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Home My WebLink About193-095XHVZE Pages NOT Scanned in this Well History File 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. IC:~ '~C~File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED -[] Logs-of various kinds [] Other COMMENTS: Scanned by: Beve Vincent Nathan Lowell TO RE-SCAN Date: Is/ Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si ON BEFORE Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: ~Ob - ~q ~ DATE Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 Re' This memo wffi 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 ddil. 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 redfills and or multilaterais 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 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 descnbed in AOGCC staff memorandum "Multi-lateral (welibore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ; LI ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Januaw 10,1994 Paul Mazzolini ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Mr Mazzolini: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this o. ffice). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of.12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project, if I may be of any assistance, please call me at 279-1433. Yours very truly, ./. , -- Robed P Crandall Sr Petr Geologist encl jo/A:RPC:\drlstats 'ALASKA WELLS BY ARCO PACE OPERATOR ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA 93-0078-0 93-0095-0 93-0064-0 93-0066-0 WELL NAME NORTH FORELAND ST 2 S COOK INLET ST 1 S COOK INLET ST 2 S COOK INLET ST 3 Memorandum State of Alaska Oil and Gas Conservation Commission To: Commission ~9( June 24, 1993 Variance Requests - ARCO So. Cook Inlet #1 Fm~ subj: ARCO's request for exception to 20 ACC 25.030 (b) 2 is predicated on operating experience and specific information gained from drilling Sunfish 1, North Foreland St. No. 1, and Sturgeon 1. Drilling information from the above referenced wells confirmed shallow seismic surveys which also showed no indications of shallow gas prior to drilling. Arco and their contractors provided the results of shallow seismic surveys around South Cook Inlet No. 1 on 6/23/93 at the AOGCC office. The results of the surveys showed no indications of shallow gas above 3500' at the location. A previous review of wells nearby showed no abnormal drilling conditions nor indications of shallow gas in the surface holes. Based on lack of indications of shallow gas hazards, the staff recommends approval of the variance to casing setting requirements of 20 AAC 25.030 b(2), and support setting 13 3/8" to 2500' MD (2300' BML) in So. Cook Inlet St. #1. The variance to H2S requirements, 20 AAC 25.065, is reasonable in that there has been no evidence of H2S in the Sunfish and North Foreland St. wells. ARCO indicated that there will be monitoring equipment on board and in use to detect H2S and measures would be enacted if it is detected while drilling. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 24, 1993 Paul Mazzolini, Sr Drlg Engr ARCO Alaska Inc P O Box 10036 Anchorage. AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Dear Mr Mazzolini: South Cook Inlet St. #1 ARCO-Phillips 93-95 670'FSL, 2014'FWL, Sec 34, T11N, R10W, SM same Enclosed is the approved application for permit to drill the above referenced well. Your application for a variance to the setting depth of casing required by 20 AAC 25.030(b)(2) to allow setting 13 3/8-inch casing as deep as 2500 feet TVD is hereby approved. For this well, Phillips is also exempted from the requirements of 20 AAC 25.065 relating to hydrogen sulfide unless hydrogen sulfide is detected dudng drilling operations. 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. 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 at 279-1433. . David W JohnA[,0" '~ . Chairman ' BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl .... STATE OF ALASKA "-' ALAS._ . OIL AND GAS CONSERVATION COMMIS,5. PERMIT TO DRILL 20 AAC 25.005 i la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory X Stratigraphic Test __ Development Oil Re-Entry __ Deepen --I Service __ Development Gas __ Single Zone _ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 200' above mudline f~et Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 381217 ALK 4645 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 670' FSL, 2014' FWL, SEC 34, T11N, R10W, SM N/A Statewide At top of productive interval 8. Well number Number ARCO-Phillips SAME South Cook Inlet St.#1 #U630610 At total depth 9. Approximate spud date Amount 670 ' FSL, 2014 ' FWL, SEC 34, T11N, R10W, SM 6/25/93 $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 NF #1 15100' MD RKB 670' @ surface feet 4 mile at surface feet 3840 15100' TVD RKB feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth N/A feet Maximum hole angle N/A Maximum surface 2650 psig At total depth (TVD) 15100 ft 18. Casing program I Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling LenCh MD TVD MD TVD (include stage data) Driven 30" 457# B D-60 253' 47' 47' 300' 300' N/A 17.5" 13-3/8" 72# N-80 BTC 2453' 47' 47' 2500' 2500' Lead 4960 cf, Tail 575 cf 12.25 9-5/8" 53.5# L-80 BTC 9753' 47' 47' 9800' 9800' 470 cf or Suff cover all H.C. 8.5" 7" 35# L-80 BTC 15053' 47' 47' 15100' 15100' 1080 cf ClassG 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 Vertica~e Structural,.,, ~,~ E la F !) Conductor Surface Intermediate Production U N Liner Alaska 0il & Gas Cons. (~0mmissio¢ Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report ~20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed'~P~ ~'/fO.,/t,4.~:-~ Title Sr. Drilling Engineer Date ~/~,,/~ ! # ~ Commission Use Only Permit Number I APInumber Approval date I See cover letter for ¢,.~ - <~' 50- ? ~ - .2-.0 ~'._.~.2._ other requirements Conditions of ap[~roval Samples required ~z~Y e s ~ N o Mud Icg required ~' Y e s __ N o .~,pproved Copy Hydrogen sulfide measures~ Y e s ~ N o Directional survey required __ Yes z~. N o Returned Required working pressure for BOPE __2M; ...~. 3M;- 5M' "T~'IOM; -- 15M Other: Original Signed By David W. Johnston by order of ,.Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Post Office Box lbu$60 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 14, 1993 D. W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO-Phillips South Cook Inlet gl (SCI gl) Dear Commissioner Johnston: ARCO Alaska, Inc. hereby applies for a Permit to Drill (APD) an offshore exploratory / delineation well, the ARCO-Phillips South Cook Inlet g 1 (SCI g 1), in State waters of the Cook Inlet. ARCO will act as operator for itself and Phillips Petroleum Company in evaluating acreage previously leased in State of Alaska Lease Sales. The proposed well location is approximately 8 miles southwest of the Phillips North Cook Inlet Platform in about 32 meters of water. ARCO proposes using the 'Glomar Adriatic VIII' jack-up drilling rig to drill this well beginning as soon as all permits are acquired in 1993. As part of this application for permit to drill, ARCO Alaska, Inc. formally requests a variance to the setting depth of casing shown in 20 AAC 25.030(b)(2). It is requested that the maximum 1000' depth BML be extended to 2300' BML (2500' RKB) as noted on the permit. This request is discussed further in the attachments to the APD. We further request exemption from the requirements in 20 AAC 25.065 relating to hydrogen sulfide. H2S was not encountered in either the Sunfish gl or North Foreland gl wells and is not expected in the SCI gl. At SCI gl it is Arco's intent to monitor for the presence of H2S while drilling the entire well. If H2S is detected, the Commission will be notified as required and contingency equipment will be installed immediately. BOP tests will be conducted as required and noted in 20 AAC 25.035 (7.A). The initial test of the BOPE's will be to the rated pressure and the weekly tests will be conducted to 70% of burst of the last casing string run. This procedure will save unnecessary fatigue on the equipment. ~As required by 20 ACC 25.005 (c) (10), ARCO Alaska, Inc. requests permission to utilize the 13-3/8 X 9-5/8" casing annulus for pumping of drilling muds incidental to the drilling of this well. The end of well repo~s, Completion Repo~ 20 AAC 25.070 and Geologic Data and Logs 20 ~C 25.071 will be provided by James Trantham 265-6434 and Mike Navolio 365-6191 respectively. Wee~y operational updates will be conducted by James Trantham. ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company JUF~ I ,5 ~99,~ Alaska 0il & Gas Cons. Commission Anchorage Please note that we are currently evaluating a shallow hazards survey and we will forward this information as soon as we receive it. In accordance with usual practices, the AOGCC is requested to keep this application and attachments confidential. If you have questions please contact myself at 265- 6434 or Paul Mazzolini at 265-6112. Thank you for your attention. Si~erely, ~ James A. rant am Drilling Engineer 'Attachments CC' SCI #1 Well File J. R. Winegamer ATO-1934 M. E. Navolio ANO-748 d U ~,,~ ! 5 199~ ~qlaska Oil & Gas Cons. ~.,omrr~issior~ /lnchorage ARCO - Phillips South Cook Inlet #1 CASING SCHEMATIC (All depths RKB) Beluga Fm @6,300' Tyonek Fm @9,600' Sunfish Fm @ 13,900' N.Foreland Fm @ 14,400' ::'..; .,..... ::::. .?.; %°,1 :; :::: .'::: ::.... ....~. :::..':::;. ::..':::..':::;:::..':::.. ::::::::::::::::::::: ::.::::..':::.::::..':::.. 30"x 1-1/2" Wall, D-60 Drive Pipe @300' or to refusal Top of Cement @surface 13-3/8",72, N-80, BTC Surface casing @ 2,500' TOC @ 8,800' or 500' above HCZ TOC @9,500' 9-5/8", 53.5#,L-80, BTC Intermediate Casing @ 9,800' 7", 35#,L-80, BTC Production casing @ 15,100' TD @ 15,100' Gas uons. Comri~lssto,' Anchorage bsr6/07/93 DRILLING PROCEDURE Per 20 AAC 25.005 (c) (10) (All depths are measured from RKB unless otherwise noted) Tow rig from Rig Tenders' Dock to well location and jack down legs. Estimated tow distance is 30 miles. Using leg jacking mechanisms, maintain constant air gap of 1' to 5' through one complete tide cycle. Divers will check the spud cans during the slack tide. Preload will consist of taking on 11,000 Kips (5,400 short tons of Inlet water). After 12 hours at pre-load conditions or after all discernible leg settling has ceased, whichever last occurs, discharge pre-load water and jack up to operating height and rig up to spud. Rig up drive hammer and drive 30" structural casing to refusal (Minimum of 100' BML). Buttweld hanger sub should be positioned about 15' BML. Install 27-1/2" x 37" Diverter on 30" structural casing and function test. Notify Alaska Oil and Gas Conservation Commission (AC)GCC) 24 hours in advance of testing the diverter so they may witness if desired. Pick up drilling assembly and clean out conductor. Drill 17-1/2" hole to 2,500' RKB. Run 13-3/8", 72#, N-80, BTC surface casing to 2,500' RKB. Land casing in buttweld sub in 30" drive pipe. Be sure to have space out pups handy. Centralize in 30" casing. Cement 13-3/8" casing to surface. Open cleanout ports at mudline hanger and assure there is no cement in 13-3/8" x 30" annulus above the mudline hanger. If desired, spot water containing a cement retarder in the 13-3/8" x 30" annulus. Close hanger ports. Install 13-5/8" 10,000 psi starting head. NU a 13-5/8" 10,000 psi WP BOP stack. Pressure test BOPE to 10,000 psi. Notify AOGCC 24 hours in advance of test so they may witness if desired. NOTE: All weekly BOPE tests shall be tested to 70% of the burst of the last csg string. (13-3/8" = 3750 psi) All BOP and casing pressure tests should be recorded on a pressure chart. The chart should be signed by the ARCO Drilling Supervisor and the PushedDriller on tower. Pressure test 13-3/8" casing to 3750 psi (70% of burst). Drill out and perform formation integrity test to leak-off. Drill 12 1/4" hole to 9,800'. RKB with MWD equipment in the string. At 9,800', run the following open-hole logs to 13-3/8" shoe: 1 --DITE/LDT/CNL/Sonic/AMS 2--CST (PercUssion sidewall) - optional 3--VSP (Cased hole) - optional Alaska. 0il & Gas 00ns. Anchorage Run 9-5/8", 53.5#, L-80, BTC casing to 9,800' RKB and land in mudline hanger system. Cement 9-5/8" casing to cover all significant hydrocarbon bearing zones as per state regulations. Open cleanout ports at mudline hanger and assure there is no cement in 13-3/8" x 9-5/8" annulus above the mudline hanger. If desired, spot water containing a cement retarder in the 13-3/8" x 9-5/8" annulus. Ensure the 13-3/8" x 9-5/8" annulus is open for annular injection. Close hanger ports. ° Raise BOP stack, cut off the 9-5/8" casing and install 13-5/8", 10,000 psi x 13-5/8", 10,000 psi casing head. ° Nipple up BOP stack on casing head and test to 10,000 psi. Notify AOGCC of BOP test. NOTE: All weekly BOPE test shall be tested to 70% of the burst of the last csg string. (9-5/8" - 5550 psi) All BOP and casing pressure tests should be recorded on a pressure chart. The chart should be signed by the ARCO Drilling Supervisor and the Pusher/Driller on tower. ° Run cased-hole logs if any from TD to the 13-3/8" casing shoe. o Pressure test 9-5/8" casing to 5,550 psi (70% of burst). ° Drill out and perform formation integrity test to leak-off. o Drill 8-1/2" hole to approximately 15,100' RKB. This includes 2-3 60' cores in primary objective sands (Sunfish section), and 1-2 60' cores in the secondary objective sands (North Foreland). ° ' At 15,100', run the following open-hole .logs to the 9-5/8" casing shoe: 1 --DITE/LDT/CNL/Sonic/AMS 2--FMS or FMI/GR/AMS - Dipmeter 3--DSl (Dipole Sonic) - optional 4--CST (Percussion sidewall) - optional 5--MDT or RFT - optional Note: If logs indicate further testing of the zones proceed and test as follows: o Run 7", 35#, L-80, BTC casing to 15,100' RKB. o Cement 7" to cover all hydrocarbon zones. Design the top of cement at the minimum of 300' above 9-5/8" shoe. Open cleanout ports at mudline hanger and assure there is no cement in 9- 5/8" x 7" annulus above the mudline hanger. If desired, spot water containing a cement retarder in the 9-5/8" x 7" annulus. Close hanger ports. o Clean out to the top of float equipment. o Run cased-hole logs (casing caliper, CBT) as necessary. o Pressure test 7" casing to 5,000 psi. o Test using 3-1/2" tubing string by perforating under balanced and flowing up the tubing and through surface testing facilities. Test liquids are to be stored in tanks aboard the drilling unit and pumped back into the reservoir or down the 9-5/8" X 13-3/8" annulus after testing. Gas is to be flared. Testing will involve alternating flow periods and shut-in periods. Individual intervals may be tested separately or concurrently. o After completion of testing, kill well and remove test string and packer. o When testing is completed, squeeze all open perforations and abandon well per 20 AAC 25.105. o Disengage running tools (MLH) and recover all casing from 15' BML. Cut off 30" casing BML. ° Jack up legs of drilling unit and remove rig from location. Anchora[le SOUTH COOK INLET #1 DRILLING TIME CURVE -1 -1 -1 -1 0 -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 0000 1000 2000 3000 4000 5000 6000 7000 8000 _ ~ \. North Foreland #1 Actual - ........... . ~).t-[::~__ I%,n +;~ /a ~,~.~, ~; Depth _' ~~ _ ~ · ~ SCl ~1 Planned . ~, ..... I ..... ~ - ......... _ _ ~ - ._ ....... ;--=~. ,~ ........................... ; .... ~ ...................... : ..................... i .................. ~ .... [ ................... ; ................ ....................................................... ........ ....... ...... ~ ~ ~'~ ~ .... .................................... ............. ~_~ ............... L- ..... ~....... ~ ....... ~ ...... , , ..... ,_ 0 10 20 30 40 50 60 70 80 90 100 110 120 DAYS BSR 5~3~93 PROPOSED DRILLING FLUID PROGRAM per 20 AAC 25.005 (c) (6) INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: From Base of Drive_ Pipe to 2500' RKB 17-1/2" 13-3/8" Flocculated Bentonite/Inlet Water System MUD PARAMETERS WEIGHT: 8.5 - 10.0 ppg VISCOSITY: 50 - 100 sec./qt PV: 12 - 18 YP: 15 - 30 pH: 9.0 -10.0 FILTRATE: 2 0 MAX SOLIDS: < 6% Spud the well with a mud consisting of prehydrated bentonite, extender, and caustic soda flocculated into an Inlet water system. String the prehydrated bentonite slurry into the Inlet water system allowing the flocculation to provide the viscosity required for good hole cleaning. If necessary, additional flocculation can be provided by using lime or cement. Both shallow gas and lost circulation may be a problem in this interval. LCM and weight material will be on board for use if needed. In the event of massive lost circulation, the deep well sea water pumps are capable of pumping water directly into the bell nipple. Controlled drilling will be practiced if required. Due to fast penetration rates and the large diameter hole, the drilled solids content can increase rapidly. Run all solids control equipment to reduce mud dilution requirements. Some controlled drilling may be required. 41ask.:'-~ Oil & Gas 6ohs, Anchorage. INTERVAL: HOLE SIZE: CASING SIZE: MUDTYPE: 2500' RKB to 9,800' RKB 12-1/4" 9-5/8" Flocculated Bentonite/Inlet Water System MUD PARAMETERS WEIGHT: 9.0 - 13 ppg VISCOSITY: 50 - 80 sec./qt PV: 15 - 20 YP: 15 - 20 pH: 9.0 - 10.0 FILTRATE: - 20 SOLIDS: < 8% Drill the 13-3/8" casing shoe and rat hole with spud mud from the preceding interval, routing returns for disposal. Drill to 9800' MD for logs. Log the well. Maintain adequate viscosity for effective hole cleaning using the flocculated bentonite. Control any excessive rheology which may develop with Desco-CF on an as needed basis. PAC polymers may be used toward the bottom of the interval for improved well bore stabilization. The reduction in water loss from the PAC treatment will also improve conditions for logging and reduce the possibility of differential sticking. It is possible that some of the sand intervals that may be drilled will still have virgin pressures. This is more of a concern in the Beluga intervals below 6500' TVD. Close attention to the PV'T' system must be maintained at all times. Coals are again of concern, especially near TD of the interval. Increases in mud weight have been used to control sloughing coals. Increases in the mud weight are of concern given the potential for lost circulation in the depleted intervals. ,, -.a. iaska Oil & Gas Cons, ;qrll, nO~ agt~ INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: 9,800' RKB to 15,100' RKB (TD) 8-1/2" ii Weighted PHPA Polymer Mud MUD PARAMETERS WEIGHT: 13.5 - 15.0 ppg VISCOSITY: 40 - 50 sec./qt PV: 15 - 25 YP: 10 - 20 pH: 8.5 - 9.5 FILTRATE: 4 - 6 cc/30 min. SOLIDS: 1 4- 1 8 % KCI: 3 - 5% Drill the 9-5/8" casing shoe and rat hole, routing returns for disposal. Displace with the PHPA mud prior to drilling ahead in the 8-1/2" hole, if necessary. Use a high viscosity fresh water/Barazan pill to separate the old mud from the new. Drill to TD, maintaining mud system properties as listed above and adjusting to those dictated by wellbore conditions. Sodium Bromide, at a concentration of .05 ppb, will be used as the tracer material in this hole section. Alaska 0il & 6as 00ns. Anchorage DRILLING FLUID SYSTEM DESCRIPTION PER 20 AAC 25.005 (C) (6) MUD STORAGE CAPACITIES · DrillWater 13,060 bbls · Bulk Mud 5,600 cu. ft. · Surge Tanks 100 cu. ft. · Liquid Mud (Active System) 1925 bbls · Sack Storage (Approximate) 1,265 sq. ft. MUD FACILITIES AND EQUIPMENT · Shale Shakers: (4) Derrick FIo-Line Cleaners. · Desander: Brandt desander unit charged by 8X6R centrifugal pump driven by 100-hp explosion-proof motor. · Mud Cleaner: Brandt dual cleaner including two (2) 3-hp 1,800 rpm explosion-proof motors charged by Mission 8X6R centrifugal pump driven by 100-hp electric motor. · 'Degasser: Wellco model 6200. · Centrifuge: Baroid 24" x 38" High G variable speed decanting centrifuge. · Mud Agitators: 1. One (1) 5-hp explosion-proof electric mud mixer mounted on slugging pit. 2. Four (4) 25-hp explosion-proof electric mud mixers on main mud tanks. 3. Four (4) 2-hp explosion-proof electric mud mixers on sand trap tanks. · Mud-Gas Separator: Global Marine design. · Mud Testing Facilities: Basic kit for viscosity, filtration, weight and titration. · Mud Mixing Pumps: Two (2) Mission 8X6R centrifugal pumps driven by a 100-hp electric motor. · Pit level indicator on active tanks with totalizer at drilling position. · Manifolding to cement surge tank to permit mixing of barite plug at cementing unit. · Gas Detection System: 1. Control Instruments fixed combustible five-point monitor gas detection system with sensors strategically located on the rig. 2. Seigar fixed H2S five-point monitor gas detection system with sensors strategically located on the rig as per state regulations. .A~ask~ 0il & Gas Cons. bo~ A~chorage .. .. /' '""" t N[3., ..... / TAr 1 i-::i '[ g N K T h NK II h'E], S~ [ NIl, 4 l h. lO. 5 DER~IICK: [IE/P~ICK I.'IE E'K,~ ICI( ~ERI;..IC:K FLO-.LINE Il Fl.,O-LINE [~ Il F'L..O...-LINE H FL[]--L IME Ct EANER "- -ti C:LEANE .I .................. L ................... .... ADRIATIC VIII ARCO - Phillips SOUTH COOK INLET #1 PRESSURE ANALYSIS per 20 AAC 25.005 (c) (7) A pressure analysis was performed for this well using site-specific seismic data and offset well information from wells in close proximity to the planned drilling location. The purpose of the pressure analysis is to predict the potential for over pressured strata based on remote seismic data and specific well information. The closest well to the SCl #1 is the NF #1 (drilled to 17,700' TVD). Attached is a graph showing the mud weights used in the NF #1 well and the Sunfish #1 well. The recently completed NF #1 is located about 4 miles to the Northeast. In addition to the specific drilling information gained from these wells (i.e.; mud weight vs. depth and sonic log data), a site specific seismic survey was performed and is presented in graphical format. This information was used to compile and submit the Proposed Mud Program for this well. As noted on the following graph of the North Foreland and Sunfish Mud Weight vs. Depth, we anticipate raising the mud weight to approximately 10 - 12 PPG in the Tyonek formation (+ 9650'). This is necessary to control hole stability due to the flow of tectonic-stressed coal stringers. The associated sands throughout the Tyonek are mostly normally pressured as experienced in both the Sunfish #1 and North Foreland #1 wells. A sharp pressure transition is expected below the Sunfish formation but prior to North Foreland penetration. The anticipated pore pressure in the Sunfish is 9.8 PPG and 13.5 PPG in the North Foreland. Mud weight will be raised to 13-14 PPG in anticipation of the North Foreland pay expected @ +14,350'. We are currently interpreting a shallow hazards survey and will submit the analysis as soon as possible. Alask~, Oil & Gas bon~. Anchorage NORTH FORELAND vs SUNFISH MW -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 -110o0 -12000 -13000 -14000 -15000 -16000 -17000 -18000 8.00 9.00 10.00 11.00 12.00 13.00 14.00 15.00 16.00 17.00 MUD WT, PPG SWR 8/25/92 2000 4OOO 6OOO 80OO 10000 12000 14000 16000 18000 10 SCI #1 Seismic Data lO0 ITT (ms/fi) 1000 ~,laska Oil & Gas Cons. Oommissio~~. Anchora.~e II G~,O?~,So ~k%O - CALC Ne-~" ~ ~;1"II AVG SONIC i - SHALE MUD WEIGHT SONIC TRANSIT TIME DERIVED MUD WEIGHT 3 O , 2000. 4000. 6000. 8000. 0000. 12000. 14000. ~-?: 16 0 00. "=~ :".-?.-~: 18 0 00. i ! ! , ,~.. - ! /- ~_:.... ~~_.., / . US ET . PPG . 40. US~FT 200. 8. PPG 20. 40. US~FT 200. 4 0. U S/F T '2 0 0. .--SIESMIC VS SONIC LOG Ti-. ,NSIT TIME COMPARISON INTERVAL TRANSIT TIME (ITT) SUNFISH SIESMIC FI-I' SUNFISH SONIC LOG i'1-1' NORTH FORELAND SIESMIC FI-I' .Oil & Gas Cons. Commission' ~nchorage TEM-1119/92 Shell SRS Pressure Graph -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 -11000 -12000 -13000 -14O0O -15OOO -16000 -17000 -lB000 -19OOO -20000 ' [] SSRS-mud w ;, SSRS-SI EMW ' I ' I ' I ' I ' I ' I " I ' ! " i ' 8 9 10 11 12 13 14 15 16 17 18 SSRS-mud w Alaska Oil & Gas Cons. Cornrnission Anchorage PRESSURE INFORMATION ARCO-Phillips' South Cook Inlet #1 per 20 AAC 25.035 (d) (2) The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Sunfish well: Casing Setting Depth Rationale 3O" 100' BML 1 3- 3 / 8" 2,500' RKB, 2,300' BML 9-5/8" 9,800' RKB, 9,600' BML ii 15,100' RKB, 14,900' BML Structural casing. Depth as required by 20 AAC 25.030(b)(1). This string of casing will top set the Sterling formation. It will provide a good anchor for the BOPE to ensure sufficient fracture gradient for well control while drilling the next interval. Intermediate casing to isolate potential shallow gas zone (Beluga Fm) and Lower Tyonek. Production casing/liner to isolate primary objective Sunfish sand interval and the secondary objective North Foreland sand interval for prospective testing. Casing Size (in.) 3O 13-3/8 9 -5/8 7* Casing Setting Depth (ft. RKB) Pore Fracture Pressure Anticipated Pore ASP Gradient Gradient Max MW Pressure Drilling (lbs/gal) .(lbs/gal) (lbs/gal) (psi) (psi) 300 8.8 8.7 10.0 135 104 2,500 14.8 9.1 12.0 1183 806 9,800 17.0 11.0 15.0 5605 2650 15,100 18.0 14.4 16.0 11307 4475 * In case of deepening the well below 7" casing. Alaska 0il & 6as Cons. Anchorage Casing Performance Properties Size Weight Grade Conn. (in) (Ib/ft) 30 1 - 1/2" B D-60 wall 13-3/8 72 N-80 BTC 9-5/8 53.5 L-80 BTC 7 35 L-80 BTC Internal Collapse Tensile Strength Yield Resistance Joint Body (psi) (psi) (1000 lbs) 3150 300O 26OO 5380 2670 1693 1661 7930 6620 1286 1244 8460 1 01 80 833 814 Casing Design Safety Factors 13-3/8" 72 N-80 BTC 9-5/8" 53.5 L-80 BTC 7" 35 L-80 BTC 3.91 1.71+ 11.5 11.3 3.00 4.06 3.00 2.91 3.19 2.15' 2.05 2.00 + Complete evacuation * Calculation using DST condition. Procedure for Calculating Anticipated Surface Pressure (ASP) 1. Drilling below Structural and Conductor Casing ASP is determined on the basis of breakdown of the formation at the casing seat with a gas gradient to the surface as follows: ASP = [(FG x 0.052) - 0.11]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 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2. Drilling Below Surface Casing ASP is determined on the basis of breakdown of the formation at the casing seat with accompanying complete loss of returns and the hole filled with seawater: ASP = (FG - 8.60) x 0.052 x D where: 8.60 - density of seawater in lb/gal 4iaska 0ii & Gas 0ohs. 60mr,dssio~' Anchorage 3. Drilling Below Intermediate Casing / Drilling Liner ASP is determined on the basis of breakdown of the formation at the casing seat, an accompanying mud level drop of 1/2 of the shoe depth and the remainder of the wellbore filled with seawater: ASP = BHP - MUD COLUMN WEIGHT - SEAWATER COLUMN WEIGHT ASP = FG (.052) D-[MW (.052)] .5 D-[8.6 (.052)] .5 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 8.60 = density of seawater in lb/gal MW - drilling mud weight lb/gal D = True vertical depth of casing seat in ft RKB ASP Calculations 1. Drilling below structural casing (30") ASP= [(FG x 0.052) - 0.11]D = [(8.8 x 0.052) - 0.11] 300 = 104 psi 2. Drilling below surface casing (13-3/8") ASP = (FG - 8.60) x 0.052 x D = (14.8 - 8.60) x 0.052 x 2500 = 806 psi 3. Drilling below Intermediate casing (9-5/8") ASP = FG (.052) D -[MW (.052)] .5 D -[8.6 (.052)] .5 D = 17.0 (.052) 9800- [15.0 (.052)] (4900) -[8.6 (.052)] (4900) - 2650 psi 4. Drilling below Production casing (7") ASP = FG (.052) D -[MW (.052)] .5 D -[8.6 (.052)] .5 D [16.0 (.052)] (7550) = 18.0 (.052) 15100 - [8.6 (.052)] (7550) = 4475 psi Alaska 0il & Gas Cons. Cornm~sSioo Anchorage CASING PERFORMANCE SAFETY FACTOR CALCULATIONS SAMPLE CALCULATIONS FOR: I. 9-5/8", 53.5#, L-80, BTC - INTERMEDIATE / PROTECTIVE CASING A. INTERNAL YIELD / BURST Csg Burst Rating = 7930 psi Anticipated Surface Pressure while drilling ahead = 2636 psi (See Calcs for ASP) SF b = 7930/2650 = 3.00 B. COLLAPSE RESISTANCE Csg Collapse rating Evacuation depth = 6620 psi = Csg Depth (1 - pore press grad / expected max mw) = 9800 (1 - 11/15) = 2613 feet P external @2600' = 2613 * 0.052 * 12.0 (mw used when cmtg the csg) = 1631 psi SF c = 6620 / 1631 = 4.06 In case of complete evacuation (very unlikely), P external at shoe = 0.052 * 12.0 * 9800 = 6115 psi SF c -' 6620 / 6115 = 1.08 C. TENSILE STRENGTH Buoyed Csg Weight = 53.5 * 9800 * (1 = 428,157 lbs SF Tj = 1,286,000 / 428,157 = 3.00 SF Tb = 1,244,000 / 428,157 = 2.91 - 12.0/65.44) II. 7", 35#, L-80, BTC - PRODUCTION CASING A. INTERNAL YIELD / BURST Csg Burst Rating = 8460 psi S F b = 8460 / 2650 = 3.19 If well is deepened and drilled below 7" shoe: ASP = 18 * 0.052 * 15100 - (16 + 8.6) * 0.052 * 7550 = 4475 psi SF b = 8460 / 4475 = 1.89 Alaska Oil & Gas Oons. Anchorage B. COLLAPSE RESISTANCE Csg Collapse Rating = 10180 psi North Foreland DST (base on NF #1 DST data) Estimated Sunfish sand depth -- 14400' Fluid weight produced = 8.4 ppg Test Tree pressure = 200 psi P external = 0.052 * 14400 * 15.0 (mw used when cmtg the csg) = 11232 psi P internal = 0.052 * 8.4 * 14400 + 200 = 6490 P collapse = 11232 - 6490 = 4742 psi SF c = 10180 / 4742 = 2.15 C. TENSILE STRENGTH Buoyed weight -- 35 * 15100 * (1 = 407,358 lbs SF Tj = 833,000 / 407,358 - 2.05 SF Tb -- 814,000 / 407,358 = 2.00 15.0/65.44) alaska el! & Gas Cons, 6ornrpissi~ Anch0ra~,e CASING DEPTH SETTING VARIANCE REQUEST ARCO Alaska, Inc. (AAI) requests a variance to the required setting depth of the conductor casing as specified in 20 AAC 25.030(b)(2) for the ARCO/Phillips South Cook Inlet #1 (SCI #1) well. The proposed conductor string in SCI #1 is 13-3/8", 72#, N-80. The proposed setting depth is approximately 2300' below mud line. AAI is requesting this variance based on the operating experiences gained at the Sunfish #1, North Foreland State #1, and Sturgeon #1 and the specific drilling information gained at Sunfish #1 and North Foreland State #1. By approving the change in conductor setting depth, the hole/casing design planned for SCl #1 will be optimized and allow the operating experiences gained in the most recently drilled wells to be employed to significantly reduce the anticipated operating time without incurring undo risk. AAI has conducted shallow seismic surveys in the immediate areas of the Sunfish #1, North Foreland State #1 and the intended location of the SCl #1 well. All reports have been previously submitted to the Commission. When presented to the Commission, the report findings were discussed. In the case of the first planned well, Sunfish #1, it was interpreted that according to seismic information no significant shallow hazard existed at the proposed location. Drilling confirmed the analysis. When the North Foreland information was presented, the same conclusion was reached and verified when drilled in the 1992 drilling season. In the intervals above 3500' RKB in both the Sunfish and North Foreland wells, no drilling anomalies were encountered. The mud weights used were at most 9.0 ppg and the actual mud weight was dictated by the drilled solids content of the mud rather than any added barite. At no time during the drilling of these intervals was there any indication of or attempt by the well to flow. When the initial hole intervals (~300' - 1200' RKB) were drilled on Sunfish and North Foreland (316- 2500' on North Foreland), a 12-1/4" pilot was employed. This approach results in exposing a minimal wellbore area and allows a quicker reaction time to any potential flow. Since the hole size difference between 17-1/2" and 12-1/4" is not as significant as in the earlier wells, it is planned to drill this interval on SCl #1 with a 17-1/2" bit. No hole opening will be required. Mud flow into and out of the well is monitored with two independent PVT systems, the rig's own and the mud logger's. In the event of lost circulation a fillup line connected to the rig's sea water pumps has been installed to allow the hole to be flooded with sea water. With regard to diverter and BOP equipment, reference is made to the diagrams included elsewhere in this application. It is planned that a 30" diverter, as employed on the past wells, will be used while drilling below the 30" drive pipe. The diverter lines are 12" and extend in straight runs from the spool to beyond the cantilever deck beams. A 13-3/8" BOP stack will be in use while drilling below the 13-3/8" casing (2300 BML). This is in contrast to the use of the 30" diverter on both the 30" structural and the 20" conductor casings in the past wells. If a conductor string is required at approximately 1200' (1000' below mud line), insufficient formation integrity at the shoe would preclude shutting in a BOP stack since poor rock strength at this depth would result in an underground blowout which would broach the seafloor. Therefore, setting the conductor in rock with sufficient rock strength (2300' BML) results in a more reliable well control situation sooner, than if a diverter system is used until the next casing point, probably 3500' as in Sunfish #1. In support of this request, several wells in the Cook Inlet area have been identified where the conductor casing string (String 2) has been set deeper than 1000' below mud line or ground level. The wells and the RKB-TVD casing depths are: Well String 1 String 2 ARCO Fire Island #1 30" @ 328' 20" @ 1685' Stuart W. McArthur RU #1 30"@ 127' 20"@ 2040' Phillips NCIU A-12 30"@ 381' 20"@ 1990' ARCO/Phillips North Foreland #1 30" @ 316' 20" @ 2489' ARCO Funny River #1 30"@ 60' 20"@ 2971' ARCO Beluga RU 214-26 20' @ 95' 13-3/8" @ 2985' String 3 13-3/8" @ 7603' unknown 13-3/8" @ 6950' 13-5/8" @ 8498' 13-3/,,8" @ 831~ 9-5/8 ,.J U h,! 1 5 199 Alaska. 0il & 6as 00ns. Anchorage Cementing Program South Cook Inlet #1 per 20 AA C 25.030 13-3/8" Surface Casing Casing Size: 1 3 - 3 / 8" Hole Size: 1 7 - 1 /2" Depth: 2,500' RKB Top of Cement: Surface Excess Calculated: 2 0 0 % BHT (Static): 80°F BHT (Circ): 70°F Slurry Components and Properties: Preflush: 20 bbls seawater, with volume and weight adjusted based on hydrostatic considerations Lead: 2375 sacks Class G cement + 1.0% D-79 (chemical extender) + 2.0% S-1 (Calcium Chloride) Slurry Volume Slurry Weight Slurry Yield Mix water Thickening time 4960 cuft 12.5 ppg 2.09 cu. ft./sk 11.89 gps 4+ hours Tail:. 500 sacks Class G cement + 0.05 gps D-47 (antifoam) + 2.0 % S-1 (Calcium Chloride) Slurry Volume Slurry Weight Slurry Yield Mix water Thickening Time 575 cuft 15,8 ppg 1,15 cu. ft,/sk 4,97 gps 3,5 - 4,0 hours Alaska Oil & Gas Cons. Cornmissior, Anch0ra,ge 9-5/8" Intermediate Casing Casing Size: Hole Size: Depth: Top of Cement: Excess Calculated: BHT (Static): BHT (Circ): 9-5/8" 12-1/4" 9,800' RKB 8,800' (or 500' above HCZ) 5O% 135°F 110OF Slurry Components and Properties: Preflush: 20 bbls seawater, with volume and weight adjusted based on hydrostatic considerations Tail: 408 sacks Class G cement + 1.0% D-156 (FLA) + 0.05 gps D-47 (antifoam) + 1.0% D-65 (dispersant) + D-801(retarder) as required. Slurry Volume Slurry Weight Slurry Yield Mix Water Thickening Time 470 cuft 15.8 ppg 1.15 cu. ft./sk 4.97 gps 3.5 - 4.0 hours A/ask,~ Oil & 6as Cons. ' -:' Cornlfi~ss:,.,~ AnchoraCe 7" Production Casing Size: Hole Size: Depth: Top of Cement: Excess Calculated: BHT (Static): BHT (Circ): Casing i! 8-1/2" 15,100' 9,500' RKB (minimum 300' above 9-5/8" shoe) 50% 220°F 210°F Slurry Components and Properties: Preflushes: 30 bbls ARCO Spacer-weighted as appropriate Slurry: 830 sacks Class G cement + 35% D-66 (silica) + 1 gps D-600 (latex) + 0.1 gps D-135 (latex stabilizer) + 1.0% D-65 (dispersant) + 0.05 gps D-47 (antifoam) + D-801 as required Slurry Volume Slurry Weight Slurry Yield Mix Water Thickening Time Fluid Loss Free Water 1080 cuft 17.0 ppg 1.30 cu. ft./sk 4.5 gps 3.5 - 4.0 hours 100 c¢/30 min. 0 cc Alaska (iii & Gas Cons. Comt~lssioi~ Ancho[age DIVERTER SCHEMATIC per 20 ACC 25.035 (a) (1) I Flowline I I MSP-1000, 30" Annular Preventer 12", 2000 Hydraulic psi Valve 30113 1000 psi Spool 12" Outlets 12", 2000 Hydraulic psi Valve No-Weld Adapter 3O" X 1-1/2" Drive Pipe · '~iaska 0il & Gas Gons. Oommission Anchorage Glomar Adriatic VIII per BOP SCHEMATIC 20 ACC 25.035 (a) (1) I J I I I I I ' I I I I I I I 2 I I 13-5/8", I 10,000 PSI, RRRRA Anchorage See listing of individual components on following page. Glomar Adriatic VIII BOP COMPONENTS per 20 AAC 25.035 (d) (2) 13-5/8, 10,000 PSI, RRRRA 1. 13-5/8", 5000 psi WP, Hydril annular preventer with companion flange to bell nipple. 2. Double 13-5/8", 10,000 psi WP type "U" Cameron blowout preventer fitted with 5" pipe rams top and blind rams bottom. 3. Double 13-5/8", 10,000 psi WP type "U" Cameron blowout preventer fitted with 5"pipe rams top and bottom. 4. 13-5/8", 10,000 psi X 13-5/8", 10,000 psi Drilling Spool. Choke Valves: 5. 3-1/16", 10,000 psi WP hydraulic valve 6. 3-1/16", 10,000 psi WP manual valve Kill Valves: 7. 3-1/16", 10,000 psi WP manual valve 8. 3-1/16", 10,000 psi WP hydraulic valve Glomar Adriatic VIII Alaska Oil & Gas Cons. Anchorage SCIItl Ct4T.XLS S tare: ,4/,~,,'¢,'8 E ngineer: Well: So. Cool< Inlet #1Work Sheet: Field: Wildcat Date: State Permit ~ 93-.95 £err~n! Vo/ume £a/cub#on, ¢/22/93 Ca~g Type Casing Size -Inches Casing Length- Feet Hole Diameter-Inches Cement-Sacks 111 Cement-Yield ltl Cement- Cubic tt~11 Cement- Cubic ttItl Cement-Sacks 112 Cement- Yield Cement- Cubic Cement- Cubic tt112 Cement- Sacks 113 Cement- Yield Cement- Cubic it 113 Cement- Cubic ft Cement- CUbic ft /Vol Cement- Fill Factor Conductor Surface 0.000 13.375 0.000 2,453.000 0.000 17.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 4,960.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 575.000 0.000 0.000 0.000 0.000 0.000 5,535.000 I~:i:)iV/0! 3.248 Line~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~DIV/O! Casing Type Casing Size -Inches Casing Depth - Feet Hole Biameter-Inches Cement-Sacks Itl Cement-Yield Itl Cement- Cubic itItl Cement- Cubic tt111 Cement- Sacks Cement- Yield 112 Cement- Cubic It 112 Cement- Cubic tt Cement-Sacks II3 Cement- Yield 113 Cement- Cubic It 113 Cement- Cubic tt 113 Cement- Cubic Il: / Vol Cement-interval ft Top of Cement- Feet Intermediate ~I1 Intermediate It2 0.000 9.825 0.000 9,800.000 0.000 12.250 0.00 1,700.00 0.00 0.00 0.00 0.00 0.00 470.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 470.00 ~IDIV/O! 1,500.73 ~:DIV/O! 8,299.3 Production 7.000 15,100.000 8.500 0.00 0.00 0. O0 1,080.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1,080.00 8,516.90 6,583.1 Plea, sured Depth, ,,,,, Printed 6/22/93 St~t~: Borough: Well: Field: St Alaska So. Cook Inlet #1 Wildcat 98-95 SCi_i C.gG.)~LS D~te Eng~ 6/2_ 1/93 M. Minder Casing t nterval Interval Description Size Bottom Top Length Lbs 1A 30 300 47 253 457 2A 13.375 2500 47 2453 72 3A 9.626 9800 47 9753 53.5 4A 7 16100 47 15053 35 5A 0 0 0 0 0 6A 0 0 0 0 0 7A 0 0 0 0 0 8A 0 0 0 0 0 9A 0 0 0 0 0 10A 0 0 0 0 0 Description Grade B N-80 L-80 L--80 0 0 0 0 0 0 Description Thread D-60 BTC BTC BTC 0 0 0 0 0 0 Tension Lbs 0 0 0 0 0 0 0 0 0 0 lB 25 35 45 55 65 75 85 95 105 Mud Weight PPg 10.0 12.0 12.0 15.0 0.0 0.0 0.0 0.0 0.0 0.0 Hydraulic Gradient psi/ft 0.520 0 624 0.624 0.780 0.000 0.000 0.000 0.000 0 000 0.000 Collapse Gradient 0.420 0.524 0.624 0.680 -0.100 -0.100 -0.100 -0.1 O0 -0.1 O0 -0.1 O0 Maximum Pressure psi 104 2650 4475 4475 0 0 0 0 0 Minimum Yield psi 3150 4980 7930 8460 0 0 0 0 0 0 BDF 30.3 1.9 1.8 1.9 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #OlV/O! #DIVt0! 1C 2C 30 4C 5C 6C 7C 80 90 10C Tension K/Lbs 115.621 176.616 521.7855 526.869 0 0 0 0 0 0 StrenCh K/Lbs 26OO 1661 1244 814 0 0 0 0 0 0 TDF 22.49 9.40 2.38 1 J54 #OlV/O! #DIV/0! #DIV/0! #DIV/0! #DIV/O! #DIVtO!. Collapse Pr-Bot-Psi 126 1310 5135 10268 0 0 0 0 0 0 Collapse Resist. 3000 2670 6620 10180 0 0 0 0 0 0 Page 1 ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS APPROVE DATE [ 2 thru (3) Admin '~9 thru , ~. ,~, [10 & 13] 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. 8. . 10. 11. 12. 13. 14. 15. [lq- thru 22] (5) BOPE ~~./~'~. (, ~? -- ~. [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26 27. 28. [29 thru 3]~] 30. 31. (7) Co__Dn_tact.~32~__~[~ 32. (8) Addl ~.~.~-/ ~'~3-~ 33. geology' engineering' Dp~ MTM,/A'F., RAD_i~ ¢ TAB~~,_Z ? rev 6/93 jo/6.011 Compan~ /~ Lease & Well YES NO Is operator the only affected party .................................. ~. REMARKS Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ntrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided .......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on (~m~~,~-surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ............... . ......................... Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE_attached .... Does BOPE have sufficient pressure rating -- test to ~0~~sig.. Does choke manifold comply w/API RP-53 (May 84) ........ ~ ............. Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntrnber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional remarks' INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE UM MERIDIAN' SMTC WELL TYPE' Exp/Dev ~ In j... Red r il 1 Rev