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Home My WebLink About197-008Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available 'in the original file and viewable by direct inspection. i qff'- 0c:)~ File Number of Well History File PAGES TO DELETE Complete RESCAN El Color items- Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other - Pages: DIGITAL DATA Diskettes, No. n Other, No/Type -OVERSIZED Logs of various kinds Other COMMENTS: Scanned b~~-D;r~ Nathan Lowell TO RE-SCAN Notes: oN OR B FORE Memorandum State of Alaska Oil and Gas Conservation Commissioa Re: Cancelled or Expired Permit Action EXAMPLE- Point Mclntyre P2-36AXX AP1 # 029-22801-95 This mem, will remain at the fr,nt of the subject well fie. 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 i' the treatment of these kinds of applications for permit to ddii. 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 remair unchanged. The AP! number and in some instances the well name reflect the number of preexistin,( reddils and or muitilaterais 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 ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9[ The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbenng methods, descnbed in AOGCC staff memorandum "Multi-lateral (weiibore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 6, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Cancellation of Approved Permit to Drill for 2V-17 Cache Well Dear Mr. Commissioner: This is to inform you of our intentions to cancel the approved Permit to Drill for the 2V-17 Cache well in the Kuparuk River Unit. The permit number is 97-08, AP1 #50-029-22736. We do not have intentions of drilling this well at this time. Sincerely, ,' Drilling Superintendent Kuparuk Development MZ/skad TONY KNOWLES, GOVERNOR DEPARTMENT OF NATURAl. RF.~OURC'F~ DIVISION OF OIL AND GAS 3601 "C" STREET, SUITE 1380 ANCHORAGE, ALASKA 99503-5948 PHONE: (907) 269-8784 MarCh 10, 1997 Al*CO .. Alaska, Lac. Via Fax .3~_.O..,~.6)... a~d Mail P.O. Box 100360 Anchorage, Alaska 99510-0360 ........ ~:-L:.:i:;._)~' "'.~.". ....... ]j'3~._ Attention: James R. Wineg~er Senior Landman .............. 5" ..... ' Subject: Kup~k River Unit ~~ 7'~'~'~'~::{~' Tract Operation on ~U Tract 42 ADL 25645 ~ ~ i~ (~ts;: ~C~he Prps~ect ~ell ~ ~ ~ Wondze~i~ ................ De= Mr. Winegamer: ~ V~ 1 7~~O~ By letter, dated Febm~ 5, 1997, ~CO Alaska, Nc. (ARCO) applied to initiate Tract Operations on ADL 25645 and to co~ngle production from the Cache Prospect tract well with production from Kup~k P~icipating ~ea (~A) wells of the Kup~k River Unit (~U). I approve the drilling plan submitted by ARCO in accordance Article 5.4 of the KRU Agreement. The lessees may commingle production from the Cache wellbore with KPA production for a period of 30 days. A brief written status report of the tract operation must be provided to the Division by the 15th day of the testing period. A final status report will be due upon conclusion of drilling operations or within 5 days of completion of the 30 day test period. All production from the Cache Well shall be allocated to the lease, ADL 25645. The requested participating percentages of ARCO 58.4649% and BPX 41.5351% are approved for the 30 day test period. ARCO and BPX shall each submit royalty reports for their share of production from the lease. They should separately account for oil, gas, and NGL production from the well. ARCO, as operator of the tract operation, shall submit a monthly production allocation report that accounts for all substances produced and allocated to the Cache Well. . . James R. Winegamer March 10, 1997 Page 2 If ARCO intends to continue production after the 30 day test period, it shall apply to either expand the KPA or form a new participating area. This application must be filed before any production commences after the 30 day test period. Sincerely, Kenneth A. Boyd~ Director cc: David Johnston - AOGCC John E. Pilkinton - ADOR KRU.CacheOps.txt ALASKA OIL AND GAS CONSERVATION COMMISSION i / ! February 13, 1997 Michael Zanghi, Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Rez Kuparuk River Unit 2V-17 Cache ARCO Alaska, Inc. Permit No: 97-08 Sur. Loc. 112'FWL, 1773'FSL, Sec. 8, T11N, R9E, UM Btmhole Loc. 1570'FWL, 2940'FSL, Sec. 9, T1 IN, R9E, UM TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dear Mr. Zanghi: 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records, FIT data, and any COLs are to be submitted to the Commission prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice .may be given by contacting the Commission petroleum field inspector on the North Slope David,,W. J6hnston / ~ Chai~_) ' BY ORDER OF E COMMISSION dlf/Enclosures Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end. - STATE OF ALA,~KA ALA~_ ~ OIL AND GAS CONSERVATION COMMISS. P£F{MIT TO DF{ILL ~' 20 AAC 25,005 la. Type of Work Drill X Redrill [~] lb Type of Well Exploratory X Stratigrapl~ic Test [] Developmen~Oil Re-Entry [~] Deepen [~ Service r~ Development Gas ~] Single Zone Multiple Zone X 2'. Name of Operator 5. Datum Elevation (DF or KB) 10. Field ancl Pool ' ARCO Alaska, Inc. RKB 42', Pad 80' feet Sag River Expl. 3. Address 6. ProPerty Designation Ivishak Expl. P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25645, ALK 2576 Lisburne ExpI. 4. Location of well at surface 7. Unit or proPerty Name 1 1. Type Bond (see 20 AAC 25.025} 112' FWL, 1773' FSL, Sec. 8, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive inter,~al (@ TARGET ) 8. Well number Number 1373' FWL, 2906' FSL, Sec. 9, T11N, R9E, UM 2V-17 #U-630610 Cache At total depth 9. Approximate spud date Amount 1570' FWL, 2940' FSL, Sec. 9, T11N, RgE, UM 2/01/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Propose¢l dep~ (MD and TVD) proPerty line KRU 2-08A MD 12,259' 1373' ~ TD feet 29' ~ 740' MD feet 2560 TVD 9,522' feet 16. To be completed for deviated wells 17, Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 49° Max~um,urfac~ 331 0 psig At total depth ('r'vo) 4308 psig 18. Casing program Serdng I~epth ' size Specifications Top Bottom Quantit~ of cern. ant Hole Casing Weight ,Grade Coupling Length bi3 TVD , MO 'I~/D (include stage data) 24" 20" # H-40 Weld 80' 42' 42' 122' 122' 248 sx Arcticset I 16" 13.38 68# L-80 BTC 3418' 42' 42' 3540' 3142' Stcj 1:131sx/Stcj 2: 553sx 12.25" 9.625 53.5# L-80 BTC 8128' 42' 42' 8250' 6247' 354 sx ClassG 8.5" 7" 26# L-80 BTC-M 2350' 8050' 6115' 10400' 7822' 376 sx Glass G/Latex 6.125" 5" 18# L-80 LTC 1860' 10200 7641' 12260' 9522' 177 sx Class G/Latex ,, 1 9. 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 dep~ Structural Conductor Surface Intermediate LinerPr°ductl°n JAN 1 61997 Perforation depth: truemeasuredvert~ca~ ,AJaska 0il & Gas Cons. Commission ~ncnor~q,g 20. Attachments FIIlng fee X ProPerty plat [] BOPSketcn X Diverter Sketch X Drilling program X Drilling fluid program X; Time vs depth plot [~] Refraction analysis r-! Seabed report [~] 20 AAC 25.050 requirements X 21. I hereby certify thtat the foregoi~ng is true and correct to the best of my knowledge Signe~ --" · Title Drill Site Develop. Supv. Date Commission Use Only Conditions of approval Samples required J~ Yes ['"J No Mud Icg required ,]~ Yes ~ NO Hydrogen sulfidemeasures ~ Yes [~ No Directional survey required ~ Yes r-~ No Other: Approved byDavid~. ,~0hriSt0~ by order of Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 13,1997 Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Re- Application for Permit to Drill ARCO 2V-17, Cache Dear Sirs: JAN 4 1997 0il & Gas Cons. Comr~js$ior~ Anchorage ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory tail below KRU 2V- 17. The well is designed to penetrate the Kuparuk, Ivishak and Lisburne formations. Upon completion of either drilling or testing the exploratory tail, the well will be reverted back to a Kuparuk producer. Attached find the information required by 20 ACC 25.005 (c) for your review. Other pertinent information attached to this application is confidential data including the following: 1) Pressure information as required by 20 ACC 25.035 (d) (2). 2) Prediction of overpressured strata as required by 20 ACC 25.033 (e). 3) Annulus pumping request as required by 20 ACC 25.005 (c) (10). There are no shallow hazards expected at 2V-17, such as shallow gas. There have been 16 wells drilled on KRU 2V pad and shallow gas has not been encountered. Therefore, ARCO requests a waiver from 20 ACC 25.005 (c) (8). Please note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment operating as is the usual case while drilling wells in the Kuparuk field. If you have any questions or require any further information, please contact me at 265-6434 or Mike Zanghi (ARCO Kuparuk Drill Site Development Supervisor) at 265-6206. Silpcerely,.__~... James Trantham Project Manager (SDE) Attachments cc: 2V-17 Cache Well File Steve Porter ATO-1396 John Braden ATO-1460 ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company · , , , o o . . · 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 2V-17, Cache Move in and rig up PDC Rig #245 over pre-installed 20" conductor. Install diverter system. Drill 16" hole to 13-3/8" surface casing point (3,540' MD)according to directional plan. Run and cement 13-3/8" casing. Install and test BOPE to 3000 psi. Test casing to 2700 psi. Drill out cement and 10' of new hole. Perform leak off test(16 ppg EMW max). Drill 12-1/4" hole to the base of the Kuparuk formation @ 7,570' MD according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 9-5/8" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 9-5/8" casing to 3500 psi. Drill out cement and 10' of new hole. Perform leak off test(16 ppg EMW max). Drill 8-1/2" hole to the top of the Ivishak formation @ 10,400' MD according to directional plan.. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" liner. Pressure test 9-5/8" casing and 7" liner to 3500 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 6-1/8" hole through the Sag River and Ivishak formation, then through the the Lisburne formation (top @ 11,760') to TD @ approximately 12,260'. Run open hole evaluation logs or LWD tools as needed. If the well is to be tested, run 5", 18#, L-80, BTC liner. (If the well will not be tested, prepare the well for Kuparuk production by completing the well (Steps 22- 26) with P DC #245). Run 3-1/2", 12.9# tubing for a test string. Sting into the top of the 5" liner. ND BOPE. NU upper tree. Shut in and secure well. RDMO PDC #245. 19. 20. 21. 22. 23. 24. 25. 26. Hook up well for flow testing through Drill Site 2V facilities. Test zones as appropriate, abandoning each using a CTU. When complete, plug and abandon the well below the Kuparuk Fm as per AOGCC regulations and RDMO CTU. MIRU Nordic Rig #2. ND tree, NU BOPE and kill well. Pull test string and ensure lower section is abandoned appropriately. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE. NU tubinghead and either full opening valve (if injector and logging planned) or master valve and upper tree assembly (if producer and no logging planned). Note: If the well will be a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 2V-17 Cache Spud to 13-3/8" 9-5/8" Intermediate 7" Intermediate 5" Production surface casinQ casinQ liner liner Density 9.0-10.0 9.5-10.5 10.0-11.0 10.5-11.5 PV 20-26 16-20 15-20 15-20 YP 15-25 15-20 8-12 8-12 Viscosity 50-70 30-40 35-50 35- 50 Initial Gel 5-15 4-6 2-4 2-4 10-Min. Gel 15-40 6-8 4-8 4-8 APl Filtrate 10-12 8-10 4-8 4-8 pH 9.5-10 9.5-10 9.5-10 9.5-10 % Solids --.10% 4-7% <12% <12% Drilling Fluid System: 3 ea 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 audio alarms) Trip Tank Fluid Flow Sensor 8 ea Brandt pit mixers Drilling Area Risks' Identified risks in the 2V-17 drilling area include possible sub-normal pressure in the Kuparuk River Formation (resulting from production drawdown) and lost circulation in the Lisburne formation. To reduce or control these risks and allow for evaluation of the exploration tail, the following is planned: The Kuparuk River formation will be cased off with 9-5/8" casing to allow drilling deeper, normally-pressured intervals without experiencing fluid losses to the Kuparuk. The Sag River formation will be topset with 7" casing and PDC #245 will drill out a 6-1/8" hole to expose the Sag River, Ivishak and Lisburne formations for testing. The exploration tail will be cased with a 5" liner if testing the well is warranted. The 9-5/8" and 7" casing shoes will be tested to leak-off or to a maximum of 16 ppg EMW upon drilling 10 foot of new formation. jAN ! 4 1997 .A. iask~ Oil & G~s Cons, Commission Anchorage KRU 2V-17 (Cache) PRESSURE INFORMATION AND (;;A$1NG DE$1(,~N (per 20 AAC 25.005 (c) (3,4) and as required in 20 AAC 25.035 (d)(2)) DISCUSSION The following presents the data used for calculation of the allowable surface pressures (ASP) used for the design and drilling of the 2V-17 Cache well. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressu re Drilling !inches) (ft, TVD) (ppg) (ppg) (psi) (psi) 20 115 N/A N/A N/A N/A 13-3/8 3142 10.5 9.0 1470 1125 9-5/8 6052 14.0 9.8 3084 2418 7 7822 15.6 9.8 3986 3126 5 9522 16.2 8.8 4357 3310 * Note: 5000 psi BOP equipment is adequate. Expected Maximum Mud Weights: 16" Surface Hole to 3541/3142': 12-1/4" Intermediate Hole to 8250/6247': 8-1/2" Intermediate Hole to 10403/7822': 6-1/8" Production Hole to 12259/9522': 9.7 ppg 10.5 ppg 11.0 ppg 11.0 ppg Procedure for calculatina ASP: -- ASP calculations are based on anticipated pore pressures in each hole interval and are presented using the following equation: ASP = ((PP x 0.052)- 0.11)D where: ASP = Anticipated Surface Pressure in psi PP = Pore Pressure in ppg (use above mud weights) 0.052 = Conversion Factor from ppg to psi/ft D = True Vertical Depth of Casing Shoe Calculations; 1) Drilling below 20" Conductor: ASP = ( (PP x 0.052)- 0.11) D = ( (9.0 x 0.052) - 0.11) 3142 -- 1125 psi 2) Drilling below 13-3/8" Surface Casing: ASP =((PPx0.052)-0.11) D = ( (9.8x 0.052) -0.11) 6052 = 2418 psi 3) 2) Drilling below 9-5/8" Intermediate Casing: ASP = ( (PP x 0.052)- 0.11) D =( (9.8 x 0.052) - 0.11) 7822 = 3126 psi Drilling below 7" Intermediate Casing: ASP =((PPx0.052)-0.11) D = ( (8.8x 0.052) - 0.11) 9522 = 3310 psi KRU 2V-17 Exploration Tail (Cache) PRESSURE ANALYSIS AND PREDI(;:;TION (per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) DISCUSSION: An analysis and prediction of overpressured strata was performed for the 2V-17 Cache well as required by AOGCC regulations. ARCO does not expect to encounter abnormal pressure from any zones. The prediction is based on an evaluation of offset wells KRU 1E-06, W. Sak #1, Colville #1, East Ugnu and Kalubik Creek #1). Attached are the following: Mud weight versus depth graph for these wells. Sonic log interval transit time analysis for KRU 1E-06. Pore pressure, frac pressure & anticipated mud weight graph. There are no shallow hazards (such as shallow gas) expected at 2V-17. There have been 16 wells drilled from KRU 2V pad and shallow gas has not been encountered. Therefore, ARCO requests a waiver from 20 ACC 25.005 (c) (8). 2V Cache Exploration Tail OFFSET MUD WEIGHT DATA 2OOO 4000 6OO0 80OO 100o0 I 12000 8 10 1 WEIGHT (ppg) West Sak #1 ~.~- East Ugnu ---i-- Kalubik Creek --,-- KRU 1E-06 13 Cache 2V Exploration Tail -1000 1000 3000 5OO0 7000 900O 11000 13000 . 10 1 o0 1000 SHALE - ITT (ms/fO data from KRU 1 E-06 2000I 4000- -:- -i-- 6000 8000 ~- .... 10000 12000 -i 6 7 8 --~-- FP I--FP --X-- MC/ 9 101112131415161718 EMW (ppg) tI a nmrw_ t5718 _ d 1009_p I o t 09125728 I a nmr w - .................... C~ii-O-~-~-----~'-~J-g-~- ........... i-"~'""i'""5~"-I I 1 iJ I'- x c ANNULAR PUMPING OPERATIONS WELL KRU 2V-17 Incidental fluids developed from drilling operations will be pumped down the surface/production casing annulus of an existing well or the nearest dedicated disposal well (2M-23). fNote that cement rinseate will not be injected down the dedicated disposal well but will be'recycled or held for an ooen annulus.~ The open annulus will be left with a non- freezing fluid during any extended shut down (>4 hr) in pumping operations. The 2V-17 surface/intermediate casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost and with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 2V-17 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set +200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the injection pump's pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg)* (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3458 psi The surface and intermediate casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)!Grade Range Type (psi) Collapse (psi) Burst 13.375 68 L-80 3 BTC 2270 1930 5020 42{i7 9.625 53.5 L-80 3 BTC 6620 5627 7930 6741 Fluids to be disposed of in the subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). · . .-. ~;, '~,, jAN ! 4 1997 Created by jones For: D~te plaited : 26-Dec-g6 Plot Reference is 17 (Cache) Verison Coordinates ore in feet reference elot I~Coche. ~True VeHicel Dep[hs ore reference RKB not set. ARCO ALASKA, Inc. Structure: Pad 2V Well: Cache Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 5OO 500 1000 1500 2000 2500 3000 3500 4000 4500 5ooo 5500 6000 6500 7O0O 7500 8000 8500 9000 9500 10000 500 0 500 1000 1500 2000 2500 3000 5500 4000 4500 5000 5500 6000 6500 7000 I I I I I I I I t I [ t [ II II II II II II I I I I I i L 1 500 ~'~ ~ o 5oo ~.oo _.._.----~--~ oo ~.oo ~ % o 15.00 DLS: ~.00 deg per 100 ft 21.00 27.~ 500 ~°oorO~ ~t so~ so~ '45.00 EOC Bose We~t Sok Sond~ 13 3/8 Cosing ~ 95/8 Coslng ~~k oche Sog Rv Rvsd 26-Dec-96 Coche Isbrne 26-0ec-96 TO-S L~..~~ ' 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 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 Verficol Section (feel) -> Azimuth 80.17 with reference 0.00 N, 0.00 E from slot #Coche ARC0 ALASKA, Inc. Structure: Pad 2V Well : Cache Field : Kuparuk River Unit Location : North Slope, Alaska WELL PROFILE Poir~ MD Inc Dir -~0 Tie on 0.00 0.00 80.17 0.00 KOP 1300.00 0.00 80.17 1 End of Guild 2924.82 48.74 80.17 27,35.79 End of Held g237.0~ 48.74 60.17 6698.15 Target Cache Sag Rv Rv 104g`3.22 2,3.62 80.17 7904-.00 Target 11759.29 2`3.62 ~3.17 906~,.00 T.D. & End of Hold12259.17 25.62 80.17 9,522.00 2400 2500 3~ DATA North East V. Sect Beg/lO0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 111.04 640.92 650.46 3.00 921.08 5`316.625395.81 0.00 1046.67 6041.51 6131.51 2.00 11`33.266541.,346658.78 0.00 1167.45 67,38.696839.07 0.00 Created by jones Date plotted : 26-Dec-96 Rot Reference ia 17 (Cache) Verison Coordinot. es are in feet reference slot ~C~che. True Ve~col Dept~e~ce RKB not eot. TRUE NORTH 2300 5 5 0 0 1 0 340 500 20 ~oo 330 ~oo 30 40' 5O 6O 290 70 280 80 270 -F 9O 260 100 250 110 240 120 230 150 1700 220 1 4O 210 11oo 150 200 160 190 180 ~8oo Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ARCO ALASKA, Inc. Pad 2V,Cache Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 17 (Cache) Verison #~ Last revised : 26-Dec-96 Dogleg Vert Oeg/lOOft Sect 0.00 0.00 80.17 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 80.17 500.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 80.17 1000.00 0.00 N 0.00 E 0.00 0.00 1300.00 0.00 80.17 1300.00 0.00 N 0.00 E 0.00 0,00 1400.00 3.00 80.17 1399.95 0.45 N 2.58 E 3.00 2.62 1500.00 6.00 80.17 1499.63 1.79 N 10.31 E 3.00 10.46 1600.00 9.00 80.17 1598.77 4.01 N 23.17 E 3.00 23.51 1700.00 12.00 80.17 1697.08 7.12 N 41.12 E 3.00 41.74 1800.00 15.00 80.17 1794.31 11.11 N 64.12 E 3.00 65.08 1900.00 18.00 80.17 1890.18 15.96 N 92.10 E 3.00 93.48 2000.00 21.00 80.17 1984.43 21.65 N 124.99 E 3.00 126.85 2100.00 24.00 80.17 2076.81 28.19 N 162.69 E 3.00 165.12 2200.00 27.00 80.17 2167.06 35.53 N 205.11 E 3.00 208.16 2300.00 30.00 80.17 2254.93 43.68 N 252.12 E 3.00 255.87 2400.00 33.00 80.17 2340.18 52.60 N 303.59 E 3.00 308.12 2500.00 36.00 80.17 2422.59 62.26 N 359.40 E 3.00 364.75 2501.75 36.05 80.17 2424.00 62.44 N 360.41 E 3.00 365.78 2600.00 39.00 80.17 2501.91 72.65 N 419.37 E 3.00 425.62 2700.00 42.00 80.17 2577.95 83.74 N 483.36 E 3.00 490.56 2800.00 45.00 80.17 2650.47 95.49 N 551.17 E 3.00 559.38 KOP Top West Sak Sands 2900.00 48.00 80.17 2719.30 107.87 N 622.64 E 3.00 631.91 2924.82 48.74 80.17 27'55.79 111.04 N 640.92 E 3.00 650.46 EOC 3000.00 48.74 80.17 2785.36 120.68 N 696.61E 0.00 706.98 3237.54 48.74 80.17 2942.00 151.17 N 872.56 E 0.00 885.56 Base West Sak Sands 3500.00 48.74 80.17 3115.07 184.85 N 1066.98 E 0.00 1082.87 3540.83 48.74 80.17 3142.00 190.09 N 1097.23 E 0.00 1113.57 13 3/8" Casing Pt 3809.25 48.74 80.17 3319.00 224.54 N 1296.06 E 0.00 1315.36 Top Tabasco 4000.00 48.74 80.17 3444.78 249.01N 1437.35 E 0.00 1458.76 4500.00 48.74 80.17 3774.49 313.18 N 1807.72 E 0.00 1834.65 5000.00 48.74 80.17 4104.20 377.35 N 2178.09 E 0.00 2210.54 5500.00 48.74 80.17 4433.91 441.51 N 2548.46 E 0.00 2586.43 6000.00 48.74 80.17 4763.62 505.68 N 2918.84 E 0.00 2962.32 6500.00 48.74 80.17 5093.33 569.84 N 3289.21 E 0.00 3338.20 7000.00 48.74 80.17 5423.03 634.01 N 3659.58 E 0.00 3714.09 7453.38 48.74 80.17 5722.00 692.19 N 3995.41 E 0.00 4054.93 7500.00 48.74 80.17 5752.74 698.17 N 4029.95 E 0.00 4089.98 7559.53 48.74 80.17 5792.00 705.81 N 4074.05 E 0.00 4134.74 8000.00 48.74 80.17 6082.45 762.34 N 4400.32 E 0.00 4465.87 8500.00 48.74 80.17 6412.16 826.50 N 4770.69 E 0.00 4841.76 9000.00 48.74 80.17 6741.87 890.67 N 5141.06 E 0.00 5217.65 9237.00 48.74 80.17 6898.15 921.08 N 5316.62 E 0.00 5395.81 9274.22 48.00 80.17 6922.8~ 925.83 N 5344.03 E 2.00 5423.64 9374.22 46.00 80.17 6991.08 938.32 N 5416.09 E 2.00 5496.77 9474.22 44.00 80.17 7061.78 950.38 N 5485.76 E 2.00 5567.48 9574.22 42.00 80.17 7134.91 962.03 N 5552.96 E 2.00 5635.68 9674.22 40.00 80.17 7210.38 973.22 N 5617.60 E 2.00 5701.28 9774.22 38.00 80.17 7288.09 983.97 N 5679.60 E 2.00 5764.21 9874.22 36.00 80.17 7367.95 994.24 N 5738.90 E 2.00 5824.39 9974.22 34.00 80.17 7449.86 1004.03 N 5795.41 E 2.00 5881.74 10074.22 32.00 80.17 7533.72 1013.33 N 5849.07 E 2.00 5936.20 9 5/8" Casing Pt Top Kuparuk Begin Angle Drop Att data is in feet unless otherwise stated. Coordinates from slot ~K:ache and TVD from RKB not set (122.00 Ft above mean sea level). Bottom hole distance is 6839.07 on azimuth 80.17 degrees from wet[head. Total Dogleg for we[tpath is 73.87 degrees. Vertical section is from wet[head on azimuth 80.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO ALASKA, Inc. Pad 2V,Cache Kuparuk River Unit,North SLope, Ataska Measured Inc[in. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 17 (Cache) Vet]son #4 Last revised : 26-Dec-96 Dogleg Vert Deg/lOOft Sect 10174.22 30.00 80.17 7619.44 1022.12 N 5899.82 E 2.00 5987.70 10274.22 28.00 80.17 7706.89 1030.39 N 5947.58 E 2.00 6036.18 10374.22 26.00 80.17 7795.99 1038.14 N 5992.32 E 2.00 6081.58 10403.09 25.42 80.17 7822.00 1040.28 N 6004.66 E 2.00 6094.10 7" Liner 10474.22 24.00 80.17 7886.62 1045.36 N 6033.95 E 2.00 6123.84 10493.22 23.62 80.17 7904.00 1046.67 N 6041.51E 2.00 6131.51 Cache Sag Rv Rvsd 26-Dec-96 10500.00 23.62 80.17 7910.21 1047.13 N 6044.19 E 0.00 6134.22 11000.00 23.62 80.17 8368.32 1081.33 N 6241.58 E 0.00 6334.56 11500.00 23.62 80.17 8826.43 1115.53 N 6438.98 E 0.00 6534.89 11759.29 23.62 80.17 9064.00 1133.26 N 6541.34 E 0.00 6638.78 TARGET #2 - T/ Lisburne 12000.00 23.62 80.17 9284.54 1149.72 N 6636.37 E 0.00 6735.23 12259.17 23.62 80.17 9522.00 1167.45 N 6738.69 E 0.00 68~9.07 TD - 5" Liner All data is in feet unless otherwise stated. Coordinates from slot #Cache and TVO from RKB not set (122.00 Ft above mean sea [eve[). Bottom hote distance is 6~9.07 on azimuth 80.17 degrees from wellhead. Tota[ Oog[eg for wel[path is 75.87 degrees. Vertical section is from wellhead on azimuth 80.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ WELLBORE SCHEMATIC AND CEMENT PLAN 2V-17 Cache 20" Conductor @ 120' RKB 16" Hole 13-3/8" Surface Casing @ 3,540' MD-RKB 12-1/4" Hole Stage Collar ,465' MD Top W. Sak @ 2,910' MD TOC @ 7,500' MD TOC & TOL @ 8,050' MD 9-5/8" Intermediate Casing @ 8,250' M D-RKB 8-1/2" Hole TOC & TOL @ 10,200' MD 7" Protective Liner @ 10,400' MD-RKB 6-1/8" Hole 5" Testing Liner @ 12,260' MD-RKB Casing Size / Hole Size: 20"/24" Depth: 120' MD-RKB Top of Cement: Surface Excess Calculated: 100% Volume Calc: (120')(0.96 cu-ft/ft)(2) = (230 cu-tt)/(0.93 cu-ft/sk) = 248 sacks ARCTICSET I Slurry Volume 230 cult ARCTICSET Slurry Weight 15.7 ppg Slurry Yield 0.93 cu-ftJsk Casing Size/Hole Size: 13 3/8"/16" Depth: Top of Cement: Surface Stage Collar: 1,465' MD Excess Calculated: 45% Stg. 1 Lead; 35% Stg. 1 Tail; 400% Stg. 2 BHT (Static): 70°F BHT (Circ): 70°F Stage I Volume Calc: Lead (2,410.-1,465')(0.4206 cu-ft/ft)(1.45) = (576 cu-ft)/(4.41 cu-ft/sk)= 131 sacks Stage I Volume Calc: Tail (3,540.-2,410')(0.4206 cu-ft/ft)(1.35) = (642 cu-ft)/(1.16 cu-ft/sk)= 553 sacks (+ 58 sxs for shoe jt.) Lead: 131 sacks ClAss G + 3.5% D44.(NaCl) + 30% D53(Gyp) + 50% D124(spheres) + 1.5% S 1 (CaCl2) + 1.5% D79(extender) + 0.2% D46(defoam) + 1/4 #/sk D29 (celloflake) Slurry Volume 576 cu-ft Slurry Weight 10.5 ppg Slurry Yield 4.41 cu-ft/sk Thickening time 6.0+ hours Tail: 611 sacks Class G cement + 1% SI(CaCI2) + 0.3% D65(dispersant) + 0.2"/,, 1346 (defoam) + 1/4 #/sk D29 (celloflake) Slurry Volume 709 cu-ft Slurry Weight 15.8 ppg Slurry Yield 1.16 cu-flJsk Thickening time 3.5 - 4.5 hours Stage 2 Volume Calc: (1,465')(0.4206 cu-ftJ'ft)(4) = (2,465 cu-ft)/(4.41 cu-ftJsk)= 559 sacks of Stage 1 Lead Slurry (above) minus the D29 Casing Size / Hole Size: Depth: Top of Cement: Excess Calculated: BHT (Static): BHT (Circ): Volume Calc: (8,250' - 7,500.)(0.3132 cu-ft/ft)(1.75) = (411 cu-ft)/(1.16 cu-ft/sk) - ~A.~cks (+29 sxs for shoe jt.) 383 sacks ClAss G cement + 0.2% D65(dispersant) + 0.15% D8OO(retarder) + 0.1 gps [)47 (defoam) Slurry Volume 445 cu-ft Slurry Weight 15.8 ppg Slurry Yield 1.16 cu-ftJsk Thickening time 3.5 - 4.5 hours 9 5/8" 1 12 1/4" ....... 8,250' MD ............ 7,500' MD 75% (depending on est. OH) 160oF 130"F Casing Size / Hole Size: T' /8 1/2" Depth: Top of Cement & Top of Liner: 8,050' MD Excess Calculated: 50% (depending on est. OH) B HT (Static): 1700F BHT (Circ): 140"F Volume Calc: (10,400'- 8,050')(0.1268 cu-ft/ft)(1.5) = (447 cu-ft}/(1.19 cu-ft/sk) - 376 sacks (+15 sxs for shoe it.) 390 sacks ClAss G cement + 2 gps D6OO(latex) + 0.1 gps D135(stabilizer) + 0.1 gps [34.7 (defoam) + 3% D53(Gyp) + 0.7% D65(dispersant) + 0.15% D800(retarder) Slurry Volume 464 cu-ft Slurry Weight 15.8 ppg Slurry Yield 1.19 cu-ft/sk Thickening time 3.5 - 4.5 hours Casing Size / Hole Size: ~ 5" / 6 1/8" Depth: 12,260' MD Top of Cement & Top of Liner: 10,200' MD Excess Calculated: 50% (depending on est. OH) B HT (Staff c): 190°F BHT (Circ): 160°F Volume Calc: (12,260' - 10,200.)(0.0683 cu-ff./fl)(1.5) = (211 cu-ft)/(1.19 cu-ft/sk) = 177 sacks (+7 sxs for shoe jl.) 164 sacks ClAss G cement + 2 gps D600(latex) + 0.1 gps D135(stabilizer) + 0.1 gps D47 (defoam) + 3% D53(Gyp) + 0.7% D65(dispersant) + 0.2% DS00(retarder) Slurry Volume 219 cu-ft Slurry Weight 15.8 ppg Slurry Yield 1.19 cu-ft/sk Thickening time 3.5 - 4.5 hours KUPARUK RIVER UNIT~ 20" DIVERTER SCHEMATIC I HCR I I 3 2 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 20" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER EDF 3/10/92 7 I 5 3 1. 20" - 2000 PSi STARTING HEAD 2. 13-3/8"- 5000 PSI CASING HEAD 3. 13-3/8"- 5000 PSI X 13-5/8"- 5000 PSi SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8"- 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8"- 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR 13 5/8" 5000 PSI" OP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO~-FOM PIPE RAMS. TEST BOI-FOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DA;LY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE THE BOP STACK TEST WILL BE CONDUCTED AS DESCRIBED ABOVE, BUT WILL BE TESTED TO 5000 PSI HIGH. ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL ALSO BE TESTED TO 250 PSI LOW. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re~ THE APPLICATION OF ARCO ) ALASKA, INC. for an order granting ) an exception to spacing requirements of ) Title 20 AAC 25.055 to provide for the ) drilling of the ARCO Cache No. 1 ) exploratory oil well. ) Conservation Order No. 387 ARCO Alaska Inc. Cache No. 1 February 11, 1997 IT APPEARING THAT: le . . ARCO Alaska, Inc. submitted an application dated January 17, 1997 requesting exception to 20 AAC 25.055(a)(1) to allow drilling the ARCO Cache No. 1 exploratory oil well closer than 500 feet to a drilling unit boundary. Notice of hearing was published in the Anchorage Daily News on January 18, 1997 pursuant to 20 AAC 25.540. No protests to the application were received. FINDINGS: The ARCO Cache No. 1 well as proposed will be a deviated hole drilled fi.om a surface location 1773' fi.om the south line (FSL) and 112' from the west line (FWL) of Section 8, T1 IN, RgE, Umiat Meridian (UM) to a bottomhole location 2940' FSL and I570' FWL of Section 9, TllN, RgE UM. s Offset owners BP Exploration (Alaska), Inc., Chevron U.S.A., Inc., Exxon Company, U.S.A., Mobil Oil Corporation, and Union Oil Company of California have been duly notified. 4. An exception to 20 AAC 25.055(a)(1) is necessary to allow drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the ARCO Cache No. 1 well as proposed will not result in waste nor jeopardize correlative fights. Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of ARCO Alaska, Inc. for exception to 20 AAC 25.055 to allow drilling the Cache exploration oil well. ARCO Alaska, Inc. by letter dated January 17, 1997 has requested an exception to the provisions of 20 AAC 25.055(a)(1) for the drilling of an exploratory oil well to an undefined pool from the 2V drill pad within the Kuparuk River Unit on the North Slope. The exception would allow ARCO to drill the Cache exploratory oil well to a producing location that is closer than 500 feet from a quarter section line. The well will be drilled as a deviated hole from a surface location 112' from the west line (FWL), 1773' from the south line (FSL) of Section 8, T11N, R9E, Umiat Meridian (UM) to a producing location 1373' FWL, 2906' FSL of Section 9, T11N, R9E, UM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM February 10, 1997 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 AM on February 26, 1997 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433 after February 10, 1997. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than February 19, . David W. Y~.~ Chairman Published January 18, 1997 ADN AO02714024 WELL NAME GEOL AREA PROGRAM: e ev ~ redrl~ serv~ wellbore seg~ ann disp para r ADMINISTRATION z//e/? ? ENGINEERING APPR 0 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool .............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ ~.~ N 11. Permit can be issued without conservation order ..... 12. Permit can be issued without administrative approval..~ N 13. Can permit be approved before 15-day wait ........ 15. Surface casin~ protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf cng. 17. CMT vol adequate to tie-in long string to surf cng . . 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 abndnmnt been approved 22. Adequate wellbore separation proposed .......... /~ N 23. If diverter required, is it adequate .......... Y~ N 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~/~psig.~ N 27. Choke manifold complies w/API RP-53 (May 8~)... p~ .t~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY GEOLOGY: 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones .... O N 32. Seismic analysis of shallow gas zones, i i i i i i i i .O N /2 33. Seabed condition survey (if off-shore) 34. Contact name/phone for weekly progress reports .... [exploratory only] ENGINEERING: COMMISSION: Comments/Instructions: /' RPC HOW/dlf - A:\FORMS\chekiist rev 01/97