Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
170-024
STATE OF ALASKA AL,. <A OIL AND GAS CONSERVATION COM. _SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other❑ Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver❑ Time Extension E-COVED Change Approved Program I=1 Operat.Shutdown❑ Stimulate-Other I] Re-enter Suspended Well[ E E D 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory El 170.024 MAY 0 4 2015 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 '50-733-20214-00 /\Q c3 C C 7.Property Designation(Lease Number): 8.Well Name and Number: �� ADL0018731 Trading Bay St/A-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Trading Bay Field/Middle Kenai B,Middle Kenai C&Middle Kenai D Oil Pools 11.Present Well Condition Summary: Total Depth measured 10,180 feet Plugs measured N/A feet true vertical 9,927 feet Junk measured 6,693 feet Effective Depth measured 6,432 feet Packer measured 2,091 feet true vertical 6,287 feet true vertical 2,037 feet Casing Length Size MD ND Burst Collapse Structural Conductor 228' 20" 228' 228' 2,410 psi 770 psi Surface 1,085' 13-3/8" 1,085' 1,045' 3,090 psi 1,540 psi Production 7,092' 9-5/8" 7,092' 6,942' 6,330 psi 3,810 psi Liner 6,475' 7-5/8" 6,475' 6,330' 6,890 psi 4,790 psi Perforation depth Measured depth See Schematic feet f� 15 True Vertical depth See Schematic feet l 0 2 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.6#/L-80 2,121'(MD) 2,065'(ND) 2,091'(MD) 301'(MD) Packers and SSSV(type,measured and true vertical depth) Stimtop Pkr 2,037'(ND) SSSV 301'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Tyonek B,C,and D Sands-Perforations from 2,170'-6,062' Treatment descriptions including volumes used and final pressure: 330 gallons of Baker Petrolite WAW-5206(Mutual Solvent),990 gallons Xylene,and 4,500 gallons of 7.5%Hydrochloric Acid;Displaced with 450 bbls FIW.510 psi Final Tbg Pressure and 530 psi Final Csg Pressure at surface. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 52 0 33 792 102 Subsequent to operation: 36 0 32 524 100 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Straligraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas El WDSPL❑ GSTOR El WINJ El WAG El 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: 315-097 Contact Trudi Hallett Email thallett( hilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature aVU.ilif fidelltt Phone (907)777-8323 Date 5/4/2015 Form 10-404 Revised 10/2012 ✓ S---7.-11--A0_, ,_/5---- RBDM Submit Original Only MAY - 62015 Trading Bay Unit • SCHEMATIC Well #A-11 Completion Date: 02/13/14 CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate RKB to TBG Hngr=41.50' hrs y� 20" 34"Wall H40 Weld Surf 228' 1750 20.5 226�p': „�} (risked) 1 3 13-3/8" 61# J-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs t s i. ,! yam a Stage Collar 3622.8' 6330 1250 sxs See below 373 :;*:. e. 43.5 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs 1 " 7.4 ^7,"4' 7-5/8" 29.7 1-80 SLI1-II 6.875 Surf 6,475' TUBING +066,,��.> Iw, t> 2-7/8" 16.6 ► 1-80 I I I Surf I 2,121' I iia „:: JEWELRY DETAIL 9-5/8"Cement Job ++a0+isa NO. Depth ID Item 1160 2700' Fair/Poor(USIT) 11e0' 1 301' Baker TE-5 SSSV 2700' 2830' Good cmt(Top of Log) IA sand 2 2,016' Gas Lift Mandrel 2830' 3110' Poor cmt 1660'1700' 3 2,068' ChemicalInjection Mandrel 3100' 3700' Good cmt 4 2,091' Stimtop Hyd Perm Packer 3700 4056' Poor cmt 24056' 4200' Good cmt in 5 2,111' X Nipple 3I 6 2,121' WLEG 4200' 5100' Poor cmt 1.1 5100' 7092' Good cmt OM 5 in 'AI 244 sand 6 -�_2170'2260' PERFORATION DATA %' Top Zone (MD) Btm(MD) Top(TVD) Btm(ND) Amt SPF Date Present Condition , � B 24-6 2,170' 2,260' 2,111' 2,195' 90' 6 02/11/14 Open 0. B B 26-7 2,606' 2,655' 2,521' 2,568' 49' 6 02/11/14 Open ,s B 26-7 2,708' 2,770' 2,618' 2,676' 62' 6 02/11/14 Open . B 26-7 2,788' 3,106' 2,694' 2,995' 318' 6 02/11/14 Open Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT cmt Sqz Perfs 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/csg bond C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. C-2 4,197' 4,233' 4,062' 4,098' 36' 6 02/11/14 Open C-3 4,270' 4,340' 4,135' 4,204' 70' 6 02/11/14 Open ii:.J CZN6 4,364' 4,384' 4,228' 4,248' 20' 6 02/11/14 Open 6 4,000' C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 P. C-5 4,471' 4,476' 4,335' 4,340' 5' 4 4/73 C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 P'-4 1 C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. 11 .. C-7 4,642' 4,712' 4,505' 4,575' 70' 6 02/11/14 Open C 47-5 4,817' 4,827' 4,679' 4,689' 10' 6 02/11/14 Open { Stray 4,819' 4,824' 4,681' 4,686' 5' 4 4/73 C 47-5 4,846' 4,870' 4,708' 4,732' 24' 6 02/11/14 Open C C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 C 48-5 4,932' 4,948' 4,794' 4,810' 16' 6 02/11/14 Open C 48-7 4,954' 4,976' 4,816' 4,838' 22' 6 02/11/14 Open r, C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 II X C 50-3 5,140' 5,178' 5,002' 5,040' 38' 6 02/11/14 Open Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond D ZN2 5,568' 5,590' 5,428' 5,450' 22' 6 02/11/14 Open D D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 D 53-8 5,600' 5,652' 5,460' 5,512' 52' 12 5/4/1998 Open f/prod. D 53-8 5,605' 5,634' 5,465' 5,494' 29' 6 02/11/14 Open g D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/prod. gr ��� D 54-5 5,670' 5,708' 5,530' 5,568' 38' 6 02/11/14 Open 7-s�e�� (!((!((((((((!((((((ll 054-9 5,740' 5,750' 5,600' 5,610' 10' 6 02/11/14 Open ¢ D 54-9 5,742' 5,769' 5,602' 5,629' 27' 4 5/70 !r D 54-9 5,760' 5,770' 5,620' 5,630' 10' 6 02/11/14 Open KB ELEV=101' D 55-7 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 PBTD=6,432' TD=10,180' D 55-7 5,802' 5,828' 5,662' 5,688' 26' 6 02/11/14 Open ANGLE thru INTERVAL=8.5° D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. D 56-1 5,856' 5,949' 5,715' 5,808' 93' 6 02/11/14 Open D 57-2 5,975' 6,055' 5,834' 5,913' 80' 8 5/4/1998 Open f/prod. D 57-2 5,975' 6,062' 5,834' 5,920' 87' 6 02/11/14 Open Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/csg bond Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/csg bond FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. Updated by JLL 03/13/14 Hilcorp Alaska, LLC Hi'carp Alaska,LIA Weekly Operations Summary Well Name API Number Well Permit Number Start Date _End Date A-11 50-733-20214-00 170-024 4/5/2015 4/5/2015 Daily Operations: 04/05/15-Sunday Spot and rig up tankage.Rig up suction lines from Acid,XYLENE and FIW tanks to Marlowe Pump. Pump acid Job As Per Procedure: Pump 31.5 bbls WAW-5206/XYLENE Mixture @ 1.8 BPM with 140 psi.Pump107bbls 7.5%HCL Acid @ 1.8 BPM with 300 psi.Back Flush Acid and Xylene lines with FIW back to tanks.Chase Acid/Solvent with 450 bbls FIW @ 1.8 bpm with 300 psi with 25 bbls pumped @ 06:00 hrs. PT HP line to 2500 psi.Flood suction lines and Hydro test to 45 psi charge pump pressure. Establish injection rate @ 110 psi @ 1.8 bpm with 32 bbls pumped.Caught pressure @ 10 bbls away. Shut down and shut in pump.Mix WAW-5206/XYLENE in Chem Tank. Continue pumping FIW Displacement f/25bbls away t/total 450 bbls @ 1.8 bpm w/final pressure of 510 psi on tbg and 530 psi on 7-5/8"annulus.Dn pump,shut in well. Turn well over to production for 6 hr soak.Clean stow pump job equipment and load same on boat. Job complete. f T�I�jjsTHE STATE Alaska Oil and Gas (7"; s���:- fALASI�:A oConservation Commission t_ _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 oFm ' Main: 907.279.1433 AL"AS' Fax: 907.276.7542 www.aogcc.olaska.gov Dan Marlowe 1170 019' Operations Engineer // Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B, C, and D Oil Pools, Trading Bay St A-11 Sundry Number: 315-097 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, 4.e. Daniel T. Seamount, Jr. Commissioner DATED this 24 day of February, 2015 End. SCMMED F. 2 T- l RECE° IED l STATE OF ALASKA FEB 2( -U 6 ALASKA OIL AND GAS CONSERVATION COMMISSION 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❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension El Operations Shutdown❑ Re-enter Susp.Well❑ Acid Stimulate 0' Alter Casing 0 Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 0 , 170-024 • — 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service CI6.API Number. Anchorage,AK 99503 50-733-20214-00 ' 7.If perforating: 8.WeN Name and Number What Regulation or Conservation Order governs well spacing in this pool? NiA Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bey St/A-11 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 • Trading Bay Field/Middle Kenai B, Middle Kenai C &Middle Kenai D Oil Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,180. 9,927, 6,432- 6,287 - N/A 6,693 Casing Length Size MD TVD Burst Collapse Structural Conductor 228' 20" 228' 228' 2,410 psi 770 psi Surface 1,085' 13-3/8" 1,085' 1,045' 3,090 psi 1,540 psi Intermediate Production I 7,092' 9-5/8" 7,092' 6,942' 6,330 psi 3,810 psi Liner 6,475' 7-5/8" 6,475' 6,330' 6,890 psi 4,790 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic i See Schematic 2-7/8" 6.6#/L-80 2,121 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Stimtop Packer and SSSV • 2,091'(MD)2,037'(ND)and SSSV:301'(MD) 301'(ND) ' 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 3/2/2015 Commencing Operations: Oil 0' Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned El Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Itagij Signature Phone (907)283-1329 Date 2/20/2015 Tn4ai Ha)ie-fr Mil maI1Uvvej COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l5 —v`\--T Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test El Location Clearance ❑ Other: Spacing Exception Required? Yes 0 No IDd Subsequent Form Required: /0 — 510 if 0APPROVED BY r Approved by: COMMISSIONER THE COMMISSION Date: 2..` z 15 II 2.23.15 .--ft2/�1/S � �5s /eh ,2-,244/.s andlaGc[NisAiL2r Submn Form ane Form 10-403(Re sed 10/2012) 12 months from the date of approval. Attach`m�nts in Duplicate RBDMSJ c FEB 2 4 2015 ., fii Well Work Plan Well: A-11 llilcoru Alaska,LL. Date:02/20/2015 Well Name: Monopod A-11 API Number: 50-733-20214-00 Current Status: Gas Lifted Producer Leg: N/A Estimated Start Date: _ 03/02/15 Rig: N/A Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 170-024 First Call Engineer: Dan Marlowe Office: (907) 283-1329 Cell: (907) 398-9904 Second Call Engineer: Trudi Hallett Office: (907) 777-8323 Cell: (907) 301-6657 AFE Number: Max. Allowable Surface Pressure: 2,000 psi pump pressure. Well Summary A-11 has had limited productivity since its 2014 work-over. During the 2014 work-over loss control material was used to control fluid loss in preparation for liner installation and cement work. It appears that this has caused near well-bore skin damage. This procedure will attempt to reduce the skin and restore productivity. Procedure: 1. MIRU pumping equipment 2. Shut down ESP 3. Pressure test surface lines to 2,000 psi 4. Mix chemicals and pump in the following sequence: a. Mix and pump 330 gallons WAW-5206 blended with 990 gallons Xylene b. Pump 4,500 gallons 7.5% HCL c. Displace with 450 bbls of FIW d. Shut down pump and let acid soak for 6 hours 5. RD Pumping equipment 6. Return well to production Attachments: 1. As-built Schematic SC H E M ATI C : JIhitWll #A-11 Completion Date: 02/13/14 CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate RKB to TBG Hngr=41.50' _ hrs ;�y/,, , 20" Y::"Wall H40 Weld Surf 228' 1750 20.5 22r. `5� (risked) } 13-3/8" 61# 1-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 koc 9 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs 4,i�y; ,1_..,,,726, Stage Collar 3622.8' 6330 1250 sxs See below 373 ..44, r' ue• 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs i' mai•264 7-5/8" 29.7 L-80 SLIJ-II 6.875 Surf 6,475' `.mak ~x, TUBING 102r:.� 1 2-7/8" 6.6 L-80 Surf 2,121' 4118 t%2 ``11,22' JEWELRY DETAIL 9-5/8"Cement Job 41eo• 1 1De301' Baker TE-5 SSSV Log)1152 NO. 1160' 2700' Fair/Poor(USIT) 1pth ID Item 2700' 2830' Good cmt(Top of Lo ) 5A Sand 2 2,016' Gas Lift Mandrel 2830' 3110' Poor cmt 8°°770" 3 2,068' Chemical Injection Mandrel 3100' 3700' Good cmt 4 2,091' Stimtop Hyd Perm Packer 3700 4056' Poor cmt 24056' 4200' Good cmt IMF 5 2,111' X Nipple s I 6 2,121' WLEG 4200' 5100' Poor cmt 5100' 7092' Good cmt 111 s ' ,244 Sand 6 2170.2260' PERFORATION DATA Top Zone (MD) Btm(MD) Top(ND) Btm(TVD) Amt SPF Date Present Condition B 24-6 2,170' 2,260' 2,111' 2,195' 90' 6 02/11/14 Open B B 26-7 2,606' 2,655' 2,521' 2,568' 49' 6 02/11/14 Open • B 26-7 I*n`jf 2,770' 2,618' 2,676' 62' 6 02/11/14 Open . B 26-7 2,788' 3,106' 2,694' 2,995' 318' 6 02/11/14 Open Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT cmt Sqz Perfs 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/csg bond C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. C-2 4,197' 4,233' 4,062' 4,098' 36' 6 02/11/14 Open C-3 4,270' 4,340' 4,135' 4,204' 70' 6 02/11/14 Open CZN6 4,364' 4,384' 4,228' 4,248' 20' 6 02/11/14 Open 4,000' C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 C-5 4,471' 4,476' 4,335' 4,340' 5' 4 4/73 C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 Y4 1 C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. rr.. C-7 4,642' 4,712' 4,505' 4,575' 70' 6 02/11/14 Open ; S C 47-5 4,817 4,827' 4,679' 4,689' 10' 6 02/11/14 Open all Stray 4,819' 4,824' 4,681' 4,686' 5' 4 4/73 L1' C 47-5 4,846' 4,870' 4,708' 4,732' 24' 6 02/11/14 Open C C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 _- C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 C 48-5 4,932' 4,948' 4,794' 4,810' 16' 6 02/11/14 Open r� C 48-7 4,954' 4,976' 4,816' 4,838' 22' 6 02/11/14 Open •-� C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 F C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 41 C 50-3 5,140' 5,178' 5,002' 5,040' 38' 6 02/11/14 Open ,. Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond Z. D D ZN2 5,568' 5,590' 5,428' 5,450' 22' 6 02/11/14 Open D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 D 53-8 5,600' 5,652' 5,460' 5,512' 52' 12 5/4/1998 Open f/prod. D 53-8 5,605' 5,634' 5,465' 5,494' 29' 6 02/11/14 Open i' D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/prod. 6M 7-5/58- 054-5 5,670' 5,708' 5,530' 5,568' 38' 6 02/11/14 Open 7- 9 ' AY �i,, - D 54 9 5,7425,600' 0 ' 5,769' 5,62' 5,629' 2 ' 6 025/ 7/ Open 014 D 54-9 5,760' 5,770' 5,620' 5,630' 10' 6 02/11/14 Open KB ELEV=101' D 55-7 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 PBTD=6,432' TD=10,180' D 55-7 5,802' 5,828' 5,662' 5,688' 26' 6 02/11/14 Open ANGLE thru INTERVAL=8.5" D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. D 56-1 5,856' 5,949' 5,715' 5,808' 93' 6 02/11/14 Open D 57-2 5,975' 6,055' 5,834' 5,913' 80' 8 5/4/1998 Open f/prod. D 57-2 5,975' 6,062' 5,834' 5,920' 87' 6 02/11/14 Open Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/csg bond Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/csg bond FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. Updated by AL 03/13/14 --13U A- i RM 1700 440 Regg, James B (DOA) From: Regg, James B (DOA) j Sent: Thursday, March 20, 2014 11:48 AM �l 5/� 14_ To: Timothy Cole c l Cc: DOA AOGCC Prudhoe Bay Subject: RE: AOGCC1 Test Witness Notification Request: Other, Monopod Platform Cook Inlet Are both wells currently on production? For how long? How will you confirm for AOGCC that there are no restrictions in the well and tree? What if anything is rigged up to IA? What is the line size that will be used between the tree and low flow meter? What other potential flow restrictions will be in place upstream of the meter (e.g., size of needle valves)? Do you have a calibration report for the low flow meter? What is the division on low pressure gauge? (Appendix A of Guidance Bulletin 10-004 indicates 1 psi divisions for the low pressure test gauge; link to AOGCC Industry Guidance Bulletins is Guidance Bulletin Index) What is downstream of the low flow meter? The elimination of a safety critical device such as the subsurface safety valve (SSSV) on an offshore platform will only be allowed after a critical review by AOGCC, and the burden of proof falls solely on Hilcorp. The no -flow test procedure must instill confidence in AOGCC that the test will give an accurate representation of the well's (in)ability to flow to surface and that spill, fire, and explosion hazards have been appropriately mitigated. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Timothy Cole [mailto:tcole(cbhilcorp.com] Sent: Thursday, March 20, 2014 8:42 AM To: Regg, James B (DOA) Subject: RE: AOGCCI Test Witness Notification Request: Other, Monopod Platform Cook Inlet The procedure will be to shut they well in, block in flow lines and bleed down to 0. Install 300 pound calibrated gauge. Install No flow meter and calibrated 2 pen recorder on tubing and casing. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, March 18, 2014 9:58 AM To: Timothy Cole Cc: DOA AOGCC Prudhoe Bay Subject: RE: AOGCCI Test Witness Notification Request: Other, Monopod Platform Cook Inlet TBU A-11 (PTD 1700240) — packerless ESP completion TBU A-17RD (PTD 1810670) — ESP with uphole packer set below SSSV and orifice valve in tubing string below packer Provide a copy of the no flow test procedure and list of equipment with calibration dates for the measuring devices that you intend to use. Jim Regg Supervisor, Inspections 1 'AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Tim Cole [ma iIto: noreply@form response.com] Sent: Tuesday, March 18, 2014 9:08 AM To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay Subject: AOGCCI Test Witness Notification Request: Other, Monopod Platform Cook Inlet Question Type of Test Requested: Requested Time for Inspection Location Name E-mail Phone Number Company Other Information: Submission ID: Answer Other 03-24-2014 12:00 PM Monopod Platform Cook Inlet Tim Cole tcoleghilcorp.com (907) 776-6670 Hilcorp State Witness on No -Flow for A-11, and A-17. 260971671242550892 2 G2u2je type i.D. n €� m b e r: T .0 3 HI CORP CAUBRATION CERTIFICATE Pressu--e Standards Referenced to NIST File TN822-2156610-96. TN838-256609-96. P-8523 Pressure range: TEST PREESSURE Me: INDCATION Calibrated by Test equipment S/N: Y 77 This certificate expires in 90 days on For recertification, contact Gina Bogart 776-6825. HILCORP CALIBRATION CERTIFICATE Pressure Standards Referenced to NIST File TN822-256610-96, N838-26609-96, P-823 Gauge type: -Fel c< ��� Pressure range: SCs� E.D. number: of O Date: TEST PRESSURE INDICATION `5- 1 `L5 _ as0 asd cjo C) �� D Calibrated by: Q-�-_�Test equipment S/N: This certificate expires in 90 days on 5-,-\ r ao For recertification, contact Gina Bogart 776-6825. 2 1 e�v WI M • a Calibration qoOd f f 30 days - � ,rte► LED WiR To Name Dat BYi y�ij$�t�V1 trr r C? 1{ for 30 d:ay.� i -283-5900 - -. S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate R Other R] Run Gas un completion Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well El 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: / E Hilcorp Alaska, LLC Development ❑ Exploratory El Stratigraphic❑ Service ❑ 170-024' '� d 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: MAR 13 2014 Anchorage, AK 99503 50-733-20214-00 7. Property Designation (Lease Number): - 8. Well Name and Number: ��ADL0018731 Trading Bay St / A-11 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Trading Bay Field / Middle Kenai B, Middle Kenai C & Middle Kenai D Oil Pools 11. Present Well Condition Summary: Total Depth measured 10,180 feet Plugs measured feet true vertical 9,927 feet Junk measured 6,693 feet Effective Depth measured 6,432 feet Packer measured 2,091 feet true vertical 6,287 feet true vertical 2,037 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 228' 20" 228' 228' 2,410 psi 770 psi Surface 1,085' 13-3/8" 1,085' 1,045' 3,090 psi 1,540 psi Production 7,092' 9-5/8" 7,092' 6,942' 6,330 psi 3,810 psi Liner 6,475' 7-5/8" 6,475' 6,330' 6,890 psi 4,790 psi Perforation depth Measured depth See Schematic feet RBDMS MAY 1 3 2014 True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.6# / L-80 2,121' (MD) 2,065' (TVD) 2,091(MD) 301' (MD) Packers and SSSV (type, measured and true vertical depth) Stimtop Pkr 2,037' (TVD) SSSV 301' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 0 0 0 130 100 Subsequent to operation: 193 710 272 520 74 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 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1314-065 Contact Ted Kramer Email tkramer .hilcoro.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature oeZPhone (907) 777-8420 Date 3/13/2014 Form 10-404 Revised 10/2012{ �Z ��� Submit Original Only RKB to TBG Hnar = 41.50' roc a 911' loss'°Jl I ll'�1 Trading Bay Unit SCHEMATIC Well # A-11 Completion Date: 02/13/14 CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate hrs 20" X" Wall H40 (risked) Weld 5 Surf 228' 1750 2,121' WLEG 20.5 13-3/8" 61q 1-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 6330 1050 sxs See below 373 Stage Collar 3622.8' 1250 sxs 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs 7-5/8"29,7 1,154' L-80 SLIJ-II 6.875 1 Surf 6,475' 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/ csg bond TUBING 4,193' 4,233' 4,057' 4,098' 2-7/8" 6.6 L-80 Open f/ prod. C-2 Surf 1 2,121' 4,062' 4,098' 36' 01150' 1159' 1199• 5A s.nd 1990' 1700' 4 �} 244 9..d 2170. 2290' B 4,000' 1 KB ELEV = 101' PBTD = 6,432' TD =10,180' ANGLE thru INTERVAL = 8.51 L LN IEWELRY DETAIL 9-5/8" Cement Job NO. Depth ID Item 1 301' Baker TE -5 SSSV 2 2,016' Gas Lift Mandrel 3 2,068' Chemical Injection Mandrel 4 2,091' Stimtop Hyd Perm Packer 5 2,111' X Nipple 6 2,121' WLEG 1160 27W Fair/Poor (USIT) 2700' 2830' Good curt (Top of Log) 2830' 3110' Poorcmt 3100' 3700' Good curt 37W 4056' Poorcmt 4056' 4200' Good curt 42W 51W Poorcmt 5100' 7092' Good curt PERFORATION DATA Zone Top (MD) Btm (MD) To (TVD) Btm (TVD) Amt SPF Date Present Condition B 24-6 2,170' 2,260' 2,111' 2,195' 90' 6 02/11/14 Open B 26-7 2,606' 2,655' 2,521' 2,568' 49' 6 02/11/14 Open B 26-7 2,708' 2,770' 2,618' 2,676' 62' 6 02/11/14 Open B 26-7 2,788' 3,106' 2,694' 2,995' 318' 6 02/11/14 Open Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT curt Sqz Perfs 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/ csg bond C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/ prod. C-2 4,197' 4,233' 4,062' 4,098' 36' 6 02/11/14 Open C-3 4,270' 4,340' 4,135' 4,204' 70' 6 02/11/14 Open CZN6 4,364' 4,384' 4,228' 4,248' 20' 6 02/11/14 Open CA 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 C-5 4,471' 4,476' 4,335' 4,340' S. 4 4/73 C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/ prod. C-7 4,642' 4,712' 4,505' 4,575' 70' 6 02/11/14 Open C 47-5 4,817' 4,827' 4,679' 4,689' 10' 6 02/11/14 Open Stray 4,819' 4,824' 4,681' 1 4,686' 5' 4 4/73 C 47-5 4,846' 4,870' 4,708' 4,732' 24' 1 6 02/11/14 Open C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 C 48-5 4,932' 4,948' 4,794' 4,810' 16' 6 02/11/14 Open C 48-7 4,954' 4,976' 4,816' 4,838' 22' 6 02/11/14 Open C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 C 50-3 5,140' 5,178' 5,002' 5,040' 38' 6 02/11/14 Open Sqz Perfs 5,505' 1 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/ csg bond D ZN2 5,568' 5,590' 5,428' 5,450' 22' 6 02/11/14 Open D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 D 53-8 5,600' 5,652' 5,460' 5,512' 52' 12 5/4/1998 Open f/ prod. D 53-8 5,605' 5,634' 5,465' 5,494' 29' 6 02/11/14 Open D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/ prod. D 54-5 5,670' 5,708' 5,530' 5,568' 38' 6 02/11/14 Open D54-9 5,740' 5,750' 5,600' 5,610' 10' 6 02/11/14 Open D 54-9 5,742' 5,769' 5,602' 5,629' 27' 4 5/70 D 54-9 5,760' 5,770' 5,620' 5,630' 10' 6 02/11/14 Open D 55-7 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 D 55-7 5,802' 5,828' 5,662' 5,688' 26' 6 02/11/14 Open D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/ prod. D 56-1 5,856' 5,949' 5,715' 5,808' 93' 6 02/11/14 Open D 57-2 5,975' 6,055' 5,834' 5,913' 80' 8 5/4/1998 Open f/ prod. D 57-2 5,975' 6,062' 5,834' 5,920' 87' 6 02/11/14 Open Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/ csg bond Sqz Perfs 6,410' 1 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/ csg bond FISH/JUNK IN WELL 1979: GO Int. left a radioactive source in well at 6693'. DO NOT DEEPEN BELOW 65001. Updated by JUL 03/13/14 Hilcorp Alaska, LLC �O�P-IN�5 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number IWell Permit Number Start Date End Date A-11 50-733-20214-00 170-024 2/6/2014 2/13/2014 ;�� �r �hlr iV��l' 9�i,iiidil qty �4 PJSM. NU riser and BOPS. Finish making up HP mud line. Function stack. PU test jt. Service and clean rig. Unable to operate crane due to high winds. Today 3% Brine fluid loss to well 0 bbls - Total 3% Brine fluid loss to well 0 bbls - Today SSP loss to well 0 bbls - Total SSP loss to well 0 bbls - Today Ditch magnet metal recovered from well 0 lbs - Today boot basket metal recovered from well 0 lbs - Total metal recovered from well 0 lbs, Previous fluid loss to well not recovered - Total 3% Brine fluid loss to well 2157 bbls - Total SSP loss to well 125 bbls - Total LCM loss to well 268 bbls - Total metal recovered from well 568 lbs. 02/07/14 - Friday Rig operations shut down due to high winds. Waiting on reply or waiver from state to test BOPS. Work on housekeeping and rig maintenance. Prep to test BOPS. Test all BOP equip to 250 psi low and 2000 psi high. Witness of test waived by Jim Regg, AOGCC. Test with 2-7/8" and 4" pipe. Had 1 fail pass with the choke line HCR. Greased and operated valve and it tested good. Pulled BPV and installed TWC to test blinds. Blow down and rig down test equip. LD/PU sling, XO's, RU flowlines, clear floor and monitor well. LD saver sub off Kelly. Set Kelly back. PU mousehole. Change elevators. LD 5" DP out of derrick using the mousehole. PJSM. Continue LD 5" DP. LD 6-1/2" DC. Today 3% Brine fluid loss to well 0 bbls - Total 3% Brine fluid loss to well 0 bbls - Today SSP loss to well 0 bbls - Total SSP loss to well 0 bbls - Today Ditch magnet metal recovered from well 0 lbs - Today boot basket metal recovered from well 0 lbs - Total metal recovered from well 0 lbs, Previous fluid loss to well not recovered - Total 3% Brine fluid loss to well 2157 bbls - Total SSP loss to well 125 bbls - Total LCM loss to well 268 bbls - Total metal recovered from well 568 lbs. 02/08/14,- Saturday Finish laying do 6-1/2" DCs. Clear floor of 5" subs and tools. Rig up to circ do ann and back up through tbg. Pump 65 bbls before catching pressure. Circ at 1 BPM at 1350 psi. Highest gas units were 400. Pump 1 circ, shut down and bleed ann off. Start pumping again and it took 4 bbls to fill. Shut down and let gas migrate. Rig up landing jt with circ head. Bleed trapped pressure off ann. Screw into hanger. Back out LDS. Pull hanger off seat w/ 36k. Monitor well. Gas breaking out and fluid falling very slow. PU and pull seals out of seal bore with no real indication. Circ do tbg while monitoring ann closely. Rig up to pull 2-7/8" tbg. Rig up spool to coil up control lines. Monitor well while laying do landing jt and hanger. Well is static. POOH Standing 2-7/8" tbg back in derrick and laying do SSSV, GLM, CIM, and Seal Assem. Rig do tbg equip and rig up to PU milling BHA. PU BHA #1 = Pkr Mill w/ 3/8" nose, 5 Boot Baskets, Bit Sub w/ float, Bumper Sub, Oil Jars, Pump Out Sub, 6 DCs, XO = 232.17'. RIH to top of Tie Back Sleeve above Packer at 2,095' on completion tally. Tag top of tieback sleeve at 2,101'- mill from 2,101'-2,108'. PJSM. Continue milling on packer at 2,108'- 5 bpm/400 psi - 60 rpm/100k/torq -15k wt -packer came free. Chase fish down to 2,471'. Circ clean hole. Blow down and rack back Kelly. POOH with BHA # 1. LD BHA # 1 - clean boot baskets, Recovered 52 lbs. MU BHA # 2 - 3-1/4" Itco Spear shoulder type - 4-3/4" Bowen bumper sub - 4-3/4" Bowen oil jar - 6 ea 4-3/4" DC - 4-3/4" Accelerator jar - XO = CAL 219.33'. Today 3% Brine fluid loss to well 78 bbls - Total 3% Brine fluid loss to well 78 bbls - Today SSP loss to well 0 bbls - Total SSP loss to well 0 bbls - Today Ditch magnet metal recovered from well 60 lbs - Today boot basket metal recovered from well 0 lbs - Total metal recovered from well 60 lbs, Previous fluid loss to well not recovered - Total 3% Brine fluid loss to well 2157 bbls - Total SSP loss to well 125 bbls - Total LCM loss to well 268 bbls - Total metal recovered from well 568 lbs. ' (('c Hilcorp Alaska, LLC Hileorp Alaska, LLC Well Operations Summary Well Name API Number JWell Permit Number Start Date End Date A-11 50-733-20214-00 170-024 2/6/2014 2/13/2014 OVOW14-56nd4y Finish PU & MU BHA # 2 - 3-1/4" Itco Spear shoulder type - 4-3/4" Bowen bumper sub - 4-3/4" Bowen oil jar - 6 ea 4-3/4" DC - 4-3/4" Accelerator jar - XO = 219.33'. RIH and engage fish at 2,471', Up wt 63k, Dn wt 62k. Set down on packer 12k, PU to 75k, Set back down putting 12k on pkr, PU to 100k and let jars bleed, PU to 157k and packer came free with wt falling back to 120k. PU and set Kelly back. POOH slowly watching for drag to 1 std before guns. Rig up a safety it for the guns. Stand back DCs, lay down fishing tools and packer. Rig up to lay down gun. Have PJSM for laying down guns. Lay down 4-1/2" Expro perf guns. Laid do 32 guns. Shots that fired were 2,170-2,260 2,606-2,655 2,707-2,770 2,788-3,106]. Continue POOH laying do live guns. LD TCP handling tools. No guns were fired from gun 33 -184. Clear floor of TCP gun handling tools. Cut 205' drilling line. Inspect draw works and brakes. MU BHA #3 -6-3/4" junk mill - 3 ea 4-3/4" junk baskets - 7-5/8" csg scraper - 2 ea 4-3/4" junk baskets - 4-3/4" bit sub - 4-3/4" bumper sub - 4-3/4" oil jar - 4-3/4" pump out sub - 6 ea 4-3/4" DC - 4-15/16" XO = oal 236.05'. RIH - fill pipe at 3,000'. Today 3% Brine fluid loss to well 0 bbls - Total 3% Brine fluid loss to well 78 bbls - Today SSP loss to well 0 bbls - Total SSP loss to well 0 bbls - Today Ditch magnet metal recovered from well 43 lbs - Today boot basket metal recovered from well 52 lbs - Total metal recovered from well 155 lbs, Previous fluid loss to well not recovered - Total 3% Brine fluid loss to well 2157 bbls - Total SSP loss to well 125 bbls - Total LCM loss to well 268 bbls - Total metal recovered from well 568 lbs. x"40,15 ,�< ,. M E '� ;, ti . 4ti ". ('m . �i::�i , ; Continue RIH with scraper run. Tag at 6,426'. Wash from 6,426' to 6,432' [Float Collar]. Workbootbaskets and circ hole clean. Got back about 1 bbl of sand and a high of 450 units of gas. Gas died off after first bottoms up. Circ 2 bottoms up. Monitor well, Hole static. Blow do equip and set Kelly back. POH and lay down clean out assem. Clean boot baskets. Recovered 24 lbs of sand and metal. Rig up to run perf guns. Make up safety it and hang back out of the way. Have PJSM for picking up guns. RIH picking up perf guns. Run 10 guns and have BOP drill. Safety it was picked up, made up, and RIH. Drill went well. Pull up and break safety it. Guns had filled with KCL. Notify town about having to lay guns down due to being full of KCL. POH laying do the perf guns. Expro has 10 more guns being built. Work on rig maintenance projects while waiting on guns. PJSM for TCP guns. RIH with 4- 1/2" TCP guns. Today 3% Brine fluid loss to well 0 bbls - Total 3% Brine fluid loss to well 78 bbls - Today SSP loss to well 0 bbls - Total SSP loss to well 0 bbls - Today Ditch magnet metal recovered from well 0 lbs - Today boot basket metal recovered from well 0 lbs - Total metal recovered from well 155 lbs, Previous fluid loss to well not recovered - Total 3% Brine fluid loss to well 2157 bbls - Total SSP loss to well 125 bbls - Total LCM loss to well 268 bbls - Total metal recovered from well 568 lbs. " t "�9^` n }ysin RIH picking up Expro 41/2" Perf guns. Run 92 guns. Continue RIH picking up perf guns. Ran 181 gun total, Break down safety it. Make up firing head, 1 it tbg, Ported circ sub, 2 its tbg, RA marker pup, and 2 XOs. RIH on 4" DP out of derrick. Rig up wireline. RIH and correlate guns on depth. RA marker at 2,065'/top shot @ 2,166'. POOH/rig down wireline. Rig up bar drop assy/rig up cement line to asst//drop bar/guns fired at 2030 hrs. Good indication that guns fired. Fluid fell. Fill hole with trip tank/19 bbls to fill hole. Gas to surface, close upper pipe rams/circulate well through choke line. At 1-1/2 bottoms up -no oil in returns. Shutdown pump. Open upper pipe rams/monitor well. Kick pump on/circulate hole with well open. Shut down pump @ 1900 stks (+/- 3 btms up). Still no oil in fluid/minimal gas. Monitor well/static loss rate -10 bph. POOH 1 stand from BHA/flow check well. Prepare to lay down TCP guns. Fluid losses at 4 bph. Rack last stand of 4" drill pipe. Break out crossover. Build kill assy or safety it. Pull and lay down RA sub, circ sub, and firing head. 1st TCP gun at rotary/shots fired/Lay down TCP. 67 of 181 guns laid down as of 0600 hrs. 4 bph losses. Today 3% Brine fluid loss to well 54 bbls - Total 3% Brine fluid loss to well 132 bbls - Today SSP loss to well 0 bbls - Total SSP loss to well 0 bbls - Today Ditch magnet metal recovered from well 0 lbs - Today boot basket metal recovered from well 0 lbs - Total metal recovered from well 55 lbs 103 lbs, Previous fluid loss to well not recovered - Total 3% Brine fluid loss to well 2157 bbls - Total SSP loss to well 125 bbls - Total LCM loss to well 268 bbls - Total metal recovered from well 568 lbs. ' (('c Hilcorp Alaska, LLC Aaeor,,A,aska,LLC Well Operations Summary Well Name API Number JWell Permit Number Start Date End Date A-11 50-733-20214-00 170-024 1 2/6/2014 2/13/2014 Daily Operations: 02/12/14 - Wednesday POOH laying do 4-1/2" Perf Guns. All shots fired. Laid down a total of 181 guns. Hole taking 1/2 BPH. Continue cleaning while rigging up to test upper pipe rams. Pull wear ring. MU test jt with test plug. Test upper pipe rams w/ 4" DP to 250 and 2000 psi on chart. Good test. Rig do test equip. RU to PU packer. Pick up packer assy. and RIH ick up wt 44k/slack off wt 42k. Rig up to drop ball. Drop ball. After 5 minutes pressure drill pipe to 2500 psi. Hold pressure for 5 minutes. Packer set at 2,090'. Open drill pipe. Close upper rams/pressure annulus to 1500 psi/hold for 5 minutes/good test on packer. Release running tool from packer. Rig down surface equip. POOH racking back 4" drill pipe. Clean rig floor. Rig up to run 2-7/8" completion. Pick up seal assy and Chem inj mandrel. Hang off. Rig up sheave to run control line. Connect line to chem inj mandrel/test same. RIH w/ 2-7/8" completion. Install safety valve. Test to 5000 psi for 15 min. RIH remainder of 2-7/8" tubing. Tag packer/space out completion. Today 3% Brine fluid loss to well 51 bbls - Total 3% Brine fluid loss to well 183 bbls - Today SSP loss to well 0 bbls - Total SSP loss to well 0 bbls - Today Ditch magnet metal recovered from well 0 lbs - Today boot basket metal recovered from well 0 lbs - Total metal recovered from well 103 lbs, Previous fluid loss to well not recovered - Total 3% Brine fluid loss to well 2157 bbls - Total SSP loss to well 125 bbls - Total LCM loss to well 268 bbls - Total metal recovered from well 568 lbs. 02/13/14 - Thursday Space out and PU hanger. MU control lines through hanger and test. Land hanger. Good indication of seals going into seal bore extension. Run in LDS. Test back side to 1500 psi for 30 min on chart. Good test. Pull landing jt. Set BPV. Rig down landing jt and test equip. Clear floor of completion tools. PJSM and prep to nipple down BOPS. Break stack loose. PU and move over to the side. Break riser loose from wellhead and pull out of well head room. Prep hanger and control lines. Put air controlled valve in wellhead room. PU and land tree on wellhead. MU tree bolts to specs. Install connector to control line for SSSV. Work on getting 3/8" Chemical Injection Line connection on tree flange made up. All fittings made up to tree. Rig up and test void area to 5000 psi/5 min. Good test. Pull BPV/Install 2 way check valve. Test tree to 5000 psi/5 min. Good test. Rig up lubricator and slickline. Turn well over to production. Release rig f/ A-11. Today 3% Brine fluid loss to well 0 bbls - Total 3% Brine fluid loss to well 183 bbls - Today SSP loss to well 0 bbls - Total SSP loss to well 0 bbls - Today Ditch magnet metal recovered from well 0 lbs - Today boot basket metal recovered from well 0 lbs - Total metal recovered from well 103 lbs, Previous fluid loss to well not recovered - Total 3% Brine fluid loss to well 2157 bbls - Total SSP loss to well 125 bbls - Total LCM loss to well 268 bbls - Total metal recovered from well 568 lbs. I'5it- �I ('6 ( 70 ()Z+r-, Regg, James B (DOA From: Marvin Rogers - (C) [mrogers@hilcorp.com] ���� ZIN l4 Sent: Wednesday, February 12, 2014 1:42 PM 71 To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Subject: Monopod A-11 Test Used upper rams on 2-11-14 at 2100 hrs A-11, Monopod, PTD 170-024 Monopod rig 56 Operator Contact,Marvin Rogers Ran perf guns and fired them off at 2030 hrs. While circulating we started getting back a lot of gas so we closed the upper pipe rams on 4" pipe and circulated through the open choke. This allowed the gas to vent out the gas buster instead of on the rig floor. We did this for about 20 min then we opened the rams and circulated down the flow line. We are currently still POH laying do guns. When we get out of the hole this afternoon [Approx 1700 hrs] we will test the upper rams. Thank You Hilcorp Alaska, LLC Marvin Rogers DSM Monopod Platform SCANNED [907] 776-6675 E -Mail: mrogers@hilcorp.com 07 ��'��\��%%� TI aE STATE a51:ce O'-.� F �' ` c Wit 1/4 �_,_ 333 s esi Seventh Avenue GOVERNOR SEAN PARNEI. Anchorage, Alaska 99501-3572 s' g;' u Main: 907.279.1433 �� -ALAS'. �.�6p. 907.27( 7542 SCANNED MAY 1 6 ?DSA Ted Kramer Sr. Operations Engineer ��L Hilcorp Alaska, LLC i 7 °- 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B, C, & D Oil Pools, Trading Bay St A-11 Sundry Number: 314-065 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, ;t4. 24Cathy P Foerster !c Chair DATED this (o day of February, 2014. Encl. RECEIVED LVED • STATE OF ALASKA SER 0 3 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20AAC 25280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate El - Pull Tubing El - Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing 0 Other. Run ESP 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development CI- 170-024 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20214-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 93B Will planned perforations require a spacing exception? Yes ❑ No CI Trading Bay St/A-11 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): • ADL0018731 - Trading Bay Field/Middle Kenai B, Middle Kenai C &Middle Kenai D Oil Pools 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): 10,180 • 9,927 - 6,432 - 6,287 " 6,693 Casing Length Size MD TVD Burst Collapse Structural Conductor 228' 20" 228' 228' 2,410 psi 770 psi Surface 1,085' 13-3/8" 1,085' 1,045' 3,090 psi 1,540 psi Intermediate Production 7,092' 9-5/8" 7,092' 6,942' 6,330 psi 3,810 psi Liner 6,475' 7-5/8" 6,475' 6,330' 6,890 psi 4,790 psi 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 2,127' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Production Packer and SSSV - 2,100'(MD)2,045'(TVD)and SSSV:311'(MD) 311'(ND) • 12.Attachments: Description Summary of Proposal 0 • X13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 • Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/8/2014 Oil 0 • 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 tkramerCc thilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature —dei, Phone (907)777-8420 Date 2/3/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3\` .— O(Q� Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other: Jf 2OO(Dps.; 45b ---/---Z,---/- RBDM MAY U 9 2014 Spacing Exception Required? Yes ❑ No / Subsequent Form Required: '0 —yfl L' I / APPROVED BY Approved by: ja46,..14-____ C I NAHLOMMISSION Date: Z- 4 _/ 1 ;14111 Submit Form and Form 10-403(Revised 10/2012) 0 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: A-11 H!carp Alaska,LL Date:02/03/2014 Well Name: Monopod A-11 API Number: 50-733-20214-00 Current Status: SI oil producer(Gas Lifted) Leg: N/A Estimated Start Date: February 8, 2014 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(907)777-8332 Permit to Drill Number: 170-024 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: 1,958 psi @ 5,890' MD(5,749' ND) From 4/16/2007 Shut-in Bottom Hole Pressure Survey(=0.341 psi/ft. grad.) Maximum Expected BHP: 1,958 psi @ 5,890' MD (5,749'ND) Max.Anticipated Surface Pressure: —Opsi (1,958 psi -(5,749'TVD X .341 psi/ft.)) Brief Well Summary The A-11 well was recently worked over with a new 7-5/8" 29.7#L-80 SLIJ-II tie-back liner added. The well was then perforated using 4-1/2"5 JSPF TCP guns with 23 gram charges shot under a packer. The well was then turned over to production but the well would not flow. Diagnostics indicated that the perforations did not provide connectivity to the reservoir. This workover plan entails pulling the current completion,cleaning out the perf debris,and then re-perforating with larger deeper penetrating charges. Depending on the inflow results,the well will be completed either on gas lift or on ESP. Brief Procedure: 1. MIRU Monopod Platform Rig. 2. RU Slickline and pull GLV from Mandrel at 2,025'and Circulate Hydrocarbon off of well. 3. ND Wellhead,NU BOP and test to 250 psi low/2,000 psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. Unseat tbg. hanger and pull out of well with 2-7/8" Production tubing,GLM,and Chemical Injection Mandrel,and Seals. 5. PU 7-5/8" Mill Shoe and RIH to Production packer at 2,120'. Mill over packer until free. POOH with Shoe. 6. PU RIH with Spear,engage fish and POOH laying down packer and TCP Guns. 7. PU RIH with 7-5/8"clean out assembly. Clean out perf debris to PBTD 6,440'. Circ,le clean with 3%KCL (Casing was pressure tested to 2,500 psi for 30 minutes on 1/22/14). 8. PU RIH with 4-1/2"39 gram TCP guns to re-perforate shots according to final Perf Request Form dated 1/9/2014. 9. RU E-line, Log Guns on depth. POOH with E-line,Fire Guns. il Well Prognosis Well: A-11 Hilcorp Alaska,LL, Date:02/03/2014 10. Circulate out pert gas, Monitor well for 1 hour. Evaluate if well is taking fluid. Allow well to stabilize, IF well wants to flow,balance well and POOH laying down TCP guns. Go to step 12. If well is taking fluid, Prep to run ESP Completion. 11. PU RIH W/ESP,GLM with orfice valve,SSSV,ESP packer and tbg Hanger.Pressure up and set ESP packer. Go to step 14. w„1) T1t PU 7-5/8" Permanent Production packer,RIH on Drillpipe to 2,090'. Pressure up and set packer. fie'"` POOH with drillpipe. 13. PU RIH with 2-7/8" Production tubing,chemical injection mandrel,GLM,SSSV,and tubing hanger. 14. Hang off well. 15. ND BOP,NU wellhead and test. 16. NU Slickline. RIH pulling dummy valves in the chemical injection mandrel and the GLM. Replace with live valves and/or orfice valve. 17. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing . li Trading Bay Unit SCHEMATIC Well#A-11 • Completion Date: 01/23/2014 CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate RKB to TBG Hngr=41.50' hrs r t20" W'Wall H40 Weld Surf 228' 1750 20.5 228 (risked) 13-3/8" 61# J-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs C e f' j 720 Stage Collar 3622.8' 6330 1250 sxs See below 373 ass• 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 10505x5 .114• 7-5/8" 29.7 L-80 SLID-II 6.875 Surf 6,475' y TUBING >" 2-7/8" 6.5 I L-80 I 8rd EUE I I Surf I 2,157' 1085' di 1122' JEWELRY DETAIL 9-5/8"Cement Job ;=.1180'1152• NO. Depth ID Item 1160' 2700' Fair/Poor(USIT) 1180' 1 311' _ SSSV 2700' 2830' Good cmt(Top of Log) 54 sand 2 2,025' Gas Lift Mandrel 2830' 3110' Poor cmt uw 1700 3 2,077' Chemical Injection Mandrel 3100' 3700' Good cmt 4 2,100' Production Packer 3700 4056' Poor cmt 5 2,115' X Nipple 4056' 4200' Good cmt I♦ 3 4200' 5100' Poor cmt 6 _ 2,126' Ported Sub I AIL 4 I IIII 6 7 2,170' TCP Perforating Guns 5100 7092' Good cmt 244 sand 2170'22801111 PERFORATION DATA Top Date Zone (MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Last Opr. Present Condition A . B 24-6 2,170' 2,260 2,111' 2,195' 90' 6 1/22/14 Open B B 26-7 2,606' 2,655' 2,521' 2,568' 49' 6 1/22/14 Open B 26-7 2,708' 2,770' 2,618' 2,676' 62' 6 1/22/14 Open B 26-7 2,788' 3,106' 2,694' 2,995' 318' 6 1/22/14 Open 1Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT cmt f= Sqz Perfs 4,192' _ 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/csg bond = C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. C-2 4,197' 4,233' 4,062' 4,098' 36' 6 1/22/14 Open C-3 4,270' 4,340' 4,135' 4,204' 70' 6 1/22/14 Open ti CZN6 4,364' 4,384' 4,228' 4,248' 20' 6 1/22/14 Open 4,000' C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 4 ' C-5 4,471' 4,476' 4,335' 4,340' 5' 4 4/73 1 C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. K; C-7 4,642' 4,712' 4,505' 4,575' 70' 6 1/22/14 Open xl c; C 47-5 4,817' 4,827' 4,679' 4,689' 10' 6 1/22/14 Open 8.-1 Stray 4,819' 4,824' 4,681' 4,686' 5' 4 4/73 ZS C 47-5 4,846' 4,870' 4,708' 4,732' 24' 6 1/22/14 Open Cc C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 ni C 48-5 4,932' 4,948' 4,794' 4,810' 16' 6 1/22/14 Open C 48-7 4,954' 4,976' 4,816' 4,838' 22' 6 1/22/14 Open C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 1 A C 50-3 5,140' 5,178' 5,002' 5,040' 38' 6 1/22/14 Open 4. Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond D ZN2 5,568' 5,590' 5,428' 5,450' 22' 6 1/22/14 Open _ D D 53-0 5,570' _ 5,586' 5,430' 5,446' 16' 8 4/73 . D 53-8 5,600' 5,652' 5,460' 5,512' 52' 12 5/4/1998 Open f/prod. D 53-8 5,605' _ 5,634' 5,465' 5,494' 29' 6 1/22/14 Open y� D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/prod. xl D 54-5 5,670' 5,708' 5,530' 5,568' 38' 6 1/22/14 Open 745° / D54-9 5,740' 5,750' 5,600' 5,610' 10' 6 1/22/14 Open �i�// .� D 54-9 5,742' 5,769' 5,602' 5,629' 27' 4 5/70 D 54-9 5,760' 5,770' 5,620' 5,630' 10' 6 1/22/14 Open KB ELEV=101' D 55-7 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 PBTD=6,432' TD=10,180' D 55-7 5,802' 5,828' 5,662' 5,688' 26' 6 1/22/14 4 Open ANGLE thru INTERVAL=8.5° D 56-1 5,856' _ 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. D 56-1 5,856' 5,949' 5,715' 5,808' 93' 6 1/22/14 Open D 57-2 5,975' 6,055' 5,834' 5,913' 80' 8 5/4/1998 Open f/prod. D 57-2 5,975' . 6,062' 5,834' 5,920' 87' 6 1/22/14 4 Open Sqz Perfs 6,070' . 6,071' 5,928' 5,929' 1' 4 5/70 1 Cmt Sqzd f/csg bond Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 f Cmt Sqzd f/csg bond FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. Updated by JLL 01/30/14 • Trading Bay Unit PROPOSED Well #A-11 Completion Date: Future CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate RKB to TBG Hngr=41.50' hrs 20" X"Wall H40 Weld Surf 228' 1750 20.5 ill 22e 2 (risked) 13-3/8" 61# J-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 .1i. ee� 3 .. 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs '' '- 4I) y �p�p, Stage Collar 3622.8' 6330 1250 sxs See below 373 '' we, ,9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs v --, `S C_• "4. 7-5/8" 29.7 L-80 SLI1-II 6.875 Surf 6,475' +2",x �,,�), TUBING ioas a * '� 2-7/8" 16.5 I L-80 I 8rd EUE I Surf 2,157' v-•i .++1 422. JEWELRY DETAIL 9-5/8"Cement Job - „so'lies• NO. Depth ID Item 1160' 2700' Fair/Poor(USIT) 1150' 1 _ ±300' SSSV - 2700' 2830' Good cmt(Top of Log) 5A Sand 2 ±310' Packer - 2830' 3110' Poor cmt , 111e0'7700' 3 ±318' _ X Nipple 3100' 3700' Good cmt 4 ±326' Gas Lift Mandrel w/Orifice Valve 3700 4056' Poor cmt 5 ±4,640' Bottom of ESP 4056' 4200' Good cmt 4200' 5100' _ Poor cmt ''���� 5100' 7092' Good cmt /, 4244 Sand e use PERFORATION DATA NTop Date Zone (MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Last Opr. Present Condition B 24-6 ±2,170' ±2,260' ±2,111' ±2,195' 90' 6 1/22/14 0B B 26-7 ±2,606' ±2,655' ±2,521' ±2,568' 49' 6 1/22/14 B 26-7 ±2,708' ±2,770' ±2,618' ±2,676' 62' 6 1/22/14 i3?' B 26-7 ±2,788' ±3,106' ±2,694' ±2,995' ±318' 6 1/22/14 Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT cmt Sqz Perfs 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/csg bond -- C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. C-2 ±4,197' ±4,233' ±4,062' ±4,098' 36' 6 1/22/14 ., C-3 ±4,270' ±4,340' ±4,135' ±4,204' 70' 6 1/22/14 CZN6 ±4,364' ±4,384' ±4,228' ±4,248' 20' 6 1/22/14 `,},4.,4,000' C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 C-5 4,471' 4,476' 4,335' 4,340' 5' 4 4/73 IR C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 Y4 t C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. y� 0„ C-7 ±4,642' ±4,712' ±4,505' ±4,575' 70' 6 1/22/14 1/22/14 Y� �� C 47-5 ±4,817' ±4,827' ±4,679' ±4,689' 10' 6 5 ill Stray 4,819' 4,824' 4,681' 4,686' 5' 4 4/73 C 47-5 ±4,846' ±4,870' ±4,708' ±4,732' 24' 6 1/22/14 Vis =C C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 - C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 C 48-5 ±4,932' ±4,948' ±4,794' ±4,810' 16' 6 1/22/14 C 48-7 ±4,954' ±4,976' ±4,816' ±4,838' 22' 6 1/22/14 d C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 U t C 50-3 ±5,140' ±5,178' ±5,002' ±5,040' 38' 6 1/22/14 Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond E D ZN2 ±5,568' ±5,590' ±5,428' ±5,450' 22' 6 1/22/14 D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 53-8 5,600' 5,652' 5,460' 5,512' 52' 12 5/4/1998 Open f/prod. D 53-8 ±5,605' ±5,634' ±5,465' ±5,494' 29' 6 1/22/14 D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/prod. ID D 54-5 ±5,670' ±5,708' ±5,530' ±5,568' 38' 6 1/22/14 7e% 054-9 ±5,740' ±5,750' ±5,600' ±5,610' 10' 6 1/22/14 e-se/ jj/ �j+T� D 54-9 5,742' 5,769' 5,602' 5,629' 27' 4 5/70 D 54-9 ±5,760' ±5,770' ±5,620' ±5,630' 10' 6 1/22/14 KB ELEV=101' D 55-7 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 PBTD=6,432' TD=10,180' D 55-7 ±5,802' ±5,828' ±5,662' ±5,688' 26' 6 1/22/14 ANGLE thru INTERVAL=8.5° D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. D 56-1 ±5,856' ±5,949' ±5,715' ±5,808' 93' 6 1/22/14 D 57-2 5,975' 6,055' 5,834' 5,913' 80' 8 5/4/1998 Open f/prod. D 57-2 ±5,975' ±6,062' ±5,834' ±5,920' 87' 6 1/22/14 I Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/csg bond Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/csg bond FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. Updated by ILL 02/03/14 . . • ll Monopod Platform A-11 Current 2/03/2014 Hikorp AMud.M,I.IU: Monopod Platform Tubing hanger,SME-CL,11 X A-11 3 Y:EUE lift and susp,w/3" 13 3/8 X 9 5/8 X 7 5/8 X Type H BPV profile,2-3/8 2 7/8 CCL Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union ll Le. , Will 1.1 OM 9 1di Valve,Swab,WKM-M, � 3 1/8 5M FE,HWO,DD trim ,���{{{ Valve,Wing,WKM-M, ., ,.. 3 1/8 5M FE,w/15"OMNI ilEnr t r operator,DD trim J \ , Valve,Master,WKM-M, 0©e 3 1/8 5M FE,HWO,DD trim ®� 0 ©—ii'0 m Multibowl Wellhead-uppericn e ��it . _ SMB-22,11 5M X 11 5M,w/ "il� •F VIM J".-- 2-2 1/16 5M SSO,w/1- 2 1/16 5M WKM-M valve - -rte +�'''I Casing spool,5,13 5/8 3M x 11 5M,w/2-2 1/16 5M SSO, ill 1 'I 1e1 711,1001: w/BG bottom w/1-2 1/16 5M WKM-M ilit It il i valve IIiII M III*'401 I1'�I-1.:' iii.., it Casing head, ®I . 1�1 Shaffer KD, 135/83MX 13 3/8 SOW,w/2-2" ■ 1 'MIMI r l III-i. LPO, 0 II • ll Monopod Platform A-11 Proposed ESP Hikes AI..ki,LILA: 2/03/2014 Monopod Platform Tubing hanger,Seaboard- A-11 ESP-EN,11 X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 7 5/8 X and Susp w/3"Type H BPV 2 7/8 profile,2-h CCL,Prepped for BIW Kwik Lok penetrator BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union Valve,Swab,WKM-M, 3 1/8 5M FE,HWO,DD trim $ Q1a Valve,Wing,WKM-M,3 1/8 Valve,Wing,WKM-M,2 1/16 5M FE,w/15"OMNI 5M FE,HWO,DO trim �'. operator,DD trim / w�i Valve,Master,WKM-M, ®O0 3 1/8 5M FE,HWO,DD trim m n. IL A Adapter,Seaboard-ESP, 11 5M rotating flange x 3 1/8 5M rotating flange,w/ �, 411/16 pocket,w/2-4 CCL, • ported for BIW penetrator 1 .4 Multibowl Wellhead-upper •— � -� SMB-22,115M X 115M,w/ 2-2 1/16 5M SSO,w/1- 2 1/16 5M WKM-M valve 1 II 1- iI 1 _1111111,- ' Casing spool,5,13 5/8 3M x ° 11 5M,w/2-2 1/16 SM SSO, 11 pi IUI w/BG bottom w/1-2 1/16 5M WKM-M IL 0 � IIr , valve I III Tam •/®���II111 . f - Casing head, IHi 1�1 Shaffer KD, 135/83MX yy..{{� 13 3/8 SOW,w/2-2" s I�111�IH�3; 4111-1.LPO, _ 7 . 11 Monopod Platform 2013 BOP Stack HI!carp Alw.k.,LU 03/12/2013 Rig Floor 1111111.111 Bottom of air boot flange 5'below rig floor 16" 14.72' 9.50' Pipe I11 111r111!111! ti 1 • O itl ff�l frit al Iftl 3.74' Shaffer 13 5/8 5M III 111111 Ill III 26.25' Shaffer LXT 2 7/8-5 Variables 2.50 13 5/8 5M Blind i i li 1.76 I :I Mud Cross i Awl" v- 135/8 5M FE X FE w/31/85M EFO w/2 1/16 5M Choke and Kill valves w/Unbolt end connections for lines 4 1358SM 283' 4r- -mar Dual Cameron Fle><rams -'11'11 .70' i.l I , 111 f I • 14.20" Drill deck UOCD 1911 azar 14.20' 1 3 5.3'A'F F X 1 3 5 i 8 SNA F E Inn 43 4 STd«r,p3al 1.5' 13 3/8 3 M X11 3M Wellhead @ 1500' STATE OF ALASKA ALA_..A OIL AND GAS CONSERVATION COML. _JON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations 9 Perforate Q Other 0 Add 7-5/8"casing liner& Performed: Complete Alter Casing ❑ Pull Tubing El Stimulate-Frac ❑ Waiver❑ Time Extension❑ _ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WeI10 2.Operator 4.Well Class Before Work: 5.Permit to Drill Nurr�er������D Name: Hilcorp Alaska,LLC Development❑� Exploratory El 170-024 ♦ ���®?71 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20214-00 • JAN 31 2014 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 r Trading Bay St/A-11 ' /\Q u CC 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • (4•5).- 17-- C IS L Trading Bay Field/Middle Kenai B,Middle Kenai C&Middle Kenai D Oil Pools 11.Present Well Condition Summary: Total Depth measured . 10,180 feet Plugs measured feet true vertical 9,927 feet Junk measured 6,693 feet Effective Depth measured ` 6,432 feet Packer measured 2,100 feet true vertical 6,287 feet true vertical 2,045 feet Casing Length Size MD ND Burst Collapse Structural Conductor 228' 20" 228' 228' 2,410 psi 770 psi Surface 1,085' 13-3/8" 1,085' 1,045' 3,090 psi 1,540 psi Production 7,092' 9-5/8" 7,092' 6,942' 6,330 psi 3,810 psi Liner 6,475' 7-5/8" 6,475' 6,330' 6,890 psi 4,790 psi Perforation depth Measured depth See Schematic feet ED JUL 1 6 213.4 SCAN* True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 2,127'(MD) 2,071'(ND) 2,100'(MD) 311'(MD) Packers and SSSV(type,measured and true vertical depth) Prod Pkr 2,045'(ND) SSSV 311'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMS4=`I"'AY 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: 0 0 0 8 0 Subsequent to operation: 0 0 0 7 0 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 r Q Gas ❑ 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 Naber or N/A if C.O.Exempt: 313-574&314-001 Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature '"7 Phone (907)777-8420 Date 1/30/2014 Form 10-404 Revised 10/2012 s 2 3 �`t Submit Original Only ..0* .57 91 ,11 TradBay Unit SCHEMATIC Well #ingA-11 Completion Date: 01/23/2014 CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate RKB to TBG Hngr=41.50' hrs 20" Y:"Wall H40 Weld Surf 228' 1750 20.5 228 J (risked) S 13-3/8" 618 J-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 9-5/8" 43.5 N-80 8rd LT&C 8rd LT&C 8.755 Surf 7092' 1050 sxs .���p Stage Collar 3622.8' 6330 1250 sxs See below 373 (fit ?;ass 9-5/8" 43.5 N-80 8.755 Surf 7092' 1050 sxs s+�, 7-5/8" 29.7 L-80 SLII-II 6.875 Surf 6,475' it; r"t 2-7/8" 16.5 I L-80 Weld EUE I I Surf I 2,157' 1085' s 22' JEWELRY DETAIL 9-5/8"Cement Job 51_,'++w++se' NO. Depth ID Item 1160' 2700' Fair/Poor(USIT) so' 1 311' SSSV 2700' • 2830' Good cmt(Top of Log) 54 sand 2 2,025' Gas Lift Mandrel 2830' 3110' Poor cmt +880'1700' 3 2,077' Chemical ' on Mandrel 3100' 3700 Good cmt 4 2,100' Production Packer 3700' 4056' Poor cmt 24056' 4200' Good cmt 5 2,115' X Nipple 6 2,126' Ported Sub 4200' 5100' Poor cmt I ma a 7 2,170' TCP Perforating Guns 5100' 7092' Good cmt ir�' I =z4e Sand 2+70'2200 PERFORATION DATA Top Date Zone (MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Last Opr. Present Condition B 24-6 2,170' 2,260' 2,111' 2,195' 90' 6 1/22/14 Open• B B 26-7 2,606' 2,655' 2,521' 2,568' 49' 6 1/22/14 ' Open B 26-7 2,708' 2,770' 2,618' 2,676' 62' 6 1/22/14 , Open B 26-7 2,788' 3,106' 2,694' 2,995' 318' 6 1/22/14 Open Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT cmt 0 === Sqz Perfs 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/csg bond C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. C-2 4,197' 4,233' 4,062' 4,098' 36' 6 1/22/14 Open C-3 4,270' 4,340' 4,135' 4,204' 70' 6 1/22/14 Open CZN6 4,364' 4,384' 4,228' 4,248' 20' 6 1/22/14 Open 4,000' C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 ' C-5 4,471' 4,476' 4,335' _ 4,340' 5' _ 4 4/73 C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 0 1 C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. C-7 4,642' 4,712' 4,505' 4,575' 70' 6 1/22/14 Open i • C 47-5 4,817' 4,827' 4,679' 4,689' 10' _ 6 1/22/14 Open 0. Stray 4,819' 4,824' 4,681' 4,686' 5' 4 4/73 C 47-5 4,846' 4,870' 4,708' _ 4,732' 24' 6 1/22/14 Open 0,. C C 47-5 4,850' 4,867' , 4,712' 4,729' 17' 4 4/73 C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 C 48-5 4,932' 4,948' 4,794' 4,810' 16' 6 1/22/14 Open C 48-7 4,954' 4,976' 4,816' 4,838' 22' 6 1/22/14 Open C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 =7C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 1 1 = C 50-3 5,140' 5,178' 5,002' 5,040' 38' 6 1/22/14 Open Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond 1 was D ZN2 5,568' 5,590' 5,428' 5,450' 22' 6 1/22/14 Open a:.= D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 ill D 53-8 5,600' 5,652' 5,460' 5,512' 52' _ 12 5/4/1998 Open f/prod. D 53-8 5,605' 5,634' 5,465' 5,494' 29' 6 1/22/14 Open I D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/prod. D 54-5 5,670' 5,708' 5,530' 5,568' 38' _ 6 1/22/14 Open �jsie% ` D54-9 5,740' 5,750' 5,600' 5,610' 10' 6 1/22/14 Open /���/ D 54-95/70 s-se j` D 54-9 5,760' 5,770' 5,620' 5,630' 10' 6 1/22/14 Open KB ELEV=101' D 55-7 5,802' 5,816' 5,662' 5,676' 14' _ 4 5/70 PBTD=6,432' TD=10,180' D 55-7 5,802' 5,828' 5,662' 5,688' 26' 6 1/22/14 Open ANGLE thru INTERVAL=8.5° D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. D 56-1 5,856' 5,949' 5,715' 5,808' 93' 6 1/22/14 Open D 57-2 5,975' 6,055' 5,834' 5,913' 80' 8 5/4/1998 Open f/prod. D 57-2 5,975' 6,062' 5,834' 5,920' 87' _ 6 1/22/14 Open Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/csg bond Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/csg bond FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. Updated by JLL 01/30/14 Hilcorp Alaska, LLC Hileurp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-11 50-733-20214-00 170-024 1/2/2014 1/23/2014 Daily Operations: 01/02/14-Thursday Rigging up. 01/03/14-Friday Set BPV and nipple dn tree. Nipple up riser and spacer spool. Continue prep for BOPE test. NU BOPE,HCR valves and choke Koomey lines.Install turnbuckles/drip pan. AOGCC Insp Jeff Turkington gave approval at 2300 hrs 1/3/14 to proceed with test without a witness-call him if helicopter starts flying and he will come out.PJSM.Finish NU BOPE. PU test tools.Pull BPV-set TWC. MU 5"test jt-fill lines stack choke-circ to pits.Test BOPE as per HAK/Kuukpik/AOGCC procedures-250 psi low/2000 psi high. Total fluid 3%Brine loss to well. 01/04/14-Saturday Rig up to test with 3-1/2'.Test upper rams and Hydril to 250_p5i low and 2000 psi h gh.Pull test jt and test blind rams.Rig dn test equip.Pull TWC. Install mouse hole.PU landing jt and screw into hanger.Back out LDS. Pull hanger loose w/47k,wt fell back to 42k.Pull hanger to rig floor and lay dn landing jt.Secure well for crew change on boat.Rig up to circ to get oil cap off ann.Circ 30 bbls and it cleaned up.Rig dn circ equip,lay dn hanger and pups,and rig up tongs.POOH standing back 3-1/2"tbg.[33 stds of 3-1/2"EUE 9.3#w/mule shoe]Rig dn tbg equip.PU BHA#1=8-1/2"bladed junk mill,Four 7"boot baskets,Bit sub w/float,Bumper sub,Oil jars,Pump out sub,XO,9 DCs,OX=329.97'. RIH with BHA#1-tag at 3,986'.Obtain parameters-puw/118k-sow/108k-rtw/120k-pump/8 bpm/360 psi/70 rpm-Milling from 3,986'-4,003'thru retainer-745 max gas units at 3,992' light sand and some rubber across shakers. CBU to clean well and circ gas out. Wash to 4,110'.Mill on junk and packer to 4,112'..CBU to clear gas- 525 max gas units.PJSM.Blow down Kelly.POOH with BHA#1. LD BHA#1. Total 3%Brine fluid loss to well 38 bbls.Today Ditch Magnet Metal recovery 5 lbs-Today boot basket metal recovery 00 lbs-Total metal recovered from well 5 lbs. 01/05/14-Sunday Waiting on State to reply regarding re-doing our BOP test due to misunderstanding about starting time of BOP test. Working on rig maintenance projects.Cleaning and house keeping on rig.Change out trip tank pump.Work on crown lights.PU BHA#2=8-3/8"packer mill,WP ext,Top sub,XO, Four 7"boot baskets,Bit sub w/float,Bumper sub,oil jars,Pump out sub,XO,9 DCs,XO=335.97'[Stand back in derrick untorqued]. Rig up to test BOPs. [Lou Grimaldi,AOGCC Inspector,arrived on platform at 16:45 to witness test].Test BOPs to 250 psi low and 2000 psi high as per KUUKPIK/ HAK/AOGCC procedures.1 failure on Trip tank level indicator read 5 bbls high vs strap-will recalibrate and retest.Completed BOPE test-1 failure of HCR Kill valve-serviced valve-passed retest.RD test equip. Install wear ring.Blow down lines.PJSM. PU BHA#2-RIH with BHA#2. Today 3% Brine fluid loss to well 7 bbls-Total 3%Brine fluid loss to well 44 bbls-Today Ditch Magnet Metal recovery 43 lbs-Today boot basket metal recovery 13 lbs-Total metal recovered from well 56 lbs. 01/06/14-Monday Tag packer at 4,112'_.Mill over packer f/4,112't/4,116'and packer moved down hole.Chase to 4,133'and circ bottoms up.RIH to 5,767'and started taking wt.Lay dn singles and Kelly up.Wash and ream to 5,795'.Started getting a flow increase with gas breaking out.Shut in well 125 psi build up at choke panel.Circ gas out through degasser.Started getting a lot of crude oil just before bottoms up.Est getting 50 bbls back.Had a high of 4300 units of gas.Open up well and circ bottoms up one more time.Tag packer at 5,795'.Monitor well w/hole taking 26.5 BPH. Set Kelly back and blow dn lines.POH to 4,219'. Spot 20 bbl size salt pill at top of perfs.POH. LD BHA#2-recovered 118 lbs metal from boot baskets-recovered part of a composite plug in packer shoe.Remove wear ring.PU BOPE test tools.Conduct test of Koomey and BOPE components used in well shut in-CMV's 15 /16-HCR kill-5"vbr to 250 psi low/2000 psi high.LD test equip.Install wear ring.MU BHA#3-8-1/4"Overshot,XO,WP ext,top sub,XO,Bit sub w/float,bumper sub,oil jars,pump out sub,XO, (9)6-1/4"DCs,XO,accel jar-oal 324.79'. PJSM. MU BHA#3. RIH with BHA#3,CBU-to clear well of gas-725 max gas units-40 bph loss at start of CBU-30 bph loss at end of CBU. Engage fish at 5,795'-jar fish free 2 hits-work fish up hole to 5,765'-hanging up-work fish up/down to break it free-now moving fish up hole.Today 3%Brine fluid loss to well 234 bbls-Total 3%Brine fluid loss to well 296 bbls-Today SSP loss to well 36 bbls-Total SSP loss to well 36 bbls-Today Ditch Magnet Metal recovery 86 lbs-Today boot basket metal recovery 134 lbs-Total metal recovered from well 276 lbs. 1 Well HAiilcorp Alaska, LLC Hi/V i!carp Alaska,LLC e l l Operations Summary Well Name API Number Well Permit Number Start Date End Date A-11 50-733-20214-00 170-024 1/2/2014 1/23/2014 Daily Operations: 01/07/14-Tuesday POH with fish[packer].Pumping out laying down sngs from 5,765'to 5,060'. PU Kelly and start pumping out and LD sngs.Blow down and stand back Kelly. Cont POOH without Kelly.LD BHA#3-recovered 2.80'of packer fish.MU BHA#4-8-1/4"junk mill,4 ea 7"boot bskts,bit sub w/flt,bump sub,oil jars,pump out sub,XO, 9 ea 6-1/4"DCs,XO,accel jar,-oal 342.92'.Service rig. RIH with BHA#4,CBU 200 max gas units. Tag at 5,797' milling and washing from 5,797'to 5,909'at 70 rpm-200 amps-10 bpm/620 psi-CBU 430 max gas units/sand-20 bph loss. PJSM crew change. Milling/washing from 5,909'. CBU 6000'425 max gas units/sand/rubber -18 bph loss-6100'CBU 540 max gas units/sand-13 bph loss-6200' CBU 525 max gas units/sand-20 bph loss-6300'CBU 480 max gas units/sands-25 bph loss. Today 3%Brine fluid loss to well 495 bbls-Total 3% Brine fluid loss to well 729 bbls-Today SSP loss to well 36 bbls-Total SSP loss to well 36 bbls-Today Ditch Magnet Metal recovery 98 lbs-Today boot basket metal recovery 134 lbs-Total metal recovered from well 276 lbs. 01/08/14-Wednesday Continue cleaninLout 9-5/8"casing from 6,300'.CBU every 100'.10 BPM/650 PSI,Up Wt 190K,Dn Wt 150K,RT Wt 155K,60 RPM,2-8K TqMax Gas @ 620 Units,18 BPH Losses while circulating. Tag solid @ 6,498',Circulate well clean at 10 BPM/650 PSI,16 BPH Loss Rate.Build Calcium Carbonate Pill while circulating.POOH from 6,465'to 5,931'. RU Cement line and head pin.Pump 110 BBLS LCM,chase with 74 bbls Brine.R/D CMT Line.TOH above pill to 4,415'(40'above pill),Circulate drill string volume.(90 bbls),Monitor static losses for 30 Min.with 16 BPH at start.13 BPH @ 15 Min.8 BPH @ 30 min.Attempt to CBU,losses increased to 19 BPH while circulating.POOH above top perfs to 4,131'.Monitor well and mix 40 BBLS Calcium Carb LCM Pill.Losses @ 7 BPM before pumping pill.Pump 40 bbls LCM pill and chase with 60 bbls Brine.R/D CMT Line. POOH from 4,131'to 3,374'- pump additional 9.5 bbls to clear DP. RD circ equip-blow down.Monitor well for 15 mins-static loss 13.5 bph. POOH with BHA#3. LD BHA#3- empty boot basket-recovered 134 lbs of sand. RU E-line. RIH with 8.5 GR/Junk basket-work thru tight spot at 4,484'unable to work thru tight spot-600#over pull at 100 fpm-400#over pull at 80 fpm-7 bph loss(clean/scrub/organize rig).POOH to inspect tools-pulling^'100 lbs heavy- stop at^'250'from surface.PU lubricator-wire line had a birds net in the bottom of lub-strip wire out of hole-no marks on GR.Clean rig floor of wire.Re-head cable. Prep to log well-6 bph fluid loss. Today 3%Brine fluid loss to well 4bbls-Total 3%Brine fluid loss to well 729 bbls-Today SSP loss to well 36 bbls-Total SSP loss to well 36 bbls- Today LCM pills loss to well 150 bbls-Total LCM loss to well-Today Ditch Magnet Metal recovery 202 lbs-Today boot basket metal recovery 0 lbs-Total metal recovered from well 568 lbs. 01/09/14-Thursday RIH with Gamma Ray/CCL to 6,310'WLM. Log up from 6,310'to 1,050'.POOH to surface.Rig down E-Line.Clean and housekeeping.P/U 9-5/8"EZ Drill SVB Squeeze Packer.TIH on 5"Drill Pipe from derrick to 6,165'.Single in hole from 6,165'to 6,483'.Set EZ Drill Bridge Plug. Tag top of Plug with 10 K down.POOH with Mechanical setting tool.MU 3 ea DC-RTTS-1 ea std DP RIH set at"90'.Test RTTS 1500 psi/15 mins. Pull wear ring.PJSM-ND BOPE to change out well head spools-install PU slings-remove bell nipple-table-flow box flange-mouse hole-breaking well head bolts.PJSM-continue ND BOPE-bleed down Koomey-HO cranes-remove turnbuckles-lift stack and secure-pull riser to cellar and remove spool- pull riser to floor and LD-Spot old spool for removal via crane-dress up casing head.Prep cellar and new multi spool for installation.PJSM-Install spool make u tIo pec-test to 2500 psi/15 min. PJSM-NU riser to spool-NU BOPE to riser-install casing vlvs on spool-install turnbuckles-drip pan-bell nipple-air boots-charge Koomey. Today 3%Brine fluid loss to well 129 bbls-Total 3%Brine fluid loss to well 1334 bbls-Today SSP loss to well 36 bbls-Total SSP loss to well 36 bbls-Total LCM loss to well-Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. 01/10/14-Friday Continue to NU BOP after installing Multibowl Wellhead.Shell Test BOP/Wellhead Breaks to 250/2000 psi against RTTS.TIH,release,retrieve and L/D RTTS.Stand back 9 DC's.PU 7-5/8"landing jt.Land 7-5/8"HGR Mandrel and Pack off.Install Wear Bushing. RU 3-1/2"tubing handling equipment. TIH with 3.5 Kill string from Derrick.POOH Laving down 3-1/2"Kill String.Pull wear ring-4.5 bph loss.Change over to 2-7/8"handling equipment. PJSM-PU and TIH with 2-7/8"completion tbg with collar on bottom, for kill string from surface to 2,153'. PU land hanger.RILDS-RD tubing running equip-clear rig floor. PJSM-ND BOPE.RU slings-de-energize Koomey-pull mousehole-flow riser. PJSM-ND BOPE-remove drip pan-air boot flange- ND stack move/secure-pull and LD riser.NU dry hole tree-pull BPV-set TWC-test pack off 5000 psi/15 mins-test tree valve 2000 psi 15 mins- good-pull TWC. Waiting on casing. • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-11 50-733-20214-00 170-024 1/2/2014 1/23/2014 Daily Operations: 01/11/14-Saturday Waiting on casing. 01/12/14-Sunday Waiting on casing. 01/13/14-Monday Waiting on casing. 01/14/14-Tuesday Waiting on casing. 01/15/14-Wednesday Rig up and circ down landing jt taking returns off annulus back to pits.Took 38 bbls before we got returns back to pits and the first bbl was crude oil. Circ bottoms up at tail of kill string at 2,156'.Monitor well w/hole taking 10 BPH.Pull landing jt and set BPV.RU to test BOPs.Test all BOP equip to _ 250 psi low and 2000 psi high.Test both on 5"and 2-7/8".Witness of test was waived by Jim Regg,AOGCC.Rig down test equip.Pull test joint. Retrieve 2 way check valve.Rig down test joint.PU/MU landing joint and RIH. Screw into hanger/back out hold down pins.Pull hanger loose.PU+/- 5'.Fill hole-7 bbls to fill hole.Pull hanger to floor/break out hanger/lay down same. Pull 2-7/8"tubing and rack back.PU landing joint to pull 7-5/8" hanger.Pull hanger.Lay down hanger and landing joint.Prepare to run 5"drill pipe.RIH w/5"drill pipe to 4,262'. Today 3%Brine fluid loss to well 130 bbls-Total 3%Brine fluid loss to well 1548 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 36 bbls-Total LCM loss to well 150 bbls- Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. 01/16/14-Thursday Rig up to pump calcium carb pill and monitor well.Hole taking 6 BPH.Pump and spot 40 bbl calcium carb pill with 20 bbls outside pipe and 20 bbls in DP.Shut in and squeeze 10 bbls with a final pressure of 360 psi.Pressure bled back to 14 psi in 5 min.Open well and monitor losses.The losses went up to 10 BPH.RIH to top of BP at 6,480'and rig up to circ.Monitor well for losses.Hole taking 7 BPH.Pump 75 bbls to move calcium carb pill up hole around perfs and monitor well.Hole taking 7 BPH.Pump 50 bbls to move pill up hole and monitor well.Hole taking 8 BPH.Pump 87 bbl size salt pill, chase with 90 bbls 8.6 KCL,and 35 bbls 10 ppg KCL and 10 more bbls 8.6 ppg KCL.Shut down and monitor well.[This places the size salt pill 100' above and covering all the perfs].Monitor the well and the 1st hr the well took 6 BPH.Next 1/2 hr it still was at 6 BPH. Pump another 30 bbls to bring size salt back up hole past perfs.POOH to 4,000'.Static losses at 6 bph.Spot 40 bbls salt pill.Rig down surface equip.Static losses 8 bph.POOH w/5"Drill pipe. Break out BHA.Pull wear bushing.Drain stack.Bleed down Koomey.Change upper rams to 7-5/8". Test 7-5/8"rams. Rams not testing.Pull test joint multiple times.Change 0-rings.Still no test.Drain stack.Close blind rams.Open doors and inspect 7-5/8"rams.Today 3%Brine fluid loss to well 130 bbls-Total 3%Brine fluid loss to well 1548 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 36 bbls-Total LCM loss to well 150 bbls-Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. • Hilcorp Alaska, LLC Elileorp Alaska,LU Well Operations Summary Well Name API Number _Well Permit Number Start Date End Date A-11 50-733-20214-00 170-024 1/2/2014 1/23/2014 Daily Operations: 01/17/14-Friday Inspect 7-5/8"rams.Order new rams.Put 5"rams back in stack and test to 250 psi low and 2000 psi high.MU 8-1/2"bit and RIH to BP at 6,480'.Fill pipe and pump 176 bbls and started getting size salt returns.Shut down.Monitor hole.Hole taking 10 BPH in first hr.Pump another 116 bbls to move more of the pill to the upper hole section.Monitor well.Hole taking 7.3 BPH.Circ 147 bbls to get everything balanced out.Monitor well while blowing down and setting back Kelly.Hole taking 7 BPH.POOH.Break and lay down bit.Break out bit.Monitor well.6 BPH losses. RIH 3 stands of drill collars. Make up RTTS and circulating sub. RIH with 5"drill pipe to 948'.Set RTTS and test casing to 500 psi. Good test.RIH to 1,326'.Set RTTS.Test casing to 500 psi.Good test.RIH to 2,084'-test casing to 500 psi.Good test.RIH to 3,031'.Hole circulating when we attempted to test.Pulled 1 std and tested casing to 500 psi.Test good. RIH to 3,032'.Did not get a test.Picked up a single.Annulus tested to 500 psi.RIH to 3,032'.Annulus tested to 500 psi. Continued to RIH testing each stand.RIH to 4,073'.All test good to 500 psi.RIH to 4,073'. Monitor well for loss rate.6 BPH losses.RIH and set RTTS at 5,305'.RTTS hung up at 3,335'and 3,460'.Today 3%Brine fluid loss to well 202 bbls-Total 3%Brine fluid loss to well 1942 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 125 bbls-Total LCM loss to well 190 bbls-Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. 01/18/14-Saturday Set RTTS at 5,305'between C&D perf zones.Pressure up on back side to 200 psi.Pressure bled right off.Pressure up dn DP to 200 psi and had a slight bleed off.Open bypass and spot 38 bbl 9.6 ppg LCM pill on back side.Close bypass.Monitor well with a loss rate of 2.5 BPH for 1st hr.Next 1/2 hr well lost 2.4 BPH.Squeeze 5 bbls in 1 bbl increments w/a high pressure of 200 psi.Open bypass so pill will settle.Monitor well w/losses at 6 BPH. Squeeze 10 bbls in 2 bbl increments with a final pressure of 283 psi.Pump and spot 40 bbl 9.6 ppg LCM pill in annulus with 10 ppb barafibre and steal seal 400.Monitor well 1st hr 2.6 BPH static loss.Then it went to 1.5 BPH.Open Bypass and release RTTS.Blow dn circ lines.POOH slow to top of perfs making sure not to string out remaining LCM pill.Continue POOH to RTTS.Lay dn RTTS and stand back 6-1/2"DCs.Change upper pipe rams to 7-5/8". Test rams 250 psi low/2000 psi high for 5 minutes.Good test.Rig down test equipment.Rig up Weatherford.JSA for running 7-5/8"casing. RIH w/7- 5/8"casing.Today 3%Brine fluid loss to well 105 bbls-Total 3%Brine fluid loss to well 2047 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 125 bbls-Total LCM loss to well 268 bbls-Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. 01/19/14-Sunday Running 7-5/8"SLIJ-II csg slow to 5,580'.Pipe displacing right amount of KCL.Continue running 7-5/8"csg t/6,435'and tag fill from LCM pills. MU XO and PU 10'pup and Kelly.Wash fill from 6,435'to 6,484'as per csg strap.Circ hole clean.Ended up getting back about 3.5 bbls of LCM material.Break out Kelly,pup and XO.Blow dn Kelly and set it back.PU hanger and landing jt. MU and land out csg.RU circ head.Circ with rig pump at 3 BPM while rigging up and mixing Mud Push.Rig up cement head and lines.JSA for cement job.Pressure test surface lines to 3500 psi.Pump 35 bbls mud push. Drop plug.Begin pumping cement job.Pump 130 bbls of 11 ppg cement at 4 bpm/100 psi.Drop second plug,Pump 5 bbls fresh water. Pump 210 _bbls 8.6 ppg KCL at 5 bpm/300 psi. Reduce pump rate to 3 bpm. 220 bbls pumped/3 bpm @ 600 psi. 230 bbls pumped/3 bpm @ 800 psi.240 bbls pumped/3 bpm @ 900 psi.250 bbls pumped/3 bpm @ 1000 psi 260 bbls pumped/3 bpm @ 1100 psi. 270 bbls pumped/3 bpm @ 1150 psi. 280 bbls pumped/reduced rate to 2 bpm/1100 psi.Pumped 10 bbls at 2 bpm @ 1100 psi. Shut down pump.Pressure bled off.Final circulation psi/rate-2 bpm/1100 psi.Got back 35 bbls mud push and 10 bbls cmt. 295 bbls total displacement pumped.Did not bump plugs.Check flow back.Hole flowing back.Shut in cement manifold.Wait on cement.Rig down.Check flow back.Hole still flowing back.375 psi on hole.Shut in.Wait on cement.Today 3%Brine fluid loss to well 110 bbls-Total 3%Brine fluid loss to well 2157 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 125 bbls-Total LCM loss to well 268 bbls-Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. Hilcorp Alaska, LLC II'Hemp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-11 50-733-20214-00 170-024 1/2/2014 1/23/2014 Daily Operations: 01/20/14-Monday Open valve on head and bleed 1/4 bbl to trip tank.Remove cmt head and pull landing jt.Install pack off running tool and run pack off.Test to 250 low and 2500 psi high for 10 min.Change upper rams from 7-5/8"to 2-7/8"X 5"VBRs.MU 4"test jt and test upper rams.Test rams to 250 low and 2000 psi high.RD test jt and set wear ring.PU 6-5/8"mill and 7-5/8"csg scraper.Scraper would not go into csg.Lay down scraper.RIH with 6-5/8"mill/Bit sub w/float/bumper sub/jars/3 stands 4 3/4 drill collars and 4"drill pipe(picking up singles off the deck.)Tag @ 6,348'.Lay down 2 singles.Rig up Kelly. Wash down to 6,340'.Shakers plugging off.Shut down.Clean shakers.Pick up single 196 to 6,350'.Hard drilling.Sitting on plug.Milled through plug.Drilled to 6,372.Pick up single 197.Drill/wash to 6,404'. 5 bpm/60 rpm/390 psi/5k down/negligible torque,pick up single 198.Drill wash down to 6,432'.5 bpm/60 rpm/390 psi/5k down/negligible torque,Circulate hole clean.Prepare to swap hole over to clean fluid. Today 3%Brine fluid loss to well 0 bbls-Total 3%Brine fluid loss to well 2157 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 125 bbls-Total LCM loss to well 268 bbls-Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. 01/21/14-Tuesday Displace well with clean 3%KCL.Blow down Kelly and POOH.Rig up to run wireline.RIH.Run USIT log.Test casing 2500 psi f/30 min-Charted.Prepare lit5) to run TCP.Stage baskets on pipe rack. JSA for picking up and running TCP guns.Pick up and RIH w/TCP guns.Today 3%Brine fluid loss to well 0 bbls- Loj Total 3%Brine fluid loss to well 2157 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 125 bbls-Total LCM loss to well 268 bbls-Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. 01/22/14-Wednesday Cont.to run 4-1/2"6 SPF Perf Guns(123 guns total). MU Firehead PKR Assy as follows:Safety Impact Mechanical Firing Device,Tubing Joint 2-7/8" 6.5#,Ported Flow Sub w/debris barrier,Pup Joint,2-7/8",'X'Nipple 2.313 profile,Pup Joint,2-7/8",Seal Bore Box X 2-7/8"eue 8rd Box tubing Adapter,Seal Bore Extension w/3.25"ID,Combo Coupling,7-5/8"Simtop Perm Packer,Tie Back Sleeve w/5"ID,RA Sub XO to HT 38. TIH with Guns/PKR Assy on 4"drill pipe from derrick to 2,098'PKR Depth(DPM)and 6,066'Bottom Shot Depth(DPM).RU Schlumberger,Log,correlate and place Guns on depth.RA tag @ 1,995',Top shot @ 2,170',Bottom Shot @ 6,062'. Verify depths with Project Engineer. POOH with E-Line.R/D E-Line.RU TIW and circulating manifold to drill string.Drop Ball(1-5/8")Pressure up on tubing with good indication of packer setting.Packer started to set @ 2200 psi.Walk PSI up to 3200 psi before stabilizing.Held 3200 psi for 5 min. Pressure Test top of packer to 700 psi for 5 min.Test good.R/D Circulating equipment.Release running tool from Tie Back Sleeve.POOH standing back 4"drill pipe.Lay down PKR Running tool and RA Sub. Drain Stack and pull wear bushing.RU to run 2-7/8"completion:JSA f/running completion. RIH w/Completion.pick up and install safety valve.Test valve.RIH,Tag packer.Space out. Make up hanger. Terminate control lines.RIH and land hanger.Run in Hold down pins.Test packer to 1500 psi for 30 minutes.Good test.Bleed off.Blow down lines.Break out landing joint.Prepare to nipple down.Jim Regg with AOGCC waived witness of BOP test on 1/22/14 @ 09:38 hrs. Mr.Regg also gave extension of BOP test due to being so close to end of well.Today 3%Brine fluid loss to well 0 bbls-Total 3%Brine fluid loss to well 2157 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 125 bbls-Total LCM loss to well 268 bbls-Total Ditch Magnet Metal recovery 300 lbs-Total boot basket metal recovery 268 lbs-Total metal recovered from well 568 lbs. 01/23/14-Thursday Lay down landing joint.Set BPV.N/D BOP.Remove and lay down Drilling Riser.Land and NU Tree.Test Tbg Head Adapter to 250/2500 Psi Test Good. Pull BPV Set TWC and test Tree to 5000 psi.Test Good.Pull TWC. Install Bowen adapter tree cap.Make up Slick Line Lubricator from Tree to Floor. Rig up test pump and PT Lubricator to 2000 psi.Test Good.PJSM. Drop EXPRO 1"OD Bar and fire guns.Good indication of detonation @ 1 min 28 sec.Tubing on a vac and balanced out after 15 Min.0 Tubing Pressure after 30 min.RU Slick Line.Pull Dummy valves and set live valves in Chemical Inj Mandrel and GLM.R/D Slick Line.Turn Well over to Production.Tubing pressure @ 150 PSI. Regg, James B (DOA) From: Marvin Rogers - (C) [mrogers@hilcorp.com] Sent: Monday, January 20, 2014 5:59 PM To: DOA AOGCC Prudhoe Bay Cc: Ted Kramer; Pete Solomon - (C); James Lott - (C) Subject: Monopod A-11 Csg & Cmt Report Attachments: A-11 7.625 csg and Cmt report.xlsx Ul-lilcorp Alaska, LLC Marvin Rogers DSM NNev Monopod Platform [907] 776-6675 E -Mail: mrogers@hilcorp.com a Lease & Well No. County TD Hilcorp Energy Company CASING & CEMENTING REPORT CP -ib ►ZDO z�w� A-11 Trading Bay Unit Date 20 -Jan -14 Kenai Peninsula Burough State Alaska Supv. Marvin Rogers/Pete Solomon CASING RECORD 6480.00 Shoe Depth: 6475.67 PBTD: MD Csg Wt. On Hook: 183,280 Type Float Collar: Float No. Hrs to Run: 18 Csg Wt. On Slips: 0 Type of Shoe: DJ/Float Casing Crew: Wfd Fluid Description: 8.6 ppg / 3% KCL Liner hanger Info (Make/Model): Liner top Packer?: Yes x No Liner hanger test pressure: Centralizer Placement: NA CEMENTING REPORT Preflush (Spacer) Casing (Or Liner) Detail Setting Depths No. of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 75/8 Volume pumped (BBLs) SLIJ-II Ray Oil Tool 2.15 6,475.67 6,473.52 1 75/8 L-80 SLIJ-II VAM 38.19 6,473.52 6,435.33 F. Collar 75/8 Post Flush (Spacer) SLIJ-II Ray Oil Tool 2.08 6,435.33 6,433.25 145 its 75/8 L-80 SLIJ-II VAM 6,389.55 6,433.25 43.70 XO pup 75/8 L-80 SLIJ-II 5 bpm Volume (actual / calculated): 295 bbls / 295 bbls 1.90 43.70 41.80 Hanger Casing Rotated? Yes Butt Yes x No % Returns during job 100 1.35 41.80 40.45 RKB Cement In Place At: 0:15 Date: 1/20/2014 Estimated TOC: 40 40.45 40.45 0.00 Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Totals Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Csg Wt. On Hook: 183,280 Type Float Collar: Float No. Hrs to Run: 18 Csg Wt. On Slips: 0 Type of Shoe: DJ/Float Casing Crew: Wfd Fluid Description: 8.6 ppg / 3% KCL Liner hanger Info (Make/Model): Liner top Packer?: Yes x No Liner hanger test pressure: Centralizer Placement: NA CEMENTING REPORT WtLLHI=AU Make Seaboard Type SMB -22 Serial No. Test Head To 2500 PSIG 10 MIN X Remarks: H240248 Size 11" W.P. 5000 OK Preflush (Spacer) Type: Mud Push II Density (ppg) 10.7 Volume pumped (BBLs) 35 BBLS Lead Slurry Type: LiteCRETE Density (ppg) 11 ppg Volume pumped (BBLs) 130 ✓ Mixing / Pumping Rate (bpm): 5 bpm Tail Slurry Type: (uJ Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): U Post Flush (Spacer) � Type: Density (ppg) Rate (bpm): Volume: FL Displacement: Type: 3% KCL Density (ppg) 8.6 ppg Rate (bpm): 5 bpm Volume (actual / calculated): 295 bbls / 295 bbls FCP (psi): 1100 Pump used for disp: Schlumberger Plug Bumped? Yes X No Bump press 1100 Casing Rotated? Yes X No Reciprocated? Yes x No % Returns during job 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 10 bbls Cement In Place At: 0:15 Date: 1/20/2014 Estimated TOC: 40 Method Used To Determine TOC: Took returns from annulas valve when we started getting mud push back Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type: w Density (ppg) Volume pumped (BBLs) Mixing i Pumping Rate (bpm): Post Flush (Spacer) 0 0 z Type: Density (ppg) Rate (bpm): Volume: LuDisplacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No % Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: WtLLHI=AU Make Seaboard Type SMB -22 Serial No. Test Head To 2500 PSIG 10 MIN X Remarks: H240248 Size 11" W.P. 5000 OK Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, January 10, 2014 12:10 PM To: 'Ted Kramer'; Ferguson, Victoria L (DOA) Cc: Juanita Lovett Subject: RE: Monopod A-11 Well Plan - Forward, Sundry # 313-571/ #314-001 PTD# 170-024 Ted, Thanks for update. You have approval to run kill string and move off well.... set BPV and secure well. It appears you will be back on the well very soon... <30 days so don't submit a 10-404 yet. If the well work is delayed for more than 30 days then contact me and we will figure out a plan. You don't need to submit a new sundry... just continue on with 314- 001. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office KA"Im From: Ted Kramer [ -iiltoakramerCcO c ] Sent: Friday, January 10, 2014 10:22 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Juanita Lovett Subject: Monopod A-11 Well Plan - Forward, Sundry # 313-571/ #314-001 PTD# 170-024 Guy and Victoria, I wanted to take the time to communicate with the AOGCC what work has been completed on the above well to date and advise the Commission of a work delay that will occur starting this weekend on the above well. Under Sundry #313-571 we have completed the work down through Step # 8. A slight variance was encountered during the cleanout. The plug back TD (PBTD) on this well should have been at 6,440'. However, no bottom plug was found at this depth. If you notice on the bottom of the Well Schematic there is a note concerning a radioactive source that was lost in this well at 6693' and that well should not be deepened below 6,500'. Since we did not find a hard bottom at 6,440, we wanted to ensure that there was a cap over this source. We continued in the hole until we tagged up hard at 6,498'. From there we pulled out of the well and picked up a bridge plug and RIH and set it at 6,483' DPM. This will give us a hard bottom for when we run in with the 7-5/8" Casing String. This will also slightly change the set depth of our 7-5/8" casing shoe downward to 6.480' (+/-). We have now switched form Sundry #313-571 to Sundry # 314-001. The issue we have now is that our 7-5/8" 29.7# casing has not arrived yet. This is mainly because we are ahead of schedule on the well. The casing left Tacoma yesterday on the weekly steamship headed to Anchorage. It is scheduled to arrive in Anchorage on the 14th of January (this Tuesday). Although slightly out of sequence, we have completed the following work on the well to progress as far as we can with the workover: Step 12 RU E -line. RIH With uamma Ray and CCL to 6,150'. Log out of hu.,.: running Gamma Ray and CCL up to 1,085'. RD E -line (We ran the log so that the proper adjustments could be made for loading the TCP guns). Step 9 A). Set RTTS at 90 ft and tested to 1,500 psi. Step 9 B). RD BOP, Installed new casing spool and multi -bowel wellhead. Step 9 Q. RU BOP, Shell tested to 2,000 psi. Plan Forward The plan forward for this well is that we would like to pick up our 2-7/8" production string (2,100 ft +/-)and run it in the well as a kill string. We will then RD off of the well so we can skid the rig to other wells while we are waiting. This movement with the rig is so we can production log 5 wells that we worked on previously and one injector (A -18, A-3RD3, A-7, A-16RD, A-32, and A-29RDinj). Hilcorp needs these logs in order to book reserves so this is an opportune time to get them while we are waiting on pipe. When the pipe arrives, if we are not finished logging, we will make the decision at that time to immediately move back to the A-11 and finish, or to complete logging the wells prior to moving back to A-11. We never want to stop work on a well to wait on equipment. We currently have very good momentum going but, completing these logs seems to be the best use of the downtime. Please let me know what paperwork we need to submit in order to move in this direction. Please call me if you need any further clarification on these plans. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Friday, January 10, 2014 10:22 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Juanita Lovett Subject: Monopod A-11 Well Plan - Forward, Sundry # 313-571/ #314-001 PTD# 170-024 Guy and Victoria, I wanted to take the time to communicate with the AOGCC what work has been completed on the above well to date and advise the Commission of a work delay that will occur starting this weekend on the above well. Under Sundry #313-571 we have completed the work down through Step # 8. A slight variance was encountered during the cleanout. The plug back TD (PBTD) on this well should have been at 6,440'. However, no bottom plug was found at this depth. If you notice on the bottom of the Well Schematic there is a note concerning a radioactive source that was lost in this well at 6693' and that well should not be deepened below 6,500'. Since we did not find a hard bottom at 6_,440, we wanted to ensure that there was a cap over this source. We continued in the hole until we tagged up hard at 6,498'. From there we pulled out of the well and picked up a bridge plug and RIH and set it at 6,483' DPM. This will give us a hard bottom for when we run in with the 7-5/8" Casing String. This will also slightly'Efia g he set depth of our 7-5/8" casing shoe downward to 6.480' (+/-). We have now switched form Sundry #313-571 to Sundry # 314-001. & L (__ The issue we have now is that our 7-5/8" 29.7# casing has not arrived yet. This is mainly because we are ahead of schedule on the well. The casing left Tacoma yesterday on the weekly steamship headed to Anchorage. It is scheduled to arrive in Anchorage on the 14th of January (this Tuesday). Although slightly out of sequence, we have completed the following work on the well to progress as far as we can with the workover: Step 12 RU E -line. RIH With Gamma Ray and CCL to 6,150'. Log out of hole running Gamma Ray and CCL up to 1,085'. RD E -line (We ran the log so that the proper adjustments could be made for loading the TCP guns). Step 9 A). Set RTTS at 90 ft and tested to 1,500 psi. Step 9 B). RD BOP, Installed new casing spool and multi -bowel wellhead. Step 9 Q. RU BOP, Shell tested to 2,000 psi. Plan Forward The plan forward for this well is that we would like to pick up our 2-7/8" production string (2,100 ft +/-)and run it in the well as a kill string. We will then RD off of the well so we can skid the rig to other wells while we are waiting. This movement with the rig is so we can production log 5 wells that we worked on previously and one injector (A -18, A-3RD3, A-7, A-16RD, A-32, and A-29RDinj). Hilcorp needs these logs in order to book reserves so this is an opportune time to get them while we are waiting on pipe. When the pipe arrives, if we are not finished logging, we will make the decision at that time to immediately move back to the A-11 and finish, or to complete logging the wells prior to moving back to A-11. We never want to stop work on a we,, co wait on equipment. We currently have very good momentum going but, completing these logs seems to be the best use of the downtime. Please let me know what paperwork we need to submit in order to move in this direction. Please call me if you need any further clarification on these plans. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 %cc� Sde ;4 — if PT)6 1700 Z-40 Regg, James B (DOA) From: Marvin Rogers - (C) [mrogers@hilcorp.com] Sent: Tuesday, January 07, 2014 2:50 PM T ff �I %//!I To: Regg, James B (DOA); Ted Kramer; Joe McInnis - (C) Cc: DOA AOGCC Prudhoe Bay Subject: RE: Circ out gas I know this is late but here is the information I didn't give you on the initial notice. -1/6/2014, 1100 hrs, Upper 2 7/8 X 5" var rams -A-11, Monopod Platform, PTD 1700240 ,l� -Rig 56 -Hilcorp Alaska, Marvin Rogers -Had milled over a model D packer at 4112' and chased it to 4133'. Circulated hole clean. Continued chasing it to 5767'. Kelly up and circ pushing it down to 5795. Started to get a gain in flow so we picked up and the well was flowing. Shut upper rams and circulated the gas bubble out through the choke manifold and poorboy degasser, until we got good weighted fluid back. -We used the upper rams on 5" DP and the flothe pnnrhny degasser. -We used the BOP to shut the well in and divert the gas away from the rig. -BOPS were tested when we came out of the hole on 1/6/2014 and our complete BOP test was also finished on 1/6/2014. Thank you! I will make sure we get all the right information in in the future. Hilcorp Alaska, LLC Marvin Rogers DSM Monopod Platform [907] 776-6675 E -Mail: mrogers@hilcorp.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, January 07, 2014 1:02 PM To: Marvin Rogers - (C); Ted Kramer; Joe McInnis - (C) Cc: DOA AOGCC Prudhoe Bay Subject: RE: Circ out gas We don't have a specific form for the notification when ROPE used to prevent the flow of fluids from a well but there is required information in the notice. Attached is our guidance document. Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 1 From: Marvin Rogers - (C) [mailto:mrogersC�hilcorp.com] Sent: Monday, January 06, 2014 2:21 PM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Ted Kramer; Joe McInnis - (C) Subject: Circ out gas We are in the hole chasing a packer down until it tagged fill. The packer tagged up at 5767. We picked up our Kelly and washed down to 5797'. At that point we started to get a flowline increase so we picked up and shut the well in with the upper rams. We ended up circ a gas bubble out and now we are opened back up and circ normal. This is to notify you we will be testing the Upper rams and choke line valves when we get out of the hole. Thank You Hilcorp Alaska, LLC Marvin Rogers DSM Monopod Platform [907] 776-6675 E -Mail: mrogers@hilcorp.com ico � �jysTHE STATE Alaska Oil and Gas 14 °f ALAS ^- c nservati®n Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue *4' ALAS�� Anchorage, Alaska 99501-3572 Main: 907.279.1433 .OlkFax: 907.276.7542 S NEn Ted Kramer Sr. Operations Engineer I '7 0 - Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C & Middle Kenai D Oil Pools, Trading Bay St A-11 Sundry Number: 314-001 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. ) oerst r Chair DATED this day of January, 2014. End, 441.3( RECEIVED STATE OF ALASKA ��� JAN 0 2 20'k ALASKA OIL AND GAS CONSERVATION COMMISSION a S ii 6) brk APPLICATION FOR SUNDRY APPROVALS /\000C i 20 AAC 25280 1.Type of Request: Abandon CI Plug for Redrill❑ Perforate New Pod 0- Repair Well CI Change Approved Program Suspend❑ Plug Perforations El Perforate 0 . Pull Tubing 0 - coo`I ff' Time Extension❑ Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing❑ Other. Add 75/8"casing liner ' 0 2.Operator Name: 4.Current Well Class: 5.Permit to Dl ii Number: Hilcorp Alaska,LLC . Exploratory 0 Development 0` 170-024 - 3.Address: 3800 Centerpoint Drive,Suite 100Stratigraphic El Service CI6.API Number. Anchorage,AK 99503 50-733-20214-00 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? CO 938 / Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay St/A-11 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 . Trading Bay Field/Middle Kenai C &Middle Kenai D Oil Pools 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): 10,180 . 9,927 - 5,915 . 5,773 - 6,693 6,404 • Casing Length Size MD ND Burst Collapse Structural Conductor 228' 20" 228' 228' 2,410 psi 770 psi Surface 1,085' 13-3/8" 1,085' 1,045' 3,090 psi 1,540 psi 1 Intermediate Production 7,092' 9-5/8" 7,092' 6,942' 6,330 psi 3,810 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.3#/N-80 3,145 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Model D Pkr&SSSV:N/A . 4,110'(MD)3,976'(ND)and SSSV:N/A 12.Attachments: Description Summary of Proposal 0 ' 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 • Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/3/2014 Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramerOhilcoro.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature �� ?��'� -• Phone (907)777-8420 Date 1/2/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test L!S Mechanical Integrity Test 0 Location Clearance ❑ Other Z000 / $c- j30r 77-5i-- S'i-- �. RBDMS AY o 9 2014 C13 re-5 II Spacing Exception Required? Yes ❑ No [ii/ Subsequent Form Required: 40,S0Lf �� APPROVED BY ' / Approved by: ( 74,,„(„44.2,---__ `-f' COMMISSIONER THE COMMISSION Date: /— 6 —/ .,'/.d 1 fzI tot 1-3•11 n D I.1 I.A L.A 1-- - Submit Form and • II Well Prognosis Well: A-11 Hilcory Alaska,LL Date:01/02/2014 Well Name: Monopod A-11 API Number: 50-733-20214-00 Current Status: SI oil producer(Gas Lifted) Leg: N/A Estimated Start Date: January 3, 2014 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 77. 7-8332 Permit to Drill Number: 170-024 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: 1,958 psi @ 5,890' MD (5,749' TVD) From 4/16/2007 Shut-in Bottom Hole Pressure Survey(=0.341 psi/ft. grad.) Maximum Expected BHP: 1,958 psi @ 5,890' MD (5,749'TVD) Max.Anticipated Surface Pressure: —Opsi (1,958 psi-(5,749' TVD X .341 psi/ft.)) Brief Well Summary The A-11 well was drilled and completed as a gas lifted D zone oil well in 1970. Two workovers occurred over time,C zone was added in 1973 and a re-pert of the C and D zones was completed in 1988. The A-11 well developed a casing leak in 2007 which led to pressure communication on the 13-3/8"X 9-5/8" annulus and the 13-3/8"X 20"annulus. To remediate this leak,two sets of perforations(904-914'and 891— 901')were shot in 2007. Circulation was established through the perfs and up the 9-5/8"X 13-3/8"annulus. The perfs and backside were then squeezed with 75 bbls. of cement. The 9-5/8"casing was then pressure tested to 1,000 psi. The 2014 workover plan entails pulling the production tubing,drilling up a cement retainer at 4,000', and milling up the Baker Model D packer at 4,110'. The well will then be cleaned out to 6,440(PBTD). A 7-5/8" '' tieback liner will then be ran and from PBTD of 6,440'to surface and cemented in place. The B Zone will be added and the C,and D zones re-perforated./The well will then be returned to gas lift. Brief Procedure: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3. ND Wellhead, NU BOP and test to 250 psi low/2,000 psi high.(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). tA, 4. Unseat tbg. hanger and pull out of well with 99 joints of 3-1/2 tubing. 9aQ�.4 t 5. PU 8-1/2"bit on WS. RIH to 4,000 ft and drill up fast drill cement retainer. C/O to top of packer J`�' at 4,110'. POOH with Bit. J 6. PU RIH with Mill Shoe. RIH to 4,110'and Mill over Baker Model D Packer. POOH with Shoe. 7. PU Spear and and RIH with Spear and Remove Packer. it 8. PU 9-5/8'Cleanout assembly. RIH Cleaning out 9-5/8"Casing to 6,440'(PBTD). Circ Hole clean. Pooh with Work String and C/O assembly. 9. PU RIH with 7-5/8"29.7#SLIJ-II Casing String With Float Shoe and Float Collar in place to 6,440'. u. S Rtes' :1A / /6 �. j /frA� a r c . pc( Par - / e s f- -lam L� /° s z- C. L r e-4-4-s) ._P-_ /d/1.. • s , x .���_ ??$gvAlell Prognosis Well: A-11 Hilcorp Alaska,LL Date:01/02/2014 10. RU Cementing Company and cement 7-5/8"casing in lace according to Cementing procedure. WOC. 'j 1'S t e, boo, NA'(. 11. PU 7-5/8"C/O assembly. RIH to tag Cement,C/O cement to 6,150'. Circ Hole Clean. POOH With WS. 12. RU E-line. RIH With Gamma Ray Ind CCL to 6,150'. Logo of hole rpnningamma Ray and CCL / up to 1,085'. RD E-line. — C 6 L w� 7 o G. . �(�-�-- 13. Pressure the 7-5/8"casing on a chart recorder to1,60015si for 30 minutes. .T-w 1 rA tb f So° 14. PU RIH with TCP guns(according to the Final Approteg Perforation Request Form)hanging them off of the bottom of a hydraulically set permanent packer . 15. RU RIH with E-line,Log TCP Guns and Packer on depth. RIH with plug and Set packer. RD E-line. 16. Pick up production tubing with seal bore assembly,chemical injection mandrel,GLM,and SSSV. RIH stabbing seal bore into permanent packer. Pressure test packer and completion tubing on backside. Chart same. 17. Pressure up drop bar and fire guns. 18. ND BOP,NU wellhead and test. 19. NU Slickline. RIH pulling dummy valves in the chemical injection mandrel and the GLM. Replace with live valves. 20. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing Trading Bay Unit • • n SCHEMATIC Well #A-11 Completion Date: 5/3/2007 RKB to TBG Hngr=41.50' CASING AND TUBING DETAIL 220J Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate hrs ,. t`, 20" ''/:"Wall H40(risked) Weld Surf 228' 1750 20.5 ' 13-3/8" 618 J-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 TOCe 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs ,',r1 0' •,, :965' -'2908'91!' Stage Collar 3622.8' 6330 1250 sxs See below 373 1. :^` 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs "• .; TUBING v. + 3-1/2" 9.3 N-80 8rd 2.992 Surf 3145' 10570 1085' ^"bi 1122' JEWELRY DETAIL 9-5/8"Cement Job tea'„s0'1158' NO. Depth ID Item 1160 2700 Fair/Poor(USIT) 1190' 3145' 2.99 Half MS 2700' 2830' Good cmt(Top of Log) 4000' NA FastDrill Retainer 2830' 3110' Poor cmt 1 4110' 4.75 Baker Model"0"Packer 3100' 3700' Good cmt 3700' 4056' Poor cmt 4056' 4200' Good cmt SA Sand _ Wireline Summary 4200' 5100' Poor cmt 1660'1700' 5100' 7092' Good cmt 2004-2006 Tag fill with 2.25"GR at 5915'RKB 244 sand 2170'2260' PERFORATION DATA Top Btm Top Btm Accum. Date Zone (MD) (MD) (TVD) (TVD) Amt. SPF Last Opr. Present Condition Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT • cmt Sqz Perfs 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/csg bond C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. C-3 4,270' _ 4,340' 4,135' , 4,204' 70' 12 5/4/1998 Open f/prod. C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 • C-5 4,471' 4,476' 4,335' 4,340' 5' 4 4/73 ' C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 r-� 4,000' _ C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. .kStray 4,819' 4,824' 4,681' 4,686' '5' 4 4/73 1 C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 C 49-4 _ 5,056' 5,0611 4,918' 4,923' 5' 4 _ 4/73 C 50-3 5,140' 5,178' 5,002' , 5,040' 38' 8 5/4/1998 Open f/prod. Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 D 53-8 5,600' 5,652' 5,460' - 5,512' 52' 12 5/4/1998 Open f/prod. D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/prod. D 54-9 5,742' 5,769' 5,602' 5,629' 27' 4 5/70 D 55-7 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 =tet_ D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. D D 57-2 5,975' 6,055' 5,834' 5,913' 80' 8 5/4/1998 Open f/prod. Fill at a;- Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/csg bond 5915' Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/csg bond rdifi9, FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. KB ELEV=101' 1988:Has perf debri from Vann Gunns at 6404'. PBTD=6,440' TD=10,180' ANGLE thru INTERVAL=8.5° Updated by: .ILL 10/25/13 .• • Monopod Platform A-11 Current 10/16/2013 Ham,. tInokm.11.11d; Monopod Tubing hanger,CIW-DCB- A-11 FBB,11X4%22EUE lift X4 13 3/8 X 9 5/8 X 3 1/2 EUE susp,w/4"type H BPV, 1/8 non continuous control line,7"extended neck prep BHTA,Bowen, 4 1/16 5M FE .., lir n1 • ^` Valve,WKM-M,4 1/16 5M _,0/,Q FE,HWO,AA y© • I t TM Tubing head,CIW-DCB, 13 5/8 3M X 11 5M,w/2- 1@i ISI Valve,CIW-F,2 1/16 5M FE, 2 1/16 5M SSO,X-bottom , '- : HWO,AA prep I�iZ'r .1 �,#1%2 VR profile L. - III I 5i, Casing head, �, Shaffer KD, 11I ! III 135/83MX 6 13 3/8 SOW,w/2-2" ill Ivn. 101 itr-1.• 2"LP ball valve LPO, l ) �� 4 Iti PROPOSED Trading Bay Unit Well#A-11 Completion Date: Future CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate RKB to TBG Hngr=41.50' _ hrs 1 %"Wall H40 Weld Surf 228' 1750 20.5 2211_ (risked) �. 13-3/8" 618 J-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 7'6 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs )' Iim e Stage Collar 3622.8' 6330 1250 sxs See below 373 ' F 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs ` .. p4.r7�. 7-5/8" 29.7 L-80 SLID-II 6.875 Surf ±6,440' • .� Q TUBING 111745' r 2-7/8" 16.5 I L-80 I 8rd EUE I I Surf I ±2,115' I .74 1122' JEWELRY DETAIL 9-5/8"Cement lob 7750'775r NO. Depth ID Item 1160' 2700' Fair/Poor(USIT) 2700' 2830' Good cmt(Top of Log) 1180• 1 ±300' SSSV -,, 5A Sand 2 ±2,080' Gas Lift Mandrel 2830' 3110' Poor cmt / 7550 1700 3100' 3700' Good cmt • IV 3 ±2,110' Chem- Productl ion Packer nMandrel 4 ±2,120' Production Packer 3700' 4056' Poor cmt 2 4056' 4200' Good cmt 1 IIX_ r5 ±2,128' X Nipple bvl4200' 5100' Poor cmt 6 ±2,134' Ported Sub 0% l+lIIII e 7 ±2,170' TCP Perforating Guns 5100' 7092' Good cmt / . M 244 Sand :170'2250 PERFORATION DATA Top Date I, 11111 Zone (MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Last Opr. Present Condition 1 ' B 24-6 2,170' 2,260' 2,111' 2,195' 90' Future B B 26-7 2,606' 2,655' 2,521' 2,568' 49' Future B 26-7 _ 2,708' 2,770' 2,618' 2,676' 62' Future B 26-7 2,788' 3,106' 2,694' 2,995' 318' Future B 0 11 . Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT cmt Sqz Perfs 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/csg bond !- C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. 11// 16 1. Q, C-2 ±4,197' ±4,233' ±4,062' ±4,098' 36' Future C-3 ±4,270' ±4,340' ±4,135' ±4,204' 70' 12 Future Re-pert ok, ICZN6 ±4,364' ±4,384' ±4,228' ±4,248' 20' Future a,000 C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 b C-5 4,471' 4,476' 4,335' 4,340' 5' 4 4/73 0., 1' C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 1 - 1 C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. y . , C-7 ±4,642' ±4,712' ±4,505' ±4,575' 70' Future i1 C 47-5 ±4,817' ±4,827' ±4,679' ±4,689' 10' Future ''. Stray 4,819' 4,824' 4,681' 4,686' 5' 4 4/73 C 47-5 ±4,846' ±4,870' ±4,708' ±4,732' 24' Future V, I I. _C C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 A ,0 I C 48-5 ±4,932' ±4,948' ±4,794' ±4,810' 16' Future T C 48-7 ±4,954' ±4,976' _ ±4,816' ±4,838' 22' Future C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 i V- C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 E. i C 50-3 ±5,140' ±5,178' ±5,002' ±5,040' 38' 8 Future Re-pert • Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond i D ZN2 ±5,568' ±5,590' _ ±5,428' ±5,450' 22' Future -_ D D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 ' D 53-8 5,600' 5,652' 5,460' 5,512' 52' 12 5/4/1998 Open f/prod. D 53-8 ±5,605' ±5,634' ±5,465' ±5,494' 29' Future ' D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Openf/prod. D 54-5 ±5,670' ±5,708' ±5,530' ±5,568' 38' Future Ill /� �� A` D 54-9 57 6 760' 5,7 5 70' ,62 4 0'S 630' 10' Future KB ELEV=101' D 55-7 , 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 PBTD=6,440' TD=10,180' D 55-7 ±5,802' ±5,828' ±5,662' ±5,688' 26' Future ANGLE thru INTERVAL=8.5" D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. D 56-1 ±5,856' ±5,949' ±5,715' ±5,808' 93' Future D 57-2 5,975' 6,055' _ 5,834' 5,913' 80' 8 5/4/1998 Open f/prod. D 57-2 ±5,975' ±6,062' ±5,834' ±5,920' 87' Future Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/csg bond • Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/csg bond FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. , 1988:Has pert debris from Vann Gunns at 6404'. Updated by DMA 12/31/13 • Monopod Platform A-11 Proposed 1/02/2014 Hilrncp:%baska.1.1.1,, Monopod Platform Tubing hanger,SME-CL,11 X A-11 133/8X95/8X75/8X TypeH EUE iftandsle,2-3usp,w/3" 2 7/8 H BPV profile,2-3/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union Illi i MIAMI iMiiiiMk pm Valve,Swab,WKM-M, ,®,�', . _ 31/8 5M FE,HWO,DD trim A� $ Valve,Wing,WKM-M, ,• ,•, 3 1/8 SM FE,w/15"OMNI operator,DD trim Iil1 II I_ Q :i111111u I an m Valve,Master,WKM-M, 0 3 1/8 SM FE,HWO,DD trim o 0 0 0 ui�, it in 101 Valve,Master,WKM-M, 0er 31/85M FE,HWO,DD trim 00, o 0®0 Multibowl Wellhead-upper :.k...11l in ������- S 2 11 5M X 11 SM,- 2- 1 . 2-2 1/16 5M SSO,w/1- 2 1/16 5M WKM-M valve Isl 6 � �ilbs•%4ftiiI'I" .. ININI— SIA. r Sy Casing spool,5,13 5/8 3M x limi1 pI 1®! N11 5M,w/2-21/165M 550, ,1 /BGbottom _ _ric„.4,,,,,..,_,. w/1-21/165MWKM-M ' 1 , . valve - �r ' 1l1 3N`' 119s; Casing head, Shaffer KD, ;f, ------ t 1e1 13 5/8 3M X 111 CV 13 3/8 SOW,w/2-2" LPO, cF`0 1 'p _i 'M_$ purl. 01 II II IIP. IM, Monopod Platform 2013 BOP Stack 03/12/2013 Ilikutp Ain.Iis 1.1.0 Big Floor Bottom of air boot flange S'below rig floor 16, 14.72' 9.50' Pipe �1,I1l Il ltllll lL Flll.11111111 3.74' Shall*, 115/1SM iii 11 II iii 2625' = Sha X1 - O 27/8.5 Variables ....2.50' 42/11 t!O V S Slind 111 I ! 1.76 it Ito ( f' 1h �..i1,'sy..1 Mud Cross I 1 ni u1 ni 1 1' 135/85MFEXFE w/3 1/6 5M EFO w/2 1/16 5M Choke end Wil valves wl Unbolt end II 111 III connections for Ines 2.83' I _..., — Dual Cameron Flex rams 11 11i 111!1! II .70' 111131.131 131 131 14 20" Ong desk UOCD 1911 Riser 1420' 13S/8Sh1FEXI3 S/8 9.1 FE 1II I.II6.I it I 1 1 Spacer spool IS 135/85F.1FE X 11361 I --- li III III III i1 Wellhead A 15.00' p Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Thursday,January 02, 2014 10:54 AM To: 'Ted Kramer' Cc: Juanita Lovett Subject: RE: Monopod A-11 (PTD 170-024) -Application for Sundry Approval Ted, Sounds good ... will look at new sundry today. Continue with approved sundry 313-571 until casing work. We won't have to retract this sundry ..just roll over to the new one at that point. The final 10-404 will close out both sundries. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From:Ted Kramer [maiIto:tkramera ilcorp.com] Sent:Thursday, January 02, 2014 10:14 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: Monopod A-11 (PTD 170-024) -Application for Sundry Approval Guy, Just a heads up that the attached A-11, 10-403 is on its way over to you by courier this morning.This sundry will replace Sundry Number 313-571, PTD# 170-024. Timing wise, we will be skidding to the A-11 this evening. As we discussed, we will begin the work under Sundry 313-571 up to running the casing. By then, we should have the new Sundry to proceed. This is a much improved solution for this well. I appreciate your help on getting this turned around. Happy New Year, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 1 r r Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Tuesday, December 31,2013 1:16 PM To: Schwartz, Guy L(DOA) Subject: Monopod A-11 Procedure Change Guidance Sundry#313-57,1 PTD# 170-024 Attachments: Monopod A-11 Proposed 12-31-13.doc Guy, I want to talk to you about the above well. We have a change to the well program to submit and I want to see how to best go about it. It will be the next well on Monopod. My belief is that it is a better approach but it does result in a significant change. Basically,the change involves: 1. Run a 7-5/8"tieback Liner and cement in place. 2. Add the B-zone 3. Perforate under a packer(leaving the guns in place). 4. Placing the well on gas lift. The new proposed schematic is attached. Please give me a call to discuss. Ted Kramer Sr.Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1 • • • ♦,OF Tb 4,0"\ //77 cv THE STATE Alaska Oil and Gas N `aM ®� JL`�l 1 d ALAS Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 OF ALAS� Main: 907.279.1433 Fax: 907.276.7542 Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC /170 O4`"1 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C & Middle Kenai D Oil Pools, Trading Bay St/A-11 Sundry Number: 313-571 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. oerster Chair, Commissioner ISfr DATED this I day of November, 2013. Encl. • • RECER'ED u j S" qn STATE OF ALASKA 1��� hT2 ItfiiD3 1 ALASKA OIL AND GAS CONSERVATION COMMISSION A t' APPLICATION FOR SUNDRY APPROVALS 20 MC 25280 1.Type of Request: Abandon El Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate B. Pull Tubing Q. -line Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Install ESP. El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Ei- 170-024• 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20214-00• 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 93B Will planned perforations require a spacing exception? Yes ❑ No O Trading Bay St/A-11 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 - Trading Bay Field/Middle Kenai C &Middle Kenai D Oil Pools - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,180• 9,927 - 5,915 5,773 6,693 6,404 Casing Length Size MD TVD Burst Collapse Structural • Conductor 228' 20" 228' 228' 2,410 psi 770 psi Surface 1,085' 13-3/8" 1,085' 1,045' 3,090 psi 1,540 psi Intermediate Production 7,092' 9-5/8" 7,092' 6,942' 6,330 psi 3,810 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic • See Schematic 3-1/2" 9.3#/N-80 3,145 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Model D Pkr&SSSV:N/A 4,110'(MD)3,976'(TVD)and SSSV:N/A ■ 12.Attachments: Description Summary of Proposal CI 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch D Exploratory ❑ Stratigraphic❑ Development!J • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 11/21/2013 Commencing Operations: Oil El• 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 tkramenfthilcor0.com Printed Name / �TedKd ramer Title Sr.Operations Engineer Signature �5i'i' ,`�•.. ..��'— Phone (907)777-8420 Date 10/29/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:, I Plug Integrity ❑ BOP Test Lids Mechanical Integrity Test ❑ Location Clearance ❑ Other: le Z.OOV gyps. got' Ga t- Spacing Exception Required? Yes CI No Subsequent Form Required: /y-- ye y APPROVED BY Approved by: aliiii itga.,e4,7,4.... COMMISSIONER THE COMMISSION Date: it- /-*/3 Form 10-403(Revised 10/2012) Appro application is valid for°RIG e a proval. I s upl' '1 • • Well Prognosis Well: A-11 Hilcorp Alaska,IL Date:10/29/2013 Well Name: Monopod A-11 API Number: 50-733-20214-00 Current Status: SI oil producer(Gas Lifted) Leg: N/A Estimated Start Date: November 21,2013 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: 170-024 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: 1,958 psi @ 5,890' MD (5,749' TVD) From 4/16/2007 Shut-in Bottom Hole Pressure Survey(=0.341 psi/ft. grad.) Maximum Expected BHP: 1,958 psi @ 5,890' MD (5,749' TVD) Max.Anticipated Surface Pressure: -Opsi (1,958 psi -(5,749'TVD X.341 psi/ft.)) Brief Well Summary The A-11 well was drilled and completed as a gas lifted D zone oil well in 1970. Two workovers occurred over time,C zone was added in 1973 and a re-perf of the C and D zones was completed in 1988. The well developed a casing leak in 2007 which led to pressure and on the 13-3/8"X 9-5/8" annulus and the 13-3/8"X 20" annulus. To remediate this leak,two sets of perforations(904-914' and 891-901'). Circulation was established through the perfs and up the 9-5/8"X 13-3/8" annulus. The pe sr then squeezed with 75 bbls.of cement. The 9- 5/8"casing was then pressure tested to 1,000 psi. The Workover plan entails pulling the production tubing,drilling up a cement retainer at 4,000' and milling up the Baker Model D packer at 4,110'and cleaning out the well to 6,440(PBTD). The C and D zones will then be /re-perforated and the well placed on an ESP for artificial lift. Brief Procedure: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3. ND Wellhead, NU BOP and test to 250 psi low/2,000 psi high.(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. Unseat tbg. Hanger and Pull out of well with 99 joints of 3-1/2 tubing. 5. PU 8-1/2" bit on WS. RIH to 4,000 ft and drill up fast drill cement retainer. C/O to top of packer at 4,110'. POOH with Bit. 6. PU RIH with Mill Shoe. RIH to 4,110'and Mill over Baker Model D Packer. POOH with Shoe. 7. PU Spear and and RIH with Spear and Remove Packer. 8. PU 9-5/8'Cleanout assembly. RIH Cleaning out 9-5/8"Casing to 6,440'(PBTD). 9. RU E-line. RIH With Gamma Ray and CCL to 6,440'. Log out of hole running Gamma Ray and CCL up to 1,085'. RD E-line. 10. PU RTTS Packer. RIH to 4,190'. Set and Pressure the 9-5/8"casing on a chart recorder to 1,000 psi for 30 minutes. POOH with RTTS packer. G Lot 11. PU Storm Packer. RIH to 300'. Set and test packer. ND BOP and change out tubing hanger and well head to ESP hanger. -feat— P,kw 7 • • • Well Prognosis Well: A-11 Hilcoru Alaska,LI) Date: 10/29/2013 12. NU BOP and re-test(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 13. POOH with Storm Packer. 14. PU RIH with TCP guns according to the Final Approved Perforation Request Form. 15. RU E-line, Log TCP Guns on depth. Fire Guns. 16. Pick up TCP guns above perforations,monitor well by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 17. RU Schlumberger. PU ESP building into the well. RIH with ESP on 2-7/8"production tubing and set bottom of ESP at 4,147'(+/-). 18. ND BOP,NU wellhead and test. 19. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing • • Trading Bay Unit .. -ll SCHEMATIC Well #A-11 Completion Date: 5/3/2007 RKB to TBG Hngr=41.50' CASING AND TUBING DETAIL 228':'A' Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate hrs - #!', 20" 14"Wall H40(risked) Weld Surf 228' 1750 20.5 13-3/8" 61# 1-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 `r {'T°6 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs 4 a8 Y 885' Stage Collar 3622.8' 6330 1250 sxs See below 373 904'914' 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs , sl TUBING � 3-1/2" 9.3 N-80 8rd 2.992 Surf 3145' 10570 1085'A.5 '_t 1122' JEWELRY DETAIL 9-5/8"Cement Job 1150'1158' riQ Depth ID Item 1160 2700 Fair/Poor(USIT) 1750' 3145' 2.99 Half MS 2700' 2830' Good cmt(Top of Log) 4000' NA FastDrill Retainer 2830 3110 Poor cmt 1 4110' 4.75 Baker Model"D"Packer 3100 3700' Good cmt 3700' 4056' Poor cmt 4056' 4200' Good cmt 54 Sand Wireline Summary 4200' 5100' Poor cmt MO'1705' 5100' 7092' Good cmt 2004-2006 Tag fill with 2.25"GR at 5915'RKB 4i 244 Sand 2170'2280' , PERFORATION DATA Top Btm Top Btm Accum. Date Zone (MD) (MD) (ND) (ND) Amt. SPF Last Opr. Present Condition Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT a t• • cmt Sqz Perfs 4,192' 4,194' 4,057' 4,059 2 4 4/73 Cmt Sqzd f/csg bond C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. wie C-3 4,270' 4,340' 4,135' 4,204' 70' 12 5/4/1998 Open f/prod. Ism C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 ern C-5 4,471' 4,476' 4,335' 4,340' 5' 4 4/73 Az 4,000' C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 �: C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. JI Stray 4,819' 4,824' 4,681' 4,686' 5' 4 4/73 1 C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 C 48-7 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 R A C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 `-1 C 50-3 5,140' 5,178' 5,002' 5,040' 38' 8 5/4/1998 Open f/prod. C Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond ' D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 .a D 53-8 5,600' 5,652' 5,460' 5,512' 52' 12 5/4/1998 Open f/prod. ,,, D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/prod. S s D 54-9 5,742' 5,769' 5,602' 5,629' 27' 4 5/70 it Al D 55-7 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. l' D D 57-2 5,975' 6,055' 5,834' 5,913' 80' 8 5/4/1998 Open f/prod. Fill at Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/csg bond 5915' Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/csg bond /j��� FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. KB ELEV=101' 1988:Has pert debri from Vann Gunns at 6404'. PBTD=6,440' TD=10,180' ANGLE thru INTERVAL=8.5° Updated by: JLL 10/25/13 • • Trading Bay Unit PROPOSED Well #A-11 Completion Date: Future RKB to TBG Hngr=41.50' CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate 228 .. � hrs - 20" %"Wall H40(risked) Weld Surf 228' 1750 20.5 • 13-3/8" 61# J-55 Butt 12.515" Surf 1085' 3450 200 sxs Surf 314 roc @ 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs 720' • eas Stage Collar 3622.8' 6330 1250 sxs See below 373 906'914' 9-5/8" 43.5 N-80 8rd LT&C 8.755 Surf 7092' 1050 sxs TUBING . 2-7/8" 6.5 L-80 8rd EUE Surf ±4,050 1085' 1122' 5°,1158, JEWELRY DETAIL 1180' NO. Depth ID Item 41.5' Tubing Hanger ±4,147 Bottom of ESP IA sand 1880'1700' PERFORATION DATA , "24.6 sane Top Date 2170'2260' Zone (MD) Btm(MD) Top(ND) Btm(TVD) Amt SPF Last Opr. Present Condition Sqz Perfs 1,150' 1,158' 1,146' 1,154' 8' 4 4/30/07 Sqzd 300sx of LXT cmt Sqz Perfs 4,192' 4,194' 4,057' 4,059' 2' 4 4/73 Cmt Sqzd f/csg bond C-2 4,193' 4,233' 4,057' 4,098' 40' 8 5/4/1998 Open f/prod. C-2 ±4,197' ±4,233' ±4,062' ±4,098' 36' Future C-3 ±4,270' ±4,340' ±4,135' ±4,204' 70' 12 Future Re-perf • CZN6 ±4,364' ±4,384' ±4,228' ±4,248' 20' Future C-4 4,376' 4,382' 4,240' 4,246' 6' 4 4/73 C-5 4,471' 4,476' 4,335' 4,340' 5' 4 4/73 i .. • C-6 4,560' 4,570' 4,423' 4,433' 10' 4 4/73 C-7 4,638' 4,713' 4,501' 4,576' 75' 8 5/4/1998 Open f/prod. C-7 ±4,642' ±4,712' ±4,505' ±4,575' 70' Future C 47-5 ±4,817' ±4,827' ±4,679' ±4,689' 10' Future 4,000' Stray 4,819' 4,824' 4,681' 4,686' 5' 4 4/73 C 47-5 ±4,846' ±4,870' ±4,708' ±4,732' 24' Future C 47-5 4,850' 4,867' 4,712' 4,729' 17' 4 4/73 1 C 48-5 4,922' 4,944' 4,784' 4,806' 22' 4 4/73 ��''kk C 48-5 ±4,932' ±4,948' ±4,794' ±4,810' 16' Future Xk C 48-7 ±4,954' ±4,976' ±4,816' ±4,838' 22' Future C 48-7 _ 4,958' 4,972' 4,820' 4,834' 14' 4 4/73 _ C 49-4 5,056' 5,061' 4,918' 4,923' 5' 4 4/73 C C 50-3 ±5,140' ±5,178' ±5,002' ±5,040' 38' 8 Future Re-perf Sqz Perfs 5,505' 5,506' 5,366' 5,367' 1' 4 5/70 Cmt Sqzd f/csg bond D ZN2 ±5,568' ±5,590' ±5,428' ±5,450' 22' Future D 53-0 5,570' 5,586' 5,430' 5,446' 16' 8 4/73 D 53-8 5,600' 5,652' 5,460' 5,512' 52' 12 5/4/1998 Open f/prod. D 53-8 ±5,605' ±5,634' ±5,465' ±5,494' 29' Future 0 D 54-5 5,665' 5,710' 5,525' 5,570' 45' 12 5/4/1998 Open f/prod. �F D 54-5 ±5,670' ±5,708' ±5,530' ±5,568' 38' Future i D54-9 ±5,740' ±5,750' ±5,600' ±5,610' 10' Future D D 54-9 5,742' 5,769' 5,602' 5,629' 27' 4 5/70 D 54-9 ±5,760' ±5,770' ±5,620' 15,630' 10' Future i D 55-7 5,802' 5,816' 5,662' 5,676' 14' 4 5/70 T D 55-7 ±5,802' ±5,828' ±5,662' ±5,688' 26' Future D 56-1 5,856' 5,941' 5,715' 5,800' 85' 16 5/4/1998 Open f/prod. D 56-1 ±5,856' ±5,949' ±5,715' ±5,808' 93' Future /j��� D 57-2 ±5,975' 6 062' ±5,834' 5 920' 807' 8 5/4/1998 Open f/prod. Sqz Perfs 6,070' 6,071' 5,928' 5,929' 1' 4 5/70 Cmt Sqzd f/csg bond KB ELEV=101' Sqz Perfs 6,410' 6,411' 6,265' 6,266' 1' 4 5/70 Cmt Sqzd f/csg bond PBTD=6,440' TD=10,180' ANGLE thru INTERVAL=8.5° FISH/JUNK IN WELL 1979: GO Int.left a radioactive source in well at 6693'.DO NOT DEEPEN BELOW 6500'. 1988:Has pert debris from Vann Gunns at 6404'. Updated by: JLL 10/28/13 • • Monopod Platform A-11 Current 10/16/2013 Hilrorp:\1a«kn.l U Monopod Tubing hanger,CIW-DCB- A-11 FBB,11 X 4'A EUE lift X 41/2 13 3/8 X 9 5/8 X 3 1/2 EUE susp,w/4"type H BPV, 1/8 non continuous control line,7"extended neck prep BHTA,Bowen, 4 1/16 5M FE I 111 -Iffi-1 II .0^` Valve,WKM-M,41/16 5M ,,0 FE,HWO,AA ` y 0 0' v.`A I i - - Tubing head,CIW-DCB, :41 ,I ��� 13 5/8 3M X 11 5M,w/2- 1.1 1�1 Valve,ClW-F,2 1/16 5M F .f wb; 1 2 1/16 5M SSO,X bottom II ` , . HWO,AA • 1''A VR profile Ns 'llt �e �l 1n 1 '� in I m Casing head, �_ II. l■-■"-,- ShafferKD, III ' 1l1 135/83MX 13 3/8 SOW,w/2-2" im, 1 I I i 1; 0-h 2"LP ball valve LPO, di WIPP • • • Monopod Platform A-11 Proposed 10/16/2013 tl lrnrp:%luau.1.1.1, Tubing hanger,CIW-DCB-ESP, Monopod 11 X 4'A IBT lift and susp,w/ 13 3/8 X 9 518 X 3 1/2 4"type H BPV profile,5 X EN, 3-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,4 1/16 5M FE X 7"-5 Stub acme Bowen Union I In III MEM Valve,swab,WKM-M, 0$ Cross,stdd,41/16 5M X 4 1/16 5M FE,HWO, _ \■ T-24 C,, 3 1/8 5M X 2 1/16 5M Valve,wing,WKM-M, r �° o I,/ V2 1/16 SM FE,HWO, , 11 Q Valve,WKM-M,3 1/8 5M FE,w/ T-24 �. ° MA-16 operator ice^u. Valve,lower master,WKM-M, In('-t-0 4 1/16 5M FE,HWO,T-24 0 0 0 :a 1.1 w. Adapter,CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE,prepped for 5''4 EN neck,3-'/2 npt continuous r control line ports,BIW penetrator �1 port Tubing head,CIW-DCB, , I ice' 13 5/8 3M X 11 5M :Gil pp I FF1 I:■= w/2-2 1/16 5M SSO, 1 ■ rl i X bottom Valve,WKM-M,2 1/16 5M FE,oix? i ,,, _ HWO,DD 1.1.4„, 11 ... . 111_ III LI 1. Casing head, ' ,1 Shaffer KD, 11 1I la I I I1 13 5/8 3M X 133/8 SOW,w/2-2" LPO, illy 111 0' •I•i.; 2"LP CIW ball valve 0_--!. . ... • • Monopod Platform 2013 BOP Stack 03/12/2013 Hilrnrrp:Uarka, Rig Floor Bottom of air boot flange ■ 5'below rig floor 16" 14.72' 9.50' Pipe I11 111 iiiliilll 711111 ._ r, 3.74' Shaffer 13 5/8 5M — i 26.25' Shaffer OCT 2 7/8-5 Variables 2.50' r 13 5/8 5M -- -- Blind . if PIS 11011 rlrl 1.76 1.l _ �,� 11 Mud Cross I eo (y' '�� L1 r t lil ll1 "4'4 135/851 FEXFE w/31/85MEFO ---- w/21/165M Choke and Kill valves w/Unbolt end connections for lines Ii{4U4JJ41 �!l clw- 13585U 1 2.83' ,-. - Dual Cameron Flex rams if III IT 11"t1TI11 .70' I1, II 'i I I:. V Drill deck Riser 14.20' 13 5/8 5M FE X 13 5/8 5M FE i1: 1: !11 1:11! I ill Spacer spool 1.5' 135/85M FEX113M 11' I. 1:. 11' Wellhead @ 15.00' ! i Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 4, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 ~~~E~ DEC 1 1 2007 PERMIT# API f l ~: E=~ v'iE'~L BOG TYFE ~~ '.~~~ ~ L ;~ DATE ~ Ih1TER. ;a~ ~ PUf! I B ~~ILG,1 ~ P,JTES - 'I ~ LuG~ED LI^.c ~ ~ ~ ,°,S, ~ i I ~ PDS. ULTRA-SONIC IMAGING TOOL CEMENT EVALUATION IMAGE GAMMA 170-024- RAY /CCL 6-May- 0 507332021400 TBU A-11 CORRELATION 5" 07 70 - 3975 1 1 1 PDS ULTRA-SONIC IMAGING TOOL CEMENT EVALUATION IMAGE GAMMA 170-024- RAY (CCL 28-Apr- 0 507332021400 TBU A-11 CORRELATION 5" 07 100 - 3980 1 1 1 PDS ULTRA-SONIC IMAGING TOOL CORROSION EVALUATION IMAGE GAMMA 170-024- RAY /CCL 28-Apr- 0 507332021400 TBU A-11 CORRELATION 5" 07 100 - 3980 1 1 1 PDS RESERVOIR SATURATION TOOL SIGMA LOG AND GR / 170-024- CCL PRESS 28-Apr- 1 507332021400 TBU A-12 TEMP SURVEY 5" 07 100 - 3980 1 1 1 1 PDS Please acknowledge receipt by signing and returning one copy of this tr~r-s~-it~al nor FA~t-0 907 263 7828. Received By: } Date: -• r V • Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 4, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste#100 ~~;~~® ~~~ ~ ~. 2~~7 Anchorage, AK 99501 PERMIT # Pl NUMBER r 'idELL COG TYPE ~ SCALE i0G DATE ~~ INTERVAL. RUrd ~- ~ ~ NOTES - CD . LOGGED .~ I LIidE ! I ~ LAS. PDS. ~~ ~ _ _ _ ~ _ _ _ I' - ___ _ ~ DLIS - - ULTRA-SONIC IMAGING TOOL CEMENT EVALUATION IMAGE GAMMA 170-024- RAY /CCL 6-May- 0 507332021400 TBU A-11 CORRELATION 5" 07 70 - 3975 1 1 1 PDS ULTRA-SONIC IMAGING TOOL CEMENT EVALUATION IMAGE GAMMA 170-024- RAY /CCL 28-Apr- ~ 0 507332021400 TBU A-11 CORRELATION 5" 07 100 - 3980 1 1 1 PDS ULTRA-SONIC IMAGING TOOL CORROSION EVALUATION IMAGE GAMMA 170-024- RAY /CCL 28-Apr- 0 507332021400 TBU A-11 CORRELATION 5" 07 100 - 3980 1 1 1 PDS RESERVOIR SATURATION TOOL SIGMA LOG AND GR / 170-024- CCL PRESS 28-Apr- 1 507332021400 TBU A-12 TEMP SURVEY 5" 07 100 - 3980 1 1 1 1 PDS 1 ~b -~~l ~ ~ 5 ~ ~~~ Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: ' Date: ~~ Monopod A-II Current Schematic . . Subject: Monopod A-II Current Schematic From: "Tyler, Steve L" <tylersI@chevron.com> Date: Mon, 25 Jun 2007 13:37:59 -0500 To: "Maunder, Tom" <tom_maunder@admin.state.ak.us> Tom My bad. You are correct. We did leave a retainer at 4000' and the production pkr in the well. Sorry it took so long to respond back to you. \1 D ~ or'-\' Drilling Engineer, Adviser Union Oil Company of California (Office: (907) 263-7649 (Cell: (907) 350-6295 (Home: (907) 696-1837 (Fax: (866)730-9392 .Email: tylersl@Chevron.com SCANNED JUN 262007 . .......~._...."..,.- ...,.-~-". , .. Monopod A-II Current Content-Descnption: S h t· pdf cerna IC. Monopod A-ll Current Schematic.pdf C t t T 1· t· n/ t t tr on en - ype: app Ica 10 oc e -s earn Content-Encoding: base64 10fl 6/25/2007 10:40 AM 'i/1:> ,^ 1. Operations Abandon U Repair Well ~ Plug Perforations U Stimulate U Other U ..... 1:i8~ ~ -'vU/ Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 WaiverD Time Extension 0 4/Jclta 'O/J$. C. Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 'l"80e %IJ}J; 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: 1. Name: Development [] Exploratory 0 170-024 - 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic 0 Service 0 6. API Number: 50-733-20214 . 7. KB Elevation (ft): 9. Well Name and Number: 41.50 RKB ' A-11 - 8. Property Designation: 10. FieldfPool(s): Monopod Platform Trading Bay Field _ 11. Present Well Condition Summary: Total Depth measured 10,180 ¡ feet Plugs (measured) 6693 true vertical 9927 feet Junk (measured) 6404 Effective Depth measured 5915' feet true vertical 5773 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 228' 20" 228' 228' 2410 psi 770 psi Surface 1085' 13-3/8" 1085' 1045' 3,090 1,540 psi Production 7092' 9-5/8 " 7092' 6942' 6330 psi 3810 psi Liner Perforation depth: Measured depth: See attach Schematic True Vertical depth: See Attach Schematic Tubing: (size, grade, and measured depth) 3-1/2", 9.3# N-80 3145' Packers and SSSV (type and measured depth) None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service 0 Daily Report of Well Operations X 16. Well Status after work: Oil[] Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 307-136 Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ? -~ A~ C) Phone 907-276-7600 Date ~ -(;. - <;>:::¡-. - -- ~ . STATE OF ALASKA ¿-;;;Þ;b ALAS OIL AND GAS CONSERVATION COM.ON hGt[¡..&" REPORT OF SUNDRY WELL OPERA""IiONS 4431- lf8a J:iS-C12 dÚN IV~D .20 '(}/J RBDMS BFl JUN 2 6 1007 Form 10-404 Revised 04/2006 ORIGINAl Submit Original Only 228 H40 risked) Weld Surf J-55 Butt 12515" Surf N-80 8rd L T&C 8.755 Surf N-80 8rdLT&C 8.755 Surf N-80 8nj 2.992 Surf 3145' HI57 0 1160 2700 HaJfMS 2700 2830 Lo FastDriU Retainer 2830 3HO Poor emt Baker Model "Ð" Packer 3100 3700 Good emt 3700 4056 Poor cmt 4056 4200 <lilt 4200 5100 Poor <lilt 5H!O 7092 Gooo <mt Tag fill with 2.25" GR at 59 J 5' RK" c o KB ELEV '" 111'1' PElTO'" 6,440' TD'" 10,180' ANGLE !hm INTERVAL'" 8.5' A-II Current Schematic. doc REVISED: 5/3/2007 SLT 1IIIIII1IIIIII_1IIIIII"IIIIIiIII"'@IIIiIIIII_IIIIIII~ -...-- -- --.....-., CASING AND f)i?T An RKEI to TElG Hngr = 41.50' SIZE WT GRADE CONN m TOP ont. CMT CMT TOP Tree connection: 11 r 20" \/;,"Wall Dr. hoe Surf 228' 13-3/8" 61# J-55 Butt 12.515" Surf 1085' 200 sxs Surf 9-5/8" 43.5 N-80 8rd LT&C 8755 Surf 7092' 1050 sxs See below Stage Collar 3622.8 1250 sxs See below Tubin,;,: 3- J/2 9.3 N-80 8 rd 2.99" Surf 3145' / : / IŒ REV = 101' P~D = 6,440' TO = 10,180' ANGLE thru INTERVAL = 8.50 A-II Due Diligence Schematic. doc s "\)"'C~~ 7 / t",I<Wt<HW TIOl'i DATA / I I Accum. Date Zone T96 I Btm i Amt. SPF Last Opr. Present Condition î<R.Eerfs 4<'192'---+ .. ... 4,19L.. _L~.. ~.. 4. t 4/73.. Cmt Sqzd II csq bond c.2__L.E19ª,---+-- 4,233' 1_ 40':'_ _8 5/4/98 Openf/prod. ~.::l.--.l/....1,270':'_j~.1,340' =r~f--......J2__---..91~ Open II prod__~_~ C-4 4 376' I 4 382' I 6' 4 4/73 C-5 / '44ITT 4:476' t-&-1--4~ ~4/n------ ~ 4,560' -t 4,570' t--c10' 4/73 '_ ...4,638'.. . ....4713'.. 75' 5/4/98 Ooenf/prod, 4 819'.L 4824' 5' I 4/73 C47.5~7-IÙ67"- 17' 4/73 _º 48.L 4,922' I 4,944' 22' ..~~+______ C 48·7 4,958' -r 4,972' 14' 4/73 C 49·4. I-- 5,056' .~.61'.. I.... 5' 4/73 C 50.3" ''(;14tY -I 5,17ir--r- 38" 8 5i4/98 Open fl nrod, . SqzpE>.iTI.I-_22Q§'.... .......It.._. .5,506~1. . 1'---. 4., 5/70.._ICmt SQzdII CSQ bond D 53·0 5,570' 5,586' I 16' 8 4/73 ~ D53'8--I--'..§,600'~=r-=5,652'T- 52'~ - 12-1--' 5/4/98. 10penf/orod. '_ D 54-5 .. 5,665' .-L., 5,710' I 45' 12 5/4/98 10pen II pr-º'L......__ D 54·9 5742' I 5769' T 27' 4 5/70-1 D 55-7 5,802' .... I 5,816' .L.1.£... 4 5/70 I D 56·1 . 5 856'-T-5,94-:¡;-- I 85" 16 5/4/98 100en II prod.- D 57-2 5,975' I 6,055' 80' 8 5/4/98 100en f/orod. Soz Perfs 6,070' '-1- 607r' l' 4 5/70' ICmt Sqzd II CSQ bond SQZ Perfs 6410' I 641 r l' 4 5170 ICmt Snzd II csn bond ~ ~ C f- D Fill at 5915' '~hL "" NOT , 6500' ¡ro", 0'';&[",,' ,}-5/8' 7092'- 5100' - Good <mt 5100'- 4200' - Poor <mt 4200'- 4056' - Good <mt 4056'- 3700' Poor <mt 3700'· 3100' - Good cmt 3110'- 2830' - Poor cmt 2830' - 2700' Good cmt (Top of Log) .".. REVISED: 2-8-07 BCA · . Primary Job Type Workover Jobs Primary Job Type Workover Daily Operations 4/11/200700:00 - 4/12/200700:00 Operations Summary DSM travel to Monopod. Monitored A-11 csg annuli pressures and 13-3/S" bleed. 13-3/8" flowing thru Kurts meter @ 30 mcfpd to flare. 4/12/200700:00 - 4/13/2007 00:00 Operations Summary RU 1" high pressure line from 13-3/S" x 9-5/S" annulus to Kurts meter. Continue monitoring well. 13-3/S" flowing @ 30 mcfpd. 4/13/200700:00·4/14/200700:00 Operations Summary Continue monitoring well. PJSM w/ skeleton rig crew. Start mobilizing Monopod rig. 13-3/S" flowing @ 30 mcfpd. 4/14/2007 00:00 - 4/15/2007 00:00 Operations Summary Bleeding tbg & 9-5/S" annulus. Continue mobilizing Monopod rig. Clear decks. 13-3/S" flow rate @ 31.6 cfpm. 4/15/200700:00 - 4/16/200700:00 Operations Summary Continue mobilizing rig. Continue bleeding tbg & PC annulus. RU slickline. Worked slickline thu multiple tbg obstructions. Tagged fill @ 5915'. 13-3/8" flowing @ 31.6 mcfpd. 4/16/200700:00 - 4/17/200700:00 Operations Summary Continue to mobe rig. Slickline retrieve GLV in #3 GLM @ 4041'. Slickline convey temp/pressure tools down tbg. Set down @ 2345'. Worked tools. No Joy. POOH. Installed knucle jt. RIH worked tools pass 2345' obstruction. Log to 5S90'. Log up to surface. 13-3/8" Flow rate @ 32 mcfpd. 4/17/200700:00 - 4/18/200700:00 Operations Summary Continue mobilizing rig. Noted increase in flow rate from 13-3/8" x 9-5/8" annulus. Shut-in same. 13-3/S" & 20" pressured up to 260 psi in 15 min. Checked meter. Open 13-3/S" x 9-5/8" annulus to flow meter. Flow rate now @ 75 mcfpd. 4/18/200700:00 - 4/19/200700:00 Operations Summary Continue to mobe Monpod rig. Flow Rate from 13-3/S" x 9-5/S" annulus now @ 90 mcfpd. 4/19/200700:00 - 4/20/200700:00 Operations Summary PJSM with rig crew. Circulate hydrocarbons from well to production w/192 bbls of 3% KCI/FIW @ 3.5 bpm. Bullhead 25 bbls of 3% KCIfFIW into prodution interval. Well on vacuum at 47 bbls/hr loss rate. 4/20/2007 00:00 - 4/21/2007 00:00 Operations Summary NU BOPE. Pre-Spud meeting with all personnel. Flow Rate from 13-3/S" x 9-5/S" annulus now @ 96.5 mcfpd. 4/21/2007 00:00 - 4/22/2007 00:00 Operations Summary Continue NU BOPE. Testing BOPE. Flow Rate from 13-3/S" x 9-5/8" annulus now @ 103.7 mcfpd. 4/22/2007 00:00 - 4/23/2007 00:00 Operations Summary Continue Testing BOPE. Pumped 50 bbl sized salt pill. Flow Rate from 13-3/8" x 9-5/S" annulus now @ 105 mcfpd. 4/23/2007 00:00 - 4/24/2007 00:00 Operations Summary Continue rebuilding Koomy Unit. Test same. Pump 2nd 52 bbls sized salt pill down tbg. Pump 3rd sized salt pill (50 bbls). Loss rate @ 35.6 bph. RU Eline for tbg cut. Pull on tbg, seals came out of pkr @ 30k. Loss rate increased. Start building 4th sized salt pill. Flow Rate on 13-3/S" x 9-5/S" is now @ 112.3 mcfpd. Daily Operations 4/24/2007 00:00 - 4/25/2007 00:00 Operations Summary Mix and pump 60 bbl sized salt LCM pill and monitor well. Mix and pump another 95 bbl sized salt LCM pill and monitor well. Losses to hole reduced from 32 bbls/hr. to approximately 13 bbls/hr. Pull tubing hanQer and start to pull and lav down 2-7/S" tubing. Install choke on 13-3/S" x 9-5/S" annulus. Flow rate from the 13-3/8" x 9-5/S" annulus is at 110.9 mcfpd on choke. With 25 psi back pressure. 4/25/2007 00:00 - 4/26/2007 00:00 Operations Summary POOH. LD tbg. Test Blind Rams. PU tandem csg scrappers, boot baskets & DC. Total fluid loss to well since seals were pulled from pkr is 15S4 bbls. Flow Rate on 13-3/S" x 9-5/S" annulus is at 112.3 mcfpd on choke with 25 psi back pressure. 4/26/2007 00:00 - 4/27/2007 00:00 Operations Summary Continue RIH (picking up 5" DP) w/ tanden csg scrapper assy. Circulate/wash from 4005' to 4112'. Loss rate increased to 76 bph. Start building 100 bbls CaC03 pill. Total fluid loss since seals were pulled = 2105 bbls. Flow rate from 13-3/8" x 9-5/S" annulus = 1 03.6 mcfpd on choke w/ 26 psi back pressure. 4/27/200700:00 - 4/28/200700:00 Operations Summary Pump 15 bbls sat salt followed by 53 bbles Calcium Carb LCM pill, and squeeze. POOH with BHA. PU and set Fasdrill pluQ at 3990'. CBU. POOH. PU and run USIT log. 13-3/S" x 9-5/S" annulus currently has 26 PSI back pressure and is flowing 103.7 MCF/day 4/28/2007 00:00 - 4/29/2007 00:00 Operations Summary Finish running the USIT log from 3,990' to surface. Log w/ RST from 39S6 to 1000'. RD eline. MU landing jt. Pull wear ring and run test plug. Test BOPE (250/3000psi). Witness by AOGCC. PU setting tool and stinger and RIH to 3990'. Displace the FIW in wellbore with 10.2 PPG mud. 4/29/2007 00:00 - 4/30/2007 00:00 Operations Summary Finish displacing hole with 10.2 PPG mud. POOH and LD setting tool. RU and function test kelly. PU FAS Drill bridge plug and RIH and set at 11S0'. POOH. RIH w/ mule shoe to 1007'. RU APRS and spot tubing punch guns on depth. 4/30/2007 00:00 - 5/1/2007 00:00 Operations Summary Pun~ csg @ 1150' - 115S' w/ 100 psi on wellbore. No Joy on establishing circulation to surface. Pumpllnject 107.7 bbls away @ 0.9 bpm rate. RI set FastDrill retainer (â) 1122' DPM. Test retainer to 1000 psi. Establish injection rates & pressures thru retainer. Mix/pump/circulate 10 bbls of Mud Push and 9 bbls of LXT cmt. Strip-in/stab into retainer. Mix/pump/inject remaining 31 bbls of LXT cmt plus DP displacement. Total 40 bbls (200 sx) LXT cmt below retainer. PU reverse DP clean. POOH. RU Eline w/ temp/pressure memory tool. RIH log to 1122'. Log up to surface. 13-3/8" x 9-518" annulus @ 0 psi w/ No Gas Flow. 20" x 13-3/8" @ 0 psi. ./ _____"o 5/1/2007 00:00 - 5/2/2007 00:00 Operations Summary MU Temp/Pressure memory tools. RIH w/ same to 1,115'. Log up to surface. Log depicted n,o cmt above too of retainer. RIH w/ OE DP to 775'. RIH w/ 10' csg punch gun. Perf cSQ 904' - 914'. POOH w/ eline. Establish injection rate of 2.2 bpm @ 400 psi. NOTE: While pumping saw a slight flow of gas @ 8 scfpm from 13-3/S" x 9-5/S" annulus. No Flow with pumps off. 5/2/200700:00 - 5/3/2007 00:00 Operations Summary Pumped 10 bbls Mud Push and 60 bbls Qf LXT cmt throuah retainer (â) 875'. Displaced DP. PU Reverse Circ DP clean. POOH. WOC 12 hrs. RIH w/ Bit and CO assy. Dril! retainer @ 875'. Clean out cmt to 996'. 5/3/200700:00 - 5/4/2007 00:00 Operations Summary Continue drilling cmt from 996' to 1027'. POOH. Clean boot baskets. Jug test csg several times until 500 psi test was achieved. attempt to pressure up to 1000 psi, broke back to 700 psi. Inject @ 700 psi. Saw returns @ surface. RI punch additional csa holes S91' to 901'. Established circulation rate of 7.7 bpm @ 760 psi. CBU 5x. RI set retainer ~ S65'. Establish circulation rate of 5 bpm @ 550 psi.. CBU 5x. RU cementers, mix waters. · . ~~ ~, &~ w:~ ~''''l¡II~~R ,":ç,~ !b.~\&,; ..~ N ~.~". . ,~, II.., :.'%'0' ¡¡¡\II N N,~~ ,&\ **~ N Ny "N N 1i! ;i0':' ,\ ' '..\~<Z y 't~ ""I ~~ ' !!!? e0¥1 .%1'~ ,".'1;)< ,&, .",\, ~ ill .'\~ N ,,1Iî0 <\it". \ II Daily Operations 5/4/2007 00:00 - 5/5/2007 00:00 Operations Summary Mix Chem wash and batch mix LXT cmt. Pump 40 bbls of chem wash. At 35 bbls away saw chem wash returns @ surface. Cont pump chem wash, 10 bbls of 13 ppg mud push and 15 bbls of LXT cmt. Displace DP w/1 0.2 ppg mud @ 3.5 bpm. Last 2 bbls of diplacement was pumped @ 0.5 bpm. PU reverse circulate DP clean. POOH. RU slickline. Run temp survey. RD slickline. WOC 12 hrs. RIH w/ drilling/CO assy. Drill retainer tm 865'. Drill cmt to 998'. pressure test sqeeze holes to 1000 psi. Lost 100 psi over a 30 min period. RI to 1018'. Drill/ CO retainer @. 1022'. 5/5/2007 00:00 - 5/6/2007 00:00 Operations Summary Continue drilling cmt retainer @ 1122'. Drill/CO cmt and bridge plug @ 1180'. RI to 3986'. CBU. POOH. RI w/ tandem csg scrappers to 3986'. Change well over to FIW w/ corrosion inhibitor. 5/6/2007 00:00 - 5/7/2007 00:00 Operations Summary Continue changing well over to FIW w/ corrosion inhibitor. POOH. RU SWS. RIH w/ USIT log tools to 3980'. Log up to surface. RD SWS. Lay down DP. NOTE: BOP weekly test waived by Lou Gramaldi 5/5/07 5/7/2007 00:00 - 5/8/2007 00:00 Operations Summary Continue laying down DP. PU 3-1/2" kill string RIH w/ same. Land kill string @ 3,146'. ND BOPE. 5/8/2007 00:00 - 5/9/2007 00:00 Operations Summary Clean pits. RD Quadco equip. Dissemble Koomey to send in for repair. 5/9/200700:00 - 5/10/2007 00:00 Operations Summary Clean, Demobe equipment. Remove Koomey. 5/10/200700:00 - 5/11/2007 00:00 Operations Summary Continue Demobe. 5/11/2007 00:00 - 5/12/2007 00:00 Operations Summary Continue Demobe. 5/12/200700:00 - 5/13/2007 00:00 Operations Summary Finished Demobe. LAST REPORT. . . 1TŒ 1"1 'I ts SARAH PALIN, GOVERNOR AI/ASIiA OIL AlQ) GAS CONSBRVATlON COmoSSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ThnothyBrandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: Trading Bay Field, Middle Kenai Oil Pool, A-II Sundry Number: 307 -136 SCANÞiE.D APR 2 S 2007 \1°;{);µl.\ Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 11 day of April, 2007 Enc!. " . STATE OF ALASKA PT-S "If Ið' Ó, RECE IVED A~~LlC~~I~~ ~~~O;~~~~~~~~M~~~Sffli(\~ APR 1 7 2007 20 MC 25.280 Operational shutdown D Plug Perforations 0 ./ Perforate New Pool D 4. Current Well Class: Development 0./ Stratigraphic D Suspend D Repair well 0 . Pull Tubing D Perforate D Stimulate D Time Extension Re-enter Suspended Well D 5. Permit to Dri~~b:rl Exploratory D 8 1 '1~ Service D 6. API Number: ... Abandon D Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: 1. Type of Request: Þ ""IS Þ7 P.O. Box 196247, Anchorage, Alaska 99519 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D No 0 A-11 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Mono od Platform AI> '- 18731 ./1'.6 41.50 RKB Tradin Ba Field 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10,180, / 9,927' 5,915' 5,773' 6,693' 6,404' Casing Length Size MD TVD Burst Collapse Structural 50-733-20214 / 8. Well Name and Number: Conductor 228' 20" 228' 228' 13-3/8" 1,085' 1,045' 9-5/8" 7,092' 6,942' 2410 psi 770 psi 3090 psi 1540 psi 6330 psi 3810 psi Surface Intermediate Production Liner 1,085' 7,092 Packers and SSSV Type: Perforation Depth TVD (ft): Tubing Size: 2-7/8", 6.4# Baker Model D Pkr; 2-7/8 Otis BV SSSV Tubing Grade: N-80, Butt Packers and SSSV MD (ft): Packer - 4,110'; SSSV - 293' Tubing MD (ft): 4150' Perforation Depth MD (ft): See Attached Schematic 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 15. Estimated Date for Commencing Operations: 17. Verbal Approval: Commission Representative: 14. Well Class after proposed work: Date: Exploratory D Development 4/16/2007 16. Well Status after proposed work: Oil D Gas D WAG D GINJ D ~/ o Service D Plugged WINJ o ~ Abandoned D WDSPL D D 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature 907-276-7600 Date L/_! COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D Mechanical Integrity Test D Location Clearance D ~cr:o~~\. ~\> \C*. ~\~~"c...~ ~Ö\' ~\~~r-.!-û.CCß~tu.~\~. t.o"--\oc:....\- x:::..r-S\,~~' .~, \Y ~~..\. ~\\~"::> BOP Test I)Q Other: . Subsequent Form Required: Approved by: Form 10-403 Revised 06/2006 . . Monopod A-tt Cover Sheet /~ A-II has a history of pressure on the 20" drive pipe of28 psi. on April II, 2007 the pressure went from 28 psi to 400 psi. - Subsequent bleeding of the 20" drive pipe confirmed communication to the 13-3/8" surface casing, also at 400 psi. Addition diagnostic work substantiates a continuous gas flow of 75 mcfpd. ~. Repair/Secure wellbore to remediate the surface casing communication to the 20" drive pIpe. . . Monopod A-tt Work Summary · Mobe Monopod Rig. Skid rig over A-II. · MIRU Slickline. Gauge tbg to EOT. RI tag for fill. Run temp/pressure survey. Retrieve GL V in #3 GLM. · Circulate/fill wellbore. Establish injection rates and pressure into zone. Pump one tbg volume. · ND tree. NU BOPE. Test same. · RU Eline (APRS). RIH cut tbg @ 4075'. POOH w/ 2-7/8" tbg. LD same. · PUMU GR/Junk Basket. RIH to 4070'. POOH. RD Eline. · PUMU Fasdrill Retainer on DP. Set same at 4000'. CBU. POOH. · RU Eline. RIH w/ USIT to 4000'. Log up to surface. RIH with RST to 4000'. Log up to surface. RD Eline. / · RU Eline (APRS). RIH punch csg above TOC. Establish circulation rates and pressures. RD Eline. · PUMU Fasdrill retainer on DP. Set same above csg punched holes. CBU. Mix pump 9-5/8" x 13-3/8" annular volume ofLXT cmt from csg punch holes to surface. ..-' · Monitor pressure on all annuli. CONTINGENCY if it is determined a circulating cmt job will not remediate surface csg breach. · RIH w/ cement stinger on DP. Stab into retainer @ 4000'. Pump/inject 143 bbls of cmt below retainer. · PU place spot 10 bbls of cement on top of retainer. · PUMU BOT section mill. RIH mill csg section across shallow gas sand(s). · Lay-in cmt across shallow gas sands. POOH. · Monitor well annuli pressures. · Demobe rig. RKB to TBG Hngr '" 41.50' Tree connection: ?? Size Wt Grade Corm , s;;rt Ius p... 20" Y,"Wall H40 (risked) Weld 228' 1750 2(1, 1 13-3/8" 61# J-55 Butt 12.515" Surf 1085' 200 sxs Surf 314 9-5/8" 43.5 N-80 8rd L T&C 8.755 Surf 7092' 1050 SXS Stage Collar 3622.8' 1250 sxs See below 9-5/8" 43.5 N-80 8rdLT&C 8.755 Surf 7092' 1050 sXs 2 r~t: Tubin!!, 2-7/8" 6.4 N-80 Butt 2.441 Surf 4L50' 1'.:.;::.4"" .~ " \ "\'00 ~~ 24~ :n "10 ~~d~D JEWELRY DETAIL 1;;~7~~~' L NO. Depth m Hem 41.5' 10" x 4" Cameron 5M Tubing hanger, XO to 2-7/8" Butt I 293' 2.3 13 2-7/8" Otis, BV SSSV Nipple, 3 2 2153' GLV#I BST GLM 3 3480' GLV #2 BST GLM II 4 4041' GL V #3 BST GLM 5 4078' I 2.3 13 I Otis "XA" Slidiug Sleeve 6 4109' I 3.00 Locator Seal Assv. w/8' of seals. 7 4110' 4.75 Baker ModeL "0" Packer 8 4142' 2.313 Otis "X" Profije Nipple, 2.313 9 4L49' 2.5 WLEG btrr¡ 4150' 4 . r. 2004-2006 Tag fill 2.25" GR at 5915' 5 6 7 , . A1IU1'ol D<\.TA 8 I Accum. Date Zone Top Btm Amt. $PF Last Opr. Present Condition 9 Soz Perfs 4J92' 4,194' 2' 4 4/73 CmtSnzd C-2 4,193' .. 4,233' 40' 8 5/4/98 I Open f/prad. 1---. C-3 4270' .~4,340' ..~ 70' 12 5/4/98 I Open f/ orad. . C-4 4,376' 4,382' ~ 4 4/73 f:::: C-5 4471' 4,476' 5' 4 4/73 C-6 4,5Ê.()' 4,570' 10' 4 4/73 C C-7 4638' 4,713' 75' 8 5/4/98 f/ orad. Stray 4819' 4,824' 5' 4 I 4/73 C47--5 4,850' 4 867' 17' 4 I 4/73 C48·5 4,922' I 4,944' 22' 4 4/73 C48-7 4958' 4972' 14' 4 4/73 C49·4 5,056' 5,061' 5' -.... 4 4/73 : C50-3 5140' 5178' 38' 8 5/4/98 Opénf/prad. Soz Perfs 5,505' 5506' l' 4 5/70 GmtSozdf/ œo band 053-0 5,570' 5,586' 16' 8 4/73 053·8 5600' 5652' 52' 12 5/4/98 : D 054--5 5,665' 5,710' 45' 12 5/4/98 Open fl prado 054-9 5742' 5,769' 27' 4 5/70 äU"'- 5,816' 14' 4 5/70 056·1 5856' 5941' 85' 16 I 5/4/98 Open fI brad. Filla! o 57·2 5,975' 6,055' 80' 8 I 5/4/98 Open f/orod. 5915' 6.070' I 6,071' l' 4 I 5/70 Cmt Snzd f/ CSQ bond 6410' I 6411' l' 4 I 5/70 ¡Gmt Sqzd f/csg bond II .... r" " n "U~ G'n",_ a, 640"·'. £.mu;,w",' 1>!O;!i.A'"n ""UIJ" KB ELEV '" 101' PBTD '" 6,440' TD'" 10,180' / ANGLE thru INTERVAL'" 8.50 2700' 2830' 3100' 3700' 4056' 4200' 5100' Monopod A-II Current Schematic.doc REVISED: 2·8-07 SLT . . Monopod A-11 Restore Well Integrity WO Unocal Alaska requests Sundry Approval to perform workover operations on Monopod A-11 with the following exceptions to surface equipment requirements: 1.) To employ the use of 2" 5M flanged hose on choke and kill side. No chicksans or swivels will be utilized. 2.) To take returns to the production low pressure separator and/or a poor-boy de-gasser as required. 3.) Test Blind Rams after tubing is retrieved from well bore. A 41/16" 5M HCR Valve B 4 1/16" 5M Manual gate valve C 4 1/16" 5M Manual gate Kill line D 4 1/16" 5M Manual gate Kill line TOp of drill deck ('chevron RKB to TBG Hngr = 41.50' Tree connection: ?? ~ ~UU:l.J¡. ..~ -1 KB ELEV = 101' PBTD = 6,440' TD .::¡¡ 1û,1ôû' ANGLE thru INTERVAL = 8.50 Monopod A-II Current Schematic. doc ...':. SA . 24<1 '~,fTop ore ~2100' ~-"ì .,. , l~,1 t:.¡ ~ .". ',,:'? ~t' f' ;~. ~-~ . . Trading Bay Unit Well # A-ll Completed 10/88 CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm. Burst Cmt Cmt Top Rotate hrs 20" Y,"Wall H40 (risked) Weld Surf 228' 1750 20.5 13-3/8" 61# J-55 Butt 12.515" Surf 1085' 200 sxs Surf 3t4 9-5/8" 43.5 N-80 8rd LT &C 8.755 Surf 7092' 1050 sxs Stage Collar 3622.8' 1250 sxs See below 373 9-5/8" 43.5 N-80 8rdLT&C 8.755 Surf 7092' 1050 sxs Tubin!!:: 2-7/8" 6.4 N-80 Butt 2.441 Surf 4150' JEWELRY DETAIL L NO. DeDth ID Item 41.5' 10" x 4" Cameron 5M Tubin!! han!!er, XO to 2-7/8" Butt 1 293' 2.313 2-7/8" Otis, BV SSSV Nipple, 2 2153' GLV#1 BST GLM 3 3480' GL V #2 BST GLM 4 4041' GL V #3 BST GLM 5 4078' 2.313 Otis "XA" Slidin!! Sleeve 6 4109' 3.00 Locator Seal Assv. w/ 8' of seals. 7 4110' 4.75 Baker Model "D" Packer 8 4142' 2.313 Otis "X" Profile Nipple, 2.313 9 4149' 2.5 WLEG btrn 4150' Q~ \~ 4(Xj:)' 2004-2006 Wireline Summary Tag fill wit~ 2.25" GR at 5915' RKB l PERFORATION DATA Accum. Date Zone Top Btm Aml SPF Last Opr. Present Condition Soz Perfs 4192' 4194' 2' 4 4n3 Cmt Sozd f/ cso bond C·2 4,193' 4,233' 40' 8 5/4/98 Open f/ prod. C-3 4270' 4340' 70' 12 5/4/98 DDen 11 prod. C-4 4,376' 4,382' 6' 4 4/73 C-5 4471' 4476' 5' 4 4/73 C-6 4,560' 4,570' 10' 4 4/73 C-7 4638' 4713' 75' 8 5/4/98 DDen fl orod. Stray 4,819' 4,824' 5' 4 4/73 C 47-5 4850' 4 867' 17' 4 4/73 C 48-5 4922' 4944' 22' 4 4n3 C 48-7 4958' 4972' 14' 4 4/73 C 49-4 5056' 5,061' 5' 4 4/73 C5Q-3 5140' 5178' ! 38' 8 5/4/98 Doen I/orod. Saz Perfs 5505' 5506' l' 4 5/70 Cmt Sozd 11 csa bond D 53·0 5,570' 5,586' 16' 8 , 4/73 D 53-8 5600' 5652' 52' 12 5/4/98 Doen fl Drod. D 54-5 5,665' 5,710' 45' 12 5/4/98 Open fl prod. D 54-9 5742' 5769' 27' 4 5/70 D 55-7 5,802' 5816' 14' 4 5/70 D56-1 5856' 5941' 85' 16 5/4/98 Ooen I/orod. D57-2 5,975' 6055' 80' 8 5/4/98 Doen fl prod. Saz Perfs 6070' 6071' l' 4 5/70 I Cmt Sazd fl cso bond Saz Perfs 6410' 6411' l' 4 5/70 Cmt Sazd fl cso bond D FISWJUNK IN WELL 1979: GO Int. left a r.dioactive source in well.t 6693'. DO NOT DEEPEN BELOW 6500'. 1988: Has perf debri from Vann Gunns at 6404'. 9-5ì8" Cement Job ~""""\\c...\ \~-\-C ~\~~~\..t:. ~~\\ ',~ c...\ ~~~\~'\t,~s.~~(.~L."- ~O(t '> ~O -\- ~ () ",-<- 2700' 2830' Good emt (Top of Lo!!:) 2830' 3110' Poor emt 3100' 3700' Good emt 3700' 4056' Poor emt 4056' 4200' Good emt 4200' 5100' Poor emt 5100' 7092' Good emt REVISED: 2-8-07 SLT ALASKA OIL AND GAS CONSERVATION COPl~iSSION September 5,: 2001 Dwight Johnson, Superintendent Chris Meyers, Superintendent UNOCAL Field Superintendents 260 Caviar Street Kenai, Alaska 99611' TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: No-Flow Verification TBU Well A-11, PTD 170-024 Gentlemen: On April 26, 2001 AOGCC Petrole~Jm Inspector John Spaulding witnessed a "no flow test" on Unocal's Trading Bay Unit Well A-11. Mr. Spaulding arrived on Monopod Platform and found the well Shut in and ~epressurized as requested. Over the course of the three (3) hour witnessed period, test performance of TBU Well A-11, PTD 170-024 demonstrated no liquid and produced only a very slight gas. Therefore, this well need not be equipped .with a commission approved fail-safe automatic surface-controlled subsurface safety v~tlve ("SSSV") system. However, this well must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason this well becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board Monopod. Sincerely Thomas E. Maunder, PE Sr. Petroleum Engineer JMH:\jjc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor FROM: John H Spaulding, Petroleum Inspector DATE: April 26, 2001 SUBJECT: No Flow test Unocal / TBU Monopod Platform Well A-11 Ar)HI 26,. 2001, i traveled to Unocal's Monopod Platform to witness the No Flow test on . . well A-11. Prior to my ardval the well had been shut in and de-pressured as requested. An Armor flow meter was attached to the tbg to monitor flow. The flow meter can measure from - 100 standard cubic feet per hour (scfh) to 2000 scfh. A 5 gal bucket was used for monitoring for fluids. Initial reading: 9am Tubing: 10 psi Inner annulus (ia): 0 psi Flow rate: 550scfh No Liquids 9:10 am Tbg: positive IA: 0 psi Flow rate: 225 scfh Liquids: none 9:30 am Tbg.: positive IA: o psi Flow rate: 110 scfh Liquids: none 11 am Tbg.: positive IA: 0 psi Flow rate: 110 scfh Liquids: none Tbg.: positive IA: 0 psi Flow rate: 110 scfh Liquids: none 12 noon SUMMARY: I recommend well A-11 for No-flow status based on the observed test. Attachment: None No,n C, onfidential MEMORANDUM TO: THRU: Julie Heusser, ,~~\~o', Commissioner Tom Maunder, P. I. Supervisor o~1c~%'° \ State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 5, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field Thursday. A~)ril 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 I Witnessed the testing of 18 wells and 53 components, with four failures~ The pilot on well A-02 tripped at 26 psi and was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed. ! indicated to Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 SSSV failed to close and will require maintenance. Wells A-13 and A-21 have been certified as "no flow'' status and do not have SSSV's installed. While on location I inspected the platform and found it very clean and it appeared to be in excellent condition. Summary..: I witnessed the semi annual Safety Valve System testing at Unocal's Monopod Platform in the Trading Bay Field. Monopod Platform, 18 wells, 53 components. 4 failures, 7.5% failure rate. Platform inspection conducted. Att~..chment: SVS TBF Monopod Platform 4/5/01 JJ NON-C0NFIDENT..IAL SVS TBF Monopod Platform 4-5-01 JJ 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 J, Number Number PSI PSI Trip Code Code Code Passed GaSorC¥CLE A-01RD 1901470 65 45 42 P P P OI~ A~2 1660490 65 45 26 3 P '~43 4/5/01 OIL A-03RD3 1971300 65 45 42 P P P OI~ A-04 1670020 '' - A-06 1670250 65 45 45 P P '43 OI~ A-07 1670460 65 45 42 P P P OI~ A-09RD 181036'0 ' A-10 1670760 ~:,~,,-'. ,1700240 65 ~5 43 P P ~"~3 'oIL ~A-13 ,, 168Q020 65~ '45[ 41 P P oILI iA-14 1680270 , A-15 1680330 65: 451 45 P P P 'oIL A-16RD 1880380 65 45i41/42 P P 'P ' OIL A-17RD 1810670 65 45 43 P P P OIL ~-18 16807601 65 45 47! 'P P P OIL A'21 1700470~ 65 45' 46 P P ' 0iL [A-22 1700310: "65 45 44 P P P ' OIL A-23 1700590 A-23DPN 1720200 A-24RD 18!0400 65 45 4'1 P P P ' OiL A-27RD1 1970630 65 45 43~ P P p ' oIL A-28RD 1890920 65 45 45~ P P P oIL , , A-30 1730140 A-32 1770180 65 45 44! P P P OIL , ,, .~ Wells: 18. Components: 53 Failures: .... 4 Failurc Rate: 7.5% F'lg0Dav 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 Unocal North Americ;lg~ Oil & Gas Division ~ ~ Unocal Corporation '~ P.O. Box '190247 Anchorage, Alaska 995'19-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as.well as the Union Oil-operated Monopod and Granite Point .Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your,~needs. Yours very truly, GRaeg~o~~~l ~ i~~g ~a n~a g er GSB/lew APR 2 ~, 199('!" ~il & Gas ~n$o Oommlssbn / CONDUCTOR , l0 ll 12 13 14 15 16 17 18 19 20, 21 22 · .__.Z~. -~__ 24 25 26 27 28 29 3O 31 32 .MONOpOD CENTER FROM SOUTHEAST CORNER, SECTION 4, T9N, R13W "Y" : 2,523,126 "X" = 218,871 "Y" COORD. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,113.2 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133.8 2,523,137.6 2,523,138.8 2,523,138.8 2,523,137'.2 2,523,132.8 2,523,129.4 2,523,132.0 2,523,128.4 ..2,52.3,_'L~. _R .. 2,523,133.9 2,523,120.9 2,523,131.4 2,523,118.1 2,523,127.2 2,523,123.6 2,523,120.0 2,523,122.6 2,523,119.2 LAT. : 60°53' 48.65"'.~'oa~, LONG. 151°34, 4 3.51" ' ~,a'~,~o,~°'~ Oo,~ "X" COORD. WELL # FSL 218,880.9 A-28 1621 218,883.2 A-25 1617 218,883.9 A-30 1612 218,883.2 1608 218,881.3 A-27 1605 , 218,876.8 A-23 .1601 218,873.0 A-21 and RD 1600 218,869.0 A-22 1600 218,864.6 A-14 1601 218,861.1 A-1 3 1604 218,858.8 A-17 1608 218,858.1 A-8 1612 218,858.8 A-15 1616 218,860.7 A-24 and RD 1620 218,865.2 A-29 1624 218,869.0 A-9 and RD 1625 218,873.0 A-19 1625 218,877.4 A-18 1624 218,875.7 A-11 1619 218,878.6 A-3 1616 ,. 218,870.8 A-1 1618 218,873.9 A-7 1615 .~ ?.1 R. R?F~. 9 A-4 1611 218,867.0 A-6 1600 218,878.1 A-32 1607 218,863.9' A-12 and RD 1617 .218,875.0 A-20 1604 218,865.1 A-2 1613 218,868.1 A-16 1610 218,871.1 A-26 1606 218,863.4 A-10 1609 218,866,3 A-5 and RD 1605 1 &2 FEL 554 551 551 551 '553 557 561 565 57O 573 576 577 577 574 570 566 562 558 559 556 564 561 558 "568 556 571 559 570 566 563 571 568 J. STATE OF ALASKA t A .,A OIL AND GAS CONSERVATION COMMI ..JN REPORT OF SUNDRY WELL OPEF TIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing ~ Alter casing __ Repair well ~ Pull tubing 2. Name of Operator ! 5. Type of Well: Un.ton 0il Company of Cal±fornla (U~0CfiL) Development.~._ / Exploratory ~ 3. Addres~.o. BOX 190247, finch, fik., 99519-1247 StratigraphiC__service__ / 4. Location of well at surface 1619' N f 559'W from SE cot., Sec. 4, TgN, R13W, SM Perforate][~. Other __ 6. Datum elevation (DF or KB) RT 101' MSL 7. Unit o.r ProQerty me ~raozng ~ay State 8. Well number TBS A-il At top of p. roductive interval 4200' MD, 4064 At effective depth 6440' MD, 6295' TVD, At total d. eoth 10180' MD, 9928' TVD, TVD, 662' S & 600' W f/Surface Location 544' S and 743' W f/Surface Locatiol 271' N and 523' W f/Surface Locati, 9. Permit number/approval number 8-469 10. APl number 50-- 733-20214 11. Field/Pool in Middle Kenai "C" & "D' 12. Present well condition summary. Total depth: measured true vertical Effective depth: measured true vertical 10180 ' 9928' feet Plugs(measured) feet 6440 ' feet Junk(measured) 6295' feet Cem,e, nt P,l, ug 10180' - 7150' 6508 ' 6440 ' ' Fill and Junk 6802' - 6508' Casing Structural Conductor Surface Intermediate Production Liner Pedoration depth: Length Size Cemented 1085' 13 3/8" 675 sxs measured true vertical 7092 9 5/8' 800 sxs (lst) 850 sxs (2nd) See Attached Measured depth True vertical depth 1085' 1045' 7092 ' 6942 ' Tubing (size, grade, and measured depth) 2 7/8", N-80, 6.4fi/ft, 0-4150 ' Packers and SSSV (type and measured depth) OtisBakersssvM°del$ 293"'D" Perm Pkr. $ 4110' . R~c~V ED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure feet 14. Tubing Pressure Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 115 196 i600 349 i075 i030 Service Title Environmental Engineer 2OO Date02/3/89 Subsequent to operation 476 1600 672 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run C~BI,-VDI,-GRI Daily Report of Well Operations,~r i Oil xx Gas ~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed RC~ D. Rooer~s Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Zone C-2 8--3 C-4 8-5 C-~ C-7 Stray 47-5 48-5 48-7 50-3 53 -8 54-5 54-5 54-9 55-7 56-i 56-1 57-2 Perforating Detail Perforations Measured Depth 4196' - 4232' 4266' - 4310' 4311' - 4340' 4363' - 4386' 4468' - 4483' 4554' - 4570' 4643' - 47i5' 4819' - 4824' 4845' - 4867' 4917' - 4944' 4958' - 4977' 5056' - 5061' 5142' - 5177' 5566' - 5586' 5602' - 5655' 5667' - 5705' 5740' - 5770' 5796' - 5816' 5852' - 5899' 5906' - 5940' 5977' - 6055' Perforations True Vertical Depth 4060' - 4096' 4130' - 4174' 4175' - 4204' 4226' - 4249' 4331' - 4347' 4419' - 4433' 4505' - 4577' 4581' - 4586' 4716' - 4729' 4780' - 4806' 4820' - 4839~ 4917' - 4922' 5003' - 5038' 5426' - 5446' 5462' - 55i5' 5527' - 5564' 5600' - 5630' 5656' - 5676' 5711' - 5758' 5763' - 5798' 5835' - 5912' Feet 36' 44' 29' 15 ' 16' 72 ' 6' 22' 27' 19' 5' 20' 53' 38' 30' 20' 47' 34' 78 ' RECEIVED Alaska Oil ,& Gas Cons. Commission: STATE OF ALASKA ALASK~ 'IL AND GAS CONSERVATION COMMI~,[ q APPLlCAIlON FOR SUNDRY AP OVALS 1. Type of Request: Abandon [] Suspend E] Operation Shutdown [] Re-enter suspended well E] Alter casing Eli Time extension [] Change approved program [] Plugging I-I Stimulate [] Pull tubing ~ Amend order [] Perforate j~3 Other [] Name of Operator Union Oil Company of California Address P.O. Box 190247 Anchorage AK. 99519-0247 Location of well at surface 1619' N, 559' W F/SE Cor. Sec 4, T9N, R13W, SM At top of productive interval 4200' MD, 4064' TVD, 654' S, 600' W, from ~urfa~ce Locti At effective depth 6802'MD, 4064'TVD,654'S, 600'W, from Surface Location At total depth 10,180'MD, 9927'TVD, 302'N, 518'W from Surface T. ocation 5. Datum elevation (DF or KB) RT 101 'MSL feet 6. Unit or Property name Trading Bay State 7. Well number TBS A-il 8. Permit number · on 9. APl number 50-- 733-20214 10. Pool Middle Kenai "C" & "D" 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 1085 ' Intermediate Production 7092 ' Liner Perforation depth: measured true vertical 10,180' feet 9,927' feet 6,802 ' feet 6,651 ' feet Plugs (measured)cement P. lug 10,180'-7150' Junk (measured)Fill and Junk at 6802' Size Cemented Measured depth True Vertical depth 13-3/8" 675 sxs 9-5/8" 1st stage:800 sxs 2nd stage:850 sxs SEE ATTACHED 1085' 1045' 7092' 6942' Tubing (size, grade and measured depth) SS: 3-1/2", 9.3~'/,N-80 Butt. 0'-4100' LS: 3-1/2", 9.39/ N-80 Butt 0-4234' ..- 2-7f8'!, 6.M/.,]~-80 Butt-4100'-41A~.'~, 2-7 " ~- ' "5540'Szde String. 2-?/8 6 4~ N-80, Butt ~Ooo -4(65' 4102' .Brown Triple H~d., 5466' Brown "BD",LS: 302 'SSSV.~.,'SS:..3.03~vSSSV -" 12.Attachments .Description summary of proposal [] Detailed operations' program [] BOP sketch 13. Estimated date for commencing operation 7-15-88 14. If proposal was verbally approved Name of approver Su])sequeat: ~Vor]~ ~eportec] on Form No. . D~.ted__/--./-ig.ate approved 15. I hereby certify that the foregoing is true S, ne ,, Royj ~oberts Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 correct to the best of my knowledge ~.~6~itle Environmental Engineer DatP 6/16/88 ~ Commission Use Only Notify commission sp representative may witness I Approval No. [] Plug integrity ~i~r' BOP Test [] Location clearanceI Approved C,opy .Returned -- -- by order of ~ ~,.~<~,~ Commissioner the commission Date RECE]VE triplicate jdN 1 7 ]9o8 Alaska 0il & Gas Cons, Commission Anchorage PERFORATED INTERVAL MEASURED DEPTH TRUE VERTICAL DEPTH ZONE 4200' - 4232' 4270' - 4310' 4318' - 4336' 4367' - 4382' 4471' - 4476' 4560' - 4570' 4646' - 4707' 4819' - 4824' 4850' - 4867' 4922' - 4944' 4958' - 4972' 5056' - 5061' 5145' - 5166' 5570' - 5586' 5605' - 5652' 5672' - 5705' 5905' - 5940' 5981' - 6055' 4064' - 4096' 4134' - 4174' 4182' - 4200' 4230' - 4245' 4334' - 4339' 4423' - 4433' 4508' - 4569' 4581' - 4586' 4721' - 4729' 4784' - 4806' 4820' - 4834' 4917' - 4922' 5006' - 5027' 5430' - 5446' 5465' - 5512' 5532' - 5564' 5764' - 5798' 5839' - 5912' C-2 C-3 C-3 C-4 C-5 C-6 C-7 Stray 47-5 48-5 48-7 49-4 50-3 53-8 53-8 54-5 56-1 57-2 0570N RECEIVED JUN 1 7 !988 Alaska Oil & Gas Cons. Commission Anchorage ATTACHMENT SUMMARY OF PROPOSAL TBS - A-ii 1. Move in and rig up. 2. Kill well 3. Install BPV's, nipple down tree and nipple up the BOPE. 4. Pull and recover existing dual 3-1/2" completion. 5. Mill over and recover the Brown "BD" permanent packer at 5466'. 6. Run a bit and scraper and clean out to 6802'. 7. Run CBL-VDL-GR from 6800' to 3500'. 8. Reperforate the existing "C" and "D" presently open. 9. Run a single 3-1/2" tubing completion with a permanent packer set at + 4000'. 10. Rig down and move off. 0570N PRESENT MONOPOD PLATFORM.. %qCLL A-Il · PROPOSED TRIP, ~ 4~ 02 ~ ZOI~ n zo z , ~an4 ~p%h~ CZ 4200 = ¢:32 C3 4=10 ~ 4310, 40 · 4315 - 4330 ¢4 43~? - 438Z 45~0 - 4~70 4646 - 490? SI ' 4D)~ - 4624 4850 - 4a~? 40=7 4~58 - 4972 14 54-$ 660~ - 5652 54-5 5672 - 57[,$ 5G-~ ~OOO & 58~9 39 i $?-Z 5983 - 6055 74 41~$ - 4232 ~6 420; - 43~0 44 4311 - 43Z0 ~ 43~3 - 438~ 23 4643 - 4?IS 72 - 0 4~? - 6944 ~? 4958 - 49?? 19 - 0 ~66 - ~86 2O 5¢52 - 5705 53 58£2 - 5~99 47 , 4 4 8 -5 4 3 20 6 4 p~2 P~a. 411'I' CHOKE HYDRAULIC ' VALVE GATE MANIFOLD SEE DRAWING TO MUD PUMPS & CEMENT UNIT ANGLED FILL UP LINE HYDRIL PIPE RAMS GATE PIPE RAMS H II __ _ GATE GATE KILL LINE FROM MUD PUMPSi & CEMENT UNIT BLIND RAMS CONTRACTOR FURNISHED OPERA TOR FURNISHED WELL NAME: RIG CONTRACTOR: RIG: STACK PRESSURE RATING: CHOKE LINE SIZE & MSP: NOTES: 1. HYDRAULIC VALVES OPEN AUTOMATICALLY WHEN DIVERTER IS CLOSED. 2. FLEX HOSE (~/~) IS TO BE USED iF NECESSARY WITH DDS" APPROVAL. NOTE: ALL CHANGES MUST HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT DEPT. APPROVAL RECEIVED ..1tIM t 7 1988 Alas?,a Oil & Gas Cons, Commission DATE 13 5/8" BOPE STACK 5M OR 10M ALL WORKOVER OPERATIONS UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, /~LASKA DRAW. BHE CKD. CGN APP'D. SCALE NONE [;)ATE 6/26/85 S.Eds ?'~.~T .WALL 8'43/4· 8WACO CHOKE T To Panel · 18' 31/2- 8w^co CHOKE 1'o BOPE 13'9 STATE OF ALASKA ALA~'~' ' OIL AND GAS CONSERVATION COMM~~ 'ON APPLlCA. ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F'] Suspend F'] Operation Shutdown f-] Re-enter suspended well [] Alter casing E] Time extension E] Change approved program E] Plugging 12] Stimulate ,"] Pull tubing ~ Amend order r-I Perforate ~ Other [] 2. Name of Operator Union Oil Company of California "3. Address P.O. Box 190247 Anchorage AK. 99519-0247 4. Location of well at surface 1619' N, 559' W F/SE Cdr. Sec 4, TgN, :R13W, SM 5. Datum elevation (DF or KB) RT 101 'MSL 6. Unit or Property name Trading Bay State 7. Well number TBS A-11 - At top of productive interval 8. Permit number 4200' MD, 4064' TVD, 654' S, 600' W, from ~urfa~e Loct~an' At effective depth 9. APl number 6802'MD, 4064'TVD,654'S, 600'W, from Surface Location 50--733-20214 At total depth 10. Pool 10,180'MD 9927' ' ' , TVD, 302 N, 518 W from Surface Location Middle Kenai "C" & "D" feet 11. Present well condition summary Total depth: measured true vertical 10,180' 9,927' Effective depth: measured 6,802 ' true vertical 6,651 ' Casing Length Size Structural Conductor Surface 1085 ' 13-3/8" Intermediate Production 7092' 9-5/8" Liner Perforation depth: measured true vertical feet feet feet feet Plugs (measured)cement Plug 10,180'-7150' Junk (measured)Fill and Junk at 6802' Cemented Measured depth True Vertical depth 675 sxs 1085' 1045' 1st stage:800 sxs 2nd stage:850 sxs 7092' 6942' SEE ATTACHED Tubing (size, grade and measured depth) SS: 3-1/2", 9.3#,N-80 Butt. 0'-4100' LS: 3-1/2~', 9.3# N-80 Butt 0-4234' ?-7/-8", 6.4#.~-80 Butt- 4100'-4141'~ ~ . 2-7/8" A .4ff. N--A~ 'R~,~-~-. A~..,, 5540' Side String: 2-7/.8 6.4~ N-80, But.t /-+U.1~'-4( ~'acKers add"SE~SV"('ty-'~'e ~'h-d°mea's'rJred Cel~l'1') - ,,. ,. , , 4102' .Brown Triple ,yd., 5466' Brown "BD",LS: 302 SS~!f~S:~3~S~540!' ' · : 5' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketcl3 ~ 13. Estimated date for commencing operation 7-15-88 14. If proposal was verbally approved Su~)sequeat '~or~ Heported on Form No Dated__/~/__ Name of approver Date approved 15. I hereby certify that the foregoing is true Roy ¢oberts Commission Use Only Date 6/16/88 Conditions of approval Notify commission so representative may witness [] Plug integrity "~BOP Test f-; Location clearance Approved Copy Returned _,., Approved by 10NNIF C. SMITH Commissioner Approval No. by order of the commission Date Form 10-403 Rev 12-1-85 Alaska Oil & Gas Co~s. C..,,,,,,=ok, n A,,~lu, aue PERFORATED INTERVAL MEASURED DEPTH TRUE VERTICAL DEPTH ZONE 4200' - 4232' 4270' - 4310' 4318' - 4336' 4367' - 4382' 4471' - 4476' 4560' - 4570' 4646' - 4707' 4819' - 4824' 4850' - 4867' 4922' - 4944' 4958' - 4972' 5056' - 5061' 5145' - 5166' 5570' - 5586' 5605' - 5652' 5672' - 5705' 5905' - 5940' 5981' - 6055' 4064' - 4096' 4134' - 4174' 4182' - 4200' 4230' - 4245' 4334' - 4339' 4423' - 4433' 4508' - 4569' 4581' - 4586' 4721' - 4729' 4784' - 4806' 4820' - 4834' 4917' - 4922' 5006' - 5027' 5430' - 5446' 5465' - 5512' 5532' - 5564' 5764' - 5798' 5839' - 5912' C-2 C-3 C-3 C-4 C-5 C-6 C-7 Stray 47-5 48-5 48-7 49-4 50-3 53-8 53-8 54-5 56-1 57-2 0570N ATTACHMENT SUMMARY OF PROPOSAL TBS - A-Ii 1. Move in and rig up. 2. Kill well 3. Install BPV's, nipple down tree and nipple up the BOPE. 4. Pull and recover existing dual 3-1/2" completion. 5. Mill over and recover the Brown "BD" permanent packer at 5466'. 6. Run a bit and scraper and clean out to 6802'. 7. Run CBL-VDL-GR from 6800' to 3500'. 8. Reperforate the existing "C" and "D" presently open. 9. Run a single 3-1/2" tubing completion with a permanent packer set at + 4000'. 10. Rig down and move off. 0570N CHOKE MANIFOLD SEE DRAWING HYDRAULIC - VALVE GATE TO MUD PUMPS & CEMENT UNIT ANGLED FILL UP LINE HYDRIL PIPE RAMS PIPE RAMS GATE GATE K ILL LINE ROM MUD PUMP & CEMENT UNi' BLIND RAMS CONTRAdTOR FURNISHED OPERA TOR FURNISHED WELL NAME: RIG CONTRACTOR: RIG: STACK PRESSURE RATING:, CHOKE LINE SIZE & MSP; NOTES: 1. HYDRAULIC VALVES OPEN AUTOMATICALLY WHEN DIVERTER IS CLOSED. 2. FLEX HOSE (~?/) IS TO BE USED IF NECESSARY WITH DDS" NOTE: ALL CHANGES MUST HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT APPROVAL. DEPT. APPROVAL REV. i DATE B,A,W,; 6/17/86 ALL 13 5/8", BOPE STACK 5M OR 10M WORKOVER OPERA~' IONS UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, /IL/1SKA DrAwn BHE C~D. CGN APP'D. SCALE N 0 N E DATE 6126/85 SHEETS I SHEET PRESENT --_. PROPOSED TRIP. PKR, ~ 4102':" "C ZON~ ~-3/8", 6~#, J.S5 ¢~g. ~ ~Serfor~,l~nw C3 4:tO ~ ~010. 40 · ¢4 4387 - 4~82 15 ¢~ .4471 - 4478 C~ 45~0 - 4~?0 10 401~ - 4824 5 4~~5 ~9~Z ~ 4~44 22 40-? 4~$~ - 4972 14 :54-$ 56?2 - 57£'5 j $7-2 ~SSI - ~055 74 C2O~ - 4~10 44 4 44~8 - 44~3 :~ 'O ~$BO - ~570 lO 0 46¢3 - Bl~2 55C6 - ~58G 20 4 5~{~2 - bG~2 50 3 5¢52 0 120 P:"RLt. PKR. 0 4111' .._ 10' VENT -- .WALL 8WACO CHOKE 8'43~. 2 To Chok Pa~el To aOP£ DWACO CIIOKE 13' L STATE OF ALASKA ALAS '~-iL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator UNZON 0IL CONPANY OF CALIFORNIA 3. Address PO BOX 62~7 ANCHORAGE AK 99502 4. Location of Well 1619'N & 559'W from the SE corner, Section 4, TgN, R13W, SH. 5. Elevation in feet (indicate KB, DF, etc.) 101' RT above MSL 6. Lease Designation and Serial No. ADL 18731 7. Permit No. 70-24 8. APl Number 50733-2021400 9. Unit or Lease Name TRADING BAY STATE 10. Well Number TBS g-ll 11. Field and Pool TRADING BAY FIELD "D" Zone 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~' Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following sands were reperforated $ 2 HPF: RERFORATIONS SAND INTERVALS 5570 - 5586' 53-8 16 5605 - 5652' 54-5 47 5672 - 5705' 54-5 33 5742 - 5769' 54-9 27 5920 - 5940' 56-1 20 5981 - 6020' 57-2 39 RECEIVED MAY 1 4 19 ]4 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certif~"-thaj;/th'~ foregoing is true and correct to the best of my knowledge. SignedC~_ ~~ TitleDistrict Engineer The space below for Commission use 5/11/84 / / Conditions of Approval, if any: Approved by ,, Form 10-403 By Order of COMMISSIONER the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALAS ,.iL AND GAS CONSERVATION ..,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator UNION OIL COHPANY OF CALIFORNIA 3. AddresSpo BOX 6247 ANCHORAGE AK 99502 4. LocatioQ of Well 1619'N & 559'W from the SE corner, Section 4, T9N, R13W, SN. 7. Permit No. 70-24 ~;*_P~-~b21400 9. Unit or Lease Name TRADING BAY STATE 10. Well Number TBS A-il 1 1. Field and Pool TRADING BAY FIELD 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 101' RT above MSL I ADL 18731 "D" Zone 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) · Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any' proposed work, for Abandonment see 20 AAC 25,105-170). It is proposed to reperforate the following intervals: PERFORATIONS SAND INTERVALS 5570 - 5586' 53-8 16 5605 - 5652' 54-5 47 5672 - 5705' 54-5 33 5742 - 5769' 54-9 27 5802 - 5816' 55-7 14 5860 - 5899' 56-1 39 5905 - 5940' 56-1 35 5981 - 6020' 57-2 39 25O ECE VED FEB 1 61984 ~.o~ No. !~ J ...... ~. ~; 3 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,.~~ - Tit,e District Engineer The space below for Commission use , Date 2/14/84 Conditions of Approval, if any: Approved by. 9t' LI]N~I[ C. $1tlTIJ Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate '"f STATE OF ALASKA ' ALASK~ J~L AND GAS CONSERVATION G~,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLY/~I OTHER [] 2. Name of Operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 70-24 3. Address 8. APl Number P. O. Box 6247, Anchorage, Alaska 99502 5o-133-20214 4, Location of Well 1619' N and 559' W from SE corner of Sec. 4, TgN, R13W, SN. 5~ ELevatioain feet (indicate KB DF, etc.) Ol' RT above NSL ' 6. Lease ~gna~i~l Serial No. 9. Unit or Lease Name Tradi~ Bay State 10. Well Number A-11L 11. Field and Pool Trading Bay D-Sand 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: bruit in Duplicate) Altering Casing [] Abandonment [] Other [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were reperforated August 26, 1980: Sand Perforations 53-'8 5570' - 5586' 54-5 5605' - 5652' 54-5 5672' - 5705' 54-9 5742' - 5769'' 55-7 5802' - 5816' 56-1 5860' - 5899' 56-1 5905' - 5940' 14' l hereby ceB~/~°ing is true and c°rrect t° the best °f my kn°wledge'.. Signed C~'/ ~~..... ~? ~ Title District Fnofneer The space be~.vv f~;~r.C(:~W~ion use Date March '2]; 1983 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ir] Duplicate February 16, 1953 Union Oil Company of .California P.O. Box 6247 ~chorage, Alaska.9 9502 Re, Subsequent Reports, Sundry Notices and Reports on Wells (Form 10-403 } For the following lists of "Notice of Intention To:" Sund~--y ~otices and Report on Wells (form 10-403) this office does not have on record the "Subsequent Report of~" defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. ~el I UDion Date Brie..f. Description .of.. Intention TBU G-~RD 10/1/80 TE.U G-SRD 10/1/80 TBU G-2 3RD 10/1/80 TBU A-11L 10/1/80 TBU F.-4 PD 11/6/~0 GPS 33-14RD 2/11/81 EBU 13-~ 6/1/~1 TBU D-9 6/8/81 TBUS C-27 11/25/81 TBUS G-6 1/20/~2 TBU D-6 RD 3 / 1 $ / 82 TBU G-7 4/21/82 TBUS G-2 5/24/82 TBUS ~-3 6/30/E2 K-1PD 7/14/82 Re~:erforate C-3, C-4 Reperforatu B-l, B-2, Reperforate B-5, B-l, B-4 Reperforate Reperforate Perforate B zone Clean out, reperforate. Plug & abandon for sid. etrack Puli tubing, reperforate Squeeze cement to abandon hemlock Change kickoff point Reperforate Revise setting abandonment retainer Repair casing Perforate LCSIJKT/g lh Form 10-403 REV. 1-10-73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL L---I OTHER 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR P.O. Box 6247, Anchorage, AK 99502 i5. APl NUMERICAL CODE ~ 50-133-20214 ~ 6. ~EASE DESIGNATION ANO SERIAL NO. ADL 18731 ~C/~ 4. LOCATION OF WELL At,~ace 1619' N and 559' W from SE corner of Sec. 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) lOl' ET above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 7. IF INDIAN, ALLOTTEE OR TRIBE NAME .//~/ 8. UNIT, FARM OR LEASE NAME Trading Bay State ~ 9. WELL NO. TBS A-11L 10. FIELD AND POOL, OR WILDCAT Trading Bay - D Sands 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, E13W, S.M. 12. PERMIT NO. 70-24 )ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF ' PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) R~p~f ~ist, ing inte~wl q SUBSEQUENT REPORT OF= WATER SHUT-OFF [~ REPAI RING WELL FRACTURE TREATMENT~.~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEs Report results of multiple completion on Well Coml~letion or Recompletion Report and Log form.) 1.5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertln®nt ~letalls, and give pertinent dates, including estimated date of starting any proposed work. We propose to reperforate the following intervals. Sand Perforations 53-8 5570 - 5586 54-5 5605 - 5652 54-5 5672 - 5705 54-9 5742 - 5769 55-7 5802 - 5816 56-1 5860 - 5899 56-1 5905 - 5940 Work Beporter~ 16. I hereby certify that the foregoing is true and correct SIGNED ~ TITLEDistrict Engineer CT H. CASE (This space for State office u ~ . " ~ COMMISSIONEB APPROVED BY ~- -'.-~-~,~ '.~''4~'~vv TITLE CONDITIONS OF APPR~)~VAL, IF AN~/~: DATE lO/1/8o See Instructions On Reverse Side DATE · Form ~0-403 ( Submit '1 ntentlons" In Triplicate & REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF A~S~ 5. APl NUMERICAL CODE OIL AND GAS CONSERVATION COMMI~EE 50_133_20214 6. L~SE DESIGNATION AND SUNDRY NOTICES AND RE~RTS ON WELLS (Do not u~ this fo~ for pr~osals to drill or to d~en U~ "APPLICATION FOR PERMIT~' for ~ch propo.l~) ADL18731 WELL~ WELL OTHER UNION OIL CO. OF CALIFORNIA T~AnTN~ RAY ~TATF ~ ADDR~5 OF OPERATOR 9. WELL NO. P.0. B0~_~247. ANCHORAGE. ALAS~ 99502 TBS A-11 4. LOCATION OF WELL [0. FIELD AND~OL, OR At su~ace i TRADING BAY - 1619' N & 559' W from SE corner of Sec 4 T9N, R13W,S M ~. S~C.,T.,,.,~..mOTTO~,O":~"=~=,~ SEC. 4, T9N, R13W,S.M. ~2. ~L~VATIONS(~ho~helheFD~, ~T,~,el~} 1~. P~IT NO. 101' RT Above MSL 70-24 --. 14. Check Appropnate Box To Indicate Nature of Notice, Report, or O'ther Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) SUBSEQUENT REPORT OF: MULTIPLE COMPLETE F.L/~AI~TJ.I.R_E_TREATMENT ALTERING CASING ABANDON* _ __ (~ ......... ABANDONMENT* CHANGE PLANS (Otb.r) See Bel0w (NOTEs Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. ACID SOLVENT "ASHED ALL "C" AND IlDU ZONE PERFS IN TBS A-11 AS FOLL C£1VED l. Removed tree, installed and tested BOPE. 2. Pulled and layed down existing dual 2 7/8" production equipment!~, 3. Cleaned out with 8 1/2" bit and 9 5/8" csg. scraper to ETD of 6802~. . Acid solvent washed "C" and "D" perfs 6025' to 5981', 5940' to 5905', 5899' to 5860' 5816' to 5802' , , and 5769' to 5742',5705' to 5672', 5652' to 5605', 5586' to 5570' with 20 gal/ft. 5% HCL, 7% Mutual solvent, .4% A-170, .5%'W-35. 5. Cleaned out with 8 1/2" bit and 9 5/8" csg. scraper,to ETD of 6802'. 6. Ran dual 3 1/2" completion assy. with perm. pkr. at 5470'm~cl %~i13:Le 13t~ e4102' 7. Removed BOPE, installed and tested tree. e 16. I hereby certify that the foregoing is true and correct ~ o~m ~. ~-~-~,u~' \ ........ (This space for State office use) ~ APPROVED BY ' T IT LE ~ /CONDITIONS OF APPROVAL, IF ANY.. ~e Instructions On Revere Side Put well on .qas lift production~ producin§ from "C" and "D" sands. DATE :]_0/2.5/78 DATE P~.%. ~- 1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 4. LOCATION OF WELL 1619' N & 559' W from SE corner of Sec. 4, T9N, R13W, S.M. 5. APl NUMERICAL CODE 50-133-20214 . T' -. ":" ?: 6. LEASE DESIGNATION AND SEI~iAL NO. -- ; ADL 18731 ~ =~': _._~_ .... . -o · 8. UNIT FARM OR LEASE NAME.__.'. TRADING BAY STATE ~'~ 9. WELL NO. ~ * S .~ , TBS A-11 =. ..... "' ...... 10. FIELD AND POOL, OR WILDCAT ' ' TRADING BAY -'I~I'""ID'?'~; :' sANDaLS · ~.~ '~ '' '- ' "i-" 11.SEC. T. R. M. (BOTTOM HOLE _ OBJECTIVE) - Sec. 4, TgN, R13W,S.H. 12. PERMIT NO. 70-24 e 0 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JoBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. ~ i . 9/17/78 lO,180' TD 6775' ETD (fill) 9 5/8"@7093' 13 3/8"@1085' Co~t~ued .ope.Fat,ion ~)200 Hrs. (Noon) 9/17/78. Moved Moved rig f~o~.:~BS~'#A~32i~:~ TBS #A-11. R.U. & pulled ball valves i~6'~E:~;~S. & S.S. tbg. Bullheaded tbg. string w/81# CACL2 & circ. csg. ann. well dead. 9/8/78 lO,180' TD Installed back press valve. Removed tree, installed 6867' ETD .BOPE. Pulled all 4 gas lift valves from Short String. (cmt. ret.) Cut S.S. at 4089', 6' above dual pkr. Circ. BTMS up 13 3/8"@1085' thru S.S. Pulled & L.D. 2 7/8" S.S. compl assy. Pulled ~' 70,000# over string on L.S. and pulled dual pkr. loose. Circ. btms up thru L.S. 9/19/78 10,180' TD Circ. & spotted Safe Seal Pill. POOH. Pulled & L.D. 6802' ETD 2 7/8" compl Assy. RIH w/ Tri-State Pkr. Picker & (fill w/junk) Mill & cut over pkr. at 5488'. POOH w/ Pkr. RIH to 6867' ETD 6802' w/ 8 1/2" bit & 9 5/8" csg. scraper. (Found fill (cmt. ret.) w/ junk on top). Circ. clean. 9/20/78 10,180' TD RIH'w/ Baker retrievamatic and set @4136'. Tested 9 5/8" 6867' ETD ~g. to 2000 psi above ret. POOH. RIH w/ Baker ret. (cmt. ret.) BP and set @1000' Removed BOPE and changed DCB 9 5/8"@7093' spool from 10" 3050# to 10" 5000# and tested. Replaced 13 3/8"@1085' and tested BOPE to 2500 psi. RIH to pick ret. BP. Gas below BP Circ. out at 1000' PU BP and RIH to 6712'.. Circ- out gas cut mud ~d raised mud wt. frOm 72# to 78 PCF. 14. I hereb~rce~ffy that. the~t~regaing ~s true and correct SIGNE, i~V--_~,,~-~,-~ ~.~-~/'~'~--~---~---~ TITLE DISTRICT DRILLING SUPT, DATE 10/17/78 N(~'E-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. e 9/21/78 9/22/78 9/23/78 lO,180' TD 6867' ETD (cmt. ret.) 9 5/8"@7093' 13 3/8"@1085' Mixed mud. Built wt. to 78 PCF. POOH w/ ret. BP. PU Baker circ. washer. RIH to 6030'. Circ. hole volume. Acid washed "D" zone perfs w/20 gal per ft. 5% HCL w/ 7% Solvent. lO,180' TD 6867' ETD (cmt. ret.) 6802' ETD 9 5/8"@7093' 13 3/8"@1085' Acid washing "C" Zone perfs. lO,180' TD Finished washing "C" zone perfs w/20 gal/ft. 5% 6867' ETD HCL, 7% sol vent. POOH. L.D. wash tools. CO to 6802' ETD 6802' ETD w/bit & scraper. Ran gage ring and junk 9 5/8"@7093' basket to 5600'. Set Brown "BD" perm pkr. on W.L. 13 3/8"@1085' at 5470'. RIH w/seal on DP and tested "BD" pkr. at 5470' to 500 psi. - OK. (Acid washed perfs 6025' -5981' 5940'-5905' ,5899'-5860' ,5816'-5802', 5769'-5742' ,5705'- 5'672', 5652'-5605', 5586'-5570', w/5355' gal 5% HCL~) 1 e 9/24/78 9/25/78 10,180' TD Ran dual 3 1/2" compl assy. Landed w/long string 6867' ETD muleshoe 5540' "XN" at 5508' "XA" @5430' 4200' 6802' ETD 4061'. Seal a~d locator sub at 5465'. Triple pkr. 9 5/8"@7093' ·4102'. Ball valve at 303' Short string, muleshoe 13 3/8"@1085' 4142' "XA" 4064 triple p~r. 4102' ball valve 303' , , * , Top of 1 1/2" string at 4056', BTM at 5435'. Spaced out and set triple pkr w/3700 psi. Tested pkr w/500 psi - ok. Opened "XA" in long string 5430' & 4061.'. lO,180' TD 6867' ETD (cmt. ret.) 6802' ETD 9 5/8"@7093' 13 3/8"@1085' Installed back pressure valve. Remove BOPE. Installed and tested tree to 5000 psi O.K. Changed over to FIW. Closed XA at 5430' and 4061'. RU to move to TBS A-10. Released rig at mid 9/25/78. Form 10-403 REV. 1-10-73 Submit "Intentions" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) O,L ~ GAS F-I WELL"' WELL'' OTHER NAME OF OPERATOR Union Oil 'Company of California ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL At surface 1619'N & 559'W from SE corner of Sec. 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) I DI' RT a hnvP M.ql Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 50-133-20214 6. LEASE DESIGNATION AND SERIAL NO. APL ]8731 7. IF INDIAN, ALLOTTEE OR '~RIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. TBS A-11 10. FIELD AND POOL, OR WILDCAT Trading Bay - "C" & "D" sands 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) .Sec. 4, T9N, R13W, S.M. 12. PERMIT NO. 70-24 )ort, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) See hel ow SUBSEQUENT REPORT OF.' WATER SHUT~)FF F"--I REPAIRING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE~ Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ali 13ertlnent details, and give pertinent dates, Including estimated date of starting any proposed work. To acid/solvent wash all of 5% HCL and 7% solvent· PROCEDURE' · 2. 3. 4. 5. 6. 7. 8. "C" and "D" Zone perforations in TBUS A-II, with a mixture Move rig over A-11 and rig up. Remove tree, install and test BOPE. Pull and lay down existing dual 2 7/8" production eqUipment. DA,iaio.~ Clean out to ETD with bit andscraper. · Ac~d/so]Ven[ wash all "C" and "D" perforations w~th 5% HCL and 7% Run dual 3 1/2" production equipment· Remove BOPE, install and test tree· Put well on gas lift production, producing from "C" and "D" sands· ESTIMATED STARTING DATE' September ll, 1978 ESTIMATED OPERATING TIME- 16 days I hereby certJfy that the foregoing is true and correct Dqst Drlg upt. (This ~i~ace for State Office use) ~ /' / ......... cONDITIONS OF ~ROVAL~F, ANY: TITLE. , ~ ~ .. See Instructions On Reverse Side 7/25/78 DATE Union Oil and Gas Division' Western Region Union Oil Company .~alifornia P.O. Box 6247, Ancl~orage, Alaska 99502 Telephone: (907) 276-7600 un.l n August 9, 1978 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99510 Dear Mr. Hamilton' Transmitted for approval and information .are the following duplicates .of State forms that were not received 'in your office via our, transmittal of July 26, 1978' TBUS G-12RD-2 Completion Report Subsequent Abandonment Sundry Notice ~ TBS A-32 Sundry Noti.ce II II II II TBS A-14 " " Sincerely yours, '~'im~R. Callender Dist. Drlg. Supt. . . . . ... ~ ~ 70 Harry Kug let Divs. of Oil and Gas State of Alaska From G. H. Laughbaun .,'u'~chorage District Tr:)nsm~it~n¢l ~h,~ fo~ Iow; ~f~: ._. I ilea 2" Seoia and Eiue-:-:~ ?:~ DiL TBU D-Si :'(32X-6) ~o" Scnia and Sluel. ine ~,'~' DiL ..... ~se ..i-i~, _.,q-' Surveys TBS A- 22 __.:. ~rectiona! ............................. (44-4)! ,iease ac..,::zc'.:ied" 3 -','~ '"e.i ' ...... : return -i!;::c..'/ - *"' '~': ..... ~- ,.',- .... 2czion copy to Union., ..... & Gas T_,':i. vis:~o:a -.: - _ . - -,, ........................ ._...,,._--_- ~-~,,-- .. _.--. Oi%L 0i2 ,~O;i;'::;:,:.;i :," 0 f: i~&iS_ZO~:'ill~i · ,, ¢:,i~,-~:~ o-~-X ~3~-~;:'.f:~' ;-::-~':~ a 9'9'5'03' !~: 369 .Rev 12,'67i l~rm No. ~'v. ~-~ STATE OF ALASKA SVB~T ~ m~PLICA~ ~, API NI~IEHICAL CODE OIL AND GAS CONSERVATION COMMITTEE S0-i33-20214 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 6. LE~SE DESiGNAi'ION AND SE1RIAL NO. ADL - 18731 1. ?. IF INDIA]~, ALOTTEE OR TR1BE NAME OILwELL ~-~ GASWELL [] o,,,R Injector NAME OF OPEP. ATOR lJ~ion Oil Company of California ~. ~DRESS OF 909 ~'est 9th Avenue ~ Anchorage, Alaska 4. LOCATION OF W~ Conductor #19, 1619'N ~ ssg'w from the S. E. corner. Section 4: TgN, R13W, S. M. 8. L~IT,F.:ul~ OR LEASE N~E Trading Bay State 9. WELL NO. A-II 10. F~ ~k-WD POOJ~..~OR WILDCAT ' H. S~C.. T., R., M.. (~O~OM 0~~ Section 4: T9N, R15W, S. M. 12. PIglllVIIT NO, 70-24 REPORT TOTAL DKPTH AT END OF MONTH, CI-L~N'GES IN HOLE SIZE, CASING AND C]~VIENTING JOBS INCLUDING DEPTH SET AND VOLLrNIES USED, PERFORATIONS, TESTS ANT) RESULTS, FISHING JOB~, JLrNK IN HOLE AND SIDE-TRACKED HOLE AAFD ~NY OTHER SIGNIFICA_NT C}IA/~GES IAI HOI~ COiXrDITIONS. Moved rig over A-il MD, 4/16/73. Unable to 'open sleeve above Otis RH-1 hydraulic packer at 5440' Perforated tubing w/ 4 holes at 5458'. Displaced tubing and casing annulus ~/ 72# cu. ft. invermul. Installed back pressure valve. Removed x-mas tree, installed and tested BOP's. Pulled and laid down all 2 7/8" N-80 Seallock tubing and accessories. Ran Schlumberger ~-CBL from 6100' to 4000'. Bonding poor at ., base of productive "C" zone. Set Halliburton RBP at 5400', tested to 3500 psi~ and R~rS tool at 538~'. Displaced inver~lw/ filtered Inlet water. Reset RTI'S tool at 5290'. Dumped 15 ft~ sand on top of RBP. Reset RTTS tool at 5025'. Ran Schlumberger 2 1/16" scallop gun thru 5" drill pipe. Perforated 4 holes from 5174' to 5176' . Squeezed to a final pressure~of 4400 psis. w/ 1~5 sx cement outside casing. Reset R/rs tool at 4033'. Perforated as before w/ 4 holes from 4192' to 4194'. Squeezed'w/300 sx "G" cement to a final pressure of 1800 psi. Drilled out cement and tested from 4192' to 4194', squeeze w/ 1800 psi over 72# cu. ft. mud and 5174' to.5176f, squeeze w/ 1800 psi as before. Cleaned out to bridge plug and retrieved saul. Reperforated "D" zone and added "C" zone perforations as follows: SAND INTERVAL FEET U~- 4~br4l~ C-3 4270-4310 40 = 4367-4382 15 C-5 4471-4476 5 ~ ~,~,.~ 4560-4570 10 C-7 4646-4707 61 stray L~l'/'i~i,~,~.~ ,,i"ClJ~ /.H~ ~A~ 4819-4824 5 47-5 A~qC?JC>~A©!] 4850-4867 17 48-5 '4922-4944 22 48-7 4958-4872 14 49-4 5056-5061 5 50-5 5145-5166 21 Fcn-m No. P--4 ~EV, B- 1-70 SUBMIT IN DIJP~CA~ OIL AND GAS CONSERVATION CON~I'I-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Injector 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 4. LOCATION OF WELL Conductor #19, 1619'N ~ 559'W front the S. E.corner. Section 4' T9N, R13W, S. M. ~'~'Pi NI/~IERICAL CODE ,50-133-20214 6 LEASE D~iGNA~ON AND S~IAL NO. ADL - 18731 ? IF INDiAI~. ALOTTEE OR TRIBE NAME 8. L.~IT F.a~.A{ OR LEASE NAME Trading Bay State 9 \¥":~-L NO A-Il (44-4) 10. I~'~ A_ND POOL. OR WILDCAT Trading Bay Field. I1. SEC., T.. R., l~i.. (BOTTOM HOLE oB.mcTrv~_.) Section 4' T9N, R13W, S. M. 1~.. PEP, MIT NO. 70-24 13. REPORT TOTAL DKPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PERFORATIONS. TESTS ANT) RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLI[I COI~DIT!ONS. "C" POOL TOTAL 265' SAND INTERVAL FEET 55-8 5605-5652 47 54-5 5672-5705 33 56-1 5950-5940 35 "D" POOL TOTAL 131' ,Ran guage ring and junk basket on wireline to 6735' Ran 9 5/8" x 4 1/2" ID Guiberson permanent packer set at 5480'. Ran dual ~ 7/8" tubing strings w/ Guiberson RH-2 (dual) hydraulic packer. Tested permanent packer. Landed tubing w/ back pressure valve. Displaced invermul w/ diesel and atten~ted to set packer. Unable to set hydraulic packer. Pulled dual tubing strings and re-ran as before w/ Baker 3 1/2" x 3 1/2" X 9 5/8" dual A-5 hydraulic packer. Set Baker packer at 4097'. Tested packer. Set gas lift valves and ball valve. Placed well on gas lift for production testing. Rig released at 4/24/73. s,a~-----__~-- 'i~' ~u?= District Drlg. Supt. D^~ ~,.~y 4, 1973. , // ,ilm - : ..... ~OTE --Repor~ on ~hi~ form is required for ,each calendar ~nth~ regardless of Ihs sl~us of operations, amd mus~ ~ filed ~n duplicate ~i~h oil and gas consorvotlon commiflee bythe 15~ of the luccNding mon~, unle~ otherwise directed. STATE OF ALASKA ~i AP! NUiVIEI~CAL CODE OIL AND GAS CONSERVATION COMMITTEE $0-133- 20214 J Use "APPLICATION 'FOR ~'ER~IT--" .... 'pr~osals.) ~'OILw,LL C 0*Bw,LL ~ OTHER Injector APR ~ 0 ~g~'~3 ~ ?. IF INDIA.N. ALLOTTEE OR TRiBEi~EoL 2. NAME OF OPERATOR Union 0il Company of California DIVi$1 .... i', =-. r. ~ i~ ,.,N~ ~A~ s. ~.~,~ o~ L~s~. ~,~.: ...... . ...... , Trading Bay State '--~ DR^F? 3. ADDRESS OF OPERATOR ~1%1~,~r]~%,~[~/~ 9. V~L NO. 909 West 9th Avenue, Anchorage, Alaska A-11 (44-4) 4. LOCATION OF WF~L 10. FIF_J~ ~ POOL, OR WIL~DC At sur£ace Conductor #19, 1619'N & 559'W from S. E. corner. Trading g~v Pimld Section 4'. T9N, R13W, S.M. n. S~-O.,om~.c~VE,T., ~., ~.. r~o~o~ ~O~ Section 4' TPN, R13W, S. M.. 13. ELEVATIONS (Show whether DF, ET, GR, etc. 12. PE~T ~O. RT 101' above MSL. 70-24 14. Check Appropriate Box To I,ndicate Nature of N~ti'ce, Re, x)r~, or Other Data NOTICE OF INTENTION TO: TEST WATER BHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE J J ABANDON* REPAIR WELL CHANGE PLANS SUBSEQUENT REPORT OF: WATER SItUT-OFF J J REPAIRING WELL __i FRACTURE TREATMENT __ ALTERING CASING J J SHOOTING OR ACIDIZINO [ff~ ABANDONMENT* ~Other) Well Repa~--'-r. (NOTE: Report results of multiple completion on Well ~Other) Completion or Reeompletlon Report and Log form.) DESCRIBE PROPOSgD OR COMPLETED OPERATION'~ (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Conm,eaced 0pera.ti.0ns,: ,,~2,,:,01 'am,, 4/12/73. le 2. 3. 4. 5. e Removed ball valve and gas lift valves. Removed tree and installed BOPE. Pul led tubing. Perforated four 1/2" holes at 5170' (base productive . "C" Zone). RIH w/ retrievable BP and RT~S tool, Set BP at 5400'. Dumped 20' sand on plug. Set packer and pressure tested. Squeezed cement holes at 5170' to eliminate wet sands below "C" zone. Perforated four 1/2" holes at 4190' (top productive "C" zone). Squeezed cement holes at 4190' to eliminate wet sands above "C" zone. Cleaned out cement and sand to BP at 5400' Retrieved BP. Perforated Middle Kenai "C" zone - four 1/~-" holes per foot. SAND INTERVAL FEET c--ri- 4~00-~232 32 c-3 4270-4310 40 4318-4336 18 c-4 4367-4382 15 C-5 4471-4476 5 C-6 4560-4570 10 C-7 4646-4707 61 Completed, Op.e.,rations- 12'00 Midnite.,, 4/15/73,. Killed. well w/ 70# invemul. Form I~EV. 9-30-4 9 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Submit "Intentions" in Triplicate & "Subseque[lt Reports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS (DO not use this form for proposals to drill or to deepen Use "APPLLCATION 'FOR ~ER~IT-L~' 'for such 'pro,os. IS.) . , W£LL WELL 7q OTHER In ector 2. NAME OF OPF~RATOR Union 0il Company of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue~ Anchorage~ Alaska 4. LOCATION OF WE,LL At su.'face Conductor #19, 1619'N ~ SSg'W from S. E. corner. Section 4: TgN, R15W, S. bi. 13. ELEVATIONS (Show whether DF, RT, GR, etc. BT lO1 ' above l~SL. 14. 5. AP1 N~CAL CODE , 50-133-20214 . 6. ~E DI~GNA'I'iON /kND SERI.~L NO. ADL - 18731 7. IF liN'DIAN, ~d-J.~)TT~dg OR TI~IBE NA-M~. 8. UNIT, FA~LIV~ OR LEASP. NAi~IE Trading Bay State A-Il (44-4) 10. FtW. Lr~ AzN'D POOL, OR WILDCAT TrnH~no Rmv Fiald n. s~.c., T., ~., ~., t~OT~O~ Hou~ OBJECTIVE) Section 4' TgN, R15W, S. 12. PER1VIIT I~O. 70-24 Check Apgropriate Box To I,ndJcate N;at'ure of N~tice, Re, ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS ~Other) SUBSEQUENT REPORT OF: WATER SItUT-OFF [~ REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEKT' (Other)Well Renair. & , (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date Of starting any proposed work. SAND INTERVAL FEET Str----~y 481g-4.8~4 ~ 47-5 4850-4867 17 48-5 4922-49~4 22 48-7 4958-4872 14 49-4 5056-5061 5 50-3 5145-5166 21 ANcBORAGH 11. 12, 13. 14. 15. 16. Cleaned out w/ bit and scraper to 6882'ETD. Circ. clean. Rm~ dual 2 7/8" tubing strings complete w/ gas lift assemblies and ball valves. Long String: Tail at 6050', RH-1 single hydraulic packer at S480' & RH-2 dual hydraulic packer at 4175 '. Short String: Tail at 5170' hung below dual packer at 4175' & stabbed into packer at 417:5 '. Landed tubing, set and pressure tested packers· Removed EOPE and installed tree. Changed over to diesel oil thru sleeves above both single and dual packers. Ran gas lift valves. Place well on production via gas lift· Long String-Middle Kenai "D" Zone. Sho~t~:String-Middle Kenai "C" Zone· 16. I hereby cert~that the ~)qo~ 1! true and correct ,d"/Jim (Th~ =~ace for State o~ce use) APPROVED BY CONDITIONS OF APPROVAL, IF AI~: TITLE District Drlg. Supt. DATE TITLE DATE April 25, 1973 . See Instructions On Reverse Side REV, 9-30-69 & "Subsequent P, eports" in Duplicate STATE O'F ALASKA .~. ~,P~ NU~,mmC.,U. CODE OIL AND GAS CONSERVATION CO~I~EE '50-153-20214 use "A,~LICATION FO~ 9~I'i~' ]or ,uch'pE~lS.)~L - 18751 ~i~ Oil C~~v o~ ~lifomia Trad~g Bay 909 ~est 9th Avenue. ~chora~e. ila~k~ State A-II 4. LOCATION OF W~L -- ' 10. F~ ~ P~L, OR Trad~g ~y Field ~"~ Conductor ~19~ 1619~N ~ 559~r from S. E. comer. ~tion 4' TgN~ ~5~ S. M. n. .s~C"o~w~ ~'' ~'' ~'' (~om~ ~o~ Section 4' TgN~ 13. ELEVATIONS (Show whether D~, RT, GR, etc. I~. P~T NO. R.T. 101' Above ~SL 70-24 ~4. Check Appropriate I~x To I,nc[~c~te N, ature of N~ti'ce, Re ~ort, or Other D~ta ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT .MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONe REPAIR WELL CHANGE PLANS iOrher) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ~ ABANDONMEN'T* J j (Other) ...... (.NOTE: Report results of multiple completion on Tell Completion or Reeompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertineut details, and ~tve pertinent dates, including estimated date of starting any proposed work. . 2. 5. 4. 5. . 7. 8. 9. 10. Remove ball valve ~ gas lift valves. Kill well w/ 70# invermul. Remove tree ~ install BOPE. Pull tubing. Perforate four 1/2" holes at S170' (base productive "C" Zone). RIH w/ retrievable BP and RTTS tool, Set BP at S400'. Dump 20' sand on plug. Set packer and pressure test. Squeeze cement holes at S170' to eliminate wet sands below "C" Zone. Perforate four 1/2" holes at 4190' (top productive "C" Zone). Squeeze cement holes at 4190' to eliminate wet sands above "C" Zone. Clean out cement and sand to BP at S400'. Retrieve BP. Perforate Middle Kenai "C" Zone - four 1/2" holes per foot. C-4 C-5 C-6 C-7 INTERVAL 4270-4310 4318-4336 4367-4382 4471-4476 4560-4570 4646-4707 Perforations continued on second page Form P--3 I~EV. 9-30-6 9 Smbrntt "Intentions" in Triplicat~ & "Su~Cluent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APP-LACATION 'FOR ~'EP,~iI'i'---'" 'for such . . 0IL ~ GAS r'~ Injector WELL ~ WELL OTHER NA.~IE OF OP~.~L~TOR ADDRESS OF OPERATO~ LOCATION OF W~L .t,.r~ Conductor ~lg~ 1619~N ~ 55g~W ~rom S, E. comer. 13. ELEVATIONS (Show whether DF, aT, Ga, etc. R. T. 101 ' Above MSL ,4. Check Appropriate Box To I,ndi,cate N;ature of N~ti'ce, Re NOTICE OF INTENTION TO: TEST WATER 8HUT-OFF~1 I PULL OR ALTER CASINO ~__ FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE -- ABANDON* REPAIR wELL CHANGE PLANS ,__ ~Other) 5. AP1 NU-~CA.L, CODE 50-133-20214 6. LEASE DESIGNATION A_ND SERIAl, NO. ADL - 18731 7. IF INDIA.N, A.I.,LO'l-r~z2E OR TRiBE N,M~LE 8. UNIT, FA.RNi OR LEASE NAME Trading Bay~ 9. V~ELL NO. , State A-11 (44-4) 10. ~'i~:[.D A24'D POOL, OR WILDCAT Tradin~ Bay Field 11. SEC., T., ~., M.0 '(BOTTOM HOI-~ OBJECTIVE) Section 4: TgN, RI~, S. M. 12. PER/VI_IT NO. 70-24 ~or~, or Other D~ta ' I~IUBSEQUENT REPORT OF: SHOOTING OR ACIDIZINO ABANDONMEI{T* (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting proposed work. 11. 12. 13. 14. 15. SAND INTERVAL 47-5 4850~4867 48-5 4gZ2-4944 48-7 4958-4872 49-4 5056~5061 50-5 5145-5166 Cleaned out w/ bit and scraper to 6882'ETD. Circulate clean. 16. Long String - Middle Kenai '~" Zone. ShoYt String - Middle Kenai "C" Zone. 16. I hereby cer~-~'~~,~/<~~that the f%~lO~l~g ti true and correct SIGNED TITLE District Drilling SLT~t. Run dual 2 7/8" tubing strings complete.:iw/ g~s lift assemblies and ball valves. Long_ St~ing: Tail at 6050', ~{-1 single hydraulic packer at 5480' ~ aH-2 dual hydraulic packer at 4175'. S~or$ Stri!)g: Tail at 5170' hung below dual packer at 4175' ~ stabbed into packer at 4175' Land ~ubing, set I pressure test packers. Remove BOPE .and install tree. Change over to diesel oil thru sleeves above both single and dual packers. Run gas lift valves. Place well on prpduction via gas lift. DiTE 3/28/73 (This space for Stat~ office _use)/ CONDITIO~ O'~'~aowL, ~ TITLE See Instructions On Reverse Side STATE OF ALAS A :i ~ENO I '!~, % ^m NU~,m~c.~.. COD~ ...... ^.D co.s .w.,o, s0-z - 0zz , ' ~ 7 .... U e. ~ D~GNA~ON ~D S~I~ SUNNY NOTICES AND REPORTS ON wIL~ ENG '~--- ~L 18731 use "AP~btCATtO~ FO~ ~E~ri'~" ~o~ such . , o.,~,~ ~ ~*"~,~ ~ o,,,, Injector . ' O~-ot._ ~. ~*~,~ o~ o~o~ ~~XF~ "Tra~ing~m~ ~ o~y~State Union 0il Co, my of .Califo~ia. i g~d~ ~. m,~o. ' ........ 3. ADDRESS OF OPERATOR 909 W. 9~ Ave., ~ch0r~ge,. Alaska 99501 co~:~~. A-Il (44-4) ~. LocAtiON O~ W~n FILe: m. ~ ~' POOL~Oa ~C~W '" . ~,, AtsurfaceConductor ~19, 1619'N 6 559'W from SE Trading ock ~ones co~er section 4, T9N, R13W, ~. n. s~C..om~w) ~'' ~'' ~'' (~oz~o~ ~o~ Sec. 4, T9N, R1SW, ....... R.T. 101' above MSL 14. Check Appropriate Box To Indicate Nature of NOtice, Re, NOTIC} OF INTNN~ION TO: TEST WATER 8HUT-OFF II PULL OR ALTER CASINO SHOOT OR ACIDIZ~ -- ABANDONS REPAIR WELL, CHANGm PLAN8 ~Orher) 70~24 tort, or Other Data ' FRACTUE~ TREATMENT ALTERING CASING 8HOOTING OR ACIDIZINO ABANDONMENT" (Other) (NOTI~: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. REASON FOR RECCNPLETION' Trading Bay SAate A-11 is presently producing through a single 2~7/8" tbg string from the "D" zone. It is proposed to increase the withdrawal rate by perforating the "C" zone, Fault Block 2A and re-complete the well as a dual "C"--"D" producer. This would provide complete drainage of the "C" zone during the Secondary Recovery operation. PROCEDURE: R ~ C E !V J(JL 3 0 1971 1. Remove bali valve ~ g.l. valves. Jill well w/70# invert1. 2. Remove tree ~ install BOE. 3. ~11 tbg. 4. Perforate four 1/2" holes at S170' ~e productive "C" zone). 5. RI w/retrievable BP ~ R~S tool. Set BP 8 5400'. ~ 20' s~d onplug. set pkr ~ pressure test. 6. ~z ~t holes ~ S170' to eliminate wet sands below "C" zone. 7. Perforate four 1/2" holes ~ 4190' (top productive "C" zone). 8. ~z ~t holes ~ 4190' to eli~nate wet s~ds above "C" zone. 9. CO ~t ~ s~d to BP ~ 5400'. Retrieve BP. Form P--3 I:LEV, 9o30~ 9 Smbmit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use -APPLICATION 'FOR ~ER~IT-l'' 'for such 'proposals.) · . 0IL ~ GAS ~ WELL ~ WELL~ OTHER 2. NAME OF OPEaR2kTOTL 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface TBS A-Il 13. ELEVATIONS (Show whether DF, RT, GR, etc. APl NLF/YLEB/CAL CODE 6. LEASE DESgGNAT~ON A.ND SERIAL NO. 7. IF INDIA.N, ALLO'I-£EE OR TRIBE NA.M.E %. UNIT, FAR1Vi OR LF. ASE NAME 9. WELL NO. 10. FIF:.LD' .~D i~OOL, OR WILDCA~ 11. SEC., T., R., NI., (BOTTOM HOL~ O]~IECTIVE) 12. PEI~T 1~O. 3oft, or Other Data NOTICE OF INTENTION TO TEST WATER EHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASINO MULTIPLE COMPLETE ABANDON* CHANGE PLAN8 Other EUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERINO CASINO'~' SHOOTING OR ACIDIZINO ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletton Report and Log form.) _ _ I5, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 10. 11. 12. Perforate Middle Kenai "C" zone - four 1/'2" hpf: Sand Interval Feet ~ ~200-~23'2 C-3 4270-4310 40 4318-4336 18 C-4 4367-4382 15 C-S 4471-4476 S C-6 4560-4570 10 C-7 4646-4707 61 stray 4819-4824 5 47-5 4850-4867 17 48-5 4922-4944 22 48-7 4958-4972 14 49-4 5056-5061 5 50-3 5145-5166 21 Total 5~ JUL 3 0 19'/i ANCHO~ COw/bit ~ scraper to 6862'ETD. Circ clean. Run dual 2-7/8" tbg strings complete w/g.1, assemblies & ball valves. LONG STRING - tail @ 60S0', P~I-1 single hydraulic pkr @ S480', ~ RH-2 dual ~ydraul~cpkr @ 4175'. SHORT STRING - tail @ 5170' hung below dual pkr @ 417S' & stabbed into pkr @ 417~~. . Form P--3 REV. STATE O'F ALASKA Smbmtt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS {Do not use this form for proposals to drill or to deepen use "APP'L, LCATION 'FOR ~'EP,~IT--' 'for such-pl:o~osals.) · . oIL ~-~ oas WELL ~.~ WELLI.__j OTHER 2. NAME OF OPEH~TOR ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface TBS A-11 5. AP1 NUMF_,PACAL CODE 6. LEASE DIEC~IGNATION A.ND SERIAJ~ NO. '/. IF lbrDIA. N, A.L~O~ OR TRIBE NA.I~LE 8. UNIT, FAI~N[ OR L~F_,&.SE NAME 9. WELL NO. ' 10. FLELD A~D POSL, OR WILDC.~T 11. SEC., T., R., M., (BOTTOM HOl.m OBJECTIVE) 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PEI~'VLIT N'O. ,4. Check Appropriate Box To Indicate Nature of N~tice, Re ~ort, or Other D~ta ~ NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASINO MULTIPLE COMPI,ETE ABANDON* CHANGE PLAN8 ~Other) BUBSEQUENT REPORT OF: FRACTURE TREATMI~NT ALTERING CASINO SHOOTING OR ACIDIZING ~ ABANDONMENTs (Other) (NOTZ: Report results of multiple completion on Well Cornpletion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONB (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. 15. 14. 15. 16. Land tbg, set & pressure test pkrs.. Remove BOB & install tree. Chng over to diesel oil thru sleeves above both single & dual pkrs. g.1. valves. Place well on production via gas lift. LONG STRING - Middle Kenai "D" zone. Run SHORT STRING - Middle Kenai "C" zone. ESTIMAT~ STARTING DATE: n/V7 ~JL 3 0 19/'i /I // /.t n ' - i]i ,,,,~. Dist, Drlg. Supt. (This 'paC~ fOr ~tlte o~ce~ ~ . ' "',, _ APPROVED CONDITIONS OF~~APP~oVX~, IF 1~: ~Z See I,n.strudions On Reverse Side DATE 7/28/71 Approved Copy Returned Submit "Intentions" in Triplicate "Subsequent Reports" in Duplicate $. APl NLrNIF_RR/CAL CODE OIL AND GAS CONSERVATION. ,COMMITTEE SUNDRY NOTICES AND REPORTS : "WELLS noI use this form for proposals to drill or to deepen Use "APPLiCAT10N FOR P~T~" 50-133-20214 KLV __ 6. LF_ASE DESIGNATION A-ND SERL~.~ ..... 4. LOCATION O,F WELL Atsurface Conductor #19 - 1619'N a 559'W from SE corner section 4, T9N, R13W, SM. :ADL 18731 ?. IF LNDIAI~, o,~ ~ o,s ~ o,,~ Injector Fi~ WELL WELL 2. N~E OF OP~TOR 8. UNIT, F~ OR ~SE N~E Union 0il Company of California Tradin~ Bay S~a=e 3. ADD~S OF OP~TOR 9. w~L NO. 507 Wes~ Northern Li~h=s Blvd., Anchorage, Alaska 99503 A-ii .Tradin~ ~y-HemI~ck Zones 13. ELEVATIONS (Show whether DF, RT, GR, etc. R.T. 101' above MSL 1i. SEC., T., R., M., (BOrI'I~M HOLE OBJECTIVE) Sec. 4, T9N, R13W, SM. 19.. i~m~tlVfIT NO. 70-24 14. 'Check Appropriate Box To }nd}cate N~at'ure of l~ti'ce, Report, or ,Other 'Data N0,,C, o, ,,TEN,,0, ,o: { { REPAIR WELL CHANGE PLANS (Other) As dual water injector SUBBEQUENT REPORT OF: FRACTURE 'T.R~'ATMENT ALTERING CASINO SHOOTING OR ACIDIZINO ABANDONMEN'T* (Other) NOTE: Report results of multiple completion on Well ompletion or Reeompletion Report and Log form.) 15, DESCRIBE PROPOSED OR ~COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, Trading -Bay State A-il was originally programmed as a dual water injector in the Upper Fault Block Middle Kenai "D" and Hemlock Zones. .The well was temporarily completed for production in the Middle Kenai "D" for well bore clean up prior to injection. It is now proposed that the well be re-entered and completed as a dual Middle Kenai "D" and Hemlock Zone injector as per original~Lprogram; (see Sundry Notice dated 5/21/70). ~ PROCEDURE: 1. Kill well w/70#/ft3 salt wtr, install BOE, pull 2-7/8" tbg string. 2. Perf ~emlock Zone @ intervals from 6420-6850 & an additional interval in the Middle Kenai "D" from 5508-5570. 3. Set wireline production pkr @ 6350'+-. ~' 4. Run dual strings 2-7/8" tubing w/dual hydraulic pkr @ 5450'+-. 5. Install dual 2-7/8" 3000# xmas tree & test. 6. Return well to service as a dual water injector. Long String - ~emlock Zone and the Short String - Middle Kenai "D" Zone. ESTIMATED STARTING DATE: 8/15/70 16. I hereby ~rue and correct SIGNED~~ ' ,~,,-_~,j _ ,//j- . (This spree for APPROVED BY CONDITXONS OF APPROVAL, TITLE Dist. Drlg. Supt. DATE 7/6/70 See Instructions On Reverse Side Approved Copy }"l~r::l P - 7 STATE OF ALASKA OIL AND GAS CONSERVATION i i i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: on, [] oas ~-~ [] WELL IYELL ~ DS¥ Other b. TYPE OF COMPLE~ON: WELl. OVER ~ EN BACK RESVR. Other SUBMIT IN (Seeother m-I structions on ! 5. COMMITTEE 50-133-2021 ...... i ii ii ........... 2. N&~.fE OF OPgRATOR Union 0il Company of California 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOC^TZ0,~ 0~' WELL (Report location clearly and in accordance with any State requirements)' At surface Conductor 19, 1619'N & 559'W from SE corner Sec. 4, T9N R13W, SM. At top prod. interval reported below 6045' 690'W from SE corner See,. 4, T9N, R13W, SM. At total depth ",~ 10,108'MD 9858'VD ~,"281'N,:514'W}from SE Corner sec. 4, 6. L~ASE DESIGNATION A1ND S~. ADL 18731 ?. IF INDI.~N, ~1.,O~ 8. UNIT,F~dR2VI OR ~ Trading Bay State 9. WIKLL 1~O. A-11 (44-4) 10. FI_ELD A2,ID POOL, OR WILDCAT riddleKenai & adine Bay - Hemlock 11. SEC., T.~I{., 1VI., (BO/mi'OM HOT.I~. OBJECTIVE) Sec. 4, T9N, R13W, SM. 12. P~IR2VIIT NO, TgN., R13W, SM ~'~,,lh, ~ 9Zt f~c. t- t 07¢ F ac 70-24 TOTAL DEPTH, ~ a TVDJlg.[ PLUG,. B~CK MD & TVD~0.[ I~ 1VfLTLT~PLE COiVI~L., I 21. 10180'-9927' [6862'~ - 6702'VD. [ aow~,single I ~~x, PRODUCING !N~VAL(S), OF ~IS CO~TION--TO~, BOSOM, NAME (~ AND ~)* 5570'-6055'MD 5428 '-5927 'TVD "D" Zone INTERVALS DRILLED BY rotar~ tools 1,23. WAS DIRECTIONAL ! SURVEY MADE ! yes 24. TYPE ELECTEIC AND OTHEt{ LOGS RUN DIL, Gamma Ray., Density, DiPmeter log, & SNP · 25. CASING REC. ORD (Report all strings set in well) I z0as, 17-1/2"1 860 cu.ft. BJ blend240cuqft, neat cmt. 9-5/8" [ 43.5~ [ N-80 [ 7092' 12-1/4"l First s~age 1504 cu.ft. ~J blend & 300 ' . l. cu.ft. 'G" cmt. 2pd stagq thru DV 0' .... [ [ ,[ 3622' w/1250 sx "O" w/zZ/~F~-2 LINE~ E~C0~ [27. TUB~G REC, OP~ :l., - , , , 28. PERFORATIONS OP~ TO PRODU O (Interval size and number) 2~. ACID, Si!OT, Fil.~CTURE, C~5iENT SQUEXZE, ETC. 6055'-6025' 5769'-5742' 4 hpf (hyper-jet) 6025 '-5981' 5705 '-5672 ' 4" carriers 5940 '-5905 ' 5652 '-5605~' NONE 5899 ' -5860' 5586 '-5570' 5816'-5802' Measured Depths. 30. PRODUCTION D-~.TE FIRST PI%ODUCTIOiNT [ P~[tODUCT1ON MEII{O'D (Flowi~*g, gas lif~, pumping--size and type of pump) 5/25/70~ flowing DATZ OF T~ST, ~OURS TES,T~~ '[CI-tOXE SIZE PROD'I¢ ~- 1161 481 FLOW, ~BING ~ASLNG PRESSURE CALC~T~ OI~BBL. GA~MC~. ~SS. [2~-HOUR RA~ ~50 7~5 ~ ~ ,, ~6~ ~ 48~ 31. v~s?osmo~ or oas (8oi~, used for fuel, vented, ei'c.) none 32. LIST OF ATTACHMENTS none 33. I hereby certify i AMOUN'i7 ,'~ND'I-ilND OF MAq E'?3~kL USED · jVC'ELL STATUS (Producing or ~"~='~"=) producing V~ATEri--BBL. [ GAS-OIL II.%TIO J 12 i 418 w~-~.. JoIL G~vI~¥-~ (com~.) I 12 I 31.0° JTE~T WITNESSgD BY M. Bratcher ~at the foreggqng/~nl)//attached i. nfo~ation is complete and correct as determined from all-available records ~*/ wi'rum Dist. prig. Supt. DXTE 6/1/70 ~ . ii i iiiiilll *(See Instructions and Spaces [or Additional Data on Reverse Side) 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: Id: Indicate which elevation is used as reference (where nol otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 33:: If this well is completed fOr. separatc, prcduction fi:om more than one interval zone (mulliple completion), so state in item 20, and in item 22 show the prcducing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only'the interval reported in-item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item3~ "Sacks Cement": Attached supplemental'records £or this well should' show the details of any mul- tipJe stage cementing and the location of the cementing tool. Item 38: Submit a se~)arate completion report on~ this form for each interval to be separately' produced. (See instruction for items 20 and :22 above). ~4. S~AIIY O1,' I~OP..IiATION 'I'ES3"~ INCLUDiN(; INTERVAL. TE.~{TED. pRIgSSURE DATA ./k.-'k']) ~Ot/]~3ll~.~; OF OIL. GAS. - · ~. ss. G~O~oOW WArl~H AND MUD . ' . . . MEAS. I~-*PT~~ t/I~Z~. Perforated Intervals as follov8 for purpose of zone is°lation - unable to - . breakdo~m formation to squeeze. 6410~ - 4 hole~ - 1 ft:. ."C" ~ 4162~ t~OBO~ 6070~ - 6 holes - 1 fro ' 5505' - 4 holes - 1 fl:. ' ~'' "D" 47~2' ~4634" lte~lock 6445 ~ 6302 ~ ~ ~est Foreland ~ 6850 ~ 6700 ~ ..... ~. ~'~ '~ n**~. A'rr~¢~,~ ~ ~ ~ ~. ~. ~~. -~~ ~ Top Jurassic 7180' j 7040' i UNIC~' OIL CO OF CALIFO X!tA DRILLING RECORD LEASE Tradin_g__Ba_y__St_ate .... WELL NO. A-ii FIELD_~ T__r_a_d i_Bg_~ a y_. LOCATION Conductor #19 , 21619 '_N_, 599'W from SE.c_o_rner:Aie_r~ion 4, T9_N, R!_3~, SM.' · PERMIT NO._7_0_-24 __ 'SERIAl, NO. ADL 18731 T.D. 10_~180 'TD T.V.D.~~ DEVIATION (B.tt.L.) S ~IL~ ET A OKG ~ SPUD DATE 3/20/710 COMP. DAR}t~K~3/70 ~_ CONTRACTOR. WODECO R~6 ]~'~). ~ TYPE UNIT Oilwell 860 E ~ ,, ,DRILL'PIPE DESCRIPTION._. 5"_. 4.~1/2_ I~F_----~~ ELEVATIONS: WATER DEPTH 62' vn.E~ ~-:--'~ ~ tt T. TO. OCEAN FLOOR 174' 1R.T. TO MLLW 112' · R.T. TO DRILL DECK 22,07' *- COMPANY ENGINEER Stinnett~ Shell, Rardin R.T. TO " 82' APPROVED:' (B.E. Taller) - BIT RECORD MUDWEL. BIT ........ JET [ DEP';i'H ..... VERTICAL [] DlkT..E DEPT,.H_ N__0_.__ ._SIZE MAI¢E TY_PE SIZE OUT FEE__T HOURS ANN. J_ET DIRECT!O,I~,AL ~[~ , ~/20/?0228 i 12-1/4"Slopess3~ ~-14 750 522 5 100 21 750---2 " .... " ..... SST3 ..3-24 1086 336 .....7'i-/2 DD-rl~ '10° . .... 22 ..... 228 tibl~ 17.__-1/2" smith 6 pt - "~086 858 S ....... ~ .... 24 "" 1038 1R~! 12-.!/4..." G!.obe SS3A 10-10-'12. 1337 29'9" 2-1/2 82 510 '" , , 25 1337 3 " Smith DSJ 24-24-24 DDr~ld 18° 25 'i'.4'90 3~h ,,' ,, ... ,, 10_102'11..1490 153 3 80 705 ...... . ...... 25 2025 4 " Reed YT3A 10-10-11 2025 535 9-1/2 80 7O5 T-2 B-2 I 26'" 2402 5 " .. 'Reed YT3A'" 10_11_11 2563 538 13-1/.~ ,, .,,.. T_6 B-2 '1/4 ' 27 300~ 4RB "- ' '" " 12-12'2'12 3004 441 10 80 "'" T-6' B-4 3/8 ' 29 .... 356g '"6' ' " ~ smith "DTIt 11-1i'2'11 3650 g~6' 17-1/2 90 '440 T-3' B-2 I ' ' ...... . 31 3.737 7 .... " HTC ODV., 24-24-24 37_37. .87 ~3.-.3/4 " -. T-2 B-2 I-DDrl #3 4/1/70 4.194 8... " .. Reed YT1AG 12~13r13 4190 453 .1..6-1/2 " .4.65 T-5 B-4 I 2 4190 9 "" Smith K2It 12-13-113 4414' 224 10-1/2 94- ,, T_7' B-3'""1/4 5° VD 42~9 2 4414 10 " "' ..... HTC ODVJ 12-12-12 4722 308 15-1/2 " '"" T-4 B-4 3045'. VD )+'58'g .3 ... 4..722 11 " ..... S.ec. S4tG~ i2-i2"1J2 5i57 435 .17-1/2" 465 T-5 ~22 Og 1/8 4 5.157 [. 12 " Reed YT1AGJ12'12-12 5463 306 12-1/4 " " T-3 B-40G 1/8 ..... ~ . . ~.463 13 " Smith K2HJ 12-13-1]3 5725 .... ~62' 10-1/2 "" 415 T-5 B-4'i/16 .......... 6 5725 14 " HTCr ODGJ 13-13-13 5840 115 8 " 395 T-5 B-30G 1/8 ...? ..... 5840... 15 _ '". .... Gl°b'e MT.3GJ 18-18-18 5898 58 ..4.-3/4 .'.'86 - DDrld '#4'T-8 B-7 1/2 · . 7 5898 16 " " " " 5930 32 4 " - " "T'6 B-4 1/2 8 _ 5930_.. 1.7 " 'ItTc ' ODVJ 13"1132i3 6039 109 7-1/.~ 94 395 T'6 B23 I ' .... ~ 6039 1~ " Reed YMGJ " 6084 45 4 " " T-3 B-1 I 9 .... 6084 1.S '" Smith. Y2HJ ...... " 6222~ 138' i2 " " ...... 9 6222 ..2£ " HTC O.DV .... out.... 62851 63 5-1./2 95' ~25 DDrld. #5' T-8 B-8 ..1./2 10 6285 21 ..." Reed YT1AG ~3-13-1:3 6325! 40 2-1/4 " 39.0 T-3 B~4. ...... _ 11 ..6.325 22~ " Sec. M4NG 13-13212 636'~1 63 .7-1/2 '-95 385 , , 11 6368 22! '" . .See. 8-44 13-13-12 647fi 102 7 85. '385 T-2 B-4 1/16 : 12... 6470 ' 24.. " HCS V2H out 6523 53 4-1/2 85 - DDr!'¢i6...T-8 B-~ .... 13 6523 25 " .... Sec. S-4'~' i3-13...-13. 6609 86 "7-1/4 " 385 Tr8' ~-30~ 3/8 . 13 6609 26 ..." Smith SIS 12-12-13 6896 287 26-1/2 80.. 47.0.. T-4 B-8 ' __ 15 ' 6896 27 " " D.THJ " 7019 ..123 9-1/..2 " " T-4 B-4 OG 1/8 · 16 7019 28 ,, ,, ,, -' ,i' 7090 71 6 95_ '2~30 T-2 B-I 9030' VD 6937 ...~8 ._. 709028P~i~ ,, "',, ",,r4_14-].6 7~00 xo~ " 335i"5-3 z-~..... 20.. 7'~00 29 ..... 8-1/2 s,c. sNzsJ r~-~i..-.l~ 7130 3o 6~1/2,. i60370"Z-g z-4 Dr'id'fl°ai~ 22 7130 30 " Reed ¥SIGJ 14-14-13 7130 - 7 255 370 T-5 B~2 Drld BP ............. . ......... 22 7130 3i " " YTIAGJII-1i-i1 7146 I6 3 " "' T-3 B-4 Drld on junk .................. 23 ..7.!46,. 3.2" 'Sm±th. Dm~3~1-.1!~ 728o '.'i'i34. .!1,1/2 2oo " ..~_5.~.~6 ,~/.8 , 23 ..... 728.o 32 " . ........... " " tO-lO-~r 7438 158 14 ~70480:z-7 ~-3 1/8 24. . 743--8 .... 34 " ~eed X;'~Ag 9-9-101 7S87 ~49 ~2-1/21 " " ~-6 ~-5 ~/~6 ,24, 7,438 ,35! '; s,m±,.t.h Dm~.... , -929-10!,', -7736 149 13 " " T-5 B-5..~/8 25 . 7736 36 " Reed YTIAG " 7~40 104 11-1/4 .... " " T-6 B'6 1/16 · · 27 ..... 5'925 37 " ....s'm±th b~u ,, 7925 .... 85 i.10-1/.41 ,, /,.76 "~-8 ~-6 ],/~6'" , . , ........ 28 7925 38 " Sec. M4NG " 80O1 76 10 " " T-7 B-4 ....... 28 8001 39 " " $88 " 8155 i54 23 " " T-2 B-2 - , ...... , ....... 30 .. ,8155-- 4(] " ltTC XDV " 8283 128 12-~/2 " " T-7 B-3 .... . i ........... 5/1/70 8283 4]. " Reed YSIG ". 8371 88 7 '175' ~10 T-~.B-4 2 .. 837~-39RR " " Sec...~S:88_ '" 8404 ..33 3-1~21 " : "... .3 cones mi. ssing" 2 8404 42 ..... ,i' Sec. lt7sG [3-13-13:8426 22 2-1/4 135 215 D~ld on junk ___3 84~'~ . 43 .... '" ' . ..... S.'.mith_ V2HJ" 8"'8-9 85_0_5. -7'~_ _ 4~i/.2 1301:510: -... ...... :: "- __3 8505 44 " Reed YTIAGJ " 86441 139 8-1/2 " " 4. 8644 45 " ..... "~- ysiGj " ~47' lYJ- ' 6-1/2 " " " q--~- ] ~8747 .4'6" ii ....... Smith L4It~" open 8805]--5'~-'' 4'-i/2 ,__2 ...... DDrl #7 T-7 B-6 5 ....... 880--~ ..... 4~~'' '" R~ed YSlC~" 8-~---~~ 8~72i .6~-- 4-3/4 ~i36 510 T-5 g-3 " 5 -~-~7--~- 4'8 ,,'" i', 'Y-}~iiGJ i'open -'~~ 3~--4'1/2 "'if i, 'L D~r1 ~8'~T_8 B-8 ---6:' ~9~5' 49 " HTC ...... ODG.] -8-~--'i~ 8~51 '-~ I-4Z'~72" 130 510 ~, 18955 I soi " " · oPvY-I "' I 90~87---63-T-._~6 i, ~i- ---'_--' -~- .... OIL CO. OF CAL1FC.._ NIA' DRILLING RECORD LEASE FIELD Tradi---nK_Bay.State LOCATION_ SH EFT A PAGE NO, __ WELL NO. A-Il SPUD DATE CONTRACTOR.. TYPE UNIT DRILL PIPE DESCRIPTION COMP. DATE .. RIG NO.._ PERMIT NO ....... 'SERIAl, NO. T.D. T.V.D. DEVIATION (B.H.L.) COMPANY ENGINEER ELEVATIONS: ~VATER DEPTH R.'T. TO OCEAN FLOOR R.T. TO MLLW R.T. TO DRILL DECK R.T. TO PRODUCTION DECK APPROVED: ' BIT RECORD ; MUD VEL. DEPTH & DEVIATION BIT .......... JET DEPTH t ' - ' VERTICAL [] __ DATE, DEPTH NO. SIZE MA. KE i,TYPE SIZE OUT FEET HOURS AIIN. JET . DIRECTIONJkL FI .. 5, i/i.9/70 9107 52 i 8.-1/2", .,Reed YSIG 9-99 9!87 80 ;_ 5_ 165 450 T-6 B-3 I ... 10 9187 53, " Smith L4H 9-9-8 9301 114 8-1/2 140 490 T-6 B-3 I . 10 9301 54 " Sec, M4LG 9~9-8 93,8..7 86 7 " " ...... .... 11. 9387 55 · ' ....... ' ' Reed YSIG " 94~5 108 9-1/2 130 " T-7 B-40G 1/16 11 9495,, 56 " , ,HTC, 0DV 9-9-8 9582 87 9-1/2 " " Ta7'B-7 OG 1/8 · '12· 9582 57 " Smith V2HJ " .9582 Ruin,~_d thre~d~ m~tkin~ un 12 9582. 58,, " .Sec, M4NGJ 9-.9-9. 9600 18 ' ''l 2-1/.2 Rem~ed 1~i37' for 10 hour.~ 14 9600 59 " ' HTC XD7J " 9778 68 11 130 490 T-5 B-3 15, 9668... 60- " HTC XDVJ " 9724 56 5-1/2 " " T~7 16 ,, 9724 61 " Smith 4JS " 10017 29~ 25-3/4 " '" T-7 B-4 1 18 10017 62. ,, HTC XD7 .... ' ' 10k08 9_1 2-1/2 ,, ,, T_5 B-2 1/.80G 19 10108 63,, " Sec. It7SGJ -" ' 10180! 72 8-1/2 ,.." " T-5 B-3 20 I I 6_3,,,PJ~. " " ".. L6-16-15 Clealt out ~)r scrm)er __~? .. - ...... " " " open " " " ,, ., , , , , . . ,,- · · · · . ., · · · . · __ · !i --. .. ~b-,~iION OIL CO. OF CALIFORN~ DRILLING RECORD PAGE NO. L E A S E TRADING BAY STATE W E L L N O. .A-ii F I E L D TRADING BAY STATE DATE E.T.D. 1988 Feet 10-27-88 7092'TD 10-28-88 7092'TD 10-29-88 7092'TD 10-30-88 7092'TD 10-31-88 7092'TD 11-01-88 7092'TD 11-02-88 7092'TD 11-03-88 7092'TD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Skid rig to A-11. Pulled BV's from both strings. Ran 2-7/8" scratcher in LS to 5430'. Ran 3-1/2" scratcher in SS to XO at 4235'. Bled well off. SS flowing. Loaded annulus with FIW and 3% KCL (64.5 pcf). Well not standing full. Pumped 50 bbls sized salt pill (40 PPB salt) down LS. LS on vacuum. Pumped 50 bbls sized salt pill (75 PPB salt) down' LS. LS on vacuum. Pressure on SS at 180 psi. Filled hole. Pumped down LS taking returns up ss to production. Pumped down the 9-5/8" annulus while taking returns up the tubing. Pumped down the long string while taking returns up the annulus until clean. Check well and both strings were on a vacuum. Mixed and pump two sized salt pills. Well taking fluid at 10 bbls/hour. Set back pressure valves, nippled down the tree and nippledupthe BOPE. Tested BOPE. Attempted to pull triple packer at 4102'. Packer would not release. Rigged up wireline, cut the short string at 4014' and cut the long string at 4004'. Pulled and laid down the production tubing. Picked up 5" drill pipe and overshot and ran in hole. Worked over long string and pulled 165,000# over string weight. Overshot pulled off tubing. Pulled out of the hole and changed out overshot. Ran in hole and continued to work On packer without success. Rigged up wireline to run freepoint. Freepoint tool stopped at 4235' (3-1/2" X 2-7/8" XO). Freepoint showed free above the packer but no movement below. Made up jet cutter to cut long string above the permanent packer at 5466'. Cut stopped at 4235'. Pulled out of hole with cutter. Ran in hole with 800 gram string shot. Fired in LS inside packer (4102'-4108') while pulling 165K over string weight. No packer movement. Jarred fish while pulling up to 190K over string weight. Tripped for new BHA (#3). Ran in hole with jet cutter into LS - 3 attempts. Only a 2.25" cutter could pass top of LS. Cut LS at 4040' Recovered 35.23' of LS (3-1/2" tubing). Ran in hole with BHA $4. Latched SS at 4014'. Pulled 70K over string weight. Pulled stab-in mandrel out of top of packer. Recovered 88.05' of SS. Ran in hole and latched long string with 3-1/2" grapple at 4040'. Ran 2.7" jet cutter and cut long string at 4210'. Pulled ll0K on long string. Packer released and dip tube parted. Recovered packer. Dip tube at 4188' and long string at 4210'. Ran in hOle and latched 1-1/2" dip tube. Dip tube parted at 4221'. Recovered 32' of 1-1/2" tubing. Ran in hole and. latched long string at 4210'. Pulled 2-7/8" tubing apart at 4373'. Ran in hole to grab dip tube. Pulled out of hole with dip tube fish. Recovered 160'. Top at 4378'. Ran in hole to long string. Engaged at 4373'. Ran 2.5" scratcher on wireline to 5460' and 2.3" swedge to 5443'. Ran free point. No movement below 4940'. Ran 2.25" cutter. CUt 2-7/8" long string at 5405'. Ran a 2nd cutter and cut long string at 4910' WLM. Pulled out o~ hole with.fish, pulling dip tube apart. Dip tube top at 4736', long string top at 4921' DPM. Ran in hole to swallow dip tube. Swallowed dip tube to 4916'. Backed off manually. Pulled out of hole. Recovered 308' 1-1/2" tubing. New dip tube top at 4944'. Ran in hole with wash over pipe. Washed over fish from 4921'-5016'. Pulled out o~ hole. Recovered 505' 1-1/2" tubing and 493' of 2-7/8, tubing. All 1-1/2" tubing out of wellbore. New 2-7/8" top at 5413'. Ran in hole with 8-1/2" bit. 9 LEASE DATE 1988 L~'NiON TRADING BAY STATE E.T.D. Feet OIL CO. OF CALIFORNI~''"~ DRILLING RECORD PAGE NO. .- . WELL NO. A-il FIELD_TRADING_BAY STATE DETAILS OF OPERATIONS, DE, SCRIPTIONS & RESULTS _ __ · . 11-04-88 11-05-88 11-06-88 11-07-88 11-08-88 11-09-88 11-10-88 11-11-88 7092'TD 7092'TD 6440'TD 6440'TD 6440'TD 6440'TD 6440'TD 6440'TD Ran in hole with 8-1/2" bit and cleaned out to 5410'. Heavy scale from 5074'-5410'. Pumped high viscosity pill and pulled out of hole to 4190'. Spotted 50 BBL of sized salt. Pulled out of hole. Ran in hole with wash over pipe and cleaned out from 5413'-5470'. Pulled out of hole. Ran in hole with oVershot and engaged fish at 5413'. Pulled out of hole and recovered all the 2-7/8" tubing and seal assembly. Made up 9-5/8" burn over shoe and ran in hole. Burned over the packer to 5472' and pushed packer to 5486'. Pulled out of hole and recovered the mandrel and bottom retainer nut. Ran in hole,.washed and pushed packer junk to 6449'. Continued to curculateand push packer to 6508'. Pulled out of hole. Ran in hole with open ended drill pipe and laid a 37 sx balanced cememt plug from 6508'-6400'. Pulled out of hole. Tested BOPE.' Picked up a bit and scraper and ran in hole. Cleaned out to 6440'. Pulled out of hole and rigged up to run logs. · Ran CBL-VDL-GR from 6298'-2700'. Rigged down dresser. Ran in hole with 8-1/2" bit and 9-5/8" scraper to 6440'. Circulated the well and shipped surface volume to production. Cleaned the mud tanks and built new completion fluid system. Changed over well taking returns to production. Finished building fluid volume. Pulled out of hole and picked up 4-5/8" tubing conveyed perforating guns with 8 SPF' 32 gram charge and 120° phasing. Ran in hole, ran GR-CCL log to position guns and set the packer at 4158'. Positioned guns across the "C" and "D" zones with' perforations from 4196'-6055'. Pressured up on the annulus and fired guns. Shut in well with an initial pressure of 125 PSI. Pressure built to 140 PSI. Reverse circulated out well on the choke. Finished circulating well on choke. Released the packer and pulled out of hole. All tubing conveyed guns fired. Ran in hole with 8-1/2" bit and scraper and tagged fill at 6406'. Pulled out of. hole and picked: up 9-5/8" Baker model "D" permanent packer. Set packer, i at 4110' and puled out of hole. Picked up test seals and ran in hole. ~' Tested packer to 1500'PSI. Increased the fluid weight from 64 PCF to 67 PCF. Finished circulating and condition completion f!uid~i: Pulled out of hole to pick up tubing. R~% completion as follows: ? Wireline re-entry quide at 4150' "X" nipple 4142' Seal assemble 4110' "XA" sleeve 4078' #1 GI2~ 4041' #2 GI~ 3480' ~3 GI~ 2160' Ball valve (SS~;) 293' Stabbed in permanent packer at 4110'. Set back pressure valve and nippled down BOPE. Nippled up the tree. Cleaned sand and mud from pits. .!1/!1/88.. Released the rig at 2400 hours 3591N Trading Bay .State ~EASE--~~lfona te. 2YPE UNlOh~ Ol~ C.g. gl"' MUD RECORD '- WELL 'NO[A-11 PAGE NO FIELD Trading Bay DISTRIBUTOR Baroid 3-~0/)0 500 69 46 7.0 '12' 29,700 , Tr 8 Spud -- Ge~ 1010' "70' 41 1.2.6" 9'.5 28~050 Tr 8 ..... 108b-- 72 47 10.2 10.5 24~750 Tr 9 Opened hole '.. 23' 13_3/~""csg - cmtd - WOC . 24 1337 72 51 4.1 11 2.4,750 3/4" 9 Drld'~mt DDrl ~2 ... ---25. 1490 71 46 I3,8 l0 24,750 2 10. , ---2-6-- 2300 71.5 61 6,6 9~3 24,925 3 11 27 2904' 70.~ 44 4.4 9'' '24,915, 1-1/. 9 . . 28 3004 ' gilled well'after ~'o~)ut 29 3004 78 4.8 3.3 8.8 23,750 'Tr 3 ''12 30 3530 75 42 ~.4 9.0 24,750 Tr 1-1/~ 10 .... 31 3690 75.5 63 3.6 9.0 26,400 Tr 1 1~ DDrl #3 ~/1/7( 3740 76 43 3.8 8 3 26,400 .Tr .5 12 . . 2 4350 74 46' 4.8 8.8. .26,400 Tr 1/4 10.5 3' 4640 74 54' '4.4 8.9 28,050 .Tr 1/4 10.5 -4 5070 74 60 4.3 9~0 26,400 Tr 1/2 9 Plas. Vis. 24 yield 17 ... 5 5460 74 53 4.7 9.9 25,575 Tr !/2 10 , 6 5724 7~.5 49 4.6 8-~5 2~]57-~i Tr 1/I2 11 Plas. Vis. 18.yield 16 7 5895 77 '46 4.6' 9.6 2~,905 Tr 1/2 12 DDrl #4 8 '6039 77 58 4.1 9.5 26,400 Tr 1 13 9 6207 76 49 4.4 9.0 27,375 Tr 1 13 DDrl #5 --10 6250 76.5 61 4.4' 9.0 26,575 Tr 3/4 13 11 635'0 76 54' 4.0 9.0 26,400 Tr 3/4 13 .. " " 12 6470 76 46 4.4 9.2 26,400! Tr 1/2 12 DDrl #6 . It3 6'560 76 45 4.8 8'8 25,600 'Tr 1/2 13 . . 14 6660 75 44 4.4 9.0 27,200 Tr 1/2 12 P.V. 15 Yield 9 15 6840 75 45 4.5 8.5 2.7,200 Tr 1/2 14 P.V. 18 Yield 12 ... 16 '7'090 75.5 50 4.3 9.0 27,200 Tr 1/2" 14 " '19 " 18 . . 17 7090 75 48--- 5.0 . 9.0 27,200 Tr 1/2 14 " 19 " 12 Started logging 18 7100 76 57 4.0 9.0 27,200 Tr 2 14 Lo~ged . 19 7100 76 55 4.2 8.5 27,200 Tr 1-1/; 14 9-5/8" cs8 .. 20 7130 75.5 56 4.6 8.5" 27,200 Tr 2 -14 Drld out shoe' .. ~2i 7130 7~ 57 4.6 10.5 27,200 - 2 15 Squeezed . .. 2'2 7130 76 48 4.1 11.0 27,200 - 1 15 Drld out BP 23 7230 76 56 3.9 11.0 28,050 - 3/4 15 24 7400 75.5 57 .3.9 11.0 28,200 - 1/2 15 25 7587 -- -75' 48 4.1 10.5 '28,050 - 1/2 12 26 7715' 76 48 4.1 10.0 28,050 - 1/4 13 _ 27 7850" 75 45 3.8' 9.5 28,100' - .1/2 13 .... ' 28 I8000 '-- 76 51 I3.6' 10.2 ~7,200: - 1/2 14 _ 29 80'09 75 53 3.8 10.0 28,000 - 1/2 14 Down for repairs ... _ 30 8130 75 55 3.6 9.3 27,300 "1 1/2 13 .. _ 5~1~7~ 8255' 75 57 3.5 10.0 26,400 - 1/2 13 2 8400 74 52 3.6 9.7 28,000 - 1/2 13 _ 3 8490 75 51 3.5 10.0!24,000 - 1/4 13 4 873'0 75 52c 3.7 9.5 26,400 - 1/2 14. DDrl #7 . .. _ ,,, 5 8872" 75 56 4.'1 9~0 27,200 1 1-1/~I 14 DDrl #8 '- ' 6 8953 ' 76 58 '3.8 9.8 26,400 1 1/2 15 , 7 910'7 76 59 3.6 10" ~6,400 . -.. 172 lq _ ,, 9 ' 9228 76 66 3.8 9.8 26,400 - 1/2 15 10 '9387 75 55' 3.5 10 28,700 - 1/2 15' ' 11 9495 76 61 '3.6 10 28,700 Tr 3/4 15 P.V. 27-Yield 21 12' 95--~2 76 62 3.5 10 28,875 Tr 3/4 15~--P.V. 26 Yield 24 13 9600 75.5 56 "3.8 10 .28,875 Tr 3/4 15 P.V. 25 Yield 21 14 964~' · 76 54 4.0 10 28,050 Tr 3/4 '15 P.V. 21'Yield 15 15 9724 76 55 4.1 10 28,050 Tr 3/4 15 16 9906 i76 ~-----~'~-L~,~ ~8,050 Tr 1-1/!'15 ~.,. I 17 10077 .... 76.5' 57' 3.8 10 l-8,050 Tr 1 16 ~''18'' 10108 76 51 4 O 9..9 28,050 Tr 3/4 16 · ; , 19 10180 .... 76 - 50 '3.9 9.7 28,050 Tr 1 15 ''20 .... '76 50 3.9 9.7"' 28,050 ~r '1 15 21 6862 75.~' 5i 7.0' 10.5 28,050 Tr ~/2 14 · 22____ 686'2 7~. 51 '" 7.0 10.5 28,050 Tr_ 1/~. .... .... 14 UI I0il 0IL d--' CALIF01 J:IA ,ELL t{COI [~AGE " i ,O, 7 LEASE Trading Bqy State FIELD TradinE Bay Field _DF~TAILS OF OP_EF.'~TiOIiS, DESqRIPTIOi!S o - .. ~, RESULTS. TUBING DETAIL SHORT STRING DESCRIPTION JTS, LENGTH BOTFOI': TOP ' 2 7/8'.' Otis N Nipple-ID-2,205 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6,5# N-80 Buttress Pup Jt, 2 7/8" 6,5# N-80 Buttress Tbg, 2 7/8" Buttress x 2 7./8" 8rd X-over . 2 7/8" Guiberson Adjustable Union 2 7/8" BUE 8rd Pup Jt. 2 7/8" 8rd x 3 1/2" 10 rd X-over Baker 9 5/8" x 3 1/2" A-5 Packer 3 1/2" 10rd x 2 7/8" 8rd X-over 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6,5# N-80 Buttress Pup Jt, 2 7/8" Buttress x 2 7/8" 8rd X-over 2 7/8" Otis CX ~'~ndrel 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6,5# N-80 Buttress Tbg, 2 7/8" Buttress x 2 7/8" 8rd. X-over. 2 7/8" Otis CX ~&~ndrel 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6.5# N-80. Buttress Tbg. 2 7/8" Buttress x 2 7/8" 8rd X-over 2 7/8" Otis CX Mandrel 2 7/8" 8rd x 2 7-/8" Buttress X-over 2 7/8" 6.5# N-80 Buttress Tbg. 2 7/8" Buttress x 2 7/8" 8rd X-over 2 7/8" Otis CX ~.~ndrel 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6.5# N-80 Buttress Tbg 2 7~8" Buttress x 2 7/8" 8rd X-over 2 7/8" Otis Bail_ga]~ Nipple 2 .7/8" 8rd x ~2~/8'" Buttress X-over 2 7/8" 6.5# N-80 Buttress Tbg. 2 7/8" 6.5# N-80 Buttress. Pup Jr. 2 7/8" Buttress x 2 7/8" 8rd X-.over CIW Tubing Hanger Landed Below gero .34 15 23 22 61 .65 5179.58 5178.95 1.S0 5178.93 5177.43 10.10 5177.43 5167.33 1049.59 5167.33 4117.74 1.20 3.87 2.00 .50 13.20 1.25 .50 8.80 1.20 5.40 .85 469.36 .95 5.40 1.25 710.01 .95 5.40 1.25 686.36 .95 5,40 1,25 1889,74 1,10 2.05' .95 745.79 12.26 ...55 1.00 37.00 4117.74 4116.54 4116.54 4112.67 4112.67 4110.67 4110.67 4110.17 4110.17 4096.97 4096.97 4095.72 4095.72 4095.22 4095.22 4086.42 -4086.42 4085.22 4085.22 -4079.82 4079.82 4078.97 4078.97 3609.61 3609.61 360~.66 3608.66 ' 3603.26 3603.26 3602.01 2892.00 2891.05 2885.65 2884.40 2198.04 2197.09 2191..69 2190.44 300.70 296.60 50,81 38.55 38,00 37,00 3602,01 2892.00 2891,05 2885,65 2884,40 2198.04 2197,09 2191,69 2190,44 500,70 299,60 297,55 296.60 50.81 38,55 38,00 37,00 UlllOll l)IL'Ca D',ilY O: G~LIt--UI~I;I/~ ~E Trading Bay State A-Il FIELD Trading Bay Field D~-rAILS OF OP,~p~TIOIlS, DUSCRIPTI(~!S..g R~.SULTS T[33ING DETAIL LONG STRING (cont,..) . DESCRIPTION JTS. LENGI}t BOTlrC%! TOP 2 7/8'.' 6.5# N-80 Buttress Tog. 2 7/8" Buttress x 2 7/8" 8rd X-over 2 7/8" Otis CX ~.~andrel 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6.5# N-80 But{ress Tbg. 2 7/8" Buttress x 2 7/8'.' 8rd "X-over .2 7/8" Otis Ball Valve, 2 7/8" 8rd x~/8." Buttress X-over 2 7/8" 6.5# N.-80 Buttress Tbg. 2 7/8" 6.5# N-80 Buttress Pup Jto 2'7/8" Buttress x 2 7/8" 8rd X-over CIW Tubing Hanger Landed Belm~ Zero 22 61 683.64 .95 5.4O 1.25 1889.9.0 1.10 2.05 .95 249.41 .. 12.23" .55 1.00 57.00 2885.43 2201.79 2201.79 2200.84 2200.84 21.95.44 2195.44 2194.19 2194.19 304.29 303.19 301.14~' 301.14 300.19 300.19 50.78 50.78 38.55 38.00 37.00 38.SS. 38.00 .~7..oo -0- · VAGE iD, ~ UiilUIl UIL'LLJ~I't'dII LA" LJ'~LII'-Ut~II~, "..., kELL t COI D 'l.f/kSE Trading Bay State FIELD Tradfl~g Bay Field · DETAILS OF O_PEaATIpIis, DESCRIPTIO[!S llFBING DETAIL IX3NG STRING DESCRIPTION JTS. 2 7/8" Buttress TapeSed Guide 2 7/8" 8rd x 2 7/8" Butt. X-over 2 7/8" Otis N Nipple-ID 2. 205" 2 7/8". Buttress x 2 7/8" 8rd X-over 2 7/8" 6.5# N-80 Buttress Tbg. 17 2 7/8" 6.5# N-80 Buttress Pup ' 2.. 7/8" 8rd x 2 7/8" Buttress X-over · 2 7/8" EUE 8rd Pup Jt. 3 1/2" 8rd x 2 7/8" 8rd X-over Guiberson A-1 Seal Assbly ID-3.25" Guiberson Type P. Landing Coupling 2 7/8" 8rd x 3 1/2" 8rd X-'over 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6.5# N-80 Buttress Tbg. 1 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" Otis XA Sleeve ID-2.313" 2 7/8" Buttress x 2 7/8" 8rd X-over 2 7/8" 6.5# N-80 Buttress Tbg. 43 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 8rd x 3 1/2" 10rd X-over Baker 9. 5/8" x 3 1/2" x 3 1/2" A-5 Packer 2 7/8" 8rd x 3 1/2" 10rd X-over 2 7/8" 8rd x 3 7/8': Buttress . X-over " 2 7/8" 6.5# N-80 ButtYess 2 7/8" Buttress x 2 7/8" 8rd X-over 2 7/8" Otis XA Sleeve ID 2.513" 2 7/8" Buttress x 2 7/8" 8rd X-over 2 7/8" 6.5# N-80 Buttress Tbg 1 2 7/8" Buttress x 2 7/8" 8rd. X-over 2 7/8" Otis CX b~ndrel 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6.5# N-80 Buttress Tb§. 14 2 7/8" Buttress x 2 7/8" 8 rd. X-over 2 7/8" Otis CX b~ndrel 2 7/8" 8rd x 2 7/8" Buttress X-over 2 7/8" 6.5# N-80 Buttress Tbg. 23 2 7/8" Buttress x 2 7/8" 8rd : X-over 2 7/8" Otis CX Mandrel 2 7/8" 8rd x 2 7/8" Buttress , X-over 2 7/8" 6.5// N-80 Buttress Tbg. 22 . 50 6056.64 6056.14 .1.35 6056.14 6054.79 .65 6054.79 6054.14 1.80 6054.14 6052.34 .527.24 6052.34 5525.10 10.05 5525.10 5515.05 .. .90 5515.05 5514.15 .10.10 5514.15 5504.05 .37 5504.05 5503.68 16.95 5503.68 5486.73 .70 ' 5486.73 5486.03- .65 5486.03 5485.38' 1.50 5485.38 5483.88 31.13 5483.88 .5452;75 .95 2.70 1.70 1331.99 1.20 .50 5452.75 5451.80 5415.80 5449.10 5449.10 5447.40 5447.40 4115.41 4115.41 4114..21 4114.21 4113.71 13.14 4113.71 4100.57 .50 4100.57 4100.07 1.25 4100.07 4098.82 10.10 4098.82 4088.72 1.40 3.66 1.25 30.20 4088.72 4087.32 4087.32 4083.66 4083.66 4082.41 4082.41 4052.21 1.20 4052.21 4051.01 5.40- 4051.01 4045.61 i.25 4045.61 4044.36 433.30 4044.36 3611.06 , ;95 3611.06 3610.11 5.40 3610.11 3604.71 1.25 3604.71 3603'.46 710.43 3603'.46 2893.03 ' .95 5.40 2893.03 2892.08 2892.08 2886.68 1.25 2886.68 2885.43 683.64 2885.43 2201.79 Trading Bay State t,,ELL I COIO t,;~LL ID, A-11 wo 'FLED Trading Bay Field ~DATE 4/20/73 4/21/73 .. .' 4/22/73 4/23/73 · 4/24/7: ETD 10,180'TD 6,867'ETD 10,180'TD 6,867 '.ET[ 10,180'TD 6,867'ETD 10,180'TD 6,867 'ETD 10,180'13 6,867'ETD DETAILS OF .OPEpATiOI;$, DESCRIPTIOj!S g RESULTS Rltt w/ 9 5/8" junk basket on wireline to 6735'. Pooh. klI! w/ 9 5/8" OD · x 4 1/2" ID Guiberson type A permanent packer, on wireline. Set at 5480'. Ran dual strings of 2 7/8" 6.5# N-80 Seallock tubing. Stabbed into permanent packer at 5480' w/ 9 5/8" x 2 7/8" x'2 7/8" guiberson Rtl-2 hydraulic packer at 4097'. Tested permanent packer to 500 psi - ok. Landed tubing and removed BOPE. Installed x-mas tree. Displaced invermul w/ diesel. Set plug in "N"'nipple at 5173'. Set dual hydraulic packer, at 4097' w/ 2500 psi. Packer failed to pressure test. Displaced diesel w/ 72#/ cu. ft. invermul in tubing and annulus. Removed x-mas tree and installed BOPE. Tested ~OPE to 2000 psi - Pulled dual strings of 2 7/8" 6.5# N-80 Seallock tubihg, Changed out dual hydraulic packer. TIH w/ dual strings of 2 7/8" 6.5# N-80 Seallock tubing and Baker 9 5/8" x 3 1/2" Hodel A-5 double grip hydraulic dual packer. TIt1 w/' dual strings of tubing. Completed running dual strings of 2 7/8" 6.S# N-80 Seallock tubing. Displaced invermul below permanent packer at S480' w/ diesel. Spaced' out and landed tubing w/ Guiberson 9 S/8" x 4 1/2" Type A wireline permanent packer.at S480' and a Baker 9 5/8" x 3 1/2" x 3 1/2" Model A-$ dual hydraulic packer at 4097'. Removed BOPE. Installed x-mas tree. Displaced invermul in tubing and annulus w/ diesel. Set dual hydraulic packer w/ 2000 spi. Tested packer w/ 1S00 psi - ok. Completed wireline work, setting gas lift .valves and ball valves. Unloaded diesel in both' strings tubing by gas lift. GROSS NET CUT MCF GOR GRAV. TBG/~SG. A-11 S llZ9 - 1110" '1.7%' ' '2'94 .... Z65 Z9.5°' 1007'103-0-- .. _ A-il L 300 9 97% - - - 85/1030 Continued production testing A-Ii S. GROSS NET CUT MCF (F/vi) GOR 1042 102--~ .1~-~o 519 SUb-- GRAV. TBG/CSG. 7EI° 1i~/1~052 . Cohtinued cleaning up and unloading A-Il L. .RIG. ,RE.L.EASEp A.T 1.2'00 NOON, 4/24/73 . Production testing well. Uitlg. ll UIL. &,LAd ltill bi L.I,LIt LF~$E Trading Bay State t, ELL l h,wo FlED 'Trading Bay' Field ~DATE 4116173 4/17/73 4/18/73 '4/19/73 DF.TAILS OF CPEP, ATIO[IS, D!iSCRIPTIOi!S o t: ,,--, .......... t, 10,180'TD 6,867'ETD 10,180'TD ' Commenced operations at 12'01 am, 4/16/75. Ran slickline shifting tool. 6,867'ETD Unable to open "CX" sleeve in 2 7/8" tubing at 5440'. (Otis RH-1 packer set at 5481'). Rigged up Schlumberger and perforate, d 2 7/8" tubing at . 5458' w/ 4 holes using 1 1/2" OD tubing puncher.. Displaced 2 2/8" 6.4# N-80 seallock tubing and 9 5/8" casing annulus w/ 72#/ cu. ft. invermul. Installed BPV in tubing hanger. Removed x-mas tree. Installed BOPE. Completed installing BOPE. Tested 2 7/8" pipe rams and 'hydril to 2000 psi-ok Pulled single hydraulic packer loose at 5481'. Removed 2 7/8" tubing hanger. Circ. bottoms up around packer. Bottoms up cut to 63#/ cu. ft.. Circ. and conditioned invermul to 72#/ cu. ft.. Pulled and laid dram 176 jts. of 2 7/8" 6.5# N-80 seallock tubing and hydraulic packer. RIH. w/ 9 5/8" Howco retrievable 'bridge plug on 5" drill pipe and set at 900'. Tested 9 5/8" pipe rams to 1400 psi' - ok. Pooh w/ retrievable bridge plug. Rigged up Schlumberger and ran GR-CBL Collar Lop. from 6100' to 4000' .. Poor bonding indicated at base of productive "C" zone interval at 5175'. 10,180'TD 6,867'ETD TIH w/ 9 5/8" RBP and 9 5/8" RTTS t0ol on 5" drill pipe. Set RBP at 5,400' and RTrs tool a~ 5,380'. Tested to 3500 psi - ok. Displaced invermul w/ filtered Inlet water. Pulled RTrS tool up to 5,290'. Pumped 15 ft3 of sand on top of RBP. Pulled RTFS tool to 5025' RItI w/ Schlumberger 2" OD scallop gun. Found 76' of fill on top of R~P., Perforated bottom · "C" zone from 5174' to 5176' w/ 4 }BF. _Set RTTS tool at 5025'..Broke down perfs w/ 2800 psi-. Pumped in8 ftc~ minute w/ 2800 psi. Mixed 150 sx class "G" cement. Squeezed 135. sx into perfs to a final squeeze pressure of 4400 psi. Pulled RTTS tool to 4033'. RIt! w/ Schlumberger-2" OD scallop gun and perforated top of "C" zone from 4192' to 4194'- w/ 4 HPF Set R/TS at 4033'. Broke down perfs w/ 1800 psi. Pumped in at 18 ft3 per minute w/ 2000 psi. Mixed 300 sx of class "G" cement. Squeezed 277 sx into perfs to a final squeeze pressure of 1800 psi. - ----.~' Pooh w/ RTrS tool. 10,180'TD 6,867 'ETD TIHw/ 8 1/2" bit. Drilled out cement; block squeeze No. 2 from 4108' to 4207'. Tested squeeze perfs, top of "C" zone at 4192'.to 4194' DIL w/ 1800 psi - ok. Drilled out cement, Block squeeze No. 1 from 5101' to 5187'. Tested squeeze perfs, bottoms of."C" zone at 5174' to 5176' DIL w/ 1800 psi ok. Cleaned out to top of RBP at 5400'. Displaced sea water w/ 72#/ cu. ft. invermul. Picked up bridge plug and Pooh. Riggedup Schlumberger. Reperforated "U' zone and added "C" zone perforations as shown: C-4 C-5 C-6 C-7 stray 47-5 48-5 48-7 '49-4 50-5 53-8 53-8 54-5 56-1 4367:-4382 4471-4476-- 4560-4570 4646-4707 4819-4824 4850-4867 4922-4944 4958-4872 5056-5061 5145-5166 'W' POOL TOTAL 5570-5586 5605-5652 567'2-5705 5905-5940 :"D" POOL TOTAL 17 22 14 5 21 16 47 33 35 Point- 101' RT to HSL /I]BING ACCESSORIES: L-0ng S'~Ying-~ 2 7/8" N-80 Buttress: 1. Otis Ball Valve Nipple - 301' ~ 2. Otis CX ~,.~ndrel - 2195'. 3. Otis CX b~ndrel - 2887'. 74. Otis CX b~ndrel - 3605'. 5. Otis CX ~,;~ndrel - 4046'. 6. Otis XA Sleeve - 4048'. 7. 9 5/8" x 3 1/2" x 3 1/2" A-5 t'~. Pkr. - 4100'. 8. Otis XA sleeve - 5449'. 9. Locator sub & 4.75" OD seal assby, 5486' . 10. Guiberson 4.75" OD Perm. Pkr,-5487' 11 Otis N Nipple - 6054'. 12~ 2 .7/8" Tapered Guide - 6056'. Short String - 2 7/8:' N-80 Buttress: A. Otis Ball Valve Nipple - 298'~ B. Otis CX ~kndrel - 2191'. C. Otis CX 5~ndrel - 2885'. D. Otis CX ~kndrei - 3603'. E. Otis CX Mandrel - 4080'. F, 9 5/8" x 3 1/2" x 3 1/2" A-5 Hy. Pkr. - 4097'. G. Guiberson Adjustable Union - 4113'. H. Otis N Nipple - 5179'. 1085'-13 3/8" 61# J-55 csg. Cemen£ed w~ 475 sx. "U' cement w/ 1/2 cu. ft. perlite/sx, and 670 gel and 200 sx. "G" cement. 5180'-Short String Tubing Tail [. ,. TOP PACt~R Baker A-5 Dual tb/drostatic Set Packer- 9 5/8" x 3 1/2" x 3 1/2". BOTTa~,I PACKER Guiberson "A" Single Wireline Set Packer- 9 $/8" x 4 3/4". DATE I'~LL S[~tATIC TRADING BAY STATE A-Il WO 9 10 11 12 6057'-Long String Tubing Tail. 7092'-9 5/8" 43.5# N-80 Csg. self fill collar at 7045' and DV DILAWN .... CKD. SCALE DATE AFE #40499. 4/23/73. UNION OIL COMPANY OF CALIF-C)RNIA SHE~$ ~ ~HEE! FORM 247 (NEW 5/66) ~JASE WELl., NO ........ FIELD_ ;1ZE .3-3/8 9-5/8 V/EIGHT 43.5~/ THREAD seallock buttress GRADE DEPTH J-55 N-80 1085 7092 REMA}IK S Baker flexiflow shoe btm-coIlar bet jnts #1 & #2 HowcO'float shoe btm-Howco float' & 'self fill Bet. ~.ts #1 & #2. Howc° DV collar @ 3623' PERFORAT~.NG REcoRD __ 6410, ,(1_') ., . 6862' s_q_z_ f/1 Unable to break formation - open .......... 21 ' 6070 (1.,) I. ....... " l/2 " " " " 22 5505 ' " "' ' ' . (1 ).. ~/3 " " " · · "23 6025_5'98i .--.x ........ _ _ ) .. ......... 5899-5860 ' .... 5816-5S02 ~ FO~ PRO. DUCTIJNi". .... ., ,,- 5769-5742 ...... , , , 5705-5672 \ ..... 5652-5605~ ,,. ......... ,.., . ....... ' ........... " · 55"8625570 "-'~' .I .'. - · . . . · · '. ~ INITIAL PRODUCTION TYPE: cameron . V~EJ~L_ttE~ 12" v' . CASING HEAD: Series 900 SOW 13-3/8" OD caSing-type ,,WF, .. ' 12" CASING HANGER: x 9-5/8" type "CA"-slio & seal assembly CASING SPOOL: TUBING t-iEAD:_12" 30001! ~ x 10" 30001/ WP tYpe' DC-B spool. TUBING tlANGER: '.10" x 2-7/8" DC-FBB single / TUBING HEAD TOP' Cameron Single block tree - w/Shaffer-Cameron adapter flange MASTER VALVES: Cameron' BlOck s~ab master Willis choke Willis High-Low 2-7'/8" 8rd LEASE UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. FIELD SHEET D PAGE NO. 3, , e e DATE 9/17/78 9/1~/78 9/19/78 9/20/78 9/21/78 9/22/78 9/23/78 9/24/78 ETD lO,180' TD - 6775' ETD (fill) 9 5/8"@7093' 13 3/8"@1085 lO,180' TD 6867' ETD (cmt. ret.) 13 3/8"@1085 lO,180' TD 6802' ETD (fill w/junk) 6867' ETD (cmt. ret.) lO,180' TD 6867' ETD (cmt. ret.) 9 5/8"@7093' 13 3/8"@1085 lO,180' TD 6867' ETD (cmt. ret.) 9 5/8"@7093' 13 3/8"@1085 lO,180' TD 6867' ETD (cmt. ret.) 6802' ETD 9 5/8"@7093' 13 3/8"@1085 lO,180' TD 6867' ETD 6802' ETD 9 5/8"@7093' 13 3/8"@1085 10,180' TD 6867' ETD 6802' ETD 9 5/8"@7093' 13 3/8"@1085 DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS Commenced operation @1'200 Hrs. (Noon) 9/17/78. Moved Moved rig from TBS #A-32 to TBS #A-11. R.U. & pulled ball valves in L.S. & S.S. tbg. Bullheaded tbg. string w/81# CACL2 & circ. csg. ann. well dead. Installed back press valve. Removed tree, installed BOPE. Pulled all 4 gas lift valves from Short String. Cut S.S. at 4089', 6' above dual pkr. Circ. BTMS up thru S.S. Pulled & L.D. 2 7/8" S.S. compl assy. Pulled 70,000# over string on L.S. and pulled dual pkr. loose. Circ. btms up thru L.S. Circ. & spotted Safe Seal Pill. POOH. Pulled & L.D. 2 7/8" compl Assy. RIH w/ Tri-State Pkr. Picker'& Mill & cut over pkr. at 5488'. POOH w/ Pkr. RIH to 6802' w/ 8 1/2" bit & 9 5/8" csg. scraper. (Found fill w/ junk on top). Circ. clean. RIH w/ Baker retrievamatic and set @4136'. Tested 9 5/8" csg. to 2000 psi above ret. POOH. RIH w/ Baker ret. BP and set @1000' RemoVed BOPE and changed DCB spool from 10" 30~0# to 10" 5000# and tested. Replaced and tested BOPE to 2500 psi. RIH to pick ret. BP. Gas below BP. Circ. out at 1000'. PU BP and RIH to 6712'. Circ. out gas cut mud and raised mud wt. from 72# to 78 PCF. Mixed mud. Built wt. to 78 PCF. POOH w/ ret. BP. PU Baker circ. washer. RIH to 6030'. Circ. hole volume. Acid washed "D" zone perfs w/20 gal per ft. 5% HCL w/ 7% Solvent. Acid washing "C" Zone perfs. Finished washing "C" zone perfs w/20 gal/ft..5% HCL, 7% solvent. POOH. L.D. wash tools. CO to 6802' ETD w/bit & scraper. Ran gage ring and junk basket to 5600' Set Brown "BD" perm pkr. on W.L. at 5470'. RIH ~/seal on DP and tested "BD" pkr. at 5470' to 500 psi. - OK. Acid washed perfs 6025' -5981' 5940'-5905',5899'-5860',5816'-5802', 5769'-5742',5705'- 5672', 5652'-5605', 5586'-5570', w/5355' gal 5% HCL. Ran dual 3 1/2" compl assy. Landed w/long string muleshoe 5540'. "XN" at 5508', "XA" @5430', 4200', 4061'. Seal and locator sub at 5465'. Triple pkr. 4102'. Ball valve at 303'. Short string, muleshoe 4142' "XA" 4064, triple pkr. 4102', ball valve 303'. Top of 1 1/2" string at 4056', BTM at 5435'. Spaced out and set triple pkr w/3700 psi. Tested pkr w/500 psi - ok. Opened "XA" in long string 5430' & 4061'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE WELL NO. FIELD e DATE 9/25/78 ETD lO,180' TD 6867' ETD (cmt. ret.) 6802' ETD 9 5/8"@7093' 13 3/8"@1085 DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS Installed back pressure valve. Remove BOPE. Installed and tested tree to 5000 psi O.K. Changed over to FIW. Closed XA at 5430' and 4061'. RU to move to TBS A-10. Released rig at mid 9/25/78. UNIO!I OIL OF CALIFOP 'IIA SHEET D PAGE LEASE TRADING BAY STATE I'i~LL IlO, A-11 WO FIELD TRADING BAY ~ATE ETD JTS 1 1 15 7 5 6 7 1 3 1 3 5 7 1 17 25 6 56 1 8 39 5 134 178 DETAILS OF OPEP~TIONS, DESCRIPTiG~IS & RESULTS TUBING DETAIL LONG STRING DESCRIPTION LENGTH BOTTOM 2 7/8" Mule Shoe 2 7/8" X-Over 2 7/8" 6.4# N-80 Butt. Tbg. 2 7/8" Otis "X" Nipple 2 7/8" 6.4# N-80 Butt. Tbg. Brown Seal Assembly and X-Over to top of Packer Locator Sub 2 7/8" X-Over 2 7/8" 6.4# Butt. Tbg. 2 7/8" Otis "XA" Sleeve 2 7/8" 6.4# Butt. Tbg. 2 7/8" Camco KBUG gas lift Mandrel 2 7/8" 6.4# Butt. Tbg. 2 7/8" Camco KBUG gas lift Mandrel 2 7/8" 6.4# Butt. Tbg. 2 7/8" Blast Joints 2 7/8" 6.4# Butt. Tbg. 2 7/8" Camco KBUG gas lift Mandrel 2 7/8" 6.4# Butt. Tbg. 2 7/8" X 3 1/2" Butt. X-Over 3 1/2" 9.3# N-80 Butt. Tbg. 3 1/2" Otis "×A" Sleeve 3 1/2" 9.3# Butt. Tbg. Brown Triple Hyd. P_kr. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" Otis "XA" Sleeve 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" Camco KBUG gas-1 ift Mandrel 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" Camco KBUG gas lift Mandrel 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" Camco KBUG gas lift Mandrel 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" Otis Ball Valve 3 1/2" 9.3# Butt..Tbg. 3 1/2" 9.3# Butt. Pups (4) CIW Tubing Hanger E1 evation 1.05' .96' 30.03' .75' 30.06' 12.00' .89' 1.25I 29.84' 3.60' 30. O1 ' 7.82' 448.50 7.82 208.06 97.54 178.69 8.28 208.41 .68 30..40 4.00 91.89' 6.34 6.15 31.16 4.00 91.58 6.10 152.15 7.00 212.98 5.08 29.43 5.10 525.69 7.00 767.81 10.12 182.07 7.00' 1713.54 4.08 28.35 2.65 250.74 14.70 1.00 36.50 Total joints of 2 7/8" 6.4# N-80 Butt. Tbg. 2 7/8" Blast Joints Total joints .of 3 1/2" 9.3# N-80 Butt. Tbg. Total Joints 5540.85' 5539.80' 553,8.84' 55O8.81 ' 5508.06' 5478.00' 5466.00' 5465.11 ' 5463.86' 5434.02' 5430.42 5400.41 5392.59 4944.09 4936.27 4728.21 4630.67 4451.98 4443 .-70 4235.29 4234.61 4204.21 4200.21 4108.32 41 O1.98 4095.83 4064.67 4060.67 3969.09 3962.99 381 O. 84 38O3.84 3590.86 3585.78 3556.35 3551.25 3025.56 3018.56 2250.75 2240.63 2058.56 2051.56 338.02 333.94 305.59 302.94 52.20 37.50 36.50 TOP 5539.80' 5538.84' 5508.81 5508.06' 5478.00' 5466.00' 5465.11 ' 5463.. 86' 5434.02' 5430.42' 5400.41 ' 5392.59' 4944.09' 4936.27' 4728.21 ' 4630.67 4451.98 4443.70 4235.29 4234.61 4204.21 4200.21 41 O8.32 4101.98 4095.83 4064.67 4060.67 3969.09 3962.99 381 O. 84 3803.84 3590.86 3585.78 3556.35 3~51; 25 3025.56 3018.56 2250.75 2240.63 2058.56 2051.56 338.02 333.94 305.59 302.94 52.2O 37.50 36.50 .00' uHie[l OIL CF CALIFOF 'IIA ',ELL I',ECO D SHEET D PAa LEASE TRADING BAY STATE l'~ll ,iO, A-11 WO FIELD TRAD I NG BAY DATE ETD JTS ,, 1 1 8 7 11 10 17 2 9 8 9 16 13 10 8 1 130 131 DETAILS OF OPEP~TIONS, DESCRIPTiG~IS & RESULTS TUBING DETAIL SHORT STRING DESCRIPTION LENGTH BOTTOM 2 7/8" Otis "N" Nipple 2 7/8" 6.4# N-80 Butt. Tbg. Brown Triple Hyd. Pkr. 2 7/8" 6.4# Butt. Pup 2 7/8" X 3 1/2" Butt. X-Over 3 1/2" Butt. Coupling 3 1/2" 9.3# N-80 Butt. Tbg. 3 1/2" Otis "XA" Sleeve 3 1/2" 9.3# Butt. Tbg. 3 1/2" Camco KBUG g.l.m. 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" Camco KBUG g.l.m. 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" Camco KBUG g.l.m. 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" Camco KBUG g.l.m. 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tbg. 3 1/2" 9.3# Butt. Pup 3 1/2" 9.3# Butt. Tb§. 3 1/2" Otis Ball Valve 3 1/2" 9.3# Butt. Tbg. _ 3 1/2" 9.3# Butt. Pups (4) CIW Tubing Hanger E1 evation Jt. 2 7/8" 6.4# N-80 Butt. Tbg. Jts. 3 1/2" 9.3# N-80 Butt. Tbg. Total Joints .75 31.41 7.78 2.15 .53 .81 31.80 4.00 30.96 7.00 246.63 6.09 218.50 7.00 333.53 5.02 307.92 7.00 520.01 5.11 57.36 5.08' 281.34' 7.00' 238.85' 6.10' 267.75' 4.13' 485.68' 4.15' 390.57" 6.05 309.04 2.65 248.69 16.77 1.00 36.50 4142.71 4141.96 4110.55 4102.77 4100.62 4100. n9 4099.28 4O67.48 4063.48 4032.52 4025.52 3778.89 3772.8O 3554.30 3547.30 321 3.77 3208.75 2900.83 2893.83 2373.82 2368.71 2311.35 2306.27 2024.93 2017.93. 1 779.08 1772.98' 1505.23 1 501.10 1 O1 5.42 1011.27 620.70 614.65 305.61 302.96 54.27 37.50 36.50 TOP 4141.96 4110.55 4102.77 4100,62 4100.09 4099.28 4067.48 4063.48 4032.52 4025.52 3778.89 3772.80 3554.30 3547.30 3213,77' 3208.75 2900.83 2893.83 2373.82 2368.71 2311.35 2306.27 2024.93 2017.93 1779.08 1772.98 1505.23 1501.10 1015.42' 1011.27' 620.70' 614.65' 305.61 ' 302.96' 54.27' - 37.50' 36.50' .00' LEASE UHIO!'I OIL CF CALIFOP 'IIA I',£LL I TRADING BAY STATE SREF[ D PAGE:~ l'~'~L]_ ~I0, A-11 WO FIELD TRADING BAY DATE ET~ JTS ,, 1 13 1 6 6 4 1 9 1 33 3 6 1 43 · DETAILS OF OPEP~ATIONS, DESCRIPTIGilS & RESULTS TUBING DETAIL SIDE STRING DESCRIPTION LENGTH BOTTOM 1 1/2" Tubing 34.18 Camco gas 1 ift mandrel 8.34 1 1/2" Tubing 416.58 1 1/2" Pup 10.08 1 1/2" Telescoping Jt. 22.75 Camco gas 1 ift mandrel 8.34 1 1/2" Tubing 198.29 1 1/2" Pup 10.03 1 1/2" Blast Joints 99.01 1 1/2" Tubing 131.78 1 1/2" Pup 20.14 1 1/2" Telescoping Jt. 23.42 Camco gas lift mandrel 8.34 1 1/2" Tubing 290.93 1 1/2" Pups (4.) 22.48 1 1/2" Telescoping Jt. 22.51 Brown Triple Hyd. Pkr. 8.35 1/2" x @ 2 7/8" X-Over 2.56 7/8" 6.4# Butt. Tbg. 31.48 7/8" Pup (perf'd) 10.10 Jts. 1 1/2" Tubing Jts. 1 1/2" Telescoping Jts. Jts. 1 1/2" Blast Joints Jts. 2 7/8" 6.4# N-80 Butt. Tubing Total Joints 5435.19 5401. O1 ' 5392.67' 4976.09' 4966. O1 ' 4943.26 4934.92 4736.63 4726.60 4627.59 4495.81 4475.67 4452.25 4443.91 41 52.98 4130.50 4107.99 4099.64 4097.08 4065.60- TOP 5401.01 5392.67 4976.09 4966.01 4943.26 4934.92 4736.63 4726.60 4627.59 4495.81 4475.67 4452.25' 4443.91 4152.98 4130.50 4107.99 4099.64 4097.08 4065.60 4055.50 ,' ,, T~JBING DETAIL LONG STRING 1 3 1/2" Otis Ball Valve - 303' 2. 3 1/2" Camco KBUG GLM - 2051' 3. 3 1/2" Camco KBUG GLM - 3019' 4. 3 1/2" Camco KBUG GLM - 3804' 5. 3 1/2" Otis "XA" Sleeve - 4061' 6. Brown Triple Pkr. - 4102' 7. 3 1/2" Otis "XA" Sleeve - 4200' 8. 2 7/8" Camco KBUG GLM - 4444' 9. 2 7/8" Blast jts - 4631'-4728' 10. 2 7/8" Camco KBUG GLM - 4936' 11. 2 7/8" Camco KBUG GLM - 5393' 12. 2 7/8" Otis "XA" Sleeve - 5430' 13. Locator Sub - 5465' 14. Brown "BD" Pkr. - 5470' 15. Seal Assembly - 5466'-5478' 16. 2 7/8" Otis "X" Nipple -'5508' 17. 2 7/8" Mule Shoe - 5540' SHORT STRING A. 3 1/2" Otis Ball Valve - 303' B. 3 1/2" Camco KBUG GLM - 2018'' C. 3 1/2" Camco KBUG GLM - 2894' D. 3 1/2" Camco KBUG GLM- 3547' E. 3 1/2" Camco KBUG GLM- 4026' F. 3 1/2" Otis "XA" Sleeve - 4063' G. 2 7/8" 6tis "N" Nipple - 4143' SIDE STRING I. Top of 2 7/8" String - 4056' II. 1 1/2" Telescoping jt - 4108' III. 1 1/2" Telescoping jt - 4452' IV. 1 1/2" Blast jts - 4628' - 4727' V. 1 1/2" Telescoping jt - 4943' VI. End of. Side String - 5435' 13 13 3/8" C. 1085' 14 '-- 9 5/8"' C. 7092' t TBS A-ii WO 9/25/78 UNI5N 01£ .C~MPAHY OF CALIFO}:NIA- _ $CAL~ , I DA'C~ ....... UNION OiL CO. OF CALIFORNIA DRILLING RECORD Sh EET D PAGE NO.- 10 Trading Bay State LEASE V~ELL NO,. A-Il FIELD Trading Bay DATE 5/21/70 22 23 E. T. D. 6862' 6862' 6862' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RIH. Circ & cond mud. Drl d med to firm cmt. from 6630' to 6865'. Circ & cond. POH. RU Schlum. Set Howco BP @ 6862' on wireline. Ran GR correlation log. Perfd 4 holes @ 6410'. RIH w/Howco RTTS tool. Set Below perfs. Tstd dp to 3500 psi OK. Pulled & set tool @ 6348'. Backed up annulus w/2000 psi. Pressd to 4000 psi. Unable to get breakdown. Stopped @ 4000 psi. Bled off to 3000 psi @ 1-1/2 ft3/min. Second time bled off less. Released press. POH. Schlum perfd 4 holes @ 6070'. Rill & set Howco RTTS @ 6005'. No breakdown. Pressd to 350~ psi. Bled off to 2500 psi in 10 min. Pressd to 3500 psi again w/4 ft~. Bled off to 3000# in 5 min. Repressd w/l-l/2 ft3. Released pressure. POH. Schlum'perfd 4 holes @ 5505'. RIH & set Howco RTTS @ 5449'. Slight breakdown @ 3500 psi. Pumped 2 ft3/min @ 3300 psi. Pulled tool loose. Pumped 50 ft3 wtr a~ead, 50 sx (57 ft3) Class "G" cmt, 436 ft3 wtr. Closed tool. Sqzd w/60 ft~ wtr 3500-4000 psi. tteld steady @ 4000 psi. Bled off and repressd w/same volume. Released press. Pulled tool loose. Could not circulate either direction w/2200 psi. POH. Found cmt. 18 Singles above tool. Cmt firm in top 16, soft in btm 2. Tool clear. RIH w/bit & scraper to plug @ 6862'. Circ & cond m~d. Lay down dp. Spot'77#/ft3 Invermul from 6862' to 4800'+- (150 bbls). POH. RU Schlumberger. Perfd 4 hpf 4" guns from 6055' to 6025' w/hyper jet, . Schlumberger completed perforating 4 hpf from 6025' to 5981', 5940' to 5905' 5899' to 5860', 5816' to 5802' 5769' to 5742' 5705' to 5672' 5652' to 5605' & 5586' to 5570'. Rigged down Schlumberger. Rigged up and ran tubing:.as indicated in attached packer installation plan. RU Howco. Displaced mud & invermul w/diesel after installing xmas tree. Set pkr w/3000#. Tstd pkr for seal w/llO0#. Released rig for mov~ to ~22, Conductor #8 _@ 10:00 PM 5/23/70. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D 9 PAGE NO .... LEASE. Trading Bay State WELL NO, A-11 FIELD. i T~ading Bay DATE 5/5/70 10 11 12 13 14 15 16 17 18 19 2O E.T.D. 8895' 8978' 9107' 9107' 9228' 9387' 9495' 9582' 9600" 9640' 9724 .' 9906' 10077' 10,108' 10,180' 10,180' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DDrld & surveyed 8-1/2" hole from 8797' to 8805'. POH for bit chng. RIH w/DA & bit #47. Drld & surveyed 8-1/2" hole to 8872'. P0H for DDrl. RI w/DDrl & bit #48. DDrld to 8895'. : DDrld & surveyed 8-1/2" hole from 8895' to 8905'. POH for bit chng. RIH w/DA & bit #49. Drld & surveyed 8-1/2" hole to 8955'. P0H for bit chng. RIH w/bit #50. Drld to 8978'. Drld & surveyed 8-1/2" hole from 8978' to 9018'. POH for bit chng. RIH w/bit #51. Drld & surveyed 8-1/2" hole to 9107'. Pulled to shoe for electrical.~rprs. POH following rprs. RIH w/bit #52. Made electrical rprs. Drld & surveyed 8-1/2" hole from 9107' to 9228'. Drld & surveyed 8-1/2" hole from 9228' to 9387'. Drld & surveyed 8-1/2" hole fro~ 9387' to 9495'. POIt.~ Changed drilling line. RIH w/bit #56. RIH. Drld & surveyed'8-1/2" hole from 9495' to 9582'. POH. RIH w/bit #58 and locked in DA. Reamed tight spots @ 7945' & 8045'. Plugged bit. ?OIt. RIH reamed tight spots. Plugged jets, pulled 15 stds, Jets unplugged· RIH. Reamed from 8045' to btm. Drld 8-1/2" hole to 9600' Circ POH Tight. Circ & added'asphalt treatment to mud. Pulled to'shoe. Shut down worked on DC power problem until 8:15 am. P0tt. RI to top of HWDP w/bit #59. Cont work on DC power. Rill, drld 861/2'' hole from 9600'' to 9640'. Drld 8-1/2" hole from 9640' to 9668'. Dropped survey. POH for new bit. RIH w/bit #60. Drld 8-1/2" hole from 9668' to 9724'. POH for bit chng. RI w/bit #61. Drld & surveyed 8-1/2" hole from 9724' to 9906'. Drld & surveyed 8-1/2" hole from 9906' to 10,077'. Drld & surveyed 8-1/2" hole 10,077' to 10,108' (T.D.). Circ for logs. Ran Schlumberger DIL, GR density & dipmeter. Completed dipmeter log. Ran SNP. RD Schlumberger. Made up DA. RIH. Drld 8-1/2" hole from 10,108'TD to 10,180'. Dropped survey. POH. RIH w/oedp to 9500'~ Pumped 20 ft3 wtr ahead, 85 sx (98 ft3)_Class "G" cmt, mixed to a 116# slurry, and 10 ft3 wtr behind. Disp w/820 ft3 mud. Pulled to 7215'. Pumped 20 ft3 wtr ahead, 100 sx (115 .ft3) Class "G" cmt, mixed to 116# slurry, and 10 ft3 wtr behind. Disp w/680 ft3 mud. CIP on first plug @ 9500 @ 5:20 am 5/20/70. Pulled 6 stds. Circ. POH. Laid down HWDP. PU bit & scraper. RIH. Did not have cmt above shoe. POH. RIH w/oedp to 7150' (firm cmt). Pumped 20 ft3 wtr ahead, 200 sx' (230 ft3) Class "G" cmt, mixed to a 116# slurry, & 10 ft3 wtr behind. Disp w/658 ft3 mud. CIP @ 8:40 am 5/20/70. Pulled 10 stds. Circ. PO}I. PU bit & scraper. RIH. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO LEASE Trading Bay State VVELL NO.. A-11 I FIELD ..... Trading Bay DaTE 4/21/7o 22 23 24 25 26 27 28 29 3O 511170 E. T. D. 7130' 7130' 7280' 7438' 7671" 7828' 7925' 8001' 8068' 8155' 8344' 8426' 8644' 8797' DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS Drld DV collar @ 3623'. RIH, rubbing dp to 7045'. Drld both collars. RI to shoe. No cmt between float shoe & collar. Drld shoe & CO to 7100'. Drld 8-1/2" hole to 7130'. Circ btms up. POH. RU Dresser-Atlas. Set Howco EZ drill BP on wireline @ 7085'; perfd four 1/2" hpf @ 7075'. RD Dresser-Atlas. Set Howco EZ drill retainer @ 7056' on dp. Rigged Howco. Broke formation @ 3800 psi. Pumped 4 ft3 / min @ 3600 psi. Pumped 50 ft3 wtr ahead, 70 sx (80 ft3) Class "G" cmt slurry (118#), and 20 ft3 wtr behind, followed'with 480 ft3 mud w/tool open. Closed tool. Disp w/125 ft3 mud. Final pressure 4000 psi. Pulled tool. CIP @ 10:00 pm 4/21/70. Pulled 5 stands, circ. POH. POH. WOC. RIH w/bit #30. Found cmt @ 7028'. Drld cmt to 7038'. Tstd cmt. Circ until 10:30 am. Drld to 7048'. Tstd cmt. Circ until 11:30 am. Drld cmt to retainer @ 7056'. Drld retainer. Drld cmt to 7080'. Dropped to BP @ 7085' & drld on same. Pushed BP to btm & drld on it. POH for bit & DA change. RIH w/bit #31. RIH. DRld on junk from 7130' to 7146'. Bit would not drill. POH, for bit chng. RIH w/bit '#32 & junk sub~ Drld 8-1/2" hole to 7280'. POH. RI bit #33. Drld 8-1/2" hole to 7438'. POH. Changed bit, RI w/bit #34. Reamed 7382' to 7438'. Drld 8-1/2" hole 7438' to 7587'. PO. RI with 8-1/2" bit #35 to 7671'~ Cont drlg 8-1/2" hole w/bit #35 to 7736'. POH. RI bit #36. Drld 7736' to 7728'. Drld 8-1/2" hole to 7840' PO tight hole 7718' 7608' Bit chng @ 7608' RI bit # 37. Reamed 7590; to~7840'. ' ' Drld 8-1/2" hole 7840' to 7925'. PO. Chngd to bit #38. Reamed 7820'- 7925'. Drld 7925' to 8001'. POll. Chngd to bit #39. RI to shoe. Rprd rotary DC motor (7-1/4 hfs). Replaced rotary motor. RI w/bit #39. Reamed 7790' to 8001'. Drld to 8068'. Drld 8-1/2" hole to 8155' w/short wiper trip @ 8112'. Dropped survey. POH. Chnd bit. RI w/bit #40. Chngd out HWDP, DOT Jars & monel collar. Drld & surveyed 8-1/2" hole from 8155' to 8283'. Dropped survey. POH. RI w/new bit # 41. Drld to 8344'. Drld & surveyed 8-1/2" hole to 8371. PO for bit chng. RI w/bit #39RR. Drld to 8404'. Torqued and lost pump press. POH. Cones missing from bit. RI w/bit #42 & junk sub. Drld up junk to 8426'. POH for bit chng. POH~ RIH w/bit #43. Drld & surveyed 8-1/2" hole to 8644' w/trip for bit #44 @ 8505'. POll for bit chng. POH. Rill w/bit #45. D~ld 8-1/2" hole from 8644' to 8747'. Dropped survey. POH. PU DDrl. RIH w/bit #46. DDrld & surveyed 8-1/2" hole to 8797'. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PagE NO.~ 7 Trading Bay State LEASE ~VELL NO. A-11 FIELI~. Trading Bay DATE 4/16/70 17 18 19 2O E, T. D. 7090' 7090' 7100' 7100' 7100' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Drld 12-1/4" hole from 7000' to 7019'. Dropped survey. POll for bit chng. RIH w/bit #28. Drld 12-1/4" hole from 7019' to 7090'. Circ btms up. POH. Reamed tight spots 5985-6075, 5892-5950, 5612-5651, 4076-4100, 3167-3230, 3130-3140, 2980-3009 & 2620-2630. ,. Ran back to btm. Circ & cond for "E" logs. POH. RU Schlumberger. Ran DIL &. FDC-GR logs. Cont rng SNP, BHC-Sonic & HDT logs. RD Schlumberger. RIH w/DA. Reamed from 7042' to 7090'. Drld to 7100'. Reamed btm 60' several times. Circ & cond mud to run 9-5/8" csg. Circ & cond mud. POll. RU & ran 172 jts 9-5/8" 43.5# N-80 buttress csg. Howco float shoe @ 7092', and collar @ 7045'. Centralizers located at 7070', 7043', 6963', 3581', 3539', 157', 116', & 74'. 9-5/8" Casing Detail Bottom Top Length Jts Description 7092.00 7090.00 7090.00 7048.75 7048.75 7047.21 7047.21 7045.19 7045.19 6392.95 6392.95 6380.30 6380.30 3624.95 3624.95 3622.77 3622.77 39.00 39.00 -0- 2.00 41.25 1 1.54 2.02· 652.24 16 12.65 1 2755.35 67 2.18 3583.77 87 39.00 9-5/8" Howco Float Shoe 9-5/8" 43.5# N-80 buttress csg. 9-5/8" Howco Float Collar 9-5/8" Howco Self Fill Collar 9-5/8" 43.5# N-80 buttress csg. 9-5/8" 43.5# N-80 buttress csg. (pup jr.) 9~5/8" 43.5# N-80 buttress csg. 9-5/8" Howco DV cmt. stage collar 9-5/8" 43.5# N-80 buttress csg. Elevation - Landed below R.T. Landed w/9.29' .above R.T. Total Joints (cut off Jt 7.39') Circ & cond3mud. Rigged Ho~co. Cmtd~first stage w/800 sx Class "G" cmt with 1/2 ft prlt per sk, 1% D-31 & 6% gel added, mixed w/Inlet wtr to a 94# slurry. This was tailed w/250~sx Class "G" cmt mixed w/Inlet wtr to a 116# slurry. Total slurry 1900 ftj. Lead w/25 ft3 wtr. Disp w/1548 ft3 mud. Bumped plug w/2500 psi. Bled off csg, floats held. CIP @ 12:00 Midnight 4/19/70. Circulation was lost 3 times during displacement for periods up to 1 minute and pressure build ups were experienced to 1800 psi before plug bumped. Dropped bomb. Opened DV collar w/700 psi. Circ for 2-1/2 hrs. No cmt to surf. Pumped 850 sx Class "G" cmt w/l% CFR-2 added, mixed w/Inlet wtr to a 116# slurry. This tailed w/400 sx Class "G" cmt mixed w/Inlet wtr to a 118# slurry. Total slurry 1500 ft3. Disp w/1520 ft3 mud. Good returns to surface. Bumped plug w/2500 psi . Bled off csg. CIP @ 4:30 am 4/20/70. Raised BOP & riser. Instld Cameron 12" x 9-5/8" type "CA" slip and-seal assy. Landed csg w/approx 190,000#. Cut off 9-5/8" csg. Instld Cameron 12" 3000# x 10" 3000# type DC-B tbg head spool. Tstd to 3000# OK. Re-instld BOP, riser & flow lines, etc. Tstd blind rams to 2000# OK. PU 7-3/4" magnet. RIH on dp to attempt retrieving chipping hammer in holeo Unsuccessful. POH. ~de up DA. RIH. Rubbered every joint dp tested hydril to 1500 psi & pipe rams to 2000 psi . Hyd.valve on choke line inoperative. Replaced w/Howco valves temporarily. Drld cmt from 3613' to 3623'. UNION OIL CO. OF CALIFORNIA DRiLLiNG RECORD GH EET D PAGE NO. LEASE Trajing Bay State %VELL NO. A-ii FIELD Trading Bay DATE 3/29/70 3O 31 4/1/70 10 11 12 13 14 15 E. T. D. 3004' 3566' 3737' 4194' 4560' 5013' 5327' 5711' 5840' 5930' 6084' 6244' 6325' 6368' 6523' 6609' 6828' 7000' DETAILS OF OPERATIONS, DESCrIPTiONS & RESULTS Opened Hydril. RI to 985'. Disp salt wtr w/78# mud. RI. CO bridge from 1085' to 1600'. Circ. RI to 2971'. CO to 3004'. Circ & cond mud. POH. RI w/bit #6. Reamed 2960' to 3004'. Drld 12-1/4" hole 3004' to 3238'. Plugged bit. PO. Change Jets. RI fill pipe @ shoe. RI & dlrd 3238' to 3566'. Drld 12-1/4" hole 3566' to 3650'. PO. RI w/bit #7 with 7-3/4" DDrl #3. Drld 3650' to 3737'. PO. RI w/bit #8. Reamed 3591' to 3737'. Cont drlg 12-1/4" hole w/bit #8 3737' to 4190'. PO. RI w/bit #9. Drld 4190' to 4194'. Drld & surveyed 12-1/4" hole from 4194' to 4560'. Chngd to bit #10 @ 4414'. Drld & surveyed 12-1/4" hole from 4560' to 5013'. Trpd for bit #11 @ 4722'. Drld & surveyed 12-1/4" hole from 5013' to 4327' with trip for bit #12 @ 5157'. Pulled 12 stands on trip. Ran back to btm & circ to loosen · tight hole. Drld & surveyed 12-1/4" h01e from 5327' to 5711' with trip for bit #13 @ 5463' & short trip (15 stands) to clean hole @ 5701'. Drld & surveyed 12-1/4" hole to 5840' w/trip for bit #14 @ 5725'. POH. RIH w/DDrl & bit #15. Reamed to btm. DDrld from 5840' to 5930' w/trip for bit #16 @ 5898'. Stuck @ 5930'. Jarred loose. POH. Laid down DDrl. RIH w/DA & bit #17. Reamed to btm. Drld & surveyed 12-1/4" hole from 5930' to 6039'. POH for bit chng, tight spots. Laid down 1 stand collars. RIH w/bit #18. Reamed tight spots 2987' to 3027' & 3230' to 3270'. Rill to 5945'. Reamed to btm. Drld 12-1/4" hole to6084'. POt{ for bit change. POH. 'RIH w/bit #19. Drld 12-1/4" hole to 6222'. Dropped survey. POH. Changed bit. Ran in with 7-3/4" DDrl #5. Reamed 6135' to 6222'. DDrld 6222' to 6244'. Cont DDrld 6244' to 6285'. PO. RI with bit #21. Drld 6285' to 6325'. PO. Cont POH. RI w/bit #22. Reamed 6017' to 6325'. Drld 6325' to 6368'. POH. RI to shoe w/bit #23. RI w/bit #23. Drld 6368' to 6470'. POll. RI w/bit #24 on 7-3/4" DDrl #6. DDrld 6470' to 6523'. POH. RI w/bit #25.' Drld 6523' to 6609'. POH. RI w/bit #26. Cont RIH w/bit #26. Drld 12-1/4" hole 6549' to 6609'. Drld 6609' to 6828' (wiper runs @ 6743' & 6820') 15 stands. Drld 12-1/4" hole from 6828' to 6896'. Dropped survey. POH. Changed bit. Rill w/bit #27. Reamed from 6846' to 6896'. Drld 12-1/4" hole from 6896' to 7000'. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO, LEASE Trading Bay State VMELL NO.A-11 FIELD Trading Bay DATE 3120/70 21 22 23 24 2¸5 26 27 28 E.T.D. 388' 1017' 1086' 1086' 1337' 1594' 2404' 2960'. 3004' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Began moving rig to Conductor #19, well A-Ii @ 6:00 am 3/20/70. Completed move, instld riser, mud line & flow line. Cleaned mud pit & mixed new mud. SPUDDED A-il @ 9:00 PM 3/20/7Q. Drld & surveyed 12-1/4" hole from 228' to 388'. Drld & surveyed 12-1/4" hole from 388' to 750'. POH to PU DDrl. RIH. DDrld and surveyed 12-1/4" hole from 750~ to 1017'. Drld & surveyed 12-1/4" hole to 1086'. POH. Laid down DDrl & monel. RIH w/hole opener. Opened 12-1/4" hole to 17-1/2" to 1086'. Made wiper trip. Circ hole clean. POH. Ran 35 its 13-3/8" 61# J-55 seallock csg w/Baker flexiflow shoe @ 1085' & collar @ 1050'. Four centralizers @. 1067' - 1018' - 87' & 57'. 13-3/8" Casing Detail Bottom Top .Length Jts Description 1085.00 1082.90 1082.90 1052.08 1052.08 1050.28 1050.28 39.00 39.00 -0- 2.10 30.82 1.80 1011.28 '39.00 33 34' 13-3/8" Baker flexiflow shoe 13-3/8" 61# J-55 seallock csg. 13-3/8" Baker flexiflow collar 13-3/8" 61# J-55 seallock csg. Landed below "O" Landed 4.90' above rotary table Total Joints - Cut Off 8.20' RU Howco. Pumped 50 ft3 wtr ahead. Mixed & pumped 475 sx Class "G" cmt with 1/2 ft3 prlt per sk, 6% gel, 1% D-31, tailed w/200 sx Class "G" cmt. Ail cmt. Mixed w/Inlet wtr. Perlite mix cmt to a 98# slurry & Class "G" to A 118# slurry. Displaced w/960 ft3 mud. Bumped plug w/2000 psi. Bled pressure off csg. Floats held. Approx 300 ft3 cmt.returned to surface. CIP @ 2:15 am 3/23/70. WOC. Cut 13-3/8" csg. Instld Cameron type "WF" 12" 900 Series 13~3/8'' OD csg head. Tstd weld w/1600 psi., OK. Instld riser, BOE., Hydraulic & flow lines. Tstd blind rams, riser, Etc. w/2000 psi. OK. Mud in pit, pump lines &csg found to be coagulated. Staged to btm w/oedp. Cir¢ & cond mud. Continued staging to btm conditioning mud. POH. PU bldg da. RIM. Found cmt @ 1038'. Drld cmt, collar & cmt to float shoe. Collar found @ 1050'. Circ & conditioned mud to lower wtr loss and raise vis. Drld shoe. Drld and surveyed 12-1/4" hole to 1337'. POH to PU DDrl to correct right turn. POH. PU DDrl. RIH. DDRL plugged. POH. Cleaned bit, DDrl, dump sub, kick sub, etc. RIH. Plugged again. POH. CO. RIH, DDrld & surveyed 12-1/4" hole from 1337' to 1490'. POH. PU DA. RIH, drld & surveyed to 1594'. Drld 12-1/4" hole to 2025'. Lost Jet out of bit. PO. RI w/NB. Drld 'to 2404'. Drld 12-1/4" hole to 2563'. PO. RI w/bit #RR4. Drld to 2960'. Drld 12-1/4" hole to 3004'. PO to monel DC. Well blew in w/one std DC's in derrick & bit, stab-monel, DC in hole. Closed 'hydril. ~tad 450 psi on annulus. Bled off gas to atmosphere thru choke line. Well head producing room & thru DC in top of derrick. Decreased press to 225 psi, production line cut out in wellhead room, filled it with gas. Shut off valves. Pumped Inlet wtr into annulus. Killed well temporarily. Instld Shaffer lower kelly cock & hydril inside preventor. Well pressured up. Bled off gas. Pumped in 160 bbls of 75# salt' water, thru annulus, killed well. · r - FormD,&1OO1-A · UNION OIL CO. OF CALIFORNIA REPAIR RECORD · · · SHEET A Page NO. ] LEASE_TRADING BAY STATE WELL NO.~-ll W0 CONTRACTOR_~RILLING COMPANY FIELD IRADING BAY TYPE UNIT 0ILWELL 860-E BEGAN: 9/17/78 COMPLETED: 9/25/78 ELEVATIONS: GROUND , PERMIT NO. 70-24 SER~A~ NO. ADL 18731 CASING HEAD COMPANY EIIGINEER UNDE~HY[L . /~/~ /~ / . TUBING HEAD APPROVED (J~..~. g~,~k_ ~--~ ~ ~~.~ ROTARY DRIVE BUSHING ~J '/ CASING & TUBING RECORD --SIZE DEPTH,. WEIGHT ~'/ GRADE ...... I ...................... REMARKS ,_ 13 3/8" 1085' 63# J-55 Cmt'd w/475 SX "G" cement w/.5 F3 perlite/SX plus 6% Gel plus 1% D-31 and 200 S× of "G" cement. 9 5/8" 7092' 43.5# N-80 Howco self fill collar @ 7045' and Howco D.V. collar at' 3623' 3'1/2"i Dual 9.3# N-80 See attached detail PERFORATING RECORD DAT-E-- INTERVAL E.T.D. REASON P~ESENT CONDITION 5/21/70 6410' 6867' Sqz. #1 Unable to break formation - op, en 6070' 6867' sqz. #2 " " " " 5/22/70 5505' 6867' sqz #3 " " " " " 6055'-6025' 6867' Production Open for Production 5/23/70 6025'-5981 ' 6867' " " " " 5940'-5905' 6867' " " " " 5899' -5860' 6867' " " " " 5816'-5802' 6867' " " " " '- 5769'-5742' 6867' " " " " 5705' 5672' 6867' " " " " 5652' 5605' 6867' " " " " ' 5586'-5570' 6867' " " " " · INITIAL PROD~ DATE I I~TERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR R~MARI~B · . · · , · · . . - . · · :(,,', /..: . .: '.. , - . . '..' '. , . I , COMPL. ETION DATE: PRODUCING INTERVAL: INITIAL PRODUCTION: WELL HISTORY PRIOR TO REPAIR LAST COMPLETION NO. 2' "C" and "D" Zone LAST REGULAR PROD. & DATE: "C" Pool 500/485 B/D "D" Pool 550/528 B/D CUMULATIVE PRODUCTION' REASON FOR REPAIR: CLEAN OUT AND ACID WASH All PFRFORATI(IN.q ,o,.,:- :' :;::!-:.,:?:::UNION ";$H E - . "' ' -'- .... ::'"':'>;-'-':' ": :" REPAIR RECORD : .-. ' ..... · . ,...,.: , .' .:,' -:, .- .', '",.:"': , PAGE :: ;-i:-i! :.,:.':':? "' !.:' .'i:-' 'ii/ '" :.:, "'--'i:7":'-'"." . ':' ::'" "' .... --':. :- '.'"' ':':,"'::~; .... -,-: .' . : . .... :-": '~.!"i ..... · .... '" ....... ' """ '" ;" "<'":::" '"' '" LEASE TRADING BAY STATE ':'" '.WELL NO..A-11 NOFIELD TRADING BAY COM?LETION DATE: 9/25/78 A?P. ROVED DAT£ ~--,T,D, D~..TAIL~ OF OPERiTION~, DI~SCRIPTION$ & DATE 4/18/73 4/19/73 INTERVAL ETD REASON 5174 -5176' 4192 -4194' 4200 -4232' 4270 -4310' 4318 -4336' 4367 -4382 4471 -4476 4560 -4570 4646 -4707 4819 -4824 4850 -4867 4922 -4944 4958 -,49~2 5056 -5061 5145 -5166' 5570 -5586' 5605 -5652' 5672 -5705' 5905 -5940' ~ZP~.: CAMERON 5324' 5324' 6867' ,, ,I ,I ,, ,I ,, ,, ,I I, C-2 .C-3 II Sqz. Isolation Sqz. Isolation ~Production - 1! I, I, - ,, ' 11 .. II II . II Ii II ,, . Ii PRESENT CONDITION Sqz'd w/15OSX Cl. "G" Sqz'd w/300S× C1. "G" : C-4 .... C-5 C-6 C-7 StraY 47-5 48-5 48-7 49-4 Open for Production · .. :-'~.50-3 -53-8 53-8 54-5 56-1 II II II II II II II II II II II II II II II II II II II II tl II II II II II II II 'ti II !1 II II II II II II II II II II II II !1 II II II II CASING HANGER: ' ^ ~ 5/8" ' ' '? '" "' ....... ' ................... ' ..... "'"'"' ...... "'~ .... ' .... :" ...... TUBING '-]'2': 3000# ]0" 3000# .r ',v" ~'" "v"~' '".'?:': ..... :'"'":~'":::" .... '-":' "..: ~:" "'".:' :,":-::?,',:""'~' .... :'?':"-":?~,"-":~ ....... ' ..... '" TUBING HEAD TOP: 10" 3000# × 3 1/2" Cameron Dual :~'..,... ..... -: '- '..i-:":. '- -:-..--' : .... :':::: :::?' '::'.'..", .'/:':'::':'i.-:: .... MASTER VALVES: -' CHRISTMAS TREE TOP CONN.' - '3 1/2" EUE . .. -. :::..-.: .: :.,: :-__?::.. :::, :.. .- . . . :-. ...-, _.' ....-.... . .... .:--.<. Form D-IOO1-B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO. LEASE Trading Bay State COMPLETION DATE:,, 4/23/73 DATE DATE 5/21/70 5121170 5/22/70' 5/23/70 Il Il 3/19/73 E.T.D. INTERVAL 6410 (1') 6070 (1') 5sos (1') 6035-5981 5940-5905 5899-5860 5816-5802 5769-5742 5705-5672 5652-5605 5586-5570 4200-4232 4270-4310 4318-4336 4367-4382 4471-4476 4560-4570 4646-4707 4819-4824 4850-4867 4922-4944 4958-4872 5056-5061 5145-5166 5570-5586 5605-5652 5672-5705 5905-5940 TYPE: Cameron WELL NO. A-Il WOFiELD APPROVED Trading Bay Jim R. Callender (Dis..t... I)rl~. Supt.) DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS R~SON PRESFNT CONDITION 6867' Sqz. #1 Sqz. #2 Sqz. #3 Production Unable to break formation - open Il ti It It II II II It Open For Production Il Il Il Il II 11 t! it ti t! ti II II 11 II 11 II II I1 11 II II 11 II 11 11 11 II 11 II 11 I1 II I1 II II II I1 II I1 11 II II' I1 ti I1 II 11 I1 11 II I1 II I1 I! II I! II I1 II I1 I1 II. 1t II WELL I4'~-AD ASSEMBLY- ' CASING H .EAD: 12" series 900 SOW - 13 3/8'' OD csg. type '%~". CASING HANGER: 12" x 9 5/8" type "CA" slip and seal assy. CASING SPOOL: TUBING HEAD: TUBING HANGER: 12,' 3000# WP x 10" 3000# WP type DC-B spool t0"x 2 7/8" Dual TUBING HEAl) TOP:. 10" 3000# x 2 0/16" C. amernn Fhml w/ .g bolt cap top. MASTER VALVES: ¢ · :CHRISTMAS TREE TOP CONN.' Form D-IOO1-A UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET A Page NO. _ i LEASE . FIELD Trading Bay, .... BEGAN: 4/16/73 COMPLETED: ,,4/23/73 PERMIT NO. 70-24 SERIAL NO. ADL - 18731 COMPANY ENG&~EER Wats.on rPv~rdin , Trading Bay State WELL N(~t-ll W0 CONTRACTOR TYPE UNIT__ 0ilwell 860 ELEVATIONS: GROUND See Prev.~.ous CASING HEAD P. eport TUBING HEAD ROTARY DRIVE BUSHING CASING & TUBING RECORD SIZE DEPTH WEIGHT GRADE REMARKS, 13 5/8" 1085' 61# J-55 Cement w/ 475 sx. "G" cement w/ 1/2 ft.3 perlite/ sx. plus 6% gel plus 1% D-31 and 200 sx. of "G" cement. 9 5/8" 7092' 43.5# N-80 Howco self fill collar at 7045' & l!owco DV collar at 3623'. 2 7/8" Dual 6.5# N-80 See attached detail. PERFORATING RECORD II ~)AT~ INTERVAL E.T,D, REASON PRESENT coNDITION SEE A~.~Ct~D St-~ET. ' ., ii , i , INITIAL PRODUCTION AFTE19 AI~ ' DATE I INTERVAL NET OIL CUT C.P. T.P. CHOKE MCF GOR REMARI~.q · ,. · , WELL HISTORY PRIOR TO REPAIR COMPLETION DATE: s/z3/73 LAST COMPLETION NO. PRODUCING INTERVAL: "D" Zone INITIAL PRODUCTION' LAST REGULAR PROD. & DATE: CUMULATIVE PRODUCTION: REASON FOR REPAIR: To Reco..~. lete. FOR REPORT li~IION 0~ CO~A~,]Y OF CALIFOrnIA TVP~ OF SURVEYs' Single .Shot, 9~froscopic Survey ~ T~ad~ng 'Bay Unit w~ NO. A-11 COUNt/PARISH Kenia STATF Alaska OFFmE: Anchorag~,,~?~a~ka . ~ , A-D]'~N-~ B A Y U N I T ASKA 22 MARCH 1970 ERRY-SUN WELL SURVEYING COMPANY SU-0-16~69 ::':' ................... '~ ................................................ :'::'X~::~C~X~{~:::~:':~ ........ ~-'~:~~:~~-~=~?~=~:~:~'-~o~ ~ c co'~'~'~O"Ys:~ ........... ::':;':='":' ":- ~':" ....................... : ........... : . ........ . .... 371 0 0 370,99 370,99 N 0 W 0,00 N 0,25 E 0.25 N 88 0 0 E 0,~9~ . -0,17 ~65 0 20 ~6~,99 464,99 N 6'7 'W 0,22 N 0.26 W 0.3~ N ~8 57 46 W 0,362 -0.00 776 '1 0 775,99 775,99 S 19 W 0,29 N 0,00 W 0.29 N 0 4D 34 W 4.0~1 -0,22 .P32 6 45 ..... -9-~-IL-,48 981,48 S 41 W 8,78 S 7,44. W-- !'I'J-51--S--g-O-15 44 w --~'JO=.~l' I1~,5% ..... TTO~ HOLE' CLOSURE 11..51 FEET AT S 40 15 6,q. W DEPTH TVD' SUB SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION 1000 2000 300O 4000 998,68 897.68 -16'.18$ 1948.32 186'7o32 -232.12S -231o62W 2892,49 2791'49 -698'35$ -625.10W 3868-06 3767-06 -646":58S -573o'25W I 1 51 50 . 107 56 131 26 5000 6863.6! 6762.61 -635.13S '-657.50W " 136 5 6000 7000 5859.45 5758,45 -569,37S -716.52W 160 6 6848-73 6767.73 -4'33.92S -709.64W 151 11 7723.50 -231.30S -632.'39W 175 24 8000 7826,,50 9000 8794,4~4 10000 9755'4]. 8693.44 -23.14S -509.40W 205 30 9656.41 ' 249.56N -509.59W 246. 39 8 TVO = ~_c~r27., :D T_ R F_ C T .1'_ O N A I_ $ 'U R: V'E Y ' ~ .......... -~, p AG~ I '~ ~ TANGENTTAL METHOD UNI_ON n_T~t CNHPANY A-!l_ WFl~k C[IMPLI~TION :RI~PORT PREPARED BY SCS 05/27 ) ~FPTH ANGLF D !'RFCTT~}N TV~) SlJB SEA TOTAL. COORDINATES C L ~0 S U'R..E S DOG LEG SECT[O! LATITUDE DEPARTURE DISTANCE ANGLE SEVERITY DISTANC! OR!GTN tOgA'TEO AT ~O = 0.007 TVD = 0,007 LATITUDE = ) 228 0 O" N OF 228.00 ~77.00 0.00 . ?RA O 15t N ~RF 285'99 1.84.99 O.OON 371 0 O" N OF 370*99 762.99 O.OON ) 465 0 20t N 67W 464.29 363.99 0.22N ) 7~8 0 !5~ N 41F 727.99 626,99 0.74N 745 0 15~ N 23~ 7~4~99 643.99 0.81N 776 i 0~ S 19~ 775:°99 674.99 O.30N O.OOt DEPARTURE = 0.00 0.00 0.00 0.00 0-000 0.25E 0.25 N 88'00E 0.431 0.25E 0.25 N' 88~'00E 0.294 0.25W 0.33 N ~8-38W 0.354 0.13W 0.63 N 12'56W 0-416 O.06W 0.50 N' 7.32W 0.328 O.14F 0.75 N 11'23E 0.386 0,17E 0,83 N 12'27E 0,460 O,OOE 0-30 N O-09E 4,030 0,0 -0.2 -0.2 0,4. 0.3 ) 807 2 O' S 29W 806.97 705.97 0.64S 0.52W 0,8.3 $ 39.0~W 3.322 0.1 838 3 10' S 37W 837.92 736.92 2.0'1S 1.55W 2.54 S 37.66W 3.9'30 0.3 869 .4 10' S 41W 86.8.84 767.84 3.71S 3.03W 4.79 S 39.23W 3.327 0.7 ) 9o I 5 30' S 41W 900,69 799,69 6,02S 5,04W 7.86 S 39,92W 4,166 1,3 932 6 45' S 4iW 931.48 830.48 8.77S 7.43W 11.50 S 40.26W 4.032 2.0 951 7 30' $ 38W 950.31 849.31 10.73S 8.96W 13.9.8 $ 39.86W 4.405 2.3 z ) ~ 887'83 15,04S 13,27W 20,06 S 4.1,4'2W 4,622 3,8 990 9 0" S 45W 988.83 1021 10 O' S 49W 1019-36 918'36 18,57S 17-33W 25,41S 43,02W 3,863 5,6 1154 13 45" S 56W 1148.55 1047.55 36o25S 43.54W 56.66 S 50.21W 3.015 19.3 ) 1245 16 O' S 59W 1236,03 1135,03 49.17S 65,04W 81,54 S 52,91W 2,612 31,4 62,52S 90,14W 109,70 S 55,25W 2,373 46,4 1337 18 O' S 62W 1323,52 1222,52 1381 18 30' S 55W 1365.25 1264,25 70,52S I01,58W 123.66 S 55.22W 5,106 52.2 1412 19 O' S 50W 1394.56 1293.56 77.01S 109.31W 133.72 $.54.83W 5.427 55.6 1453 19 O' S 44W 1433.33 1332.33 86.61S 118.58W ~// 146.85 S 53.85W 4.762 58,8 1501 18 45' S 39W 1478,78 1377,78 ) 1596 18 45' S 39W 1568.74 1467.74 98.60S 128,29W 161.'81 S 52'45W 3,408 122.34S 147.51W 191.64 S 50.32W 0.000 1782 19 45' S 38W 1743.80 1642,80 171,86S 186,21W i./ 253,40 S 47,29W 0,566 74,3 1970 20 15' S 37W 1920,18 1819,18 223.83S 225,37W 317,64 S 45,19W 0,322 82,0 ) 2160 20 15' S 37W 2098.43 1997.43 276.35S 264.94W 382.84 S 43.79W 0.000 89.7 2347 20 O' S 37W 2274.15 2173.15 327.43S 303.43W ~' 446.41 S 42.82W 0.133 97'3 12 2535 19 15' S 37W 2451,64 2350,64 376,93S 340,74W 508,11S 42,11W' 0,398 104,6 )~ 2717 18 45' S 35W 2623.98 2522.98 424.85S 374.29W 566.21S 41.37W 0.451 109.4 3 Ftl,.E ----,--'-"' 2904 18 30' S 36W 2801.32 2700.32 472.86S 409.17W 625.3'1S 40.87W 0.216 3004 18 t5' S 32W 2896.29 2795.29 499.41S 425.76W / 656.27 S 40.44W 1.285 3115 17. 30' S 36W 3002. I5 290t.15 526.42S 445.38W 689.55 $ 40.23W 1.295 3210 16 15' S 37W 3093.36 2992.36 547,65S 461,38W 716'10 S 40-1IW 1.350 ) 3335 15 O' S 40W 3214.10 311,3.10 572.43S 482.18W 748'45 $ 40..10W 1.190 3524 11 30' S 39W 3399.3I 3298.31 601.72S, 505.89W 786,12 S 40.'05~ 1.855 3650 I0 O' S 39W 3523.39 3422.39 618.72S .... 519.66W ~,/ 808.00 S 40-02W 1.'190 3690 10 15' S 51W 3562.75 3461.75 623.20S 525.19W 814.'99 S 40.12W 5.3..01 3756 11 '15" S 61W 3627.48 3526'48 629:.44S 536.45W 827.03 S 40.43W 3.200 3942 10 01 S 64W 3810.66 3709.66 643.60S 565.48W ~' 856.73 S 41.30W 0.734 ) 4. 3o 8 15t S .69W 399'6.71 389.5.71 653.27S 590'67W 880.71 S 42.11W 1.0.:21 4315 6 0t S 86W 4180.70 4079.70 654.62S 609.96W. 894.75 S 42.97W 1'6:54 4414 5 O' N 88W 4279.32 4178.32 654.32S 618.58W 900.43 S 43.39W 1.163 ) o 4596 5 15' N 76W 4460.56 4359.56 650.29S 634.74W.'~ 908.72 S 44.30W 0.603 4722 3 45' N 69W 4586.29 4485.29 647.33S 642.43W 912,01 S 44'.78W 1.265 5157 4 O' N.51W 5020.23 4919.23 628.24S 666'~01W 9.15.'§7 S 46.:,67W 0,284 z 5464 4 45' N 44W 5326'18 5225.18 609.95S 683.67W 916.22 S 48.26W 0.299 5725 4 30' N 38W 5586.37 5485.37 593.81S 696.28W 915.11 S 49'.54W 0.208 5840 5 O' N 41W 5700.93 5599.93 586.25S 702.86W 915.26 S 50.16W 0.485 ,) 5968 8 O' N 39W 5827.69 5726.69 572.40S 714.07W K 915.17 S 51.28W 2.350 6039 7 O' N 39W 5898.16 5797.16 565.68S 719.51W 915.26 S 51.82W 1.408 6222 6 30" N 35W 6079.98 5978.98 548.71S 731.40W 914.35 $ 53.12W 0.374 6233 6 45' N 31W 6090.91 5989.91 547.60S 732.06W 914.21 S 53.20W 4.769 6248 6 30' N 24W 6105.81 6004.81 546.05S 732.75W 913.84 S 53.30W 5.6'31 6325 7 01 N 6W 6182.24 6081.24 536.72S 733.73W 909.08 S 53.81W 2.810 ) 6368 8 O' N OW 6224.82' 6123.82 530.73S 733.73W~/ 905.56 S 54.12W 2.950 6467 9 0~ N 2W 6322.60 6221.60 515.26S 734.27W 897.02 S 54.94W 1.053 6484 8 30' N 4E 6339.41 6238.41 512.75S 734.10W 895.44 S 55.06W 6.117 ) 6526 9 O' N llE 6380.89 6279.89 506.30S 732..84W 890.73 S 55.36W 2.798 6609 9 45' N 15E 6462.70 6361.70 492.72S 729.21W 880.07 S'55.95W 1.196 6752 9 30" N 17E 6603.73 6502.73 470.15S 722.31W 861.84 S 56.93W 0.291 6896 8 .30' N 20E, 6746.15 6645.15 450.15S 715.03W i,-/'-844'93 S 57'80W 0.766 ) 7019 9 30' N 19E 6867,47 6766.47 430.96S 708.42W 829.21 S 58,68W 0.822 7090 9 30' N 1SE 6937.49 6836.49 41g.81S 704,80W 820-36 S 59.21W 0.2'32 7280 11 O' N 17E 7124.00 7023,00 385.14S 694,20WF" 793,88 $ 60.97W 0.794 ) 7438 12 15' N 19E 7278-40 7177.40 353.45S 683.28W 769.29 S 62.64W 0.8131 7587 13 O' N 1SE 7423.58 7322..58 321.57S 672,92W I~'t745.81S 64-45W 0.524 7736 1.3 O' N 21E 7568.77 7467.77 290.28S 660.91W~ 721'85 $ 66,'28W 0.452 ) 7840 14 0m ' N 245 7669.68 7568.68 267..29S 650.68W 703.44 S 67,6'6W 1.173 7925 14'30' N 26E 7751.97 7650.97 248.16S 661.35W 687.69 S 68.86W 0.825 8001 14 45' N 285 7825.46 7724..46. 231.08S 632,27W ~ 673.17 S 69,92W 0.7~1 8155 15 151 N 29E 7974'04 7873.04 195.655 612.63W 643,11 S 72,28W 0.365 8283 15 15' N 295 8097.53 7996.53 166.20S 596.31W 619.04 S 74.42W 0.000 8371 15 O' N 305 8182.54 8081-54 146.48S 584-92WV'~ 602.98 S 75.94W 0.410 8505 15 O' N 34E 8311.97 8210.97 117.73S 565.52W 577,65 S 78.24W 0.772 8747 13 30' N 35E 8547,28 8446'28. 71.45S 533.12W 537.89 S 82.36W 0.628 8858 13 15' N 30E 8655.33 8554.33 49.42S 520.40W~-' 522.74 S 84-57W 1.065 8955 11 30' N 245 8750.38 8649.38 31.75S 512.53W 513.52 S 86.45W 2.236 9018 11 45' N 205 8812.06 8711.06 19.69S 508.15W 508.53 $ 87.77W 1.339 9141. 13 15' N I4E 8931.79 8830-79 7.65N 501'33W 501.38 N 89.12W 1'611 9[87 114 O' N lOE 8976.42 8875.42 18.61N 499.39W 499°74 N 87.86W 2.617 9301 14 45' N 7E 9086.66 8985.66 47.42N 495.86W 498.12 N 84.53W 0.926 9387 15 45' N '5E 9169.44 9068.44 70.67N 493.82W\/ 498.85 N 81.85W 1'313 ) 9495 16 15' N 2E 9273.12 9172.12 100.88N 492.77W 502.99 N 78.43W 0.894 9582 17 15' N 2W 9356.21 9255.21 126.66N 493.67W~V' 509.66 N 75.60W 1.753 9668 17 15' N 5W 9438.34 9337.34 152.06N 495.89W 518.68 N 72.95W 1.034 ) 10017 17 15' N 8W 9771.64 9670.64 254.55N 510.29W ~ 570.26 N 63.48W 0.254 10108 17 15' N 9W 9858.55 9757.55 281.20N 514.51W__ 586.35 N 61.34W 0,325 10180 17 O' N lOW 9927.40 9826'40 301.93N 518'17W ~ 599.72 N 59,77W 0.536 .)ti __ 10 CLOSURE 599.72 N 59- 46' W DIFFERENCE CORRECTION DEPTH TVD SUB'SEA LATI'TUDE DEPARTURE 301 301.00 200-00 O,OON 0.25E 0 0 401 401.00 300.00 O.07N O-09E 0 0 501 501-00 400,00 0.:37N -O.'20W 0 0 ) 601 601.00 500.00 0.56N -O.IOW 0 0 701 701-00 600-00 0.65N O,07E 0 0 80t 801.00 700'00 -0.46$ -0.42W 0 0 ) 901 901.00 800-00 -6.'05$ -5.06W 0 0 ! 002 1001.00 900-00 -16'45$ -14.89W 1 I 1105 1101.00 1000.00 -29.74S -33.89W 4 3 1209 1201.00 1100,.00 -4~o. 00S -56'43W 8 4 1313 1301.00 1200.00 -59.08S -83.68W 12 4 1419 1401.00 1300.00 ' -78.6IS -110.85W 18 6 1524 1630 1501.00 1400-00' -104',46S -133.04W 23 5 1601.00 1500.00 -131'46S -'154.64W 29 6 1736 1701-00 1600-00 -159.75$ -176.75W 35 6 z 1843 1801-00 1700.00 -188.72S -198.91W 42 7 1950 1.901.00 1800.00 -218.18S -221.11W 49 7 2056 2001.00 .1900,00 -247'64S -243.31W 55 6 ,) 2163 2101.00 2000-00 -277.10S -265.50W 62 7 2269 2201.00 2100.00 . -306'16S -287.41W 68 6 2375 2301.00 2200.00 -334.92S -309.08W 74 6 .) 2481 2401.00 2300.00 -362.81S -330.09W 80 6 2587 2501.00 2400.00 -390-65S -350.34W 86 6 2693 2601.00 2500.00 -418.46S -369.82W 92 6 ) 2798 2701.00 2600.00 -445.70S -389.44W 97 5 2904 2801.00 2700.00 -472.77S -409.10W 103 6 _ 3009 2901.00 2800.00 -500.61S -426.64W 108 5 ) 3114 3218 3001.00 2900.00 -526.12S -445.17W 3101.00 3000.00 -549.22S -462.70W 113 5 117 4 12 3321 3201.00 3100.00 -569.74S -479.92W 120 3 ~' TVD SUB .SEA (~O~t~Ec~ION DEPTH LATITUDE DEPARTURE DI,FF~I~ENCE 3627 3301.00 3200,00 3401.00 3300.00 3501-00 3400.00 -586.17S -493.30N 123 -601or95S -506,:08~ 125 -615.65S -517.17W 126 ) 3729 3601.00 3500.00 -626,89S -531o84W 128 2 3701.00 3600-00 -635.12S -5'8"10W 130 2 .3932 ) 4033 3801.00 3700'00 3901.00 3800-00 --662'85S --648-295 -563.95W 131 ,I -577.71N 1:32 4136 6235 6001.00 3900'00 -653.30S *101.00 4000.00 -656o03S -591.12~ 133 I -601.60~ 134 : 1 /,201,00 4301.00 41100-00 -654'555 4200.00 -653.83S -61t',73W 134 :0 -620.51W . ' 135 1 z~536 ) ~ 4637 4401.00 ,300.00 4501.00 -651.61S -629'~3W 135 0 ,400.00 -649.3,S -637'21W 136 1 ~ ze7..37 6601-00 Z 4500-00 -646:'69S -643.23W 136 0 4837 6701.00 6937 4801.00 5037 ,901, O0 5138 5001.00 5238 5101.00 6600.00 -662.29S -648'67N 136 0 4700°00 -637.89S -654.10W 136 0 ~800°00 -633.48S -659.54W 136 0 4900,00 -629,08S -66~.97W 137 1 5000.00 -623.41S -670.68W 137 0 5338 5201.00 5100.00 -617.63S -676.45W 137 0 5439 5301.00 5200.00 -611.46S -682o22W 138 1 ) 5539 5401.00 5300.00 -605.31S -687.30~ 138 0 5639 5501.00 5600.00 -599.11S -692o14W 138 0 57,0 5601.00 5500-00 -592o85S -697.12W 139 1 ) 58,0 5701.00 5600.00 -586.24S -702°86W 139 0 5941 5801.00 5700.00 -575.32S -711o71N 140 1 60z+2 5901.00 5800.00 -565.42S -719.70W 141 1 ) __ 6143 6001.00 5900.00 -556.08S -726.23W 1,2 1 6249 6101o00 6000.00 -546.55S -732.53W 142 0 6201.00 6100.00 -53,.08S -733.73W 143 1 8 2 DIFFERENCE CORRECTION DEPTH [,VD SUB SEA LATITUDE DEPARTURE ) 6445 6546 6301'00 6200.00 -518,68S -734ot5W 640['00 63:00.00 -502,96S -731.95W 1 145 I . 6749 6850 6501,00 6400,00 6601':00 6500-00 6701-00 6600-00 -486,59S -727'33W 147 2 -470.59S -722'66W 148 1 -456.49S -717-33W 149 6952 6801.00 6'700.00 -441.47S '712.'04W 151 7053 7[55 7257 6901.00 6800,00 7001,00 6900-00 · 7t01.00 7000-00 7201,00 7100,00 7301.00 7200-00 7401.00 7300-00 7501,00 7600,00 7601,00 7500,00 ~7701.00 7600-00 7801-00 7700,00 7901,00 7800-00 8001.00 7900'00 8101.00 8000,00 -425.62S -70'6"68W 152 1 -408.01S -701.19W 154 2 -389.42S -695.50W 156 2 ) 7359 74611 7564 ) ~, 7666 ~ 7769 oz 7872 ) ~ 7976 ~ 8079 o ~ 8183 ) 8287 -369.36S -688,75w 158 2 -348.48s -681.67w 160 2 : . -282'94S -260.01S -647.13W -236.77S -635o29W -213.07S -622.28W -326.53S -674'54W 163 3 -304.88S -666.52W 165 2 -657.66W 168 3 171 3 175 4 178 3 -189.22S -609.07W 18,2 4 -165.40S -595.84W 186 4 8390 8694 820t.00 8100.00 -142.38S -582'15W 8301.00 8200.00 -120-16S -567-17W 189 3 193 4 ) .... 8597 8401.00 8300,00 -I00.22S -553.26W 196 3 87.00 8501.00 8400.00 -80.55S -539.49W 199 3 8802 8601.00 8500.00 -60.50S -526.80W 201 2 ) 8905 8701.00 8600.00 -40.93S -516.62W 204 3 9007 8801.00 8700-00 -21.86S -508.93W 206 2 9109 ) _ 9212 8901-00 8800.00 0.61N -503.08W go01.O0 8900.00 25.03N -498.60W 208 2 211 3 9316 9101.00 9000.00 51.44N -495.50W 215 4 9420 9201.00 9100,00 79.87N -493.50W 219 4 ,) 8 CORRECTION 12 ) 11 __ 10 9 ,} 8 7 6 :) 5 4 3 DEPTH T_,VD SUB SEA LATITUDE DEPARTURE DIFFERENCE 9524 930t,.00 9200-00 109,53N -493.07W 223 4 9629. 9401°00 9300.00 140o51N -494'88W 228 5 9734 -498-'60W 233 5 9501.00 9400.00 171,33N 9601-00 9500.00 202'08N 9839 -502'92W 238 5 99~3 9701.00 9600-00 232.83N -507-24W 242 4 ~00~8 9801.00 9700-00 263o55N -511-'72W 247 5 10152 9901.00 9800-00 293°98N -516'77W 251 4 0 ,,, O0 O.O00 901 ~> 3(]' S, 41~ ~O0,,~'v 79'9.69 ~.O2S 9.0:~ 7.86 S ]~.92~ ~.t66 1.]. ) .t 5q,,6 {.78~ T~NGEN'T tAL ~E~ THOD UNION L~T'ITUOE D~PARTU~E O!S'T~NCEi ~NGLE SE¥t~ITY OJST~N'CE )~ 5795 6039 ~ O ' N 3~g~ 122,92 ~60,56 ~)5~,~,5{~ ~50,2gS $)4,7~ gaS.72 S ~4.30W 0,603 22i.02 5020.2:~ ~9'L,g.~3 62~..2~5 6(~,OI.W 9i5,57 .S 4~,.67W O.~fi.~ ., ., o ? i 58g~.1~, 577:)7.i~';, 565.68S 71g.5tw g15.2~ $ 51.82W l.~O~ ? $~ 0 ' 6339.4t ~23~.~,1 512.755 7~..lOw 89s~.~,~ S 55.06W 6. tl. 7 6~,~.~2.70 63~[.70 ~92.72S "t29.Ttw,.,, e~O.O~ $ 5~_.gSW t.l~6 ~1.9 ~2_ 675J ) 8 ) 5 DIVISION OF DRESSER iNDUSTRIES,' 'P. O. Box 1106 Dallas, Texas ~, I"1~1[ ! Prepared For MR. Lease [Company IWellNo. jField ICa. or Parish I/'?:''/ ,,t '~:' '~"' ' ' Weight Grade State New Completior, Workover CASING 'LINER Size TUBING FIRST STRING SECOND r NUMB jWeight Grade Size JWeight Size Weight Grade Grade Grade jThread ;....'..',' ~:,& ;~'/" JThread Thread Thread T hre ad DESCRIpTIoN " Depth Depth Depth Depth ESTIMATE Completion Procedure TOTAL ESTIMATE ,~,,;K ..... w ,-,,,,. k ..... I T~le~hone . IDT No. STATE OF ALASKA OIL AND GAS CONSERVATION CO/WV~ITTEE SUBMIT 1/~ DLq~LIC~%~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS API NLrS{ERICAL CODE ~L¥ ' ~- 50-133-20214 HWK ~ L~SE D~iG~A~ON AND S~IAL NO. ~ 3. ADDRESS OF OPEP..A'INDR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 ' 4. L~DCATION OF WFJ...L WELL WELL OTHER 2. NAME OF OP~ATOR 8. L-~IT FP~RA{ OR LEASE NA/~E Union Oil Company of California Trading Bay State 9. WELL NO. A-il (44-4) Conductor #19, 1619'N & 559'W from SE corner Section 4, T9N, R13W, SM. ADL 18731 ---- 7. IF INDIA~ A~T~E OR TRIBE N~ Kenai Trading Bay _~-~xuu~e& Hemlock 11. SEC., T., R., Al., (BOSOM MOIRE OB0~CrrVE) Sec. 4, T9N, R13W, SM. 12. PIgR1VIIT NO. 70-24 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ANI) VOLLr~ USED, PF~OI~ATIONS, TESTS ~ RESULTS. FISHING JOBS, JU/~K IN HOL~E AND SIDE-TR3%CKED HOLE AND A/~Y O~rIER SIGNIFICANT CHAN{3F~ IN HOL]~ CONDITIONS. TRADING BAY STATE A-il (44-4).,..MAY 1970 Continued drlg 8-1/2" hole 8155'-10,108'. Conditioned for logs. Ran Schlumberger DIL, density, dipmeter & SNP logs. RD Schlumberger. Drld 8-1/2" hole 10,108' - 10,180'. PO. Circ. RI w/oedp. Hung @ 9500'. Plugged 8-1/2" open hole w/85 sx "G" cmt. Estimated top cmt 9300'. CIP 5:20 a.m. 5/20/70. Hung Oedp @ 7215'. Plugged across shoe of 9-5/8" csg w/100 sx "G". CIP 6:50 p.m. 5/20/70. WOC. Layed down HWDP & DC's. RI & located top cmt. Did not have cmt above shoe. Plugged across shoe w/200 sx "G" cmt. CIP 8:40 p.m. 5/20/70. POH. RI w/bit & scraper. Located top cmt @ 6630'. CO cmt to 6865'. Circ clean. ~Schlumberger set Howco BP on wireline @ 6862'. Ran GR corr. log. Perfd four 1/2" holes @ 6410 (top Hemlock). RI w/RTTS tool, Set @ 6348'. Pressd perf~ @ 6410' to 4000#, no breakdown. POH. Schlum perfd four 1/2" holes @ 6070' (base Middle Kenai "D"). Set RTTS pkr @ 6005'. Pressd perfs @ 6070' to 3500# no breakdown. Schlum perfd four 1/2" holes @ 5505', top Middle Kenai "D". Ran RTTS tool. Set @ 5449'. Attempted to sqz w/50 sx, unable to displace cmt to perfs w/4000#. POH. Ran bit & scraper. Circ clean. Spotted 150 bbls Invermul 6862' - 4800'. Schlum perfd Middle Kenai "D" with four 1/2" hpf w/solid carrier hyperjets as follows: 6055'-5981', 5940'- 5905', 5899'-5860', 5816'-5802', 5769'-5742', 5705'-5672', 5652'-5605', & 5586'-5570'. Ran 176 j ts 2-7/8" 6.5# N-80 seal lock tubing. Hung w/tail @ 5555' & Guiberson RH-1 pkr @ 5481'. Rmvd BOE. Instld tree, displaced mud & invermul w/diesel oil. Set pkr & tstd OK. RIG RELEASED @ ..1.0.:00. p.m. 5/23/7.0. 14. I hereby s~G~m~~"~.v~~-----,~'~f=VLm Dist. DrlK. Supt, nAT~ 6/9/70 NOTE--Report on this f~m~ ~'equired for each calendar month, regardless of the status of operations, anti must be filed in d~plicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. ,Form HEV. 9-30-67 Submit "Intentions" in Triplicate & "Sul~aequent Reports" in D~plic~te STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (De not use this form for proposals to dr/Il or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PF_/~VIIT--" for such proposals.) AP1 ~CA_L CODE DESIGNATION AND SERIAL NO. 1. ?. IF INDIAN, A_LI.~ OR TRIBE NA.MJE 01L ~-~ OAS [-~ WELL WELL OTH m.R 2. N~E OF OP~TOR 8. UNIT, F~ OR ~SE Union 0il Company of California 3. ADD~S OF OP~R 9. ~L 10. F~.~ ~ ~L, OH W~T Check Appropriate Box To [ndi'cate N~at'ure of N~oti'ce, Re 4. LOCATION OF w~t,L At surface 13. ELEVATIONS (Show whether DF, BT, Glt, etc. 14. 11. SEC., T., R., M., (BOrI"fOM HOLE OBJECTIVE) t2; P/~It~M_IT NO. ~rt, or Other 'Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: FRACTURE TREAT ~__ MULTIPLE COMPI.ETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING: R 'ACIDIZING J. 'J .i ABANDONMEN'T* REPAIR WELL CHANGE PLANS (Other) (NOTZ: Repi)rt results of multiple completion on Weli" (Other) · Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OB COMPLETED OPERATIONS (Clearly state all p~rtinent details, and give pertin~nt dates, including estimated date of starting any propo~d work. .. u . ........ 6. Spotted invemul in 9-5/8" csg from 6862' - ~800'. Schlumberger perfd four 1/2" holes per foot Hiddle Kenai "D" from: 6055-5981, 59~0-590'5, 5899-5860, 58i~-5802, 5769- 5742, 5705-5672, 5652-5605, 5586-5570. 5. Ran 176 j ts 2-7/8" 6.5# N-80 seal-lek tbg on Guiberson RH-1 hydroset pkr. @ 5555' & pkr @ 5481'. Hung w/tail 6. Removed BOE. Installed 'tree. Changed over from mud-& inVermul t° diesel oil. Set pkr and tested OK. :' · 7. RIG RELEASED FROH A-ii @ 10:00 PI/ 5/23[70. Placed well on production, flowing from Middle Kenai "D" Zone. 16. I hereby certify th~ fo%~ttr~e/~d SIGNED ~ (This space for Sta~e Office llse)~//[ APPROVED BY CONDITIONS OF APPROVAL, IF correct TITLE Dist. Drlg. Supt. TITLE DATE DATE 5126/70 See 1,nstrucflons On Reverse Side Submit "Intentions" in Triplicate & "Subsequent Reports" in DupLicate · STATE: OF ALASKA OIL AND-'GAs CONSERVATION; COMMITTEE 1'.' SUNDRY NOTICES AND REPORTS ON WELLS not Use this form for proposals to dr/~,l Or to deepen or plug back to a di£fierent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) . · · 0IL ~. GAS WELL. WELL [] OTHER 2. NAME OF OPERATOR Union 0il Company of California 3. ADDILESS 'oF'oPERATOR 4. LOCATION. O,F WELL At surface 13. ELEVATIONS (Show whether DF, RT, OR, etc. Check Appropriate Box To I~ndicate Niat'ure of N~o~ce, Re NOTICE OF INTENTION TO : TEST WATER 8HUT-OFF ~'~ PULL OR ALTER CASING FRACTURE TREAT ~J MULTIPLE COMPLETE I~IHOOT OR ACIDIZE --I AEANDON$ REPAIR '~'ELL CHANGE PLANS (Other) PAGE TWO 5. API NUMEB/CAL CODE 6. LEAS]~ DESIGNATION A_ND SERIAL NO. 7. IF INDIAN, ALLO'i"r~E OR TRIBE N~_]~ 8. UNIT, FA~B2VI OR LEASE NAME Trading Bay State 9. WELL NO. A-n (44-4) 10. FLELD ~ POOL, OR WILDC4~T , 11. SEC., T., R., M., ~(BOTTOM HOLE OBJECTIVE) 12'] PEP, A~T 1VO. 70-24 ~ort,' or ISUBREQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACID~IZI~IG ABANDONMEN'T* (Other) , NoTE: Report results of multiple eompletion on Well ompletion Or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS '(Clearly state all pertinent details, and give pertinenti'dates, Including estimated date of starting an}' proposed work. 4. Perforate @ 6410' (top upper Hemlock), 6070' (base Middle Kenai "D"), and 5505' (top "D"). Block squeeze for zone segregatioN. 5. CO & pressure test squeezed pefs. 6. Perf Middle Kenai "D" @ intervals from 5570' - 6055'.~ 7. Run single string tbg w/hydroset pkr to 5450'+-. 8. Place well on production to clean up zone prior to injection.. 9. Re-enter well after producing clean up period, perforate Hemlock. Zone @ intervals fm 6420' 6850' & return well to service as a dual "D" zone - "Hemlock" zone water injector. ESTIMATED STARTING DATE: May 20, 1970 ,. 16. I hereby certify ~.~t (Th~ ~pace for State off APPROVED BY fore ~1 /true/~hd correct ? TITLE Dist. Drlg. Supt. DATE See 1,nstrucfions On Reverse Side 5/21/70 · Focm Subnc~lt "Intentions" in Triplicate & "Subsequent Reports, in Duplicate · STATE OF ALASKA OIL AND GAS CONSERVAIION, CO~MITIEE SUNDRY NOTICES AND REPORTS ON WELLS no* Use this form for proposals to' drill or to deepen or plug back to a diffierent reservoir. Use "APPLIC~iTION FOR IaEPJ~IT~'' for such proposals.) 0IL OAS WELL. WELL OTHER 2. NAME OF OP~TOR Union Oil Company ...qf .California 3. ADDRESS 'OF' OPERATOR ' ' 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 LOCATION O,F WELL_ ~ ~f~sF~a~~ ~ % f' y'-~,~.~ ~ ........ C0i~id~c~r #10 - 1619'N & 559'W from SE corner Section 4, T9N, R13W, SM. ~*~.~AT~i ~S~~er DF, RT, GlO, etc. RT Au~; above MSL 14. NOTICE OF INTENTION TO: HtR ~ TRM, QKG ~. API NUlX4-EPJ[C~ CODE KLV .. 50-133-20214 HWK ~ 8. LEASE DESIGNATION A_ND SERIA3~ NO. ~ ADL 18731 ~ ?. IF INTDIA-N, A3-J~OTTEE OR TRI B~-- ~RIE ,_~,.,~m~ s. ~mT, F~ OR LF~SE NA~E Trading Bay State 9. WELL NO. A-il (44-4) '10. FrZI~ A~D POOL, O~I~ Kenai Trading Bay - Hemlgck ~. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, SM. 12. PERM/T NO. 70-24 .~,~, or Other 'Data TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT j j MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZXNO ABANDONMEN'Ts (Other) (NOTE: RepOrt results of multiple completion on Well (Other) Completion or Recompletion RePort and Log form.) 15. DESCRIBE pRoposED OR CO.~fP~ETED OPERATIONS (Clenrly state all pertinent details, and give pertinent dates, including estimated date of starting any p rol~osed work. Trading Bay State A-11 was originally programmed as a Hemlock Zone Trading Bay Subthrust fault block test. If the lower zone proved to be non-productive, the well was to be plugged back and completed as a dual water injector in the upper fault block Middle Kenai "D" and Hemlock Zones under an approved pressure malntemance project. Trading Bay State A-iI was drilled to 7100', 9-5/8" csg set @ 7092' and 8-1/2" hole drilled to a TD of 10,180' without encountering any produCtiVe intervals below the sub-thrust fault. It is now proposed to plug and abandon the lower 8-1/2" hole with cement top to be across the. 9-5/8" sho~, block squeeze above and below t~e Middle Kenai "D" and Hemlock intervals for zone segregation, mnd temporarily complete'for production in the Middle Kenai "D" interval. The "D" interval Will be produced to clean up'the well bore prior to injection, the well re-entered and converted as a dual Middle Kenai "D" - Hemlock Zone injector. · PROCEDURE: 1. Plug across lower non-productive Hemlock interval (toP @ 9493') w/cement fm 9550'- 9350'. 2. Plug across 9-5/8" shoe (shoe @ 7092') w/cement fm 7200' - 7000'. 3. Set BP in 9-5/8" csg @ 7000'.~ Form No. P--4 REV. 9-~0-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'ri'EE SUBMIT IH DUPLICA, TF- AP1 NUMERICAI, CODE LEASE DESIGNATION AND' ' L N~ ~ - MONTHLY RE!PORT O:F 'DRILLING AND WORKOVER OPERATIONS 1, W~.LL WELL OTHER NAME OF OPIgl:L~TOR Union 0il Company of California 3,ADDRESS OF OPE~:~LTOR 507 West Northern Lights Blvd·, Anchorage, Ak. 99503 4.LOCA~ON OF WELL Conductor #19, 1619'N & 559'W from SE corner Section 4, T9N, R13W, SM. JADL 18731 ?. IF INDIA]~'. ALOTTEE OR TRIBE 8. UNIT,Fa<[ OR LEASE Trading Bay 9. WELL NO. State A-11 (44-4) 10. FIELD AND POOL. OR WILDCAT ..Trading Bay - Hemlock il. szc.. r.. R., ~<[.. no-roM Ho~ om.rmCTr~ Section 4, T9N, R13W, SM. 1~. PI!II:~MIT NO. 70-24 13. REPORT TOTAL DEPTH AT END oF MONTH, cHANGES IN HOLE SIZE, CASING AND CE1ViENTING JOBS INCLUDING DEPTH SET A/WI) VOLI/NEES USED, PEI~FO-I~ATIONS, TESTS ~ RESULTS, FISH/NG JOB~, JUI~K IN HOLE A-ND SIDE-TRACKED HOLE AND A-~Y OTHER SIGNIFICANT CH3%N-Gl~ IN HOLI~ CONDITIONS. TRADING BAY STATE..A-i.1 (44-4~.,.. ~PRIL .1.970 Cont drlg 12-1/4" hole 3737' - 7090'. Circ& cond for logs· Ran Schlumberger DIL, density, SNP, sonic logs & dip meter· Drld 12-1/4" hole 7090' - 7100'. Cond for csg. Ran 172 its 9-5/8" 43.5# N-80 buttress csg. w/shoe @ 7092' & DV @ 3623'· Cmtd thru shoe w/800 sx Class "G" mixed with 1/2 tn.ft, perlite per sack, 1% D-31 & 6% gel followed by 250 sx ClaSs "G". CIP 12:00 M~dnilht 4/19/70. Opened DV @ 3623'. Circ clean· Cmtd thru DV w/850 S~ CiaSa ""G" ~/1% CFR-2 'followed by 400 sx "G". Good cmt returns to surface· CIP 4:30 am 4/20~70. Removed BOP's. Lan4md csg., instld 12" S900 & 10" S900 Cameron tbg head· Reinstld riser & BOE. Tstd OK. RI ~/da, top cmt @ 3613'· Drld out DV. RI to FC's. Fnd no cmt between FC & shoe. Drld shoe· CO to 7100'. Drld 8-1/2" hole to 7130'· Rigged up D-A. Set Howco EZ drill BP @ 7085' in shoe jr. Perfd four 1/2" holes @ 7075'. Set cmt retainer @ 7056'. Sqzd shoe jt w/70 sx Class "G". Max press 4000#. CIP. 10:00 pm 4/21/70, Circ clean· WOC RI & located top cmt @ 7028' Drld cmt 7028'-7056' cmt · · , retainer @ 7056' & cmt to 7080' Hole open to BP @ 7085' Drld BP @ 7085' · , · · · CO to 7130'. Drld 8-1/2" hole 7130'-8155'. Now drilling. hereby certify that j[]~e~lfregoin~ ~ and correct ' ' NOTE--m~orJon t~s form i/Jrequired for each calendar month, regardless of the status of operations, an~ must ~ filed in duplicatt with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. Porto REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS 2, NAME OF OPEi:LATOR Union Oil Company of California SUBMIT IN DUPLICA. TE 3, ADDRESS OF OPER,ATOR 507 W. Northern Lights Blvd.~ Anchorage, 4. LOCATiON OF WF_J~ Conductor Section 4, TaN, Ak.. 99503 I619'N & 559'W from SE corner Ri3W, SM. TRM AP1 NUMERICAL CODE 50-133-20214 KLV LEASE DESIGNATION AND SER~'~/~O. ~ ~- ADL 18731 RE! ?. IF INDIA]~, ALOTTEE O]~ TRIBE NAME i ?ILE 8. LrNIT,FA-RM OR LEASE NA2AE Trading Bay 9. WELL NO. State A-Il (44-4) 10. Fl~?.r~ A_ND POOL, OR WILDCAT Trading Bay - Hemlock 11. SEC., T., R., Ai., (BO~'~OM HOLE OB,rECT~ Sec. 4, TaN, R13W, SM. 12. PEH~IT NO. 70-24 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING A/ND CEMENTING JOBS INCLUDING DEPTH SET ~%q) VOL~ USED, PERFOH3~TIONS, TESTS A/%rD I~ESULTS, FISHING JOB~. JLrNK IN HOLE A2iD SIDE-/q~ACKED HOLE ANT) Ally OT~tER SIGNIFICA/~;T CI{ANGES IN HOI~ COI~FDITIONS. TRADING 'BAY STATE 'A-I'i (44-4)', March '1970 SPUDDED 9:00 pm 5/20/70. Drld 12-1/4" hole to 1086. Opened hole to 17-1/2" Ran 35 its ~3-3/8" 61# J-55 csg. Shoe set @ 1085. Cmtd w/475 sx Class "G" with 1/2 ft~ Perlite per sk, 6% gel F~ 1% D-31, followed By 2~0 sx Class "G". Bumped plug w/2000 psi, floats held OK. Good cmt returns to surf. CIP @' 2':'1'5 'am '3/2'8/70. InstI~[ &.tstd 12" S900 Cameron type WF csg head. I~n§tld-ris~-f--'f~i'Z''v Sa00 BOE. Tstd w/2000 psi OK. RI da. Url~[ out to top of Rhoe. Cond mud. Drld 12-1/4" hole to 3_~'., P0 for bit change W__el! starte..d .blowing w/monel in hole and one stand DC in derrick. ~hut hydril., 450~ on annulus. Blew dry gas thru DC's. Pumped Inlet wtr down annulus, partially ~illing well. Removed DC, ins'eld lower Kelly Cock and hydril insi~[e BOP. Pumped 160 bbls 75# salt wtr down annulus. Stripped ir~ hole tkru hYdril to 985'. Circ w/mud. Killed well. Drld out sand mu~.bridgeSDrld1085'-'I600'12-1/4" ~oleH°leto open 3737'i. 600'-2971'' CO to 3004'. Circ& cond Now dril!in~ @ 3737' SlGNED~~ TITLE 9ist. Drl~. gu.ne. DA~ 4/6/70 NO'lE~-J~eport 4n this forr~lis~required for each calendar month, regardless of the status of operations, and must ~ filecl in duplicate ' with the Division of Mines & 7erals by the 15th of the succeeding month, unless otherwise directed. AMD ~ C,O/~V2KTION 20° 1970 ~. Wade 8. ~ster, ~ Unloa 0tl Company of GsU~ 2805 ~ ~ RIJ: Trading Bay State A-Il (44-4) UMoa Oil Co. of C~II~., operatcx Enc~ is the apWoved applloetlcxa for permtt to drill the above ~ ~., on or about M~ 20, 1970, from the M~ PLutfotu. Well samples end oore .chips ere not requtmd. A direotioml ,urva~ is requ~. ~ 13 3/8' and 9 S/Ii ~ casiMs must be tied in with cemoK. ~ ~~ Log, teFM., end print ~ pur~ to AS 31.09.030 and tho aps~ reguh~, shall Lu~hdo tho otltbratLon file end the meohanical zero posmons of ail log trmM~, both .beh~ and after the log mn. bob log shall sb0w ell format data lnoluding (1) type of fluid tn the hole, (2) ohonges in mud type end addmomt sanu)les, (3) soak changes, (4) oqul~ dam, and (5) equtpme~ ~. In the evon~ of susponol~ or abandonment phase noZtfy this offioo adequately in ~~ so that we my have a witnss present. 1'homo R. Marsimli, Jr. l~ecu~lve Secm'etery cc: ~pe~'~ Fish'& _Game w/o encl- Department of ~ w/o oriel. l~orrn P--1 REV. b U-Ii j-z UZ.l.~ ~ ' STATE O,F ALASKA SUBMIT IN TRIP, rTE (Other instructions on reverse side) OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPJ O~ WOrK DRILL [~ DEEPEN [--] PLUG BACK [] b.TYP]~ OF WELL °'L 1~ °" [9 .,NOLE~ WELL WELL OTHER ZONE ZONE 2. NAME OF' OPEI~TOR Union 0il Company of California 3. ADDRI!~S O~ OPF_~RATOR 2805 Denali Street, Anchorage, Alaska 99503 4.LOCATION OF WELL ^ts. Place Conductor //19 - 1619'N & 559'W from SE corner Sec. 4, T9N RI3W, S.M. ^t pro~sed prod. zo,e Top Hemlock (Trading Bay Subthrust) 1817'N & 1071 W from SE corner, Sec. 4, T9N, R13W, S.M. : ~ 8. UNIT, FARM OR LEASE NAME Trading Bay State g. WELT. iNTO. A-II (44-4) 10. FIEI. X) AND POOL, OR WILDCAT Trading Bay - Hemlock 11. SEC.. T,, R.. M.. (BO~'TOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. 13. DISTANCE IN MILES AND DIRECTION FiIOM NEAREST TOWN OR POST OFFiCe* 12. approximately 27 air miles north of:Kenai, Alaska 14. BOND INFORMATION: TYPE Statewide Surety and/or No. United Pacific nsurance Co. B-55372 A~o,,-t $100,000.00 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ii any) 18. DISTANCE FROM PHOPOSED LocATION* 1071' TO NEAREST WELL Df'tILLING, COMPLETED, OR APPLIED FOR, FT. :: 575' !6. NO. OF ACRES IN LEASE 3; 840 Ig. PROPOSED DEPTH iO,460'MD & lO,161VD I7. NO. ACRES ASSIGNED TO THiS WELL 4O 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START* 101' RT above MSL March 20, 1970 23. pTtopOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING ~Ve'EIGHT PER 1~OO~ GP. AX~E: S~,-i-i-LNG DEPTH QUANTITY ]7~Il ' ' 3--3/8Il 61~ 'J--55 ~ , 100' 1,200 sacks- to 121" 9-5/,8'' 43.5g N 7,000' 2,000 sacks ,' 8~'l 7" ~ 2qg N 10:460' 1 OOO sacks r , ANCHORAGE Cement 13-3/8" casing in 17½" hole at 1100'. Install series 900 BOE. Drill 12¼" directional hole to 7000'. Run open hole logs. Cement 9-5/8'~ casing at 7000'. Install casing head and series 900 BOE. Drill 8½" directional hole to 10,460' TD. Run open hole logs. Run and Cement 7'~ liner from ~800~ - 10,~60~TD. Complete ns single oil ~ell - * Hemlock subChrusC ~u]t zone ~s indicnted. *NOTE I~ Hemlock Zone Tax,co - Trnding Bny subthrust ~nult block (8~'~ hole) proves unproductive, wall.tony be completed ns dun] injector in ~iddle Kenni ~D ~nd-Hemlock interval in upper ~nu]t block under nn ~pproved pressure mninten~nce project or ~s ~uthorized injectivity tests prior to ~pprov~] o~ ~ project. Bottom Hole Loc~tion - 181~cN~ 1071~H ~rom SE corner, Sec. ~, TDN, RI~ S.~. ~ ABO~ SPA~ D~BE ~O~S~ ~R~: If ~1 is to dee~n or plug ~. give ~ on present p~u~ive zo~ ~d pro~ ~w produ~ive ~ne. Ii propel ~ ~ drill or d~n d~e~Lo~ly,, give pe~ent ~ on subsu~a~ ~t~ ~d meas~d ~d ~ue ve~al dept. Give bio--at preventer p~gram. ..I h~D~i}y that t~,o~, ts ~e~~ , m~ Landman (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: ISAMPLES AND CORE CHIPS R.F_,~ [] Y~ )~NO. i D II~EC'rlONAL SURVEY YES [] NO See Transmittal Letter A.P.I. NIIMERICAL CODE March 20, 1970 UNION _(~)_ W TB ~ I TD 6528 T~D6627 A-15 1 6790 A- 6 ~',%,~1 _~A.' TO 7358 '--~ PBHL TMD 10,460 A-8 TVD 10,161_ A-JI / : A-2_ ~ A-7 ~/ ~--- Prop. T/HEM(Subthrusfl¢-~.¢' . ~ ' ' TV D~_~ I ~,~' TD 10,60~ ~ ~ ./~ ,. ' ' TM04650 _A~ / ~/ TVD4511 ~ / / 51-6 TO 8015 / / .I ~) TMD5415 ~ ....... / ~ ~ TVD5281 / -~A"5 TVD 5851 TVD , ,TS-5 2 ¢12-/ '"% .,-, 712~ 3313-4 ~'-~----- 3-4J3.5 J TO 7103-'(~)'~ _(~)_m~-/' ~ 2--"L~ ~ J TD~I~8_?~7 TD'~0,456 TD 10,458 / TS ADL 17597 ADL 18776 33 34 3''-I ,,I,.3 A-18 A-9 i % TD I1,000 ID600i / / · A-I // TO 6509 .. ADL 18775 ,5 A-19 TD 9259 J7 9 UNION TB + TD 7260 UN ION -M A RAT HO N ADL 18731 R 13W 9 JO J8 J.~ TO 11,637 ARCO TSS'Ii~ TD 10,950 T I0 N ADL 18731 JO RE.CEIVED t~Ai~ 20 1970 ,3..5__ ,32 T 9 N ADL 17596 JJ U-M ETB ~1 TD 10,364 -UNI(~;:~~~(~Y OF CALFORNIA ALASKA DISTRICT TRADING BAY FIELD COOK INLET, ALASKA LOCATION PLAT TRADING BAY STATE A-II (44-4) ]ATE: FEB 4tl970 I"= 2000' Company Trading Bay State A-11 ADL 18731 Lease & Well No. Trading Ray State A-11 CHECK LIST FOR NEW WELL PERMITS Yes No Remarks 1. Is well to be located in a defined pool ................. 2. Do statewide rules apply ........................ 3. Is a registered survey plat attached .................. 4. Is well located proper distance from property line ........... ~. Is well located proper distance from other wells ............ ~,~ .... 6. Is sufficient undedicated acreage available in this pool ........ 7. Is well to be deviated ......................... A~,/F __ 8. Is operator the only affected party ................... ~___ 9. Can permit be approved before ten-day wait ............... 10. Does operator have a bond in force ................... 11. Is conductor string provided ...................... 12..Is enough cement used to circulate on conductor and surface ...... · l~kI Will cement tie in surface and intermediate or production strings · . . 14. Will cement cover all possible productive horizons ......... 15. Will surface casing cover all fresh water zones ............ _16. Will surface csg. internal burst equal .5 psi/ft, to next string 17. Will all casing give adequate safety in collapse and tension . . 18. Does BOPE have sufficient pressure rating ............... Additional Requirements: Approval Recomme~ed- TRM ..... ,'xY/-'h, ,, / REL HWK .~ ~ LCS .Form Submit "Intentions" in Triplicate & "$ul~sequent Reports" in Duplicate :STATE O,F ALASKA OIL AND GAS CONSERVA,TIONi COMMITTEE SUND~Y NOTICES AND REPORTS ON WELLS (Do mot use this form for proposals to drill o~ to deepen or plug back to a dit£ierent reservoir. Use "APPLICATION FOR' P~IT--" for such proposals.) WELL WELL OTHER ]5~ ~ ~.~, 2. NAME OF OPERATOR, Union Oil Company of California 507 W. Northern Lights Blvd.~ 4. ~CATfON. O~ at~ Conductor #19, 1619'N & 559'W from SE corner: Section 4, T9N, R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RT 101' above MSL 14. Check Appropriate Box T° i~n~i~ate N~at'ure of I~tice, ~j UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL. NO, A-11 (44-4) · ~0. ~mLV ~SD ~OO'-, O~ ~~re Kenai & ~Trading =Bay - Hemlock H. sec., T., m., M., (BOTTON/ HOLE ' OBJECTIVE) Sec. 4. T9N, R13W, SM. 12~ PERlvHT NO. -~70-24 :oft, or O~her~ 'Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE ~REATMENT ' ALTERIN0 CASINO SHOOT OR ACIDXZ~ ABANDON' SItOOTINO OR ~CIDiZINO REPAIR WELL CHANGE PLANS (Other) - · change plans ~O:her) (NOT~: Report results of multiple com~Wtion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including e~tlmated date 0f starting any prop~d work. ~ . Trading Bay State A-11 was drilled :hrough the Hemlock zone~ Trading Bay Subthrust faul~ block, Co a TD of 10,180'. The lower zone proved to be nOn-productive, and the well was progra~ed for abandonmen~ through the subthrust fault 'b~ock, ~w/th temporary completion in ~he Hiddle Kenai "D" Zone. The "D" Interval ~21I be produced for well bore clean up prior ~o injection, ~he well re-entered and converted' as a dual Hiddle Kenai "D" -ttemlock Zone injector. The well was completed, as programmed, in the Middle Kenai "D" as follows: 1. Hung open end dp in 8-1/2" hole @ 9500'. Plugged from 9500' - 9300' w/85 sx Class "G" cmt. CIP @ 5:20 am 5/20/,,,70. Hung dp @ 7215'. Plugged across shoe of 9-5/8" csg (7092') in two stages from 7215' - 6630' w/300 sx Class "G" cmt. CIP @ 8:40 pm 5/,20/70. 2. Located top cmt in 9-5/8" csg @ 6630'. DO cmt to 6865'.- Set Howco BP @ 6862' ETD. 3. Ran GR correlation log. Perfd four 1/2" holes for block squeeze zone segregation jobs @ 6410' (top Hemlock) 6070' (Base Middle Kenai "D") & 5505' (top Middle Kenai "D") Attempted to squeeze individually. Could not obtain formation breakdown w/4000#. Ail zohes segregated. .... Continued
