The URL can be used to link to this page

Home My WebLink About185-079 Imal ect Well History File' ge XHVZE This.page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing (done) RESCAN Well History File Identifier DIGITAL DATA [] Color items: [] Diskettes, No. [3 Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: /'('-(~ h I(~_~ J,~', NOTES: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: Scanning Preparation x30= + Isl -- TOTAL PAGES BY: BEVERLY ~ VINCENT SHERYL MARIA LOWELL DATE: ~/0~/S/ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE' ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' V~YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES ~ VINCENT S HERYL MARIA LOWELL D ATE:/,./~//~..~_./S! ~ B Y: BE V ERLY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIREO ON AN INDIVIDUAL PAGE BASIS DUE TO QUALFFY, GRAY$C.ALE OR COLOR IMAGES) NO NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: DATE: /SI Quality Checked (done) 10/25/02Rev3NOTScanned.wpd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. IWame of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory__ S~jraph~ _ Service_.X 4. Location of well at surface 1395' FNL, 4997' FEL, Sec. 12, T12N, RSE, UM At top of productive interval 1229' FSL, 1400' FWL, Sec. 12, T12N, R8E, UM At effective depth (asp's 498655, 6000260) At total depth 4320' FNL, 4126' FEL, Sec. 11, T12N, RSE, UM (asp's 494247, 5997337) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit '8. Well number 3H-07 9. Permit number / approval number 187-079 / 10. APl number 50-103-20079 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8620 feet Plugs (measured) true vertical 6207 feet Effective depth: measured feet Junk (measured) true vertical feet C:asing Length Size Cemented Measured Depth CONDUCTOR 115' 16" 22a sx AS I 115' S UR. CASING 3496' 9-5/8" 1100 sx AS III & 500 sx Class G w, 3572' P ROD. CASING 8534' 7" 30o sx Class G & 175 sx CS I 8610' True vertical Depth 115' Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description 'including volumes used and final pressure 14. Pdor to well operatioh Subsequent to operation 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations __X Representative Daily Averaqe Production .or Injection Data OiI-Bbl . Gas-Mcf Water-Biff Casing. Pressure Tubin.q Pressure Title Production Engineering Supervisor 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/. 'u,~'..~./'Z' ~ Jeff A. Questions? Calf Jeff Spencer 659-7225 Date ~--~ 2- ~! ~ ~ Prepared b~fFAobert Ch/f~tensen 659.7535 'J BFL Form 10-404 Rev 06/15/88 * SUBMIT IN DUPLICATE 3H-07 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Memorandum To: Re' State of Alaska Well File: <~ ~-~ -- ~ (.~r-~ c~ DATE Cancelled or Expired Permit Action EXAMPLE' Point Mclntyre P2-36AXX API# 029-22801-95 Oil and Gas Conservation Commission 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 ddll. 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 reddlls 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 APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (welibore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician · / '=/ ~ '¢~ .o ~¢,/ ~s-- -2_08 ¢..o.,,.d r~o,/: April 26, 1985 t,~r. David J. Oryall Vice President Alaskan Crude Corporation 550 W. Seventh Avenue, Suite 1600 Anchorage, Alaska 99501 Re: Epperson Knob Unit No. ! Alaska Crude Corporation Permit M.o. 85-7.9 Sur. Loc. 1395'S~ZL, 2467'E~.~, Sec. 30, T4S, R131~, SM. Btmhole Loc. S A M E Dear ~.~r. Oryall: Enclosed is the approved application for-permit to drill the above referenced well. , A complete set of drill Cuttings samples is required consisting of no less than four tablespoop, s of washed and dried cuttings for each 10, 20, or 30 foot interval of hole drilled, whichever interval is determined for sample collection. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. A complete mud log is required. An inclination survey is required as per 20 AAC 25.050(a)(2). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity sUrveys and dipmeter surveys. -~ · Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator s .~f~zce, Department of Fish and Game. Pollut.~on o~ any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ?4r David J Orv~. ] Epperson Knob Unit ~o. 1 -2- April ~ z.~, 1985 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. )~ere a diverter system is required, please also notify this office 74 hours brio to commencing equipment installation so that the Commission may witness testing b~fnre drilling below the shoe of the conductor pipe. In. the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly <yours, C. V. Chattert6n Chairman of Alaska Oil and Gas Conservation Co~nission be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. Mr. Bill H. Lamoreau× DESIGNATION'OF"OPERATOR The undersigned is, on the records of the State of Alaska, Department of Natural Resources, Division of Minerals and Energy Management, holder of State of Alaska Oil and Gas Lease ADL-319686, and hereby designates: ALASKAN CRUDE CORPORATION 550 WEST SEVENTH AVENUE SUITE 1600 ANCHORAGE, ALASKA 99501 as its operator and local agent, with full authority to act on its behalf in complying with the terms of the lease and regulations applicable thereto and on whom the authorized officer of the State of Alaska or his authorized representative may serve written or oral instructions in securing compliance with applicable regulations with respect to the portion of said lease covering lands described as follows: ADL-319686 TWP. 4S, RNG. 13W SECTIONS: 18, 19, 30 E/2 E/2 NW/4, S/2 SE/4, N/2 LOT 4, SW/4 LOT 4, NW/4 SE/4 SW/4 SEC. 31. This designation of operator is made subject to that certain Farmout and Participation Agreement between CITIES'SERVICE-and GRAND'-BANKS 'ENERGY'CO'MPANY dated Qctober'6, ~98't~,~ Also, this designation of operator is specifically limited to those lands described above and to any operations thereon. It is understood that this designation of operator does not relieve the Lessee of responsibility for compliance with the terms of the lease and the applicable regulations. It is also understood that this designation of operator does not constitute an assignment of any interest in the lease or the appointment of an agent to obligate the undersigned to any undertaking or agreement. In the case of default on the part of the designated operator, the Lessee will make full and prompt compliance with all regula- tions, lease terms, or orders of the authorized officer of the State of Alaska or his authorized designee. The Lessee agrees to promptly notify the authorized officer of the State of Alaska or his authorized designee of any change of the designated operator. DATED this 4th day of April, 1985 CITIES SERVICE OIL AND GAS CORPORATION ~'. T. Via'' ' --rren -- Attorney in Fact RECEIVED APR 0 9 A!ask~ 01t & Gas Cons. A~chorage STATE OF CALIFORNIA COUNTY OF KERN ss. THIS IS TO CERTIFY that on this 4th day of April 1985, before me. the undersigned, a Notary Public in and for the State of California, duly commissioned and sworn as such, personally appeared G. T. Warren, to me known to be the Attorney in Fact of Cities Service Oil and Gas Corporation, named in the within and foregoing DESIGNATION OF OPERATOR; and he acknowledged to me that he had in his official capacity aforesaid executed said instrument as the free act and deed of said corporation for the uses and purposes therein set forth, having full power and authority so to do. WITNESS my hand and official seal the day and year in this certificate first above writt~___..~_~~_.. NOtar~ PubliC in and for California RECEIVED APR 0 9 Alaska 0it & Gas Oons Or, remission ,a. nchora¢~-3 NORTHERN TECHNICAL SERVICES, INC, 750 WEST 2ND AVENUE, SUITE 100 · ANCHORAGE, ALA,SKA 99501 (907) 276-4302 March 18, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill Alaskan Crude Corporation Epperson Knob Unit No. 1 Gentlemen: On behalf of Alaskan Crude Corporation, we are submitting here- with three (3) copies of their Application for Permit to Drill the Epperson Knob Unit No. 1 exploratory well on the Kenai Peninsula. The following documentation is included as part of the application: 1. AOGCC Form 10-401 2. Summary Drilling Program ./ 3. Designation of Unit Operator 4. BOP and Diverter System Diagrams 5-. Location Plat 6. Filing Fee of $100.00 We understand a statewide drilling bond in the form of a $200,000 certificate of deposit (No. 0100000452) from Ranier Bank Alaska, Inc. is presently in place with the Alaska Oil and Gas Conservation Commission and that supporting documentation is in your hands. RECEIVED 2 o 985 Alaska 0il & Gas Cons, Corf~rnission Anchorage Alaska Oil and Gas Conservation Commission Page 2 Thank you for your consideration of this application. If you need additional information, please contact the undersigned, or Alaskan Crude Corporation at your convenience. Yours very truly, NORTHERN TECH~I~L SERVICES, INC. Robert C. Gardner Vice President RCG/vdh 529-001 Enclosures cc: Alaskan Crude Corporation RECEIVED STATE OF ALASKA ALASKA .~ ~L AND GAS CONSERVATION Ct-~. ,iMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ REDRILL~ ''~ DEEPEN ,'~ lb. Type of well EXPLORATORY DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE ~ STRATIGRAPHIC SINGLE ZONE ~ MULTIPLE ZONE 2. Name of operator Alaskan Crude Corporation 4. 1395' SN-L., 2467' EWL, Sec. At top of proposed producing interval Same At total depth Same . _ 5. Elevation in feet (indicate KB, DF etc.) ~ 1230 ft. KB Address 550 W. 7th Ave., Suite 1600, Anchorage, Alaska Location of well at surface 99501 30, T. 4 S., R. 13 W., SM. 6. Lease designation and serial no. ADL 319686 9. Unit or lease name Epperson Knob Unit 10. Well number 11. Field and pool Exploratory 12. Bond information (see 20 AAC 25.025) CD~ -0100000452, Type Blanket Surety and/or number Ranier Bank 13. Distance and direction from nearest town Nikolaevsk~ NW 1.2 miles 16. Proposed depth (MD & TVO) 11,000' ND & TVD fe~t 14. Distance to nearest property or lease line Lease Line to West 2467 feet 17. Number of acres in lease 2075.46 19. If deviated (see 20AAC 25.050) (Straight Hole) KICK OFF POINT feet. MAXIMUM HOLE ANGLE Amount $200,000 I 15. Distance to nearest drilling or completed well 8675 feet 18. Approximate spud date I I April 15, 1985 20. Anticipated pressures (Max.) 4820 o (see 20 AAC 25.035 (c) (2) 5368 psig@Gas tO .Surface * psig@ll.000 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole Casing 30" 24" 18 5/8" 16" 14 3/4" 10 3/4" 9 5/8" 7" 6 1/2" 4 1/2" CASING AND LINER I Grade Weight I !J-55 65# ~ 75# ij-55 51 # iN-80 26# !N-80 11.6# iN-80 22. Describe proposed program' Coupling Length !BTC 2D !BTC 450 IBTC 2400 BTC !9300 !8R 2000 SETTING DEPTH MD TOP TVD MD BOTTOM TVD Surface I 121 121 Surface I i450 1450 Surface ~ 2100 12100 Surface I i9300 i9300 i 9000 ~000 i11,000 ~11,000 QUANTITY OF CEMENT (include stage data) To Surface To Sur face To Su r face 500 sx Class "G" Cmt. vol. from caliper Log + 15% + 50sx. SEE ATTACHED SHEET - (Page 2) 23. I hereby certify that the foregoing is true~rld correct to the best of my knowledge David J"~'Y///~2-- *Pressures based on 0.483 gradient (normal gradient plus 0.023 safety factor) TITLE Vice President CONDITIONS OF APPROVAL DATEMarch 13, 1985 Samples required '¢ES ']NO Permit number APPROVED BY Form 10-401 Rev. 7-1-80 Mud log required ,:::~ s ~_NO Approval date Directional Survey required APl number ~YES ~O 5O- 231-20009 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE April 26, 1985 bv order of the Commission Submit in triplicate NIPPLE · . :-~ FILLUP LINE 20° 2,000 PSI ANNULAR PREVENTER ~\x~ \\ \ l ~ I : / / / / /// 20' x 2,000 PSI FLANGE ADAPTER FLANGE OR SPOOL AS REQUIRED 2' GATE VALVE 2° KILL LINE ~- DRILLING SPOOL 8" HYDRAULIC VALVE (OPENS AUTOMATICALLY WHEN ANNULAR PREVENTER CLOSES) 2' BULL I 00 DiVERTER LINES HAVE DOWNWIND DIRECTIONAL PLUG ~ I~/CS'G HEAD" ~ 2' BULL PLUG DISCHARGE CAPABILITY. i~:~; i : ,-.-r----__.________ 16' 75,f, J-55 ~ ~ BTC TO = 450' KB Diverter System for 16" Surface Casing. LOWLINE BELL~ . -~ FILLUP LINE I ZI' 20' 2.000 ~ANNULAR PREVENTER k\\\\ \ \ i I ~ / / / //// i- 2' GATE VALVE ~ ~ LINE 20° x 2,000 PS1 FLANGE 24° FLANGE 8= HYDRAULIC VALVE (OPENS AUTOMATICALLY WHEN CLOSES) CONDUCT'R PIPE ANNULAR PREVENTER TO NAT= DiVERTER LINES HAVE DOWNWIND DIRECTIONAL DISCHARGE CAPABILITY. 24' 65. J-55 BTC TO 80'-85' (GR) Diverter system for 24" conductor pipe TO ~EI~M~ D 8" BUTTERFLY VALVES (NORMALLY OPEN) VALVES LINKED THROUGH CONTROL UNIT SO ONE MUST BE OPEN AT ALL TIMES. TO BERMED STORAGE AREA NOTE FLUIDS TO BE DIVERTED DOWNWINO, AWAY FROM RIG BY CLOSING APPROPRIATE 8 INCH BUTTERFLY VALVE. WELLHEAD AND ANNULAR PREVENTER \ / / SCHEDULE 40 STEEL PIPE HYDRAULIC VALVE, NORMALLY CLOSED (OPENS AUTOMATICALLY WHEN DIVERTER IS CLOSED) / /'~ 12' DIA. CELLAR Diverter system layout. FILLUP LINE 5,000 PSi WP ANNULAR PREVENTER I 5,000 PSI W~ PIPE RAMS I I 5,000 PSI W~BLIND RAMS ~ FLOWLINE CHECK GATE GATE GATE H.C.R. VALVE VALVE VALVE ~ VALVE VALVE TO 5,000 PSI WP CHOKE MANIFOLD 5,000 PSI WP PIPE RAMS ['//×××/×//1:'*"-----'-----'-- ADAPTER FLANGE OR SPOOL AS REQUIRED SECTION ~_ B.O.P. Stack Configuration, 13-5/8" Triple Ram Stack with Annular Preventer. ~9 LEASE BOUNDARY T4S PROPOSED WELL LOC'N 0 1 2 $ 4mi. 1395' FNL .. I I PROPOSED EPPERSON KNOB UNIT WELL NO. I LOCATED IN THE NW 1/4, SEC 30, T4S, R13W, S.M. PREPARED FOR ALASKAN CRUDE CORPORATION PREPARED BY NORTHERN TECHNICAL SERVICES, INC. Anchorage, Alaska ALASKAN CRUDE CORPORATION EPPERSON KNOB PROSPECT KENAI PENINSULA, ALASKA DRILLING PROGRAM SUMMARY Exploratory Well: Epperson Knob Unit No. 1 Program Basis: A. Hole sizes and casing sizes 1. 30" hole: 24", 65%, J-55, BTC casing 2. 18 5/8" hole: 16", 75%, J-55, BTC casing 3. 14 3/4" hole: 10 3/4", 51%, N-80, BTC casing 4. 9 5/8" hole: 7", 26%, N-80, BTC casing 5. 6 1/2" hole: 4 1/2", 11.6%, N-80, 8-R liner. B. Casing Points 1. 24" Conductor @ ~ 120' KB 2. 16" Surface @ ~ 450'KB 3. 10 3/4" Intermediate @ ~ 2400'KB 4. 7" Longstring @ ~ 9,300' KB 5. 4 1/2" Liner @ ~ 11,000' KB Cemented to Surface 7" casing string will be set near the top of the Hem- lock formation and the length of the string will be modified to accomodate the geological conditions en- countered. C. Well will penetrate Hemlock formation. D. Hole will be drilled as straight hole. E. Maximum anticipated mud weight = 10.2 ppg to base of Hemlock format ion F. Preliminary estimated formation tops. Beluga: 3500' TVD Tyonek: 5700' TVD Hemlock: 9300' TVD Preliminary Program: · Auger 30" hole to ~ 90 ft (gr.)and run 24", 659, J-55, BTC casing. Cement casing to surface from the top with con- struction grade cement. Install 24" API 2000 flange on casing. · Resurvey location. Move in and rig up. Install 20" diver- ter system as shown on attached illustrations. Function test diverter and hydraulic value. Notify AOGCC suffici- ently in advance so their representative can witness test. · Drill 18 5/8" hole to approximately 450 ft. KB. No logs will be run in the 18 5/8" hole. a) Initiate mud loggers at surface. b) Use high viscosity spud mud (250-350 sec.) and maintain annular velocities in the 50 ft/minute range. c) Maximize use of solids control equipment. 4. Run and cement to surface 16" casing. a) Use Cold Set III slurry until cement returns to sur- face, then tail in with Cold Set II slurry. See detailed cementing program. b) Use stab-in float collar and float shoe. c) WOC as directed. · Nipple down diverter and cut off 24" conductor even with floor of cellar. Cut off 16" casing as directed and in- stall 16" API 2000 psi wp SOW casing head. · Re-nipple up 20" API 2000 psi diverter system as shown in attached illustration. Pressure test casing and test diverter as directed. a) Use 16" API 2000 x 20" API 2000 adapter spool b) Notify AOGCC sufficiently in advance of diverter test to allow representative to witness test. · Drill 14 3/4" hole to approximately 2400 ft. KB. Limit penetration to maintain mud weight in the 9.0 - 9.3 ppg range. a) Maintain viscosity in the 250 sec. range. b) Maximize use of solids control equipment. · At ~ 2400 ft condition hole and run wireline logs from TD to shoe of 16" casing a) Run 1: DIL/SP/GR combination tool. 9. Run and cement to surface 10 3/4" casing. a) Use Class "G" oilfield cement b) Use stab-in float collar and float shoe. c) WOC as directed 10. Nipple down diverter and land 10 3/4" casing using a 16" API 2000 x 10 3/4" API 5000 wellhead section. Test seal as directed. 11. Nipple up and test 13 5/8" x 5000 psi wp BOP stack as shown on attached illustration. BOP stack to consist of 2 sets of pipe rams, blind rams, drilling spool and annular pre- venter. a) AOGCC representative to witness test 12. Pressure test casing as directed. Drill out shoe of 10 3/4" casing and drill no more than 30 ft. of new hole. Make leakoff test. a) Use conditioned spud mud to drill out float collar, shoe jts and shoe. 13. Drill 9 5/8" hole to ~ 9300 ft. KB or other depth as directed. 9 5/8" hole will be drilled into a competent formation above the top of the Hemlock formation. a) Use low solids non-dispersed mud to approximately 4000 ft, and lightly dispersed mud thereafter. b) Maintain weiqht in the 9.0-10. 1 ppg range as hole con- ditions dictate. c. Maintain viscosity in the 36-46 sec range, above 4000 ft. and in the 33-38 sec. range thereafter. d) Control fluid loss to between 6 and 10 cc to approxi- mately 4000 ft and <6 cc thereafter e) Maximize use of sol ids control equipment. 14. At 9300 ft + (or other designated depth) condition hole and run wireline logs from TD to 10 3/4" casing shoe. a) Run 1: DIL/SP/BHC/GR b) Run 2: CST (optional) 15. Run and cement 7" casing. a) Use Class "G" oilfield cement. b) Use float collar and float shoe. c) Use top and bottom wiper plugs. 16. Land 7" casing in 10 3/4" 5000 x 7" 5000 wellhead section. Test seal assembly as directed. 17. Reinstall 13 5/8" 5000 psi BOP stack and test all BOPE. 18. Pressure test casing as directed. Drill out shoe of 7" casing and drill no more than 30 ft of new hole. Make for- mation competency test to pre-determined EMW. 19. Drill 6 1/8" hole to ~ 11,000 ft. or other depth as direct- ed. a) Use lightly dispersed weighted mud. Maintain weight in 9.6-10.1 ppg range as required by downhole conditions. _ - Maintain minimum 200 psi overbalance. b) Maintain viscosity in 33-38 sec. range. c) Control fluid loss to <6 cc. d) Maintain optimum solids control. 20. At ~ 11,000 ft (or other designated TD), condition hole and run wireline logs from TD to 7" casing shoe. a) Run 1: DIL/SP/BHC/GR b) Run 2: CNL/LDT/GR c) Run 3: CST 21. Based on log evaluation and shows of hydrocarbons, be pre- pared to run and cement 4 1/2" liner from TD with minimum of 300 ft. of lap into 7" casing. a) Use hydraulic liner hanger that will allow reciproca- tion while cementing. b) Cement volumes to be determined from caliper log + safety margin c) Use Class "G" oilfield cement blended with fluid loss and friction reducing additives. 22. A testing program will be provided based on known downhole conditions. Use annular pressure activated test tools. 23. Complete, suspend or abandon well as directed. This proqram is preliminary. A detailed drilling prognosis and operational plan will be issued prior to the start up of drill- ing operations. Notes: I · Ail BOPE equipment will be tested weekly, or more frequent- ly if required. · An inventory of barite and LCM will be maintained on loca- tion during all downhole operations. · Any kicks will be handled by established procedures· Drilling crews will be trained in these methods. Kick and BOP drills will be practiced at regular intervals and noted on tour sheets· Care will be exercised not to swab the hole. Scheduled mud weights will adequately control pres- sures presently known to exist in the area.~'~.~!i~,~~"~ ~" ~? 1,~.~ CHECK LIST FOR NEW WELL PERMITS Company ~/~/~---- ~ Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (z2 thru 8i (3) Admin ~--- ¥-%~9~ (i0 'an"~ '12) (13 thru 21) (5) (22 ' thru 26) · 2, 3. 4. 5. 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO Is the permit fee attached .......................................... Is well to be located in a defined pool ........... Is well located proper distance from property line Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ............... Can permit be approved before ten-day wait ........ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed .................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive, horizons ...................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ REMARKS Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~'OOd) psig .. ,~ Does the choke manifold comply w/API RP-53 (Feb.78) Is the presence of H2S gas probable ................................. __ Additional requirements .............................................. /~ Geology: 'EngiM.eering: WVA MTM HJH ~I~ JAL ' ' / rev: 03/13/85 ' 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE