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197-063
• • E _ .. STATE OF ALASKA APR 0 5 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION 1a.Well StatusWEOil❑LL COMPLETIONh OR RECOMPLTION REPORT ANe ❑ ❑ Abandoned IV • Suspended Class: 20AAC 25.1054 ' 20AAC 25.110 Development 0 • Exploratory ❑ GINJ LIWINJ❑ WAG❑ WDSPL❑ No.of Completions: 1 ' PIA"It Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Hilcorp Alaska,LLCband.: 4 3/12/2016 1 197-063/316-052 • 3.Address: 7.Dade mudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 5/12/1997 50-733-20246-01-00 • 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 1599'FSL,552'FEL,Sec 4,T9N,R13W,SM,AK 6/6/1997 Trading Bay St A-27RD1 • Top of Productive Interval: 9.Ref Elevations: KB: 101' 17.Field/Pool(s): N/A GL:0' BF: 93.5' McArthur River Field/Hemlock Oil Pool • Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 1215'FSL,354'FEL,Sec 8,T9N,R13W,SM,AK 10,824/8,246 % ADL018731 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 218882 y- 2523112 Zone- 4 12,933/9,948 N/A TPI: x- N/A y- Zone- 12.SSSV Depth MDITVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 213670.8592 y-2517562.662 Zone- 4 N/A N/A 5.Directional or Inclination Survey: Yes ❑(attached) No 0 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 66' (ft MSL) 10,808'/8,233 22.Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCANNED SEP 2 9 2016 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" Surf 225' Surf 225' Driven 16" 65# H-40 Surf 1,065' Surf 1,025' 22" 950 sx 13-3/8" 61# K-55 Surf 4,009' Surf 3,209' 18-5/8" 2000 sx 9-5/8" 47# S-95 Surf 8,451' Surf 6,329' 12-1/4" 2600 sx 7" 29# L-80 Surf 10,808' Surf 10,068' 8-1/2" 1806 sx 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): N/A N/A 12,217' N/A Am 7? '1.-r -r , twc cc, 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. l Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period -N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate -+ N/A N/A N/A N/A /13P(.' Form 10-407 Revised 11/2015 C TINUED ON PAGE 2 RBDMS L.1, APR 0 7 11)1 Submit ORIGINIAL onl r. • • 28.CORE DATA Conventional Core(s): Yes ❑ No 1=I Sidewall Cores: Yes ❑ No II If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. N/A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No CI Permafrost-Top If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval information,including reports,per 20 AAC 25.071. N/A N/A N/A Formation at total depth: 31. List of Attachments: Summary of operations,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontolooical reoort.production or well test results.Der 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Marlowe(907)283-1329 Email: dmarlowe(U hiIcorp.com 41/ Printed Name: Stan W.Golis Title: Operations Manager Signature: Phone: (907)777-8356 Date: q �S (1(0 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only H . • Trading Bay Field . 11 Well:A-27RD SCHEMATIC PTD 197-063 03/12/2016 Hilcorp Alaska,LLC API: 50-733-20246-01 CASING DETAIL 20,J l Size Wt Grade Conn ID Top Btm 20" Surf 225' 16" 65# H-40 8RD Surf 1,065' 16" 13-3/8" 61# K-55 Butt 12.515" Surf 4,009' 9-5/8" 47# S-95 Butt 8.681" Surf 8,451' (KOP) 7" 29# L-80 BTC TKC 6.184" Surf 10,808' (KO P) TUBING DETAIL N/A 4 iL JEWELRY DETAIL 13-3/8" No Depth Depth ID Item (MD) (TVD) 1 10,824' 8,246' CIBP(set for whipstock) 2 12,217' 9,362' 3.880 HES 7"23-29#VTL Retrievable Packer w/seal bore assembly 3 12,271' 9,406' 2.813 HES X Nipple 4 12,303' 9,432' 2.992 Muleshoe Wireline Re-entry Guide ® El PERFORATION DETAIL Btm Zone Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status 9-5/8" HK1 12,392' 12,406' 9,503' 9,515' 14' 6/19/1997 A 6 HK 1-4 12,402' 12,752' 9,511' 9,798' 350' 4/16/1998 HK 2&3 12,448' 12,581' 9,549' 9,657' 133' 6/19/1997 HK3&4 12,595' 12,647' 9,668' 9,711' 52' 6/19/1997 Cemented HK 4&6 12,756' 12,780' 9,801' 9,821' 24' 4/16/1998 HK 5&7 12,792' 12,848' 9,831' 9,877' 56' 4/16/1998 HK 6 12,858' 12,890' 9,886' 9,912' 32' 4/16/1998 TOW @10,808' lihhiih. 0BP 10,824' t TOC 12,120' Top of packer @ ,`� 2 12,217' x , 3 '+ 4 • = Hemlock 7' Landrg Cellar a 1 at 12,846' PBTD=10,824' TD=12,933' Updated By:1LL 04/01/16 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-27RD (Plug Back) Monopod Rig 56 50-733-20246-01 197-063 2/23/16 3/12/16 Daily Operations: 02/23/2016-Tuesday Finished N/D tree. NOS rep examined lift threads and M/U blanked 3 1/2" IBT x 3 1/2" EUE sub (left hand M/U). N/U 13 5/8" 5k BOP stack as per Sundry. Installed flow nipple adapter, flow nipple, flow lines, air boot, turn buckles and changed rams from 2 3/8" to 2 7/8" x 5 1/2" variables. M/U 3 1/2" test jt w/pumpin, safety valve and IBOP. Screwed into x-overs in top of tb hanger. Filled stack, closed annular and outside valves. Shell tested to 2800#s. Tested all BOPE 250#s low/3000#s high (annular tested to 250#s low/2500#s high) as per AOGCC and Hilcorp requirements. Performed passing accumulator draw down test. B/O test jt and tested blinds. Witness waived by Mr. Regg/AOGCC. Screwed back into NOS hanger subs and backed out of hanger. B/D test jt. Pulled BPV and M/U 3 1/2" EUE landing jt w/S/V into hanger. Picked up string to 160k and hanger pulled free (weight dropped back to 80k). Continued picking on string and it started moving uphole at 115k. Pulled hanger to surface. 02/24/2016-Wednesday NOS rep B/D L/0 hanger and landing jt. Filled hole with 66 bbls of FIW (well taking fluid). POOH L/D 3 1/2" 9.2# L-80 BTC production tbg along with associated hardware (constant fill up using trip tank). 368 jts+ hardware laid down at report time = 11,640'. Daily fluid loss 63 bbls. Total fluid loss 136 bbls. 20" = 76psi. 16" = 82 psi. 13 3/8" = 20 psi. 9 5/8" = 85 psi. 02/25/2016-Thursday Finished POOH from 11,640' w/recovered 3 1/2" 9.2# L-80 BTC production string plus all accessory hardware. Full recovery down to seal assembly (12,232'/top of HES VTL pkr at 12,216'). Cleared and cleaned rig floor, pipe deck and change house. Loaded out recovered production string and on loaded PH6 workstring. Prepped rig floor to TIH. Cleaning rig floor, pipe deck and quarters. M/U recovered seal assembly w/x-over back to workstring= 15.75'.TIH picking up 3 1/2" 12.95# P-110 PH6 workstring w/ BHA strapping and drifting to 8,950' (288 jts+ BHA). Secured well. Onloaded SWS cementing package while rig shutdown to slip and cut drill line. R/U cementing package as complete as possible without running iron to the floor. Fluid loss last 24 hrs= 27 bbls.Total fluid losses = 163 bbls FIW. Casing pressures unchanged: 20" 76#s, 16" 82#s, 13 3/8" 20#s, 9 5/8" 85#s. 4110 i Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-27RD (Plug Back) Monopod Rig 56 50-733-20246-01 197-063 2/23/16 3/12/16 Daily Operations: 02/26/2016- Friday Finished slipping and cutting 100' of drill line. Checked crown-o-uratic. Continued in hole from 8,950' w/old seal assy (15.75') on 3 1/2" 12.95# P-110 PH6 workstring.Tagged at 12,216' (P/U 177k S/O 82k). Stung into pkr and pulled out. R/U circ head and circulated 90 bbls at 6.4 BPM 1900#s L/W. Stung into pkr and attempt to inject at 2000#s(4 bbls pumped)- no go. Held PJSM w/ rig personnel and SWS.Tied in SWS and started injecting at 2 BPM 2600#s. Pumped 20 bbls FIW then 3 bbls FW. Started blending 15.8 ppg Class G cement. Pumped 28 bbls cement followed by 87 bbls FIW (putting 25 bbls below pkr- leaving 3 bbls cement inside workstring, to be left on top of pkr). Broke off circ head (slight flow back on tbg and casing). Pulled 5 stands and M/U circ head. Circ 400 bbls FIW at 8 BPM 2500#s L/W. Broke down circ head and POOH from 11,750'. Secured well and B/D L/0 seal assy. Cleared and cleaned rig floor. Fluid loss last 24 hrs= 160 bbls FIW/ accumulated total of 323 bbls. Casing pressures unchanged: 20" 76#s, 16" 82#s, 13 3/8" 10#s, 9 5/8" 85#s. 02/27/2016-Saturday M/U BOT BHA#1- bit &scraper/gauge assy (6" rock bit, 5 3/8" x 1 1/4" scraper f/7" casing, 4 3/4" x 1 9/16" bit sub, 6.059" x 1 1/2" string mill, 4 3/4" x 2 11/16" x-over sub= 13.32'). TIH w/ BOT BHA#1 on 3 1/2" 12.95# P-110 PH6 workstring to tag at 7,636. Wiped this spot out and CIH to tag at 11,775' (P/U 165k S/O 80k)- set 20 k down. P/U to 1st connection (11,765') and B/O L/D single. R/U Kelly hose. Established circ L/W and closed upper pipe rams. Pressured up to 2500#s on 7" casing. Pressure leaked off 140#s. Found small leak on test hose. Changed out connections and pressured back up to 2500#s. Pressured leaked off 50#s in 20 mins. Bled off pressure. Plans are to retest casing after setting CIBP at— 10,800'. Lined up to push returns to production- clearing trip and active tanks of 390 bbls at 5 BPM 2000#s. Cleaned and prepped tanks for caustic & Baraklean wash pills while displacing well with clean FIW-420 bbls at 5 BPM 2000#s. 02/28/2016-Sunday Continued cleaning out fluid tanks, pits and shakers- prepping to chemically clean fluid system and well bore- pumping fluids to production. Mixed 50 bbls caustic pill and pumped thru surface lines into pits both mud pumps, bleeder, standpipe, trip tank, gun lines and choke manifold-disposing of pill in dirty pit (#3). Mixed 50 bbl Baraklean pill and repeated previous circulations-catching pill in dirty pit (#3). Mixed and pumped 50 bbl caustic pill followed by 10 bbls FIW then 50 bbl Baraklean pill followed by 10 bbls FIW then 40 bbl Barazan-D hi-vis pill followed by 850 bbls FIW (6 BPM 2400 PSI) (returns cleaned up). Flushed upper portion of stack functioning annular and pipe rams. Flushed trip tank and lined up to send dirty fluids to prod shipping line. Pumped dirty pit away along with all rinse fluids from tanks. R/D circulating lines t/production. POOH w/ BOT bit& scraper/gauge assy from 11,765' to 3,084' (33 stands in hole) at report time. Fluid loss last 24 hrs= 0 bbls FIW/accumulated total of 323 bbls. 9 5/8" = 90psi, 13 3/8" = 18 psi, 16" = 78 psi, 20" = 74 psi. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-27RD (Plug Back) Monopod Rig 56 50-733-20246-01 197-063 2/23/16 3/12/16 Daily Operations: 02/29/2016- Monday Finished POOH w/ BOT bit & scraper/gauge assy from 3,084'. BID L/0 BOT tools. Cleared and cleaned rig floor. R/U Pollard E-Line equip and TIH w/5.375" CIBP. Recorded CCL and set CIBP at 10,824' (WLM), 5' above casing collar. POOH & R/D/R E-Line. Closed blinds and pressured up to 2500#s on 7" casing, testing casing and CIBP. Charted f/30 mins-good test- released pressured. M/U 6" bit w/ bit sub and workstring x-over. Checked M/U torque on Gill tongs.TIH w/6" bit on 3 1/2" 12.95# P-110 PH6 workstring to 10,828'. Set down 10k on plug. POOH from 10,828' to 3,914' at report time (268 of 394 jts OOH). Fluid loss last 24 hrs= 0 bbls FIW/accumulated total of 323 bbls. 9 5/8" = 90psi, 13 3/8" =19 psi, 16" = 76 psi, 20" = 72 psi. 03/01/2016-Tuesday RIH from 3,914' w/remaining 14 stands of 3 1/2" 12.95# P-110 PH6 workstring to 5,220'. POOH laying down all workstring. B/D 6" bit &x-over subs. Secured well by closing the blind rams. FINAL WELL WORK ACTIVITY UNDER SUNDRY 316-052. WORK WILL RESUME UNDER NEW PERMIT TO DRILL# FOR THE SIDE-TRACK. 3/2/16-Wednesday Unstring national block w/hook on 8 lines t/IDECO 360 shorty block on 10 lines and installed 10 line dial on weight indicator also spotted &stacked Tesco HPU.Cleaned&clear rig floor,chk thrust and throw on crown sheaves, continue stack tesco HPU removed national block and hook from rig floor& prep same for storage on steelhead. Loosen clamps, lower strong back f/tq rail into position&secure, unload remainder of tesco top drive eq. r/u top drive rail in derrick, spot centrifuge feed pump, install cribbing on west sub. Rig @ 30%r/u, TDS @ 40% Annular PSI 7" =0,9 5/8=90, 13 3/8=19, 16"=76, 20" 72 3/3/16-Thursday Continue install TDS torque tube, continue cribbing for cmt silo. Finish torque tube resume assembly of tesco HPU, prep &skid rig to well center,secure same, p/u TD, clear floor TD carrier. Install flow nipple,c/o plug on HPU,test communication cable f/TDS, load &backload boat,spot DD shack, lay cribbing for CMT silo, unload &stand same on pipe deck. Hang HPU service line's in derrick. Rig @ 50%r/u, TDS @ 75% Annular PSI 7" =0,9 5/8=82, 13 3/8= 18, 16" =74, 20" 70 3/4/16- Friday Continue hang service loop exercise same chk free travel, install kelly hose and exercise same and chk free travel, power up dd shack. Fuel and fire HPU and warm oil, Dress TDS w/Hilcorp 11' bails and install and adjust link tilt chk crown saver bell (failed)and measure distance set cmt silo. Install service loop wrap and set mud loggers shack, attempt free up crown saver bell and mark same. Install derrick cameras, prep centrifuge stand, hang blocks&TD, cut drill line,clean pits, clean & plug deck drains,clean lights in derrick replace bulbs as needed. Rig @ 65%r/u, TDS @ 95% Annular PSI 7" =0,9 5/8=82, 13 3/8= 18, 16" =74, 20" 70 • S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-27RD (Plug Back) Monopod Rig 56 50-733-20246-01 197-063 2/23/16 3/12/16 Daily Operations: 3/5/16-Saturday Finish securing centrifuge and work on install of feed and dump lines to same.Continue cleaning pits#3&4 and house clean rig, remove crown saver bell system and attempt repair(no-go). Remove upper static drlg line stabilizer for weld repair. Power up mud loggers shack and install comms in both out buildings. repair equalizer between pit 2&3.Welder finish extension for flow line and install same install supports for flow lines. Prep for dp&mud product. MWD hand on board start r/up of unit&equipment. Canrig rig watch hand on board activate auto driller and go thru rig watch system. Troubleshoot TDS IBOP bypass switch.Cont.clean active pits,assist MWD r/u encoders, install mousehole,clear floor of xo's, unload boat w/4 1/2" DP, &30 jts HWDP,clean TT&slop tank,install splash guards on mud pumps. Unload mud products&stage in center bay,clean rig floor sump,&pipe rack drains.Attempt to start Tesco HPU,did not turn over, pulled started found broken flywheel teeth. Rig @ 75%r/u, TDS @ 95% Annular PSI 7" =0,9 5/8=85, 13 3/8=20, 16" =72, 20"68 3/6/16-Sunday Continue trouble shoot Prime mover for Tesco HPU, Roll fly wheel and inspect found(5)spots(3)w/single tooth missing and (2)w/double teeth missing.Start chasing repair parts. Fire HPU(8)times(ok)and ran unit for 5 hrs noticed oil leak (possible rear main seal)work repair plan and parts and mech.Continue and finished install of Lexan splash guards on MP's,install and r/up derrick board Mule,cleaned out cellar catch tank,chk koomey bottles and charged(6)bottles investigate koomey pump#1 and found failed starter mtr and chase parts. Installed new mud line shock hoses.Snake out •' rig floor drains assist can rig w/PVT system repair. Held platform drill gas alarm&abandon platform w/debriefing. Continue assist can rig w/pvt system. Prep to test PVT system and test IBOP bypass and mud system Low pressure valves R/u fill pill pit,check PVT levels, pump through bleeders,verify IBOP bypass function good,transfer fluid to all pits check valve integrity&pvt levels, r/u pressure sensor on gasbuster.Set and test all pop off valves,transfer fluid through pits testing PVT&check low pressure valving,test HP mud line t/4k,found leak on flange, repair same, re-test t/4k had leak on kelly hose r/d line,tq connection, re-install&test t/4k, had leak on gooseneck connection, re-tq. re-test same. 3/7/16- Monday Skim oil and clean pit from LP testing.Test and commission both flow shows(ok) r/up to p/up dp,chg dies on ST-80, repair die block on st-80. R/up tongs, clean MP suction screens and strap dp. Perform derrick inspection. M/up xo to floor valve and M/up xo to stack washer and trouble shoot brake cooling pump. Elect ordered koomey pump starter ETA 9th. MTU mech inspected Tesco prime mover determined oil lead was just gasket and sealed same also confirmed that out of state fly wheel was needed for repair and ship same ETA 9th. Mud logger on board start r/up of shack and equipment.Set wear ring, m/u stack washer,xo od too large to run, l/d same,clean&flush surface pits. P/U 4 1/2"CDS 40 HWDP, 27 jts, adjust&train on ST-80,verify tq w/tongs,good.TIH w/10 stands 4 1/2"CDS 40 16.6#DP,f/derrick t/1756', cont. P/u singles t/4077', up wt 107k,dn wt 84. Repair light @ crown,troubleshoot light at board, hands train on ST-80,clean pill pits, repair crown bell prep to hang.Cont. p/u 4 1/2" Dp t/5572', up wt 130k,dn wt 98. Rig @ 87%r/u, TDS @ 80% Annular PSI 7"=0,9 5/8=90, 13 3/8=18, 16"=75, 20"68. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-27RD (Plug Back) Monopod Rig 56 50-733-20246-01 197-063 2/23/16 3/12/16 Daily Operations: 3/8/16-Tuesday Continue P/up rabbit and strap 4-1/2"CDS-40 16.6#drill pipe t/180 jts @ 6191' w/27 jts of 4-1/2" HWDP barefoot chking up/dn weights every 1000' 141/102k.And continue build first batch of 9.2 ppg KCL/Gem mud and chase Hot parts for Tesco prime mover and koomey pump repair(both in state)continue chase hot shot to platform.Secure well and install rebuilt crown bell saver system measure and test same(ok) Bell @ 13'from crown bumper and re set and test crown-O-matic @ 18'from crown bumper. Elect.continue trouble shoot derrick camera system. Continue build first batch of mud. Finish first batch of mud and re clean reserve tank before shipping.Continue trouble shoot derrick cameras, repair brake water cooling pump control and continue centrifuge hook up. Housekeeping,Cont. mix, &transfer 9.4ppg KCL/polymer/GEM mud t/fill reserve pit 231bbls,cont. p/u 4 1/2"dp rih t/8878'. Cont. mix, &transfer 340bbls 9.2ppg KCL/polymer/GEM mud, Cont. p/u 4 1/2" dp, 323 jts total,t/tag CIBP @ 10824.84', up wt 251k, dn wt 135k, l/d single,c/o bails. Rig @ 95%r/u, TDS @ 97% Annular PSI 7" =0,9 5/8=90, 13 3/8=18, 16" =75, 20" 68 3/9/16-Wednesday Continue chg out bails install saver sub and hook up link tilt and adjust same. Elect work on chg out of mtr starter on koomey pump interment tech work on troubling and repair of derrick cameras Cont. mix, and transfer 9.2 ppg KCL/polymer/GEM mud, have 430 bbls surface volume build and working on last batch continue work on to-do list spot and install connex landing and stairs New drill crew on board go over expectations of contract drilling personel @ PTSM Re clean trip tank r/up hoses to displace well to mud and pump non produced water to production Continue work on koomey pump and derrick cameras and to-do list, work on tesco and canrig communication of rpm and torque. PJSM test line to production(ok) Displace well w/370 bbls of 9.2 ppg KCL/polymer/Gem mud w/mp#2 and pumping water returns to production w/ MP#1 Finish new mtr starter repair on koomey pump and test same and adjust pressure switch set points. install derrick PTZ camera from steelhead Wash stack&cellar, install centrifuge discharge line, troubleshoot TDS ROT&TQ.sensor& repair,wk on tie in t/rigwatch sys. clean pit 1&TT,train making connections w/ day crew,test Deluge system, POOH f/10767't/10147', up wt 170k,dn wt 103k Rig @ 97%r/u, TDS @ 98% Annular PSI 7" =0,9 5/8=90, 13 3/8=20, 16" =70, 20"70. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-27RD (Plug Back) Monopod Rig 56 50-733-20246-01 197-063 2/23/16 3/12/16 Daily Operations: 3/10/16-Thursday Continue building surface volume 9.2 ppg KCL/polymer/Gem mud. Continue Pooh racking back dp for maximum set back and crew training on TDS operations and practice making conn.Working on to do list r/dn hoses from production, r/up hoses and pump for stack draining Trouble shoot and repair Communications between tesco and rig watch install and adjust chains on link tilt for maximum drill dn of std work on to do list.finish r/up of DD shack Continue building surface volume 9.2 ppg KCL/polymer/Gem mud. Continue Pooh racking back dp for maximum set back and crew training on TDS operations and practice making conn. Finish POOH, r/u&drain stack R/U pull wear bushing, m/u 4 1/2"Ti,set test plug, fill stack&surface eq w/FIW,.Close Annular,shell test t/250/2500,good, Pre-test BOPE, 250 low, 3500psi high as per sundry,all test good M/u Ti, refill surface eq. ready for BOPE test,cut pipe rack boards, mark shaker screens, Rig @ 99%r/u, TDS @ 99% Annular PSI 7" =0,9 5/8=86, 13 3/8=20, 16"=70, 20" 65. 3/11/16- Friday Finish pre-bope test continue work on do-do list and housekeeping while waiting on state man and continue work on derrick camera system. Mr. Chuck Scheve w/AOGCC on board Platform orientation discuss current well and rig status and review paper work and tour bopes and chk chart and continue w/BOPE test as per regulations w/one failure "8" manual choke. R/dn test equipment,set wear ring. mech prep to rebuild "B" manual choke and remove old coaxial cable out of derrick.Abandon platform drill: Held H2S drill, shut in well,all muster,then roll into abandon platform, all go to escape capsule's.Take apart choke"B" re-assemble, re-test 250/1000 bleed off through choke,good. Prep&p/u Whipstock assy_,� BHA#1, p/u assy.shallow test MWD @ 4.5-5.8 BPM, 705 psi.goad. M/U 7"whipstock slide,w/38k shear bolt, anchor pinned for 14,240. RIH t/7147' @ 1 1/2-2min stand,easy on&off slips,filling every 30 stands, up wt 160k, dn wt 110k.9 5/8=88, 13 3/8=20, 16"=70, 20"66. 3/12/16-Saturday Continue Rih slow w/Bha#1= 7"whipstock assy.f/7147't/10771' remove shaker jack for weld repair,trouble shoot elect issue w/charge pump#3 while tripping. Fill pipe, chk weights, set depth and orient whipstock face t/22 L and sat v dn 20 k @ 10826'and tripped anchor over pulled 20k chk same(ok)set dn sheered bolt @ 40k dn wt. P/up establish z 1` parameters Up/dn/rot 217/122/175 @ 202 gpm @ 1300 psi at 70 rpm w/14,500k free torque. Mill window f/10808' ✓ S(I T.O.W @ 10808' B.O.W @ 10821' recovered 1321bs iron including +/-201bs scale. ROP stopped @ 10818',changed paramaters, broke past spot,cont mill 20' rat hole t/10841'.CBU till clean while reaming window,s/d pumps,&rot, drifted through window t/10841', POOH t/10740' clean, up wt 235,dn wt 150, (lost hour for DST). R/u perform FIT, PSI up t/1420psi w/mud pump @ .5bpm, MWE 12.5ppg, pump 1.8 bbls, monitor&record for 10 min, bleed back t/1.7bbls. L/D single, POOH changing break t/9935'.9 5/8=88, 13 3/8=20, 16" =70, 20" 66. Milk w w 10 F . 1%%i''s� THE STATE Alaska Oil and Gas �•" a o f A S I,(LAConservation Commission tst} = = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALA€' Fax: 907.276.7542 www.aogcc.alaska.gov SCANNED VER 0 8 2016 Stan W. Golis Operations Manager Hilcorp Alaska, LLC ( .#f 7 " d G3 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Granite Pt St A-27RD1 Permit to Drill Number: 197-063 Sundry Number: 316-052 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair f�- DATED this 28 day of January, 2016. RBDMS L-L- JAN 2 9 2016 0 • RECEIVED STATE OF ALASKA JAN 2 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION ors if 2$/I b APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown LI Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 - Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Prep-fefi-Sidetraek- (I] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development 0 . 197-063 - 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20246-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay St A-27RD1 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 McArthur River Field/Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,933 9,948 . 12,846 9,876 , 2,729 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural 225' 20" 225' 225' Conductor 1,065' 16" 1,065' 1,025' 1,640 psi 630 psi Surface 4,009' 13-3/8" 4,009' 3,209' 3,090 psi 1,540 psi Intermediate 8,451' 9-5/8" 8,451' 6,329' 9,150 psi 7,100 psi Production 12,933' 7" 12,933' 9,948' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12,392-12,890 • 9,503-9,912 3-1/2" 9.2#/L-80 12,303 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES 7"VTL Retrievable Packer ' 12,217'(MD)9,362'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/8/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 ' I 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallett@hilcorp.com Printed Name Stan W.Golis/ Title Operations Manager Signature ) l Phone (907)777-8356 Date 1/LS / LID COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: W1-i n�o /�� / �f >� may) �•' /moi`� /-t S � ,f ..�J('q•.. y .r,.. f��'1%..t.l�R� �,CiJ/� 1 / Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /0 rL(0 4...4......)V_ ___ APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date:/-2,F--//7 - 7-/40 /�+� r P�a 14?-lig- RBDMS (..1.- JAN 2 9 gots 1 - N i ubmn Form and Form 10- .3 Revised 11/2015 f ��1�iY1" p C � fL�•ilid for 12 months from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: A-27rd Hilrnrp Alaska,►Lc Date: 01/20/2016 Well Name: A-27rd API Number: 50-733-20246-01 Current Status: Gas-Lift Producer Leg: N/A Estimated Start Date: February 08, 2016 Rig: Monopod Rig#56 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 197-063 First Call Engineer: Trudi Hallett (907) 777-8232 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) Current Bottom Hole Pressure: 3,659 psi @ 12,328'(9,451'TVD) 0.387 lbs/ft(7.46 ppg)06/05/2009 static BHP Maximum Expected BHP: 3,659 psi @ 12,328'(9,451'TVD) 0.387 lbs/ft(7.46 ppg)06/05/2009 static BHP Maximum Potential Surface Pressure: 2,729 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Note:This is a no-flow Well(07/08/15) Brief Well Summary A-27rd is a Hemlock only gas-lifted producer. This workover will pull the current completion and plug the well for a sidetrack. Procedure: • 1. Skid Rig into position above A-27rd 3000 K"` 2. ND Wellhead, NU BOP and test to 250psi low/ si high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Attempt to pull tubing and seals, if unsuccessful, RU e-line and RIH to +/-12,200' and cut tubing. 4. Circulate hydrocarbons from well to production—Workover fluids will be FIW. 5. POOH laying down completion. 6. Cleanout to+/-12,200' 7. Option A—Tubing in good condition w/o recovering seals: a. RIH with overshot engaging top of production tubing @ ±12,200' b. RU cementing equipment and pump ±25 barrels Class G cement through packer to plug existing perforations. c. PU above Packer and spot an additional ±3 barrels cement to put TOC @ ±12,120'. 8. Option B—Tubing in good condition w/recovering seals: a. RIH with workstring and sting into production packer. b. RU cementing equipment and pump ±25 barrels Class G cement through packer to plug existing perforations. c. PU above Packer and spot an additional ±3 barrels cement to put TOC @ ±12,136'. 9. Option C-Tubing not in good condition: a. RIH with CRET and set @ ±12,200' b. RU cementing equipment and pump ±25 barrels Class G cement into CRET and squeeze into 7" liner to plug existing perforations. c. PU above CRET and spot an additional ±3 barrels cement on top of CRET @ ±12,200'to put TOC @ ±12,120'. 10. PU WS to 12,120', circulate hole clean. INA(111. PT casing to 1; psig for33dmin tes and chart. � � 12. POOH standing back WS, 13. RU e-line and RIH w/CIBP to ±10,800'. Set CIBP 5' above casing connection. 14. RD e-line. 15. ***Remaining Procedure to be included on the Permit to Drill for the sidetrack*** ! •• . IIWell Work Prognosis Well: A-27rd Hilmrp;Uacka.I,I,C Date: 01/20/2016 Attachments: 1. Well Schematic Current -- 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing 5. Fluid Flow Diagrams Lar 6. RWO Sundry Revision Change Form ;J"' �. �-- res / . J lea r2 1 cv IQ' et., 0 • Trading Bay Field Well:A-27RD HSCHEMATIC Last PTD: 197-063 Completed:06/21/1997 Ililcorp Alaska,LLC API: 50-733-20246-01 CASING DETAIL 21Ll Size Wt Grade Conn ID Top Btm 20" Surf 225' 16" _ 65# H-40 8RD Surf 1,065' 16" 13-3/8" 61# K-55Butt Surf 4,009' 9-5/8" 47# S-95 Butt Surf. 8,451' q (KOP) 7" 29# L-80 BTC TKC Surf 12,933' TUBING DETAIL 3-1/2" 9.2# L-80 BTC Surf 12,303' i JEWELRY DETAIL 4 11 1111 i No Depth Depth ID Item 13-3/8" (MD) (TVD) 35.70' 35.70' Cameron"AP"10"x 3-1/2"Hanger a p 1 326' 326' 2.813 HES 2.813"XXO SVLN II 2 2,525' 2,154' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve 3 4,342' 3,446' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve it P 4 5,413' 4,201' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve 5 6,232' 4,796' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve 6 6,961' 5,299' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve i' 7 7,630' 5,764' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve 8 8,271' 6,206' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve ® I 9 8,872' 6,645' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve 10 9,444' 7,113' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve i 11 9,958' 7,539' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve 12 10,532' 8,008' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve 9-5/8" 13 11,079' 8,451' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve A 14 11,650' 8,906' 2.991 3-1/2"x 1"McMurry SMO-GLM w/live valve r 15 12,128' 9,291' 2.991 3-1/2"x 1"McMurry SMO-GLM w/orifice 16 12,174' 9,328' 2.813 HES 2.813"XU Sliding Sleeve IR i 17 12,217' 9,362' 3.880 HES 7"23-29#VTL Retrievable Packer w/seal bore assembly 111 18 12,271' 9,406' 2.813 HES X Nipple i 19 12,303' 9,432' 2.992 Muleshoe Wireline Re-entry Guide diPERFORATION DETAIL 1 Zone Top(MD) Btm(MD) Top(TVD) Btm FT Date Status (TVD) HK1 12,392' 12,406' 9,503' 9,515' 14' 6/19/1997 Open i HK 1-4 12,402' 12,752' 9,511' 9,798' 350' 4/16/1998 Open IIIHK 2&3 12,448' 12,581' 9,549' 9,657' 133' 6/19/1997 Open q HK 3&4 12,595' 12,647 9,668' 9,711' 52' 6/19/1997 Open r t HK4&6 12,756' 12,780' 9,801' 9,821' 24' 4/16/1998 Open �.�1C HK 5&7 12,792' 12,848' 9,831' 9,877 56' 4/16/1998 Open I HK 6 12,858' 12,890' 9,886' 9,912' 32' 4/16/1998 Open Hernlock r _ Landing Collar 1 • 1 at 12,846' ...................... PBTD=12,846' TD=12,933' Updated By:11101/07/16 H . Trading Bay Field • Well:A-27RD Last Completed: FUTURE PROPOSED PTD: 197-063 IIilcorp Alaska,LLC API: 50-733-20246-01 CASING DETAIL 20', L Size Wt Grade Conn ID Top Btm 20" Surf 225' 16" 65# H-40 8RD Surf 1,065' 16" 13 3/8" 61# K-55 Butt 12.515" Surf 4,009' 9 5/8" 47# 5 95 Butt 8.681" Surf 8,451' (KOP) 7" 29# L-80 BTC TKC 6.184" Surf 12,933' TUBING DETAIL JEWELRY DETAIL 4 11 Depth Depth No ID Item 13-3/8„ (MD) (TVD) ±10,800' CIBP 17 12,217' 9,362' 3.880 HES 7"23-29#VTL Retrievable Packer w/seal bore assembly 18 12,271' 9,406' 2.813 HES X Nipple 19 12,303' 9,432' 2.992 Muleshoe Wireline Re-entry Guide 4 PERFORATION DETAIL Btm Zone Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status 9-5/8" HK1 12,392' 12,406' 9,503' 9,515' 14' 6/19/1997 a • HK 1-4 12,402' 12,752' 9,511' 9,798' 350' 4/16/1998 HK 2&3 12,448' 12,581' 9,549' 9,657' 133' 6/19/1997 HK 3&4 12,595' 12,647' 9,668' 9,711' 52' 6/19/1997 Cemented HK 4&6 12,756' 12,780' 9,801' 9,821' 24' 4/16/1998 HK 5&7 12,792' 12,848' 9,831' 9,877' 56' 4/16/1998 HK 6 12,858' 12,890' 9,886' 9,912' 32' 4/16/1998 CI BP±10,800' AlL Y TOC±12,120' / F Tubing cut±12,200 r & o 4�q, Hemlock 7" 1t**,.A 74 7'a LandrBCollar A 1 at 12,846' PBTD=12,846' TD=12,933' Updated By:JLL 01/20/16 • 0 Monopod Platform A-27RD Current 11 01/19/2016 Hiburp:tla.ka.I.JA Monopod Platform Tubing hanger,CIW-F-FBB, A-27RD 11 X 3114 IBT lift and susp,w/ 20 X 16 X 133/8 X 95/8 X 3"type H BPV,1/8 non 7 x 334 continuous control line, 6 1/4"extended neck prep BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union lin imial Valve,Swab,CIW-FL, -1 31/85M FE,HWO,DD trim 4Z IMF Valve,SSV,Willis, �I C-20 i♦ • "111 I Valve,Master,OCT-20,31/85M FE,HWO,DD trim0,10:::-.0. ♦►� O0 Valve,Master,OCT-20, � 3 1/8 5M FE,HWO,DD trim 0:34*:01 Tubing head,CIW-AP - 115Mx115M,w/2- c1 - ,_`..-. - ei 2 1/16 5M SSO,w/X bottom ■■ uI '�, w/1-21/165M ■��li L � IHI _'��_ -i CIW-FC valve _.0. . :i i: im.., Casing spool,CIW-AP , / 135/83M x 115M,w/2- F. 2 1/16 SM 550,w/X bottom �L" r1 w/1-2 1/16 SM Ih — M � 11111�I_I-;l McEvoy C valve - J 1g1 cX11= r-- 4 -� .}- Casing spool,OCT-29L, --•lel `� 111 um 21 V.2M X 13 5/8 3M,w/2- _ 2 1/16 5M SSO, �� E• l�l_' 13 3/8-00 bottom ' 11-1I .I■II) 1 -RLht C-22 slips installed 181 I ' 1M1 • �! ., - Starting head,OCT Type II, gm `� ra 1a1 21 Y.2M X 20"SOW, - — -- w/4-21/162M SSO ; ; 16"casing hung off on mandrel 13 3/8"casing on C-29 slips '�f i' w SII=II 1.111 )111 ®, 16" 13 3/8" 9 5/8" 3 114" • • Monopod Platform 2016 BOP Stack(Workover) 01/08/2016 1rblr 1,rp. 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L 47.a C71‘ OsIO Q N O a. os e'a � Q a X u) .rn_ r U Q' — o c 16 a' y U x i0 �, 0 Q it 0 U Cti). — O V Tis -6 a) V = aoi 0 o) 2 u •r4 _ .0 C >,C7 a Q a��i 0 U) CO Q v w • • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,IAA, Attachment#1 Attachment #1 Hilcorp Alaska, LLC. BOP Test Procedure: Monopod Rig # 56 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru the flare to atmosphere. 2) Load well with FIW to kill well. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Check well is static, shoot fluid levels if necessary. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. Clean and inspect lift threads (screw sub into threads, count the number of turns). Install blanking sub if using one. 2) NU BOP 3) Test BOPE per Monopod Rig#56 BOPE test procedure. Initial Test(i.e.Tubing Hanger is in the Wellhead) Rolling BOP Test If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level, shoot fluid level with an echometer gun or tag with slick line to establish static fluid level if necessary. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift-threads to accept test joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set BPV and/or have lift-threads prepped for test joint. d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. • • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,LAttachment#1 LLC 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator or hanger leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC- guy.schwartz@alaska.gov)and Mr.Jim Regg(AOGCC-jim.regg@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: 5) With stack out of the test path, test choke manifold. 6) Conduct a rolling test: a. Test the rams and annular with the pump continuing to pump, holding a constant pressure on the equipment (monitor the surface equipment for leaks to ensure integrity). b. Record the pumping rate and pressure. 7) Once the BOPE tests are completed, test the remainder of the system following the normal test procedure (PVT,gas detection, etc.) 8) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment, list pressures and rates. 9) Pull hanger to surface (May require tubing cuts to free tubing) 10) Remove the old hanger, MU a new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. 11) Test BOPE per Monopod Rig#56 BOPE procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Rig 56 BOP TEST Open kill line valve, mud cross valves, all CMV except 15, open%"valves above valve 16, remove sensor above valve 3, and close all standpipe manifold valves. Fill stack w/water through kill line fill BOP and CMV's to top of annular. Close annular preventer X2 to get air out and continue to fill to top of dart valve. Close dart valve and continue to fill until fluid is seen out of CMV#5. Cont.fill till fluid comes out%" valves above CMV 16, close valve 16&4"kill valve on mud line. Open bleed line on standpipe manifold Have a hand in wellhead room w/casing valve open monitoring it open ended or to a gauge during all tests. In freezing temperatures, blow down mud line back through MP bleeder.Shell test. Test w/31/2 Ti 1) Close pipe rams, Open Annular, test CMV 3,5,15& 16, dart valve,pipe rams, 4"demco kill line valve, t/250 low f/5 min, 2500 high f/5 min (straight line time each and remaining tests) 14 410 • Monopod Rig#56 BOP Test Procedure • Hilcmp Alaska,LLc Attachment#1 2) Close TIW open dart valve, CMV's 8,9,12,13,14 kill line HCR, open CMV 15& 4"Demco kill line valve (drain gas buster "U"tube immediately in freezing temps) 3) Close CMV's, 1,7,10,11, manual kill line valve, open CMV's 8,9,12,14, & kill line HCR 4) Close CMV's 2,4,6, open valves 1,7& 13 5) Close HCR choke line, open CMV 2 6) Close manual choke line valve, open HCR choke line valve Preform Accumulator test....then pull TJ With test jt in hole&system up to pressure. 1) Turn off electric& air pumps 2) Record accumulator pressure (+-3000psi) 3) Close Annular,pipe ram's, & her valves, open pipe rams to simulate blinds 4) While pressure is stabilizing check pressure in nitrogen bottles& record. 5) Record accumulator pressure 6) Turn on electric pump& time seconds to pressure up 200 psi, turn on air pumps& time till unit pressures up to 3000 psi&shuts off. (time will start from time electric pump starts till all pumps shut off) 7) Back out test jt&pull, close blinds, install test hose to choke manifold outside valve 5, close valves 2,4,6, open valve 11, choke HCR& inside choke line valve 8) M/U 2 7/8 t/j, close annular,fill test jt w/test pump till tiw/dart valve is full, then close, test 9) Close pipe rams, open annular, close tiw, open dart valve FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Test PVT system 3) Double check all rams and valves, for correct operating position 4) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. I • Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday,January 27, 2016 4:14 PM To: Schwartz, Guy L (DOA); Roby, David S (DOA); Bettis, Patricia K (DOA) Cc: Juanita Lovett;Trudi Hallett Subject: RE:A-27RD1 Sidetrack(PTD 197-063) Attachments: Proposed A-27RD2.pptx Guy Here is a diagram that shows you the high level plan.The drilling permit will be submitted in the next couple of weeks. The A-27rd2 location is the red triangle that is circled,with the current A-27rd laying just to the north west.The A-27rd2 will remain in the same structure but move farther away from the fault to get into better quality rock.The latest well test information has the well producing around 90 bbls gross/20 bbls oil/No measurable formation gas. Here is a brief analysis from our reservoir engineer. Multiple wells have had low productivity in the Hemlock if they are too close to the major northeast-southwest fault(K-10, K26, K-26RD, and A-27RD). We want to sidetrack the A-27RD further away from the fault because we expect to find higher quality reservoir rock (higher permeability)and do not believe that this area is swept. The K-26 and K-26RD are the best analogs for this proposed sidetrack as the K-26 initially came on at lower 100 BOPD but was sidetracked 300' away from the fault and the K-26RD came online at rates over 1000 BOPD. Let us know if you have any additional questions on the A-27rd P&A Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(a�hilcorp.com Hilcorp A Company Built on Energy From: Schwartz, Guy L(DOA) [mailto:quv.schwartz@alaska.guf] Sent: Wednesday, January 27, 2016 3:41 PM To: Trudi Hallett Cc: Roby, David S (DOA); Bettis, Patricia K(DOA) Subject: A-27RD1 Sidetrack (PTD 197-063) Trudi, Please provide your justification and reasoning for P&A of A-27RD1 and sidetracking the well. 1 . N g • ... _ Nii.t........ ....-- 1.. %. 43 4;b>Al \\..„... O - K C 9820 - 03 11 0 / ..,- »- -----" a '" m r. 1 A x ��h h...ik a I. .,411 1 f\I-,ziNhvics, .......,,,,T . .„..,,,,, :.: , _ cp co __,. „,.. .... . , ,, . 7-j.i. r IL\ si‘„_, 71-c‘41. rib". (1., , \ N., co. `, A - brif 41%k:: 0 .ri jiptl.-i. 0 ' ------. - I in T 0 s.:, ... 6 401 8„,,,_ ,.. -414m,, regs... iv:. • 1 -,,,,„" i, A1Y/4:1_,Aiallifillaii '01,.. t‘ *11MM - , -. 1 co ,.0 ; "" %-'.*.- - * 4‘'IL -a-uid"' - 414 PAINN ts V \ - *„....-•‘:&.' ' 1-14*44 ' ''\ \Y ' ‘4‘ ' *I i \ *7 eg -, a � iitaillEst • 11 - 11, \ C ,,,,.-_ i., - v,- - taa. �� r i.1-__ Ma s'm e� ,, ;p_� �. i$ �� -- OSI Nil `� ' it; Ira l' , - . \� `�1 FR. z I arl ICi IS l it i ..' I I Ell O- I jl 1> 14 YY! ygj p( i$$ g Anil£l I j '12S; `Baha ldiii6 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or / "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist / work) the initial reviewer will cross out that erroneous entry and initial -then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July,the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. /~/~- ~-~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] GraYScale, halftones, pictures, graphs, charts -, Pages: [] Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. c~ Other, No/Type 'OVERSIZED D .Logs of vadous kinds ~ Other Complete COMMENTS: Scanned by: ~y Mildred-i~retha ~ Lowell · TO RE-SCAN Date: Notes: Re-Scanned by: eever~ U~red Darelha Nathan Lowell Date: /s/ • • r a SEAN PARNELL, GOVERNOR U LAU ALASKA OIL AND &AS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 April 6, 2012 Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524 -4027 RE: No -Flow Verification Trading Bay State A- 27RD1' APR 0 20 PTD 1970630 Dear Mr. Myers: On March 14, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay State A -27RD 1 located on the Monopod Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail -safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that Hilcorp verified no obstruction exists in the wellbore, the well was shut in, and calibrated flow measurement equipment with suitable range and accuracy was installed. The Trading Bay State A -27RD1 was monitored for flow for 3 hours through calibrated flow measurement equipment. During the flow monitoring periods, less than 300 standard cubic feet per hour was measured. There was no measurable liquid production to surface. The subsurface safety valve must be returned to service if Trading Bay State A -27RD1 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Monopod Platform. Sincerely, P> James B. Regg 1 Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I r DATE: March 14, 2012 P.I. Supervisor � ef 1 ' 1 6 `( 1 7_ FROM: Jeff Jones l 4 SUBJECT: No -Flow Test Petroleum Inspector Hilcorp Alaska LLC Trading Bay State A -27RD1 PTD 1970630 Monopod Platform March 14, 2012: I traveled to Hilcorp's Monopod Platform in Cook Inlet to witness a No -Flow Test on well A- 27RD1. On my arrival on the platform I met with Hilcorp Lead Operator Greg Geller and we discussed the operational details of the test. Mr. Geller indicated that the well pressure had been bled down and the wellbore perfs were open to the tree cap with no plugs or restrictions. Well A -27RD1 was lined up from the tree top swab valve through an Armor -Flow model # 3461 -03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 cubic feet per hour or 6.3 — gallons per hour flow rate during the test. Well A -27RD1 meets the AOGCC requirements for a No -Flow status determination. Summary: I witnessed a successful No -Flow Test on Hilcorp's Trading Bay State A -27RD1 on the Monopod Platform. Well No -Flow Test Data Operator: Hilcorp Operator Rep: Greg Geller AOGCC Rep: Jeff Jones Field/Unit /Pad TBF / Monopod PLT Well: A -27RD1 Time Well Flow Comments Gas Liquid 11:30 300 scfh none Start Test 12:00 250 scfh none 12:30 250 scfh none 13:00 300 scfh none 13:30 250 scfh none 14:00 250 scfh none 14:30 250 scfh none End Test Produced to open top container through Armor -Flow meter model #3461- 03T0 -13 ser. # 112377 Total liquid produced: no significant amount. Attachments: none 4 RJF 09/19/02 Page 1 of 1 2012 - 0314_ No - Flow _Trading_Bay_State_A- 27RD1Jj Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb~unocal.com UNO£AL Beverly Harrison Business Ventures Assistant May 30, 2002 To: Lisa Weepie AOGCC 333 W. 7th Ave. Anchorage, AK 99501 DATA TRANSMITTAL - Alaska / Offshore / Monopod Platform Dry Samples A-3RD 2 A-3RD 3 3492'-4890' 4890'-6210' 6210'-7262' 5980'-7240' 7240'-8350' 8350'-8525' Box 1 of 3 Box 2 of 3 Box 3 of 3 Box 1 of 3 Box 2 of 3 Box 3 of 3 A-8RD A-27RD 3440'-4510' 4510'-5590' 5590'-6850' 6880'-7641' 8460'-9600' 9600'-10710' 10710'-11640' 11640'-12660' 12700'-12900' Box 1 of 4 Box 2 of 4 Box 3 of 4 Box 4 of 4 Box 1 of 5 Box 2 of 5 . Box 3 of 5 Box 4 of 5 Box 5 of 5 Dry and ~,'ct Pl~knowledg~_re~J~i~.by signing and returning one copy of this transmittal or FAX to (907) 263-7828. · ~ :":';i' ...' ~ MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julia Heusser, ~'~\~\ Commissioner Tom Maunder, P. I. Supervisor o~c~,,~'° \ DATE: April 5, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field Thursday, ..April 5, 2001' I traveled to UNOCAL's Monopod Platform and witnessed the semi annual safety valve system testing. Lead operator Gary Smith conducted the testing today; he did a thorough job and was a pleasure to work with. As the AOGCC Safety Valve System test report indicates ! witnessed the testing of 18 wells and 53 components, with four ~ failUres, The pilot on well A-02 tripped at 26 psi and.was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well ^-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed, i indicated to Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 SSSV failed to close and will require maintenance. Wells A-13 and ^-21 have been certified as "no flow" status and do not have SSSV's installed. While on location ! inspected the platform and found it very clean and it appeared to be in excellent condition. Summary: I witneSsed the semi annual Safety Valve System testing at Unocal's Monopod Platform in the Trading Bay Field. Monopod Platform, 18 wells, 53 components. 4 failures, 7.5% failure rate. Platform inspection conducted. .A .tt~..chment: svs TBF Monopod Platform 4/5/01 JJ .NON-CONFIDENT.!AL SVS TBF Monopod Platform 4-5-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: UNOCAL Submitted By: Jeff Jones Date: 4/5/01 Operator Rep: Gary Smith Field/Unit/Pad: Trading Bay ,Field Monopod AOGCC Rep: Jeff Jones Separator psi: LPS 65 HPS i i . i Well Pemit Separ Set ~ T~t Test Test Date Oil, WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed GAS orCYCLE i i i i i i I i '~-01~ 1901470 65 45 42 P' P P Om A~02 1660490] ~ 65 45' 26 3 e 43 4/5/01 OIL A-03~3 1971300 65 45~ 42: P P P '"OIL A-~ 1670020~ A-06 1670250 65 45~ 45 P , P ~43 OIL A-07 1670460 65 45~' '42]P P P OIL 'X_og~ ~o36o ....... . ,, , , . . ., , . A-10 1670760 ~a~ ' ~7~40 ' 65 ~S 43 P P ~ .... , , , A-13 1680020 65 45 41 P P OIL A- 14 1680270 A-15' ~'1680330 65 45 45 P 'P P "OiL A-16~ '1880380 ..... 65 ' 45 4i/42 P '~ 'P ......... OIL A-I~ ~0670 65 45 43 P' P P ' 'OIL . ,, . ,. i , , . , , . A- 18 1680760 65 45 47 P P P OIL A-21 1700470 65 45 46 P P OIL A-22' ~7003'i0 '6S~ 45 ' ~' P P P O~L A_23' ,~700590 ...... A-23OpN ~720200 ' ' A-24~ ~0400 6S 4S" '~i P P P ~~: 1970630 ' ' '65 45 43 'P P' P " OIL A-2a~' ~90920 " 65 45 45 P P P ....O~ A-30 1730140 ...... A-32 1770180 65 45 44 P P P o~L ,, ,. , , , Wells: 18 Components: 53 Failures: ~4 Failure Rate: 7.5% Flgo var Remarks: A-13 & A-21 reported as No-Flow Wells. SSSV's removed for repair: A-02 out since 2/24/00. A-11 out since 11/7/99. , .,A.-0.,2 p~o,t repaired and r.etested "OK". A-06 SSSV failed to close. A-16 RD is a dual completion. 4/9/01 Page 1 of 1 SVS TBF Monopod Platform 4-5-01 JJ 01'4 OR ggFO C:LORBI,41~ILwLDOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/24/99 RUN RECVD /97-063 /97-063 97-063 ~97-063 ~97-063 "97-063 97-063 ~97-063 97-063 DEPTH DET/TCP PROD PACKER COMP RCD CBT SRVY CALC COMP RCD PROD ~11900-12300 100- 2250 /~i0/97 12500-12865 ~400-12918 PEX-LDT/NL ~444-12033.4 PEX-RES AI~AT/GR ~8444-12033.4 ~BH8450.-12933 10-407 ~OMPLETION DATE ~ &/2t DAILY WELL OPS _~Y/;Z/~7/ TO ~ /~/q~ T D BOX .... Are dry ditch samples required? yes ~____~_~nd received? Was the well cored? yes ~Analysis & description received? Are well tests required? yes ~Received? ~ Well is in compliance Initial COMMENTS 1 08~28/97 1 08~28/97 1 08/28/97 1 08~28/97 1 08/28/97 1 08/28/97 10/23/97 1 05/20/98 F IN~u~ ~71' 2 ~9~-~ Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih chfldersd@unocal, com UNOCAL ) Debra Childers Geotech Assistant DATA TRANSMITTAL May 12, 1998 To: Laurie Taylor From: Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Anchorage, AK 99519-6247 Alaska Oil & Gas Unocal Transmitting the following items: SMSG 18746-15 1 1 5" Completion Record 2 1/8" HSD 1 4/17/98 TBF A-11 1 1 5" Completion Record 1 5/01/98 TBF A-27RD t 1 1 5" Completion Record 1 4/13/98 TBU D-47 1 1 5" Completion Record 2 7/8" HSD 1 4/01/98 ' TBU ~ ~-i,"/ 1 1 5" Completion Record 2 ½" HSD 1 4/12/98 TBU G-36-SPN ~) 1 1 5" TCP Correlation Log GR/CCL 1 4/25/98 TBU G-7 1 1 5" Gamma Ray/CCL Log 1 4/09/98 TBU Go7 1 1 5" Completion Record 2 7/~" HSD 1 4/10/98 Please acknowledge receipt.~ signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received b¥:~~ Date: .. ' ' STATE OF ALASKA - ALASKA Oi- AND GAS CONSERVATION CU,dMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal '- -~. i~7-i~i ~'~:~' ~-;-;;,¥" ':-' 97-63 3. Address i(',,~, ~.,~'~ "~'r'&7;: ~.: 8. APl Number P.O. Box 196247 Anchorage, AK 99519 .~L.~"'~_~._~.~_~ 50- 733-20246-01 4. LocalJon ofwell atsurface Conductor#5 i ~~ ~'. _. · . :~ ~ 9. Unit or Lease Name 1605' FSL & 553' FEL, Sec. 4, T9N, R13W, SM ..--¢-VLL..,-~_¢-~.~ :,~ ,, Trading Bay State At Top Producing Interval ~ ............... ¢¢ ...¢* ~:;~~ 10. Well Number 1328' FSL & 64' FEL, Sec. 8, T9N, R13W, SM @ 12389' MD / 9501' TVD~.~, ,..--,w.. -~.;:,.~._~r¢:. A~27RD At Total Depth :;~~-'~' 11. Field and Pool 1215' FSL& 354' FEL, Sec. 8, T9N, R13W, SM @ 12933'MD / 9947' TVD Hemlock 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease DesignatiOn and Serial No. 101 MSLI ADL 18731 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Complelions 5/12/1997 6/6/1997I 6/21/97 62' feet MSL None 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) I 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 12933' MD/9948'TVD 12923' MD/9939'TVDI Yes: X No: 326' feetMDI N/A 22. Type Electric or Other Logs Run 1st Run ARI \ LDT \ CNL \ Sonic 2nd Run LWD \ RAB Azimuthual 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'II'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 45 225' Driven 16" 65# H-40 45 1065' 22" 950 sx 13-3/8" 61# K-55 45 4009' 18-5/8" 2000 sx 9-5/8" 47# S-95 45 9450' 12-1/4" 2600 sx 7" 29# L-80 7687 12923' 8-1/2" 1806 sx 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2", 9.2#, L-80 12304' 12217' 12,392-12,406'; 12,448-12,581'; 12,595-12647' MD (6SPF) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9,503 - 9,513'; 9,548 - 9,656'; 9,668 - 9,712' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Producl~on I Method of Operation (Rowing, gas lift, etc.) 7/3/1997I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER;BBL CHOKE SIZE I GAS-OIL RATIO 7/3/97 24 TEST PERIOD => 140 0 0I 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 70 620 24-HOUR RATE => 140 0 0 33 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~ 29. T 30. GEOLOGIC MARKERS~ FORMATION TESTS NAME I I Include interval tested, pressure data, all fluids recovered and gravity, ' MEAS. DEPTH I TRUE VERT. DE.P-,~H ! GOR, and time of each phase. I (Producing zone) 12,450' 9.539 I 31. LIST OF A'I-FACHMENTS Daily Operations Summary, Wellbore Diagram 32. I hereby certify that the foregoing is true and correct to the best of-my knowledge Dale A. Haines /~,-,/'/mi Drilling Manager 'October 17, 1997 Signed~,.,'~c..~ it c4z,-,- Title 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 elevalJon is used as reference (where not otherwise shown) for depth measurements given in other space 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 productin 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 lor 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". Form 10-407 MONOPOD PLATFORM HISTORICAL SUMMARY 50-733-20246-01 WELL A-27RD 1997 4/5 5/12-16 5/16-21 5/22-28 5/29-6/3 6/5-10 RELEASE RIG: 4/5/97 @ 0600 HRS (P&A'd A-27). ACCEPT RIG: 5/12/97 @ 1800 HRS (REDRILL A-27RD). NU & TEST AP CASING SPOOL. NU & TEST BOP. RIH TO 464' & RETRIEVE STORM PACKER, POOH & LD SAME. RIH W/8-1/2" BIT & SCRAPER TO 8483' PBTD. CCH. POOH MU & RIH W/WHIPSTOCK. WHIPSTOCK SET DOWN @ 6082'. JARRED FREE & POOH. RIH W/8-1/2" CLEANOUT MILL ASSEMBLY. CLEANED UP RATTY CASING F/ 6047'-6065'. RIH TO 8222'. COULD NOT WORK WHIPSTOCK ASSEMBLY PAST 6489'. POOH. RIH W/CLEANOUT MILLING ASSEMBLY. WIPED OUT ROUGH SPOTS IN CASING @ 6090'-6115' & 6460'-6470'. RIH TO BOTTOM @ 8483'. CCH. MU BOTTOM TRIP WHIPSTOCK ASSEMBLY. RIH. CORRELATE & ORIENT WHIPSTOCK. TRIP WHIPSTOCK ON BOTTOM & SET TOP @ 8452'. SHEAR STARTING MILL & MILL WINDOW F/8451'-8455'. POOH. MU & RIH W/WINDOW MILL ASSEMBLY. MILL WINDOW F/8451'-8463'. DRILL NEW FORMATION F/8463'-8475'. POOH. MU & RIH W/DRESSING MILL ASSEMBLY. DRESS WINDOW F/8451 '-8463'. POOH. RIH W/8-1/2" MOTOR ASSEMBLY. DRILLED 8-1/2" HOLE F/8475'-8613'. POOH F/BIT & BHA CHANGE. RIH W/8-1/2" MOTOR ASSEMBLY. DRILLED 8-1/2" HOLE F/ 8613'- 9757'. STUCK PIPE @ 9724' WHILE REAMING HOLE TO MAKE A CONNECTION. JARRED PIPE FREE. LOST PUMP PRESSURE. POOH FOR WASHOUT. FOUND WASHOUT @ 1147'. TEST BOP. RIH W/MOTOR ASSEMBLY. DRILLED 8-1/2" HOLE F/9757'-9904'. LOST PUMP PRESSURE. POOH & FOUND WASHOUT @ 393' CHANGE OUT UPPER 3000' OF S135 DRILL PIPE. RIH. DRILL 8- 1/2" HOLE F/9904'-10666'. DEVELOPED HOLE IN DRILL PIPE. POOH & FOUND HOLE @ 408'. LAYED DOWN UPPER STRING OF 5" DRILL PIPE & REPLACED. RIH. DRILL 8- 1/2" HOLE F/1-666'-11009'. POOH F/BIT. RIH W/MOTOR ASSEMBLY. DRILL 8-1/2" HOLE F/11009'-11252'. POOH F/BIT. RIH W/MOTOR ASSEMBLY. DRILL 8-1/2" HOLE F/11252'-11829'. POOH FOR NEW BIT & TORQUE REDUCTION SUBS. TEST BOP. INSTALL TORQUE REDUCTION SUBS. RIH W/MOTOR ASSEMBLY. INSPECTED BLOCKS AND HANGING LINE. HUNG BLOCKS AND SLIPPED 600' DRILLING LINE ON TO DRUM. REMOVED ROTARY HOSE AND "S" PIPE FROM TOP DRIVE. LAID DWN BLOCKS ON RIG FLOOR AND UNSTRUNG. INSTALLED FALL PROTECTION. REMOVED TONG & AIR TUGGER SHEAVES & LINES. INSTALLED TEMP JACKING BEAM. REMOVED DAMAGED CROWN SUPPORT BEAM. SERVICE DRAWWORKS BRAKES AND TOP DRIVE RAIL GUIDE. REPAIR DAMAGED MONKEY BOARD AND RE-INSTALL. INSTALLED CROWN SUPPORT BEAMS. TIGHTEN CROWN SUPPORT BEAM. RE-STRING TONG AND TUGGER LINES AND STRING BLOCKS. RIH WITH BHA NO.11 ENCOUNTERED TIGHT SPOT AT 12,207'. PIPE STUCK AT 12,207',. LOST ABILITY TO CIRCULATE AND HEAVY JARRING DOWN REQUIRED TO FREE PIPE. CONTINUED REAMING IN HOLE TO 12,678'. DRILLED 8-1/2" HOLE FROM 12,678' TO 12,933'. POOH AND RIG UP SCHLUMBERGER. RIH WITH RUN NO. 1 HALS/LDT/CNL/GR/AMS. TOOL UNABLE TO PASS 11,239'. LOG INTERVAL FROM 6/11 6/12 6/13-15 11,239 TO WINDOW AT 8,451 ". RE-CONFIGURE LOGGING TOOLS AND RE-RUN. UNABLE TO PASS 11,239'. POOH AND RIG DOWN SCHLUMBERGER. RIH WITH CLEAN OUT ASSEMBLY ON MUD MOTOR. REAM THROUGH SLOUGHING COALS AT 11242', 11468', AND 12178'. PUMP DENSIFIED HI-VIS PILL AND POOH WITH MINOR OVERPULLS. RIG UP SCHLUMBERGER AND RE-RUN HALS/LDT/CNL/GR/AMS. TOOL UNABLE TO PASS 11,280'. POOH AND RIG DOWN SCHLUMBERGER. RIH WITH CLEAN OUT ASSEMBLY. REAM THROUGH TIGHT SPOTS AT 12060', 12265-95' AND 12325'. POOH TO SHOE WITH EXCESSIVE OVER-PULLS. RIH AND WIPE OUT TIGHT SPOTS. CIRCULATE BOTTOMS UP TO CLEAN WELLBORE AND POOH FOR LWD LOGGING RUN. RIG UP SCHLUMBERGER AND RIH WITH HALS/LDT/CNL/GR/AMS. UNABLE TO WORK PAST 11,560'. POOH WITH TIGHT SPOTS AT 11255', AND 8985'. RIG UP ANADRILL SURFACE LWD EQUIPMENT AND MAKE UP LWD ASSEMBLY ON MUD MOTOR. RIH TO 6,332'. RIH WITH LWD ASSEMBLY TO 11,659'. LOG FROM 11,650' TO 11,890' AT 180 b-T/HR. LOG FROM 11,890' TO 12,360' AT 300-600 FT/HR. LOG FROM 12,360' TO 12,526' AT 180 FT/HR. LOG FROM 12,526' TO12,623' AT 50 FT/HR. LOG FROM 12,623 TO 12,907 (BIT AT TD) AT 180 FT/HR. CIRCULATE HOLE CLEAN AND POOH WITH MODERATE OVERPULLS. CONTINUE POOH AND L/D LWD ASSEMBLY. DOWNLOAD LOG DATA AND PREPARE TO RUN 7" LINER. CONTINUE POOH AND L/D LWD ASSEMBLY. DOWNLOAD LOG DATA AND INTE~RET LOGS. PERFORM WEEKLY BOP TEST. CHANGE OUT FAULTY BRAKE BANDS ON DRAW-WORKS. MAKE UP BHA AND RIH FOR WIPER TRIP. WORK THROUGH TIGHT SPOTS AND PUMP DENSIFIED SWEEP ON BOTTOM UP. PREPARE TO POOH TO RUN LINER. CONTINUE RIH FOR WIPER TRIP. WORK THROUGH TIGHT SPOTS AND PUMP DENSIFIED SWEEP ON BOTTOM UP. POOH TO RUN LINER. CHANGE OUT UPPER PIPE RAMS TO 7" CASING RAMS AND TEST TO 3,500 PSI. RIH WITH 128 JTS OF 7" 29LB/FT L-80 TKC CASING. MAKE UP LINER HANGER AND CIRCULATE ONE LINER VOLUME. CONTINUE RIH 7" LINER ON DRILLPIPE. TAKE UP/DOWN AND TORQUE READING AT SHOE AND CONTINUE RIH TO TD AT 12,933'. CEMENT LINER WITH 172 BBLS G CEMENT WITH 4% D-20, .5% B-71 MIXED AT ASW OF 12.9 LB/GAL FOLLOWED BY 149 BBLS G CEMENT WITH 1.3 GPS D-300 AND .15 GPS D-145. DISPLACED CEMENT AND BUMPED PLUG WITH 5 BBLS FIW AND 333 BBLS MUD. SET HANGAR WITH 3000 PSI AND RELEASED FROM HANGAR WITH 4500 PSI. PU AND CIRCULATE OUT CONTAMINATED MUD, CEMENT FROM WELL. POOH WITH RUNNING TOOL LAYING DOWN EXCESS 5" DP. M/U POLISHING MILL ASSY. AND RIH TO TOL AT 7678'. DRESSED OFF LINER TOP AND POOH LAYING DOWN EXCESS DP. M/U 7" TIE-BACK STRING WITH BAKER 7" ZXP PACKER AND HOWCO ES CEMENTER STAGE COLLAR. RIH WITH 7" 29 LB/FT L-80 BuTr. CASING. STAB INTO TIE-BACK SELAS AND P/T TO 2000 PSI. SET ZXP PACKER AND PFF TO 2800 PSI. CEMENTED TIE-BACK LINER WITH 91 BBLS G CEMENT WITH 4% D-20 AND .5 % B-71 MIXED AT ASW OF 12.9 LB/GAL DISPLACED CEMENT WITH MUD AND BUMPED PLUG WITH 3000 PSI. PFU BOP'S AND SET CASING SLIPS WITH 100K OVERPULL. MADE ROUGH CUT AND INSTALLED TUBING SPOOL. PI' TO 5000 PSI. NFLI BOP'S AND INSTALL VBR'S IN TOP RAMS. PRESSURE TESTED 7" CSG TO 3500 PSI FOR 30 MINS. DRILLED CMT F/7621'-7629'. RIH TO 7696' & RIGGED UP HALLIBURTON PUMP @ 2400 HRS. 6/16 CONT RIH W/CLEAN OUT ASSY, PICKING UP 3-1/2" DP @ 0600 HRS. P/T 7" CASING TO 3500 PSI. CONT. RIH AND CLEAN OUT CASING TO 12,923'. PI` CASING TO 3500 PSI. DISPLACE WELL TO 3% KCL AND POOH. 6/18-22 POOH WITH CLEAN OUT ASSEMBLY. R/U SCHLUMBERGER AND RUN CBT/GR/CCL FROM ETD AT 12,926' TO 4,200'. R/D SCHLUMBERGER. M/U HALLIBURTON TCP GUN ASSEMBLY (199' OF 4-5/8" , 32GM DEEP PENETRATING, 6SPF, 60 DEG PHASING). RIH AND SPACE OUT GUNS WITH SCHLUMBERGER GR/CCL. CORRELATE AND SPACE OUT GUNS. SET CHAMP PACKER AND RIG UP SURFACE LINES. PERFORATE WELL INTERVAL FROM 12392-12647', 12448-12581', AND 12595-12647'. FLOW WELL FOR 60 MIN TO EVALUATE WELL RESPONSE. SHUT IN WELL AND REVERSE OUT THROUGH CHAMP PACKER BYPASS TO PRODUCTION FACILITIES. UNSEAT PACKER AND CIRCULATE OUT LONG WAY. RIG DOWN SURFACE LINES AND POOH WITH TCP ASSEMBLY. LAY DOWN EXCESS DRILLPIPE AND DC'S. 6/19 i)F - Perforate Hemlock W/4-5/8" TCP Guns, 6HPF, 60 Phase Zone Interval Feet HB-1 12,392'- 12,406' 14' HB-2&3 12,448' - 12,581' 133' HB-3&4 12,595'- 12,647' 52__~' TOTAL 199' 6/22 CONTINUE LAYING DOWN EXCESS DRILLPIPE AND DC'S. R/U SCHLUMBERGER . M/U HALLIBURTON VTL RETRIEVABLE PACKER ON E-LINE SETTING TOOL. RIH WITH PACKER ASSEMBLY. UNABLE TO PASS 7601' (7" DV TOOL). POOH AND CHECK TOOLS . RUN BACK IN HOLE WITH PACKER AND SET AT 12,216'. R/D SCHLUMBERGER. R/U TO RUN COMPLETION TUBING. RUN 3-1/2" COMPLETION TUBING TO PACKER SET AT 12,216'. STAB SEALS INTO PACKER AND TEST TUBING TO 2000 PSI. ( NO ANNULUS COMMUNICATION). LAND HANGAR WITH NEUTRAL WEIGHT ON TUBING. N/D BOP'S AND NFU TREE. TEST TREE TO 5000 PSI. INSTALL FLOWLINES AND PREPARE TO SKID RIG. RIG RELEASED TO A-8RD2 AT 1500 HRS 22 JUNE 1997. APl 50-733-20246-01 Monopod Plof, form Conductor 5 TBS A-27Rd Trading ~ay State Trading uay Field RKB Elev. 101 FI:. MSL Tbq Heed FI9 Dep[h 57.50 Fl:. Micr-Perf Devietion 45.0 Begs. 20.0 - 1045.0' 16" OD 65.00#/f1:H-40 SURF CSG 1045.0 - 1045.0' SHOE'::::: 20.0 - 4009.0' 1,3,3/8" OD 61.O0#/ft K-55 INT CSC 4009.0 - 4009.0' SHOE 20.0 - 8451.0' 9 5/8" OD 47.00#/ft S-95/N-80 PROD CS(; 8451.0 - 8451.0' SHOE 5/16/97 L20.4 - 21.1' HANGER Cameron AP ,. 326.1 - 328.5' 2.813" ID SSSV HES "XXO" SVLN 2525.1 - 2532.1' (;ASLIFT VALVE #1, McMurry SMO-1 GLM 4541.9 - 4348.9' GASLIFT VALVE//2, McMurry SMO-1 GLM 5415.1 - 5420.1' OASLIFT VALVE//,3, McMurry SMO-1 GLMM 6231.6 - 6258.6' GASLIFT VALVE//4, McMurry SMO-1 GLM 6961.0 - 6968.0' GASLIFT VALVE #5, McMurry SMO-1 GLM 76,.30.4 - 76,37.5' GASLIFT VALVE//6, McMurry SMO-1 GLM 8270.5 - 8277.6' OASLIFT VALVE//7, McMurry SMO-1 GLM 8871.8 - 8878.9' OASLIFT VALVE//8, McMurry SMO-1 OLM 9444.5 - 9451.4' OASLIFT VALVE//9, McMurry SMO-1 OLM 9958.3 - 9965.4' GASLIFT VALVE//10, McMurry SMO-1 GLM 105,32.5 - 105.39.6' OASLIFT VALVE #11, McMurry SMO-1 GLM 11078.8 - 11'085.8' GASLIFT VALVE #12, McMurry SMO-1 GLM 11650.1 - 11657.1' OASLIFT VALVE JJ15, McMurry SMO- 1 GLM KB ELEV: 101' PBTD: 12923' TD: 129,33' APl 50-733-20246-01 Monopod PIG[form Conductor ,.5 TBS A-27Rd Trading B_ay State Trading Bay Field RKB Elev. 101 Ft. MSL Tbq Head Fig Dep[h 37.50 FI[. Mid--Perf Deviolion 45.0 Degs. 19.0 - 12737.0' 7" OD 29.O0#/ft L-80 LINER 12730.0 - 12933.0' CEMENT PLUG 6/14/97 12735.0 - 12737.0' SHOE KB ELEV: 101' PBTD: 1292,:3' I'D: 129,.t3' 20.4 - 12216.8' ,3.500" OD 9,20#/fi L-80 TBG 6/21/97 12128.2 - 121,35.2' GASLIFT VALVE//14, McMurry SMO-I GLM 12174.5 12216.8 12216.3 12216.8 12216.8 12270.9 12303.4 - 12179.0' 2.813" ID SLEEVE HES "XU" - 12237.4' RETRV. PACKER HES VrL Pkr. W/Seal Bore Ext. - 12216.8' LOCATOR JOINT - 12303.4' 5.500" OD 9.20#/f[ L-80 TBG 6/21/97 - 12255.4' SEALS - 12272.3' 2.813" ID LANDING NIPPLE HES "X" - 12304.0' 2.992" ID MULESHOE 12392.0 - 12406.0' PERFS HB, 6/18/97, 6SPF, 14', 4-5/8" 'rcP Guns, 60 Phase 12448.0 - 12581.0' PERFS HB, 6/18/97, 6SPF, 153', 4-5/8" TCP Guns, 60 Phase 12595.0 - 12647.0' PERFS HB, 6/18/97, 6SPF, 52', 4-5/8" TCP Guns, 60 Phase 'ii I;=_] Company UNOCAL Rig Contractor & No. Pool Arotio Alaska-Monopod Field TRADING BAY UNIT " Well Name & No. MONOPOD PLATFORM/A-27RD Survey Section Name Definitive Survey BHI Rep. MILLER, SUTHERLAND ~lli~Jl=~¢l~ ......... WELL DATA ........ i Target TVD (i-r) Target Coord. N/S Slot Coord. N/S 1605.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. EAN -553.00 Magn. Declination 22.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOftL~ 30m0 lomL-] Vert. Sec. Azim. 236.39 Magn. to Map Corr. 22.000 Map North to: OTHER " "' "" '" ' " ' SURVEY DATA '" " ' ' " ' " Survey Survey Incl. Hole Course Vertical ' Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DD) (FT) __(.FT) (F'T) (F'r) (_P_er m0 FD Drop (-) Left (-) GMS 8450.00 47.10 223.50 6328.37 4748.20 -4365.70 -2798.80 TIE IN POINT 19-MAY-97 MWD 8694.00 40.70 230.98 244.00 6504.21 4914.09 -4480.81 -2922.34 3.37 -2.62 3.07. -- ........... 19-MAY-97 MWD 8788.00 37.20 232.49 94.00 6577.31 4972.98 -4517.42 -2968.71 3.86 -3.72 1.61 .......... 19- MAY-97 MWD 8881.00 36.30 233.19 93.00 6651.82 5028.51 -4551.04 -3013.05 1.07 -0.97 0.75 20-MAY-97 MWD 8975.00 35.90 236.37 94.00 6727.78 5083.86 -4582.97 -3058.28 2.04 -0.43 3.38 .-m 20-MAY-97 MWD 9068.00 35.70 237.79 93.00 6803.21 5138.25 -4612.54 -3103.94 0.92 -0.22 1.53 20-MAY-97 MWD 9161.00 34.80 238.51 93.00 6879.16 5191.90 -4640.87 -3149.53 1.07 -0.97 0.77 ~ 20-MAY-97 MWD 9348.00 34.20 241.67 187.00 7033.28 5297.57 -4693.68 -3241.30 1.01 -0.32 1.69 20-MAY-97 MWD 9442.00 33.90 241.12 94.00 7111.16 5350.00 -4718.88 -3287.51 0.46 -0.32 -0.59 21 -MAY-97 MWD 9534.00 34.20 240.99 92.00 7187.39 5401.34 -4743.81 -3332.59 0.34 0.33 -0.14 21 -MAY-97 MWD 9626.00 34.00 240.74 92.00 7263.57 5452.76 -4768.92 -3377.64 0.27 -0.22 -0.27 -- 22-MAY-97 MWD 9752.00 33.50 241.75 126.00 7368.34 5522.51 -4802.60 -3439.01 0.60 -0.40 0.80 , , 22-MAY-97 MWD 9846.00 33.90 241.23 94.00 7446.54 5574.46 -4827.50 -3484.84 0.52 0.43 -0.55 23-MAY-97 MWD 9941.00 34.50 240.42 95.00 7525.12 5627.69 -4853.53 -3531.46 0.79 0.63 -0.85 23-MAY-97 MWD 10034.00 34.70 242.14 93.00 7601.67 5680.30 -4878.90 -3577.77 1.07 0.22 1.85 23-MAY-97 MWD 10128.00 34.50 240.26 94.00 7679.05 5733.49 -4904.61 -3624.54 1.16 -0.21 -2.00 23-MAY-97 MWD 10221.00 35.60 236.73 93.00 7755.19 5786.84 -4932.53 -3670.04 2.48 1.18 -3.80 .- _ 23-MAY-97 MWD 10316.00 35.90 235.66 95.00 7832.29 5842.34 -4963.41 -3716.16 0.73 0.32 -1.13 23-MAY-97 MWD 10410.00 35.80 235.99 94.00 7908.48 5897.39 -4994.34 -3761.71 0.23 -0.11 0.35 24-MAY-97 MWD 10505.00 35.50 236.29 95.00 7985.68 5952.76 -5025.19 -3807.69 0.37 -0.32 0.32 24-MAY-97 MWD 10598.00 35.50 237.28 93.00 8061.39 6006.76 -5054.77 -3852.87 0.62 0.00 1.06 24-MAY-97 MWD 10656.00 35.40 239.10 58.00 8108.64 6040.38 -5072.50 -3881.45 1.83 -0.17 3.14 24-MAY-97 MWD 10750.00 35.20 239.36 94.00 8185.35 6094.63 -5100.29 -3928.12 0.27 -0.21 0.28 25-MAY-97 MWD 10~43.00 36.00 240.05 93.00 8260.97 6148.68 -5127.59 -1 -3974.87 0.96 0.86 0.74 : n Job No. 0450-85474 Sidetrack No. 1 Page ....... .2. .... of { -~ (!~rr] :l :~r~--~ Company Rig Contractor & No, Pool Arctic Monopod Field UNOCAL Alaska- TRADING BAY UNIT /I Well Name & No, MONOPOD PLATFORM/A-27RD Survey Section Name Definitive Survey BHI Rep. MILLER, SUTHERLAND WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord, N/S 1605.00 Grid Correction 0.000 Depths Measured From: RKB ~(] MSL~J SS~]' Target Description Target Coord. E/W Slot Coord. E/W -553.00 Magn. Declination '22,000 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft~ 30m~ 10mQ Vert, Sec. Azim. 236.39 Magn. to Map Corr. 22.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'rVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DO) (DD) (FT) (IT) (FT) (FT) (Per mO ET) Drop (-) Left (-) -- 25-MAY-97 MWD 10938,00 36,30 244.40 95.00 8337.70 6204.40 -5153.69 -4024.43 2.72 0,32 4,58 26-MAY-97 MWD 10971.00 36.90 245.01 33,00 8364,19 6223.87 -5162,09 -4042.22 2.13 1.82 1,85 26-MAY-97 MWD 11066.00 36.90 243.10 95.00 8440.16 6280,39 -5187,05 -4093.50 1.21 0,00 -2,01 26-MAY-97 MWD 11160,00 36.80 242,79 94,00 8515,38 6336,40 -5212,69 -4143.71 0.22 -0,11 -0.33' 26-MAY-97 MWD 11212.00 36.80 242,57 52.00 8557.02 6367.36 -5226,98 -4171.38 0.25 0.00 -0.42 -- 27-MAY-97 MWD 11254.00 37.40 242,07 42.00 8590.52 6392.56 -5238.75 -4193.82 1.60 1.43 -1.19 27-MAY-97 MWD 11348.00 37.30 240.49 94.00 8665.24 6449,37 -5266.15 -4243.82 1.03 -0.11 -1,68 ' 27-MAY-97 MWD 11443.00 37.40 241.18 95.00 8740.76 6506.83 -5294.24 -4294.15 0.45 0,11 0.73 27-MAY-97 MWD 11536.00 36.80 239.64 93.00 8814.94 6562.79 -5321.94 -4342.93 1.19 -0.65 -1.66 28-MAY-97 MWD 11632.00 36.80 240.26 96.00 8891.81 6620.19 -5350.73 -4392,71 0,39 0.00 0,65 28-MAY-97 MWD 1'1727,00 37.10 240.40 95.00 8967,73 6677,16 -5379.00 -4442,33 0.33 0.32 0.15 - 28-MAY-97 MWD 11784.00 36.90 239.33 57.00 9013.25 6711.40 -5396.22 -4472.00 1.18 -0.35 -1.88 _ -- 29-MAY-97 MWD 11827.00 36.70 239.20 43.00 9047.68 6737.12 -5409.38 -4494.14 0.50 -0.47 -0.30 ' 29-MAY-97 MWD 11923.00 36.20 241.31 96.00 9124.91 6794.02 -5437,68 -4543.65 1,41 -0.52 2,20 30-MAY-97 MWD 12018,00 35.80 242.65 95.00 9201.76 6849.59 -5463,92 -4592,94 0.93 - -0.42 1.41 31-MAY-97 MWD 12105.00 36.30 243.34 87.00 9272.10 6900.45 -5487.16 -4638,55 0.74 0.57 0,79 31-MAY-97 MWD 12201.00 36.30 244.24 96.00 9349.47 6956.81 -5512.26 -4689.54 0.56 0,00 0.94 --. 31-MAY-97 MWD 12296.00 36,60 245.33 95.00 9425.89 7012.64 -5536.31 -4740.60 0.75 0.32 1.15 .... 31 -MAY-97 MWD 12393.00 36.10 246.94 97.00 9504.02 7069.30 -5559.57 -4793.18 1.11 -0,52 1.66 01-JUN-97 MWD 12493.00 35.60 248.83 100.00 9585.07 7126.69 -5581,62 -4847.42 1,21 -0.50 1.89 J, 01 -J U N-97 MWD 12590.00 34.80 249.00 97.00 9664.34 7181.27 -5601.74 -4899.59 0.83 -0.82 0.18 -- 01-JUN-97 MWD 12640.00 34.30 249.53 50.00 9705.52 7208.91 -5611.78 -4926.11 1.17 -1.00 1,06 I I I IIIII I II TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 17, 1997 Dan Williamson Drilling Manager Union Oil Company of California P O Box 196247 Anchorage, AK 99519-6247 Re: Trading Bay State A-27RD UNOCAL Permit No. 97-63 Sur. Loc. 1605'FSL & 553'FEL, Sec. 4, T9N, R13W, SM Btmnhole Loc. 1136'FSL & 185'FEL, Sec 8, T9N, R13W, SM Dear Mr. Williamson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. Chairma~n~-~..__~ BY ORDER OF THE COMMISSION dlffEnclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA AND GAS CONSERVATION _ OMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Ddll: Redrill: x lb. Type of well Exploratory: Stratigraphic Test: Development Oil: x Re-Entry: Deepen: Service: Developement Gas: Single 7one: Multipie Zone: ~, r',?h,,-n Flevation (DF or KB) KB 101 feet 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247 Anchorage, AK 99519-6247 4. Location of well at surface Conductor #5 1605' FSL & 553' FEL, Sec. 4, T9N, R13W SM At top of productive interval ~ 12055' MD / 9250' TVD 1360' FSL& 152' FWL, Sec. 9, T9N, R13W SM At total depth ~ 12737' MD / 9800' TVD 1136' FSL& 185' FEL Sec. 8, T9N, R13W SM 12. Distance to nearest property line 1136' feet 13. Distance to nearest well King Salmon K-26rd 3158' @ 9800' TVD 16. To be completed for deviated wells Kickoff depth: 8125' feet Maximum hole angle: 18. Casing program size feet J Grade J Coupling JBTC JBTC 6. Property Designation ADL 18731 7. Unit or property Name TRADING BAY STATE 8. Well number A-27RD 9. Approximate spud date 4/21/97 14. Number of acres in property 3840 10. Field and Pool TRADING BAY FIELD/ i ':E,¥1LOCK 11. Type Bond (~ee 20 AAC 25.025) AK STATEWIDE OIL & GAS BOND Number U62-9269 Amount $200,000 15. Proposed depth (MD and 'I'VD) 12737' MD / 9800' 'rVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 608 psig At total depth (TVD) Setting Depth 3771 psig TVD MD 065 4009' 8125' KOP 12737' Quantity of cement Specifications Top Bottom Hole Casing Weight Length MD TVD (include stage data) EXISTING 6" 65 1020' 45' 1031 950 sx EXISTING 3-3/8" 61 3964' 45' 3216' 2000 SX EXISTING 9.5/8" 47 8080' 45' 6104' 2600 SX 8-1/2' 7" 29 12692' 45' 9800' 1800 sx 19. To be completed for Reddll, Re-entry~ and Deepen Operatmr~. Present well condition summary Total depth: measured 9450' feet true vertical 7031' feet cmt ret. @ 5878' cmt ret. @ 7080' cmt ret. ~ 7300' cmt ret. ~ 8615' cmt ret. ~ 8825' Effective depth: measured 5878' feet .. :~ i:-~ ': ." :: -~:'~' true vertical 4539' feet . . . Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1020' 16' 950 sx 1065' 1031' Surface 3964' 13-3/6" 2000 sx 4009' 3216' Intermediate Production 8080' 9.5/8' 2600 sx 9450' 7031' Liner Perforation depth: measured see attached schernatic ORIGINAL true verticalsee attached schematic 20. Attachments: Filing fee: x Property Plat: x BOP Sketch: x Diverter Sketch: Drilling program: x Drilling fluid program: x Time vs. depth plot: x Refraction analysis: Seabed report: 20 AAC 25.050 requirements: x 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Date: J Permr,,C~,,,~,,~mbe,~,,,=,,.~ JAP, number 4:::)/J Approval date "'~ J CondOne ofappro~l Samples require: [ ] Yes ~No Mud log required: [ ] Yes ~No Hydr~ sulfide measures ~Y~ [ ] No Dir~fionalsu~eyrequir~ ~Yes [ ] No ~quir~wo~ngpressureforBOPE [ ]2M; [ ]3M; ~SM; [ ]10M; [ ]15M ~heE J 0riginat Signed By by order of Approv~ by n~wid ~ Johnston Commissioner the Commission See cover letter for other requirements Date: ~----~'"- / '~ '"' ~"~ Form 10-401 Rev. 12-1-85 Submit in triplicate R-19 I -i-- R-12 R-8 16RD R-6 R-1 / /,, R-1 NBPEID PLATFORM 29 I R-;~SRD R-25 R-I 8 PROP A-27RD I R-1"7 I I I I I R-26 UNFICAL FBRCE I , ADL_ -- I I 50X 50Z 18731 I I I UNBCAI_.. 50Z K- FFIRCE 50X _ + AEIL - 17594 + -3 Ii mm m (m 10 BCAI'.I~ .o,,o FB.TI mmmmm mm' LAND FLAT PROFOSI~D LOCATION FOR MONOPOD PLATFORM A27 RD COMPLETION R.T. = 101' MSL 1.2-7/8' 6.4# N-80 BTC TBG 0 - 4600'. 2.2-7/8" X 2.313" SSSV LDG NPLE ~ 307'. 3.2-7/8" KBMG GLM ~ 1043'. 4.2-7/8" KBMG GLM ~ 2132'. 5.2-7/8" KBMG GLM ~ 3089'. 6.2-7/8" K.BMG GLM ~ 3854'. 7.2-7/8' KBMG GI. aM ~ 4571'. 8.2-7/8" X 2.313" XA $SD SLIDING SLEEVE ~, 4588'. 9. lIES "vs'r' 3.88' BORE PKR (~ 4600'. 10.2-7/8" X 2.313" "X" NIPPLE (~ 4644'. 11. WIRELINE RE-ENTRY GUIDE ~ 4656'. 12. BAKER 9-5/8" X 4.75" SC-1 PACKER ~ 4670'. 13.5" 15# BLANK PIPE F/4706'4726'. 14. 5" 15# X .012 SSWW "BAKERWELD" SLOTTED LINER F14726'-5004' GRAVEL PACKED W/107 CF 2040 SAND. 15. BAKER 9-5/8' X 6" SC-lA PACKER ~ 5007'. 16. 5" 15# BLANK PIPE F/5043'-5091'. ]7. 5" x.ou ssww BAr R LD' SLOTTED LINER F/5091%5340' GRAVEL PACKED W/76 CF 2040 SAND. 18. BAKER 9-5/8" X 4.75" "D" SUMP PACKER ~ 5340'. PBTD = 5878' 12 13 14 15 16 17 8 9450' 9-5/8' 47# S-95 CASINO (~ 9450' N 16" 65# H-40 CASING (~ 1065'. 13-3/8" 61# K-55 CASING ~ 4009'. UPPER PERFORATIONS 8 JSPF .83" DIAMETER 4765' - 4795' 4890' - 4950' LOWER PERFORATIONS 8 JSPF .83" DIAMETER 5120'-5185' 5256'-5320' See Perforation Data Sheet for complete U~ing of perforations and condition. PERFS 5845'-5865' BELOW SUMP PACKER c~fr RET @ 5878' PERIS 5978' - 6470' SQZ'D W/3 I0 8X CMT RET @ 7080' PERFS 7136' - 7230' SQZ'D W/120 8X ckfr RET (~ 7300' CMT RET (~ 8615' PE~ 8689'-8701', 8763'-8~5' W/I00 SX c~ ~T ~ 8825' PE~ 8936'-89~' W/1~ SX MONOPOD PLATFORM A27 RD ABANDONDED STATUS (PToE-REDRILL) 1LT.: 101' MSL PBTD = 5878' TD ,,, 9450' / 9-~/8" 47# S-95 CASING (~ 9450' 16" 65# H-40 CASING ~ 1065'. 13-3/8" 6Itt K-55 CASING ~ 4009'. UPPER PERFORATIONS SQUEEZED W/300 SX PLUG #2 4765'-4795' 4890'-4950' LOWER PERFORATIONS SQUEEZED W/300 SX PLUG #2 5120'-5185' 5256'-5320' See Perforation Data Sheet for complete listing of perforations nd condition. PERFS $84~'-~865' SQZ'd W/75 SX PLUG #1 PERFS $975' - 6470' SQZ'D W/310 SX PERFS 7136' - 7230' SQZ'D W/120 SX CMl' RET ~ 8615' PERFS g689'-g701', 8763'.g775' W/100 SX c~fr RET ~ 8825' PERFS 8936'-8940' W/1440 SX MONOPOD PLATFORM A27RD PROPOSED COMPLETION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 1LT. = 101' MSL 3-1/2" 9.2# D-80 BTC TBG F/0 - 12000' SCSSSV @ 300' OL~ @XXXW OLM @ XXXX' GLM @ XXXX) G.LM ~ XXXX' GLM ~ XXXX' GLM ~ ~' GLM ~ ~' GLM ~~' GLM ~ ~' GLM ~~' SLID~ SLEE~ ~ ~' ~R SC4L FAC~ ~ ~ ~9~4' HE~ (~' PROFILE NIPPLE ~ ~ ~ 12000' ~, 16" 65# H-40 CASING. (~ 1065'. 13-3/8" 61# K-55 CASING ~ 4009'. 9-5/8" 47# S-95 CASING ~ 8125' KOP PBTD = 12697' TD-- 12737' PROPOSED PERFORATIONS 12055' - 12697' (400' NET) 7" 29# L-gO BTC 0 - 12737' (Tied back @ +/-7600') Monopod Well gA 27 Abandonment February 28, 1997 Driilinu Hazards: Lost circulation zones: None Time Otour~) Low pressure zones: None Over pressured zones: None Shallow gas zones: None Cumu_ia __~!ve Ch~mulative Time Time (Itoun) Preliminary Procedure 0.0 234 9.8 1 0.0 234 9.8 2 2.0 236 9.8 3 4.0 240 10.0 4 2.0 242 10.1 5 2.0 244 10.2 6 1.0 245 10.2 7 12.0 257 10.7 8 12.0 269 11.2 9 2.0 271 11.3 10 1.0 272 11.3 11 5.0 277 11.5 12 4.0 281 11.7 13 5.0 286 11.9 14 2.0 288 12.0 15 7.0 295 12.3 16 2.0 297 12.4 17 1.0 298 12.4 18 5.0 303 12.6 19 6.0 309 12.9 20 6.0 315 13.1 21 1.0 316 13.2 22 5.0 321 13.4 23 6.0 327 13.6 24 4.0 331 13.8 25 1.0 332 13.8 26 5.0 337 14.0 27 5.0 342 14.3 28 30.0 372 15.5 29 1.0 373 15.5 30 5.0 378 15.8 31 4.0 382 15.9 32 5.0 387 16.1 33 SKID RIG OVER SLOT #5 VERIFY WELL IS DEAD SET BPV, ND TREE NU & TEST BOP POOH STANDING BACK KILL STRING RIH & SET RBP ~ 1000' POOH ND BOP & DCB SPOOL NU & TEST CASING SPOOL & BOP RIH & RETRIEVE BRIDGE PLUG POOH RIH W/8-1/2" BIT & CASING SCRAPER TO 8500' CCH POOH PU WHIPSTOCK & MWD RIH & ORIENT WHIPSTOCK SET WHIPSTOCK & RUN STARTING MILL CCH POOH PU BHA & RIH RUN WINDOW MILL CCH POOH PU BHA & RIH PUN WATERMELLON MILL ASSBY CCH POOH RIH W/BIT #1 DRILL 8-1/2" HOLE F/8163' - 9100' CCH POOH TEST BOP & CHOKE MANIFOLD RIH W/BIT #2 30.0 1.0 7.0 6.0 30.0 1.0 6.0 6.0 30.0 1.0 6.0 4.0 6.0 30.0 1.0 7.0 6.0 30.0 1.0 6.0 6.0 30.0 1.0 7.0 6.0 30.0 6.0 4.0 2.0 35.0 2.0 7.0 2.0 6.0 2.0 8.0 3.0 8.0 3.0 12.0 3.0 6.0 2.0 7.0 4.0 2.0 1.0 4.0 3.0 Cumula~,e Time (Hours) 417 418 425 431 461 462 468 474 504 505 511 515 521 551 552 559 565 595 596 602 608 638 639 646 652 682 688 692 694 729 731 738 740 746 748 756 759 767 770 782 785 791 793 800 804 806 807 811 814 Cumulative Time (Days) 17.4 177. 17.7 18.0 19.2 19.3 19.5 19.8 21.0 21.0 21.3 21.5 21.7 23.0 23.0 23.3 23.5 24.8 24.8 25.1 25.3 26.6 26.6 26.9 27.2 28.4 28.7 28.8 28.9 30.4 30.5 30.8 30.8 31.1 31.2 31.5 31.6 32.0 32.1 32.6 32.7 33.0 33.0 33.3 33.5 33.6 33.6 33.8 33.9 Preliminary Proc...re 34 35 36 37 38 39 4O 41 42 43 44 45 46 47 48 49 5O 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 DRILL 8-1/2" HOLE F/9100' - 9550' CCH POOH & CHANGE BHA RIH W/BIT #3 DRILL 8-1/2" HOLE F/9550' - 10000' CCH POOH RIH W/BIT #4 DRILL 8-1/2" HOLE F/10000' - 10450' CCH POOH TEST BOP & CHOKE MANIFOLD IH W/BIT #5 DRILL 8-1/2" HOLE F/10450' - 10900' CCH POOH & CHANGE BHA RIH W/BIT #6 DRILL 8-1/2" HOLE F/10900' - 11350' CCH POOH IH W/BIT #7 DRILL 8-1/2" HOLE F/11350' - 11800' CCH POOH & CHANGE BHA RIH W/BIT #8 DRILL 8-1/2" HOLE F/11800'-12250' POOH TEST BOP & CHOKE MANIFOLD RIH W/BIT #9 DRILL 8-1/2" HOLE F/12250' - 12750' CCH POOH RU WlRELINE RUN TRIPLE COMBO F/12750' - 10200 RD WIRELINE RIH W/CLEANOUT ASSBY & TEST BOP & CHOKE MANIFOLD CCH POOH RU CSG CREW RIH W/7" CSG F/10200' - 7700' CCH CMT 7" CSG W/725 SX "G" CMT (500 SX LEAD F/B 2 TAIL) SET HANGER & REV CMT POOH W/SETTING TOOL RIH W/POLISH MILL DRESS TBE @ 7700' CCH POOH RU CSG CREW Time Es~dmate Otour~) 7.0 3.0 2.0 4.0 6.0 10.0 7.0 10.0 10.0 7.0 10.0 7.0 2.0 13.0 13.0 4.0 4.0 2.0 4.0 8.0 40.0 0.0 Cumulat, ve Time ~tours) 821 82,~ 826 830 836 846 853 863 873 880 890 897 899 912 925 929 933 935 939 947 987 987 Cumulative Time (Days) 34.2 34.3 34.4 34.6 34.8 35.3 35.5 36.0 36.4 36.7 37.1 37.4 37.5 38.0 38.5 38.7 38.9 39.0 39.1 39.5 41.1 41.1 . , Preliminary Procc. C. 3 RIH W/7" CSG F/7700' - SURF 84 CMT 7" TIE BACK STRING W/; 50 SX C .1V~,_. 85 ND BOP 86 CUT CSG & NU 11" 5M X 7-1/16" 5M DCB SPOOL 87 NU & TEST BOP 88 RIH W/BIT & SCRAPER & CLEAN OUT TO LINER Tc 12700' 89 POOH 90 RIH W/MILL PU 2-7/8" DRILL PIPE & CLEANOUT T( 91 TURN WELL OVER TO 3% KCL 92 POOH 93 RU WlRELINE & RUN BOND LOG F/12750' - 6000' 94 RIH W/7" PACKER TO 11700' 95 SET & TEST PKR 96 POOH LD DRILL PIPE 97 RIH W/SEAL ASSBY PU 2-7/8" TUBING TO 11700 98 SPACE OUT & LAND TUBING 99 INSTALL BPV & ND BOP 100 NU & TEST TREE 101 INSTALL SURFACE LINES 102 GAS LIFT WELL TO GET REQUIRED UNDERBALAN 103 RU WIRELINE & PERFORATE 400' NET IN 13 RUNS 104 RELEASE RIG UNOCALe Trading Bay Field Monopod A-27rd Depth vs. Time Summary Z 7,500 9,500 11,500 AFE Time ~"Actual Optimum 0 5 10 15 20 25 30 35 Time (Days) A27R7CST.XLS 3~3~97 MONOPOD A-27rd BOP SCHEMATIC 5000 PSI WORKING PRESSURE ANNULAR BOP 13-5/8" 5000 PSI PIPE RAMS 13-5/8" 5000 PSI 4~ CHOKE LINE TO MONOPOD CHOKE MANIFOLD HCR 5000 PSI MANUAL 5M GATE VALVE BLIND RAMS 13-5/8" 5000 PSI MANUAL 5M GATE MUD CROSS PIPE RAMS 13-5/8" 5000 PSI RISER 13-5/8" 5000 PSI MANUAL 5M GATE VALVE FROM MUD PUMP & CEMENT UNIT DSA 13-5/8" 5M TO 11" 5M ICIW 13-5/8" 3M X 11" 5M AP SPOOL I ........................... m ii ii t II i , i ........... -- .... iiii ~ ill )VI l l&,~Wll -::l:~ ......... 3 '1 c) DOPE I'IOiE: SWACO CItOKE$ EACH ltY'DRAUI_ICALLY ^CTtlA'IE'I! VIA, II£MDIE. I Han_E.R. I 1'RIP 'I'ANI( 20 BBI.s TO MUD H~X~Ne, HI IS A u,r. J. EVEL HELOW TIlE ACTIVE SYSlEId ' 100 BI31.s IflO BIll s ues~L~iii~ J SUC!ION PlJ' lIDO Hill :~ NOIE: IlIE SY$IEU WILL BE EOUIPPED Wllll A Illlll I.INl:} PiT LEVEL INDI£AIOI;~ Wllll AUDIO & VISUAl_ WARNINO DEVICI~S. ' ............ · ..................... I) RESERVE Pit (2) %IIAI(E.IIS 4) PIF LEVEL INDI~AIOR (v~su~. &, AUDIO) 5) FLUID [I.OV~ SENSOR 1RIP 'lANK 7] Pff AmrAr,)RS DESLTER IINOC, fil, tJOHOI:~OD ~IIIL'., I:'1[SCI I£kI^I'IC DRAWN: CLL APP'D: SCAI.E: NOI, IE DALE: 04- 17-90 Monopod Platform Well # A-27rd Pressure Calculations Monopod Platform Well # A-27rd Trading Bay Field ?,,hu'ch 3, Hole Section 1 Depth Interval: 8125'-12737' 8-1/2" hole size 9-5/8" casing to 8125' Mud weight: Shoe depth (Top Sq~d Peri): Est. fracture gradient of 9-5/8" shoe: Depth of next hole section (8-1/2"): BHP gradient: Gas gradient (assume worst case): 9.6 ppg=0.50 psi/it 4765' MD/3751' TVD 0.70 psi/R at top sqz'd pelf 12737' MD/9800' TVD 0.437 psi/It 0.0 psi/It Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHP - (3/4 mud + 1/4 gas) MSP=-(9800'x.437 psi/fO - ((.75(9800'x0.50 psi/It)) + (.25(9800'x0.0 psi/It))) MSP= 608 psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 9-5/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 608 + (375 l'x0.50 psi/It) HPsh= 2484 psi This (Hpsh = 2484 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 2484 psi < Fpsh = 0.70 psi/It x 3751' = 2626 psi. The maximum surface at TD (MSPtd)pressure is calculated based on a normal pressure gradient to total depth (9800' TVD) and the hole full of gas (estimated 1 ppg gas density). MSPtd = (8.4ppgx.052x9800') - (lppgx.052x9800') = 3,771 psi File name: a27rdcal.doc ~ O~Tcst (LOT) Dam Cook Inlet, Al~a Revised idatch 15, 1996 Well # Date Uno,aA En~y Resources ,a3~ka Size Shoe Dcp~ (TVD] Frac Grad. (usi/ft.') . Baker P{nfform Ba 28 10-10-93 Ba 30 10-24-93 Ba 30 10-28-93 Ba28 11-1%93 Ba 29 12-17-94 Ba 29 12-29-93 Ba 30 01-27-94 Ba 28 03-01-94 Ba31 03-04-96 Ba31 03-09-96 Ba31 03-15-96 24' 802' 0.94 18.10 24' 803' 0.83 15.90 18-518" 2011' 0.94 18.10 18-5/8' 2135' 0.75 14.50 18-5/8" 2054' 0.76 14.61 13-3/8' 5869' 0.85 16.33 13-3/8" 5467' 0.93 17.96 13-3/8' 3509' 0.75 14.40 18-5/8" 801' 0.82 15.68 13-3/8" 2076' 0.80 15.40 9-5/8" 5937' 1.02 19.70 Grw, yiing Platfom G-40 01-24-90 G-40 16' 1926' 0.96 18.46 13-3/8' 4977' 0.86 16.54 Monouod Platfom A-ltd 04.434-91 A-Srd 07-01-89 A-20rd 03-30-90 A-20rd 04-13-90 A-28rd l 1-20-89 A-28rd i 1-27-89 9-5/8' 1132' 1.07 20.57 9-5/8' 3760' 1.02 19.61 13-3/8' 755' 0.95 1820 9-5/8' 1931' 0.85 16.30 20' 240' 0.75 14.42 13-3/8" 1140' 0.97 18.65 Granite Point Platform 11-13rd 02-14-92 51 O8-07-92 51 07-28-92 51 08-25-92 50 05-27-92 50 06-04-92 50 06-27-92 9-5/8" 9966' O. 96 1 g.40 13-318' 3803' 1.00 1920 18-518" 1010' 0.87 16.80 9-5/8" 9592' 1.05 2020 18-5/8' 982' 0.91 17.50 13-3/8' 4208' 0.84 1620 9-5/8' 9877' 0.93 17.90 Dillon Platform 16 04-22-94 18-5/8' 1131' 16 06-16-94 13-3/8" 3640' 16 07-04-94 9-5/8" 9469' 17 04-27-94 18-5/8' 1142' 17 05-01-94 13-3/8' 3560' 17 05- 9-5/8' 9213' 18 07-26-94 18-5/8" 1132' 18 08-01-94 13-3/8" 3988' 1.12 0.82 1.01 0.83 NA 1.02 0.80 21.72 15.80 142 (FIT) 19.47 15.~ 16.5 (FIT) 19.63 15.3 L~k Off T~ (LOT) Page 2 Anna Platform t ltd 10-23-94 13-3/8" 2976' 1 ltd 11-I 1-94 9-5/8" 8750' 3rd 12/10/94 9-5/8" 7839' 50 2/8/95 18-5/8" 1160' 50 2/13195 13-3/8" 4251 50 3/8/95 9-5/8" 9844' 51 1/29/95 18-5/8" 1130' 51 5/15195 13-3/8" 3796' 51 6/3/95 9-5/8" 9842' 52 2/3/95 18-5/8' 1153' 52 3/27/95 13-3/8" 3940' 52 4/15195 9-5/8" 9470' 7rd2 8/25195 9-5/8" 4439' No. te& All fracture gradients relxa'tea have been corrected for air and water gaps. (FIT)-Fo~on lnta:grity Test 0.89 O.92 0.75 1,38 1.01 .86 1.36 .71 .88 1.41 .84 .91 .96 17.2 17.7 (FIT) 14.5 26.6 19.5 16.5 26.2 13,6 17.0 (FIT) 27.0 16.15 17.6 (~3 18.5 Filcnamc Lotdam. doc WELL: MONOPOD A-27RD FIELD: 1. MUD WT. I 9.6 PPG 2. MUD WT. II 0 PPG 3. MUD WT. III 0 PPG INTERVAL CASING SIZ~ BO'I-rOM TOP 7" 12737 45 '[VD 9800 45 CASING DESIGN TRADING BAY FIELD DATE: 3-Mar.97 DESIGN BY: P.A. RYAN M.S.P. TENSION MINIMUM WEIGHT TOP OF STRENGTH DESCRIPTION W/O BF SECTION TENSION ~_ENGTH vv-r. GRADI~ THREAD LB___~S LBS 1000 LBS 12692 29 L-80 BTC 368068 368068 676 794 psi 844 psi 0 psi TD.~F COLLAPSE COLLAPSE PRESS {~ RESIST. BO'I'rOM TENSION PSl.....~* PSI 2803 7020 BURST MINIMUM PRESSURE YIELD ,P.S~** ps._j 2205 8160 3.70 * Collapse pressure is calculated; Difference between two cement alurriea (i.e. Avg of a 15.8 ppg (tail) & 142 ppg (lead) = 15 ppg, aubtract a mud of 9.5 ppg ,, 55 ppg - ,280 p~I/ft gradient X TVD of the ca~lng string). '* Burst pressure Is calculated; (BHP ~ depth next csg X TVD next csg) X (0.5 half evacuated). File name: A27rdcsg.xls DEPTH- CASING SIZE HOLE SIZE MUD TYPE UNOCAL MONOPOD PLATFORM WELL #A-27RD +/- 1273 8-1/2" F.I.W./GENERIC MUD #2 (with PHPA) ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss API HPHT Fluid Loss 9.4 - 9.8 ppg 40 - 60 sec/qt 10 - 15 cps 10 - 25 # / 100 fO. 4- 12 8 20 File name: A27rdmud.doc MONOPOD PLATFORM WELL # A-27RD TRADING BAY FIELD ROTARY KELLY BUSHING (KKB) Elev. 101' DRILL DECK LEVEL Elev. 75' PRODUCTION DECK LEVEL Elev. 56' SEA LEVEL (MLW) Elev. 0' MUD LINE Elev. -62' 20" Structural Casing ~ 225' RKB (62'BML) 16" 65# H-40 Con&sctor Casing (~ 1065' 13-3/8" 61# K-55 BTC Surface Casing ~ 4009' 7" Tied back to surface w/Liner Hanger ~ +/- 7800' 9-5/8" 47//S-95 BTC Intermediate Casing ~ 8125' (KOP) ~' · 7" 29# L-80 BTC Production Casing ~ 12737' UNOCAL ,'e: tdONOPOO Platform Well : A27Rd UNOCALe /r .\ cook ~.,.t. A~o,~o <- West ~teeT) 5250 5000 4730 ,500 .250 4000 ~750 ~00 ~250 ~000 2750 2500 2250 3750 ICreateo ~y jones For:-~at Eyanl Oote plotted : 27-Feb-g7 Plot Reference is A27Rd Version ~[5. '. Coordlnotes ore in feet reference slot ~5. True Vertical Dep~erence wellheoa.! 5750 6250 6750 70O0 ~ 7250 C- 7500 t '+- -1 ' 7750 1 ~o00 -J >. 825O 850O KOP / T:e-m Point 43.68 41,51 39.42 .~L$: ,3.00 deg per 100 ft EOC Average Angle o~.39 Azimuth 7273' (To TD) KOP / Tie-In Point EOC 4250 8750 g000 9250 950O 1 0000 36.32 Deg TD TARGET A27Rd RvsO 26-Feb-97 WELL PROFILE DATA 4500 0 4750 r" 5000 5250 5500 5750 6000 6250 45t8.~2 . ..... Po~t ..... ldO !nc Oir 'P~ NOs'th Cast K(~ 812~.00 ~ 5..17 222.{3Q 6104.42 -4192.32 - 263g.~.7 ~d ~ ~um ~71 ~5.32 236.39~32.92-4378,~-2~.~ 4797,g2 Tar~ ~TRd ~ 2~ 12~4~ 26.32 236.39g2~.O0-5525.~-4575.~ ~,~ ~5.32 236.39g8~.O0-57~.76-4g~1,677~2.71 TARGET I I I I I 1 I I [ I , I i , ; ' I I r I 4250 ,t500 ~750 2~-O00 5250 5500 5750 6000 6250 6500 6750 7(;00 7250 7500 Vertical Section (feet) -> Azimuth 256.$9 with reference 0.00 N, 0.00 E from slot #5 UNOCAL HONOPO0 Platform A27Rd slot ~5 Trading Bay Field TBU, Cook Inlet, ALaska PROPOSAL LISTING by Baker Hughes [NTEQ Your ref : A27Rd Version ~5 Our ref : pro~025 License : Date printed : 27-Feb-97 Date created : 19-Dec-96 Last revised : 26-Feb-97 Field is centred on n60 53 32.7Tg,w151 34 32.077 Structure is centred on n60 53 32.779,w151 34 32.077 Slot location is n60 53 48.584,w151 34 43.255 Slot Grid coordinates are N 2523118.309, E 21888~.444 Slot local coordinates are 1605.00 N 553.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL MONOPOD Platform,A27Rd Trading Bay FieLd, TBU, Cook Inlet, Alaska Measured. !nctin. Azimuth True Vert R E C T A N G U L A R Depth Dc~grees Deg-,%~s Depth C 0 0 R D I N A T E S PROPOSAL LiSTiNG Page 1 Your ref : A27Rd Version Last revised : 26-Feb-97 Dogleg Vert Deg/lOOft Sect 8125.00 45.37 222.00 6104.42 4192.32 S 2639,47 W 0.00 4518.82 8200.00 43.68 224.13 6157.89 4230.75 S 2675.36 W 3.00 4569.98 8300.00 41.51 227.18 62~1.51 4278.07 S 272~,72 W 3.00 4636.45 8400.00 39.42 230.50 6307.60 4320.79 S 277~.53 W 3.00 4700.75 8500.00 37.43 234.11 6385.96 4358.81 $ 2821,66 W 3.00 4762.71 8558.71 36.32 236.39 6452,92 4378.89 S 2850.59 W 3.00 4797.92 9000.00 36.32 236.39 6788.50 45~.55 S 3068.25 ~ 0.00 5059.27 9500.00 36.32 236.39 7191,~58 4687.47 S 3314,87 W 0.00 5355.39 10000.00 36.32 236.39 7594.27 4851.38 S 3561.48 W 0.00 5651.51 10500.00 36.32 236.39 7997.15 5015.29 S 3808.10 W 0.00 5947.62 11000.00 36.32 236.39 8400.03 5179.20 S 4054.71 W 0.00 6243.74 11500.00 36.32 236.39 8802.91 5343.11 S 4301.33 W 0.00 6539.86 12000,00 36.32 236.39 9205.80 5507.02 S 4547.94 W 0.00 6835.97 12054.86 36.32 236.39 9250.00 5525.00 S 4575.00 ~ 0.00 6868.46 12500.00 36.32 236.39 9608.68 5670.93 S 4794.56 ~ 0.00 7132.09 KOP / Tie-in Point EOC A27Rd Rvsd 26-Feb-97 127'57.44 36.32 236.39 9800.00 5748.76 S 4911.67 ~ 0.00 7272.71 TD All data is in feet unless otherwise stated. Coordinates from slot ~5 and TVO from wellhead (101.00 Ft above mean sea Level). gottom hole distance is 7561.27 on azimuth 220.51 degrees from wellhead. Total Dogleg for wellpath is 13.01 degrees. Vertical section is from wellhead on azimuth 236.39 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes INTEQ UNOCAL ~ION~ PLatform,A27Rd Trading Bay Field,TBU, Cook Inlet, Alaska PROI~OSAL LISTZNG Page 2 Your ref : A2~Ed Version Last revised : 26-Feb-9? Cc.-~nents in wet[path ND TVO Rectangular Coords. Co~,nt ....... ..... .......... ..... .......... .......... .......... ...... 8125.00 6104.42 4192.32 $ 2639.47 W KOP / Tie-in Point 8558.71 6432.92 4378.89 S 2850.59 W EOC 12054.86 9250.00 5525.00 S 4575.00 ~ A27Rd Evsd 26-Feb-97 12T57.44 9800.00 57~+8.76 S 4911.67 ~ TD Targets associated with this uel[path Target name Geographic Location T.V.I). Rectangular Coordinates Revised ... .......o............ .... ... ............... . .... o....... ..... .oo..... ........ . ......... ...... A27Rd Rvsd 26-Feb-97 9250.00 5525.00S 4575.00~1 19-0ec-96 UNOCAL HOflOPO0 Ptatform,A27Rd Trading Bay Field,TaU, Cook inlet, ALaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL L[ST[NG Page 1 Your ref : A27Rd Version ~5 Last revised : 26-Feb-97 Dogleg Vert Deg/lOOt= Sect 8125.00 45.37 222.00 6104.42 2587.32 S 3192.47 W 0.00 4518.82 8200.00 43.68 224.13 6157.89 2625.75 $ 3228.36 W 3.00 4569.98 8300.00 41.51 227.18 6231.51 2673.07 S 3276.72 ~ 3.00 4636.45 8400.00 39.42 230.50 6307.60 2715.79 $ 3325.53 W 3.00 4700.75 8500.00 37.43 234.11 6385.96 2753.81 $ 3374.66 W 3.00 4762.71 8558.71 36.32 236.39 6432.~2 2TT5.89 S 3403.59 W 3.00 4797.92 9000.00 36.32 236.39 6788.50 2918.55 S 3621.25 ~ 0.00 5059.2? 9500.00 36.32 236.39 7191.38 3082.4? S 3867.8? ~ 0.00 5355.39 10000.00 36.32 236.39 7594.2? 3246.38 $ 4114.48 ~ 0.00 5651.51 10500.00 36.32 236.39 7997.15 3410.29 S 4361.10 W 0.00 5947.62 11000.00 36.32 236.39 8400.~ 3574.20 S 4607.71 W 0.00 6243.74 11500.00 36.32 236.39 8802.91 3758.11 S 4854.33 W 0.00 6539.86 12000.00 36.32 236.39 9205.~0 3902.02 $ 5100.94 W 0.00 6835.97 12054.86 36.32 236.39 9250.00 3920.00 $ 5128.00 W 0.00 686~.46 12500.00 36.32 236.39 9608.68 4065.93 S 5347.56 W 0.00 7132.09 127'57.44 36.32 236.39 9800.00 4143.76 S 5464.67 W 0.00 7272.71 TD KOP / Tie-In Point EOC A2~Rd Rvsd 26-Feb-97 AL[ data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 4, T9N, R13~ and TVO from wellhead (101.00 Ft above mean sea level). Bottc~n hole distance is ~561.27 on azimuth 220.51 degrees from wellhead. Total Dogleg for wellpath is 13.01 degrees. Vertical section is from wellhead on azimuth 236.39 degrees. Calculation uses the minin~zn curvature method. Presented by Baker Hughes [NTEQ UNOCAL 140#OPOD Platform,A27]~d Trading Bay FieLd,TBU, Cook inlet, Alaska PROPOSAL LISTING Page 2 Your ref : A27Ed Version Last revised : 26-Feb-97 Conments in weLLpath ND TVO Rectangular Coords. Cona~nt 8125.00 6104.42 2587.32 S 3192.47 W KOP / Tie-in Point 8558.71 6432.92 2775.89 S 3403.59 W EOC 12054.8~ 9250.00 3920.00 S 5128.00 W A27Ed Rvsd 26-Feb-97 12737.44 9800.00 4143.76 S 5464.67 W TD Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised A27Ed Evsd 26-Feb-g7 ~250.00 3~20.00S 5128.00W lg-Oec-g6 UNDCAL MONOPO0 Platform,A2~d Trading Bay Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : AZ?Rd Version Last revised : 26-Feb-9? Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees ~apt~ C C 0 R D I N A T E S Deg/lOOft Sect Easting Northing 8125.00 45.37 222.00 61~.42 4192.32S 26~9.471d 0.00 4518.82 216144.04 2518990.66 8200.00 43.68 224.13 6157.~9 4230.755 2675.36W 3.00 4569.98 216107.24 2518953.10 8~00.00 41.51 227.18 6231.51 4278.075 272~.72W 3.00 4636.45 216057.75 2518906.96 8400.00 39.42 230.50 6307.60 4320.795 2772.53W 3.00 4700.75 216007.93 2518865.42 8500.00 37.43 234.11 6385.96 4358.815 2821.66W 3.00 4762.71 215957.91 2518828.59 8558.71 36.32 236.39 6432.92 4378.89S 2850.59~d 3.00 4797.92 215928.50 2518809.21 9000.00 36.32 2~.39 6788.50 452~.555 3068.25W 0.00 5059.2? 215707.43 2518669.82 9500.00 36.32 2~.39 7191.38 4687.475 3314.87~1 0.00 5355.39 215456.95 2518511.88 10000.00 36.32 236.39 7594.27 4851.385 3561.48l~ 0.00 5651.51 215206.4? 2518~53.95 10500.00 36.32 236.39 7997.15 5015.295 3808.10W 0.00 5947.62 214955.99 2518196.01 11000.00 36.32 236.39 8400.03 5179.20S 4054.71W 0.00 6243.74 214705.51 2518038.08 11500.00 36.32 236.39 8802.91 5343.115 4301.33W 0.00 6539.86 214455.03 2517880.14 12000.00 36.32 236.39 9205.80 5507.02S 4547.94W 0.00 68~5.97 214204.56 2517722.20 12054.86 36.32 236.39 9250.00 5525.005 4575.00W 0.00 686,8.46 214177.07 2517"?04.8~ 12500.00 36.32 236.39 9608.68 5670.935 4794.56W 0.00 7132.09 213954.08 2517564.27 12737.44 36.32 236.39 9800.00 5748.765 4911.67W 0.00 7272.71 213835.13 2517489.27 All data in feet unless otherwise stated. Calculation uses mininu~ curvature method. Coordinates from slot ~5 and TVO from wellhead (101.00 Ft above mean sea level). Bottom hole distance is 7561.27 on azimuth 220.51 degrees from wellhead. Total Dogleg for welLpath is 13.01 degrees. Vertical section is from wellhead on azimuth 236.39 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCAL MONOPO0 P latform,A27Rd Trading Bay Fie[d,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : A2?Rd Version Last revised : 26-Feb-97 Coaments i. weklpath MD TVD Rectangular Coords. Conm~ent 8125.00 6104.42 4192.32S 26)9.47t4 KOP / Tie-in Point 8558.71 6432.92 4378.89S 2850.59~ EOC 12054.86 9250.00 5525.00S 4575.00W A27Rd Rvsd 26-Feb-9? 12737.44 9800.00 5748.76S 4911.67g TD Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised A2ZRd Rvsd 26-Feb-97 9250.00 5525.00S 4575.00W 19-0ec-96 Creotecl I~ jones .~ plot. t~l: 27-F'eb-g7 ~,u~ Reference is A27Rd Version ~5. Coordinote$ ere in feet reference s~ot ~5. '.me Verticol Depths ore refe:ence UNOCAL 5800 Structure : MONOPOD Plofform Well : A27Rd Field : Tradlng Boy Field Locution: TBU, Cook Inlet, Aloska UNOCALe <- West (feet) 5400 5200 50~ ~00 46~ 4400 z2~ 40~ 38~ 5600 5400 3200 3000 2800 2~ 2~00 i ' i I i i i i ' I i ~ i i i i i i i i ; ; ' 2200 2200 2600 2600 2800 26~ 3000 3000 3200 3200 3400 O0 570 3600, 3800 4000 4200 - 4,~00 - 4600 4800 5000 5200 5400 5600 0 630 7100-/' /~700 I4600 7900"/./ [ 5000 8100 /- 8300"/'/' L 5200 8500./.." 8700 ,-" 8900 ~" - 5~00 9 A27Rd ~vsO 26-Feb-g7 9500 ./~/ 3600 5800 1 6000 t 6200 [ , .......... 5400 5200 5000 4800 4600 4400 4.200 4.000 ~80~ 3600 3400 3200 3000 2800 2600 2,~00 <- West (feet) 5800 6000 ......... ,. , , , '- [ 6200 L~O~AL MONOPOO Platform AZTRd slot ~5 Trading Bay Field TBU, Cook Inlet, Alaska SUMMARY CLEARANCE Baker fl~ghes [NTEQ REPORT Your ref : A27Rd Version #5 Our ref : prop2025 License : Date printed : 28-Feb-97 Date created : 19-Dec-96 Last revised : 26-Feb-9? Field is centred on r60 53 32.779,w151 34 32.077 Structure is centred on r60 53 32.779,w151 34 32.077 Slot location is n60 53 48.584,w151 34 43.255 Slot Grid coordinates are N 2523118.309, E 2188~3.444 Slot local coordinates are 1605.00 N 553.00 W Projection type: alaska - Zc~e 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PGHS <O-9784'>,,A-28RD,MONOPOD Platform GMS <250-6432'>,,A-28,MONOPO0 Platform MSS <O-66691>,,A-2,MONOPO0 Platform MSS <1415-7-/96'>,,A-25,MONOPO0 Platform PGHS <O-8650'>,,A-25RD,MONOPO0 Platform MSS <2656-8535'>,,A-17,MONOPO0 Platform GMS <O-5100'>,,A-1ZRD,MONOPO0 Platform GMS <O-6750'>,,A-32,MONOPOO Platform MSS <437g-9259'>,,A-19,MONOPOD Platform PGMS <0-7350'>,,A-19RD,MONOPO0 Platform PGMS/MSS <0-1000-8473'>,,A-12RD,MONOPOD P[atfo MSS <1030-73581>,,A-12,MONOPOD Platform GMS <O-7000~>w,A-gRD~MONOPO0 Platform MSS <395-6896'>,,A-9,MONOPO0 Platform PGSS/PMSS <3945-4164-7430'>,,A-SRD,MONOPOD Pla PGMS <0-4498'>,,A-8,MONOPO0 Platform PGSS/PMSS <1100-1273-6592'>,,A-1Rd,MONOPOD P[ A-1Comp.<PGMS/MSS O-6509'>,,A-1,MONOPO0 Platf MSS <0-6407'>,,A-7,MONOPO0 Platform GMS <0-3300'>,,A-4~MONOPO0 Platform MSS <0-10180'>,,A-11,MONOPOO Platform MSS <O-7292'>,~A-13,MONOPOD Platform MSS <0-6340'>~A-15,MONOPCX) Platform MSS <47g-~SO'>,,A-24,MONOPO0 Ptatform GMS <O-5~50'>,,A-24dH),MONOPOD Platform GMS/MSS <0-6500-8070~>,,A-14,MONOPOD Platform GMS/MSS <O-4900-9066'>,,A-22,MONOPOD Platform MSS <7259-8431'>,,A-21RD,MONOPOD Platform Closest a~proach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 21 -Apr-94 21 -Apr-94 21 -Apr-94 21 -Apr-94 21 -Apr-94 21 -A~r-94 21 -A~r-94 21 -A ar-94 21 -A ~r-94 21 -A ~r-94 21 -A ~r-94 21-A ~r-94 21 -A ~r-94 21 -A ~r-94 21 -A ~r-94 21-A ~r-94 21-A )r-94 21-A )r-94 21-A ~r-94 21 -A~r-94 21 -Apr-94 21-A~r-94 21 -A ~r-94 21-Apr-94 21-A~r-94 21-A :~r-94 21 -A Dr-94 7039.8 8125.0 8125.0 7013.3 8125.0 8125.0 4760.9 8125.0 8125.0 3671.6 8125.0 8125.0 3109.7 8125.0 8125.0 217g.1 8125.0 8125.0 3209.2 8125.0 8125.0 4822.1 8125.0 8125.0 4506.1 8125.0 10627.6 4735.7 8125.0 8125.0 5030.8 8125.0 8940.0 5293.6 8125.0 8125.0 4110.9 8125.0 8125.0 6781.5 8125.0 8125.0 3436.1 8125.0 8125.0 4865.1 8125.0 8125.0 5388.3 8125.0 8125.0 6318.5 8125.0 8125.0 5117.1 8125.0 8125.0 6100.4 8125.0 8125.0 4094.7 8125.0 8125.0 3537.0 8125.0 8125.0 6572.9 8125.0 8125.0 3852.~ 8125.0 8125.0 3476.6 8125.0 8125.0 3020.9 8125.0 8125.0 2648.9 8125.0 8125.0 980.3 8125.0 8125.0 MSS <O-8310'>,,A-21,MONO, Platform 21-Apr-94 MSS <O-6498'>,,A-6,MONOPO0 PLatform 21-Apr-94 G$S/PM$$ <1030-1932-68~,>,,A-16RO,MONOPO0 Pta 21-Apr-9~ PGMS/MSS <O-~O00-7460'>,,A-16,MONOPO0 PLatform 21-Apr-94 GMS <O-7360'~,,A-30,MONOPO0 PLatform 21-Apr-94 PMS$ <1~72-6120'>,,A-20 RD#2,MONOPO0 PLatform 21-Apr-94 GMS <O-11926'>,,A-20,MONOPO0 PLatform 21-Apr-94 A-29 RD <GMS 0-8600'>,,A-29 Rd,MOHOPOD Platfor 21-Apr-94 A-29 Orig. <MSS 5398-8577'>,,A-29,MONOPO0 PLat ~1-Apr-94 GMS/MSS <O-475O-75~n,>..A-23~MOHOPO0 PLatform ~l-Apr-94 MSS <6106-750b'>,,A-5 RD#1,MONOPO0 PLatform 21-~pr-94 GMS/MSS <O-1650-7646'>,,A-5,MONOPO0 PLatform ~1-^pr-94 MSS <5544-7101'>,,A-5 RO#2,MONOPO0 PLatform 21-Apr-94 MSS <O-11000'>,,A-18,MONOPO0 PLatform 21-Apr-94 MSS <O-8795'>,,A-26,NONOPO0 PLatform 21-Apr-94 PGHS/MSS <O-900-70'i"5'>,,A-IO,MONOPO0 PLatform 21-Apr-9~ MSS <486-11637'>,,A-3,NONOPO0 PLatform 21-Apr-94 GMS/MSS <O-1600-7224~>,,A-3RO,MONOPO0 PLatform 21-Apr-94 GMS <O-8825'>,,A-27,MONOPO0 PLatform 20-Jun-96 905.6 5996.1 5040.6 4239.7 4428.6 48,35.8 4651.6 4239.0 4162.? 1972.5 2381.3 2270.6 1968.2 6959.1 2447.7 3694.6 6799.1 6904.7 0.0 812~ 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 8125 .U .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 8125.0 8125.0 8125.0 8125.0 8125.0 8125.0 8125.0 8125.0 8125.0 8125.0 6~2~.0 8125.0 8125.0 8125.0 8125.0 8125.0 8125.0 8125.0 8125.0 PERFORATION DATA SHEET PRIOR TO ABANDONMENT ADL 18731 'MONOPOD A-27 1/2C;97 4765-4795 4770-477~- 4890-4950 51:20-5185 5256-5320 5844-5846 5845-5865 5978-6008 6030-6060 6079--6074 6455-6470 6485-6487 7136-7230 7228-723O 8040-8042 8689-8701 8697-8701 8763 -8775 8936-8940 T~ C~EET} 3751-3772 3756-3758 3839-3881 4001-4047 4098-4143 4521-4522 4521-4536 4618-4640 4656.4678 4687-4688 4959-4970 4980-4981 5430-5495 5494-5495 6058-6059 6506-6514 6512-6514 6555-6563 6671-6673 Current Condition PRODUCING SQUEEZED W/150 SX PRODUCING PRODUCING PRODUCING SQLr~.z~'D W/300 SX OPEN BELOW SUMP PKR BELOW CMT RET ~ 5878' BELOW CMT RET. ~ 5878' SQUE~7~D w/500 sx BELOW CMT RET ~ 5878' SQUE~ W/500 SX BELOW CMT RET. ~ 7080' so~ w/300 sx SQU'E~-~o W/300 SX BELOW CMT RET.@ 8615' SQUEEZED WI 600 SX BELOW CMT RET ~ 8615' BELOW CMT RET. ~ 8825' Original Reaso,n. PRODUCTION SQUEEZE PRODUCTION PRODUCTION PRODUCTION SQUE~.MP- PRODUCTION PRODUCTION PRODUCTION SQUEEZE PRODCUTION SQUEEZE PRODCUTION SQUEg. ZI~- SQUEEZE DST #1 SQUE~.TF~ DST #1 SQUEeZe- Re: Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conselwation Commission ., The application of Union Oil Company of California (UNOCAL) tbr exception to 20 AAC 25.055 to allow drilling the Trading Bay Field A-27RD development oil well. UNOCAL by letter dated March 6. 1997 has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of a development gas well to an undefined gas pool in the Middle Ground Shoal Field located in the Cook Inlet Basin, Southcentral Alaska. The exception would alloxv UNOCAL to directionally drill the Trading Bay Field A-27RD development oil well to a producing location that is closer than 500 feet from a section line. the proposed surface location is 1605' from the south line (FSL) and 553' from the east line tFEL) of Section 4. T9N. R13W. Seward Meridian (SM). the proposed top of the productive interval is 1360' FSL and 152' from the west line of Section 9, T9N, R13W, Ski and the proposed bottom-hole location is 1136' FSL. and 185' FEL of Section 8, T9N, R13W. SM. The well as proposed will be open to production within 500' of a spacing unit boundary in both Sections 8 and 9. The exception will provide for both sections. A person who mav be harmed if the requested order is issued may file a written protest prior to 4:00 PM. April 1. 1997 with the Alaska Oil and Gas Conservation. 3001 Porcupine Drive. Anchorage, Alaska 99501. and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am on April 22, 1997, 1997. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, p at 279-1433 no later than April 15. 1997. David WNJohnston. Chairman_ Alaska Oi~ervation Commission Published March 18. 1997 ADN AO02714026 Memorandum UNOCAL 12 March 1997 From: To: Bob Crandall - Nan~ Permit to Drill A-27RD I have enclosed a revised second page to Kevin Tabler's letter dated March 6, 1997 regarding the Permit to Drill A-27RD. Please substitute the March 6th edition with this replacement page. Thank you for generous foresight in rectifying this error. :nk Enclosure gnch~ FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. Unocal Corporation .... Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL( March 6, 1997 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Trading Bay Field State of Alaska Permit to Drill A-27RD Dear Mr. Johnston: Union Oil Company of California (Unocal), as Operator of the Trading Bay Field, requests your approval to drill Trading Bay Field A-27RD and further requests a spacing exception to 20 AAC 25.055 (3). Enclosed as part of this application, in triplicate, is our Permit to Drill A-27RD (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2000050 in the amount of $100.00 as required under 20 AAC 25.005. (c)(1). Also enclosed, is Verification of Application by the undersigned stating that applicant is acquainted with the facts pursuant to 20 AAC 25.055 (b). Unocal intends to drill the A-27RD well from the Monopod Platform into the Hemlock Oil Pool less than 500' from the quarter section line. Unocal and Forcenergy are the Lessees and Operators of the governmental quarter sections directly and diagonally offsetting the quarter section where the oil well is located. Forcenergy is a participant in this well. A-27RD shall be completed at a crestal withdrawal point which will result in additional recovery of HemlOck Production. The specific location, interval and depth are as follows: 1. Surface Location: 1605'FSL & 553'FEL, Section 4, T9N-R13W, SM. 2. Top of Prod. Interval: 1360'FSL & 152'FWL, Section 9, T9N-R13W, SM. 3. Total Depth' 1136'FSL & 185'FEL, Section 8, T9N-R13W, SM. If you require addition information, please contact the undersigned at (907) 263- 7600 or Dan Williamson, Drilling Dept. at 263-7677. We appreciate your review and trust that the enclosed is satisfactory. enclosures V/ery truly yours, ~'Kevin A. Tabler Manager, Land and Government Affairs VERIFICATION OF APPLICATION FOR SPACING EXCEPTION TRADING BAY FIELD, COOK INLET, ALASKA STATE OF ALASKA ADL # 18731 MONOPOD PLATFORM I, KEVIN A. TABLER, Manager, Land and Government Affairs for Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the A-27RD, Monopod platform well. I have reviewed the application submitted for the exception to 20 AAC 25.055 (3) (statewide spacing) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly Portrays pertinent and required data. DATED at Anchorage, Alaska this 6th day of March, 1997. --~Kevin A. Tabler Manager, Land and Government Affairs STATE OF ALASKA THIRD JUDICIAL DISTRICT ) )ss ) SUBSCRIBED TO AND SWORN before me this 6th day of March, 1997. NOTARY PUBLIC IN AND FOR THE STATE OF ALASKA ' My Commission expires' /2~/~/~?' FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERF?~J-~BMI1-FED ~, , vENDC'~,qO. DATE CHECK NO. ,,. 103151~8 03-L,_ -9'7 2000050 . DA.TE '. ". i '..i CHER' ':.GROSS .... DISco.UNT NET 05-MA1R.-97 ])RILLPEI:L~ITMONO 03S73000326 100.00 100 O0 FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. ~l=T^.~u ~TI I1~ ~E'~E~I;:: r3.1::D~qlTlFJ~4 ~.1-11~~ 100, O0 100 OO WELL PERMIT CHECKLISToo YL/' /2 ,, /"f~?'/ --// G~/OL A~LEA ' ~¢~__/. ~,~ UNTT~ ' '~'/' ¢'~. ON/OFF SHORE ADMINISTRATION ENGINEERING REMARKS 1. Permit fee attached ................... ~ N ~ /~ ~,~/ //_ 2. Lease number appropriate ................ ~ N 3. Unique well name and number ............... 4. Well located ~n a defined pool .............. Y .5. Well located proper distance from drlg unit boundary...Y 6. Well located proper distance from other wells ...... 7. Sufficien acreage available in drilling unit ...... . If deviated, is wellbore plat included ......... 89. Operator only affected party .............. ~N 10. Operator has appropriate bond in force ......... ~ ~ ~,;~ ~f--~ ~~ ~X3 11. Permit can be issued without conservation order ..... y 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ........ Y 14. Conductor string provided ................ Y N~ 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg. . Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... .Y~ N 19. Casing designs adequate for C, T, B & permafrost .... .~ N 20. Adequate tankage or reserve pit ............ . Y~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~ N 22. Adequate wellbore separation proposed .......... N 23. If diverter required, is it adequate .......... ~/J/T 24. Drilling fluid program schematic & equip list adequate .Y~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to %d~l~-~ psig.F~ N 27. Choke manifold complies w/API RP-53 (M~y 84) ...... ~) N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY / 30. Permit can be issued w/o hydrogen .sulfide measures .... Y N// 31. Data presented on potential overDressure zones ..... Y//'N 32. Seismic analysis of shallow gas zones .......... y N 33. Seabed condition survey (if off-shore) ....... / Y N 34. Contact name/phone for weekly progress reports . . .//. . Y N [explorator~ only] GEOLOGY: ENGINEERING: COM~ISS ION: Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01197
