Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
174-013
OllI&IN STATE OF ALASKA -~L~SKA OIL AND GAS CONSERVATION COIV,~nSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r-'-] GAS ~ SUSPENDED r~ ABANDONED [] SERVICE 2 Name of Operator ARCO Alaska, Inc 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 2150' FSL, 515' FEL, SEC 8, T7N, Rgw, SB & M At Top Producing Interval N/A At Total Depth 2190' FSL, 533' FEL, SEC 8, T7N, Rgw, SB & M 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 178', 152' GL 12 Date Spudded O3/O6/74. 17 Total Depth (MD+TVD) 10,790' MD, 10,779' TVD 13 Date T.D. Reached 05/08/75. 18 Plug Back Depth (MD+TVD) 9451"MD, 9449' TVD A-028996 14 DateComp., Susp. orAba[~. I 02/02/91. (Aband & sidetracked) 19 Directional Survey ' 20 YES O NO 7 Permit Number 74-0013 & (10403 SA) 90-822 8 APl Number 50-133-10121-01 9 Unit or Lease Name SWANSON RIVER UNIT i0 Well Number J'~43A-8 11 Field and Pool SWANSON RIVER FIELD HEMLOCK OIL POOL 15 Water Depth, if offshore N/A Depth where SSSV set I I N/A feet MD 16 No. Completions feet MSL N/A 21 Thickness of permafrost NA 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD Note: 7' Plugged back to 9451' and sidetracked as 43B-8 I 24 Pedorations open to Production (MD+TVD of Top and Bottom and interval, size and number) SETTING DEPTH MD TOP BOTTOM SURF 42' SURF 2,081' SURF 1O886' 9451' N/A HOLE SIZE I CEMENTING RECORD *Previous csc, I corrected to new RKB of 178' 16" I 1300 SX 9-7/8"I 2200 SX AMOUNT PULLED 25 TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL {MD) I AMOUNT & KIND OF MATERIAL USED *See Attached Operations Summary 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested IPRODUCTION FOR OIL-BBL IGAS-MCF I TEST PERIOD Press.Flow Tubing Casing Pressure _I24'HOUR CALCULATEDIO L'BBL IGAS'MCF RATE 28 CORE DATA Brief description of lithology, porosity, fractures, appareht dips and presence of oil, gas or water. Submit core chips. N/A WATER-BBL WATER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl' (corr) RECEIVED Alaska,O~i & Gas Cons. Commission ~chorage' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS , , , NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A 31. LIST OF ATTACHMENTS REPORT OF DAILY OPERATIONS , , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ....... ~__~__~_~~ Title AREA DRILLING ENGINEER Date __~_""/~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod 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 pedinent 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. 'ARC~ ALAS~KA INC. WELL: SCU DAILY OPERATIONS PAGE BOROUGH: FIELD: UNIT: LEASE: API: WELL: PERMIT: KENAI SWANSON RIVER FIELD SOLDOTNA CREEK UNIT A-028996 50-133-10121-01 SCU A3A-8 ~,74-0013 APPROVAL: ~ AFE: AD7150 WI: 48.4864 ACCEPT: 01/25/91 SPUD: RELEASE: 02/~)2/91 OPERATION: .'8 & .A' r% ~.~,~,-',--~-~-~ RIG: GRACE 154 KtttlVtU JUN 1 7 1992 Alaska Oil & Gas Cons. Commission ;Anchorage 01/25/91 (1) TD: 0'( SUPV:EB 01/26/91 (2) TD: 0' ( SUPV: EB 01/27/91 (3) TD: 0'( SUPV:EB 01/28/91 (4) TD: 0'( SUPV:EB 01/29/91 (5) TD: 0' ( SUPV: EB 0) 0) 0) 0) 0) TEST BOPE MW: 0.0 VIS: 0 RIG UP GRACE 154,ACCEPT RIG @ 18:00, CHECK CSG PRESS(0PSI) ND TREE AND NU ADAPTER FLANGE AND BOPE, TESTING BOPE DAILY:S155,063 CUM:$155,063 ETD:S155,063 EFC:$1,390,000 RD CSG TOOLS MW: 9.6 VIS: 0 TEST HYDRILL & BOPE, BOLDS, PULL BAKER 15' S-22 LOCATOR SEAL ASSY F/PKR W 93K ANNULUS FULL, LD LANDING JT, HANGER & PUP JT, CBU @ 10130', GAS BUBBLE TO SURFACE, CLOSE RAMS & CIRC TO 9.6 PPG, MONITOR WELL-STATIC, POOH, LD COMP STRING & JEWELRY. DAILY:S21,589 CUM:$176,652 ETD:S176,652 EFC:$1,390,000 PU CSG SCRAPERS MW: 9.6 VIS: 0 RD GBR TBG TOOLS & CLEAR FLOOR, SET TEST PLUG & TEST UPPER & LOWER KELLY COCKS FLOOR SAFETY VALVE & INSIDE BOP TO 250/4500 PSI, RIH W/BAKER PKR RETRIEVING TOOL TO 10,100' AND WASH TO PKR @ 10,151', SHEAR RELEASE ON PKR, CONT TO PU SHEAR RELEASE ON SAFETY JOINT W/24K, ATTEMP TO CIRC, RELEASE TOOL, CBU, SMALL GAS BUBBLE TO SURFACE, CIRC TO 9.6 PPG, RE-ENGAGE TOOL, ATTEMPT TO CIRC, POOH SLOW TO 7" CSG, CBU-NORMAL, POOH, LD PKR & TAIL PIPE W/SAFETY JOINT, SET WEAR RING & MU 5" CSG SCRAPER. DAILY:S32,246 CUM:$208,898 ETD:S208,898 EFC:$1,390,000 PREPARE TO SPOT BALANCED PLUG MW: 9.6 VIS: 0 FIN SETTING WEAR PLUG, PU & TIH W/5" & 7" TANDEM CSG SCRAPERS TO TBG STUMP @ 10,178' DPM W/7" SCP @ 9600', CBU-NORMAL, POOH LD 18 JTS 2-7/8" DP, RU AWLS & RUN VERTILOG IN 7" F/9500' TO SURF, REPEAT F/6100' TO 5000', RD ATLAS, MU HOWCO 5" CMT RETAINER & RIH TO 9997', SET RETAINER & PRESS TEST BACKSIDE TO 2000 PSI, RU HOWCO & TEST LINES TO 5000 PSI, ATTEMPT TO ESTABLISH RATE, PUMP 1.25 BBL, PRESS @ 4100 PSI, CIRC. DAILY:S36,146 CUM:$245,044 ETD:S245,044 EFC:$1,390,000 TIH MW:10.0 VIS:100 CIRC & BATCH MIX CMT, PUMP 10 BBLS H20 & 75 SX G CMT BLENDED W/.l% HR-5 & .3% CFR-3 MIXED @ 15.8 PPG, DISPLACE & BALANCE PLUG W/2.6 BBLS H20 & 62.5 BBLS NACL, 9.6# BRINE HOLDING 500 PSI BACKPRESSURE ON CHOKE. POOH SLOW 9400', REV OUT DRILL STRING, CHAIN OUT OF HOLE,~LD 15 JTS DP & ST BACK 2-7/8" TBG PU 15 4-3/4" DC & TIH, PREPARE 10.0 PPG HI-VIS MUD, TAG UP ON FIRM CMT @ 9470', DISPLACE HOLE W/50 BBLS H20 & HI VIS WINDOW MUD, POOH, PU 7" MILL & TIH. DAILY:S50,483 CUM:$295,527 ETD:S295,527 EFC:$1,390,000 01/30/91 ( 6) TD:' 0" ( SUPV: EB 01/31/91 ( 7) TD: 0'( SUPV:EB 02/01/91 (8) TD: 0'( SUPV:EB o) o) 0) 02/02/91 (9) TD: 9385' (9385) SUPV:EB 02/03/91 (10) TD: 9436'( 51) SUPV:EB CUT DRLG LINE ~ MW:10.0 VIS:120 Tf'~'~/MILL, TAG CMT @ 9470' POOH ~ MILL 7" CSG · , Fi ~0'-9450' & PUMP 300 VIS SWEEP, CBU, MONITOR HOLE, STABLE, POOH, INSPECT MILL, NORMAL HOLE FILL W WEAR PATTERN ON CUTTER ARMS INCONCLUSIVE, iNTEGRITY OF COMPLETE CUT QUESTION- ABLE, CHANGE OUT MILL, TIH TO VERIFY POSITIVE 70' WINDOW, SLIP & CUT DRLG LINE DAILY:S27,870 CUM:$323,397 ETD:S323,397 EFC:$1,390,000 WOC MW:10.4 VIS: 52 REAMED F/ 9380 T/ 9450,CBU, POH, TIH W/ BIT AND WORK INTO STUMP,POH, TIH W/ TBG STINGER TO 9465,RIG UP HOWCO AND BATCH MIX CEMENT,PUMPED 75 SX CMT AND SET BALANCED PLUG, POH 4 STDS AND REVERSE OUT, SHUT IN WELL WITH 2000 PSI, HOLDING PRESS ON WELL AND WOC DAILY:S47,800 CUM:$371,197 ETD:S371,197 EFC:$1,390,000 RIH MW:10.4 VIS: 47 WOC, POH,WORK ON BOPE, TEST BOPE, RIH, STOP AND CIRC AT 4000' DAILY: $24,818 CUM: $396,015 ETD: $396,015 EFC: $1,390,000 GYRO AND ORIENT MW:10.0 VIS: 46 RIH, TAG CMT @ 9183,DRILL HARD CMT F/9183 T/9385,CIRC, POH LD BHA, PU STEERABLE SYSTEM, RIH, S&C DRLG LINE, RIH, RUN GYRO AND ORIENT 'DAILY:S28,079 CUM:$424,094 ETD:S424,094 EFC:$1,390,000 TIH MW:10.0 VIS: 53 ORIENT TOOL FACE, SIDETRACK OFF OF CMT PLUG, DRILLED FROM 9385 T/9436,MWD SURVEY AND POH,BHA CHANGE, RIH DAILY:S48,114 CUM:$472,208 ETD:S472,208 EFC:$1,390,000 RECEIVED JUN 1 ? 199 Alaska CJI & Gas Cons. CommJssio~ Anchorage ' STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. ~'ype of Request: Abandon _ " Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging ~ Time extension _ Stimulate _ Change approved program _ Variance _ Perforate _ Other 2. Name of Operator 6. Datum elevation (DF or KB) ARCO Alaska. In(;, . 3. Address P. O. Box 100360, Anchorage, AK 99510 Pull tubing ~ 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2150' FSL, 515' FEL, Sec. 8, T7N, RBW, SB&M At top of productive interval 2237' FSL, 539' FEL, Sec, 8, T7N, RBW, SB&M At effective depth 2199' FSL, 533' FEL, Sec, 8, T7N, RBW, SB&M At total depth 2190' FSL, 529' FEL, Sec. 8, T7N, RBW, SB&M 12. Present well condition summary Total Depth: measured 10,790' feet true vertical 1 0,779' feet Effective depth: measured 1 0,745' feet true vertical 10,735' feet Plugs (measured) Junk (measured) RKB 170' GL 152' feet 7. Unit or Property name Soldotna Creek Unit 8. Well number ECU 43A-8 9. Permit number 74-0013 10. APl number ~;0-133-10121-01 11. Field/Pool Swanson River Field Hemlock Oil Pool 13. 43A-8 will be P&A @ 9,500'. 43B-8 to be sidetracked from 43A-8 Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 20" Driven 34' md 91' tvd Surface 2,051 1 1-3/4" 1300 sxs 2073' md 2073' tvd Intermediate Production 10,860 7" 2200 sx 10,866' md 10,873' tvd Liner 1 1 71' 5" 117 sx 9,619'-10,790' md 9,617'-10,779' tvd Perforation depth: measured 10728'-10717', 10714'-10708', 10702'-10688', 10678'-1064,~,~1~:~7.'=-:[0,,61,,3~,. 10601'-10584', 10576'-10567', 10556'-10531', 10523'-1051 KI:Li:IV U true vertical Tubing (size, grade, and measured depth) NOV 0 1990 3-1/2" 9.3# N-SO @ 9,559; 2-3/8" 4.7# N-80 f/9,559'-10,166' Packers and SSSV (type and measured depth) Baker "SC-1L" Pkr ~ 10,151' A~achments Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation De{;ember 15, 1990 16. If proposal was verbally approved Date approved 15. Status of well classification as: Oil ~; Gas _ Suspended Service Name of approver Date 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (,.~///~¢/~~ Title Area Drilling En,(]ineer FOR COMMISSION USE ONLY IApproval No. ,,~ .~ .,~ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- ~c~ Commissioner Approved b), the order of the Commission 0RIglN~t. ~t~NED BY LONNIE C. SMITH Approved Date //--/o3 ~ SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 SCU 43B-8 Sidetrack and Redrill Summary The following general procedure outlines the planned work to sidetrack and redrill the SCU 43A-8 as SCU 43B-8 and complete the well in the Hemlock formation as a non-gravel packed single completion. The procedure includes the cutting of approximately a 70 foot section in the 7 "casing~at +9350' and then sidetracking from the original wellbore using conventional methods. The well will then be redrilled to a total measured depth of approximately 10,800'. The new wellbore is planned for a minimum step out to the east/northeast. Except for the sidetrack out of the old wellbore, this well will be essentially a straight hole with as low an angle as possible through the Hemlock. Following the re-drill and open hole logs a 5" liner will be run and cemented in place. The well will then be completed as a non-gravel packed single completion in the Hemlock formation. Actual completion procedures will be determined after cased hole logs have been run and evaluated. Please note that the new well is renamed as SCU 43B-8 and will be referred to as such in the future. RECEIVED NOV o 91990 ~1 & Gas Cons. ~~1~ SCU 43B-8 General Procedure · e . . e e . . e 10. 11. Install BPV in tubing hanger· Move in and rig up Grace Rig #154. Pull BPV. Bleed off pressure in tubing and casing annulus. Kill well by bullheading 9.2 ppg NaCI kill weight brine down tubing. RU slickline and set plug in Otis 'X' Nipple @ 10,133'. Pull valve from GLM @ 10,092'. Circulate kill weight brine down tubing up annulus. Pull plug in Otis 'X' Nipple. RD slickline. Ensure well is dead, install BPV, ND tree, NU BOPE, pull BPV. Install test plug and test BOPE to 5000 psi. Pull test plug. Stab into Shaffer tubing hanger with a joint of 3-1/2" EUE 8rd tubing and pull present completion assembly. LD all tubing - and accessories. PU cement retainer for 5" 18# casing and RIH. Set retainer at + 10,100'. Test retainer with 10,000# string weight and 3000 psi on backside. Squeeze + 75 sacks class G cement below retainer and spot an additional 75 sacks cement on top of retainer to put TOC @ + 9,500'. POOH 10 stands and reverse out any excess cement. Finish Make 6" bit and scraper run to TOC. POOH. Test casing to 2500 psi for 30 minutes. If casing does not test, RIH with retrievable packer w/bypass and isolate casing leak interval. POOH. If casing tests, skip to step #12. PU and RIH with a 7" drillable bridge plug on drill pipe and set below leaking interval. Shear off bridge plug and spot a balanced cement plug of sufficient volume to put th top of cement + 250' above top of leaking interval. POOH 150' above TOC and bradenhead squeeze 6-8 bbls cement into leaking interval. POOH. Drill out cement to bridge plug. Test casing and repeat procedure if necessary. If casing tests, drill up bridge plug and make bit run to PBTD. 12. Displace casing w/ 10 ppg Hi-Vis mud suitable for section milling. 13. GIH w/ Tri-State Metal Muncher section mill for 7" casing. 14. Cut 70' section f/+ 9,350' - 9,420'. POOH. 15. GIH open ended and spot a 65 sack balanced densified cement plug on top of existing cement so that TOC is 200' above the top of section. POOH 7 stands and squeeze 2 to 3 bbls cement into the formation if possible. Open preventers and POOH. 16. GIH w/ 6" bit and dress off kick-off plug to 10' below top of casing section. POOH. 17. Side track well out of section with 100' displacement (+ 50') to the East/Northeast from the current bottom hole location keeping angle as low as practical. Redrill well to + 10,800' TVD, 18. Log open hole and make any additional necessary rat hole on the conditioning trip prior to running casing. 19. Run 5" production liner and cement same. 20. Clean out to TOL and test same to 2500 psi. 21. Clean out inside of liner and retest to 2500 psi. 22. Run cased hole logs 23. 24. 25. 26. Run completion assembly. Perforate w/TCP. POOH and LD drill pipe. ND BOP's, NU tree, and test same. Displace to lease crude. 27. RD and MO rig. Turn well over to Production Supervisor. , . ~ SCU 43A-8 Spud Date: 5/74 Original RKB: 18' Top of Hemlock:10,352' MDMax. Hole Angle: APl#: 50-133-10121-01. Well Type:S1 Pro<lurer ; Completion Date: 5/17/74 Lilt Workover: 1-1/5/89 Hanger Type: Shaffer Hanger: Shaffer Angle @Hemlock: 0o All Depths are RKB MD to Top of Equipment. 4 k, L Jewelry 1 1999' 2 3940' 3 9569' 4 10092" S 10133' 6 10151' 7 10174' 8.. 1.01Z_~. 9 10453' . . 1'0 10,678' 11 10,692' K-BUG Mandrel w/'E' Dummy BK2 Latch K-BUG Mandrel w/'E' Dummy BK2 Latch 3 1/2' x 2 3/8' X-Over TMPOX Mandrel wi1' CEV 8K2 Latch 2 3/r 'x' Nipple Baker SC-IL Packer X-Over Sub Shear-out. S_a.fety. Jr._ Baker Weld Screen (0.20 Gauge) O-Ring Seal Sub (I.D. 1.316') 3 7/6· Bull Nose -~.1: ?" F~O~ SOU 9827' Window Casing and Tubing 20" 11-3/4" 4711 J-55 7" 29il N-60 5" 18il N-80 3-112" 9.3il N-80 2 3/8' 4.7# N-60 Perforation Data 10,514'- 10,523' 10,531'-10,556' 10,567'-10,576' 10.$84'-10,601' 10.613'-10,63~' 10.646'-10,678' 10..688'-11,70~' I~, '/'~e,'o IO/?/~~ / I0, '71'7 o 10/'7 Z.~ ' H6 9' 4 H8 25' 4 148 9' 4 1-18 17' 4 H9 19' 4 H10 32' 4 H10 14 4 '-"1 0 30' 0 2085' 0 9619' 9619' 10,790' 0 9656' 9559' 10.166' 5/74 5/74 5/74 5/74 5'74 5/74 5/74 DeacrlDtlo~ Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Reperf 10/89 · · Reperf 10/89 H9 HIO II PBTD · 10,745' TO · 10.790' ~ $CU 43A-8 JLB 11/15/89 SCU 43B-8 Liner Schematic ,~. 20" @ 34' 11-3/4" @ 2,093' Top of SCU 43B-8 5" Liner @ _+9,050' SCU 43B-8 7" Section Cut @ -+ 9,350'-9,420' Kick off Cement Plug Top of Squeeze Cement/Bottom of Kick off Plug at _+9,500' Top of SCU 43A-8 5" Liner @ 9,627' SCU 43A-8 7" Section Cut @ _-+9,835' 5" Cement Retainer @ _+10,100' SCU 43A-8 Abandoned Wellbore PBTD @ 10,753' ---- TD @ 10,798' = Cement Note: All depths are measured, corrected to RKB=178', G.L.=152',RKB-G.L=26' (Original RKB-G.L.=18°) '' G~DRILL]:IqG COMPANY - RIG 1~54/-.~ 10,000f CHOK.B MALqZFO.T.,D ZN EXZDDED HOU~E , (1). 10,000J LTNB, }'ROI4 BOPS - (2).- 10,000I-C~AOS8 (3) 4*' 10,000l VALVBB ('4) 3" 10,000'! VM, V'aS ' (5) 10,000! HYDRAULXC CHOlq~8 ($) 3" 5000! VAr, VB8 (?) 3" x S000l CROgS ' ."q l) 3" x S000t X, ZNB8 ' ,9) 4" x $000l LXHB8 Grace 154 Drilling Fluids System i ~1 .I I I ! · · I " I )~ ;" " II Iii I I I : 13-5/d" SO00 PSI BOP S', ACK DIAGRAM ACCUMULATOR CAPACITY TEST ! "l REYENTER/ II . PIPE RAMS BLI ND RAMS ~-~ DRILLINO SPOOL I PIPE RAMS I TBO SPOOL 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2, ASSURE THAT ACCUMULATOR PRESSURE IS 3500 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD. 3. OPEN CASING VALVE(S) ON TUBING HEAD. (MONITOR CASING VALVE FOR FLOW THROUGH OUT BOP STACK TEST). 4. CLOSE ANNULAR PREVENTER AND TEST TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO. 5. OPEN ANNULAR AND CLOSE TOP PIPE RAMS. TEST TOP PIPE'RAMS, CHOKE MANIFOLD VALVES, AND STACK VALVES TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN PIPE RAMS. 8. CLOSE CASING VALVE(S) AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF A NON-FREEZING LIQUID AND ALL VALVES ARE SET IN THE DRILLING POSITION. 9. TEST STANDPIPE VALVES TO 250 AND 5,000 PSI. 10. TEST KELLY COCKS AND INSIDE BOP TO 250 AND 5,000 PSI. 11. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR, 12, PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. FUNCTION TEST BLIND RAMS EACH TIME OUT OF THE HOLE. ALL BOP EQUIPMENT 5000 PSI RATED ~"'".. STATE OF ~ AD-,.... ,A OIL AND GAS CONSERVATION COMMi,.'~,.$iON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed' Operation Shutdown__ Stimulate __ Plugging Perforate Alter casing Repair well ~ Pull tubing Other X recomplete 2. Name of Operator ARCO Alaska, lng. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2150' FSL, 515' FEL, Sec. 8, T7N, Rgw, SM At top of productive interval 2237' FSL, 539' FEL, Sec. 8, T7N, R9W, SM At effective depth 2199' FSL, 533' FEL, Sec. 8, T7N, Rgw, SM At total depth 2190' FSL, 529' ~FEL, Sec. 8, T7N, Rgw, SM 12. Present well condition summary Total Depth: measured 1 0790' true vertical 1 0779' feet feet Plugs (measured) 6. Datum elevation (DF or KB) 172' RKB 7. Unit or Property name Soldotna Creek Unit feet 8. Well number $CU 43A-8 9. Permit number/approval number 74/9-764. 9-948 'lq- L;5 10. APl number 50-133-10121-01 11. Field/Pool Swanson River/Hemlock Pool Original 7" plugged w/ sidetrack window @ 9827' Effective depth: measured 1 0745' true vertical 1 0736' feet feet Junk (measured) Casing Length Size Structural 1 1 ' 2 0" Conductor Surface 2051' 11 Intermediate Production 1 0860' 7" Liner 11 72' 5" Perforation depth: measured true vertical 3/4" Cemented 1300 sx 2200 sx 117 sx 9618-10790' Measured depth 110' 2073' 10886' True vertical depth 110' 2073' 10873' 9616-10779' 10540-10576;10584-10601;10613-10630;10646-10678 10537-10573;10581-10598;10610-10627;10643-10675 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 2 3/8" 4.7# N-80 @10693'md Baker Gravel pack "SC-1" Pkr ~ 10151 'md RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure [V AY 0 1 199 ~aska 0il & Gas Cons. C0mmissi '. ;~ch0rage 14. Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation () Subsequent to operation () 15. Attachments '~i6. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector __ Daily Report of Well Operations X Oil X Gas Suspended '17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 05/17/89 Title Area Drilling Engineer SUBMIT IN DUPLICATE ARCO C~. ,~nd Gas Company Well History - Initial Report -/l~ily Inslraetlona: Prepare and submit the "Initial Raiment" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field SOLDOTNA CREEK UNIT Auth. or W.O. no. AD6552 ICounty. parish or borough SWANSON RIVER FIELD Lease or Unit A-028996 Title WORKOVER SCU 4~-8 Well no. Operator ARCO Spudded OrWORKOvERW.O. begun fOate IHour Date and depth aa of 8:00 a.m, 10/13/89 ( TD: 0 PB:10745 SUPV:BES 10/14/89 ( TD: 0 PB:10745 SUPV:BES 10/15/89 ( TD: 0 PB:10745 SUPV:BES 10/16/89 ( TD: 0 PB:10745 SUPV:BES 10/17/89 ( TD: 0 PB:10745 SUPV:BES lO/18/89 ( TD: 0 PB:10745 SUPV:BES 10/19/89 ( TD: 0 PB:10745 SUPV:RWS 3) The above i~,,j~orrect Signat~--~'~,~l~ ~ For form preparetlga~iad ~is..tribu.t[on, ~ see Procedures M~nu~, Section 10 Dr rig, Pages 86 ~87. Complete record for each day reported GRACE 154 NU BOP'S MW: 9.2 NaCl ACCEPT GRACE 154 @ 0600 HRS, 10-12-89. DAILY COST INCLUDES COST OF SNUBBING OPERATION ($99,901.) RU ATLAS WIRELINE. SHOT HOLES IN 2-7/8" TBG F/9,535'- 9,537'. DISPLACED WELL W/9.2 PPG BRINE. WELL DEAD. SET BPV. ND TREE AND NU BOPE. DAILY:S205,291 CUM:$205,291 ETD:S205,291 EFC:$1,535,000 TESTING BOPS MW: 9.2 NaC1 FIN NU BOPE. TEST BOPE 5000 PSI. DAILY:S27,253 CUM:$232,544 ETD:S232,544 EFC:$1,535,000 GIH W/4-1/8" BIT MW: 9.2 NaCl PU AND RELEASED PKR. CBU. POH AND LD 2-7/8" TBG. STD 2-3/8" TBG IN DERRICK. GIH FOR CLEAN OUT TRIP. DAILY:S15,877 CUM:$248,421 ETD:S248,421 EFC:$1,535,000 CLEANING OUT 5" LINER MW: 9.2 NaCl FGIH. TAGGED @ 10,532'. DRILLED OUT SAND AND ASPHALT TO 10,633'. ARCO W.I. 48.4864 AR3B-459-1-D iPage no. Prior status if a W.O. DAILY:S14,995 CUM:$263,416 ETD:S263,416 EFC:$1,535,000 CKEANING OUT 5" LINER MW: 9.2 NaCl DRILLED OUT LINER TO 10,650'. TFNB. HAD TO REAM F/ 10,530'-650' WHILE GIH. CLEAN OUT TO 10,680' W/ BLADED JUNK MILL. (ROP = 4 FPH) DAILY:$17,887 CUM:$281,303 ETD:S281,303 EFC:$1,535,000 POH W/MILL MW: 9.2 NaCl FILLED FILL F/10680-10702. POOH LAY DOWN 2 3/8" TBG. STRAP & PICK UP 3 1/8" DC & 2 7/8" DP FINISH POOH. SERVICE RIG. PICK UP MILL BUMPER SUB & OIL JARS RIH TIGHT @ 10526. TAG FILL @ 10639. WASH & REAM F/10639-10695. MILL ON FILLR OR JUNK @ 10695 (POSSIBLE 5" LINER COLLAPSED?) RIG UP AND REVERSE CIR @ 10695 MILL @ 10695. PUMP HI-VIS SWEEP. CIRC HI-VIS SWEEP OUT. POOH DAILY:S18,515 CUM:$299,818 ~TD:$0 EFC:$1,834,818 SOAKING PERFS W/XYLENE MW: 9.2 NaCl POH LD MILL AND JARS. PU DU[v~4Y GP ASS'Y AND GIH. TAGGED @ 10,693' POH AND LD GP SCREENS. GIH W/ 5" RTTS TO 10,497' SET PKR. COULD INJECT DOWN BACK- SIDE W/ 2,800 PSI @ 2.75 BPM. TREATED PERF W/ 55 BBLS XYLENE. LET XYLENE SOAK. INumbe, all las they are ~:mp~k,'~d~f6r:'~ well.' ARCO Oi,:. .... d Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporled on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState ARCO ALASKA INC. I SWANSON RIVER FIELD I AK Field ILease or Unit I SOLDOTNA CREEK UNIT I A-028996 SCO 43E-8 Date and deptll Complete record for each day while drilling or workover in progress as of 8:00 a.m. GRACE 154 10/20/89 ( TD: 0 PB:10745 SUPV:RWS 10/21/89 ( 9] TD: 0 PB:10745 SUPV:RWS 10/22/89 ( 10 TD: 0 PB:10745 SUPV:RWS 10/23/89 ( 11 TD: 0 PB:10745 SUPV:RWS 10/24/89 ( 12 TD: 0 PB:10745 SUPV:RWS 10/25/89 ( 13 TD: 0 PB:10745 SUPV:BS POH W/ RTTS MW: 9.2 NaCl REVERSE OUT CONTAMINATED BRINE AND XYLENE. POH. PU 5" BP AND 7" RTTS AND GIH. SET BP @ 9676' AND RTTS @ 9551'. ATT TO TEST TOL TO 3,000 PSI. WOULD BLEED TO 2,700 PSI AND HOLD. COULD NOT ESTABLISH INJECTION. POH. ISOLATED 7" CASING LEAK BETWEEN 6173'-5640'. POH W/ RTTS. DAILY:S18,140 CUM:$343,981 ETD:S343,981 EFC:$1,535,000 TESTING BOP'S MW: 9.2 NaCl POH AND LD RTTS. GIH AND SET 7" BP @ 6,200'. SPOT 5 SX SAND AND 1SK SF ON BP. SPOT 200 SX 'G' CMT ON TOP OF BP. POH TO 4,746'. REV CIRC. SQZ AWAY 2 BBLS@ 3,000 PSI. WOC. POH. CO TBG SPOOL. TEST BOPE. DAILY:S53,749 CUM:$397,730 ETD:S397,730 EFC:$1,535,000 POH MW: 9.2 NaCl FIN TESTING BOPE. GIH W/ BIT AND TAG TOC @ 5,125'. DRLD CMT AND TESTED CSG TO 3,000 PSI EVERY STD. FIRST BLEED OFF @ 5,592' DRLD TO 6,100' W/O TEST- ING. ATT TO EST INJ W/O SUCCESS. PRESS WOULD BLEED F/3,500 PSI TO 2,600 PSI IN 6 MIN. POH. DAILY:S15,050 CUM:$412,780 ETD:S412,780 EFC:$1,535,000 DRILLING CEMENT MW: 9.2 NaCl PU STINGER AND GIH. SPOT 150 SX 'G' CEMENT. POH 11STDS. REV CIRC. SQZ AWAY 2.75 BBLS. WOC. TFB. TAG TOC @ 5,343'. DRLD CMT TO 5,781' TESTING CSG TO 2,500 PSI EVERY STD. OK SO FAR. DAILY:S15,050 CUM:$427,830 ETD:S427,830 EFC:$1,535,000 GIH MW: 9.2 NaCl DRLD CMT TO 6186' TESTING CSG EVERY STD TO 2500 PSI. WASH SAND TO 6191'. TRIP AND RETRIEVE 7" BP. TESTED CSG AND TOL TO 2500 PSI. OK. GIH TO RETRIEVE 5" BP. DAILY:S15,050 CUM:$442,880 ETD:S442,880 EFC:$1,535,000 MIXING BRINE CLEANING PITS MW: 9.2 NaCl FINISH TIH, TAGGED SAND AT 9665'. REVERSED OUT SAND ON TOP OF 5" RBP TO 9676' LATCHED AND RELEASED RBP. CBU. POH AND LD 5" RBP. MU 4 1/8" BIT AND 5" CASING SCRAPPER. TIH AND SPACE OUT CASING SCRAPPER. FINISH TIH TAGGED AT 9591'. CBU. CIRCULATED GAS-CUT BRINE THROUGH CHOKE. OPENED CHOKE AND BAG, CIRCULATED WELL AND MONITORED. RU D-5 AND PUMPED SCOUR SLURRY. MIXING CLEAN- ING BRINE AND CLEANING PITS. DAILY:S33,769 CUM:$476,649 ETD:S476,649 EFC:$1,535,000 Well no, The above is correct Signatu re~.~ IDate For form preparation an. mW~tist~ibuti0n ~ see Procedures Manua~'S~ction 10, Drilling, Pages 86 and~6F' AR3B-459-2-B INumber all daily well history I'Orms consecutively as they are prepared for each well. IPage no. ARCO 0i~ ~'.,d Gas Company Daily Well History--Interim Inatructione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem testa sequentially. Attach description of alt cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Finni" form. t) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and Iollowing setting of oil strinG until completion. District Field Date and deptl~ as of 8:00 a.m. County or Parish ARCO ALASKA INC. J SWANSON RIVER FIELD Lease or Unit SOLDATNA CREEK UNIT I SCU 43B-8 Complete record for each day while drilling or workover in progress GRACE 154 10/26/89 (14) TD: 0 PB:10745 SUPV:BES 10/27/89 (15) TD: 0 PB:10745 SUPV:BES 10/28/89 (16) TD: 0 PB:10745 SUPV:BES 10/29/89 (17) TD: 0 PB:10745 SUPV:BES 10/30/89 (18) TD: 0 PB:10745 SUPV:BES 10/31/89 (19) TD: 0 PB:10745 SUPV:BES 11/01/89 (20) TD: 0 PB:10745 SUPV:BES JState POH MW: 9.2 NaCl FIN CLEANING PITS AND MIXING BRINE. DISPLACED HOLE W/ CLEAN BRINE. CIRC & FILTER BRINE. POH W/ SCRAPERS. DAILY:S34,041 CUM:$510,690 ETD:S510,690 EFC:$1,535,000 MU SURGE ASS'Y MW: 9.2 NaCl FIN POH W/ SCRAPERS. MU BAKER TCP ASS'Y. GIH AND TIE IN. SET 7" PKR AND PRESSUkED UP TO 1400 PSI ON ANNULUS TO FIRE GUNS. POH W/ PERF ASS'Y. ALL SHOTS FIRED: 10,540'-576', 10,584'-601', 10,613'-630', 10,646'-678'. DAILY:S55,792 CUM:$566,482 ETD:S566,482 EFC:$1,535,000 REVERSE OUT FILL MW: 9.2 NaCl GIH W/ SURGE ASS'Y AND SURGE WELL. ALLOW TO FLOW FOR 1 HR. LEFT WELL SI I HR. REVERSED OUT WELL FLUIDS UNTIL BRINE CLEANED UP. TFB. TAGGED FILL @ 10,589'. REVERSED OUT FILL. DAILY:S32,393 CUM:$598,875 ETD:S598,875 EFC:$1,535,000 POH MW: 9.2 NaCl CLEAN OUT FILL TO 10,714' FILTER FLUID. ATT TO INJECT INTO WELL. COULD NOT PUMP IN A~ 1500 PSI. PRESSURE WOULD BLEED OFF 200 PSI/MINUTE. ST TO TOL. TAGGED FILL @ 10,616'. DP PLUGGED. POH 30 STDS AND PLUG LET GO. GIH AND REVERSED OUT FILL. POH. DAILY:S20,427 CUM:$619,302 ETD:S619,302 EFC:$1,535,000 POH MW: 9.2 NaCl GIH W/ RTTS. SQZ 70 BBLS XYLENE INTO PERFS. LET XYLENE SOAK 3 HRS. FLOWED WELL TO GAGE TANK FOR 5-1/2 HRS. OPEN BYPASS AND KILL WELL. DAILY:S52,919 CUM:$672,221 ETD:S672,221 EFC:$1,535,000 GIH MW: 9.2 NaC1 POH AND LD RTTS. GIH W/ BIT. REV OUT FILL TO 10,694'. DRILLED OUT TO 10,714'. CIRC OUT. ST. TAG @ 10,700'. WASHED TO 10,714'. PLUGGED DP. POH AND UNPLUGGED 750' OF 2-3/8" TBG OF SAND. GIH TO CLEAN OUT. DAILY:S40,577 CUM:$712,798 ETD:S712,798 EFC:$1,535,000 POH MW: 9.2 NaCl TAGGED FILL @ 10,678'. CLEANED OUT TO 10,714'. ST. TAGGED FILL @ 10,625. CLEANED OUT TO 10,720'. SPOT 25 BBL XC PILL. ST. TAGGED @ 10,698'. DAILY:S29,653 CUM:$742,451 ~TD:$742,451 EFC:$1,535,000 IWell no. The above is correct Signatur~.~ ~ For form preparation ~ dis~rib~'tion ~ see Procedures Manq~l~Section 10, Drilling, Pages 86 anE"87 Date AR3B-459-2-B Number all daily well history forms consecutively ~Page no. as they are prepared for each well. I ARCO O,...nd Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ali drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporled on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District JCounty or Parish IState ARCO ALASKA INC. I SWANSON RIVER FIELD I AK t Field ,ILease Or Unit SOLDATNA CREEK UNIT I SCO 43B-8 Complete record for each day while drilling or workover in progress GRACE 154 Date and depth as of 8:00 a.m. 11/02/89 (21) TD: 0 PB:10745 SUPV:RWS 11/03/89 (22) TD: 0 PB:10745 SUPV:RWS 11/04/89 (23) TD: 0 PB:10745 SUPV:RWS 11/05/89 (24) TD: 0 PB:10745 SUPV:RWS GIH W/ GP ASS'Y MW: 9.2 NaCl POOH TO 9,476'. CLEAN PITS AND BUILD VOLUME. GIH AND TAGGED @ 10,698'. POH TO 10,300'. CIRC AND FILTER FLUID. POH. MU GP ASS'Y AND GIH. DAILY:S37,087 CUM:$779,538 ETD:S779,538 EFC:$1,535,000 TESTING GRAVEL PACK MW: 9.2 NaCl TAGGED FILL @ 10,693'. SET GP PKR. PUMPED 1,000 GAL 15% HCL PICKLE JOB AND REV OUT. GP WELL W/ 25 BBLS 8 PPG 12/20 SLURRY. SAND OUT W/ 4,000 PSI AFTER 20 BBLS SLURRY THROUGH TOOL. REV OUT EXCESS SLURRY AND WO GEL TO BREAK. PACK WOULD NOT TEST. REPACK WELL W/ 30 BBLS OF 6 PPG SLURRY. SANDED OUT TO 4,000 PSI W/ 10 BBLS SLURRY THROUGE TOOL. REV OUT EXCESS SLURRY AND WO GEL TO BREAK. TESTED GP TO 3,500 PSI. DAILY:S36,399 CUM:$815,937 ETD:S815,937 EFC:$1,535,000 RUNNING COMPLETION ASS'Y MW: 9.2 NaCl TEST-GP. POH & LD DP. PU 2-3/8" X 3-1/2" COMPLETION. DAILY:S28,996 CUM:$844,933 ETD:S844,933 EFC:$1,535,000 LOGGING GRAVEL PACK MW: 9.2 NaCl FIN RUNNING COMP ASS'Y. SET 'PX' PLUG AND TEST TBG STRING TO 2,500 PSI. OK. ND BOP'S AND NU TREE AND TESTED. OK. RU ATLAS AND GIH W/ PHOTON GP EVALUA- TION TOOL. DAILY:S67,971 CUM:$912,904 ETD:S912,904 EFC:$1,535,000 IWell no. The above is correct Signature ~ ~ For form preparation ~ distribution see Procedures Manu~iSection 10, Drilling, Pages 86 and 87 IDate AR3B-459-2-B JNumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Flail Rellert" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report combleflolt and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available, I Accounting cost center code JCounty or Parish i State I s.~sON RIVER Field ILease or Unit IWell no. SOLDATNA CREEK UNIT I A-028996 SCU 439-8 I Auth. or W.O. no. JTitle AD6552 ~ WORKOVER District ARCO ALASKA INC. Operator A.R.Co. W.I. ARCO I 48. 4864 Spudded or W.O. begun ~ Date J WORKOVE R Date and depth Complete record for each day reported as of 8:00 a.m. GRACE 154 11/06/89 (25) TD: 0 PB:10745 SUPV:RWS Iotal number of wells (active or inactive) on this, Dst center prior to plugging and I bandonment of this well our ! Prior status if a W.O. I RIG RELEASED MW: 9.2 NaCl FIN LOGGING GP. RD ATLAS. EVALUATE LOG. PREP RIG TO BE STACKED TEMPORARILY OVER THE WELL. (GP LOOKS POOR.) RIG RELEASED @ 1600 HRS, 11-5-89. DAILY:S41,455 CUM:$954,359 ETD:S954,359 EFC:$1,535,000 Old TD I New TD 1 PB Depth 1 Released rig ] Date ]Kind of rig Classifications (oil, gas, etc,) Type completion (single, dual, etc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasT~st time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected · The above is correct I o o preparatio~/a~u distribution, see Procedures Man~, Section 10, Drilling, Pages 86 and 87. AR39-459-3-C Number all daily well history forms consecutively Page no. Ias they are prepared f°r each we ' I Dlvllto~ ol AtlantlcRIchfleldCompaay ARCO, ~nd Gas Company O Well History - Initial Report - Dail~ Iltlllll~tl~ltl: Prepare end submit the "lltttill R~tt" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior tO SPudding should be summarized on the form giving inclusive dates only. District lCounty, perish or b gh .... ARCO ALASKA INC. SWANSON RIVER FIELD Field Lease or Unit SOLDOTNA CREEK UNIT I A-028996 SCU 43~-8 Auth. or W.O. ilO. ITitle AD6552 I WORKOVER Iwel! no. Operetor ARCO Date and depth as Of 8:00 a.m. 10/13/89 ( TD: 0 PB:10745 SUPV:BES 10/14/89 ( TD: 0 PB:10745 SUPV:BES 10/15/89 ( TD: 0 PB:10745 SUPV:BES 10/16/89 ( TD: 0 PB:10745 SUPV:BES 10/17/89 ( TD: 0 PB:10745 SUPV:BES 10/18/89 ( TD: 0 PB:10745 SUPV:BES 10/19/89 ( TD: 0 PB:10745 SUPV:RWS IARCO W I 48.4864 Prior status if a W.O. Complete record for each ~ay GRACE 154 1) 2) TESTING BOPS FIN NU BOPE. 3) 4) CLEANING OUT 5" LINER FGIH. TAGGED @ 10,532'. 10,633'. 5) 6) 7) NU BOP'S MW: 9.2 NaC1 ACCEPT GRACE 154 @ 0600 HRS, 10-12-89. DAILY COST INCLUDES COST OF SNUBBING OPERATION ($99,901.) RU ATLAS WIRELINE. SHOT HOLES IN 2-7/8" TBG F/9,535'- 9,537'. DISPLACED WELL W/9.2 PPG BRINE. WELL DEAD. SET BPV. ND TREE AND NU BOPE. DAILY:S205,291 CUM:$205,291 ETD:S205,291 EFC:$1,535,000 TEST BOPE 5000 PSI. MW: 9.2 NaCl DAILY:S27,253 CUM:$232,544 ETD:S232,544 EFC:$1,535,000 GIH W/4-1/8" BIT MW: 9.2 NaCl PO AND RELEASED PKR. CBU. POH AND LD 2-7/8' TBG. STD 2-3/8" TBG IN DERRICK. GIH FOR CLEAN OUT TRIP. DAILY:S15,877 CUM:$248,421 ETD:S248,421 EFC:$1,535,000 MW: 9.2 NeC1 DRILLED OUT SAND AND ASPHALT TO DAILY:S14,995 CUM:$263,416 ETD:S263,416 EFC:$1,535,000 CKEANING OUT 5" LINER MW: 9.2 NaCl DRILLED OUT LINER TO 10,650'. TFNB. HAD TO REAM F/ 10,530'-650' WHILE GIH. CLEAN OUT TO 10,680' W/ BLADED JUNK MILL. (ROP - 4 FPH) DAILY:S17,887 CUM:$281,303 ETD:$281,303 EFC:$1,535,000 POH W/MILL MW: 9.2 NaCl FILLED FILL F/10680-10702. POOH LAY DOWN 2 3/8" TBG. STRAP & PICK UP 3 1/8" DC & 2 7/8" DP FINISH POOH. SERVICE RIG. PICK UP MILL BUMPER SUB & OIL JARS RIH TIGHT @ 10526. TAG FILL @ 10639. WASH & REAM F/10639-10695. MILL ON FILLR OR JUNK @ 10695 (POSSIBLE 5" LINER COLLAPSED?) RIG UP AND REVERSE CIR @ 10695 MILL @ 10695. PUMP HI-VIS SWEEP. CIRC HI-VIS SWEEP OUT. POOH DAILY:SiS,S15 C0M:$299,818 LTD:SO EFC:$1,834,818 SOAKING PERFS W/XYLENE MW: 9.2 NeC1 POH LD MILL AND JARS. PU DUt~JY GP ASS'Y AND GIH. TAGGED @ 10,693'. POH AND LD GP SCREENS. GIH W/ 5" RTTS TO 10,497'. SET PKR. COULD INJECT DOWN BACK- SIDE W/ 2,800 PSI @ 2.75 BPM. TREATED PERF W/ 55 BBLS XYLENE. LET XYLENE SOAK. ~Tu:~2~,6~ ~'~:~,~3~,uuu The above i~orrect Slgna~ see Procedures M[Inul~, Section 10, Drilling, Pegee 86 tn~lf 87. AR3B-459-1-D I Number ell dally well hlllofy forms consecutively they are prepared for each well. iPage no. ARCO ~d~ Gas Company ,~,"~ Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in desCribing work performed, Number ail drill stem testa sequentially, Attach description of all cores. Work performed by Producing Section will be reported on "lnlltl111" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovera and following setting of oil strin~ until completion. ARCO ALASKA INC. I SWANSON RIVER FIELD Field JLea.e or Unit I A-028996 SOLDOTNA CREEK UNIT SCU 43B-8 Date and depth ss of 8:00 a.m. 10/20/89 ( TD: 0 PB:10745 SUPV:RWS 10/21/89 ( 91 TD: 0 PB:10745 SUPV:RWS 10/22/89 ( 10; TD: 0 PB:10745 SUPV:RWS 10/23/89 ( 11 TD: 0 PB:10745 SUPV:RWS 10/24/89 ( 12 TD: 0 PB:10745 SUPV:RWS 10/25/89 ( 13 TD: 0 ?B:10745 SUPV:BS Complete record for each day while drilling or workover in progress GRACE 154 POH W/ RTTS MW: 9.2 NaCl REVERSE OUT CONTAMINATED BRINE AND XYLENE. ?OH. PU 5" BP AND 7" RTTS AND GIH. SET BP @ 9676' AND RTTS @ 9551' ATT TO TEST TOL TO 3,000 PSI. WOULD BLEED TO 2,700 PSI AND HOLD. COULD NOT ESTABLISH INJECTION. POH. ISOLATED 7" CASING LEAK BETWEEN 6173'-5640'. POH W/ RTTS. DAILY:SiS,140 CUM:$343,981 ETD:$343,981 EFC:$1,535,000 TESTING BOP'S MW: 9.2 NaC1 POH AND LD RTTS. GIH AND SET 7" BP @ 6,200'. SPOT 5 SX SAND AND 1 SK SF ON BP. SPOT 200 SX 'G' CMT ON TOP OF BP. POH TO 4,746' REV 'CIRC. SQZ AWAY 2 BBLS @ 3,000 PSI. WOC. POH. CO TBG SPOOL. TEST BOPE. DAILY:S53,749 CUM:$397,730 ETD:S397,730 EFC:$1,535,000 POH MW: 9.2 NaCl FIN TESTING BOPE. GIH W/ BIT AND TAG TOC ~ 5,125'. DRLD CMT AND TESTED CSG TO 3,000 PSI EVERY STD. FIRST BLEED OFF @ 5,592'. DRLD TO 6,100' W/O TEST- ING. ATT TO EST INJ W/O SUCCESS. PRESS WOULD BLEED F/3,500 PSI TO 2,600 PSI IN 6 MIN. POH. DAILY:S15,050 CUM:$412,780 ETD:S412,780 EFC:$1,535,000 DRILLING CEMENT MW: 9.2 NaCl PU STINGER AND GIH. SPOT 150 SX 'G' CEMENT. POH 11STDS. REV CIRC. SQZ AWAY 2.75 BBLS. WOC. TFB. TAG TOC @ 5,343'. DRLD CMT TO 5,781' TESTING CSG TO 2,500 PSI EVERY STD. OK SO FAR. DAILY:S15,050 CUM:$427,830 ETD:$427,830 EFC:$1,535,000 GIH MW: 9.2 NaCl DRLD CMT TO 6186' TESTING CSG EVERY STD TO 2500 PSI. WASH SAND TO 6191'. TRIP AND RETRIEVE 7" BP. TESTED CSG AND TOL TO 2500 PSI. OK. GIH TO RETRIEVE 5" BP. DAILY:S15,050 CUM:$442,880 ETD:$442,880 EFC:$1,535,000 MIXING BRINE CLEANING PITS MW: 9.2 NaCl FINISH TIH, TAGGED SAND AT 9665'. REVERSED OUT SAND ON TOP OF 5" RBP TO 9676' LATCHED AND RELEASED RBP. CBU. POH AND LD 5" RBP. MU 4 1/8" BIT AND 5" CASING SCRAPPER. TIH AND SPACE OUT CASING SCRAPPER. FINISH TIH TAGGED AT 9591'. CBU. CIRCULATED GAS-CUT BRINE THROUGH CHOKE. OPENED CHOKE AND BAG, CIRCULATED WELL AND MONITORED. EU D-5 AND PUMPED SCOUR SLURRY. MIXING CLEAN- ING BRINE AND CLEANING PITS. DAILY:S33,769 CUM:$476,649 ETD:S476,649 EFC:$1,535,000 ' 1Well no. The above is correct Sign atu re,~,l~".-4.~ ~ , For form preparation an~e~'~is~ibution see PrOcedures Manua~rS~ction tO. Drilling, Pages 86 and~&; AR3B-459-2-B ~Number all daily well history forms consecutively }Page no. las they are prepared for each well. ARCO C ~d Gas Company Daily Well History--Interim Ifletl~lotioIts: This form iS used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work 0erformed. Number all drill stem tests sequentially. Attach description of all COreS. Work 0erformed by Producing Section will be reported on "Interim" sheets unUl hnal completion. Report official or representative test on "Filtal" form. 1} Submit "Interim" sheets when filled Out 0u! riot less tre(~uently than every 30 days, or on Wedneeclay of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District ICountyor Parish let ARCO ~L~SY, A ];NC. Field lLease or Unit Scu 43B-8 SOLDATNA CREEK UNIT Date and dePtl~ as of 8:00 a.m. 10/26/89 (14) TD: 0 PB:10745 SUPV:BES 10/27/89 (15) TD: 0 PB:10745 SUPV:BES 10/28/89 ( 16} TD: 0 PB:10745 SUPV:BES 10/29/89 (17) TD: 0 PB:10745 SUPV:BES 10/30/89 (18) TD: 0 PB:10745 SUPV:BES 10/31/89 (19) TD: 0 PB:10745 SUPV:BES 11/01/89 (20) TD: 0 PB:10745 SUPV:BES Complete record for each day while drilling or workover in progress GRACE 154 POH MW: 9.2 NaCl FIN CLEANING PITS AND MIXING BRINE. DISPLACED HOLE W/ CLEAN BRINE. CIRC & FILTER BRINE. POH W/ SCRAPERS. DA];LY:$34,041 CUM:$510,690 ETD:S510,690 EFC:$1,535,000 MU SURGE ASS'Y MW: 9.2 NaC1 FIN POH W/ SCRAPERS. MU BAKER TCP ASS'Y. GIH AND TIE IN. SET 7" PKR AND PRESSURED UP TO 1400 PSI ON ANNULUS TO FIRE GUNS. POH W/ PERF ASS'Y. ALL SHOTS FIRED: 10,540'-576', 10,584'-601', 10,613'-630', 10,646'-678'. DAILY:S55,792 CUM:$566,482 ETD:S566,482 EFC:$1,535,000 REVERSE OUT FILL MW: 9.2 NaC1 GIH W/ SURGE ASS'Y AND SURGE WELL. ALLOW TO FLOW FOR 1 HR. LEFT WELL SI I HR. REVERSED OUT WELL FLUIDS UNTIL BRINE CLEANED UP. TFB. TAGGED FILL @ 10,589'. REVERSED OUT FILL. DAILY:S32,393 CUM:$598,875 ETD:$598,875 EFC:$1,535,000 POH MW: 9.2 NaCl CLEAN OUT FILL TO 10,714'. FILTER FLUID. ATT TO INJECT INTO WELL. COULD NOT PUMP IN A~ 1500 PSI. PRESSURE WOULD BLEED OFF 200 PSI/MINUTE. ST TO TOL. TAGGED FILL @ 10,616'. DP PLUGGED. POH 30 STDS AND PLUG LET GO. GIH AND REVERSED OUT FILL. POH. DAILY:S20,427 CUM:$619,302 ETD:S619,302 EFC:$1,535,000 POH MW: 9.2 NaC1 GIH W/ RTTS. SQZ 70 BBLS XYLENE INTO PERFS. LET XYLENE SOAK 3 HRS. FLOWED WELL TO GAGE TANK FOR 5-1/2 HRS. OPEN BYPASS AND KILL WELL. DAILY:S52,919 CUM:$672,221 ETD:S672,221 EFC:$1,535,000 GIH MW: 9.2 NaCl POH AND LD RTTS. GIH W/ BIT. REV OUT FILL TO 10,694'. DRILLED OUT TO 10,714'. CIRC OUT. ST. TAG @ 10,700'. WASHED TO 10,714'. PLUGGED DP. POH AND UNPLUGGED 750' OF 2-3/8" TBG OF SAND. GIH TO CLEAN OUT. DAILY:S40,577 CUM:$712,798 ETD:$712,798 EFC:$1,535,000 POH MW: 9.2 NaCl TAGGED FILL @ 10,678'. CLEANED OUT TO 10,714'. ST. TAGGED FILL @ 10,625. CLEANED OUT TO 10,720'. SPOT 25 BBL XC PILL. ST. TAGGED @ 10,698'. DAILY:S29,653 CUM:$742,451 ETD:S742,451 EFC:$1,535,000 no. The above is correct Signatur~~.~ ~ For form preparation ~1~ di~rib-~'tion ~ see Procedures Men~[l~l.~Eection I0, Drilling, Pages 86 an~'"~7 AR3B-459-2-B Number al~" daily Well history ~orms consecutively as lhey are prepared tot each well. IPage no. ~ ~----~ ARCO C ~d Gas Company,~, Daily .Well History--Interim Instructions: This form is used during drilling Of workovef operations. If testing, coring, or Derforating, show formation nsme in describing work 0ertormed. Number all drill stem tests sequentially. Attach description of all Cores. Work performed by Producing Section will be reported on "lnlerim" sheets until hnal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when tilled out but not less frequently than every 30 days. or (2) On Wednesday of the week in which oil string is set. Submit weekly for workovefs and following setting of oil strm~ until completion. District Field Date and depth as of 8:00 a.m. I County or Parish ARCO ALASKA INC. J SWANSON RIVER FIELD I Lease or Unit SOLDATNA CREEK UNIT I SCU 43B-8 Complete record for each day while drilling or workover in progress GRACE 154 11/02/89 (21) TD: 0 PB:10745 SUPV:RWS 11/03/89 (22) TD: 0 PB:10745 SUPV:RWS 11/04/89 (23) TD: 0 PB:10745 SUPV:RWS 11/05/89 (24) TD: 0 PB:10745 SUPV:RWS State GIH W/ GP ASS'Y ~: 9.2 NaCl POOH TO 9,476'. CLEAN PITS AND BUILD VOLUME. GIH AND TAGGED @ 10,698'. POH TO 10,300'. CIRC AND FILTER FLUID. POH. MU GP ASS'Y AND GIH. DAILY:S37,087 CUM:$779,538 ETD:S779,538 EFC:$1,535,000 CUM:$815,937 ETD:S815,937 EFC:$1,535,000 TESTING GRAVEL PACK ~: 9.2 NsC1 TAGGED FILL @ 10,693'. SET GP PKR. PUMPED 1,000 GAL 15% HCL PICKLE JOB AND REV OUT. GP WELL W/ 25 BBLS 8 PPG 12/20 SLURRY. SAND OUT W/ 4,000 PSI AFTER 20 BBLS SLURRY THROUGH TOOL. REV OUT EXCESS SLURRY AND WU GEL TO BREAK. PACK WOULD NOT TEST. REPACK WELL W/ 30 BBLS OF 6 PPG SLURRY. SANDED OUT TO 4,000 PSI W/ 10 BBLS SLURRY THROUGH TOOL. REV OUT EXCESS SLURRY AND WU GEL TO BREAK. TESTED GP TO 3,500 PSI. DAILY:S36,399 RUNNING COMPLETION ASS'Y [~: 9.2 NSC1 TEST GP. POH & LD DP. PU 2-3/8" X 3-1/2" COMPLETION. DAILY:S28,996 CUM:$844,933 ETD:S844,933 EFC:$1,535,000 LOGGING GRAVEL PACK MW: 9.2 NaCl FIN RUNNING COMP ASS'Y. SET 'PX' PLUG AND TEST TBG STRING TO 2,500 PSI. OK. ND BOP'S AND NU TREE AND TESTED. OK. RU ATLAS AND GIH W/ PHOTON GP EVALUA- TION TOOL. DAILY:S67,971 CUM:$912,904 ETD:S912,904 EFC:$1,535,000 lwell no. The above is correct Signature ~ ~ For form preparation ~ distribution see Procedures Manu{l~,,~ection 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO '~Jil and Gas Company Daily Well History-Final Report InllrUctionl: Prepare and submit the "Filial RI~I~" on the first Wednesday after allowal}le has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted iIIo ~ operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completlen and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I County or Perish J SWANSON RIVER FIELD Field ILease or Unit SOLDATNA CREEK UNIT I A-028996 SOU 43B-8 I Title J WORKOVER District ARCO ALASKA INC. ./Accounting cost center code I Slete JA~< I Well no. Auth. or W.O. no. AD6552 Operator I A.R.Co. W.I. ARCO ] Spudded or W.O. begun Date 48,4864 WORKOVER Date and depth as of 8:00 a.m. Iotal number of wells (active or inactive) on this DSt canter prior to plugging anti banc~onment of tt~is well our I Prior status if a W.O. I 11/06/89 (25) TD: 0 PB:10745 SUPV:RWS Complete record for each day reposed GRACE 154 RIG RELEASED MW: 9.2 HaCl FIN LOGGING GP, RD ATLAS. EVALUATE LOG. PREP RIG TO BE STACKED TEMPORARILY OVER THE WELL. (GP LOOKS POOR.) RIG RELEASED @ 1600 HRS, 11-5-89. DAILY:S41,455 CUM:$954,359 ETD:S954,359 EFC:$1,535,000 Old TD Released rig INew TO I PB Depth Date IKind of rig Classifications (oil, gal, etc.) I Type Completion (single, dual, etc.) 1 Producing method I Offl~'iel reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production 011 on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity AIIowei~ls Effective date correcte(:l ,, ,= The above is correct Drilling, Pages ~ and 87. AR3B-459-3-C INumber Ill dally well history fermi consecutively I Page no. es they are prepared for each well. I Olvl#on of AtlantlcRIchfleldComl~n ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSM1TrAL #388 TO:. John Boyle COMPANY: AOGC~ DATE: Feb, 5, 1990 FROM: Tom Wellman COMPANY: ARCO Alaska, Inc W~L NAME: SCU 43A-8 Transmitted herewith are the following Blue Sepia Sepia Line Folded Rolled Mylar Tape Photon Log Gravel Pack Survey 11/5/89 1 1 " 12/29/89 1 1 Receipt Acknowledgement: Return reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' FEB - 6 19 0 Alaska 0il & Gas Cons. c0mmi~1011 Anchorage ~/...,,. ~"-'~ STATE OF ALASKA ' A~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator Alter casing _ Repair well _ Plugging _ Change approved program ~X Pull tubing _ 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ 99510 Service _ ARCO Alaska. Ino, 3. Address P. O. Box 100360, Anchorage, AK _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) RKB 172' 7. Unit or Property name Soldotna Creek Unit 4. Location of well at surface 2150' FSL, 515' FEL, Sec. 8, T7N, R9E, SM At top of productive interval 2237' FSL, 539' FEL, Sec. 8, T7N, R9E, SM At effective depth 2199' FSL, 533' FEL, Sec.8, T7N, R9E, SM At total depth 2190' FSL, 529', FEL, Sec. 8,T7N, R9E, SM 12. Present well condition summary Total Depth: measured 1 0790' true vertical 1 0779' measured 1 0745' true vertical 1 0736' feet 8. Well number 43A-8 9. Permit number 74-0013/9-764 10. APl number .50-133-10121-01 11. Field/Pool SwansonRiver Field/ - .. Hemlock Oil Pool ~-~.~1(~ _Oi! .& Gas Cons, C0mmJsS[0~ ECE VED OCT 2 ? 1989 Effective depth: feet original 7 plugged w/sidetrack window @ 9827' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 1 1 ' 20" 34' md 34' tvd 2051' 11 3/4" 1300 sx 2073'md 2073' tvd 10860' 7" 2200 sx 10886' md 10873' tvd 11 72' 5" 117 sx 9618'-10790' md 9616'-10779tvd measured 1 0728'-1 071 7';1 071 4'-1 0708';1 0702'-1 0688';1 0678'-1 0646';1 0632'-1 061 3' 1 0601 '-1 0584';1 0576'-1 0567';1 0556'-1 0531 ';1 0523'-1 0514' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Change approved program from p&a and sidetrack to reperforate and run gravelpack completion in existing wellbore. 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch_ 15. 14. Estimated date for commencing operation October, 1989 16. If proposal was verbally approved Name of approver Date approved Status of well classification as: Oil X Gas _ Suspended Service 17. I here. by certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~~~ ~~"~4..~ Title AreaDrillin~En~]ineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No.g? Plug integrity __ BOP Test _ Location clearance__ Approved C~PY Mechanical Integrity Test_ Subsequent form require 10-¥0,M · Returne(~ Original Signed By Approved by the order of the Commission David W. Johnston Commissioner Date / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE _* ..... ; ~KA OIL AND GAS CONSERVATION COM! ~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend _ Operation Shutdown Re-enter suspended well Alter casing _ Repair well Change approved program _ _ Plugging ~ Time extension _ Stimulate Pull tubing _ Variance _ Perforate_ Other X SIDETRACK 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 2150' FSL,515' FEL, Sec. 8, T7N, R9W, SM At top of productive interval 2237' FSL, 539' FEL, Sec. 8, T7N, R9W, SM At effective depth 2199' FSL, 533' FEL, Sec. 8, T7N, R9W, SM At total depth 2190' FSL, 529' FEL, Sec. 8, T7N, R9W, SM 6. Datum elevation (DF or KB) RKB 172' 7. Unit or Property name Soldotna Creek Unit 8. Well number 43A-8 9. Permit number 74-0013 10. APl number 5o-133-1 01 21 -01 11. Field/Pool Swanson River Hemlock feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 11' 2051' 10860' 1172' measured 10728-1071 10601-1059 true vertical 1 0790' feet 1 0779' feet Plugs (measured)original 7" plugged w/sidet~l~v~ ~7~ 1 0745' feet Junk (measured) ~UG 2 1 0736' feet Alaska 0il & Gas Cons..~.om Size Cemented Measured depth True vertica/t,~l~g8 20" 34' MD 34' TVD I 1-3/4" 1300 SXS 2073'MD 2073'TVD 7" 2200 SXS 10886'MD 10873'TVD ,, 117 SXS 9618-10790'MD 9616'-10779'TVD 7;1 0714-10708;10702-10688;10678-10646;10632-10613 9;1 0599-1 0584;1 0576-1 0567;1 0556-1 0531 ;1 0523-1 0514 13. Tubing (size, grade, and measured depth 2-7/8" 6.5# N-80 @9568'MD; 2-3/8" 4.7# Packers and SSSV (type and measured depth) Baker 5" FH Packer @ 10,453'MD, No SSSV Attachments Description summary of proposal X N-80 f/9568'-10541'MD Detailed operation program X BOP sketch X 14. Estimated date for commencing operation Se.Dtember 20. 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ;~ Gas _ Suspended _ Service 17. I here~l,b~ certify that the foregoing is true and correct to the best of my knowledge. Signed j/-~'~ ~ ~ Title Area Drillinc~ Enc,:lineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance m Mechanical Integrity Test _ Subsequent form require ORIGINAL $I~iNE0 BY Approved by the order of the Commission LONNIE C. SMrI'H 10- ~o/-/ Commissioner IIAppr°val No~., ~, Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE ALASKA VICINITY MAP COOK INLET VICINITY IN 81TE OF $1DETRAGK ~ OPEFIATiON$ SCU 43A-8 ~~. ~ JULY '~g I 1~ 20 21 II_~ ' -- ~ II SOLDO~- ~ ~" SCU 43A~ ~ JULY '8~ , I I I I I SCU 43A-8 PLUGGING PROCEDURE SUMMARY: The following procedure outlines the proposed plugging of the current SCU 43A-8 completion prior to sidetracking. The sidetrack is required due to casing problems in the perforated interval making it impossible to clean out for a gravel pack completion. The procedure includes running a casing inspection log and squeezing off possible leaking casing in the 7" casing from 5,500' to 6,000'. Following plugging, the well will be sidetracked with a minimum step-out to the east or north east. SCU 43A-8 PLUGGING PROCEDURE (prior to sidetracking) Pre-ria work; -- 1. Rig up slickline unit and open sliding sleeve @ 10,418'. 2. Circulate and kill well with kill weight brine. Drilling mud may be used if necessary. 3. Set BPV in tubing hanger. R, ig work: 1. Move in and rig up Grace Drilling Co.'s Rig # 154. , Ensure well is dead. Nipple down tree and nipple up 13-5/8" 5M BOP stack. Pull BPV and set two-way check test plug. Test BOP's to 4,500 psi. Test annular preventer to 3,500 psi. 3. Pull test plug. Screw into tubing hanger with joint of 3-1/2", 9.2#/ft N-80, BT&C tubing. Pick up on tubing string and un-seat Baker "FH" packer from 10,453'. No recorded shear value available, typical for other SRF wells is has been 40,000# or 6-8 right hand turns. If packer will not pull or rotate free, cut tubing with electric line and fish packer with drill pipe. 4. Circulate bottoms up and pull out of hole with tubing string and packer assembly. . Run in hole with 5" 18# cement retainer on tubing. Set retainer at 10,464'+. (Approximately 50' above perforations.) Test retainer with string weight and 1,000 psi. Note: Because of the possibility leaking perforations shallow in the 7" casing between 5,500' and 6,000' the casing may not test. , Squeeze cement below retainer into perforations (approximately 25-30 sacks). Unsting from retainer and spot a balance cement plug (approximately 90 sacks) on top of retainer such that the final top of cement is at 9,500!+-- (100'+- above liner top). 7. Pull out of cement to 9,550' (50' below proposed sidetrack point). Reverse out excess cement. Pull out of hole. 8. Rig up electric line and run casing inspection log from 9,500' to surface. 9. Pick up RTTS and run in hole to 6,100'. Test casing and isolate possible leaking perfs in the 7" casing. 10. If required, squeeze leaks in the 7" casing, drill out and test same. (Squeeze procedure to follow after diagnostic work is done). 11. Begin sidetrack operations. WELL PROFILE 20' O 34' · 239' OTIS 'S' NIPPLE 11 3/4' O 2073' 2154' 326~ 400~ 4705' 6O79' 6687' 9524' 9827' 9870' CURRENT COMPLETION RAN 2/10186 ARCO-'~-~**~, INC CAS;NG CASING CASING LI~ER ,, wa]. SCU 43A-8 SEE 2 0" ] I. 3 /7" 5" 2g 28 SWANSON RIVER ~ 4 7~ = 3 · I 8 ~ R~ STA~ A L A S KA ~ N. a o N-80 , ~ 8 - 8 g ~ 8nD COMPL~ION D~AIL ~ 2073. 10886, .ele'. ,,, I 2 7/8", 6.5#, N-80 AND 2 3/8", 4.7#, N-80 COMPLETION TUBING CAlVlCZ) MM MANDREL W/DUMMY VALVE CAMCO MM MANDREL W/DUMMY VALVE CAMCO MM MANDREL W/DUMMY VALVE CAMCO MM MANDREL WI DUMMY VALVE CAMCO MM MANDREL WI DUMMY VALVE CAMCO MM MANDREL W/DUMMY VALVE CAMCO MM MANDREL W! DUMMY VALVE CAMCO MM MANDREL WI CEV 2 7~8' X 2 3/8' X-OVER SIDETRACK WlNC)OW FROM SCU 4~8 10418' OTIS 2 3/r "XA" SLIDING SLEEVE 10453' BAKER 5' "FH" PAKER 10468' OTIS 2 3/8" "X" NIPPLE 10501' BAKER BLAST JOINT 10621' BAKER BLAST JOINT 10541' BAKER SHEAR SUB PERFORATED ZONES: 10514-10523; 10531'-10556'; 10567-10576':10584'-10599': 10599'-10601'; 10613'-10632'; 10646'-10678';10688'-10702'; 10708'-10714'; 10717'-10728' 0745' PBTD 107g0' 'ID J WELL PROFILE L20" @ 34' PROPOSED PLUGGING COMPANY ARCO ALASKA, INC CASING CASING CASING LINER wa J_ SCU 43A-8 SF_E 2 0" I 1.31 ~ 7" 5" 29 26 ReD SWANSON RIVER WBGHT 4 7# 2 3 # I 8 # STATE ALAS KA GRN~ N- 8 0 N- 8 0 DATE ? - 8 9 THREAD 8 R O 9618', COMPLETION DETAIL DEPTH 2073' 10886 1079(3 :/ 11 3/4" @ 2073' PROPOSED SIDETRACK @ 9500 TOP OF CEMENT @ 9,550' 9618' TOP OF 5" LINER 9827' 7" SIDETRACKWINDOW FROM SCU43-8 9870' 10,389' TOP OF CEMENT 10,464' CEMENT RETAINER 10,514' TOP OF PERFORATED ZONE 10745' PBTD 10790' TD SCU 43A-8 SIDETRACK SUMMARY: The following procedure outlines the planned work to sidetrack SCU 43A-8 as SCU 43A-8 re-complete the well in the Hemlock formation as a single gravel pack. The procedure includes the cutting of approximately a 50 to 70 foot casing section in the existing 7" casing at 9,500'+ and then sidetracking from the original wellbore using conven-tional methods. The well will then be sidetracked to a total measured depth of approximately 10,800'. The new wellbore is planned for a minimum step out to the east and, except for sidetracking out of and away from the original well, will be essentially a straight hole with as Iow of angle as possible. Following the sidetrack and open hole logs a 5" liner will be run and cemented in place. The well will be re-completed as a single gravel pack in the Hemlock formation. Actual completion procedures will be determined after cased hole evaluation logs are run. SCU 43A-8 SIDETRACK PROCEDURE FOLLOWING PLUGGING OF THE $¢U 43A-~ COMPLETION: 1. Cut a 50' to 70' casing section from approximately 9,475 to 9,545'. 2. Set kick-off cement plug through casing section. Dress of cement to 5-10' from the top of the casing section. 3. Pick up 6" bit with 4-3/4" kick-off bottom hole assembly and run in hole. Orient the assembly to the e~-st, using multi-shot gyro. Sidetrack well to the east. 4. Test the formation to a 12.5 ppg EMW. Drill a 6" hole to 10,800'.+_ with a minimum step out from the existing well bore maintaining as close to vertical as practical. 5. Condition hole and run open hole logs. 6. Condition hole and run 5" liner from approximately 9,200' to 10,800'. 7. Cement liner with approximately 175 sacks of blended cement. 8. Clean cement out of casing and top of liner. Test casing to a minimum of 0.2 psi/ft. 9. Run cased hole logs and gyro survey 10. Perforate and gravel pack well as a single gravel pack in the Hemlock formation. (Final procedure to be determined after logs are obtained). 11. Run 3-1/2" x 2-3/8" completion string. Set 3-1/8" 5M tree. Circulate well to lease crude. Release rig and turn well over to production. SCU 43A-8 SIDETRACK Casing program: Casing Size Deoth (MD/TVD~ Wt,(#/ft) Grade Conn. Remarks Structural 20" 34'/34' ...... SCU 43A-8 Surface 11-3/4" 2073'/2073' 47 J-35 8rd $CU 43A-8 Intermed. 7" 9,500'/9,498'* 23,26&29 N-80 8rd SCU 43A-8 Liner 5" 10,800'/10,789' 1 8 N-80 FL4S NEW * at the proposed sidetrack depth. Cementing: The 5" liner will be cemented with approximately 175 sacks of class 'G' blend cement. Cement weight will be approximately 15.8 ppg and have a yield of 1.15 cu. ft./sk. Exact cement volumes and slurry to be determined after drilling operations are complete and prior to running the liner. Wellhead and Pressure Control Equipment: A 13-5/8" 5,000 psi BOP stack (see attached diagram) in the RSRRA arrangement will be installed on the existing SCU 43A-8 tubing spool. The current wellhead equipment consists of a 11-3/4" x 13-5/8" 3,000 psi starting head and a 13-5/8" 3,000 psi x 7-1/16" 5,000 psi tubing spool. All pressure control equipment will be rated to 5,000 psi. The maximum anticipated surface pressure (ASP) during drilling operations is approximately 3,700 psi based on a 16.0 ppg fracture gradient at the 9,500' proposed sidetrack depth. For completion operations the maximum ASP is 3,970 psi based on a 4,950 psi bottom hole pressure in the Hemlock formation from an offset well converted to 10,620' TVD. BOP equipment will be tested to 4,500 psi based on 70% of the burst rating of the 7" 23#/ft casing. The annular preventer will be tested to 3,500 psi (70% of the rated working pressure). The accumulator system is a Koomey model 6-BK 6A with a closing units located at the accumulator and on the rig floor. Geological Information: The well is to be sidetracked out of the existing 7" casing at approximately 9,500' and will be drilled with a minimum displacement in a generally easterly direction The new wellbore for all practical purposes will be considered a straight hole. Because of the close proximity to the current wellbore the formations encountered are expected to be the same as seen in the original completion. Key formations tops are' FORMATION DEPTH (MD=TVD~ CONTENT 'G' Sand 1 0,21 0' salt water Hemlock 1 0,350' oil/gas SCU 43A-8 Drilling Fluids Program Density PV Viscosity Initial gels 10 minute gels Filtrate APl % Solids From sidetrack to Total Deoth .. 9.5 -11.0 15-18 10-15 40-55 5-10 10-15 4-8 9-10 10-20 point Drillino Fluid System _ -Dual tandem shale shakers -Mud cleaner -Centrifuge -Degasser -Pit level indicators (visual and audio alarm) -Trip tank -Fluid flow sensor -Fluid agitators Drilling practices will be in accordance regulations stated in 20AAC25.033. with the appropriate 4 ' 13-5/8" 5000 PSI BOP STACK DIAGRAM ACCUMULATOR CAPACITY TEST I ' I , PREYENTER PIPE RAMS BLI ND RAMS DRILLING SPOOL PIPE RAMS TBS SPOOL I I-:&/4" STARTING HEAD 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3(X)0 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER MMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT ALL HCXJ~DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND 8EAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD, 3. OPEN CASING VALVE(S) ON TUBING HEAD. (MONITOR CASING VALVE FOR FLOW THROUGH OUT BOP STACK TEST). 4. CLOSE ANNULAR PREVENTER AND TEST TO 250 AND 4,500 PSI FOR 10 MINUTES. BLEED TO ZERO. 5. OPEN ANNULAR AND CLOSE TOP PIPE RAMS. TEST TOP PIPE RAMS, CHOKE MANIFOLD VALVES, AND STACK VALVES TO 250 AND 4,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST TO 250 AND 4,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 250 AND 4,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN PIPE RAMS. 8. CLOSE CASING VALVE(S) AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF A NON-FREEZING LIQUID AND ALL VALVES ARE SET IN THE DRILLING POSITION. 9. TEST STANDPIPE VALVES TO 250 AND 4,500 PSI. 10. TEST KELLY COCKS AND INSIDE BOP TO 250 AND 4,500 PSI. 11. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 12. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. FUNCTION TEST BUND RAMS EACH TIME OUT OF THE HOLE. ALL BOP EQUIPMENT 5000 PSI RATED * TEST PRESSURES BASED ON 70% M.I.Y. OF 7" ,23~/FT, N-80 PRODUCTION CASING. -::- ;:2qe -~ka 995':. 0-0360 · ,.;ne ' ~;~ t'~ ~'>-..a-/'/~ ~_t~.~t ~-,'%,,, COMIC4 '-' R,, I, g I N A L AK Dept of Oovemmon~ C~r~afion Office of Management and Budget 26~ Den~i, Suite 7~ Dc~ ~s. Diohws~: A ARCO Alaska, Inc. pi~s to poffo~ a ~ll of two wcHs- SCU 4i~-9 and SCU 4~ ~ Sweden River Fidd in o~dcr to improve off pr~ucfion. ~llin~ iS planned to ~in on or aborn A,~st ~, ~989. All thc wor~ ~ll bc done from ~hc cxisdn~ well p~ds. ~c PI~ of O~radons for ~c at~chcd ~s wcH as ~c "Co~s~ ~oj~t qucsdo~c." Wc have applied for pc~its ~ follows: ~L~: Pc~t to W~tcr ~a~cmcnt: Tompo~ W~tcr Usc. Copies of these appUc~dons at~Chcd for your info~afion. Our coma~ for thc ~L~ pc~t 'and for ~e W~tcr Usc pc~t is Bill Wright .... If you have any questions, please do not hesitate to call me at 263-4675. -- Sincerely, Marcia P. Matthieu Cook Inlet. Permits Coordinator MPM:es MPM/O7/{X)9 Enclosures: Plan of Operations CZM Questionnaire CC: J. Dygas, BLM, Anchorage* L. Leatherberry, ADEC, Soldotna L~.'.~mith-',aAOGCCcAni:horage~ B. Richey, USFWS, Soldotna* J. Gabler, KPB, Soldotna* H. Friedman, ADEC, Anchorage B. Wright, DNR, Anchorage *with attachments ARCO Alaska, inc. ,s a Subsidiary ol AllanticRichlietdCompany .'-R 18-60G3 C July 18, 1989 Mr. Henry Friedman AK Dept. of Environmental Conservation 3601 "C" Street, Suite 1350 Anchorage, Alaska 99503 Dear Mr. Freidman: ARCO Alaska, Inc. plans to perform a redrill of two wells, SCU 4 lB-9 and SCU 43B-8, at Swanson River Field in order to improve oil production. The drilling will begin on or about August 1, 1989. All the work will be done from the existing well pads. The Plan of Operations for these redrills is attached for your information. The drilling waste to be generated will consist of used mud and formation cuttings which will be cOnfined to a metal "cuttings box" for transport to the Swanson River Field Central Disposal Facility, which is a lined, permitted facility for the disposal of this type of drilling waste. All pumpable liquids generated during the drilling and testing of the well will be injected into disposal well SCU 43-4. It is estimated that approximately 3000 barrels of drilling waste fluid will be injected in this manner. .. Our evaluation of the planned activities indicates that this is not storage and 'therefore, permits are not required. We request, however, that ADEC review and provide written concurrence with the plan outlined above. If you have any questions, pleaSe do not hesitate to call me at 263-4675. Sincerely, Marcia P, Matthieu Cook Inlet 'Permits Coordinator MPM:es MPM/07/010 Enclosures: Plan of Operations CZM Questionnaire cc w/o enclosures: P. Bielawski, DGC, Anchorage J. Dygas, BLM, Anchorage J. Gabler, KPB, Soldotna L. Leatherberry, ADEC, Soldotna B. Richey, USFWS, Soldotna L. Smith, AOGCC, Anchorage B. Wright, DNR, Anchorage '.~'CO ,'Haska. !nc. is a :~ubsi=iar~ Of AtlanticRiclalieldC:mpany ;F ';~ ..h.,;! ,. July 18, 1989 Mr. Bill Wright Department of Natural Resources Land and Water Management P.O. Box 107001 Anchorage, AK 99510-7001 Dear Mr. Wright: ARCO Alaska Inc. (AAI) is planning redrill operations on two oil wells in the Swanson River Field commencing about the 10th of August, 1989. The wells involved are SCU 41B-9 and SCU 43B-8. As part of this activity, we plan to utilize groundwater from nearby water wells which were drilled prior to 1970. The drilling and testing activities on each well will last less than one month and we anticipate the dsily water use to be apprcximately 10,000 gallons per day for each well., in anticipation of these and future workover operations, AAI is by this application requesting a temporary water use permit for each of these wells from Land and Water Management. To minimize the administrative burden on AAI and the Division of Land and Water Management, it is preferred that AAI be issued a permit that would allow temporary use of any installed water well within the field for a period of at least one year. We feel that one permit would address the multiple anticipated activities in the field. Periodic reports would be provided to ensure that the State and US Fish and Wildlife Service records are complete. We would, however, continue to obtain USF&WS and BLM authorizations for field operations as needed. I have attached for your information the Plan of Operations that applies to the two subject wells and the required checks for $50.00. If you have any questions or need additional information about these drilling operations, please call me at 263-4675. I hope to hear from you at your earliest convenience due to the short time frame before the work is planned to begin. Sincerely, Marcia P. I~latthieu Cook Inlet Permits Coordinator MPM:es MPM/07/011 MPM:es M PM/07/011 Enclosures: Plan of Operations CZM Questionnaire cc w/o enclosures: P. Bielawski, DGC, Anchorage J. Dygas, BLM, Anchorage H. Friedman, ADEC, Anchorage J. Gabler, KPB, Soldotna L. Leatherberry, ADEC, Soldotna B. Richey, USFW.S, Soldotna L. Smith, AOGCC, 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. Chevron U.S.A. Inc. 74-0013 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of Well 2150' N & 515' W of SE Corner Section 8, T7N, R9W, SB&M 5. Elevation in feet (indicate KB, DF, etc.) G.L. -- 152' K.B. = 172' 12. 8. APl Number 5o- 133-10121-01 9. Unit or Lease Name 6. Lease Designation and Serial No. A-028996 Soldotna Creek Unit 10. Well Number scu 433r8 11. Field and Pool Swanson River - Hemlock 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). See Attached RECEIVED MAR 2 0 1986 Alaska 0il & Gas Cons, Commission Anchorage 14. I her i t h oregoing is true and co[rect to the best of my knowledge. Area Operations Signed '~-,~L {~~/~i/~-~----~ Title. Superintendent The spacefb4ov~ for Commission use Conditior~f APproval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA~-,L AND GAS CONSERVATION Cfi, ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .1. Status of Well ,. Classification of Service Well ~, · OIL ~[ GAS [] SUSPENDE~ [] ABANDONED [] SERVICE [] 2. Name.of Operator 7. Permit Number Chevron U.S.A. Inc. 74-0013 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 5°-133-10121-01 , 4. Location of well at surface 2150' N & 515' ~ of SE ~..r"o"ner Section 8, 9. unit or Lease Name TTN, R9~, S.B.&M. Soldotna Creek Unit At Top Producing Interval 10. Well Number 2233' N & 552' IV of SE Corner Section 8, SC.U 43A-8 At Total Depth TTN, R9W, S.B.&M. 11. Field and Pool 2190' N & 528' ~ of SE C(~rner Section 8, 5. Elevation in feet (indicate KB,.Jt~)./l~fq~c~.,~ ~.,_-__ __ S.j~§%~t~e~____ Designation and Serial No. Swanson River- Hemlock .... G.L. = 152' K.B. = 172'' | A-028996 12. Date Spudded 13. Oate T.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore 116. No. of Completions ,3-16-'74 ~:8-74 2-10-86J NA feet MSLI 1 ,~17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+-rVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost .... 10~790'; 10,779' 10,745'; 10,735' YES [] NA NO [][ NA feet MD NA 22. Type Electric or Other Logs Run GR/Neutron/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · . , 20" 23' 34' "i 1-3/4" 47#. 22' 2,073' 16" 1.300 SKS 7" _ '23,26,29# N-80 20' · 10,886" 9,7/8' .2.200 SKS 5" 18# N-RD 0_618' 10.790' 6" 117 · - 24. Perfo[ations open t° Production (MD+TVD of Top and Bottom and 25. TUBING REGORD · interval, size and number), · SIZE DEPTH SET (MD) PACKER SET (MD) '2..3/8",2-7/8'' 10,540' 10,452' See Attached Sheet . . .... 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,: :.. -.., · .- , . ~. ': :.:. , . .., . . DEPT.H INTE. RVAL(MD) AMOUNT. & KIND OF MATERIAL USED ' ..6,020' - 5,770'. 85 SKS C1 "O" Cement _ ' , : · ,.:: . ,~ : · . . - ., :. ~ · .... '"" "': PR'~UCTIONUU i-;'ST 27. Date.Firs~ Pro:ducfion . , ,. · :....[ Met.hod of Operation (Flowing,gas lift, etc.) . . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF W~TER-BBL CHOKE SIZE [GAS-OILRATIQ :.: ~,2"1-86': : 15 - TESTPERIOD I~ .. 126.1 . NA 0 12/64[ NA · Flow. Tubing;.. Casing Pressure CALCULATED ~ OIL'BBI' · . GAg, MCF WATER-BBL OILGRAVITY-API (corr) 'Press. 426, .~ . 0·' 2~T-HoUR RATE"~I 195--- ' - NA NA 28. CoR'E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.' NA '' ~ ~ ~ I ' I ' ' RECEIVED . · ,. MAR 1 9 1986; .: . , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. · GEOLOGIC MARKERS FORMATION TESTS NA NA .... NAME ... Include interval tested, pressure data, all fluids recovered and gravitY, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , , , ., ,31. LIST OF ATTACHMENTS NA 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title S~m~.rint~.n dc.n r Date 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". WORKOVER COMPLETION REPORT SWANSON RIVER FIELD, ALASKA Soldotna Creek Unit Well: SCU 43A-8 Lease No.: A-028996 Surface Location: 2150' N. & 515' W. of SE Corner S8, T7N, R9W, SB&M Drilling Rig: Brinkerhoff Signal Inc. #16 Rig Acceptance: January 1, 1986 Rig Released: February 10, 1986 Elevation: G.L. - 152' K.B. = 172' Total Depth -- 1.0,790' Plug Back Total Depth = 10,745' Casing: 20" Cemented at 30' 11-3/4" Cemented at 2073' 7" Cemented at 10,886' with window from 9827'- 9870' Liner: 5" Cemented 9618' - 10,790' Perforations: (Existing 4-1/2" JSPF) 10,728' 10,714' 10,702' 10,678' 10,632' 10,601' - 10,717' - 10,708' - 10,688' - 10,646' - 10,613' - 10,599'. (Reperforated 6-1/2" JSPF) 10,599' 10,576' 10,556' 10,523' - 10,584' - 10,567' - 10,531' - 10,514' Logs Run: Dresser Atlas GR/NEUTRON/CCL stopped at 10,530' and the interval was not logged. M~ K.- Ha~u%'~ Senior Area Engineer RECEIVED Alaska Anchorage 12-31-85 1-1-86 1-2-86 1-3-86 1-4-86 1-5-86 1-6-86 First Report: Located 2150'N and 515'W of SW Corner Section 8, T7N, R9W, S.B.&M., GL. = 152', K.B. = 172', MI & RU BSI Rig # 16 from SCU 21 B-16. Accept rig at 6:00 A.M.l-l-86. TD=10,790' PBTD=10,745' 5" Liner 10,790'- 9618', Lease Water, SITP=270 PSI, SICP=400 PSI, Bled off tbg and csg pressure, ND tree and NU 10" - 5000 PSI BOPE, test to 5000 PSI, test annular and blind rams to 3500 PSI, RU C.A. White and run equalizing bar to 534' - hung up, run tbg stop rtrvng tool to 534' - no recovery, run 2 1/4" and 1 3/4" impression blocks - inconclusive, run equalizing bar to 534' - hung up. Run I 3/4" and 2 1/4" impression blocks to 532'. TD=10,790' PBTD=10,745' 5" Liner 10,790'- 9618', Lease Water, Run 1 3/4 and 2 1/4" impression blocks - inconclusive, operator check truck and lower half of tbg stop running tool missing - believe left in hole, W.O. fishing tools, Run 1.875" and 2.35" overshots - no recovery, IB's had indicated some gravel, W.O. bailing tools, Run 6 mech 1 3/4" bailer runs - rcvd sand, gravel, and metal ,nill shavings, Run 3 Hyd bailer runs -rcvd some sand and metal, Run 2.35" OS w/l" - I 3/8" grapples- latch fish but slipped off, Run OS w/7/8" - 1" grapples - latch fish and sheared off pulling tool. TD=10,790' PBTD=10,745' 5" Liner 10,790'- 9618', 9.5PPGBW, RU Otis sliekline, RIH & latch fish at 534', POH - Rcvd Modle "H" tool and both latch keys connected to top tbg stop, RIH w/equalizing bar to Baker plug at 490' and pushed to 500', RIH w/Baker retrieving spear and engaged plug at 500' worked back to 429' sheared off, Reran pulling tool -worked and dragged plug to 22', Tools blew up hole and stuck in 2 7/8" safety valve and Otis lubricator, Tried to pump stuck tools down w/BOP test pump and lubricator - no good, Pumped down tbg w/9.5 ppg brine and killed well to recover tools, Break down and retest lubricator to 3500 PSI, Reran tools and latched onto Baker plug at 538', Recovered tbg plug, RIH w/tbg stop retrieving tool - recovered tbg stop, RIH w/"S" plug retrieving tool, Pulled prong from plug at 10,509', Made two attempts at plug. TD=10,790' PBTD 10,745' 5" Liner 10,790'- 9618', 9.5PPGBW R/D Otis slickline, Circ. 9.4+ ppg in/out, Attempt to rls pkrs w/62,000~ pull and righthand torqe, Circ. and pull 47,000~ and WO tbg cutter, R/U Alaska pipe recovery wireline, RIH w/jet cutter, Cut of 2 7/8" tbg at 8988', Circ. I 1/2 hole vol. 9.5 ppg, POH and laydown 84 jts and well flowing up tbg and anulus, Stab in safety valve and closed hydril, - tbg and esg = 100 PSI, Circ out Driller's method - well dead, TIH picking up tbg. TD=10,790' PBTD-10,745' 5" Liner 10,790' - 9618', 9.8PPGBW Fin TIH to 8981' monitor well, Circ 2 Bu 9.8 ppg in/out, POH and lay down 103 jts 2 7/8" tbg, Circ 2 Bu 9.8 ppg in/out at 5708', POH w/44 stds laydn GLM ~6 w/l"xl/4" split, TIH to 5992', Circ 2 Bu 9.8 ppg, POH and lay down 2 7/8" tbg. TD=10,790' PBTD=10,745' 5" Liner 10,790'- 9618', 9.8PPGBW Fin POH and laydown 2 7/8" tbg, Install 3 1/2" rams and test to 5000 PSI. PU and TIH w/5 3/4" OS guide, mill extension, OS extension, bumper sub, Alaska 0it & Gas Anchorage 1-7-86 1-8-86 1-9-86 1-10-86 1-11-86 1-12-86 1-13-86 TD=10,790' PBTD=10,745' 5" Liner 10,790'- 9618', 9.8 PPG BW, Mill over 2 7/8" tbg.at 8989', Attempt to release 5" packer w/70,000# - w/no success, Release packer w/rotation, Work fish up to 8981' - fish stuck, RU Otis WL & run rtvng tool-plug ~ 10,500'- tool stopped ~ 10,490', .. Ran I 3/4" bailer -Rcvd a couple of metal shavings,-RD Otis, Work and jars on fish w/70-80,000# -no sucess. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9,618', 9.8 PPG BW, Cont. working & jarring fish, RU Otis WL, RIH w/1.815" Imp Blk to 10,490' - Ind junk 3/4" x 1/2", RIH w/2.16" guage ring w/collar locater - Ind junk 5'-7' above "XA" sleeve, RIH w/junk basket & hyd bailer -rcvd a piece of iron junk, RIH w/1.734 IB to 10,490' - Ind top of "S" plug, RIH w/retrieving tool. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.8 PPG BW, RIH twice w/rtvng tool to 10,490' - no rcvy & no indication of being on plug, RIH w/shear down retrieving tool - no revy or indication of plug, Run JB & hyd bailer -recvd some scale & btm of JB flared out, Run retrieving tool w/no rcvy, Reverse tire tbg & D.P. vol-small amount of scale over shaker, Ran 1.815" blk - shows top of "S" plug, RIH w/1 3/8" grapple to 10,490' - couldn't work fish free w/470~, POH grapple broken & missing, RD Otis WL & RU Otis Coil Tbg. TD=10,790' PBTD=10,745' 5" Liner 10,790'- 9618', 9.8 PPG BW, Fin RU Otis, RU Howco, RIH w/1 1/4" coil tbg 1 3/4" Navi-drill & 1-3/4" washover shoe to 10,490', washover "S" plug, Circ clean w/Hi-Vis sweeps, POH w/coil tbg, RU Otis WL Unit, RIH w/overshot and 1-3/8" grapple, Pull 200-300# & kept slipping off, POH & modify by shortening stop, RIH w/overshot, Pulled 250# con't to slip off, RD Otis WL & Otis coil tbg, RU APRS WL, RIH w/1-13/16" jet cutter to cut 2-3/8" tbg. TD=10,790' PBTD=10,745' 5" Liner 10,790' - 9618', 9.8 PPG BW, Fin RIH w/jet cutter to TOF ~ 10,490', Cut 2 3/8" tbg ~ 10,489', POH & RD APRS, POH-laydn 17-1/2 its 2 7/8" tbg & 31 its & 24.93' of 2 3/8" tbg, Test BOPE, LaY dn fishing tools, PU & TIH w/4" WO mill & Extension junk bskt 12-3 1/8" DCS 20 its 2 7/8" DP bumper sub jars & pump out sub to fill ~ 10,363'. TD=10,790' PBTD=10,745' 5" Liner 10,790'- 9618', 9.8 PPG BW, Wash to TOF 10,363'- 10,483' (SLM), mill over fish to collar ~ 10,486.5', mill 6" of collar & "XA" sleeve, POH & laydn fish tools, PU & TIH w/4 1/8" guide OS w/2 3/8" grapples extension 12-3 1/8" DC's 20 - 2 7/8" DP Bumper sub jars 8-4 3/4" DC's accelerator sub pump out sub, Drop BHA while backing out lifting sub, TIH & screw into TOF ~ 9239', POH - Rcvd 4.3' 2 3/8" tbg w/"S" plug - left piece of OS guide in hole. TD=10,790' PBTD=10,745' 5" Liner 10,790' - 9618', 9.8 PPG BW, Lay dn fishing tools, PU & TIH w/4 1/8 x 3 1/4" wash shoe, extension, BHA, millover fish 10,488' - 10,491', POH, PU & TIH w/4 1/8" guide extension OS w/3 1/16" grapples & BHA, Circ btms up, Workover fish, work & Circ fish w/75,000#, RU APRS & Run FPI-stop ~ 10,490',~.~! 'RD- Work fish & WO coil tbg unit. R ~ ...... 1-14-86 1-15-86 1-16-86 1-17-86 1-18-86 1-19-86 1-20-86 TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.7 PPG BW, WO coil tbg & work pipe, RU Arctic Coil Tbg-test to 4,000 psi, RU Dowell, RIH w/OE 1 1/4 tbg, Attempted to clean hole ~ 10,490' 1 BMP 3700 psi -no success, POH w/coil tbg, RD coil tbg, Rlsd OS, Circ, POH - 3 1/16" grapple missing, PU & TIH w/4 1/8" guide OS w/3 1/16" grapples 31 its 2 3/8" tbg RVS sub Jars 8-4 3/4" DCS Accelerator sub Pump out sub. TD=10,790' PBTD-10,745' 5" Liner 10,790'-9618', 9.7 PPG BW, TIH w/fishing tools to TOF ~ 10,488', Latch onto fish, RU Arctic Coil Tbg, PUi 3/4" mill & Navi-drill, Test lines to 4,000 psi, RIH w/coil tbg, Attempt to mill through inside of fish no success,POH, RD coil tbg, RU Otis WL, Ran 1.815" IB to 10,489' showed OD decreased to 1.625", RIH w/1 1/2" sincker bar to 10,490', PU 10 & work to 10,509', RIH w/1.840" GR to 10,490', Attempt to work through -no success, WO APRS, RU APRS, RIH w/1 7/16" OD CCL. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618' 9.7 PPG BW, Run CCL to 10,560'-Ind tbg parted ~ cc jt, Attempt to run FPI - shorted out, RIH w/FPI-Ind pkr stuck ~ 10, 492' RD APRS, Rlsd OS, Circ, POH-laydn fshg tools, PU & TIH w/5" RBP 2 its 2 2/8" tbg 7" "EA" pkr on 3 1/2" DP, set RBP ~ 9692' testing 7" Csg w/7" pkr to 2000 psi. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.7 PPG BW, Locate leaks in 7" Csg F/6020'-5770', Test Csg below 6135' to 3300 PSI,POH w/7" pkr & 5" RBP running tool, PU & TIH w/23 its 2 7/8" tbg 7" "EA" pkr on 3 1/2" DP, Dump 2 sks sd on RBP, RU Dowell & test lines to 5,000 psi, set pkr ~ 3281' & estb inj rate 2 BPM (~ 3,000 psi, Rlsd pkr, Batch mix 85 sks C1 "G" + 1% D-60 ~ 15.8 ppg, Pump 5 BFW Cmnt & Disp w/39 Bbls BW, POH to 5500' & Rvs tire 1 1/2 DP vol, Set "EA" pkr ~ 4765', Pressure test annulus to 1500 psi Sqzgt w/1/4 BPM 3,000 psi 5 Bbls cmnt total- CIP ~ 12:01 AM 1-19-86, WOC. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618' 9.7 PPG BW, Rlsd pkr, POH-Laydn pkr, PU & TIH w/6 1/8" bit & 8-1/4 3/4" DC's, Drill hard cmnt 5754'-6020', wash to 6050', TIH to 6080', Circ hole clean, test 7" esg to 2,000 psi - OK, TIH to 9618', POH. TD=10,790' PBTD-10,745' 5" Liner 10,790'-9618', 9.6 PPG BW, Fin POH, PU & TIH w/RBP Retrieving tool - slip & cut DL, Latch onto RBP ~ 9682', Circ hole clean, POH-Laydn RBP, Test BOPE to 5000 psi- Test annular to 3,500 psi, PU & TIH w/4 3/16" x 3 3/4" shoe 4" wash pipe JB 12-3.1/16" DC's 20-2 7/8 DP Bumper sub jars to 9830', Attempt to work through tight spot, POH. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618' 9.6 PPG BW, Fin POH, PU & TIH w/4 1/8" x 3 1/8" shoe - slip & cut DL, Washover TOF ~ 10'489' & Attempt to washover, pkr ~ 10,492' - pkr appears to be spinning, POH, PU & TIH w/4 1/8" x 3 15/16" shoe. 1-21-86 1-22-86 1-23-86 1-24-86 1-25-86 1-26-86 1-27-86 TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.7 PPG BW, Fin TIH, workover TOF ~ 10,489', Millover pkr 10,492'-10,493.5', POH, PU & TIH w/4 1/8" OS w/3 1/16"' spiral grapples w/packoff 12-3 1/8" DC's 20 - 2 7/.8" DP Bumper Sub Jars 8-4 3/4" DC's Accelerator Sub Pump out Sub- slip & cut DL, Work onto fish ~ 10,489', Push fish to 10,501' & engage fish, work fish to 10,460' w/220,000~, Cite BU, POH to TOL ~ 9618', Cite BU, POH. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.7 PPG BW, Fin POH, Rcvd "XA" sleeve pkr "S" nipple blast Jt "XA" sleeve pkr "S" nipple 2- blast Jts top half "cc" jt, PU & TIH w/4 1/8" guide & "cc" retrieving tool to 10,530'-Tight f/10,520'-10,530', Pull 240,000# & jar guide free, Cite, POH, PU & TIH w/4 1/8" FB mill to TOF ~ 10,553', Cite, POH. TD=10,790' PBTD=10,745' 5" Liner 10,790'- 9618', 9.7 PPG BW, TIH w/4 1/8" FB Mill & Work through tight csg 10,523'-10,526', Work to TOF ~ 10,556', Circ, POH, Repair DWKS brakes, PU & TIH w/4 1/8" guide & "cc" retrieving tool- Slip & cut DL, Work through 10,523'-10,526', Screw onto fish, Rlsd two pkrs & "cc" jt ~ 10,603', Circ, POH to 9618', Circ, POH. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.7 PPG BW, Fin POH -Rcvd btm "cc" jt "XA" sleeve pkr "S" nipple blast jt "XA" sleeve pkr "S" nipple blast jt & top half "cc" jr, TIH w/4 1/8" guide & "cc" retrieving tool - slip & cut DL & level derrick, Workover & screw onto fish ~ 10,603', Rlsd pkr, Work pkr through tight spots ~ 10,560' 10,523' & 10,488', Circ BU- some gas, work fish out of liner, Circ BU, POH. TD=10,790' PBTD-10,745' 5" Liner 10,790'-9618', 9.7 PPG BW, Fin POH -Rcvd btm "cc" jt "XA" sleeve pkr "S" nipple 2-blast its & top half of "cc" jr, PU & TIH w/4 1/8" FB Mill & 4 1/8" string mill, Attempt to work through tight spot 10,523'-10,530' & milling very slowly, POH- Rcvd tapered piece of Csg 2'xl/4"xl" inside throat (1" ID) of mill, PU & TIH w/3 1/8" DC & 4 1/8" string mill-slip DL, Work mill f/10,530'- 10,607' to TOF ~ 10,637', Circ. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.7 PPG BW, Fin Circ BU, POH, PU & TIH w/4 1/8" wash shoe to 10,529'- Attempt to work through, POH, Test BOPE to 5000 psi, Test Annular to 3500 psi, PU & TIH w/3 1/4" lip guide "cc" retrieving tool 3 1/8" DC 4 1/8" string mill - Slip DL. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.8 PPG BW, Fin TIH TOF ~ 10,637' w/no problem (! 10,523'-10,530', Screwed onto fish w/retrieving tool, Rlsd pkr & pull pkr to 10,520' w/240,000#, Circ BU - some gas & place on choke, Pull fish out of liner w/drag most of way, Circ, POH-Rcvd btm "cc" jt "XA" sleeve pkr "S" nipple 2-blast its top half "cc" jt, PU & TIH w/same fishing tools to TOF ~ 10,681', Circ hole vol w/gas cut BU, Screw~.~nto fish, Work pkr free & work up hole to 10,523', Attempt to tire, Drop shear bar & could not open pump out sub, POH to 9618', Drop shear bar &' attempt to open pump out sub w/4500 psi, pOH wet. ~;i ~ ~ ;~i': ~ ~ ''~ 1-28-86 1-29-86 1-30-86 1-31-86 2-1-86 2-2-86 TD=10,790' PBTD=10,745' 5" Liner 10790'-9618', 9.8 PPG BW, POH wet, SIW, Monitored press buildups SICP=100 psi to 150 psi & bleedoff 3 times w/cont, oil migration & flow, Tried to open pump out sub w/50' of 2" & 1 3/4" sinker bars w/no success, Lay down a washout jt & Tried to circ w/3500 psi w/no success~ RIH w/BOF ~ 9601' & pumpout sub ~ 8155', WO APRS, R/U wireline lubricator, RIH w/perfgun & CCL to 8095', Shot 3-¼" JSPF decentralized controlled shot ~ 8080', POH w/wireline, Circ gas & oil cut brine through choke for 1 hole vol., Cire through flowline. TD=10,790' PBTD=10,745' 5" Liner 10790'-9618', 9.8 PPG BW, cont. circ, POH w/fish; hot t "cc" safety jr, "XA" sleeve, Baker "FA" packer, Otis "N" nipple w/plug, 2 blast its, & shear sub, PU & TIH w/3 5/8" bullnose mill & BHA to PBTD, Circ. hole vol w/little gas & pumped hi- vis sweep till clean, POH & R/U Dialog, Run Csg Insp log - stop ~ 10,528-1og showed greater than 4¼" ID in 5" Csg ~ 10,520 - 10,528', PU 30' - 1¼ sinker bar & centralizer to rerun tool. TD=10,790' PBTD=10,745' 5" Liner 10790'-9618', 9.8 PPG BW, Made two more attempts w/profile log to 10530', R/U Dresser Atlas, Ran CCL/GR/Neutron - stop ~ 10,530', Run log w/4' "hole finder" -Stop ~ 10,530', Run log w/10' Extension - Stop /~ 10,530', R/D Dresser Atlas; PU & TIH to 10,743' w/bull nose mill, float sub, 2-3 3/8" DC, 4 1/8" string mill, 10-3 3/8" DC, 26 its, 2 7/8" DP, XO, bumper sub, oil jars, 8- 4 3/4 DC, 3i" DP, & worked thru bad spot ~ 10,523' to 10,530' (tight), Circ. TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.8 PPG BW, Fin circ 1 1/2 BU, POH-Cut DL, RU & TIH w/3 3/8" Dresser Atlas TCP guns 2 its 2 3/8" tbg ported sub 2 its 2 3/8" tbg 5" retrievamatic pkr 2 its 2 3/8" tbg RA Collar 26 its 2 3/8" tbg 2 its 3t" DP pumpout sub & test string - pushed through bad spot (~ 10,530' w/2,000/~, RU Dresser Atlas WL & ran CCL/GR - spaceout guns, Rerun CCL/GR w/firing mechanism, Checked spaceout & set mechanism into firing head ~ 10,535', R/D Dresser Atlas, set Baker retrievamatic pkr (~ 10,406', Test annulus to 1,500 psi -OK, R/U Test head & lines, WO BJ Titan, R/U N2 lines & test to 5,000 psi, Pump N2 Cushion. TD=10,790' PBTD=10,745' 5" Liner 10790'-9618', 9.8 PPG BW, Fin pumping N2 cushion - 3900 psi BHP (1,000 psi underbalanCe), Bleed off 50 psi excess N2 to check lines, Drop bar to open ported sub & fire guns, Bleed of N2 on 8/64" choke, Flow test well-Fluid to sfc in 5 hrs 18 min, change choke to 12/64" rate stablized ~ -198 BOPD FTP=426 psi at end of 23 hrs. TD=10,790' PBTD=10,745' 5" Liner 10790'-9618', 9.8 PPG BW, Fin flow test & SWI, Open by pass - Reverse DP, Rlsd pkr - tire dn DP w/l~ BU, POH & Laydn tools & guns - 58' of top guns fired & 66' of btm guns misfired - Left 33.85' guns in hole w/10' of internal carrier from gun above fish on top of fish, Test BOPE to 5000 PSI, Test annular to 3500 · + PSI, PU & TIH w/4" JB head 20' extension to BOF ~ 10,530', Circ. 2-3-86 TD=10,790' PBTD=10,745' 5" Liner 10,790'-9618', 9.8 PPG BW, Fin circ, Closed Hydril & Reverse cite & work junk basket, POH W/no revy, Pu & TIH w/4 1/8" x 3 3/4" washshoe to TOF ~l 10,496' SLM w/no corr- slip & cut DL, Cite B/U, worked washshoe 10,496'-10,500' & stopped solid, POH & shoe appeared to be turning on Csg, PU & TIH w/1 1/8" x 2 3/8" Taper tap. 2-4-86 2-5-86 2-6-85 2-7-86 2-8-86 2-9-86 TD = 10,790' PBTD = 10,745' 5** Liner 10,790' - 9,618', 9.8 PPG BW, Fin TIH w/1 1/8'* x 2 3/8** Taper Tap to 10,499', Screw int° fish, Circ, POH w/some drag in 5** Liner - no rcvy, TIH w/1 1/8'* x 2 3/8** Taper Tap to 10,499' - slip DL, Circ, Screw into fish, POH w/some drag in 5** Liner - no rcvy and marks on Taper Tap indicate getting inside of fish, TIH w/l" x 2 3/4** Taper Tap to 10,498' - slip & cut drlg line, Screw into fish, POH w/40-50,000# overpulL TD = 10,790' PBTD = 10,745' 5" Liner 10,790' - 9,618', 9.8 PPG BW, POH w/l" x 2 3/4" Taper Tap w/some drag in 5** Liner - no rcvy, TIH w/4" x 3 1/16'* washover shoe to 10,498, Attempted to washover Junk & Perf Guns - Fish appeared to be spinning, POH w/shoe -Indicated approx. 2'* of wear on inside, TIH w/l" x 2 3/4** Taper Tap to 10,498', Screw into fish, Drop pump out - Sub Bar, POH. TD = 10,790' PBTD = 10,745' 5** Liner 10,790'- 9,618', 9.8 PPG BW, Fin POH -rcvd entire fish: 33.85' of 3 3/8** Perf Guns, TIH w/3 5/8" Mill 3 1/16'* DC 4 1/8" string mill to 10,743' & worked through 5** Liner ~ 10,530' w/string mill w/no problems, Circ, POH, RU & TIH w/Dresser Atlas 3 3/8** OD TCP guns & related equip'to 10,530' -Slip & cut drlg line- Guns stopped ~ 10,530', Attempted to work guns through tight spot ~10,530' - no success, POH. TD = 10,790' PBTD = 10,745' 5" Liner 10,790' - 9,618', 9.8 PPG POH w/3 3/8*' O.D. guns, TIH w/3 5/8'* mill 3 1/16'* DC 4 1/8" string mill to 10,743' - worked through tight spot ~ 10,529', Cite, Lay dn DP & DC*s, Retrieve wear ring, Changed 3 1/2" pipe rams to 2 7/8** tbg rams & tested to 5000 psi, PU & TIH w/2 3/8" Production tbg. TD = 1'0,790' PBTD = 10,745' 5'* Liner 10,790' - 9,618', 9.8 PPG BW; Fin PU & test in hole to 5000PSI 2 3/8** shear sub, 40* blast jts, "X" nipple, "FH" pkr, "XA" sleeve, 30 jts 2 3/8'* 4.7# 1~-80 8RD EUE tbg, 301 jts 2 7/8** 6.5# 1~-80 8RD EUE tbff, GLM's ~ 9523* 6686' 6078' 5408' 4703' 4001' 3268* 2153'; Installed BPV - Landed tbg ~ 10,540' w/Pkr ~ 10,452', R/D Hydrotest, I~/D BOPE. TD = 10,790' PBTD = 10,745' 5" Liner 10,790'- 9,618', Lease Crude, Fin lq/D BOPE, I~/U 5,000# tree & test to 5,000 psi - Retap lock down screws on tubing head, Retrieved BPV, cleaned mud pits, Disp well w/crude oil, Dropped shear sub ball & set 5** Baker "FH" pkr ~ 10,452', Tested annulus/pkr to 1,000 psi, set BPV, Rlsd Ri~ ~ 12:01 2-10-86 FIliAL .REPORT- DROP 24. Perforations open to Production (MD · TVD of Top and Bottom and interval, size and number). MD TVD INTERVAL NUMBER 10,514 10,531 10,567 10,584 10,613 10,646 10,688 10,708 10,717 - 10, - 10, - 10, - 10, - 10, - 10, - 10, - 10, - 10, 523' 556' 576 601 632 678 702 714 728 10,508' - 10,517 10,524' - 10,549 10,560' - 10,569 10,577' 10,605' 10,638' 10,679' 10,699' 10,708' - 10,593 - 10,624 - 10,669 - 10,693 - 10,705 - 10,718 9 25 9 17 19 32 14 6 11 54 150 54 98 76' 128 56 24 44 SIZE 1/2" 1/2" 1/2" 1/2" 1/2" 1/2" 1/2" 1/2" 1/2" * INTERVALS: 10,514'- 10,523', 10,531'- 10,556', 10,567'- 10,576', 10,584'- 10,599' Reperforated with 6-1/2" JSPF. The remaining intervals were not reperforated. RECEIVED MAR 1 9 1985 c)i! & Gas Cons. Commission ,~ ~ch~rage ,5: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~~I~EIV E D SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] 2. Name of Operator Chevron U.S.A. Inc. COMPLETED WELL JAN 0 2 1986 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of 2150'N & 515'W of SW Corner Section 8, T7N, R9W, S.B.&M. OTHER [] Alaska 0il & Gas Cons. Commission 7. Perm it N~.n~orage 74-0013 8. APl Number 50-133-10121-01 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 43A-8 11. Field and Pool Swanson River - 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Hemlock o.g. = 152' K.B. = 172' [ A-028996 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 10407 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). . . 5. 6. 7. . 9. 10. 11. 12. 13. 14. 15. 16. Move in and rig up workover rig. Kill well as required. Nipple down the tree, and nipple up and test the Class III BOPE to 5000 PSI. Test the annular to 3500 PSI. Pull the tubing and production equipment. Clean out to PBTD of 10,745'. Squeeze off perforations 10,728'-10,514' with 75 sks C1 "G" cement. Test the 7" casing and 5" liner top to 3000 PSI. Locate the 7" casing leak with a retrievable packe~ (leaks expected in WSO holes 6007'-5500'). Squeeze off'casing leaks as required. Clean out 7" casing to liner top and test squeezes and casing to 1500 PSI. Clean out cement inside 5" liner to PBTD and test to 1500 PSI. Run Neutron log to locate high GOR zones. Perforate as directed. Run production equipment and tubing .as directed. Nipple down the BOPE and nipple up the tree and test to 5000 PSI. Displace the annulus and tubing with lease Crude. Hydraulically set the packer at 10,500'+. Rig down and move off the workover rig. ~ihgen::ace be,~~~----~'--- /--~1'(~)~'~x /~' Title Area Operations Superintendent Conditions of APproval, if any: ilRltt~llt SIG~E~ Approved bY COMM ISS ION ER Approved Copy RetUrned -.~ By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate COMPLETION REPORT - REDRILL STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS. INC., OPERATIONS AREA: Swanson River Field Kenai Peminsula- ~Cook Inlet Area, Alaska LAND OFFICE: Anchorage PROPERTY: Soldotma Creek Unit LEASE NO: A-028996 WELL NO: SCU 4SA-8 API NO: 50-133-10121 LOCATION AT SURFACE: 2,t50' North and 515' West of Southwest Corner of Section 8, T7N, R9W. Seward B & M. · . . LOCATION AT DEPT~: 2,211' North and 570% West of Southwest Corner of Section 8, TTN, R9W, Seward B & M. ELEVATION: 172' KoBo ~ DATE: JBY: K.B. is 20' above ground level. R. M. McKinley Area Engineer DRILLED BY: Kenai Drilling of AlaskA, Inc. DATE COMMENCED DRILLING: 2:00 PM, M~rch 16, 1974 · . . · DATE COMPLETED' 10:30 PM, May 77, 1974 DATE OF INITIAL PRODUCTION: SUMMARY ORIGINAL ~/~Z DEPTH: 10,886' REDRILL DEPTH: iO, 790 ' EFFECTIVE DEPTH: 10,735' R/D CASING: 20" conductor cemented at 30'. 11 3/4" cemented at 2,073' with 1,300 sacks cement.. · " cemented at top of window 8,927'-9,870' ~ PLUGS: ~R/D Plug 10,790'-10,735' " LINER: · JUNK S.T': 7" casing from 9,870' to 10,886' orig. hole 1,171' of 5" cemented at 10,790' with 140 cu.ft, of "G" cement. Top at 9,618'. Float Collar at 10,745'. · DIVISION OF OIL AND. GAs Perforations Four 1/2" jet holes per foot: 10,728'-10,-717' 10,714'-10,708 10,702'-10,688' 10,-678'-10,643'- 10,632'-10,613' 10,601'-10,584' 10,576'-10,567 10,556'-10,531' 10,523'-10,514' Formation'Test . HFT # 1 10,717'-10,728' (May 11, 1974) Logs: Schlumberger Dual Induction Borehole Sonic Compensated Neutron Micro Compensated Neutron-Micro Saraband Dresser Atlas Neutron Go-International Cement Bond Log Neutron 9,828'-10,752' 9,826'-10,755' 4,500'-10,757' 9,828'-10,757' 4,500'-10,757 ~,830'-10,728' 10,450'-10,740' 9,600'-10,740' 9,600'-10,725' 11__511 2 "15" ~ 51l 5" 5" 5" 1! 1! 5" March*16,'1974 · , · Con~nenced operations at 2:00 PM. Killed well with 84 pcf mud. i'March'l?i'1974 _ _ Circula~eq:l and con~,~','oned Ga~ cut mud. Installed Cosasco plug. Tested 'I to 1,5~ psi, ok. ~ved pr~uction ~eeo March.'18.& '1974 .. Installed 10', Class III, 5,000 psi BOPE. Tested to 5,000 psi, ok. Circulated' and conditioned mud. 'March ~ 195~' 1974 Lost 16 h~%rrels drilling fluid. Trouble releasing packers. Cut tubing at 10,447' o March 20, 1974- Cut tubing at 54'° Recovered 331 joints. M~rch ' 21, '1-974 Top-of fish at 10,447'o Found and t~ried to pull. Fish is sanded in. March 22--28, 1974 Jet cutting at 10,491' but could not pull out° Engaged fish at 10,447', recovered 20'. Top of fish at 10,467'. Washed over tubing and began milling on.packer at 10,500o5'o Milled 7". Fished out 8.5' fish. Top of fish at 10,476' *March '295 '1974 Milled f~om 10,476'-10,483' · *March 30 :& * 31& '1974 ,, · Milled from 10,483'-10,486' · *April *1~ -1974 Washed over packer to 10,501'°. . April ~2; '1974 83 pcf mud 84 pcf mud Cut tubing at 10,490'o .Recovered fish. Top now at 10,490'. 84 pcf mud Recovered 8' fish./-~Top now at 10,498' April '4 ;.' 1974 Washed down ~ 10,502'. l:t~covered 2' of fish. '!'April '5; '1974 .. ~Re¢overed' 1 ' of fish. Top -still at 10,500'. Top now at 10,500'. 85 pcf mud 85 pcf mud '~'April'6-7~'1974 . . Lost 4' of overshot in hole.- Top of fish at 10,496' 83.5 pcf mud · -April '8; '1974 Recovered 8' fish. Top now at 10,503'o. .83.5 pcf mud · '.April '9, '1974 ~11ed from 101503'-10,504~. Recovered 33' fish° Top at 10,537'. .83.5 pcf mud 'April ' 10; 1974 .. Washed over fr~ 10,537'-10,561' Lost 4' of shoe and washpipe. 84 pcf mud 'April 11;'1974 Recovered 14.5" fish. 10,557'. Top now at 10,551.5'. · 'April '12, '1974 Recovered all 4'. of wash pi~e fish° Milled with 6" from 10,551.5'- 85 pcf mud 84 pcf mud. · 'April 13, ',1974 Milled from 10,557'-10,567' ' ',lpril '14, '1974 85 pcf mud Milled from 10,567'-10,571' 84.5 pcf mud April '15, ~1974 Milled from 10,564'-10,571' ''April'16,'1974 85 pcf mud Plugged 7" casing from 10,571'-10,021' through 3 1/2" drillpipe. 96 sacks ~G" cement, preceded with 36 Cuofto -Water and equalized with 7 cu. ft. Water and 411 cu. ft. mud. Pulled' up to 9,990' and reversed out 3 cu. ft. cement. Downsqueezed 100' with 21 cu. fto cement° Circulated and conditioned mud. Increased mud weight from 85 to-87 pcf. Located solid cement at 10,309'. Tested casing, held 1,800 psi. Circulated and conditioned mud to recement. Plugged 7" casing from 10,309'-9,909'. 73 sacks "G" cement equalized with 412 cu.fto mud. 87 pcf mud · April '17, ' 1974 .. P~lled to 9,889", 'reversed' out trace of cement° Tested 7" casing to only 2,000 psi for 15 minutes. Located top of cement at 9,966'. Circulated and conditioned mud° Lowered viscosity from 96 to 55. Tested 7" casing from 9,966'-6,020'' held 3,000 psi. Found holes in casing at 6,007'. 87 pcf mud Apri!18~ 1974 Did dqueeze job on holes at 6,007'° Took fluid at 100 cu.ft./min, with breakdown at 2,900 psi° Squeezed 100 sacks "G" cement to 4,000 psi. Holes at 6,007' and 5,898' held 3,000 psi° Holes at 5,772' tooR fluid at 15 cu. fto/mino at 2,700 psi° Squeezed holes at 5,772'. Used 150 sacks "G" cement at 4,000 psi. Holes at 5,670' took fluid at 16 cu. ft./min. at 2,900 psi. Squeezed holes at 5,670' with 150 sacks "G" cement to 4,000 psi. 87 pcf mud April.'19,'1974 Cleaned out cement from 5,589'-5,756'° Tested holes at 5,670' and they broke down at 2,800 psi. Resqueezed holes at 5,670' with 150 sacks "G" cement at 4,000 psi. 87 pcf mud April 20, 1974 Drilled cement with 6" bit from §,656'-5,756'. Tested holes at 5,670' and held 2,500 psi for 15 minutes, ok° 87 pcf mud April'21;~1974 Increased viscosity from 56 to .100o.~ Drilled cement from 5,756'-5,980'. Tested holes at 5,670'-5,772' and 5,898,-5900'. Held 2,500. psi~ for 15 minutes, oko. Drilled cement from 5,980'-6,049'. Tested holes in casing down to 6,007', held 2,500 psi for 15 minutes, ok° Started cutting window at 9,827'. Milled with 7" from 9,827'-9,830'. 87 pcf mud '_April 22, '1974 Milled from 9,830'-9,855' 86 pcf mud '...Ap. ril '23; '1974 Milled from 9,855' -9,870'. 86 pcf mud April '24 ~ '1974 Opened window to 12" from 9,830'-9,870'° Decreased mud viscosity to 55 and circulate and condition mud° Plugged from 9,948'-9,466' with 119 sacks "G" cement preceded with 40 Cuofto Water and followed by 389 cu.ft. mud. Reversed out trace of cement at 9,418'o Circulated and conditioned mud. Located top of cement at 9,516'o 87 pcf mud : April 25, 1974 Drilled cement with 6" bit from 9,516'-9,832'o Cement held 2,800 psi pump pressure for 5 minutes, ok° Ran Dyna-drill with l°15 bent. sub. 87 pcf mud 'A_pril '26; '1974 Dyna-drilled 6" hole 9w832'-9,876' (44') 87 pcf mud 'April'27,'1974 Drilled 6" hole 9,876'-9,952' 'A~ril '28; 1974 Drilled 6': hole 9,952'-10,018' (76') 87 pcf mud (66') 87 pcf mud April ~-9, '1974 _ 3 J, ,,~, ~ Drilled 6" hole 10,018 '-10,119' April SO; 1974 Drilled 6" hole 10,119'-10,230' ' i'~May 'l; -1974 Dyna-drilled 6" hole 10,230'-.10,308 ' Reamed ' ,May_' 2 ~ -1974 Drilled 6". hole 10,308 '-10,360 ' (10I') "' 87 pcf mud · . (111 ' ) 88 pcf mud (78') 87 pcf mud (52') - · ' May ' 3, - 197.4 Dyna-drilled 6" hole 10,360'-10,405 ' : 'May '4, 1974 Drilled .6" hole 10,405 '-10,482 ' (45') 86 pcf mud (77') 86 pcf mud 'May'5, 1974 Drilled 6" hole 10,482'-10,572' (90') .86 pcf mud 'May '6, 1974 Drilled 6" hole 10,572' lO, 744' (172'). 86 pcf mud 'May '7, 1974 Drilled 6" hole 10,744'-10,762' " . (18') Circulated to get ready for logging° Ran Schlumberger Dual Induction Sonic Log from 9,828'-10,752, Compensated Neutron Log from 4,500'-10,757' Microlog from 9,828'-10,757, Compensated Neutron Micro-Log 4,500 '-10,757 ' 86 pcf mud '197.4 Drilled 6" hole 10,762 ' -10,790' (28.') . .- '. . , Lan~ed 1,171' of 5", 18~ 8rd N-80 liner' at 10,790'· float at 10,745' and top of liner at 9·618' Cemented liner with 140 cu.ft slurry · o · ~: "G' cement° Preceded by 40 cu. fto Water and displaced with 5 cu. ft. Water and 512 cu. fto mud. Reversed out at 9,300' got trace of cement · · 87 pcf mud ' '5" 'Iduner · Detail Bottc~ 1.50' 41.55' 1..-46' 911°81' 1.40' -211.89' ..... · '2~02' -1,171.63' Baker Float Shoe 5"-18~ N-80 Extreme Line Baker Float Collar 5"-18# N-80 Extreme line xo 5"-18# N-80 8rd LT&C O.D. Collars Hanger 5x7 Bruns Bott~ 10·790' Float Collar at 10,745'. Top at 9,618' ¢ .. May'9;'1974 Lost 31' jUnk in hole. No cement at top of liner. Located junk and cement a~ 10,723'. Drilled cement from 10,723'-10·745'. Casing held 2,600 psi for lOminuteso Lowered 'mud weight from 86 to 72 pcf. 86 pcf mud '_May'lO;-1974 Ran Go-International Cement Bond Log and Neutron Collar LOg from 9,600- 10,740'o Perforated 5" liner from 10·717'-10,728' and 10·708'-10,714' 72.5 pcf mud 'May ll~, '1974 HFT #1 10,681'-10,741' (May 11, 1974) ~sed two outside recorders with 10' of perforated tailpipe. Two i~side recorders. Ran 9,505' of 3 1/2"o Using 1,200 psi of field Gas cushion, set packer at 10,681' with tail at 10,701'. Opened · ~ol at 1:30 PM for 6 hour flow test° Shut in for 3 hours and X5 minutes for final shut-in pressure° Pulled packer at 10:50 PM had 5 minutes of light blowo Backscuttled and recovered 58.6 barrels of slightly Gassy Oil. .- (cOn't next page) 'May' 11, '.1974 'con't Pressure Data '''I~ '''FF 'FF - '''FSI '''FH , Top Inside ' 5,1480 1,493 628 4,300 5,480 Bott(an Inside 5,523 1,-602 639 4,319 5,523 Top Outside 5,297 1,614 635 4,294 5,297 Bott. om Outside 5,495 1,607 629 4,320 5,495 Schlumberger ran Saraband Computer Processed Interpretation 9,830'-10,728 . May · 12 ~ '1974 Go-International perforated 5" liner from 10,688'-10,702' 73 pcf mud Go-International perforated 5" liner from: .. 10,678'-10,646' 10,576'-10,567' 10,632'-10,613' 10,556'-10,531' '10,601'-10,584' 10,523'-10,514' .May 14, !974 ~ Installed 2 7/8" pipe rams. Circulated tubing clean. . 'May 15; '19'74 . Ran Production string° Pulled string and removed crooked joint. ~May'16, 1974 Reran production string. Ran Dresser Atlas Neutron Collar Log. 10,450'-10,740'. -May -17,' 19 74 Landed tubing at 10,727'. Removed BOPEo Installed and tested x-mas tree to 5,000 psi° Displaced mud with lease crude° Opened XA sleeve at 10,679'. Hooked'well to flowline° Ri.'g released at~..10:30 PM. _ · J. W. Wilson ......... ~ ....... K.B. TO TUBING flANGER ~ ~ 2~# x 6" ~BING HANGER W/uAS~O B.P. THREAD ' 3 ~P 4TS. 2~" ~E ~ TUB1NO(iO.08-6.~-2.6~) 20" Cern. ot ~' I1~" Cern. et 2073' 68 JTS. 2~" EUE 8rd TUBING 3~ 273.18' -- ~ ~MCO ~ ~ND~L 7. ' ":"~ "-'. .... '-:-:?1 ~:-' '.. '.:": a ~s. ~I". sue 6.5~ ~rd ~SZU~ N-~ ". ' *.-: :,'-.~:~-~*-'<~t'-:-~~ '"<'>..:~":9o:J~.'e~" s~ 6.~ 8rd TUB~O N-8o · 9B27' 'WH~DOW IH ?" [,8,o' ' 10, 10, -- 10, : 10, 5;20.60' 10,~23.45' ~ 10,528.93' : -- 10, ,o~-:e ' L. 10, 55h. 67' .... ,o~e,' -- .10, ~3.01' ' 573 ~8' · ~ 10, ,os,o' 10,576.37 ' 31 JTS. 2~" ~JE h.7# 8rd TUBING N-80 ' OTIS "XA" SLEEVE 2~" X 5" BAKE~ "FH" PACKER OTIS "S" NIPPLE ( Position #6 ) BAKER. BLAST JT: .. .. '.. OTIS "XA" ~'~"'V~ 2~" x ~" BAKER "FH" PACKER OTIS. "S" NIPPLE ( Position ~'5 ) 2 BAKER BLAST JTS. ( 2.~?'- 20.33' ) 2~" ~0~: "CC': SAFETY JOINT .' -' 2%" OTIS "XA" SLEEVE 2~" X 5" BAKER "FH" PACKSR OTIS "S" NIPPLE ( Position ~. h ) 'BAKER BI'ST JT. " · OTIS "XA" SLEEVE 2.%" x %" BAKER "FH" PACKE~ OTIS ."S, NIPPLE ( Position #3 ) .. 1.%00' 19.?~' 2128.91' .13.O8' 1093.66' 12.94' 12.90' 6§?. 6~, .12.96' 68%068' 12.90' ~56.93' lZ,90' 621.03' 28~161' : 1.12t 963.10' 2.90' ~O,87' . 22.80' 1.~1' 2.89' 1.h3 ' 2.~9' 1.50' : BAKSa slAST Jr. ... 17.1o, ,oeo,' - 10,600.42' 2%" R~,~ "CC" S~.FgTY._J_O.!~T_ ...................... l '_ '' l'h2t .... :"':--I0,601;8h' OTIS "~" SLEEVE ... 2.8U' lo,6oh. Tz,- '2~,,' ~' g,, 'BAKER "F" PA . _ ...... , _~ ........ H _ C . ...: ... . . ~o~' u- -10,OIO.~ .--~ OTIS "S" NIPPk2 ( Position ~2 ) :. 1.~' '- ~ i'~ - 10,633.9~'~ o~,, o~.~, "C"" eA~'~ d~ .... '. '~.~' ~ ' t' /---v .... · ' .... ~ S ,] 10,638,28 .~ 2{" X 5~ BAKER "FH" PACER .. , ~: : .... _ c_, ~ 2 ~K~R B~5T JTS. ( 10.08' - ~0.30' ) ~.3~' ~u i ~,oe,,' "10,665.33'~ ;~,, ~,'~ ,~'~.;,';-~o~'~ ..... ".' ..... 1.05' ~. .~;?]. ' '--.'; '1~ ".. ': ~ ~ ~s~ ~. ( ~.~o, - ~o.~o, ) ,o.~o, o I ~,o~,, , ~. . -,o,,~'-- zo,7~.98 . [ ~ ~A~ s~{~s~ su~ · . '. · ~ ~~' " ":'": ":i ..-~- . ..['n-... -. · ' S.C.U 43A-8 _ f ..~:. -' zo,~~°, ~... ' ': '' CA5IN~ 6 TU5ING DZTAIL. -- . SECTION 8 ~'ZN.,r~.sw. SM ..... - ...... ............. OIL AND GAS CONSER~ATION":C~ WELL ~OMPLETION OR RE~OMPL TYPE OF COMPLE~ON: ~.' , , , ~-~ ~ -- -' .- .~t~rd O%1 .~mpany of . .~a~ · ~.< Z:: ;,.- ':.~ .... [j; .... ~---, -~j -';~: i~: . ',< [ {'" ~,~..0~ iViANY ...' ! ROTARY TOOLS 10790 '~:~{~10~BT~TVD ::: [10~45 '~ ZD73~*'~TVD [3~3 ~ ~ ...... ~ ~ 0-10790' ! j i ' , ~_ weU) :: -' il cm~n.~r~ i~,co~a~ 1300 sacks cemen~ '~ . 2200 sacks cI~. ~ ~v.. TUSm~ ~O~ S~ (~D) S~Z~ . None None None P.~CKER SET (MD) ___ DATE FIRS~JPI~ODUCTION :ii '~O'DUCT~ON M~'[~O'D <Flowh~g, ga{ lifL p~mpmg--s,ze and ~e of p~P) iW~_~A~S (~oduc~ or 5~20/74; :~: , ~}[ :.~ FloWing :i: ~ ~ ~ I~ 'Producing 5/23/74{: J ~? ~ ~;'~. -~](~' J;.~ '-;-::~ J~ ¢s~~.'~_~...~j}~ ......... 2,2.t~...5 .......... J ....... ~7';5 ..... J .... 1;5 ~~, w~~ io~ ~~ l$~~= 'o~SL. ~ ~:~: ~.~.- W~T~BBL. JO'' G~Vt','~-~ (C~.) ~o~. - I': ..... t'~- ; I ~ ~ ~:~ i:'.~: .~o. ~ ~ I ~.~ - ~ll;.DISPOSITION OF GAS (~old, used lot ]uel, vented, etc.) ~ ~;~ ~ ) ¥: : -'....: , ~., ~ . ITEST WITNESSgD BY Injected back into field ~ ~':: ~ ~::~ ~''~ ;'-:" 32 LIST OF ATTACHMENTS ' -' Directional s~vey~ t~in9 detail ~ ~ ~:::~ , *(See Instructions andSpacel F~Additional Data on Reverse Side) . INSTRUCTIONS ::.General: This form is designed fOr submitting a c°mple}e!~and correct well completion r'eport and :log on !~.].11 types of lands and leases in Alaska. :ltem;~i'~16: Indicate which el~evation is "'used as refere:nce'-(Where, not otherwise ~hoWn) for depth measu~:e- ments'g yen in other spaces on tliis form '~ad in any att~ck~men'ts. -Item~i20, ind 22:: If this well.is coml~leted for separaf~' 'P'rod~.¢fion from -more than one interval zone · (mull!pie completion), so state in item 20,. and 'in item.. 22. s'h0~v the prcducing interval, 'or intervals, i?~,op(s),: bottom(s) and name (s[)~:!(if any)..for only the jn:tergal, repo.r.ted in'item 30. Submit a, separate report '.:r(p ge)~.on th~s form, adequately :ldentff~ed,..fo~: each adCtitional interval to be sePeratel~ produced, shoW- :i:ng (Fie ~d~itionaI data perfi~en';t ih' ~0c~': interval. Item2'~;J '.'Sacks Cement": Attached supplemental .te~:0i;dls fbrI thJ's well 'shoUld show the detailS of::any mul- tiple~fage cementing and the location of the c~men'tingi'to?l,. .. Item 8i Submit a separate completion report on this f~0'm~-::fer', each interval to be separately produc~, - :. i.(,l~ee'i.nstruction for items 20'and 22 above). ' t '- ~'08:~''-~'~}107:14 ~' ~0717. ' 1,0728' ~used': 1440 ,~PS~G ?~ield Fo~ati6n %est Perts 10 ' ' MEAS. ,, , ,, , , , · ~, . gas C:Ushion. Tester 0pen~'6,.::hourS~ ReC°ver~d 5}8.6 barrels }qf 28~9~.~I.. ~oil cut 0;4%'water fl6wing preS~re 628_i~:~93 psiG. ~ Final S.i:. Preshu~e ~300 PSIG. · H1 10353 i~035O, : :~ ~ , ~ , ., . ''~ ~,,~:, f-;:.'.,?, H8 :?:.,:" 10527 10524' :'~ ' ~10~: 10646 1064"~ ~ : : '' ~ : '~ r ...... BH10: 1'0729 10726 ' ~6. CO~ DATA. A~ACH BRI$~ D~C~IP~ONS O~ LITHOLOGY, POROSITY, FRAC~R~. AP~NT DIP~' ."AND DETECTED, SHOWS OF OIL, O~ OR %VA~. . TRANSMITTAL AND ACKN?'i, EDGMENT OF RECEIPT OF MATERIAl _ , :-/::":-, " .~-.-. THE FOLLOWING IS A'LIST OF MATERIAL.ENCLOSED HEREWITH PLEASE' ' - - -.."- :'- .... CHECK ;aND bODVISE II~fEDIATELY. ' - .. . . . ece].v=d and checked by: . Date: Rb.. ma r k s: J.UN ~ ~ 1974 COt'IPA NY WELL RUN AND ADVISE I2,D~DIATELY. . i I '~1 ' , i ~' -'SCALE · ' .... · INDUCTION EL'ECTRICAL LOG DUAL INDUCTION LATEROLOG ~ 4,,-- BOREHOLE COMPENSATED'SONIC · '--" ~,~- -. BOREHOLE COMP. SONIC w/caliper BOREHOLE COMP.- SONIC w/gamma BOREHOLE TELEVIEWER . · CONTINUOUS DIPMETER HIGH RES, CDM -POLYWOG PLOT CEMENT BOND LOG CASING, COLLAR LOG COMPENSATED FORMATION -DEN: -- ' _ IrORMATION ANALYSIS LOG - IrORMATION DENSITY LOG Ir' lr _ · FORMATION TESTER FORMATION FACTOR F F --- - G~:;.,UA RAY '.,-: .. GAMMA RAY- NEUTRON ' - GAMMA RAY COLLAR LOG MICRO LOG -. MICROLATEROLOG MUD LOG NEUTRON LOG', "· ' :'" · PRoXi~.ITY MiCROLOG PERFORATING RECORD RWA COMPARISON PLOT SANDSTONE ANALYSIS SIDEWALL NEUTRON POROSITY SONIC ' TEMPERATURE LOG COMPLETION REPORT DIRECTIONAL SURVEY- don./97.5 'SEPIA .. BLUE LINE Eeceived ,and checked by: ._ ~'-~'- Date: _~ _. , · ; - Remarkes: .... ._ . 20"' Cern. et 34' Cern. at 2073' -- 3,273.18'- 4-008.O7' m 4'708.61' --~ "K.B. TO TUBING HANG~R 2[" x 6" TUBING HANGER ~/CASOCO B.P. THP~]AD - 3 PUP JTS. 2~" Eq3E 8rd TUBING(lO.08-6.06-3.64) 68 JTS. 2~" RUE 8rd TUBING N-80 ~-.ICAMCO MM MANDRBL 35 JTS. 2-[" RUg 6°5# 8rd TUBING N-80 CAMCO ]~4 MANDREL 23 JTS, 2e~'' RUE 6.5# 8rd TUBING N-80 CAMCO 'MM KANDREL 22- JTSo 2[" RUE 6°5# 8rd TUBING N-80 CAMCO MM MANDREL 22 JTS. 2~" RUE 6.5# 8rd TUBING N-80 17.00' .75' 19.78' 2128.91' 13.O8' 1093.66' 12o94' 721.95' 12.90' 687.64 ' 12.96' 685°68' ------- 5,407.25 ' -- .: ~CAMCO MM MANDREL 12.90' _ ~ i 21 JTS. 2~" RUE 6.5# 8rd TUBING N-80 656.93' b,077.O~' ~ ' -. ~,CAMCO F~4 MANDREL 12,90' "' :.i .....I~ : 20 JTS. 2[" ]~JE 6~5// 8rd TUBING N-80 621°03' ,---,- 6,?n.oz, ..... ~-;>--cAMco MM.MAND~L ' 12.98' .:1! (90 JTS. 2-~" DJE 6.5;# 8ret TUBING N-80 281Z~61, ...... la ~n~ V~,- ~ 'OTIS '.~,, SLEEVE 2.~O' ~'~'~, ~ 2~"x ~" BAKER "FH" PACKER ~'~ ..... ' ~ OTIS "S" NIPPLE ( P~i%ion fi6 ) [o'~;~'.~, ~ OTIS "XX,, s~s~ 2.8~, ' ~'~ ' ~ 2~'' x " ' ~ " ', ~ , ~ c~ o~, ~~. s · 5 B~ER FH PACKoR ~v,~u.~ --~_ OTIS~"S" NIPP~ ( Position ~5 ) 1.53' _'L~'~_7:.' ~ 2 B~ER B~ST JTS. ( 2.~7- 2o.33, ) 22.80' lo,)>a.o-f .~ ~%,, OTIS "XA" S~EVE 2.89' -10,557.56' 2 ,, ,, ,, ,, .. ~ ~% x 5 BAKER FH PACKm~ ~ ~ ~ fl ~U ~ ~ 5.45' 10,563.O1' ,, ,, 10,576.37' - ~ 2~,' x '5" BAKER "~" PACK~ ' BAKER B~T JT. ~',~ ~ ~;' ' ' · ~ ~ i7.10~ · u,blO.13 ~ OTIS "S" NIPP~ ( Position ~2 ) ' 1.55' 10 6~ ~8' J 2 BA~ 9~ST JTS. ( 2.00' - 20.30 ) ' 22.30' U? ...... , ~ OTIS "XA" SLEEVE - 2.87' '~'~-"'~ -~ .~ "S" NIPP~ ( Position ffl ) ' 1. gO' ~ 6~ ~, ~ 2 ~A~Sa SUST S;S. ( ~O.0~, - SO.30' ) 30.~' Au' ~3'~u ~' 2" RO' " " ~"' , 10 67v mo, ~ { BE W~ CC SA. mTY JT. 1.4~ ~n ~c ~,~ 2% x 5 BAKER "FH" PACKER 5.h7' · 0,72b.9~ ' .. - 2a- BAK~ SHE~ SUB . .59' . ' S.C.U. 45A-8 10, 7~0 T ...... - IU]CASING & TUBINGDaTAIL.J u~ JUN251974 ~J SECTION e ! .Formation Testing Service Report ju~',l '-' 6 i974 DIVISION OF OiL AND (;AS HAlllBlllITi~Ill SEII I/i~, E$ DUNCAN, OKLAHOMA Ticket .n~ F L U I D S A M P L E D A T A Dote 5-11-74 Number 598836 , Sampler Pressure P.S.I.G. at Surface Kind Halliburton~luf, UrtD/t~E- Recovery: Cu. Ft. Gas of Job HOOK WALL District n,~,,,u~r~UL CC. Oil cc. Water Tester C.H. BOATMAN Witness DON REDLINE cc. Mud Drilling Tot. Liquid cc. Contractorl~E-l~l DRILLING COMPANY SM S Gravity. ° APl @ °F. E(QU I PM E N T & H O LE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDE Elevation 1 57' GL 172' K B Ft. CONTENT 16I Net Productive Interval. .Ft. Recovery Water ~ @ ~ °F. ppm All Depths Measured FromI<el ly bushing Recovery Mud ~ @ ~ OF. .ppm Total Depth 10741 ' Plug back depth Ft. Recovery Mud Filtrate ~ @ °F. ~ppm Main Hole/Casing Size 7n 5'm 18~ Mud Pit Sample ~ @ ~ °F. ppm Drill Collar Length - I.D Drill Pipe Length 1146-9507' LD. 1.995 - 2.764" Mud Pit Sample Filtrate __ @ ~ °F. ~ppm Packer Depth(s). 10681 ~ Ft. Mud Weight vis cp Depth Tester Valve 10662 m Ft. , TYPE AMOIN~00# Depth Back Surfac~j/8,' & Bottom Cushion Gas PSI Ft. Pres. Valve 10657' Chokel)Ubble hose Choke 5/8" Recovered 1145 Feetof 2 ,3/8" tubing - gas cut oil ~ Recovered 3660 Feetof 3 1/2" IF - gas cut oil Recovered Feet of ~ <,~ Recovered Feet of 9- GO ~ o z Recovered Feet of :;o ' I,-=l Remarks TOO1 opened and bled off gas cushion .... light blow throughout test. m Closed tool for 196 minute closed in pressure period. , Gouge No. 3382 Gauge No. 3647 Gouge No. 3381 TEMPERATURE TIME Depth: 106§7 Ft. Depth: 10671 Ft. Depth: 10603 Ft. 48 Hour Clock 24 Hour Clock 48 Hour Clock Tool 5-11 ~X./dX O Est. 170 °F. Blanked Cfff rio Blanked Off no Blan,ked ,Offyes Openedl ' 31 P.M. Opened5-11 A.M. c= Actual °F. Pressures Pressures Pressures Bypass 1 O' 50 P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic 5480 5494 5297 5481 5523 5506 Minutes Minutes Initial 1493 1667 1614 1663 1620 1694 ~.o_ Flow ._~_ Final 628 635 635 629 639 639 364 363 Closed in 4300 4307 4294 4294 43' -g- 4312_ _195 196 8'~ Flow ~.~ ~Y I~ I,I U ~-~ r-' = ~ Final ~' Closed in LJ ~ Go Initial JUN 6 i974-- ~ Flow" ~.~.. Final Closed in BJ¥i$iON IJF 011 Final Hydrostatic 5480 5359 5297 5353 5523 ~{~JOJ~ [;£ ~ ~., FORM III--PRINTED IN U.8.A. FORMATION TEST DATA "'""'"'"'"'"'/" % ~'-~ FLU ID SAMPLE DATA Ticket Date 5-11-74 Number 598836 , Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE ' ?' cc. Oil '~. cc. Water Tester C.H. BOATMAN Witness DON REDLINE cc. Mud Drilling Tot. Liquid cc. Contractor KENA! DR!LL!NG COMPANy SM S Gravity, ° APl @ °F. E Q U I P M E N T & H O L E D A T A Gas/Oil Ratio ........ cu. ft./bbl. Formation Tested OO RESISTIVITY CHLORIDE Elevation Ft CONTENT Net Productive Interval Ft. Recovery Water ~ @ ~ °F. .ppm All Depths Measured From, Recovery Mud ~ @ ~ °F. .ppm Total Depth Ft. Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size. Mud Pit Sample @ ~ °F. .ppm Drill Collar Length I.D._, Drill Pipe Length I.D., Mud Pit Sample Filtrate ~ @ ~ °F. .ppm Packer Depth(s) Ft. Mud Weight vis cp Depth Tester Valve Ft, TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke' .... Recovered Feet of ~: Recovered Feet of ~n Recovered Feet of ~ z !< Recovered Feet of ,o i- Recovered Feet of m Remarks FOURTH GAUGE on TEMPERATURE Gauge No. 3646 Gauge No. Gauge No. · TiME ~-~ Depth: ln~7 Ft. Depth: Ft. Depth: Ft. CO 24 Hour Clock Hour Clock Hour Clock Tool A.M. o Est. °F. Blanked Of~R.R Blanked Off Blanked Off Opened P.M. c:= Opened A.M. -r' Actual °F. Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic 5495 5502 M~.ute, Minutes =~o Flow Initial 1607 1687 .~_'r- Final 629 643 Closed in 4320 4318 ~ Initial ~ Fl°w Final, ,, Closed in , Initial ~ Flow ~_~. Final .... Closed in Fina!.,HYdrostatic 5495 5367 .., ,, Ii FORM I~I--PRINTED IN U.I.A. FORMATION TEST DATA Gouge No. 3382 Depth 10667' Clock No. 8105 48 hour No. 598836 First First Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Deft. PSIG Time Deft. t -l- 8 PSIG Time Defl. PSIG Time Deft. t -J- t~ PSIG Time Deft. PSIG Time Deft. t ~ i~ PSIG Temp. Log. Temp. Temp. Log Temp. Teml~. Log Teml~. .000" Corr. .000" t~ Corr. .000" Corr. .000' ~ Corr. .000" Corr. -000'° ~ Corr. o .0000 1667 .0000 635 1 . ]080!" 232 .0238** 3245 2 .2]08: 360 .4059 3537 3 .3]36 435 .0680 37]7 . .4]64 5]5 .090] 3838 5 .5!92 577 . ] ]22 UTR 6 .6220 635 .1343 3872 .' 7 .1564 3981 8 .1 785 4062 9 .2006 4111 lo .2227 4154 1 ] .744R 41 ql 12 _ ?6tqc) 422'7 13 _ 2RQC! 42_~R 14 ,.3111 428! ~s 3330 4307 Gouge No. 3647 Depth 10671 ' Oock No. 8420 24 hour o _onnn 1663 .0000 629 1 _2117. 224 .0466** 3175 2 _ 4133 357 .0899 3500 3 _ 6149 429 .1332 3682 4 R!65 509 .1765 3807 5 1 nlR1 572 .2198 UTR 6 i 9pnn 629 .2631 3842 ,,. 7 .3064 3958 8 .3497 4032 9 .3g.':Jfl 4095 l0 .4363 4143 ~ .4796 4180 12 -_ .~299 4217 I 13 ~? 4246 ~4 . ~nqg 4269 15 ~cqn 42q& Reoding Interval ~0 13 Minutes REMARKS: *First interval is equal to 63 minute.~ ** = 14 minIJt~ IITR : Unable to read ,,, FORM lll3--PRINTED iN U.S.A. SPECIAL PRESSURE DATA "'"'"'"'"'"'"'/" ,: Gauge No. 3381 Depth 10693 Clock No. 10054 48 hour No. 598836 Fi rst Fi rst Second Seco nd Th i rd Th i rd Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Deft. PSIG Time Deft. t -f- ~ PSIG Time Deft. PSIG Time Defl. t -~- ~ PSIG Time Deft. PSIG Time Deft. t -J- ~ PSIG Temp. Log Temp. Temp. Log Temp. Temp. Log Temp. .000" Corr. .000" ~ Corr. .000" Corr. .000" ~ Corr. .000" Corr. .000" ~ Corr. 0 .0000 1694 .0000 639 1 .1059'~ 236 .0231 *~ 3238 2 .2067 364 .0446 3541 3 .3075 437 .0661 3710 4 .4083 416 .0876 3835 s .5091 582 .1091 UTR 6 .6100 639 .1306 3865 .' ? .1521 3980 8 .1736 4054 9 .1951 4111 ~0 .2166 4157 ~l .2381 4197 12 .2596 4231 13 .2811 4263 14 .3026 4287 is .324(1 4312 Gauge No. 3646 Depth 10697' Clock No. 6727 24 hour 0 .d0D0 1687 .0000 643 1 .2128' 243 .0473** 3213 2 .4154 374 .0912 3530 3 .61RD 446 .1351 3535 4 _~?n6 .~74 .1790 3830 s l_n?.~? ~7 .2229 ' UTR 6 1-7260! 643 .2668 3868 7 .3107 3982 8 .3546 4(158 9 .3985 41'15 ~ 0 .4424 4159 11 .4863 4199 12 _ .~ 3("12 13 ..~741 is .6620 4318 , ,Reading Interval 60 1 ~ Minutes REMARKS: *First interval is equal to 63 minutes. **: 14 minutes. UTR: Unable to read , FORM 18~'"'PRINTED IN U.S.A. SPECIAL PRESSURE DATA ,.,,-.r.,., ,,,, ,. ,/,, Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill C~X. P.ipe Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... A~ Running Case .................. Hydraulic Jar ..................... VR Safety Joint ................. Pressure Equalizing Crossover ......... Packer Assembly ................... Z~V~r~X..P.e.rfs ................. Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... DriXX~Y~: Blanked. o.f.f..BT ..... Anchor Pipe Safety Joint running .case Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. ! Blanked-Off B.T. Running Case ........ Total Depth ....................... Oo D. 3 7/8" ? 3/8" 3½" 3 7/R" 3 7/8" 3 7/8" 3" 3 7/8" 1" Jo D, 1 _ 2. 764" _ R7" TICKET NO. LENGTH 2_77' 114fi' 9507' 598836 DEPTH .E_ 4~' E_7E' 4.6' 4.b/' 3.95' 3 7/8" . 75" 3.23' 3.9" 1.99" 3.59' 2 7/8" 2.4" 8.81' 7/8" 3" 7/8" ,, 3" 10667' 10681' 4,05' 4_25' !0693' 10697' TIME Each Horizont'al Line Equal to 1000 p.s.i. I · · TIME NOMENCLATURE b -- Approximate Radius of Investigation ........................ Feet b~ -- Approximate Radius of Investigation (Net Pay Zone h~) ......... Feet D.R.-- Damage Ratio ............................................ E! -- Elevation .............................................. Feet GD -- B.T. Gauge Depth (From Surface Reference) ................... Feet h -- Interval Tested ......................................... Feet h~ -- Net Pay Thickness ....................................... Feet K -- Permeability ........................................... md K~ -- Permeability (From Net Pay Zone h~) ........................ md I'rl -- Slope Extrapolated Pressure Plot (PsiS/cycle Gas) .............. psi/cycle OF~ '--Maximum Indicated Flow Rate ............................ MCF/D OF2---Minimum Indicated Flow Rate ............................ MCF/D OF3 --- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF:4 ~' Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D Ps -- Extrapolated Static Pressure ............................... Psig. P F -- Final Flow Pressure ..................................... Psig. Pot -- Potentiometric Surface (Fresh Water '~ ) ...................... Feet Q -- Average Adjusted Production Rate During Test ................ bbls/day Q, -- Theoretical Production w/Damage Removed .................. bbls/day eg Measured Gas Production Rate ............................ MCF/D -- Corrected Recovery ...................................... bbls -. ~ Radius of Well Bore ...................................... Feet t to --- Flow Time ............................................. Minutes ~ Total Flow Time ......................................... Minutes -- Temperature Rankine ...... · .............................. °R Z -- Compressibility Factor .................................... ~lJ -- Viscosity Gas or Liquid ................................... CP Lo~l --' Co'mmon Log * Potentiometric Surface Reference to Rotary Table When Elevation Not G;ven, Fresh Water Corrected to I00° F. 0 I R E C T I 0 N A L $ U R ¥ E ¥ SJ3.E_A_L__5_QU 43A.-8 ~g~.~.LAND DIRECTIONAL DRILLING 05 114/74 MEASURED D E V I A T I O N .-~ A NG ~_IJ{EC.T_[GN TOTAL COORDINATES C L TV__Q___ .SUB 5.~ LATITUDE DEPARTURE DISTANCE SUP, ES ANGLE DOG LEG SECTI SEVERITY DIST **' ORIGIN LOCATED AT NO = ___100 .... 0 _~0 ' 200 0 30' $ 30E 300 0 O* S OE A.O0 o_ Om $__QE_ . 500 0 30' N lOW 600 0 ].5m N 14W ___._Z_O 0 0_.15 ' 800 0 15~ N 22W 900 0 )0m 0~00, TVD = O.OOt LATITUDE = 0.00, DE 99.99 -72.00 0o74S O..~6E 199.99 27.gg lo 49S 0.ODE 2gg.gg .1~7.9g !.ADS 0.89E 399.99 .~ 27_.., 99 1.49S O. 89E 499,98 )27.g8 0.63S 0.74E 599.98 ~27.98 O.2lS 0'64E 799.98 627.98 O~60N PARTURE =. 0.00 0°8? S 31.ggE O.aO0 O.~2E 0.68 N O. [6E 1.46 N 1.74 S 30.99E 0.017 IoTA S 30o99E I. IS__._S. ..... ~o.:__~g.~. __ _o_..._ooo 0.98 S 49o57E 0,,'500 0.67 S 71.63E 0.251 0.53 N' 68.196 0~026 ...... 28~6'1E 0.00 ~ 6.35E 0.259 _IOQO IlO0 1200 l~00 1500 ~.~..~.W 999~97 . .. 151 N 3OW .1099~97 15' h 53W 1'1.99,97 O' N OW 1399.97 15' N 8W 1499.97 927.97 2'.70N O.ll~ 1027.97 2.96N 0.46~ 1227,97 2,96N 0,46W 1327o97 3.40N 0o52W 2.70 N 2.q, 6W 0.296 3.00 N 8,90W 0.099 3.00 N 8.90W 0.250 3.00 N 3°44 N 8o78W 0.250 1700 I 15' S lSW 1699'g5 1527,.95 0,85N 1800 2 451 $ 24W 1799,83 1627.83 3,525 _. ! 9.0..0 Z,~ _.~' ...... ~_..Z2.~__ 1.8.99.,~ 1.~ ~..~..,.,~ 7 ......... _~.~.ZF S 2100 I O' $ 2'8W 2099,72 1927.'~2 10'.765 ............. ' 12,28S 2~00 0 30' S 47W 2299~70 2~ 7.?0 2~00 0 ~5~ S 44W .2399,69 227-69 13,82S . . 0o56W 3,07W 5.28W 6.10W 8'49W 9.'79W 2600 0 45' N 76~ 2599.68 2427.68 13.36S II,,06W 2700 I .15' N 46W 2699.'65 2527..6S 1!~,85S 12.63W zgoo o ~5, N ,~w z899.6~ z'?zT..6',~ [o,.z!s 15.15~ . . . : ~000 I .!5' N 36W 2999.,60 2827'60 8.~5S 16.~3W 1,,,~1 N 52.70W 1.004 4.67 S ql.].SW 1.527 8.05 S 32~.q8~,,~ 10.62 S 29..81~'.J 0~503 I2~36 S 29,.55~ 0.528 ~ ~- ~ .!._..~ ...... 2.g.._ ~ ~.~ ............ p.~..o t 7 1~.9~ S 30.49W 0,546 16.22 S 31.57~ 0 ~:~ 16,83 S 35,59W 0,657 17.35 S 39.61W O.lOz, 17'32 S 46.82¥t 0.707 18.07 S 51,93W 0.461 1.8~2~ S ~6.01W 0.402 18.,G8 S 62.78N 0~522 19,55 S 66.93W 0.57E: 2~ _YLAhlGLN.IIAL=P~J!r.j_D · 'S.O~~A.L, _$_C..,U 43A-8 GREAT LAND DIRECTIONAL DRILLING 05/lq/74 MEASUREO D E V I A T I 13 N TOT~,L COORDINATES C L a $ u R E S OaS LEG SECT _.I:]EJ?TH ANGLE__I1LRECTI~_QN _lV_p ~;UB SEA LATITUOE DEPARTL~RE DISTANCE ANGLE SEVERITY giST:h! 3200 0 30' 3400. 0 45" 3500 0 45e ~.QO 0 45e 3700 0 30' 3800 0 30~ __.,) 90, CL ,, 0 JO ~ 4'000 0 30 m %],00 0 30' 4300 0 Om 4400 0 0e .=._45.Do ... 0 ~600 0 30~ 470'0 0 ~5 m __a60.O ' 0 ~'. 4900 0 5000 0 45' N 4gW 3199.58 3027.58 7.08S 18',,6§W ID.g5 S 69.18W 00528 -2 N ~._8W 3209.58 3~27.58 6.76S 19.46W 20~60 S 70.83W 0.~5 -1, N 12W 3399.57 3227.57 5.48S ~9.73W 20:'~-~ 74':'~7W 0.626 -~ N 2~W 3499.56 33.27.56 4.265 20.2aw 20.64 S 78.09W 0.117 o N 8._W 359g~56 3427.56 2.g6S~q_e. QSW 20.50 S 81.72W O. I6g 2 N ~W 36Ng,55 3527.5~ 2,30S 20.g~W 2~.0~ S 83.72W 0.~28 2 N 5E 379g,55 3627.5~ ~.43S 20,88W 20.g3 S ~36.'06W 0.3'~0 ('"3 N LAE ~8gg.54 3727.5~ 0.58S 20,67W 20.67 S B3.36W O.OTB 4 N 1~ 3ggg,54 3827,54 0.26N 20.47t~ 20047 N 89026W 0.008 5 N [~E ~Ogg.54 3927,54 i. OgN 20.23W 20.26 N 86.88H O.02b 6. N ~e 4_.1~.9..5_~ '. ~.Z7_,.~_]' _.L,_~_IN ~.,.!TW 20.26 N 8~o42w 0.~0~ "6 N OE ~299,53 4127~53 .L,.g7N 20,17~ 20,26 N 84.42W~ 0.500 6 N OE 4399,5.3 4227,53 I'97N 20.17W 20.26 N 84.42V; 0.000 6 N .~E ~._99.~_~_) ~.~.~53 2.83N 20'.06w 20.26 N 81.95W O. 500 ? N 2E ~59'9,52 4427,52 N %4W 4699,-52 4527,52 . ~ ~.W._ . 4799.~2 4627,52 N 47W 4899.51 4'727.51 N 3bW 4999,50 4827.50 3.70N 20.0.3W 20.37 N 79.51k( 0.0'%3 4.65N 20.94W 21.4§ N _~.~.~._ : _ZQ.~,.~.~__2 ~ ?~_S_,...H ..... 7 7, ~ ~ ~ o. 7 ~ o .5..2~N 2~. 58w zz. z t N 7~'~'3 6.30N 22.3'5W 23.22 N 74.24~ 0.276 5200 0 30' 5300 0 30' _ 5_~0.0., 0__~0'. 5500 0 30'~ 5600 0 45 ' ~_~o ~, 5800 .l O' 5900 I 0~ 6~00 1 6200 2 O' N 48W 5199,50 5027'50 ?,'OON 23,42W .. "N.~.ON.. 5~.9.~.,.~~~.~:.~_.!. 40 e'. ~ON 23.8~, w N ~SW' 5499,49 5~27,49 . 8,99N N 5W 5599,48 5427,48 Io,2gN 24.61W N L2E 5799.46 5627.46 13,28N 23,gTW' 23.66 N 7q.24~ 0.574 24.44 N 73.34~ 0,296 24.4~ N 71029~ 0.529 25.28 N 70.57W 0.544 26,6~ N 67.29N 0~513 26.g~ N ~,.s6~ o.~2t 28.08 N 57.68W 0,069 24 ,,63W fl g li. t6 l? IU 20. 22 52.05 N 50.21W 0~641 2,5 35.,14 N 47.43W 0.2.~'~] 29, JUN 2:5 i974 0 I' REC T ! ONAL SUR V E Y TANGENT [AL HETHOD SO_~AL .S_C~. ~3~A-8 GREAT LAN9 DIRECTIONAL DRILLING 05t14t74 MEASURED O E V ! A T ! 0 N 0EPTH ANGLE OIRECT 1O.N SUB SE A TOTAL COORDINATES C L a 5 u R E S DOG LEG SECTI( LATITUDE ·DEPARTURE OISTANCE Ar~GLE SEVERITY DIST~N[ 6300 _.69__Q0 6500 6600 _ 67~0 6800 6900 7].00 7200 7400 7500 7700 7~.00 8000 -8100 _L.SZ.0.O 8300 8400 8600 8700 6299.20 6127'20 6399.13 6227.].3 6499,05 6327.05 659G.97 6~,26.97 66g_B.~Sq 6526.89 6798,82 6626,82 6898.74 6726.74 6998..e 69 6826.60 7098,66 6926,66 T198.61 7026'.6:1. 28.05N 26,.7].W :~8.7A N 43.60W 0.633 33. 3I.q6N 27o06W 41o8~ N 40.24W 0.352 35.7~N 28.14~ ~5.4q N 3~:.21~ 0.~! 39.66N 28.14W 48.63 N 35.35W 0.626 45.' 43.56N 28.62W 52.12 N 3~.30W 0.27q 47.~5N 29.16W 55.69 N 31.57W 0.039 5~.29N 29.98W 59.4~ N 30.3~W 0.157 . 56.33N 29.77W 61.95 N 2C~71W 0.744 __ 56.94N 29.qgW 64.12 N 27.38W 0.2'5~'~ 62., 5qeg6N 29.07W 66.64 N 25.86W 0.256 T 2~8_-~5 T 1~.6.55 63.40N 29.67~ 70.00 ~.__.25.08W__O. 63~, 6~.' 7398.5/ 7226.51 66.39N 30.26W 72.97 N 2~.50~ 0.252 7I.. T498.~6 7326.46 6g.4'SN 30.20W 75 73 N *;~.50~ O 365 74 7~_~8.43 7426.43 7l_e~.gN 30.58W 77.8~ N 23.13W 0.57z~ 76.' 7698.42 7526.42 73.3'~N 30,67W 7c~.50 N 22.69~ 0.284 7798.~0 7626.40 75,52N 30.83~ 81.57 N 22.20W 0.250 O, . tN 1014 45' N I1W 45' N IE 15' "N 'I.O_W O' N 3N 15' fq 4W O' N ,AW 15' N 7W ;)Om N {.6W 15' ' N 30' N 9w 15' N 15" ' N_1_5 15' N .!9W 15' N 23W 7898.38 7726,38 7998,36 7826.36 8098.32 7926.32 8_198.30 __8026,30 8298.26 8398.2~, 8598.19 8426,19 8698.17 8526'17 77.26N 30.cJSW 83.23 N 21.t{.3u 0.250 79,,42N 31.21k{ -- 85-;-'3"~--'-~---21.4 5 '~- ........ b',='2'56~ 84.. . . . 84,09N 32,31~ 90.08 N 21,02W __0,28~ 86.67N 32.'72~ 92.64 N 20.68W 0,251 92. 88.79N 33.,25W 9q-81 N 20.5,'3W 0.277 gO,gON 33.~2W g6,g6 N 20.*OW 0,021 _._~SOO 2 O' N 8900 2 O' N 5W 9000 Z 15' N 2W _ 9.1_0._0__ 2 O .... ___H_ ' q.. , 9200 I 45' N 8W ~300 2 15' N 3W _ - f~ ~ ~ rm fl.,nn 8798'11 8626.11 8898.05 8726.05 8997,97 8825,97 ~.097.vI 89z5.91 9197,86 9025.86 92.97,79 9125.79 105.80N 36..q3W 111.90 N 1~:,.99~ 0.273 1! 109.29N 36,43W 115.20 N 18.~3W 0.260 ~ , DIVISION OF OIL AND U, AS 0 [ R EC T IONAL SUR VE ¥ ~GENTIAL METHOD 50,~At,. $CU 63A-8 GREAT LAND DIRECTIONAL DRILLING 05/tA/74 MEASURED O E V ! A T ! O N TOTAL COORDINATES C L O S _OEY_T H A NG_LE DIRECT [~N TvD SUB SEA LATITUDE OE'PARTIJRE 01 STANCE U R ~: S DOG LEG ~NC L ~-: SEYERITY SEC.'ri[ 9400 gSD_O Z 15' 9600 9700 ___9_~ 0_0 _2__[_5_ ' 9900 2 45' lO000 Z O' _LO_I_Q.O .L&~ ' [0200 [ 15' 10300 I 30' _1_0883 · 1 ~_O' " PLUGGED BACK TO 10018 2 0' .iO~Jt0 ~ ~5" i011q ~ 0" 10170 ] 65' 10~18 6 I0360 7 15' 9397.7! 9225.71 120.16N 36.99W 9497.63 9325.63 124.09N 37o 12W 125.73 N l~.ltfl 0.157 12~.~ 129.52 N 16.51W 0.117 129,,, 9597.55 9625.55 127.78N 38.ATW 9697.48 95~5.48 131o3lN 40o tgt~ 9797.40 9625.40 135o08N 41,27W 9897,2It 9725.28 139.59N .42.91W 9997.22 9825'22 142.67N 44, 55W 10097. [8 9925~= 18 I65.44N 45.84W 10197.I5 10025.,15 147.27N 10297.[2 10t25,,,12 1~9.56N !_08'79.92 I0707.g2 162.90N 9830, TVO = 9827.57~; LATITUDE 10015=25 9843,25 130,94N 10077o18 990=5_'!_18 12B,20N 101'16ol~ 9944.13 126,,32N 10167.02 9995,02 12].ION 10314..32 ', 10142.32 log. 13N 10355.g8 10183.g8 104.18N 133.64 N lo. ,~ 5W 137.32 N 17~Ot~ 152.4g N 17.4~W 0,268 I54.5g N 17'~71~ 0.5~0~ 157.16 N 17.89W 0.267 172.16 N 18.87W ................................. DEPARTURE 134.o2 N 20.56W 0.641 132,22 N 21.40W 1.733 128.6~ N 22.3HW 1.068 0.703 13~ : 0.2~5 137.' O, 39,. 14 47.&IW .45o 154. 156 .~ ltl.. 139. 13'5 'o 134. 131o. 127. 113.77 N 23.6~ 4,333 112., _i0_~&7 8 t5'-, ,$,,'2_o! 10~SZ'.oe t o~ez -'V-ts' s '~.~ -~o~,'i'~;~"&~ "~.' i6'~-O-~X ~ 10550 9 30* S 26E 10543,69 10371.69 i0'76a ti 45' S ,36E 10751~92 1057g.g2 10790 Il 45' $ 36E :107"79,33 10607..33 0.603 0°520 63.' OoO00 . . . CLOSURE 4'0.2.6 N ['~ '!.7~' W i D I R E C T I O N AL S U R V E' ¥ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB SEA DEPTH .S(3CAL SOU ~3.A-8 GREAT LAND DIRECTIONAL DRILL ING 05 PAGE TANGEI~T i ,?:L ~0 OEPTH _ 372 ~72 672 TOTAL COOROINATES ~D-TVO SUB SEA LATITUDE DEPARTURE- DIFFERENCE · VERTICAL CORRECTION 272.00 [00.00 -1.~9S 0o89E 0 0 372.00 200.00 -1.09S 0.89E 0 0 ~72.00 300.00 LO.~7S 0.78E O 0 ~7~_.O0 400.00 -0.33S O.67E 0 0 672.00 500.00 O.O8N 0.53E 0 0 772 972 1072 ____L1_7_2 1272 1372 1572 ],672 ____17.72 1872 t _-.~.~_72 2172 2272 772.00 600.00 O,z~SN · 872.00 700.00 1.21N 972.00 800.00 2.08N [ 072. O0 gO0'. OO 2.60N [ [_~_~_e_0_.Q_ [.~00.OO 2.89N ],272;,00 ]. 1OO,,,00 2~96N [37.2.00 [200.00 2,g6N 141.~,_._00 ! 3g_o,. OD 3 ._ 2 aN 1572.00 l~,O0.O0 3.08N t672.O0 1500.00 1.44N ],__7. 7_ 2',~_0.0.. '~_0,.01. O0 ' 2,30S 1872.00 1700.00 -5.BBS 1972.00 1800.00 -8.53S 20.72_._g__0. lgoo.oo -t0.33S 2~z~.oo ~ooo'oo 2~zTz.oo ~zoo';oO .. , 12',71S . . 0.37E 0 0 O.,~oE 0 o OollE O 0 .: ~O. 05W ,O 0 -0,36W 0 0 -O.~6W 0 0 -o.~6~ ~ o -O.§OW 0 0 -0.55W 0 0 -o.g7w 0 0 ~2'53W 0 0 -~.02W 0 0 -5.03~ 0 0 · . '5o87W 0 0 -;6.,71W 0 ~ 0 '?'.'~OU 0 . o -8o20W O ~ 0 2.72 2572 2772 2872 3072 3172 2q72oao 2572,00 2772°00 2872°00 2300.00 "13.'72S 2**00.00 -13.4§5 2500.00 -I2.27S ~.~o-,,?s .............. -.~._..~fi__s: ...... :~oTz.oo z~oo.oo -7-ess 3172.00 3 00O.. oo j~.7.,'. 24$ .. , , ,, ~ .... JUN 2-5 I974 2600.00 2700.O0 tO.TrW O ~ 0 12.20w 0 "'" 0 -l~.gaw -16.08~ 0 ' 0 0 0 0 0 DIRECT INTERPOLATED VALUES FOR [aNAL EVEN 100 FEE S U R T OF V E SUB ¥ SEA DEPTH SOCAL SCU 43A-8 GREAT LANO DIRECTIaNAL . . _J~ASUREO DEPTH TVO SUB SEA . 3272 - 3~!~_.oo 31oo.oo DRILLING O5114/74 TOTAL COI3RD!NATES LATITUDE DEPART URE ND-TVD VERTICAL DIFFERENCE CCRRECT I0N -6.855 -19.23W 0 O TANGENT [AL METEC 3372 3372.00 3200.00 -5.83S -19.65W 3472 3472.00 3300.00 -4.59S -20.07W ___~.72 3572.00 3400.00 -3.32S -20.33W 0 0 0 ,~ 0 0 0 36'12 5672.00 3500.00 -2.~8S - 20'. 79~-~ 3772 3772.00 3600-00 -1.67S -20,DAW _ ~ P~_2 387_2.00 3700.00 '0-825 -20.72W 0 0 0 0 0 0 3972 3972.00 3800.00 4.072 4072.00 3900.00 .... 4 % ~ 2 4 Li~_2~9._0 ~__q_o.o .oo 4272 4272.00 4100-00 4372 4372'00 4200,,00 4572 4572.00 ~00.00 4672 4672.00 4500~00 4 77 Z 4._?.72_.._00 4600_~ 0 4872 4972 4972.00 4800.00 ~~,~Z ..... 5o~.~._0~ 49oo.oo 5172 5~72"00 5000.00 5272 5272.00 5100.00 5473 5472.00 5300.00 5573 5572.00 5400.00 O.02N -20.52W 0.86N -20.29W 1,.73N -20.18W 0 0 0 .... ~' 0 ],.gTN -20.LTW ['97N -20.'17W 2'59N -20.O9I~ Q 0 0 0 O 0 3,46N -20,O~,W 4o 39N -20,69W 5.08N -21-40W 6.0IN -22o14W 6.39N -2'2.65W 7,.6tN -23.2~N 8.25N -23,,66W 0 0 O O O O 0 0 0 0 0 0 i 0 ]. O 5500.00 57T3 5772.00 5600.00 5873 5872.00 5700.00 ..5L9_73_ 5_.9_71~_? 00__ 5 ~00. O0 6073 6072.00 5900.00 61 ? 3 61.72., O0 6000. O0 12.81N -2~.07W 14.53N ~23o79W 16~gIN -23°66w 19,..72N -26,36W 22~8.8N D I R E C T [ ON A L S U R V E Y INTERPOLATED VALUES FOR EVEN I00 FEET DF SUB SEA DEPTH MEASMREO 9274 9374 $OCAL SCU 43A--8 GREAT ,. LAND DIRECTIONAL DRILLING 05/14/74 TOTAL COORDINATES MD-TVD VERT TANGENTIAL TVD SUB SEA 9272.00 9100.00 9372°00 9200°00 LATITUDE DEPARTURE 115.23N -37.00W 119.15N -37,00W DIFFERENCE 2 CGRR _ 0 ec't ~ ~n 9474 9574 9674 9472.00 9300.00 9572.00 9aO0.O0 9672.00 9500,00 123.O8N -37.09W 126.83N -38.12W 130.4iN -39.75W q775 ___g~7~5 9975 10075 J.0.175 10275 10375 9772.00 9600.00 9__872°00 9700.00 9972.00 9800°00 10072.00 9900,00 LQ ! 7 ~,,_..O 0 ~ O O O.O t0272,00 10100,00 10372.00 10200.00 10575 10675 [O875 9875 t0075 1057;~'00 lo~oo.oo. 10672,00 10500'00 !~..772..,....g.0_ 10872°00 10700°00 9872,00. 9700.00 _g_.' 9_7_g_,...0..0 9~oo'.o0 10072°00 'q900.O0 134.12N -40.99W 138.4§N -42o50W ,3 141o89N -44.14W 144.74N '45.51W 146.81N -46o73W 148,98N ~47.98W i51o27N -49o25W 153o5&N -50.52W 155,85N -51,79W 162,:72N -55.60W 3 135,04N : -42o56W 132.18N '44.56W 128.43N -46.49W 10175 10376 10477 10600 [0783 10172,00 :10000o00 .1027.2,.00_,, !.O.lO0',O0 10372'00 lO2O'0oO0 10'472,0'0 iO300..O0 Lo ST.~_:.0__0_o. )0400,00 10672.00 10772.00 10600'00 ~22'7qN 102 o OON 88,00N 72,~'82N 57,07N 40:25N -48.32W -48,25W -44o91W -31°89W - >:'~':-d-s w 4 7 8 D [ R E C T I 0 N A L S U R V E Y [NTERP(]LATED VALUES FOR EVEN 100 FEET OF SUB SEA DEPTH .__~ASUR EI~ DEPTH 6~,73 6373 6473 .6.573 6673 6773 .SCICAL SCU q3A'-8 GREAT LANCI OIRECTIC1NAL ORiLLING TOTAL COOED[NATES NI3-TYD ¥[!RT if" ' L TVD SUB SEA LATZTUOE DEPARTURE DIFFERENCE 6272.00 &lO0oO0 26.8BN -26o4~H ! 0 6372,00 6200.00 30.90N -26.96W ~ 0 6472°0.0 6300.00 34o71N -27.'BSW ~ 0 6572.00 6400°00 38.60N -28-.14W ! 0 6672.00 6500.00 ~2,,5[N -28.49W I 0 . , 6772,,00 6600.00 46°~0N -29°02W ]. 0 6872.00 6700,,00 50o26N ~'29°76W '[ 0 6972.00 6800.00 53o52N -29,82H ! 0 7073 7~73 7279 7373 · _ 73,7.4 7574 . . 7072.00 6900.00 56°2~N -29.57W Y172~.0:0 7000',00 59.15N ~2golSW 1 0 7272°00 7100o00 62.~8N -29.51W I 0 · , . 7372.0'0 7200.00 65o60N ~30.XQW [ Q 7~72.00 7300.00 7572°00 7400.00 7[.03N -30o~8N 2 0 7674 7874 7672°00 7500'00 72,86N "30.65W 2 0 .7~,72,00 7600.00 74,94N -30.79W 2 0 7872°0r0 7700°00 76,80N -30°92W 2 0 797~ 8tTq 827q 847~ 8§74 ~77~ 7972°00 7800°00 78e85N -31o1~W 2 0 8172.00 8000.00 83°52N -32.2[W .2 0 82.72,0'0 8].00,00 85o99N =32°62W -2 O B47Z°OO 8300,00 90o3qN -33o67W. .2 0 8572°00 8qO0°00 92,42N ;-' 3/~ ° 34t~J 2 : _8.~.~.~.,, 00 8500,.00 94.4,~N -35,,1§W 2 O 8'772.00 8600,,00 97.5].N -3":;o83~ 2 --0' 887~ 9074 9174 8872.00 8700..00 100o97N 9072.00 8900°00 ],08°,39N 9[72,'00 9000°"00 ll'to, 53N IilKI O:R ~Q7A -36,2LW 2 0 '36o3g~1 2 0 -36°43W 2 0 o O [ R E C ~' [ 0 N A L S U R VE ¥ INTERPOLATED vALUES FOR EVEN I000 FEET OF MEASURED DEPTH PAGE 1 ~SUREO DEPTH SQCAL TVD SCU 4~A-8 GREAT LAND OlRECTIaNAL DRILL[NG--05/l~/T4 TQTAL COaRDINATES MD-TV~ ~/ERT ICAL SUB SEA LATITUDE DEPARTURE DJ FFERENCE C~,RR ECT I aN TANGENTIAL METHg 1.000 2000 999.97 1999o7~ ~27,97 2,32N OotOE 1827.74 -9,21S -5.28W 0 0 0 0 3000 5000 2999.60 3999.~SA 4999°50 2827.60 .~8.55S -16o43W __3827.54 0o26N ~20'.47W ~827o50 6o30N -22o35W 0 0 0 0 6000 .___.Y_Q.Q 0 8000 5999.~1. 6_9_9...8.,.... 69 7998,,36 5827.41 17,62N L23.66W 6826.69 54.33N -29.77W 7826.36 79,42N -31o21~ 0 0 ! 1 0 9000 __LO_O_O0 .tO000 8997.97 . . 8825.97 'LOSeSON ~-36°43W 98_2~_._'._..2__g _142,,,67N -44'~55'W 9825..:26 .~3!.~46N -45.07'W 2 '1 2 O 2 0 .......... . ........... JIIN ~ A ~OT, a D i R E C T I ON A L S U R V E Y INTERPDLATED VALUES FOR NON SURVEY PDINTS P~GE TANGENTIAL METHOD 'ME AS_UR E O SOCAL SCU .. GREAT LAND DIRECTIONAL TOTAL CODRDINATES DR[LL[NG 05/ HARKER OEPTH TVO SUB SEA LATITUDE DEPARTURE HI. 10353 ].0350,,10 101.78.].0 },.50.77N .H~ . L._O_5_O l~ d 498 ,, 05 10326.05 154,.16N '-50o85W T/H8 10527 /0524.0~ 10352,0~ 15~,,75N T/HIO 10646 106~3.00 lO~e? 1.00- 157.48N -52.69W B/HI.O 10729 '1.0725.97 I0553.q7 ].59.38N TO ,~0'/90 1078~,95 .106.14.95 160.o~77N ;'54.52td C ! ~ " .... · ' REV. 9.30-6? &. "S~se~me~t Repe~s" tn Duplicate ~ STATE'OF' A - ' - ' GA , -"' . ' %. Am OIL .AND- $ CONSERVATION?' "'"CO]M~tTTEE~ ' ' - ' ' ......... ' II I 11 6. LEASE DES/GNATION AND SERIA: SUN'I~Y NOTICES AND'REpORTS ON (DO not use this form for proposals to drill Or to deepen or plug'back ica diffierent reservoir. A-028996 Use "Ai~PLICATIOAI FOR.PERNIIT-'' for such " ' ' .... ' ~ 7. IF INDIA.N, ALLO'ri',:E OR TRIBE'. OIL OAS F-1 OT',ER , WELL WELL . 2. NAME OF OPERATOR ' ' - 8. UNIT, FA/~/i OR LEASE NA1VIE STANDARD OIL COMPANY OF CALIFORNIA, WOI Soldotna Creek 3. ADDRESS OF OPERATOR ' . " 9. IVELL NO. . P. O..Box 7-839 Anchorage,. Alaska. , 99510. 43-8 & 43A-8 Ats~face 2150' N & 515'W of ST corner Sec. 8, T7N, SWanson River R9W, SB&M u. sec.. W., R.. ~., (BOTTO~ HOL~ OBJECTIVE) Sec 8~T7N, R9W, SBaM . ! 172 ' KB 74-13 ~' Check Apprepria~e Box To 'l~ndicate 'N~ture of N~fice, Re ~ort, er Other 'Data NOTICE OF INTENTION TO : TEST WATER SHUT-OFF II PULL OR ALTER CASING I.___~I F~ACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE J J ABANDONe REPAIR %','ELL ~_J CHANGE PLANS ~ Other) 8UB~IEQUEN'T REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASINO S~[OOTING Oil ACIDIZINO ABANDONMEN'Ts (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR CbMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. (Proposed changes verbally approved by Mr. H. H~ton on April 16, 1974) Status: Unable to recover existing tubing from below 10571' per Step #5 of original proposal. Propose abandoning well from this depth and redrilling to new bottom hole ~ocation about 100 feet away from existing well b~re. Revised Program: Following step 95 of original proposal - --=,--'m.. ' - '. 1. Equalize cement plag from 10571 '-to 10130'. Downsqueeze~ leaving top of cement above 10296'. 2. Locate top of cement. If cement is below 10296', recement. Pressure test casing to 3000~pSi. 3. Mill 40' Window .in 7'! casing from 9830-9870'. 4. Plug .windOw and 7" casing with densified cement. 5. Drillo~t cement .to bel0w..:~Qp of window. 6. Redri.ll well through Window on a ~70© East course to a total depth of 10770' TVD. Total deviation to be at least 100 feet. 7. Return to step ~13 of original program. 16. I hereby certify that-the fore$oing is tru?~and 9osreet DATE /~ /74 (This space for State office use) CO~VZT~O~S OF ~rAo~x,, See l~nstrucfions On Reverse Side ~v...ed op,~' -- ~ALASKA ST. TBMn' :mT DU'PL,C~'rs ~z, 9-~-~, STATE OF ~. AP! N~EmC~d~ bODE OIL AND GAS CONSERVATION COMMITTEE 50-133-10121-10 J .... ,, MONTHLY REPORT O'F 'DRILLING 6. L~,SE DES:G.^~ON A.','O S~, AND WORKOVER OPERATIONS A..028~ ....... WI~LL W~LL Standa~rd 0il Co~~ of Califomnia~ W0I SOldo%na Creek ~r-~'G~OL _~ DRAFT P. 0. Box 7-839, ~ho=a~e, Alaska ~ S~ ~3A-8 ~ ...... 21~0' No~ ~a ~1~' Wes% of ~ Comnem of Section 8~ Swanson Rive= CON~R: O~~ , , SEC 8; T-4N, R-~ 7~-13 , 13, REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGES IN HOLE SIZE, CASING A/ND CEbIF2~TING JOBS INCLUDING DEPTH SET AN~ VOLU1VfES USED, PF_.H~OHATIONS, TESTS AND PLESULTS, FISHING JOB/~. JUNK IN HOI~E AND SIDE-TH~CKED HOLE ~ND A2JY O7'I-IER SIGNIFICANT CI-IAN~ES IN HOLE CONDITIONS. MARCH, 1974 Commenced work March 16, 197~. Install Class 111 BOPE. ~Fish and recover production tubing to 10485' leaving 153' of tubing fish in hole 10485 '~ 10638' APRIL, 1974 Milled up and or recivered production tubing fish to 10571' leaving 67' tubing fikh in well from 10571 - 10638'. Bridged well with 169 sacks of / Class "G" cement in two stages from 10571' to 9966'. Located holes in 7" casing at 6000', 5772', 5670', and 5550'.' Squeezed holes at 6007' w/83 sacks Class "G" cement, pressure tested ok under 3000 psi. S~eezed holes at 5772' with 133 sacks Class "G" cement. Squeezed holes at 5670' with 133 sacks Class "G" cement~. Press tested holes 5550 and 5670 ok under 2500 ~psi DOC and .C.0..to ~049'. Pressure tested all holes in 7" casing / ok ~n.der 2500 psm. Mzlled window in 7" casing 9827' - 9870'. Bridged hole wzth 119 sacks class "G" cement from 99~8' - 9516' x DOC to 9832'. Directionally redrilled 6" hole from 9832' to 10230'. ~ 9 I974 sre~ R.,. ,M' McKinley~,~/~ A=~ea..E~-qineer/''- n.~ 5~¢ ~ i :- NOTE--~eport on t~is form is required for e~ch calendar mo~th, regardless of the status of operatio.% an¢ must ~ file~ i, duplicate with t~e Division of Mi.es & Mi.erals by the 15t~ of me succeedi.g mo.th, u.less othe~ise directe¢. Form P--3 REV. 9-3O-67 .. ~ & ;~So]~e~ment Reports".in -Duplicate ,STATE OF ALASKA OIL AND, -GAS CONSERVATION', ,C0'MMI~EE SUNDRY NOTICES AND REPORTS ON .WELLS (Do not use this form for proposals %o drill or lo deepen or Plug back to a dif£ierent reservoir, Use "APPLICATION FOR PEI{blIT~-'' for such proposals.) , . _ .; , 1, , , ,.. '1. 01L [] OAS [--] WELL WELL OTHER . 2. NAME OF OPERATOR Standard Oil Company of California, WOI s. ADD,SS OF OP~ATOR P. O. BOX 7-839, 4. LOCATION. O,F WELL Anchorage, Alaska 99510 At surface 2150' North and 515' West of SW Corner of Section 8, T-7-N, R-9-W, SB&M 13. ELEVATIONS (Show whether DF, RT, OR; etc. 172 ' KB 5. AP1 NU1ViF_,R/C~ CODE 50-133-10121-0~ 6. LEASE. DESIGNA~ON AND SERIAL NO. A-028996 7. IF INDIAN, ALLOTTEE OR TRIBE NAM. E 8. UNIT, FAI~NI OR LEASE NAME Soldotna Creek Unit 9. WELL NO. SCU 43A-8 10. FIEI3) A~ID POOL, OR WILDCAT Swanson River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T 7N, R 9W, 12. PER1VIIT NO. 74.~13 Check Appropriate Box T° i,nd?ate Nmture of N~ti'ce, Re tort, or Other Data SB&M NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I t PULL OR ALTER CASINO FRACTURE TREAT j j MULTIPLE COMPLETE SHOOT OR ACIDIZE ]__[ ABANDONs REPAIR lA'ELL CHANGE PLANS (Other) .~. SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL ~ FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZlNO ABANDONMENT* (Other) Splld NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 15. DESCRIBE I'nOPOSED OR Cb.%fPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work ..... [. Commenced drilling operations on SCU 43A-8 at 2:00 p.m., March 16, 1974. I ~---ib'~AFTI ___ FILE: .... --- (Thl~ space foil Sta~e office u~e) correct APPROVED BY CONDITIONS OF APPROVAL, IF AN~: TITLE Area Supervisor DATE 3/20/74 TITLE DATE See 1,nstrucfions On Reverse Side Approved .,op~' Returned February 26, -1974 Re: Sotdotna Creek Unit 43A~ Standard OII Co. of Cai I f., Ope~tor Permit No. 74-t3 Nr. J. '~. Walker Standard OIi Coapany of Cal lfornla P. O. Box 7t~839 A~:'horage, A I aska 99510 Dear Sir: Enclosed Is the approved a~ltcatton for pera.lt to drtlt lithe above ~ferenc~ wel I, on or about t4arch i, t974, at a lOCation In Sect!~ 8, Tovnshtp 7N, Range 9W, S.M. I~el I saaptes, core chfps and a mad l~ aM ~ot ~ul~. A dlr~imt survey Is required. Many r I vets I n A l aska and the I r drat ~ ~st~a~s ~have ~ cl ass t fled as [mpor~a'nt for the spawning or algratl~ of ana~~s flsh, operat{onS these areas are s'ubJact to AS t6.05,870 and ti~e reejulatl.~ under (TI?la 5, Alaska Ad~lnlstretl~ ~). ~ler ~-~i~ operatl~s yOU may be contacted by the Habl-~,a~ Coordinator's offl.m, ~~-of FiS~h and Game. Poi lutlon of any waters of the State is prohlblte~ by AS 46, Chapter 03, ~icie 7 ~d ~e ~ulatl~ p~t~t~ t~~ (Title t8, Alas~ ~tnls~ttve ~e, Chapter 70) ~d by the Fe~l ~ter ~llufl~ ~rol Act, ~ ~, ~a~t of Envlro~ta I ~~t I~. In ~he event of suspenstcm, or aband~ pte~se give this office advance notification so that ~a may have a ~i~sS preslmf. Very truly yours, Thoaas R. Marshal I, Jr. Emut I va Alas-~ OII and Eno t o~ure Cc: Department of Fish and 6aae, Hablfat Section ~/e enc. 1. Department of Environaental Conservaf'ion ~/o anti, DISCUSSION PROPOSED SIDETRACK OF SCU 43-8 SCU 43A-8 PROPOSAL: .. . R~drill SCU 43-'8 through the Hemlock Zone and recomplete in the It8 through 1110 sands. The H1-5 sands are produced at downstructure wells and will not be perforated in the sidetrack. · .. 11ISTORY: upper .half of the H8'sand. SCU 43-8 was completed in 1961 in the H1-8 sands with an initial producing rate of 585 BOPD and 6 BWPD. Cumulative oil production is 1,722,000 STB. Currently, the well is shut-in because of its uncontrollable high GOR of over 30,000 CFB and sand and rock production. . . Gas injection was initiated in 1962 at upstructure well SCU 312-9. By 1966, gas breakthrough had occurred at SCU 43-8. The well Was shut-in early in 1967 with a "high" GOR of 3400 CFB. In September, 1967, a workover was performed to install packers to isolate the high GOR zones and to perforate the upper portion of the HiO sand for production. After the workover, the :111-5 sands were excluded and the H8-10 sands produced. The GOR increased from about 800 SFB to 6500 CFB during the next two year period. In October, 1969, the H$ sand .was shut-in and the H9-10 .q~nds to .about 1000 CFB. In D~cember, 1969, the H1-5 sands were produced with the H9-10 sands. The GOR immediately increased to over 6000 CFB. When the H1-5 sands were supposedly shut-in a short time later, the GOR never decreased to the previous value. Since this time in early 1970, the well has produced large quantities of sand an'd rocks. This, plus the GOR history, indicates the tubing is probably damaged and the H1-5 sands are communicating in the well bore with th.e H8-Ht0 sands. Therefore, the current high GOR of SCU 43-8 is probably representative of the H1-5 sands and not the H8-10 sands. . RESERVOIR AND GEoLoGY_: ~ .. '..'~2s..s. ho.~m.on the attached map, SCU 43-8 is the only Well in the fault block s6dth. :o f :..Faul t "."B~' ~Com~eted for production 'in the tt10~'s'and. It is' ais6' ti~.c °nly well in the fault-block which produces a full H8 sand. SCU 14-9 is the only..other-H8 producer in the fault block and it is completed in only the .. .-. SCU 43-8 is completed only in the upper portion of the HiO sand. However, .it.is structurally at the same elevanion, in the H10 sand as SCU 323-9. SCU 323-9 has produced oil from the interval equivalent to 10,663' - 10,690' in. SCU 43-8. This interval is not perforated in SCU 43-8. Log evaluation of this interval indicates it may be oil productive. Formation tests of thc middle and lower portions of the HiO sand will be made if the open-hole logs ~n:ttie redriil indicate a p°ssibility °f °i! pr°ducti°~ ~ ~ ~ ~ IVj ~ ~.. _ . D.~ scu~s ion ~ Proposed Sidetrack. of SCU 43-8 SCU 43A-8 o. Volumetric calculations of the incremental sweep pattern to SCU 43A-8 indicate; 669,000 barrels of oil will be recovered by sidetracking SCU 43-8. This recovery is based on the oil r.~maining in the IlS, Hg, .and upper H10 sands. If the middle section of the.H10 is oil productive, t]L%s will add 382,000 barrels of reserves. The past production history Of scu 43-8 indicates both the' H8 and H9-10 sands have had gas k, .... ~t ....... u~h. The ~-. s of these sands are probably m~ch lower than the current high GOR of 30,.000 CFB because of well-bore communication with the H1-5 interval. Generally, if a high GOP, zone is produced with a low GOR zone, the high GOR zone completly dominates the production characteristics of the well. Also, if portions of the P, 8 sand are high GO~, these can be excluded in the sidetrack since it will be perforated so packers can be installed. It is not possible to set any packers within the H8 sand in SCU 43-8 because of the way it was originally perforated. -. - ...... ... ALTEP~NAT IVES: : - Two alternatives to sidetracking have been considered: · . ... · . 1. Remedial job to pull and rerun packers and formation test the / · HiO sand. _ ..,. ~ ~ ~...~.. ., · 2. 'Redrill the well to an upstructure pcsiti0n to obtain a full H10 sand. · .. · . . The sidetrack is favored-over the remedial job because it will be possible to perforate the well so that packers can be installed to control GOR. Also, by running a good set of open hole logs, data on the current oil- water contact within the H10 sand can be obtained. This will be valuable- in evaluating other development locations in the H10 sand in this fault .~lock. . ' " - The sidetrack is favpred over the upstructure redril! because the gain . -.' ;~.! ~ .i~- structure .may .not. be .su£ficient .to~. g~t above '.the 'water,. es~ecia llv ~-" .' if there has been encroacbm~ent. At the s~me time, a' redrill upstrucnure would put the well closer to the gas injector in the H8 - upper H10 sands, thus increasing the'possibility that these main objectives will be at a higher 'GOR. Volumetric calculations indicate very little addi- tional oil can be recovered by completing with a full til0 sand section at an upstructure location. However,.if the middle of the H10 sand is good in the sidetrack, reserves of the well will be increased significantly. RISKS: The two main risks of sidetracking SCU 43-8 are 1) the new well will be at higher GOR ~han anticipated, and 2) the aquifer has encroached into the reservoir past the well. Discussion Proposed Sidetrack of SCU 43-8 $CU 43A-8 -3- -The HS-H10 sands are the objective zones for this well, and the produc- tion history indicates n~ost of the current gas production is from the H1-5 sands. The H1-5 sands ~ilt not ba perforated in the sidetrack. Packers will be run in SCU 43A,8 to segregate the various members of the H8-H10 sands so that high GOR production' from any member can be shut-in. The estimated initial producing rate, 1000 BOPD with a GOR of 5300 CFB, has taken into account the probability that some zones will prc~uce some gas.' · TO minimize the risk of water encroackment, the reserve estimate includes only oil to be recovered from the H8, H9, and upper H10 sands. PROPOSAL FOP, WELL 0PEF=ATIONS - PRO 316-1 REDRILL PROGRAM FIELD: Swanson River PROPERTY AND %~LL NO: Soldotna Creek Unit 43-8 CASING: 20" cemented at 30' ' ii 3/4" ce~mented at 20?3' '' ?" cemented at 10,886' as follows: SURFACE LOCATION: 2150' North and 515' West of SW corner of Section 8; T-7-N,~ R-9-W, SB&M . . · ~Tg.J~ DEPTH: 10,886' . PLUGS: 10,886'-10,838' . : · · . · Top Next Next Next Next Bottom 0' - 294' 294' - 1,143' 1,143' - 4,811' 4,811' - 6,651' 6,651' - 8,465' 8,465' - 10,886' 7" 29# N-80 BT , , , '7", 26~, N-80, BT .7", 23#, N-80, BT 7", 26~, N-80, BT 7" 29= · ~, N-80, BT 7", 29#, P-110, L8R PERORATIONS: · Five 1/2" holes at 5550', 5670', and 5772' (all s~ueezed) -- ~/~ .... ~s/~. ~o~o-~uu ~d 6007-6010 (~ii squ~z~u; Five 1/2" holes at 10346' (WSO) ~our 1/2" holes/ft. 10350-10362 , 10384-10419', 10423-10461', .10466-10498 ' 10510-10520' 10524-10590 ' 10598-10608' and 1'0632-10657 ' . . '~'-~'" .... JUNK: No ju~k reported. TUBING DETAIL: Per attached detail dated December 17, 1968. ."FRESENT ~CHA~NICAL CONDITION: Damaged or collapsed tubing or casing is · -sUspected throughout the perforated interval because of well's history · '~0f rock and sand production~ ....... -- · .BLOWOUT PREVENTION CONSIDE~hTIONS: 1. Potential Problems: A. Gas __ Gas may be encountered after packers are released, while cleaning out-the 7" casing prior to akandonment and while redrilling. Gas entries into ti~e ~ud column can cause serious problems. Care must be exercised at all times not to swab the well during trips or when pulling production equipment. Gas entries Would most likely occur when working within the Hemlock Zone. Formation press, ute in thc Hc~mlock is approxi- mately 4700 psi. Programmed mud weight of 82 pcf will over- · · B. Water Entries' Extreme caution must be exercised while redrilling this well .,-- , : for high pressure water entries. The top portion of the '.'.' ~ ~ interval to be redrilled has recently been drilled in t4A-33 ~ '-' "' ~., and 23A-3 with 82 pcf mud with~ no problems. A formation test · - ~ i Of this interval in 23A-3 indi'cated a maximum pressure of ,5500 psi. 'fha ~est was made using 82 pcf mud with no problems. · ,.... .- R~e programmed mud weight of 80-82 pcf will overbalance this ..~· .-~.-.. pressure by 350-500 psi. M~d weights of 93~96 pcf are required ....... ~:.. .. ": ' to overbalance the intervals above the kickoff point, Caution should be exercised during the milling operations for oossible water entry f~om b~hind the casing from these higher pressure intervals. C. Lost Circulation: ' - The programmed mud weigh~ of 80-82 pcf' is the lowest which can .be used in the well and yet maintain adequate overbalances of the intervals immediately above the Hemlock. However, because .. .of the lower fo~-mation pressure in the Hemlock zone, lost cir- ''' '" ' ~ culation could occur. Lost circulation materials should be at a-l~ .~1 I ~-' - - · .,&,,.~., w~v,-~..~.~..~.~.t~- - . :'.'-,: ~-.. . . D. Precautions: ..~' Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods and care should be exercised at all times by every member of the crew. The · hole must be kept full at all times. - · 2. Maximum Anticipated Formation Pressure: 4700 psi in Hemlock. - 550. psi in "G" zone. · · 3' Maximum Possible Surface Pressure: 3900 psi.' .. ... , . ,' :....., ...'_ --.,'}, · . : 7.', , -. 4, Blowout Prevention A. As per "Operating Instructions D-17." B. Class III, 10" - 5000 psig for all work. DATU>f: Take all measurements from a point 14.5' above ground level, Original KB of SCU 43-8. PROGRAM · . ~ote: ~.: Mandrels at 10,262', 10,476' and 10,568' are open· Tubing and casing may be damaged, and tubing may be plugged with asphalt or sand. 1. Move in drilling rig and m~x 80-82 ~cf mud. ... 2~ Kill well by displacing 80-82 pcf mud down the tubing, out the ~2~ Mandrel at 10.,262' and up the annulus. Install Cosasco plug in ~e donut. Remove xmas tree. · 3. Install 10~' - 5000 psi BOPE, including. 5000 psi blow and kill lines. Pressure test according to Operating Instructions D--i~ Remove Cosasco ~lug. °' 4. Release hvdraui~c packers. Pull tubing and production equipment. .Ex,_mine the tubing closely for signs of damage. Note depth of damaged tubing. 5. Clean out 7" casing to the top of the Baker Model "F" packer at 10,592'. Mill and recover Baker Model "F" packer at 10,592'. Clean out to below the bottom perforation at 10,657'. '-~""~ ~' '10,190'. Downsqueeze 100 linear feet of cement . '7. Kun bit an'd locate top of-cement plug. If plug is below 10,296'' recement. Division of Oil and Gas and USGS to witness the location and hardness of the finaI"plug. Condition mud to 80-82 pcf. -".',:" '~ . -- ..- ..... ~ ...... ~. .--.--.-- : - ..~-: ..... 6. 'Equalize cement plug in stages, if necessary, from effective depth to 8. Pressure test the 7" casing to 3000 psi for 15 minutes. 9... ~ window~ in-thee 7",_~#, P-110 casing from 10,220' to ~10,260'. Casing collars are located at 10,188', 10,231', 10,243' and 10,283', DIL depth. ~..~ ' Note: ContinUally'monitor the mud.system for possible high ' ~ ~ pressure f]~uid entry during milling and redril!ing operatien~. Be prepared to shut the well in and raise the mud weight. 10. Plug the 40' window and 7" casing with densified Class "G" cement (126-129 pcf). Top of plug to be 150'+ above top of window. Downsqueeze leaving top of plug above top of window. 11, Drill out cement plug to 2' belo~ top of window. 'C i2. Sidetrack original hole and directiona~!y drill a 6" hole in a northerly direction to the equivalent of 10,770' MD in SCU 43-8. Directional details will be furnished. 13. Condition hole for logs. 'Obtain 1/2 gallon sample of drilling mud before pulling out of hole. k 14. Run Schlumberger Dual Induction Laterolo9 with SP, Microlog and BHC Sonic I.~g with SP' from total dept;.h to 5'" casing. · · A. Use linear scale for 2" DIL and logarithmic scale for 5" DIL. ., . B. Use + 10 ~.~; SP scale and 0-50 ohm-meters for the linear DIL. C. Compensated Neutron Log and Compensated Density Log will be ,: · ._ .. considered as a tectu'~ique for locating gas saturated intervals. 1·5. Ce:ment approximately 750' of 5" liner at total depth with sufficient class "G" cement pr~"'~xe '~d ~i~-3_-4%-CFR-'-2 to obtain returns above top of liner. Eq,2ip liner with 5" x 7", 29~) Burns liner hanger grooved .for cementing. Allow for 200' of liner lap. ... ' A. Run float collar and float shoe. Float collar to be one joint above shoe. -- -. B Use slow displacement method with densified cement. Do not · .: use centralizers, but. use solid cementers in lap area. · .- · ~..,' C. Liner detail: " · "'"' - - Bottom 550' 5", 18#, N-80 Extreme Line Ca~ing Next 1' Crossover Extreme Line by LT&C Top 199' 5", 15#, N-80 LT&C, Special Clearance Couplings . Total ~ (In Lap) .. . 16. ~__ ~-.. ........... ..... ,_.~,,, .-..~,e~ ~ 'fl~t c~,- .......... - . · ~?. Run Variable Density Cement Bond Neutron-Collar Log .from effective -. '' · depth, to above the top of the 5" liner hanger. -'.~-- '" " 18. Pressure test the 7"..casing, 5" liner and 7" X 5" liner lap to .3000. psi. .. 19. Run formation tests of lower Hemlock 10 sand if indicated by logs. ;. .... '.. Test details will follow. "- - 20.' Jet perforate selected Hemlock 8 and 10 sand intervals for production. . · , , -., , .- ; ,. -. . : ~ -. . .: .' , .:., ~ ,," ' . ' ,,, ,' , :; .,,: -. .... '::' i-"..: ', ._'21'o: Run'~an'~efi~ caJing S'cr'aper~ 'a.~d sdg~pe the' t~al liner. .. .22. Run and hyd~otest to 5000 psi approximately 10,730' of 2 7/8" x 2 3/8" tubing, gas lift mandrels and completion jewelry. A 'detailed completion program will follow after T.D. logs have been run. . -. 23. Remove BOPE and install xmas tree. Pressure test tree to 5000 psi. Displace drilling fluid down annulus and up the tubing with lease crude oil. . 24. Set the production packe~s and release rig. place well on production as indicated on production progra~ which will follow. · ~. B'. BERGET DRILLI~'~,~,_~ FLOID PROGPe%/4 SIDETRACK SCU 43-8 S~[ANSON RIVER FIELD BADIC DRILLING FLUID~ SYJTEM Weight - ~cf · ' Viscosity - sec/qt., API Fluid Loss - cc, API Plastic viscosity - CPS Yield point - Lb/100 ft2 Gel - Lb/100 ft2 - 10 min Calcium~- PPM Solids content - % Vol ....... Diesel content - % Vol .RF24ARKS - 80 - 82 43 - 47 4- 7 10 - 14 8 - 12 0- 5 .9.5 50 max. 6 - 10 6- 8 1- Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 2. Maintain adequate, supply of barite and LCM on location. '3. During milling and redrilling operations continually monitor "(on 24-hour basis) mud system for evidence of high pressure water entry BE PREPARED 5~D SHUT WUELL IN /kND RAISE ~EIGHT. . -.... "'.' r -~ · '. ' -: ' .'~ ,.-"..'. "'' .['" ' ' ' . ' ' J I 10600 10400 ' 10500 o ,--t 10800 'l'! ::;":i'-'"" - t' "'' "' "' ..-' ~Proposed4o,' -: t't' ,' ' '- /Win~ow in 7" cs~. . ",'',: · - ..'.- ' '",..".'. · ... .' .... ' . .~ ~ ..... j .'". ".'/' ."' · .' ' '- [ .-.' ' - '~ ~.-". : .... ' ' ' - . .' .':: -.~:,-'..: . -'-,... ', ;. ~-:'._~ t .- ~.. -.. . .. f ~;-'~,~ , . .. ~ '-'~ *X ~ "' ..... ,-: ~Lt_-;~ ~- ~ .... I .- [~_ :~ 1 '"" 5" . . ! ~..; . . ' . . ~ :.:, .~ - . .~:..~ _..~-.. ~ '.,- . . ~- . ' _ ., -'..- ; .-.' ..'... . . . .' ~ .... , , . ; . . . _ - ...'~;. ~ .... . . . . . - . ~- ,, ~ . Possible .... , .. .. ,.. - _. 770~TD .. Proposed Redrlll , -. · Liner Detail: -- ''' [; ~ '~ ~-~ . . ton 550', 5'~ 18#, N-80 Extreme line ' ' ~ext'l' Crossover extre~ue ].tne X LT & C · ' o . · · . .. - . - · . . .. · . .. SCU 43-8 E LOG StiOWINC POSED P~';DRILL ;2L~) POSSIBLE 'PRODUCTION INTERVAL SWanson ltivar Field i '. ..... ~?~,,'~ ~.lif ~I ' ' g~~' 4I'. Jt~. MANDREL'2~- EUE TUBING · - ~ -- 36 Jt-s. 2*]fi". EUE TUBING 1129, -- 2,454.64--~ CAMCO MM MANDREL '."~" -- 2,467.69-- . . ' . ~'. ' ~ -- 30 Jts.'2'~~ EUE'TUBING 935.55' , · .. . .- -. --' 3,403.24__ -- CAMCO MM HANDREL : ' 13.05' ": ' ~' ' .... 3,416,29~] .... . _-.'~~' __" 24 Jts. 2~' 'EUE TUBING 750.97~ , . __ 4,167.26.1__ CAMCO MM MANDRZL (w.cev.} 13.00~' - ... - ~., 4~80'. 26-- · ...: .' {'~ .. ~ -- s~¢~. . ~ . .,.~?t .. .. -' ,:,.. .~. _ -'- ~ ' ~ ~ ~. ~V 'Eu~ ~u~ ~o~.~6' - ' ~- 10,261 72- . · ~', . ~ Z0,2.74,70- -?'-~-, . : ' '~2 i Jt 2~' EUE TUBING 31 83' ,-:- .'. ~ = · ,- -- -- 10,306.5~ '- -- BAKER FH PACKER 6.60' · ., . -- 10,313.13--__ 1 Jt. 2~" EUE TUBING 31.~0~ · . : ,. __ lo,344.2~ OTIS "S" NIPPLE POSITION~4 1.54' -*-- ' ' ~ 10D45 7~-- ' ;.- · .... ~- - ~ · . .~ : .'.... . . : . . .... ' '" . ~ ;82' ~' . '." ' ,,: .. .~ I~" .. -. -. ..-- .... ": ~':, .i -, : ;' 3 ~s. 2~" E~ TUBZNG 95.03' N Jt ' '10,444 ' :.:.--~...~._.. :... ....... 10,440.54_ ~.?:,..:.x.::-<~.': .. :--:~ .. ,' BROWN EkPANSI0 3 74' : !I :~. ~' PUP J~. 2 ~' EUE TUBI,,C . 1n 06' 10,~ 99.34 ,, - . ~1 -- ' ~ BEO~J RS 16-1 PAC~=R . 6 03' 5- - , - , · :t~ !!~,~ ~qso~.~, ~ ~ .....:..~- "' · : - :..'~ Jc 2~' ~US TU~ZhO' , .. 30.2~' ~ ,-:- -- ~.~. o~-- · · ,, ,, ' ~ ~ c · ,:,,: -~,~-.~__ . ..... "' '"' ' ~: Il: /' ' . , -,.. · ~'~ t!~ ' . ~ . - Jc '2'~J' ' EU~ TUS~G ~O.O7' .:---:..,-- '~>,?z,~ ~!!~' ~o<.. ~ ~- ~A~z szoe su~ .' .s~'"~' ~: Jt 27o EUE TUoI,,G ~u U~ 10,627.62 PUP · ~ ~ 3 '~ ' .%~ 1~ ~ 1~6o8.38J ' WENTURI SHO~ , ' , " ~- ... ~, ..... ..... .:. I!.- .' ,'..,...' _:;.... -' I · ,1~: .... ": ',',. ~ ' ~~t.,.,~. '~:~, ~, ,:~ ~::~:~.r.-:.::---::::::::::::::::::::::::::: - -- ~:': o .. · · . · 't x, l ,5, 0 (./Z.2~ ~' GM ,0 12 *-30C0 ~ CLASS ~ BOPE /i 't .... ] ~ KENA! ': , r- '-, t ' ' __ , . SRU · ..... "~-.' i~'-~?~ - ' ~ ' ~ s ~ ~' ' ~" ' :" '" · .:r/'-'-~ · ~ ~ ~ '.-~". ~ -X ~ '- ~ .'- " " ' '" ~ ....- .......... '~" ~ - I ~ ' ' ~ Iq. "" ..... ' '"" i:L '" -'"" '*" ' . .- '; K ~t ~, ?, . ~::. ~.7N. R. gW. - i ~ ~ ~ .. ~ ~ .. ~ .... -.'. .. ' ' -, · ' FI - - ..... ~ ~ ·. .~ : . . '.'.- .' :.... ~34 ' · .,- ~ '. e .. · ,' ..; ..... ':.' ....... ~ -. - : - . .. ~- ., /~, .., ., ,::.i. .-.- .......... ,, ..,... " ~'~'"~ ' ~[~ i . . e''~ - ~'1 S.C U qB-g EOCATICN ( : · · . ij .~,. ~- .... :..:i. PROPOS=D.. REDRILL ~, ~ ' .......... "'":'"~ .... '~' ': " L.~.:'~'~ ..... SECTIO~ 8 T. 7 ~. F~ S V/ " t j':~ ezt ~ ~, S~:.'~hSO~; ;::iVEq F.Ei,3 - . : ] S~'A~DLa::'OIL COS%~iT OF C,,UFOR:~..~ t-~ ,:c v:.?~..d 5~z / ' :-:"'" ' :' ;:', ' ' (-'.1 · , · ,a't. 1-15-74 DISCUSSION PROPOSED SIDETRACK OF SCU 43-8 $CU 43A-8 PROPOSAL: Redrill SCU 43-8 through the Hemlock Zone and recomplete in the H8 through HIO sands. %"ne H1-5 sands are produced at downstructure wells and will not be perforated in the sidetrack. HISTORY: $CU 43-8 was completed in 1961 in the H1-8 sands with an initial producing rate of 585 BOPD and 6 BWPD. Cumulative oil production is 1,722,000 STB. · Currently, the well is shut-in because of its uncontrollable high GOR of over 30,000 CFB and sand and rock production. . Gas injection was initiated in 1962 at upstructure well SCU 312-9. By 1966, gas breakthrough had occurred at SCU 43-8. The well was shut-in early in 1967 with a "high" GOR of 3400 CFB. In September, 1967, a workover was performed to install packers to isolate the high GOR zones and to perforate the upper portion of the H10 sand for production. After the workover, the -.H1-5 sands were excluded and the H8-10 sands produced. The GOR increased from about 800 SFB to 6500 CFB during the next two year period. In October, 1969, the H8 sand was shut-in and the H9-10 sands produced.. The GOR dropped to .about 1000 CFB. In December, I969, the H1-5 sands were produced with tile H9-10 sandS. The GOR immediately increased to over 6000 CFB. When the H1-5 sands were suppoSedly shut-in a short time later, the GOR never decreased to the previous value. Since this time in early 1970, the well has produced large quantities of sand an'd rocks. This, plus the GOR history, indicates the tubing is probably damaged and the H1-5 sands are communicating in the well bore with the H8-H10 sands. Therefore, the current high GOR of SCU 43-8 is probably representative of the H1-5 Sands and not the H8-10 sands. RESERVOIR AND GEOLOGY: As sho~a on the attached map, $CU 43-8 is the only well in the fault block south of Fault "B" completed for production in the H10 sand. It is also the only well in the fault, block which produces a full H8 sand. SCU 14-9 is the only other H8 producer in the fault block and it is completed in only the upper half of the H8'sand. . -. sCu 43-8 is completed only in the upper portion of the HIO sand. However, it is structurally at the same elevation in the H10 sand as SCU 323-9. $CU 323-9 has produced oil from the interval equivalent to 10,663' - 10,690' in SCU 43-8. This interval is not perforated in SCU 43-8. Log evaluation of this interval indicates it may be oil productive. Formation tests of the .middle and lower portions of the HiO sand will be made if the open-hole logs in the redrill indicate a possibility of oil production. ~ ~ ~ ~ ~r'~= I!~'l~ f E [5 -/, I 74 -- Discussion Proposed Sidetrack of SCU 43-8 SCU 43A-8 ' · / --2-- Volumetric calculations of the incremental sweep pattern to SCU 43A-8 indicate 669,000 barrels of oil will be recovered by sidetracking $CU 43-8. This recovery is based on the oil remaining in the H8, H9, and upper H10 sands. If the middle section of the H10 is oil productive, this will add 382,000 barrels of reserves. - The past production history of SCU 43-8 indicates both the H8 and H9-10 · sands have had gas breakthrough. The GOR's of these sands are probably much lower than the current high GOR of 30,000 CFB because of well-bore ~- communication with the H1-5 interval. Generally, if a high GOR zone is produced with a low GOR zone, the high GOR zone completly dominates the production characteristics of the well. Also, if portions of the H8 sand are high GO~, these can be excluded in the sidetrack since it will be perforated so packers can be installed. It is not possible to set any packers within the H8 sand in SCU 43-8 because of the way it · Two alternatives to sidetracking have been considered: ..... '"' 1. Remedial job to pull and return packers and formation test the .' Hi0 sand. . - .- - . ......-,,:..~.-!-'~'" 2. Redrill the well to an upstructure positiOn to obtain a full H10 - sand .... ..- .~ . . The sidetrack is favored-over the remedial job because it will be possible to perforate the well so that packers can be installed to control GOR. Also, by running a good set of open hole logs, data on the current oil- water contact within the H10 sand can be obtained. This will be valuable in evaluating other development locations in the H10 sand in this fault .~lock. The sidetrack is favpred over the upstructure redrill because the gain in structure may not be sufficient to get above the water, especially if there has been encroachment. At the same time, a redrill upstructure. Would put the well closer to the gas injector in the H8 - upper H10 sands, thus increasing the possibility that these main objectives will be at a higher GOR. Volumetric calculations indicate very little addi- tional oil can be recovered by completing with a full H10 sand section at an upstructure location. However, if the middle of the H10 sand is good in the sidetrack, reserves of the well will be increased significantly. RISKS: The two main risks of sidetracking SCU 43-8 are 1) the new well will be at higher GOR than anticipated, and 2) the aquifer has encroached into the reservoir past the well. Discussion Proposed Sidetrack of SCU 43-8 SCU 43A-8 -3- The H8-H10 sands are the objective zones for this well, and the produc- tiOn history indicates most of the current gas production is from the H1-5 sands. The H1-5 sands will not be perforated in the sidetrack. Packers will be run in SCU 43A-8 to segregate the various members of the H8-H10 sands so that high GOR production'from any member can be shut-in. The estimated initial producing rate, 1000 BOPD with a GOR of 5300 CFB, has taken into account the probability that some zones will produce some gas.' To minimize the risk of water encroachment, the reserve estimate includes only oil to be recovered from the H8, H9, and upper H10 sands. PROPOS.AL FOR WELL OPERATIONS - PRO 316-1 REDRILL PROGRAM FIELD: Swanson River PROPERTY AND WELL NO: Soldotna Creek Unit 43-8 SURFACE LOCATION: 2150' North and 515' West of SW corner of Section 8; T-7-N, R-9-W, SB&M TOTAL DEPTH: 10,886' PLUGS: 10,8'86'-10,838' CASING: 20" cemented ~t 30' 11 3/4" cemented at 2073' 7" cemented at 10,886' as follows: Top Next Next Next Next Bottom 0' - 294' 294' - 1,143' 1,143' - 4,811' 4,811' - 6,651' 6,651' - 8,465' 8,465' - 10,886' 7", 29#, N-80, BT ~'7", 269, N-80, BT 7", 23#, N-80, BT 7", 26#, N-80, BT 7",_ 29#, N-80, BT . 7", 29%, P-110, L8R PERFORATIONS: ';.j- '~'' FiVe 1/2" holes at 5550', 5670', and'5772' (all Scueezed) Four 1/2" holes/ft. 5898-5900' and 6007.6010' (all squeezed) Five 1/2" holes at 10346' (WSO) ~our 1/2" holes/ft 10350-10362 , 10384-10419' 10423-10461' .10466-10498' 10510-10520' , 10524-10590' 10598-10608' and 106'32-10657 ' . JUNK: No junk reported. TUBING DETAIL: Per attached detail dated December 17, 1968. · PRESENT MECHANICAL CONDITION: Damaged or collapsed tubing or casing is suspected throughout the perforated interval because of well's history of rock and sand production. .BLOWOUT PREVENTION CONSIDERATIONS: 1. Potential Problems: A. Gas Gas may be encountered after packers are released, while cleaning out the 7" casing prior to abandonment and while redrilling. Gas entries into the mud column can cause serious. problems. Care must be exercised at all times not to swab the well during trips or when pulling production equipment. Gas entries ~ould most likely occur When working within the Hemlock Zone. Formation pressure in the Hemlock is approxi- mately 4700 psi. Programmed mud weight of 82 pcf will over- balance the 4700 psi by 1200 psi. B. Water Entries: ~Extreme caution must be exercised while redrilling this well for 'high pressure water entries. The top portion of the interval to be redrilled has recently been drilled in 1-4A-33 and 23A-3 with 82 pcf mud with-no problems. A formation test .of this interval in 23A-3 indicated a maximum pressure of 5500 psi The test was made using 82 pcf mud with no problems. The programmed mud weight of 80-82 pcf will overbalance this pressure by 350-500 psi. Mud weights of 93096 pcf are required to overbalance the intervals above the kickoff point. Caution should be exercised during the milling operations for possible water entry f~om behind the casing from these higher pressure intervals. C. Lost Circulation:~ . --.:,- ' - . '' ~'~i'-: ...... The programmed mud weight of 80-82 pcf' is the lowest which can ' be used in the well and yet maintain adequate overbalances of ,~ the intervals immediately above the Hemlock. However, because ' ~ ·-:-.~of the lower formation pressure in the Hemlock zone, lost cir- .':'·-~ '~"~, ~....-'~ '..: "~: i~i':'-..· :~ :':-~ culation could occur. Lost circulation materials, should be at ":: .... ' '" ' · " '- the "~"" ' . . . ~ - . -. . ~Site .... . :-['.',:'::i'.::~-.-~:..." D. Precautions: .... ' ' ~"'~-'- .... Any kicks should be handled by Our normal procedures. Drilling crews should be made aware of these methods and care should · be exercised at all times by every member of the crew. The .. . hole must be kept full at all times. · . -, 2. Maximum Anticipated Formation Pressure: 4700 psi in Hemlock. 550 psi in "G" zone. 3. Maximum Possible Surface Pressure: 3900 psi. 4. Blowout Prevention Equipm_ent: "0 ' A. As per pera~ing Instructions D-17." -. ,. ~-.: ' B. Class III, 10" - 5000 psig for all work. .' . DATLIM: Take all measurements from a point 14.5' above ground level. .",:'.- Original KB of SCU 43-8. PROGRAM Note: MM Mandrels at 10,262', 10,476' and 10,568' are open. Tubing and casing may be damaged, and tubing may be plugged with asphalt or sand. 1. Move in drilling rig and mix 80-82 pcf mud. . 2. Kill well by displaCing 80-82 pcf mud down the tubing, out the ~-.. · MM Mandrel at 10,262' and up the annulus. Install Cosasco plug ~ ....- ~ in the donut· Remove xmas tree· · ..... '~-i ':-.. - . 3. Install 10" - 5000 psi BOPE including 5000 psi blow and kill lines. '...:-::' j' .'i,;.i- '.:' .' '-..'.--' Pressure test according to Operating Instructions D-17. Remove i~ Cosasco plug. . 4. Release hydraulic packers. Pull ~tubing and production equipment. · Exs~mine the tubing closely for signs of damage. Note depth of damaged tubing. 5. Clean out 7" casing to the top of the Baker Model "F" packer at 10,592'. Mill and recover~Baker Model "F" packer at 10,592'. Clean out to below the bottom perforation at 10,657'. 6. Equalize cement plug in stages, if necessary, from effective depth to ~10,I90'. Downsqueeze 100 linear feet of cement. 7. Run bit and locate top of cement plug. If plug is below 10,296' recement. Division of Oil and Gas and USGS to witness the location ;~ . and hardness of the final plug. Condition mud to 80-82 pcf. . 8. Pressure test the 7" casing to 3000 psi for 15 minutes. 9.' Mill 40' windoW in-the 7", 29#, P-110 casing from 10,220' to 10,260' Casing collars are located at 10,188' 10 231' 10 243' . · ~ , , , and 10,283', DIL depth. Note: Continually monitor the mud system for posSible high pressure fluid entry during milling and redrilling operations. Be prepared to shut the well in and raise the mud weight. ...... ' ' . (126-129 pcf). Top of plug to he 150'+ above top of window. i~i.'-' .~'-~''~ . , Downsqueeze leaving top of plug above t--op of window. i."-.:..-'- ~". 11~ Drill out cement plug to 2' below top of window· C. · . 10. Plug the 40' window and 7" casing with densified Class "G" cement . . 12. Sidetrack original hole and directionally drill a 6" hole in a northerly direction to the equivalent of 10,770' MD in SCU 43-8. Directional details will be furnished. 13. Condition hole for logs. Obtain 1/2 gallon sample of drilling mud before pulling out of hole. .'.' "",i ' ' 14o Run Schlumberger Dual Induction Laterolog with SP, Microlog and BHC Sonic Log with SP'from total depth to 7" casing. · · A. Use linear scale for 2" DIL and logarithmic scale for 5" DIL. B. Use + 10 MV SP scale and 0-50 ohm-meters for the linear DIL. C. Compensated Neutron Log and Compensated Density Log will be considered as a technique for locating gas saturated intervals. 15' Cement approximately 750' of 5" liner at total depth with sufficient ~ Class "G" cement premixed with 3/4% CFR-2 to obtain returns above .... top of liner. Eq6ip liner with 5" x 7", 29# Burns liner hanger grooved.for cementing. Allow for 200' of' liner lap. A. Run float collar and float shoe. Float collar to be one joint "' : above shoe. . . --: B.,. Use slow displacement method with densified cement. Do not ---.~ :~ - use centralizers, but use solid cementers in lap area. , - -~- .:.:'.-..-.".C. Liner.detail: '"'""'""~":' ' :'"'~'"~" .... "'' ' '"!i,--..i..'. "'i':(!":i:'i"i.-:' ..'.'. · Bottom 550' 5", 18~, N-80 Extreme Line Casing ' ' Next 1' Crossover Extremle Line by LT&C -, Top 199' 5", 15#, N-80 LT&C, Special Clearance Couplings · ~- -Total ~ (In Lap) .. .... -' 16, Clean cut cement tO float collar. - · .i7. Run Variable Density Cement Bond Neutron-Collar hog'.from effective . ~'..... :' -dep~'~.to above the top of the 5" liner hanger. . 18. Pressure test the 7".casing, 5" liner and 7" X 5" liner lap to 3000_psi. - . . '19. Run formation tests of lower Hemlock 10'sand 'if indicated by logs. .. - Test details will follow. · 20.' Jet perforate selected Hemlock 8 and 10 sand intervals for production. 21. Run tandem casing scrapers and scrape the total 5" liner. 22. Run and hydrotest to 5000 psi approximately 10,730' of 2 7/8" x 2 3/8" tubing, gas lift mandrels and .completion jewelry. A detailed --'- ' completion program will follow after T D. logs have been run. '23. Remove BOPE and install xmas tree. Pressure test tree to 5000 psi. Displace drilling fluid down annulus and up the tubing with lease crude oil. 24. Set the production packers and release rig. Place well on production as'indicated on production Program which will follow. B. B. BERGET DRILLING FLUID PROGRAM SIDETRACK SCU 43-8 SWANSON RIVER FIELD BASIC DRILLING FLUID sYSTF~M Medium treated Lignosulfonate mud. ~'' '- OPgI~ DRI LING FLHID ?ROPERTIE$ " · · .PROPERTY · Weight - ~cf ....... Viscosity - sec/qt., API Fluid Loss - cc, API Plastic viscosity - CPS Yield point - Lb/100 ft2 Gel - Lb/100 ft2 - 10 min pH Calcium'- PPM .Solids content - % Vol Diesel content - % Vol VALUE OR RANGE 80 -82 43- 47 4- 7 10 - 14 8 - 12 0- 5 9.5 50 max. 6 - 10 6- 8 .... i- Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 2. Maintain adequate, supply of barite and LCM on location. 3. During milling and redrilling operations continually monitor (om 24-hour basis) mud system for evidence of high pressure water entry. BE PREPARED TO SHUT WELL IN AND RAISE WEIGHT. / ~5~ /N 7'U~Z t4/0 "~ . - ,, ,, / / X x ~ ~oo....,o.~.o. , / / 'V . ' I -" / .' o, · ~ ~ ~ .. ~ .'-. . . .. ~~ ~ .' ,~. '.._ /. . .~ / / N~~!~ ~ .. . /x. / / N ~~--....z : '"~- ...--.~~/ . / , ~ . ~'. ~. · ~ ' " X · 'J ' ] ~ '~.-~ !~~~ , ............. - "~~%1~ ~ '' I I ' ', (contoUr interval o,--I '~" ~ 10~-220' Proposed 40~ Wtnaow in 7" csg! 10,260 Possible Produt Interval Proposed Redrill *Liner Detail: Bottom 550', 5" 18~, N-80 Extreme line csg. ~ext it Crossover extreme line X LT & C · ; '-:C.' . ' SCU 43-8 E LOG SHOWING PRO~' POSED REDRILL AND POSSIBLE PRODUCTION INTERVAL .. · · Swanson Ever'Field f;~_ ~ Standard Otl Co° of, Call _- . 15.~0L. .. 1,324.71- 2,454.64- 2,467.69- · 3,403.24- 3,416.29'- S5..,4'O ' 4.167.2 6.2 · 4,180.26- 10,261.72- 10,2,74.70- -' - _ 10,440.80_ :'-2 : -- 10,444.54-- : ,. .- 2' ' 100476.33_ : -- 10,489.28-. 9~'_ 10,499.34- lo;-- 10,505. 37-- 10,306.53- 10,313.13- lu,344.23- ~.-- 10,345.77- }' LANDING MANDREL :' 2 'PUP .,JLa. Lio'& Z. O0' Z%' ]ZU£ "rumN= 41-. JtS. 2P~" EUE TUBING . CAMCO MM MANDREL 36 Jt~s. 2°~''. EUE TUBING CAMCO MM MANDREL -30 .lts."2~' EUE-TUBING ~35.55' TUBING DETAIL 13.05'~ ~9.95'~~ 13.05'~ CAMCO MM'. MANDREL -.. ' 13.05' . ~ 24 Jts. 2%' 'EUE TUBING 750.97' CAMCO MM MANDREL (w.¢ev.) 13.00' 195 Jca. 2~' 'EU~ TUBING 6081.46' CAMCO MM MANDREL (w/cev.) 12.98' 1 Jt.2~' EuE TUB. lNG .- 31.83' BAKER FH PACKER 6.60' 1 Jr. 2~" EUE TUBING .... 31.I0' OTIS "S" NIPPLE POSITION'4 1.$4' .... i:-'i,'!':i"':-'-'~''' :~' "'"-'~-': .'.""~ '.-:" ii".' '_._' ".'-' ..:'" · .. EUE 3 JCs. 2~". 'TUBING 95,03' . : , :.. :.. ... - .:..'.),.~. .:: , ~'.: _' .-'.. BROWN EkPANSION- Jt ' ""~ 3'.74' 1 Jt 2~" EUE TUBING . CAHCO MM'MA,ND,REL (w/cev.) PUP Jr. 2~' EUE TUBING BROWN HS 16-1 PACKER 31.79' 1.2.9'5 ' 1'0.06 ' 6.03' ~jj::tl --- 1 3t 2~" EUE TUBING- 30.29' ~-~ -m'__ '10535.66--' ,, ,,'" - .. ,,, , }H ~US4'__ 10'537 2''-~''- OTIS S NIPPLE-OSITION Z 1.54 "~' Il- , · v . _,:~: ~ 10,568.04-- ' ' ' ': :"' '- ' · "~'' :'. ~ - "' · . o-~- _ 10581.10:~ -CAMCO ~M MANDREL ' '. - - '" 13.0~' ' ~ II~ ' ..... . Jt '2'~'' EUS rU.B:SG' ; "' . ~O.O~' '~'~~ ~J~_~' 10~o, ~ {~ SA~E~ StOP SUB : ." "-~' ' ' -- .8~~. ~11: ~o,~2s.~s~_ .~ CA~co "u" ~ee~ . .' -', .~"'~ ~ ~ = ~&63s.3s~ ~Tu~ S, OE. ' .". '-. ',"....~, · "PlI' Ii '.. ' ' ' '- ". ,"'-.'.--'..'-' .' . --'": '" " : ': ' J. -- $:0' · ! IP "-3000~ · o _ CLASS ]~. BOPE i wd'z~ :,PCU. 43-& '[ o · p'p '/. /'- oo .'/- .. "'": - rJ'l "~' · ..., . KENAi 24 ' . e23 314 2 3,43 o [ · o- · · · ®34 41 35' . . . 'T.,.8.~.,R 9w. T. 7 N,.,R. 9 W. . - · - . . i J p S.C.U. 4.'5- 8 LO C AT ION PROPOSED REDRILL SECTION 8 T.?N. RgW SWANSON RIVER FIELD Form 10'-- 401 , BEV. I--I--71 STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [] DEEPEN SUBMIT IN TRI~ (Other mstruetioq~ reverse side~ APl //50-133-10121-01 6. I~J~.SE DI~SIGNATION AN'D SEJ~LAL NO. A-028996 7. IF INDIAN, A_LLO'i-r.:~ OR TP.~BE NA~/LE b. TYPE or WELL OI~ [] GAll ~] 8INGLE f'-] MUI'TIPI'E F-] WELL WELl, OTHER ZONE ZONE NAME OF OPERATOR Standard Oil Company of Cal±fornia, WOI 3. ADDRESS O~ OPF_~ATOR P. 0. Box 7-839 Anchorage, Alaska 99510 ,? 4. LOCATION OF WELL ~- Atsurface 2t50' North and 515' West of__ corner of Section 8: T-7N, R-9W, SB&M ^tp,'o~,edpr0d. zo,e Approximately the same as surface locati( 13. DISTANCE 1N MILES AND DIRECTION FI~OM NEAREST TOWN OR POST OFFICE* Approximately 16.5 miles from Kenai 8. UNIT, FARM OR LEASE NAME Soldotna Creek 9. WELL NO. SCU 43A-8 10. FIELD AND POOL, OR WILDCAT Swanson River SEC.. T. R., M., tBOTTOM HOLE OBJECTIVE) .nS. ection 8; T-7N, SB&M R-9W 14. BOND INFORMATION: TYpENat ion Wide Surety and/or No. 15. DISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) SL 6205862 660'± 18. DISTANCE FROM PROPOSED LOCAT~JON* TO NEAREST WELL DRILLING COMPLETED, OR APPLIED FOR, FT. 900' NO. PROPOSED OF1120 ACRES DEPTH IN LEASE 10,770 ~ 21. ELEVATIONS (Show whether DF, RT. CH, etc.~ 172 ' KB 23. PROPOSED CASING AND CEMENTING PROGRAM A~no,-,t ~5 0, 0 0 0 17. NO, ACRES ASSIGNED TO THiS WELL 4O 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* ~arch 1, 1974 ,, SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SE'I~ING DEPTH quantity of cement As exi ting in ~, CU 43-8 :' - , ' : ...... /',e.~: - '-" ' . , , , We propose to hole location sidetrack SCU 43-8 to approximately the same bottom as per the attached program. FEB 1 9 1974 · DIVISION Oi; OIL 1~ ABOVE SPACE D~SCRIBE _1~. OPOSED PROGRAM: .If _.l~OpOSal is to dee~nt 'giv~ ~m .~n ~resent p~u~v~ zone ~ .pyo~ ~w prffdu~ive ~ne..!~~1 1~ ~. ~IlL 0r a~n a~e~to~lly, give p~r~en. ~ on ~osu~a~ ~tw~ ~a .mea~a ~a wue 've~ical~p~. Give bl~t preveo~er p~gram. 24. I hereby ~ydthat th~ For~ng is ~e ~e Corre~ ' ~llh~ ~,i t 2/7/74 ' Area Supervisor '(This space f~S~te office ~) CONDI~ONS O~ ~P~V~, I~ ~: J SAMPL~ AWD CORE CHIPS R.~U~ J M,U'D L0'~ ~ ~U~~: . J o I o Y~ ~.o SEE TRANS"I/TAL LETTER EY R API ~C~ COD~ JDI~ION~ SURV ~~ · · ' ~m~rrr~o_ '7z''/-/3 . ~ov~D^~ February 26,, 1994 APPHOVED BY , Execut i ve Secretary *$~ Instructions On Reverse Side February 26, 1974 Company Lease & Well No CHECK LIST FOR NEW WELL PERMITS Yes No Remarks · Is well to be located in a defined pool ................. Do statewide rules apply ........................ y~ __ ;. Is a registered survey plat attached . · . Is well located proper distance from property line ........... ~ ,. Is well located proper distance from other wells ............ x~ ;. Is sufficient undedicated acreage available in this pool , . Is well to be deviated ......................... Is operator the only affected party ................... ~.___~ Can permit be approved before ten-day wait ............... /~:~ ........ O. Does operator have a bond in force .................... , , -- ~ , J , , , , , , 1. Is conductor string provided ...................... ~/~. 2. Is enough cement used to circulate on conductor and surface ...... 3. Will cement tie in surface and intermediate or production strings . . . 4. Will cement cover all possible productive horizons ........... ~/~.__ 5 Will surface casing cover all fresh water zones 16. Will surface csg. internal burst equal .5 psi/ft, to next string .... 17. Will all casing give adequate safety in collapse and tension ...... ~' 18. Does BOPE have sufficient pressure rating ............... ~ , Additional Requirements:
