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165-004
PLUGGING & LocATioN. CLEARANCE REPORT State of Alaska : . ~. · · Memorandum TO File': .ALAS.KAOIL &~AS'CONSERVATION COMMISSION . Lease , API No. "~ ~ - I oo~- ~o Well Name.' ~_~-'43-1'1 . . .. . .. · Location .,,',_Se.z. I~ -~"['~i%~ - F..o~v~ PTD NO. b~-~oo ~ Abnd Date · Spud: 4 ]~'!~g ., '" TD: '~eO:. , · Completed · . Note casing size, wt, depth, cmt vol, '&.procedure. ' . .. . ~ . . . . . Liner. ~ . Perf intervals - 'toPs:' Review the well file, and--comment on plugging, well head status, and loCation clearance - provide loc. clear, code. . , .. ,-/~.~ ~ o.~ .~ c.?~ ~1 '~,,+$~-'. ' .. . . . . Well head Cut off= Marker ~ost or plate: LocationClearance= ~A ConclusiOns: Code Date x--",, STATE. OF ALASKA '"-'" ,~.,..,&SKA OIL AND GAS CONSERVATION CON .... ','SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well o, n s .w n 2. Name of Operator 7. Permit Number Shell Western E&P Inc. 65-4 / 95-079 3. Address (WCK 6265) 8. APINumber P.0. Box 576, Houston, TX 77001-0576 5o- 733-10082 4. Location of well at surface 9. Unit or Lease Name PLATF A, LEG 1, COND 3, 1628' FSL & 430' FEL Sll, T8N, RiL~,J~[~.~,~~ MIDDLE GROUND SHOAL At Top Producing Interval,~CI~~ 10. Well Number NA ~ A43-11 At Total depth ~ 11. Field and Pool 9840' MD, 9791'. TVD; 1855' FSL & 1055' FEL Sll, T8N, R13~ 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial N~ MIDDLE GROUND SHOAL 116' KBI ADL 18754 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband.115. Water Depth, If offshoreI 16. No. of Completions 4-4-65, 6-3-65 5-15-95I 80 feet MSL'1 SINGLE i7. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey. 120. Depth where SSSV set I 21. Thickness of Permafrost 9840' HD; 9791' TVD 6797' MD: 6790'~'vj) YES [] NO I-'I 1~-6 SSSV Ca 340 feetMDI N/A 22. Type Electric or Other Logs Run NA 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SiZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 24" CONDR 0 319' 650. SX - - - 13-3/8" 54.5~f J-55 0 1609' 18-1/2" 1925 SX - - - 7" 29~ N-80 0 8798' 9-7/8" 1500 SX - - - 24. Perforations open to Production (MD + TVD of Top and Ek)ttom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 0RIGINAL DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7296' - 8296' CHT PLUG - 87 SX CI.ASS G 27. PRODUCTION 'TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NOV 08 1995 Na$~ 0it .& Gas Cons. Commission, --'-, ~ch0rage Form 10-407. Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - 49- 29. 30. GEOLOGIC ,~KERS FORMATION TESTS Include interval tested, pressure dat&, all fluids recovered and gravity, GOR, NAME MEAS. DEPTH TRUE VERT. DEPTH and time of each phase. GM 7250' 7242' GN 7263' 7254' GO 7288' 7279' GR 7605' 7593' GS 7663' 7645' HC 7887' 7874' HD 7967' 7948' HE 8025' 8011' HF 8050' 8036' HI 8120' 8106' IlK 8158' 8144' HN 8314' 8298' - 31. LIST OF: ATTACHMENTS MORNING REPORTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge L~..//~/r~/t~.x~.~v ~'~.~%~r~ G. S. NADY TiUe MGR. - ASSET ADMIN. Date 10/30/95 Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL.) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. SWEP/~'~'ASKA DAILY DRILLING REPORT RlC-NAME PLATFORM "A" ~'I' MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A43 - 11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: RUNNING IN HOLE W/6" WHIPSTOCK PROG. DEPTH 10040 PRESENT DEPTH 6797 FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE 05/16/95 DIST. KB TO BHF 38.4 DAY 5 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 769 __ LAST BOP TEST 05/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HR.g) PP1% KILL SPEED ~ PP2 · KILL SPEED · SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 FINISHED TIH W/CASING SCRAPER ASSMY T/7100'~ TOP OF 5" LINER. 1.00 CIRC HOLE CLEAN W/INLET WATER. (PUMPED ALL RETURNS DOWN DISPOSAL WELL) 1.50 POH W/SCRAPER ASSMY. REPAIR IRON ROUGHNECK, BROKEN ELECTRICAL WIRE IN CONTROL BOX. FINISHED POH W/SCRAPER ASSMY. LAY DOWN MILL/SCRAPER. MAKE UP 2 7/8" MULE SHOE, TIH W/18 STDS 2 7/8" TUBING BELOW DRILLPIPE. TAGGGED TOP OF HARD CEMENT AT 7437'. (SET 10K WEIGHT ON CEMENT) MAKE UP TOP DRIVE, CLOSED PIPE RAMS. TEST CASING T/2300 PSI Fl30 MINS. HELD OK. .50 2.00 3.00 1.00 1.50 POH W/DRILL PIPE'T/TBG X-O. 1.50 LAYED DOWN TBG (54 JTS) CEMENTING STINGER. 6..50 RIG UP SWS. RAN BAKER CIB ON WIRELINE. SET PER CCL AT 6797'. POH/RD. MAKE UP WEATHERFORD 6" WHIPSTOCK{ ANADRILL ORIENTING SUB~ INSTALLED ANADRILLMWD IN NM FLEX COLLAR~ SURFACE TEST MWDi OK. TIH AT REPORT TIME. (WE ARE CHECKING EACH TOOL JOINT FOR WEAR AND HARDBAND CONDITION 3.50 _ WHILE TIH AND RECORDING THE CONDITION AND JOINT LOCATION IN STRING) NOTE: BAKER CIB IS SET 6' ABOVE A CASING COUPLING LOCATED BY THE CCL. (COUPLING IS AT 6803') TIME (HRS} CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING 13.50 C&C 1.00 REAMING SURVEYS JET REPAIRS .50 FISHING NIP UP/DOWN /BOP/WT{ __ TESTING BOP /WH 1.00 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 1 . 50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 6.50 · ' SWEP~ASKA DAILY DRILLING REPORT ~, PAGE 1 OF 1 R~a NAME PLATFORM bi ) MIDDLE GROUNDSHOAL LEASE PLATFORM "A" WELL A43-11LW WORK ORDER 728520 SIDE TRACK PROG. DEPTH 10040 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD /.__ DAYS +/- DAYS SINCE LAST LTA 767 LAST BOP TEST 05/14/95 LAST CSG TEST DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: COMPLETE BOP TEST /GALLOWAY DR S{Y OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 COMPLETE RIG UP pROCEDURES OVER A43-11LW. BHA INSPECTION (CUM. ROT HRS) PPl ~ KILL SPEED PP2 ~ KILL SPEED 1.00 HELD PRE-JOB SAFETY MEETING. INSTALLED TWO WAY CHECK IN TBG HANGER. REMOVE SAFETY VALVE AND PRODUCTION CHOKE. M/U LANDING JT TO ND TREE. .50 UNABLE TO WORK TREE LOOSE WITH PULLS UP TO 120,000#. M/U OBSTINATE TREE REMOVAL BHAi X-OVERt 1 JT HWDPt FISHING JARSr 1 - 4 3/4 DCt ACCELERATOR, AND 1 JT HWDP. JARRED TWICE ON TREE WITH PULLS OF 85r000 TO 95t000#. TREE CAME FREE ON SECOND JARRING LICK. L/D JARRING EQUIPMENT. HELD PRE-JOB SAFETY MEETING. N/U BOP'S AND RELATED EQUIPMENT. PERFORM SUCCESSFUL BOP TEST. PREPARING TO POH WITH PRODUCTION 2.50 11.50 6.00 EQUIPMENT AT REPORT TIME. NOTE: RECOGNITION TO THE AIT TEAM FOR HAVING THE FORSIGHT TO _ ANTICIPATE THE POSSIBLE PROBLEM WITH THE WELLHEAD TREE AND/OR TUBING HANGER AND HAVING THE PROPER EQUIPMENT ON LOCATION AHEAD OF TIME. THIS ACTION SAVED CONSIDERABLE TIME AND MONEY. THANKS GUYS ..... 9~/14/9S 3 TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/W}{ 11.50 TESTING BOP /WH 6.00 RUNNING CASING CEMENTING PICkUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN 2.50 WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 4.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 10040 9 MIDDLE GROUND SHOAL PRESENT DEPTH LEASE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V /GALLOWAY DR PRESENT ACTIVITY: RIH WITH SCRAPPER ASSEMBLY ELEVAT. KB TO MSL 116.0 DATE ~ DIST. KB TO BHF 38.4 DAY 4 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 768 LAST BOP TEST 05/14/95 LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 % KILL SPEED · PP2 % KILL SPEED e .. SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.00 REMOVE BPV. M/U LANDING SUB AND PULL TBG HANGER AND LINER SEAL ASSEMBLY FREE. CIRCULATE BOTTOMS UP. 6.50 POH LAYING DOWN PRODUCTION EQUIPMENT. 1.50 SET WEAR RING AND M/U MULESHOE ON 18 STDS 2 7/8. 3.00 RIH WITH 3.5 DRILL PIPE AND CEMENT STINGER. TAGGED UP AT 8296'. COULD NOT WCRK DEEPER. 2.00 ATTEMPTED TO BREAK CIRCULATION AT 8296'. DRILLPIPE WAS PARTIALLY PLUGGED. PULLED UP HOLE TO WORK PLUG FREE. RETURNED TO 8296' AND BROKE CIRCULATION. CIRCULATED BOTTOMS UP. 1.00 HELD PRE-JOB SAFETY MEETING. RU HOWCO. BROKE CIRCULATION AND PUMPED 30 BBLS FRESH WATER AHEAD OF CEMENT. MIXED AND PUMPED 87 SX'S CLASS G CEMENT WITH .25% CFR-3e 1 GPS HALAD 344Le AND .15% HR5. FOLLOWED CEMENT WITH 10 BBLS FRESH WATER AND 39 BBLS FIW TO PLACE ON SPOT. CEMENT PLUG SHOULD BE IN PLACE FROM 8296-7296'. RD CEMENT LINES. 2.00 POH WITH 15 STDS DRILLPIPE AND CIRCULATE BOTTOMS UP TO CLEAN HOLE. 2. O0 CHECK FLOW AND POH WITH ASSEMBLY. 1.50 CUT AND SLIP 100' DRILLING LINE AND SERVICE TOP DRIVE. 1.00 M/U 6" MILL AND 7" CASING SCRAPPER ASSEMBLY. ~0 RIH WITH CASING SCRAPPER AT REPORT TIME. TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING 13.50 C&C 4.00 RF_AMING SURVEYS REPAIRS FISHING NIP UP/DOWN /BOP/WH __ TESTING BOP /WH RUNNING CASING CEMENTING PICkUP/LAY DOWN DS 3.50 INSPECT BHA RIG UP/TEAR DOWN 1.00 WAIT ON WEATHER/MAT __ EVALUATION CORING OT~ERS 2.00 SWE("-'~LASKA- DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" ) MIDDLE GROUND SHOAL L~-~5E PLATFORM "A" WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 10040 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 /GALLOWAY DR PRESENT ACTIVITY: RIGGING UP ON PLATFORM ELEVAT. KB TO MSL 116.0 DATE 05/12/9~ DIST. KB TO BHF 38.4 DAY 1 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 765 LAST BOP TEST LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 · KILL SPEED · PP2 ~ KILL SPEED · SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 PREPARED FOR BOAT CALLOUT. UNLOADED BOAT AND TOOK ON DIESEL FUEL DURING DAY. COMPLETED RIG SKID OVER LEG #1 ON PLATFORM. WELD BEAMS BACK ON PIPE RACK. SET MUD LINES AND CLEAN PITS. R/U ELECTRICAL CABLES IN TRAYS TO RIG AND OTHER ASSOCIATED ELECTRICAL EQUIPMENT. INSTALL FRESH WATER LINE TO RIG. M/U STEAM LINES. HANG 10" FLOWLINE MANIFOLD BETWEEN RIG AND MUD PUMPS. HANG LINES FOR CHOKE FLOWLINES AND WATER RE/URN LINE. PREP TO HANG MANIFOLDS. CLEAN FLOWLINE TO SH~RS. CONT. RIG UP PROCESS. NOTE: TO AlT MEMBERSi IT'S TIME TO INVOICE FOR HS&E SAFETY BONUS FOR A24-01LE. ANOTHER GOOD~ SAFE, JOB GUYS!!! TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C &C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH__ TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 24.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 10040 ~ MIDDLE GROUND SHOAL PRESENT DEPTH ~ .~E PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V /GALLOWAY DR PRESENT ACTIVITY: RIGGING UP ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 766 LAST BOP TEST LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PPl ~ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 COMPLETE CONSTRUCTION OF CHOKE MANIFOLD. INSTALL ALL SAFETY BOOMERS ON FLOWLINES. FABRICATE NEW 6" WATER RETURN LINE FROM RIG. SET ALL HANDRAILS AND V DOOR. SET SLOP TANK IN WELLEEAD ROOM. M/U VALVES ON MUD CROSS. HAND WATER LINES. FABRICATE AND HANG 4" CHOKE LINE TO 6" LINE. HANG BUFFALO FAN IN PITS. PREPARING TO NU BOP AT REPORT TIME. 05/13/9~ 2 TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING 24.00 SWEPI,_LLASKA DAILY DRILLING REPORT RIG NAME PLATFORM "A" PROG. DEPTH 10040 D MIDDLE GROUND SHOAL PRESENT DEPTH L~,,~SE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V /GALLOWAY DR PRESENT ACTIVITY: RIGGING UP PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE 05/11/95 DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY __ LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 764 LAST BOP TEST 05/11/95 LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED · PP2 ~ KILL SPEED ~ S~Y OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : RIG ACCEPTED ON A43-11LW 12:00 P.M. 5/10/95. 18.00 REMOVE AND SECURE ALL RIG ASSOCIATED EQUIPMENT IN PREPARATION FOR RIG PLATFORM MOVE. SKID RIG OVER PLATFORM #1 WHILE CLEARING DECK AHEAD OF IT. ALIGNED RIG OVER A43-11LW AND RIGGED UP ALL DRILLING EQUIPMENT IN PREPARATION FOR WORKOVER/DRILLING. PREP. TO BEGIN OPERATIONS, DURING RIG MOVE SLICKLINE UNIT RIH AND PULLED GLM #6. CIRCULATED HOLE WITH FIW IN ATTEMPT TO KILL WELL. TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CIL~ING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 18.00 NOV 08 1995 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend After casing . Repair well Change approved program Operation shutdown .. Re-enter suspended well Plugging Time extension Stimulate.. Pull tubing Variance Perforate Other 2. Name of Operator Shell Western E&P Inc. 3. Address ~-~U~ (~l~ P.O. Box 576, Houston, TX 77001-0576 5. Type of Well: Development X Exploratory Stratigraphio Service 4. Location of well at surface 1628' FSL & 430' FEL Sll, T8N, R13W, S.N. At top of productive interval 8314' HD-KB, 8298' TVD-KB; 1707' FSL & 782' FEL 511, TaN, R13W, $.H. At effective depth 8700' HD-KB, 8675' TVD-KB; 1735' FSL & 857' FEL Sll, TaN, R13W, S.H. At total depth 8798' HD-KB, 8771' TVD-KB: 1744' FSL & 878' FEL Sll, T8N, R13W, S.H. 6. Datum elevation (DF or KB) 116' KB feet 7. unit or Property name HIDDLE GROUND SHOAL 8. Well number A43-1! 9. Permit number 10. APl number so- 733-10082 11. Field/Pool NIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measured 8798 feet Plugs (measured) true vertical 8771 feet Effective depth: measured 8700 feet Junk (measured) true vertical 8675 feet Casing Length Size Cemented Measured depth Structural Conductor 319' 24" 319' surface 1609' 13-3/8" 1925 SX 1609' Intermediate Production 8798' 7" 1500 SX 8798' Liner 1635' 5" 126 SX 7100' - 8735' Perforation depth: measured 8314' - 8609' true vertical 8298' - 8587' Tubing (size, grade, and measured depth) 2-7/8', 6.5~, N-80 EUE 81~ g 7184' HD-KB Packers and SSSV (type and measured depth) TIH SEN_ UNIT ASSEHBLY g 7113' HD-KB True vertical depth 319' 1609' 8771' 7093' - 8709' RECEIVED APR 2 4 1995 At~ska 0il & Gas Cons. C0mmissi0n Anchorage 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation MAY 1, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (?, ~,,~3/,~_,¢~ ,,'//~7'/ G. $. N~Y Title I~-ASSET ~HIN. / [, - ~' /~'~" ! FOR COMMISSION USE ONLY Date 4/17/95 Conditions of approval: Notify commission so representative may witness Plug integrity ~ BOP Test ,"" Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Original Signed By David W. Johnston Approved Copy Returned Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE A43-11 ABANDONMENT PROCEDURE 1. Move to A43-11 (leg 1, conductor 3) and rig up. 2. Kill well. Test casing to 2,000 psi. 3. Nipple up 5,000 psi BOP stack and test. 4. Pull tubing and completion equipment. 5. GIH w/tubing and cement retainer. 6. Set cement retainer at 8,270' (44' above top of existing per~orations). 7. Spot a cement plug from the top of the retainer to 300' above the retainer. (Cement plug from 8,270' to 7,970'.) POOH. 8. GIH w/scraper for 7" and tubing stinger and tag the cement top. APR 2 4 199,5 Oil & Gas Cons. Commission Anchorage Shell Western E&P Inc.O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 March 18, 1991 Alaska Oil and Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen- SUBJECT' SUBMISSION OF THE REPORT OF SUNDRY WELL OPERATIONS MIDDLE GROUND SHOAL WELL NO. A43-11 Enclosed in duplicate is the report of Sundry Well Operations for MGS Well No. A43-11. The workover included a coil tubing unit acid treatment. Operations were completed February 21, 1991. If you have any questions, please call Ms. Susan Murnan at (907) 263-9614 or Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures AOGCC~SUNDRY.DOC STATE OF ALASKA A~ ~ OIL AND GAS CONSERVATION COMMI,. .,ON REPORT OF SUNDRY WELL OPERATION 1. OCerations performed: Operation shutdown Pull tubing ~ __ Stimulate X Plugging__ Perforate__ Alter casing__ Repair well __ Other 5. ]ype ct Well: 2. Name of Operator Shell Western E&P Inc. Development X 3. Address 601 West 5th Avenue, Suite 810 Exploratory~ Anchorage, AK 99501 Stratigraphic Service 4. Location of well at surface Conductor 3, Leg 1.1,630' FSL and 430' FEL of SI~ Corner Sec. 11, T8N, R13W. At top of productive interval 1,708' FSL and 782' FEL of SE Corner Sec. 11, T8N, R13W At effective depth At total depth 1,736'-FSL and 857' FEL of SE Corner Sec. 11, T8N, R13W 1,878' FSL and 1,085' FEL of SE Corner Sec. 11, T8N, R13W 6. Datum elevation (DF or KB) 116 DF feet 7. Unit or Property name Middle Ground Shoal 8. Well Number A43-11 9. Permit number/approval number 65-4/90-592 10. APl number 50-733-10082-00 11. Field/Pool Middle Ground Shoal/"G" Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner 10,038 feet true vertical 9,984 feet measured 8,700 feet true vertical 8,675 feet Length Size Plugs (measured) Junk (measured) Cemented 1,609' 13-3/8", 54.5#, J-55 1,925 sx 8,798' 7", 29#, N-80 1,500 sx 1,635' 5", 18~, N-80 126 sx Measured depth True vertical depth 1,609' 1,609' 8,798' 8,771' 7,100'-8,735' 7,093'-8,709' Perforation depth: measured 8,314'- 8,609' true vertical 8,298' - 8,586' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 EUE @ 7,814' Packers and SSSV (type and measured depth) 20' PBR with tieback receptacle on top of liner @ 7,100' 13. Stimulation or cement squeeze summary Jet Wash and Acid Squeeze Treatment Intervals treated (measured) F/8200' T/8645',F/8609' T/8234 Treatment description including volumes used and final pressure 78 bbls 7.5% HCL Acid, ISIP = 1975# 14. Prior to well operation Subsequent to operation OiI-Bbl Shut-In 98 Representative Daily Averaae Production or Iniectior~ Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 0 253 770 90 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run I I Oil X.~_ Gas__ Suspended__ Service Daily Report of Well Operations 17,"'1 hereby certify that the toregoing~'true and correct to the best of my Knowledge ~igned ~' ~'' Title . Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DATE 2/20/91 2/21/91 DAILY REPORT OF OPERATIONS A43-11 DESCRIPTION Rig up coil tubing unit on well. Start filling back side with fresh inlet water. PSI test lubricator/CTU to 5000# for 5 minutes. Test double check valves - OK. RIH with jet wash nozzle at 0.5 bpm, 1800#. Tag and wash through bridge, at 8000~. Tag hard scale at 8237~. Wash with jet nozzle T/8241~. Thaw out fluid lines to Howco pump and manifold. Blend 8000 gals of 7.5% HCL per prog. specs. Spot 10 bbls HCL at EOT, soak and wash down with acid F/8241~ T/8250~. Hard scale indicated not economic to acid wash. Pump 5 bbl XCD Polymer sweep to displace suspended solids. POH while "chasing" sweep to surface. Rig up and operational test Drillex I 11/16" motor with side ported sub and tapered mill. Test BOPE and lubricator. RIH w/Drillex motor and tapered mill while pumping at .5 bpm (below SSSV nipple). Tag scale at 8241~, mill hard pack scale or other material through top perforations T/8365~. Mill soft "bridge" scale through second perforated interval. Mill and wash through "fill" scale F/8565~ T/8699~ (PBTD). POH T/Tailpipe at 7184~. Make repeat run through interval back to 8699~ to confirm clear bore. Mix up and prepare to pump XCD Polymer sweep to clear hole of suspended solids. Other: Pump 20 bbls of diesel into surge tank #1 to begin demulsification of "sludge" material. Tag top of fill at corrected depth of 8678~. Mix and pump.5 bbls of XCD Polymer sweep. POH while "chasing" sweep, direct sweep to surge tank. Rig down Drillex motor and tapered mill. Pick up 2.0" jet wash nozzle. Pressure test BOPE. Pump/transit down and encounter slight bridge at 8200~. Jet wash F/8200~ T/8645~, unable to wash beyond this point. Per prog. item #15, #18, repeat #15 and #18: Pump a total of 50 bbls of 7.5% HCL acid. Begin with a 6 bbl soak and 30 minutes through perforated interval and observed top of scale. Proceed with acid jet wash at 1 bpm and hoisting speed of 20 fpm F/8609~ T/8235~. RIH and locate jet wash nozzle at 8609~. Pump 6 bbls HCL acid and soak interval for 30 minutes. Proceed with acid jet wash at I bpm and hoisting speed of 20 fpm F/8609~ T/8235'. RIH to 8645~ and follow immediately with 7 bbls XCD Gel sweep. 031491A Displace and isolate in surge tank 54 bbls of low pH fluid. Begin acid squeeze per prog. item #20: Locate nozzle at 8609~. Shut-in well, pressure test coil tubing and production tubing at 2200#, monitor annulus to confirm TBG/Annulus integrity. Open well, fill CT with 22.6 bbls HCL acid, shut- in well, pump 11.2 bbls additional HCL acid. Pump 62 bbls fresh inlet water to over displace and squeeze acid to formation. Max squeeze pressure was 2800# at a rate of I bpm. ISIP = 1975#, FSIP = 50# in 40 minutes. Rig down coil tubing equipment. Begin move to leg #2, A42-11. Operation released to A42-11 coil tubing job at 2200 hrs, 2/21/91. Other: Blend contents of surge tank #1 and pump to production. Pump 700 bbls of completion fluids to production at various intervals. 031491A August 2, 1990 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Lonnie Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Smith' SUBJECT: RE-SUBMISSION OF THE APPLICATION FORMS FOR SUNDRY APPROVALS MIDDLE GROUND SHOAL WELLS NO. A13-O1L AND A43-11 Per my August 1, 1990 conversation with John Boyle of AOGCC, please find enclosed the above referenced sundry approvals submitted on actual AOGCC forms. The entire packets, with forms and back-up information, have been re-submitted in triplicate in the event AOGCC has need for them. I apologize for any inconvenience caused your office. Certainly you can understand our desire to use computer generated forms as a time and energy saving device. Perhaps you could advise as to what is necessary in order to make our computer generated forms acceptable to the AOGCC. Si nc/ejrel y, Val 3ones Sr. Clerk /vj Enclosures cc' W. F. Simpson, Manager Regulatory Affairs, Shell Western E&P Inc. S. B. Brown-Maunder, Environmental Technician, Shell Western E&P Inc. ~AOGCC\080290. DOC ~ Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 July 27, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT: SUBMISSION OF THE APPLICATION FOR SUNDRY APPROVALS MIDDLE GROUND SHOAL WELL NO. A43-11 Enclosed in triplicate is the Application for Sundry Approvals for well No. A43-11, Middle Ground Shoal. The surface location is Platform A, Leg 1 Conductor 3. Estimated date for commencing operation is August 1, 1990. If you have any questions regarding this report, please contact Paul Huckabee at (907) 263-9646 or Val Jones at (907) 263-9614. Very Truly Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/PTH/VYJ/vj Enclosure R' CEIVED ~AOGCC\072790. DOC STATE OF ALASKA ALAS~., OIL AND GAS CONSERVATION COMIV~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [~ Pull tubing [] Amend order [] Perforate [] Other [] Name of Operator SHELL WESTERN E&P INC. Address 601 West Fifth Avenue~ Suite800~ Anchoraqe~ AK 99501 Location of well at surface - Conductor 3, Leg 1. 1,630' FSL and 430' FEL of SE Corner Sec. 11, T8N, R13W At top of productive interval 1,708' FSL and 782' FEL of SE Corner Sec. 11, T8N, R13W At effective depth 1,736' FSL and 857' FEL of SE Corner Sec. 11, T8N, R13W At total depth 1,878' FSL and 1,085' FEL of SE Corner Sec. 11, T8N, R13W 5. Datum elevation (DF or KB) 116' 6. Unit or Property name Middle Grgund Shoal 7. Well number A43-11 8. Permit number 65 -4 9. APl number 50--7~l)-10082-00 10. Pool Middle Ground Shoal, "G" Pool feet 11. Present well condition summary Total depth: measured true vertical 10,038 feet Plugs (measured) 9,984 feet Effective depth: measured 8,700 feet Junk (measured) true vertical 8,675 feet Casing Length Size Cemented Structural Measured depth True Vertical depth Conductor Surface 1,609 ' Intermediate 13-3/8",54.5#,J-55 1,925 sx 1,609 ' 1,609 ' Production 8,798 ' 7" ,29#,N-80 Liner 1,635 ' 5" ,18#,N-80 Perforation depth: measured 8,314' - 8,609' true vertical 8,298' - 8,586' Tubing (size, grade and measured depth) 2-7/8", 6.5#, N-80 EUE ~ 7,184' Packers and SSSV (type and measured depth) 20' PBR with tieback receptacle on top of liner @ 7~100' 12.Attachments Description summary of proposal [] 1,500 sx 8,798' 8,771 ' 126 sx 7,100'-8,735' 7,093'8,709' Detailed operations program X[~ BOP sketch [] 13. Estimated date for commencing operation August 7, 1990 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,-//~~, ~ Title Manac, ier Alaska Operations ~,~ · ' r/ Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Returneo " ----~issioner ORIGINAL~, SIGNED BY LONNIE ~, SMITH Date 8/1/90 I Approval No. ¢ (~ _ .~_.- ~'c~-- by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate MIDDLE SROUND SHOAL WELL No. A43-11 COILED TUBING ACID TREAT PRESENT STATUS: Well producing from HN-HR and HR-HZ. Last Test 7/03/'90; 16 BO?D - i$ BW?D Acid soluble scale tagged 5/05.'90 ~ ~278' (36' above top peri ~ 8314'). OBJECTIVES: Coiled Tubing Unit Acid Treatment -o remove scale fill and damage. CURRENT PERFORATIONS: HN-HR HR-HZ 8314' - 8356' + 8420' - 8454' 8534' - 8565' + 8578' - 8609' RECOMMENDED PROCEDURE 1. SI gas injection. Close crown valve. RU Slickiine Unit to .recover SSSV. Test lubricator to 3500 osi. RIH and retrieve ~ Otis Bail Valve from XEL nipple at 299' PCOH. RD Slickiine. 2. Hold safety meeting with Arctic Recoil ant other oiatform personnel to discuss the proposed operations and concerns with H2S during acidizing operations. 3. RU Arctic Recoil CTU with CTU assist oumo. 7esr CTU stack to 5000 psi. 4. Call out 36+ bbis 7-1/2~ HCL via Dowe!i-ScniumOerger {D-S) with the following additives: - 0.4~ A-250 Corrosion Inhibitor, - 0.5~ W54 Non-Emulsifying Agent, - 0.2% F?5N non-Ionic Surfactant, - 20#/lO00gal L-58 iron sequester'nc 5. RU circulation (reverse and conventiona- , return line manifold to allow injection of NALCO Visco 3631 H2S scavenger into the return fluids at (or near) the wellhead. 6. RU return line manifold to take returns zo an enclosed, isolated tan~. In the returns tank, add 5 gals D-$ D47 Ant/foam additive per !000 gallons of tank capacity ~DC ~I©T put this ~dditive in the acid system to be pumped downhole! . . MIDDLE GROUND SHOAL No. A43-11 COILED TUBING ACID TREATMENT 7. RU Filtered Inlet Water (FIW) source line to access FiW downstream of CUNO cartridge filters. NOTE: Be prepared to blend in 0.5% CaC12 to all FIW water while pumping. RIH with 1-i/4" coiled tubing with standard wash nozzle to the top of fill (~ 8278'). Clean out fill to PBTD at 8700'. Blend in 0.5% CaCi2 to ail FiW water while pumping. 9. Mix and pump/circulate a 5 bbl HEC polymer pill to clean up the weiibore. POOH. !0. RiH with "jet wash:' nozzle on 1-1/4" coiled tubing perforation @ 8609' . NOTE: Coiled tubing length = !2500' 1-1/4" coiled tubing capacity = (1.124 bbis/'1000~:~':~:[:~00' = 14.05 bbls Annular capacity to 8609' = 53.82 bbis 5:' csg capacity across perfs = (8609'-8314')~0.0177 bbl/ft = 5.22 bbis 11. Reverse 6 bbis 7-1/2% HCL to the end of the coiled tubing (EOT) to cover the interval from the bottom perforation @ 8609' to above the scale fill top @ 8278'. SD pump and let acid soak for at least 30 minutes. 12. Continue in hole to PBTD. Mix and pump/circulate a 5 bbi HEC polymer pill to clean up the wel!bore. Monitor return fluid for H2S and treat with NALCO Visco 3631 as needed. Take returns to an isolated tank to neutralize return acid. Add D-S D47 Antifoam additive to the returns tank as needed To prevent foaming overflow. 13. PU to 8609'. Pump/circulate, while reciprocating coiled tubing, to jet wash the perforations from 8609' - 8314' with 10+ bbls Doweil 7-1/2% HCL to remove perforation damage. Take returns to an enclosed, isolated tank. Monitor return fluid for ~23 and treat with NALCO Visco 3631 as needed. Displace wash acid from the wellbore. Ensure acid is spent/neutralized before sending to the production facilities. Refer to Attachment No. 1 for guidelines on return fluid handling. 14. Spot circulate 14 bbls 7-1/2% HCL (with above additives) to the EOT % 8609. Close annulus and pump/squeeze 6 bbls additional acid followed by 39 bbis FIW (+ O.5% CaCl2) into the perforations at a pressure not to exceed 2500 psi surface pressure with an acid hydrostatic. Do not exceed 3000 psi surface pressure with a FIW hydrostatic. MIDDLE GROUND SHOAL No. A43-11 COILED TUBING ACID TREATMENT NOTE: PumD acid at the maximum rate possible without exceeding - the pressure constraints. NOTE: The FIW volume has been calculated To overdispiace the perforations with 20 bbls FIW. 15. POOH. RD D-S. RD CTU. Open well to production. 16. RU Slickline Unit. Test lubricator to 3500 psi. RIH and install Otis Ball'Valve in XEL nipple at 299'. POOH. RD Slickiine. 17. After well performance stabilizes, production test well via the test separator. PTH 7/26/90 /~u Recommended: & o Concurred · ~ . . ~L work ph # 263-9646 home ph # 344-5857 Approved: Date: cc: ANCHORAGE Manager Alaska Operations - R. G. Blackburn Division Drilling/Production Engineer - V. E. Unger Kenai Production Office - B. N. Osborn Platform "A" Operations Foreman - R. V. Hi!i, J. W. Landess/Tracy Environmental Technician - S. S. Brown-Maunder Anchorage Engineering File Room - Category 16) HOUSTON WOODCREEK C. M. Kidwell - WCK 1178 R. G. Lippincott - WCK 1140 S. M. Logan - WCK 1162 E. W. Kitchen - WCK 1136 ORIGINAL TO: Woodcreek File Room - WCK 4100 MIDDLE GROUND SHOAL No. A43-11 COILED TUBING ACID TREATMENT ATTACHMENT NO. I PROCEDURES FOR HANDLING BACKFLOWED AND CIRCULATED FLUIDS All backflowed and circulated fluids must be routed through the test separator prior to being sent to the Onshore Facility for discharge. Emulsion breaker should be added as required. Bottle testing is recommended to determine the concentration of breaker. Monitor fluids for H2S and add appropriate scavenging chemicals as required. Note: Ensure any acid treatment fluids that are circulated or backflowed are neutralized prior to sending to the production separator. To satisfy EPA requirements, if the amount of fluid exceeds 2§0 bbls at one time, the Onshore Operator must take samples of all completion and/or well treatment fluids at the onshore discharge line. Samples must be sent to C&G labs in Anchorage for oil/grease and pH analysis. The Onshore Operator should label samples with description of fluid and date, such as: "Fluid returns from A43-11 acid treatment - 8/xx/90". Notify Onshore Operator when the fluid is being sent. Use the following calculation to'determine when the samples need to be caught. Pipeline Delay = "A" Pipeline Capacity (bbl) Gross Daily Prod "A" (bbl) + Workover fluid slug (bbl) x 24 hfs = hfs Onshore Facility Delay = 1000 bbl Gross Daily Prod "A", "C", and "Baker" (bbl) x 24 hfs = hfs Total time between slug shipment and s~mple time = hfs NOTE: The Onshore Operator should be notified and instructed to divert the transfered fluid to the holding tanks. This will allow dilution of the workover fluid prior to processing through the pl an t. COMPLETION EQUIPMENT DETAIL SHEET MGS A43-11 6/25/87 NO ITEM ,, APPROXIMATE TVD. MD. PSI OR 1. OTIS XEL LANDING NIPPLE 2. CAMCO KBMG.#1 3. CAMCO KBMG #2 4. CAMCO KBMG 5. CAMCO KBMG #4 6. CAMCO KBMG #5 7. CAMCO KBMG 8. CAMCO KBMG #7 g. TIW LOCATOR SUB 10. TIW SEAL UNIT ASSBqBLY 11. OTIS "X" NIPPLE 12. 2 7/8" MULESHOE 299 299 1914 1914 890 3/16 3489 3489 890 3/16 4803 4804 885 3/16 5681 5684 930 1/4 6378 6383 930 1/4 6776 6782 925 1/4 7053 7060 OR 5/16 7089 7096 7105 7113 7144 7152 7176 7184 CASING 13 3/8", 54.5#, J-55 @ 1609' w/1925 sx 7'" 29#, N-80 @ 8798' w/1500 sx 5" 18/f, N-80 FL4S LINER @ 7100-8735' w/126 sx (20' PBR WITH TIEBACK RECEPTACLE ON TOP) PBTD : ~ ~?00~ TD = 1~-;038' TUBING 2 7/8", 6.5#, N-80 EUE @ 7184' PERFORATED ZONE GROSS INTERVAL HN-HR 8314-8356' HN-HR 8420-8454' HR-HZ 8534-8565' HR-HZ 8578-8609' 10 11 12 Shell Western E&P Inc. O 601 West Fifth Avenue * Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson: In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following: location surveys showing the location of Platform A list of conductor/well locations (in relation to the SE corner of Sec. 11, TSN, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion RepOrt and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\06 ! 190. DOC RECEIVED JUN Alaska Oil& Gas Cons. tlnchora~ HIDDLE GROUND SHOAL P1 atform "A" WELL/CONDUCTOR LOCATIONS ~- Center of Leg 1 Ca 1627'N & 435'W from SE corner of Sec.11, TSN, R13W, S.M. '~ A 12-01 1 A 11-01 2 A 43-11 3 A 34-11 4 A 34-14 RD 5 A 22-14 6 A 12A-01 7 A 13-01 8 1632'N & 437'W from SE corner 1632'N & 432'W " " " 1630'N & 430 W 1625'N & 430 W 1622'N & 433 W 1622'N & 437 W 1625'N & 440 W 1630'N & 440 W II II II II II II II II II II II II II II II I! II II Leg 2 - Center of Leg 2 @ 1681'N & 372'W from SE corner of Sec. 11, T8N, R13W, S.M. A 42-11 9 A 44-O2 10 A 42-14 11 A 41A- 11 12 A 11-12 13 A 11-13 RD 14 A 31-14 15 A 44-11 16 1685'N & 374'W from SE corner 16 85' N & 370' W " " " 1683'N & 368'W " " " 1678'N & 368'W " " " 1675'N & 371'W " " " 1675'N & 375'W " " " 1678'N & 378'W " " " 1683' N & 378'W " " " Leg 3 - Center of Leg 3 @ 1620'N & 321'W from SE corner of Sec.11, T8N, R13W, S.M. Le9 4 - Center of Leg 4 @ 1566'N & 383'W from SE corner of Sec.11, T8N, 'R13W, S.M. A 33-11 25 A 14-01 26 A 12-12 27 A 24-01 28 A 13-12 29 A 33-14 30 A 41-11 31 A 23-01 32 1571 1571 1568 1564 1561 1561 1559 1569 N & 388'W N & 385'W from SE corner N & 381'W " " " N & 378' W " " " N & 378'W " " " N & 381'W " " " N & 385'W " " " N & 388'W " II :i E£EIVED JUJ, i 1 1990 ~laska Oil & Gas Cons. commission Ancl~o~a~ · ~ .'"-f'fi'h'"g;~l."'i',-'~.. ~ ........... · : · · · · ' ADL 18754 : , .... · ; ..... , . · .... ·, ,,, , 9 I0 ~* ~. " II " '" 12 : · LAT. 60e47' 44.808" ; ,~t, II . LONe. ,Ss° 2~' 44.005' i -/q ?//47'F'O/?A!_,t~~LOC/4r!o//.~ 1' :: STATE (;;qlO COORO. ' . , ' ' ,~'......o.....eol ZO;tE 4 ....... ..~ ......... _ ................ ............ _ . .... . ...... I$ IS 14 13 I1 ! . · ' ~ ~' i · ,. .~. II t2 Z3 .' . ~4 19 ~0 . . ~ .' f-- ,-'. - ......... .. . ' ' .......... ~ .... ~ : .. :~. LOC~TION OF ~ -~JU~ 19[::[) SE~ CONTAINED DRILLING ~,l~a, ~ii I Gas Cons. t ~mmission P R 0 O U C ~ N 0 P L,', T F 0 R M T 8 N S.M. , N~chora~ ~ SHELL. MIDDLE GROUND SHOAL 4 ~ T 7N S.M., ~ , ~ PLATFORM A m COO)< INLET. ALASKA ! 4003' eGGo ,2oo0 APPLIC~.TION BY eaHF..LL OIL CO. .... ; .......... '' LOS ANG[LES, CALIFORNIA T. 8N. R 13W. S M 5 2 ' ' ' ' ' II II 14 I ADL 18754 t I0 LEG NO. I.,~x~3'' ~0~¢~/,.~- 4 2 I II 12 14 LEG NO. I -- X = 232~78 3 Y = 2~485,845 1627' I'i IA 435'W FROM THE SE COR. OF SEC. II, TSN, RI3W, SM. LEG NO. 2 LEG NO. 3 PA Afl£ X = 232,846 Y = 2,48 5,897 C 00t?D/N,~ X= 252~896 Y = 2,485,8:55 PUBLIC /.,4 ND 1681' N D, 37Z' W FROM THE SE COR. OF SEC. II, T8N, RISW, SM. DESCI~IP 7~/ON 1620'N 'B~ :321' W FROM THE SE COR. OF SEC. II, TSN, RISW~ SM. LEG NO. 4 X = 2 32,835 Y =2,485,783 1566'N I~ 383'W FROM THE SE COR. OF SEC. II, TSN,RI3W, S.M. LAT.- 60o47'44.839" LONG.- 151° 29'45. II 2", G£O D E T'I C CO0/?D IlV/~ TE LAT. - 60°47'45.368'' LAT. - 60°47'4q. 768" LONG.-151°29' 43.942" LONG.-151°29' 42.'899" LAT.- 60°47'44,244" LOt,IS.- 151° 29' 44.154" Shell Western E&P Inc. A Subsidiary of Shell Oil Company P.O. Box 576 Houston, TX 77001 June 18, 1987 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99510 Attn: John Boyle Dear Mr. Boyle: SUBJECT' DATA TRANSMITTAL FOR MIDDLE GROUND SHOAL FIELD COOK INLET, ALASKA We 11· j) '~ ~-IJ,~ ~?i~$~ [/.,/ (.." ~/' Work Order No. Enclosed you will find data pertaining to the Middle Ground Shoal Well 1 isted above. Please return a signed copy of this transmittal letter to acknowledge recei pt. C. C./q~i 11 iams A1 as a~9~/Division Shell Western E&P Inc. CCW:mh Enclosure Received by: CRCT8701303 SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECTION DATE :February 9, 1987 COMPANY :Shell Western E&P Inc. LEASE : WELL NO.:A43-11 API ND. :50-733-10082 FIELD :Middle Ground Shoal STATE :Alaska COMMENTS: Sample Depth Grain Density No. ft gm/cc ~mmmmmm~mmmmmm~mmmmmm Atm Air Porosity Permeability % md 1 8281.0 2.637 11.8 NT 1-1 8281.0 2.633 10.4 NT 2 8282.5 2.636 10.1 NT 2-1 8282.5 2.635 10.8 NT 3 8505.0 2.636 7.01 NT 3-1 8505.0 2. 639 7.17 NT 4 8509.5 2. 646 11.2 4.43 4-1 8509.5 2. 647 11.2 4.22 Grain density determined by Archimedes principle . RECEIVED JUL 1 ~' ~ '~ --' 1-,8/ Alaska Oil & 6as Cons. Cornmissio'n Anchorage 1000C SHELL DEVELOPMENT COMPANY~- PETROPHYSICAL SERVICES SECTIG,, STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 4500 PSI ,~ , , I o 1000 ' . ~ ,, , ,, '~ .... ~ ......... 100 90 80 70 60 50 40 50 20 10 0 MERCURY SATURATION - % PORE VOWME OccUPIED DATE : FEBRUARY 20, 1987 COMPANY; SHELL WESTERN E4cP INC. LEASE : WELL NO'. A45-11 APl NO: 50-75~-10082 FIELD : MIDDLE GROUND SHOAL ~"rA~ ~, Aa A~fA SAMPLE NO. ; 2-1 LAB NO. : A-4987 DEPTH (Irl~ t 8282.5 ATM POROSITY : 10.8 · GRAIN D[HSITY : 2.835 GM/CC SHELL DEVELOPMENT COIdPAN'-~ PETROPHYSICAL SERVICES S£CTI~,,I STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 4500 PSI rI I I I II i ° c L ! ..,.. ~ ~ 1000 : ,i :r , ' ' ::::::) 100 ' : " ...... ,. , 1.2. >.. , -I -.. ....... ~.. ~ · ry. L ~,, i 10 ~- .- ~ .......... __ 1 · , · _ · · 1 100 10 1 0.1 MERCURY SATURATION - % BULK VOLUME ocCUPIED DATE : FEBRUARY 20, 1987 COMPANY: SHELL WESTERN E&P INC. LEASE : WELL NO: A4&-11 APl NO: 8o-7&3-10o82 HELD : MIDDLE GROUNO SHOAL _qTiTir : Al SAMPLE NO. : 2-1 LAB NO. : A-4967 DEPTH cfr) : 8282.5 ArM POROSITY : 10.8 X GRAIN DENSITY : 2.635 GM/CC SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECTION STRESS ANALYSIS DATA DATE :February 20, 1987 COMPANY:Shell Western E&P Inc. FIELD :Middle Ground Shoal WELL NO:A43-11 API NO :50-733-10082 STATE :Kenai County, Alaska SPL NO.:2-1 LAB NO. :A-4967 DEPTH :8282.5 ft STRESS :4500 psi PORE VOL. :1.65 cc GRAIN VOL. -:16.808 cc BULK VOL. :18.458 cc POROSITY :8.94 % GRAIN DEN. :2.635 gm/cc WT. OF SPL :44.285 gm ATM POROSITY: 10.8 % AIR PERM. : 105 md ~ STRESS 200 psi AIR PERM. :43. ! md @ STRESS 4500 psi PSIA PUMP BLANK MERCURY CORR. % PV % BV READING INTRUSION VOL. OCCUPIED OCCUPIED VOL. 4 .0435 .0435 0.0000 0.0000 5 .0775 .0530 .0245 .0245 1.49 .13 6 .1250 .0620 .0630 .0630 3.82 .34 7 .1665 .0685 .0980 .0980 5.94 .53 8 .2215 .0750 .1465 .1465 8.88 .79 9 .3180 .0790 .2390 .2390 14.5 1.30 11 .5100 .0870 .4230 .4230 25.6 2.29 13 .5940 .0950 .4990 .4990 30.2 2.70 15 .6565 .1000 .5565 · .5565 33.7 3.02 17 .6980 .1045 .5935 .5935 36.0 3.22 21 .7640 .1070 .65?0 .65?0 39.8 3.56 26 .8250 .1125 .7125 .7125 43.2 3.86 31 .8520 .1150 .?370 .?370 44.7 3.99 41 .9400 .1225 .8175 .8175 49.5 4.43 51 .9875 .1270 .8605 .8605 52.2 4.66 76 1.1000 .1325 .9675 .9675 58.6 5.24 101 1.1230 .1400 .9830 .9830 59.6 5.33 131 1.1760 .1555 1.0205 1.0205 61.8 5.53 161 1.2160 .1650 1.0510 1.0510 63.7 5.69 201 1.2525 .1685 1.0840 1.0840 65.7 5.87 251 1.2825 .1710 1.1115 1.1115 67.4 6.02 301 1.3105 .1765 1.1340 1.1340 68.7 6.14 401 1.3605 .1820 1.1785 1.1785 71.4 6.39 601 1.4400 .2040 1.2360 1.2360 74.9 6.70 801 1.5060 .2250 1.2810 1.2810 77.6 6.94 1001 1.5600 .2400 1.3200 1.3200 80.0 7.15 1251 1.6010 .2610 1.3400 1.3400 81.2 7.26 1501 1.6480 .2810 1.3670 1.3670 82.8 7.41 1751 1.6970 .3030 1.3940 1.3940 84.5 7.55 ..2001 1.7380 .3240 1.4140 1.4140 85.7 7.66 With the initial injection pressures the volume of intrusion mercury will var This is due to mercury filling open spaces around the sample,(between sample frit,and or sample and viton rubber), which can't be taken into account with blank. As the injection pressure increases, the blank volume will increase wh the sample volume might remgin constant, or increase with a smaller change in volume. SHELL DEVELOPMENT COMPAI~~-*~' PETROPHYSICAL SERVICES SECTION STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 4500 PSI I000 100 10 t 100 90 80 70 60 50 40 30 20 10 0 MERCURY SATURATION - % PORE VOLUME OCCUPIED DATE : FEBRUARY 20, 1987 COMPANY~ SHELL WESTERN EJrP INC. LEASE : WrLL NO: .(43-11 &Pi NO: S0-733-10082 · fi[ID : MIDDLE: (;ROUND SHOAL SAMPLE NO. : 3-1 LAB HO. : A-4968 DE:m (F"r) ,8S05.0 ATU POROSITY : 7.17 ~ GRAIH DE:NSITY ~ 2.839 GU/CC; SHELL DL'VELOPMENT COMPAb"~' PETROPHYSICAL SERVICES SECTluN STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 4500 PSI 1000 Li __ ~' ~ ! '~ i _ ~ _ . :- . __ · , , . ,. . ' ' " ...... ( ' -' : "' o o 100 . . ..~ ~ ~ ,~ ~ . .... ., ~ . ~; - 10 ..... . -. ~ ~= === =.- _ _ 100 10 1 0.1 MERCURY SATURATION - % BULK VOLUME OCCUPIED DATE : FEBRUARY 20, lg87 COMPANY: SHELL WESTERN F.~P INC. I/ASr = WELL NO: ),43-11 APl NO: 80-733-10082 FIELD : MIDDLE GROUND SHOAL ,~1~" & ~FE~ . ~,1 SAMPLE NO. : 3-1 LAB NO. : A-4988 DrPTH (tO : 8505.0 ATM POROSITY : 7.17 S GRAIN DENSITY : 2.83g Gu/cc SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECTION STRESS ANALYSIS DATA DATE :February 20, 1987 COMPANY:Shell Western E&P Inc. FIELD :Middle Ground Shoal WELL NO:A43-11 API NO :50-733-10082 STATE :Kenai County, Alaska SPL NO.:3-1 LAB NO.:A-4968 DEPTH :8505.0 ft STRESS :4500 psi PORE VOL. :.980 cc GRAIN VOL. _:17.315 cc BULK VOL. : 18. 295 cc POROSITY : 5.36 % GRAIN DEN. : 2. 639 gm/cc WT. OF SPL :45.703 gm ATM POROSITY:?.17 % AIR PERM. :37.3 md @ STRESS 200 psi AIR PERM. :3.32 md ~ STRESS 4500 psi PS IA PUMP BLANK MERCURY CORR. % PV % BV READING INTRUSION VOL. OCCUPIED OCCUPIED VOL. 21 .1070 .1070 0.0000 0.0000 26 .1405 .1125 .0280 .0280 2.86 .15 31 .3210 .1-150 .2060 .2060 21.0 1.13 41 .4025 .1225 .2800 .2800 28.6 1.53 51 .4445 .1270 .3175 .3175 32.4 1.74 76 .5220 .1325 .3895 .3895 39.7 2.13 101 .5750 .1400 .4350 .4350 44.4 2.38 131 .6225 .1555 .4670 .4670 47.7 2.55 161 .6565 .1650 .4915 .4915 50.2 2.69 201 .6825 .1685 .5140 .5140 52.4 2.81 251 .7065 .1710 .5355 .5355 54.6 2.93 301 .7315 .1765 .5550 .5550 56.6 3.03 401 .?800 .1820 .5980 .5980 61.0 3.27 601 .8380 .2040 .6340 .6340 64.7 3.47 801 .8880 .2250 .6630 .6630 67.7 3.62 1001 .9215 .2400 .6815 .6815 69.5 3.73 1251 .9640 .2610. .7030 .7030 71.7 3.84 1501 1.0000 .2810 .7190 .7190 73.4 3.93 1751 1.0370 .3030 .7340 .7340 ?4.9 4.01 2001 1.0775 .3240 .7535 .7535 76.9 4.12 With the initial injection pressures the volume of intrusion mercury will var This is due to mercury filling open spaces around the sample,(between sample frit,and or sample and viton rubber), which can't be taken into account with blank. As the injection pressure increases, the blank volume will increase wh the sample volume might remain constant, or increase with a smaller change in volume. I00, O00 · · $ · ,~'", SHELL DEVELOPMENT~.OMPRNY P~TROPHYSICRL SERVICE~ LRBORRTORY MERCURY CRPILLRRY PRESSURE DRTR t&ooo · · $ · · · S 4 · lo · S 4 · 100 90 MERCURY SRTURRT!ON- PERCENT 4O 90 2O PORE VOLUME 10 0 OCCUPIED DRTE COMPRNY LERSE WELL NO. FIELD STRTE DEPTH SflMPLE :FEBRUARY 1~ 1B87 :~I-IELL WESTERN E&P :MIDDLE OROUND :ALA{A :8281' NO.:,. MERSURED VRL.UES KB - G- D*' 2. ~? OMB/CC VRLUES EST. FROM KB-est =~ ~ CURVE 8O 8O 8{) SO 10 · · · S SHELL DEVELOPIIEI~, COIIPRNY ~ETROPHYSICRL SERVICES LRBORRTORY IflERCURY CRP[LLRRY PRESSURE DRTR ~ ~ ~ ~ ~ ~~ ~~ ~ ~ .............. .,..; . i - .- ! I t I i ...... ....... · --.; .... ,~ = ~_ , ~ ......... ; ~ ...... ~ · ........... : ~ ~ .... ~ ........ .. - ..................... =~= ~ ~ .......................... . - ~ . { ', I ~ ~ ~ I [ ._ 1 . L ....... ~ .... i ...... ........ ,-- , .... J , ..... --' , "~ , ..... '_..] ..... L_.. ~ - ....... ,, .-, .... ~- ~ ......... , , .... . ..... , ' ~ ~ i ~ ~ I ' , .. I.~ ............. j ................ ~-= .... ~.~ .1......-=. .......... --= .......... q · . , ..... r .... , ..... ~.: ..... ~..- . .... y . ..,, ~ ...; ...... ~ ........ ~~'.= .... - ....... - ....... --,=,. .... ~. ~.... ~ .......... ~ -:;, , ...... ~:= ~::~: ~ ..... :::':..' , czc:: ~ ~,~ '" --.'~-.:''-' ...... ~;;-.:; :~;~;~ ................... ?';.'-~ ..... ~ .... ............................ ~:: :z:::~7'5 r.'~' ,c='_~. j -~ .... ~ . , . ........ ~ ~ : J '' "I1 11 . ._ ; ...... 4 ~,.~:~,~ ~;: ::;;,':~...- ..-2; '~&~~==, ,, : ...... ~'~-' ':=:'~ = :: .:"~ ~"~"~;: :;' I..2 ~~~~~ "-~~~~~~~~~~ ...... ~======= ..... ~=~~ _.., ........ ._.._, ......... ......... ~ ~ '~ .~"" --'~1] ~ ...... '" . ..' .... : * ..... ~. - - : ==; .... ,-:--t ........... ...... ' .... i - 8So·,..o88 o~ 8 S ooo. ,,..·· ,. · e, -··...,..·.,,,. ,,.. ·. -. -. I~ERCURY SRTURRTION-PERCENT BULK VOLUPIE OCCUPIED SRMPLE NO. =~ DEPTH .-828t' am', LERSE : HI WELL NO. :^4~-~ 2 0 i.O 0.1 O.S O. 4 O. 2 O. 010 &eob 0.005 · SHELL DEVELOPPIENT.~COPIPRNY ~ETROPHYSICRL SERVICE., LRBORRTORY PORE SIZE DISTRIBUTION O0 go 80 '70 80 SO 40 :~0 :LK:) t 0 PERCENT RELRT I YE PORE S I ZE D I STR I BUT l ON "sRHPLE NO. : 2 LERSE : DEPTH : 82B2' e" tJELL NO. : A43--Xt IDIqTE : FEBRUARY 23. 2. ge'7 FXELD : MZDDLE ORCIUND SHOAL COMPANY: SHELL WESTERN/-~, P INC. FIELD : MIDDLE GROUND DEPTH : 8281' O" PERCENT POINT # PRESSURE INTRUSION VOLUME .... psia 1 O.9 O.O 2 1.2 0.4 3 1.5 1.9 4 I .9 3.1 5 2.5 4.3 6 ' 3.1 5.4 7 4.0 7.2 8 5.1 9.5 9 6.5 14.6 10 9.3 28.0 11 10.5 31.1 12 13.5 36.6 13 17.3 41.2 14 22.0 45.3 15 24.4 47.3 16 25.3 47.7 17 28.5 49.2 18 31.6 51 .O 19 34.9 52.3 20 45.0 55.8 21 57.1 59.1 22 74.4 62.3 23 95.4 65 .O 24 120.5 67.1 25 158.O 69.3 26 200.6 71.2 27 254.6 73.0 28 331.5 75.1 29 421.3 76.7 30 536.5 78.6 31 686.9 80.4 32 872.5 82.3 33 1130.3 84.2 34 1441.9 86.2 35 1838.4 88.1 36 2325.8 89.9 37 2967.0 91.6 38 3787.1 93.0 39 4874.9 94.6 40 " 6245.8 95-7 4i : 7959.6 96.7 42 1 0090.5 97- 7 43 12847.4 98.2 44 16721 -9 99.0 45 21207.4 99.2 46 26914.9 99.6 47 34589.5 99.8 48 44171.5 99.8 49 56078.3 99.8 50 37003.6 99.8 LEASE: "~-~ STATE: ALASKA SAMPLE NO.: 1 CUMULATIVE INTRUSION VOLUME WELL NO.: A43-! INCREMENT INTRUSION VOLUME 0.'0000000 0.0053960 0.0269800 0.0431680 0.0593560 0.0755440 0.0998260 0.1322020 0.2023500 0.3885120 0.4316800 0.5072240 0.5719760 0.6286340 0.6556140 0.6610100 0.6825940 0.7068760 0.7257620 0.7743260 0.8201920 0.8633600 0.9011320 0.9308100 0.9604880 0.9874680 1.Ol17500 1.O4!4300 1.O630100 1.O899900 1.11427OO 1.1412500 1.16823OO 1.1952100 1.2221900 1.2464800 1.2707600 1.2896400 1.3112300 1.3274200 1.3409100 1.3544000 1.3624900 1.3732800 1.37598OO 1.38138OO 1.38407OO 1.3840700 1.38407OO 1.3840700 ol. o0oo00o 0.0053960 0.0215840 O. 01 6188O O. 01 61880 O.01 61 88O 0.0242820 0.0323760 0.0701480 0.1861620 O.O43168O 0.O755440 0.0647521 0.0566580 0.0269800 0.0053959 0.0215840 0.0242820 0.0188860 0.0485640 0.0458660 0.0431680 0.0377720 0.0296780 0.0296780 0.0269800 0.0242820 0.0296781 0.0215839 0.0269800 0.0242820 0.0269800 0.0269799 0.0269800 0.0269800 0.0242820 0.0242820 0.0188860 0.0215840 O.01 61880 O. O134900 O. 0134900 O. O08O941 0.0107920 0.0026979 O.OO5396O 0.0026979 0.0000000 0.0000000 0.0000000 COMPUTER PICKED .O75544 CC'S AS CLOSURE VOLUME. APPROX. POROSITY = 11.6 % APPROX. PORE VOLUME = 1.427 cc's ESTIMATED Kair = 50 md APPROX. BULK VOLUME = 11.658 cc's ESTIMATED Kbrine = 32 md GRAIN DENSITY = 2.637 gms/cc · · · · S 4 · · · · SHELL DEVELOPME~.~COMPRNY r-'[TROPHYS!CRL SERV! LRBORRTORY ~IERCURY CRP]LLRRY PRESSURE DRTR lO · · · 100 90 MERCURY 80 70 60 50 40 30 20 l 0 0 SRTURRTION- PERCENT PORE VOLUME OCCUPIED DRTE IFEBRUARY tg, lo87 MERSURED VRLUES COMP RNY : SHELL WESTERN Ef, P ! NC. ~ ,- l e. 1 [ . LERSE : [8 WELL NO. : A43-11 G* D.= ~. mgm GMS/CC FIELD : MIDDLE ~ROUND SHOAL VRLUES EST. FROM STRTE : ALASKA ~ me. · · Kw-est -10 MD DEPTH cO2O2' 8'* Ka-ott m32 MD 5R~PLE NO.: 2 9. D. est- CURVE PAGE DF' ; 40,000 10,004) lO0 14) I0 ";0 I0 6O lO · · 7 · · SHELL DEVELOPHEN~T~ COHPRNY /-~:TROPHYS!CRL SERV]:£ ~ LRBORRTORY HERCURY CRP]:LLRRY PRESSURE DRTR 8Sg,-° S it o, ft f~ ooo,'-. - *, ,, - ,, -oo,-... ·. ,,,. ". '*. '". '. HERCURY SRTURRT I ON - PERCENT BULK VOLUNE OCCUP ] ED / SRHPLE NO. ;2 LERSE ; J DEPTH =8282' B" WELL NO. :A4~-I. t DRTE =F£BRUARY tO. tee? FI:ELD :MZDDL. E OROUND S AL PAOE 2 DF ~ Cl lO · · 4 · O.I O.S O. 4 O.Z SHELL DEVELOPMENT-~COMPRNY 2ETROPHYSICRL SERVI(,..$ LRBORRTORY PORE SIZE DISTRIBUTION .... =~ .... - ~ :--.--===:=~== .... ~ : ~. ~:-~-~=.: - ~=~.-.. :---~i..,== -:-: ....... ~1~. ! ::~;i:: ' T! } i ii i~' !: : -:: ',': ''iT ;- "~ '-': ::i~::: ~;'''i : ; :, , 'i, : ; : i : z z ' : I i 7 . , ~ · . .I.71; _ - , I : ; I z i i 7_ : .' ~ ~ - - : ' ' .~ :, ,;.1] ; ~ ' I ' · ; , ,,,;2,,J i i' ; ' _ I I _ , ' ' ~-~T~'=';'~,- ~'.~~-4-: ~!~~.~.c ~ !J: 7 2'i~-~~,: ~~ I I I I i i I I 0 I.d ~2 0.~0 O. OS O. O4 O. OOt 1 O0 go ~0 '70 80 SO 40 ~0 20 ! 0 0 PERCENT RELRTIVE PORE SIZE DISTRIBUTION SRMPLE NO. :2 LERSE : DEPTH :B282' e" WELL NO. :A49-22 pETROPHYSICAL SERVICES SECTION FEBRUARY 1~, 1 987 DATA PROCESSING -- A ,Ip~PORE MERCURY CAPILLARY' PR.~ ~URE COMPANY: SHELL WESTERN E&P INC. FIELD : MIDDLE GROUND SHOAL DEPTH : 8282' 6" PERCENT POINT # PRESSURE INTRUSION VOLUME psia % LEASE: STATE: ALASKA SAMPLE NO.: 2 CUMULATIVE INTRUSION VOLUME 1 O. 9 O. 0 O. OOOOO00 2 1.2 0.7 0.0080670 3 1.5 4.0 0.0457130 4 ' 1.9 4.9 O.O564690 5 2.5 6.3 0.0726030 6 3.1 7.7 O. 0887370 7 4.0 9.4 0.1075600 8 5- 1 12.0 O.1371390 9 6.5 1 6.9 O. 1 936080 10 9.3 27.9 0.3199910 11 10.5 31.2 0.3576370 ~, 2 13.5 36.6 O.4194840 13 17.3 42.0 0.4813310 14 22.0 46.5 0.5324220 15 24.4 48.4 0.5539340 16 25.3 48.7 O. 5579680 17 28.5 50.4 0.5767910 18 31.6 52.0 0.5956140 1 9 34.9 53.4 O.6117480 20 44.9 56.7 0.6493940 21 57.0 59.7 0.6843510 22 74.3 62.6 O.7166190 23 95.3 64.9 0.7435090 24 120.4 67.0 0.7677100 25 157.9 69.1 0.7919110 26 200.5 71 .O 0.81 34230 27 254.5 72.7 0.8322460 28 331.3 74.5 0.8537580 29 421 · 1 75.9 0.8698910 30 536.4 77.8 0.8914040 31 686.7 79.5 0.9102270 32 872.3 81.6 0.9344280 33 1130.1 83.7 O.9586290 34 1441.6 86.0 0.9855180 35 1838.1 87.9 1.0070300 36 2325.5 89.8 1.0285400 37 2966.7 91.4 1.0473700 38 ..3786.7 93. t- I .O661900 39 4874.5 94.5 1.0823200 40 ~ 6245.5 95.9 1.0984600 41 7959.2 96.8 1. 10921OO 42 10090.1 97.8 1. 11997OO 4 3 12847. O 98.5 1.1 280400 44 16721.5 99.2 1.1361OOO 45 21 207.0 99.4 1.1 387900 46 2691 4.5 99.9 1.14417OO 47 34589.1 99.9 1.1 441 700 48 44171.1 99.9 1.1 441 700 49 56077.9 99.9 1.14417OO 50 37003.2 99.9 1.1 441 700 WELL N0.: A43-~. INCREMENT INTRUSION VOLUME OC'S 0.0000000 O. 0080670 0.0376460 0.0107560 0.0161340 0.0161340 O. 0t 88230 0.0295790 0.0564690 0.1263830 0.0376460 0.0618470 0.0618470 O.05109~,0 0.0215120 0.0040335 O. O1 88230 0.0188230 0.0161340 0.0376460 0.0349570 0.0322680 O. 0268900 0.0242010 0.0242010 0.0215120 O.01 88230 0.0215120 0.0161340 0.0215120 O. 01 88230 0.0242010 0.0242010 0.0268900 0.0215120 0.0215120 0.01 88230 O. 01 88230 0.0161339 0.0161340 0.0107560 O.O107560 O. 0080670 0.0080670 0.0026890 0.0053780 O. 0000000 O. 0000000 O. O000000 O. 0000000 COMPUTER PICKED .088737 CC'S AS CLOSURE VOLUME. APPROX. POROSITY = 9.9 % APPROX. PORE VOLUME = ESTIMATED Kair = 32 md APPROX. BULK VOLUME = 1.215 cc's 11.416 cc's · · · · LLJ · O'J 4 U~ LLJ · n 2 ::::) n- · LLJ S YSI NERCURY CRPILLRRY PRESSURE DRTR 10 · · 4 · .100 9O HERCURY 80 70 60 SO 40 30 20 10 0 SRTURRT!ON- PERCENT PORE VOLUHE OCCUP!ED DRTE .'FEBRUARY 1S. toe? HERSURED VRLUES COHPRNY .'SHgLL YESTERN ;'&P ]:NC. ~ --?.~. X ' LERSE : Ka - VELL NO. : A4g-t I G.D.- e. e'~e GMS/CC F l ELD : HZOOL; GROUND SHOAL VRLUES EST. FROH CURVE Kw-est -e. '7 HO DEPTH :e5~5' e" Ks-est -le MD SRMPLE NO.:9 G.D. est- PAGE i OF ~ tO, 000 8OOO 8OOO 7OOO 8OOO lO0 8O 7O SO I0 · · · SHELL DEVELOPME, ' COMPRNY PETROPHYSICRL SERVICES LRBORRTORY MERCURY CRPILLRRY PRESSURE DRTR ~ ........... ~ t ;:::- ~ '~:'i ~ ~:'":: .... : ......... ~ ..... ~ ...... : ............. : : - :tt.q ......... ' .... ' .......... ........ +!~-, '~ ~':::~:':' :":' : ..... : ' ............. ., ....... [ .......... ~ -..~.. ~ ~=-*.~ ......... ~ ...... : d..~ .:-:== ..... =....:.~.:-:::~__.. ~ =:~": ..... = ~ ~:::: ::::* .... ~.::';~ ~ ~-4...~.4 ....... ~:.:-~-~: ..... .~ .~-.::::: .... ~ ................... ....................... '~ ,, ~ 1 ...... I'~ [~ ................ , , ~ ..... ' ~ '~ ..................... :~ ........... ~-. I .... q- q.~.-~ ........................ ~ .......... ~ ............. ...... ~ ....... ~. _. ~ .. , .. ....... ~ ........... ~ _ . . ~,, ~ ~ ~ ........ , ~ ........ t .................. ...... :: :~ :~; --- ;::~ ~.~::: ~: :.~ ::. +--, .-:,.=~ ..... .... :::.-::::.i ..... ~ .... :~ ....~._ = -::: :::.,:::.=_.:_:..: .... :::::::::::::::::::::::::::::::: :::~I:' :': { ............ : ....... , ............ .......... , ~ ....... ~ , ;::~~::=:.. ~ -~ .... ........ i ...... i w ........ .'~'- ' ', .... ~ ~ .......... . "'~ ........ ~ ~ :: ~ ....... + ........... t ....... ~'~ "' ::~=_~ ......... ~ ; ;'~;q~:~;:' .~ , . ........................................ :...:...:: +....'...; ...... ~ +.._~ ..... ~ ~..~.~::,. :7:~ :~: . :.::: ::::~;:::: ~ ":::: ~ 5::: ~.' ..... ~:~:~: :-~' :.:.::~': '-'~~='~h~=~::;;;;~; ;~:-- - ~ ~z~_':;;;::.;::~;~. :~:]' --- ....... q ......... + ....... . .. ~-':::F.: ::: ........ 4: : ]:~. ..... -~.-.~::.~ .... -........ '-"~=: .... '.-~ .... ~ =~ ....... , ...... ~ .... : -:-.~-- -:~-~:.:.~: ..... :.: .... ~ ..... .. ~:~:::'~ ~:- ~' !:~ ~:::~ :' I~=: , ~'~;~;~:~ W'".~ ~- '-::':- - .... '-:::=~: ~:!', -- / 8gSggg ~ Il ~ 2-o`` ·''" '* " -oo,,,...o.=. -. ,,. ... -. NERCURY SRTURRTXON-PERCENT BULK VOLUNE OCCUPIED SRNPLE NO. :9 LERSE : 1 WELL NO. :A49-$t FIELD =HZDDLE GROUND SH AL DEPTH :eses- e" DRTE :FEBRUARY Ld 0 I0 · · · · 1.0 O.S 0.4 O. 2 0.10 0.0S O, O4 0. m o, ooe Ob(lOS 0..0O4 0.000 0. O02 SHELL DEVELOPPIEN~-~,COMPRNY PETROPHYSICML SERVICES LRBORRTORY PORE SIZE D!STRIBUT!ON 100 90 80 70 80 PEROENT RELRTIVE PORE 40 SO 20 t 0 SIZE DISTRIBUTION SRMPLE NO. DEPTH DRTE :g 2, OB7 LERSE : WELL NO. :A43-11 FIELD :MIDDLE G~OUND SHOAL DATA PROCESSING -- AUTOPORE MEHCUH! COMPANY: SHELL WESTERf-~P INC. FIELD : MIDDLE GROUND SHOAL DEPTH : 8505' O" PERCENT POINT # PRESSURE INTRUSION VOLUME psia % 1 O.9 0.O 2 1.2 0.7 3 1.5 1.5 4 1.9 1.8 5 . 2.5 2.9 6 3.1 3.7 7 4.O 5.5 8 5.1 10.3 9 6.5 17.6 10 9.3 24.9 11 10.5 27.1 12 13.5 31.1 13 17.3 35.2 14 22.0 39.2 15 24.4 40.7 t6 25.3 41 .O 17 28.5 42.5 18 31.1 43.6 19 35.4 45.4 20 44.0 48.4 21 57.O 52.4 22 73.0 55.7 23 93.2 58.6 24 121.3 61.2 25 155.3 63.7 26 199.2 66.3 27 252.1 68.9 28 330.0 71.4 29 425.6 73.6 30 537.9 75.8 31 686.3 78. O 32 865.9 80.2 33 1109.1 82. ! 34 1413.8 83.9 35 1 829.9 86.1 36 2326.0 87.9 37 2978.6 89.7 38 3771.3 91.2 39 4888.9 93. O 40 6245.0 94.1 41 : 7973.6 95.6 42 10119.4 96.3 43 12846.5 97.4 44 16750.8 98.5 45 21251.2 98.9 46 26914.0 99.3 47 34648.2 99.6 48 44304.7 99- 6 49 56032.6 99.6 50 40042.7 99.6 LEASE: STATE: ALASKa SAMPLE NO.: ) CUMULATIVE INTRUSION VOLUME O0'S 0.0000000 0.0056882 0.0113764 0.0142205 0.0227528 O.O28441O 0.0426615 0.0796348 0.136517O 0.1933990 0.2104630 0.2417490 0.2730340 0.3043190 0.3156950 0.3185390 0.3299160 0.3384480 0.3526680 0.3754210 0.4067060 0.4323030 0.4550560 0.4749650 0.4948730 0.5147820 0.5346910 0.5546000 0.5716640 0.5887290 0.6057930 0.6228580 0.6370780 0.6512990 0.6683640 0.6825840 0.6968050 0.7081810 0.7224010 0.7309340 0,7423100 0.7479980 0.7565310 0.7650630 0.7679070 0.7707510 .0.7735950 0.7735950 0.7735950 0.7735950 WELL NO.: A45-~ INCREMENT INTRUSION VOLUME CO'S 0.'0000000 0.0056882 0.0056882 0.0028441 0.0085323 0.0056882 0.0142205 0.0369733 0.0568820 0.0568820 0.0170646 0.0312851 O.031285~ O.031285! 0.0113764 0.0028441 O.01~3764 0.0085323 0.0142205 0.0227528 0.0312851 0.0255969 0.0227528 0.0199087 0.0199087 0.0199087 0.0199087 O. O1 99087 0.0170646 0.0170646 0.0170646 0.0170646 0.0142205 0.0142205 0.0170646 0.0142205 0.0142205 0.0113764 0.0142205. 0.0085323 0.0113764 0.0056882 0.0085323 0.0085323 0.0028441 O.O02844! . 0.0028441 O.OO00000 O.O000000 O.OOOO000 COMPUTER PICKED .O142205 CC' APPROX. POROSITY = 7.1 % ESTIMATED Kair = 19 md ESTIMATED Kbrine = 9.7 md AS CLOSURE VOLUME. APPROX. PORE VOLUME = 0.849 cc's APPROX. BULK VOLUME = 11.638 cc's GRAIN DENSITY = 2.636 gms/cc I00, aO0 · · 4 · lO, 000 · · · 4 · · · S 4 · · S · · lO · · S 4t 100 90 I"IERCURY SHELL DEVELOPMENT COMPRNY r~TROPHYSICRL SERVICF~'~ LRBORRTORY MERCURY CRPILLRRY PRESSURE DRTR '~.::: .~ .::~. .~:-,:~;:7 ,~::::7::::; ;::2 .~ :.~;~r~:~?: ''';.'~?:t%: i : . : _ ~ : . . . : * . . .; i : : : i : _; : . : ; .~. - - - - - '_ . : 1 ~ ,, J --- ; , ~ ~ , -. , =-- _ :~ ~ '~ ,1~';::~ ;1::'7:~ ~.~t~;.~i~: :~ ;~ ~;~' ); : ::'~~.~J.~~ -.=4 -.--~.~..~:q,~-~! ~ z:~.~-~:~ c ; ~ ~ - : : : : = - : 1-- ~ - '+~ == =~ .~.~.~ ~.. ~.--~.-~.. - ~-~-., .... ~'~---~ I 80 ?0 80 SO 40 90 20 10 0 SRTURRT]ON- PERCENT PORE VOLUPIE OCCUPIED DRTE =FEBRUARY le. 10B7 PIERSURED VRLUES COIIPRNY .'SHELL WESTERN E&P INC. ~ - t [. 2 X LERSE : Ia -4-4a MD t~ELL NO. : A4~-1 1 O, D.' 2. B4B eMS/CC FIELD = MIDDLE GROUND SHDAL VRLUES EST. FRO~ [W-elt -. ~2 MD DEPTH =es~' 0" Ii-est -. e2 MD SR~PLE NO. = 4 G.D. e~t- , i . . . CURVE PAGE 80, 000 ~0. 000 10o ~0 Io lo · · · · SHELL DEVELOPI"IE~"'"" COI"IPRNY r-ETROPHYSICRL SERVICr..S LRBORRTORY NERCURY CRP!LLRRY PRESSURE DRTR ~ ---~--.,~,t : ~ ."'~., : ' -'.~:~' : -" .......... :;2½..,Jr.. -~ '--':-ii" ~ ..--:c' ;.~.;.': !:.-.-4 h-,:: , . i--: :"i?"'~ ; ...... .-1 .~ -- .... -.-': · - + ~ .......... ~l i .::~ [.. ;: ' ':'--"i "' ~" ' ::: :t: ..... : .......... -'- : ........ ........... _.~ .. ; : ,. : . ! · .-- h--.' ~ -: ....... ..... i ......... -.----_1----' ' ' , ; .......... i '-": .......... ~ .......... :.=:. .......... :, ........ ~ .......... i '.:12:: 4 ....... ~E~.¥'.._::-"'~::- ......... - ....... :::::..wm.- _._/:::'::":~:'-'-"':': ..... i ~...... · ...."'-" ..... -'~-'--'-~::] ...... ' .... ::--- i.:. :;:jr;i:! :-- ~- :-: ...... --.. = := %i: :.2-":: 77. ! .-.'.--~!'-_--i ~..: i : : ..-':":k:~:' ..... .F~ '-:':'~i -*-: ..... , ............ ----, ................. ..---'w ........ , i : :, --:- ~ l ...... I -,i [ ..... ;-:i-i I ".;'i.';..:' '~ ,;--;~.. ~-'-'~w_-'---. ; ....... "'"' 'x'~'r-_-.: '.1-.-'" ::'!';'!~':.'!-.;;-' - '-~2-2 i'i i:.:.-:.~i ]----': 2111 .';.-.-.:.::~ ~'i-'i ;;~-.' l.:._ .-:: ~ :"q-:~.:~: -':::'"-'~:'-fi :':'.w.!i:%-'":;-'_ ..-~-' '~-/"' -':"' ....... !:'=;;:'::=~=2:::.~ :.'I;:-.'c7_.%7_;x :'; 'izT_:L.L':' 1:::: ~ i '"i.-:; ~ -~" :--:" r--:"F.'~ . ; ..... 2.2_.1._ * ........ Ill:' . -'-T"'-'t'-'" .";.*~ ';I ..,.:.r'::. '; .... ---I..- -:. ~ '- '"&f ......... : ..... , ', .... ~ i : .......... I ..... '; - ' i: :-.:;= ........... - ..... :._ ' '-'::t .... ;if ..... ...... : ... ~ ...: ::'i - ~ ....... 2 .... .4 ........ [ ~,? ............. ~ .... ~ ' ~ ...... -.1 '4..- i ~ r-_' :":'"": -'-'~-_"'~..::;: .' '~ .-_"~..~-~ ....... ~ ....... ~....i ......... · ..... , 'u .......... ' ......... ~ -°"--~ ............ "' . ' - - ............................ '7 ....... ~ ::[ . :.:.'-' ....... · ' '- '~ ' ' ' ~ ....... i~..~ :._:._,.~._: o., · = ..---:-~ ::: : -:~-:'::::~ ........ i ...... -,:-: ....... ...... = = ......... --. :.._: c-.4 ...... :::~;x.:: :.:~:4' - ~.: -:::::i;! -~--.----:~?=:::!::..: ' .......... .:.-~.---:.:x::-+:~:--i .....- ,-:::'4"'- -- ::: -:, ~-": ........ _= ..... ~,......... 4 ...... , ...........'% t- i !-:--'--- ~-~- .................... --t'-:---- c _ ...... .--: i~- ! .i '-'+:::I '---~" ----,' ..-'~_ :~.~;;'.: :i;:: "':::X.. ...... ":"-=.., ...... :--. ....... ,... '4 ---!"' .-.---J-~ -: ~ ..... .,!~; f ....... ','--,' -~---=..---r-~- ! .... :.,..-". ':-:.--'- :: '- .. ..... 4- ''"_'.. ',__ - --'": .;; ...... .'.--r'.:''W'"::'.:% .~.~.:.~-''--~ ; . . I'~.; .~' ' : !':::"-::z:.: ?':';::-;7 ...... i ;":' ,...., ..... '":'I .... ~ · ~ i'<i_':-:..]_, _.,] .... __ ..... ,. .... ,.:,. ..... __.,~_.:.:; z :::: :::.~ =--. ---= [-=-~ E~:.. :..-....*-~::-~.---: =.....:.. :.-:, "-'7 :-:i"'.i.:-':12-'..:!;-'-;i ~-:~' :2;" ..~'~ ...." ;;.';..'~ ;': ~..z. ...... ...J ..;;i; 'r-;.~ ...... ' ~ ..... ;2..2-..2 '"- ...... --"*i "~ . ~ , , ........ : ;'..:;Ir-:-. ' ' - -.-.; .- '~"q ..... ' .......... ...... ..-:=..,.-= ...... ;.-q...: : ..--' ,._._;:. ,.- ~_:j.. -'t ................... '"-- , ~1' ..... ~ : " .... - .... ', .......~ ~ -.4. :.;:2,2 ' ':._..' ~ ·.:;7, .%-..~ ~ ' I ::::.~,.. .'. :_x , .... -.,. 4-:X ;" : ~ I . -., ..... j,..., -_-, ,= :.. ...:,.....,,. ....... .-+.,,;...=ij:9.:.~...--;~.f.~, .-_.. ....i.- .1..: .-. ::-.- ....... :~::::-- .... ' .... " ..... ~:.::.~ ::- '"'~ ~--> .... i:-::::~!!:~:7..-. ! _.'- , I' 88o°g88 ~ 8 Il-°°'**"·'" * ** ,,, -oo..,,..o.,,,. -. ,*. -. -. PIERCURY SRTURRTION- PERCENT BULI~ VOLUI'IE OCCUPIED SRHPLE NO. :,4. DEPTH :eseg' e" DRTE tF'EBRU^RY I O. WELL NO. ^4g-ll 1o87 FIELD .'MZDDLE GROUND SH AL PAGE ~ OF ~ E LJJ 0 1.0 O.I 0.8 0.$ O. 4 0.$ o, lO 0.08 O. OS O. O4 O. OO 4).OAS 0.0O4 O.'008 O, 002 O. O01 SHELL DEVELOPMEN~-~,COMPRNY PETROPHYSICRL SERVI[,.S LRBORRTORY PORE SIZE DISTRIBUTION tO0 90 80 ';0 8O PERCENT RELRTIVE PORE 40 90 20 10 SIZE DISTRIBUTION SRHPLE NO. :4 DEPTH : DRTE :FEBRUARY I ms7 LERSE : WELL NO. : A4~J-li FIELD :HZDDLE GROUND SHOAL PETRO~HYSICAL SERVICES SECTION FEBRUARY 16, 1987 DATA PROCESSING -- AU~0RE MERCURY CAPILLARY PRF'-m~URE COMPANY: SHELL WESTERN E&P INC. LEASE: FIELD : MIDDLE GROUND SHOAL STATE: ALASKA DEPTH : 8509' 6" SAMPLE NO.: 4 PERCENT CUMULATIVE POINT # PRESSURE INTRUSION VOLUME INTRUSION VOLUME psia % cc' s 1 O. 9 O. 0 O. O000000 2 1 .2 0.6 O. O083034 3 1 · 5 2.3 O. 0304458 4 -1 · 9 3.3 O. 0442848 5 2.5 4.0 0.0525882 6 3.1 4.4 0.0581238 7 4.0 4.8 0.0636594 8 5- 1 4.8 0.0636594 9 6.5 5.0 O. 0664272 10 9.3 5.2 0.0691950 11 10. 5 5.2 O. 069~, 950 12 13.5 5.4 0.0719628 13 17.3 5.6 0.O747306 14 22.O 5-8 0.0774984 15 24.4 6.0 0.0802662 16 25.2 6.O 0.O802662 17 27.O 6.O 0.O802662 18 30.3 6.O O.O802662 t 9 32.9 6.3 O. 0830340 20 37.2 6.5 0.0858018 21 45.9 7.3 O.0968730 22 59.0 11.7 0.1549970 23 74.7 28.5 0.3791890 24 94.8 39.2 0.5203460 25 122.8 47.3 0.6282910 26 156.8 53.1 0.7057890 27 200.7 57.9 0.7694480 28 253.6 62.3 0.8275720 29 331.5 66.3 O.8801610 30 427.1 69.8 0.9272130 31 539.4 72.5 0.9631940 32 687.8 75.2 O.999!760 33 867.5 77.5 1.0296200 34 1110.7 79.8 1.06OO700 35 141 5.4 81 · 9 I .O877500 36 1 831 . 5 84.2 1 · 11 81 900 37 2327.6 86.2 1 · 1 458700 38 2980.2 88.3 1 · 1735500 39 3773.0 90.0 1 · 1 956900 40 ~ 4890.6 92.3 1.2261400 41 6246.7 94.4 1.2538100 42 7975.3 96.O 1.27596OO 43 10121 · 1 97.5 1. 2953300 44 1 2848.2 98.5 1 · 3091 700 45 16752.5 99.4 1.3202400 46 21 252.9 99-8 1 · 3257800 47 2691 5.7 99.8 1. 3257800 48 34649.9 1 OO.O 1 · 3285400 49 44306.4 1 CO . O I · 3285400 50 56054.4 100.0 1. ~5285400 WELL NO.: A43-I INCREMENT INTRUSION VOLUME CO'S 0.0000000 0.0083034 0.0221424 0.0138390 0.0083034 0.0055356 0.0055356 O.0000000 0.0027678 0.0027678 O.O000000 0.0027678 0.0027678 0.0027678 0.0027678 0.0OO0000 O.O000000 O.O000000 0.0027678 0.0027678 O.O11071 2 0.0581238 0.2241920 O.1411580 0.1079440 0.0774984 0.0636594 0.O58~238 0.0525882 0.0470526 0.0359814 0.0359814 0.0304458 0.0304458 0.0276780 0.0304457 0.0276780 0.0276780 O.O221424 0.0304458 0.0276780 0.0221424 0.0193746 0.0138390 0.0110712 0.0055356 O.0000000 0.0027678 O.O000000 0.0000000 COMPUTER PICKED .O71 9628 CC' APPROX. POROSITY = 11.1 ESTIMATED Kair = .02 md ESTIMATED Kbrine = .002 md S AS CLOSURE VOLUME. APPROX. PORE VOLUME = 1.383 cc's APPROX. BULK VOLUME = 11.843 cc's GRAIN DENSITY = 2.646 ~ms/cc RSH 1655 1151-C BRITTMORE ROAD HOUSTON, TEXAS 77043 (713) 932-7183 TRANSMITTAL LETTER RECORD OF SHIPMENT OF CONFIDENTIAL INFORMATION TO. Mr. John Boyle A.O.G.C.C. 3001 Porcupine` Drive Anchorage, Alaska 99501 FROM: G'eorge W. Bolger Project Leader (NAME & TITLE) DATE: June 30, 1986 VIA: u.s. Mail QUANTITY DESCRIPTION CONTENTS 2 copies: Geological Analysis and Evaluation of GB Sands, Shell Western Exploration and Production, Inc., A~3~11 Well (6965-6986 Feet), A33-11 Well (7021-7150 Feet), A41-11 Well (7366-7494 Feet)~ Middle Ground Shoal Field, Alaska. INSTRUCTIONS: RECEIVED BY: REMARKS: PLEASE ACKNOWLEDGE RECE I PT PROMPTLY BY S IGNI NG AND RETURNING THE YELLOW COPY, ~_~T~~~~/~Ov7 19~~' ~ /Alasl Oil & G~s Cons. wm~i~!O~ Anchorage ltl/llVlJlll GEOLOGICAL ANAL YSIS o CLASTICS / CARBONATES SINGLE WELL / FIELD / REGIONAL STUDIES WELL COMPLETION / STIMULATION STUDIES ROUTINE AND SPECIAL CORE ANALYSIS 1151 - C BRITTMORE ROAD HOUSTON, TEXAS 77043 (713) 982-7153 June 27, 1986 Mr. John Boyle A.O.G.C.C. 3001 PorCupine Drive Anchorage, Alaska 99501 Dear John: The two copies of this report are being provided to the A.O.G.C.C. at no charge to yourself or Shell Oil. This material is considered confidential to Shell Oil Company and should be treated as such. Permission was granted to provide these copies by Mr. Clay Williams of Shell. GWB:mml ~je'~t Le~der · Enclosures GEOLOGICAL ANALYSIS AND EvALuATION OF GB sANDs S!-I_ELI. WESTERN' EXPLORATION-AND PRODUCTION, INC. ~'~ ...... ~ ' W' ~ _~§96'''~-ELL 5-6986 ............. F]~ET)~_~ A43-11 · A33-11 WELL (7021-7150 FEET) A41-11 WELL (7366.7494 FEET) MIDDLE GROUND SHOAL FIELD, ALASKA Prepared for Shell Western Exploration and Production, Inc. Houston, Texas f-- COMPANY PROPRIETARY 1151- C BRITTMORE ROAD · HOUSTON, TEXAS 77043 · CONFIDENTIAL June, 1986 (713) 932-7183 GEOLOGICAL ANALYSIS AND EVALUATION OF GB SANDS SHELL WESTERN EXPLORATION AND PRODUCTION, INC. A43-11 WELL (6965-6986 FEET) A33-11 WELL (7021-7150 FEET) A41-11 WELL (7366-'/494 FEET) MIDDLE GROUND SHOAL FIELD,- ALASKA INTRODUCTION RECEIVED /~la,~ka Oil & Gas This report presents the results of a study conducted by Reservoirs, Inc. at the request of Shell Western Exploration and Production, Inc.., Houston, Texas. This study involves the description and characterization of three conventional core samples and seven percussion sidewall core samples of the GB Sands from three wells in the Middle Ground Shoal Field, Alaska. Four other sidewall samples were submitted, but as insufficient rock material with original fabric was present, no analyses were performed on these samples. Table 1 lists sample depths and the analyses performed on each sample. The purpose of this study was to determine the geological characteristics of the samples, including the texture, mineralogy, pore space types, pore geometries, and the nature of the pore-filling constituents. Emphasis was to be placed on possible explanations for the minor difference in wireline log resistivity between productive and nonproductive sandstones. In addition, the reservoir quality of these samples was to be ascertained, with suggestions made concerning the completion/stimulation procedures to be used in these rocks. To obtain this information, the ten rock samples were analyzed as instructed by Shell Western Exploration and Production, Inc. Routine core analysis data was provided by Shell Western Exploration and Production, Inc. for samples of the GB2 from Shell Western Exploration and Production, Inc. A-43-11 Well. Permeability, porosity and grain density are recorded in Table 2. Prior to subsampling for geological analysis, the rock samples were extracted using a Soxhlet apparatus in order to remove hydrocarbons and/or other volatile material which interfere with scanning electron microscopy and X-ray diffraction analysis, as well as thin section preparation. X-ray diffraction analysis (XRD) was performed on five of the samples (see Table 1) in order to provide semiquantitative data on the rock composition. X-ray diffraction data for these samples are recorded in Table 3. Each sample was ground to approximately 40 microns in a constant particle size grinder and subjected to a bulk XRD analysis of the total mineral composition. A less than 5 micron fraction was separated from the total sample by using standard XRD particle size separation techniques and subsequently analyzed to identify and quantify clay mineral components. Thin section petrographic analysis was conducted on ten samples (Table 1). Thin sections were prepared by impregna- ting the hydrocarbon extracted samples with blue-dyed epoxy at approximately 1000 psi, followed by grinding to 35 microns. The samples were stained with Alizarin Red-S to aid in distinguishing calcite from other carbonate minerals. A petrographic examination was then conducted to determine the mineral composition of the granular and pore-filling constitu- ents, to characterize the nature of the pore space, and to estimate the grain size and degree of sorting. A modal analysis consisting of a point count of 250 points was conducted on five of the thin sections which were composed of rock material with a natural fabric. These data are presented in Table 4. Two photomicrographs were taken of each sample. Generally, one photomicrograph was taken at a low magnifi- cation to show the general rock fabric of the sample, and a second photomicrograph was taken at high magnification to illustrate selected features. Thin section photomicrographs and corresponding descriptions are presented in Figures 1-5. Scanning electron microscopy (SEM) was performed on six of the samples supplied (Table 1). Each sample was examined in order to visually observe and document the general rock fabric, and to provide high magnification photomicrographs illustrating grains, cement types, pore space morphology and occurrence, and the mode and distribution of clay minerals present within the rock pore system. Photomicrographs were taken of three areas of each sample, represented by two separate plates. In the first plate, succeedingly higher magnifications of 100X, 500X, and 2500X illustrate the genera! rock fabric as well document the presence and mode of occurrence of diagenetic minerals. In the second plate, low and high magnification photomicrographs of two other areas of the sample are used to illustrate the type and distribution of diagenetic minerals and pore spaces. Additionally, appropriate minerals were analyzed using a EDAX 9140 EDS system in order to provide elemental compositional data on specific minerals and/or particular areas of the general rock material. These data are presented in the form of an atomic percent table. This presentation represents a computer subroutine that semiquantifies the measured X-ray spectrum. Photographs of the atomic percent tables obtained from the EDS spectra are included with the SEM photomicrographs in Figures 6-11. ReserVoirs Job Number RSH 1655 was assigned to this study. Any communications regarding this report should refer to this job number. Three copies of this report have been forwarded to Mr. Clay C. Williams, Engineer, Alaska Division, Shell Western Explora- tion and Production, Inc., Houston, Texas. Reservoirs, Inc. retains the original copy for possible future reference in conversations with authorized personnel on specific details of this study. Additional copies of this report may be obtained for reproduction costs by contacting Reservoirs, Inc. Original prints of all photomicrographs presented in this report are on file at Reservoirs, Inc. The SEM samples and thin sections prepared for this study will be retained by Reservoirs, Inc. in referenced storage systems. All data, interpre- tations and other matters related to this study are considered highly confidentia! and the sole property of Shell Western Exploration and Production, Inc., Houston, Texas. Susan E. Koellner General Projects Supervisor RESERVOIRS, INC. Jam'~s J. Parr Geologist RESERVOIRS, INC. Harry L./~I~rton, P.E. Senior St~gf Petroleum Engineer RESERVOIRS, INC. RESULTS AND DISCUSSION The rock properties and reservoir potential of three conventional core samples and seven percussion sidewall core samples of the GB Sands from three wells (A43-11, A33-11, A41-11) in the Middle Ground Shoal Field, Alaska, are discussed in this section of the report. A complete list of wells, samples and analyses performed is given in Table 1. For the purposes of this report, the analysed samples have been subdivided and discussed by sand bodies, GB1 Sand and GB2 Sand, as specified by Shell Western. Depths for the sand intervals in the following table were taken from logs supplied by Shell Western. Well GB! Sand Interval (Feet) Samples Submitted (Feet) A43-11 6872-6930 A33-11 6996-7060 7021 7038* 7053* A41-11 7350-7438 7366 7382 7410' Well GB2 Sand Interval (Feet) Samples Submitted (Feet) A43-11 6946-7010 A33-11 7064-7160 6965 6971 6986 7083 7118 7150' A41-11 7460-7522 7475 7494 * Denotes insufficient sample to conduct analyses. GBl Sand Three of the samples submitted from this sand body were deemed suitable for analysis (Table 1). The percussion sidewall sample from 7021 feet (A33-11 Well) is extensively fractured and infiltrated by drilling mud with virtually all the original rock fabric destroyed (Figure 2). The largest intact framework grains remaining are in the coarse sand category (500-1000 microns), however, grain size is skewed towards the finer grain size categories due to the breakage of grains during sidewall coring with many grains having been completely ground to "rock dust". The most common discernable framework constituents present in roughly sub- equal amounts are monocrystalline quartz and metamorphic rock fragments. The metamorphic rock fragments are virtually all polycrystalline quartzite grains, with mica inclusions common. Schistose metamorphic rock fragments are rare, and consist largely of micas and clay minerals with minor quantities of silt-sized quartz. Less abundant framework grains include argillaceous rock fragments, chert, muscovite and biotite mica (Figure 7). Due. to the sample destruction, the types and nature of the pore-filling constituents and the pore space cannot be ascertained. The two other percussion sidewall core samples of the GB1 Sand which were examined are from 7366 feet and 7382 feet in the A41-11 Well. They are moderately sorted with framework grains predominantly in the upper fine sand category (177-250 microns). X-ray diffraction analysis (Table 3) of the sample from 7366 feet shows quartz to be the major mineral present (59%). Most of this quartz occurs as monocrystalline framework grains (Table 4), with lesser amounts present as polycrystalline metamorphic rock fragments ("quartzites"), chert and quartz overgrowth cements. Quartz is also the dominant mineral in the sample from 7382 feet. Chert, however, is the major phase present (50%) with subordinate amounts of monocrystalline quartz, quartzite rock fragments, and silica cement (Table 4). Chert grains are sub-rounded (Figure 4), indicating they have been reworked and redeposited rather than having an authigenic origin. The sample from 7366 feet contains abundant feldspar, with XRD showing plagioclase (11%) to be more abundant than potassium feldspar (6%). Approximately 50% of the feldspar present occurs as single detrital grains (Table 4) with the remainder present as constituents of composite rock fragments. Only a trace of feldspar was observed as distinct grains in the sample from 7382 feet. Argillaceous rock fragments are common in the sample from 7366 feet (14%), constituting a large proportion of the total clay (24%) measured by XRD (Table 3). These relatively soft, ductile grains, together with mica, are frequently deformed due to compaction (Figures 2 and 7). Argillaceous rock fragments are less common (7%) in the sample from 7382 feet (Table 4). Minor framework constituents include extrusive igneous rock fragments, mica and opaques. Both of the samples of the GB1 Sand in .the A41-11 Well are well lithified, in particular the sample from 7382 feet (Figure 4). Silica in the form of quartz overgrowths is the main cement (Table 4). The source for the silica is probably the pressure induced solution of quartz framework grains following compaction. Clay minerals probably also act as minor lithifiers. As stated previously, a large portion of the clay present in the GB1 Sand samples from the A41-11 Well is detrital, mainly in the form of argillaceous rock fragments (Table 4). Authigenic clay occurs mainly as diagenetic replacement of unstable framework grains such as feldspar and rock fragments, hence, has an isolated, patchy distribution. The dominant species is kaolinite (Table 3), replacing grains and partially occluding large secondary pores (Figure 4). Lesser quantities of illite, smectite and chlorite occur. Thin section petrography shows the sample from 7382 feet to be "cleaner", containing less authigenic and detrital clay than the sample from 7366 feet (Table 4, Figure 4). The framework grain composition has affected the degree to which pore space has been retained. Silica cement has significantly occluded the primary pore space in the sample from 7382 feet, leaving small pore apertures and a poorly connected, tortuous pore network. Leaching of unstable framework components forming large secondary pores has added to the total visible pore space (2%). Minor microporosity associated with the abundant chert grains (Figure 4) will also contribute to the total porosity of the sandstones. In contrast, the abundance of argillaceous (clay-rich) rock fragments has aided in the preserva- tion of primary pore space in the sample from 7366 feet. The presence of these framework grains preserves some of the primary pore space because they cannot nucleate quartz overgrowth crystals (cement). They also frequently undergo alteration in the subsurface, producing secondary intergranular and intragranular pore space. However, this secondary alteration commonly provides material which is reprecipitated as diagenetic clay within the leached grain cavities and throughout the remnant pore system. Abundant intercrystalline microporosity is associated with the diagenetic clay minerals. Judging from the logs, the GB1 Sand is thickest in the A41-11 Well (88 feet), thinning in the A33-11 Well (62 feet) and the A43-11 Well (58 feet). Log responses from the A41-11 Well correlate well with the observed characteristics of the rocks. The increase in clay content ("shaliness") towards the top of the zone corresponds to an increase in gamma log response. The increase in deflection of porosity and SoP. toward the top of the interval also correlate with observed porosities. Overall, the reservoir quality of the GB1 Sand is judged to be moderately good in the upper zone, decreasing in quality with depth. GB2 Sand Seven of the samples submitted from the GB2 Sand were analysed (Table 1). Four of the seven samples are percussion sidewall cores, two from the A33-11 Well and two from the A41-11 Well, and the remaining three samples are conventional core pieces from the A43-11 Well. The conventional core samples from the A43-11 Well range from moderately well sorted (6986 feet) to very poorly sorted (6971 feet). Average grain size ranges from upper fine sand (177-250 microns) in the sample from 6986 feet to coarse sand (500-1000 microns) in the samples from 6965 feet and 6971 feet (Figure 1 and 2). Hand specimen investigation shows the coarser samples to contain pebble clasts up to several centimeters in diameter. Framework grains are angular to sub-rounded. All three samples show evidence of bedding on a centimeter scale. The four sidewall core samples contain virtually no original fabric due to process of obtaining percussion sidewall samples. The framework grains are heavily fractured and infiltrated with drilling mud (Figures 2, 3, 9 and 10). The largest surviving framework grains in the samples from A33-11 Well range from upper medium to lower coarse sand (350-750 microns). The samples from the A41-11 Well appear slightly finer-grained, remnant intact grains being in the medium sand category (250-500 microns). Little textural information, however, can be inferred due to the damaged nature of the samples. Silica is the dominant mineral constituent in all of the samples (Table 3), ranging from 62% of the bulk (7475 feet, A41-11 Well) to 80% (6965 feet, A43-11 Well). Petrographic examination reveals monocrystalline quartz and metamorphic fragments (polycrystalline quartzite) present in all of the samples in roughly sub- .equal amounts (Table 4, Figures 1-3). These are the dominant framework grains. Silica also occurs as reworked detrital chert, constituting approximately 10% of the samples and as minor quartz overgrowth cement (Table 4). X-ray diffraction analysis shows a total feldspar content ranging from 12% (6965 feet, A43-11 Well) to 21% (6986 feet, A43-11 Well), averaging 16% (Table 3). This value is higher than the 9% average determined petrographically (Table 4) as some of the .feldspar detected by XRD is included within the rock fragments. Both plagioclase feldspar and potassium feldspar (dominantly microcline and otho- clase, with minor perthite) are present. The feldspar is commonly diagenetically altered to clay minerals, particularly along cleavage planes (Figure 1). Leaching has given rise to secondary intergranular and intragranular pores. These pores commonly are partially occluded by grain remnants and authigenic clay minerals, particularly kaolinite (Figure 1, 5 and 6). Heavily altered volcanic igneous rock fragments of basaltic origin, argillaceous rock fragments, and both biotite and muscovite mica are present in minor amounts (Table 4). Argillaceous rock fragments average 6% for the GB2 Sand compared to 11% in the GB1 Sand (Table 4). Opaque minerals (predominantly pyrite) and organic debris are present in trace amounts. Framework grains have a "fitted" texture with some sutured grain contacts due to compaction (Figure 1 and 2). Compaction has resulted in the deformation of relatively "soft" framework grains such as argillaceous rock fragments and cracking in more brittle quartz grains (Figure 1). Quartz overgrowths aid in the lithification process (Table 4). The source of silica for these overgrowths was probably the pressure induced solution of framework quartz following compact- ion. Minor cements include authigenic clay minerals and rare authigenic dolomite. Clay mineral percentages determined from X-ray diffraction analysis (Table 3) range from a low of 7% (6965 feet, A43-11 Well) to a high of 22% (7475 feet, A41-11 Well). Thin section point count data (Table 4) show clay content to vary from 3% (6965 feet, A43-11 Well) to 6% (6961 feet, A43-11 Well). The lower percentages detected petrographically are due, firstly, to difficulty in seeing the grain-coating and pore-filling authigenic clays that are evenly distributed throughout the rock and, secondly, to the inclusion of the clay in argillaceous rock fragments and other framework components in the total clay mineral category in XRD. X-ray diffraction analysis shows kaolinite as the major clay species in the three samples analysed with smectite also relatively common. Lesser quantities of illite and chlorite were also detected (Table 3). Scanning electron microscopy shows kaolinite as the major authigenic phase present, being widely distributed throughout the samples, often forming as a diagenetic alteration product of unstable feldspar framework grains (Figures 1, 2, 5 and 6). Well developed booklets and stacks of pseudohexagonal authigenic kaolinite plates and elongated vermiform crystals occur filling pores and lining large pore throats (Figures 5 and 6). Elongate fibers, ribbons and laths of authigenic illite present in pores may be an alteration production of unstable framework grains such as argillaceous rock fragments. Authigenic illite occurs attached to authigenic kaolinite (Figure 6), indicating illite formed at a later stage in the diagenetic history of the rocks than the kaolinite. Both the smectite and chlorite detected by XRD were not observed in SEM. It is, therefore, probable that these clay minerals occur as constituents of detrital argillaceous rock fragments. Abundant intercrystalline microporosity is associated with the authigenic clay minerals. Routine core analysis data (Table 2) show porosity to range from 16.0 (6986 feet, A43-11 Well) to 18.8% (6971 feet, A43-11 Well), averaging 17.6% for the three samples analysed. Petrographic examination shows both primary intergranular and secondary pore types present, with primary more abundant than secondary (Table 4). Primary pore space has been occluded by compaction, quartz overgrowth cement, and detrital and authigenic clay minerals. Secondary pores are generally large and were formed due to unstable framework grain leaching. Minor intragranular secondary pores are also present. Petrographic examination (Table 4) shows porosity to range from 12% (6986 feet, A43-11 Well) to 15% (6965 feet, 6971 feet, A43-11 Weld averaging 14%. The lower amount of pore space detected visually is due to the difficulty in seeing the abundant microporosity present in all samples which is detected by routine analysis techniques. This microporosity is associated with framework grains including chert, leached feldspar and argillaceous rock fragments (Figures 1 and 5) and with authigenic clay minerals (Figure 5 and 6). Measured permeabilities range from 195 millidarcies (6965 feet, A43-11 Well) to 15.0 millidarcies (6986 feet, A43-11 Well). The sample with the lowest permeability is also the finest grained, hence, has the smallest pores and pore throats. Additionally, quartz overgrowths and clay minerals are most abundant in this sample. The components further occlude pore space, decrease pore aperture size and increase the tortuosity, hence, decreasing the effectiveness of the pore system. The net impact of finer grain size and greater degree of mineral diagenesis is to produce a rock type with moderate to good porosity and relatively low permeability. The effects of diagenesis are less in the coarser grained samples whose larger pores and pore throats are less significantly occluded with subsequent less reduction in permeability. The logs indicate the GB1 Sand is thickest in the A33-11 Well (86 feet), thinning in the A43-11 Well (64 feet) and A41-11 Well (62 feet). Log responses indicate the best porosity and permeability in the GB2 Sand is towards the top of the zone, which correlates well with the results of the analyses discussed above. Overall, the reservoir quality of the GB2 Sand is judged to be good, particularly in the upper zone, decreasing with depth. Log responses appear similar for the three wells studied in this report. SUMMARY The geological analysis of three conventional core samples and seven percussion sidewall core samples of the GB Sands from three wells (A43-11, A33-11 and A41-11) from the Middle Ground Shoal Field, Alaska, performed for Shell Western Exploration and Production, consisted of thin section petrography, scanning electron microscopy and X-ray diffraction. The results of these analyses lead to the following conclusions: le The rocks are very poorly to moderately well sorted sand- stones. Estimated average grain size ranges from upper fine to coarse sand (177-1000 microns), with some samples ranging up to pebble conglomerates. The conventional core pieces show evidence of bedding on a centimeter scale. e Compositionally, the rocks are sub-mature mineralogically. Sub-equal amounts of monocrystalline quartz and metamorphic rock fragments (quartzites) are the dominant framework grains. Subordinate amounts of microporous chert, feldspar, argillaceous and volcanic igneous rock fragments, and mica are also present. Other framework components include organic debris and opaque minerals. e The rocks are moderately competent with compaction and quartz overgrowths the main lithifiers. Additionally, clay minerals in the form of deformed detrital rock fragments and authigenic clays contribute to grain bonding. e Both authigenic and detrital clay are present. The major authigenic phase is kaolinite with lesser amounts of illite. Other clays detected by XRD are smectite and chlorite. These clay minerals were not observed using SEM and are thought to be present as components of framework grains such as argillaceous rock fragments, with consequently less likeli- hood of interaction with fluids in the reservoir. e The effects of mineral diagenesis, comprised predominantly of quartz overgrowths and authigenic clay development has detri- mentally affected the quality of the reservoir rock. The fine- grained, better sorted .sandstone samples in particular, have reduced pore space and lowered permeabilities. Additionally, the abundant microporosity associated with framework grains such as chert and argillaceous rock fragments, and authigenic clay minerals may increase immovable water saturations and affect log response. e Overall, the reservoir potential of the GB1 Sand is judged to be moderately good in the Llpper zone, decreasing in quality with depth. Similarly, the GB2 Sand is judged to be good, particularly in the upper zone, again decreasing in quality with depth. Ie ENGINEERING ANALYSIS AND RECOMMENDATIONS Engineering Analysis Ae Both of the GB Sand intervals in these three wells are characterized by moderate porosity, good permeability and high clay content. Be Averaging the available data from the three wells indicates a strong similarity between the GB1 Sand and the GB2 Sand. Item GBl Sand GB2 Sand Gross Height 76 ft. 73 ft. Net Height 60 ft. 57 ft. Hn/Hg ratio 79% 78% Porosity 15% 17% Clay Content 18.5% of bulk 18.5% of bulk Kaolinite 9.0% 8.5% Illite 3.5% 3.0% Chlorite 3.0% 3.0% Smectite 3.0% 4.0% Feldspar Content 17.0% of bulk 18.5% of bulk C~ The highest quality reservoir rock in each zone is located near the top of the zone and the quality decreases with depth in each sand. De Kaolinite and some illite in these samples are authigenic while the chlorite, smectite and some illite appear to be detrital in origin. Ee Both the kaolinite and illite occur as pore-filling materials that are loosely attached to the pore surfaces. The materials are susceptible to dispersion with minimal fluid flow through the pores. Fe Detrital chlorite, smectite and illite are part of the framework structure and are not likely to contribute to potential com- pletion problems. Ge Kaolinite is not particularly sensitive to most fluids in normal use. However, a high pH fluid (8 to 10) appears to have a slight stabilizing affect on kaolinite. H. Illite is rich in potassium which is easily removed from the crystal structure by fresh water or undersaturated brines. The illite crystals may collapse into a mushy mass when potassium ions are removed. Ordinary clay stabilization techniques are not effective with illite because of the very slow ion exchange rate of illite. Illite probably will not stabilize in the time frame of a norma! clay stabilization treatment. II. The low resistivity characteristic of the GB sands, as indicated by the induction logs may be due to excessive invasion of filtrates from the drilling mud, cement slurries and mud spacers. Engineering Recommendations A~ Reducing the water loss of the drilling mud to a range of 1 to 5 cc/30 min. would help to control filtrate invasion. A high overbalanced hydrostatic pressure would increase the risk of excessive filtrate invasion. A water base drilling mud containing diavalent calcium ions at a pH of 9 to 10 could be .considered for these zones. Be The water loss of the cement slurries and spacers should be controlled to 20 cc/30 min. or less. Placing the slurries in the annulus in plug flow will reduce the differential pressure from the annulus to the formation which would aid in controlling filtrate invasion. Ce Perforating underbalanced will allow the formation pressure to purge the critical area around the well bore. However, a high underbalanced pressure that would allow a fluid surge in the formation may dislodge the kaolinite and create an immediate migrating fines problem. The recommended underbalanced pressure is 1500 to 2000 psi. Use the lower value if the fluid level must be lowered to obtain the underbalanced pressure. The recommended minimum perforation diameter is 0.375 inches with 10 inches minimum formation penetration. De Testing immediately after perforating with a subsequent pressure build up survey will identify such problems as migrating fines. Migration of fines is indicated when the rate and/or pressure decrease rapidly at the beginning of the test period, then the rate of decline gradually decreases but fails to stabilize during the test period. Ee A matrix treatment to stabilize the clays may be required to control migrating fines. The recommended treating material is fluoboric acid which stabilizes by structual fusion. The recommended volume is 125 gallons per foot of net pay. A spearhead of hydrochloric or hydrochloric-hydrofluoric acid is not recommended for this formation. If subsequent stimula- tion by fracturing is contemplated, a matrix diverting agent or buoyant ball sealers will be required to insure that most of the perforations are open. Fe If fracturing is necessary, a water base fluid with a pH above 8 and containing diavalent calcium ions (1% to 2% calcium chloride brine) would be appropriate. This fluid should also contain an ion exchange type clay stabilizer and a surface tension reducing agent. TABLE 1 ANALYSES CONDUCTED SAMPLE THIN SCANNING X-RAY DEPTH SECTION ELECTRON DIFFRACTION (FEET) PETROGRAPHY MICROSCOPY ANALYSIS Shell Western Exploration and Production A43-11 Well (Conventional Core Samples) 6965 X X X 6971 X 6986 X X X Shell Western Exploration and Production A33-11 Well (Percussion Sidewall Core Samples) 7021 X X X 7038 7053 7083 Insufficient Original Fabric/Sample Insufficient Original Fabric/Sample X 7118 X 7150 Insufficient Original Fabric/Sample Shell Western Exploration and Production A41-11 Well (Percussion Sidewall Core Samples) 7366 X X 7382 7410 7475 X Insufficient Original Fabric/Sample X X 7494 X X X TABLE 2 ROUTINE CORE ANALYSIS DATA GB~. SAND, A-43-11 WELL (Data supplied by) Shell Western Exploration and Production, Inc. SAr~PLE POROSITY AIR GRAIN DEPTH (%) PERMEABILITY DENSITY (FEET) (md) (gm/cc) 6965 18.1 195 2.63 6971 18.8 169 2.63 6986 16.0 15.0 2.65 TABLE 3 X-RAY DIFFRACTION DATA "Bulk" Mineralogy ( ) ( Relative % of <5l~clay Minerals ) Sample De (Feet) GB ~ Sands A 33-11 Well 7021 70% 7% 10% -% 13% A 41-11 Well 51% 17% 17% 15% 7366 59 6 11 - 24 47 21 16 16 GB 2 Sands A 43-11 Well 6965 80 6 6 1 7 40 9 42 9 6986 64 10 11 - 15 46 16 24 14 A 41-11 Well 7475 62 6 10 - 22 46 18 20 16 ' TABLE 4 THIN SECTION POINT COUNT DATA ( Framework Grain Constituents ) ( Pore-Filling Constituents ) ( Pore Space, ) GB ~ Sands A 41-11 Well 7366 33% 8% 4% 5% 14% 13% 1% 2% -% 1% 5% 7382 21 50 tr tr 7 9 2 - - tr 8 GB 2 Sand A 43-11 Well 6965 25 11 7 2 4 27 2 2 1 tr 1 6971 25 9 4 4 4 26 3 2 - tr 2 6986 25 9 4 5 9 21 2 3 tr 1 4 -% 1% tr 3% 2% 1 tr 2 1 4 2 2 3 5% 1 10 9 8 3% 1 FIGURE 1 A43-11 WELL (6965 FEET) Porosity*: 18.1% Permeability*: 195 md Visible Pore Space: 15% Estimated Average Grain Size: Lower Coarse Sand Sorting: Poorly Sorted Ae The wide variety in grain size and composition and the degree of sorting of this sample are evident in this photomicrograph. Metamorphic rock fragments (R) are the dominant framework constituent, generally consisting of polycrystalline quartz grains with minor amounts of mica. Other framework grains present include monocrystalline quartz (Q), chert (C), and argillaceous rock fragments (A). The cracked framework grains (arrows) and deformed argillaceous rock fragments are indicators of compaction, with minor lithifiers including quartz overgrowths, detrital clay and authigenic clay. Pore space (blue) is common. 32X Be Higher magnification details the nature of the framework grains and pore space. Patchy rhombs of high relief, sparry authigenic dolomite (D) partially replace monocrystalline quartz framework grains (Q). Feldspar grains (F) are commonly diagenetically altered to clay minerals. Leaching and dissolution of unstable framework grain minerals has lead to the development of large, secondary macropores, which are commonly infilled by authigenic kaolinite (K). Note the abundant microporosity associated with this clay mineral. Primary intergranular macropores are much smaller than the secondary pores (arrow). 128X A43-11 WELL (6971 FEET) Porosity*: 18.8% Permeability*: 169 md Visible Pore Space: Estimated Average Grain Size: Coarse Sand Sorting: Very Poorly Sorted Co Mineralogical and textural immaturity is evident in this photomicrograph. Metamorphic rock fragments (R) and monocrystalline quartz (Q) are present in subequal amounts, with lesser quantities of chert (C). Other framework grains include biotite mica (B) and volcanic igneous rock fragments (V). Abundant microporosity is associated with large chert grains. Compaction has resulted in grain deformation (arrow). Intergranular pores are large (blue) and appear to be well interconnected. 32X De This crossed-nicols photomicrograph is the same view as "C" and details the wide range in framework grain composition of this sample. Metamorphic rock fragments (R) appear as coarse, dark and light mottled grains. This is due to the variation in orientation of the individual crystals which comprise these polycrystalline quartz grains ("quartzites"). Other framework grains present include monocrystalline quartz (Q), chert (C) and biotite mica. 32X * Routine core analysis data supplied by Shell Western ( I (, I I ' 0.Sram 0.5mm ~ 0.5 mm ~ ! FIGURE 2 A43-11 WELL (6986 FEET) Porosity*: 16.0% Permeability*: 15.0 md Visible Pore Space: 12% Estimated Average Grain Size: Upper Fine Sand Sorting: Moderately Well Sorted This finer grained sample is comprised of predominantly monocrystalline quartz (Q) and metamorphic rock fragments (R), with lesser quantities of chert (C), feldspar (F), argillaceous rock fragments (A), and muscovite mica (M). Unstable framework grains appear brownish due to partial replacement by authigenic clay minerals. The grains have a "fitted texture", with argillaceous rock fragments deformed due to colnpaction. Muscovite and elongate argillaceous rock fragments show some degree of preferential orientation. Pore space (blue) is common, however, pore throats appear relatively constricted due to the poor sorting and authigenic clay minerals present. 32X Bo Diagenetic alteration of unstable framework grains has lead to the development of large secondary intergranular macropores (II). These pores often contain remnants of framework grains and are partially occluded by diagen~etic alteration products including authigenic kaolinite clay (K). Primary intergranular macropores (I), monocrystalline quartz (Q), and microporous chert (C) are also shown. Quartz overgrowths (arrows) aid in lithifying the sample but are not abundant. 128X A33-11 WELL (7021 FEET) Ce The process of percussion sidewall coring has destroyed all original texture in this sample. Identifiable framework grains include metamorphic rock fragments (R), monocrystalline quartz (Q), argillaceous rock fragments, chert, and mica. Some of these framework grains appear to be in the upper medium/lower coarse sand category. Framework grains are heavily cracked, with original pore space obliterated by rock "dust" and brown and green drilling mud. 32X A33-11 WELL (7083 FEET) De Extensively fractured framework grains and large quantities of drilling mud are evidence of the obliterated original fabric of this percussion sidewall sample. Identifiable grains include monocrystalline quartz (Q), metamorphic rock fragments (R), volcanic igneous rock fragments (V), and chert (C). The larger framework grains visible in this photomicrograph are in the upper medium lower coarse category. 32X 0.5 mm , ,.j FIGURE 3 A33-11 WELL (7118 FEET) A. Ce The surviving framework grains in this sample are in the lower coarse sand category. Identifiable grains include metamorphic rock fragments (R), monocrystalline quartz (Q), volcanic igneous rock fragments (V), and microporous chert (C). 32X A41-11 WELL (7475 FEET) The remnant metamorphic rock fragments (R) and microporous chert (C) grains of this sample are in the medium sand category. Monocrystalline quartz is also present. This sample has been intensely cracked and ground to rock powder due to the process of percussion sidewall coring. Note the abundant dark brown drilling mud. 32X A41-11 WELL (7494 FEET) This sample is intensely fractured, with large amounts of dark brown and green drilling mud present. Framework grains include monocrystalline quartz and metamorphic rock fragments, intact grains falling in the lower medium sand category. 32X FIGURE 4 A41-11 WELL (7366 FEET) Ae Be Ce De Visible Pore Space: 8% Estimated Average Grain Size: Upper Fine Sand Sorting: Moderately Sorted This finer grained sample is well lithified, with quartz overgrowths and detrital clay in the form of deformed argillaceous rock fragments (A) being the main cements. Framework grains include chert (C), monocrystalline quartz, metamorphic rock fragments, argillaceous rock fragments, and feldspars. Both large secondary (II) and smaller primary intergranular macropores are present. 32X High magnification shows white monocrystalline quartz, microporous chert (C), and brownish argillaceous rock fragments (A) present as framework grains. Unstable framework grains including feldspar (F) are commonly intensely leached and diagenetically altered, with authigenic kaolinite (K) a common alteration product. Note the abundant microporosity associated with the unstable framework grains and authigenic clay minerals. Pore space (blue) is further occluded by quartz overgrowths (arrows). 128X A41-1! WELL (7382 FEET) Visible Pore Space: 2% Estimated Average Grain Size: Upper Fine Sand Sorting: Moderately Sorted This sample is very well lithified with quartz overgrowths being the main cement. Chert (C) is the dominant framework constituent, with lesser quantities of monocrystalline quartz (Q), metamorphic rock fragments (R), and argillaceous rock fragments (A) also present. Pore space is relatively scarce with microporosity (arrow) associated with chert. Large secondary (II) macropores are present, formed due to leaching of unstable framework grains. 32X This photomicrograph shows the same portion of the sample as under crossed nicols and illustrates the abundance of finely speckled chert. Less common monocrystalline quartz and metamorphic rock framents and also evident. 32X A ! 0.5mm ' ,~ FIGURE 5 6965 FEET The photomicrographs shown on this plate are successively higher magnifications taken of one area of the sandstone sample. The area shown in the white square is seen in the next photomicrograph at higher magnification. The low magnification photomicrograph presented in "A" shows the general nature of the rock fabric. Note the coarse-grained nature of this sample. Large primary intergranular macropores (arrows) are common due to the coarse grain size. Feldspar (F) is present as framework grains. Closer investigation (View B) details the diagenetic alteration of feldspar grains. Authigenic kaolinite (K) occurs as a diagenetic replacement mineral, reducing pore space. Greater detail (View C) details the morphology of the kaolinite, which is present as pseudohexagonal platelets stacked face-to-face ("booklets"), and as elongate vermiform crystals. Abundant micropores are present between the individual platelets. An energy dispersive spectrum (EDS) was obtained from the area of the sample shown in Photomicrograph C. This spectrum was converted into a table showing atomic percents and is shown in "D". In the succeeding plates of photomicrographs, the elemental data table will always follow the photomicrograph of the portion of the sample from' which the data was obtained. The aluminium and silicon are components of kaolinite and feldspar, with the presence of the cation potassium indicating the feldspar may be potassium rich. The presence of the cations magnesium and iron may indicate the presence of other clay minerals. A - 100X first area B - 500X C - 2500X D - Elemental data FIGURE 5 Continued) 6965 FEET The photomicrographs found on this plate were taken of two other areas of the sandstone sample. Intergranular macropores (arrows) are large. Closer investigation (Photomicrograph F) shows a feldspar framework grain which has undergone extensive leaching. Preferential dissolution along cleavage planes has resulted in remnant elongate fibers and laths (arrow). Books of authigenic kaolinite (K) occur as diagenetic alteration products of feldspar. Note the associated microporosity and the abundance of fine material which may disperse and migrate, potentially decreasing permeability. The third area photographed (Photomicrographs G and H) shows an intergranular macropore partially occluded by diagenetic minerals. Stacked vermicular aggregates of authigenic kaolinite (K) occur loosely attached to framework grains, partially reducing and occluding pore space. E - 50X second area F - 250X G - 200X third area H - 1000X FIGURE 6 6986 FEET A large secondary macropore (II) contrasts in size with primary intergranular macropores (arrows). The secondary pore, formed due to leaching, is partially occluded by diagenetic alteration products. Authigenic kaolinite (K) occurs as intergrown masses of booklets and stacked vermicular aggregates. This diagenetic mineral has formed as a pore-filling constituent, forming micropore space in a former macropore space. Photomicrograph C illustrates the morphology of the kaolinite in detail. Elemental data (Photograph D) shows the 1:1 ratio of aluminium and silicon in kaolinite. A - 100X first area B - 500X C - 2500X D - Elemental data FIGURE 6 (Continued) 6986 FEET The second and third areas photographed detail the diagenetic alteration and disintegration of framework grains. Authigenic kaolinite (K) is present as pseudohexagonal platelets, seen tightly stacked to form booklets, replacing the grains and infilling the surrounding pore space. Elongate ribbons of authigenic illite (I) occur growing on authigenic kaolinite (Photomicrograph F), indicating a later stage of diagenesis. E - 250X second area F - 2500X G - 250X third area H - 2500X FIGURE 7 7021 FEET The poor quality of this sample is evident at low magnification (Photomicrograph A). Abundant fine debris and cracked framework grains are a result of the process of taking percussion sidewall cores. Closer investigation (View C) shows a biotite miea framework grain partially altered, with the edges of the mica grain appearing splayed and abundant authigenie illite elay (I) "growing" on the grain surface. The eations magnesium, potassium and iron are all present in biotite mica, with potassium also present in illite clay. A - 100X B - 500X C - 2500X D - Elemental data FIGURE 8 '/366 FEET Framework grains are shattered and generally coated with fine debris in this percussion sidewall sample. Heavily shattered quartz framework grains (arrows) and heavily deformed mica grains are visible in Photomicrograph C. High magnification (View B) details the deformed nature of biotite mica (B) present in this sample. Elemental data shows the high iron content of biotite mica. A - 100X B - 500X C - 2500X D - Elemental data FIGURE 9 74'/5 FEET Low magnification (View A) shows this sample to be coarse grained, with fine debris surrounding framework grains. Little or no original rock fabric is present. A deformed argillaceous rock fragment (R) is viewed in Photomicrograph B. High magnification (View C) shows the preferential orientation of platey clay minerals present in this argillaceous rock fragment and some associated microporosity. A - 100X B - 500X C - 2500X D - Elemental data FIGURE 10 7494 FEET Identifiable framework grains in this heavily shattered sidewall sample include quartz (Q) and mica (M). Photomicrograph B details a heavily altered argilaceous rock fragment. Authigenic kaolinite (K) and authigenic illitic clay (I) have formed during the diagenetic alteration of this unstable framework grain. Note the abundant microporosity associated with these clay minerals. A - 100X B - 500X C - 2500X D - Elemental data 1151-C BRITTMORE ROAD HOUSTON, TEXAS 77043 (713) 932-7183 TRANSMITTAL LETTER RECORD OF SHIPMENT OF CONFIDENTIAL I NFORMAT I ON TO: Mr. John Boyle State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive FROM: DATE: VIA: James J. Parr Geologist (NAME & TITLE) Anchorage, Alaska 99501 ~UANT I TY DESCRI PT I ON CONTENTS 1 Copy: Geological Analysis and Evaluation of GB Sands, Shell Western Exploration and Production, Inc., A43-11 Well (6965-6986 Feet), A33-11 Well (7021-7150 Feet), A41-11 Well (7366-7494 Feet), Middle Ground Shoal Field, Alaska. INSTRUCTIONS: RECEIVED BY: PLEASE ACKNOWLEDGE THE YELLOW COPY, RECE I PT PROMPTLY BY S I GN I NG AND RETURN I NG DATE: REMARKS: SCHLUMBERGER OFFSHORE SERVICES A' Division of Schlumberger Limited SHELL WESTERN E&P INC. P.O. BOX 527 .HOUSTON, TX. 77001 Attention: LOG FILES, WCK 4147 HOUSTON. TEXAS 77001 JUNE -'21, t985 PI. EA"I' RI'PL.Y TO .AN cHW .*f ~['0~.~L'~[~PORT RD. O~GE~ ALAS~ 99502 ' ATTN: BETH CUZZORT Gentlemen: Enclosed are tBL prints of the CCL/GR Company ..SHELL WESTERN E&P INC. , Well -~$.- 43-11 Field HIDDLE GROUND SHOAL Additional prints are being sent to: 1BL nrints ' SHEL~ WESTERN E&P INC. P.O. BOX 5'27 HOUSTON, TX. 77001 ATTN: BRIAN TEPPER,WCK 1128 on: 2BL nrints SHELL WESTERN E&P INC. 601W.FIFTH AVE;SUITE 810 ANCHORAGE~ ALASKA 99501 ATTN' TIM PUTNAM 1MYLAR 1BL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN' JOHN C. HAVARD 1BL nrints SHELL' PLATFORM "A" OR "C" C'/O SHELL KENAI OFFICE NORTH STAR ROUTE #1 P.O. BOX 485 WIK RD. KENAI, ALASKA 99611 ~.prints 1RROLLED SEPIA P.O. BOX 107839 ANCHORAGE, ALASKA 99510 ATTN: J. L .' WEAVER The film is RETURNED TO SHELL We appreciate the privilege of serving you. prints alaska Oil & ~:: C0,,s. Commission DATE: ~, .... ...... u~ Very truly yours, SCHLUMBERGER OFFSHORE SERVICES OISTIqICT June 11, 1985 Shell Western E&P Inc. 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen' Please find the enclosed monthly report of Drilling and Workover Operations for our Middle Ground Shoal wells. The wells that were worked on during the month of May are' A34-11, A43-11, A32-14, and A22-14. Each report is submitted in duplicate. ~ truly yours, A Sr. Sl~a/ff Environmental Engineer Pacifl'd Frontier Division DLY/kka Enclosures RECEIVED J U N 1 4 1985 Alaska 0il & (]as Cons. Commission Anchorage SBBB/aogcc8 _. ~", STATE OF ALASKA ~.~ ALASKA O,L AND GAS CONSERVATION CC vIISSION "MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation 2. Name of operator Shell Western E & P [nc, 3. Address 601 West Fifth Avenue, Suite 810; Location of Well atsurface Conductor 3, Leg 1. 1627'N & 435'W Sec. 11, Twsp 8N, Rge 13W. 5. Elevation in feet (indicate KB, DF, etc.) 116' KB Anchorage, AK 99501 of SE Corner of SM. 6. Lease Designation and Serial No. ADL 18754 7. Permit No. 65-04 8. APl Number 50- 733-10082-00 9. Unit or Lease Name Middle Ground Shoal 10. Well No. A 43-1! 11. Field and Pool Middle Ground "G" Pool Shoal For the Month of MAY ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth- 8700' 13. Casing or liner ru.n and quantities of cement, results of pressur9 tests NONE 14. Coring resume and brief description NONE JUNi 4. Gas Cons A$~ChoraBe' OO~,un~s~/on 15. Logs run and depth where run Logged well on 5-6 & 5-7-85. See attached, well history for details. 16. DST data, perforating data, shows of H2S, miscellaneous data Perforated well 5-05 - 5-08-85. See attached well history for details. $,,,ED~~J~/'/) T,TLESr .Staff Environment Eno. 6-11.85 , ~ .,,. [ / ~ "' . '/ '"' ' ~'_ __'~ATE. · -' · · .a J__. required. 'z ' NOTE--Report on thi]~/tor_m Is f(~/Ir each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservat~)n Commission by .the 15th of the succeeding month, unless otherwise directed. Submit in duplicate k~l~l_L HISTORY MIDDLE ~0~ SHOAL A ~-11 S-Q1-8~ 5-Q~-86 FINISH DISPLACING MUD UNTIL HOLE WAS CLEAN. ~)OH WITH SCRAPER A~ SEC~ NOTE: RIG OPERATIONS SUE~E~ TO PER~ORATE A ~-11. RESUME OPERATIONS AT O~:OO ~. MAKE UP SEAL A~Y. RL~ IN HOLE WITH SEAL AShY A~D STAB IN SPACE OUT. TEST A~~ TO 1~0O PSI FOR 15 MIN. ~ TEST LI~-S TO 8S00 PSI llJBING A~D ~EAL A~Y TO ?~OO PSI FOR MIN. RUN CCL-GR TOOL FROM BM]O' TO ?lOB FAILED. CHANGED TOOL A~ RERAN. ~EI~C~ATE ~ROM 85~D~ TO 8~QS' (l& SHOTS) W/2 1/0'~ SWS A~ PERF. 'ED 8~36' TO ~' WITH 4 SHOTS A~D TO Ek~~ WITH 4 SHOTS. TEST SURFACE EQUIP~-NT TO ~M]QO PSI. TEST ~B4UTO0~ A~ SAFETY EQUIP. PER~=ORATE E~2O~ TO 8~D~ WITH 4 SHOTS A~ ~t~=. 8335~ TO 8~~ WITH 4 SHOTS. PERORATE FROM 8S?0~ TO 8~Q' WITH ~ SHOTS. RIG U~ FRACTURE EQUIValENT, TEST LI~ES A~ ESTASILISH BREAKDOWN. SPOT 30 8BLS. O~ 15~. HCL OVER PERF. ~S A~ LET ACIO SOAK FOR ~] MIN. Pk~ED 20 iS O~ SLICK H20 FOLLO~ W/ FRAC. FLUIOS. A~E~AGE PRES~ &90Q PSI. CLEAN L~ FRAC. EQUIPS. RUN TEXTURE LOG AND GA~ RAY. FAILED. GELLS REMAI~ L~~EN. ATl~T TO RL~ F~ RAY A~ TE~ATURE LOG. 1~ TO GET BELOW 8150~ (EST. TO~ C~ SA~S). REPAIR KOOk. PICK UP BIT A~D SCRAPER. CLEAN OUT TO 8~~. POOH WITH BIT A~D SCRAPER. RUN CCL-GR ~ROM 8?35' TO 'M]~Q~. ~RAC. ~3P~TION WAS NOT EVIDENCED ON F-~ RAY. ~. WITH ~ ~/0 GL~ FROM 8~' TO 85~8'J FROM 8S~S~ TO ~ROM 8~' TO 8~4~ MEE)M Ek~~ TO 8~ ~ROM 83~2' TO 8~1~'. USED ~ SHOTS IN 121 FEET. TRIP IN HOLE W/ E~IT A~D SCRAPER. CLEAN OUT REMAINING FRAC. SA~. ~33H WITH BIT A~ SCRAPER. CHANGE PIPE RAMS GA~ INJECTION LI~E. NOTE: RIG ~ AT [W~:I]Q H~S. TO A Ji2-1~. RECEIVED Naska Oil & Gas Cons. OommlssJon Anchorage Shell Western E&P Inc. ~ 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil and Gas Conservation commission 3001 Porcupine Drive Anchorage, A1 aska 99502 Gentlemen' Please find the enclosed Sundry Notice for work to be done on our Middle Ground Shoal Well # A43-11. The work will not commence immediately, but a reply is desired at your earliest convenience. If there are any questions, contact Susan Brown at (907) 263-9613. ~./~y Truly Yours, D.L. /~sl and ~ Sr. ~aff EnvirOnmental Engineer SBB/sbb RECEIVED APR 1 1 1985 Alaska Oil & Gas Cons. commission Anchorage STATE OF ALASKA "~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Shell Western E & P, Inc. 65-4 3. Address 601 West Fifth Avenue, Suite 810; Anchorage, Alaska 99501 4. Location of Well Location at surface' Conductor 3, Leg 1. 1627'N & 435'W from SE Corner Sec. 11, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 116' DF 12. I 6 . Lease Designation and Serial No. ADL 18754 8. APl Number 5o-733-10082-00 9. Unit or Lease Name Middle Ground Shoal 10. Well Number A43-11 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see the attached prognosis for details of the work to be done. RECEIVED APR ! I 1985 Alaska 0il & Gas Cons, Commission Anchorage 14. I h a nd Signed/~./;'/~ ,/ ~/~.~,~~// The ,pace'belo'w/for/C~i~i0n use / Conditions of Appr~l, if any: / Approved by correct to the best of my knowledge. Title Sr. Staff Environ. Engineer Date 4-3-85. Approved Copy R#turngld By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate sTATus: OBJECTIVE: WORKOVER PROGNOSIS A43-11 W. H, ROOM #1 CONDUCTOR #3 PLATFORM A MIDDLE GROUND SHOAL FIELD 'Well producing 75+_ BDO, 70% Cut. ull tubing. Isolate zones with cement squeeze and 5" inet. Perforate and. frac Lower Hemlock. Return-to production. - MECH_AN_ICAL DETAILS: See' attached schematic. Note: probably holes in tu)~ing at 7,182' and top of junk at 8,620'. PROCEDURE: r III Zm Shut well in and allow to build up. Bleed off annulus. Circulate well through tubing hole at 7,I82' with filtered injection water taking returns out annulus. Rig up wireline with tubing punch. Perforate tubing between each isolation packer if needed to be sure all zones are. in communication with-tubing string. Determine mud weight needed to kill well (up to t2.5#/gal, may be possible). t Kill well by circulating mud down tubing, around through hole in gas lift valve #7 at 7,182' .and taking returns out annulus. Circulate and condition mud until stable. 1 .M.I.R.U. Set BPV in tubing hanger. Nipple down tree. Nipple up BOP. Test BOP to 3000 psi. Pull BPV. Pull bind on tubing. If packers do not pull loose (most likely the case) RIH with chemical cutter., Cut tubing at 7,230.'. POOH and lay down tubing. Cut and fish as necessary to recover hydraulic packers. 4. . RIH with burning shoe and mill over Baker F-1 packer at 8,313'. Recover packer,- .. m '~ . . _ RIH with bit and scraper..Clean well oUt to top Of junk at 8,620'. POOH---'-, ' ' . Rig up wtreltne. Run GR/CCL from 8,620'-7,,200'. Send results to Houston for evaluation of possible production test before proceeding. Run-casing caliper log from PBTD to surface [o determine condition of Casing'. TelecoPY results to Houston. TSB$084! 8. g~ E. Area around 7,ZSZ~ ts of special concern ~he~e Ictd ts kn .Arm to have _- u : n-O !e-~tng annulus. Run tn And set drtllable brtdge plug on wtreltne at 8,Z56', Run Jn wlt:h Baker "K-l" cement retatner with slldtng valve, and set ~t~h ~rel~ne a~ 7,750'. R~O d~ w~e1~n~. Establish an injection r~te of I BI~. NOTE: Have following cement tested for at least 4 hours pumptng ttme before Pumptng. 200 sxs class 'a" cement Ir, 0-19 flutd loss 0.1~; A-2 accelerator ~.~. 0.1r, 0-6 Oefoamer 4.96 Gal, H~O/$ack cement: .The Above mTxture yields 1.15 cu. ft./sack cement ~v~th 70-80 cc flutd loss And an approximate pump ttme of 3.6-5 hours 10. Pull @ut of retatner"and begtn pu.mptng squeeze cement. Pump BBLS (_1,150' tn 3-.1/2" 1~or.k~.trtng) fresh ~ater followed by 200 sacks (230 cu. ft,) Class "G" cement. Follow cement with. 10 fresh trater, NOTE: Perforations are open above retainer. Check for loss of returns during cement: displacement, monitor annulus closely for flo~ throughout squeeze ~lob, ~f con~nun1¢atton with the annulus is established during ~lob, tnTnedlately pull out of retainer and equalize remaining cement on top of retainer. Pull ~0 stands, and reverse circulate. Pressure up on annulus and.braden squeeze perfs above retainer. Contact Anchorage and Houston concerning further squeeze attempts. · 11. Stab into retainer ~hen cement Js l,OOO' above retainer. Pump at a maximum rate of ~ BPJd. Tf 1000 ps~ squeeze pressure above pump pressure is obtained pull out of retainer and reverse out excess cement. Zf squeeze is not obtained, dJsplace to top of retaJnet~ pull out and reverse circulate. 12. Pump 25 BBL (2800' tn 3-1/2" worksteJng, 1000~ tn 3-1/2" x 7" annulus) fresh water follo~ed by 150 sacks of Class "G" cement (same mixture as step 10). Follow cement wi. th 10 BBLS fresh water. £qualtze cement on top of cement retaine~. Pull 20 stands and reverse circulate. Close pipe rams and pressure up to obtain bratden squeeze on perfs at (7,262'-7,2B8') and (7,608'-7,662'). POOH. w~. TSBS0841 1~':0~ HOU RROD ~NGR N0.005 00~ 13. RIH with bit and collars and clean out cement to 8,620'. Make bit and scraper run to 8,6;?0'. Run 5" Liner NOTE~' L(ner will be cemented wtih 120 sacks of Class "G" with the following= 0.75% D-lg fluid loss 0.3% D-31 friction reducer 0.2% 0-6 defoamer The above cement yields 1.14 cu. ft./sack with 100 cc fluid loss and an approximate 4 hour pump time. Have above cement tested with platform water and cement prior to pumping. .. 14. Run liner as follows-' Ltner shoe 30' 5" 18# S&lP liner Landing col lar 1400' $" 18// SF,.1P liner 20' PBR - Liner Hanger Liner packer with tie back receptacle setting tool NOTE: Keep liner filled while RIH. Extreme care should be exercised while installing liner wiper plug on polished extension nipple in setting tool. Record weight of 1 tner. 15. With shoe on bottom break circulation and circulate bottoms up. Attempt to reciprocate liner. If possible reciprocate liner through cement job, 16. Pump 25 BBLS fresh water. Mix and pump 120 sx Class "G" cement. Release ball and-pump down plug. Slow pumps down as pump down plug reaches liner wiper plug. 17, Continue-pumping until bal-1 seats. Release pump pressure, and position liner Just off bottom. Pressure up to set liner. When 1 inet is' set shear' out bal 1 seat. 18. Continue pumping.until wiper, plug lands.. Test plug to 1000 PSI above circulating pressure. 19.. Set rotary slips leaving 30,000# on swivel and cement manifold. Rotate to right 8 turns, check for torque. Continue to rotate to right.20 torque free turns. 19, Pick up 5' to position setting dogs for packer. Note loss of liner weight. Slack off 20,000#, repeat several t~mes to ~nsure packer is set. ~ TSBS0841 20. Remove setting tool from liner and reverse out any excess cement. POOH and WOC. 21. RIH with 4-1/8" bit, casing scraper, 1500' 2-3/8" tubing and drillpipe. Clean out to 8,610'. 22. Test casing to 1500 psi Reverse mud out of hole using filtered injection water. Continue circulating until clean. POOH, RIH with 6" bit and scraper to top of liner. POOH. 23. RIH with 4 - 7/38" polished mill and dress PBR. Circulate NE(: pill to insure hole clean. POOH. NOTE: Undetbalanced liner lap test may be-required dependent on liner cement Job, 24. RU wtreline. Test lubricator to 1000 psi. Run CCL/GR from PBTD to 7,110'~. Co~relate log with SWS DIL dated 6/3/65 or SWS CBL dated 6/10/65. 25. Make up 3-3/8" 4OSPF casing guns. Perforate interval from 8,$10' - 8,600', Rig down wireltne. NOTE: If well is not dead, killl well with NeC1 {up to g~/gal.) weighted fluid. If higher weights are required weight using CaCl3. Filtee all weighted fluids through 2 micron filter. Lower Hemlo¢,k Frac Surface pumping pressure may approach 7_~z(2Q_p~t at rates up to 15 BPM. ~1o unnecessary personnel should be in the area during the pumping phase of operation. Pipe ram BOP and drilling spool are rated at 3000 psi. Annulus -pressure will be carefully monitored throughout job. 26. RIH with 3-1/2" 9.3#, N-80 Frac .stPing as follows: 1 Joint 2-7/8" tubing TIW locator seal assembly,with latch I ~lotnt .2-7/8" tubing 2-7/8" x 3-1/2" cross-over RECEI'VED APR'i ~ 1985' 7,150'-3-1/2" tubing Alaska Oil & Gas Or, ns. Ou,;~mission .- 27. Tag locator. Space out as necessary to have collar tmmeo~a:e.~ below pipe rams. Latch into polished bore. ~8. . ig up-1 nes and equipment Test all lines from pump to tubing to 8000 pst TSB508¢I 04×02/05. 1~:10' HOU PROD ENGR N0.005 005 ...... _IL · 29. Heat water in 500 BBL frac tanks to 75°F. Mix pad and pre-pad with fresh water as below:- 300 .BBL Pre-p..ad {Slick Water) ~"ZO~/lOOO'gal, SF i'I 'YF4~SD 3~ KCL 0.05[ M76 Bactericide 0,2~ F75N Surfactant 475 BBL Pad Containing: 40#~000 gal-j" SF II YF4PSD 3% KCL 0o2~ F75N Surfactant 0,05% M76 Bactericide 0.5#/1000 gal. J-218 Breaker-(Additional [~/gal, to be mixed on fly) 0.5% XE6755 Hydrocarbon Fluid Loss Additive Before start of job, do sieve analysis on 20-40 proppant. Save sample. After pad and pre-pad are mixed, check for crosslink time using wartng blender for pad and save sample of both. A maximum of 5 minutes crossltnk time is required. Adjust crosslink activator concentration as necessary, 30. Pressure up annulus to 1000 psi. Maintain and monitor pressure through out job. 31, Start pumping pre-pad at 3 to 5 BPM. Increase rate slowly to 15 BPM, Monitor backside and tubing pressure through out job. Maximum allowable pump pressure is 7620 psi. This maximum pressure is based on tubing burst with a 1,3 safety factor. Pump job at 15 BPM: VOLUME COltCENTRAT !ON (BBL) CLEAN SLURRY ~ 100 '" Pre-pad slick water 0 20O 200 Pad 0 24 2~5 Pad I#/GAL ' 100 MESH 24 25.8 Pad 2///GAL 100 HESH 20 20 Pad 0 24 25.8 Pad 2~/GAL 20-40 ISP 60 69.2 Pad 4#/GAL 20-40 90 110.8 Pad 6#/C~kl. 20-40 ISP 83 BBL Pre-Pad Slick Water 0 Check crossllnk time using war~ng blender during initial pad, Adjust activator to achieve 5 minute crossltnk. Catch sample and check cross link time at beginning of each stage. TSBS084.1 -,, 04x02x85 · 15:11 HOU PROD ENGR N0.005 006 Displacement calculation starts when densiometer indicates decreasing density {i.e., 5.g#/gal. instead of 6.#/gal.). Do not overdisplace. Tubing and 5" casing volume to perfs is 83 Bi)L. 32. RU to run temperature survey. Wait 4 hours after Job completion. Run survey from PBTD to 7,100' at intervals of 4, 8, and I2 hou~s after job. Send results to Houston with additional fracing contingent on results. 33. Unlatch and POOH. RIH and clean out to PBTD with filtered injection water. POOH, 34, PePt~Orate remaining zones with 3-3/8" 4dSPF casing gUns on wtreline. Exact zones to be determined, by GR/CCL logs. Probably perfo~atlng length will probably not exceed 235' over a g~oss interval of 280'. 35. RIH with-bit and scraper to PBTD. Circulate hole clean. POOH. 36. Run production equipment as per attached sketch. NOTE: Do not run latch on seal assembly. 37, Space out. Install BPV. Nipple down BOP. Nipple up tree, Test tree to 3500 psi. Pull BPV. 38. Bring well on slowly for first few days to avoid producing back frac sand, APPROVED: ,.. DATE: TSB:Jc TSBS0841 XEROX TELECOP ! ER Q~.,/02×85 · · · · . .. ii .... _ 295 ; 14:52 . · · ,~--?:IU,P~OD ENG~ NO. L30.~.,, 13136 .' · 2 / . N-80 6.5~.EUE , . 7262 1288 ' HE-HF .8026~8051 x- ' · .. . · Hi-HK 8122-6306' .. . ' ~4×02×85- 1'4:54 r HOU PROD ENGR NO. ~3 RECOMPLET! ON D I ~ 43;-11 PLATFORM M!DDLE GROUND 8NO,N,. F I ELD 1 2 4 5 6 10 11 12 14. ITEM NO. DESCRIPTION 1 · OT !B BALL VALVE 2. KBU8 MANDREL 1 it I1 ~ ~ II II 6 1 tl II 1 I! II ~. TIW LOCATOR 10. T IW PBR & SEAL AS~EM 11 , L I NER HANGER 12. OTIS "X' NIPPLE 15. WIRELINE REENTRY GUIDE 14. PBTD DEPTH ~00 2000 3600 4900 6400' 6900 7100 7140 7190 7220 7221 CABIN8 1~ 5/8", ~4o~#, ~-~ SHOE e 1609' 7"ii 29#~ N-80, XL'INE W/SHOE 8 8790' LINER 18# N-80 SF~P ~/SHOE ~ 8&20' TUB Z NB 2 7/8" & ~# N-GO EUE BRD P08~; I BLE PERFORAT IONS HK/HN 8170'- 8280' HN/HR 8325'*- B450' H~/HZ 8510'- (FRAC INTERVAL) July 13, 1983 Shell Oil Company Q 200 North Dairy Ashford P. O. Box 527 Houston, TX 77001 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' In response to the July 1 letter from The Commission's Mr. William Van Alen, we enclose a complete history for Shell's West Mikkelsen Unit No. 4 well. The well's mud log was transmitted under separate cover last week. The requested reports of production tests, including time intervals, quantity and description of recovered fluids and pressure data were included on the Well Completion Report (Form No. 10-407) which was sent to the Commission on June 3. A separate page of the Well Completion Report Form was submitted for each of the four production tests. No drill stem tests were performed. Also enclosed are the following routine reports' · Sundry Notices - Subsequent Reports for Middle Ground Shoal Wells A12-O1, A42-11, A43-23, C23-23, C44-14,~A43'11,'A42-14, and A24-01. · Monthly Report of Drilling & Workover Operations for Seal Island Well No. BF-47 #1. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH 'mh Enclosures · -~- ¢ ': STATE OF ALASKA ~ ALASKA UlL AND GAS CONSERVATION CO,~IMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~X OTHER 2. Name of Operator ~_~ermit No. Shel 1 Oil Company 65-4L~ ~..Address ~--I 8'A~m~e~-- 0' -- John Doualas, P.O. Box 4500, Kenai, AK 99611 ~ ~"~ ~~ --I 9. Unit or_ Lease Name . -- ~ Shoal 1627'N & 435'W from SE Corner of Sec. 11, T8N, R13W, S.M. I 10. WellNumber -- I 11 .Field _and Pool . -- I Middle Ground Shoal 5. Elevation in feet (indicate KB, DF, etc.) } 6. Lease Designation and Serial No. ~ __ 116' D.F. I ADL 18754 ~ 12. Check Appropriate BOx To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). June 9, 1983 - Rigged up coiled tbg and tested equipment to 5000 PSI. Repaired leaks. R1H and circulated ¼ BBL/Min. POOH. Stopped @ GLV @ 6906. Chan~ed BHA. RIH Spotted 5 BBLS 10% HCL on top of bridge @ 7552' Drilled out bridge. Ran to bottom @ 8620. Pumped 800 Gal. P-20, ~00 Gal. 10% HCL, 1600 Gal.~CL-HF 7½-1½%, 800 Gal. 10% HCL. Displaced with diesel. RTP. 14. I hereby certify that tl~e foregoing is true and correct to the best of my knowledge. The space below for Commission use Title Manager Prod. Adm. Date 7/12/83 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 / Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELL, S 1. DRILLING WELL [] COMPLETED WELL ,,, 2. Name of Operator SHELL OI'L COMPANY .. John Douglas, P.O. Box. 4500: ..Kenai, AK_ 99611 . . 4. Location of Welt 1627'N & 435'W from SE Corner" of Sec. 11, TSN, R13N, $.M. 7. Permit No. ~5-4 8. APt Number so: 733-10082-00 9. Unit or Lease Name MGS 10. Well Number A43-11 11. Field and Pool OTHER [] I , r MIDDLE GROUND SHOAL 5. Elevation in feet (indicate KB, 'OF, etc.) 1 6. Lease Designation and Serial No. 116' D.F. I ADL 18754 '12. ' ........ Che:~ '/~pPr01~riate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing ~ Stimulate ~ Abandon [] Stimulation [] Abandonment I-] Repair Well (-] Change Plans r-~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report muitipte completions on Form 10-407 with a submitted Form 10-407 for each completion.) '1~. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including astimated data of starting any proposed work, for Abandonment see 20 AAC 2{5.105-170). RECE)¥ED MAY 0 5 1983 Alaska 0ii & Gas Cons. Commission Anchorage See Attached 4/19/83 14. I hereby~rtif¥ that ~he foregoing is true and correct to the best of my knowledge. Signed , · 9~ ~ Title Production Administration The space below for Commission use Conditions of Approval, if any: Approved Copy Returned_ ORIGINAL SIGMED BY L~tiHIE C.. SBITIi By Order of Approved by COMMISSIONER the Commission Form 10-403 Submit "Intentions" in Triplicate AUTHORITY FOE EXPENDITU~ ' ~~1[1' I. ~ ~l~I~'1 J. II I I , ] . I i~m~ ~111~ ~111~1 ~1 i A43-11. Middle Ground Shoal. Field 4/1g/83 Kenai, Alaska ~ ~ ~~ m '1 [ m m . m I m · m mmml m m m m m m ~. OMO~M ~ :~I~ON ' ~ .......... ~.~ ~ .~ ,, ..... ............. · ..... ] .... ........ -R&R Clean out and acidize with coiled tubing $49,000 $16,300 $16,300 ReCo~ended by- J.H Douglas T.S. Burns. Non Operator Approval Not Requi red ~~,~ $49 000 $16 300 $) 6 300 "~... ' . ~ m m mm.' 'm ~ ~ F )' )mm[ m mmml ~ I)) ~ m ~m ~ JlL ~ m m m m ) m m mUOG~ N 8Y ~EV~SmON tOTaL COST . ,,,,,,,, ,,_r,,, , ,,, , ' ' "I I/I I [ / I I I I I' I '1 I I II [ I I I I ~1 I]11 . See attached 3ust~fication. , CONTINUKD I I I I.I I I I Iilll ~ I I I II I I [ ~ ~ ~ ' ' ~ ~ M APP~OVA ~ z ~- . 'j ~ ~ -~ ~ m m m m r m m ' J m i m m m mm m m m m m I I I IJ I II I I I i I I I I I II I A43-11 Justification Coiled Tubing Cleanout and Acidization Funds totalling $49,000 ($16,300 Shell's 1/3 share) are requested to cleanout and acidize Well A43-11, Platform A, Middle Ground Shoal Field, Kenai, Alaska. Well A43-11 was the first well drilled on Platform "A" and was completed in July 1965. A 43-11 produced a maximum of 2200 BDO (1% cut) in July 1966, but decreased rapidly to a rate of 650 BDO in October 1969. A43-11 responded to waterflood in 1970 and production increased to a peak of 1300 BDO (9% cut) in 1973. Shortly thereafter, major water breakthrough occurred and production dropped to 300 BDO (50% cut) by 1977. In 1977, well A43-11 was pulled to cleanout mud sediment in the tubing casing annulus which hindered gas lifting the well. Isolation packers were run to shut off the watered out zones. After the well was recompleted, an attempt was made to acidize the lower zones in the well. During the acid job, the lowest most gas lift valve leaked and the majority of the acid u-tubed into the tubing casing annulus. The acid partially destroyed the gas lift valve and it appears that several holes were made in the tubing. The 1977 well work was justified on a minimum 350 BDO increase in production, but resulted in a 150 BDO decrease in production. The well work was also justified because of the significant reserves remaining in this area of which A43-11 is the only drainage point. The production of a major portion of these reserves will never been realized, without a more efficient draingage point in the area. For these reasons, A43-11 has been a redrill candidate since 1980. From the production characteristics of this well, it appears that the oil bearing zones have near wellbore impairment. It is felt that an attempt should be made to repair this damage before a redrill is attempted. If a significant increase in production occurs, the well will remain on production and R&R work will be considered to repair the mechanical problems in the well. Over $1.5MM could be saved if the stimulation followed by well work is successful. If the stimulation is unsuccessful, an AFE to redrill 43-11 during 1983 will be prepared. Your approval is'requested. TSB :mh Status: Coiled Tubing Acid Stimulation A43-11 Pt atform "A" W. H. Room #1 Conductor #3 Middle Ground Shoal Field ~ Kenai, Alaska ~'~ ~ Well gas lifting 40 BDO (80% cut) from GN through HZ zones. Mechanical Details: See Attached Schematic. Purpose: Remove tubing patch, place dummy mandrels across probable wet zones, clean out to bottom perforation with coiled tubing, acidize with coiled tubing, and return well to production. Procedure: Note: Conduct Steps i through 5 well in advance of rigging up coiled tubing such that changes in the prognosis can be made if unexpected results are obtained. 1. M.I.R.U. wireline and lubricator. Test lubricator to 3000 psi. Pull ball valve. 2. R.i.H. with gauge run. Clean out tubing as necessary.down to tubing patch across gas lift mandrel #7 (+7182'). P.O.O.H. 3. R.I.H. with pulling tool and pull tubing patch (+7182'). P.O.O.H. with tool and tubing patch. 4. R.I.H. with gauge run. Clean out tubing as necessary to bottom. Tag and record bottom depth. If fill is present, R.I.H. wi th .wi rel i ne bailer and obtain sample. Send sample to Dowell for acid and solvent solUbility testing. Place dummy valves in mandrels #9 (7839') #11 (7999') and #13 (8082'). Rig down wireline. Return well to production. Note: Have copy of all test results sent to T. S. Burns, Houston. 5. Obtain oil sample from flowline and send to Dowell for compatibility test with prognosed acid treatment. 6. M.I.R.U. coiled tubing ~nd Dowell acidizinq equipment. Fill lines and coiled tubing with filtered inlet'water to determine displacement volumes. Test lines, tree, and coiled tubing to 5000 psi. Test hydraulic system and B.O.P. Place well on test separator and monitor production closely throughout operation. 7. With well flowing, open swab valve and pump filtered injection water through system at 1/4 bbl/min to flush system. After system is flushed, filter all fluids through a 2 micron filter positioned immediately before coiled tubing (see attached piping sketch). Cut back pumping rate to a minimum (1/8-1/16 bbl/min). Be prepared to choke pump outflow line if the equipment will not pump at a slow rate. 8. R.I.H. with coiled tubing (no more than 100 FPM). If well's production interferes with coiled tubing, choke well back at surface. Note: Do not pump down coiled tubing at a rate faster than the returns and production rates out the flowline. Attempt to maintain flowing well conditions at all times. An increase in injection gas may be necessary to keep the well from loading up. 9. Tag fill and record depth. Attempt to circulate fill out of hole using filtered injection water. Use 4750 psi maximum pumping pressure and produce well at maximum rate with minimum back pressure. Note' Keep coiled tubing moving at all times while circulating fill to help prevent bridging which could stick tubing. 10. If penetration rate is slow or cannot be established, pump 2 bbls 10% HC1 with additives (see attached for composition) _ Follow acid with filtered injection water and continue cleaning out operation. Note: Repeat step 10 as needed if successful. If cleanout operation is determined to be unsuccessful, proceed with acid stimulation across available perforations. 11. Clean out to below bottom perforation at 8612' Circulate bottoms up while continuing to move tubing. Circulate until production is clean (no particulate fallout when centrifuged). Pump 50 bbls diesel to displace injection water out of well. 12. Shut well in at surface and allow well to build up and stabilize, Maintain 1000 psi casing pressure. t3!~.~With the coiled tubing on bottom, pump 800 gal P-20 solvent "~own coiled tubing at 1/4 bbl/min. Move coil uphole to treat ZO~ entire ~nterval (8612'-8292'). With coiled tubing on bottom, pump 800 gal (19 bbls) 10% HC1 with additives down coiled tubing at 1/4 bbl/min. Move coiled tubing up hole while pumping to treat entire interval (8612'-8292'). 14. With the coiled tubing on bottom, pump 1600 gal (38 bbls) 7-1/2%-1-1/2% HCl-HF acid with additives at 1/4 bbl/min. Move coiled tubing uphole to treat the entire interval (8612'-8292' ). 15. With the coiled tubing on bottom, pump 800 gal (19 bbls) 10% HC1 with additives at 1/4 bbl/min. Move coiled tubing uphole to tPeat entire interval. Displace acid to end of tubing with diesel and pump an additional 5 bbls of diesel to flush coil. P.O.O.H. with coiled tubing. 16. Bring welt on. production on a 12/64" choke. Monitor acidity of produced fluids. Increase choke size every 4 hours and record production rates hourly. When tubing pressure reaches separator pressure, open choke to 128/64". Take well off test separator, but test daily until stable. 17. Further instructions will follow concerning reinstalling tubing patch. Approve... Date Coiled Tubing Specifications Working Depth (1.255 S.F.) Max. Working Pressure Tensile Strength Tubing O.D. Tubing I.D. Wall Thickness Capacity Tubing Weight 16,500' 5,000 psi 15,300 lbs 1.00 in. 0.850 in. 0.075 in. 0.702 bbls/lO00 ft. 29.48 gal/lO00 ft. 0.63 lbs/ft. Cost Estimate A43-11 Coiled Tubing Cleanout and Acidization 1, 2. 3. 4. 5. 6. 7. 8. 9. 10. 800 gat P-20 solvent 2000 gal 10% HC1 1600 gal 7-1/2%-1-1/2% HC1-HF Acid Additives Pump 2.5 days Tanks 2.5 days Lines 2.5 days Personnel 3 days Coiled Tubing @ $5000/day Miscellaneous Total Add 10% Contigencies Say $ 3,600 2,000 3,200 2,200 5,000 2,000 4,200 9,200 12,500 2,000 $~5',9oo $49,000 Acid Additives Composition 10% HCl (Hydro6'hlori'c Acid) 0.3% W-35 (antisludge) 0.4% F-75N (surfactant) 14 lbs/lO00 gal L-41 (iron sequestering 1.2% A-200 (inhibitor) 7-1/2% - 1-1/2% HCl-HF (Mud AC i d ) 0.'4% W-35 (anti s 1 udge) 0.4% F-75N (surfactant) 14 lbs/lO00 gal L-41 (iron sequestering agent) 0.8% A-200 (inhibitor) SN-GI :qR-HZ DATUM 38' · · . , May 1977 '-' 'Item 'Np .' .DJscri Pti on · 20. .o g, - . . '.-'lO." .-.. _ '.' .. 11.- · · 12. .1.3. . 14.' ' '15. · 16:" 17~ .. · 18. '"' 19. · . ,. · . . ~ · Otis -AO. Bal 1" .Vaive' .Ni.p~l.e [gM'Mandrel ·" .- --II · .--I! , o..'. · : ' .. · . 11 Il ., . ' ' · .. . · Ii , ~1. " · · . · 11 ' · II . · It ' '. II '. ·. ' II . ' II · Guibers'on .U'ni'packer" VI KBM Mandrel w/Dunmy ', Gu~berson' unipacker VI.t' KBM Mandrel. ,m~mi~y: ' - Guiberson UniPacker, vi':i]i.: · · · KBM Mandrel ~W-~m~./....- -' · Gu~ berson Uni packer..:'.. · KBM Mandrel ~d~m~v-'. · .. Baker Locator ' Baker -Seal s · " ..' ...'.-Otis X Nipple ..Guiberson Shear Sub. "CASING. · . · . · · . · . . . . · . · , · · ., · . · · · .. . · · o ,, ,, ; , ., · · !. · , : · · . · 1.998 · .' - · 3621 ...' .... · 4897 .." .,.. · · · 5834· ., ... . . 6459 · - /. . 6906 .... - 7182 7251" '.-.".- "," .. · · 7851"..',..'.'.. ' ,, .. .. 7999 ' ' 1. -". · .. . · · 8013.' ' ." 8082..'"'::" ::-': '" : 8096· ' '""r ' , -. . 82'92 "" ' · 8309 '"""'- .' ' , .-. '.. . " '~' ' t i 8310...· ,.,. ,, ..., '8313' i.' '.' .. ',-, · ,~, 8330 ' ,.. · . · 8341" . . · i2 14 .o 7-" 29# N-80 Ektremel. ine w/shoe @.'8798' :. . SURFACE'PIPE '. ' ... 13 3/8".J-55 54.5# w/shoe.@ 1609" TUB lNG : " · 2 7/8'.' N-80 6.5# .EUE' PERFORATIONS GN-GO GR-GS ' ' HC-HD HE-HF HI-HK HR-HZ ~7262-7288 7608-7662 7886-7968 8026-8051 8122-8306 8314-8612' Page. 50 PIPING DIAGRAH COILE~ TUBING 6, CLEANOUT ANlq ACICiZAT!ON A 1 :]-:-%12; A a 3-1 !, C31-2/_-. ' I¢~% HCL O. 3% W-35 O. 4% F-75N 25 LBS/1000 G L-41 ~ 2% A-200 C ~ i . i i L I I I I I LLI · F'-20 :=;OLVENT i, D I ESEL IN.JECTION WATER FROM WATER PLANT ...... : , , , /E~i '--" M I C:RON-L,,(--';~, H C:O ~ LED ! FLOWLINE TO TE:--.;T SEF'ERATOR~'- WESTERN E&P OPERATIONS I I.DDLE GROUND SHOAL FIELD SHELL-ATLANTIC-STANDARD , I I I I-ILII 1 l I I I ! ! ! / ~.~'~ : ' J POS . IS4,1~J / ,~, / J ,,,,, ,- / -- i-~ / t ~ P si2o ~ · ~, _ / T t '- ~a ~ / i INJECTION WELL ~~ / t ' , l I ~ , t I RODUCING WELL : , 1~--.~.. , , J .P~ pLUGGED & ABND ', I July 30, 1980 Ms. Marjorie A. Chan earathon Oil Company ological Research Dept. P.O.' Box 269 Littleton, Colorado 80160 Re: Preparation of petrographic thin sections from state well sample library. Dear Ms. Chan: This"is pursuant to and in confirmation of your July 23, 1980 discuSSion with Harry Kugler and John Levorsen at this office concerning Marathon's preparation of petrographic thin sections of samples from the designated intervals in the following wells: Sample Set No. Well Interval 46 Chevron Beluga Riv.#l (212-35) 15,8~0-90 89 Shell MGS $ A-43-11 9,710 70 9,830-40 24 Std. Oil of Cal. Anchor Pt.#1 14,450-70 14,650-70 93 Mobil Oil Granite Pt.#1 11,540-65 121 Hunt Oil Oldman's Bay St.#l 12,080-100 It is understood that Marathon will bear all costs entailed and will provide the Alaska Oil and Gas Conservation Commission with all thin sections prepared and return all remaining sample and core residues. No thin section or sample material is to be retained by Marathon. All thin sections and remaining sample material are to. be received by the Commission by January 1; 1981. All materials are to be transmitted to the Commission and are not to be examined by other parties. ~ Please understand that the State's Well sample library is public property and that granting Marathon permission to extract por- tions of material from-the library for the purpose of providing the indicated slides enhances the value of the library and is in the public interest. Very truly yodrs, William Van A!en Petroleum Geologist cc~ Robert M. Hiles Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 WVA~mm ~:'- ...... ~--"-. DEPARTMENT OF'NAT~L RESOU~ES - '-" ~ . [~ -'= ~ DATE = January 8, 1974 .. - . -='- ~Ro~ SUBJ~T, DO~4HOLE STORM CHOKE FA! LURES /~"/~ % ~- John C. Mi I ter '~ ~ ~..~ - Petroleum. Engineer '~ ~ _ SHELL, M~S ,PLA~ORM 'lB", WELL / ~:?.:- - November I, 1973 -.A platform inspe~ion on Shell's ~S ~latform "A" found the ?" Type t'H" sto~- choke'.: i-n Wel I No. I !-! to"-.leak ve~ si lghtly. Also, the TYpe'~ .... ~ -: '"H":sto~ ch°ke i.n. Well No. t3-I Upper failed to close and the Type "K" sto~ '.-t - choke in Well ~. -43-11 failed to close. . :' November 26, 1973 - ~b Grote, ~latfo~ "A" forth, called and advised that-they had pulled the storm choke out of Well No. I1-I, repaired It, and reran, tt In the well. That storm choke now operates properly without leaking. They also pulled the storm choke from Well No. 13-1 Upper, repaired it, reran tt and it' no~ operates properly. The Type 'K" storm choke in Well No. 43-11 was pul led, cleaned, and reran. It ope~ted irrafical ly and therefore was pul led a second time. The sa~ choke was cleaned, checked and rerun. Again it ope~ted ir~tically and was pul led a third time. The choke was sent to Anchorage whe~ they disassembled it and found a sheared pin which al lowed only pa~ial closure. Parts for this Type-'K" Storm choke were ordered by . air on November 16, I973. ~ December .28, 1973 - ~b Grote again cai led fo give me a report on the Type " sto~ choke~e I ! No. 43- I"~[. The parts were received and the-repaired choke was installed in the well on December 21, 1973. It was tested and it operated properly. On December 24, 1973, the. valve closed during-a routine platform shut-in but would not reopen. On December 25, 1973,.th~s T~pe .'K" storm choke was again pulled from the well and when disassembled it was found that the pin that had ~ust been replaced was broken again. Now, two Type 'K' storm choke replacements have been ordered for this well. Bob will advise me when these arrive and one is installed so I can witness its operation. JCM:oJ ~_'.'. ' t" ~t_.: 2 .... .':' .... ........... (.i:) tt~].)'~t~( ~)~'-'~::1~: Pressure Test ~': ~'- (')~::~:'~(.~ ) :~'-: 12, -'~P Pressure Test :: ::~¥:-'"~ ~Urface.?~` (.:)-:i~.!'[~:'(':-):.'t.:~;14-,:: ....... :.Pit Be~ . ~?~-:[ ....... (').?~?/():~:' 15,':. Location Be~ -. . . ':':-: ,' '"[ ',.]. ~-:. ::'~'~T -::- ' -. . .- ~o~- . . ...... .....~. ,, /_. t.~. , -,' ~ .~ ~- , . , April 16, 1973 Released to Mr. Jerry Sager, ditch samples (320-9840) of Shell Oil Company SRS MGS State #43-11 {A-l-3) for ship- ment to Los Angeles, washing and drying, and return to our offi ce. SHELL OIL COMPANY 201 NATIONAL BANK OF ALASKA BUILDING 5TH AVENUE AND E STREET ANCHORAGE, ALASKA 99501 August 11, 1965 CONFIDENTIAL MATERIAL Division of Mines &Minerals 3001 Porcupine Drive Anchorage, Alaska 99504 Attention Mr. Thomas R. Marshall, Jr. Gentlemen: Transmitted herewith is the well deviation survey and one set of unwashed ditch samples (interval 320'-9840') from the Shell- Richfield-Standard Middle Ground Shoal State A-l-3 well. Very truly yours, JDM:m For J. W. Speer Division Production Manager SHELL OIL COMPANY NATIONAL BANK OF ALASKA BUILDING 5Tl-I AVENUE AND E STREET ANCHORAGE, ALASKA 99501 August 17, 1965 State of Alaska Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Attention Mr. Tom Mm~rshall Gentlemen: Enclosed are two copies of the Completion Report for the Shell-Richfield-Standard Middle Ground Shoal.State No. A-l-3 well. Very truly yours, JDM: s Enclosures p~vis~ Production Manager Form P-~7 SUBMIT IN D. UPL. -TE* '-~TATE OF ALASKA (~..~t~heriA- structions on OIL AND GAS CONSERVATION 'COMMISSION reverse side) WELL COMPLETION OR RECOMPLETION REPORT ,AND LOG * la. TYPE OF WELL: OIL ~] GAS.. r--] E~ WELL WELL L_J DRY Other b. TYPE OF COMPLETION: WELL OVER EN PACK ItESVR. Other NAME OF OPERATOR Shell Oil Company ADDRESS OF OPERATOR 201 National Bank of Alaska Building, Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance with any Etate requirements)* At surfac~ t~,-~; '1627'~-& 435 f,~..---C~._7~.. ' of Sec 11, T8N, R13W, S.M. At top prod. interval report~ below At total dep~ I 4-4-65 Effective: July 1, 1964 · 5. LEASE DESIGNATION 'AND SERIAL' NO. ADL 18754 6. IF INDIAn, ALLOTTEE OR TRI~E NAME 7. UNIT AGREEMENT NAME $. FARM OR' LEASE NAME WELL NO. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., a., M;, OR BLOCK AND I~URVEY OR. AREA ' .Sec. 11, TSN R13W, S.M. l~¢r[~'4~*cl{' ' .- I~' PERMIT N°'. 65-4 IAprilDATEISSUEDs, 1965 12' BORO6C}H "' ' ]' 13' s'TlTl 'Alaska ~6. DATET.D.~EAC'n"'6.3.65 '~''~'"C0~'~'(~"'0~0~")6'20'65 I ~s. ,~,v,,,o~, (,r. ~,. ~,.,~.,,c.), [ ~9. ,~,v. c,s'~",,,DF 116' able ~LW . ~ 20. ~rraL ~'rH, ~ & TVD ] 21. PLUG, BAOK T.D., MD& ~ ] 22. IF MULTt~'LE COMPL, 9840~ ? [ PB 8750 ] now 24. PRODUCING INTERVAL(S)~ OF THIS COMPLETION----TOP, BOTTOM, NAME (MD AND TVD)s 7262 - 8612, lower Kenai 26. T~PE ELECTRIC AND OTHER LOGS RUN 23.INTERVALS ROTARY TOOLS CABLE TOOLS DRILLED BY > I9840 I r ' 25. WAS DIRECTIONAL su~v~ ~ADE Yes -- ' r27. was wE~.L C~RED Yes DIL, 1ES, BHC, FDC, FAL, CDM, SWS, NML, P-ML, CBL, GR-CLL 28. CASINO SIZE_ ] WEIGHT, LR./FT. -I 1,3/8~., 54.5 29 CASING RECORD (Report all strings set in well) . 1609' 18 1/2" 1925 Sack, .~i i ~,~ ... ' ' 29, LINER RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENTs SCREEN (MD) 30. SIZE 2 7/8 TUBING RECOR6NCHORAGE DEPTH SET (MD) PACKER Sn~ (MD) 8574 7175 & 7770 31. PERFORATION RECORD (Interval, size and number) 4 jets/ft: 7262'-7288', 7608'-7662', 7886'-7968', 8026'-805t', 812~'-8152', 8158'-8306', 8314'-8457', 8476'-8486', and 8498'-8612'. 32. ACID, SHOT FRACTURE, CEMENT 'SQUEEZE, ETC.. DEPTH 'INTERVAL (MD) AMOUNT AND KIND 0r MATERIAL USED 7230 95 sacks Cement,.sqUeezed 33.* PRODUCTION' rATE FIRST PRODUCTION [ PRODUCTION METHOD (.Flowing, gas lift, pumping--size and type Of pump) I WELL STATUS (ProSucing or . J shut-tn) Flowing Shut-in 34. DISPOSITION OF GAS (8ol~,_used.for fuel, vented, etc.) Vented TEST WITNESSEO ax ' ~ 35. LIST OF ATTACHMENTS 36.SIGNEDI~ereby cert~ha~t~/~ /- ~~ ($~the foregoing and attached informationTiTLE Div~.s~-oniS complete and correctprodlle t'~ arias determinedM~oo,,rfrom all a~.ailable, DATErec°rds See Instructions and Spaces I:or Additional Data on Reverse Side) INSTRUCTIONS · . · General: This form is designed for submitting a c~mpI~te .and correbt well completion report and log on all types'of lands and ieases to either a Federal agency or both, pursuant to applicable Federal and/or State la-wa and reg~ilati0ns. Any'necessary special instructions concerning..the~use of this :form and the numbc: submitted, particularly with regard to local, area, or r~gional procedures and practices, either are shown below or will be'~ ~ssued by, or ma:y be obtained from, and/or State office. See instructions on items 22 and 24, and 33, below regarding separate.reports for separate completions.· '.- If not flied prior to the time this summary record is submitted, copies of all currently available lpgs (drillers, geologists,' sample and core analysis, all types elec~.~ tion and pressure tests, and directional surveys, should be attached' hereto, to the extent requited b~ applicable Federal and/or State laws and regulations. should be listed on this form, see item 35. · ~.", : :i · I~em 4: If there are no applicable State~ requirements,.'locati0ns, on Federal or Indian land should be described in accordance' with Federal requirements. C or Federal office for specific instructidns. I~em ]8: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any at! I~em$ 22 ond 24: If this well is completed for separate' Pro'duction from more than ()ne interval zone (multiple completion), so state in item 22, and in item 24 interval, or intervals, top(s), bottom(s) and name(s).· (if any) fon only the interval reported i~ item 33. Submit a separate r~port (page) on this form, ad~ for each additional interval to be separately produced, : showing the~additional data pertinent to suCh interval: I+ern 29: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location ~f the cementin Item ]]: Submi~ a separate completion report on this form for ea~]~ interval to be separately produced. (See,instruction for items 22 and 24 above.) .. ,~; ..~ -' . , ! '-37.' SUMMARY OF POROUS ZONES: '.' f'~ " ' " .... ~qIt(}W Al,I, IMPORTANT ZONES OF I'OROS1T¥ AND CONTENTS TIIEREOF; CORED INTER~tLS'; AND ALL ~R[~L-STEM TESTS, INCLUDING 38. GEOLOGIC MARKERs DEPTH INTERVAL TESTED~ CUSHION USED~ TIME TOOL OPEN, ~LOWINO AND SHUT-I~'~RESSURES~ AND RECOVERIES FORMATION TOP ~ BOTTOM DESCRIPTION, CONTENT~'~ 'ETC. ' T~ NAME. MEAS. DEPTH ..... · ...., . .. .. _. · . . .'~ , . , ~ease Date State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS " PetrOleum Branch INDIVIDUAL W~LL RECORD ..... 7-20:67 _ Sec. ..... 11 T ..... 8N., _..~ : - :~ _..._ . . : . - , : · R. I3W S Meridian Per~it No. 65-4 O~erator Shell 0il Company __ Lease No. ADL 18754 or Owner ,.Middle Ground Shoal Well No. A-1-3 Area Middle Ground~ Shoal Spud Date=_._=4~4-65 Drilling ceased Suspended Completed ca)P, 300 Casing Issued 4-5-65 Location (Surface) 1627' N & 435 W of SE Cot, _Sec 11 327' N & 572' W of Surf. Loc. LoC. (Bottom) 1967' N & 973' ..... W of SE ..... 0or 6e¢.. 11 Abandoned 280 (F~) ~.,6-20-,65 .... IP//.'~I_llL B/D, Gray cf/Bbl . ~ Bean~/64 cP~i, S_iz__e.. D_epth sx cm~ __~__e_r.f~(2)~(.T262'.72.88~ 24"-125.5# 319' __65_0__ ~'76.62' ..~_ 13 3/8"'54.5# 1609' 1925 ,~ shoe (J~)2.6,.',-8051' -7'i -"29~ .... 8798" : - 150(~'' (8122 '-8152'~ ~ecmtd. 7230' 95 (1) (8158 ~-8306~ (8476 ' -8486 ' GEOLOGIC FORMATIONS Surface .. Total Depth 9840_ ~... DF-II6' - abOve MLT Elevation water ,4ep, th_ 80' __- MLT 5 E 37" API Cut ...... 15 ..... -: 8798'-8749' ,C~498' 28612 'PRODUCT IVE:-'HORIZONS Name Depth Contents Year · W'EL~ STATUS Jan Feb Mar ..... Apr ..... May. June July Aug Sept Oct Nov Dec . .'- '.:' ':-"=a': .~:..-: ~'%emarks: o3~, '~'//= 0 · . j ~',:./2 z 3 i SHELL OIL COMPANY 201 NATIONAL BANK OF ALASKA BUILDING 5TH AVENUE AND E STREET ANCHORAGE, ALASKA 99501 August 6, 1965 Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska 99504 Attention Mr. Thomas R. Marshall, Jr. Gentlemen: Enclosed is the following on S.R.S.-M.G.S. A-l-3 well: Well History Sepia and Blueline of Formation Logging Record Sepia and Blueline of Schlumberger Composite Dual imduction-Laterolog, Runs 1-3, 318'-8216' Sepia and Blueline of Schlumberger Induction-Electrical Log, Run i, 6850'-9833'. Very truly yours, enclosures //Divi~on Production Manager Middle Ground Shoal Cook Inlet, Alaska .: · May 9, 1965 R E C E t V E D - DIVISION OF MINES & MINERAL~ ANCHORAGE Location: 1640'N, 401'W of SE corner, Sec. State grid Coordinates: 2,485,849 N' 232,780 E Elevation: Derrick floor = 116' Water depth = 83' Note: Ail depths from derrick floor. ~April, 1965 4 319 5- 7 440 8 9 10-15 1609 t6 4149 17-t9 4380 20-24 5100 25-30 6170 440 1609 1609 1609 4149 4380 5100 6170 7331 Spudded 3:30 P.M. Drilled out of 24" conductor with 18 1/2" bit. Drilled to 1609'. Ran Schlumberger DIL, run 1, 318-1320'; cemented 13 3/8" casing at 1609' with 1925 sacks Class A cement. Set and tested BOPE - rigged up for drilling. Drilled with 9 7/8" bit. Core #1, 4149-4178'. Drilled to 5100', ran Schlumberger DIL, run 2, 1610-508Z , CDM, run 1, 1609-5083'. Core #2, 5956-5976'. Core #3, 6964-6494'. May, 1965 1- 6 7331 8125 Core #4, 7977-8007'. 7- 9 8125 8244- Ran Schlumberger DIL, run 3, 5082-8216'; BHC, run l, 1610-8219'; FDC, run 1 1610-8228'; P-}~, run 1, 1612-8223'; and NML, run 1 3130-8228': Core #5, 8238-8244'. ' 24" 319' 13 3/8" 1609' 18'1/2!~~ 319 1609 9 7/8" 1609 8244 5" Middle Ground Shoal Cook Inlet, Alaska _ June 15, 1965 TSN, R13W, S.M. May, 1965 10-22 8244 8646 Continuous coring, cores 6 through 20, 8244-8646'. 23-26 8646 8922 Cores 21 and 22, 8694-8737'; core #23, 8841-8861'. 27-31 8922 9~93 Drilled 8922'-9493'. June, 1965 1- 2 9493 9718 3- 5 9718 9840 Drilled 9493'. Ran Schlumberger IES, 6850-9833'; BHC, 6850-9835'; FAL; P-ML, 8223-9825'; CDM, 4900-9800'; SWS; FDC, 8220-9834'. 6 PBTD 8800 With open end pipe at 9002', pumped in 250 sxs Class A cement. Found top cement at 8748' cleaned out to 8800' , 7 8- 9 10.-11 12 13-14 15 PBTD 8800 Cemented 7" 29# N-80 casing at 8798' with 1500 sxs cement. PBTD ~ Laid down 5" drill pipe - made up 2 7/8" tubing. Ran Gyroscopic survey, Collar Log - Cement Bond Log. PBTD i-'~O~ Perforated five 1/2" jets at 7230', took water shut off test (packer PBTD -~-~ PBTD ~~- PBTD ~- at 7172'). Recovered estimated 2 barrels mud and 5 barrels water. Squeezed perforations at 7230' with 125 sacks cement, 95 sxs through perforations and 30 cu. ft. left in casing. Cleaned out cement. Perforated four 1/2" jets at 7228', ran W.S.O. #2 (packer at 7172'). Recovered 0.7 barrels mud. Perforated following intervals with four 1/2" Jets per foot: 7262-7288'; 7608-7662'; 7886-7968'; 8026-8051'; 8122-8152'; 8158-8306'; 8314-8457'; 8476-8486'; and 8498-8612'. Ran in tubing to 8574' with sliding sleeve valve at 7736' and packers at 7175' and 7770'. Made up well head. 24" 319' 18 1/2" 319 1609' 13 3/8'!i 1609' 9 7/8" 1609 9840' 7" 8798' 2 7/8"'tubing Middle Ground Shoal Cook Inlet, Alaska June 20~ 1965 T8N, R13W, S.M. June, 1965 16-17 I:'BTD · 18-20 Tested interval 7886-8612' -- flowed 1130 B/D (37°A.P.I.) 300 GOR through 32/64" choke, tubing pressure 160. PBTD--'~~'--- Tested interval 7262-7662'. Swabbed wellin, flowed 37.20A'.P.I.. ~ gravity at 280 B/D, 390 GOR, through 24/64" choke, tubing pressure 140 psi. Set tubing plugs. Rig released 1:00 P.M. on 6-20-65. ' ~ ~ . 24" 319' 18 1/2" 319 1609' 13 3/8" 1609' 7" 8798' 9 7/8" 1609 9840' 2 7/8" tubing SHELL OIL COMPANY 201 NATIONAL BANK OF ALASKA BUILDING 5TH AVENUE AND E STREET ANCHORAGE, ALASKA 99501 July 6, 1965 Division of Mines and Minerals 800 L Street Anchorage, Alaska Attention Mr. Thomas R. Marshall, Jr. ~ntlemen: Attached for your information is a summary of operations for the month of June, 1965, of our Middle Ground Shoal field, (wells A-l-3, A-2~.). Very truly yours, EBM:cld Attachment ? u. ~upeer :"iI Di~¢on Production Manager U Form No. P 4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 LAND DCFICE LEASE NUMBER LEASE 13R UNiT NAME LE$SEE'S MONTHLY REPORT OF OPERATIONS State __A__l___a__s__k__a__ ................. i ......... Borough .............................................. Field __M._i.4d__l__e___..G_r__o._u_n__~___S_b.ea_% Tke followin~ is a oorreot report of operations and prod~etion (inelgdin~ drillin~ and prod~ein~ wells) 'for tke mo~th of .............. .~._u__n._e_ .................... 19___6_5_ ............................................................................. ./l~ent's address _20_I__N.__B._~A.__BIa£1~J.ng ....................... Company ___~:~_t~_ e__~___l___Q_~__l_~_o..m~o._a._n_y__/__~_ .................. .................................................... .2_,,. ,;~~~lvisio~/Production Mgr, Pl~one 27 2- 9541 ............................... ~/~%,~ ~ ~ ................ / .................................... ~EC. AND BAEEELS OF OI~ GEAVITY (~ASOLINE WATER (~ (If ~ng, d~th; if shut down, ~ Or ~ TWP. RANGE WELL DAYS. CU. FT. OF GAs GAINS Or p BAR~E~ REMARKS No. P~o~c~- (~'tho~&) RECOVERED none, so state) date ~d r~ult of t~t fo~ : oon~t o~ ~) June · SRS_MG ~ A- 1- ~ · 1965 Drilled ~-7/~" hole 9539'-9840'. Ran Schlun~berger l)gs with drill pipe at 900 cemelted with' 250 sacks of ce~nent. Cle~,ned out gement t~) 8800'. Ran 7" N-80 cas .nE; cemented ~ 8798' with 1500 sacks ce nent. Atte~pte] ~. S. O. through 5 'jet )errs ~ 72~0', rec. 2 bbls ~ud and 5 bbls war Squeezed per~ s ~ 7230"with 125 s~cks cement. -. -~. S, O. tesi 'through 4 jet perfs ~ ~228'. RecovereJ 0.7 bb~'.s mud - ~. S. O. test goo(. / Perf~rat.~d w~.th fCur jets per foo~-: 7262'-] 288' 76 )8 '-7662' , 7886'-7968~ 8026'-80f 1', 8122'-'8152', 815~'-8306', ~314'-845~', 8476 8486', and ~498 -86].2' . Ran 2-~/.~" t~bing :to 85~4', With ~liding sl(eve valve ~ ~36 and packers ~ ~nd '7~0 . Tested i:~terr~al ~886'-8612'; flow~d 1130 B/I~ (3~°~I) 300 GOt~ through 32/64" ~ith 160 psi ~ubing pressure. Tested irterval ~262'-~66~'; flowed 280 B/D (37. ~°~]~) 39( GO~ through 24~ 64" choke with 80 )si tubir~g pressure· .. Set :tUbi:~g p].ugs ~nd r.ele~ed rig on' 6-20-6~ ~ 1:00 P.M. RECEIVED ,:UL 5'IVI~I~]N OF MiF,Ir~S & MINE~L5 ANCHORAGE 29# · 5' choke NOTE.--There were ......... i .... ~..O. ............................ runs or sales of oil; ................. ..N..0. ....................... M cu. ft. of gas sold; .................. ..~...o. ....... ............................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. SIX) L StFeet June 23, 1965 201 Sat'l lbmk of A~ Bu~ld~s Ancho~a~, Al~mka form (P-3). ~lhia ~ uot ~ s/! .of the tnfom~lon required ou a ~ plel:iou ~l:. P~ u~ our ~m P-? f~r £inal m.plel:ion rep~t~. The P-3 is for ~ o£ p~ aft:er any predous pLtms a~e filed As ~ chonse of plans hsd been .L=i~, thl~ L__~o oiumld h,sve been 3heu ~ cos~~ ~ covers eoup-leted condtt~ of the w110 but no dm:es ~ .pu4dtn~, ~ d~pths, eeup-la~, first: produ~loa fred .d~e need moz-e b lm~ forms p~ advise. SHELL OIL COMPANY 201 NATIONAL BANK OF ALASKA BUILDING 5TH AVENUE AND E STREET ANCHORAGE, ALASKA 99501 June 21, 1965 Subject: Well Completion M.G.S. State A-l-3 RECEIVED DfV~$,ON ' OF' £'~t/',tE$ & State of Alaska Division of Mines & Minerals Oil and Gas Conservation Commission 800 L Street Anchorage, Alaska Gentlemen: Attached for your information is a Sundry Notice on the well completion for Shell-Richfield-Standard Middle Ground Shoal State A-l-3. Very truly yours, Production Manager Ponu ~,-:~ ,, STAT~ "~ ALASKA ( Other instructions OIL AND GAS' cON$1iRVATION ·COMMISSION verse side) .. sUNDRY 'NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a dii~erent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) oil 2. NAME OF OPERATOR She 11 · Oil COmpanY 8. ADDRE~8 OF OPERATOR 201 National Bank of Alaska Bldg. 4. LOCATION OF WELL (f~ep0rt 10~ation clearly ~nd in accordance with any State requirements.* See also space 17 below.) ' At surfece - 1627' N & 435' Wfrom the SE Cot. of Sec. 11, T8N, R13W, S.M. Effective: July 1, 1964 5. LEASE DESIGNATION AND IERIAL NO. ADL 18754 -6. Ir Z~D~A~; ALLOTT~E ca ~RZSE NACRE UNIT: AGREEMENT NAME . 9. WELL _ . A-l~3 10. FIeLd'AND POOL~.DR WILDCAT mddi iCrou d Sho ,l 11. ~EC., !~.,~B.;.M., OB BLw. AND B'URV~ OB 14. PEnMIT NO. I lS.DFEI.~-¥ATION$116[.( Sh°WaboveW~herM~LWDr' -aT, OS, e~) ' 12. BOROTTGHi.. './~...;- [::'Aia~ka[ ia, STA~E 16. Check Appropriate Box l° Indicate .Nature o[ Notice, Report, or Other Data ' NOTICE OF INTENTION TO: TE8T WATER SHUT-OFFN]~[ PULL OR 'ALTER CASING ~ WATER BHUT-OFPwell, ~ --1 ~----~ (~o~: Report results of multlpl~ ~letl0~ (Other) - Completion or Recompletion Repo~ an~ Log ~orm,)- ,' , ~seai~ PROPOB~D OR coMpLR~D OPRRA~IONB (~l~l'ly state all pertinent details, and ~l~e pertinent dates, including ~mated date.of.sta~tiui any ~roposed ~ork I~ ~ell Is dl~otion~ drlll~ Blve subs~e laotians and measured and true vertical depths"f~r' All markers ~nd ~ones pertl- nent ~ ~is work.) * . The following is a summary of operations just concluded on S.RM;,M-,G.S. State A-l-3: Drilled to a total depth of 9840", plugged back to 8800'. Cemented 7" 29# casing @ 8798' with 1500 sacks cement. CleanedOUt cement to 8749'. Shot five 1/2" holes @ 7230'. Made water shut-off test @ 7,230', no good. Squeezed ho~e@ 7230' with 95 sacks cement. Shot four 1/2" holes-@ 7228', Made WSO@ 7228' O.K. Perforated with 4 holes per foot the' intervals 7262'-7288', 7608'-7662', 7886'-7968!, 8026'-8051', 8122'-8152' 8158'-8306' 8314'-845~' 8476'-8486' and 8498'-8612' Ran 2-7/8" tubing to 8574' with packers @ 7175' and 7770', slidl"g sleeve- valve at 7736'. Ci-[¢ulated out mud with diesel oil Flowed well to unload diepel., 0il. 6-18-65 tested interval7886'-8612; @ 1130 BD rate, 15% cut.emuIs~i°n~ 6-19-65 tested interval 7262'~ @ 280 BD rate, 5% cut. emU~iOn. 6-20-65 Shut-in pending complet~~of production facilities." SIGNED '~~' (This ,pac//r Feder~ State o'~ee use) APPROV~p/B~ CONDITIO~ . TITLE Division Production Manager.DA~' 'S OF APPROVAL, IF ANY: RECEIVED · J:UN g 3 I9 5 DIVISION OF MINES & MiNERAL~ i. *See Insffructions on Reverse Side TITLE DATE SHELL OIL COMPANY 201 NATIONAL BANK OF ALASKA BUILDING 5TH AVENUE AND E .STREET ANCHORAGE, ALASKA 99501 June 1,. 1965 Confidential Material Division of Mines & Minerals 800 L Street Anchorage, Alaska. Attention Mr. Thomas R. Marshall, Jr. Gentlemen: The following is a. summary of operations conducted on our S.R.S. Middle GroUnd Shoal State A-l-3 well for May, 1965: Drilled and cored 9-7/8" hole to 9539'. Ran electric logs at 8225'. Cored the intervals 7977 '-8007', 8228'-8586', 8587 '-8646', 8694'-8737', 8841'-8922'. Very truly yours, EBM:m /Divis/i~ Production Manager SHELL OIL COMPANY 201 NATIONAL BANK OF ALASKA BUILDING 5TH AVENUE AND E STREET ANCHORAGE, ALASKA 99501 May 17, 1965 State of Alaska Department of Natural Resources Division of Mines & Minerals 800 L Street Anchorage, Alaska Attention T. R. Marshall Gent lemen: With reference to your letter of April 2, 1965, attached is a surveyors plat of the location of leg No. 1, Platform A from which S.R.S.-M.G.S. A-l-3 is currently drilling. Following completion of the platform a final survey of the facility was made and the attached plat now reflects the official location of leg No. 1 as well as the coordinates for the other legs. Very truly yours, EBM:m i0 !0 2 II T. 8 N., R.13 W., S.M. 2 II ADL 18754 LEG NO. I.~3' 12 LEG NO. i LEG NO 2 LEG NO. 3 LEG NO. 4 X : 252,785 :Y = 2,485,845 1627' N 6 455'W FROM THE S E COR. QF SEC. ll, TeN, RI3W, S~M LAT.- 60047'44.839'' LONG.' 151° 29' 45. II 2" Pl. AAlE C 00,'~DINA T£S X = 232,846 X = 23,2,896 - Y = 2,485,897 Y = 2,485,855 PUB/ I C 1. A AID 1681' N 6 372' W -FROM THE SE COR. OF SEC. II, T8N, RI3W, SM. DE'SCRIP T/ON 1620'N & 321' W FROM THE SE COR. OF SEC. II; TSN, RISW, SM. GEODETIC CO0/?D//VA TEE LAT. - 60047'45.368" LAT. - 60047'44. 768" LONG.-151°29' 45.942" LONE-151°29' 42.899" X= 232,83,3 Y=2,485,785 1566'N 8: 385'W FROM THE SE COR. OF SEC. II, T8N,RISW, S.M. LAT.- 60°47'44.244"' LONG.- 151° 29' 44.154" Ill I I I I II I ~ i RSEDES Z-4150-1 c,£c~,~ ,~ ,...~. SHELLOILCOMPANY O~T~ ~'~Y ,~, ,~e~ I - 150- 2 ! _. - ...... I II I LOCATION OF SHELL- RICHFIELD-STANDARD PLATFORM "A" IN SEC. II · 8 N. R. 13W- ,M.- ~OK INLET-STATE OF ALASKA DI IETIERICH-POST CL~ARPI~I NT SHELL OIL COMPANY 201 NATIONAL BANK OF ALASKA BUILDING 5TH AVENUE AND E STREET ANCHORAGE, ALASKA 99501 May 17, 1965 Confidential Material Division of Mines & Minerals 800 L Street Anchorage, Alaska Attention Mr. Thomas R. Marshall, Jr. Gentlemen: The following is a summary of operations conducted on our S.R.S. Middle Ground Shoal State A-l-3 well for April, 1965. Spudded 3:30 P.M. April 4, 1965. Drilled 18-1/2" hole to 1609'. Ran electric log. Cemented 13-3/8", 54#, J-55 casing at 1609' with 1925 sacks of cement at the shoe and. 650 sacks in the annulus from the surface. Drilled 9-7/8" hole to 7350'. Ran electric logs at 5086'. Took cores in the intervals 4149'/4178' 5956'/5979' and 6964'/6994' . Very truly yours, EBM:m Divisi~h Production Manager 800 L S~t Shell Oil Cm~any Boom 201, It.B.A. auildins 5ch Avenue & ~. Street ~.hor~i~,e, Alaska t)emr Sirs: ~~ ia the al~rc~l appltca~ ~o deepe~ ~ell-Sf~ard~lchfield's $~a~ i~1' A ~le cu~ ~ill be re~ ~ the deepe~e~ t~erval. The sa~ptes o~ ~he int~-rval ~1~041 veme lost :tn t~e ,v~rch 27 earthquake. Vsr~ truly Tlmmas It. ltaroha I 1, Jr. Petroleum Oeolo~iot April 2, 1965 Hz. ~II O~1 C0spany 20-t Naztmml ~ o£ Alaska 5th Avem~ ami E a~: ~li~ation for P~rmit ~o D~ill S.~.S. -H.O.S. A 1-3 3) ~nthly r~t of ~perstions is due by the 10th of ~e report mouth. 4) A ~lrveyordj p~ o£ the platform local:ion should Very t~uly ym~s, ~ a. ,,,r~U~' jr. AI~ Oil & ~m Ckm~mtioa Commiz:tee FORM 95M 3/64 MEMORANDUM State of Alaska FRO~: Kathy DATE : Aprll 2, 1965 SUBJECT: ~Aq3pl:LCa[:~[O~ ~0'~' ~'e~*l~]Lt to ~1~ S.R,S.-M.G.S. State A 1-3 EncLosed is o~e approved copy of the above re~ereuced appl:lcal:~om ami a ctmck i.n the am~tmt of $50,00 to cover f~ltmg fee. 95M 3/64 MEMORANDUM TO: F ilo~coe E. Bell Kirk SLanley FROM: 'fl~C~8 R. Marshall~ Jr. State of Alaska DI%r~SION OF MIN~S ,.%N~ v ,, -.~, DATE : SUBJECT: P~rch 23, 1965 Application for permi~ to drill S.~LS - ~$ State Al-3 ~ ~have recetve~ an application for permit to drill t~m first perm~neuC platform we!!. It will req~[re a ~l~cing exception because it ie less thaa 500 feet from a quarter e~ction ii:ae. Drilling will probably start about the ~ecoud ~ek in April. ll'~e toc~ion ia as S.R.$.-~I.G.S. Stmte Al-3 - 1640'N, 401'W of $.g. Cor. Sec. Well wiI1 'be drilled from ~:he westernmost leg (leg ~I) of the platform using comduct/,,~.~ ~3. SHELL OIL COMPANY 201 NATIONAL BANK OF ALASKA BUILDING 5TH AVENUE AND E STREET ANCHORAGE, ALASKA 99501 March 22, 1965 State of Alaska Division of Mines & Minerals Oil and Gas Section 800 L Street Anchorage, Alaska Attention Mr. T. R. Marshall Dear Sirs: Please find attached a $50 fee to accompany our application to drill Shell-Standard-Richfield Middle Ground Shoal State No. A-l-3. Also attached is a Supplement to Application to Drill outlining our drilling, casing, and blowout prevention program for the well. Very truly yours, EBM:m Attachments r nager APPLICATION FOR PERMIT TO"DRILL, DEEPEN OR PLUG BACK / .: ~PPLICAT~ON TO-DRILL.[~.- ~: DEEPEN [] NAME OF COMPANY OR OP~RA~'OR- PLUG BACK O DATE City ~ . '. State Name of lease..:. XVell location ~ (give footage from section lines) Section~township~range or block & survey Field & Distance, in miles, and direction from nearest town or post office Nearest distance from propo.~ed location property or lease line: Distance from proposed location to nearest drilling, completed or applied~for well on the same lease: feet Proposed depth: Rotary or cable tools { Approx. date work will stari Number of acres in lease: Number of wells on lease, including this well, completed in or drilling to this r~qervoir: If lease, purchased with one or ~more wells drilled, from whom purchased: Name Address · . Status of bond ~e~ 0ti ~. ~ ~ ~, ~1759 ~ H~ 10, 196!, .in ammm~ of $100,000,00 (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected l~ew producing zone) RECEIVED NtAR" ~ 2 1965 DIVISION OF MINES & MINERALS ANCHORAGE CERTIFICATE: I, the undersigned, .state that I am th. ~~ of the ~IBSIl ~ ~ (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and ~lirection and that the facts stated therein are true, correct and complete to the best of my knowledge. Permit Number: 65 -4 Approved By: ~ Thomas R, Marshall, Jr, Notice: Before sending in this form be sure that you have given all haformation requested. Much unnecessary correspond- ence w/ll thus be avoided. See Instruction on Reverse Side of Form Signature I Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective' October 1, 1958 SUPPLEMENT TO APPLICATION TO DRILL SHELL-RICHFIELD- STANDARD MIDDLE GROUND SHOAL STATE NO. A- 1- 3 DRILLING PROGRAM: 1. Move over 24" sub-conductor ~/3, leg ~1. B.O.P.E. to consist . of one 20", 2000 psi Hydril preventer. Drill 18-1/2" hole to 1500'+_. Run 1500'+- of 13-3/8", 54.5~, J-55 BUttress casing. Cement With 17005 sacks A.P.I. Class "A" cement, last 200 sacks treated with 2% CaC12. 3, Land casing and flange up 12", 3000 psi preventer stack consisting of Double Shaffer Gate and G. K. Hydril. Test . B.O.P., riser, and casing to 1000 psi. Drill 9-7/8" hole to 10 000'+ Run 7" 29fA, N-80, X-line , --e , casing to 8900'+ and cement with 1000 sacks A.P.I. Class "A" cement retarded to Class E specifications with HR4 retarder. Land 7" casing as cemented, install tubing spool and flange up. Test 7" casing, wellhead and B.OoP. to 2000 psi. 5. cleanout cement and complete as directed. RECEIVED SHELL OIL COMPANY Suite 1055 Dexter Horton Building seattle 4, Washington Subject: I~froleum: Branch Mint~'. and Mi~eraJ$ Natural l~esourc~ H/ddle Ground Shoal ~ea,. Mist. Drilli,~ng and Producing Platform. Fw. Thomas R. Harshall, Jr. (2) State Petroleum Geologist Alaska Department of Natural Resources Division of Hines and Hinerals 329 - 2nd Avenue Anchorage, Alaska Dear Hr. Marshall: This is to advise you that during June, 1964, we plan to start con- struction of a permanent drilling and producing platform in the Middle Ground Shoal area-of Cook Inlet. For your information, we are enclosing copies of the following: 1. Z-3368. A vicinity map showing the location of State of Alaska Lease ADL 18754. 2, Z-3372. A location map showing the geodetic position and size to scale of the proposed structure (drilling and pro- ducing platform), 3. Z-3369, A plan of the proposed structure (drilling and pro- ducing plat form), We are obtaining all required permits from the following U. S. or State entities: A. The District Engineer, U. S. Army Corps of Engineers. B. Federal AviatiOn Agency. C~ De U. S. Coast ~uard. State of Alaska Department of Fish and Game, R. L, Freeman Division Land Manager Enclosures INDEX MAP T 13 N 61° (~0'~ 60° 45'~ R 14 W R lB W 5C&LE IN MILES T '~ONE ~ ~0o$ R IIW + T / R8 W SHELL- RICHFIELD- STANDARD LEASE A.D.L. 18754 COOK INLET, ALASKA APPLICATION BY SHELL OIL CO. LOS ANGELES, CALIFORNIA SHEET I OF 3 Z-3368 l 21 LAT. 60° 4T' LONG 151e 29' 49.7" STATE GRID COORD. ZONE 4 22 27 T9N S.M. I 18754 25 26 TSN S.M. T TN S.M. ~ 4000 lO00 12000 .~,,,,,,,. I , ! ,'--,, , I,, ' SCALE IN FEET 24 II 25 3O I I 20 2~ 12 PROPOSED LOCATION OF SELF CONTAINED DRILLING 8~ PRODUCING PLATFORM SHELL MIDDLE GROUND SHOAL PLATFORM "A" COOK INLET, ALASKA APPLICATION BY SHELL OiL CO. LOS ANGELES, CALIFORNIA SHEET 2 OF 3 Z'- '3'372" EL. + 265' EL..+ 92' ~ EL. + 41' ~ E,., ELEVATION VIEW PLAN VIEW MA X ~MUkl TiDE MLLW LOWEST TIDE O 40 80 I , I '; FEET TYPICAL SELF CONTAINED DRILLING 8~ PRODUCING PLATFORM COOK INLET, ALASKA APPLICATION BY SHELL OIL CO LOS ANGELES, CALIFORNIA SHEET 3 OF 3 ' ' ~Z' 3369- NOTICE The following well logs and oversized documents have been placed in offsite storage. To view these documents, please contact the AOGCC librarian. AOGCC 2/16/2005 III 1>- ! !zl 1:1 šl 1- 1;1 1(,,)1 '.... 1=! .... ~ Z I.C I e¡ ~ òl 0 ¡~ 0 xi ,0 ,CI) I i Z i >- >-'" 01 Z % OJ:: ¡ -< A. ::>0<.... ~ O....u~ 0 u~g~ u COMPANY SHEll Oil COHÞANY WELL FIELD STAT£ A-1-3 MIDDLE GROUHOSHOAl ST ATE ALASKA COUNTY COOK INLET 19 ~43 ~/) @ lOCA nON 164Ö M g" 401 W Other Services: FROM S.E. CORNER (S.M,) 5ec.__11-_ Twp. 8N Rge. '3W Permanent Datum;. DF log Measured From DF Drilling Measured FromOf' ,Elev. H6 ,~Ft. Above Perm. Dotum flev.. K.Si O.F. '116 G.L @; ml ml ml ~F @ OF i~ :F @ of of @ OF of @ o.F 0 OF of F --~ .~._- ~~·~~~0~<~·-:-'··~-~:':~=:---;';';':;"~~¥·_~ -. >, \ .~.. ---"'~'-""'-'>--~"'J""""--"'-'C ';"'~- -.~~-_.-,;'---'" ~"--~'~V'-' ì"t jt q~ , ' (" ~ .~ r t;¡. ., ! !: '~ j, I:' 1 II i' 1 ~I L ! '1 ---:-'>- - . ~- />'.. . . '>,- -. ".,::..",,- ...' ',,,' ",:) ;, "". ~~/ ";,',-:";; SHELL OJL COMPANY lCois--o~, ' . < ....-" -'~!\ , ~', o o "STATE A- t-3 <M IDDLEGROUND SHOAL '.......--.., ,'". COUNTY COOK ".1 NLET> , STATEALASKA ~ LOCATION1640'N'&::'401'W' FROM Other Services: ~ SE.. CORNER ~. o u . , s~c;' >. " (" ,,, "Per~(]~e~t'Datu~=,i ',', .....!D.F·· log<'Me?sured, from "DF Dr.jlJing;"Meqsured FrofTt'>D F 116 , SURFACE Liner MUD 80 '_..~-_._,^--^ :tttl~ "'! .., -' , ~ j! ,I Ii ¡ I 'I " ;ì ~ " ._-~~--- ~~.-:.........~-~~~....... .----" ""'.....:._~"'-.n"=·_'""'"""'-=~=____"~A ----. ""-:~'{"-""~T-'-O'- '." t ~ .J(J (' 0~(J1f " ." 'ij'Y~:(ì~." 5'';~''~f~~'~'~'~''-' ¡,'i"~,t r'SCHWM,BER6ER~~ ::','~. :' _~*:.--,~), !:':', -': ".,>y~," ,~J¡': ;'~~,~::', " '~-~,/'-:t·...->':-?-f;:-,;/!:;;,"::::>~::~ (;:~;-~::~:::~P~~',fr:~~:' !:~~~;:~~~~:?~ ~,:~:\,: ~ ~:<.~\l-~~;~;: ì : p 'i{ÑÙ'CL:EAR'sMAGNET I SM LOG :y,i:'. :';- :';~. '."~':',,!: ;'::~'-;':~:;- ~ -'-';;~-:)';'" -, -_,~, -i, ~:;i··,;. ;:;:..' '-,~~' '\',~- ~ : . . . ...... . . . .. '::" If:,~~ ;:; ~~~¡~;::{r~J}: ~:'~<¡;'r~<:''',~:J,:'::~'~~'k''':'''''': .', ','. " ,la' ~ COMPÀNY.~ SHELL '0 I L COMPANY ':) c,;:c ii.. I::~T:~;:~;'~:^'. .:: -:'., ,Y ',;, .. . " &~~[~,~ I:;~ '.'».;. '" "!.o' '. \'t ;,~~~, ~ '~i[;~j'~')~:,':;'~ ~~'T~ )A': '1 ~~ ¡?, ~ G5 A- - y?..:' \\ ~~ ;;i i ~ .~E~~':.::<~I ~ DL~~ GR~~N?'<~~HÒAL - . U1' 'ÇOONTY" COOK INLET;' [' STATE' ALASKA ;~~OCATtON:',l640;NORrH :);::40,1' W. " Other Services: .,ot(,·":.,'./l'.;t,c" )"."Opi: S" E'CORNER> " " ; ~ ·s.~~efc' .::} }1;:;~¡ 1,~.1:T(W/;p·· ~>~ N :'R'g' ·e' (~3 ~.) , . ,u, -', ___,r, 'I,' _. _-1 .:, ", . _.._.. ... :J~:;~' '¡D~ti;m;<:\\ 7~,;i';::DF::;';:,' . . :./, , :'Ele~~' t 16 iÒg:,Me'øsur~.froP"~"'': )F>'': "; ., Ft/Above Perm. Datum Drilling:}AeasuredFrqm" D F :, ". '. . ' ,;' , " D'" ;""'~';';:~"':'''''''~-:'''';''''5''''9' '°6"5"'''''''' ',i'r~,;~:' .;",.','. '.".:',',: , .' ,ot.~,'}';:"~,:.;~'::,·"':',,,,::; ;. .~ ' ';,<ji,,~¿ ,'I' ':::',n,o', "';,,, "'. ; ..RUl'fNo.!~;';;'·~;':,::;,,,· ONE'y.':!";::'~:",',,'l'·;,.<:;" ..', ' . Døetft";"DrUfer..,;J,'·";'·'244>¡~"~;;" " ,,,,:,;," '.". ,: .'. , Deeth-loOoer' ";'232"':'il.7 ,'F~:.' .... : ' Btm,locJnterval;228;"~7310 ~c:~Cfn~:¡:3430 ,,', , " . TOD loa Interval,' '7500, 578h :,'~ 190', ~ 1~0" I . ." , " Casina~DriJIer '. 13~@'t609""~'@ @ Casina.;....Loaaer ---':".';;': '. lfit Size',' " , ~8" "," ~,-;-::- ..' '." , Type:f.;lui.d,i~;Hol., XP~'20:""1 ...... ..;, ...... "'.' :- ,,' '~;, .., ., ': $PERSENE,,-' , . .......-, . . ,., . ~Dens,1 VISC, " 7~'.5;4.o,'. '.',"; ,'. , I .If" I rnJid Loss 1 O. 2 13 ~ 8: mr"- ~ ml '.. ,--:- mil I: Soorc:e'of Sample CIRCULATED, ;:::::-:-"; '..' , ;, .' . , Rm'@Meas:Tem ), ;'b)@':'I.lJOPF @'i ~oF" .' @ .' of' "'@' . RmI@ Meas,Tem ): .~I) @t:lI' °FI " .... @. . of ' .' @ 0F·-;'-·' @ . , I Rmc @Meas, Temp, 5 @ b . '·óf~;~~.., @, °F@' 0F@ .' r' Sourè.e: Rñ.f ~ Rmc" M' . M' ." .....~ ;....' J. : .,' .. ...... I I . I . Rm @ BHT~-'" .,@ 143 °F '; .., @' .. of @ of .... @ Time Since Clrc,' 5* HRS:", ......: J "'. . Max, Rec. Teme, ... 143 ,...' :.-: of :.,,~ ~ of . , of''' ... . of .... EauiD,' Location' r:H~n AIJI ' {', ,i ." I -:- ~ .' I ". Tecorded By'· ; MARC - ET _ ·"In",. ...{. .,.. .. .'.." Witnessed By'" MCLE -ANI -.-. ...' ~ ~ ~ ~- Elev.: K,B. .... O,F,ll Ó G.t '. . , _,'U ; @ " , ml OF OF of o.F _._--~-'.- '"-""'" -"" .. ! it qf [> '.,j..~.:.'i.'..'.;" .' .>-');., .:,,,. I,',';,'" ',.'.....'.',"'.'..."..'.'..'.:.......'.....'....:...'..........'..". ;...'.'.....'....."'.'.';"...:...........'.. '.,.,...'.,',...,.......'"....'..,',.,..,..'".. {i \"':;t I( Z,I7 1';7"; i'~; . , :," "',';' ;"";: >i"':. '. . . \~ ~'IX COMPANY ,SHELL, O'lUCOMPANY ':CI) , ~." },' ". ' " I, :';,.. 01' i:" '" ., ' , ¡ ~\, ;~c C") (,,)1 : '. ",Z I "I', to- ',.::>........: A E 3 t,¡,, :....o ~¡. .WELL . ST T A~ 1- ; ~ ','a:. -.0 Z . :fc:J" ". · ,', ,,,," , ~',~~,ô~~~~ ,FIELD' ...~ ID~L7 GR~~~~'SHOAL, ,(,' '.' ;~ ':[íi0 ~.·.~.CÔlJNTY"~COOK;,rNLE,.),'?-::\·";;STATE' ALASKA·· '... i·:r;'Z:~",; . Loeation:}640.·...,..:.N.:;...&A01 'W..·.·..·.· . .... Other Servièes: ~:õº,,·:~i:>, ." " . ' , %::o~~~:!F' : 9F;'\!FE:~CO~NE~~ " ~8'''''Uw 0: I:" . ~ ",'.' ~ ;"v~g~µ,~' See, 11"" Tw;.8NJ 'Rge. 13W(S, M, ) ! fp~r.;..CJ;,~nt','D~tÙrri::'.,.·.::;·1lF'^"¡:'·]¡/·J·'i,,'t';:',;", '·:r-EI;Y.:" 1"1 6 ' , log': Measured, fl()m .,'; '. D F·· ".' . c:,"'¡1.....::...Ft. Above:P4rm.Datum' Drilling Measuted. From DF"""'::"""'''''(;~;'' ""~'" ;",r;'" '.. Dòt~ ..:i;,' ".,. ,),::/&'·;·;;·,.··'··';:,'5'.0:7-·65·;'·. .:,:.""'.;;.:'. 6:.c3;~ 4265 ,. , Run ,No. ' ".' F,.,., .ONE':·"<"'" ,:)':'/¡ TWO:>;', .,....; Type Loa ",;; .,',',:.:"" FDC..CAL/Y.'f,' FDC-CAL I P,-GR' DeDth-Driller' ," 225 ,.......: ""'." ",·,',9 40;0 J DeDth...:...Loaaer';' "', " .' : 21,';';;\ 9 35·': .' Bottom,loaaed interval' ~20'!:\;';;'\' I;;;I~"':: Too loaaedinterval-¡¡: 11 11é( .,( 8220 >,:¡ ...... r Tvoefluidin"hole<' ""; XP-20"SPERSENI XP-20SPERSEN Salinity.PPM<:I."i' 2500":'''''t700'> 'Density".": .JV..' ":"'c"'" 78)5~'.:~C,T ,.>' 80::-:=-' " Level "',,;""","c':' ,,:,. IFUL.U">i(""f"~ h'uCL c', Max. ree. temo,'dea·'f,! 148''.;\'':::;:''':';;';''1.560 ':.' '" Ooeratinc{riatime b' ".' ,,"'(',/ £+nl\;:) ..': Recorded bv'10-' , ..'.',. MARCHETTE ,:,}, NESS:" ,.,.. Witnessedbv ..,. MCtEHANEY';:,,· ,MCLEHANEY , ,y,.' ,:' ,.,.,T, ": ....,. ' RUN "', BORE·HOLE RECORD' ¡" "," 'CASING RECORD No, Bit"" From:To" .' ·Siø· '. Wat.' From 1/ 9õ", :, 1 609 " 8225'13, " 5'4# SFC .,. 9¡:;"" "...., '''.i': ····13 U,;( , SFC ....:'" : ',"'" ." .".', i,;,' : "; '.",', ,'. i":,;,·,. ,~ Tit: ',. ..,,,;>.":",: _ "" ,.:"", !'. ". ',,"';' .' c.', ",' ::,',' " I';. "" ._, . " U , ,~- - - . . 1 J I I . . . . . . . . . . ~~.. - ~ -- .. --. .. -~--- ~- --- -- -.. -. " ,; :¡ '11<\ I" {"",., "', ,~"", '{,-.,,' ~SèHWMBER6Ea~1 <.\,:'" .,~:~-'.;" . :"~(I¡. ~": >~,' ' -. ;,'-~_";:":,(',",~' '-, '/ _::';i~;/~".~ I' , " , ~ï j ~ ~ ! I I ! ~ . . . -.-- ---- - .-- I -f- ...... . 'L{oÇ()~' /-1-~3~11 ~ i I' 11 i1 i-I ,\ 'i :1 :j I :1 :¡ I I> I: ,\ I j I~ ¡ I I , \ ,< rt :i j ¡j I ~ rj :! ~ , 'j í '. ,1 ',: ·_.........._4____._. -~ ~ -~-- _'7_ ..,.~ .- ,. .-.... -'-.-'-' __ uu, ,u -~ ."-'--~.._. ~--,.- -, . - ~" .""._~- .~... -, I- ':, .( < Q J'.",: ." Elev,: K.B. D.F. 11 6 G.L. "'. to- Z w ~ A. < " ::> " w . , . , " " " ',' , , .... ,..- "',' , ,', . -c- . c' , , . . '. , " To 1h09 1 ¡:::'Oq t! , ' OJ :I: D ~ , f , , , ~-_._.~-.-~- --- ..-.--.- ---- ...,-_.- ~1 Š~~~~(),L .. COMPANY . t' ~s-; 0 ~ if,- ,W, :..J :z ,-" , " _" .'.c,._", , . '" '.- - ." STATEA-1-3 ¡9--43-11 ",.>i ' ( .7· FIE~º . '-:';v:\:';':·,". ,- ;c,; :_-:, "',::' ::',,:' -';- -,-:"".:;>..'~,.,--;"" COUNTY.;~:tCOOK; INLET ,,,: - '.),:'!¡ i;."Z'''i>-' '. ' .... ..... ·.',....,·,i ·.h..~··8...·.:· .:.: .~,; .L8~TI9:~6~~~"·~,,:'8b~'~···~~ Z ~~.... ~ :,./;;¡"tii}\·",/.? (S M· ) §'ii:'Š'~;:' '8i' S~~1~"·:<· ··11}t';.·t~~~.8NL::,:',' ~ge:13W . . DF'."; 'Elev <1 16 . Elev,: K.8, . g~': " .." Ft. Above·Pernt. Datum .'. , D,F. ~-. G.L. MIDDL.E'GROUNDSHOAL STAT~LASKA i I ií I ¡ @ @' 'It ml OF @ of @ of o.F @ of @ o.F of @ of @ of of @ of @ of III III: III :z: D oJ 0 ... --_...._~_..,- ~1. _.....--_.-~,._'...,:--....,.- ---.-------.--..---.- , ,-- -~- ~ , " " ---- --.. " -"". ~ " ,.- .-.. '- -- -.. --. .:¡of . ,_'''V''_ _ ~_ _ .___ " :i:,,';:~- '~:"";-- !lir Ii; ii' ~:! , i<!'" ¡U¡: i#'" ~t~:'~ ~~)~ ~ !¡ If H:',~ ~Il" ,1 -- ~>~" '-". "..- .- -" '"'' '" - --- .. -" -,- " .- -- ,,' "":",,,~~;;;¡',,,,v,, ._:'" ",;",", ",', FSCflOJÙ8ERG,' , . '" "'>-'.' '~.:' :,r~"",-,-., ~ ''':''~',,''/,f..:' 'ai , . '" t . . .. . . . . . . . . . . . . - ;i, ~.: l 'f I' ~, ~::' I~ ii ~." ~;,'~ I, ~' ~,. If ~:l i,li III' r I ~: 1,1 ! ~\~ ,j}" " , :.,) "" I''',' ,', ,; , ,;;i,'" ,~!: , "oL, :",~ : :,I"'~:5§ " , :",,',,',..:J ; '~: ::~ ~ :.:~: ~ WELL. ·""~-5rAT.E'ttÀ~1;~3·:j"" -,' /9 -- df-3-// , ~ ê~ ~~, ~ flEW 1 ~ ì DDll;¡~RÒUNØ ~~~DAL '~:',;, '~~[ ~ ':;",,,,~,{ ':',:<'>' ;;->:,,;,~ ;;:t'f;,';)-,:;'" " 13 ~:t;~~I.. iñ>-, "'~~UNTY: ,,'COO~'.N::E;' :,',;:~STA,TE ALASKA r';' " 'Õ':" Z' :LOCATION\1:640"N~&j4'Or{,W, "OR., i,', ' Other Serv.ices: I'~~'¡::'.·.' -<.> ,.·'·'·;:S,E'."CQRNER:'·;: ...<,...'., 59ð=",,'~ .' ',;" '; ;:;~)::';,y~;;'/>,'>,"';~{S"M~) , ',8~:g~:' 8 See, 11, '·:t~:\~8t·l':>~ge:13W :. ", 1~¿iji2~~;!;~~~~þ~ ¡:~I.V:' ~~: ~116 ~ ........;':{.."t;¡;",,"'·,~ ~~"'6~'''f:'''~'''¡':,~~,:',~ "" ';',,', ., ,~ I: ,-,~-~~.--, ..;w.g,.~ '~il"'~~:t;i;,£.:~,I."1o:o~'>tt' N.. i~a" ~\'-"~'(\ " !"'tJ!:JI';Þ' ¡':::'?~_"F/ - <- -':'..' "'_""::"":.,:-" .r- ~'R~'Nci~~·, ao:~",*A{,;40/~:~·f:;:""·'::;".,!' ',.' ',' " :, '. 'De})th~:DñIl.f(;';c;:,\~ 2 ,", .:."1";~¡'#~'':4-;' " ''',' '" " ,"', IJ 'Djøttí-Loaaer' 'T~"'; .,' ';"" '..,' . ,'",', ~ 8tnvloaJntervaT: 223 ,", 'I~ ,'.; ':l"1;" " ,:", ',' "" "'- :~:i;:~~::I~:~:' !,~,~1';,~,:(~,~~~""~~~'1'::~~@~'\W ; ': I: ' ~' ,: ~ :'" ~ :. r....sif')o.;.::;loaaer, ".:"< ;' "", '", ,,; , I '., I'~ ,Bit 'Slze" ;':f;"" ,'""",' '9: ','" :;~" ",. "':" , ',' ! zrype"~luid;in Hol,e 'XP-'20 au-'2 - :r'" ,'",' ,,', ',' ,~ ¡ 0 ",: . SPERSENE:', PER ,ENE ,,,;C~ I -, "Dens, TVisc, ,7~'" 5' .. 38';' "', I,' " ~ .'". Tffuid Loss· :1'0;,2 1;4!~( :rmIlT...<'t¡4~ 2ml '," ml ' 1\" ml " ; I 1'Sourc8' 'of Sam '''III ^T~I'''' ~ ;·NE:.;;;....;~" , -', . , "~ "Rm@ MeoJ,Temc:r.;: )5·@ lOO~1 L2:i@:"8.o°F;' . @ .' .oF --:- @oF . c::¡ · ';".Rmf@Meos.Témc.L ~6"'@61;,"Qt 1('7"@'71.;,of '. @. .oF @QF,'; '" ~;imc@Meas>T~mc. '.. voJ @ ó7 '..o~ 3,~ ·~'.:¡:@~70i<oFI"',' @, .oF '....... @ ,oF ,'. I :;' Source: Rmf" Rm,M;;"""'~;'I~M':>'<" :'," ",':'", '1"M':--'i ,'" I "-. ~ :;',Rm @',BHT "~':1.17@l4 1Qe ~';:H <'@'145°F,'L,'@ ,oF .'@ '. of " CI .., ,rtme,S¡nce:-Circ.~':r:3 HRS."~ ' ': - <'HRS:;.L,'''-' ;" ..........., '. .,' ,7 . Max, Rec, 'Temo,14 J ' r14S'( "I ""::'°f·' ',':- .oF" of ~ ~ t Eauip, Location,C 180' IA LASK IALA SK " . I . '~ ~ I Rec:orde'" It.. '" I 11:.':' ESS;' ~,:; " ' :. '. ' -:- ". '. ',0 ì Witnessed By ~EHANEY' ICLEHANEY' . ).. . .'.. ,~ , .-.., , " ''< "'i:",:'-:. " ".' ('" ~" n', , ;::;~,*,,-.:,:' ,,'~ "~'~' ," :~ I;~' ~ ~ COMPANY' SHELL 'OIl, COMPANY { 09ði ·,'..f,' ;!:>:":,,""} f. . . ~ -!f ; ,,~J ~ ';",'" :.-.;: \<). " , " , r r ~ ~ i.-: (' )' (' ~ ' ¡, \~ : , í~' , 1:\ ~ ~ I" ~~ I, ,,1 ~" " ~ .. .. 1; c: -- -~" , ""- " , , ,,,¿ , ' ','''' -" " ~/} 4/1 'I'r':" ",'; ',!, '. "''..JI'''_.....".. " : .~~ , t r ~ . -4 ..J' ~,r I î '1 t' ~i I (I')i I (::1(";,'1,,' ~. 21_1" w 6!"';" I i.:= 0:: i<r., ,r,. Ui f ,¡~~ C, 4f; i:¡0r; Z· ·t: f>- :;. '- 0 t,'Z , ':; 0 ~ I".,' II « ,L,' 0... ... 0 «:::t' I' 5 -'-JUui - O~O>: 10 u lL. _01 ;>': i U I~! ;1 ~~ ¡ 0, (~, 121 :01 1 t I ~ ¡_~i j¡-;J I ':I: i I~! CÓMPANY $HELL (; IL CO~1PANY' & :/11.,(;'.¡ ;/Z___~:5 ,- / Ii :W~,;LL /"ott>- S";ATE f~..1-3) , :, "~,,,--,-,.,...,,,__,, ___h__'"''''__''_''~''''''''''' I &:,ÇÖi R ~r"\I'-r\ i\ t F' i ' I" ¡ ,I ',-~- ...--,-...., ......--.. -";..,-._...'!':J____._.~ _~.;~l1jt~ ~_._...~)._J_3_5 5... -4 i , 25 j ¡ 0 11 ' u ~1 fODL E GROUND' SHOAty!Slu;\¡ i";, I: :~CÖU.NIY; COOK :LOCATIONì640 N ,', " nr',:~ E Vt ~, INLET ! f n II: H j i ¡'i , , at !; 1 I: .fl !Wi 'I Ii í i' I 1; I J, I 11 I: i · ¡;,LL.=;, '~';"~=~"==~.. ,-. .;:.." .·?i:'":::..·.d.:.:¡;;~~~~-.,.~.""":';5".,.~..c , . ;/ ,- , Permanent; Datum: ~!: , ,fie'!, 1 i 6 j- Elev ' i l.og Meos4red' From .~. , ft Above Perm DotufTl ¡ Drillin9 M~osurt~d Fr~ml f 1 j £, t, BO\! E /'-1L:_ \fl , . Dofe ~ 4 - 7 - 65 4·, 1 9" 6 5 5 - 7 - 6 5 ¡ J.t. . ;. , Run No. Y QNE TWO THRE E ·g=~;R·~~·Pt~'~i;"""v'''l ~ 2~ ,~g~ ~ '~}~ g ßtm, i 09 Ifltervol 'f;320 '5082 '821 G Top Log Ir\tervali\.i ~18 1610 5082 Casing D)-illin ' 44 '" 319 13:1 1 609 13 ~ 'd 1 609 '-cösin~J';"t~gge'I""M;'q í 8 '61 0 ' Bit Sizc' ~ í:8 ,]; 9" 02 Type F!ui(~in Hqle0LAŸ. BASE XP~:20 XP~~20 ,\. SPE'R'SENE' SPERSENE j Dens, ~ Visc(,.r, 15 ,50, )5( ,;44¡ ,78,5 38 j pH Flµid,l9ss; ~ 0 ,9 4 rnJ,11 ,.0 :,6',4 tn 10 2 ,4,0 mi' ¡ Source oqS(f,rPle-~ 9IR~UL,A TEDC I RC\JLA'TED CIRCuLATED i :::1:' ~;'~:};~i~' t ~~:.: ~~ ~;i' ~,j,::~,~~ .~ ~ ~~" ~ iO ~. ~ RnH '" M(1hs:llo'fTl.rt;, 5,45 '" 69 f 3< 4 ~:',¡58F 5, 55: 67 I ~ Sour'e Rn~~:':R"iF', M H ::M," ,'" ;H t-1H i' R", "/ ß~T-'4,3 ,,89 r'l'2s':,,"124F 1,15,143 f r! Time :;jnc& Ciu;':' t'; HRS,. 2:, HRS;:, ,'t\ !-IRS, ~M(1x,Rec.¡rernp,,~a9 F1?t1 ,'I, 1'43 F [Equip Ld,cotion ,ctT80ALASK^:~í80¡.ALASKA C180~¡ASK^ ¡R(Kørdedoß.r"'''~·''''''''Þ1ARCHETTE· HARCHFÙrE . Î'1AHCHÉ,TJ[ ~ Wltnc,>sed By ,MCLEHANEY 1CLEHANEY ,HCL EHANEY 8~J STATEALt>SK/\ .IOthe< S""ó«" (S 1-1 J 1 31,-J K,ß, 1 i 6 [),r, G,L, I ~ , J I & 40í vi C OR N E R ( ~ 1 1 Seç~.<, " Rge. . ,.' " . .t .' r n '.J _ _ .~,,:,. ',,:...:,....~.-A~J.::..~,_.',.~_ ,,_,~__,,___"_..___~~_,-,,:,~..,.,___.,. _.,~,,,,,_~ , . .' . -."" ",.- -,-_.,..........--"._-_.._,._~............,--'-".......,......_.------.-,..,..,.. ~1 --.J >- <.( z 0 <t :r: 0... (/) :¿ 0 OM U f- Z I LLJ ~~ _J --.J 0 I Z cY <1, 0 L:J W _J ~ . 1-' _I 0 0<1. W 0 - f- :r: U ¿U1 If) Z >- >- ....0 Z I- 0- « ZQ~~ Q. ::>~U~ ~ OWOW 0 UU:--'~ U COMPANY SHELL O! L COMPANY '''Rr:-r--r--r-'T r., h)"-- , . ~-. \'.~ L. , \. L \ WEll FIELD STATE A-1-3 /1-4-3-11; ':' : \ ,) "è ::', ¡ q ~~~ ~--~ Dlvr.s¡nj\] or: ....'jt :r~r: Q ~!.~ :O:'.Ï\ M I DOLE GROUND SHOAL"" ""'''-'''~ "","u·.AlS ANCHCI.2Þ.C;F COUNTY COOK I NL ET lOCATION 1640 N & 401 W OF S,E, CORNER STATfALASKA r) I Other Services: Twp. 8N Rge. (S. M, 13W Sec. Î 1 Permanent Datum: log Measured From Drilling Measured From OF ,Elev. 116 D F Ft. Above Perm. Datum OF (11'6 AGaVE MLLW Elev.: K.B. D. F. ,1I~~,,== G.L. . Date 4 - 7 - 65 ;4 - 1 9 - 6 5 "-,--,,,, "-,,, -"-,, ¡ Run No. i ONE TWO gf~1~",p~~~e;rn--'¡ f~~~ - is 08 6 _'_''_n'_''_, _ ¡ ¡~g~~ B_t!11:._~~!1_I':'.t"e~\l.l~ .Il} 2 0 I ~~inLJ!1:-~nrtifi;ra-nt~18 (IIi 319 H ~1 0 (0 if~~~~-Toggern-I?~8, "[61Ô I 9{ 9£ Type Fluid in Hole¡CLAY BASE ixp- 20 XP- 20 I !SPERSENE SPERSENE Dens. ¡Vise. 175 ! 50 175 \44 78,5 138 pH 1 Fluid Loss 9 0 19 ,4 mil" .0 6,4 ml , 0, 2 14, 0 ml Source of Sample CIRCULATED iC IRCULATED CIRCULATED Rm (/'Meas, Tel11p. 5,25 «/'72 °F!1.9 «/80 OF 1,65 «(/'100°F - , , I Rmf (/ Meas. Temp,S. 55 «/;69 "F i2. 1 «/'58 OF 1,86 ("67°F Rmc «/)Meas.Temp. 5,45 «(/'69 "F~3,4 (/,58 "F 5.55 «(/'67 "F I I' I Source: Rmf Rmc M I M 1M 1M MM. Rm (/:BHT 4.3 «/89 "F!1,25 «(/ 124'F 1,15 ((/,143"F Time Since Cire. 1 I, HI~ S , 121, HR S . 2 \ HR S , Max. Ree. Temp. 89 . "F 11 ì4 "143 "F Equip. ¡Location (180 ¡AL^SKr.~i80IALASK C180~L^SKA Recorded By MARCHFTTE ¡MARCHETTE ~1ARCHETTF Witnessed By MCLEHANEY Cl. CHANEY MCLEHANEY I 15-7-65 ..,t THRE-E--- - ---- t8225 '8220 c ¡ 8 216 ¡ 5()82 t __..n 1____....·..·.........__.. _ . ________.___ .... ___L __ 1609' 13;~ (Í111609 -- -~~----~ -_.._--- --..-- -+-.-------- (it ----.--,..-...---- ml «/' "F (u' of (/ of (n (\F IJj "F ~ J' ~! (, ... F ! ,1\' .' ~\ ;~;L"~" ,~;, ,~..',~ , 1'1' . . /... ..... .. .~. r"; ':, ,"" "" ,,;. . ',., . ' ',.', ~,' ',:. ~~:r;\~ . C , I. .,' ;",",: { .. , y .,' '" :",,:, ::::,:~'.:,/ '; '.' ;': ;: ¿~:;:'<~ ''';'{;~;;b('Q;j¡(,§<' ;, ; :.' J" :It.' ';, ..,' ',.:::::<~f;:'?/::~i;·,::, " .... " . ~,' I ,I',': , 1'1 , , '. ' ,I , " I, ..1="; ~~ ' ..:.~,~. Ir~~-I.} , . I ¡,,, ..' " :>~ztJ.' '~·::::"::?f~t;.::~.~r '" ; ': '>:JL:'~~\(,~<Ç\F:;:~: ...,.;-: ", . L~ _LP' ... ~. ,.;.:.. . l.·~_: '_I:. :.. ~·~·~·I -' -'_~.-;.: ~:)"_ ; .. :"::J.'~i~\ ,,,'_-1 :,._"._!~_~_~~~ :.I..~~¡~ '1"'- -. "'.. ... .~. .... ·"L1',t:; .-, "~~."~ .' . ~ . t: }j~:~~;<;~~~"i;·.. .' .' . '.. ~ .' ..' . .. .. , ,:RUN ·'No." W. ·:,'2 :3.,. 4\ " ~ '.~' " .:";, ~j1 I.. ,,~ ~! i« .. :¡;.I.II¡~ '.II. ,", '" ',¡ ,~" 'If· ',I:I""':'!":I" 1. 1J ,j,¡' .,1 ,1 '-\* ~G~ >":'''1. ~ ."~~,: ;:', "'''' \'~! ....:..:- I:," i....t~ ~ 1'"..: 'It'll ~ ~ I r "I ~._ :P.~ ~~ ._~ .t 1.: . , . .)'~~ . ~ ". ..II <, ,'\" ~"\, ' ." ,.:'.\~,\ ~',:~~ }t\i'
