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Home My WebLink About175-068Memorandum To: Re' State of Alaska Oil and Gas Conservation Commission Well File: r-~% -/~6~2)~ DATE Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX~API # 029-22801-95 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to 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 refiect 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 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 described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proDosals to drill or to deepen Use "APPLICATION FOR PERMIT-J' for such proposals.) OIL i--g GAS r-'] WELL I'"1 WELL OTHER 2, NAME OF OPERATOR St~andard 0t1' ~ ADDR~S OF OPERATOR P. O. ~x 7-839 ~o~e - . 4. LOCATION OF WELL At su~ace 2157' South & 355' ~st o£ ~ co~3e~ o£ Sect/on 3 13. ELEVATIONS [Show whether DF, RT, GR, etc.) 144' G.L. CheCk Appropriate Box To' Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 6. LEASE DESIGNATION ANO SERIAL NO. A-028997 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME ~ol~o~ma C~ee~ 9. WELL NO. 11-3 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T7N, Rgw 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE-PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Plans to drill SCU 11-3 have been ,cancelled. A~proprtate notation in next-Plan o£ Development will be made.. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side Seldotna Creek 11-3 Mr. R. )lcK'inley Area Engineer $~rd 0II Cooq~ny of California P. O. Box 7-8,~ Anchorage, A1.~ 99610 De~r Str: EnClosed Js the approved a~l.t_catlon for permit to drt11 the above referenced ~ell at a locatJ~ In Sectton 3, Township 7N, Range 9~, St.1. ~11 samples, core chips, and a mud log are not required. A directional survey is required. I~any 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 16.50.870 and the regulations premulgated there- under (Tl'tle 5, Alaska Aa~_lnlstratlve Code). Prior to cemmenctng operations you may be con~c-~ by the Habi.~t Coordinator's office, Department of Fish and Game... Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 .a~d. th~ regulations pr..omulga, ted thereunder (Title 18, Alaska Administrative Code, Chapter 70). and by the Federal Water Pollution Control Act, as ~. Prior to ~i~ operations you may be contacted by a representative of the Oepartamnt of Environmental Conservation. To aid us in scheduling field.work, we would appreciate your notifying this office within 48hourl after the well is spudded. We would also 1.ike to be notified so that a represen~ttve of the Otvision may be present to witness testing of' blowout preventer equipment before surface casing shoe is drilled. Page 2 No~r 10, 1975 The 10-3/4" caslng strlng !mst be pressure tested to 3000 pstg and the 7-5/8" castng st~leg must be pressure tested to 5000 pslg. Please nottfy t~ts offtce wtt~tn 48 boers after the well ts spudded. In t~ ~vent of suspeestoa or abaadonmnt please gtve thts o¢¢tce adequate advance eottftcatloa sa that ~e my hav~ a wttaess present. 'Enclosure cc: Oepartmat ot' Ftsh and Game, Habt.tat Sectton w/o eric1. Oepartmnt of Eavtremaental Conservatlon w/o or~l. Oeparment of Laber, Supervisor, Labor Law Compliance O~vlslon w/o eat1. Form 10-401 REV. 1-1-71 la. TYPE OF WORK b. TYPE OF WELL OIL WELL ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL r~ GAS WELL[ OTHER DEEPEN [] SINGLE ZONE 2. NAME OF OPERATOR Standard Oil Company of California, WOI, 3. ADDRESS OF OPERATOR P. O. Box 7-839; Anchorage;Alaska 99510 LOCATION OF WELL At surface 2157' S & 355' E of NW corner of Sect. 3 At proPOsed prod. zone 1000' S & 900' E of NW corner of Sect. 3 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 15 miles SUBMIT IN TRIP. . fE (Other instructions on reverse side) MULTIPLE ~ ZONE [__] AP I#50-133-20282 6. LEASE DESIGNATION AND SERIAL NO. A-028997 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Soldotna Creek 9. WELL NO. 11-3 10. FIELD AND POOL, OR WILDCAT Swanson River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T7N, R9W 12. 14. 15. 18. BOND INFORMATION: Statewide ~}~862 TYP~qatlonwlGe. Surety and/or No; DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 3 500 ' + (Also to nearest drig, unit, if any) DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 144' G. L. 16. No. OF ACRES IN LEASE 1.920 19. PROPOSED DEPTH 11,100'+ 100,000 Amount 150 · 000 17. NO°ACRES ASSIGNED TO THIS WELL 80 (approximately) 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 12/5/75 23. ~r PROPOSED CASING.AND CEMENTING PROGRAM SIZE 'OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement t~,, , G%-" &v *We propose to drill a new oil producing well:per the' attached program. Request for Administrative Approval was submitted on 10/31/75. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. (Tiffs space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES /~NO DIRECTIONAL SURVEY REQUIRED ~q(ES [] NO DATE CONDITIONS OF APPROVAL, IF ANY: ~TLE Area Enqineer MUD LOG ~N [] YES O OTHER REQUIREMENTS: SEE TRANSMITTAL LETTER A.P.I. NUMERICAL CODE o'-o-/,.q$-,Zozg EERMIT NO. q'~-~'-'~ ~ g / APPROVAL DATE November 10,1975 T~TLEEXecutive Secretary D~TE November 10, 1975 nstruction On Reverse Side PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM Field: Swanson River Property and Well: Soldotna Creek Unit 11-3 Surface Location: APProximately 2070' south and 305' east of northwest corner of Section 3, T7N, R9W, SB&M, at the.existing surface pad for SCU 12-3. · Proposed Bottom Hole Location (At H8 Target): Approximately 1000' south and 900' east of northwest corner of Section 3, T7N, R9W, SB&M. Elevation: 144' G'.L.; estimated 162I' K.B. (Brinkerhoff #59 Rig). Blowout Prevention Considerations: 1.' Potential Problems: A. Gas and Water Entries: Gas sands may be encountered at any depth below the shoe of the surface casing although no gas entries were experienced in surrounding wells. Wells 43A-4, 44-4 and 13-3 experienced severe water entry problems. SCU 43A-4 had an entry at 8942' while drilling with 96 pcf mud '-and necessitated increasing the mud.weight to 102-103 pcf. SCU 44-4 had water entries at 9110' while drilling with 93 pcf mud and at 10,020' with 96 pgf mud. SCU 13-3 had ~as ~ut mud whil~ drilling at 9188'+ with 94 pcf mud, lost 300 bbls mud at 9213'+ .and the well flowed at 9253' with 95 pcf mud. Major water entry in 11-3 is expected at 9100' +50'. Caution shoUld be exercised not to swab the hole on trips. Gas and water entries can cause severe problems, and the mud System should be carefully monitored at all times. B. Lost Circulation: Circulation was lost at '6567' in well 43-4 while drilling with 96 pcf mud. In the same well 100 barrels of mud were lost at 7315'. In SCU 43A-4 circulation was lost at 9138' when mud weight had been increased to 101 pcf to combat water entries. Losses occurred in SCU 44-4 while drilling at 9252' and again at 10,020 with 97 pcf and 102 pcf mud, respec- tively. SCU 13-3 lost 300 bbls of mud at 9213'+. Lost circu- lation has occurred in other SRF wells while drilling the Hem- lock with +98 pcf mud. In SCU 11-3 casing will be cemented above the Hemlock zone before mud weight is reduced to penetrate the objective interval. Precautions: Any kicks should be handled by our normal proce- ~dures. Drilling crews should be made aware of these methods. C~r~ should be exercised at all times, but especially not to hydraulic the formation and lose circulation while running in the hole nor swab the hole while pulling. An adequate supply of W~ght and lost circulation material should be at the well site at all times. Keep hole full at all times. Proposal for Well Operations PRO 316-1 Drilling Program Well 11-3 2. Maximum Anticipated ~Formation Pressure: 4500 psi at -10,300' vss datum (H10) 3. Maximum Anticipated Surface Pressure: 3800 psig . 'Blowout Prevention Equipment 1. Class III, 5000 psi on 10 3/4" and 7 5/8" caSing. 2. Install and test per "Operating Instructions D-17." Estimated Depths and Correlations: Estimated Estimated Mark6r Drilled Depth Vertical Depth Estimated Subsea Depth H1 (Top Hemlock) H4 (Base H5 Sand) Top H8 Sand Base H8 Sand (Target) Total Depth 10,745' 10,452' -10,290' 10,885 ' 10,592 ' -10,430 ' 10,920' 10,627' -10,465' 10,980' 10,687' -10,525' 11,094' 10,787' -10,625' PROGRAM 1. Drive 18" conductor pipe to +80' or as deep as possible during rig up. 2. Drill 15" hole to 3400'+.~ Maintain drilling fluid per the attached drilling fluid program. 3. Cement 10 3/4", 40.5#/foot; K-55,. buttress casing at 3400'. a. Use float shoe and stab in duplex collar two joints up. b. centralize the casing above the shoe. c. Cement through the shoe in one stage as follows: 1. Use sufficient Class "G" cement premixed with 2.4% gel by weight of water to obtain cement returns to surface. Basis: Yield of Class "G" + 2.4% gel by weight of water = 1.86 ft. 3/sk. 2. If cement returns are not received at the surface, do a top job. Proposal for Well 2erations PRO 316-1 Drilling Program Well 11-3 d. Have stage collar on location in case lost circulation occurs while drilling top hole. 4. Cut off 10 3/4", 40.5#/ft., K-55 casing below the top of the cellar (ground level) to allow the top flange of the tubing head to be above ground level after completion. 5. Install 10" 5000 psi, 10 3/4", SOW casing head. Test welded lap to 2500 psi +. 6. Install Class III, 10" 5000 psi BOPE as per the attached BOPE design. Test BOPE, kill line, blow line, and manifold to 2500 psi per "'Operating Instructions D-17." 7. Drill out the cement in the 10 3/4" casing with a 9 7/8" bit to within 10' of the .shoe. Pressure t.~ the 10 3/4" casing to not over 2500 psi. If test is okay, drill out the 10 3/4" shoe. 8- Drill a 9 7/8" hole to a true vertical depth of 10,452', estimated 10,745' MD, estimated top of 'the Hemlock sands as follows: a. Follow mud specifications per the attached mud program. Major water entry is expected at 9100' +50'. Take single shot surveys to the estimated KOP at a minimum of ~very 480'. Should conditions warrant, reduce the survey inter- val to every 240' or less. Always take a survey on a dull bit. c. B~ginning at approximately 7600', or as required, KOP, build 2°/100' to 28° along course of N 25° 13 E; section is approxi- mately 1400'. Hold angle to TD. Target is the base of the Hemlock No. 8 sand at a location approximately 900' east and 1000' south of the northwest corner of Section 3, T7N, R9W. d. MaLntainmud weight of 96-98 pcf below 8900' vertical depth. 9. At effective depth, condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run the following Schlumberger logs: a. Dual Induction - Laterolog from ~rilled depth to the shoe of the 10 3/4" casing. Use linear scale for the 2" = 100' and logarithmic scale for the 5" = 100'. Use 10+ MV SP scale and 0-50 ohm-meters for the linear resistiviyy scale. b. Be prepared to run FDC-CNL and sonic logs if DIL indicates presence of shallow productive sands. · · 10. Drill ahead as indicated by log run to set 7 5/8" casing ,shoe at the top of the Hemlock (H-l). 11. Cement 7 5/8" casing at the top of the Hemlock as follows: Proposal for Well Lperations PRO 316-1 Drilling Program Well 11-3 a. Bottom 4,720' 33.7# P-110 Buttress Next 1,900 '. 29.7 # N-80 Buttress Next 4,045' 26.4# N-80 Buttress Top 80' 33.7# P-110 Buttress 'Total: 10,745' NOTE: For deeper TD add 26.4#, N-80 Buttress as required. Casing program based on pipe availability, which exceeds design criteria. b. Run differential fill-up shoe.and collar. c. Run stage coliar at approximately 7900'. d. Have triplex shoe on the location in case it is necessary to set the 7 5/8" casing above the drilled depth. e. Centralize the bottom 700' as well as above and below the stage collar at 7900'. f. cement in two stages using Class "G" cement mixed with 2.1% gel by weight of.water as follows: 1. Shoe Job - Use sufficient cement-gel mix to reach 8700'+. Stage Collar - Use sufficient cement-gel mix through collar at 7900' to lap the 10 3/4" casing at 3400'+. 12. Remove BOPE and land the 7 5/8" casing. Install a 10" 5000 psi bottom flange x 10" 5000 psi top flange tubing head. Test seCondary packoff to 5000 psi. Install 10" 5000 psi BOPE. Test BOPE to 3000 psi per "OperatL~g Instructions D-17." 13. Drill out cement and stage collar and clean out to within 10' of the 7 5/8" shoe. 14. Run Variable Density-Cement Bond Log from the effective depth to above the top of the cement from the stage collar job. 15. Based on CBL, squeeze for WS0 above the Hemlock as required. 16. Pressure test the 7 5/8" casing to 3000 psi. 17. Condition mud weight to 72-74 pcf. (73 pcf mud provides a hydrostatic ~ressure of 5272 psi at 10,400' VD versus 4300 psi est. reservoir pressure and 5424 psi at 10,700' VD versus 5000 psi reservoir~pressure. Proposal for Well Operations PRO 316-1' Drilling Program Well 11-3 Drill a 6 5/8" hole to true vertical depth of 10,787', estimated 11,094' MD. Maintain nitrate concentration of 100 ppm to aid in possible test of the H-10 sand. 19. Condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run and tape the following Schlumberger logs: a. Dual Induction - Laterolog from TD to the shoe of the 7 5/8" casing. Use same scales as before. b. SP~BHC Sonic from TD to the shoe of the 7 5/8" casing. Compensated Neutron-Density Log. 20. Condition hole for 5 1/2", 20# Buttress liner. Cement approximately 550.' of 5 1/2" liner at TD as follows: a. Run Float shoe and float collar. Do not use centralizers. Allow for approximately 200' of lap below the liner hanger. Use sufficient Class "G" cement trea~ed with 3/4% CFR-2 to reach to above the top of the liner. Mix a heavy slurry to 118-122 pcf. 22. Clean out cement to the top of the float collar. Run Variable Density Cement Bond Log from effective depth to above top of the liner hanger. 23° Pressure test the 7 5/8" casing, 5 1/2" liner, 7 5/8" x 5 1/2" lap to 3000+ psi using the rig pumps. 24. Jet perforate selected Hemlock 8 sand intervals for production. Use 3 3/8" OD carrier guns loaded with four 1/2" holes per foot. 25. Run tandem casing scrapers and scrape the entire 5 1/2" liner. 26. Run and hydrotest to 5000 psi~ approximately 11,000' of 3 1/2" x 2 3/8" tttbing and gas lift mandrels. Run 2 3/8" OD tubing and jewelry in the 5 1/2" liner. A detailed completion program will be provided after TD logs have been run. 27. .Remove BOPE and install xmas tree. Pressure test tree to 5000 psi. Displace the drilling fluid down the annulus and up the tubing string using lease crude oil. .. Proposal for Well Operations PRO 316-1 Drilling Program Well 11-3 28. 'Set the production packers and release the rig. Place the well on production as directed by the Production Foreman. I. J. Epperson o/s OCT ~ Area Engineer O/SAr e~rv ii'so r~~ NEW WELL NO. SCU 11-3 DRILLING FLUID PROGRAM SWANSON RIVER FIELD BASIC DRILLING FLUID SYSTEM Slightly treated lignosulfonate mud. OPTIMUM DRILLING FLUID PROPERTIES Mud Properties (Vertical' Depths) (1) (2) (3)* (4) 10 3/4" Shoe - 6500'- 7 5/8'.' 7 5/8" Shoe - 0- 3,400' 6500' Casing Point T.D. Weight - pcf Max. 75# pcf Viscosity - sec/qt., API As Required Fluid Loss - CC, API Plastic Viscosity - CPS Yield Point - lb./100 ft.2 ' Gel - lb./100 ft.2 - 10 min. pM Calcium - PPM Solids Content - % Vol Diesel Oil - % Vol 72 - 80 88 - 100 72 - 74 40 - 70 40 - 70 40 - 70 15 max. 15 max. 7 max. 22 max. 30 max. 22 max. 10 - 20 5 - 20 10 - 20 5 - 15 8 max. 5 - 15 8.5 - 10.8 8.5 - 10.8 9.2 - 9.8 80 max. 80 max. 50 max. 18 max. 25 max. 16 max. 5-7 5-7 5-7 · 1. Drill top hole to 3,400'+ with salavaged mud, if available. 2. Convert top hole mud to gel mud while drilling from 3~400' to 6,500'. At 6,500' start to increase weight and have mud properties as listed in Column No. 3 at 7,000'. 3. Use lightly treated lignosulfonate mud below 6,500'. 4. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 5. Maintain an adequate supply of lost circulation material at the rig. ., · -- 6. Make a high pressure - high temperature fluid loss determination while drilling Hemlock. Make fluid loss tests at estimated bottom hole temperature 170° F. NOTE: Major water entry is expected at 9100' to 9250' based on observations at 43A-4, 44-4 and 13-3. Ensure mud weight of 96-98 pcf prior to leading this depth. P OPOSAL FOR WEL PERATIONS PRO-316-A (TO BL JSED A G0-111) CASING REQUIREMENTS AND PRODUCING EQUIPMENT WE LL/LOCATION NO. SCU 11-3 DATE October 3!~ 1975 FIELD Swanson River ESIIMATED SPUD DATE D~ce~ber 5~ 1975 TOTAL DEPTH 11,094 METHOD OF PRODUCTION Gas Lift MAX. ESTIMATED SURF. PRESSURE 3800 PSI ESTIMATED O/W/G .... / / EQUIP. FOR STEAM INJ.- PRODUCER X CASING Gross Footag.~ APl Size Weight Grade Threads Coupling Computer Design For: Conductor 80 ' 18" 104 B Line Pipe 0. 562" Wall This Well rq Standard Design For Field r-J Surface . 3400' 10 3/4" 40.5 K-55 Buttress Well No. rq Requires: Float shoe, stab-in duplex collar and stage collar w/buttress Max. Drift Angle ° Thrds; 15 - 10 3/4" x 15" centralizers, 2 - 10 3/4" stop rings, Baker Loc. Water String: Design based on mud density 95 tbs./cu, ft. and above max. surf. pressure 4800 ' 1900 ' 4045' Cementing Ac ~C~oZ~ ~e~- Liner 550' 7 5/8" 33.7 P-110 Buttress 4 X-overs 7 5/8" 29.7 N-80 Buttress 25 9 7/8" x 7 5/8" central. 7 5/8" 26.4 N-80 Buttress 25 Stop rings. 7 5/8" x 33.7# P-110 Model G differential fill-up shoe and collar; stage collar and plugs for stage cementing. 5 1/2" 20 N-80 Buttress Hanger 5 1/2" 20# Buttress x 7 5/8" 33.7# P-110 burns plain liner hanger grooved for cementing; float shoe, collar, plugs and centralizers. ' Perforated ', to ', Mesh, Rows, Slots,. Centers, CASING } UNITIZED HEAD: 5000 PS! CWP. Bottom Conn. 10..3/4 SOW, Type KD Top Conn. 10" 5000 RJ Vl ang~_ ", 2 '~ 2 Fittings 1 - Screwed 3000 psi WOG valve, bull pluq on other side CASING SPOOL MC MUC .qcrew~ outlets TUBING HEAD 5000 PS! CWP. Bottom Conn. 10" 5000 psi RJ Flange, type 59L Top Conn. 10" 50009 RJ Flanqe ", 'Type Suspension Chaffer 59L 3 1/2" Buttress up and down full bore: bored for 3 1/2" TUBING Feet , 600' Tubing Catcher APl Size Weight Grade Threads Type 2 3/8" 4.7 N-80 8RD EUE Bottom ARMCO SEAL LOCK Next 10,400" 3 1/2" 9.3 ARMCO Seal Lock 19 - 3 1/2" Buttress x " ~ 1/9" ,, , 11,000 3 - 2 3/8 Otis "S" N~'pl~s A O e 1 Lock Total' ~ - ~ ~//~'"' BakerCamc° MMGFH PackersMandrels(20~)w/R-20 valves 2 - 2 3/R" Brown CC... Jointq 1 - 2 3/8" Camco "D" Nipples 3 - 2 3/8" Ot,,is "XA" Sleeves 120' 2 ~t81'~s~a~r Blast Joint 3 062" · type. " . ' Csg. Size "x " Type with "stroke at # wt. Other Fittings 2 Arm Remarks (Cr.oss-overs, etc.) 1 2 3/8" N-80 EUE x 3 1/2" PSi CWP. Dwg. No. AP-C-174-0 and AP-C-175-0 Type l - 3 ,, 5000 psi Willis Type 1 Bean PSI CWP. Dwg. No. Type. Polished Rod "x Type Packer with XMAS TREE 3 " Tubing Beans Header Stuffing Box PUMP: RODS: Grade , PUMPING UNIT. APl Size Engine #t , ' of .... of "' Type _ Max. Stroke "Set at Motor HP Remarks Type at ' Long "Stroke and SPM Prepared By OCT 8 ~ ';'5 R~iNi ---IJE? 10/31/75 Area Supervisor, .Sr. Drlg. Engineer. Approved by Drlg. Supt. PRO-316-A (CD-1-75) Printed In U.S.A, · . ..'. o. · . . . . . ,,~TOP HEM E.I~. LOCK... I0. SAflD .I 0,'~ 0'_ 'i ..... .... ~ . . _ .-- lES L:O0 OF SCU 44-4 - SHO~'ING PROPOSED COMPLETION INTERVAL FOR SCU ll-,-t' NEV~ V~ELL TO /5, CCOMPANY PRO 316-1 · .. JUNE 19'75 Fi(:; 3 ~ i $OLDOTNA ~.~. lC EEI 10406' "' ' T. 8 N. Rg'w. 3III' II,m~mmmmm I ImImImmmmmmmm mm)m~m ~ UNIT m D 34 ,oso~' / -10607 -10448' il OLE LOCATION I m ! ! ! ! ! 3 ! I .! I I III IIl~ i ! PORTION OF STRUCTURE CONTOUR MAP SWANSON RIVER FIELD, ALASKA 'CONTOURS ON THE BASE H8-9 SAND SHOWIN~ ESTII~ATED GAS SWEEP PATTERN THE 'PROPOSED SCU 11-3LOCATION TO ACCOMPANY PRO 316 SE.RIE-S :-' I~IOV. 1975 TO iO~" S,LAF~CR KD S.O.W. CSG. HD. 10" 50OO~ TOP FLG.. ~ith Tv/O SCD. O.L. B:JLL ?LU3 2"Y. XH x ~" LONG SCREWED 2" 3000# VALVE ~IT'H PULL PLUG. SHAFF~LH TUBING HEAD wi[h TWO STUDDED OUTLETS, 5000# 10~" MUD Q~OSS ~ith 10" 5000# FLANGE TOP '& BOT£OM, with T~O .:3" STD. OUTLETS. Ill I I I _~ I Ill~II - -. 1 ! . ' . . ,4"x .r,~ ' ~ · . . . . .. 7 2" x 3" 5~ ADAPTOR ' 8 . (4) 3" 5~ VALVES - T~O EACH-S~E ~D "X" ~ TU~' R . SHAFFER ~D~ULIC ~PE ~S 10" ~,~ BBL.' P~NT~ 10 ~IL T~P~ "Gl" 10" ~0~.~ B~WOU7 P~ENT~.- · "S.C:.U. ,. ~ . CHECK LIST FOR NEW WE'LL PERMITS - Company a , Yes No Remarks 1. Is the permit fee attached · · .............. >.t~ _ Lease & Well No. ~~, //-~' 2. Is well to be located in a defined pool ............... 3. Is a registered survey plat attached ................ 4. Is Well located proper distance from property line ......... 5. Is well located proper distance from other wells .......... 6. Is sufficient undedicated .acreage available in this pool ...... 7. Is well to be deviated ....................... A/~a/( 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day wait ............. ~ O. Does operator have a bond in force ................. 1. Is a conservation order needed ............. ...... 2. Is administrative approval needed ................. 3.' Is conductor string provided .................... 4. Is enough cement used to circulate on conductor and surface ...... 5. Will cement tie in surface and intermediate or production strings 6. Will cement cover all known productive horizons .......... 7. Will surface casing protect fresh water zones ........... 8. Will all casing give adequate safety in collapse, tension & burst 9. Does BOPE have sufficient pressure rating ............. ~dditional Requirements' }~_~ ..... ~:~ ~o,~--'- f~ t~,~-:-:,~,~ ~ ~,':~:'~' ~- ~' , ?~ :ooo,:~,' Geology Engineering' ~_,~9 ~-~ ,, ,~ ~ ~ ,,~- ~ ~' ~TRM~~HWK ~ OKG HHH ~ -- :' ' / ~ Revised 1/15/75