Field: Alpine Field Looafion: Norfh Slope, Alaska <- West (feet) 4400 4000 5600 5200 2800 2400 2000 t600 1200 800 400 0 400 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 TD - Casing Pt TD LOCATION: 908' FSL, 1552' FEL SEC. 30, T12N, R5E Begin Drop EOC TARGET-7 Cos[ng Pt-Begin Drop EOC zest Point A I TARGET LOCATION: 1 1495' FNL, 280' FEL Begin Build/Turn to Target SEC. 51, T12N. R5E HRZ Albion 96 Albion 97 XC-20 X~9 5/8 Casing Pt X_ West Sok '~ Permafrost ~)KOP ESTIMATED SURFACE LOCATION: 450' FNL, 2370' FWL SEC. 5, T11N, R5E i i i i i i i i i i i i i i i i i i i i [ i [ i i 4400 4000 5600 5200 2800 2400 2000 1600 1200 800 400 0 400 <- Wesf (feet) 7200 68OO 6400 60OO 5600 5200 4800 4400 4000 I 3600 Z 0 5200 :~- 2800 ~ --I- 2400 20aa 1600 1200 800 400 400 ~ ~"~. FOR: ROBERTSON Date plotted: 15-Mor-1999 I Plot Reference c~..~ ~ M~h~,~.. FOR: ROBE-RTE{ON Date plotted: 1B-Mar-1999 Plot Reference {s CD1-50 Vernon ~3A. Coordinates ore {n feet reference alot True Vertical Depth-. ere reference E~timeted RKEL ARCO Alaska, Inc. Stru~ure: CDt~1 Well : 50 Fqeld : Alpine Field Locotlon : North Slope, Alaska Po}nt KOP Permafrost West Sak 1072 EOC 14336 C-40 2463 C-50 2709 .9 5/8 Casing Pt 2722 C-20 5177 K-3 44337 K-2 4714 Albion 97 6878 Albion 96 7333 HRZ 7850 Begin Build/Turn to Target 8026 K- 1 8072 LCU 8207 Miluveoch A 8295 Alpine D 8,341 Alpine 8577 Deepest Point 8652 EOC 8668 TARGET - 7" Casing Pt- BOD 8911 EOC 8945 Begin Drop 10549 EOC 10589 TD - Casing Pt 11 655 MD 250.00 899.44 .16 .42 .78 .733 .03 .04 .53 .22 .57 .58 .07 O0 69 85 12 71 94 15 81 22 23 50 01 79 PROFILE COMMENT Inc Dir TVD 0.00 0.00 250.00 19.48 327.11 887.00 24.66 327.11 1047.00 35.59 327.11 1 361.57 35.59 327.11 2197.00 35.59 327.11 2397.00 35.59 327.11 2407.00 35.59 327.11 2777.00 35.59 327.11 3802.00 35.59 327.11 4027.00 35.59 327.11 5787.00 35.59 327.11 6157.00 35.59 327.11 6577.00 35.59 327.11 6720.06 39.77 327.80 6757.00 51.89 329.25 6851.00 59.73 329.95 6900.00 65.9t 330.28 6922.00 67.1 6 350.52 6937.00 90.00 331.99 6987.00 93.30 331.99 6985.95 93.30 331.99 6972.00 91.94 331.86 6970.45 91.94 ,351.86 6922.80 90.37 332.01 6922.00 90.337 332.01 6914.00 DATA North 0.00 91.85 146.32 299.62 801.74 921.94 927.95 11 50.33 1766.38 1901.62 2959.42 3181.80 3454.23 3520.21 3544.27 3626.87 3689.09 3724.70 3753.37 3970.45 4002.81 421 6.47 4246.44 5484.06 5518.92 6618.06 East 0.00 -59.58 -94.62 -195.75 -518.45 -596.16 -600.05 -745.84 - 1142.20 - 1229.65 -1915.66 -2057.46 -2220.69 -2276.29 -2291.63 -2342.05 -2378.52 -2398.98 -2415.26 -2534.19 -2551.39 -2665.04 -2681 .O2 -3342.85 -3361.44 -5945.65 V. Sect 0.00 109.,36 174.24 556.80 954.74 1097.88 1105.04 1569.85 2105.47 2264.51 5524.18 3788.99 4089.60 4191.99 4220.52 4517.27 4589.55 4430.37 4463.29 4710.27 4746.79 4988.04 5021.91 6421.21 646O.59 7701.41 Deg/lO0 0.~ 5. 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.0~ 9.00 9.00 9.00 9.00 9.00 0.00 4.00 0.00 4.00 0.00 ARCO Alaska, Inc. CD~i 30 slot #30 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-30 Version#3A Our ref : prop3016 License : Date printed : 16-Mar-99 Date created : 27-Jun-98 Last revised : 15-Mar-99 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 32.875,w150 55 36.767 Slot Grid coordinates are N 5975699.939, E 385794.940 Slot local coordinates are 429.19 S 2371.32 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path CD1-24 Version#4A,,24,CD~l CD1-19 Version #4A,,19,CD~l WD-2 Version #5,,WD2,CD~I PMSS <O-9714'>,,CD1-22,CD~l Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. lO-Mar-99 58.5 477.8 477.8 2-Mar-99 100.8 833.1 11633.8 2-Mar-99 1161.4 1680.0 1680.0 2-Mar-99 77.0 522.2 7120.0 ARCO Alaska, Inc. ALPINE DISBURSEMENT ACCOUNT P.O. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF:. The First National Bank of Chicag°-0710 Chicago,! il Ilinois Payable ThrOUgh:Republic Bank Shelbyville, Kentucky CHECK NUMBER 249O02990 73-426 839 MARCH 26, 1999 0990337 ALASKA DEPT OF REVENUE ,ALASKA OIL & GA:S~ CONSERVATION COMMI 3001 PORCUPINE DRIVE *** VOID.AFTER 90 DAYS *** . ' : EXACTLY **********.*~I00 Z~LLARs AND O0 cENTS ~**'********* 100.00 TRACE NUMBER: 249002990 I~' 2 [, clOD 2 q qO,' ':08 5 qo t, 8 ~= 81: O ~ ~0 ~ ~ 7~ll ARCO Alaska, Inc. Post Office Anchorage, Alaska 99510-0380 Telephone 907 276 12't5 March 29, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-30 Dear Sirs: ~. - ,. . ARCO Alaska, Inc. hereby applies for a Permit to-Drill'an on':~,hdi':b:Production well from the Alpine CD1 drilling pad. The intended spud date for this well is May 15, 1999. It is intended that Doyon Rig 19 be used to drill the well. The well will be drilled to horizontally penetrate the Alpine reservoir. It is intended that operations on this well be split into two distinct phases. The first visit by the drilling rig 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 March / April 2000, the rig will return and the horizontal reservoir leg will be drilled prior to completion. Upon completion, the well will be closed in awaiting field start up. 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 property and location of the proposed CD1-30 well. 4. A proposed drilling program, including a request for approval of annular pumping operations. 5. A drilling fluids program summary. 6. Proposed suspension diagram. 7. Proposed completion diagram. 8. Proposed completion diagram with open hole isolation options. 9. Pressure information as required by 20 ACC 25.035 (d)(2).. 10. Proposed cementing program and calculations. 11. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Diagrams of the BOP equipment and diverter equipment as required by 20 ACC 25.035 (a) and (b) were provided with the drilling permit submission for well CD1-19, dated March 09, 1999. t. ~=) -o Z. ~ The description of the drilling fluids handling system was provided with the permit submission for well CD1-24, dated March 18, 1999. No over-pressured strata are predicted for well CD1-30. Prediction of over-pressured strata as required by 20 ACC 25.033 (e), was fully covered under the drilling permit submission for well CD1-22, dated December 19, 1997. Seismic refraction and reflection analysis, as required by 20 ACC 25.061 (a), was submitted under the drilling permit submission for well CD1-22. Please note, ARCO does not anticipate the presence of H2S in the formations to be ,'~1~(;(', /,l,m~,,~ h~, ~: ,~ {h',~'~h~~, ~,~ .. encountered in this well?'~Owever, there will be U2S monitoring e'q~iipment operating on well CD1-30. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian~0bertson Senior Drilling Engineer Attachments CC: CD1-30 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Lanston Chin ATO 1 O54 ANO 382 ANO 384 Kuukpik Corporation ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage? Alaska 99510-,0360 Telephone 907 276 1215 March 29, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-30 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is May 15, 1999. It is intended that Doyon Rig 19 be used to drill the well. The well will be drilled to horizontally penetrate the Alpine reservoir. It is intended that operations on this well be split into two distinct phases. The first visit by the drilling rig 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 March / April 2000, the rig will return and the horizontal reservoir leg will be drilled prior to completion. Upon completion, the well will be closed in awaiting field start up. 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 property and location of the proposed CD1-30 well. 4. A proposed drilling program, including a request for approval of annular pumping operations. 5. A drilling fluids program summary. 6. Proposed suspension diagram. 7. Proposed completion diagram. 8. Proposed completion diagram with open hole isolation options. 9. Pressure information as required by 20 ACC 25.035 (d)(2). ~ · 10. Proposed cementing program and calculations. 11. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Diagrams of the BOP equipment and diverter equipment as required by 20 ACC 25.035 (a) and (b) were provided with the drilling permit submission for well CD1-19, dated March 09, 1999. The description of the drilling fluids handling system was provided with the permit submission for well CD1-24, dated March 18, 1999. No over-pressured strata are predicted for well CD1-30. Prediction of over-pressured strata as required by 20 ACC 25.033 (e), was fully covered under the drilling permit submission for well CD1-22, dated December 19, 1997. Seismic refraction and reflection analysis, as required by 20 ACC 25.061 (a), was submitted under the drilling permit submission for well CD1-22. Please note, ARCO does not anticipate the presence of H2S in the formations to be ARCO Alaska! hlc. I.'- ri SLit;&;CIISry O~ At!anl~c[-~!cnhe!dOomoam encountered in this well. However, there will be H2S monitoring equipment operating on well CD1-30. If you have any questions or. require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian~~~n~ Senior Drilling Engineer Attachments CC: CD1-30 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Lanston Chin ATe 1 O54 ANO 382 ANO 384 Kuukpik Corporation Annular disposal of drilling wastes will not bc approvcd for this well until sufficient data is submitted to ensure that the rcquiremcnts of 20 AAC 25.080 are mct. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing 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 any disposal of fluids gcneratcd from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD I must comply with thc rcquircmcnts and limitations of 20 AAC 25.080. Approval of this permit to drill docs not authorize disposal of drilling waste in a volume grcater than 35,000 barrels through thc annular space of a single well or to usc that well for disposal purposes for a period longer than onc year. · WELL PERMIT CHECKLIST COMPANY //-~ WELL NAME C~4~/' CD/-._~O PROGRAM: exp ~ dev ~' redrll ~ serv ~ wellbore seg ann. disposal para req ~ FIELD & POOL ADMINISTRATION INITCLASS z"~,~,-/ /-4:¥~ GEOLAREA ~>.~o UNIT# ,~'o2~_d5 ON/OFFSHORE 1. Permit fee attached ....................... N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from ddlling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ IYIN If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ ~Y[ N Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... . 3. 4. 5. 6. 7. 8. 9. 10. 11. Ai~;~R DATE 12. APPR DATE 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. Ddlling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~OO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. 29. ~EOL..OG.~Y 30. 31. 32. APPR . DATE/ 33. '~"~ ~/~7~ 34. APPR DATE GEOLQGY: Work will occur without operation shutdown ........... Y ~,~' Is presence of H2S gas probable. Y Permit can be issued w/o hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratoryo~ly] Y N With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... N (B) will not contaminate freshwater; or cause drilling waste . . . (C) will not impair mechanical integrity of the well used for disposal;(~ N or- T~ L5 ~z.z_. (D) will not damage producing formation or impair recovery from a N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. 0'_)N ENGINEERING: UlCtAnr:~?a~ COMMISSION: ..~ Comments/Instructions: co · c:\msoffice\wordian\diana\checklist