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181-067
Ima.q~roject Well History File Cover ~ge XHVZE This page identifies those items that were not scanned during the initial pro'duction scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~_ <~ ~_-~ (27_ Well History File Identifier Organizing RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT~ MARIA WINDY OVERSIZED (Scannable) [] Maps: / Other items scannable by large scanner OVERSIZED (Non-Scannable) ~ Other i kinds Project Proofing BY: BEVERLY ROBIN~HERYL MARIA WINDY Scanning Preparation ~'.~ x 30 = + = TOTAL PAGES ~ ' Stage f PAGE COUNT FROM SCANNED FILE: d'~ ? PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ~ NO Stage 2 IF NO IN STAGE "!¥ PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SCANNING IE COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS '~ !''` ;' ReScanned (J,,~id,,al page [special atte,tion] .~cat~nlng completed) RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /si General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA • ALS A OIL AND GAS CONSERVATION COM14, ,ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well❑ Plug Perforations ❑ Perforate 0 Other 0 Gas Lift Completion Performed: Alter Casing❑ Pull Tubing 0 Stimulate-Frac D Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 181-067• 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20135-01" 7.Property Designation(Lease Number): 8.Well Name and Number: RECIVa� ADL0018731 r Trading Bay St/A-17RD • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): - tA/4ti" 1 5 lO14 Trading Bay Field/Middle Kenai B Oil Pool 11.Present Well Condition Summary: .A0GCC Total Depth measured • 5,100 feet Plugs measured N/A feet true vertical 4,244 feet Junk measured N/A feet Effective Depth measured •• 5,027 feet Packer measured 3,142&4,471 feet true vertical 4,184 feet true vertical 2,697&3,735 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,064' 13/3-8" 1,064' 1,036' 3,090 psi 1,540 psi Intermediate 2,637' 9-5/8" 2,637' 2,307' 6,870 psi 4,760 psi Production 5,073' 7" 5,073' 4,222' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Schematic feet fr,, True Vertical depth See Schematic feet SCANNED `J U L. 1 6 2014 j4 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 3,177"(MD) 2,724'(TVD) Model D Pkr 3,142'(MD)/2,697'(TVD) Packers and SSSV(type,measured and true vertical depth) Model D Pkr 4,471'(MD)/3,735'(TVD) SSSV 293'(MD)/293'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMS-MAY 16 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 81 56 14 158 70 Subsequent to operation: 56 0 63 606 106 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run, Exploratory❑ Development0' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil, 0 Gas ❑ WDSPL❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-227 Contact Ted Kramer Email tkramerahilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature Phone (907)777-8420 Date 5/15/2014 Form 10-404 Revised 10/2012 sy'?,� ii Submit Original Only Trading Bay Unit .11 SCHEMATIC Well #A-17RD API#50-733-20135-01 Completed 04/16/14 CASING AND TUBING DETAIL RKBtoTBGHngr=38.10 SIZE WT GRADE CONN ID TOP BTM. Tree connection:Dual 3"5,0001 13-3/8" 61 K-55 Butt 12.515 39' 1064' 9-5/8" 47.0 N-80&S-95 8rd LT&C 8.681 39' 2637' 1 7" 29 N-80 6.184 39' 5073' I Tubing: 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf 3,177' 2 JEWELRY DETAIL NO. Depth ID Item i 38.14' Tubing hanger 3 1 293' 2.313" SSSV 2 2,247' 2.441" 2-7/8"Gas Lift Mandrel#1 3 3,076' 2.441" 2-7/8"Gas Lift Mandrel#2 4 3,124' 2.441" 2-7/8"Chemical Injection Mandrel 5 _ 3,142' 3.250" 7"Model"D"Permanent Packer 6 3,165' 2.313" 2-7/8"X-Nipple 7 3,177' 2.441" WLEG 4 8 I 4,471' Prod Model D Sump Packer W 5 6 x I ® FILL 1.75"bailer run to"max.safe depth of 4900' 11/17/02 B246 PERFORATION DATA 826-7 Top Btm Top Btm Accum Date 828-6 Zone (MD) (MD) _ (TVD) (ND) Amt SPF Last Opr _ Present Condition B31-8 B 24-6 3,192' 3,252' 2,736' 2,782' 60' 12/14/13 Open B 26-7 3,432' 3,540' 2,922' 3,006' _ 108' 12/14/13 Open B 28-6 3,660' 3,704' 3,098' 3,123' 44' 12/14/13 Open 8336 B 31-8 3,998' 4,127' 3,360' 3,462' 129' 8 2/90 Pre-Fracd w/80 cult of 20-40 Gravel B 31-8 4,002' 4,118' 3,363' 3,445' 116' 12/14/13 Open B 33-6 4,179' 4,224' 3,503' 3,539' 45' 8 2/90 Pre-Fracd w/80 cuft of 20-40 E8413 Gravel B 41-3 4,303' 4,327' 3,601' 3,620' 24' 8 2/90 Pre-Fracd w/80 cuft of 20-40 Gravel B 41-3 4,308' 4,328' 3,605' 3,621' 20' 12/14/13 Open B 41-8 4,355' 4,451' 3,643' 3,719' 96' 8 2/90 Pre-Fracd w/80 cuft of 20-40 B41-8 Gravel = B 41-8 4,358' 4,444' 3,645' 3,714' 86' 12/14/13 Open i 8 )•, KBELEV=101' PBTD=5,027' 1D=5100' ANGLE thru INTERVAL=38.3° Updated by: .11105/14/14 Hilcorp Alaska, LLC }Iileorp Alaska.LU Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-17RD 50-73320135-01 181-067 4/9/2014 4/16/2014 Daily Operations: 41 rd - 04/09/14-Wednesday Rigging up. 04/10/14-Thursday Rigging up. 04/11/14-Friday N ppling.up BOPs.MU test jt.Function test BOPs.HCR started leaking around hyd body.Call for another HCR valve.Give State man a call to update on progress.He allowed it would be to late to witness the BOP test so he wouldn't come out until morning.Unhook hyd line to HCR and do a body test to 250 low and 2500 psi high.Stack held good but we did have to tighten a leak on the test jt.Change out choke line HCR valve.Attempt to shell test BOPE.Leaking uni-bolt connection on choke line.Change out ring gasket.Continue testing BOPE components at 250 L/2500 H.Choke manifold valve #16 not holding.Continue with testing while repairing valve.Retest CM valve#16(good test).Perform accumulator draw down test.Retest TDS IBOP (good test).Housekeeping and rig maintenance while waiting on reply from AOGCC inspector. 04/12/14-Saturday Spoke to state man at 1115 hrs and mentioned to him that we had a boat at 1300 hrs.He told me he wasn't going to ride a boat,and he would just wait for the weather to clear up.Still on weather hold.Got permission from AOGCC[Jeff Jones]to proceed with BOP test and send charts in to him to review before we can proceed.Start testing BOPS.Test BOPE as per sundry at 250 L/2500 H with exception of blind rams.All tests good.Attempt to pull BPV to set two-way check.Gas behind BPV.Close blind rams and bullhead 60 bbls 3%KCL at 2 BPM/550 psi.Shut down and bled to 335 psi. Pump 70 bbls 3%KCL at 1.5 BPM/730 psi.Shut down and bled to 485 psi.Bleed pressure through BPV.Still churning.Lubricate and bleed at 10 bbl increments 3 times until well was stable.Pull BPV and set two-way check.Test blind rams at 250 L/2500 H.Pull two-way check.Contacted AOGCC inspector at 0300 hrs by phone with BOP test information.Monitor well for loss rate while making up landing joint.20 BPH loss rate.Standby while awaiting okay to proceed with well work from AOGCC state inspector.Received conformation to proceed with well work at 0550 hrs from Jeff Jones. 04/13/14-Sunday MU landing jt into hanger.Pull hanger free and pull 40k over to pull packer free.Circ hole volume with no gas returns.Hole is taking 25 BPH.Rig up equip on floor while circ.PJSM.Pull hanger to floor.Remove control lines and ESP cable.Pressure up SSSV line to 4500 psi to hold valve open.Lay do hanger and landing jt.PU 1 sng so we can stand back 3 stds above pkr.Rig up chem injection sheave and spool.Have cable cutting drill PJSM.POH standing back 3 stds and laying down SSSV,Packer,and X-nipple.Tbg started to get oily.POOH with ESP standing back tbg in derrick. At 2,439'the oil was getting heavy on the pipe so we circ 11 bbls down the pipe to remove the oil cap off the hole,drained the oil out of the trip tank.Continue POOH pressure washing pipe and cable.Inspect,clean and lay down ESP.Rig down ESP sheaves and equipment.Clear and clean rig floor,pipe deck,etc. Make up clean out BHA:6"junk mill,drive sub,XO,Bit sub(with float),XO=8.33'. Run in hole with BHA#1 with 2-7/8"EUE tubing out of derrick. Daily Fluid Lost to Well:426 bbls.Total Fluid Lost to Well:651 bbls Average Loss Rate:18 bbl/hr. 04/14/14 Monday RIH w/6"toothed mill shoe w/tbg out of derrick to 4,093'.RIH picking up tbg and tag fill at 4,397'. Break circ and wash f/4,397'to 4,475'tubing measurements.Circ hole clean at 9 BPM,1850 psi.POOH laying down first 42 jts of tbg and stand the last 32 stds back in the derrick.Pick up packer assembly.RIH with same to 3,142'.Set packer at 3,142'with 2350 psi.Shear out at 3000 psi.POOH standing back 2 7/8"tubing.Hold PJSM.R/U control line sheave.P/U seal assembly,chemical injection mandrel and first GLM.M/U chemical injection line and test at 5000 psi/10 minutes.RIH with completion string.Install clamp on control line every other joint.Daily Fluid Lost to Well:423 bbls. Total Fluid Lost to Well:1074 bbls. Average Loss Rate:18 bbl/hr. r I Hilcorp Alaska, LLC HiIcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-17RD 50-73320135-01 181-067 4/9/2014 4/16/2014 04/15/14-Tuesday RIH with 2-7/8"gas lift completion.Rig up to circ into seals.Work pipe down 3 times to get stabbed into seals and slack off into packer.PU and space out.PU hanger and land out.R/U and test back side(failed).Pumped 44 bbls 3%KCL down tubing at 4 BPM/1100 psi with no returns up annulus. Secure well while waiting on wireline crew.R/up slick line&test lubricator 250-2500psi(ok).Rih w/2-7/8"DD hole finder&set @ 3,115'(just below #2 Glm) Pump fiw w/3%kcl dn tbg and pressure up t/350 psi w.2.2 bbls&monitor for bleed off(ok).Continue pressure up t/800 psi w/total 2.7 bbls&monitor bleed off 800-700 psi in 5 min,bleed off pressure.Pooh and re-pin&inspect tool(ok)Rih w/same attempt set in 10'area below Chemical injection mandrel&seal assy @ 3,136'.Pump fiw w/3%kcl dn tbg(unable to build pressure).Pull tool up hole t/3,127'Pump dn tbg& pressure up t/350 psi(ok)continue pressure up t/800 psi.Bring#2 MP on line pump dn 7"w/fiw w/3%KCI&pressure up t/1200 psi and tbg tracked pressure,Bleed off tbg and annulus bleed off also.Re-pressure up tbg&annulus t/1000 psi.Bleed off annulus and only annulus bled off (appears have live valve in hole).Bleed off tbg pressure POOH w/2-7/8"DD hole finder.Retrieve live valve from GLM#2 at 3,079'WLM.Pull dummy M1` -‘,F\ valve from GLM#1 at 2,258'WLM to confirm type of valve.Set dummy valves in both GLM's.Test packer and 7"annulus at 2000 osi on chart for 30 minutes.Good test.Rig down slick line.Set BPV.Pull blind and variable rams and clean cavities.Nipple down BOPE.Daily Fluid Lost to Well:385 bbls. Total Fluid Lost to Well:1459 bbls.Average Loss Rate:18 bbl/hr. 04/16/34-Wednesd8y � _, _ Finish removing rams. Clean and preserve rams and cavities. Nip/dn flow nipple Air boot,annular Choke&kill lines.Nip/dn and remove double gate, Mud cross&flow line to pits. Ship NPF from pits to production.Pull riser. Set tree.Torque bolts to spec.Continue clean Pits&rig. Install flow lines on well head.Test Bonnet and neck seals t/250-5000 psi for 15 min each(ok).Pull BPV&set TWC shell, test tree 250-5000 psi(ok). Pull TWC. Continue r/up flow lines.Continue clean pits&rig.R/up Slick line&lubricator&test same t/250/2500(ok).Rih w/2-1/2"Daniels KO tool attempt to locate Chemical injection mandrel @ 3,121'. No go due to catcher sub.Locate&pull GLM valve in GLM#2 @ 3,079' pull valve.Pooh.When toolstring reached SSSV flapper-cut wire due to no pressure on control line.Pressure up control line&block in same.Re head wire.RIH w/2.25 LIB tag fish @ 3,075'WLM.Pooh,LIB shows no wire.Rih#3 w/2.5 JDC.Retreive tool string and valve.Pull dummy valves in GLM's#1, Set live valves in both glm.Pull catcher sub and pull dummy&set live valve in Chemical injection valve. Rig down slickline.Turn well over to production and release rig.Daily Fluid Lost to Well:0 bbls.Total Fluid Lost to Well:1459 bbls. Average Loss Rate:0 bbl/hr. �����\ 1%%% � 1HE STATE z:,- L2 , '-- 1.1, c �n:. s _^ �•t,.. --------::-=.6--_-.: -- -- 333 West Sever 1Fi Avenue ""Ks Ci<)VFP.�'<)l: ,1�� `)A�.Ati".II Anchorage Aos'.o995013572 v1(m 907 279 '"<3 , „ftrF F "•0 7 2/6 ��E00206\4 Dan Marlowe 5`p► Operations Engineer / Hilcorp Alaska, LLC � i Q 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B Oil Pools, TBU A-17RD Sundry Number: 314-227 Dear Mr. Marlowe: 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 Pdy.e,ix /g.71_,,,/„..____ oerster Chair DATED this 'r day of April, 2014. Encl. . A STATE OF ALASKA ;',: ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS "" )i s 2Q_AAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend 0 Plug Perforations❑ Perforate❑ Pull Tubing 0 Time Extension❑ Operations Shutdown 0 Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Run G/L Completion ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Q 181-067 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-733-20135-01 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❑ Trading Bay StA-17RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 Trading Bay Field/Middle Kenai B Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 5,100 4,244 5,027 4,184 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,064' 13-3/8" 1,064' 1,036' 3,090 psi 1,540 psi Intermediate 2,637' 9-5/8" 2,637' 2,307' 6,870 psi 4,760 psi Production 5,073' 7" 5,073' 4,222' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" 6.5#/L-80 4,188' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packer/SSSV 329'(MD)329'(TVD)/4,471'(MD)3,375'(TVD)and 307'(MD)307'(TVD) 12.Attachments: Description Summary of Proposal 9 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development 0 Service 0 14.Estimated Date for 15.Well Status after proposed work: 4/10/2014 Commencing Operations: Oil 9 Gas ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: 11././L( WINJ 0 GINJ 0 WAG 0 Abandoned ❑ Commission Representative: (iS�a.��r-ftGSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true land correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowetc'�i hilcorp.com Printed Name Dan Mario Title 2perations Engineer Signature4ePhone (907)283 1329 Date 4/9/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so sothat a representative may witness Sundry Number: ^ ^ � � Plug Integrity 0 BOP Test Q Mechanical Integrity Test 1:21 Location Clearance ❑ (I/]` Other: -{F 2506 r5` t RBDMS,MAY 9 9 2014 Spacing Exception Required? Yes 0 No 0 Subsequent Form Required: /D— 17 6 '-1 aie2 APPROVED BY Approved by: P 4-e..4,-,1/44"--- COMMISSIONER THE COMMISSION Date: e--u-/ 3gcY0-t5tiliUi -I ORIGIUALd Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Well Prognosis • Well: A-17RD Iiilcor')Alaska,LI) Date:04/09/2014 Well Name: Monopod A-17RD API Number: 50-733-20135-01 Current Status: Oil producer(ESP) Leg: N/A Estimated Start Date: April 10, 2014 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 181-067 First Call Engineer: Ted Kramer (907) 777-8420(0) (985)867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) AFE Number: Current Bottom Hole Pressure: 1,075 psi @ 4,230' (3,543 TVD) Maximum Expected BHP: 1,200 psi @ 4,230' MD (3,543 TVD) Max.Allowable Surface Pressure: ^'0 psi (Based on 1,200 psi @ 4,230'—(4,230 X 0.402 psi/ft.fluid gradient) Brief Well Summary The A-17RD well was converted to an ESP producer in 2013 but is currently experiencing ESP reliability issues. We plan to pull the ESP and replace with a gas-lift completion. Brief Procedure: (ori L 1. MIRU Monopod Platform Rig#56. 2. Bullhead three percent KCL to kill well. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. RU Schlumberger artificial lift. Unseat tubing hanger,Straight pull to release high set packer. 5. Circulate hydrocarbon from well 1---' CPt7 0lc. b•- -11-Z. l . 6. POOH with ESP completion. 7. RU and RIH setting production packer at 3,100' (+/-). 8. PU new completion consisting of Seal Assembly,GLMs,and SSSV spaced out on 2-7/8" production tubing string and hang off same. 9. ND BOP, NU wellhead and test. L-- PT (* cit...-7t/Eo . 10. Turn well over to production. Z cr17 r s,. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Wellhead Diagram 4. BOP Drawing Trading Bay Unit SCHEMATIC Well #A-17RD • API#50-733-20135-01 Completed 12/18/2013 CASING AND TUBING DETAIL RKBtoTBG lingr=39.42' SIZE WT GRADE CONN ID TOP BTM. Tree connection:Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 39' 1064' 9-5/8" 47.0 N-80&S-95 8rd LT&C 8.681 39' 2637' I 1 M 2 I 7 29 N-80 6.184 39' 5073' Tubing: 3 2-7/8" 6.5 1-80 8rd EUE 2.441 Surf 4,188' 4 JEWELRY DETAIL NO. Depth ID Item 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 307' SSSV 2 329' Packer i 3 343' X Nipple 4 352' Gas Lift Mandrel w/Orifice Valve 5 4,188' Head 6 4,189' Pump 7 4,216' Intake 8 4,220' ESP Shroud 9 4,225' Motor 10 4,235' Centralizer 11 4,471' Prod Model D Sump Packer FILL 1.75"bailer run to"max.safe depth of 4900' 11/17/02 B24-6 PERFORATION DATA 826-7 Top Btm Top Btm Accum Date 828-6 Zone (MD) (MD) (TVD) (ND) __Amt SPF Last Opr Present Condition 631 8 B 24-6 3,192' 3,252' 2,736' 2,782' 60' 12/14/13 Open B 26-7 3,432' 3,540' 2,922' 3,006' 108' 12/14/13 Open 5 B 28-6 3,660' 3,704' 3,098' 3,123' _ 44' 12/14/13 Open it 6 E 1333-6 B 31-8 3,998' 4,127' 3,360' 3,462' 129' 8 2/90 Pre Fracd w/80 cuft of 20 40 Gravel 8 B 31-8 4,002' 4,118' 3,363' 3,445' 116' 12/14/13 Open 9 B 33-6 4,179' 4,224' 3,503' 3,539' 45' 8 2/90 Pre-Fracd w/80 cult of 20-40 10 Gravel 641 3 Pre-Fracd w/80 cult of 20-40 B 41-3 4,303' 4,327' 3,601' 3,620' 24' 8 2/90 Gravel B 41-3 4,308' 4,328' 3,605' 3,621' 20' 12/14/13 Open B 41-8 4,355' 4,451' 3,643' 3,719' 96' 8 2/90 Pre-Fracd w/80 cuft of 20-40 Gravel B41-8 B 41-8 4,358' 4,444' 3,645' 3,714' 86' 12/14/13 Open MF10 11 KB ELEV=101' PBTD=5,027' TD=5100' ANGLE Ulm INTERVAL=38.3° Updated by: JLLO1/17/14 Trading Bay Unit M iii PROPOSED Well#A-17RD • API#50-733-20135-01 Completed FUTURE CASING AND TUBING DETAIL RIB toTBG Hngr=39,42 SIZE WT GRADE CONN ID TOP BTM. Tree connection:Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 39' 1064' 9-5/8" 47.0 N-80&5-95 8rd LT&C 8.681 39' 2637' 1 it 7" 29 N-80 6.184 39' 5073' Tubing: 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf ±3,125' 2 JEWELRY DETAIL NO. Depth ID Item 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 ±300' SSSV 3 1 2 ±2,000' GLV 3 ±3,050' GLV 4 ±3,075' Chemical Injection Mandrel 5 ±3,100' Packer 6 ±3,120' X-Nipple 7 ±3,125' WLEG 46 r 5 FILL 7 1.75"bailer run to"max.safe depth of 4900' 11/17/02 B24-6 PERFORATION DATA 826-7 Top Btm Top Btm Accum Date B288 Zone (MD) (MD) (TVD) (TVD) Amt SPF Last Opr Present Condition 631 B 24-6 3,192' 3,252' 2,736' 2,782' 60' 12/14/13 Open B 26-7 3,432' 3,540' 2,922' 3,006' 108' 12/14/13 Open B 28-6 3,660' 3,704' 3,098' 3,123' 44' 12/14/13 Open E B33-6 Pre-Fracd w/80 cuft of 20-40 B 31-8 3,998' 4,127' 3,360' 3,462' 129' 8 2/90 Gravel B 31-8 4,002' 4,118' 3,363' 3,445' 116' 12/14/13 Open B 33-6 4,179' 4,224' 3,503' 3,539' 45' 8 2/90 Pre-Fracd w/80 cuft of 20-40 Gravel E B 41-3 i B 41-3 4,303' 4,327' 3,601' 3,620' 24' 8 2/90 Pre-Fracd w/80 cuft of 20-40 Gravel B 41-3 4,308' 4,328' 3,605' 3,621' 20' 12/14/13 Open B 41-8 4,355' 4,451' 3,643' 3,719' 96' 8 2/90 Pre-Fracd w/80 cuft of 20-40 E B41-8 Gravel B 41-8 4,358' 4,444' 3,645' 3,714' 86' 12/14/13 Open 21-121 ai iO KB ELEV=101' PBTD=5,027' TD=5100' ANGLE thru INTERVAL=38.3° Updated by: JLL 04/19/14 M12/0onop9/2od013 Platform A-17RD Hilrnrp Alar,ka.MA: Monopod Tubing hanger,FMC-TC- A-17RD B-EC,11 X 3 Y:TC-2 lift 13 3/8 X 9 5/8 X 7 X 2 7/8 and susp,w/3"type H BPV profile,300-1 pocket,3-Y."continuous control line BHTA,Bowen,3 1/8 5M X 2 Y:Bowen Union V ,JIB Valve,Swab,WKM-M, "'s' 3 1/8 5M FE,HWO,DD trim ,b� ,. .. Valve,Wing,WKM-M, All Valve,SSV,WKM-M, 2 1/16 5M FE,HWO,DD trim liki\ All 3 1/8 5M FE,Omni oper, �I '�/' EE trim imoszik • Valve,Master,WKM-M, :/' 3 1/8 5M FE,HWO,DD trim ARM i:4 X ! P:4 [Ilk '.1li an; Completion spool,C-29L, 11 5M FE X FE,17"in length I 4 Ii kiln, r 4 I14 III -.a . I Tubing head,CIW-DCB, ni ill Valve,WKM-M,2 1/16 SM 13 5/8 3M X 11 5M,w/2- ,,,, rip . ,,,,, FE,HWO,AA 2 1/16 5M EFO,X-bottom 1..%- ' . prep w/1'/:VR profile i :111141 41II� I.-I Casing spool,CIW-WF, — 1 `1-- -. 13 5/8 3M X 13 5/8 3M, Valve,CIW-FC,2 1/16 5M FE, w/2-2 1/16 5M EFO III it 1- , WO,AA 'hi IP! '-'1,,I11,10 -P11.1.--i.. 11 }, III _ I Ili Q N ,®.; c Casing head,Shaffer-KD, s 135/83MX13"SOW bottom,w/2"LPO III I ill d OM ■1' 441311 2"LP plug valve .— CO C N N al N 0 .iii Monopod Platform A-17RD Proposed 04/09/2014 Hitrnrp Aladcr.I.1A. Monopod Tubing hanger,FMC-TC- A-17RD 1A-EN-CCL,11 X 2 7/8 13 3/8 X 95/8 X 7 X 2 7/8 EUE lift and susp, w/2 1/2"type H BPV profile,6 5/8 EN,2-3/8" continuous control line BHTA,Bowen,3 1/8 5M X 2 Y Bowen Union 11 Amor as Valve,Swab,WKM-M, " plorill 3 1/8 5M FE,HWO,DD trimi ">� o° Valve,SSV,WKM-M, l — ,_/li_ ,z--- 3 1/8 SM FE,Omni oper, EE trim I CI tt o a Valve,Master,WKM-M =tg, 3 1/8 5M FE,HWO,DD trim a - i Valve,Master,WKM-M, _; � 3 1/8 5M FE,HWO,DD trim ,'u�o-: az i H _�1 .tit =ta-. Completion spool,C-29L, ti tit 11 5M FE X FE,17"in length 1fih c: ' h ti _[ _Ho", 241 Tubing head,CIW-DCB, [U Ji Valve,WKM-M,2 1/16 5M 13 5/8 3M X 11 5Mrip,w/2- FE,HWO,AA 2 1/16 5M EFO,X-bottom I 1 . I[° 5`1l-t.', prep w/1/:VR profile a , ° 3I it'. . tt, `'t Casing spool,CIW-WF, _ Valve,CIW-FC,2 1/16 5M FE, 13 5/8 3M X 13 5/8 3M, ,It lar HWO,AA w/2-21/165M EFO 'If � 0111• .' tit s Ell Casing head,Shaffer-KD, II i 13 5/8 3M X 13"SOW bottom,w/2"LPO it I t ti I■I'I i j 2"LP plug valve Monopod Platform 2014 BOP (A-17) Nam.Alaska,t.1A 04/09/2014 Rig Floor • Bottom of air boot flange 5'below rig floor 15.05' 16- 9. 0' 6"9.50' Pipe I11 III 11111itit • lit lit 111 111 tit lit iIt\I 1 26.25' 3.74' Shaffer 13 5/8 5M III Ill Iii Shaffer SL ._�' _ � 2 7/8-5.5 Variables 2.83' =� 13 5/8 5M — Blind • IfI III III 1.76' ; �°,� 'It Mud Cross "4 '6/ 1111 111 III litlil ttt 0��J ®� 135/85MFEXFE w/31/85MEFO w/2 1/16 5M manual and HCR valves for choke and I t 1 III.1 t 1 11I tJ I kill lines,w/Unibolt end connections for lines 2.87' w Drill deck Riser 13 5/8 5M FE X 13 5/8 5M FE k 111 tit til tit lit ItI Itt Itt Iil Itl Spool 1.33' 13 5/8 5M X 11 5M 111 til tit iit tit Wellhead @ 6.05' Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,April 09, 2014 3:30 PM To: Dan Marlowe' Cc: Regg,James B (DOA);Juanita Lovett;Ted Kramer Subject: RE: Rush:A-17rd PTD 181-067 Sundry request Dan, You have verbal approval to perform RWO as proposed in your sundry application. The request to test the Blind rams after the tubing is pulled is denied. You will have to set a TWC to test BOPE then reset a BPV if you wish to have one in your tubing string when you pull the hanger. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Wednesday, April 09, 2014 2:16 PM To: Schwartz, Guy L(DOA) Cc: Regg, James B (DOA); Juanita Lovett; Ted Kramer Subject: RE: Rush: A-17rd PTD 181-067 Sundry request Guy, Per your request The background on this is that our ESP is "locking up" causing it to trip offline once to twice per day.As we are scheduled to start the Drill well (A-31) which will tie the rig up for approximately 70 days. Our goal is to fix this issue now prior to starting the drill well next week so we don't have to sit with a failed ESP in the well waiting for rig availability. In addition we would like to ask for a waiver to leave the BPV in the tubing and test the blinds once we pull the tubing out of the well. This will allow us to be able to continue to pump on the well while we release the packer. We believe with the high set packer set in this well, being able to pump down the tubing will aid in keeping the well under control. Once we are out of the well with the tubing,we will test the blinds at that time. Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe@hilcorp.com Hilcorp A Company Built on Energy 1 From: Dan Marlowe Sent: April 09, 2014 10:31 AM To: Schwartz, Guy(guy.schwartz@alaska.gov) Cc: Regg,James B(DOA) (jim.regg(aalaska.gov); Juanita Lovett; Ted Kramer Subject: Rush: A-17rd PTD 181-067 Sundry request Importance: High Guy We will be sending this sundry request over before lunch. This is a rush job that we would like to complete prior to the drill well.We are skidding the rig now and will be ready as soon as we obtain Sunday approval We are working up the BOP stack drawing and proposed wellhead diagram now and then will send over official copies. Sorry about the short notice Call me with any questions Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp.com Hilcorp A Company Built on Energy 2 • STATE OF ALASKA RECEIV ED AL A OIL AND GAS CONSERVATION COMM,__,ION REPORT OF SUNDRY WELL OPERATIONS JAN 2 1 201�4 1.Operations Abandon El Repair Well❑ Plug Perforations ❑ Perforate ❑ Other(]AVpef1�IL' Performed: Alter Casing❑ Pull Tubing 0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development E Exploratory ❑ 181-067 3.Address: 3800 Centerpopint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20135-01• 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 - Trading Bay St/A-17RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Trading Bay Field/Middle Kenai B Oil Pool 11.Present Well Condition Summary: Total Depth measured , 5,100 feet Plugs measured N/A feet true vertical 4,244 feet Junk measured N/A feet Effective Depth measured • 5,027 feet Packer measured 329'&4,471' feet true vertical 4,184 feet true vertical 329'&3,735' feet Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,064' 13/3-8" 1,064' 1,036' 3,090 psi 1,540 psi Intermediate 2,637' 9-5/8" 2,637' 2,307' 6,870 psi 4,760 psi Production 5,073' 7" 5,073' 4,222' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Schematic feet cc True Vertical depth See Schematic feet �F� MAY L rJ 4 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 4,188'(MD) 3,510'(ND) Pkr 329'(MD)/329'(ND) Packers and SSSV(type,measured and true vertical depth) Pkr 4,471'(MD)/3,735'(ND) SSSV 307'(MD)/307'(ND) 12.Stimulation or cement squeeze summary: p Intervals treated(measured): RBDMSA'S MAY 16 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 12 9 5 547 76 Subsequent to operation: 258 121 88 95 80 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run. Exploratory[] Development • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil. ly1 Gas El WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-481 Contact Ted Kramer Email tkramertc7i.hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature „OP-601 Phone (907)777-8420 Date 1/20/2014 y2,... s---22-/I Form 10-404 Revised 10/2012 `_ ji/O_/r Submit Original Only ' Trading Bay Unit • SCHEMATIC Well #A-17RD API#50-733-20135-01 Completed 2/90 CASING AND TUBING DETAIL RIB toTBG Hngr=39.42' SIZE WT GRADE CONN ID TOP BTM. Tree correction:Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 39' 1064' 9-5/8" 47.0 N-80&S-95 8rd LT&C 8.681 39' 2637' I1 1 2I 7 29 N-80 6.184 39' 5073' -� - Tubing: 3 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf 4,188' --)4 JEWELRY DETAIL NO. Depth ID Item ----- 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 307' SSSV 2 329' Packer 3 343' X Nipple 4 352' Gas Lift Mandrel w/Orifice Valve 5 4,188' Head 6 4,189' Pump 7 4,216' Intake 8 4,220' ESP Shroud _ 9 4,225' Motor 10 4,235' Centralizer 11 4,471' Prod Model D Sump Packer FILL 1.75"bailer run to"max.safe depth of 4900' 11/17/02 B24-6 PERFORATION DATA 5= 8• 26-7 Top Btm Top Btm Accum Date 828-6 Zone (MD) (MD) (TVD) (TVD) Amt SPF Last Opr Present Condition 8• 31 B 24-6 3,192' 3,252' 2,736' 2,782' 60' 12/14/13 Open B 26-7 3,432' 3,540' 2,922' 3,006' 108' 12/14/13 Open 5 B 28-6 3,660' 3,704' 3,098' 3,123' 44' 12/14/13 , Open 6 = B 33-6 Pre-Fracd w/80 cuft of 20-40 7 - B 31-8 3,998' 4,127' 3,360' 3,462' 129' 8 2/90 Gravel 8 B 31-8 4,002' _ 4,118' 3,363' 3,445' 116' 12/14/13 Open 9 Pre-Fracd w/80 cuft of 20-40 10 - B 33-6 4,179' 4,224' 3,503' 3,539' 45' 8 2/90 Gravel 841-3 B 41-3 4,303' 4,327' 3,601' 3,620' 24' 8 2/90 Pre-Fracd w/80 cuft of 20-40 Gravel B 41-3 4,308' 4,328' 3,605' 3,621' 20' _ 12/14/13 Open B 41-8 4,355' 4,451' 3,643' 3,719' 96' 8 2/90 Pre-Fracd w/80 cuft of 20-40 _ Gravel _ 8• 41 B 41-8 4,358' 4,444' 3,645' 3,714' 86' 12/14/13 Open i gl=tig 11 VO3 ELEV=101' PBTD=5,027' TD=5100' ANGLE thruINTERVAL=38.3° Updated by: HI 01/17/14 Hilcorp Alaska, LLC HikorpAlaska.LU: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-17RD 50-73320135-01 181-067 12/5/2013 12/19/2013 Daily Operations: 12/05/13-Thursday Skid rig to A-17RD. Rigging up. 12/06/13-Friday Nipple down and remove flow line from tree.Nipple down gas lift lines and nipple up 1502 on annulus valve.Rigging up lubricator and test same to 1500 psi._Rih w/tbg punch,tie into tbg detail,punch holes in tbg at 3,836'to 3,839'ELM. POOH.Rig down E-line.Circ well.Pump 200 bbls 8.6 ppg w/3%KCL taking returns to production,pumping at 2 bpm pressure at 250 800 psi,pump 13 bbls before showing any pressure at sample port at production header.Pumped total of 250 bbls,got back oil.Water and gas in returns,shut down monitor well.Pump 105 bbls 8.6 ppg w/3%KCL, pump 2 bbls got returns at header,spot 15 bbls size salt pill and spot in place. Rig down lines.Well on vacuum.Install back pressure valve.Continue to nipple down tree and nipple up BOP.Nipple up BOP's. 12/07/13-Saturday Modify bell nipple,re-install bell nipple continue with BOP test 250p_si low and 2500_psi high.Jim Regg(AOGCC)waived witness to BOP test.Pull BPV and install TWC.Continue to test.Continue testing BOP. Annular would not test. Mechanic coming out to re-build annular.Housekeeping.Pull bonnet on annular and cleaned. 12/08/13-Sunday Working on annular.Replacing o-ring and seals. Continue repairing annular and testing annular to 250 psi low and 2500 psi hi on 2-7/8"and 4"pipe ok).Rig down test equipment and clear floor.Rig up E-line. RIH with tubing punch and punch 10-.34"dia.holes from 3,955'to 3,957.5'.POOH.RIH w/2"radial torch and sever 3-1/2"blank pipe at 3,952',16'from top of first screen.Rig down E-line and prep to pull pipe.Pull hanger to floor.Pull to 60k to unseat hanger,dropped to 40k and 45k to pull seals out packer at 3,855'.Tubing travel at 38k.Prep to pump and pull tubing.Took 43 bbls to fill hole.Pumped 40 bbls salt pill leaving 6 bbls in tubing.Loss rate 5 bbl/hr. Lay down 2-7/8"tubing filling hole every 10 joints. 12/09/13-Monday POOH w/2-7/8"6.4#N-80 Buttress production tbg,pups.GLM,seal assembly.Found no holes in tbg.Clean rig floor,handling tools,and pipe rack. Lay down 6.5 drill collars out of derrick. Pick up BHA,TIH to 310 ft.BHA=(S-1 Pulling tool,x/o sub,4-3/4"Bowen Lub,Bumper sub,4-3/4"Bowen Oil jar,3-1/2"IF pump out sub,(9)4-3/4"spiral Drill Collars,x/over sub=310.93'. Trip in hole picking up 4"HT 38 drill pipe to 3,828'.Circulate bottoms up at 5 BPM/375 psi.Engage_packer at 3,852'.Circulated bottoms up.Released bottom collar and top of packer and then went back down and latch top part of packer.Worked free.POOH with packer and cut. 12/10/13-Tuesday Finish laying down Baker S1 packer and 3 blank pipe(97 ft total).Clear rig floor and Beaver slide,static loss at 1.5 bph.P/U BHA#2=(6'Scallop bottom shoe,18 jts 5-3/4"TSS Washpipe,5-3/4"Washover boot Basket,double Pin Sub,Bit sub w/float,4-3/4"Bowen lub,bumper sub,4-3/4" Bowen Oil jar,3-1/2"IF pump out sub,(9)4-3/4"Spiral Drill Collars,4-3/4"Bowen Acc Jar,X/o sub=854.66'.Trip in hole w/4"Drill pipe to 3,837'. Wash through spot at 3,860'and do to top of cut at 3,950'. Wash over tbg stub and screens from 3,950'to 4,468'using various parameters-CBU- min sand across shakers. Blow down Kelly/mud line-monitor well 0.5 bph fluid loss. Monitor well-1 bph loss-POOH.Change out elevators. L/D BHA#2. LID 18 jts 5 3/4"wash pipe-wash over shoe' 80%worn out.Clear floor of wash pipe running tools-get measurements of derrick for Top Drive.Fluid loss to well today 151 bbls.Total fluid loss to well 513 bbls. Sized Salt Pill loss to well today 0 bbls. Total SSP loss to well 47 bbls. Hilcorp Alaska, LLC HikorpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-17RD 50-73320135-01 181-067 12/5/2013 12/19/2013 Daily Operations: 12/11/13-Wednesday Clear rig floor&service rig.Couldn't get derrick measurements due to high winds.PU BHA#3=6"drag shoe,WP extension,Spear w/2.933 grapple, X0,Boot basket,XO,Bit sub w/float,Bumper sub,Oil jars,Pump out sub,9 DCs,Acc jars,XO=331.93 [323.67 to spear].RIH to 3,935',Break circ., establish parameters.Work down over to of fish at 3,952'.PU a extra 7k on the up wt but no increase in pump pressure.Blow down and POOH to BHA.Stand back DCs and Lay down fish[Screens].Recovered all the fish,520.88'.Break dn spear assem BHA,Clean boot basket,[Recovered 1 lb black tar and sand]and clear rig floor of tools.PU BHA#4=6'Econo mill,7"csg scraper,2 boot baskets,Bit sub,Bumper sub,Oil jars,Pump out sub,9 DCs,XO=318.54.RIH tag at 4,468'-no fill-CBU min amount sand at shakers-pull up hole 60'-let any fill fall out-RBIH tag at 4,468'no fill-CBU- no sand at shakers. Blow down Kelly/mud line-monitor well 2 bph loss.POOH with BHA#4.LD BHA-clean boot baskets-no recovery.Clean rig floor.RU e-line.MU TIW vlv-hang sheaves- 2 bph loss.RIH and log up from 4,468 to 2,500'with GR/CCL-email log data to Anc Eng.POOH with logging tools.Fluid 3%Brine loss to well today 52 bbls-Total fluid 3%Brine loss to well 565(corrected)bbls-Sized Salt Pill loss to well today 0 bbls- Total SSP loss to well 47 bbls-Metal from Ditch Magnets today 3 lbs-Metal from Boot Baskets today-5.5 lbs-Total metal recovered from well 8.5 lbs. 12/12/13-Thursday Rig down E-line.Have PJSM.Work spool into sub base.Put new tbg spool in wellhead room.Work on rig maintaince projects.Run 3 stds of 4-3/4"DC and PU RTTS.RIH to 3,170'.Set RTTS at 3,170'and rig up to test csg.Test csg to 1500 psi for 30 min on chart.Good test.Bleed off pressure.Blow lines P down,and release RTTS.POOH to RTTS.PU storm valve on top of RTTS and RIH 1 std.Set RTTS and release from storm valve.POOH. Test to 1500 psi. Test was good.Blow dn mud line.Pull wear ring,Nipple down BOPS. PU stack w/riser and secure.ND BOPE. Install ESP tubing spool piece-set BOPE,h riser down on new tbg spool-NU BOPE. Body test new tbg spool 250 psi/1500 psi-5 mins ea no leaks.RU test tools to conduct weekly BOPE test- Witness of test waived by AOGCC Jim Regg 12/12/13-set test plug.Fill stack-test jt-choke manifold-pressure shell test-replace 0-rings in test hose- install valve handle correctly. Test BOPE as per HAK-Kuukpik-AOGCC procedures-250 psi/2500 psi-hold 5 min test-good test-no failures. LD test tools-set wear bushing.Witness of test waived by AOGCC Jim Regg 2100 hrs12/12/13.Fluid 3%Brine loss to well today 22 bbls-Total fluid 3% Brine loss to well 587 bbls-Sized Salt Pill loss to well today 0 bbls-Total SSP loss to well 47 bbls-Metal from Ditch Magnets today 3 lbs-Metal from Boot Baskets today-0 lbs-Total metal recovered from well 12 lbs. 12/13/13-Friday PU and put all the equip away from nipple up and BOP test.RIH and engage storm valve_.Release RTTS..Hole took 14 bbls to fill.POOH and lay down tools. POOH with DCs,MU 6"mill.RIH to 4,428',tag packer,PU 5'and rig up circ head.Hold PJSM.Start pumping dirty KCL from OBM tank to production w/#2 pump.[144 bbls]Displace well with clean KCL w/#1 pump.[165 bbls].Continue pumping dirty KCL to production w/#2 pump. Clean trip tank.Clean pit#3 and build new volume.-pumped 465 bbls dirty fluid to production.RD high pressure hoses from production header- continue cleaning pits-clean organize work areas.PJSM.POOH. LD 4"DP-stand 34 stands in derrick and 2 singles on deck to run with TCP guns.LD BHA and 4-3/4"DC.Monitor well-cleaning rig and handling tools with power washer-organize tools and grease traveling equipment-reconnect draw works vent hose-measure derrick for top drive-organizing/inventory parts conex - 2 bph fluid loss,Fluid 3%Brine loss to well today 25 bbls- Total fluid 3%Brine loss to well 612 bbls-Sized Salt Pill loss to well today 0 bbls-Total SSP loss to well 47 bbls-Metal from Ditch Magnets today 0 lbs-Metal from Boot Baskets today-0 lbs-Total metal recovered from well 12 lbs. 12/14/13-Saturday Wait on guns and personnel due to bad weather.Work on housekeeping and maintence projects.Inspect and change pins on drwks brakes. Clean out OBM tank.Change out bail bumpers on the kelly swivel.Boat showed up with guns,2-7/8"tbg,and personnel. Unload Gun Baskets and personnel.PU safety jt for guns and rig up to run guns.Hold PJSM for running guns.Run 56 jts 4-5/8"-5 SPF millenium perf guns.Change elevators to 2-7/8"tbg-MU spacer sub-firing head-2 jts 2-7/8"tbg. Change elevators to 4"DP-run 1 std DPand RA Sub. RIH with 33 stands 4"DP-PU 5'pup jt- MU TIW.RU eline. RIH with GR/CCL and tie in perf guns with RA marker at 3,006'-top shot at 3,194'-bottom shot at 4,444'-POOH.RD eline. Monitor well.Continue with cleaning rig-measuring 2-7/8"tbg-re-install reserve tank transfer pump-installing nonskid strips on steps.Fluid loss 3 bph static loss,Fluid 3%Brine loss to well today 30 bbls-Total fluid 3%Brine loss to well 642 bbls-Sized Salt Pill loss to well today 0 bbls-Total SSP loss to well 47 bbls-Metal from Ditch Magnets today 0 lbs-Metal from Boot Baskets today-0 lbs-Total metal recovered from well 12 lbs. Hilcorp Alaska, LLC HikorpAlaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-17RD 50-73320135-01 181-067 12/5/2013 12/19/2013 Daily Operations: 12/15/13-Sunday Work on rig maintence projects.Finish installing the tread grip to the beaver slide stairs.Continue cleaning solids out of the OBM tank.Put heat tapes and insulation back on the reserve pump line.Continue vac out OBM tank.MU lubricator for rod/ball drop firing rod.Monitor well 2 bph loss. Blow thru lines. Clean/organize rig.Drop ball rod and fire TCP guns-guns fired at 2026 hrs-fluid level dropped^'10'.Load well with 9 bbls fluid- Circulate condition well at 5 bpm 325 psi-gas to surface with 62 bbls pumped-max gas units 35-146 bbls pumped. Monitor well-10 bph static loss. Circulate/condition well with 110 bbls-max gas units 23. Monitor well-10 bph static loss-no gas to surface. RD and blow down circulating lines. POOH-LD 4"DP-10 bph fluid loss.Continue LD 4"DP.LD TCP running assy.MU safety jt. PJSM.LD TCP guns.Fluid 3%Brine loss to well today 98 bbls-Total fluid 3%Brine loss to well 740bbls-Sized Salt Pill loss to well today 0 bbls-Total SSP loss to well 47 bbls-Metal from Ditch Magnets today 0 lbs-Metal from Boot Baskets today-0 lbs-Total metal recovered from well 12 lbs. 12/16/13-Monday Finish laying down perf guns.All shots fired.Clean floor and tools.Remove gun tools and PU completion tools.Pull wear ring.Rig up completion equip.Load out guns and 4"DP on boat.Bring on completion Equip.9 bph fluid loss.PJSM.MU ESP pump assembly.PU shroud,Hang cable control line sheaves-tie in control line and power cable-test same-good.Start up new Jet Heater. MU discharge pressure sub and bolt onto pump.PJSM. RIH with ESP on 2-7/8"tbg.PJSM.Continue PU tbg and RIH with ESP assembly-test cable continuity and control line psi each 1,000',place Canon clamps every other jt.8 bph fluid loss- total 85 jts rih at report time.Fluid 3%Brine loss to well today 98 bbls-Total fluid 3%Brine loss to well 740 bbls-Sized Salt Pill loss to well today 0 bbls-Total SSP loss to well 47 bbls-Metal from Ditch Magnets today 0 lbs-Metal from Boot Baskets today- 0 lbs-Total metal recovered from well 12 lbs. 12/17/13-Tuesday Continue RIH w/ESP completion on 2-7/8"tbg. Run 118 its total. MU GLM,X-Nipple,and Dual string packer. Hole taking 11 BPH.{putting canon clamps on every other Jt and test ESP cable every 1,000'). Cut cable and make splice at connectors on short string side of dual string packer. Had to hook up connectors on the bottom and top of the packer. Run chemical injection lines through packer. Test Schlumberger ESP cable. MU SSSV and test to 4,000psi for 5 min. Good test. PU 1 more jt of tbg and install canon clamps and bands. Schlumberger said they were not sure about there connection so we picked back up removing the canon clamps,bands,and SSSV line. Re-test there ESP cable. Tested good. Hook SSSV control line and test again. Continue RIH putting canon clamps on every collar. RIH to 4,198'. MU hanger and landing jt.w/penetrator opening facing east. Tie into hanger with SSSV line and Both chemical injections lines.Splice ESP cable into penetrator on hanger. Attempt to test cable. No test @ Power Pak Connection. POOH to packer inspecting the cable.Found flat spot on cable just below the packer. Picked up hole to splice and found that the main cable pulled out of the bottom of the Packer Lead Connector. The splice was obviously to long and had been wrapped around the tubing several times. Tested the main cable down hole with good test. Schlumberger consult with town and try to find another Main Cable to Packer Lead Connector for splice. One not available according to Schlumberger. Perform Main Cable to Packer Lead field splice. Losses at 11 BPH @ 03:00. Fluid 3%Brine loss to well today 182 bbls-Total fluid 3%Brine loss to well 1,159bbls-Sized Salt Pill loss to well today 0 bbls-Total SSP loss to well 47 bbls-Metal from Ditch Magnets today 0 lbs-Metal from Boot Baskets today-0 lbs-Total metal recovered from well 12 lbs. Hilcorp Alaska, LLC HHeart)Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-17RD 50-73320135-01 181-067 12/5/2013 12/19/2013 Daily Operations: 12/18/13-Wednesday Continue to make field splice below packer. [Hole taking 11 BPH] Attempt to take slack out of cable by picking string up to GLM. Ended up just getting more slack. The decission was made to cut the cable and re-splice it to make it tighter. Cut cable at splice and take out about 1'. Make 2nd lead field splice. Test 300'of cable from hanger to top of packer that we pulled back onto the spool. Now it wouldnt test. Spool it off and string new cable back up through sheave. Install new connector on cable and test. Tested good. Use adjustment on connector on top of packer to take up slack. Install bands to secure lines below packer. Test cable and it tested good. RUN into SSSV and install line. Test to 4,000 psi for 5 min. Good test. Continue RIH installing canon clamps and bands. PU hanger and landing jt,MU and install penetrator. Meg and test ESP cable. Make tubing hanger pentrator splice. Test Good. MU to penetrator. Test Good. Termintate flat pack and SSSV control lines. Test good. MU Umbilicle Cord to TBG HGR. Test Good. Land Tubing Hanger with 20K String Weight below hanger. Up Wt 55K,Dn Wt 35K.Test Cable. Good Test. RILDS. Test cable with weak MEG signal. Pull Hanger to floor. Remove and clean umbilicle cord connection. Test Good. Land TBG HGR. Test Good. RILDS. Test Good. Clean and clear rig floor of tools.Rig down ESP running equipment. Shuffle equipment on deck for slick Line. Rig up Pollard Slick Line. Trouble shoot power issue with 480 volt recepticle for Wireline unit. Found one of three breakers was thrown in MCC. Continue R/U Pollard Slickline. RIH and set plug in 'X'Nipple. POOH,MU and RIH and set Prong. POOH set slick line aside. Rig up and pump down tubing to 3,000 psi with good indication of Packer setting. Hold 3,000 psi for 30 min to ensure good setting of Packer. Maintain 3,000 psi on tubing and pump down Annulus to test top of packer and 7"casing from 328'to surface @ 1,500 psi. Chart same for 15 min. Blow Down and rig down circulating lines. R/U Pollard Slick Line. RIH and pull prong and PX Plug. 12/19/13-Thursday Rig down Pollard slickline. Set BPV. RD @ Weatherford equip and clear equip off rig floor. Bleed down accumulator. Nipple down BOPs and remove riser. Nipple up tree and test void to 5,000 psi.Lay do 4'handling equip. Orient tree and install emergrency shut-in valve and blank flange. Test tree to 5,000 psi for 5 min. Good test. Turn well over to production. [Working on flushing out accumulator system]Prep rig for skidding. Remove flow lines and lines tied off to sub.Freeze protect test pump. String hyd lines for jacking rig. PJSM for skidding Rig. Skid rig East 10'. Remove flow trough. Set Mechanics Shop. Move rams to west side. Skid East 2'. Remove Beaver slide. Shuffle Equipment. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, December 06, 2013 2:07 PM To: 'Ted Kramer'; Ferguson,Victoria L(DOA) Cc: Juanita Lovett Subject: RE:Completion Change for A-17RD Sundry Number 313-481 PTD#181-067 Ted, As per our phone conversation the proposed change to the completion is approved. Packer depth is not regulated ... as long as the ScSSV is 100 ft below mudline. Guy Schwartz Senior Petroleum Engineer AOGCC NED { t ` .. 907-301-4533 cell 907-793-1226 office From: Ted Kramer [niailto tkramera hilcorp_com] Sent: Friday, December 06, 2013 1:24 PM To: Schwartz, Guy L(DOA); Ferguson, Victoria L(DOA) Cc: Juanita Lovett Subject: Completion Change for A-17RD Sundry Number 313-481 PTD# 181-067 Guy and Victoria, Hilcorp is asking to make a change to the ESP completion on the above workover. Because of the possibility of gas,we would like to move the esp packer up the hole just underneath the SSSV and then add an orifice valve below it to direct any gas back into the tubing. Hilcorp feels that this is the best way to complete this well to satisfy the requirement of having an SSSV and to keep gas from building up under the packer and gas locking the ESP. This design also involves running the ESP deeper in the well and utilizing a shroud. This is desired in order to insure proper gas separation,motor cooling and maximum drawdown while retaining good pump intake pressure in this B-zone only completion. I have attached schematics showing both the original proposed completion(dated 9-05-13)and the revised completion (dated 12-03-13) . Hilcorp asks the commission's approval to make this change. Ted Kramer Sr.Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 1 rading Bay Unit PROPOSED Well #A-17RD ��`'J API#50-733-20135-01 Completed 2/90 CASING AND TUBING DETAIL RKBtoTBGHgr=39.42' SIZE WT GRADE CONN ID TOP BTM. Tree connection:Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 39' 1064' 9-5/8" 47.0 N-80&5-95 8rd LT&C 8.681 39' 2637' I - 1 � 2 I 7" 29 N-80 6.184 39' 5073' Tubing: 2-7/8" 6.4 L-80 8rd EUE 2.441 Surf 3 r JEWELRY DETAIL NO. Depth ID Item 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 S55V 2 Packer /'%. 3 -330" Gas Lift Mandrel w/Orifice Valve w 4 ±4,230' Bottom of ESP ',_---- .... FILL Tagged w/2"Swedge @ 4452'KB 12/2/05 1.75"bailer run to"max.safe depth of 4900' 11/17/02 V 0 w. 824- PERFORATION DATA li,k B26-7 Top Btm Top Btm Accum Date B28.6 Zone (MD) (MD) (TVD) (TVD) Amt SPF Last Opr Present Condition g. B318 B 24-6 ±3,192' ±3,252' 12,736' ±2,782' 60' Future B 26-7 ±3,432' ±3,540' ±2,922' ±3,006' Future 3 28-6 ±3,660' ±3,704' X3,098' ±3,123' Future ® = 833-6 Pre-Fracd w/80 cuft of 20-40 B 31-8 3,998' 4,127' 3,360' 3,462' 129' 8 2/90 Gravel L ? ±4,118' x3,363' ±3,445' 116' ■u Lure II1l r 4 B 33-6 4,179' 4,224' 3,503' 3,539' 45' 8 2/90 Pre-Fracd w/80 cuft of 20-40 Gravel 8413 B 41-3 4,303' 4,327' 3,601' 3,620' 24' 8 2/90 Pre-Fracd w/80 tuft of 20-40 Gravel B 41-3 -4,308' ±4,328' b05 621' Future Pre-Fracd w/80 cuft of 20-40 P. B 41-8 4,355' 4,451' 3,643' 3,719' 96' 8 2/90 Gravel B41-8 B 41-8 ±4,444' ;,645 ±3,714' 86' Future I I DO KB ELEY=101' PBTD=5027' TD=5100' ANGLE thru INTERVAL=36'3° Updated by: JLL 12/03/13 trading Bay Unit PROPOSED Well #A-17RD II API#50-733-20135-01 Completed 2/90 CASING AND TUBING DETAIL RIB toTBGHngr=39,42 SIZE WT GRADE CONN ID TOP BTM. Tree connection:Dual 3"5,0001✓` 13-3/8" 61 K-55 Butt 12.515 39' 1064' 9-5/8" 47.0 N-80&5-95 8rd LT&C 8.681 39' 2637' 1 I 7" 29 N-80 6.184 39' 5073' Tubing: 2-7/8" 6.4 N-80 Butt SPLCLR 2.441 Surf ) 2 („D NO. JEWELRY DETAIL NO. Depth ID Item 3 40.8 __ 10 Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 ±300' SSSV 2 ±1,500' GLV 3 ±2,900' GLV 4 ±3,027 Packer 5 ±3,031' P . oint 6 ±3,035' X Nipple 7 ±3,036' Pup Joint -_ - 8 ±3,040' Sliding Sleeve 4 9 ±3,042' Pup Joint 6 x 5 10 ±3,1, Bottom of ESP 7 8 000 RP�®., 9 i 10 .,, -.....a., 624-6 FILL 826-7 Tagged w/2"Swedge @ 4452'KB 12/2/05 - B 28-6 1.75"bailer run to"max.safe depth of 4900' 11/17/02 8 31-8 633$ PERFORATION DATA Top Btm Top Btm Accum Date Zone (MD) (MD) (ND) (ND) Amt SPF Last Opr Present Condition B 24-6 ±3,192' ±3,252' ±2,736' ±2,782' 60' Future _ B 26-7 ±3,432' ±3,540' ±2,922' _ ±3,006' 108' _ Future B41-3 B 28-6 ±3,660' *3,704' ±3,098' ±3,123' 44' Future Pre-Fracd w/80 cuft of 20-40 B 31-8 3,998' 4,127' 3,360' 3,462' 129' 8 2/90 Gravel ±4,1 ±3,363' 45' 116' Future B 33 6 4,179' 4,224' 3,503' 3,539' 45' 8 2/90 Pre-Fracd w/80 cuft of 20-40 J� 841 Gravel (/ 6 41-3 4,303' 4,327' 3,601' 3,620' 24' 8 2/90 Pre-Fracd w/80 cuft of 20-40 Gravel B 41-3 ±4,308' ±4,328' ±3,605' Future 1 B 41-8 4,355' 4,451' 3,643' 3,719' 96' 8 2/90 I Pre-Fracd w/80 cuft of 20 40 Gravel B 41-8 ±4, ±4,444' ±3,645' ±3,714' 86' Future i) IBELEV=101' PBTD=5,02T 1D=5100' ANGLE thru INTERVAL=38.3° Updated by: JLL 09/05/13 VOF • • 7.4._ s� THE STATE Alaska Oil and Gas OfALl l S Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O Anchorage, Alaska 99501-3572 ALAS' Main: 907.279.1433 Fax: 907.276.7542 ' Ted Kramer � ANN ® ' 0 4,013 Sr. Operations Engineer ._ Q Hilcorp Alaska, LLC VCg . 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B Oil Pool, Trading Bay St A-17RD Sundry Number: 313-481 Dear Mr. Kramer: 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 DATED this /� day of September, 2013. Encl. ll ., • • ,\4 RECEIVED STATE OF ALASKA CO. SEP 0 9 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION 5 9't 141 13 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend El Plug Perforations El Perforate 0 Pull Tubing 0 • lime Exton❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Atter Casing❑ I Other. CompleteU • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development p . 181-067 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20135-01 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 93.6 Will planned perforations require a spacing exception? Yes ❑ No O • Trading Bay St A-17RD. 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 • Trading Bay Field/Middle Kenai B Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 5,100 • 4,244 • 5,027 4,184 N/A N/A Casing Length Size MD TVD Burst Collapse Structural • Conductor Surface 1,064' 13-3/8" 1,064' 1,036' 3,090 psi 1,540 psi Intermediate 2,637' 9-5/8" 2,637' 2,307' 6,870 psi 4,760 psi Production 5,073' 7" 5,073' 4,222' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" 6.4#/N-80 3,852 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker SC1 L Pkr,Baker"D"Pkr and Otis SSSV 3,855'(MD)3,249' (ND),4,471'(MD)3.735 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development G Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/14/2013 Commencing Operations: Oil O Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramerehilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature'd;/f4.,""fr.L— Phone (907)777-8420 Date 9/9/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: si 3 q l Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 2 D° fp St 60 Q -,� J✓ ! {S RBDMS OCT 1 0 20 Spacing Exception Required? Yes ❑ No l Subsequent Form Required: /0—Li O If APPROVED BY Approved by:/✓ /` 1L/..� COMMISSIONER THE COMMISSION Date:I_/�j •-- "3 2.7 -/i ff� Submit Form and Form 10-403(Revised 10/2012) Appro p t I fo 12 onths from the date of approval. Attachments in Duplicate C��' 1 • • • Well Prognosis Well: A-17RD flilcorp Alaska,LL Date:9/6/2013 Well Name: Monopod A-17RD API Number: 50-733-20135-01 Current Status: Oil producer(Gas Lifted) Leg: N/A Estimated Start Date: September 14, 2013 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 181-067 First Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) Second Call Engineer: Trudi Hallett (907)777-8323 (0) AFE Number: Current Bottom Hole Pressure: 1,083 psi @ 4,230' (3,543 TVD) From 6/5/09 shut in survey . Maximum Expected BHP: 1,200 psi @ 4,230' MD (3,543 TVD) Max.Allowable Surface Pressure: -Opsi (Based on 1,200 psi @ 4,230'-(4,230 X 0.402 psi/ft. fluid gradient-calculated from expected production rate of 500 bpd at 30%WC.) Brief Well Summary The A-17RD well was drilled and completed as a B zone oil well in July of 1981.• i Production from the well has decreased over time and is currently making 24 bopd and 6 bwpd through four sets of B Zone gravel packed perforations from the B 31-8, B33-6, B 41-3,and the B 41-8 intervals(see attached schematic). The current re-completion plan involves removing the current gas lift completion and gravel pack, cleaning out the well to+/-5,007' MD. The well will then be perforated and placed on an ESP for artificial lift. Brief Procedure: 1. MIRU Monopod Platform Rig#56. 2. RU E-line,RIH and punch tubing at 3,840(+/-). s�, 3. Circulate Hydrocarbon off of well. Z�po f 4. ND Wellhead,NU BOP and test to 250 psi low/20389 43si high.(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 5. RU E-line. RIH and make cut in the first blank joint above the screen 3,891'(+/-). RD E-line. - 6. Pull 2-7/8"tubing string out of seal assembly and POOH laying down same. • 7. PU WS and RIH with SC-1 Retrieving tool . 8. Retrieve SC-1 packer,wash over and remove screens down to the Baker Model D sump packer at 4,471'according to the Baker fishing procedure. 9. RU E-line and RIH W/gamma ray and CCL to 4,460'. POOH logging well to 2,637'. 10. PU RTTS test packer and RIH to 3,170'and set. Pressure test casing 1,300 psi and chart same for 30 minutes. Unset and PUH with RTTS test Packer to 100'and set.— , -ist 4o 1 606r Y.: 11. ND BOP and change out tubing hanger. Re-test well head. 12. NU BOP and re-test all connections broken back to 250 psi low/2500 psi high. 13. Change out completion fluid to clean 3%Kcl water. 14. PU TCP perf guns and run into hole. RU E-fine. Use e-line to place Perf guns on depth and perforate well according to the approved Perf Request Form. • • Well Prognosis Well: A-17RD Hilcorp Alaska,LL Date:9/6/2013 15. Pick up TCP guns above perforations,monitor well for one hour by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 16. RU E-line. PU ESP,Sliding Sleeve,X-nipple,ESP twin seal Packer and RIH on 2-7/8"tubing setting the bottom of the ESP at(+/-)3,142', 17. RU Slick line. RIH with X plug and set in X nipple. Pressure up on tubing according to the Twin Seal Packer setting procedure. Set Packer. 18. Pressure up on back side to 1500 psi and pressure test packer X 7"casing. Chart for 15 minutes. 19. Hang off well. 20. ND BOP,NU wellhead and test. 21. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing • •Trading Bay Unit Well#A-17RD API#50-733-20135-01 Completed 2/90 CASING AND TUBING DETAIL RKB to TBG Hngr=39.42 SIZE WT GRADE CONN ID TOP BTM. Tree connection:Dual 3"5,00011 13-3/8" 61 K-55 Butt 12.515 39' 1064' 9-5/8" 47.0 N-80&S-95 8rd LT&C 8.681 39' 2637' I 7" 29 N-80 6.184 39' 5073' o l 1 I Tubing: 2-7/8" 6.4 N-80 Butt sat CLa 2.441 Surf 3852' 2 3 4 JEWELRY DETAIL NO. Depth ID Item 0 5 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, 1 315' 1.50 2-7/8"Otis Ball Valve,SSSV,2.313 2 1859' Camco"KBMG"GLM 6 3 2826' Cameo"KBMG" GLM 7 4 3765' Cameo"KBMG"GLM 5 3806' 2.313 Otis"XA"Sldg Sive. 3213'TVD 6 3841' 2.313 Otis"X"Nipple -�r 8 7 3854' 3.00 Baker Locator Seal Assy 8 3855' 4.00 Baker"SC-IL"Pkr 9 3889' 2.992 3-1/2"Blank Pipe 19 10 3968' 2.992 3-1/2"Wire Wrap Screen.Gravel Packed w/89 cuft of 20-40 gravel placed. 11 B 31-8 a- 13 4471' 2.406 Baker Snaplatch ealeassy latched into Mod"D"Sump Pkr 12 E. B 33-6),1 FILL 10 = B 41-3 Tagged w/2"Swedge @ 4452'KB 12/2/05 = 1.75"bailer run to"max.safe depth of 4900' 11/17/02 B 41-8 PERFORATION DATA \ Zone Top Btm Amt. SPF Last Opr. Present Condition 11 B 31-8 3,998' 4,127' 129.0' 8 2/90 Pre-Fracd w/80 tuft of 20-40 • B 33-6 4,179' 4,224' 45.0' 8 2/90 Gravel 12 B 41-3 4,303' 4,327' 24.0' 8 2/90 Pre-Fracd w/80 cult of 20.40 B 41-8 4,355' 4,451' 96.0' 8 2/90 Gravel „ 13 K9 /' KB ELEV=101' PBTD=5,027' TD=5100' ANGLE thru INTERVAL=38.3° REVISED:9/27/00 DRAWN BY: SLT Updated by BGA 6/26/06 II 0 .Trading Bay Unit PROPOSED Well#A-17RD API#50-733-20135-01 Completed 2/90 CASING AND TUBING DETAIL RKBtoTBGHngr=39.42' SIZE WT GRADE CONN ID TOP BTM. Tree correction:Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 39' 1064' 9-5/8" 47.0 N-80&5-95 8rd LT&C 8.681 39' 2637' I 1 I 7" 29 N-80 6.184 39' 5073' Tubing: 2-7/8" 6.4 N-80 Butt SPLCLR 2.441 Surf ±3,046' woo 2 JEWELRY DETAIL NO. Depth ID Item 40.8' 10"Cameron DCB Dual 2-7/8"EUE 8rd Tubing hanger, ®t 3 1 ±300' SSSV 5 2 ±1,500' GLV 3 ±2,900' GLV 4 ±3,027' Packer 5 ±3,031' Pup Joint 6 ±3,035' X Nipple �� 7 ±3,036' Pup Joint I ___ 8 ±3,040' Sliding Sleeve 9 ±3,042' Pup Joint 6 liEsi 10 ±3,142' Bottom of ESP 8 IffD1 a 9 al V _. 10 B246 FILL B 26-7 Tagged w/2"Swedge @ 4452'KB 12/2/05 828-6 1.75"bailer run to"max.safe depth of 4900' 11/17/02 B31-8 63as PERFORATION DATA Top Btm Top Btm Accum Date Zone (MD) (MD) (ND) (ND) Amt SPF Last Opr Present Condition B 24-6 ±3,192' ±3,252' ±2,736' ±2,782' 60' Future B 26-7 ±3,432' ±3,540' ±2,922' ±3,006' 108' Future 8413 1n B 28-6 ±3,660' ±3,704' ±3,098' ±3,123' 44' Future ' B 31-8 3,998' 4,127' 3,360' 3,462' 129' 8 2/90 Pre-Fracd w/80 cuft of 20-40 Gravel B41-8 Ly / B 31-8 ±4,002' ±4,118' ±3,363' ±3,445' 116' Future 1 B 33-6 4,179' 4,224' 3,503' 3,539' 45' 8 2/90 Pre-Fracd Gravel of 20-40 Pre-Fracd w/80 cuft of 20-40 B 41-3 4,303' 4,327' 3,601' 3,620' 24' 8 2/90 Gravel B 41-3 ±4,308' ±4,328' ±3,605' ±3,621' 20' Future 0 B 41-8 4,355' 4,451' 3,643' 3,719' 96' 8 2/90 Pre-Fracd w/80 cuft of 20-40 ®- Gravel 1. \ B 41-8 ±4,358' ±4,444' ±3,645' ±3,714' 86' Future SO KB ELEV=101' PBTD=5,027' TD=5100' ANGLE thru INTERVAL=38.3° Updated by: JLL 09/05/13 • • Monopod Platform 2013 BOP Stack 03/12/2013 U,Iemp Vnrkn.1.11. Rig Floor Bottom of air boot flange 5'below rig floor 16" 14.72' 9.50' N III Ill lit Nr' • •'i IIII 11 1 I II 1 111 111.11 3.74' Shaffer Ill 111111111111 26.25' - ,- Shaffer IXT 2 7/8-5 Variables 2.50' _��. 13585M — Blind r, I11 lil Iii 111 11! 1.76 �11II0.I'' • 4 !∎/d9•�II,11 Mud Cross It' 1., t: t ItI' 135/85MFEXFE w/31/85M EFO w/2 1/16 5M Choke and Kill valves w/Unibolt end connections for lines Ill Ii.11! II! I11 — 2.83' - -- Dual Cameron Flex rams III :1I Ih tt; ,tl .70' it I Ifl 111111 Drill deck 14.20' Riser 14.20' 135/85M FE X 135/85M FE II'. i '1- is 'i, Ili 1 II II 111 Spacer spool 1.5' 13 5/8 5M FEX113M It t t '.t It' Wellhead @ 15.00' •• • • Monopod Platform A-17RD Current 09/06/2013 Hilcnrp Alnnka.1.1.t, Monopod Tubing hanger,CIW-DCB, A-17RD 11 X 2 7/8 EUE lift and 13 3/8 X A-17RD 7 X 2 7/8 2 7/8 IBT susp,w/2 1/2" type H BPV profile,6'''4" EN,'A"non continuous control line BHTA,Bowen,2 9/16 5M X 2%Bowen Union ill s / fir �. Valve,Swab,CIW-F, t117,:e a 2 9/16 5M FE,HWO,DD trim O /' s 1111 I Valve,Upper Master,CIW F, = '` , 1.V 2 9/16 5M FE,HWO,DD trim ,. limo NIlC —lip Valve,Master,CIW-F, 2 9/16 5M FE,HWO,DD trim Adapter,CIW,11 5M FE X Hu ,___ Iii 29/165M,w/6'%.pocket f and%npt control line exit Tubing head,CIW-DCB, 135/83MX11SM,w/2- 1v. jI1 ��� Valve,WKM-M,21/165M 2 1/16 5M EFO,X-bottom !f FE,HWO,AA prep w/1%VR profile I ® .. I„... JIB 1= I I I I 1,. Casing spool,CIW-WF, Ill 1. Valve,CIW-FC,2 1/16 5M FE, 135/83MX135/83M, III w/2-2 1/16 5M EFO i i ( s i : _ HWO,AA III _ •r n, Casing head,Shaffer-KD, a 13 5/8 3M X 13”SOW • bottom,w/2"LPO I%I 1 III i * , 2"LP plug valve II 01•11111111X1.; war Illr r .. • •II Monopod Platform A-17RD Proposed 09/06/2013 INilenrp:tiasku.VI I Monopod Tubing hanger,Seaboard- A-17RD ESP-EN,11 X 3 1/2 EUE lift and Suspw/3' Type HBPV 133/8X95/8X7X31/2 profile,2-'''A CCL,Prepped for BIW penetrator(kwik-lok) BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I Valve,Swab,WKM-M, 3 1/8 5M FE,HWO,DD trim r Valve,Wing,WKM-M,3 1/8 ,,, ,,, 5M FE,w/15"OMNI — operator,DD trim Valve,Wing,WKM-M,2 1/16 i. o 5M FE,HWO,DD trim I ��� o Valve,Master,WKM-M, 0®• C.116 3 1/8 5M FE,HWO,DD trim d$o I. ^•. Adapter,Seaboard-ESP, 11 5M rotating flange x 3 1/8 5M rotating flange,w/ 4 11/16 pocket,w/2-F CCL, ported for BIW penetrator l�! ELI Tubing head,S-8,13 5/8 3M -ice' � ,—��� - x 11 5M,w/2-2 1/16 5M SSO,w/BG bottom lel u ICI � w/1-2 1/16 5M WKM-M . - _ �. valves " _ 1. r1 1 f �,p�t.� ,. - r 1II_l 1.,—.- _--- Casing spool,CIW-WF, Valve,CIW-FC,2 1/16 5M FE, 13 5/8 3M X 13 5/8 3M, i 8 i i lei HWO,AA w/2-2 1/16 5M EFO 1 II' 1.i111,1i '11l1'�I. � - al Casing head,Shaffer-KD, Ii 13 5/8 3M X 13"SOW Mk I bottom,w/2"LPO 11 i— I in . Ir 2"LP plug valve p.uit-� ~I ') lID~ i%~~~[K\i% ) AI,ASIiA OIL AlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR December 20, 2004 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verifications Trading Bay State A-17RD, PTD 181-067 Dear Mr. Johnson: On December 15, 2004, AOGCC Petroleum Inspector Lou Grimaldi witnessed a "no flow test" at Unocal's Monopod platform, Trading Bay State Well A-17RD. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored for several hours. The well demonstrated an inability to flow to surface unassisted, with a gas rate less than 180 standard cubic feet per hour (SCF/hr); no liquid was produced to the surface. The subsurface safety valve may be removed from service in Well A-17RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any c1eanout, 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, r-:- ;jp¡1i& B'K ~~ James B. Regg \ I Petroleum Inspection Supervisor cc: Bob Fleckenstein 8CA,NNE[i DEe G~ 1 ?OO1å 47 ç.,." L, - tJ ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '{&.-1 IZ(lblof P. I. Supervisor \ '1t DATE: December 15, 2004 FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: No-Flow Test Unocal Monopod A-17 RD Trading Bay Field PTD 181-0670 NON-CONFIDENTIAL Wednesday, December 15, 2004: I witnessed a No-Flow verification on UNOCAL's Monopod platform well #A-17RD in the Trading Bay field. Following is a timeline and well status during test. 0900 SITP <1 psi, Open well to atmosphere, initial flow at 700 scf. Decrease to less than 180scf in <1 minute 0930 Well flowing at less than 180 scf (bare whisper), no fluid. Shut-in well 1030 SITP <1 psi. Open well to atmosphere, initial flow at 600 scf. Decrease to less than 180scf in <1 minute (bare whisper). 1100 Shut-in well. 1130 SITP <1 psi. Open well to atmosphere, initial flow at 300 scf. Decrease to less than 180scf (bare whisper). 1200 Shut in well. 1215 SITP <1 psi, open well to atmosphere. Flow initially less than 180 scf and dropped to no flow. Shut-in well, turn over to production. Note: The Flow meter gauge used to check flow was incapable of measuring below 180 scf or above 2000 scf. The 60 psi gauge used to check pressure was incapable of measuring below 1 psi. This well exhibited inability to flow to surface unassisted and I recommend it be granted No-Flow status. I explained to Gary Smith (Platform Lead Operator) that any cleanout, perforating or other stimulation will require another No-Flow test. Also any significant change in flow profile should be reported SUMMARY: I witnessed No-Flow verification on UNOCAL's Monopod platform well #A-17RD in the Trading Bay field. NON-CONFIDENTIAL CC: Dwight Johnson/Glen Payment (Unocal) SCANI"E[} FES 1 /1 Z005 Attachment: None No-Flow UNOCAL TBF A-17RD 12-15-04 LG.doc MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: April 5, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field Thumdi~y, 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 iwitnessed the testing of 18 wells and53 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 A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed, lindicated 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 A-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. Su, mmarv: 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, Attachment: SVS TBF Monopod Platform 4/5/01 JJ NON-CONFIDENTIAL SVS TBF Monopod Platform 4-5-01 JJ ... Alaska Oil and Gas Conservation CommissiOn Safety Valve System Test Report Operator: UNOCAL Operator Rep: Gary Smith AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Date: Field/Unit/Pad: Trading Bay Field Monopod Separator psi: LPS 65 HPS 4/5/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GASorCYCLE i i i ii i A-01RD 19014701 65 45 42 P P P OI1~ A-~2 1660490 65 45 ... 26 3 P 43 4/5/01 OI~ , A-03RD3 1971300 65 45 42 P P P OIL A-04 1670020 A-06 1670250 65 45 45 P P '43 0IL l, A-07 1670460 65 45 42i P P P oIL A-09RD 181036'0 .... , ,, A-10 1670760 , A-il 1700240 65 ~5 43 P P '~3" OIL A-13 1680020 " 651 '45 41 P P oIL ,, A-14 1680270 ,, , A-15 .1 1680330 65 45 45 P P . P .. OIL :A-16RD 1880380 65 45 41/42 P P P OIL !A-I~RD 1810670 65 45 43 P P P OIL iA-18 1680760 6~ 45 47 P P 'P OIL A'21 1700470 65 45 46 P P ' OIL , A-22 1700310 65 45 44 P P P OIL 'A-23 1700590 ' A-23DPN 1720200 A-24RD 1810400 65 45 41 P P P oIL A-27RD1 1970630 65 45 43 p p p I" OIL A-28RD 1890920 ' 65 " 45 45 P P P OIL 3,-30 1730140 , A-32 1770180 65 45 44 P P P OIL , ,, Wells: .. 18 Components: 53 Failures: ~' 4 Failure Rate: 7.5% Ulg0Da¥ 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.-02 pilot repaired and retested "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 STATE OF ALASKA 0 E A(' ,<A OIL AND GAS CONSERVATION COMk~~'' JON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __x Alter casing __ Repair well __ 2. Name of Operator i 5. Type of Well: I Perforate Pull tubing __ Other Development ]'~n; ~n r~; 1 r,,.,,.,.,,=,,.,,, ~f r,~ ~; f,-,~.,,,; ~ , T,~,~,",'~T '~ Exploratory ............... .k. .... ,.~ ............. · ....... · · 3. Address I Stratigraphic __ P.O. Box 190247. Anch. Ak.. 99519-0247 Se~ice__ 4. [ocation of we~l at surface Monopod Platform Conductor #11 1603' N & 576· W F/SE cor., Sec. 4, T9N, R13W, S.M. At top of productive interval 3998' MD, 3237· TVD, 362· NSL & 2258· WEL of Sec. 4 At effective depth 5027' MD, 4185' TVD, 15' SNL & 2568' WEL of Sec. 9 At total depth 5100' MD, 4244' TVD, 43' SNL & 2605' WEL of Sec. 9 6. Datum elevation (DF or KB) ~n~ I r~l · 7. Unit or Property name Tradlno Bay Field -- -- 8. Well number TBS A-17RD 9. Permit number/approval number 81-67/90-005 10. APl number 50-- 733-20135-01 11. Field/Pool Tyonek "B" Zone feet 12. Present well condition summary Total depth: measured true vertical 5100 ' feet Plugs (measured) 4244 ' feet Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Pedoration depth: 5207' feet Junk(measured) 4185 ' feet Length Size Cemented Measured depth 1064' 13-3/8" 1200sxs 1064' 2637' 9-5/8" Window 2637' 5073' 7" 600sxs 5073' measured 3998'-4127'; 4179'-4224'; 4303'-4327'; 4355'-4451' True vertical depth 1037' 2309' 4222' true vertical 3237'-3327'; 3365'-3395'; 3451'-3469'; 3488'-3558' Tubing (size, grade, and measured depth) 2-7/8" N-80, 6 4# Packers and SSSV (type and measured depth) Baker "D" PKR @ 4471', Baker "SClL" PKR @ 3855' 13. Stimulation or cement squeezesummary ............ "~ ~ ~ ~ / 14. Intervalstreated(measured) See Attached ~£story Treatment description including volumes used and final pressure .... Representative Daily Average Production or Injection Data ~" OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA Subsequent to operation NA 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ~ Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/~.~- _~-'~ ~itle Environmental Engineer Form 10-404 Rev 06/15/88 Service Date 3/1 6/90 SUBMIT IN DUPLICATE 13-3/8"61//J-55 @ 1064' 9-5/8" 47# N-80 WINDOW 2637'-2700' KOP @ 2637' GRAVEL PACKED WITH 72 SXS OF OTTAWA SAND 20-40 MESH 97% OF THEORETICAL. PRE-PACKED WITH MINI FRAC IN TWO STAGES WITH 92 CF OF SAME SAND. 7" 29# N-80 @ 5073' 1 J2 J J 3 4 \ TUBING DETAIL 2-7/8", 6.4#, N-80 TBG BT&SC. 1) OTiS BALL VALVE @ 315' 2) GLM's; 3765', 2826', 1859' 3) OTIS XA SLV @ 3806' 4) OTIS "X" NIPPLE @ 3841' 5) BAKER SC-1L PACKER AT 3855' 6) BAKER SEAL ASSLY @ 3860' 7) 3-1/2", 9,2//, J-55 WIRE WRAPPED SCREEN ,012" 8) BAKER SUMP PACKER AT 4471' "B" ZONE INTERVAL 3998,-4127, 4179'-4224' 4303'-4327' 4355'-4451' JUNK AT 5015' ETD FLOAT COLLAR @ 5027' WELL TBS A-17RD PRODUCER WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL SCALE: NONE DATE: 3-06-90 UNOCAL DRILLING RECO~" ALASKA REGION PAGE NO. i of LEASE TRADING BAY STATE WELL NO. A-17RD FIELD TRADING BAY, DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 2/14/90 5027' Accepted rig at 0000 hrs. Rigged up to wellhead and displaced tubing string and casing volume below packer with 64 pcf of 3% KCL/FIW. Displaced casing lift gas with same fluid and observe well. Installed BPV and removed tree. Install crossover, riser and BOP. 2/15/90 Test BOPE after replacing packing element in annular. Pull tubing string out of production packer and circulate out gas to choke and gas buster. Monitor well, OK. Well taking 20 bbl/hr. Mixed and pumped size salt pill to perfs. POOH, down tubing and equipment. 2/16/90 Change rams and test BOPE. RIH with packer retrieving tool to Baker Model "D" packer at 3978'. Burn over packer and POOH. 2/17/90 RIH with 6" bit to 4117', clean out bridge and fell through to 4919'. Clean out fill at 4919' and had H2S alarm at shakers. Close well no pressure, check shakers and no H2S present. Circulate bottoms up to choke and gas buster with 5 ppm H2S. Continue to clean out fill to 5032'. POOH. RIH with 7" casing scraper to 5027'. POOH RIH with 7" RTTS packer and set at 3950', pressure test backside to 1500 psi for 30 minutes, OK. POOH. Pick up 3-1/2" PH-6 workstring. 0 ,'~C~,.~~ RIH measuring workstring to 5030'. Clean mud 2/18/9 ~//~, tanks, build volume of 3% KCL/FIW and filter ,.~ii~i~ ?~, ~.ii'with Baker DE and absolute filters. Mix and ?~,~ ,~ '. 4p~O.'~':~'~?: pumped 50 ~bls caustic/FIW~ 30 bbls HEC . .~ ~^~ ~ , Poly/FIW wlth 25# per bbl coarse sand, and 100 bbls FIW/DIRT magnet. Displaced well "u$u;e~£u/~ with filtered brine. Transfer sweep returns ~a '~'~ from active to reserve and clean active. Circulate and filter fluid to 28 NTU's at flowline. 2/19/90 Pick up Baker TCP gun assembly and RIH. Rig up test head, lubricator and manifold. RIH with Schlumberger GR-CCL and log guns on depth, top shot at 3998'. Attempt to set Baker "SC" test packer at 3908' negative , · Made several attempts to set packer between 3906'-3910' without success. POOH with GR-CCL. POOH, lay down packer. Pick up Baker "~" retrievam~ packer and P~ Spot ~u~o on depth anu set packer at 3s/2'. POOH with GR-CCL. 2/20/90 Make up test head, lubricator and manifold, pressure backside to 500 psi. Dropped firing bar and perforated "B" zone intervals; 3998'-4127', 4179'-4224', 4303'-4327', 4355'-4451' at 8 SPF and 600 psi H20 cushion. Open bypass and reverse tubing clean, release packer and circulate out gas (40 ppm H2S on bottoms up). Circulate and filter fluid to 30 NTU's at flowline. POOH, lay down TCP assembly. RIH with 7" casing scraper and tagged fill at 5015'. Circulate and filter fluid. POOH. RIH with Baker model "N-i" drillable bridge plug. UNOCAL DRILLING RECOk..w~ ALASKA REGION PAGE NO. 2 of LEASE TRADING BAY STATE WELL NO. A-17RD FIELD TRADING BAY DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 2/21/90 4409' 2/22/90 4500' 2/23/90 5007' 2/24/90 Set bridge plug at 4500' and POOH. RIH with Baker "EA" retrievamatic packer and 30' tubing tail, set packer at 4260' Established injection rate with ~ig pumps, 1650' psi at 3.75 BPM. Rig up Baker Sand Control equipment and mix fluids. Test lines to 5000 psi and established injection rate, 2950 psi at 10 BPM. Pumped 50 bbls of 70# HEC gel pre-pad, 25 bbls of slurry with 12 ppg 20/40 sand and 32 bbls of 705 HEC gel after pad. Final injection pressure 3000 psi at 10 BPM, 1100 psi with pumps off. Bled to 300 psi in 3 hours. Released packer and POOH. RIH with open ended tubing, tagged sand at 4409'. Mix and pumped 28 sx of sand and POOH. RIH with Baker "EA" retrievamatic packer and 30' tubing tail. Set packer at 3949' and tail at 3983'. Established injection rate, 3200 psi at 10 BPM. Pumped 50 bbls of 70~ HEC gel pre-pad, 25 bbls of slurry with 12 ppg 20/40 sand and 32 bbls of 70~ HEC gel after pad. Final shut in pressure with pumps off 1800 psi, bled to zero in 3 hours. Released packer and POOH. RIH with 3-1/2" open ended tubing and reversed out sand from 4026'-4500'.. POOH. RIH with 6" mill. Milled 7" bridge plug at 4500' and chased to 5007'. Shipped active and reserve pits to onshore facility. Cleaned pits and built volume of 3% KCL/FIW. Filter and change well over. RIH with Baker 7" x 3.25" model "D" sump packer on 3-1/2" tubing and set at 4471'. POOH. Ran 480' of 3-1/2", J-55, 9.35 Bakerweld wire wrapped screen with 2-1/16" tail pipe on 3-1/2" PH-6 tubing. Snapped in/out of sump packer at 4471', tested lines to 3500 psi, snapped into packer at 4471', dropped 1-7/16" setting ball and set Baker 7" x 4" SClL packer at 3855' with 900 psi. Other equipment as follows: Model S-22 snap latch at 4470', 3-1/2" tell tale pup at 4450', 15 joints of 3-1/2" J-55, 9.3~ blank liner at 3889', Baker 7" x 4" SCl6 packer at 3855'. Tested packer at 1000 psi and released. Obtained injection rates: "lower gravel pack positio~i 20.0 P~! ~ 2-BP~', 35~ p~i ~' 3'~ upper gravel pack position 200 psi @ 2 BPM, 350 psi @ 3 BPM, reverse position 150 D~ 0 ~2 BPM, 2~ =~i @ 3 BPM. .umped 10 bbls o~ pre-pad, 28 bbls (81 sxs) of 10 ppg slurry 10-20 mesh Ottawa sand, 5 bbls of after pad all at 2.5 BPM and 350 psi. Sanded out at 2200 psi, 65 sxs sand in place (88% of theoretical). Reverse out approximately 10 sxs and waited 3 hours. Mixed slurry for repack. Repack #1:5 bbls of pre-pad, 10 bbls (30 sxs) of 10 ppg slurry 10-20 mesh Ottawa sand, 3 bbls of after pad all at 2.5 BPM and 300 psi. Sanded out at 2000 psi. Total 72 sxs of sand in place, 97% theoretical. Reversed out approximately 20 sxs. Tested pack to 1800 psi. Closed and tested port collar at 2100 psi. POOH.. Laid down gravel pack tools and 2-1/16" tail pipe. UNOCAL DRILLING RECOR~..w~ ALASKA REGION PAGE NO. 3 of ,,,3 LEASE TRADING BAY STATE WELL NO.... A-%TRD FIELD TRADING BAY DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 2/25/90 5007' 2/26/90 Ran Schlumberger gravel pack log from 4476'-3700', good pack. Ran 2-7/8" production string and stabbed into 7" SClL packer at 3855'. Spaced out and landed tubing as follows: Baker 4" OD seal assembly 3860'-3852' 2-7/8" Otis "X" nipple at 3841' Otis "XA" sleeve at 3806' GLM's at 3766' I , 2872' 1860' Otis ball valve at 315' Install back pressure valves, remove BOPE and install tree. Completed installing tree and tested to 5000 psi, ok. Installed flowlines and released rig at 0600 hrs. STATE OF ALASKA ALASKA el L AN D GAS CONSERVATION COM MISSION ~ APPLICATION FOR SUNDRY APPROVALS" 1. Type of Request: Abandon __ Suspend __ Alter casing ~ Repair well __ Change approved program __ Pull tubing _2[. Variance __ 2. Name of Operator 15. Type of Well: AL) __ Union Oil Company of California (UNqC Development x / Exploratory __ 3. Address .]. Stratigraphic_ P.O. Box 190247, Anch, Ak., 99519-0197 Service__ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate __ Other __ 4. Locationofwellatsudace Monopod Platform Conductor #11 1608' N & 576' W f/SE cor., Sec. 4, T9N, R13W, S.M. ~topofpr0ductiveinterval 4030' MD, 3385' TVD; 1238'S & 1538'W f/Surface Loc. ~effectivedepth 5027'MD, 4185' TVD; 1618'S & 1992' W f/Surface Loc. ~to~ldepth 5100' MD, 4244' TVD; 1646' S & 2029' W f/ Surface Loc. 6. Datumelevmion(DForKB) RT 101' MSL Z Un[or ~QpertyDame .... Traa~ng uay ~e±a 8. Well number 9. Permit number 10. APl number 50-- 733-20135-01 11. Field/Pool Tyonek "B" Zone 12. Present well condition summary Total depth: meas'ured true vertical Effective depth: measured true vertical Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: Length 5,100' feet Plugs(measured) 4,244' feet 5,027' feet Junk(measured) 4,185' feet Size Cemented 1064' 13-3/8" 1200sx 2637' 9-5/8" Window 5073' 7" 600sx measured 4385'-4405'; 4313'-4320'; 4200'-4210'; 3667'-3683'; 3610'-3615'; 3520'-3527'; Measured depth true vertical Tubing (size, grade, and measured depth)2 ?/8", N-80, 6.4# @ 3980' Baker Model "D" pkr at 3970' Packers and SSSV (type and measured dg~h~s "XEL" BV at 317 True vertical depth 1064' 1037' 2637' 2309' 5073' 4222' 4108'-4115'; 4030'-4055' 3448'-3453'; 3385'-3406' 13. Attachments feet RECEIVED 04 :i~;~ !jj~ .& Gas Cons~ Description summary of proposal ~ Detailed operations program __ BOP sketch Date approved 15. Status of well classification as: Oil x Gas__ Suspended Service 14. Estimated date for commencing operation January 25, 1990 16. If proposal was verbally approved Name of approver 17. I hereby certify that the.fore, goings t~or~ct to,the best of my knowledge. . Signed~~"~'~ ~ Roberts~ Title Environmental Engineer Date /~//~P ,~~'" 'FOR COMMISSION USE ONLY / / Conditions ojfa'pproval: Notify Commission so representative may witness I Approval No. ¢~ _. ~ 0,~ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Z/o ~ Approved by order of the Commission ~pproved Returned Commissioner SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 ORIGINAL SIGNED 8¥ LONNIE C. SMITH PROCEDURE: 1) 2) 3) 4) 5) 6) 7) 8) 9) Z0) 11) ~2) 13) MIRU. Kill well, remove tree and install BOPE. Pull existing 2-7/8" single completion from 3,980'. (Completion ran in 1981). Mill over and recover permanent packer at 3,980'. Clean out to 5,027' ETD, float collar at 5,033'. RIH and perf with TCP guns 294' (8 SPF) in 4 intervals: 3998'-4127', 4179'-4224', 4303'-4327', 4355'-4451'. Clean out to 5,027' ETD. Fracture stimulate the interval 3,998'-4,451' in two stages (50 BBL, 12 PPG slurry each stage). RIH with a sump packer to 4,480' and set. MU wire wrap screen (3.5") and production packer. Gravel pack the zone from 3,998'-4,451'. Clean out to 5,027' ETD. Run a single string of 2-7/8" tubing, GLM & GLV. RDMO. NOTE: Should H2S be encountered, Unocal will conform to all requirements as set forth in 20 AAC 25.065. Anticipated SBHP: 1400 psi. '% WELL TBS A-17 I . ~____. CASING & ABANDONMENT DETAIL -- i.) Rotary Table Measurement at 0.00' ~- II.) Single CIW Tubing Hanger at 35.52' -- IlL) 13 318', 61~, J-55 Casing at 1064' ~11 l I~/.) 9 5/8' Window from 2637' to 2700' -- with KOP at 2700' I ; V.) 9 518°, 40&43.5~, J-55 & N-80 Casing , Plugged Back to 2710' VI.) 7°, 29~, N-80 Casing at 5073' IV I I ~ ! TUBING DETAIL V , 2 7/8 , 6.4¥/% N'80 TUBING 1.) Otis 'XEL' Ball Valve at 317.11 2.) Camco Gas Lift Mandrel at 2318.36' 3.) Camco Gas Lift Mandrel at 3930.53' 4.) Locator Sub at 3968.93' 5.) Baker Packer with Seal Assembly iC~l 2 from 3970.00' to 3980.05' i 6.) Bottom of Mule Shoe at 3980.52' 0,~ 3 PERFORATION RECORD I DA TE INTERVAL CONDITION' , 6118181 4385'-4405' Frac-Pac 4~1-8 Sd. Open 6/20181 4313°-4320, Frac-Pac 4.1-3 Sd. Open 6127/81 4200'-4210' Frac-Pac 33-6 Sd. Open ~ ~ ~ 6/29/81 4108'-4115'. Frac-Pac 31-8. Sd. Olden I 5 6130/81 4030'-4055' Frac-Pac 31-8 Sd. Open i I 31'8 __ 3:3'6 /t, T-3 = 4, T-8 ~E:v. ; D~TE O~w~ BHE ¢~D. i . WELL TBS A-17 I ~.~: 5/29/85 [ WELL SCHEMATIC t UNION OIL COMPANY OF CALIFORNIA ANCHORAGE. ALASKA FOau v~7 A 5/56 750 ~3-3/8" 6~# J-55 1064' / 9-5/8" 47# N-80 WINDOW 2637'-2700' KOP @ 2637' BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND 7" 29# N-80 @ 5073' 1 J2 J J 3 5 6 I 8 · TUBING DETAIL 2-7/8", 6.4~, N-SO TBG BT&C. 1) OTiS BALL VALVE 2) GLM's 3) OTiS XA SLV 4) OTIS'~/ST" PACKER 5) OTiSY,A SLV 6) OTIS"X" NIPPLE 7) BAKER SC-1L PACKER AT 3850' 8) 3-1/2", 9.2#, J-55 WIRE WRAPPED SCREEN .012" 9) BAKER SUMP PACKER AT 4471' "B" ZONE INTERVAL 3998'-4127' 4179'-4224' 4303'-4327' 4355'-4451' FLOAT COLLAR ~ 5027' WELL TBS A-17RD PRODUCER PROPOSED WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL SCALE: NONE DATE: 9-07-89 BELL NIPPLE I FLOWLINE 2" KILL LINE WITH (2) 2" 5M VALVES q[) KILL LINE FROM MUD PMP &: CEMENT UNIT 12" 3000 PSI ANNULAR __1 I I BLIND RAMS PIPE RAMS I PIPE RAMS I I RISER I I I I 15-5/8" ,3M FLANGE ADAPTER ,3M x 5M 1,3-5/8" 5M FLANGE DOUBLE GATE 5M 15-5/8" 5M FLANGE 4-" CHOKE LINE WITH ONE REMOTE &: 1 MANUAL 4." 5M VALVE I CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) I 1,3-5/8" 5M FLANGE SINGLE GATE 5M 1,3-5/8" 5M FLANGE 10" 5M x 15-5/8" 5M ADAPTER CAMERON 5M DCB SPOOL I RECEIVED 15-5/8" BOPE 5M STACK ALL DRILLING OPERATIONS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL APP'D: GSB SCALE: NONE DATE: 5/12/89 February 4, 1983 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 7247 Anchorage, Alaska 99502 Dear Mr. Anderson= The Alaska Oil and Gas Conservation Commission has recently checked the records of wells completed' since January 1, 1979. This review has revealed that the digitized data for certain logs run in a well is not on file with the Commission. The Oil and Gas Regulations require the operator to file, withtm 30 days after completion, suspension, or abandonment of a drilling well, the digitized data, if avsilable, for copying, for all logs run in the well except velocity surveys, experimental logs and dip- meter surveys. We would request that you check your records to see if the data has been submitted to the Commission and, if not, that you comply with the regulation with regard to~ the following wells: Trading Bay Unit No. D-34A Trading Bay Unit No. D-15 RD Trading Bay Unit No. D-3 RD Trading Bay Unit No. D-25 RD Trading Bay Unit No. ~.-21 RD Trading Bay Unit No. K-24 Tungak Creek No. 1 Tra'ding Bay St. No. A-17 RD Cannery Loop Unit No. 1 Cannery Loop Unit No. 2 Cannery Loop Unit No. 3 Kenat Tyonek Unit No. 43-6X Thank you for your cooperation in this matter. Yours very truly, Harry W. Kugler Commissioner BY ORDER OF THE COMMISSION be Hr, Robert C. Warthen Union Oil Company of California P. O. Box 6247 .Anchorage, Alaska 99502 April 22, 1982 Missing Information - Completed Wells Dear Bob: We wish to bring to your attention that the below-indicated material on the following Union Oil Company wells has not yet been received by the Alaska Oil and Gas Conservation Commission: W,11 Comp!~t !9_n ___Dar e, ~!$s ing Material Granite Pt. ~33-14RD 3/6'/81 -DIL/SP & CBL/VDL Elec. Logs, Trading Bay Unit ~D-gRD 3/2/82 -Digitized E. Log Tape Trading Bay Unit ~D-16RD Trading Bay Unit ~D-17RD 5/8/81 6/22/81 -Directional Survey -Elec. Logs -Directional Survey Trading Bay Unit ~K-3RD Trading Bay ~St. #A-9ED "~Trading Bay St. ~A-I?RD ~ Cannery Loop Unit ~3 /22/Sl /5/Sl 7/3/81 9/13/ 1 -Well History -Directional Survey -Digitized E. Log Tape -Digitized E. Log Tape -Digitized E. ~og Tape Kenai Uni~ #34-32 1/lS/82 -Digitized E. Log Tape -Certified Survey Plat -Directional Survey -DST or Prod. Test Reports Trail Ridge Unit 12/13/SO -Certified Survey Plat Please submit the above material at your earliest convenience since you are now in violation of Title 20, Chapter 25 of the Alaska Admin- istrative Code. Very t~uly ~jours, William Van Alen Petroleum Geologist WVA:v~I STATE Or; ALASKA ~ ALASK~ IL AND GAS CONSERVATION (]~ ~IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS/ . 1. Drilling well IX] Workover Operation [] -L~I 2-~ Nam----~ o-~ operat ~.~~oo. r~ UNION OIL COMPANY OF CALIFORNIA 81-67 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50-733-20135-01 4. Location of Well atsurface Cond. #11, 1608'N & 576'W of the SE Corner, Section 4, T9N, R13W, SM. 5. Elevationl 01 ' inKBfeet above(indicate ~B~LDF, etc.) 6. LeaAeDtesi¥~i§l and Serial No. 9. Unit or Lease Name TRADING BAY STATE 10. Well No. TBS A-17 ¢'~ 11. Field and Pool TRADING BAY - "B" For the Month of. .L],UL:¥ , 19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 5]00' TD Frac packed & recompleted in "B" zone. Re]eased rig 24'00 hrs 7/3/8]. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run · GR log f/ 4600' to 3500'. 1 6. DST data, perforating data, shows of H2S, miscellaneous data None /iJaska Oil & Gas Cons. Cornmissio,~ /mchorage 17. I hereby certify~hat the foregoing is true and correct to the best of my knowledge. SIGNED DIST DRLG SUPT DATE 8/18/81 NOTE--Rep(~/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate ~/ ~ " ALASK/~ ~'" STATE OF ALASKA . .,iAND GAS CONSERVATION C~' :tlSSION ELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL)~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 733-20135 4. Location of well at surface Conductor #11, 1608'NSL, 576'WEL of 9. Unit or Lease Name ---- TRADING BAY STATE Section 4, T9N, R13W, SM. 1-~oc^]loNs~ lO. WeliNumber "' AtlopProducinglnterval 382'NSL & 2101' WEL, Section 4, T9N, R13W, SM. Is~d. ~__~-~ TBS A-17 RD At Total Depth 37'SNL & 2,609'WEL, lB' H. ~ 11. Field and Pool Section ~1 T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 101' KB Above MS~_I ADL 18731 TRADING BAY "B" 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 6-1,1-81 K.0. 6-14-81 7-3-81 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness.of Permafrost 5100'/4244' 2639'/2308'YES[~]NO[-] ·I 317 feetMD N/A 22. Type Electric or Other Logs Run DLL-SP-GR, FDC-CNL-GR, BHC-Sonic-GR & 3-ARM CALIPER-GR 23'. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CAS NGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" .61# J-55 SURF. 1071' 17 1/2" - 9 . 5/8" 40# J-55 SURF. 2637' 12 1/4" - 7 " . 29#' N-80 SURF. 5073' 8 1/2" 600 SX P-!!O . .... 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) 2 718" 398(1' 3c~7,q' 4030-4055/ 3386-3405 TVD · .. . 4108-4115/ 3447-3453· TVD ~' :" 26. ACID, FRACTURE, CEMENT SQUEEZE' ETC' ' ". . "4200-4210/ 3520-3528 TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4313-4320/ 3609-3615 TVD · .... .~?_ A'ttachea' - 4385-4405/ 3666-3683 TVD .... · · , , , 27. " PRoDuC-~ION TEST ' ., , , Date P-irst'Production · I Method of Operatio,0.(Flowing, gas lift, etc.) :714181 " ':1 Gas 'Lift' ' ': ':' : ' , , Date of Test Hours Tested PRODUCTION FOR OIL-BBL ': GAS-MCF WATER-B'BL CHOKESlZE GAS-OIL RATIO ' ;'7i21/'81 ~'. ' 12. TEST PERIOD I~ .7.0. -- 3 40/64 -- FioTM Tubing'" Casing Pressure CALCULATED I~b OI'L-BBL GAS-MCF' i WATER-BBL OIL GRAVITY-APl (corr) ' 24-HoURRATE'"~ 1'40'"'. · 'P~es's.:168 "i '588 6 ' 21.8 "28. ' ' "' ' "-' ' ' 'CORE DATA ' · NONE .:-,. :... . AUG 1 4 1981 "Alask.~ Oil & Gas Cons. CommiSsion : . ~. , Anchora~ .. - · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME :'~ -'~' I~' 30. GEOLOGIC MARKERs ' MEAS. DEPTH TRUE VERT. DEPTH T/"B" Zone T/" C" Zone 3]8O 4844 2727 4035 · I nclu de interval tested, pressure data, all fluids recovered and gravity; GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~ ~, ~~Ii~~/~ Title DIST DRLG SUPT Date., 8/,,12/81 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and' log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. I~em 16 and 24: If this well is completed for separate production from more than one ,interval (multiple completion), so state in item 16, and in item.,24 shOw the producing intervals for only th'e 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 (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement? lng 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 A-17 FRACS SAND 41-8 PERF 4385-4405 FRAC 13,000# 100 mesh sand, 30,000# 20-40 mesh sand & 44,000# 10-20 mesh sand. 41-3 4313-20 lO,O00# 100 mesh sand & 18,000# 20-40 mesh sand 33-6 4200-10 lO,O00# 100 mesh sand, 30,000# 20-40 mesh sand & 44,000# lO-20'mesh sand. 31-8 31-8 4108-15 4030-55 lO,O00# 100 mesh sand, 30,000# 20-40 mesh sand & 44,000# 10-20 mesh 'sand. lO,O00# 100 mesh sand, 30,000# 20-40 mesh sand &'44,000# 10-20 mesh sand. AUG 1 4 Oil & Gas Cons. Ap. cborage sper -sun A. D. Etchelecu Pre.dent June 19, 1981 Mr. John Underhill Union Oil Company P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Underhill: Re: Our Boss Gyroscopic Survey Job No. Boss-16828 Well No. A-17RD (SEC4 T9N R13W) Trading Bay Unit Kenai, Alaska Date of Survey: June 17, 1981 Operator: Everett Sellers Enclosed is the "Original" and seven (7) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. KB/pr Enclosures Yours very truly, SPERRY-SUN, INC. Ken Broussard · District Manager RECEIVED ~.A-17RD TRADING BAY UNIT KENAI· ALASKA BOSS GYROSCOPIC SURVEY TRUE MEASURED VERTICAL DEPTH DEPTH BOSS 16828 SPERRY-SUN~ INC · TVD DEG MIN DEG MIN DEG/iO0 NORTH/SOUTH fAST/WEST SECTION 0.00 100.00 200.00 ~oo.oo__ 350.00 0.00 -101.00 ORIGIN AT THE SURFACE ........ 0.00 N 0.00 E 0.00 3~9.90 2~8.90 q 31 S 69 36 W 5.97 ,50 S 3.75 W 3.29 ~00 O0 399 64 298.64 6 57 S 66 0 W ~.91 2.z+2 S 8.36 W 8.12 . · ................... .~-, ........ ., ....... ~.~,-?,.,,.-~ ..................... ... ~-,~;~:~~~.~~::~!~:. ~. ................... ~.~.:~;::;!.'~?' ~'~'~ ....... 4'~ 0';-~'~ ................ 4 ~ 9 · 16 5oo.oo ~8'~9: 600.00 595.92 898.92 650 O0 64/.+ 59 543.59 12 53 S 60 0 W 6.90 37.36 S' ~+1.98 W 56.03 850,00 ~838.11 737,11 18 59 S 68 5~ ~ 6.31 56.29 S 88.25 ~ 10e.32 900.00 --~ -')50.00 [ ' ooo.oo I lo5o.oo 1 -~ '0-~;' 0'0' 885.07 784.07 21 4 S 69 6 W 4.16 62.z+3 S 10~+.2~+ W 120.76 ~_ ...... ,=_ ...... ~~,~,~. ~..~,~ .-.-,,~--~ ~?--,..~ ~~,~., .:..:.~:.~.~.,.~?~.~:.:~:,.:~ ?~ ~ ~:~::~::~:'-~.:~.:~.~:.~:~?.~.~,,~??;,~.,::~:~ .:,:~,.~::"'~,~. ~:~,::~.~:%.~.~::~,5~F::T'~ ,..~::. ..... : .~.:.'?.~. ........... · ' .... ~- .... ...... ~..'.:'.:~' ........... :~:'.--,.' ...... : ................... '-". ~",'. ,,", ,',,'"':'-'". ............... ' .......... """:':'~'~";"~'4:":"'~" ........... '"'" ........................ i'"~:'~'"';'"~'6"'""'"e'''''''''':'''''~ .................... z:"~ ;::~ ~' ', ~068.6~ 967.6~ 26 ~7 S 7~ 0 ~ 3.82 .. 1200.00 ~~300.00-- 1350.00 1400,00 1~50.00 1156.8~+ 1055.8~+ 29 55 S 70 12 W 3.6Z+ 104.61 S 22}.27 W 241.04 12 8~' ' o 2 .::.: ~::':.~ ~::~':2::~¥:':5 ~:'':'::?'?: :~:.::~ ~:~:.~'~i::::'::::~::S!:i~:~i~ii~:~;::~ · . ,.. ,, . ....,..'. _~. : ..... ~ . .... :~.:. :: :,,. 1367.83 1266.83 3~ 1 S 51 18 W 3.46 169.8~+, S 339.4A W 3/'3.00 1500.00 15 5 o. o o 1600.00 1700.00 1800.00 ~ ..... ?A..D..~ N__G_,.B,A.Y UN I T · KENAIs ALASKA BOSS GYROSCOPIC SURVEY TRUE SUB ! MEASURED VERTICAL SEA ~ ........ [~E'PTH ................. DEPTH 'TVD BOSS 16828 2¢00.00 2122.52 2021.52 37 16 S /48 30 W .21 552.37 S 771.27 i~ 948.28 ......... ~'8-O"d';~'o- .......... 2 ~ 3"~'2-~ 9 ~3~i' ;~ ' ~'9' ; ~ ~'-4~'"~""~''~'':' ............ 2900,00 2509.76 2/+08.76 39 25 S 47 /42 W 1.08 765.19 S 1004.99 W 1263.14 3000 · 00 2587 · 26 2 ~ 86 · 26 ...... ~ ~ -58 :- ". S :.-.. :~ 8..~:~ ~ .d'~:-::';-::'~:~:.:: :~.:':~ :~:'.~::::-:.-.:~:.i;;<::~:~:~:?~8~7:*...~:.-.:.-.~:;.:~.:;:~::::~?:~.~ ~I~2':6';:~1'"2'' 3~,00.00 2896.77 2795.77 39 3 S /48 6 W .51 979.95 $ 1237.52 W 1578.23 3900.00 40 00";0-o' ..... " .... ~100.00 ~2oo .oO /4~+00.00 3678.25 3577.25 37 I S 51 /42 14 .83 1382.63 S 1713'.69 W 2201.00 j ....... -4 5 0"0';'-0 O ............. 3 7'5 8; 2"4""'T':'-,,3-~;' 5:7;:'2'i~-.:T'~7~:3E;:7~'477;~:~'::': ' S7:~'~2 ~~ :O:~:: :~ ~S:0TgE=-:::-{ ~6 0 0 · 0 0 38 38 · 6 7 :. :' 3 7 3 7'6.7 :::::::::: :: :?: :.3 i UNION OIL 'COMPANY ! A-1TRD I ...... i.T~ A..D. ~..m..9~... ~.A,.~ U.~ ~.T KENAI,~ ALASKA BOSS GYROSCOPIC SURVEY BOSS 1682~ SPERRY-SUNe INC .............. · ' :: : R ECOR. D :.:O:F i :SUR V E:¥ :.:~i :? :?:!:: '.i.i:::ii::;it:.;i: .:;:'~:~ :: :'!!i;i'f:i: :i: ii::~;;~ii: :':.!i~?iL::::: ;i:.?:::f :i ::: : !i ~UE ' SUB .~: :::i CoU~.S~:' :. ::ii:;:: DEPTH DEPTH TVD DEG MIN DEG NIN DEG/IO0 NORTH/SOUTH EAST/WEST SECTIOhi ~+080,95 3979,93 55 57 S 50 3~ W o31 1572.4z+ S 19q1°28 W 2~+97o05 ....................................................... ~ .............................. . . . . :r~.. :..::?r ..~:~ :~...~ .~-.~.. ~...~...: .~...:.~ ..:. .... .~:.::~. ..::?' ..~..:..:....~.?;...~ .. .::..::~: ..~.~:...:.....::.:...~...~ :.......:~ .~'~:~.~'~'T~'~-'?~ ........ ~ i 7 ~ 0 61 · 17 :' ~ 5 · 2 ~ · : S 5 2 ;'12;: ;W;:~:] ~;:~::~;~'.:~:,:~:~:~::':~.:0 8::6t~...8:..:.'.::.~:~:~:.Wt.~;?.::.~;~;~.:::.~?..2.~:5 5 · '~ ~ ~ THE CALCULATIONS ARE BASED ON THE MINIMUM RADIUS OF CURVATURE METHOD ** HORIZONTA. L DISPLACEMENT : 2585,5I FEET AT SOUTH 51 DEG,' 1 MIN, WEST (TRUE) .................................................. i ........ i i .... :~' ':' ~!~':":i'~i': '7/ :' ]" :~i:!7' 7":i~Tl'Z!~ . . .......... iT..RADING BAY UNIT KENA I ~-,-,% L-,~ SKA .................................................................. BOSS GYROSCOPIC SURVEY 1981 BOSS 16828 hE A' S U R'E-D VER-T I-C'A-[.- :SuB ..... DEPTH DEPTH TVD ELEVATI ON NORTH/SOUTH EAST/WEST i 0 201. 301 · 401. 505. 1025. 1001. 900. -900. 79. S 1~9. ~ 1616, 1501. lz+O0- -!z~O0. 235. S ql~+. W '~: .' :: · .: :.:: .':...: :.:.....:.?.::.:t ..: .. : :.:: :. · ' · .7 :'~:-.:L-: :.:.::'.S'.::'.~.:<-.S'..Y ;~-:::::)b.~....t~'...:.:.':.'..<.b..?y.::;.:~-:.:'~'...~'::.)':': ~..)-:: ~.::.c~C'~-:.')':-.?.::g-:-~g.:.'-?b:L-:.'~-...'~-.t.'t')~.:gvc(':.>Xc'<,--..) -..' y:--7:>: ::.<:-:..'-..:.~-~-:.:-::<:<v>:.:>.>.:::c>:,.. :-::<:'.-,?.<.><: c- .. · ; 199q, ' ,: ':,: 180I:'/ ::? 1 22~7. 2001. 1900. -1900. ~91. S 702. '.~ . ........ . ':" ' 2000 .: .':: ..... . :.::;:.: .~. :: ............ :?:.:::.'::~:::.:.:: ===================== 0'0 .:.::'~-.. ~::: '-'-...:.:::.: ::.::..:.:-: :.: .' .:; ~ .':. 73 2101. : 23 - ·-.. ....... .- · ,:,,.-. :.-:.... -- ............................ :.. ............. .,... ................. .:............. ...... -. ...... · ......... ~ · ..... ......... ...- ......... ..:.:..-......-..:.:.:. :. ..... '~760. 2~01. 2889. 2501. 2~00. -2~00. 760. S 1000. ! 5277. 2801".': ::;'. :.::: 2700 3 ................................................. q05. 2'90"I · 28'0'0 . '~ ~ z, 355~. 5001. 2900,, -2900. 1036. UNION OIL 'COMP ANY A-17R D ~ i i TRA_O..~_N~.G. .B._A ¥ .UNIT . .... KENAI, ALASKA BOSS GYROSCOPIC SURVEY BOSS 16.828 ....................................................................... : . . S P:, R R:Y~'SU N :~.?i IN C!' i:~:. TRUE : . : :. : : ,EASU~ VE~C~,L SU~ SE~ T.U~ ~ECT~N~ULAR OEP TH DEPTH TVD ELEVA T I ON NOR TH/SOUTH EAST/~EST i?!~.- - --- :.i- o'5O' .................. ~oz. ~oo. . ~177. 3501. 3~00. -3~00. 1297. S 1608. 50~8. 5050· INTERPOLATED COORDINATES FOR EVERY 100.00 FEET OF SUB-SEA DEPTH ........................ i ...... "'"'~"i.'.7:~'7~:: ~-'~ 0~: i:i~'?.r:i': :. i' 0 ~'0O' ' FEE T ;; .' . . A-ITRD :': -~ :':: ::::. :" DA TE:~" OF: 198! iT.R.A..DiNG BAY..UN!? ............................................. -.= ..................... .i VERTIC:AL iSECTIONi X - KENA!· ALASKA BOSS GYROSCOPIC SURVEY BOSS 16828 SPERRY-SUN, INC : :: EC D. ~.OF~S:S:. DEPTH DEPTH TVD DEG HIN OEG gin DEG/~O0 NORTH/SOUTH EAST/WEST SECTION 0,00 0,00 -101,00 ORIGIN AT THE SURFACE 0.00 N 0,00 E' 0,00 200,00 200,00 99,00. O' .28 4 350.00 3~9.80 2~8.80 ~ 51 S 69 56 W 5.97 1.38 S 6.2~ W 5.80 400.00 399,~4 298,~Z~ 6 57 S 66 0 W 4.91 3,8~ S 11,77 W 1.1.69 600,00 595,15 ~9~,15 13 q3 S q5 24 W 6,06 3q,75 S 37,79 W 51,12 650.00 6q. 3,89 5~2,89 12 53 S 60 0 W 6,90 40,33 S 47,~5 ~.-~ 62,i8 · . : . : .:. ::.:: :..::~:~ ::::..': ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .~::. ::..: :::: :':.::~::..:.~f:.;:.:~:~:::?j:~¥:~:':::::;~.::;::~;:f;.~S ~Q::;~..~::::~:::~:~:f:~`:~::~::;:~;~;:~::~:f~::::~;~:.~;.::~;::;:~:~?:~ :f;:':: ·. 850,00 836.66 735,66 18 59 S 68 5~ W 6.31 59,41 S 96,47 W 112'75 900,00 883,32 782,32 21 z~ S 69 6 W z~,16 65,82 S 113.26 W 130,00 1100.00 1065.97 96~.97 26 17 S 71 0 W 3.82 92.7~ S .. 1'89.9~ ~ 207.3~ 1200,00 1152,65 1051,65 29 55 S 70 12 W 3,6z~ 109,63 S 2~6,R8 W 254,91 1300 · 00 1236 · 39 1135 ' 39 ~: .1:4.::?~ :i::~: 33 : 8 ~;::-~ :i::: :S !'i.::6:~:?::36:' :.~::!'~?'::~;/;~:i;:~i.;!i?L~ ~::~ 308' ~:: 2:: ~ 1A50,00 1361,90 1260,90 3~ I S 51 18 M 3,A6 181.,00. S 352,81 W 390,~0 1500,00 1402.28 1301,28 36 8 S 48 36 W 5.25 200,51 S 374',93 W 419,81 ....................................................................... ":" ...... ' "~'" '~"7~"~'' ..... ~ ~-' ~'~~'"'~"'?~"~'~'~". ~ ~'"'-~ ~ ~','~-~'"',~~",-' ...... ~~'-'v'~'<-'-'-,-'':- r .... r : '.. :. '... '.:. : ...':1.. :::..: :~ ...:-.'L.':.~ 1..:. :~. · -.1.. :...'::.. ~.:.:::: :' : -.~::..:: :..... .... ~.:..;' ..~ : ..... ~.::..:1 :...: ~: . 1800.00 1640,00 1539,00 37 35 S 48 12 W ,~3 321,93 S 511,85 W 602,29 UNION OIL 'COMPANY A-17RD 'TRADING BAY UNIT K Ef;,,l'~,' ! "~-'-~'[.~A'S' t<"X BOSS GYROSCOPIC SURVEY SPERRY-SUN, INC BOSS 16828 1900.00 1719,51 1618,51 37 20 S 48 46 W .~ 361.87 S 557.47 W 662.79 2100 · 00 1877,75. : r:l '7.7'6 '7 i~!.~:~ 8'~.' ~'~o.~b" ~'O-~'g';-3-'~-- 'i-~.35 37 2~ ' ~ 4~--~b W .~2 ~ s 739.55 w 24.00.00 2115.94 2014.94. 37 16 S 48 30 W .21 564.64 S 784.90 W 966.55 2900.00 2501.97 24.00.97 39 25 ~1oo.oo 2ese.~ 5200.00 2733.97 34.00.00 2889.19 2788.19 39 25 S 4.8 6 W .51 993.18 S 1251.90 W 1597.68 ~8"o-~-;~-o ~-~'~e;~2' ~"~-~~2~'9---~'~' .... ..... """:""~ 3900.00 3275.95 3174.95 38 5;5 S 50 6 W .50 1199.17 S 14.92.56, W 1915.93 { .......... ~4'0 o 0"2'00 --'S 35 4.; 4 g--'~,~ 2'5sT~"8'~7:=::i:~ ;~;~;: z:~¥:~:~=¥;.? ~¥5'::. ~:.~F~ · :~.:...:-.':.: :... :-?~. : ~'. ?:.':.:;-~.-: 7 }.:-~:. '-:...: ~:%A.~.:~..-.:..: :., ;-~:...:....}:~ :-.. L ...}.:':;.. y.,.:.(. :-...;-. ~(.. x.:~.F :; -:..:.:.. :-... :-..:;- .?:?:,:.. x ..:.: ..:.: .: .:....: :..:: .' , · ~ t ~ 2 o o. o o ~ 5 ~ 2 ' 7 ~ 's ~ t 1.7 ~ ' ~'o~;~'o' ~'[; 92' ~-¢~;~ ~ ~=~'~ '~ '"' '~%°~¥~;':~i=~==%i~~ ,3671.76 ,3570.76 37 1 S 51 42 W .83 1.393.z+8 S 1728.25 W 2219.15 A-ITRD KENAIe ALASKA BOSS GYROSCOPIC SURVEY BOSS 16828 SPERRY-SUN~ INC DEPTH DEPTH TVD DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/~EST SESTION ~+900.00 fl. 075.00 397q-.00 35 57 S 50 36 W .31 158,.5.26 S 195~+.89 W 2514.fl3 - ...................................................... ----7 ............. ='; ..... :'"~:~-% ']. . ~ 'F'~:q"T'T~ ~:~ "T57~;~]~-~. '~i~ ~~;?~~ '~ .~-.~: ?:~:' -.:. .:~.?¥:~::':~'::~;::.:.~' T~r:7~--:'T ....... ~'~" ' t 5 0 00. 0 0 ~ 15 6 · 5 ~ .~ 0 55.51 :::: 3 ~...:: 2 ~:: :. :::; r: .: S ;-5 2:~ :..! :~.~ ..:.~:.: ... ~..:,~:;::::::::; ~:.:~ :,:~:~?~;.,:.?:,.?;¥~: :~?':~!::.~..:~::8.:~?.;~:~¥::':~ ~:?::,?.: ::::;?:?:.~::' 5;~ 2- S ~ ! · ' .....:-~' ' ".'. . · : :-~ ::~':.. ."' :'..:,.h: :"'~:."::::t.~%~..~.:::'~?~:¥..S~ .:~-."~. ~' '~ :~-..' .':' '.::..':.~:.']'.'.:' '. '~:"~i? :',:.:i:~t:::~:::.'::.?~:.:.~.: '. '0 ' ~ " ~ s 0 s o. 0 0 ~ t ~ 7.2 s ~ 0 ~ ~. 2~'.::~'~ S.:..::.2 ~ .: :..~ ::: ::.:s :::.S:~ ~: ~ z::'.- 5 · * THE CALCULATIONS ARE BASED ON THE TANGENTIAL OR TERMINAL ANGLE METHOD ** HORIZONTAL DISPLACEMENT : 2602.52 FEET AT SOUTH 51 DEG. 2 MIN. WEST (TRUE) UNION OIL 'COMPANY A-17RD KENAI, ALASKA BOSS GYROSCOPIC SURVEY BOSS ]6828 DEPTH DEPTH TVD ELEVATI ON NOR TH/SOUTH EAST/WEST 201. q02. 503. 1140. 1258. 1377. lq98. 1625. 1877. 2003. 2129. 2255. 2001. 1900. -1900. 507. S 719. 2508. 26½0. 2-?-gg. 2899. 2 ~ o 1 · :::' '. :':::, :...::.:;. 2 2 2501. 2~00. -2400. 778. S 1019. UNION OIL 'COMPANY A-17RD KENAI9 ALASKA BOSS GYROSCOPIC SURVEY DOSS 16828 HEASURED VERTICAL SUB SEA TRUE REC TA~81.JLA R £OORDINATE$ DEPTH DEPTH TVD ELEVA T I O~ NOP, TH/$OJTH EAST/WEST 380~. 3932. ~059. ~185o ................................................................................................................................................... ~ 10.. ...... S ............................ zu.l.. ....... 3100. ............................................................... ~::.~..~.. -..3 t0.:0 ;..~.::;.~::~ :~::~.:~:::~. ::~..~::. :?:...;~::.. :~ - ~ .-;~:s .-.:~ ~;~.~:.;~;~ ::.;:.~.::: :~--::; .;~ .... 3401, 3300. -3300, 1262, S 1568. 3501. 3flOD. -3~00, 1312. S 1627. ~685, 3901. 3800. -3800. 1503. S 1857. ~809. ~001, 3900, -3900, 15~9, S 1913, ............. ~_9~_~_,~_ ............................... :'7 ..... = ~"-'4-i-O"i'~'~::: :":.::--T:"~'?~'?';~:'~:'n fi~`h~:~~:~:~~:J~T~`~A~?~?~`~`~~~~~~~?~- ...... ~ · : :, .: ".: :.. .':'-.: .::..:~::: '::':.:: '::~ ::::~ ~ ~ ~ .~ :.-:::: :~:!~.~.:~?~f L.' ':;-: :. ~ k~:u.:.-u ~¥]::' :-.":;' ======================= :.:.':~ ::.:-.:'/:L: :~:.:: ~:.~:~::-.~-~ ~ ~::'b::~.:~::~.~c~;'e~f ::~-~:~:~;:~:~:~¥f~%~::'.~?.:: .:::~ :~ 5 0 5 0 · ~ - - - ...... - ........ '~' ':"":-':' ........ "'"'-' ":'--": :"'" :':':'"'~":':"-': "'~"."':.' ':':: ':' ':~'::-:': ."- ....... .':': ~':-~- ' ...... ".' .............. :" :'.::':'. '-~ :-.~:'::?:-'~-':' :' ':'~:-:.? ':':'::'~::-'"' ':':"': :-? --' -,~ ~ ~ - -:: INTERPOLATED COORDINATES FOR EVERY 100.00 FEET OF SUB-SEA DEPTH FROM 0.00 FEET TO 4096.25 FEET i ..... " ....................... . ........................................... '" "~'- ~":-'"'~""~ ~~ ..... ?:-"-"~' .... "'"'"~"' ~" ........? .........'"~ ....... ' ~'~ ............ ; L UNION OIL tCOMP/~NY A - 17RD KENAI, ALASKA BOSS GYROSCOPIC SURVEY BOSS 168'28 SPERRY-SUN, INC · ' TRUE ./.:::SUB::: ~:.:: ::~.: ~:: DEPTH DEPTH TVD DEG NIN DEG NIN DEG/IO0 NORTH/SOUTH EAST/~EST SECTION 0,00 0.00 -101,00 ORIGIN AT THE SURFACE 0.00 N 0.00 E 0.00 ........... ~ ....... -.-,-.,-~-~-.~--~ ~-~-r ......... :- -~ ~,~---?,.~.?*-,: - -~',-~_ :~ ~ .. 06 550.00 3~9.91 2q8.91 4 31 S 69 36 W 5.97 .~8 N 3.59 W 2.57 ~00.00 500.00 550.00 600.00 399,66 298.66 6 57 S 66 0 W z~.91 1-~1 S 8.21 W 7.39 .............. .., , ..... ............ .:. ...... .,~.~:.~.~.,~.:..:. ..... ..~.:...:.~?..:.~.:?::..:?;~.::~.~.~.~.~.~.?.:.~..~.~.~...~`~.~`~..~..... ........... .~....,..... ................. 22.,3 ' --595.93 ~94.93 13 43 S 45 24 U 6.06 29.36 S 33.08 W ~.I0 650.00 6Z+Z~,59 5~+3.59 12 53 S 60 0 W 6.90 36.33 S 42.23 W 55,61 900.00 885.10 78~.10 21 4 S 69 6 W A.16 61.~2 S 104.51 W 120.37 ~ ......... ~ ........ ~: ~ =~:~ ....... ~=-,,,,~-~,, . ~'~~{~~:s~:~-:.-'. ::..' ::..F~~~ · ............. U ........................ 1' ............ ~ ~:~'"'~'?: ..... ~" S' '6 ~:~' 48' W''~?'~''~ .............. ""2'~:20'~'?'":':':~'~":':' ................... '6~~~'~.':~ 21 '~"~ 5'""W 1 ~ 8 ' 00 1100.00 1068.68 967,68 26 17 S 71 0 W 3.82 87.95 S 179.15 W 195.83 1200.00 1156.89 1055.89 29 55 S 70 12 W 3.6A~ 103.59 S 223.57 W 2A0.67 --i3 0 b';'O"O- ........... i'~'~2~-JY'--~T':"fi~'~l ~8:: :~:..: .S-..-:6~:~;.~3~ 91,2 ~ 1 ~ 5 0 . : :::.. ~: . :..: : ': ' :~ -'.'., .:.:;:;.:..:::..:~:;:.~::: ~;;~.?.:.:;~:;;:;-;:~.::;;....... :..::~.:-. :;~:%~.?:::::.";:.;;;;:~.:??.:;.. ::...::.-.:.:::.. :::..~:...:::::: '. ':::;% ~.::::<:;;..:.?.?;::~::;.;::~:¢../.;'.~':.::::.~:;:~ :':: 1 ~ 00 · 00 1326 · 08 122'5 ,"~0 38.:. ~ '::: :' :::: $ :::~-53'~:7I 2'.;?~:.~?~: 5:1;.;;;~5:: S ~;:: ';'.~ ;~'.~?;' 2 ~ --le50.00 1367.86 1266.86 3e I S 51 18 ~ 3.~6 168.77 S 339.89 ~ 372.71 1500.00 1A08,78 1307.78 36 8 S ~+8 36 W 5.25 187.26 S 361.89 W 401,~+1 ~...:~..... ..:.:. ~..........: ;.~: ...~....:...:.::.. :...?/;:..:.~:..:;.~:..:.:: .:.:.. :..:.:. ....::?~.~: ...... . .. . ~.. :.:~..~: ~ ..... :~ ..: .~: ........... :'~:.~:~....... :..:.:.....~....~..... ..~..:....~ ..~.~....~..~....~.~.:~....¥.~...~:..~...:.~:.~:.:~..~.~.?........~ . ...... ........ . ......... .:: ................. L.....:.:.:........~... ............. ......L.....~: ............ ~.:.:..:.:..~..:.!:.......~ .~..:... ': ....... ~-~'~g-O"O- ........ '164'6.77 15~5.7'?-- 37 35 S ~8 12 W .43 308.32 S ~9B.63 W 583.54 UNION OIL 'COMPANY A-17RD 'TRADING BAY UNIT BOSS GYROSCOPIC SURVEY BOSS 168-28 SPERRY-SUN, INC 1900.00 1726.16 1625.16 37 20 S 48 48 W .4A 548.61 S 544.18 W 644.18 ...................... " ..... '~'?'"? ............. '~ ......... >'~ ...... t .....~ ...... <...... :. :~'~ ?'-~:~'~' '..~.....<..::.~ .:: ..... ' 2'O"OO'.O0 .... 1805'2'~'5:--- ...... 1'70~.~3' 37:~7 ~ .... S~ ~8.~.~!~:~......~,~.?~...~:,.,?~...~.~88-~.?.~j~~5~~~~~:0~'.';"98'~' '~ 2100 · 00 18 8 4 · 5 A: 178 ~ · 54 ~: .'57 "~ 7 '.'': : S -:q 7 :-::~'6 '::~ :.;:::':' 2400.00 2122.55 2021,55 37 16 S A8 30 W .21 551.50 S 771.75 W 948.01 2600. O0 2278 2700.00 255~. 85 ~ b'O:'d'O- .......... 2'~ ~'2':~'~' '~'~'~'~=~'~" -"s~: ..... ~"': .......... ::"s'='~'~"=~~' '':~' ..... ; ~'~' ": "-"'"' ~':~'°':~'~=~~~~' ~':~':':<:' :'~': ~: :'" ~ :~';'s ~"'"": 2900.00 2509.80 2~08.80 ,39 25 S A7 q2 I,J 1.08 76~.16 S 1005.47 W 1262.90 ~ ~200.00 2v~l.~o' .:~2~0'~ .:.~. ~ .... -~'~'0' d'Tb' O- .............. ~-8 i'~'; ~ i" =::-' ~'Y:'i ~"T'~"i--~:~'-~-':''B'==:''===s=::~ ~O~=~~-4'~:~=":'~=:~:'~:g'': '~":~=~'"'":= ~':T~r~;- ,3~.00,00 2896,82 2795,82 39 ,3 S 48 6 W .51 978,92 S 1238.0,'5 W 1578,01 ,3900.00 `328:5.51 3182.51 ,38 5,3 S 50 6 W .50 i185.83 S 1A7B.08 ~ 1894.33 ;~.;' ;~:~ :F":.::<~.: :::;~ '...j.:.~:.:.::'""::;":;~'..J:::':j~:~.'.~?.~ ' :' ~20 o. 00 ~519.~ ~18"~::' 50 79-1~ 4400.00 `3678.31 `3577.31 ,37 1 S 51 /+2 W .83 1381.62 S 1714.24 W 2200.82 ~500.00 3758.30 3~57.30: :::~ ~ · . : · j .- .<: .::: ;.::.::.L: .: :'...::~::.:~- -.. ::'.'"-:.:JJ-~':.:'c::::::..~..:-.~:>:'~-:'>:<:<. ": :'<'::'::.. "<7 ::.::.c · .:' >. :?::...-..: e 600 · 00 383 8 · 73 3757 "73.: :7 :'.: 5 6? 1 0 <. ~'. <::: S;~::~;.~9:.~;:h~5~<::~;~:~:~;~;~;~..;~.~..~>5~7..?:~;~<~:;~?~:~;;~?.~`~58~:~.~39~<.~:~;.;~:~.~?~8~.5:::~7~.~?~<~;~.~;:;~?~?7:2:~ 0 ~'.1 ~.~ ~ 700 · 00 39 ~ 9. ~ 7 38 ~ 8 · ~ 7 · 36 ~ 0.' ' S ~ 9:5 ~:~:~.' ~ ~:~< :~:~'.:.::.";~.-.2 4.~ ~:?~;'.~ ~ ';.:::'~'I~96,55 :...~ S~.~ ~.; ...~'~::~?:,<-~ .85:0 .,:;73.?~.:~.:~.:.:~;:~:.:.~...?~':~.:<2 ~'8 o'~';-o o ...... ~- oo o'-;"~"~ ..... ~--~-~-~.'7~ ~-~-~ · - s-5=~.~.=-~.~.= ~.~ ~;~ ~.-.'.. '. '.'.-.'~.; i.~=.' UNION OIL 'COMPANY A-17RD 'TRADING BAY UNIT KENA!, ALASKA BOSS GYROSCOPIC SURVEY bOSS 16 8~.. 8 SPERRY-SUN, INC ............. TRUE .' . DEPTH DEPTH TVD BEG MIN BEG MZN BEG/lO0 NORTH/SOUTH EAST/WEST SECTION qgO0.O0 4081.00 3980.00 35 57 S 50 36 W .31 1571.45 S 19z~1.85 W 2496.89 ........................... ~ ................................... r:~"T'r'-'?.-"~,~-~ '~' ~ ~:~ :'~:~?~~~~~~~~'~~~.:....'-:'.'" :~.::-:. ,~:~::? h ~:~ ~: .:~::h::~:?::-:~$~,:.~.'~.:. :~L~:."~:~''', ...... ]" ", ~ 50 00 00 ~ 16 2 · 2 3 ~ 061 · 23 :. 55 ;2 ~ ;':' ';;;::. ~:;;: S. ;:~.~;~;~;~2;~5 55' ~1 .~: ~ ~ ..... "--' ..-.-.-'"'".:-:'.'";.::.c.;;:U.:.YL~:~;.:.X.',;'L.::-.i. EL.?: :.: S.i '~ .~ ·* THE CALCULATIONS ARE BASED ON THE A'VERAGE ANGLE METHOD ** HORIZONTAL DISPLACEMENT = 2585.32 FEET AT SOUTH 51 DEG. 2 MIN. WEST (TRUE) ........................................................................... -'~--~-.~-~-,--,~' -,-"~-~'r':,~""'?'-:'---'~ "~'~t ,-~,-"?~"T:-~.~'~?'~'~'-'?~~T~~f~:~.~~? ~~~]~'~i''~''~ ' ~ _, ..: .::..:; . :..:.:::~: ::.:. ::..: . ... .: : :: ::::. ~~.:~.:...~..~..:.;.~~_.:..: :.~.?:.:: .: :. : ~ ......... ~'N'I ON'"O IL ;CO'M"~'~NY A-17RD YRADING BAY UNIT ..... -K-~N'AI, ALASKA BOSS GYROSCOPIC SURVEY BOSS 16828 MEASURED DEPTH · 1252 · , ! "': ~ ......... r~-~-'d-; ................... ~'~"~; ' --' ":=:~'o''°'';:~''"' .......... ~'~'~"~ .... ~'~°""':':'~ ..... : ..... ':~" '"':"'~":~' 1616, 1501, 1400. -lqO0, 23q. S ~15. W 1 ~ 0 ~ · :: ]; .: ;:: ' '-.:~.;.: :]...: : i: :: ; .:~:.i:.:;: t..:~.;.!~.:!..?.!;L~:::;~!~.~.:.~:.!:.~:!:!%~;L:i!~.!~.:!~.;~;~%~;;!.~.:.:~.:::~:..~i:<:::: ::::::::::::::::::::::::::::: :? :'::.:;:-:.: ::::::::::::::::::::::: :::: . :::.?:,7:/~.:.:~::-<:.:.', .:.', · ~ - . 1868. ' 1701,~. ':::':::::":'::~}~':: ::::'::; 1'600"' :60 :~;:.:5'zS'::' U · ~ 21 ~1'; .................................19'0'1 · 1 '8 O0 · ' 22e7, 2001~ 1900, -1900. ~90, S 702, ~ , ..~ ..... .~. ~ ......~ ...... ~.. ~ ~ , ~~~. ~~.~ r,-~-~, .~,,~,: ............. 2'~'73-; ....... 2'1"0~; ~:. :.::. ;': ~ '; :: ::~ :2:0 O0' :;:;.:?;~:: ::;?;; :.:.:.::..::~9 ,. ~ : 2760, 2~01, 2889~ 250~ 2~00, -2~00, 760, S 999, ~; 31~7. 3276° 34-0'5 · 353~+· 29"0'~. 2'80-0. -'~uu. 3001. 2900. -2900,, 1035. KENAI, ALASKA BOSS GYROSCOPIC SURVEY BOSS 16828 . MEASURED VERTICAL SU9 SEA TRUE RECTANGULAR COORDINATES DEP TH DEPTH TVD ELEVATION NORTH/SOUTH EAST/~EST __ . .......................................... .......,..,....................................?........:...:........, .;.,.:...:.._......;....:.;.......:....:- 3922 * ~ ~u z .~: ,.,,:.' :.:.;.." , .'-. ..' :: , .... '......:--..',:,?.::.:~:.,.:'.'.' ,. '.:: ,,.: ,';,'~'.;;,,~r;,,: ~::~::;~.~`m~:.~?`~:.:`:..;.;``.~`~`?:~.~.:..~:.~..`~...~:`:.~:`~.`~:`.;~.:~:~ ~-.:. -... ";. '-...,,-~'-,.,.',.' ,.'.'.,'.,..'-.'.'-.,'-' . ~00 ' ' ~050. ~01 "" ............................................ ~' ' -~00. ~lY6- ~501. ~00. -S'00. ~ ~ o ~. , ~";~::.?, ~ ~"?:.:?:, ;'a {,~:~? ?.~:~:~:~:;~?~:' ~,~;~;~::-: :.:-.'?~',~.~.?~"~:' o:f6, ;~?:~,, .. ~, ~ :'.:.'. :~ ~ '~.~ .~ ~;?...'::::~':~::.S::~?.. ~:~.':~:.'~:. ~:):.~:~:?:~:,'~:?}: :~-~:~.':' ?.?2:' .' ~ · .~..~::~:- ;:~::~: ?):~:~:~)~)~:~<~::;~:~.~-~.~:~)T~T~'.:;.~:~' ?~:~'~:~:~:~'::~:~-T';~ ,':- T,:..'.. ~.,,..~.:~. :'::::c'.~:~',~S': ~:-:'. · ~.:'~.;~:~?c~:~':~ ~' ~ ~/~:-/~ :'~::~'~ ?r .............................. ~55~. -3800 1~88 S 18~0 ~677. 3901. 3800. ' ~801- ~001. 3900. -3900. 1535. S 1897. W , ..- . :,... ...... ............ ~ .................. ~~,~-~-,-~,.-.~,~-:~::...~..~:...:..:.:~: :.~..:. :.:....,:~.?:.?.~::..:~...?:~?:~.:.:~.:~,.:~.~:,.{ .{~,~:.~::;.:..:;-:::?~-.~..::..~:,--:~.'.~:-:~:~.:?~:~:~::~;;::.:; ~?~:~:~:y::~:`~:~:~:~::~.~:~?~::?~:~::~F~:~.:::~..`~.~:r~::~?~7~.:~:~:~:y::.~:~:~:~:~:~:~:~:::~:~:~ '::- ..~ .-.~..., :..:; ';.].~.~ .} 50~e .... :::."-.' :' '.-'."": ' ~' · ~`:~:~/~.~::?::~:~:~::~:~:~:~::~::~:::~.~:~:~:~::~:~::::~:~?::~:`:~ · .'.-~.~:~:::~;~:~:`~:~:~:~:~:~:~.;~:~:~::~:~:~:~:~:~::~:~:`:~:~:~:~.::~:~:~:~:~::~::.~::~::~:::~:~:~:~:~:~::~:~:~:~:~:~:~:`:~:~:~:.:~:~`;~::~:~:.~.:~:~:~:~.~`~:~:~.:~:~::~:~:~:.~::~.~`:~.~::~:`~:~:~:~:~.~:::~:.:~.~:~:~:.*~::~:.~:~:~`~`:.~.:~:~::~`~:~:.~::~.~:~ ..:'-~:. .... . ~ ..... ZNTERPOLATED COORDINATES FOR EVERY ~00.00 FEET OF SUB-SEA DEPTH LEASE Trading_Bay S_tate COMPLETION DATE: ,,. DATE E.T.D. 'rom '980.52 980.05 ,970.00 .968.93 To 3980.05 3970.00 3968.93 3967.96 3937."45 3930.53 2325.28 2318.36 319.11 317.11 967.96 .937.45 ,930.53 :325.28 ~318.36 319.tl 317.11 49.37 36.52 35.52 49.37 36 52 35.52 -. TYPE: ~PP~OV~ DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Length .47' 10.05' 1.07' .97' 30.51 6.92~ 1605.25' 6.92' 1999.25' 2.00' 267.74' JTS Description 2 7/8" Mule Shoe . . Baker 2 7/8 Seal Assy. Locator . . . . :.l .' i. " ',_' 7: .. 't'f 12.85' .:. _ .. 3' '.~:'.:.'.'. 2 7/8 pup "',- -'.' :i ~.-;; '.'...i' .,: -~-/-. ".'.i, ".--:' ':. ~r.!~.:.{P,.'~!3 1.00 : - . ~. .... :. :,:, ....:': .:....- ..,,~ ·. :.Hang , :-:.....;!·~.~.~,.~...~,::,.~ .:-', ,' ,, ;-- .' - ' -. , ,': 'e.;t '- .-~ ~ '- ,' ', .*-.-.-,.;~' './~" -, ,., : .,,;"- : i. ;. :.,z. ,.'-,: · .:'~' 77;-t --t , :.... -.!-.-' '- . l-'.'-<.';: F~ i-'"';';-: '?Th' ;" '?',it'" . . - -r.:. "..~.:-':- :"-' : . - .: . :'.--:%'',. . / ':' ":', ~:,%:.:~'.,?-~%:17': , .. ~LL ~RAD ASSEMBLY - ":" i:;" camco ~n~. : '.::if!. ;-.'. ~ · ,, ',, ' ": ' '-:r'T: 3'i ':- · t:5,3 .. 2 -7/8 6.4 .N-80 .:Butt. :.:~. ...'.:',:-::{:.-~'h~.., .. ',' .:-' 65 ,:,.... :.- .... . .2 7/8 6,4 ..~-ou - -"~ 9- 2 7/s". 6,4, ~-so mee.-.-.~:_. .. : .,. : . . '.: .: , CASING HEAD: CASING HANGER: CASING SPOOL: TUBING HEAD: · TUBING HANGER' TUBING HEAD TOP' MASTER VALVES: CHRISTMAS TREE TOP CONN.: ~ ,. - z ._ ._ '" ..... Form D-IOO1-B UNION OIL CO. REPAIR RECORD OF CALIFORNIA SHEET PAGE NO LEASE Trad'..~n_g__Ba_y. St. COMPLETIOiq' ~. DATE ~r~ To 5071.10 5035.03 5033. 3804. 3782.47 37.20 .. . .- _ . :~ . ,.:; . ..... ,~-,~. ; 5073.00 5071.10 5035.03 5033.29 3804.69 3782.47 37.20 .WELL NO,A-17RD FIELD Trading Bay APPROVED_, DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1.90' 7" Casing Detail '36.07' 1 Description Howco Shoe 1.74' 1228.60' 30 7" 29~ P-110 Howco Float Collar 22.22' 7" 29# P-110 Csg. 3745.27' 92 Landed Below Zero 7" N,80 29~ Pup 7" 29~ N-80 csg. CASING HEAD: C~SING HANGER: CASING SPOOL: TUBING HEAD: TUBING HANGER: TUBING HEAD TOP' MASTER VALVES: CHRISTMAS TREE TOP CONN.:, .. - , Ui'IIOH OIL CALIFOP .iI^ £LL RECORD $ :EET PAGE LEASE . ..ADL 18731 HELL HO, TBS A-17 RD FIELD TRADING BAY FIELD DATE 1 3/15/81 DAILY COST' ACC COST' AFE AMT- 2 3/16/81 DAILY COST' ACC COST: AFE AMT: 3 3/17/81 DAILY COST- ACC COST' AFE AMT' 4 3/18/81 DAILY COST' ACC COST' AFE AMT: 5 3/19/81 DATLY COST: ACC COST: ETD 8535' TD '6690' ETD (Collapsed 13 3/8" C. 1064' 9 5/8" C. 8130' FIW $. 8,785 $ 8,785 $ 1,650,000 §535' TD 6690' ETD (Collapsed P 13 3/8" C. 1064' 9 5/8" C. 8130' FIW $ 25,345 $ 34,130 $1,650,000 8535' TD 6690' ETD (Collapsed P 13 3/8" C. 1064' 9 5/8" C. 8130' FIW $ 22,213 $ 56,343 $ 1,650,000 .. 8535' TD 4612' ETD (TOF) 13 3/8".C. 1064' 9 5/8" C. 8130' :IW $ 25,260 $ 81,603 $ 1,650,000 85 5' 4610' ETD (CMT. RET.) 13 3/8" C. 1064' 9 5/8" C. 8130' FIW $ 44,422 $ 126,025 $1,650,000 ! D.E.-FAILS OF O.P_ERATIOI'tS._DESCRIP_TI_Q !S &.RE,..SUL,T,S. . 'ipe) Commenced operations @ 12'00 hr.s 3/15/81. Killed well, installed BPV, removed tree & installed BOPE De) Tested BOPE, Pulled tbg'- couldn'i~--{Jh-seat Otis · RH-1 .pkr @ 65601'. Pulled isolation plug f/ "XA" sleeve @ 6526' w/ Otis (lost 4 1/2 hrs repairing Otis WL unit). RIH w/ 2o.1/4'' jet cutter- stopped @ 4020' POOH RIH w/ 2 1/8'.' jet cutter .to 4400'. POOH & jdded high density sinker bars.' RIH & workec 2 1/3" jet cutter down to 6550' ·' Shot cutter & pkr .came free, POOH w/ WL, (tbg not cut). pe) ) Circ clean. POOH to 5026'. Pkr swabbing. Perf'd 2 7/8" tbg f/ 4982' to 4992' POOH Pkr fouled @.4620'. Couldn't work pkr ioose u~ or down. RIH w/ 2 1/4" jet cutter & jet cut 2 7/8" tbg @ 4571'. POOH l ayin9 down 2 7/8" tbg. Made up tri- state over-shot w/-2 7/8" hal.low mill & 2'7~8" grapple on 8 1/8" guide. RIH w/ overshot on 5" DP. Engauged fish @ 4571'. Could not push fish down hole or jar it up. Jet cut 2 7/8" tbg @ 4612' w/ DA 2 1/8" jet cutter. POOH. Recovered 2 cutoffs &,Otis "XO', sleeve. Fish in hole - Otis RH-1 pkr @ 4620' w/ 2 7/8" tbg top @ 4612'. RIH w/ 8 1/2" X 7 1/4" burn over-shoe on wash pipe. Tagged fill or junk @ 4619'. Washed & reamed down to pkr @ 4620'.. Burn ove~ PKR @ 4620'. Made 8" w/shoe #1. P.O.O.H. Shoe #1 was crimped on BTM - bad csg? R.I.H. w/ shoe #2. Burn over PKR @ 4620: )~de anot~her 8". swept hole W/ viscous Pill. P.O.O.H. Left entLre 3' long burn over shoe in hole. Pin on BTM of ext. /was crimped in for 1st 8", so box of shoe in hole is probably split. R.I.H. w/ O.S. w/ 2 7/8" grapple. Engauged ~Fish @ 4612'. Coul. d not work PKR up or down.: Re~leased PKR. P.O.O.H. ran 8 1/2" bit & 9 5/8" csg. scraper to 4612'. · CIRC clean & P.O.O.H. R.I.H. w/ HOWCO cmt. ret. & tagged fish @ 4612'. Picked up 2' to 4610' & set cmt. ret. Pressure tested 9 5/8" csg. above ret. to 2500 psi. UiIIOIt OIL CO?/ N OF CALIFOP .IIA WELL RECORD S ;EET D PAGE ih, -.-2 LEASE ADL 18731 . _ DATE 6 .3 20/81 DAILY COST- ACC COST' AFE AMT- 7 3/21/81 DAILY COST: ACC COST: AFE AMT' 8 2/22/81 DAILY COST' ACC COST: AFE AMT: 9 3/23-/81 DAILY COST' ACC CO~T' AFE AMT: i0 3/24/81 DAILY COST: ACC COST- AFE AMT- ETD 8535' TD 4612' ETD 13 3/8" C. 1064' 9 5/8" C. 8130;' FIW $ ..3.2,972 $ 158,997 $1,650,000 8535' TD 4530' ETD (CMT) 13 3/8" C. 1064' 9 5/8" C. 8130' FIW $ 49,281 $ 208,278 $1,650,000 8535' TD 4600' ETD (CMT) 13 3/8" C 1064' 9 5/8" C. 8130' FIW $ 21,642 $ 229,920 $1,650,000 8583' TD 4600' ETD (CMT) 13 3/8" C. 1064' 9 5/8" C. 8130' FIW $ 185,600 $ 415,520 $ 1,650.000 8583' TD 4600' ETD (CMl) 13 3/8" C. 1064' 9 5/8" C. 8130' FIW $ 8',785 $ 424,305 $1,650,000 NELL TBS A-17RD FIELD TRADING BAY FIELD DETAILS OF OPERATi_O[tS~ DE.SCRIPTIOf!S &RESULTS Sqz'd "D" & Hemlock zone perfs for abandonment w/ 1000 sxs thru cmt ret set @ 4610'. Ret failed & moved up hole to 4601' while pulling out of ret. Set back down on ret & held press on sqz for 4 hrs. POOH. RIH w/ 8 1/2" bit. Tagged ret @ 4601'. Pushed ret to 4612'. Circ clean & POOH. Ran DA · FDC-CNL-GR & CBL-VLD-GR logs. RIH w/ 8 1/2" bit & 9 5/8" csg scraper. Closed pipe rams-to test 9 5/8" csg & pumped into 9 5/8" @2100 psi. POOH. · RIH & set RTTS @4407' Tested 9 5/8" above 4407' to 2500 psi.' Tested BOPE Sqz'd bad csg under RTTS w/ 300 sxs. Held press on sqz for 2 1/2 hrs. Released tool & POOH. WOC 12 hrs. Cleaned out hard cmt f/4539' to 4600' w/ 8 1/2" bit. Tested 9 5/8" csg to 2500 psi for lO min. POOH. Ran dia-log csg. Inspection log. Log revealed numerous spots with 30 to 40% body wall reduction w/ avg. reduction of 20 to 3C~ and max. of 40 to 50%. Offloaded Frac. Equip. ran 1100' 2 7/8" kill string in hole. Removed Bope. Installed & Tested Tree. Released RIG to. TBS A-9RD #311000-A @12-00 HRS. 3-24-81. . UIlIOl.l OIL CD'?NN OF CALIFON'iIA ELL RECORD SI EET D PAGE i]O, LEASE . ADI 187,.31 ._ . DATE ETD 11 6/6/81 DAILY COST' ACC COST' AFE AMT: 12 6/7/81 DAILY COST: ACC COST: AFE AMT: 13 6/8/81 DAILY COST: ACC COST' AFE AMT' 14 6/9/81 DAILY COST' ACC COST' AFE AMT' 15 6/10/81 DAILY COST: ACC COST: AFE AMT: 8535' TD 4600' ETD 13 3/8" C. 1064' 9 5/8" C. 8130' FIW $ 20,081 $ 444,385 $1,650,000 8535' TD 2566' ETD (CMT) 13 3/8" C. 1064' 9 5/8" C. 8130' .FIW $ 40,430 $ 484,815 $1,650,000 8583' TD 2710' ETD (Ret) 13 3/8" C. 1064' 9 5/8" C. 8130' 64 PCF 160 SEC $ 3l ,860 $ 507,891 $1,650,000 8583' TD 2710' ETD (Ret) 13 3/8" C lO71' 9 5/8" C. 8130' 64 PCF 141 SEC $ 34,718 $ 542,609 $1,650,000 8583' TD 2473' ETD (RET) 13 3/8" C 1071' 9 5/8" C. 8130' 63 PCF 37 SEC $ 27,776 $ 570,385 $1,650,000 _~'ELL NO, TBS A-17RD FIELD TRADING BAY FIELD _]D~TAIL,S OF _OPERATI~OI.[S, DESCRI~TIO~.tS & RESULTS Commenced operations O0:O1 hrs 6/6/81. Removed tree, installed & tested BOPE. Pulled & laid down 2 7/8" tbg. RIH pick- ing up 5" DP to 3040'. Circ clean. POOH. Ran CBL-VDL-GR f/ 3000' to 1500'. Perfed 9 5/8" csg f/ 2737' to 2739'. RIH & set cmt ret on DP @ 2710'. Sqz'd perfs f/ 2737' to 2739' w/ 250 sxs "G" w/ 2% CaCL2. Rev clean. POOH. Perfed f/ 2641' to 2643'. RIH w/ RTTS & sqz'd perfs f/ 2641' to 2643' w/ 250 sxs CL "G". Held press on sqz 2 hrs. POOH. RIH & CO cmt f/'2543' to cmt.ret @ 2710'. Circ clean. Mixed gel mud for section. POOH. RIH w/ section mill #1. Cut section in 9 5/8".csg f/ 2637' to 2664'. CIRC clean @ 2664'. Trip for Section ~Mill #2. Cut section in 9 5/8" csg F/ 2664' to 2690'. Circ clean. Trip for section mill #3. Cut section in 9 5/8" csg. F/'2__690' t9 2700'. Circ Clean. POOH & Lay down section M.11 #3. 'RIH W/ OEDP & equalize KO plug F/ 2710' to 2524' W/ 120 'S×S "G" W/ 10% sand & 2% CACL2. CIP @ 04:00 HRS. POOH WOC 16 HRS. Removed DCB Spool and installed 12" 3M X 12' 3M casing spool. RIH & tag soft cement @ 2450'. UilIOI.l OIL CO'PA N LF CALIFORHIA WELL RECORD SI. EET D ~L PAGE iJO, -'-4 LEASE ADL 18731 DATE 16 6/11/81 DAILY 'COST' ACC COST' AFE AMT' 17 6/12/81 DAILY COST: ACC COST- AFE AMT' 18 6/13/81 DAILY COST- ACC COST: AFE AMT' 19 6/14/81 DAILY COST' ACC COST' AFE AMT: 20 6/15/8'i DAILY' COST' ACC COST' AFE AMT' ETD 2778'/141 ' 13 3/8" C. 1071 9 5/8" C. 2637' 65 PCF 46 SEC $ 41,973 $ 612,358 $2,300,000 3674'/896' 13 3/8" C. lO71' 9 5/8" C. 2637' 73 PCF 47 SEC $ 36,938 $ 658,410 $2,300,000 4470'/796' 13 3/8" C. 1071' 9 5/8" C. 2637' 73 PCF 47 SEC $ 27,451 $ 685,861 $2,300,000 5100'/630' 13 3/8" C. 1071' 9 5/8" C. 2637' 73 PCF 53 SEC $ 29,417 $ 71 5,278 $2,300, OOO 5100' TD 13 3/8" C. 1071' 9 5/8" C. 2637' 73 PCF 53 SEC $ 74,115 $ 780,279 $2,300,000 ~'ELL NO, TBS A-17RD FIEL~ TRADING .BAY FIELD OF OPERATIOI:IS, DESCR I PTIOJ.tS & iRESUL.TS WOC. Polished off kickoff plug to 2639'. POOH. RIH w/ bit #1 on BHA #1 for dyna-drill run #1. Oriented dyna-drill 150° left of HS w/ Sperry Sun steering tool. Dyna,drilled 8 1/2" hole f/ 2639' to 2679' POOH. RIH w/-bit #1 RR on BHA #2. Directionjlly drilled 8 1/2" hole f/ '.2679' to 2718'. X-over entire mud system to 3% KCL -drilling fluid. Directionally drilled 8 1/2" hole f/ 2718' to 2778'. Directionally drilled 8 1/2" hole f/ 2778' to 3209' Trip for bit #3. RIH w/ bit #2 on BHA #~. 'Directionally drilled 8 1/2" hole f/ 3209' · to 4108' Trip for bit #4 Directionally drilled ~ 1/2" hole f/ 410~' to 4470'. Trip for bit #5. Directionally drilled 8 1/2" hole f/ 4470' to 4876'. Trip for bit #6. Directionally drilled 8 1/2" hole f/ 4876' to 5100'. Short trip to shoe. Circ & cond mud & hole for logs. POOH. Ran Dres'ser Atlas DLL-SP-GR, FDC-CNL-GR, BHC-Sonic-GR & 3-Arm Caliper-GR f/ 5098' to 2637'. IJNIOi.I OIL cC ':PArlY CF CALIFOR .IIA £LL RECORD SHEET D PAGE ih, ..5 LEASE. ADL 18731 $~'ELL NO, TBS A-17RD FIELD TRADING BAY FIELD .. _ DATE . 21 6/16/81 DAILY COST'. ACC COST' AFE AMT' 22 6/17/81 DAILY COST' ACC COST' AFE AMT' 6/18/81' DAILY COST: ACC COST' AFE AMT' 24 6/19/81 DAILY COST: ACC COST: AFE AMT: 25 6/20/81 DAILY COST' ACC COST: AFE AMT: 26 6/21/81 DA I LY COST: ACC COST: AFE AMT: ETD . . 51 00' TD 5033' ETD (FC) 9 5/8" C. 2637' 7" C. 5073' 73 PCF 49 SEC $ 152,293 $ 932,572 $2,300,000 5100' TD · 5027' ETD (FC) 9 5/8" C. 2627' 7" C. 5073' FIW $ 39,880 $ 972,452 $2,3OO, 000 5100' TD 5027' ETD (Fc) 9 5/8" C. 2627' 7" C. 5073' 64 PCF 38 SEC $ 39,421 $1,011,873 $2,300,000 5100' TD 4500 ETD (FC) 9 5/8" C. 2627' 7" C. 5073' 65 PCF 35 SEC $ 25,580 $1,046,567 $2,300,000 5100' TD 4368 ETD (FC) 9 5/8" C. 2627' 7" C. 5073' 65 PCF 35 SEC $ 28,880 $1,075,447 $2,300,000 5100' TD 4368 ETD (FC) 9 5/8" C. 2627' 7" C. 5073' 65 PCF 35 SEC $ 98,438 $1,173,885 $2,300,000 ! D~TAILS.OF .OPER~TiO[tS, DESCRIP.I'_IQI-IS &~E.S.ULTS. RIH to 5100'. Circ & cond mud & hole for csg. POOH. Ran 7" 29# N-80 f/ surface to 3864' & P-110 29# f/ 3864' to shoe @ 5073'. Landed csg w/ FS @ 5073' & FC @ 5033' Cmtd 7" w/ 600 sxs cl "G" w/'1.3% D-19, .2% D'6, .1% A-2 & 5% KCL, reciprocated csg while cmting. Had full r~turns during cmt job & bumped plugs. CIP @ 14:40 hrs. Installed & tested DCB spool. Changed hydril rubber. RIH W/. 6" bit & 7" scrpr to 5027'. X-over to FIW. Ran sperry sun .gyro & Schl umbe.rger CBL-VDL-GR. X-over to 3% KCL fluid. POOH. Perfed 4 HPF f/ 4385' to 4405' w/ Schlumbergec 4" csg guns. RIH w/ Howco 7" RTTS & 7" RTBP. Set & tested RT~"' @ 4500' to .5000 psi. Set RTTS @ 4309'. Frac pac the 41-8 sand f/ 4385' to 4405'. Held press on frac for8 hrs. Crane broke & dropped sand pod while offloading boat for second frac. Retrieved BP f/ 4500'. Perfed the 41-3 sand f! 4313' to 4320'. Set & tested RTBP @ 4368' to 5000 psi. Set RTTS @ 4250'. -~. Repair crane. Installed torque converter and disassembled drive train. U['ilOl.l OIL CO('PA h' OF CALIFORI.iIA £LL RECORD S EET D PAGE ih. LEASE ADL 18731 27 6/22/81 DAILY COST: ACC COST: AFE AMT' 28 6/23/81 DAILY COST' · ACC COST: AFE AMT' 29 6/24/81 DAILY COST' ACC COST' AFE AMT' 3O 6/25/81 DAILY COST' ACC COST' AFE AMT' 31 '6/26/81 DAILY COST. ACC COST: AFE AMT- 32 6/27/81 DAILY COST. ACC COST: AFE AMT- ETD 5100' TD 5027' ETD (FC) 9 5/8" C. 2627' 7". C. 5073' 65 PCF 35 SEC $ 19,635 $1,184,406 $2,300,000 5100' TD 5027' ETD (FC) 9 5/8" C. 2627' 7" C. 5073' 65 PCF 35 SEC $ 19,635 $1,204,041 $2,300,000 5100' TD 5027' ETD (FC') 9 5/8" C. 2627' 7" C. 5073' 65 PCF 35 SEC $ 19,635 $1,223,676 $2,300,000 5100' TD 5027' ETD (FC) 9 5/8" C. 2627' 7" C. 5073' 65 PCF 35 SEC $ 19,635 $1,243,311 $2,300,000 5100' TD 4368' ETD 9 5/8" C. 2627' 7" C. 5073' 65 PCF 36 SEC $ 20,081 $1,272,506 $2,300,000 5100' TD 4230 ETD (FC) 9 5/8" C. 2627' 7" C. 5073' 65 PCF 36 SEC $ 34,813 $1,307,319 $2,300,000 $~ELL NO, TBS A-17RD FIELD TRADING BAY FIELD D.E.TAII.,S.,.,OF OPER~TIOIIS, DESCRIPTIO)IS & RESULTS Wait on crane parts. Wait on crane parts. Wait on crane parts. Received part's @ 12:00 hrs. ~ork on crane. In operation @ 22'00 hrs, begin offloading boat. Offloaded frac equipment. Mixed frac fluid. With RTBP @ 4368' & RTTS @ 4248', frac pac 41-3 perfs f/ 4313' to 4320,. Perfs sanded . out when one of the Dowel l turbines broke down with approx 170 bbls frac fluid left to pu'mp. Reversed clean. Shut in & held pressure on frac 14 hrs (pressure built to 1200 psi). Released tool & retrieved BP f/ 4368'. Set & tested BP @ 4260' Sanded out BP to 4230'. Perfor- ated 4 ~PF f/.4200' to 4210' w/ Schlumberger 4" csg guns. RIH & set RTTS @ 4150'. Wait on weather. U:'IIOi.I OIL CCI'?AHY CF CALIFOR iIA SI-;EET D PAGE ilo. 7 LEASE ADL 18731 $~1~LJ_ l~O, TBS A-17RD FIELD TRADING BAY FIELD DATE 33 6/28/81 DAILY COST: ACC COST: AFE AMT: 34 6/29/81 DAILY COST: ACC COST: AFE AMT: 35 6/30/81 DAILY COST: ACC COST: AFE AMT: 36 7/1/81 DAILY COST: ACC COST: AFE AMT: 37 7/2/81 DAILY COST: ACC COST: AFE AMT: 38 7/3/81 DAILY COST: ACC COST: AFE AMT: ETD 5100'TD 4230 ETD (FC) 9 5/8" C. 2627' 7" C. 5073' 64 PCF 35 SEC $ 20,080 $1,327,399 $2,300,000 5100' TD 4170' ETD (BP) 9 5/8" C. 2627' 7" C. 5073' 64 PCF 35 SEC $ 180,103 $1,498,000 $2,300,000 5100' TD 4090' ETD (BP) 9 5/8" C. 2627' 7"' C. 5073' 64 PCF 35 SEC $ 178,750 $1,677,138 $2,300,00O 5100' TD 5027' ETD (FC) 9 5/8" C. 2627' 7." C. 5073' FIW $ 35,012 $1,712,150 $2,300,000 5100' TD 3980 ETD (FC) 9 5/8" C. 2627' 7" C. 5073' $ 86,617 $1,807,881 $2,300,000 5100' TD 3980 ETD (FC) 9 5/8" C. 2627' 7" C. 5073' $ 19,635 $1,827,516 $2,300,000 DE_TAILS PF OPEFLATIOI(S, DESCRIpTIOI.IS &RE. SUL.TS Offloaded frac sand. Mixed gel frac fluid. Frac pac the 33-6 perfs f/ 4200' to 4210'. Held frac in place '8 hrs. Released tool & retrieved BP F/ 4260'. Set BP @ 4170' - no test. Retrieved BP & POOH. Did not have BP. RIH & retrieved BP f/ 4260'. POOH. Perforated 4 HPF w/ 4" csg guns the 31-8 ~and f/ 4108' to 4115' w/ Schlumberger. RIH & set .RBP @ 4170'. Tested RTBP to 400.0 psi. Mixed frac fluid & frac pac the 31-8 sand. Frac pac the 31-8 sand f/ 4108' to 4115'. Held pressure on frac 8 hrs. Released' tool & retrieved BP f/ 4170'. Set & tested BP @ 4090' to 4000 psi. Sanded out BP to 4060'. POOH. Perfed the 31-8 sand w/ 4 HPF f/ 4030' to 4055' w/ Schlumberger 4" guns. RIH & set retrievamatic @ 3972'.-. Mixed frac gel. Frac pac the 31-8 sand f/ 4030' to 4055'. Held pressure on frac 8 hrs. Retrieved BP f/ ~090'. POOH. RIH w/ 6" bit & 7" csg scrpr. CO sand to 5027' ETD. POOH. Ran GR log f/ 4600' to 3500'. RIH & se~'Baker "D" pkr @ 3970'. POOH. RIH w/ 2' seal on DP. Tested pkr to 1000 psi X,over to FIW. Laid down DP. Ran 2 7/8" comp assy. Landed tbg w/ locator @ 3969', MS @ 3980', GLV's @3930, & 2318' & ball valve nipple @ 317'. Removed BOPE inStalled & tested CIW tree. (Note: Had to Jdd seal flange to btm of tree to seat tree on DCB spool). Installed production lines. Released rig @ 24:00 hrs 7/3/81. i I II I II I i ! ! i , A-17 RD Otis 2 7/8" XEL Ball Valve 317' · 13 3/8~' 1064' Perfs 4030'-4055' 4108-4115 4200-4210 14313-4320 14385-4405 "B" Zone Sand 31-8 31-8 .33-6 41-3 41r8 9 5/8" window 2637-27 )0 2MT Re,t 2710 Camco ~BK" ~GLV .231~ Camco ".BK" GLV 393 Locator sub 3969 Pkr 3970 / Mule Shoe 3980 . ~,,.- ~. . -- ~ 7"c5073 I A-17RD Trading Bay Field Well Schematic AI'P'D. OAT'T: UNION OIL COMPANY OF CALIFOi:NIA i ,, .. ;:. :.:.~;, ....-;- 1 Document Transmittal ...... ' I Union Oil Company of California 7-28-81 TO FROM Hr. Harry Kugler R.C. Warthen Conservation Co~, Anchorage, AK 99502 Anchorage, AK TELEPHONE ~O. TRANSMITTING THE FOLLOWING: i m 1 ea. sepia "and 1 ea. blueline of the following' compensated densilog coml)ensated neutrun cal i per 1 og 2" compensated densil,og 5" compensated densilo9 2" BHC acoustil.og 5" BHC acoustilog 2" dual laterol.og " ... 5" dual laterolog . .TRADING BAY STATE A-9 RD (33X4). 1 ea. sepia and ! ea. hl,,~l i ne of the fol 1 owing' 5" dual laterolog 2" dual laterolog 5" borehole compensated ;onic lee ~~" ~-~ ol- com.:'ensated ~onic lo~ comp. neutron formation ~ensity . ~ comp. formation density log ~ ~aqF~TG~_AN~ RFTI~N ONE ~OPY nATF. ,,,, ~ ~ ..... ~~ ~ I~l ' ~ '~il & Gas ~,,~ , m,,,lliSsi0n ~o~ ./' FORM I-2M02 (REV. 11-'72) PRINTED IN U.S.A. U' ' ~.,~.~,~, 0ii & Gas Cons. CornrnjSsioa U?,IJON ©Ii_ CO. OF CALIFORNIA WELL P. ECO2D SHEET A PAGE NO.. i £;f,:ASE Tradinq Bay State WELL NO.A-17RD FIELD Tradinq Bay LOCATION .Conductor #11~ 1608'N & 576'W Of SE Corner of Section 4', T9N,. R13W, S~i. · PERMIT NO. 81-67 .... SERIAL NO.733-?n~'~r-'~" SPUD DATE 6-11-81 COMP. DATE 7-3-81 CONTRACTOR Parker. RIG NO.56 TYPE UNIT.. 860 Oilwell DRILL PIPE DESCRIPTION 5" 19 1/2# "E" & S-135 ELF, VATIONS: WATER DEFI'H 62' 1~ T. TO OCEAN FLOOR 174' R.T. TO MLLW 112 ' 5100' ~.{D ~vD 4203' VD T.D.__ -' , ........ :o-qw, - - . B T TO DRILL DECK - 22...07' DEVIATION (B.H.L.) _2~__8_5_ out at 551~ t'_w_ COMPANY ,wov .D: ' ENGINEER w~ k.~c~n- Boulware 1{. T. TO ~'O~~~? 40.82'~ ~ ..... . ~ 3 3/8 '' 6 1~ Buttess·5 --S--~ N--f8 10 6 ~ ' ~'~:lW/ 1200 SXS w/Additives. ' ' 9. 5/8" 40&43 1/i Buttress ij_ 0, 2637'. See previous Histo~, ' II , 9 5'/8" Window F/2637' to 2700' F°r Redrill 7" 29~,i" Buttress N-8'd&P-110! 5~73' C~¢f.~'D w/~0_.0_ sxs w/additive, s ~-]-~7/_8" 6.4~ Buttress N-80'" 3980'. ~ ..C. ompletion String " , .. · . PKP @ 3970' PERFORATING RECORD ___DATE II{laRVAL '"E.T'D. , REASOrr ~ pllESENT CONDITIO_N 5-!8-81 438,~' to 4405 ' 5027 ' FC Eroduction rac-Pac 41'8 Sand - .Open to producti°n -- · . · 5-20-81 ~313' to 4320' 5027' FC ?rc~uction Frac-Pac ~1-3 sand,..-Open 'to Producti~ ......... J227-81 4200' t0"421~* 4230' 'gand ?roduction ?rac-?ac 33-6 Sand-Open to Production S-29-81 4108' to 4115' 4170 RBP ?roduction ?rac-Pac 31-8 Sand - OpenI to Production .ii --:-30-8_____~.~ 4030' to 4055' ~060' Sand ?roduction ~'rac-Pac 31-8 Sand- .Open' tO Pr.oductionI '~ · , . ~ · , , I . . · INITIAL PRODUCTION DATE ..... ~Z~T~VAL NET OIL CUT GRA, V. .,, 12/20/8:: ...... -~"1 84 0.1 483 93 61 .. 10 119 ..... .. .,, ,. ~ ,, WELL HEAD ASSEMBLY TYPE: CASING HEAD: shaffer "KD" w/2" Outlets, 13 3/8" SOW x. 12" 3000 psi 'Csq. Head. CASING HANGER: C~'7 12 x 7"' Type AW 12" 3000 x 12" 3000 CASING SPOOL: ' TUBING HEAD: Cameron DCB i2" 3000 psi x 10" 5., 000 psi '- ' TUBING HANGER: Single CIW 2 7/8" · . TUBING tlEAD TOP' 2 7/8" eue 8rnd. ' 2 9/16" MASTER VALVES: CtlR.rSTMAS TREE TOP CONN '__ 2 7/8" Check Fo~xn for tinely ca~.plie~ce with our regulations. Operator, Well Name and Nu~he~ Reperts and Materials to be received by: · Completion Rct~3rt Wel 1 History Sa~les Mud Log. Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Prcduction Test Reports Lcxts Run R.~luircd Yes Date Received Yes Yes Remarks Document Transmittal Union Oil Company of California union DATE SUBMITTED ACCOUNTING MONTH 7-29-81 TO FROM Harry Kugler R.C. Warthen AT Alaska Oil and Gas AT Fouch 6247 Conservation Con~. Anchorage, AK 99502 ..aa~,~v, ,~,. ~ ,,,. TELEPHONE NO. TRANSMITTING ThE FOLLOWING: Ii I TRADING BAY UNIT A 17RD' 1 ea, Gyroscopic Multishot Dire(tional Silrvey PLEASE SIGN AND RETURN ONF COPY DATE' Jilt. ~ t~; 1~81 Alaska C~u ~, ~ ~u~,~mi~ sion FORM 1-2M02 {REV. 11-72) PRINTED IN U.S.A. - ALASKA ~' . AND GAS CONSERVATION CO~..,vllSSlON MO#I'HI-¥ REI OI:II' OF DRILLI#Gi &#D WORKOVtR OI tP._&.TIO#$ · Drilling well ~X Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNTA 8]-67 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface Cond. #11, 1608'N & 576'W of the SE Corner, Section 4, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. lOl' KB above MSL ADL 18731 8. APl Number 5o- 733-20135-01 9· Unit or Lease Name TRADTNG BAY STATE 10. Well No. TBS A-17 11. Field and Pool TRADING BAY - "B" For the Month of June ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 5100' TD 2461' Drilled w/ KOP @ 2639' 13. Casing or liner run and quantities of cement, results of pressure tests 7" C. 5073' Cemented 7" w/ 600 sxs cl "G". 14. Coring resume and brief description None 15. Logs run and depth where run DLL-SP-GR, FDC-CNL-GR, BHC-Sonic-GR and 3-Arm Caliper-GR f,/ 5098' CBL-VDL-GR @ 5027'. to 2637'. I ECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data Perfed 3]-8 sand f/ 4030' to 4055'. Perfed 4]-3 Sand f/ 4313' to 4320'. Perfed 3l-8 sand f/ 4]08' to 4]]5' and 4030' to 4055'. JUL i ? :~98J Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SIGNED _ _ _ TITLE DIST DRLG SUPT DATE 7/15/81 NOTE--¢epor~t ~)n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate With the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 May 18, 1981 ADMINISTRATIVE APPROVAL NO. 93.6 Re: Application of Union Oil Company of California, to redrill, complete and produce the Trading Bay Unit A-17RD well. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on May 18, 1981 and stated that the subject well will provide an effective "B" Zone withdrawal point in the II-A fault block. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion of the referenced well pursuant to Rule 9 of Conservation Order No. 93. Yours very truly, Harry W. Kugler Commi s sione r BY THE ORDER OF THE CO~}MISSION HWK ~ be Union Oil and Gaspivison: Western Region { Union Oil comPan~ of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager May 12, 1981 Mr. Hoyle Hamilton State'of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 WEST .FORELAND AREA State' of Alaska Permit to Drill TBS A-17 Rd., Monopod Platform, Trading Bay Field ADL-18731 (8-86-71-5575-601353) Dear Mr. Hamilton: Enclosed for your further handling are three (3) copies of the above captioned Permit to Drill. Also enclosed is our check number 19121 in th~amount of $100.00 to'cover ~he required filing fee. Upon approval, we would appreciate'an executed copy for our files. Thank you. Very truly yours, sk Enclosures 1 3 I981 Alas!ca C~i a Gas Cons. 0orn~155i011 Anchorage AND GAS CONSERVATION CO ,ISSION PERMITT .DRILL 20 AAC 2~':0qs la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL D(l DEVELOPMENT OIL[X1 SINGLE ZONE ~] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] ~2. Name of operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 .... 4. Location of well at surface Conductor #11, 1608' N & 576' W of the 9. unit or lease name SE corner of Section 4, T9N, RI3W, SM. TRADING BAY STATE At top of proposed producing interval 340' FSL & 2185' FEL lO. Well number Section 4, T9N, R13W, SM. ' TBS A-17 RD At totaldepth 20'N & ~7-6:N~of the SE corner of ~ ¢e~/'/::/.?c. 11. Field and pool Section 4, T9N, RI3W, SM. ~ ~ r~.._ 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 101' KB ABOVE MSLI ADL 18731 TRADING BAY - "B" 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number United ?ac:if:i.c Tns. Co. Amount $100,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 27 air miles North of miles 4,770.00 feet well I 55 ~ feet Ken~ 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 5500' TMD, 4534' TVD feet 3,840.00, J~,~Es~)5, psig@1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures . Surface KICK OFF POINT 2600 feet. MAXIMUM HOLE ANGLE 47 °l(see 20 AAC 25.035 (c) (2) **~] 5{')(] psig@ 3Z[00 ft. TD (TVD).., 21*Assumes gas gradient to sur'face **Existing reservoir data Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT .... I Hole Casing Weight i Grade Coupling Length ME) TOP TVD MD BOTTOM TVD (include stage data) 8 1/2" 7,, 29# N-80 BUTT. 5046' SURF. I 5046' ~14160' * · CALC FROM C~LIPER [.OG TO F'ILL 50~)' INSI)E 9 5/§" SURFI~CE CSGk ~ I 22. Describe proposed program: (SEE ATTACHED)' t £C£1VEg,. A4 ¥ 1 2 1981 Alaska Oil & Gas Cons. Anchorage C°mmi$$[o~I 23. I hereby certify that the foregoing is true and. correct to the best of my knowledge The*~pacebelow-forCo~nmissionuse Robert T/Andersort~ ~- CONDITIONS OF APPROVAL Samples required I Mud log required Directional Survey required ] APl number []YES '~,,NO[ []YES '~NO '~ES I--]NO[ 50-- 755- Approval date Permit number~ ~'"'1~'? SEE COVER LETTER FOR OTHER REQUIREMENTS _ ~ n5/15/81 _v - /~/ ~' by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL TBS A-17 RD PROCEDURE: 1) 2) 3) 4) 5) 6) 7) 8) 9) Move Rig #56 over Conductor #11 TBS A-17 & rig up. Install and test BOPE. Pull and lay down 2 7/8" tubing string. Cut 60' window in 9 5/8" casing from +2700' - +2500' (exact location to be determined by CBL). Iml~.e.o. /o~ $~,,~1~.~.~ '~ Ce~,~e,,'~ ~,~/~ Directionally drill 8 1/2" hole f/ 2500' to +5046' MD TD. Run logs, run and cement 7" casing. Frac Pack the "B" zone sands as justified. Complete well with a single 2 7/8" tubing string. Remove BOPE & install X-mas tree. 10) Place on production. RECEIVED MAY 1 2 1981 Alaska Oil & Gas Cons. Cornrni.~io~t Anchorage , RI3W > 33 34 WEt. L HEAD PLAN uN,o~ A-12 RD TUO ?oe~ . , ~_ I ~' A-16 - ..... ~ ' ~ '/ ~ 4 A-29 ~-~s. ~.~ ~~....:~ : ] /I ..... ~' PROP. B H.L A- l[ ~. o4~' /: /' /I ~-~ ~--~- .>'"', ..... C:: : / "_ . _ ~-]~ .: ..... ~' A.s~D.~.~ " / T/31-8 SAND . · ..... 5325 VD ~ / ~ /' N~" ,' / - / ," ~730: MD . ~ .... ~ .--::- ...... ~.../ 3855 VD ~3/~_-~. /x ....... B.H.L. ~" 4955' TMD 4160 TVD TVD io,~ TRADING BAY FIELD PROPOSED WELL LOCATION TRADING BAY STATE A-17RD (34--4.) APRIL 6, 81 ~ch0rage V£N T ~ · · i ~HOK£ ~ · · ~ H u~d, :'=D A-! J ' * ,o . 7-":'.' ~' · :.'::...~, .. . e. . . -;. . .. ': ..' ' . . L £ VALVES · o . 8AUGE POSITIVE CHOKE ADJUST.~BLF CHOKE. .o o . · o · · e. · ,,, ALL CHANGES MUST HAVE ~,~I'TTEN APPROVAL BY'THE DISTRICT DRILLING SUPER;NTENDENT. I, ll#I$fU~,,/ ST,4/,'D,~RD ~//Ok'E /,!,4~,'/FOLD /SSE/,I£LY ~ooO ?~/' H/, /7 . · I)1 AWN 0 C mi)._ A I'i"0. H.B I. SCA[[ Non e I~ITGLEO . F/LL UP LIY~r HY£RIL CHECK V.~LVE · . HY[~A~IU~ OPERATED VALVE . .z · GAT~ 0,~ · LO-TOR~U£ GATE C~ GATE VALVE GATE VALV£ REQUIRED RECEIVED MAY 1 2 1981 ~aska Oil & Gas Cons. _/~chorage ~ission ~ " PIPE kIOTE ' ,,,~.,. c,~,.~'s ~s~' .~v~ D~iLLING SUPER h",lT E NDENT ^t~'O 14 ~ !. · · May 15, 1981 Mr. Robert T. Anderson District Land Manager Union Oi 1 Company of Ca li fornia P. O. Box 6247 Anchorage, Alaska 99502 Re: Trading Bay State TBS A-17 RD Union Oil Company of California Permit No. 81-67 Sur. Loc.: 1608'N, 576'W of SE cr Sec 4, T9N, R13W, SM. Bottomhole Loc.: 20'N, 576'W of SE cr Sec 4, T9N, Ri~W, SM. Dear Mr. Anderson Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50. 870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. Robert T. Anderson -2- Trading Bay State TBS A-17 RD May 15, 1981 cOmmencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, HOy'~ It,. liami lton Chairman of BY O~DEa 07 ?}t~ COa}il$$.lON Alaska Oil & Gas Conservation Commission Enclosure cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. CHECK LIST FOR ~SW WELL PERMITS Lease & Well No. ITeM APPROVE DATE (1) Fee (2) Loc (3) ~Rmin. (~/thru 11) -(12 thru 20) ' (21 thru 24) . e 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the p~mit fee attached ............................ · .............. __ Is roll to be located in a dafined pool ........................... Is mi1 located proper distance from property line .................. Is ~11 located proper distance from other ~lls ......... ............ Is sufficient undedicated acreage available in this pool ............ Is ~11 to.be d~viated and is ~11 bore plat included ............... ,.~ Is operator the only affected party ..... · ............................ Can permit be approved before ten-day ~it .......................... Does operator hav~ a bond in force ........... ..... ....... ~[[[~]]~ ~_/__ Is a conservation order needed ...... Is administrativa approval needed ............. Is conductor string provided ....................................... Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings Will cemmnt co~r all known productiv~ horizons ................... W±il surface casing protect fresh %ater zones ...................... Will all casing gi~ adequate safety in collapse, tension and burst. Is this v~ll to be kicked off from an existing ~llbore ............. Is old wellbore almndonm~nt procedure included on 10-403 ............ ~~. Is adequate ~11 bore separaticn proposed ........................... REMARKS Is a div~rter system required ....................................... '~..- ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE hav~ sufficient pressure rating - Test to 3o~:~ psig Does the choke manifold comply w/API RP-53 (Feb. 78) .................. ~ Additional requiren~nts ............................................. Additional Rmmarks: Ceoloqy: Engine.erin9: rev:~ 03/10/81 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE
