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173-014
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,485 N/A Casing Collapse Structural Conductor Surface 630psi Intermediate 1,540psi Production 4,760psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: CTCO, N2 N/A Trading Bay Middle Kenai B, C, & D Oil Same 5,933 3,080 2,360 1,859psi 6,820 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018731 173-014 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20253-00-00 Hilcorp Alaska, LLC Trading Bay St A-30 Length Size Proposed Pools: L-80 TVD Burst 3,901 6,870psi MD 3,090psi 1,640psi1,197' 3,821' 1,246' 5,925'9-5/8" 16" 13-3/8"5,164' 1,246' 7,476' Perforation Depth MD (ft): 5,164' 3,941 - 6,540 7,476' 2,885 - 5,071 5/16/2025 2-7/8" Model D & SSSV 3,871 (MD) (2,843 (TVD) & 312 (MD) 312 (TVD) No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:20 pm, May 02, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.05.02 11:44:38 - 08'00' Dan Marlowe (1267) 325-276 * BOPE test to 3000 psi. 48 hour notice. * Documented safety review of Nitrogen Standard Well Procedure SFD 5/5/2025MGR09JUN2025 10-404 DSR-5/6/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.09 13:55:01 -08'00'06/09/25 RBDMS JSB 061025 TBU A-30 Fill Clean Out Page 1 of 2 Well Name:TBU A-30 API Number:50-733-20253-00 Current Status:Shut in Permit to Drill Number:173-014 Estimated Start Date:5/16/25 Rig:Fox Coil Unit 9 Regulatory Contact:Juanita Lovett Estimated Duration:4 days First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Casey Morse Cell Number:603-205-3780 Current Bottom Hole Pressure:2,300 psi at 4,412’ TVD. Nodal analysis from Oct 2016 flowing bottomhole pressure survey. Max. Potential Surface Pressure:1,859 psi (Based on 0.1 psi/ft. gas gradient) Last Shut-in WHP:70 psi Min. ID:2.313’’ – 2-7/8” X nipple Max. Deviation:54϶ at 1,687’ Pool:Middle Kenai B, Middle Kenai C, Middle Kenai D, no pool change during operation. Brief Well Summary: Trading Bay St A-30 was completed in 1973 initially as a Middle Kenai D producer. In Dec 2013 a workover recompleted the well and added Middle Kenai C and B production. The well started experiencing sand issues in 2016 and tubing by inner annulus communication was discovered. The well has remained shut in since that time. In Oct 2016, slickline bailed fill down to 2,918’, then performed hole finding operations eventually identifying tubing by inner annulus communication between 1,600’ and 2,690’. A rig workover is planned for Q2 2025, and this coil cleanout to ensure the tubing is clear will simplify decompletion operations. Objective: Coiled tubing fill cleanout in the 2-7/8” tubing. TBU A-30 Fill Clean Out Page 2 of 2 Coiled Tubing Procedure: 1. MIRU Fox Energy offshore Coiled Tubing #9 and pressure control equipment. 2. Pressure test BOP and PCE to 250 psi low / 3,000 psi high. a. Provide AOGCC with 48 hr BOP test witness notification. 3. MU cleanout BHA. Dry tag top of fill, then begin cleaning out down through the tubing tail at 3,901’. a. Working fluid will be Filtered Inlet Water (8.5ppg). b. Take returns to surface up the CT x tubing annulus. c. Add foam and nitrogen as necessary to carry solids to surface. 4. RDMO CT. Attachments: 1. Wellbore Schematic 2. CT BOP schematic (Fox Energy) 3. Standard nitrogen procedure Updated by: EPD 05/02/2025 SCHEMATIC Trading Bay Unit Well # A-30 Completed: 01/02/2014 PTD: 173-014 API: 50-733-20253-00 KB ELEV = 101’ TD = 7485’ PBTD = 6,820’ ANGLE thru INTERVAL = 37q RKB to TBG Hngr = 33.8’ Tree connection: 3” 5,000# 1 2 3 7 6 5 4 5076’ Cmt Ret. @ 6820’ X Multiple holes in tubing from 1,600’–2,690’ SL tag fill 2,918’ KB, 8/18/16. 13-3/8” 5,164’ Bad Csg f/ 5016’ to 5023’. Cmt sqz hole w/ 250 sx 7/21/81 16” B Zone C Zone D Zone CASING DETAIL SIZE WT Grade Conn. ID Top Btm. 16” 65 H-40 Butt. LT&C Surf 1,246’ 13-3/8” 61.0 K-55 Butt. LT&C 12.515” Surf 3,732’ 13-3/8” 68.0 K-55 Butt. LT&C 12.415” 3,732’ 5,164’ 9-5/8” 47.0 N-80 Butt 8.681” Surf 5,076’ 9-5/8” 47.0 N-80 Butt 8.681” 5,076’ 7,476’ TUBING DETAIL 2-7/8” 6.5# L-80 8rd EUE 2.441” Surf 3,901’ JEWELRY DETAIL NO. Depth (MD) Depth (TVD)ID OD Item 33.8’ 33.8”Tbg. Hanger 1 312’ 312’ 2.313” 4.688”SSSV w/ BX profile 2 2,672’ 2,109’ 2.441” 4.688” GLM # 1 (SPM-1) 3 3,796’ 2,798’ 2.441” 4.688” GLM # 2 (SPM-1) 4 3,844’ 2,827’ 2.441” 4.688” Chemical Injection Mandrel 5 3,871’ 2,843’ 6.000” 8.120” Packer Model D 6 3,892’ 2,856’ 2.313” 3.670” X Nipple 7 3,901’ 2,861’ 2.445” 3.700” WLEG PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Accum SPF Last Perf Date Present Condition B 26-7 3,941 3,958 2,885 2,895 17 5 12/30/13 Open B 26-7L 3,988 4,030 2,913 2,939 42 5 12/30/13 Open B 28-6 4,174' 4,184' 3,028' 3,033' 10' 8 6/6/1973 Cmt sqz'd w/ 1,000 sx Tested to 1200 psi. B 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 Cmt sqz'd w/ 250 sx Tested to 4500 psi B 31-8 4,644 4,756 3,375 3,467 112 5 12/30/13 Open B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 Isolated w/ 9-5/8" Tie-back liner to surface on 6/28/73. B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8 & 4 2/7/1990 Open f/ Production. B 31-8 4,692' 4,742' 3,414' 3,455' 50' 10 6/13/1973 Isolated w/ 9-5/8" Tie-back liner to surface on 6/28/73. B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 Isolated w/ 9-5/8" Tie-back liner to surface on 6/28/73. B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12 & 8 2/6/1990 Open f/ Production. B 33-6 4,792 4,850 3,497 3,546 58 5 12/30/13 Open B 40-4 4,874 4,896 3,567 3,586 22 5 12/30/13 Open B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 Isolated w/ 9-5/8" Tie-back liner to surface on 6/28/73. B 40-4 4,872' 4,908' 3,565' 3,596' 36' 8 & 4 2/5/1990 Open f/ Production. B 41-8 4,980 5,040 3,659 3,711 60 5 12/30/13 Open B 41-8 4,986' 5,040' 3,664' 3,711' 54' 2 6/21/1973 Isolated w/ 9-5/8" Tie-back liner to surface on 6/28/73. B 41-8 4,980' 5,060' 3,659' 3,729' 80' 8 & 4 2/5/1990 Open f/ Production. B 41-8 5,148' 5,150' 3,807' 3,809' 2' 4 7/21/1981 Cmt sqz'd w/ 300 sx B 44-7 5,278 5,328 3,923 3,967 50 5 12/30/13 Open B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 Cmt sqz'd w/ 100 sx. Tested to 1200 psi. B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 Cmt sqz'd w/ 100 sx. Tested to 1200 psi. C 5 5,708 5,770 4,307 4,364 62 5 12/30/13 Open C 7 5,918 6,048 4,500 4,620 130 5 12/30/13 Open C ZN1 6,145 6,160 4,710 4,724 15 5 12/30/13 Open C 47-5 6,166 6,232 4,729 4,790 66 5 12/30/13 Open C 48-7 6,312 6,324 4,863 4,874 12 5 12/30/13 Open C 50-3 6,512 6,540 5,046 5,071 28 5 12/30/13 Open D 53-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 D 53-8 6,941' 6,956' 5,437' 5,451' 15' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 D 54-5 7,000' 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 D 57-2 7,336' 7,348' 5,798' 5,809' 12' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 D 57-2 7,358' 7,366' 5,818' 5,825' 8' 4 6/30/1973 Cmt Sqz'd w/ 400 sx on 7/20/81 Notes: 10/17/16 CTU – Tagged 4,705’ 10/24/16 Slickline - Sand/Scale in tubing @ 2,918’ KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,April 07,2017 8:57 AM To: Juanita Lovett Cc: Dan Marlowe;samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#316-442/PTD: 173-014/Trading Bay St A-30 Juanita, The AOGCC will withdraw the sundry#316-442 as requested below. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwarfz@alaska.gov). From:Juanita Lovett[mailto:jlovett@hilcorp.com] Sent:Thursday,April 06,2017 9:46 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Dan Marlowe<dmarlowe@hilcorp.com> Subject:Withdraw Sundry#316-442/PTD: 173-014/Trading Bay St A-30 Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to plug back the well for a sidetrack through the Tyonek sands into the Hemlock. Regards, Juanita Lovett Operations/Regulatory Tech r> Hilcorp Alaska,LLC SCANNED MAY 0 901%. 2 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jlovett@hilcorp.com RBDMS U\ MAY - 3 2017 1 STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Wet❑ Other:CTU Clean Outs 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development s Exploratory❑ 173-014 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20253-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-30 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Trading Bay Field/Middle Kenai D,Middle Kenai B,Middle Kenai C Oil Pools 11.Present Well Condition Summary: Total Depth measured 7,485 feet Plugs measured 6,820 feet Ctrue vertical 5,933 feet Junk measured N/A feet Nov 16 2016 Effective Depth measured 4,705 feet Packer measured 3,871 feet true vertical 3,425 feet true vertical 2,843 feet ii c m Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,246' 16" 1,246' 1,197' 1,640 psi 630 psi Intermediate 5,164' 13-3/8" 5,164' 3,821' 3,090 psi 1,540 psi Production 7,476' 9-5/8" 7,476' 5,925' 6,870 psi 4,760 psi Liner Perforation depth Measured depth 3,941-6,540 feet s@aANNRlmW MAR 16 2C17, True Vertical depth 2,885-5,071 feet W Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 3,901'(MD) 2,861'(ND) 3,871'(MD) 312'(MD) Packers and SSSV(type,measured and true vertical depth) Model D Packer 2,843'(ND) SSSV 312'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 215 125 3429 634 148 Subsequent to operation: 0 0 0 200 350 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations s Exploratory❑ Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil s Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-489 ../ Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis \ Title Operations Manager Signature SL+ w . Gr144...; Phone (907)777-8356 Date t,I I 14 ( ! 1. IX //z 3.(4. ige e/f 4 RBDMS C`�Nj'J 1 7 2016 Form 10-404 Revised 5/2015 Submit Original Only • • Trading Bay Unit • 11 Well #A-30 SCHEMATIC Completed: 01/02/2014 PTD: 173-014 Hilcorp Alaska,LLC. API: 50-733-20253-00 CASING DETAIL SIZE WT Grade Conn. ID Top Btm. RKB to TBG Hngr=33.8' 16" 65 H-40 Butt.LT&C Surf 1,246' Tree connection:3" 5,000# 13-3/8" 61.0 K-55 Butt.LT&C 12.515" Surf 3,732' J . 13-3/8" 68.0 K-55 Butt.LT&C 12.415" 3,732' 5,164' 0. ... t 9-5/8" 47.0 N-80 Butt 8.681" Surf 5,076' ra"itiden°ie.n ts^ 9-5/8" 47.0 N-80 Butt 8.681" 5,076' 7,476' tubing from TUBING DETAIL 1,755-z,esa 2 2-7/8" I 6.5# I L-80 I 8rd EUE I 2.441" I Surf I 3,901' 3 JEWELRY DETAIL 4 NO. Depth(MO) Depth ID OD Item /////i!ii. ;,,;;�i, // 5 33.8' 33.8" Tbg.Hanger 6 1 312' 312' 2.313" 4.688" SSSV w/BX profile 7 2 2,672' 2,109' 2.441" 4.688" GLM#1(SPM-1) 3 3,796' 2,798' 2.441" 4.688" GLM#2(SPM-1) 4 3,844' 2,827' 2.441" 4.688" Chemical Injection Mandrel 5 3,871' 2,843' 6.000" 8.120" Packer Model D 6 3,892' 2,856' 2.313" 3.670" X Nipple * 7 3,901' 2,861' 2.445" 3.700" WLEG Immlit PERFORATION DETAIL Top Btm Top Btm Accum Last Perf Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Present Condition B Zone B 26-7 3,941 3,958 2,885 2,895 17 5 12/30/13 Open man B 26-7L 3,988 4,030 2,913 2,939 42 5 12/30/13 Open B 28-6 4,174' 4,184' 3,028' 3,033' 10' 8 6/6/1973 Cmt sqz'd w/1,000 sx Tested to 1200 psi. B 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 Cmt sqz'd w/250 sx Tested to 4500 psi Bad cs9vsot5mso2a. 1111,1 B31-8 4,644 4,756 3,375 3,467 112 5 12/30/13 Open Coot sqo hole w/250 sx 7/21/81Isolated w/9-5/8"Tie-back liner to B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 surface on 6/28/73. I = B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8&4 2/7/1990 Open f/Production. %� iii 5076' B 31-8 4,692' 4,742' 3,414' 3,455' 50' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to A 13-3i8^ surface on 6/28/73. 5,164' B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12&8 2/6/1990 Open f/Production. B 33-6 4,792 4,850 3,497 3,546 58 5 12/30/13 Open * B 40-4 4,874 4,896 3,567 3,586 22 5 12/30/13 Open B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to C Zone surface on 6/28/73. 8&4 2/5/1990 Open f/Production. B 40-4 4,872' 4,908' 3,565' 3,596' 36' B 41-8 4,980 5,040 3,659 3,711 60 5 12/30/13 Open 8 41-8 4,986' 5,040' 3,664' 3,711' 54' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. / " //, „,I7'""' Cmt Ret. B 41-8 4,980' 5,060' 3,659' 3,729' 8&4 2/5/1990 Open f/Production. ii%%/ ii .�,,,,... 6820' gD @ B 41-8 5,148' 5,150' 3,807' 3,809' 2' 4 7/21/1981 Cmt sqz'd w/300 sx ■ B 44-7 5,278 5,328 3,923 3,967 50 5 12/30/13 Open B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. o J B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 Cmt sgz'd w/100 sx.Tested to 1200 psi. C5 5,708 5,770 4,307 4,364 62 5 12/30/13 Open C 7 5,918 6,048 4,500 4,620 130 5 12/30/13 Open C ZN1 6,145 6,160 4,710 4,724 15 5 12/30/13 Open o C 47-5 6,166 6,232 4,729 4,790 66 5 12/30/13 Open O Zone C 48-7 6,312 6,324 4,863 4,874 12 5 12/30/13 Open C 50-3 6,512 6,540 5,046 5,071 28 5 12/30/13 Open 053-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sqid w/400 sx on 7/20/81 D53-8 6,941' 6,956' 5,437' 5,451' 15' 4 6/30/1973 Cmt Sgz'd w/400 sx on 7/20/81 D 54-5 7,000' 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sgz'd w/400 sx on 7/20/81 D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sqid w/400 sx on 7/20/81 D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 KB ELEV=101' D 57-2 7,336' 7,348' 5,798' 5,809' 12' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 TD=7485' D 57-2 7,358' 7,366' 5,818' 5,825' 8' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 PBTD=6,820' ANGLE thru INTERVAL=37° Notes: 10/17/16 CTU-Tagged 4,705' 10/24/16 Slickline-Sand/Scale in tubing @ 2,918' Updated by: ILL 11/15/16 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-30 CTU/Slickline 50-733-20253-00 173-014 10/14/16 10/24/16 Daily Operations: 10/14/16- Friday Mobed coil tubing crew to Monopod, orientated same. Unloaded boat spotting coil eq. R/u circulating& control lines. M/u BOP to A-30. R/u pit eq. &function tested same. Performed accumulator draw down test, good. Circulate water attempt t/shell test. Found blockage @ 2"valve, replaced same. Shell tested t/4500psi repairing leaks as needed.Test BOPE as per Hilcorp &AOGCC requirements. AOGCC witness waived by Jim Regg @ 11:05 on 10-12-16.Test all to 250 low/4500 high. 10/15/16-Saturday R/u, install CTC, pull test t/10k good. P/T 250/4500 good. M/U BHA, pull night cap, stab lubricator, P/T 250/4500 good. Pump open SSSV lock open w/4500 psi, open well. RIH tag fill @ 3,073'. Line up circ @ 1bpm, 3200 psi, WHP 200, cleanout t/tubing tail @ 3,901'. CBU x2 @ 1bpm 3400psi, WHP 115, 1:1 returns.Shut down pump. Cont rih t/tag @ 4,272',verify. POOH. Shut in well, bleed off lubricator, blow down lines. Break down tools. R/u surface lines to reverse. 10/16/16-Sunday R/u, install CTC, pull test t/10k good. P/T good. M/U BHA, pull night cap, stab lubricator, P/T good.Verify SSSV open lock in pressure @ 4500psi, open well. RIH t/ 1,042' break circulation, line up, reverse circ, @ 1 BPM, returns @ .25 bpm, cont. circ. no change, swap t/circ. long. Discuss options &set parameters. Line up t/reverse @ 1 BPM, monitoring IA pressure & return rate. While RIH IA pressure increased f/560 t/ 1170, return rate up t/ 1 bpm. Cont. RIH f/3,615' t/4,217',getting back some solids. Return rate dropped off p/u unable to clear, swap over& pump down coil tubing. Pull up t/3,742' CBU clean. Circulate reverse @ 1bpm,good return rate. Rih t/3,942'getting back some solids. Cont. rih t/4,130' lost returns. Pump down coil tubing, pooh t/3,872', CBU clean. RIH taking circulating down coil tubing @ 1 bpm, good returns. Rih taking small sections f/3,950' pulling back up t/tubing tail getting back some solids. Cont. process t/4,300' circulating clean getting back silty/gray water returns. POOH shut in well, blew down lines, installed night cap. 10/17/16- Monday R/u, install CTC, pull test t/10k good, P/T good. M/U BHA, pull night cap, stab lubricator, P/T good.Verify SSSV open lock in pressure @ 4500psi, open well. RIH t/tag @ 4,275', p/u start circ.1 bpm took 135 bbls t/fill hole. Cont. wash in hole t/4,705' tagged, CBU, POOH getting back silty emulsion. Pull into lubricator, shut in well. R/u & blow down coil & surface eq. w/nitrogen. Rig down off well, give to production. Lay crew down to rest. 10/18/16-Tuesday Crews unsting coil from injector, spot in stand, secure same. Disconnect control lines, arrange deck to allow w/I r/u. De- mobe coil crew. Fill choke with oil, clean shakers, &surface eq. clean pits. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-30 CTU/Slickline 50-733-20253-00 173-014 10/14/16 10/24/16 Daily Operations: 10/19/16-Wednesday Arrive on location do TGSM Permit and JSA. Move Equipment and Lub then Rig up slickline. P/T lub and WLV good 2000 PSI. RIH/w 2.29" G ring to 2000' KB as requested - Do not Set down. POOH clear to 2000 FT. RIH/w 2" RB/w 2 7/8" DD hole finder to 1600' KB w/t cannot get stop on btm of hole finder to shear. Pooh repin with smaller brass in a bigger hole. RIH/w same to 1600' KB set Test- 1000 LBS, held good. Equalize and POOH. RIH/w Same to 1700' KB w/t set. Test Fail- reset 1690' KB w/t set.Test- Fail- reset at 1679' KB Test, good. Hold at 1000 PSI for 30 mins good. POOH. RIH/w 2 1/2" GS w/2 7/8"AD-2 Stop to 1701' KB (1679'WLM)w/t set Shear off and Pooh (depth is top of ad-2). RIH/w 2 1/2" GS w/BTM Packoff to 1633' KB. Packoff kicked out early and sheared GS. Pooh. RIH/w 2 1/2" GS to 1633' KB w/t latch. POOH/w packoff Repin. RIH/w 2 1/2" GS/w BTM packoff to 1699' KB (1677' wlm) w/t set shear and pooh (top of packoff depth). RIH/w 2 1/2" GS w/ Receptacle/w 10' spacer pipe/w stinger to 1688' KB (1666' WLM) w/t set shear and pooh (top Recpt). RIH/w 2 1/2" GS/w Top Packoff/w 10' Spacer pipe/w Stinger Btm to 1677' KB (1655' wlm) w/t set w/t shear and POOH (top of packoff). RIH/w 2 1/2" GS/w 2 7/8" AA Stop to 1675' KB (1653' WLM) w/t set w/t shear and POOH. OOH, Rig off and let production test patch. Still getting a leak to casing. Redress WLV's. Lay down crew for the night. 10/20/16-Thursday Morning Meeting JSA TGSM Permit. Standby for Production to unload well and Shoot Fluid levels-then standby for Plan Forward. Rig up slickline. P/T LUB and WLV GOOD 2500. RIH/w 2 1/2" GS to 1675' KB w/t latch. POOH w/AA Stop. RIH/w Same to 1677' KB w/t Latch. Pooh ooh/w Upper packoff and 10' Spacer. RIH/w same to 1688' KB w/t to latch shear pin on gs. POOH. RIH/w Same to Same w/t Latch, Pooh/w Receptacle and 10' Spacer-standby to break off while boat is being worked. RIH/w Same to 1699' KB w/t latch w/t POOH/w BTM Packoff. Standby for Crane Op to finish working boat in other crane. RIH/w Same to 1701' KB w/t latch AD-2 Stop pooh. RIH/w 2.29" G ring to 2880' KB set down w/t can not pass. POOH. RIH/w 1.75" DD bailer to same w/t not making hole.Very poor spang action. POOH. Ooh with about a cup of very fine sand. Saw a bad spot with a lot of pitting in wire around 2900'. Pull off 3000 of wire leaving 16290' On Unit. RIH/w 1.75" DD bailer to 2880' KB w/t to 2882' KB still very poor spang action (had added KJ between stem and Added 5' more stem TS was 1 1/2" RS stem KJ stem KJ stem KJ OJ Si KJ Bailer). POOH. OOH/w about 5 cups of sand very fine-and what looked like large chunks of scale. Give Sample to George. Rig off prep to leave platform. Arrive at PWL shop. 10/22/16-Saturday ARRIVE ON LOCATION DO TGSM PERMIT AND JSA. RIG UP SLICK LINE ADD 2 7/8 ROLLER BOGGIE TO TOOL STRING P/T WLV LUB LUB to 250 LOW THEN 1500 HIGH -GOOD. RIH W/2.25" X 4' DD BAILER TO 2,880' KB WT TO 2,884' KB BAILER FULL SAND. RIH W/SAME TO 2,880 W/T 2,884'KB BAILER 1/2 FULL. RIH W/SAME TO 2,880' KB WT TO 2,890'KB, SPANG OUT OF FILL. OOH BAILER FULL, SAND. RIH W/SAME TO 2,883'KB WT TO 2,888'KB. OOH BAILER FULL. RIH W/ SAME TO 2,884' KB WT TO 2,890' KB. SPANG OUT OF FILL. OOH FULL SAND. LAY DOWN, SECURE WELL FOR THE NIGHT. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-30 CTU/Slickline 50-733-20253-00 173-014 10/14/16 10/24/16 Daily Operations: 10/23/16-Sunday MORNING MEETING JSA TGSM PERMIT. RIG UP SLICK LINE. P/T LUB AND WLV 250 LOW 1500 HIGH -GOOD. RIH W/2" X 8' DD BAILER TO 2,885' KB WT 2,892' KB. OOH FULL BAILER (SAND). USED GAS PRESSURE (200#)TO PRESSURE UP LUB BEFORE OPENING WELL,TO TRY AND KEEP FILL FROM COMING IN. (WILL CONTINUE ON EACH RUN). RIH W/SAME TO 2,890' KB WT TO 2,893' KB. FULL BAILER. RIH WI SAME TO 2,892' KB WT 2,895 'KB FULL BAILER. RIH W/SAME TO 2,893' KB WT TO 2,898' KB. FULL BAILER. RIH W/SAME TO 2,897 WT TO 2,901' KB. FULL BAILER. RIH W/SAME T02,898' KB WT TO 2,904' KB FULL BAILER. RIH W/SAME TO 2,902 WT TO 2,907' KB. FULL BAILER. RIH W/SAME TO 2,905 WT TO 2,910' KB. FULL BAILER. RIH W/2.25" X 8' DD BAILER TO 316' KB SAT DOWN IN SSSV. HAND SPANGED FREE, CANNOT PASS. RIH W/2.25" X 4' DD BAILER TO 2,908 WT TO 2,913' KB. FULL BAILER. RIH WI 2" X 8' DD BAILER TO 2,912' KB WT 2,914' KB. OOH 1/2 BAILER (SAND). RIH W/SAME TO 2,914' KB WT TO 2,918' KB FULL BAILER. LAY DOWN, SECURE WELL FOR THE NIGHT. 10/24/16- Monday MORNING MEETING JSA TGSM PERMIT. RIG UP SLICK LINE. REHEAD CUT 100'WIRE 16,190 STILL ON DRUM. P/T LUB AND WLV 250 LOW 1500 HIGH -GOOD. RIH W/2" X 8' DD BAILER TO 2,915'KB WT 2,916'KB. OOH EMPTY. RIH W/SAME TO 2,916'KB WT TO 2,917'KB. EMPTY. STAND BY FOR CREW CHANGE OUT. RIH WI SAME TO 2,817'KB WT TO 2,918'KB. EMPTY. RIH W/2.30" GUAGE RING W/4'WB. STAND BY FOR EXPRO TOOL HAND TO ARRIVE. LAY DOWN LUB. FREE UP CRANE. RIG UP SLICK LINE. REHEAD CUT 100' WIRE 16,190 STILL ON DRUM. RIH TO CALIBRATE EXPRO COUNTER W/ PWL COUNTER W/2.30" GUAGE RING W/4' WB TO 2,750KB. RIH WI EXPRO CALIPER @ 120' PM TO 2,750'KB LOGGING UP @ 30' PM. RIG DOWN S/L. • L OF rit • • 1/7: THE STATE Alaska Oil and Gas of® TT cc T�`�l 1 � Conservation Commission ALV 333 West Seventh Avenue /. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O4'A Fa Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations ManagerFE2"v 11 , Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B, C, and D Oil Pool, Trading Bay St A-30 Permit to Drill Number: 173-014 Sundry Number: 316-489 Dear Mr. Golis: 11 Enclosed is thea roved application for sundryapproval relatingto the above referenced well. pp pp pp Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this day of September, 2016. II RBDMS (, OCT 0 3 2016 • • RECEIVED . SEP 2 6 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Repair Well LI Operations shutdown LI Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ and I CTU Clean Out w!N2 0 and Install Patch 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development 0 t 173-014 ' 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20253-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes ❑ No 0 J Trading Bay St A-30 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 Trading Bay Field/Middle Kenai D,Middle Kenai B,Middle Kenai C Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,485 ' • 5,933 , 6,820 . 5,316 1,223 psi N/A 6,820 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,246' 16" 1,246' 1,197' 1,640 psi 630 psi Intermediate 5,164' 13-3/8" 5,164' 3,821' 3,090 psi 1,540 psi Production 7,476' 9-5/8" 7,476' 5,925' 6,870 psi 4,760 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3,941-6,540. 2,885-5,071 2-7/8" 6.5#/L-80 3,901 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Model D Packer&SSSV 3,871'(MD)2,843'(TVD)&312'(MD)317(ND) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program LI BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/10/2016 Commencing Operations: OIL 0 - WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorD.com Printed Name Stan W.GolisliTitle Operations Manager g t (1r)_ Phone (907)777-8356 Date ° 12.4, I l to Signature 11 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: e; /'� 3 \L( - I-1 5i 9 , Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1i 500 S. & Ji 5 I- c.-� J ._7 p ( c- o(VI l l( Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: J t Loci RBDMS (,( 01;T 0 3 2016 APPROVED BY Approved by: ,4(.4,-7V-1,......_ COMMISSIONER THE COMMISSION Date:9,Z9-/ . '�`y�// NOALU x ,2 7 6 �' ��' 0 � , Submit Form and Form 10-403 Revised 11/2015 Ap�rdr p Ifor 12 mpppyyy��{ths from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: A-30 Hilcorp Alaska,LLC Date: 09/22/16 Well Name: Monopod A-30 API Number: 50-733-20253-00 Current Status: Oil Producer(Gas Lifted) Leg: N/A Estimated Start Date: 10/10/2016 Rig: Coil Tubing Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 173-014 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) Second Call Engineer: Stan Golis (907)777-8356 (0) Current Bottom Hole Pressure: 2,885 psi @ 4,386'TVD 0.524 psi/ft(10.08 ppg) Maximum Expected BHP: 2,885 psi @ 4,386'TVD 0.524 psi/ft(10.08 ppg) Maximum Potential Surface Pressure: 1,223 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary The A-30 well was last worked over in 2014 completed in the B and C sands as a gas lifted producer. It recently experienced water and associated sand break through from the offset A-12 injector.This procedure will clean out the fill blocking the tubing, evaluate the need for sand stabilization, and patch the suspected hole in tubing around 1750'. ( Last Casing Test: 12/26/2013 at 3,906' 1,500 psig for 30 minutes on chart Procedure: 1. MIRU 1.5" Coil Tubing. 2. NU BOP and test to 250psi low/4,5 si High. (Note: Notify AOGCC 48 hours in advance of test) 3. RIH cleaning out fill to±6,820' (top of cement retainer). Circulate bottoms up. If returns are not present, see attached Standard Well Procedure—Nitrogen Operations. Fluids will be Filtered Inlet Water.All returns will be through gas buster to open top rig tanks(non-enclosed) or to production header. 4. Contingent—pump sand control treatment into C-7 thru C-50-3 sands. 5. POOH with coil. 5e` `''""``-� �i Z • /e 6. Turn well over to Operations for flow back. 7. Repeat cleanout if well plugs off and pump sand control treatment into C-7 thru C-50-3 sands if needed. 8. MIRU slickline P/T lubricator to 250 low/1500psi High. 9. RU slickline and install tubing patch at±1,750'. sr . - 6 10. RD slickline and turn well over to operations. 1- q• ,./6, Attachments: 1. Well Schematic Current/Proposed (Same) 2. Coil Tubing BOP Drawing 3. Standard Well Procedure—Nitrogen Operations 4. Flow Diagrams 5. RWO Sundry Revision Change Form • • Trading Bay Unit II Well #A-30 SCHEMATIC Completed: 01/02/2014 PTD: 173-014 Hilcorp Alaska,LLC API: 50-733-20253-00 CASING DETAIL SIZE WT Grade Conn. ID Top Btm. RKB to TBG Hngr=33.8' 16" 65 H-40 Butt.LT&C Surf 1,246' Tree connection:3" 5,000# 13-3/8" 61.0 K-55 Butt.LT&C 12.515" Surf 3,732' 1 el 444. t "� 13-3/8" 68.0 K-55 Butt.LT&C 12.415" 3,732' 5,164' 1 l +7 9-5/8" 47.0 N-80 Butt 8.681" Surf 5,076' L� 16 9-5/8" 47.0 N-80 Butt 8.681" 5,076' 7,476' ,,2as' '�pp���i 2 5+' 11J/ TUBING DETAIL p r`� 2-7/8" 6.5# L-80 8rd EUE 2.441" Surf 3,901' 3 f 1.i r-"4 ice- 11' JEWELRY DETAIL %//aia/o/,,;;, %/'-ii/// 5NO. Depth Depth ID OD Item Y 6 (MD) (ND) 7 33.8' 33.8" Tbg.Hanger 1 312' 312' 2.313" 4.688" SSSV w/BX profile 2 2,672' 2,109' 2.441" 4.688" GLM#1(SPM-1) 3 3,796' 2,798' 2.441" 4.688" GLM#2(SPM-1) 4 3,844' 2,827' 2.441" 4.688" Chemical Injection Mandrel 5 ' 3,871' 2,843' 6.000" 8.120" Packer Model D 6 3,892' 2,856' 2.313" 3.670" X Nipple 7 3,901' 2,861' 2.445" 3.700" WLEG B Zone PERFORATION DETAIL _or- Top Btm Top Btm Accum Last Perf AMIE Zone (MD) (MD) (ND) (ND) Amt SPF Date Persent Condition B 26-7 3,941 3,958 2,885 2,895 17 5 12/30/13 Open B 26-7L 3,988 4,030 2,913 2,939 42 5 12/30/13 Open il Bad C,u f/5016't,5023'. B 28-6 4,174' 4,184' 3,028' 3,033' 10' 8 6/6/1973 Cmt sqz'd w/1,000 sx Tested to 1200 MIIP mi Cmt eqz hole w/250 sc 7/21/81psi. B 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 Cmt sqz'd w/250 sx Tested to 4500 psi B 31-8 4,644 4,756 3,375 3,467 112 5 12/30/13 Open '// 5076' B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to /i., i,. surface on 6/28/73. B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8&4 2/7/1990 Open f/Production. 4 13-3/6" B 31-8 4,692' 4,742' 3,414' 3,455' 50' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to 5,164' surface on 6/28/73. 11- B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12&8 2/6/1990 Open f/Production. B 33-6 4,792 4,850 3,497 3,546 58 5 12/30/13 Open C Zone B 40-4 4,874 4,896 3,567 3,586 22 5 12/30/13 Open B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. B 40-4 4,872' 4,908' 3,565' 3,596' 36' 8&4 2/5/1990 Open f/Production. --"z'/ !!�O////���///" / Cmt Ret. B 41-8 4,980 5,040 3,659 3,711 60 5 12/30/13 Open iia''''''////"////o.,,,,...' @ 6820' Isolated w/9-5/8"Tie-back liner to B 41-8 4,986' 5,040' 3,664' 3,711' 54' 2 6/21/1973 surface on 6/28/73. f' /',1., '; %V B 41-8 4,980' 5,060' 3,659' 3,729' 80' 8&4 2/5/1990 Open f/Production. I o I _ B 41-8 5,148' 5,150' 3,807' 3,809' 2' 4 7/21/1981 Cmt sqz'd w/300 sx B 44-7 5,278 5,328 3,923 3,967 50 5 12/30/13 Open B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. 1-o- = C 5 5,708 5,770 4,307 4,364 62 5 12/30/13 Open /�/i // -7E /".2 C 7 5,918 6,048 4,500 4,620 130 5 12/30/13 Open i///o',,,. , %//�/" , DZoneC� C ZN1 6,145 6,160 4,710 4,724 15 5 12/30/13 Open - it C 47-5 6,166 6,232 4,729 4,790 66 5 12/30/13 Open C C 48-7 6,312 6,324 4,863 4,874 12 5 12/30/13 Open C 50-3 6,512 6,540 5,046 5,071 28 5 12/30/13 Open �� D 53-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 53-8 6,941' 6,956' 5,437' 5,451' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 54-5 7,000' 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 (50 D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 KB ELEV=101' D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 TD=7485' D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 PBTD=6,820' D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 ANGLE thru INTERVAL=37° D 57-2 7,336' 7,348' 5,798' 5,809' 12' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 57-2 7,358' 7,366' 5,818' 5,825' 8' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 Updated by: 11.1 08/24/16 • Trading Bay Unit II Well #A-30 PROPOSED Completed: 01/02/2014 PTD: 173-014 "''c a r p Alaska,LLC API: 50-733-20253-00 CASING DETAIL SIZE WT Grade Conn. ID Top Btm. RKB to TBG Hngr=33.8' 16" 65 H-40 Butt.LT&C Surf 1,246' Tree connection:3" 5,000# 13-3/8" 61.0 K-55 Butt.LT&C 12.515" Surf 3,732' 13-3/8" 68.0 K-55 Butt.LT&C 12.415" 3,732' 5,164' e I 9 5/8" 47.0 N-80 Butt 8.681" Surf 5,076' Tubing3/8" 9- 6• 9-5/8" 47.0 N-80 Butt 8.681" 5,076' 7,476' Patch ' 11,750• 2 TUBING DETAIL it 2-7/8" 6.5# L-80 8rd EUE 2.441" Surf 3,901' • 3 4 JEWELRY DETAIL nr," ;';%„,,,ilP De th Depth Item NO. (MD) (TVD) ID OD eTt 6 7 33.8' 33.8" Tbg.Hanger 1 312' 312' 2.313" 4.688" SSSV w/BX profile 2 2,672' 2,109' 2.441" 4.688" GLM#1(SPM-1) 3 3,796' 2,798' 2.441" 4.688" GLM#2(SPM-1) t 4 3,844' 2,827' 2.441" 4.688" Chemical Injection Mandrel 5 3,871' 2,843' 6.000" 8.120" Packer Model D 6 3,892' 2,856' 2.313" 3.670" X Nipple 7 3,901' 2,861' 2.445" 3.700" WLEG B Zone PERFORATION DETAIL _ Top Btm Top Btm Accum Last Perf MOE Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Persent Condition B 26-7 3,941 3,958 2,885 2,895 17 5 12/30/13 Open iiiMipi B 26-7L 3,988 4,030 2,913 2,939 42 5 12/30/13 Open ///---'''Bad Csg 05010 to 5023'. B 28-6 4,174' 4,184' 3,028' 3,033' 10' 8 6/6/1973 Cmt sqz'd w/1,000 sx Tested to 1200 �irz et:hole w/zwax psi. B 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 Cmt sqz'd w/250 sx Tested to 4500 psi B 31-8 4,644 4,756 3,375 3,467 112 5 12/30/13 Open '// 5076' B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to /�, din,. surface on 6/28/73. B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8&4 2/7/1990 Open f/Production. 13-3/8" B 31-8 4,692' 4,742' 3,414' 3,455' 50' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to 5,164' surface on 6/28/73. B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12&8 2/6/1990 Open f/Production. B 33-6 4,792 4,850 3,497 3,546 58 5 12/30/13 Open C Zone g 40-4 4,874 4,896 3,567 3,586 22 5 12/30/13 Open B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. B 40-4 4,872' 4,908' 3,565' 3,596' 36' 8&4 2/5/1990 Open f/Production. 2"j////.„�/.-///zz Cmt Ret. B 41-8 4,980 5,040 3,659 3,711 60 5 12/30/13 Open i��,,,,,... , @ 6820' Isolated w/9-5/8"Tie-back liner to B 41-8 4,986' 5,040' 3,664' 3,711' 54' 2 6/21/1973 surface on 6/28/73. S,:,4 j////,'// B 41-8 4,980' 5,060' 3,659' 3,729' 80' 8&4 2/5/1990 Open f/Production. %,';///iii,,,,i i,,.. 0 B 41-8 5,148' 5,150' 3,807' 3,809' 2' 4 7/21/1981 Cmt sqz'd w/300 sx B 44-7 5,278 5,328 3,923 3,967 50 5 12/30/13 Open B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. 1 0 - C S 5,708 5,770 4,307 4,364 62 5 12/30/13 Open ZZ i!//%// /////// D Zone C 7 5,918 6,048 4,500 4,620 130 5 12/30/13 Open ���'///"" ���'///""' C ZN1 6,145 6,160 4,710 4,724 15 5 12/30/13 Open - ' = C47-5 6,166 6,232 4,729 4,790 66 5 12/30/13 Open C 48-7 6,312 6,324 4,863 4,874 12 5 12/30/13 Open - C 50-3 6,512 6,540 5,046 5,071 28 5 12/30/13 Open D 53-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 53-8 6,941' 6,956' 5,437' 5,451' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 54-5 7,000' 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 KB ELEV=101' D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 TD=7485' D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 PBTD=6,820' D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 ANGLE thru INTERVAL=37° D 57-2 7,336' 7,348' 5,798' 5,809' 12' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 57-2 7,358' 7,366' 5,818' 5,825' 8' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 Updated by: JLL 09/21/16 • • F on 8 ao - 4 1, > o G C.C I __..,. w > m 5' O 0 3 1 SHAKER O JHJHU '. r„ VH $a I pZo-21® -I H SHHAKER li:::: fri -I H I Iram , w> ( d W aI : �f y /,iF a it k �_ y , 1.1,911 a \ l �fi ...-II : aa _ — ONO !kir l, _ _11.,„ �-I s%, . - 1 o I 0 0 R I In ,, U Y m 6 Z .� ! I 1l��N4.-. �'�i® r9 ;+ c t s gt���lll 'c N F // 1 _ i -f, ' [ /"ill 1 . � z c�Too �._ _�� (u `1,o III li miii.r._�/1 f'j! Ilii I1IIIIIgfIlfl?II a • , Y m Ts U -i3-, O D .9. ',..,_2'12,1 3 a N U .-Ill L= ' . 0 j q O N L.Z n V J a 5 O C ccF- V < CO . • Q 0 lJ V V y O V V L go, � U V J •U Crin V V tiI.I0 M N; O U� Z _ V 2 U. 0 0-;:- 1.41 07 S :.^,• V m Vi • • STANDARD WELL PROCEDURE Ililcorp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure supplier has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 09/23/2016 FINAL v-offshore Page 1 of 1 . M pod Platform A- Coiled Tubing BOP • iii09/21/2016 IliIraq Maas.LK Lubricator to injection head £ 3 5 o 1 —— : Blind/Shear 4 1/16 101J Blind/Shear _ _-_,` _ _ - C _--f C= Blind/Shear Blind/Shear_ :1 0 —_ C 000 5 _ c_ _ _ Slip Slip =a - - - -" - k= _ _ Pipe Pipe _ _ Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 1 2 1/16 10M 2 1/16 10M . M .■. Valve,swab,WKM, 0,__® d\ 31/85M FE, HWO ,,;®fo\.rl 0®O I • T .i i 1F. O rink Valve,master,WKM, �, 3 1/8 5M FE, HWO ®� �� a, 0 0 000 0 . 0 CD CD . Ip / > W2 0 COQ — & > § o s 0 2 2 o0 2k � § / � a E � o ) 7 = § 2 0� J 3 fE « no / 0 CD CO _ � �� > = fpm' Q .§ 0_ g2 % / n -a ■ ■ 0a Nr a a 0 0 $ / a) CO2 o 2J / / Z n k46o 2 o § a \ / 4. o &a © n /£ C R m C .c COU Q \ s_ 4111 12 0 ) k E & ° 2 0 k o ƒ a 2 / / 6. a a) \ k 07 ( § »7 e c / / . 2 Q0 2 2 > 2 r. C @ 2 §� 0) o 4 4- Q / \ o a. 4 ,- Q. 2 % / E er $ q R q I- "Fs- 0 mc & Qx§ § _m CO U 2 � S 7 - 2 it § M .. « _ . . a : q C o o / > r ® E 2 \o o \ E U 2 2 CO in < 0_ • • ! Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Thursday, September 29, 2016 10:50 AM To: Schwartz,Guy L(DOA) Subject: RE:TBU A-30 sundry for N2 FCO/Patch/sand control treatment. (PTD 173-014) Attachments: SandAid Product Sheet.pdf; Poly Plug Clear Gel Product Data Sheet.pdf Follow Up Flag: Follow up Flag Status: Flagged Guy After the tubing plugged,we noticed the casing and tubing pressures tracking. We first ran a bailer and located the blockage at 3072',then followed with a D&D hole finder on 8/18 &8/19 narrowing the leak down to somewhere between 1600-1700'. We will need to narrow this leak even farther before patching it. So far I have looked at a couple different fluid packages to stabilize the sand, either would be spotted at depth with coil and squeezed into the lower sands. Data sheets are attached. • Schlumberger—SandAid • Professional Fluid Services—Poly Plug Clear Gel (would likely require re-perforating the sands afterwards under a separate Sundry) Give me a shout if you need any further information Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp.com Hilcorp A Company Built on Energy From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@ alaska.gov] Sent: September 27, 2016 4:14 PM To: Dan Marlowe Subject: TBU A-30 sundry for N2 FCO/ Patch/sand control treatment. (PTD 173-014) Dan, Can you give me more details on the sand control treatment for well A-30 you are proposing. Is this placed with CT or fullbore? What chemicals are you using? Etc. What is the nature of the tubing leak and why do you suspect one at that depth? Guy Schwartz Sr. Petroleum Engineer 1 • • • Schlumberger as •ci� Sand conglomeration technology APPLICATIONS • Unconsolidated sandstone reservoirs -1,,,, • Remedial sand control p` 1 , • Deepwater,continental shelf, and onshore wells • All well types,including oil,gas,and waterle– fr , • Wells with reservoir temperatures '' up to 350 degF[177 degC] F „40 oe ., BENEFITS t i' ' e - , • Maximizes value by increasing sand-free i production rate ` a Delivers a strengthened attraction Scanning electron microscope 1X40)images of 20/40 mesh sand showing untreated sand(left)and sand treated between particles without damaging with SandAid technology(right). formation permeability SandAidt sand conglomeration technology is Preparation, injection,and shut-in • Enhances existing sand control methods a patented chemical solution that dramatically SandAid technology is prepared and pumped by preventing plugging due to small sand improves sand management and enhances with standard blending and pumping equipment. and fines migration production.This one-of-a-kind chemical process It is recommended to pump SandAid technology • Provides a superior, nondamaging increases the attraction between particles on the fly with continuous pumping.The fluid is alternative to resin-consolidation without imposing damage,by trapping formation then injected into the reservoir at matrix rates treatments sand and fines to maximize sand-free flow rates by bullheading process or using coiled tubing. ■ Contributes to the longevity of the well and increase production. A step-rate test is performed to determine the Safe and easy to use maximum injection rate below the frac pressure. FEATURES A preflush treatment is injected to prepare ■ Range of permeability from 1 to 10,000 mD SandAid technology is easy to apply and is less the treated zone, after which the SandAid • Ability to disperse and coat sand grains damaging than resin-or epoxy based solutions. technology fluid system is injected into the and formation fines when added to In existing wells,SandAid technology can be reservoir.An overflush treatment displaces the aqueous solutions pumped through either coiled tubing or existing SandAid technology treatment from the critical production tubulars. matrix.The well is then shut in for a few hours to a Ability to alter the zeta potential of solid surfaces to optimize agglomeration Maximum attraction between particles allow for optimum agglomeration before the well • Very low viscosity for easier application When added to an aqueous solution, the is slowly put on production. on long intervals when compared formulation rapidly coats solid particle surfaces, Field-proven to increase sand-free with resins including metal oxides, sand,and formation production rates Pumpable down production tubing, fines,as well as other anionic substrates. During SandAid technology has successfully treated • this process,SandAid technology alters the zeta more than 300 wells around the lobe.After coiled tubing,or flow line potential,or the electrokinetic potential between g application of the treatment,sand-free flow rates la Can be mixed in freshwater,brines, the surface of a particle and the bulk-phase of increased in each successful well—with no and seawater the suspending liquid,to the optimal range for damage to the wellbore or the reservoir. • Adaptable to changing reservoir stress maximum attraction between particles. conditions by remaining ductile and able to reagglomerate • Pumpable downhole as a matrix treatment • Relatively low cost and simple to apply Sand Control SandAid Formation Damage Evaluation SandAid Technology Specifications Temperature,degF[degC] Up to 350[up to 177] 1111 Initial M Final Initial li Final Unconfined compressive strength,psi[kPa] N/A 3,500 Permeability range,mD 1-10,000 cl 20 1=1 E 3,000 Regained permeability,% 75 76°� a; 75.5% Max.interval length,ft[m] 200[61] 15 ° 2,500 Shut-in time,hours 6 2,000 Fluid viscosity,cp 1 at 70 degF[21 degC] 10 m 1,500 a) a) a 5 aa) 1,000 500 0 0 Low permeability High permeability Test performed with 5%SandAid technology at 195 degf[91 degC). Agglomeration Test Untreated Sand Treated Sand Agglomeration of the sand for untreated sand(left)and sand treated with SandAid technology(right). slb.com/SandAid CopyrtsandAid is a product of Lubrizol and is licensed to Schlumberger Schlumberger Copyright©2016 Schlumberger.All rights reserved 15-00-63879 i . • • POLY PLUG R CLEAR GEL PROFESSIONAL FLUID SERVICES, LLC E 1 . J{ so- i\ JANUARY 2005 % Xr s .1 , .... - .. .. .,,..., ... -.,. i ; ' Case Histories :.. CASING LEAK 2 rx: PRODUCT DESCRIPTION GRAVEL PACK 2 SHUT OFF POLY PLUG®(CLEAR GEL) is formulated with high concentrations of low mo- lecular weight anionic polymer. When combined with a carboxylate complex WATER SHUT- 2 crosslinking agent, the product produces a rubber like ringing gel structure. OFF POLY PLUG®(CLEAR GEL) is also referred to as MARASEAL-EZsM MARASEAL-EZsM is exclusively licensed technology from MARATHON OIL COMPANY. PRODUCT BENEFITS POLY PLUG®(CLEAR GEL) is NEVER a drill out problem. Simply wash through or dump bail any material left in the casing for easy clean out!!! '11- Special points of interest: POLY PLUG®(CLEAR POLY PLUG®(CLEAR POLY PLUG®(CLEAR • Full shut off treat- GEL)is designed with a GEL)is a solids free fluid GEL) is mixed into fresh ►Hants into rock matrix less than low viscosity prior to which works by enter- or salt water at concen- 750 millidarcies , crosslinking to aid in ing the reservoir and trations of up to 5%. • Effective in shutting 40 injectivity. reducing permeability, Each POLY PLUG® off water or gas When placed in small not by plugging the (CLEAR GEL)treatment is • Effective in sealing 8 a perforations as in Port- casing leak openings such as pore based on the bottom . Effective in sealing throats or small chan- land Cement treat- hole temperature, cas- fes : meats. p gravel pack nels behind casing, the ing size, linear feet of if result is total shut off. perforations and other variables. III • Casing Leak—Ewing Banks Block 296 Gulf of Mexico OBJECTIVE: The pressure was slowly bled off Seal leak in the 7"casing so the and the 1 '/4' tubing pulled. After well could be plugged and aban- two hours the well was pressured doreri as nerMMS requirements. up to 1,500 psi and held pressure f for twelve hours. y "Illi .,4 lifie Ten barrels of POLY PLUG®CLEAR Pressure held and P&A operations GEL was mixed into saturated salt commenced. water. To gain access to the 7" % casing required perforating the 2 -***41114- 7/8"tubing at 1,483'. The pill was squeezed into the 2 '/8"X 7"annu- "' lus via 1 1/4" coil tubing. The well was left shut in for one hour with an initial SIP of 750 psi. Pressure equalized at 600 psi. Water Shut Off (Gravel Pack) Ewing Banks, Gulf of Mexico OBJECTIVE: estimated to be in the order of sev- well head. eral feet from the perforations. Shut-ori n1-, i, pack completion from After waiting twenty four hours, the The well was then put in re- After waiting complete/perfo• completion mode and perforated remaining gel was removed via e- rate from 13,886'43,897' below the existing perforations. line bailer and the well was tested A fifty barrel treatment was bull to 2,500 psi or 1,000 psi over The well is currently producing over headed down the tubing and dis- 480 barrels of oil. placed with sea water. Four bar- "This was a proven success in gravel Well Specifics: rels of POLY PLUG®CLEAR GEL was pack shut off where conventional left above the gravel pack screen cement would have required a side 200-1,000 and permeability with to help prevent over displacement. track. Furthermore,this application 31% porosity. Gel invasion into the reservoir was proved POLY PLUG®CLEAR GEL could Reservoir Temperature: 205°F be applied without the expense of a rig or coil tubing." Water Shut Off (Gravel Pack) Ewing Banks, Gulf of Mexico OBJECTIVE: the gel treatment. As expected, was pressured up to 1,000 psi over Achieve a complete shut-off the well immediately went on vac- well head and the perforation treatment from channels behind uum. tested. A negative test to 400 psi 4 '!,"casing. The 45 barrel treatment was ap was also applied to verify the shut- A 45 barrel treatment designed for plied to the perforations. Approxi- off. maximum penetration into matrix mately one barrel of gel per linear This was a proven success in for- pore spaces. Prior to the applica- foot of perforations was pumped. mation shut-off where conventional tion, an injection rate was estab- The well was left shut-in for twelve cement would have required drill lished with water to determine the hours. The remaining gel was out. potential for the interval to accept washed through with via CT and high pressure nozzle. The well Page 2 POLY PLUG®CLEAR GEL +PV OF T y� • • gw ��I�y� sA THE STATE Alaska Oil and. Gas ofALIASJ�`11 �A Conservation Commission r �= 333 West Seventh Avenue 4 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OA, ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager SC.ANNED SEP 2 9 2016 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Trading Bay Field,Middle Kenai B, C, and D Oil Pools, TBS A-30 Permit to Drill Number: 173-014 Sundry Number: 316-442 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this lay of September,2016. RBDMS i( SEP - 8 2016 • • RECEIVED STATE OF ALASKA AUG 2 616 ALASKA OIL AND GAS CONSERVATION COMMISSION , /07S- cr /7 /1. APPLICATION FOR SUNDRY APPROVALS AOGCC b 20 AAC 25.280 1.Type of Request: Abandon LI Plug Perforations El Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate LI Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill 0 k Perforate New Pool ❑ Re-enter Susp Well LI Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 , 173-014 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20253-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A 0 Will planned perforations require a spacing exception? Yes ❑ No 0/ Trading Bay St A-30 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): u► ADL0018731 Trading Bay Field/Middle Kenai D,Middle Kenai B Oil Pods t Mil/t i „: L Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,485 ' 5,933 ' 6,820 + 5,316 • 1,040 psi N/A 6,820 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,246' 16" 1,246' 1,197' 1,640 psi 630 psi Intermediate 5,164' 13-3/8" 5,164' 3,821' 3,090 psi 1,540 psi Production 7,476' 9-5/8" 7,476' 5,925' 6,870 psi 4,760 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3,941 -6,540 ' 2,885-5,071 2-7/8" 6.5#/L-80 3,901 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(It): Model D Packer&SSSV • 3,871'(MD)2,843'(ND)&312'(MD)312'(ND) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 ^ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/15/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager C Signature '—J Phone (907)777-8356 Date Z S /l la COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 1 Le — '-`—{ Z Plug Integrity LI BOP TesNEr Mechanical Integrity Test ❑ Location Clearance ❑ Other: •X .'- C.;00 f'S• amt pa5iLtrc ' x w 1 C ) P`- % 1-Cle,., eArs;oc. Pcz>esc aze- ,- .s. 144- 14116 1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: C) 40 r7 RBDMS C L- SEP - 8 2016 APPROVED BY Approved by: / / (�t� COMMISSIONER THE COMMISSION Date( �.—�� oti 1/So O ,R1 / A ' A Submn Form and Form 10-403 Revised 11/2015 r fQi _p1pk\�a/t[Q�jl valid for 12 months from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: A-30 Hilcorp Alaska,LLC Date: 08/22/16 Well Name: Monopod A-30 API Number: 50-733-20253-00 Current Status: Oil Producer(Gas Lifted) Leg: N/A Estimated Start Date: 9/15/2016 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: 173-014 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907)398-9904(M) Second Call Engineer: Monty Myers (907)777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 2,020 psi @ 4,386'TVD 0.461 psi/ft(8.86 ppg) Maximum Expected BHP: 2,020 psi @ 4,386'TVD 0.461 psi/ft(8.86 ppg) Maximum Potential Surface Pressure: 1,040 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The A-30 well was last worked over in 2014 completed in the B and C sands as a gas lifted producer. l recently experienced water and associated sand break through from the offset A-12 injector.This workover will plug back the well for a sidetrack through the Tyonek sands into the Hemlock. Last Casing Test: 12/26/2013 at 3,906' 1,500 psig for 30 minutes on chart Procedure: 1. Skid Rig into position above A-30. 2. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Circulate hydrocarbons from well to production—Workover fluids will be FIW and salt as needed for weight, BOP's will be closed as needed to circulate the well. 4. POOH laying down gas-lift completion fishing as needed. 5. RIH stinging into production packer at 3,871'. 6. RU cementing equipment and establish an injection rate with FIW. 7. Mix and pump±220 barrels Class G cement to isolate existing completion. Un-sting from packer and circulate hole clean. POOH. - 8. RU e-line and RIH w/CIBP to±3,800' ±CIBP 5'above casing connection. 9. RD e-line. nn 10. PU whipstock and mills and RIH to CIBP. 1"cz�-� �,2x ��6. TO 11. Orient and set whipstock. \GCC) e 't Fort- -1- O t`4 lk �' t-c'1-541.1.10***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** General sequence of operations pertaining to drilling procedure: (informational only) ICmuuyS 12. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. hCwM 13. PU directional BHA and TIH to window. 14. Swap well to drilling fluid ® I 20/6 4•,74.1 Per 04 fG pro v/d&cf 4 WI Ic e/ 0 /401)/1'4*r4 f�f OLCYreI /4 /qfc J 4 / [yaw radvctia► fro,. r�4f -ell /moi• r-44. rc ,p/P1. f��y��y r4 w�11 �.e���'1 P e d #'04, Tor //ern/a4 ,��,a14 a(�ow �a� tic Pos,!%6j o� deco✓o��nf Gdo%�r;o�v� 4;� ` fes for pi gr-i oh kid Once yAoir Palk Cea5P-1- TZr lve(1 could 6e rero ' id l4" 7 Ae Kht W►�'I� ('S �rOG�C}'� 6141To Ire-Over tadP¢a'Onq( (e ewe , . `1/46 zortys nc� �r • • • Well Work Prognosis Well: A-30 Hilcorp Alaska,LLC Date: 08/22/16 Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current/Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • • II Trading Bay Unit SCHEMATIC Well #A-30 Hilcorp Alaska,LLC Completed: 01/02/2014 CASING DETAIL SIZE WT Grade Conn. ID Top Btm. RKB to TBG Hngr=33.8' 16" 65 H-40 Butt.LT&C Surf 1,246' Tree connection:3" 5,000# 13-3/8" 61.0 K-55 Butt.LT&C 12.515" Surf 3,732' 13-3/8" 68.0 K-55 Butt.LT&C 12.415" 3,732' 5,164' 1 9-5/8" 47.0 N-80 Butt 8.681" Surf 5,076' 9-5/8" 47.0 N-80 Butt 8.681" 5,076' 7,476' 2 TUBING DETAIL 2-7/8" 6.5# L-80 8rd EUE 2.441" Surf 3,901' 3 4 s //////i/�/'''';2,R 1;0?,;,iiii/// JEWELRY DETAIL t 6 NO Depth Depth ID OD Item 7 (MD) (TVD) 33.8' 33.8" Tbg.Hanger 1 312' 312' 2.313" 4.688" SSSV w/BX profile 2 2,672' 2,109' 2.441" 4.688" GLM#1(SPM-1) 3 3,796' 2,798' 2.441" 4.688" GLM#2(SPM-1) 4 3,844' 2,827' 2.441" 4.688" Chemical Injection Mandrel 5 3,871' 2,843' 6.000" 8.120" Packer Model D -lir 6 3,892' 2,856' 2.313" 3.670" X Nipple 7 3,901' 2,861' 2.445" 3.700" WLEG B Zone IIMB Top Btm Top Btm Accum Last Perf Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Persent Condition Mei B 26-7 3,941 3,958 2,885 2,895 17 5 12/30/13 Open Bad csgvsmemsoz3_ B26-7L 3,988 4,030 2,913 2,939 42 5 12/30/13 Open c21sgz hole w/250 sx P rzve' Cmt sqz'd w/1,000 sx Tested to 1200 me B 28-6 4,174' 4,184' 3,028' 3,033' 10' 8 6/6/1973 g psi. B 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 Cmt sqz'd w/250 sx Tested to 4500 psi ,/87 5076' B 31-8 4,644 4,756 3,375 3,467 112 5 12/30/13 Open /n,. /moi,. B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. L , 5164' B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8&4 2/7/1990 Open f/Production. B 31-8 4,692' 4,742' 3,414' 3,455' 50' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. C Zone B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12&8 2/6/1990 Open f/Production. B 33-6 4,792 4,850 3,497 3,546 58 5 12/30/13 Open B 40-4 4,874 4,896 3,567 3,586 22 5 12/30/13 Open B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. • ii// ��ii%%%% ���� ����� � ��, i Cmt 6g of B 40-4 4,872' 4,908' 3,565' 3,596' 36' 8&4 2/5/1990 Open f/Production. _� B 41-8 4,980 5,040 3,659 3,711 60 5 12/30/13 Open " 'Cr" "'�////�'" B 41-8 4,986' 5,040' 3,664' 3,711' 54' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to " /// i'i%/ii��� surface on 6/28/73. o - B 41-8 4,980' 5,060' 3,659' 3,729' 80' 8&4 2/5/1990 Open f/Production. B 41-8 5,148' 5,150' 3,807' 3,809' 2' 4 7/21/1981 Cmt sqz'd w/300 sx B 44-7 5,278 5,328 3,923 3,967 50 5 12/30/13 Open B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. o i B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. /�/��///�/� /�/'�//� D Zone C 5 5,708 5,770 4,307 4,364 62 5 12/30/13 Open iiii..,,l ///,:ii/iii..,,.. C 7 5,918 6,048 4,500 4,620 130 5 12/30/13 Open N._ C ZN1 6,145 6,160 4,710 4,724 15 5 12/30/13 Open C 47-5 6,166 6,232 4,729 4,790 66 5 12/30/13 Open C 48-7 6,312 6,324 4,863 4,874 12 5 12/30/13 Open C 50-3 6,512 6,540 5,046 5,071 28 5 12/30/13 Open D 53-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 \ D 53-8 6,941' 6,956' 5,437' 5,451' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 54-5 7,000' 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 KB ELEV=101' D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 TD=7485' _ D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 PBTD=6,820' D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 ANGLE thru INTERVAL=37° D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 Updated by: JLL 08/24/16 • • • 14 Trading Bay Unit PROPOSED Well #A-30 1[ilcorpAlaska,LLC Completed: Future CASING DETAIL SIZE WT Grade Conn. ID Top Btm. RKB to TBG Hngr=33.8' 16" 65 H-40 Butt.LT&C Surf 1,246' Tree connection:3" 5,000# 13-3/8" 61.0 K-55 Butt.LT&C 12.515" Surf 3,732' 13-3/8" 68.0 K-55 Butt.LT&C 12.415" 3,732' 5,164' 9-5/8" 47.0 N-80 Butt 8.681" Surf 5,076' 9-5/8" 47.0 N-80 Butt 8.681" 5,076' 7,476' TUBING DETAIL 2-7/8" 6.5# L-80 8rd EUE 2.441" 3,871' 3,901' '/////iii!!!;� .... //%i 2 Jewelry Detail 4 NO. Depth Depth ID OD Item (MD) (TVD) 1 ±3,800' ±2,800' - - CIBP(Set for Whipstock) 2 3,871' 2,843' 6.000" 8.120" Packer Model D • 3 3,892' 2,856' 2.313" 3.670" X Nipple F 4 3,901' 2,861' 2.445" 3.700" WLEG • • B Zone - Top Btm Top Btm Accum Last Perf • • Zone (MD) (MD) (ND) (ND) Amt SPF Date Persent Condition • - B 26-7 3,941 3,958 2,885 _ 2,895 17 5 12/30/13 Bad cs9 v sm a m sozs. B 26-7L _ 3,988 4,030 2,913 _ 2,939 42 5 _ 12/30/13 cinlsgz hole w/250 sv ;nve' B 28-6 4,174' 4,184' 3,028' 3,033' 10' 8 _ 6/6/1973 ...• B 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 B 31-8 4,644 4,756 3,375 3,467 112 5 12/30/13 ice/ 5076' B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8&4 2/7/1990 B 31-8 4,692' 4,742' 3,414' 3,455' 50' 10 6/13/1973 6 , 5164 B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12&8 2/6/1990 • B 33-6 4,792 4,850 3,497 3,546 58 5 12/30/13 • B 40-4 4,874 4,896 3,567 3,586 22 5 12/30/13 v B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 4.0 C ' C Zone B 40-4 4,872' 4,908' 3,565' 3,596' 36' 8&4 2/5/1990 0) • B 41-8 4,980 , 5,040 3,659 3,711 60 5 12/30/13 E • , B 41-8 4,986' 5,040' 3,664' 3,711' 54' 2 6/21/1973 a) B 41-8 4,980' 5,060' 3,659' 3,729' 80' 8&4 2/5/1990 U B 41-8 5,148' 5,150' 3,807' 3,809' 2' 4 7/21/1981 4, j/��� Cmt Ret. B 44-7 5,278 5,328 3,923 3,967 50 5 12/30/13 jjj /ice%%%% i,,.,,,.. A 6e20' B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 7i%///,i%% -' - %/%/� B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 i.,,, /. C 5 5,708 5,770 4,307 4,364 62 5 12/30/13 C 7 5,918 6,048 4,500 4,620 130 5 12/30/13 C ZN1 6,145 6,160 4,710 4,724 15 5 _ 12/30/13 C 47-5 6,166 6,232 4,729 4,790 66 5 12/30/13 C 48-7 6,312 6,324 4,863 4,874 12 5 12/30/13 C 50-3 6,512 6,540 5,046 5,071 28 5 12/30/13 &i" "Z,..,: =%i�j//j„�� D Zone D 53-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 53-8 6,941' 6,956' 5,437' 5,451' 15' 4 _ 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 54-5 7,000' 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 57-2 7,336' 7,348' 5,798' 5,809' 12' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 KB ELEV=101' D 57-2 7,358' 7,366' 5,818' 5,825' 8' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 TD=7485' PBTD=6,820' ANGLE thru INTERVAL=37° Updated by: JLL 08/24/16 • • •• • Monopod Platform A-30 Current 08/25/2016 It lenrlr %laska. Monopod Platform Tubing hanger,SME-CL,11 X A-30 3%EUE lift and susp,w/3" 20 X 16 X 13 3/8 X 9 5/8 X Type H BPV profile,3-3/8 2 7/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I ,i• Valve,Swab,WKM-M, 3 1/8 5M FE,HWO,DD trim ' Valve,Wing,WKM-M, 31/85MFE,w/15' OMNI 1.11111.11.1operator,DD trim Mak : )(- O 8.1 Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim •t IVO X2 = Control line I , - I I '` Tubing head,5-8,13 5/8 3M x 115M,w/2-21/16 5M SSO, i♦� �. �- w/BG bottom w/1-21/1/165MWKM-M � valves ®��./® 1111 -1 ITT ' - � I Casing spool,OCT-29L,21 Y. ° 2M X 13 5/8 3M,w/2- 2 1/16 5M 550, 13 3/8-00 bottomR C-22 slips installed .� I •®I 0 jr _eo ! 0 1 li ' Starting head,OCT Type II, 21%2M X 20"SOW, 'C " u - w/4-2 1/16 2M SSO ‘TI7— 16"casing hung off on mandrel 13 3/8"casing on C-29 slips :It I Auf 20" 116' L J133/8" 9 5/8" 2 7/8" • • fit Monopod Platform A-30 BOP Stack 08/25/2016 Hilw>Irp:11neka.I,IA Rig Floor Bottom of air boot Flange 11h III 5'below rig floor 16" 14.06' 9.00' Pipe Ili III Ii r ll • o 111 1 (n f1111111 . 3.74' Shaffer 13 5/8 5M III III III III III 26.25' Shaffer LXT " 27/8-S Variables 2.50' 135/85M Blind ANEW 111111111111 111 2 00 Il : '1111114 I�. Mud Cross grill, 1�' I`135/85MFEXFE w/31/85MEFO w/2 1/16 5M manual and HCR valves for choke and I 11:;1: 41 to kill lines,w/Unibolt end connections for lines 2.83' 27/8-5 variable lil 'II'El 1.36' 111 Ill111 I! 111 V Drill deck Riser 11.00' 135/8 SM FE X 135/8 SM FE 111 AI III iil III iggir III 1111111V IV Spacer spool 1.5' 135/85M FE 115M Iil lit Iii lil 1i1 Wellhead @ 11.14' • • • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,Lu; Attachment#1 Attachment #1 Hilcorp Alaska, LLC. BOP Test Procedure: Monopod Rig # 56 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru the flare to atmosphere. 2) Load well with FIW to kill well. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Check well is static, shoot fluid levels if necessary. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. Clean and inspect lift threads(screw sub into threads, count the number of turns). Install blanking sub if using one. 2) NU BOP 3) Test BOPE per Monopod Rig#56 BOPE test procedure. Initial Test(i.e.Tubing Hanger is in the Wellhead) Rolling BOP Test If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level, shoot fluid level with an echometer gun or tag with slick line to establish static fluid level if necessary. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift-threads to accept test joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set BPV and/or have lift-threads prepped for test joint. d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. • 1110 • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,1.11Attachment#1 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator or hanger leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC- guy.schwartz@alaska.gov ) and Mr.Jim Regg (AOGCC-jim.regg@alaska.gov )via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: 5) With stack out of the test path, test choke manifold. 6) Conduct a rolling test: a. Test the rams and annular with the pump continuing to pump, holding a constant pressure on the equipment (monitor the surface equipment for leaks to ensure integrity). b. Record the pumping rate and pressure. 7) Once the BOPE tests are completed, test the remainder of the system following the normal test procedure (PVT, gas detection, etc.) 8) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment, list pressures and rates. 9) Pull hanger to surface (May require tubing cuts to free tubing) 10) Remove the old hanger, MU a new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. 11) Test BOPE per Monopod Rig#56 BOPE procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Rig 56 BOP TEST Open kill line valve, mud cross valves, all CMV except 15, open '2"valves above valve 16, remove sensor above valve 3, and close all standpipe manifold valves. Fill stack w/water through kill line fill BOP and CMV's to top of annular. Close annular preventer X2 to get air out and continue to fill to top of dart valve. Close dart valve and continue to fill until fluid is seen out of CMV#5. Cont.fill till fluid comes out%" valves above CMV 16, close valve 16&4"kill valve on mud line. Open bleed line on standpipe manifold Have a hand in wellhead room w/casing valve open monitoring it open ended or to a gauge during all tests. In freezing temperatures, blow down mud line back through MP bleeder.Shell test. Test w/31/2 Ti 1) Close pipe rams, Open Annular, test CMV 3,5,15& 16, dart valve,pipe rams, 4"demco kill line valve, t/250 low f/5 min, 2500 high f/5 min (straight line time each and remaining tests) • • • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,LL(: Attachment#1 2) Close TIW open dart valve, CMV's 8,9,12,13,14 kill line HCR, open CMV 15& 4"Demco kill line valve (drain gas buster "U"tube immediately in freezing temps) 3) Close CMV's, 1,7,10,11, manual kill line valve, open CMV's 8,9,12,14, & kill line HCR 4) Close CMV's 2,4,6, open valves 1,7& 13 5) Close HCR choke line, open CMV 2 6) Close manual choke line valve, open HCR choke line valve Preform Accumulator test....then pull Ti With test jt in hole&system up to pressure. 1) Turn off electric& air pumps 2) Record accumulator pressure(+-3000psi) 3) Close Annular,pipe ram's, & her valves, open pipe rams to simulate blinds 4) While pressure is stabilizing check pressure in nitrogen bottles& record. 5) Record accumulator pressure 6) Turn on electric pump& time seconds to pressure up 200 psi, turn on air pumps& time till unit pressures up to 3000 psi&shuts off. (time will start from time electric pump starts till all pumps shut off) 7) Back out test jt&pull, close blinds, install test hose to choke manifold outside valve 5, close valves 2,4,6, open valve 11, choke HCR& inside choke line valve 8) M/U 2 7/8 t/j, close annular,fill test jt w/test pump till tiw/dart valve is full, then close, test 9) Close pipe rams, open annular, close tiw, open dart valve FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Test PVT system 3) Double check all rams and valves, for correct operating position 4) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. . • .R 0 N:I f i= _; m gq 11, �� 4.:,4 3 ��- - V o 0 0 V o I+o 0 0 v u U V o LJIJo u o 0 V u.o 0 0 0 0 0.:, V O O — 1 In Nati Lam. 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II- ~ A I I- SUMER s A d . s v t • i w a a 4 I GI p w 3d i 1- --II- 1.11,- I' p i 8 s a 0 • i I- .--14- i 0 • c22 2 � k .c gCC2 co 2 6 2 c 2E So ° � k 2 0.EL § f « E EE -a Sg $ Q m Y o ® = 2 i 0- E » « -o \0 2 CD w m >170 ��k = . �\ a gE § � n ■ ■ R % gt ■ 2 k k $ § t �>- Co 2 k . @ B 9 tk w , _0 § U ci 2 k k § ■ - § k -00 :2- .;.1), k � O Em © 2 0 ) f : a .0 16 0. 0 S \ � co iii co cv C -a k -a c � C W § ■ > k2 ■ 0 / 0 0- a.43 a � 12 . CC3 Q. « ■ k 0. § k ■ - 0 - 0 cid _� Q ■ � . e ■ *a RI CD § � a. $ I. 7 � 2 iz 0 .. a V ol O Re E0 2 as > k E 0 a. E 112 0 CO < < co < a_ • • Roby, David S (DOA) From: Roby, David S (DOA) Sent: Thursday, September 01, 2016 4:39 PM To: 'Dan Marlowe' Subject: RE: Sundry application for Trading Bay State A-30 (PTD 173-014) Thank you. I was suspecting that the water breakthrough occurred either late last month or early this month and thus didn't clearly show in our production database and this confirms it. Dave Roby (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.robydalaska.gov. From: Dan Marlowe [mailto:dmarlowe(Ohilcorp.com] Sent: Thursday, September 01, 2016 4:31 PM To: Roby, David S (DOA) Subject: RE: Sundry application for Trading Bay State A-30 (PTD 173-014) Yes it would pass through the same zones and the Tyonek would be available for future recompletes. Here is the raw well test info—non allocated of course. You will see the spike show up when you receive the July/August data. For now it is shut-in and remain shut-in until we can figure out how to repair it or re-drill it. 1 A _ - _ IJK LMN A-30 '!SE GRAY F' "' FOR GROSS& CUT worksheet is protected without a password so dor'tQet charged.Urprctect sheet to make c VX or Gross Net Gross Inj Form DATE Test#2 Rate Cut Oil Gas Gas Gas GOR GLR Gray Tbg Csg Choke 2 11/18114 2382 90.6 224 1001 615 386 1723 420 170 935 128 3 1211/14 2214 89.7 228 979 583 396 1737 442 170 925 128 • 1/13115 2285 89.5 240 1088 641 447 1863 476 100 839 128 1/17/15 2041 92.6 151 816 643 173 1146 400 180 860 128 6, 2118/15 1909 91.5 162 687 616 71 438 360 150 850 128 7 3/8/15 1830 91.5 156 1426 630 796 5103 779 94 796 128 4111115 2058 91 185 756 677 79 427 367 165 825 128 • 4/20/15 1844 91.7 153 797 680 117 765 432 165 810 128 • 5/18/15 1515 91.2 133 722 544 178 1338 477 160 780 128 1 6/12/15 1590 90 159 694 661 33 208 436 170 800 128 2 6/28/15 1582 88.55 181 822 656 166 917 520 95 940 128 3 7/8/15 1682 90 168 998 669 329 1958 593 180 760 128 • 8/9/15 1287 89.5 135 668 616 52 385 519 160 760 128 9/5115 1368 91 123 639 639 0 0 467 150 720 128 6 10/9/15 1289 91.6 108 730 660 70 648 566 160 510 128 7 10/29/15 1322 91.7 110 1081 964 117 1064 818 165 510 128 11/24/15 1540 91 139 1067 579 488 3511 693 100 500 128 • 12111/15 1150 89.3 123 830 666 164 1333 722 165 510 128 a 1/8/16 1210 90.5 115 1030 683 347 3017 851 160 470 128 1 2117/16 1392 91.6 117 875 704 171 1462 629 90 440 128 3/11/16 1376 91.9 111 840 720 120 1081 610 100 430 128 3 4/12116 1326 91.2 117 1044 733 311 2658 787 90 440 128 5/10/16 1324 91 119 851 710 141 1185 643 100 440 128 5 6/4/16 1322 91.3 115 935 693 242 2104 707 94 430 128 7/10/16 1331 91 120 886 700 186 1550 666 87 4-40 128 7 7121/16 2206 95 110 384 260 124 1127 174 528 1090 128 7/23/16 4435 97.1 129 748 450 298 2310 169 258 890 128 ▪ 7/24/16 4309 94 259 810 509 301 1162 188 261 808 55 a 7/30/16 4008 92 321 458 277 181 564 114 210 743 55 1 812/16 3498 92.4 266 954 680 274 1030 273 130 590 128 From: Roby, David S (DOA) [mailto:dave.robv alaska.gov] Sent: September 01, 2016 2:03 PM To: Dan Marlowe Subject: Sundry application for Trading Bay State A-30 (PTD 173-014) Dan, In reviewing the application to plug this well for redrill one of the reasons stated is that there has recently been water and sand breakthrough from a nearby injector. In reviewing the production data we have in our system it doesn't really show a water breakthrough event. Since this well was worked over and returned to production in 2014 the water cut has bounced around some but been pretty consistently in the 90-95%range and oil production has shown a fairly steady decline from its peak of 272 BOPD in November 2011 to about 90 BOPD in recent months. Can you provide more detail on the water and sand breakthrough. 2 • Also,the application mentions that t proposed redrill will target the Hemlock foormation. Is the well going to pass through the Tyonek in a position where it would be possible to recomplete the well after it's Hemlock production ceases to capture more reserves from the Tyonek? Thank you, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.roby4alaska.aov. 3 • • A Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or 7 "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial ,� then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) We' 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS DECEIVED FEB 0 3 2014 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 Other as i Completion Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension LI Change Approved Program ❑ Operat. Shutdown❑ Stimulate -Other ❑ Re-enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development [7] Exploratory ❑ Stratigraphic❑ Service ❑ 173-014 ` 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, AK 99503 50-733-20253-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018731 . Trading Bay St / A-30 ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Trading Bay Field / Middle Kenai D, Middle Kenai B Oil Pools 11. Present Well Condition Summary: Total Depth measured 7,485 feet Plugs measured N/A feet true vertical 5,933 feet Junk measured 6,820 feet Effective Depth measured 6,820 feet Packer measured 3,871 feet true vertical 5,316 feet true vertical 2,843 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,246' 16" 1,246' 1,197' 1,640 psi 630 psi Intermediate 5,164' 13-3/8" 5,164' 3,821' 3,090 psi 1,540 psi Production 7,476' 9-5/8" 7,476' 5,925' 6,870 psi 4,760 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 3,901' (MD) 2,861' (TVD) 3,871' (MD) 312' (MD) Packers and SSSV (type, measured and true vertical depth) Packer 2,843' (TVD) SSSV 312' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS MAY 11 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 0 460 560 Subsequent to operation: 232 1340 3231 936 92 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ DevelopmentE Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 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: 1313-636 Contact Ted Kramer Email tkrame[@-biLicorp.com Printed Name Ted Kramer Title Sr. Operations Engineer yam` Signature Phone (907) 777-8420 Date 2/3/2014 Form 10-404 Revised 10/2012 Submit Original Only � lyl� Trading Bay Unit SCHEMATIC Well # A-30 111 I �I. mak. I I.( Completed: 01/02/2014 RKB to TBG Hngr = 33.8' Tree connection: 3" 5,000# KB ELEV =101' TD = 7485' PBTD =' ANGLE thru INTERVAL = 37° Zone 376 64 Zone ne SIZE WT CASING AND TUBING DETAIL Grade Conn. ID Top Btm. 16" 65 H-40 Butt. LT&C 2,672' Surf 1246' 13-3/8" 61.0 K-55 Butt. LT&C 12.515 Surf 3732' 13-3/8" 68.0 K-55 Butt. LT&C 12.415 3738 5164' 9-5/8" 47.0 N-80 Butt 8.681 Surf 5076 9-5/8" 47.0 N-80 Butt 8.681 5076 7476' Tubing: 5 12/30/13 Open B 31-8 4,648' 4,684' 2-7/8" 6.5# L-80 gird EUE 2.441 Surf 3,901' NO. Depth JEWELRY DETAIL ID Item 2,885 33.8 Tbg. Hanger 1 312' SSSV 2 2,672' GLM # 1 3 3,796' GLM # 2 4 3,844' Chemical Injection Mandrel 5 3,871' Packer 6 3,892' X Nipple 7 3,901' WLEG Top Btm Top Btm Accum Last Perf Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Persent Condition B 26-7 3,941 3,958 2,885 2,895 17 5 12/30/13 Open 8 26-71. 3,988 4,030 2,913 2,939 42 5 12/30/13 Open B 28-6 4,174' 4,184' 3,028' 3,033' 30' 8 6/6/1973 Cmt sgz'd w/ 1,000 sx Tested to 1200 psi. B 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 Cmt sqi d w/ 250 sx Tested to 4500 psi B 31-8 4,644 4,756 3,375 3,467 112 5 12/30/13 Open B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 Isolated w/ 9-5/8" Tie -back liner to surface on 6/28/73. B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8&4 2/7/1990 Open f/ Production. B 31-8 4,692' 4,742' 3,414' 3,455' S0' 10 6/13/1973 Isolated w/ 9-5/8" Tie -back liner to surface on 6/28/73. B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 Isolated w/ 9-5/8" Tie -back liner to surface on 6/28/73. B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12 & 8 2/6/1990 Open f/ Production. B 33-6 4,792 4,850 3,497 3,546 58 5 12/30/13 Open B 40-4 4,874 4,896 3,567 3,586 22 5 12/30/13 Open B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 Isolated w/ 9-5/8" Tie -back liner to surface on 6/28/73. B 40-4 4,872' 4,908' 3,565' 3,596' 36' 8&4 2/5/1990 Open f/ Production. B 41-8 4,980 5,040 3,659 3,711 60 5 12/30/13 Open B 41-8 4,986' 5,040' 3,664' 3,711' 54' 2 6/21/1973 Isolated w/ 9-5/8" Tie -back liner to surface on 6/28/73. B 41-8 4,980' 5,060' 3,659' 3,729' 80' 8&4 2/5/1990 Oen f/ Production. B 41-8 5,148' 5,150' 3,807' 3,809' 2' 4 7/21/1981 Cmt sqi d w/ 300 sx B 44-7 5,278 5,328 3,923 3,967 50 5 12/30/13 Open B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 Cmt sqi d w/ 100 sx. Tested to 1200 psi. B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 Cmt sgz'd w/ 100 sx. Tested to 1200 psi. C 5 5,708 5,770 4,307 4,364 62 5 12/30/13 Open C 7 5,918 6,048 4,S00 4,620 130 5 12/30/13 Open C ZN1 6,145 6,160 4,710 4,724 1 15 5 12/30/13 Open C47-5 6,166 6,232 4,729 4,790 66 S 12/30/13 Open C 48-7 6,312 6,324 4,863 4,874 12 5 12/30/13 Open C 50-3 6,512 6,540 5,046 S,071 28 5 12/30/13 Open D 53-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sgz'd w/ 400 sx on 7/20/81 D 53-8 6,941' 6,956' 5,437' 5,451' 15' 4 6/30/1973 Cmt Sqi d w/ 400 sx on 7/20/81 D 54-5 7,000' 1 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sqi d w/ 400 sx on 7/20/81 D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sgz'd w/ 400 sx on 7/20/81 D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqi d w/ 400 sx on 7/20/81 D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sgz'd w/ 400 sx on 7/20/81 D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqi d w/ 400 sx on 7/20/81 Updated by: AL 02/03/14 Hilcorp Alaska, LLC Hi►,.orp Alaska. L►.►: Well Operations Summary Well Name JAPI Number lWell Permit Number IStart DateEnd Date A-30 50-733-20253-00 173-014 1 12/22/2013 1/2/2014 Daily Operations: 12/22/13 -Sunday Finish nipple up BOPs. Function test BOP equip. Rig up to test BOPs W/ 5"" test jt. Test all BOP equip w/ 5"" test jt to 250 psi low and 2000 psi high. Perform accumulator function test, Lay do 5"" test jt. Blow down and stand back kelly. Pull BPV and set TWC. Test blind rams to 250 psi low and 2000 psi high. Good test. BOP test witness waived by Jim Regg on Fri 12/20/2013 @ 7:37 PM via e-mail. Pull TWC. PU 2-3/8" test jt. Test annular and lower pipe rams w/ 2-3/8" to 250 low and 2000 high. Lay do test jt and rig down test equip. MU landing jt and rig up to circ. Pump 11.7 in stages taking oil back to production off ann. Shut in and monitor tbg pressure. Press increased from 35 psi to 184 psi in one hr. Shut well in and finish installing gates, cutting shoots, and flow ditch to new shakers so we can circ back to pits. Circulate 1300' hole volume pumping down tubing, taking returns through annulus under Tbg Hgr and through Mud Pump #2 bleeder to pits. 1 BPM @ 170 psi, increase to 4 BPM @ 400 psi. Caught full returns @ 3.7 bbls pumped. No gas @ bottom up or surface to surface strokes. Pumped 110 bbls. Decrease pump to 1 BPM @ 30 psi while B.O.L.D.S. Shut down pump, shut in annulus. Pull Tbg Hgr free @ 50K. PU hole and pull out of Seal Bore @ 105K. Wt fell off to 36K. Circulate 1300' hole volume @ 7 BPM with 965 psi. No gas @ bottoms up. Monitor well while having PJSM on laying down completion. Static loss @ 2 BPH. Pull Tbg Hgr to floor, breaking down 5" drill pipe landing joint. Lay down Tbg Hgr. Change over to 3-1/2" handling equipment. Pull out hole laying down 6 pup joints, 8 joints 3-1/2" tubing and SSSV. Change over to 2-3/8" handling equipment. Monitor Well. Well static. Pull out hole laying down 2-3/8" completion tubing to punched joint (32 jts total). Rig up Hot Tap Drill to plugged tubing. Joint below tubing punch had 500 psi trapped pressure. Continue laying down tubing, hot tapping each joint. Fluid 3 % Brine loss to well today 0 bbls - Total fluid 3% Brine loss to well 0 bbls - Sized Salt Pill loss to well today 0 bbls - Total SSP loss to well 0 bbls - Metal from Ditch Magnets today 0 lbs - Metal from Boot Baskets today - 0 lbs - Total metal recovered from well 0 lbs. 12/23/13 - Monday POH w/ 2-3/8" tbg f/ 3,100' t/ 2,900' Hot tapping every jt. w/ 70 psi on tbg. Continue POH laying do 2-3/8" tbg f/ 2,900 t/ 2,743'. Hot tapping every jt. Continue POH laying down 2-3/8" tbg f/ 2,743' t/ 2,176'. Continue POH laying down 2-3/8" tbg f/ 2,176' to 180'. Clean up rig floor. Continue to POOH laying down 2-3/8" tubing punching holes in each joint from 180' to surface. Lay down gas lift mandrel, seal assembly and joint with mule shoe. Recovered all of 2-3/8"" completion. Clean, pressure wash and scrub rig floor, cellar area, beaver slide and catwalk area. Well Static @ 02:00 hrs. Fluid 3 % Brine loss to well today 0 bbls - Total fluid 3% Brine loss to well 0 bbls - Sized Salt Pill loss to well today 0 bbls - Total SSP loss to well 0 bbls - Metal from Ditch Magnets today 0 lbs - Metal from Boot Baskets today - 0 lbs - Total metal recovered from well 0 lbs. 12/24/13 -Tuesday Set wear bushing. PU BHA #1 as follows: 3-1/8" PRT Spear, 3-1/8" PRT Ext, PRT Triple Conn. w/8-1/2" Mill, 3 each 7" Boot Baskets, Bit Sub w/Float, 6- 1/4" Bumper Sub, 6-1/4" oil Jar, XO Sub, 9 ea. 6-1/2" DC's XO Sub, Pump Out Sub. Total BHA Length = 335.91'. Trip in hole from 335' to 2,231'. Circulate hole volume from 2,231' shakers blinded off @ bottoms up with parafin. 8 BPM w/1000 PSI. Service Rig. Continue TIH with PRT/Mill from 2,231 to 4,530'. Make up Kelly. Break Circulation and establish parameters: 7 BPM with 745 psi, Up Wt 115K, Dn Wt 82K, Rot Wt 98K, 4K TQ @ 80 RPM. Engage top of PKR @ 4,555'. Mill PKR from 4,555' to 4,558'. Chase PKR to 4,567' staking weight. Pickup hole with 10K to15K drag. Monitor well with 1 BPH static loss. Blow down and set back Kelly. TOH slowly from 4,530' with 70K over pull coming off bottom, falling back to 10K to 15K drag swings. Work PKR Fish through tight spots. BHA at surface. Lay down pump out sub and jars. Rack 3 stands drill collars. 3 BPH losses, pull BHA. Fish on bottom. Break out mill, PRT and fish. Lay down same. Clean boot baskets and prepare to RIH with cleanout assy. Pick up BHA #2 RIH. Laid down one boot basket. 3 BPH losses. RIH. Tagged obstruction at 1,416'. Circulate 12 bbls. Shakers plugged off. Lay down 2 singles. Kelly up. Wash down singles. Clean shakers. Rig up Kelly. Wash down 2 singles. Rig down Kelly. RIH. Tag fill at 4,732'. Lay down 66 jts. Fluid 3 % Brine loss to well today 28 bbls - Total fluid 3% Brine loss to well 28 bbls - Sized Salt Pill loss to well today 0 bbls - Total SSP loss to well 0 bbls - Metal from Ditch Magnets today 0 lbs - Metal from Boot Baskets today - 44 lbs - Total metal recovered from well 44 lbs. HHilcorp Alaska, LLC �lil,.,,,,,Well Operations Summary Well Name JAPI Number JWell Permit Number I Start Date End Date A-30 50-733-20253-00 173-014 1 12/22/2013 1/2/2014 Daily Operations: 12/25/13 - Wednesday TIH from 2,693' to 4,710'. PU Kelly, Establish parameters: 10 BPM W/670 psi, Up Wt 135K, Dn Wt 90K, Rot Wt 110K, 80 RPM, 10K TQ. Mill on hard junk from 4,727' to 4,730'. Drilling break from 4,730' to 5,024'. Milled through old CMT Squeeze for bad casing @ 5,016' to 5,023'. Encountered lost circulation up to 100 BPH loss rate. Pump and spot 40 BBL Sized Salt Pill. Monitor well on trip tank while letting pill soak for 30 min. Continue Clean out operations from 5,024' to 5,136' (Top Of CMT Retainer) Check Losses before drilling out Retainer with 60 BPH while circulating 8 BPM. Pump and spot 40 BBL Sized Salt Pill. Monitor well on trip tank while letting pill soak. Static loss @ 12 BPH, Drill CMT Retainer @ 5,136' to 5,138'. 10K to 30K WOB. 80-100 RPM. Continue to Mill and chase Retainer with 15-28K WOB from 5,138' to 5,186'. WOB fell off to 5-10K. Continue to Mill and clean out from 5,186' to 5,500' not taking any weight. Blow down and set back Kelly. Losses @ 24 BPH while circulating @ 9 BPM @ 17:30. TIH on elevators from 5,471' to 5,975'. Beginning to see some obstruction. Rig up Kelly. Wash down with Kelly from 5,975' to 6,279' with little to no weight down. Kelly spinner having hard time making up connections in mouse hole. Connection leaking between Kelly hose and stand pipe. Blow down Kelly/replace seal. Install pump in sub and circulate hole while repairing Kelly hose. 7 bpm/500 psi/16 bph losses. RIH washing down from 6,279' - 6,640'. Tag fill w/10k down. Pick up off fill. Rotate Kelly at 50 rpm/13k torque/6 bpm/250 psi. RIH from 6640-6818 w/5 -10k down. 18 bph losses. Tagged up solid at 6,618'. Picked up 5'. Circulate bottoms up x 1.5. 9 bpm/590 psi. Reciprocate pipe while circulating. After 2 bottoms up, still a trace of sand in returns. Circulate another 1/2 bottoms up and check returns. Returns clean after 2 1/2 bottoms up. Shut down pump. Monitor well. Record static loss rate. Static Loss rate -12 bph. Clear floor, rack back Kelly. POOH. Fluid 3 % Brine loss to well today 407 bbls - Total fluid 3% Brine loss to well 435 bbls - Sized Salt Pill loss to well today 88 bbls - Total SSP loss to well 88 bbls - Metal from Ditch Magnets today 40 lbs - Metal from Boot Baskets today - 0 lbs - Total metal recovered from well 84 lbs. 12/26/13 - Thursday TOH from 6,818' to 5,808'. Up Wt 156K. Encounter tight spot at 5,808'. Attempt to work through tight spot with 25K over pulls with no success. Able to break free on the down stroke with 15-20K Dn Wt. Up lick jars 5 times with 70K over. Pulled free. Mouse hole single with Kelly. Work Kelly and wash and ream several times. Shut down Pump, pass by and pull through tight spot at 5,808' with 10K bobble on Wt Indicator both directions. Set Back Kelly. Continue TOH from 5,800' to BHA. Rack back drill collars, Lay down Mill and Boot Baskets. Recovered 43 lbs Metal from Boot baskets. Rig up a -Line. RIH with Logging tools on E -Line. Log hole from 6,800' to 1,246'. POOH. Rig down, Pick up drill collars, RTTS, jars and bumper sub. RIH. Set RTTS at 3,906' w/30k down. Test 9-5/8" to 1500 psi for 30 min. Pressure test charted. Unset RTTS. RIH. End of drill collars at 5,992'. RTTS at 5,707'. Circulate 1 hole volume (+/- 400 bbls) with fluid treated with bleach. Displace hole to clean fluid. 5 bpm/230 psi. Blow down lines. Monitor well. 12 BPH static losses. Shut down transferring fluid from OBM tank to production. POOH racking back 5" drill pipe. Hawk Jaw break out unit down. Fluid 3 % Brine loss to well today 251 bbls - Total fluid 3% Brine loss to well 686 bbls - Sized Salt Pill loss to well today 0 bbls - Total SSP loss to well 88 bbls - Metal from Ditch Magnets today 0 lbs -Total Magnet Metal 40 lbs Metal from Boot Baskets today - 43.5 lbs - Total metal recovered from well 167.5 lbs. 12/27/13 - Friday Continue to TOH with RTTS from 3,150' to 308' ( BHA ). Lay down Bumper sub and Oil Jars. Lay down Circulating Valve. TIH with RTTS on 9 DC's and set and release from RTTS @ 90'. Close Blind Rams and test top of RTTS to 1500 psi for 15 Min. Test good. N/D BOPE and set BOP Stack Aside. N/D and remove riser and old tubing spool from Wellhead Room. Install new Tubing Spool. Test Void to 250/2500 psi. Land Drilling Riser N/U BOP and associated Equipment. Complete tubing spool void test. 2150 psi f/5 min. 2500 psi f/15 min. Finish buttoning up riser/BOP. Close Blinds and test tubing head flanges to 1500 psi f/15 min. Test charted. Changes lower pipe rams from 2-3/8" to 2-7/8". TIH and retrieve RTTS. 19 bbls to fill hole. Lay down RTTS, stand back 3 stds DC's. Rig up and test BOPE to 250/2000 psi. Fluid 3 % Brine loss to well today 116 bbls - Total fluid 3% Brine loss to well 805 bbls - Sized Salt Pill loss to well today 0 bbls - Total SSP loss to well 88 bbls - Metal from Ditch Magnets today 0 lbs -Total Magnet Metal 40 lbs Metal from Boot Baskets today - 0 lbs - Total metal recovered from well 167.5 lbs. 12/28/13 - Saturday Continue to test BOPE to 250/2000 psi. Witness of test waived by Lou Grimaldi, AOPGCC. Upper Rams, CMV,s 1,3,5,7-16. CHCR, KHCR, Man KILL, Man CHOKE, TIW and Dart Valve. Perform Accumulator test. All tests good. Rig down and blow down test equipment. Monitored well on trip tank to annulus valve with 14 BPH loss rate. Reconfigure Annulus valve on tubing head for production tie in. Waiting on perf guns. 15 BPH losses. Fluid 3 % Brine loss to well today 357 bbls - Total fluid 3% Brine loss to well 1162 bbls - Sized Salt Pill loss to well today 0 bbls - Total SSP loss to well 88 bbls - Metal from Ditch Magnets today 0 lbs -Total Magnet Metal 40 lbs Metal from Boot Baskets today - 0 lbs - Total metal recovered from well 167.5 lbs. Shipped 149 bbls of fluid to Trading Bay Hilcorp Alaska, LLC t1ilvorpAlaska. LIJ Well Operations Summary Well Name JAPI Number 1well Permit Number IStart Date I End Date A-30 50-733-20253-00 173-014 1 12/22/2013 1/2/2014 Daily Operations: 12/29/13 -Sunday Off load guns and completion equipment from boat. Lay out Skids. Organize Top Deck. Make ready to P/U 4-5/8" 5 SPF Millennium guns. PJSM on Running Perf Guns. Run in hole picking up 4-5/8" 5 SPF Millennium Perf Guns. Pick up 2-7/8" jt/ported sub 2-7/8" joint/firing head. Install, RIH w/4- 5/8" TCP guns on 5" drill pipe. 40 stds + dbl + 5' pup joint. 140k up wt 85k do wt. Rig up wireline. RIH and Locate RA Marker @ 3,841' WLM. ( 4.00' deep )(Tie into GR/CCL Log dated 27 -DEC -2013) RA Marker @ 3,855' DPM( 14' difference from DP to WLM) POOH rig down E -Line. Confirm correlation with geologist. PU hole 4.00' to place guns on depth. RA marker @ 3,837' - Bottom Shot 6,543'. RU Bar Drop Sub. 12/30/13 - Monday Drop bar and fire guns. [Top shot at 3,934' & Bottom shot at 6,543'] Fluid level dropped. Fill hole. Took 26 bbls to get hole full. Circ gas out with a high of 400 units. Hole taking 60 BPH. Spot 40 bbl size salt pill, and monitor well. Hole taking 43.5 BPH static. Continue to monitor well. After 1-1/2 hr loss slowed to 12.5 BPH. Rig down and blow down lines. POH to 1 stand above guns. Monitor and let gas break out. Hold PJSM and MU safety jt. Lay do tbg spacer, circ sub, and firing head. Continue POH cleaning and laying do 4-5/8" perf guns. Laid down 15 perf guns. Hole taking 0 BPH. Well started having slight flow. Monitor well and it continued to flow. RIH 4 stands. Circ 3 full circ at 411'. monitor well. Started to flow again after about 10 min. RIH to where the circ port is at 3,915'. Well had oil coming to surface and gas breaking out all the way in the hole, but the displacement was correct. Circ @7 bpm/350 psi. 3170 (+/- 317 bbls) total strokes. Shut down pump. Monitor well. Gas still breaking out, 14 bph static losses. Circ bottoms up. Shut down pump. 2147 (+/- 215 bbls) strokes pumped. Monitor well. 15 bph losses, gas still breaking out although it appears to be substantially reduced. POOH. Guns at surface. 6 BPH static loss rate. Lay down guns. Clean rig floor and prepare to run completion. Fluid 3 % Brine loss to well today 269 bbls - Total fluid 3% Brine loss to well 1743 bbls - Sized Salt Pill loss to well today 45 bbls - Total SSP loss to well 133 bbls - Metal from Ditch Magnets today 0 lbs -Total Magnet Metal 40 lbs Metal from Boot Baskets today - 0 lbs - Total metal recovered from well 167.5 lbs. 12/31/13 -Tuesday Monitoring well with gas breaking out of straight crude oil on top. RIH 4 stds open ended to circ crude oil off top. Circ oil off. Monitor well while we continued cleaning. Gas and oil continue to break out with slight flow. RIH to 2,080' and rig up to circ. Circ crude oil cap off well. Still cleaning and skimming oil off pits. RIH to just above perfs at 3,880'. Circ hole clean while skimming pits and cleaning. Getting everything ready to run Tri -Point completion packer w/ plug in x -nipple below packer. Rack and strap 2-7/8" completion tbg. Shut down and monitor hole taking 12 BPH static. POH and break off bit sub and xo. MU and RIH with packer on DP and 15' DP pup. MU circulating equip - drop packer setting ball - press DP to 600 psi saw 1st shear - 1200 psi saw 2 nd shear - 3400 ( max pump press) saw no shear - PU and released from packer still no final shear - RU up test pump - pressure DP to 4900 psi saw final shear and pres drop. Circ / cond well to remove oil / gas ( 783 max units gas) - skimming and cleaning oil from pits - PT packer to 1500 psi / 5 mins - good no bleed off. RD circ equip. POOH stand back DP - LD packer running tool. Pull wear ring - RU tbg running equip, PJSM, MU indexing mule shoe -seal assy and RIH with 2 7/8" completion. Fluid 3 % Brine loss to well today 106 bbls - Total fluid 3% Brine loss to well 1849 bbis - Sized Salt Pill loss to well today 0 bbls - Total SSP loss to well 133 bbls - Metal from Ditch Magnets today 0 lbs -Total Magnet Metal 40 lbs Metal from Boot Baskets today - 0 lbs - Total metal recovered from well 167.5 lbs. 01/01/14 - Wednesday Run 2-7/8" gas lift completion to top of packer at 3,871'[ Running chemical injection line from mandrel and line from SSSV to surface]. Stab seals into top of packer at 9.80'. PU and space out picking up hanger. Make up control lines through hanger. Hold SSSV open. Drain stack. Land w/ 12k on hanger. Run in lock down screws. Test back side with tbg open to 1500 psi for 30 min. Good test. Bleed off ann. Lay down landing jt. Set BPV. Rig down equip. Nipple down BOPS. Pull riser -pitcher nipple -mouse hole. PU BOPs and trolley over to the side. Bring tree valves to floor and prep hanger for tree. NU tree - test hanger void 5000 psi- 15 min. NU tree. Break flanges. Rotate master / swab valves flow cross to align with flow line and riser. Cleaning pits. Pull BPV - set TWC. Fill tree - test tree flange breaks - 5M - 15 mins - OK. Pull TWC. Install tree cap. PJSM. Cleaning pits. Fluid 3 % Brine loss to well today 0 bbls - Total fluid 3% Brine loss to well 1849 bbls - Sized Salt Pill loss to well today 0 bbls - Total SSP loss to well 133 bbls - Metal from Ditch Magnets today 0 lbs -Total Magnet Metal 40 lbs Metal from Boot Baskets today - 0 lbs - Total metal recovered from well 168 lbs. Hilcorp Alaska, LLC HilrorpAlaska. LIJ Well Operations Summary Well Name API Number JWell Permit NumberStart Date End Date A-30 50-733-20253-00 173-014 1 12/22/2013 1/2/2014 Daily Operations: 01/02/14 - Thursday Rig up Slickline. Test lubricator to 2000 psi. Run #1 - Run in to pull prong from x -nipple at 3,892'. Looked like we latched onto prong but when we got out of the hole we didn't have it. Run #2 - Re -dress tool and run in to pull prong again. PCH with prong, lay do tools. Run #3 - Re -dress tool and run in to pull dummy valve from Chemical injection mandrel at 3,843'. POH and did not recover it. Run #4 - Re -dress tool and RIH again. Latch on and PCH with dummy valve. Run #5 - Re -dress tool and run in to pull the dummy valve out of the GLM at 3,795'. POH and did not recover the dummy valve. Run #6 - Re -dress tool and RIH again. Latch on to dummy valve and PCH. [Tbg press 250 psi]. Run #7 - Re -dress tool and RIH with live valve. Set valve in GLM at 3,795' and POH. [Pressure on tbg started climbing so we decided to set the lower live valves so we would be working in thick crude. [Tbg press 300 psi]. Run #8 - Re -dress tool and RIH with live valve. Set valve in Chemical Injection Mandrel at 3,843'. POH [ Tbg press 400 psi]. Run #9 - Re- dress tool and RIH to pull dummy valve out of GLM at 2,672'. Latch onto dummy and POH. Run #10 - Re -dress tool and RIH with live valve. Set valve in GLM at 2,672'. Run #11- Change to GS tool - RIH pull plug body from X -nip at 3,892'. RD slick line equip. Release rig at 00:00 1/3/14. Turn well A-30 over to production at 00:00 1/3/14. Total fluid 3% Brine loss to well 1849 bbls - Total SSP loss to well 133 bbls -Total Magnet Metal 40 lbs Metal - Total metal recovered from well 168 lbs. • • • 4, \�0 F�jj's THE STATE Alaska Oil and Gas TPP's s_ _ °fALASI�:A Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Oj n Anchorage, Alaska 99501-3572 ALAS* Main: 907.279.1433 Fax: 907.276.7542 J Ted Kramer t I+ Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 %MINED JAN 0 6 2014 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai D, Middle Kenai B Oil Pools, Trading Bay St A-30 Sundry Number: 313-636 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, Daniel T. Seamount, Jr. Commissioner DATED thisi 3 day of December, 2013. End. 1, ;‘4?' RECEIVED 3 STATE OF ALASKA \ti/,7 DEC 1 1 2013 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 El Suspend❑ Plug Perforations El Perforate 2, Pull Tubing El • Time Extension El Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Complete(g45 L.i-&) G 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development El . 173-014 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service Cl 6.API Number: Anchorage,AK 99503 50-733-20253-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 93B Trading Bay St A-30• Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 ' Trading Bay Field/Middle Kenai D,Middle Kenai B 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): 7,485 ' 5,933 4 6,820 5,316 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,246' 16" 1,246' 1,197' Intermediate 5,164' 13-3/8" 5,164' 3,821' Production 7,476' 9-5/8" 7,476' 5,925' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2"&3-3/8" 9.2#N-80&4.7#N-80 340'&4,595' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker"D"Pkr&SSSV:NA Pkr 4,551'(MD)3,302'(TVD)and SSSV:NA . 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch G Exploratory ❑ Stratigraphic❑ Development El v, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/16/2013 Oil GI Gas El WDSPL ❑ Suspended El 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 tkramerhilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature .0?,/,‘ Phone (907)777-8420 Date 12/10/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: •S\3 —C..SU- Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: Z.COO foss op t- ,/ Spacing Exception Required? Yes ❑ No r.� /Subsequent Form Required: 0 P APPROVED BY / �/ Approved by: COMMISSIONER THE COMMISSION Date: 1 2 J lot,0 PAL ixf alzo;6 ,,f 1 Submit Form and Form 10-403(Re ised 10/2012) Approve p c R ti n v li N 2/,,,� hs from the date of approval. � �Dupj tr !I.M L Qit 1 3 2 6 is • • Well Prognosis Well: A-30 Hilcoru Alaska,LL. Date: 12/10/2013 Well Name: Monopod A-30 API Number: 50-733-20253-00 Current Status: SI Oil producer(Gas Lifted) Leg: N/A Estimated Start Date: December 16, 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: 173-014 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: 1,217 psi @ 4,843' (3,531'ND) From 11/13/93 shut in survey Maximum Expected BHP: 2,020 psi @ 6,540' MD (5,076' ND) Max.Anticipated Surface Pressure: -32 psi (Based on A-32 BHP during that C-zone completion) Brief Well Summary The A-30 well was drilled and completed as a D zone oil well in 1973. In 1981 the well was recompleted and cmt retainers were set at 5,120'and 6,820'with the perforations below squeezed with 300 and 400 sxs.of class G cement respectively. The 33-6 and the 31-8 sands were then completed and frac packed. The A-30 well produced until September 1996 when it was shut in for lack of sufficient amount of gas lift gas. The current re-completion plan involves removing the current gas lift completion and the cement retainer at 5,120'. The well will then be cleaned out to the cement retainer at 6,820'. The well will then be perforated as a B and C zone producer and placed back on gas lift. Brief Procedure: 1. MIRU Monopod Platform Rig#56. 2. RU E-line,RIH and punch tubing at 4,545(+/-). 3. Circulate Hydrocarbon off of well. fl P T 4. ND Wellhead, NU BOP and test to 250 psi low/2,000 high.(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 5. PU tubing string and pull seal assembly out of Baker Model D pkr at 4,551'. 6. POOH laying down 3-1/2"X 2-3/8" production Tubing. 7. PU Pkr.Shoe on Work string. RIH and tag packer at 4,551'. Burn over packer until free. POOH. 8. PU Spear assembly and RIH to Spear and retrieve packer. POOH W/Same. 9. PU 9-5/8"casing C/O assembly. RIH cleaning out fill to cmt retainer @ 5,120'. 10. Drill up Cmt Retainer at 5,120'and C/O squeeze cmt and fill down to cmt retainer at 6,820'. (Note: Record indicates a Junk BP AT 6820'. Not imperative that we remove,bottom perf is at 6,540'). 11. Circulate Hole Clean. Monitor well, POOH W/work string. 12. RU E-line. RIH with GR,CCL Logging tool to 6,820'. Log well from 6,820 up to 1,246'. RD E-line. • • Well Prognosis Well: A-30 Hiicor)Alaska,LL Date:12/10/2013 13. PU RTTS Test Packer. RIH to 3,900'. Set and pressure test the back side to 1,500 psi.for 30 min. Chart same. (Note: If tubing spool needs changed,go to step 14. Otherwise go to Step 15.) 14. RIH with Storm packer to 300'and set. ND BOP stack and change out tubing head. ® � 15. PU RIH W/TCP perforating Guns as conf iited t�e Fina(k proved Perforation Request Form. 16. RU E-line. Use e-line to place Perf guns on depth and perforate well. -914y17. Pick up TCP guns above perforations, monitor well for one hour by shooting fluid levels allowing 'Sap`o s the well to stabilize. POOH with TCP guns. it ,p de 18. RU E-line. PU e-line set completion packer. RIH and set at 3,891'(+/-). 19. PU seal assembly,GLMs,SSSV,on 2-7/8"production tubing string. RIH and stab into permanent � i-te production packer. /6-66 b ( 20. Perform packer pressure test on back side to 1 psi on the production tubing X 9-5/8"casing. Chart for minutes. 21. Hang off well. 30 Nww 22. ND BOP, NU wellhead and test. 23. RU Slickline. Pull Dummy valves and install GLV's. 24. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing • • • Trading Bay Unit Well#A-30 Completed 8/2/81 CASING AND TUBING DETAIL SIZE WT Grade Conn. ID Top Btm. RKB to TBG Hngr=33.8' 16" 65 H-40 Butt.LT&C Surf 1246' Tree connection:3" 5,000# 13-3/8" 61.0 K-55 Butt.LT&C 12.515 Surf 3732' 13-3/8" 68.0 K-55 Butt.LT&C 12.415 3738 5164' 1 9-5/8" 47.0 N-80 Butt 8.681 Surf 5076 9-5/8" 47.0 N-80 Butt 8.681 5076 7476' t 2 3 Tubing: 3-1/2" 9.2 N-80 Butt 2.992 Surf 340' 2-3/8" 4.7 N-80 Butt 2.441 341' 4596' lb 4 JEWELRY DETAIL NO. Depth ID Item 33.8 CIW 11"X 3-1/2"EUE 8rd Tbg.Hanger. NMI 5 1 307' Otis 3-1/2""XL"Ball Landing Nipple 6 2 340' 1.995 Crossover,3-1/2"X 2-3/8" 7 Z S;z %j";',/, %i%% 4550' 3 2094' GLM#1 2-3/8"Camco GLM /ii,,,. �� 4 3757' GLM#2 2-3/8"Camco GLM 8 J 5 4513' GLM#3 2-3/8"Camco GLM 4549' 1.995 Crossover,2-3/8"X 2-7/8" 6 4550' Locator Seal Assy.w/10.58'of seals. 7 4551' Baker Model"D"Retainer Production Pkr. N' 31-8 8 4595' WLEG btm 4596' -33-6 FISH: Junked BP 7/24/81 @ 6820' 40-4 STIMULATIONS Bad Csg f/5016'to 5023'. 1-Cod/61 sqz hole w/250 50 7111 Frac-Packed 7/30/81 31-8,33-6,40-4,41-8 41-8 FILL ' U/ '% 5076' Tagged w/scratcher 5/23/87 @ 5097'WLM //,. %i,. °,,, , -,/1"%/�/� �' BP 5120' Tagged w/scratcher 2/5/90 @ 5095'WLM 5164' Tagged w/scratcher 11/27/90 @ 5074'WLM Tagged w/scratcher 2/15/92 @ 5064'WLM 44-7 Bailed to 4669' 8/9/95 @ 4669'WLM Top Btm Top Btm Accum Last Perf Zone (MD) (MD) (TVD) (ND) Amt SPF Date Persent Condition B 28-6 4,174' 4,184' 3,028' 3,033' 10' 8 6/6/1973 Cmt sqz'd w/1,000 sx Tested to 1200 psi. B 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 Cmt sqz'd w/250 sx Tested to 4500 psi Dim B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. Cmt Ret. .,,,,,.. 6820' B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8&4 2/7/1990 Open f/Production. B 31-8 4,692' 4,742' 3,414' 3,455' 50' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to surface ///%'" a/// on 6/28/73. /;%/// ,- Y.,S///i'17 Isolated w/9-5/8"Tie-back liner to surface ( 0 -53-7 B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 on 6/28/73. 53-8 B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12&8 2/6/1990 Open f/Production. 54-5 B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. ® = B 40-4 4,872' 4,908' 3,565' 3,596' 36' 8&4 2/5/1990 Open f/Production. S„ /'% ,Z Isolated w/9-5/8"Tie-back liner to surface // /// %//;ij/j/ ,,, B 41-8 4,986' 5,040' 3,664' 3,711' S4' 2 6/21/1973 on 6/28/73.• 56-1 8 41-8 4,980' 5,060' 3,659' 3,729' 80' 8&4 2/5/1990 Open f/Production. - 56-1 B 41-8 5,148' 5,150' 3,807' 3,809' 2' 4 7/21/1981 Cmt sqz'd w/300 sx = 57-2 B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. 57-2 D 53-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 - 57-2 D 53-8 6,941' 6,956' 5,437' 5,451' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 54-5 7,000' 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 KB ELEV=101' D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 TD=7485' D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 PBTD=' D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 ANGLE thru INTERVAL=37° D 57-2 7,336' 7,348' 5,798' 5,809' 12' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 57-2 7,358' 7,366' 5,818' 5,825' _ 8' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 REVISED: 12/10/2013 DRAWN BY: SLT 14 • • Trading Bay Unit PROPOSED Well #A-30 Completed: Future Hilcorp Alaska,LLC CASING AND TUBING DETAIL SIZE WT Grade Conn. ID Top Btm. RKB to TBG Hngr=33.8' 16" 65 H-40 Butt.LT&C Surf 1246' Tree connection:3" 5,000# 13-3/8" 61.0 K-55 Butt.LT&C 12.515 Surf 3732' 13-3/8" 68.0 K-55 Butt.LT&C 12.415 3738 5164' 1 9-5/8" 47.0 N-80 Butt 8.681 Surf 5076 2 9-5/8" 47.0 N-80 Butt 8.681 5076 7476' s Tubing: 2-7/8" 6.5# L-80 8rd EUE 2.441 Surf ±3912' 4 F. 5 g. JEWELRY DETAIL 6 7 NO. Depth ID Item 33.8 Tbg.Hanger 1 ±300' SSSV 2 ±1500' GLM#1 3 ±2800' GLM#2 CP 4 ±3700' GLM#3 5 ±3891' Packer ill 6 ±3901 X Nipple 7 ±3912' WLEG B Zone mak Top Btm Top Btm Accum Last Perf Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Persent Condition B 26-7 ±3,941 ±3,958 ±2,885 ±2,895 17 Future Bad CSg(/5016'to 5023'. B 26-7L ±3,988 ±4,030 ±2,913 ±2,939 42 Future irlCmt sqz hole WI 250= Cmt sqz'd w/1,000 sx Tested to 1200 7/21/131 B 28-6 4,174' 4,184' 3,028' 3,033' 10' 8 6/6/1973 psi. 8 28-6 4,640' 4,642' 3,372' 3,374' 2' 4 7/21/1981 Cmt sqz'd w/250 sx Tested to 4500 psi I" _III- 5076 5164' B 31-8 ±4,644 ±4,756 ±3,375 ±3,467 112 Future Re-pert B 31-8 4,648' 4,684' 3,378' 3,407' 36' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. B 31-8 4,643' 4,755' 3,374' 3,466' 112' 8&4 2/7/1990 Open f/Production. 8 31-8 4,692' 4,742' 3,414' 3,455' 50' 10 6/13/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. B 33-6 4,794' 4,840' 3,499' 3,538' 46' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to B 33-6 4,790' 4,850' 3,495' 3,546' 60' 12&8 2/6/1990 Open f/Production. CZone B33-6 ±4,792 ±4,850 ±3,497 ±3,546 58 Future Re-perf B 40-4 ±4,874 ±4,896 ±3,567 ±3,586 22 Future surface on 6/28/73. Re-pert B 40-4 4,878' 4,898' 3,570' 3,587' 20' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to surface on 6/28/73. 8 40-4 4,872' 4,908' 3,565' 3,596' 36' 8&4 2/5/1990 Open f/Production. Cmt Ret. @ 6820 B 41-8 ±4,980 ±5,040 ±3,659 ±3,711 60 Future Re-pert • ■ ■ 41-8 4,986' 5,040' 3,664' 3,711' 54' 2 6/21/1973 Isolated w/9-5/8"Tie-back liner to �- B surface on 6/28/73. `M __ B 41-8 4,980' 5,060' 3,659' 3,729' 80' 8&4 2/5/1990 Open f/Production. B 41-8 5,148' 5,150' 3,807' 3,809' 2' 50 4 7/21/1981 Cmt sqz'd w/300 sx B 44-7 ±5,278 ±5,328 ±3,923 ±3,967 Future Re-pert B 44-7 5,328' 5,330' 3,967' 3,969' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. w...= _ B 44-7 5,336' 5,338' 3,974' 3,976' 2' 8 6/12/1973 Cmt sqz'd w/100 sx.Tested to 1200 psi. C 5 ±5,708 ±5,770 ±4,307 ±4,364 62 Future D Zone C 7 ±5,918 ±6,048 ±4,500 ±4,620 130 Future 1 = C ZN1 ±6,145 ±6,160 ±4,710 ±4,724 15 Future_ C 47-5 ±6,166 ±6,232 ±4,729 ±4,790 66 Future C 48-7 ±6,312 ±6,324 ±4,863 ±4,874 12 Future C 50-3 ±6,512 ±6,540 ±5,046 ±5,071 28 Future D 53-7 6,914' 6,919' 5,412' 5,417' 5' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 53-8 6,941' 6,956' 5,437' 5,451' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 D 54-5 7,000' 7,015' 5,491' 5,504' 15' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 KB ELEV=101' D 54-9 7,040' 7,070' 5,527' 5,555' 30' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 TD=7485' D 56-1 7,188' 7,208' 5,663' 5,681' 20' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 PBTD=' D 56-1 7,224' 7,244' 5,695' 5,714' 20' 4 6/30/1973 Cmt Sqi d w/400 sx on 7/20/81 ANGLE thru INTERVAL=37° D 57-2 7,282' 7,292' 5,748' 5,758' 10' 4 6/30/1973 Cmt Sqz'd w/400 sx on 7/20/81 Updated by: JLL 12/10/13 • • Monopod Platform ,... , ll A-30 Current 12/10/2013 Uihnrp %Li$ i.1.11. Monopod Platform Tubing hanger,CIW-DCB- A-30 FBB,11X3%EUE8rdlift 20 X 16 X 13 3/8 X 9 5/8 X and susp,w/3"Type H 3 Y and 2 3/8 BPV profile,1/8 non continous control line port, 6 Y.neck,Alloy material BHTA,Bowen,3 1/8 5M X 2%Bowen Union IIII Ii • ■ Tree,Block,CIW-F,11 5M O` FE X 3 1/8 5M,single master,swab,and wing, • �• 6 Y.pocket prepped for --.•O• I� control line exit,EE trim : It /\�- [�I Tubing head,CIW-DCB, 13 5/8 3M X 11 5M, _ 1 ,°. w/2-2 1/16 5M SSO, ,•III I.1 D L L X bottom prep - i/'� _tiimmi- `%,,, i i Casing spool,OCT-29L, ,• (p ` - ow 21 Y.2MX135/83M,w/ 2-2 1/16 SM SSO, 9 � IIIIIti: 13 3/8-00 bottom ' - I1r '11 Q 1u1 1/1 Starting head,OCT Type II, : NOM 21%2M X 20"SOW, 111 `l Iii ill w/4-2 1/16 2M SSO — 16"casing hung off on mandrel 13 3/8"casing on C-29 slips I II 6 ill 1' 11(......0,_ fil .,-0---."-Ii , i , IIP1 $i%i, �i SDI-'., i I 20" 16" 13 3/8" - r 9 5/8" 13'/and 23/8 • Monopod Platform • . 11 A-30 Proposed 12/10/2013 nikiwp al:rrku.1.1.4, Monopod Platform Tubing hanger,SME-CL,11 X A-30 3'A EUE lift and cusp,w/3" 20 X 16 X 13 3/8 X 9 5/8 X Type H BPV profile,3-3/8 2 7/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union 11 . i . milo Valve,Swab,WKM-M, 3 1/8 5M FE,HWO,DD trim �� Valve,Wing,WKM-M, I 31/85MFE,w/15"OMNI „ „ operator,DD trim 11 . © ilMit Valve,Master,WKM-M, „ " 3 1/8 5M FE,HWO,DD trim O ®® u.MO... Contrr.1, 1 — Ln '161.171131-�_ ,.wli�= �kaJ 1416/4)0 Tubing head,5-8,13 5/8 3M x }r-(/ 11 5M,w/2-2 1/16 SM SSO, Ill MI �. T wl' w/BG bottom ' A, w/1-21/165MWKM-PA - —MI�,l® . iIIIIII®I_) valves 11111A11t /SQL /0s /SLt./+ . 1�1 1i1 Casing spool,OCT-291,21Y. "-' In 1:1 "_ �� to 611,4.,104. 1 2M X 13 5/8 3M,w/2- 1N1 `I + let 2 1/16 5M 550, _ —13 3/8-00 bottom is � - C-22slips installed 11 I.� t IlIll _i.., ICI ICI Starting head,OCT Type II, ' .011111— 21''A 2M X 20"SOW, .� ine, w/4-2 1/16 2M SSO MI `l 1+ IN 16"casing hung off on mandrel _ —• 13 3/8"casing on C-29 slips �� II E. ,��I 1����f � i�'��0 i Ai - 16" 13 3/8" _9 5/8" 2 7/8" • • _ Monopod Platform 2013 BOP Stack 03/12/2013 IbL'trrh thiskii.Ii.(. Rig Floor Bottom of air boot flange A 5'below rig floor 16" 14.72' 9.50' Pipe ill I►I III III III O • III I11 lil 111 III III 111 111 3.74' Shaffer 135/85M l III III Ili Ill 111 26.25' Shaffer LXT 2 7/8-5 Variables 2.50' __ 135/85M _ Blind _I11.141'1 _ rr►� .ei1r,1111111111111 . 1.76 i!.l l 0 I 1. . I mo^. D I II Mud Cross e�„/I i lii.Ill i I I ` 135/85MFEXFE 11E- w/31/85M EFO w/2 1/16 5M Choke and Kill valves w/Unibolt end connections for lines if tll I11 II! i1l 2 83' Dual Cameron Flex rams lil,Iii III lit it Am .70' III I!i III III III V Drill deck 14.20" UOCD 1911 Riser 14.20' 13 5/8 5M F E 8 13 5/8 5M FE i lil tits iii lit ,ii l l_I-Ill lit lit iiI Spacer spool 1.5' 135/85M FEX113M I11 li! III II. Ili Wellhead @ 15.00' ExxonMobil Production Company Karen Hagedorn Joint Interest, U.S. Alaska Production Manager P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 5615331 Telephone E-zzonMobil Production October 29, 2013 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 RECEIVED Re: Echooka Unit #1 (PTD 172-010) and Canning River Unit A-1 (PTD 173-014) Dear Commissioner Foerster: NOV 0 4 2013 .AOGCO We have received the Commission's letters dated October 3, 2013, regarding the referenced wells which were drilled and subsequently plugged and abandoned in the early 1970's. Regulatory compliance is a core value for ExxonMobil. Our prior track record of voluntarily conducting remedial work on Alaska wells and associated locations and the current remediation work under way on the North Slope is evidence of our commitment. We have begun an immediate review of the available information related to the status of these wells. It would be helpful to our review if the Commission would advise of its specific concerns with the current status of these wells and the manner in which the Commission believes they are not in compliance. We would be happy to meet with the Commission to discuss your concerns and our ongoing remediation work at your convenience. A full response will be provided to the Commission within 90 days of our receipt of your letter (January 7, 2014), as requested. Please contact me if you have any questions. Thank you for bringing this matter to our attention. Sinc rely, 7 JBG/KDH:dgo cc: Leslie Holland -Bartels, USGS \ -t '-s C-) � -(- o Dale A. Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 Operations Anchorage, AK 99503 Tel 907 263 7951 sem'" Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 AUG, 0 h 2009 Cathy Foerster Commissioner A';Iskp< Phil &, 00s Cors, ClOrnrrligsi«n Alaska Oil & Gas Conservation Commission�a;@��aya, 333 W. 7th Avenue Anchorage, Alaska 99501 SCAPM OCT 0 $ 014 Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, I� Ctkl Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 1642 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platforin life GP 31-14RD42 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of latform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore infection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platforrn life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 i parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 32B-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -Ono known damage no flow Possible shallow gas or gas storage 2011-2014 Mono od A-10 1670760 Apr -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Mono od A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life �-J -Zz� ^ o \ 4-� f� E"�� ` f�� SARAH PALIN, GOVERNOR AYA SKA ®IL AND GALS � 333 W 7th AVENUE, SUITE 100 CO SERVAM�C®M�`1�SSIO,1� f ANCHORAGE, ALASKA 99501-3539 V 4i % PHONE (907) 279-1433 FAX (907) 276.7542 June 22, 2009 Dale Haines UNOCAL SCA00K 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(a�alaska.f�ov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD _ Union Oil Company of California 179-033 _ Granite Pt St 18742 14 Union Oil Company of California 167-077 _ Granite Pt St 18742 16 Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD _ Union Oil Company of California 169-004 _ Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 _ Trading Bay Unit D40RD _ Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 _ Trading Bay Unit G-24 _ Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD Union Oil Company of California 168-038 _ Trading Bay Unit K-06RD Union Oil Company of California 169-066 _ Trading Bay Unit K-09 Union Oil Company of California 179-016 Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 Trading Bay Unit K-23 _ Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 _ Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL March 4, 1996 Alaska Mr. David Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Commissioner Johnston: Re: Monopod Platform Well A-30 APl Number 50-733-20253-00 On February 5, 1990, the following intervals were perforated in Well A-30: TOP (MD) BOTTOM (MD) FEET 4643 4755 80 4790 4850 36 4872 4908 60 4980 5060 112 Total 288 Very truly yours, {3. Russell $chmidt Drilling Manager Attachment STATE OF ALASKA ~ ALASKA OiL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown Stimulate Plugging ...- Pull tubing After casing Repair well 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 Location of well at surface Leg 4, Cond..18 1612' N & 551'W of SE Cor., Sec. 4, T9N, R13W, S.M. At top of productive interval 126' N, 3646' W of SE Cor., Sec. 4, T9N, R13 W, S.M. At effective depth At total depth 309' N, 3791' W of SE corn.~ Sec. 4, T9N, R13W, S.M. 12. Present well condition summary Total depth: measured 7485 true vertical 5922 5. Type of Well: Development __~ Exploratory __ Stratigraphic __ Service Perforate X Pull tubin~ Other 6. Datum elevation (DF or KB) RT 101 7. Unit or Property name Trading Bay Field 8. Well number A-30 9. Permit number 73-14/90-12 10. APl number 5O-733-20253 11. Field/Pool Trading Bay Field~ "B" Zone Plugs (measured) Effective depth: measured 6820 feet Junk (measured) true vertical 5316 feet ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1246' 16" 1246' 1185' Intermediate 5164' 13-3/8" 5164' 3814' Production 7476' 9-5/8" 3150 SX 7476' 5913' Liner Perforation depth: measured 4643'-4755'; 4790'-4850'; 4872'-4908'; 4980'-5060' true vertical 3375'-3466'; 3495'-3546'; 3565'-3595'; 3658'-3729' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-112" @ 340' 3-3/8" @ 4595' Baker "D" @ 4551' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Prior to well operation 40 3 0 --- Subsequent to operation 139 ~' 220 0 --- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the for{~:Ti~, is~r~e(,l{~;I ~l,~best of mY knowledge. ISigned G. Russell Schmidt./~',~--4~t'3~-7,-v~.,/~--w~~le Drilling Manager Form 10-404 Rev 06/15/88 ~ Tubing Pressure .._ 65 Service SUBMIT IN DUPLICATE Unocal North Americap'-'~ Oil & Gas Division ' Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 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, Regional Drilling Manager GSB/lew CONDUCTOR 1 2 3 4 5 6 7 8 9· l0 ll 12 13 14 15 16 17 18 19 2~ 21 22 24 25 26 27 28 29 30 31 32 MONOPOD CENTER FROM SOUTHEAST CORNER, SECTION 4, TgN, 'R13W "Y" : 2,523,126 LAT. = 60053, 48.65 "X" : 218,871 LONG. : 1 51 ° 34' . "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 2,523,1.13.2 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 ....2,523~.2_.z~. _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 '" X" COORD. 218,880.9 218,883.2 218,883.9 218,883.2 218,881.3 218,876.8 218,873.0 218,869.0 218,864.6 218,861.1 218,858.8 218,858.1 218,858.8 218,860.7 218,865.2 218,869.0 218,873.0 218,877.4 218,875.7 218,878.6 218,870.8 218,873.9 .~. ?.1 R. ,q7tq . 9 218,867.0 218,878.1 218,863.9 .218,875.0 218,865.1 218,868.1 218,871.1 218,863.4 2.18,866.3 WELL # FSL FEL .. A-28 1621 554 A-25 1617 551 A-30 1612 551 1608 551 A-27 1605 '553 , A-23 .1601 557 A-21 and RD 1600 561 A-22 1600 565 A-14 1601 570 A-13 1604 573 A-17 1608 576 A-8 1612 577 A-15 1616 577 A-24 and RD 1620 574 A-29 1624 570 A-9 and RD 1625 566 A-19 1625 562 A-18 1624 558 A-11 1619 559 A-3 1616 556 A-1 1618 564 A-7 1615 561 A-4 1611 558 A-6 1600 ' "568 A-32 1607 556 A-12 and RD 1617 571 A-20 1604 559 A-2 1613 570. A-16 1610 566 A-26 1606 563 , A-10 1609 571 A-5 and RD 1605 568 l&2 STATE OF ALASKA n ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension ~ Stimulate __ Change approved program ~ Pull tubing ~ Variance __ Perforate ._X_.x Other Gl 2. Name of Operator UNOCAL 3. Address P.O. BOX 190247, Anchorage, AK. 99519 4. Location of well at surface 1612'N & 55I' W of SE COR., SEC. At top of productive interval 126' N, 3646'W of SE COR., SEC. At effective depth At total depth ' 309'N, 3791'W of SE COR., SEC.4, 5. Type of Well: Development Exploratory Stratigraphic Service 4, T9N, R13W, S.M. 4, T9N, R13 W, S.M. T9N, R13W, S.M. 6. Datum elevation (DF or KB) RT 101 feet 7. Unit or Property name TRADING BAY STATE 8. Well number A-30 9. Permit number 73-14 10. APl number 50-- 733-20253 11. Field/Pool ' TRADING BAY FIELD, "B" ZOhE 12. Present well condition summary Total depth: measured 7485" true vertical 5 9 2 2 ' Effective depth: measured 6820' true vertical 5316 ' Casing Length Structural Conductor Surface 1246 ' Intermediate 5164 ' Production 7 4 7 6 ' Liner Perforation depth: feet feet feet feet Plugs (measured) Junk (measured) Size Cemented 16" 13-3/8" 9-5/8" 3150SX 6820' RECEIVE , !JAN 0 8 Measured depth ; ~'~L~'~e~ical depth 1246' 1185' 5164' 3814' 7476' 5913' measured5003'-5018', 4886'-4896', 4818'-4838', 4688'-4708', 4668'-4678', true vertical 3671'-3684' 3568'-3577' 3509'-3527' 3400'-3417' 3384'-3392' , , , ' Tubing (size. grade, and measured depth) 3-1 / 2" @ 340 ' 2-3/8" @ 4595' Packer. s and SSSV (type and measured depth) BAKER "D" @ 4551' 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation 1-15-~0 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~-¢~~)J~.~__...~ Title Environmeni;a~ Aha '-" ,) FOR COMMISSION USE ONLY Conditions of approVal: Notify'Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10-. Approved by order of the Commission 1 y s t Date I Approva, NO.~ k_proved OOP~ ORIGINAL SIGNED BY LONNIE C. SMITH ~ommissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE A-30 Perforating_ .l~ocedure: 1. RU wireline unit 2. Pressure test lubricator and BOP 3. RIH 4. Tie-in 5. Perforate followin9 intervals: 5277'-5325' 4980'-5060' 4872'-4908' 4790'-4850' 4643'-4755' 6. PC)OH 7. Ri9 down Note' SBHP 1050 psi - ~---~ STATE Or: ALASKA ~.~ ALASKA ~ ~- AND GAS CONSERVATION C(L MISSION . MONTHLY REPORT OF DRILLING AND WO____R 0V ROPERATIONS u 1. Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK' 99502 so-733-20253 9. Unit or Lease Name TRADING BAY STATE '4. Location of Well atsurfaceCond. #3 1612'N & 551 ' W of the SE corner, Section 4, T4N, RI3W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 101' RT above MSL ADL 18731 10. Well No. TBS A-30 11. Field and Pool TRADING BAY FIELD "B" ZONE For the Month of JULY ,19 81 12. Depth at end of month, footage drilled, fishing Jobs, directional drilling problems, spud date, remarks 7485' TD Commenced Operations 00'91 hrs 7/15/81. Engauged fish @ 6861' & released. Engauged fish @ 6853' & rec 3' of 3 1/2" tbg. Frac packed & recompleted in "B" zone. Released rig 12'00 hrs 8/2/81. 13. Casing or liner run and quantities of cement, results of pressur9 tests 9 5/8" C. 7476' Tested 'casing to 2500 psi, squeezed hole 501'6-5023' - ok. 14. Coring resume and brief description None 15. Logs run and depth where run GR/CCL f/ 5045' WLTD to 3000' & 2100-5120'. I 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED Perfed f/ 5148'-5150' 4640' -4642' 5003' -5018' 4818' -4838' 4688' 4708' 4668' -4678' 4886'-4896' AUG 2 4 198i Alaska Oil & Gas Cons. Commission A~chorage 17. I hereby/~ify that the foregoing is true and correct to the best of my knowledge. 'S~GNED _..! ...... :-___ E DIST DRLG SUPT DATE 8/18/81 NOTE-~port on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and~3as Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Subm;t in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator UNION 0IL CONPANY OF CALIFORNIA 3. Address P. O. BOX 6247, ANCHORAGE, AK. 4. Location of Well CONDUCTOR #3- 99502 1612'N & 551'W of the SE corner, Sec 4, T4N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) l Ol' RT above MSi 12. 6. Lease Designation and Serial No. ADL 1 g731 7. Permit No. 8. APl Number 50-733-20253 9. Unit or Lease Name Trading Bay State 10. Well Number TBS A-30 11. Field and Pool Trading Bay Field "B" zone. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing ED Perforations Stimulate [] Abandon '~ Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other ,,'~"'i, Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit 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). Pulled tubing on TBS A-30, Monopod Platform, abandoned the "D" zone, frack packed and recompleted in the "B" zone. The following work was performed' PROCEDURE' '-. . 2. 3. 4. Se e 7. 8. 9. Moved rig #56 over. Conductor #3, TBS A-30 and rigged up. Killed well, installed BPV, removed tree, installed and tested BOPE. Pulled and layed down existing 3 1/2" completion assembly. Abandoned "D" zone perf's @ intervals f/ 6914' to 7366' thru 9 5/8", cmt ret was set @ +6820' with 400 sxs cmt. Sqz'd for zone isol-ation @ 5148' 5150' 4640'-4642' 5035'-5040' 5148'-5150', 4640':.4642' , 4818'-4838' FraC packed 4 "B" zone sands @ 4688'-~728' & 4668'-4678' Completed well w/ single 2 3/8" completion assembly. Removed BOPE, installed and tested tree. Returned well to production. RECEIVED AUG 1 4 ]981 Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . . Title DIST: DRLG_ SUPT. The space below for Commission use Date B/12/8! Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Submit "Intentions" in Triplicate ..... ~n4 "q~ihe~n~l~nt I~nnrtc~ in J-~llnJJe;~t~ STATE OF ALASKA ALASKA ..IL AND GAS CONSERVATION CO~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL D(1 OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK. 99502 so- 733-20253 ....... 4. Location of Well CONDUCTOR #3' 1612'N & 551'W of the SE corner, Sec. 4, T4N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 12. I 6 . Lease Designation and Serial No. ADL 18731 9. Unit or Lease Name TRADTNG BAY STATE 10. Well Number TBS A-30 1 1, Field and Pool .TRADING BAY FIELD "B" ZONE 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 X~X Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing X~ Other X~ 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). In order to pull tubing, abandon the "D" zone, frac pack and recomplete in the "B" zone, it will be necessary to perform the following work on TBS A-30, Monopod Platform' PROCEDURE' · 2. 3. 4. Se 6. 7. 8. 9. Move rig #56 over Conductor #3, TBS A-30 and rig up. Kill well, install BPV, remove tree, install and test BOPE. Pull and lay down existing 3 1/2" completion assembly. Abandon "D" zone perfed @ intervals f/ 6914' to 7366' cmt ret set @ +6850' with 300 sxs cmt. Run Schlumberger FDC-CNL-GR w/ CCL log. Frac pack 5 "B" zone sands as justified by logs. Complete well w/ single 2 7/8" completion assembly. Remove BOPE, install and test tree. Return well to production. thru 9 5/8", RECEIVED JUN 1 9 1981 Subsequent Work Reportec~ ',.,~-k~ nil & Gas C,:ms. C0nlmissi011 on Form No.//9-.~/t~_~l ' Dated o~~_~/~ Anchorage .... 14. I her g is true and correct to the best of my knowledge. Signed//~ /~_. /~~/~,~~--~__~' Title DIST ~)R,.~ ~']PT: Date 6/19/81 The s~ below for Commission use C°Wditions of Approval, if any: By Order of ApProved by COMMISSIONER the Commission Date Approved Copy .,Returned Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION ~/ Lonnie C. Smith ~ Commissioner July 24, 1979 Blair E. Wondzell Petroleum Engineer H S Gas, Union_~s_~,~oPOd w lls A-25 Trading Bay Field, Middle Kenai C and D Pools. As a result of Harold's information and our discussion on July 23, 1979 I called Bill Brower, Monopod platform supervisor for Union at 279-9022. I asked about H~S from well %30. Mr. Brower' told me that the welI had produced some 'HgS in the past, -the well was nora shut-in, and that it probably w~uld produce H~S if .placed on production. However, no H2S has been observed when bleeding off small amounts.' Well %A-25 made some HAS after an acid job, but it cleaned up and is no longer makin~ H2S. Mr. Brower said they had portable .H_S detectors. They currently have-an AFE for permanentZVisua!/audio detectors (H2S)- Mr. Brower called back just before lunch with the following information. The record shows that in January, 1976 A-25 short and A-30 made some H2S. On December 6, 1977 Well #A-30 made 400 ppm H2S while producing. On December 7, 1977 Well %A-30 was shut-in. After shut-in samples showed up to 3000 ppm H2S. In December, 1976 H_S (at 250-400 ppm) detected in Well A-25. Sinc~ August 28, 1978, no H2S has been detected' in Well ~A-25. No acid jobs done in January, 1976, but that's about when injection water break through occurred. On our inspectors next trip to the Monopod (retest of the failed SSSV's) the valve in A-30 will be tested. -2- July 24, 1979 Union' s Monopod Wells A-25 and A-30 I asked about H~S in other Cook Inlet wells. Mr. Brower said .that he had no' ~nformation except on Monopod wells. i b. TYPE OF COMPLETION: W E L L OX' ~, R £ X B.aCK n£sv a. Other 2. NAI~IE OF OPERATOR UNION 0IL C~IPANY.,0F ~!FORNI^ 3. ADDRESS OF oPERATOR ~09 West 9th__^venue~ Anchorage~ ^laska 99501 4. LOC,~rrON OF W~LL (Report location clearly ancl in accordance with any State requirements)* At surface Conductor 3' 1612'N ~ 551'W of the S. E. corner. 126'N~ 5646'W At total depth WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OIL ~ 6A8~ [~ WELL ~ WELL DRY ~ Other * '~ SUBMIT IN DL !CATE* STATE OF ALASKA ~ (See other m-I structions on [' OIL AND GAS CONSERVATION COMMITTEE .... ,.~e .~iae; ! ~' Am ~mvmmciL CODE I s0~-20~s~,, 18. ~E~D~GNA~ON ~D SER~h NO. .! ~. I~ INDI~, ~O~ O~ T~IB~ N~ 8. UNIT,FARNI OR LEASE NAME Trading Bay State g. WELL NO. A-30 (15-4) 10. FLELD AND POOL, OR WILDCA. T Tradin~ Bay Field 11.SEC., T., R~, M., (BOTTOM HOLE OBJECTIVE) Section 4' T9N, R13W, S.M Tie-bac.,k9 S/8" HOLE SIZE [ CIq-'~LNTIING RECOILD 22" ! TO 1 g" [ TO surface .2 1/4!~ , Liner top ,[ ~ , To sur~ace ,, 26. LINE~ SIZID '[ TOP (MD) [ BOTTO}/I (liD) SACKS CEMENT* 9~5/8''' [ 5076 [ 7476 1250 sx. 9 s/ [ -% ~,, [ :~07~ , z9oo sx. 28. PERFORATIONS OP~ TO PRODU~O~ tiuterv~l ~i~a a~pmmber) "D" Zone: 6914-6919~ 6941-6956, 700~-DI5~ 7040-7070~ 7188-7208~ 7224-7244, 7282-7292~ 7556-7548, 7558-7566 (155' total). Perfs. belo~ 715~, not open due to Otis tbg. plug produc~g. .. from ~per '~" ; Zone only at this. 30. P~ODU~ION Blank I 3' 1/2" ]' 7.170' " .] Tie-back, [ "' I -- ~c6~7~' 29, 'A~ID, Si!OT, FiI.~C~'~rRE, C~IENT SQUEEZE, . [4648-4684. 4692-4742... [ 4840.487824898. 498625040. [sqw.'beh~d 9 5/8" tie-baci.- DAT'E FIRST PRODUCTION I PI~ODUCTION MElt{O,D (Flowh~g, gas lif~, purnping--size and type of pump) [VJELL STATUS (Producing or I ~inut-i$) · ,, 7/7/73 Gas Lift ] Proauc~ng ~per "D" 7/7/75 [ 12: ' [Various ~[r~"~? [ 1514/1227[ 51~ [ 1.6 [ 420 ~OW, ~IBI~G' [CA~NC PRESSURE [CAL~T~ OI~BBL. GA~' ~n ~~BBL. [OIL GR*VITY-~I (CO~,) 31. DISPOSITION OF GaS (Sold, used for fuel, vented, etc.) '33.'I hereb~- cer~fy]that the [oregOing and attached information is complete and eorr~t~a~r~d from all-avMlable records SIGNED,. ~~ ~-~E ~tT~9~- ~',t. DATE ~~ , ..~ om ~. qaiienaer ..... , - '- .- , , · (See Instructions ~ng Spaces lot A~difionu[ D~ta on ~everse Side) 13 5/8" Liner 9 5/8'.' , A3~[OUNT PULLED None None Nnne ,. 16" CASI2qG SIZE 509'N, 3791 'W 111. PERIVIIT lifO. 5/5/73 [ 6/3/73 [ 7/4/75 IRT 101' above IVtSL._ ,p~a Deck 60' 1~. TOTAL DEPTH, Nm & TVD~9. PLUG, B&CK ' MD'& ~D~. ~ ~LT~LE CO~L., ! 21. -I~TERvALS 'D~FLS~ ~Y , , _. ......... ._ ,, ~ PRODUCING _N~AL(S), OF ~S COM~{IO~--T~P, ~OM NAME (~ AND ~)' {23. WAS DIR[~ON~L '~" Zone - ~ 6914', ~ 5412' ~ 7373' ~ 58~1' ] Yes ~ 9 · ,,, J ~. T~E ~cT~c ~ND OT~E LOGS aUN DIL~GR, ~ GR-Sonic to 5209'. DIL .~ RaM ~eutron to 748~' ... · . ] ~' CAS~G RE--RD (Report all strings set in wJ~l) '' INSTRUCTIONS General: This form is designed for' submitting a complete and correct well completion report and log all types of lands and leases ~r~ Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in other spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate, production from more thar~ one interval zone (multiple completion), so state in item 20, and in item 22 show the prc.Jucing 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 ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoul.d show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMM'~ARY OF' FORMATION TF_,S'I',S IN('L,UI)IN(; INTEII. VAL TF_~CJ'FED. I:'RESSUIZE DATA ~ ~0VERI~ OF OIL. GAS. 35. G~GIC WAT~ AND MUD NA~ MEAS. D~ ~U~ V~T. NO ~CO~;RY TOP TOP "I~" Zone 4642 5060~ , , ~ , , , 36. CORE DATA. A~'I'ACII BRIE~' D~CRIPI~ONS OF LITIIOLOGY. PORtlY. FHAC~R~. A~NT A~O.D~'~CTEI) StIOWS OF OIL. G~ OR WA~. iii ii I i i i D-,oo,-^ UNION OIL CO'. OF CALIFORNIA REPAIR RECORD · · ... ~: ~" ~". :.':.:;' .:: ix ~4'V~.'_-.~' :'" "':: ' ' i~' ~'. :,.!:.::::_ :.:,-i' ::.~,...i'~¥t~?~' "SHEET A · .. . PAGE NO. LEASE Trading Bay State .... WELL NO A-30' CONTRACTOR Parker . FIELD Trading Bay TYPE UNIT Oil Well 860 ................ BEGAN: 7-15-81 ....... COMPLETED: 8-2-81 , ELEVATIONS: GROUND__-174J RT to ocean floor ~'~','l::,~/rTm Nr% ~3-14 SER!A-t:~ NO ADL 18731 : CASING HEAD. ~ APPROVE~-g'~..~./4~ ~ ~='-, ~~~ '' ' . ROTARY DRIVE BUS...HING 1-0-1'' NS_L_ z ' - ~ ~ CASING & TUBING RECORD /DEPTH G~'"' '"'-'"'" - SIZE WEI GRADE REMARKS ..... -'.: ,,~_.. , · , .... . -f ':. , .. , · .. · , 9 5/8, '7476 47~' ''~ ....... N-80 ~'z'd ~d~9 5/8" csg f/5016'-5016' w/250 s~ "G" ... '"'-' '.- '.~-: .:.': ~t ret 'at' 6820' w/400 sxs ~....:.~' ,. FE .~... ..,. .~: '....:, .'...'..::....: .'.. '..... ':. . ~..c'.:...:: .,.: 2 3/8" 4595: [ 4.7 ~ N-80 Pkr Set ~ 4551' ' ' ' 'AIAska0~[ & G2s.00,s.'G°~mi$~[0~:"'.': '~' . I PERFORATING RECORD " pATE INTERVAL E.T.D. REASON PRESENT CONDITION 7-20-81 "6914:73:66' ' ....... -'""' :' "'""~'/'"~'~'7485 ~''~ .... ':' :""" ~" ': .... ..... ~ Abndn' · ' Sqz"'"~" .: -w/. -4 0 0- -- ., s×s." "',"G" ". '':'!~('''-.,' ..... -:~"c.., ........... ' ..~:.' :-:.,>-:~.::~,: ..... 7-21-81 5148-5150 .,'~., .:,.,,-748~ ~'~..C. A~.,,n_dn ' : Sqz,d.w/300 SXS ~"G" ".-.-:~.,..::.-~.-,.'..... '::,i.i:,L:',i':?'::-.L: .' ' · i~ola~on Sqzi d "~/250 Sxs.- ,G,, . 7-21-81 4640-46'4~/''': :" ~74'85' .'~ ' -".'.~ , _-. , ,. ,, ~; ~. , , . ... -::' r.:''./i,:,'. ' ,, . -':.[ ..... 7-24-81 5148-5150 . "'..'7485.;':: ':'"':' Isolaf~on Sqz d w/300, sxs , G ,..,,..:"--'' --' ~': .... '--:~' 7-24-81 4640:4642 ': 7485" ISolation Sqz'd w/300/sXS ';iG" .".:-i::?((":i.,':'.. . .,' "!: 7-25-81 5003-5018" '7485 Production Frac-Packed, Open for Production' 41~8· Snd. 7-26-81 4886-4896.. 7485 Producti°n Frae-Packed, Open for Production '4'0'4 Snd. i':....' 7-27-81 4818-4838 · 7485 Producfiion Frac-Packed, Open for Production "33-6,"Snd. 7-30-81 4688-4708 7485 ProduCtion Frac-Packed, Open for Production '31-8'Snd.' '~": ' :"':'" 7-30-81 4668-4678 7485 i..~:. Production Frac-Packed, Open for ProductiOn ~31-8 ." - ' .- i-~!.:-:. . '. . . . ..., . . '":<:?:."' : i ii · PRODU~ AIR DATE -I INTERVAL NET'OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR . . ~0/7/81 "B" Zone '158 11 2 19 8 743 88 37 234 · -. WELL HISTORY PRIOR TO REPAIR : ' ' ... ~:"~:-~!:72,-"--'.~-~:~. ~' :'~'~'~"*~:":"~"~":"*:""'"'"~"~'~:?~-'~:'~"'~::~"'~"~'~ ............ "~'~':~""'" ..... '::'"'LAST COMPLETION NO. 1., ,'- . ../ -.: . .. ':-':' '.".~-~;'.;~'..':"~' ?. 27. '~ ' ~.OMPLETION DATE: ..7-4-7-3- '-- ?REDUCING INTERVAL: !'D"-~--?..one a~ intervals 'f/6914 '-.7366 ' _. · - 'NITIAL PRODUCTION: .. ,:.~.,.,...:. ..... ...- ~.., ..... . ~AST REGULAR PROD. & DATE: '" '"?:"~z:~"' ~ ':" '" ...... ~: '~" "':~"' ' ZUMULATIVE PRODUCTION' {EASON FOR REPAIR: Abandon "D" Zone~ Frac-Pac & reccmplete-as 'Sinqle "B" Zone producar. UilIOlt OIL CO'PAUlY OF CALIFOPJiIA WELL RECORD S~:EET D PAGE ilO, --. LEASE ~DL 1~731 DATE Fr~ 4595.61 4594.88 4564.33 4563.75 4563.08 4562.37 4561.64 4'551.06 4550.'00 4549.33 '4520.26 4513.69 3763.50 3756.95' 2100.53 2093.97 341.65 340.12 309.58 306.51 60.13 35.35 34.85 33.85 ETD 4594.88 4564.33 4563.75 4563.08 4562.37 4561.64 4551.06" 45'~o.oo 4549.33 4520.26 4513,69 3763.50 3756.95 2100.53 2093.97 341.65 340.12 309.58 306.51 60.13 35.35 34.85 33 85 -0' ~EII 1,10, A-30 FIELD Trading Bay Field .DETAILS OF OPERATIOHS, DESCRIPTIOI!S &,~ESU~TS, Tubin. g Detail Length 30.55 . .58 JTS Descri tiOn .67 .71 ..73 1~.58 1.06 '.67 .29.07 6.57 750.19 6.55 1656.42 6.56 1752.32' 1.53 24 53 56 30.54 3.07 246.38 24.78 .50 1.00 Landed Below R.T. Mule Shoe 2 3/8" Butt. XO 2 7/8" EU 8rd Pin x 2 3/8" Butt. Pin XO 2 7/8" Butt Pin x 2 3/8" EU 8rd Box 2 7/8" Special Clearence Butt. Collar XO 2 7/8" Nu 10rd Box x 2 7/8" Butt. Pin Baker M~del "D" Pkr. & Seal assembly Locator Sub. XO 2 3/8" Butt. Box x 2 7/8" Butt. Pin 2 3/8" Butt. Camco GLM 2 3/8" Butt. Camco GLM 2 3/8" Butt. Camco GLM 2 3/8" Butt '.'. XO 3 1/2" Butt Box x 2 3/8" Butt. Pin 3 1/2" Butt. Otis 3 1/2" BV "N" 3 1/2" Butt. 3 1/2" Butt. Pup XO 3 1/2" EU 8rd x 3 1/2" : Butt. D. Pin cameron Tbg. Hanger $1.EET D IE SE U[IIOIt OIL ca;PAra' CALIFORHIA ~AGE rb, '" ] £LL RECORD ADL 18731 , _ DATE 1 7/15/81. DAILY COST- CUM COST' qFE AMT- 7/16/81 LY COST' COST' AMT- 7/17/81 ' COST: OST: ,IT: 118/81 )ST: · f81 ETD 7485' TD. 7385' ETD 13 3/8" C. 5164' 9 5/8" C. 7476' 65 PCF 39 SEC $ 31,864 $ 31,864 $ 950,000 7485' TD 7385, ETD 13 3/8" C. 5164' 9 5/8" C. 7476' 70 PCF 37 SEC $ 33,069 $ 64,953 $ 950,000 · . 7485' TD 7385' ETD 13 3/8" C. 5164' 9 5/8" C. 7476' 71 PCF 37 SEC $ 38,543 $ 103,476 $ 950,000 Z485' TD 6820' ETD (FISH) 13 3/8" C. 5164' 9 5/8" C. 7476' 72 PCF 36 SEC $. 26,336 $ 129,812 $ 950,000 7485' TD 6858' ETD ~ (FISH) 13 3/8" C. 5164' 9 5/8" C. 7476' 72 PCF 35 SEC $ 31,133 $ 160,945 $ 950,000 ~'ELL NO, A-30 FlED TRADING BAY FIELD · 15ESCRIP I :~, _DETAILS.OF OpEP~k_TI_OJ't.S 'I J T"o[Is RESULTS, Commenced operations @ O0:O1 hrs 7/15/81. Moved rig .over well TBS A-30 and rigged up. Filled annulus and tbg with FIW. Pulled ball valve. Worked wax cutter on WL to 6875'. (Note: Circu- Yated out'some H2S gas when filling well with FIW- will mud up with gel mud). Opened "XA" sleeve @ 6838' Displaced well with gel mud. Raised MW to 70 ~CF to kill well. In- stalled BP.V & removed tree. ,i on '00~. in 23' · 3' ~al ;i w/ Installed-& tested BOPE. Attempted to pull tbg. Jet cut 3 1/2"'tbg @ 6893' w/ GO Int. 2 5/8" jet gun cutter (BV @ 300' is 2.75" ID). Unable to pull tbg. Jet cut 3 1/2" tbg @ 6853' w/ 2 5/8" cutter, xs Unable to.pull tbg. Ran DIA-log free point - tbg D-6. free to 6920' Could not run tool below 6920'. Jet cut 3 1/2;' tbg @ 6888' w/ 2 1/2" jet Cutter CFM (3· 1/2" DP cutter). ,Unable to pull tbg. Jet cut 3 1/2" tbg @ 6812' w/ 2 1/2" jet cutte, r (3 1/2" DP cutter.). Wor. ked tbg - still unable to pull tbg. Jet cut 3 1/2" tbg @ 1004' w/ 2 5/8" je~ cutter. Worked tbg free.. Pulled & layed down. 3 1/2" tbg f/ 1004'. RIH w/ 8 1/2" OS w/ 3 1/2" hallow mill & grapple. Worked over fish @ 1004' Pulled 175M# over pickup & pulled tbg free. PullJd & LD 3 1/2" tbg f/ cut @ 6812'. Strapped tbg -.TOF @ +6820' DPM. RIH w/ 8 1/8" OS dressed as before. C~-uld not engauge fish @ 6820'. POOH. Pulled thru tight spot @ +5017' Reworked OS guide. RIH w/ OS. · Could not w'-ork t~ru tight spot @ +5017'. Set down 2OM# & it took 45M# to pull free. POOH. RIH w/ 8 1/2" taper mill. Dressed out bad csg f/ 5016' to 5023'. POOH.' Mill 1/4" under gauge. RIH w/ 8 1/8" OS dressed w/ 3 1/2" grapple. £n- gauged fish @ 6820'. Jar on fish. POOH. No re- covery. RIH w/ OS. Engauged fish. Jar loose & POOH. Recovered tbg down to cut @ 6853'. RIH w/ OS. Engauged fish. B 1/Z" .Ut soft DO' to to ll O0 ~ld not psi. 5100' · to '3000' · termi ned t. Ui1IOH OIL CD'?AIN OF CALIFOP iIA WELL RECORD S}:Ek-'F D PAGE ih, ---3 __ LEASE ADL 18731 DATE ETD 7124/81 DAILY COST: ACC COST' AFE AMT' ll 7/25/8l DAILY COST :' ACC COST' AFE AMT' · · 12 7/26/~1 DAILY COST' ACC COST: AFE ANT 13 7/27/8l DAILY COST: ACc COST' AFE AMT' 14 7/28/81 DAILY COST' ACC COST' AFE AMT' 7485' TD 4500' ETD (CMT) 13 3/8" C. 5164' 9 5/8" C. 7476' FIW $ 29,770 $. 350,238 $ 950,000 7485' TD 5120' ETD (RET) .13 3/8" C. 5164' 9 5/8" C. 7476' 65 PCF 34 SEC $ 55,844 $ 406,082.' $ 950,000 7485' TD 4957' ETD .(SAND) 13 3/8" C. 5164' 9 5/8" C. 7476' 65 PCF 34 SEC $ 34,750 :$ 440,787 $ 950,0'00 7485' TD 5120' ETD 13 3/8" C. 5164' 9 5/8" C. 7476' 65 PCF 34 SEC $ 202,427 $ 643,214 · . $ 95O,OO0 7485' TD 4864' ETD (SAND) 13 3/8" C. 5164' 9 5/8" C. 7476' 66 PCF 35 SEC $ ,38,738 $ 681,952 $ 95O,OO0 ~ELL NO, A- 30 FIELD TRADING BAY FIELD __DETAILS OF OPERAT. IP[tS, DESCRIPTIOn. IS & .RESULTS Drilled out cmt ret @ 5100'. Found no cmt below ret... CO to 6820'. Perfed 4 HPF w/ 4" guns f/ 5148 to 5150'. Sqz'd perfS f/'5148' to 5150' thru ret set on WL @ 5120' DIL w/ 300 sxs "G" w/ 10% silica flour & .7'5% D-31. Initial rate 26 CFM @ 2600 psi, final rate 24 CFM @ 2800 psi, formation herd 1750 psi w/ pumps off. Rev clean. POOH. Perf'd 4 HPF w/ 4" guns f/ 4640' t6 4642' DIL. RIH & set RTTS @ 4432'· Sqz'd perfs f/ 4640' to 4642' v)/ 300 sxs CL "G" w/-10% silica flour & .75% D-31. .Initial ·rate 24 CFM @ 2000 psi, final rate 20 CFM @ 2600 psi, formation held 1500 psi w/ pumps-off. 'Held sqz in place'3 hrs. Rev clean. POOH. 'WOC. RIH w/ bit & scrpr. Tagged cmt.@ 4500'. woc until hard, CO hard cmt to 4674', RIH to ret @ @ 5120' X-over to KCL WO fluid. POOH. Perf'd thc 41-8 sa~d w/ 4" csg guns w/ 4 HPF f/ 5003.' to 5018' DIL. RIH & set ret-a-matic @ 4947'. Rigged up Dowel l. Frac pack the 41-8 sand perfs as programmed, max frac. pressure 3200 psi. Held frac in place 8 hrs. Circ clean. POOH. Perfed 4 HPF 'w/ 4" csg.guns the 40-4 sand f/ 4886' to 4896'. RIH & set RBP-@ 4957'. Tested RBP to 5000 psi. Set ret-a-matic @ 4840' Frac pack the 40-4 perfs f/ 4886' to 4896' as programmed. Max frac pres- sure 3500 psi. Hold frac in place 8 hrs. Re- trieved RBP f/ 4957'. Attempted to set RBP @ 4880'. 'RBP would not set. POOH. Perforatgd the 33-6 sand w/ 4 HPF using 4" csg guns f/ 4818' to 4838'. .. RIH w/ Baker ret-a-matic w/ RBP. Attempted to set RBP @ +4880'. POOH. Left RBP in hole. RIH w/ retrieving tool. Tagged RBP @ 4883' Released f/ RBP. POOH. RBP was on retrieving t~ol. RIH w/ Howco RTT~ w/ RBP. Set & tested RBP @ 4870' Set RTTS @ 4760' Attempted to break down the..3~-6 perfs f/ 481~' to 4838'° w/ 4800 psi. Released RTTS. Circ clean. POOH. RIH w/ OEDP. Sanded out RBP @ 4870' to 4864'. POOH. ' UillOIt OIL OF CALIFOPJ.iIA ELL RECORD S :EET D PAGE ih. [~J~SE _ ADL 18731 'ELL I O, Aw.3o FIELD TRADING BAY FIELD DATE 15 7/29/81 DAILY COST: ACC COST: AFE AMT: 16 7/30/81 DAILY COST: ACC COST- AFE AMT'" 17 7/31/81 DAILY COST: ACC COST: AFE 'AMT: 18 8/1/81 DAILY COST' ACC COST: AFE AMT: ETD 7485' TD 4770' ETD (SAND) 13 3/8" C. 5164' 9 5/8" C. 7476' 65 PCF 33 SEC $ 128,203 $ 810,155 $ 950,000 7485' TD 4770' ETD (~AND) 13 3/8" C. 5164' 9 5/8" C. 7476' 65 PCF 34 SEC $ 123,958 $ 934,113 $ 950,000 7485' TD.. 5120' ETD (RET) 13 3/8" C. 5164' 9 5/8" C. 7476' FIW $ 85,246 . $1,019,359 . $ 950,000 · 7485' TD 5120' ETD (RET) 13 3/-8" C. 5164' 9 5/8" C. 7476' FIW $ 26',021 $1,045,380 $ 950,000 Reperf the 33-6 sand w/ 4" csg guns loaded 4 HPF f/ 4818' to 4838' DIL. RIH & set RTTS @ 4758'. Frac pack the 33-6 'as programmed. Max pressure 3900 .psi. Hold frac in place for lO hrs. Circ clean & POOH. RIH w/ OEDP & sand out to RBP to 4770'. Rev clean. POOH. Perfed the 31-8 sand w/ 4" csg guns f/ 4688' to 4708' & f/ 4668' to 4678' w/ 4 HPF, RIH & set RTTS @ 4592'. Fi-ac pack the 31-8 sand as p.rogrammed. Held frac in place l0 hrs. Rev clean & POOH. RIH & retrieved BP f/ 4870'. POOH RIH w/ 8 1/2" bit.. CO sand f/ 4951' to ret @ 5120' DIL. Circ well clean 7 hrs to clean up frac sand co_ming back in perfs. POOH. Ran GR"CCL log f/ "2qO0' to 5120'. Set Baker "D" pkr on DP @ 4550'.. Layed down 5" DP. Ran 2 3/8" comp assy w/ MS..@ 4595', Camco GLM's @ 4514', 3757' & 2094' Ball -valve @'306', Spaced out & landed tbg. ~emoved BOPE. Installed & tested tree. Shipped mud to beach. .Released rig @ 12:00 hrs 8/2/81. · i I II I I II I I I I . 'A-30 · 0! Otis 3 1/2" *~" B.V. 307' 13 3/8" 5164' X-Over 3 1/2" x 2 3/8" 340' Camco GLM 2094' camco GI~¢ 3757' Camco GIM 4514' Locator Sub 4550' BakerModel "D" Pkr. & Seal Assy. 4551' Mule Shoe 4595' Cmt Ret 6820 9 5/8" 7476' 47# N-80 ' DAT~. Well Schematic A-30 SCALE 0A~ 8--2--81 UNION OIL COMPANY OF CALIFOJLNIA SHJ:F,.I$ ! ~HEEI ~P;ASE Trading. Bay State WELL NO ..... A:730_ t~t_,D Tradi_n_g ~Bay Field }OCATION__Condnctor 5_:_16jJ~S, 551'W of the S. E. corner oz Section ~: T9N, R13W,-~ WE'LL ~CO~D SPUD DA~.~ 5/5/75 COMP. DAT~ 7/ 4/73 CONTRACT0~ }VODEC0 'I~IC; NO.. 56 TYPE UNIT pih,~ell 860 Elev. DRILL PiPE DESCRIPTION 5" 19.50# -4 ~/2'-IF 'Co~7- S. M, AFE #331018 ' SERIAL NO. ADL-18751 ELEVATIONS: WATEII DEI~I'It 73' tL T, TO OCEAN FLOOR 174' 'ERMIT NO, !.D. 7485' T.V.D. 5933' 'R.T. TO MLLW 101' ~.ISI, ~EVIATION (B.H.L.) .509'N q 3791'W of the surface loc. R.T. TO DRILL DECK 22.07' , R.T. TO Pn~UCT[O~D~K .~.0.82 ......... ~MPANY ENGINEER Watson, l~ester ~ Rardin [ · n~,,~r,, ~~ ~ .~~ ' GASING & TUBING ~ECOBD 1~ 65~ Buttress tt-40~ 1246' Cmt. to Surface w/ 935 sx. w/ 8%_gel 250 sx 55 CdC1 13 ~/~ 61~ 68~ B~]ttre~ K-55 5164' ~t to surface w/ 1500 sx.8% gel S00 sx. 1% D-31. 9 ~/~ 47t~ g}]ttr~ N-80 7475' Cmt to 5076' toe liner w/ 12,50 sx,, "G"~t. 1~ D-31 ~' ~d 0'75% R'5 I~etarder. _9 S/~ 47~ .. Buttress N-80 5076' "Tie back'.~'tring t9 liner, cmt. w/ 1900 sx 1~ Dz~I - back to surface-good cement retfims. . ,,,., Y, ~ . .~, ,, ~,t ...... ......... ~ .......... ?ERFORATI~,IG RECORD ~~ ~i~~~ ~' I ' ' ~ O ri 2gal I ISqueeze. off "Gas Sand". /.5/73 4174-4184 Test 28-6 ¢~!4/73 4648-4684 5278'~"' Tes. t 31-8 Sd. Ran 9 5/8" Cs.g. tie-back'string- cmt. back to /? 4692-4742 52~' Surf_aCe, _a.l_l B Zone cement, bghi~d .nine._ *C.mt. Ret -/21/73 4986-50'~0 5278" Test B Zone /21/7.5 48J8-4898 5278' Test B Zone ./?.t/7~ aTq_~-d840 5278" Test B Zone " " " :' " " " ',/3~'/73- 6914-6919. 7388' Production Open f°r..product, ion w~ 4 NPF. ?~0'/73 6941-6956 .7388' Production O~,en f,o,r production ,w,/ 4. !?F., ..... " 7000-2015 " " " ...... " /U~U-./U/U. " " " " " " " I ' ' 7188,77-08 :~ "' [ ' ' ' ' ' ' ' ' 'l ' , "~" ' ' 7224-7244 " " " " " " " ~" '7336-7348 " " " " " " " "' 7358-7366 ' '" " " " '"' ;' " ~/1i/.72 5328-5330 5278' Squ.-~eze I .Squeeze.. off 44'-7 Sand. 6/i8/7J '4678'-4~84 " Test-B ZoneI Run 9 5/8" Cs~. ti~-hnck .qtr~ng-cem~.nf ..... 4692-4703. .. _.. .j~surface'-a!l B~7,one-cement behind.p~pe. ______ INITIAL PRODUCTION · .. " I , . ....... WELL HF~kD_&S SEMBLY -- FYPE: OCT ~ Cameron · 2ASING ~EAD: Uni/head 20" OD slip on & weld w/ 2" x 20" 2000# WP top flange w/' four 2" 2000# studded outlets gASING 'HANGER:Flu. ted, 20". X 16" OD 8RD 65~, ?~-SING SPOOL: -HEAD: Cameron 12" 900 ser'ies xl0" 1500 series DC-FBi. 7:UB,tNG ttANGER: cameron DC-FBB 3.1/2" EUE 8RD top - 3 1/2" EIlE' 8RDbott0m. tUBING IIEAD TOP- 10" 1500 series. .-1 ~ASTER VALVES': Cameron 3 1/2" single block type 5000# CHRISTMAS TREE TOP CONN.:_ 3 !/2"_ EUE 8RD. OIL CCi O: CALIFOi<i:IA PLCORD PAGE LEASE Trading Bay State _DATE 5/s/73 5/6/73 5/7)75 5/8/73 5/9/73 5/10/75 5111173 ¥;~]LL NO, A-30 FIELD Trading Bay Field 421'/I) 1092'TD 1255'TD · 1255'TD 1712'TD 2288'TD 3090'TD pk, iAILS OF O?ERATIOI__I~S, DESCRIP_TIO. I!S & RICSUJ_?_TS ( Footage 421') Moved rig over conductor #3, TBS A-30, Commenced operations at 12:01 am, 5/5/75. Welded OCT 20" Uni-head on 20"-drive pipe. Nippled up 20" hydril, riser and choke-diverter assembly. Drilled 15" hole to 245'. Ran and stabilized 18 1/4" mill to dress drive pipe shoe~ ~,lilled 6 hours, from 229' to 251' Lost partial circ. while milli~g. Changed to filtered Inlet water while'milling. Regained circ. Changed to mud. Drilled 12 1/4" hole to 300'. Ran Eastman turbo-drill w/ 12-1/4" bit. Turbo-drilled 12 1/4" 'hole from 300' to 421' w/ Gyro surveys. (FOotage 671') Turbo-drilled 12 1/4" hole from 421' to 665'. Pooh. building drilling assemblY. Drilled 12 1/4" hole, from 665' to 830'.. Pooh. Due to left turn tendency. Reran turbo-drill w/ 12 1/4" bit. Drilled and Gyro surveyed to 1092'. (Footage 163') Turbo-drilled 12 1/4" hole to 1255'. Ran 17 1/2" hole opener and opened 12 1/4" hole to 1255'. Pooh. Picked up 22" underreamer. .Survey: 1255' 35° S84W (Footage 0') Underreamed 17 1/2" hole to 22" to'TD at 1255'. Circ. and conditioned mud. Pooh. Rigged up and ran 31 joints of 65# }t-40 Buttress casing. Landed casing w/ shoe at 1246'. (Footage 457,). Stabbed into float collar at 1203'. t~mped 100 cu. ft. of NAOH water and 50 cu. ft'. of filtered Inlet water. Mixed 935 sx class "G" cement w/~l% CFR-2 and 8% prehydrated gel followed by 250 sx class "G" cement w/ 3% CaCl? cement in place at 2'30 am. Had good cement returns to surface. Pooh w/'~tab-in assembly. TIh w/ 15" bit. Drilled float collar at 1203' firm c~nent in shoe joint and float shoe at 1246'. Cleaned out to TD at 1255'. Poohw/ 15" bit. Picked up 12 1/4" angle building assembly. Drilled and surveyed to 1712'. tlole turned right while building angle. Pooh. TIHw/ turbo-drill to correct right~lmnd turn. SurVeys· 1255' . 35° S84W 1502' 46 1/4° S83W 1687' 53 3/4° S88W (Footage 576') Turbo drilled 12 1/4" hole from 1712' to 1826' for left turn. Pooh. Ran 12 1/4" bit on locked assembly. Reamed to bottom from 1712' to 1826'. Drilled 12 .1/4" hole from 1826' to 1846'. Jolmston drilling jars parted at the mandrel. Ran 6 1/4" grapple in 9 5/8" overshot w/ extension and 11 1/2" cut-lip guide on hydraulic jar and bunper sub w/ 3 steel 8" collars. FoUnd:top of fish at 267'' Pulled to 285,000#, freeing bottom hole assembly. Recovered fish. Laid down fishing tools. Replaced jars w/ Daily's. -Drilled 12 1/4" hole w/ locked assembly from 1846' to 2288'. o SurVeys- 1838' 52 1/2° S83~ 2026' 53° S83I'~ (Footage 802') Drilled 12 1/4" hole from 2288' to 2632'. Pooh for bit change. Drilled 12 1/4" hole from 2632' to 2880'. Surveyed and Pooh for BHA change to build angle. Drilled 12 1/4" hole w/ building assembly from 2880' to 3063'. Surveyed. Gained 2° angle and turned right 1 3/4°. Pooh to run turbo-drill for left turn and build. Turbo-drilled 12 1/4" hole from 306~ to 3090'. surveys: 2309' 51 3/4° S83W 2591' 51 3/4° S84W 2839' 51 1/4° S84W 2927 ' 51 3/4.0 S85W 3022' 53 1/2° S87W OIL. COl ?AIRY OF CALIFOI ['iIA PAGE LEASE 5/12/? 511317 5/14/73 $/15/73 5/16/73 5/17/73 Trading Bay state 3476 'TD 3546'TD 4033'TD 4475'TD 4852'TD 5225'I]) !'tILL ['~0i ^-30 FI£DD ~_'radlng Bay Field p_ETAILS .OF O?E_~P, ATI_OI!S, DE.SCRIPTIOj.!S &_RESULTS (Footage 386') Turbo-drilled 12 1/4" hole oriented'for left turn from 3090' to 3152'. Ran-12 1/4" follow-up assembly and drilled 38' to 3190'. Ran survey. }-kd 8° left turn to S79Wand no build. Pooh. Ran 12 1/4" locked drilling assembly. Drilled to 3382' Ran survey-had additional 4° left turn follow-up to S75°W with no build. D~illed to 3476'. Ran survey. Holding S75°W. Pooh. Picked up turbo-drill and TI}t. SurVeys: 3149' 53 1/2° S79W ' 3341' 53 1/2° S75W 3435' 52 3/4° S75W (Footage 70') Oriented turbo-drill for right turn at 3475'. Turbo-drilled 12 1/4" hole to 3546', and bit quit. Pooh. Bit had lost all 3 cones in hole. Ran 12 1/4" follow assembly and reamed from 3460' to 3543'-running on bit cones. Pooh.' Ran 12" globe junk basket. Reamed 3543' to 3546' Cored 1' to 3547' and Pooh. Recovered 1 bit cone and 2# junk. Ran 12 i/4" flat bottom junk mill and junk basket on drilling assembly. (Footage 487') Milled up remaining junk w/ 12 1/4" flat bottom junk mill from 3546' to 3547'. RI}I w/ following assembly. Replaced square collar above bit w/ stabilizer and drilled 12 I/4" hole from 3547' to 3904' Surveyed. Pooh and ran same assembly w/ squar,e collar. Drilled 12 1/~" hole from 3904' to 4035'. '" Surveys: 3554' 50° S79W 3626' 50 1/2° S80W 3208' 51° S80W 3801' 52 1/2o SSOW 3863' 53 1/4° S81W 3992' 53° S82W 4085' 52 1/2° S82W (Footage 442') Drilled 12 1/4" hole from 4033' to 4126'. Surveyed. Pooh an,, ran dropping assembly. Drilled 12 1/4" hole from 4126' to 4381'. Surveyed and Pooh. Ran dyna-drill for right turn. DTna-drilled and surveyed 12 1/4" hole from 4381' to 4475'. 4174' 49 1/2° S80W 4267" .-45 3/4° S79W 4359'' 42 1/2° S79W 4430' 41° S87W '4492' 40 3/4° N85W Surveys: (Footage 377') Dyna-drilled and surveyed 12 1/4" hole 'from 4475' to 4537'. Pooh and ran dropping assembly. Drilled 12 1/4" hole from 4537' to 4787'. Surveyed and pOoh to dTna-drill for right turn. RIH. Dyna-drilled and surveyed 12 1/4" hole from 4787' to 4852'. Surveys: 4671 ' 36° N82W 4765 ' 33° N82W (Footage 373') Dyna-drilled 12 1/4" hole for right turn from 4852' to 4893'. Surveyed and Pooh. b~de push run w/ following assembly from 4893' to 5034'. SurVeyed and Pooh. Relocked assembly. Reamed thru dyna drill runs and tight spots from 4705' to 5034'. Drilled 12 1/4" hole w/ locked assembly from 5034' to 5225'. b~de wiper trip to shoe of 16" csg. at 1246' Reamed tight spot at 3137'. Ran back to bottom at 5225'. Reamdd tight spot 'at 4705'. Circ. hole clean. Dropped survey. Pooh surveys® 4919' 30 1/2° N67W 5012' 27 1/2° N66W [)C'~' ~. ISto ' 5203' 27 1/4° N65W [~f~E Trading Bay State 5/18/75 5225'TD 5/19/73 5225'TD _5/20/73 ' 5225'TD · 5/21/75 5225'TD .S/22/73 5225'TD 15/23/73 5225'TD 5/24/73 5225'TD 5/25/73 5225'TD 5/26/73 5544 'TI) 5/27/73 5/28/73 5802'TD 5926'TD OIL ''5' ';' ,l UF CALIF(II, .iIA PAGE ,Eh, 4 }~LL [~0, A-30 FlED Trading Bay Field . DETAII~_S~0F OPE_RATD!IS, DESCRIPTIOjIS_.& RESU_LTS (Footage 0') (Opened 230'-18" TD at 1476') Pooh at 5225' to run logs. Rigged up Schlumberger. Ran DIL-GR, FDC-GR, and Sonic Logs. DIL-GR failed on first attempt. Schlumberger depth 5209'. Completed logging and rigged down Schlumberger. RIH w/ Baker 12 1/4"x 18" underreamer. Opened hole from 1246' to 1476' from 12 1/4" to 18". (Footage 0') (Opened 1629'-18" TD at 5105') Continued to open 12 1/4" hole to 18" w/ Baker expanding hole opener. Pooh at 2348' to change cutters. Found one cone missing. RIItw/ re-dressed hole opener, found out of guage hole from 2258' to 2348'. Reamed from 2258' to 2348'. Continued to open hole to 3105'. Drill pipe torqued excessively and backed off pin at'!30'. Found top of drill pipe fish at 485'. (Footage 0') (Opened 466'-18" TD at 3571') RIHw/ 11 1/2" cut lip guide on 9 5/8" overshot, bumper sub, jar and drill collars. Picked out 41 jts. of 5" drill pipe and 2 jts. heavy wall drill pipe. Reran fishing tool w/ 6 3/8" grapple. Found top of fish at 1827'. Pulled to 250.000# to free fish. Approximate pickup weight 120,000#. Recovered fish. Left 1/3 of one hole opener arm in hole. Rltt w/ new hole opener. Reamed from 3040' to 3105'. Found shoulder of 18" hole at 3105'. Continued to open hole from 3105' to 3571'. Pooh to change cutters at 3571'. (Footage 0') (Opened 646'-18" TD at 4217') Continued'opening 12 1/4" hole to 18" from 3571' to 4217' w/ trip:; for hole opener cutter changes at 3928' and 4213'. (Footage 0') (Opened 651'-18"TD at 4868') Continued opening 12 1/4" hole to 18" hole from 4217' to 4868' w/ trips for hole opener cutter changes at 4475' and 4868 '. (Footage 0') Opened 357'~18'' TD at 5225'-) Continued opening 12 1/4" to 18" hole from 4868"to 5225' (357'). Tripped to change hole opener cutters at 5092'. Circ. hole clean at 5225'. Rigged to run 13 3/8" casing; (Footage 0') Ran:128'jts. of 13 3/8" Butt. Csg. 36 jts. 68#, 92 jts. 61#). Landed at 5164' w/ }~wco Float shoe at 5164', ttowco Float collar at 5120' and Howco DV collar at 1966'. Cemented w/1500 sx "g" cement w/ 1% CFR-2 and 8% gel, mixed to a 98# slurry, followed by 500 sx "G" cement w/ 1% CFR-2 mixed to a 118# slurry. Total slurry volume 3455 cu. ft.. Proceeded slurry w/ 100 cu. ft. cauStic water .and 50 cu. ft. Inlet water w/ bottom and top plugs. }tad good returns doing job w/ 250 cu. ft. 91# to 97#-cement returns to surface. Bumped plug in catcher at 5080' w/ calculated displacement w/ 2500 psi. CIP at 1:15 pm, 5/24/73. Set and tested 13 3/8" x 20" slips and pack-off in OCTUni-Head. (Footage 0') Completed installing 13 3/8" BOPE & tested to UOCO spec. TIH to top of DV collar at 1966'. Shifted DV tool & closed ports. Tested to 2500 psi - ok. Drlg. FC at 5120' & firm cmt. to 5140'. Tested 13 5/8" csg. to 2500 psi - ok. (Footage 319') Drlg. firm cmt. & shoe at 5164'. CO & drlg. to 5229'. Tested FM & csg. seat equiv, to .650 psi grad; Drlg. 12 1/4" hole to 5544'. Pooh for assy. change. (Footage 258') Drlg. 12 1/4" hole 5544' to 5744'. Pooh. Ran dyna-drill oriented for right turn at 5744'. Dyna-drlg. to 5802'. Pooh w/ dyna-dril. TIH w/ follow-up assy. (Footage 124') Reamed dyna-drill run from 5744' to 5802'. Drlg. 12 1/4" hole to 5834' w/ follow-up assy. Survey showed 1° right hand turn. Pooh. Re-'ran dyna-drill from 5843' to 5886'-oriented for right hand turn. Pooh. Ran follow-up assy. Reamed dyna-drill run from 5~43' to. .~. 8~5~..~ ,,~.rl.g~ survey. Had 11° ri~) i2 1/4" hole to 5926'. Ran Surveys: 5609' 25°. N66°W 5822' 23 3/4° N64OoW .... ~,, .. 5905' 22 1/4° N53 ANC~tOkAGE ,[hlY d: CALIF01 iIA 0IL l C0[ i ^Gr· ilO, S ~E Trading Bay State DATE = .~1.D , 5/29/73 6209'TD 5./30/73 5/31/73 6/1/73 6/2/73 6/3/73 614/73 6/5/73 l',~[-'LL 'l~10, 'A-30 FIELD =.Trading_ B_ay Field 6522'TD 6894 'TD 7283'TD 7432'TD 7485'TD 7485'TD 7485'TD :DB.T_AIL.S OF OiPERATLQJIS,. DESC_R!~!IOI.!$ 8, RES_U_L!S .......... (Footage 283') Drilled 12 1/4" hole from 5926' to 6209' w/ bit trip at 6037'. Hole turning left. Pooh. Ran dyna-drill for right turn. Surveys: 5967 ' 22° Ni0W 6093' 22 3/4° N52W 6186' 22 3/4° N52W (Footage 313') Oriented dyna-drill for right' hand turn at 6209'. Dyna- drilled to 6227' (18'-7 hrs.). Pooh. Ran follow assy. Had 6° right turn On dyna-drill run and 2° right follow-up. Drilled to 6522'. Surveys: 6248' 23 1/2° N46W 6311 ' 24° N46W 6405' 24 1/2° N44W 6531 ' 24 1/2° N44W CFootage 372') Drilled and surveyed from 6522' to 6894, w/ trip at 6710'. Surveys: 6689' 24 1/2° N41W ' 6873' 23 3/4° N41W (Footage 389') Drilled and Survey .- from 6894' to 7283' Surveys: 7090 ' -24° N41W '7262' 24° N39W (Footage 149') Drilled t° 7432'. Made cond. trip to btm. csg. Circ. &'cond. mud to log. Pooh. Rigged up SChlumberger· Ran DIL-GR Log. Checked drlg. TI) of 7452' at 7420' Survey' 7420' 24 1/2° N39W (Footage. 53') Ran BHC-Sonic & FDC-GR Logs in open hole.. Ran CBL-GR Log. from 13 3/8" csg. shoe at 5164' to 3000'. Rigged down Schlumberger.. TIH w/ 12 1/4" bit & drlg. from 7432' to 7485'. Circ. hole clean. Pooh. -Rigged up to run 9 5/8" liner. CFootage 0') Ran 2400' of 9 5/8" 47# N-80 Buttress liner and BOT liner hanger to 7476'. Hung off liner w/ top at 5076'. Circ. annulus clean. Pumped 100 cu. ft. of caustic water F4 100 cu. ft. of gel water. Mixed 1250 sx. "G" cement w/1% D-30 & .75% retarder to 120#/ cu. ft. Displaced cement w/ mud. Did not see liner wiper plug shear out. Displaced liner capacity. Plug did not bump up-over displaced liner capacity by 60 cu. ft. Cement in place w/ 800 psi on drill pipe. Unable to bleed pressure off drill pipe. Back flowed 50 cu. ft. and pressure dropped to 400 psi. Back flowed 60 cu. ft. and pulled out of liner top. Drill pipe came dry when clear of liner top. Pooh w, setting tool. Had cement on two joints of drill pipe above liner setting tool Repaired DW brakes. Laid down excess drill collars & directional t. ools. Ran 12 1/4" bit & 13 3/8" csg. scraper to top of 9 5/8" liner at 5076' Circ. out. No cement on top of 9 5/8" liner. (Footage 0') RIH w/ i3 3/8" RTTS tool& set at 4986'. Broke down liner lap w/ 1000 psi at 10 cu. ft./minute. Pumped 100 cu. ft. of caustic l~mter an 25 cu. ft. of Inlet water. Mixed 300 sx. "G" cement w/ 1% D-31 to 120#/cu. ft. slurry. Squeezed 300 sx cement below tool to a maximum & final pressure of 1700 psi. Left 50' cement on top of liner lap. Pulled RTrs tool up to 4600'. Tested squeeze on lap to 2400 psi - ok. Pulled 13 3/8" RTFS tool to 4104'. Rigged up Schlumberger and perforated the 28-6 "B" Zone Sand from 4174' to 4180', using a 2" OD hyperjet .gun. Displaceed 72# mud in drill pipe to 2800'VD w/ 1400 psi gas pressure. Set 13 3/8" RTrs tool at 4104' and bled off gas pressure to separator. No entry from formation. Reversed out. Reset R/TS tool at 4153' and pumped into perfs from 4174' to 4180' w/ 1300 psi at 2.'5 cu. ft./]ninute (Total 10 cu. ft. into perfs). Pooh w/ RT~S tool. Ri ged Schlumberger. Ran 4" OD Hyperjet II perfcrqt~,':g~ ~n~,]: ~-'~'~'~ pegrforatU~ed the 28-6 "B" Zone Sand from 4174' to tool to 4153'. Displaced 72# mud in drill pipe to pressure. Set RTTS tool at ,4153., u D!',,'!?.tO~'~ :31: :i'~L I-.~'~D GAS UNIOhQIL CO. OF C'ALIF'OF' NIA DRILLING RECORD SHEET D LEASE~ ,, Trading Bay State A-50 Trading Bay Pield 'WELL NO., FIELD_ DATE 6/6/73 6/7/73 6/8/73 619'/7,3 6/10/73 6/11/73 6112115 E. T. D. 7485 'TD 7485'TD 7485'TD 7485'TD 7485'TD 7485'TD 7485'TD DETAILS OF OPERATIONS, DESCRIPTIONS fi: RESULTS (Footage 0') Open well to test seperator at 12:10 am. 'Initially produced 1087 mcf gas/day and began loading up drill p. ipe with mud. Rate continously decreased to ~0 mcf/day at 3:00 am. Reversed out gas cut mud. No formation liquids. Circ. and cond.'mud to 74#/ cu. ft. Set RTrs tool at 4100'. Broke down'28-6 perfs from 4174' to 4184' w/ll00 psi. Mixed 300 sx class "G" cement w/ 1'% D-31 to 120#/ cu.. ft., Last 150 sx mixed w/ 2% CaC12 and 5% sand. Pumped 300 sx below tool-final pressure 500 psi. No squeeze. Cleared perfs. Mixed 300 sx class "G" cement w/ 1% D-31 and 3% CaC12 to 120#/ cu. ft.. Pumped 300 sx'below tool to 4145' w/ a maximum and final · pressure of 700 psi. Reversed out. Pooh w/ RTTS tool. Ran 12 1/4" bit and 13 3/8" csg scraper. Tagged up on cement scale at 4103'. Drilled cement to 4220'...Tested_per'rs 4174,-4.184 w/, .92 psi/ft. Gradient held ok. (Footage 0') Drilled out cement to top of liner lap at 5076.'. Pooh; . Ran RTrS tool and set at 5040'. Pressure tested liner lap to 1200 psi-ok. Released RTTS tool-displaced 72#/ cu. ft. mud to 3000 VD w/1500 psi gas pressure. Set tool and bled off gas pressure-tested liner lap w/ 1350 psi differential pressure held ok. Reversed out gas. Reset RTTS tool at 4200' and tested below tool to 1200 psi over 72# mud-held ok. Reset RTTS tool at 4150'. Pumped into 28-6 sand perfs from 4174' to 4184' w/ 1100 psi. Reset RTTS tool at 4100' for block' squeeze stage #3, on perfs from 4174' · to 4184'. Mixed 200 sx class "G" cement w/l% D-31 and 1% CaC12 to 125#/ cu. ft slurry. Pumped 200 sx below tool to a maximum and final pressure of 1200 ps1.- Bled off to 900 psi in 3 hrs. 20 minutes. Pooh w/ RTTS tool. Ran 12 1/4" bit and 13 3/8" casing scraper to top of liner lap at 5076'. No cement in 13 3/8" casing. Tested perfs from 4174' to 4184'. Pumped.in at 1050 psi. (Footage 0') Pooh w/ 12 1/4" bit and scraper. Tilt w/ OD 5" DP to 4213'. Mixed 200 sx class "G" w/ 1% D-31 and 1% CaC12 and laid plug in 13 3/8" csg. from 4213' to-3950'. Pulled DP to 3800' and reversed out, Squeezed 28-6 Sand perfs from 4174' to 4184' w/ 1800 psi, final pressure. Pooh w/ drill pipe. Ran 12 1/4" bit and sqraper. Drilled.out firm cement fror 4000' to 4230'. Tested perfs from 4174' td. 4184 w/ 1200 psi - 30 minutes ok. CO to.top of 9 5/8" liner at 5076'..Pboh. Ran 8 1/2" bit and9 5/8" csg. scraper. Tagged top of cement in 9 5/8" liner at 6018'. Dr'illed firm cement frOm 6018' to 6415'. (Back pressure valve during primary cement job failed to hold and cement.equalized in casing and annulus w/ top of cement at 5980'. (Footage 0') Continued-drilling out' cement in 9 5/8" liner from 6415' to · 6942 ' " . (Footage 0') Continued drilling cement' in 9 5/8" liner from 6942' to 1.anding co, llar at 7385' Dlgi. Pooh. Rigged.up Schlumberger CO liner to Ran CBL-GR :Log from ETD to 3800'. GR tool failed to function. Rigged up Sperry Sun Gyro Scopic Survey tool. (Footage 0') Completed run~ing Sperry Sun Gyro Survey from ETD to surface. Reran Gamma-Ray Log from ETD to 3800'. Ran 9 5/8" RTTS tool and set in 5/8" Iiner at 5135'. Tested liner to 3000 psi-held ok. Ran Schlumberger ~". OD H)rperjet thru tubing perfs gun and shot the bottom of the "B" zone 44-7 Sand from 5336' to 5338' w/ 4 HPF. Unable to breakdown w/ 3000 'psi. Reshot 5336' to 5338'. No breakdown. Shot higher in sand at 5528' to 5350' w/ 2" ttyperjet 4 HPF. Brokedown pe~.fs w/ 3000 psi. Pm~ed in 4 CBi at 2900 psi. Pooh w/ RTTS tool. RaF 4" OD ttyperjet II csg. gun and reshot 4 IFF from 5328' to 5330'. Tilt wP 9 5/8" RTTS tool' Spotted water opposite perfs.. Set RTTS tool at' 5230'. Pumped in 8 CFN at 2900 psi. (~ootage 0') Set Rl'rs tool at 5230' to' squeeze '~B" zone 44-7 Sand perfs from 5328' to 5330'. ~,iixed 100 sx of class "G" cement w/ 1% D-31 to a 122#/ cu. ft. slurry. Pumped 100 sx below tool to a maximum & final pumping pressure of 3500' psi. PresSuFe bled to 1400 psi in 10 minutes. Pressured up ~o 3000 psi, bled to 2350 psi and held ok. Pooh w/ RTTS to61. RIH w/'8 1/2" bit & 9 5/8" csg. scraper. CO,firm 'cement from 5318' cemented stringers to Id collar at 7385'/& circ. 'w~ ~'~'~c~~ over to invermul. '. .... , , .. /,. , '. , , . ,, . , :.. , .~ · i . ~ ~ '1 , ', 'J. q ,:.= ' i. OIL PAGE ~t II0, 7 LEASE DATE_ 6/13/73 6/14/73 6/15/73 6/16/'73 6/17/73 6/18/73 6/19/73 6/20/73 Trading Bay State t Ell I 0;. ^-ao FIELD Trading Bay Field 7485 "rD 7485'TD 7485'TD 7485'TD 7485'TD 7485'TD 7485 'TD 7485 'TD .]D.E_TAI LS_ OF_ OPER T~!Jg_U_S_, p.IC..S.C[{ I PT I OI!S. g RE_S_U_L,TS .... (FOotage 0') Displaced well w/ 70#/ cu. ft. invermul. Ran EZSV drillable retainer on wireline and .set at 5278' Ran Schlumberger 4" OD Ityperjet II 'csg. gun and perforated the "B" zone ~1-8 Sand from 4648' to 4684' and from 4692' to 4742' w/ 4 t~F. (Footage 0') Picked up 13 3/8" RTTS tool on 3-6 1/4" DC and 7 jts. of 5" OD I-B%~P. Set RTTStool at 320' Installed safety valve in DP. Picked up BOPE and installed tubing he~d spool-12" 900 x 10" 1500. Changed rams in BOPE and re-installed same. Ran test assembly on +4240' of 3 1/2" Buttress tubing w/ Camco gas lift valves and mandrels at 4276' and 2687'. Set RTTS tool at 4598' and landed tubing. Removed BOPE and installed x-mas tree. Rigged 'up slickline unit to open sleeve at 4236'. Wireline jars failed to -function. 8 hrs. opening "XA" sleeve at 4236'. (Footage 0') Finished opening "XA" sleeve at 4236'. Displaced invermul in annulus and tubing w/ diesel. Closed sleeve and. began gas lifting diesel f~om annulus and tubing. . · · (Footage 0') Gas lifted diesel from annulus and tubing through Camco mandrels. No fluid entry after diesel recovered. Gas believed to be blowing around through top valve at 2688'. Pulled Camco valve at 2688' and installed blanking sleeve. Returned we~ to gas lift through bottom Camco valve at 4226'. , (Footage 0') Gas lifted 84 bbls. fluid w/ initial 22% mud cut to a final 6% mud cut. Oil - 24 Gravity. Unable to lift additional fluid. Attempted to pull Camco valve at 4226', Opened "XA" sleeve at 4236'. No fluid level- indicated w/ slick line while opening sleeve. Gas lifted through sleeve 4236'"w/ no recover7. (Footage 0') Rigged upSchlumberger. Ran 1.9" x 22' scallop gun w/ collar locator, stopped in "Q" Nipple at 4270'. Checked for obstructions w/ sinker bars - ok. Reran. same gun to perforate 4 HPF from 4678' to 4684' ,and from 4692' to 4703'-gun failed to fire. Pooh. Ran 1.9" x 22' scallop gun and perforated interval aS above. Pooh to 4560' where gun stuck in drill collars. Pulled wireline out of head on gun leaving top of gun at 4560'. RIHw/ sinker bar and jars on slick' line to attempt to drive gun dmm. Toolsstopped at 4530'. Pooh. Closed "XA" sleeve at 4236'. Filled tubing w/ diesel and pumped gun and collar locator out of drill collars w/ 1500 psi. -Ran slick line tools to confirm gun clear of test string. Tools stopped in mud or heavy fluid at 4190'. Pumped 100 cu. ft. diesel. Ran and set gas lift valve at 2687'. Rigged upDowell to acidize. (Footage 0') Pressured annulus to 500 psi w/ injection gas and acidizedw/ 250 gallons E95 solvent, 3440 gallons 2 1/2% ECL, 4300 gallons 12-10 L¢.~, 3440 gallons 2 1/2% I-EL and 250 gallons E95 solvent. Displaced solvent to toF perfs at 4648' w/~diesel. Increased casing pressure gradually throughout job w/ 400 to 500 psi differential over tubing pump in pressure. Final casing pressure 1500 psi final tubing pressure 1100 psi. Communication tO annulus indicated after pumping approximately 4000 gallons or midway through job. No indication of formation breakdown during injection. Bled off tubing and casing. Gas lifted 300 bbls fluid, 1% mud, 89% acid and water, and 10% diesel. Gas 'U" tubed at a rate higher than expected through Camco valves Ran sinker bars on slick line, stopped at 4160'. Unable to produce weil w/ further gas lifting. Changed over to 71# invermul. Removed x-mas tree and installed BOP's. Picked up tubing, weight 35,000#, indicating parted at approximately 4200'. (Footage 0') Pooh w/ test string. Found "Q" Nipple parted above bumper sub. Removed tubing-head, installed spacer spool and tested BOP's. Rill w/ 6 1/4" x 9 1/2" over-shot w/ 3' extension w/ 6 3/8" ID mill bottom and 11 1/2 lip guide. Rotated over fish, catching bumper sub tool jt. Circ. and Pooh w/ fish. Rill w/ 12 1/4" bit (drilling assy) to top of liner at 50,76'. No indication of junk, restrictions or up and Pooh w/ 12 1/4" bit. l..~ IL :.~ .:-~ -, · oIL PAI'IY-0-- CALIFOI<i'iIA ¥,ELL RECOI8 LF_.AS~ Trading Bay State ,ETD 6/21/73 7485'TD · 6/22/73. 7485'TD · 6/23/73 7485 'TI) · 6/24/73 7485'TD 6/25 7485'TD · 6/26/73 FIELD Trading Bay Field 7485'TD · ,,.Dg]-AILS..OF OYERAT/OIIS,. DESCRIPTIOj!S & RESULTS. .. (Footage 0') Finished Pooh w/ 12 1/4'" bit. Rill w/ 8 1/2" bit to 5200' in 9 5/8" liner. Circ. bottoms up. Pooh. Perforated w/ Dresser Atlas Jumbo Jet Guns w/ orienting belly spring assembly. Guns oriented w/ 120° phasing w/ 2 holes each 9 inches. Perforated from 4986'.-5040',. '4878'-4898', 4794'- 4840' and reperforated from 4692'-4742', 4648'4684'. Rigged down Dresser Atlas. Ran Howco RTTS and test string assemlby to top of I Bx~3P. Removed BOP's and'spacer spool, installed tubing head and BOP's. Tested BOP's. Continued running test string. Assembly same as previous w/ "XO" sleeve to replace damaged "A" .sleeve and new "Q" nipple. (Footage 0') Ran testing string w/ 13 3/8" RTTS set at 4596', "XO" Sleeve at 4236' and Camco valves at 4246' and 2689'. Spaced out assembly w/ 3 1/2" tubing hanger. Set RTFS and tested to 700 psi. Landed hanger in tubing head. Removed BOP's. Installed x-mas tree. Pmn wireline and opened "XO" sleeve. Displaced invermul w/ diesel. Closed "XO" sleeve. Placed well on gas lift. . . (Footage 0') Gas lifted diesel from 12:00 am to 6:00 am and mud and diesel from 6:00 .am to 9:00 am. Gas "d" tubed w/ 1080 psi injection gas. IncreaSed injection gas to 1440 psi. Well made additional 12 bbls fluid. Bled well down. Attempted to rock and gas lift well. No further fluid entry 45 bbls fluid produced. Test #1-20% invermul cut, 209.4° gravity, Test #2-25% invermul cut, 21.1° gravity.. Test rates, 9:30 am to 10:00 am,295 ' BOPD. 10:00 am to 11:00 am-168 BOPD, 11:00 am to 12:00 Noon-72 BOPD, 12 Noon to 1:00 pm-SO BOPD. Approximate rat hole volume bottom of perfs at 5040' to Camco valve at 4226'-35 bbls. Ran slickline and opened "XO"- sleeve at 4236'. Found no fluid in tubing to 4270'. Pooh w/ slickline. (Footage 0') Filled annulus and tubing w/ diesel. Closed "XO" sleeve at 4236'. Tested tubing string to 500 psi ok. Pumped 250 gallons D-95 solvent, 3440 gallons 2 1/2% HCL, 4300 gallons 12-10 mud acid, 3440 gallons 2 1/2% ttCL and 250 gallons E-95 solvent. Displaced acid to top of top perfs at 4648' w/ diesel. Rate increased from .5 bbls./minute to .8 bbls as 2 1/2% HCL contacted zone. Rate. increased further to 1.0 bbIs/minute as 12-10 mud acid contacted' formation. ~Nintained 1 bbl/ minute rate as directed. Pressure decreased to 500 psi until 70 bbls mud. acid to formation, then gradual rise to 1000 psi at finish of stimulation. Began gas lifting. (Footage .0') Gas lifted well unloading diesel, acid and mud. Got formation oil breakthrough..at- 5: 00 ami 8:00 rate - 305 gross B/D w/ 11% cut. 9:00 am rate -decreased to 79 gross B/D w/ 10% cut. 11:00 am rate - decreased to 14 gross B/D. Continued gas lift to 5': 00 pm. Blew dry gas around annulus and tubing. Unloaded a total of 734 bbls. of fluid (Total recoverable diesel & injected acid - 916 bbls.) Rigged up wireline unit-ran temperature survey and determined well to be lifting off bottom valve at 4236'. Opened "XO" sleeve at 4238'. Bled gas pressure off tubing and annulus. Displaced tubing and annulus w/ 600 bbls. of diesel. Pumped 200 bbls diesel w/ 1/2 gallon/bbl, of Ilyflow Surfactant. Displaced lb/flow slurry to "XO" sleeve at 4238'. Ran wireline and closed sleeve. (Footage 0') Closed "XO" sleeve at 4238'. Started injecting diesel. (10 bbl.' vol. from sleeve to perfs.) Initial pump-in 500 psi at 1/2 bbls./ minute rate. Pressure dropped to 350 psi at 1/2 bbl./minute when Hyflo at perfs. Injected a total of 200 bbls. diesel w/ 1/2 gallons Hyflo per bbl. Final pump-in 400 psi at 1/2 bbl./minute Hyflo in place in 7'30 am. Put well on gas lift at 8'00 am. Unloaded a total of 792 bbls. of diesel until 12'00 midnite and started circ. gas lift gas (Total fluid in tubing and annulus plug, Hyflo - 842 bbls.) Net loss +_ 50 bbls. ~ ~,. {'~.~ ~t .... ~ ~ .... ~., i!~ .~ LEJ SE Trading Bay State I,FLLL I,I0, ^-3o FIFLD Trading Bay Field 6/27/73 7485 'TD 6/28/73 7485.'TD 6/29/73 7485'TD · - ~6/30/73 7485'TD 7/1/73: 7485'TD 7/2/73 7485'TD 7/3/73 7485 _ DETAILS_ OF..._.OPKEATIOIiS, DESCRIPTIC~!S &~RF__;SULTS · (FoOtage 0') Attempted to gas lift t'B"dzone until 9'00 a~n. No fluid produced from 12'01 am to 9'00 am. Ble gas lift pressure off tubing and annulus. Opened "XO" sleeve at 4238'. Displaced tubing and annulus w/ 70#/ cu. ft. invermul. Released RTIS tool. Installed safety valve in DP. Picked up BOPE and removed tubing head spool. Installed BOPE and tested to UOCO specifications. Completed Pooh and laying down test tools. Picked up 8 3/8" OD globe basket w/ 2 sets of full fingers. (Footage 0') Finished TIHw/ 8 1/2" OD Globe Junk basket on 7 1/2" OD barrelland 5' ext. washed over top of fish and down to cement retainer at 5278'. Pooh w/ Globe basket. Recovered perf. gun stabilizer spring Complete w/ clamps. Ran 4 11/16" OD overshot dressed w/ 2" grapple on 8 1/2" cut lip guide. Worked oVer top of fish at 5254'. Pooh. Recovered 2" OD scallop perforating gun Complete. Hole clear of all junk. Ran BOT polish mill and dressed out liner tie-back recepticle at 5076'. Pooh. Rigged up to run 9 5/8" tie-back casing string. Ran 124 jts. 9 5/8" 47# N-80 Buttress casing located in tie-back recepticle w/ tie-back stinger and .tested to 1000 psi - ok. Pulled out of recepticle. Pumped 100 cu. ft. of Hi-Vis gel water slurry. Mixed and pumped 1900 sx Class "G" cement w/ 1% D-31 at 118#/ cu.ft, slurry. Displaced cement w/ 70#/ cu. ft. invermul. Bumped plug on bored insert collar at'5039' w/ 2000 psi. Set seals into recepticle and released pressure. Iteld ok. CIP at 10:45 pm, 6/28/73. Had approximately 100 cu. ft. of good cement returns t, surface. Itung off 9 5/8" tie-back string. - (Footage 0') Cut off-9 5/8" casing installed tubing head spool. Tested.' to Union Oil specifications -'ok. Installed BOPE and tested. Ran 8 1/2'" bit-cleaned out 9 5/8" to ETD at 737'5' and tested casing w/ 2000 psi - ok. Pooh. ' (Footage 0') Rigged up Dresser-Atlas and perforated the "D" zone interval as required using 4" OD Jumbo Jet .casing gun. Ran junk basket and guage ring. to 7350'. Ran Otis 9 5/8" x 5" type l,gB permenant packer and set at 7112'1~53{. Pooh w/ setting tools. Rigged down Dresser-Atlas. (Footage 0') trigged up and ran 235 jts. of 3 1/2" N-80 9.2# Buttress tubing ~,/ Otis single hydraulic and gas lift assembly. Located Otis ~ pac~er at 7129', tubing measurement. Spaced out locator sub 1' above tFL packer and set s.ingle hydraulic packer at 6884' Installed BPV. Removed BOPE. Installed and tested x-mas tree. R}gged up slickline unit. Ran selective pool to-shift "XA" sleeve at 6848' and displace invermul with diesel. Unable to shift "XA" sleeve. (Footage 0') Ran positive shifting tool on slickline. Latched into"inverted '~O" sleeve at 6931' between packers. Opened sleeve at 6931' after 7 hrs. of jaring. Tested between packers with 1500 psi - held of. Latched into "XA" sleeve at 6848' above top packer. Jarred 2 hrs. and pulled through sleeve w/o opening. Rigged up braided line unit. Ran selective tool-unabl7 to open "XA" sleeve at 6848'. Ran positive shifting tool-continued to jar through sleeve w/o opening..Rigged up to pull tubing; Installed BOPE & tested - ok. Picked up on tubing & released hydraulic packer at 6884'. Started circ. 72# InVermul around packer elements sealing off annulus. ., (Footage 0') Completed displacing well w/. 72# invermul. Pooh w/ 3 1/2" tubing and hydraulic packer. Lost 2 Packing rubber elements off hydraulic packer. Rigged up Dresser-Atlas. Ran junk basket and guage ring. Recovered 1/2 of 1 packer rubber. Ran Globe basket on 3 1/2" tubing and reversed out on top of perm. pkr. at 7112 '~53I. Pooh. Recovered 1 complete pkr. rubber and small pieces. Reran I~ junk basket and guage ring-ok. Recovered 2 small pieces of rubber. Ran Otis 9 5/8" x 5" bore wireline packer and set at 6858'~-~%N. Rigged down wireline unit. Rigged up to rerun 3 1/2" tubing' p,roduction string. ~ ~, ((~'; .'. ~0i1' OIL C(.~ ?A~IY t,l:: C,.~,LIFOIIi:IA '..~ t,,ELL PAGE lO Trading Bay State FIELD Trading Bay Field 7/4/75 7485'TD DF. TAILS_ OF__OPE. EF-'ATIOIi$_, Dt~SC~IPTIO~!S ~.~, t~F__~~ ..... .: (Footage 0') Completed running 225 jts'. of 3 1/2" N-80 9.2# Buttress tubing ~ and accessories. Stabbed into ~ packers and tested' same , ok. Spaced out tubing. Cleared packer bores of seals. Displaced tubing and annulus w/ diesel. Landed tubing w/ locator sub 2' above top ~.~ packer at 6858'~H, 6875' tubing measurement. Removed BOPt~ and installed x-mas tree. Tested tree to Union Oil specifications - ok. Put well on gas lift. Rig released at 12'00 pm, 7/4/73. FINAL REPORT. o ,ELL i COI i,O, 1] LF~812 Trading Bay State ____DATE _ I, ELL i.I0., A- O FIELD Trading gay Field ,,DgTAILS_.OF OPERATLOIiS, Dt:SCRIPTIOj'S 8Rg,SU_J~S - t6"--Casing Detail jTS. ' LFJqGTI t BOTTOH TOP 16" ttowco Guide Sh6e 16" 65# H-40 8. RD j t. 16" Howco Stab-in Float Collar 16" 65# H-40 Buttress Csg. 16" Buttress x 8RD "XO" 16" OCT, Flt-thru hanger Below I~q~ to Uni-Head · 1 1.25 1246.17 1 39.02 1244.92 1 2.20 ~205.90 30 1160.91 1203.70 1 2.87 42.79 1 .92 39.92 39.00 39.00 1244.92 1205.90 1203.70 42.79 ' 39.92 39.00 · -0- 13 3/8" Casing Detail JTS. L{~NGTH BO1TOH TOP 13 3/8" Howco Float Shoe 13 3/8" 68# K-55 Buttress Csg. 1 13 3/8" Howco Float Collar 13 3/8" 68# K-55 Buttress Csg.3S 13 3/8" Bl# K-SS Buttress Csg.44 13 378"ttowco DV Collar. 13 3/g" 61# K-S5 Buttress Csg.~8 13 3/8" 61# K-55 Buttress Cut-off 13 3/8" OCT slip hanger Landed below zero .2.00 40.35 1.76 1387.80 1762.47 2.95 :1898.97 5163.63 5161.63 5121.28 5119.'52 3731.72 1969.25 1966.30 5161.63 5121.28 5119.52 3731.72 1969.25 1966.30 67.33 ' 28.83 67.33 38.50 1.00 38.50 37.50 37.50 37.50 -0- 9-5/8" L-iner Hanger ' 'firS' IJ~2QG'IT{ BOTTOH TOP 9 5/8" Float Shoe 9 5/8" 47# N-80 Buttress Csg. 2 9 5/8" Landing Collar 9 5/8" 47# N-80 Buttress Csg.28 9 5/8" N-80 Buttress Pup Jt. 9 5/8" 47# N-80 Buttress Csg.10 9 5/8" 47# N-80 Buttress Pup Jt. 9 5/8" 47# N-80 Buttress Csg.17 9 5/8" BOT Liner Hanger BOT Tie-back Stinger 9 5/8" 47# N-80 Buttress Casing 1 Insert Baffle Plate in Collar 9 5/8" 47# N-80 Buttress Casing 123 Landed below zero w/ wrap around slips 2.22 7475.93 7473.71 .83.02 7473.71 7390.69 2.30 7390.69 7388.39 1147.35 7388.39 6241.04 13.27 6241.04 6227.77 414.19 6227.77 5813.58 13.32 S8lS.S8 '701.00 5800.26 23,30 9 5/8" Tie-back String I .63 5076.00 5800.26 5099.26 5075.96 TOP 5075.37 36.00- '5073.37 5039.37 5004.37 5039.37 35.00 35.00 35.00 -0- DATE. OIL t,iEIL t<LC01 J. Trading Bay State FIELD Trading Bay Field. D~AILS_..0F OPEPATiOIiS, D[i. SCRIPTIOiJS £, RESU_LJ_~ ....... TUBING DETAIL JT. LENGII-I BOTTO}I TOP 3 1/2" ~'Ble Shoe 4 1/4" OD x 3 1/4" ID 3 1/2'.' Otis "Q" Nipple 3 1/4" OD x 2 S/8" No GO ID 3 1/2" ButtresS-Collar 3 1/2" 92# N-80 Buttress Tbs. 1 3 1/2" Buttress to .4" EI~ x-over 5" OD Otis seal Assem. bly 3 1/2"'ID 3 1/2" Buttress to 4" EUE x-over 3 1/2" 9.2# N-80 Buttress Tbg. 4 3 1/2" Otis "XO" sleeve 4 1/4" OD x 2.75" ID ' '3 1/2" 9.2# N-80 Buttress Tbg. 2 3 1/2" Otis '~40" sleeve 4 1/4" OD x 2.79" ID Inverted. 3 1/2" 9.2# N-80 Buttress Tbg. 1 3 1/2" Pup Jt. 3 1/2" Buttress x 4 1/2" EUE X-over 5" OD Otis Seal Assembly'3 1/2" ID 5 9/16" OD x 3 1/2" ID x-locater sub 4 1/2" EUE x 3 1/2" Buttress x-over 3 1/2" 9.2# N-80 Buttress Tbs. 1 3 1/2" Otis "XO" sleeve - inverted 4 1/4" OD x 2.75" ID 3 1/2" 9.2# N80 Buttress Tbg. 1 3 1/2" Camco KIg'IG blandrel 3 1/2" 9.2# N-80 Buttress Tbg. 10 3 1/2" Camco KBMG Mandrel 3 1/2" 9.2# N-80 Buttress Tbg. 37 3 1/2" Camco KBMG Mandrel- 3 1/2" 9.2# N-80 Buttress Tbg. 39 3 1/2" Camco KBMG Mandrel 3 1/2" 9.2# N-80 Buttress Tbg. 57 3 1/2" Camco Ktg~IG Mandrel 3 .1/2" 9.2# N-80 Buttress Tbgi 69 3 1/2" Otis Ball Valve Nipple 3 7/8"0D x 2.76"ID 3 1/2" 9.2# N-80 Buttress Tbg.. 8 3 1/2" 9.2# N-80 Pup Jr. Cameron Tubing Hanger Landed Below Zero .57 7170.76 7170.19 .71 31.58 .55 16.55 .87 124.65 7169.22 7168.51 7136.93 7136.38 7119.83 7118.96 6994.31 4.02 62.77 6990.29 6927.52 3.95 31.00 8.10 .50 9.15 .85 1.25 31.20 6923.57 6892.57 6884.47 6883.9'7 6874.82 6873.97 6872:72 6841.52 3.75 30.54 10.00 311.64 10.00 996.91 10.00 1220.24 10.00 1776.92 10.00 2154.97 6837.77 6807i23 6797.23 6485.59 -6475.59 5478.68 5468.68 4248.44 4238.44 2461.52 2451.52 296.55 4.60 249.54 8.10 .71 291.95 42.41 34.31 '33.60 -0- 0' Point 101' RT tO MSL Tubing ttanger 33.60 Tubing Accessoreis: 1. 3 1/2" Otis ball valve - 292' 2. 3 1/2" Camco KBMG b~ndrel - 2452'. 3. 3 1/2,, Camco KBMG Mandrel - 4238'. 4. 3 1/2" Camco KBS~S ~.'kndrel - 5469'. 5, 3 1/2" Camco KB~¥~ ~;~ndrel - 6475'. 6. 3 1/2" Camco KBMG Mm~drel - 6797'. 3 1/2" Otis "XO" - Inverted - 6838' 8. Locator sub & 5" seall Ass. - 6874' 9. 3 1/2" Otis "XO" - Inverted ~ 6924' I0. 3 1/2" Otis "XO" - 6990'. 11. 5" OD seal'Ass. - 7120'. 12. 3 1/2" Otis "Q" Nipple - 7169'. 13. 3 1/2" 5~ale Shoe Guide - 7170'. 5164' - 13 3/8" 61# & 68# K-55 Buttress Csg. -. Cement. to Surface. 5076' 6875' - 9 5/8" x 5" Otis Permanent packer. [. WELL SCt'~'gTIC TRADING BAY STATE ~LL A.30 7171' - 3 1/2" Tubing Tail.,' 7476' -.9 5/8" 47# N-80 Buttress Casing-Tied-back to surface w/ recepticle at 5076'. O I~AWN ..._____ SCALE 7/16/73 UNION .OIL COMPANY OF CALIFORNIA IMCO REPRESENTATIVE Hubbard~ Bruce Snodgrass TYPE MUD _hi .o.n~_t.~_ DEPTH FT. RECORD OF' DRILLING MUD TESTS A Division at HALLIBURTON Company 2400 VV~st Lo,~l) Sauth, P. 0 Box 22605 CASING SIZE John Hall~ Bill _ 13 3~-~!64t 9 5/8"-7475 ¢ HOLE SIZE NO. BITS NO. DAYS ALKALINITY 390 868 1255 1255 1712 Ran 1712 2000 2150 3020 3030 3176 3548 3548 3760 3760 4310 4310 4860 4860 5225 5225 Ran 1250 _U_.n_i_o~u0 i L ~kCa lifc~ n W~LL ~^~.~ & ~;, ......... 1'-'~/ ~o~.,,~ 1 '""~ I ~." WELL [.IELU COUN[Y CONTRACToRT~a~ng Bay_. .... Cook.Inlet Alaska Wodeco 14 15 -) 1.25 11 o J8~ 16 , 16 19.5 19,5 21~0 21 25.5 25,5 24 24 26.25 26,25 26 ,25 'co~£"Ts:T. Tzi. der ream 12 ." hole t'o 18"~ FORM SI4B REV. IG/72 PRT'D. U.S.A. 5M IMCO REPRESENTATIVE TYPE MUD DEPTH FT. 3100 3100 3571 3571 Twis 4216 4216 4852 4853 Open 522 5225 5225 5225 5225 5225 5544 5544 Need 5802 58O2 5886 5886 All e A Division of HALLIBURTON Company 2400 West Loop South. P, O. Box 22605 Houston, Texas 77027 A/C 713 622-5555 RECORD OF DRILLING MUD TESTS CASING SIZE HOLE SIZE NO. BITS NO. DAYS ALKALINITY COMPANY WEll NAME & 1'10. TB S~T_A_-.3O (Rage 2 ~ IlO ' ' FIELD COUNIY CONTRACTOR 9~,5; 27.5 , 23.7~ 23.75 25 25 10 10 8. 26,2~ 26,2~ 26,2~ 26,2~ 25o5~ 25.51 27 ~ 27 28 o 5( 28,5 27 27 .5 COAM~ENT$: FORM, $14B REV. 10/72 PRT'D. U.S.A. IMCO REPRESENTATIVE TYPE MUD DEPTH 6209 Chant 6350 6350 6894 6894 7283 7283 7432 743.2 7485 7485 7475 7475 7475 7475 A Division ef HALLIBURTON Company 2400 west toop South, P.O. Box 22605 Houston. Texas 77027 A/C 713 622-5555 RECORD OF DRILLING MUD TESTS CASING SIZE HOLE SIZE NO, BITS NO. DAYS ALKALINITY APl J STATE I COUNTY J .LL J / _ ' I I I I I / I ~ ' ,.~ ' BLUE 25.5 , 25.5 23.75 23.75 23°75 23.75 25.00' 25000 25.0 25.0 22.5 J, COMMENTS: . . ............................................................................................................................................. ' .................................................................. .~ . .. . . . FOR/~ ,SI4B REV. 10/72 PRT'D. U.S.A. 5J~ HUGHES TOOL COM': , ' PANY has available the i': following 'bulletins and :: i films to assist you in getting your hole down ~ in the shortest time and with the fewest bits: i "Hydraulics for Jet.i Bits" !: , ~ New Hughes Simpli- fied Hydraulics" !i' "Rotary Drilling Bits"' "Best constant Weight .'il and Rotary Speed" "Care and Operation of 'ii: Tool Joints" "Hughes General Ca/~ ~i log" ? ~ Motion Picture: "Re- :"~{ search in Rock" I~ Contact your Hughes ~ Representative. He will ~ welcome the opportun- ity to work with you on ! your next well and will ' 5 furnish you with the ? latest information on ~. rock bits and drilling ?.~ techniques "for you area. Compiiments of HUGHES TOOl. ¢O~PAN~]~. HOUSTON, TEXAS U, S. A. .... ,,o,, .... BIT RECORD COUNTY ' FIELD LOCATION IWELL NO. io,..A,o. ', * LINER DRI~ PiPE SiZE TYPE' O,O, NUMBER O.D, I,D, ~ENGTH DRAWWOR KS~~POW~R ~ s P M uuD DULU. COND. DEPTH ACCUM WT. VERT PUMP FORMATION NO, SIZE MAKE TYPE JET SERIAL FEET HOURS =T/HR DRLG. 1000 R P M -- ~ REMARKS 32ND IN OUT HRS LBS DEV' PRESS ATION 1 2 WT. VI~, W,L, T B G OTHER . ~ · ' ~ag ~,'~ '" HUGHES TOOL COM- PANY has available the following bulletins and films to assist you in getting your hole down in the shortest time and with the fewest bits: "Hydraulics for Jet Bits" "New Hughes Simpli- fied Hydraulics" ,~,,~ "Rotary Drilling Bit "Best Constant Wei~/~a and Rotary Speed" Contact your Hughes/~/~ Representative. He welcome the opporturT//~ //3 ity to work with you ¢ff(//~/ your next well and wiil~/~ furnish you with t latest information on rock bits and drilling techniques for your area. "Care and 0 Tool Joints" "Hughes General Icg" Motion Picture: search in Rock" Compliments of HUGHES TOOL COMPANY ~ HOUSTON, TEXAS BIT RECORD ' I TOOl,. PUSH ~'R CONTRACTOR . [i~G .o. IOU"RATOR /' I ,,,. TOOL DRILL JOINTS COLLARS . .::.. ~. ,~.~ ,.., ~2~_ s ~ ~ ~uo OULb. CO.D. .o...~,o~ NO. SIZB MAK~ TY~ JBT S~RIAg DEPTH FEET HOURS rT/HR DRLG, 1000 R P M DEV. RRESS ATION REMARKS 32ND IN OUT MRS. LBS ] 2 WT. ViS. W,L, T B G OTH[R il /~1~ ,, ,, ,,,/%~2~' ~2 ~:~7¢~ /~o ~7 ~~ 7~ ~?/043 ·z .- HUGHES TOOL COM- PANY has available the following bulletins and films to assist you in getting your hole down in the shortest time and with the fewest bits: "Hydraulics for Jet Bits" "New Hughes Simpli- fled Hydraulics" "Rotary Drilling Bits" "Best Constant Weight and Rotary Speed" "Care and Operation of Tool Joints" "Hughes General Cat~ log" Motion Picture: "Re- search in Rock" Contact your Hughes Representative. He will welcome the opportun- ity to work with you on your next well and will furnish you with the latest information on rock bits and drilling techniques 'for your a rea. Compliments of HUGHES TOOL COMPANY HOUSTON, TEXAS U.S.A. . BIT RECORO "~buNTy r,e~.o STAT" ...... I~C'r,o. ........ TO~,,, InANG,. ~.OCA~',O. w£~.~. O.D. ~, ~ ~ ~B~R O.O. I.~: DRAWWORK~ POWER TOOL ,,~:, ,N~: D~[~ ~,{')'* ' ., ,: ,.. , ,., ,. , ......... Accu. wT. ~ S P M MUD DULL. COND. NO. SIZE MAKE TYPE JET SERIAL DEPTH FEET HOURS FT/HR DRLG, I000 R P M ~¢RT PUMP - FORMATION 32ND IN ~UT HRS. LBS, DEr PRESS ATION ~ ~ WT, VIS, W,L, T B G OTHER REMARKS ,i . , , , ..... . ,, ..... . .... ,. , , , ,.,, , ,,., , . . ., , ', ,,,, '" , ', , . ,. ,, I 't ' n) ---- i l! , ,, .. ~ . _ ~ go. P-~ STATE OF ALASKA SUBMIT IN ~LICATI~: ... OiL AN~ ~AS CONSE. VATION CO~mEE ~n-~-~n~5 , WO.KOV[. O.[.mlO.S - ,, , N~E bF OP~TOR ............ 8. L~IT F~ OR LEASE N~E ~ION 0IL C~~ OF ~IFO~IA ...... Trading Bay State .... ~-3 ~fo~'~ Trading Bay Field co~.~:~~ Conductor 3. 1612 ~N ~ 551 IW of the S. E. co.er. .. s~c., T., R., ~.. (~OM ~O Section 4. TgN, R13~, S.M. o~ _ Section 4' T9N, R13W, S. M. 12 P~IT NO. , , , 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA~NG~ IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOLUlVFE~ USED, PEI:~FOHATIONS. TESTS ~ RESULTS FISHING JOB~ JUNK IN HoL2E A.ND SIDE-TRACKED HOLE AIN'D A~Y OTI-IER SIGNIFICANT CI-IA~GES IN HOLE COiN'DITIONS Commenced-operations at' 12-~01' am, 5/5/75. Operations from..the 1st of July through t~e 4th Of J'ul~:'when~ the Well was ~On~leted, are as follows. Completed perforating "D" Zone Pool as per attached table using 4" OD csg. gun w/ 4 HPF: SAND INTERVAL FEET 53-7 53-8 54-5 54-9 56-1 57.~2 6914-691~.=~ ~ 5' 7000-701~ ~ 15' 7040- 707CLI ~,l 30 ' 7188-7208 AU~ ~ t~"~4 20' 7224-724 - 7282_729~tVI${ON OF OIL .ANI) OAS 20' 10' 7336- 7348 ANCHORAOE 12' 7358-7366 8' TOTAL "Z)" POOL .PEPd~OP, AT!ONs 13S' Set 9 5/8" by 5" permonant production packer at 7112'WLM. Pooh w/ setting tools. Rigged down Dresser-Atlas. Rigged up and ran 225 its. of 3 1/2" N-80 9.2# Buttress tubing and accessories. Stabbed into WL packers and tested same - ok. Spaced out tubing. Displaced tubing and annulus w/ diesel. Landed tubing w/ locater sub 2' above top WL packer at 6858'WLM, 6875' tubing measurement. Removed BOPE and installed x-mas tree. Tested tree to UOCO specifications -ok. Put well on gas lift. RIG RELEASED AT 12:00 pm, 7/4/73. 14.1 he.by ee~if~that ih. fo~ng~~ eorre~ S~GN~~~ ~'. ~~~ District ~lg. s~t. ~,~ . 8/5/75 N~OTE --Report on'this fora is required for .~ Galendar ~nth~ regardless of the status of operations, and must ~ filed in dupli~t$ with tho oil and gas conservation commiflee bythe I~ of the suocNding mon~, ~len otherwise directed. Union Oil and Gas ~sion' Western Region Union Oil Company of California .909 W. 9th Avenue, Anchorage, Alaska 9(` Telephone: (907) 279-7681 union 4uly 13, 1975 Mr. Homer Burrell State of ~aska Division of Oil ~ Gas 5001 Porcupine Drive Anchorage, Alaska 99S04 T~S A-SO (1S-4) P-? COMPLETION REPORT P, 4 ']vD~Y REPORT Dear Mr. Butte!l: Enclosed please find two copies each, of the above captioned State forms for well TBS A-SO. VetX truly yours, $im R. Callender District Drilling Supt. JRC/sk E~cl. (4) REPORT _of SUB-SurFAcE' DI~ECTIONAL SURVEY LrNION OIL OF CALiFOrnIA COM~'ANY %~LL NAME JOB NUMBER COOK ASI573-D4 TYFE OF SURVEY SHOT ~GNETIC DATE SURYEY BY GE!~ TnI ~D~,UX 0?5 'i ~'~HPLETION REPORT JUNE?:.?, 1973 UN'ION OIL T.B.S. A-30 ~F~LLY ~5USH.ING ELEVATION 101 FT. NAG;'~cllC DECLI;tATION 2q DEG. TANGENTIAL. HETHOD (')F CO~!PUTATIONS P~PARED FOR EASTNAN OIL ~ELL SURVFY Ct). BY F.H. L[,';DSEY. AND ASSOC. RECORD OF SURVEY ALL CALCULAT I O~,~S TRtjE HEAS,, DRIFT VERTICAL SU9 DRIFT DEPTH ANGLE. DEPTH D hl DEG 235 0 25 300 0 15 360' I 20 421 3 40 452 4 ..30 483 5 0 513 6 0 543 7 0 604 . 9 0 ~65 11 0 738 1~ 0 83O 17 15 909 19 30 '1001 23 0 O. 0 0 0.¢1© -1~.]1.():) 35 0 0 35.00 -66,00 N 23~.99 133,99 f',4 41 .,~ 299.99 198.99 359,97 258,97 S 80 W 420.85 319.85 S 67 ~51,75' 350,75 S 60 482,63 512,47 542,25 602.49 662.37 733,21 821.07 895,5~ 980.22 3~1.63 S 63 w 411.47 S 61 441,25 S 65 501,49 S 74 W 561,37 632.21 S 71 720,07 S 71 ~'~ 794.54 S 72 87g.~2 S ~0 1092 27 30 1060,94 959.94 S 80 ~, 1173 31 30 1130,00 1029.00 S 82 w 1255 35 0 1197,17 1096,17 S 84 w 132.1 40 30 1247,36 11a6.36 S 85 w 1413 ~ 30 1312,98 1211.98 S 83 w 1505 46 151376,60 1275.60 S fl3 w TOTAL COOi'~D I NAT ES 0.00 S O.0() O,00 S O,00 1.13 N 0.98 1,32 N 0.77 1,08 N 2.15 0,44 S 5. lb 1,65 S 7.85 2,88 S 10,26 4,40 $ 13.OO 5,95 S '16.32 8,58 S 25,49 10,80 S 36.92 16,55 S 53.61 25,43 S 79.41 33.58 S 10q.49 39,82 S 139,89 47.12 S 181.27 53.01 S 223.18 57,92 S 269.gb 61,66 S 312.66 69,52 S 376.66 77,62 S 442,62 84,69 S 509.93 C L O S u R E S DI STANCE ANGLE D ..u. S OoOu S 0 0 0.00 S 1.50 ,'~ qO 59 59 w 2.41 N 03"22 15 w 5,'17 S ~ 3b 46 w 8,03 S 78 4 ~7 w 10,66 $ 7~ 18 2 w 13.73 S 71 17 23 17.37 S 26,90 S 71 38.46 S f3 41 30 w 5~.11 83.38 S 109.75 S 72 11 0 1~5.45 S 74 6 3~ *' 187.30 229 · 3V ~76.10 5 7~ 9~ 21 W 31~,b8 S 78 50 3b 383.02 S 79 32 32 w 516.92 DOG LEG SEVLRIFY DEG/iOOF! 0.000 0.000 O.21b 2.593 ~.907 3.119 1.800 3.394 3,657 3-859 3.b71 4.736 3,53~ 2.876 4.932 4.945 5.08b 8,38~ 4,589 1.902 3.74b S.ECTIoa D'IbTAaLE O · U 0 O,UO 1.07 0.88 2.2q 7.09 9,99 24,71 7 l. O8 43~,~3 ~01.34 · ~ECORO OF SURVEY ALL CALCULATIONS PFRFC)R~;£D BY ! B H ELECTRONIC COMPUTER TRUE DRIFT VERTICAL SUB DRIFT ANGLE DEPTH ' SEA DIREC D u DEG. 1687 53 ~5 .1.689,39 13.~8,39 S 88 w 1770 53 30 1538.76 1437.76 S H~ w 1838 52 30 1580,16 1479.16 S h2 W ~0~6 5B 0 169B.BO 159~.30 S 83 W 2.309 51 45 1868,50 1767.5D S 83 w 2591 51 45 2043~09 19a2.09 S 8a W 2889 51 15 219~.32 2097.32 S 84 '~ 292/ 51 45 2252.80 2151,~0 S 85 w B022 5~ BO 2809,~1 220~,B1 S 87 W ~1~9 53 ~0 2~84,85 228~.85 S 79 w 3~41 53. 30 2~99,05 2398,05 S 75 w 3435 5~ 45 2559,95 2454.95 S 75 w 3554 50 O 2632.44 2531~4~ S 79 W ~626 50 30 267~..24 2577.24 S 80 w .3700 51 0 2729,85 "2628.gb S ~0 ~ 3~()1 52 30 2786.46 26~5.~6 S ~0 w 3863 53 15 2823.56 ~722.56 S B1 w 3992 53 0 2901.19 2800,19 S 82 w 4085 52 30 2957,81 2856.81 S 82 w 4~-14 49 30 3015,6J 2914.61 S 80 w 4~67 45 45 3080,50 2979.~0 S 79 v.. ~59 42 30 3~48,33 3047.33 S 79 w 4430 4~ 0 3201,91 3100.91 S 87 w q492 40 ~5 3248,88 31a7,~ N 85 w 4578 39 O 3315.72 321~.12 =N 81 w ..~671 36' 0 3390.96 3289.96 ,"~82 w ~765 33 0 3~69~79 3368,79 N 82 W 49!9 30 30 3602,48 3501.48 N 67 w 5012 27 30 ~6~14,97 3583.97 N 66 W TOTAL COORDINATES C L O S U R 6 S P! STAaCE AN(~LE D M S 87,31 S 584,88 w 95,4a.S 651.11 w 102,95 S '?04.53 W 121,25 $ 85B.55 W 148~3~ S 10'F4.14 W 171.48 $ 1294.39 w 191.70 S 1486,74 w 197,72 S 1555.58 w 201,72 S 16~.85 W 221,20 $ 17~2.06 W 26~,14 S 1881,14 W ., 280,~1 $ 1953.h2 W 297,90 5 2042.90 w 307,55 S 20~?.61 w ]18.61S 2160.37 w 3~9,20 $ 2282.10 ~ 353o5~ S 2381.12 w 363,80 $ 2~57.18 ~ 375,~6 S ..2523.83 w 388,27 5 2589.22 w 400,13 $ 2650.2~ w 402,5? $ 269~.75 ~ 399.04 S 2737,0! w 390.57 $ R~90.5~ w 382,96 $ 28~4.66 w 37~,84 ~. ~895.3~ W 591,36 S 81 3~0 34 W 658,06 S 81 39 38' w 712.01 S 81 41 10 W 862,12 S 81 54 54 w 1084.3~ S 82 8 lq w 1305.70 $ 82 27 11 w 1499,05 $ 82 3'9 10 w 1568.10 $ ~2 45 22 w 1644.2T S 82 57 11 w 1746.13 5 ~2 43 19 w 1899.18 S 82 5 47 W ~973.4~ S 81 '49 41 w 2064.51 S~I 42 11 w 2120.04 $ 81 39 31 w 2183,74 S 81 36 37 w 2257.49 $ 81 33 27 W 2307.17 ~ l~1 ~2 44 W 2410.19 $ 81 33 5~ W 2483.97 5 81 34 4(3 ~ 2551.62 S ~1 32 10 w 2618.17 S 81 28 17 w 2680.27 $ 81 2~ )1 w 2726.6~ S 81 ~0 34 w 2766.0~ S 81 42 18 w ~817.73 S 82 I 56 w 2~70.32 $ d2 19 57 w 2919,69 S 82 36 13 W 2987,33 S 8~ 21 44 w 327,83 S 3006,53 W' 3024.35 S 8;3 46 37 W LEG SEVbRIIY DEG/IOOFI' 4.859 1.882 0.500 0.442 0.278 0.202 1.055 2,488 ~.0~ 1.675 0.798 3,497 1.274 0.610 1.613 1.766 0.650 0,538 ).796 4.110 ~,533 7,790 8.450 3.609 3.191 3.268 SL,.; r 1 ON ) RECORD OF :SURVEy ALL CALCULATIONS PEFIFOR~,:IED BY ! Ft ;,l ELECTRO;,:IC COMPUTER TRUE: ~'~'~$~ '6RIFT' VERTICAL SUB DRIFT D~.DTH ,AhlGL~ DEPTH SEA DIREC 5~09 2_7 30 ~0~7.05 393~.05 ,~ ....~03 27 3.0 ~20.~2 ~0Z9.~2 N 65 _.5703 23 ~0 ..... ~302.70 ~:20t.70 N 65 _5822 23 45. 4~1,62 4310,62 N 64 5967..22 ~_ 4~.~5,~2 %~4,92 N 50 6093 22.~5 .~662,12 ~5~1,12 N 52 ...9~.86...2:~. 45. 4747,89 ~6~6,89 N 52 ~2~8 23 30 ~804e7~ ~703,7~ N 46 W 63.11.2~ 0 4862030 ~761,30 N 46 w .~.3~ 24 30 ~06~49 ~g61,49 N 46 W 66.89 ~ 30 5206,26 9~05,2~ N 41 ~73..2.3 45 537~,68 5273,58 N ~l w 7090. ~4 0 5572,92 5~71e92 N ~1 W 726~ 24 0 9730e05 5629,05 N 39 W 7~20_._~4. 30 .....5873,82 577~,~2 N 39 W .3~85 24 30 5932e97 583],97 N 39 W TOT AL C'OORDINATES 290.87 $ 308.5,7':; w 266,.19 5 31.32,22 W 2q6,~8 S 3],70.89 w 228,1~ $, 3210.23 W 209,92.. 5 .....3251,15 W Zg~,oB 5 3285,12 w 173,O7 S 3328,20 w .. 139,22_5 3371'09 W 109.23 .5 3~09,~9 W 69,91 S 3459,61 W CLOSURES DI STA?,CE ANGLE , D M S 3099.q7 S 84 36 54 W 3143,51 5 ~5 8 32 W 3180.45 $ 8:5':33 18 w 3218,33 S 85 56 5 w 3257,92 5 B6 lB 20 W 3290.85 S 86 37 .S w 3331,70 5 ~7 1 23 W 3356~84 5 ~7 Z~ ~ w 3373,97 5 87 38 5 w 34~1.2~ 5 88 9 5~ w 3~3S,93 5 8~ 3~ 95 w 3~56,32 5 88 50 ~7 w 52,11 S 3~74,05 w. 3474.44 5 ~9 8 25 w 25,03 .S 3502.09 W 11,25 N 35~.57 W 60e70 N 3582,66 W 116,63 N 363.1,28 w 183,24 N 3689.18 W 237.6Z N 3733,21W 288.53 ~ .3.774,44 W 309,48 N 3791.~O W ~;r]-0,~l H. OLE .CLOSURE 3P, O~.,'J2 FEET AT ;~ 85 20 0 ~'..-' 3502,18 S 89 35 25 w 3539.69 N 89 49 3 W 3583,17 a S9 I 45 w 3633.15 N 8U 9 37 W 3693.73 a 87 9 22 W 37~0.76 N 85 21 28 W 3785.45 ~, ~5 37 42 w 3804,o2 N 85 ZO 0 w DOG LEG SEVLRITY DEGIIOOFT 0.27¢ 1,~11 0.727 0.982 2.395 1.654 0.397 1,86~ 0.848 0o000 3.987 0,79~ 0.532 0.000 1.312 0.~08 u.l15 0o~7~ .0.316 0o000 .SE C T l o;~":"' O I'.ST A,"'~t" 3051,8'/ 310'0.15. 31~0..30.,:~ 3181::'.0 3303, 33~,28 3~,8 8.,/, Z...-. 3~ 3'¥ ~.)~ ~ INTERPOLATED TRUE VERTICAL DEPTHS, COO/<D-INATES AND CLOSURES FOR GIVEN DEPTHS ....... T F,t. IJ ~ CODE ~4 'F. ASUPED VER [ f CAL N/~ !? E DE P T H D ~ P T H T~': 1' AL COORD INATFS C L o S U t< E SUB D I ST A~NC~-{ ANGLE SLA D M $ 26-7 FOV 26--7 SAND 28-6 SAND. 3 I--B SAND 33-,5 SAND 40-4 SAND' 4 1=8 SAND 44-7 SAND C-2 SAND C-] SAN D C-4 SAND' C-6 C-7 SAND 47~5 SA F. ID ~TRAy SND 50-3 SAND 59-6 51-6 SAND 53-0 SAND 5TRAY SND 53-8 SAND 5~-5 SA~D 5~-9 gAND 55-7 SAND 56-1 SAND 57=2 SAND T,D, 3482 25fl6,16 287,3B 3930 2f163,P. 8 3~.6,65 3984 289.6,38 352,65 4168 3011.71 374.76 4641 3366,69 385.42 4790 3491.33 3-;0.88 · 4872 3561.99 354.62 4945 3625,54 34('.), 42 4980 3656,59 333. ~14 5277 B920,11 274,56 5422 a(.)48.5f~ 243,95 5482 4101,80 232.24 5561 4172,99 218.17 5638 4243,09 5706 5820 4409,79 173,42 5918 4500,~9 151.02 6144 a709, 15 97.0U 6312 '4843,21 51.a2 64F~0 6511 5044 6600 5125,28 32,85 6690 520 6843 5347,22 10?.51 6903 6937 543~,15 ~36.28 6995 7036 5523,59 ~66,~7 7107 5588.45 188.62 7161 56~7,78 205.69 7275 5741.88 241.80 7485 6709,62 825.81 1988.76 W 2009.42 S 81 ~+6 38 w, 2~+8b.16 2335,09 w · 2360.68 S 81 33 21 w 2'762.88 2377,79 w 2403.80 S 81 33 50 w 279b.38 2519.34 2827.19 2907,03 29.45,84 2978,27 2993,03 3116,~+? W 3176.3~ 3~32,62 3285.21 3327,~8 3357.03 3;25.03 352~.~b 3533.7~ 3.582,92 3623.35 3639,28 366~,83 3674.77 3707.35 3786.60 2806.90 2547,06 S 81 32 20 w 2910,71 2853.35 S 82 14 12 w 3265,69 2930,60 S 82 ~3 ~+5 W 3390.33 2966.62 S 83 8 4 ~ 3~60..99 2997.66 S 83 28 ~5 ~ 3524.5~ 301~.59 S 83 38 7 ~ 35~.59 3128,5~ S 8~ b7 54 w 3819.11 3185,69 S 85 36 29 w 3947.58 3209.85 S 85 3239,98 S 85 8 20 w 4071.99 3268.07 S 8b 24 3291.91 5 86-37 45 W 4204.40 3331.99 S 87 0 59 w 4308.79 3360.43 S 87 25 26 ~N 43V9.49 3426.41 S 88 22 ~ w 46()8.15 3~74.73 S 89 8 4~ , 4~62.21 3524.50 N 89 43 3~ W 491~.08 3533.78 N 89 46 55 ~ 4948.29 3558.60 N 89 28 15 , 5024.28 3583.44 N 89 1 27 W 3624.94 N 88 18 1 w 52~6.22 30~1.46 N 8~ 1 10 ~ 5301'09 3650.90 N 87 bl 38 W 5~2.15 3667.07 3678.55 N 87 2~ 11 W 5422.59 ~69U.35 N 87 4 35 W 5487.45 3713.06 N 86 49 27 W 5536.78 374~.42 N 86 17 50 w 5640.88 2925.86 S 73 36 20 E 6608.62 HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN lOO FEET OF ScA DEPTH. ~,~E A.StJR ED ...... DEPTH 201 ~+01 .. ....... 602 705 8O9 .... 1 · 1260 1396 · . 1"§~3 ... 1 .., .......... 4152 ~295 ..~ 4~29 ...... ..... ~559 4917 707 873' 038 200 361 523 684 843 008 505 82'5 TRUE VERTICAL StJB MD-TVD DEPTH SEA DIFFEF~FNCE · 201 · 100 · 0 301, 200. 0 401, 300,, 0 501' 400, 0 601 · 500, 1 701, 600, 4 801, 700. 8 901, 800. 14 1001, 900. 23 1101, 1000. 38 1201. 1100, 59 1301. 1200, 95 1401, 1'300. 142 lfiOl., 1400. 206 1601, 1.500. 272 1701 , 1600, 337 ].801. 1700, 399 lgO1. 1800. 460 2001, 1900. 522 2101, 2000, .583 2201, 2100- 642 2301. 2200. 707 240I . 2300, 775 2501, 2400, 843 2601, 2500, 904 2701, 2600, 961 2801, 2700, 1024 · 2901, 2800, 1091 3001, 2900, 1151 3101. 3000, 1194 :3201, 3100, 1228 ~301, 3200, 1258 3~01, 3300, 1282 · ~501 · 3400. 130o 3601 . 3500, 13 16 VERTICAL 0 0 0 0 1 3 4 6 9 15 21 36 64 66 65 62 61 61 59 65 68 68 61. 63 67 60 30 18. TOIAL COO~{D I ~'4A'rES 0,94. N "'0,81 W 1,32 N 0.80 W 0,05 iN 4,58 W 3,82 S 11,95 W 8.51 S 25.26 w 1~.93 S 46,02 w 23,40 S 73.52 w 33.98 S 106.77 W 41,70 S 150,54 W 50.5~ S 205.58 w 58,21 S 27~,21 W 6B,08 S 36~,97 W 80.60 S q71.03 w 89.22 S 600e45 W 106.~2 S 731,97 W 122.44 S 863.24 W 137.B9 S 989.15 w 152.64 S 1115,13 w 16~.90 S 1241,29 W 179,02 S 1366.14 W 191.99 S 1490.12 w 201.1~ S 1620,63 w 226.84 S 1753,14 w 261.80 S 1883,6~ w 290.75 S 2006.11 W 312,~3 S 2125.29 w 334,~7 S 2252..26 W 353.50 S 2383,86 372,59 S 2506,98 W 391,85 S 2607,66 W 402,52 S 2695,95 w 392,~4 S 27'78,75 382.06 S 2851,1~ W 368.66 S 2912,21 W ~5,6~ S 2966,50 w c,IEASLJR[~D DEPTH AND OTHER DATA FOR EVEi4Y EVEN t00 FEET OF SUB SEA DEPTId, ............. DFP TRUE VERTICAL SUP... DEPTH SEA vE R T ][ CA L. CO~,.,:-., [.C F I ON TOTAL COORDI;WATES 903° ~?03. ,, 3600. 1329 .............. 5143 B801. 3'700, 13~2 · ~.~r~ 3901, 3800. 135~ ........... . ~,~ ~ ~ ..... ........ 536g .......... 4001, 3900. [367 5592 4201, ~100, 1391 "5701 ~01, 4200, 1400 .............. . ........ ....... 5~I0. ~01, 4~00, 1409 5919 4501, 4400. 1418 6027 4601, 4500, 1426 6!35 4701 ~ h6<)0 ~ 1434 .. ............... 6354 090I, 4800, 1453 .. ... 6463 5001 · 4900 ~ 1462 .......... 6573 5101~ 5000~ 1472 ............. ...... 6 6 ~ 3 .......... 5 2.Q ! · 510 o ~ 1 ~ 8 2 6 9o2 701 l 72 ?,. 0 ............... 5301. 5200~ 1491 5401. 5300. 150t 5501, 5400. 15t0 5601, 550(]),, 1.520 5701~ 5600~ 1.529 13 ~3 9 9 8 .. 9 10 9 10 ..! o ~o 9 lo 324 · 35 S 302,58 ,5 279,3/~ .5 25.5,00 $ 232,41:5 212,86 `5 19~ .39 S 175,12 S 3014.01W 3060.69 W 3107,49 w 3154.17 w 3201,06 W 32~,55 W 3284,45 w 3324,00 W 150,89 $ 3357,19 W 125,01S 3389,29 W 99,19 S 3~22,33 W 71.04 S 3454.44 W 39.86 S 3486,73 W ~,20 S 3519,5~ w 2~+.50 N 3551.19 W 5)8,89 N 3581,08 W 92,16 N ~610.01 W .... ;i 125,47 N 3638,96 W ....... 159,08 N 3668..~17 w ................ 227.5~ N 3725.0"1 W ........................ · ................. -:. 10 262.74 1'4 .~..7.53o55 W FOR I.:'V!Ti'.l 1.000 FEET OF ,..'..~IT'.ASU~ED DEPTH° !'i,' F: l'i~ Ti' t D E P T H S E A TOTAL C,JC, F~DINATES !000 97.90 87B,~ 2000 1677~ 157G~ 3000 2296~ 2195. 5000 367~ 3573~ 7{')()C) 5~90, 5389, 39,75 S 139.51 W 118~71 $.,- 832.94 W 200,79 S L:x~'~ 161~.19 W 131,37 S 3381.15 W I55.62 N 3655.17 W VERTICAL SECTION SCALE I": I0(0' UNION OIL T.B.S. A-..~O 40o i'~ TM D 4084' \ \, \ \ '\ TVD: 5927' Tt',?. D: .q24' 'i80'0~ ,'2C0 0 i 000 HORIZONTAL VIEW SCALE 1"=5OO' UNION OIL T. 13.S. A 50 l~orm No. lq.L"V, ~,- I-?0 STATE fi,, ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND' WORKOVER OPERATIONS 1. WELL 2. N'AMF. Or OP~TOR. '4. gocA~io~ or OTH~,I~ 5.-Ap! N'I~ERIC~L CODE LEASE DESIGI~tATION A.%'D SERIAL NO, SUBMIT IN DtIPLICATE IF INDIA~, AIX)TTEE OR TRIBE ;i. PI~M'IT NO. R~6aT "TO~AL DEPTH AT E~D OF MONTH,' CHAN~ES iN' H0~E sizE. cASING A~ C~TING JOBS INCLUDING DEP~ SET ~ VOL~ USED, P~O~TIONS, ~TS ~ ~SULTS FI~IHG JO~ J~K ~ HO~ ~D SIDE-~C~ED HO~ Set 9 5/8" by 5" permenant production packer at 7112'~4. NOTE: W_ill co_replete well as a "D" Zone producer w/ an isolation packer. above the 56-1 Sand. JUl. ANcHOItAG~ 14. I hereby t th~ ................. ~ s m mm mmJm m mmmmmmm mmmm i i i i i iJ i Document Transmittal Union Oil Companv of Ca' unlen DATE SUBMITTED AccOuNTING MONTH 7/11/73 TO FROM ~ohn Levorsen W o Do Adams AT State Div. of Oil & Ga~T 3001 Porcupine Drive Anchorage Anchorage TELEPHONENO. TRANSMITTING THE FOLLOWING: Tgg A-30 (13-4~ MonoDod - 1 Sepia & 1 Blueline of each: 2", 5" DIL Runs 1 & 2" 5" Sonic " " 2" 5" FDL " " 5" Gamma Ray Run 2 J[ ~t, ! ~ I973 .... 'r ~IL AND ....... I ~v Date- CO~: .... FORM 369 (REV 2/70) PRINTED IN U.S.A, Form N'o. P---4 REV, ll- I- 70 STATE oF ALASKA SUBMIT IN DUPLICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS ~I~LL 2. NA.ME OF OPE~L&TOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OP]~ATOR 909 West 9th Avenue, Agchora£e, Alaska 4. LOCATION OF WELL Conductor 3' 1612'N & 551'W of the S. E. corner. Section 4' T9N, R13W, S. M. [5. API N~{EmCAL ~ODE 50-133-20253 6 LEASE DES/GNA/ION AND SEIKIAL NO IF INDiA~, ALOT/'EE OR TRIBE NAME 8.L.~IT FPdRAI OR LEASE NAME Trading Bay State WELL NO A-30 (13-4) 10 FIELD A_ND POOL. OR WILDCAT TradSng Bay Field 11 SEC, T.. R., M. '('BOT'TO~,I HOLE oB,mcrrvFD Section 4' T9N, R13W, S. 12 P~R~IIT NO 13.REPORT TOTAL DE~TH AT E2qD OF MONTH. CHkNGF. S IN HOLE SIZE. CAS1NG AN/3 CE2VIKNTING JOBS INCLUDING DEPTH SET A3qD VOLLrNFES USED. PERFOI:LATIONS. TESTS .*~.N'T) !:~ESULTS FISHING JOBS JUNK LN HOLE A. ND SIDE-'I-P,.ACKED HOLE A~ND A.NY OTI~EI% SIGNIFICANT CI43%NG~ IN HOL~ CONDITIONS Commenced operations at 12:01 am, 5/5/75. Operations from the 1st of .June through the 3'0th' o3 June are as folloWs· C°htinUed drilling at 6894'. Drilled and surveyed from 6894' to 7432'. Circ. and cond. mud to log. Rigged up Schlumberger and ran DIL-GR, B}~-Sm]ic, FDC-GR and CBL-GR logs. Rigged down Schlumberger. Drilled 12 1/4" hole from 7423' to final TD at 7485'. Circ. hole clean. Ran 2400' of 9 5/8" 47# N-80 Buttress liner to 7476'. }-lung off liner on BOT liner hanger w/ top of 5076'. Cemented w/ 1250 sx. of class "G" cement w/ 1% D-30 and .75% retarder to 120#/ cu. ft. Float equipmen~'-~failed to hold and cement back flowed into liner. CO to top of liner at 5076'. Liner lap failed to test. Squeezed lap w/ 300 sx. of class "G" cement to a maximum final pressure of 1700 psi. Perf. the 28-6 "B" Zone Sand from 4174' to 4180'. Drill stem tested 28-6 "B" Zone Sand - no fluid entry. Squeezed perfs, from 4174' to 4184' w/ 300 sx. class "G" w/ 1% D-31. Drilled out squeezed cement and CO to top of liner at 5076' Dry tested liner lap w/ 1500 psi differential pressure. Held ok. Pressure teste~ 28-6 sand perfs from 4174' to 4184'. Failed to hold. Resqueezedw/ 200 sx. class "G" w/ 1% D-31. Failed to get squeeze presstme. Spotted 200 sx. in 13 3/8" csg. from 4213' to 3950'. Pulled drill pipe to 3800' and braiden head squeezed 28-6 sand perfs from 2174' to 2184' w/ 1800 psi final pressure. Drilled out cement m~d test squeezed perfs-ok. Drilled out cement in 9 5/8" liner. D ' ' ,,an CBL Gmma-Ray logs from ETD at 7385 to to 3800 . Ran Sperry Sun Gyro survey from ElD to surface. Ran RTTS tool. Tested 9 5/8" liner to 3000 psi. held ok. Ran thru tubing w/ perf. gun and shot the "B" Zone 44-7 Sand from 5336' to 5338'. Unable to breakdown perfs, w/ 3000 psi. Reshot smne interval. No breakdmm. Pooh w/ RTTS tool. Reshot 5328' to 5330' w/ 4" csg. gun. Brokedoxm at 3000 psi. Squeezed perfs, w/ 100 sx. class "G" cement to 2350 psi. I)rJ. lled out cement in liner to ETD at 7385'. Displaced well w/ 70#/ cu. ft. invermul. Set EZSV cement retainer I ) i~ Ii I I I I at 5278 . terf. B Zone 31-8 Sand from 4648 to 4684 and from 4692 to 47~2 . 13 3/8" RTTS tool on 3 1/2" tubing w/ gas lift valves. Set test tool at ~598'. Dis- placed tubing in annulus w/ diesel. Gas lifted well and tested "B" Zone 0].-8 Sand-no fluid entry. Acidized perfs, from 4648' to 4684' and from 4692' to 4742'. Gas lifted well back in. No formation fluid entry. Displaced well w/ 71# invermul. Pulled tubing and test tool. Perforated the "B" Zone 33-6 Sand from 4794' to 4840'. The 40-4 Sand -- No. P--4 $-1-70 STATE O,. ALA,SKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT EN DUPLICATE APl NUA~ERICA. L CODE 6 LF, ASE DESIGNATION AND SE'SIAL NO MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS W[:LL ~'K;LL OTH ~-1~ 2. NAME OF OP~q. ATOR 8. L,~IT F.~'~,'I OR LEASE NAME 3. ADDRESS OF OPIgl~TOR 9 WELL NO 4. DCA'lION OF WFJ.,L l0 FIELD A.ND POOL. OR WILDCAT I1 SEC. T.. R.. M. (BOTTOM HOLE OBJ-F, crrv~ 12. PERMIT NO 13.REPORT TOTAL DEPTH AT EuND OF MoNT'Hi CHA. NGF-.S IN HOLE SIZE. CASING AND C~iEd":TING JOBS INCLUDING DEPTH SET AN~) VOLLFM'ES USED. PERFOI:~.TIONS. q-F. STS ANqD 1R]gSULTS FISHING JOB~ JLq~K LN HOLE AND SIDE-TR~ACKED HOLE A, NDANY OT/nEER SIGNIFICANT CH.A_~GF, S IN HOLI~ CON-DITIONS from 4878' to 4898' and the 41-8 Sand from 4986' to 5040'. Reshot the 31-8 Sand in- terval from 4648' to 4684' and from 4692' to 4742' Ran RTTS tool on 3 1/2" tubing w/ gas lift valves and set tool at 4596'. Displacgd invermul w/ diesel. Gas lifted and production tested the "B" Zone interval. No formation fluid entry. Acidized the "B" zone. Put well back on gas lift. Unloaded acid and diesel. No formation fluid entry. Treated perfs, w/ 200 bbls of diesel w/ 1/2 gallons of Hyflo Surfactant per bbls. PUt well back on gas lift. Unloaded I-¥flo Surfactant and diesel. No formation fluid entry. Displaced well w/ 70# invermul. Pooh w/ test tool. Ran 9 5/8" 47# N-80 Buttress casing tie-back string. Cemented w/ 1900 sx. class "G" cement and set into recepticle at 5076'. Got approximately 100 cu. ft. of cement returns to surface. Installed 9 5/8" csg. head spool, B©P's and tested to Union Oil Company specs. P~an 8 1/2" bit and CO 9 5/8" csg. to ETD at 7375'DPM. Tested csg. w/ 2000 psi - ok. Rigged up wireline and perforated "D" Zone pool as per attached table using 4" OD csg. gun w/ 4 }~F: SAND I~VrERVAL FEET 53-7 6914-6919 5' 53-8 6941-6956 15' 54-5 7000-7015 15' 54-9 7040-7070 30' 56-1 7188-7208 20' 7224-7244 20' 57-2 7282-7292 10' 7336-7348 12' 7358-7366 8' TOTAL "D" POOL LONG STRING PERFORATIONS Form P--3 '~' Smbmtt "Intentions" in Trtpli~at~ '~ ]-- ' REV. 9-30~9 & "Su~quent Repo~s" m Dupli~te STATE OF A~KA - '~ : ' Am ~ .... ~ ~.~c~ coo~ OIL AND GAS CONSERVATION CO:MMI~EE /~. 50-~-20~53 ~' 1' ..~ g~a~.:o~ ~g s~.~. ro, '"CE "E , SUNDRY NOTICES AND REPORTS ON W~ 1. ' - 7.IF I~I~, ~O'l"r~ OR TRIBE N WELL WELL ~ion 0il Co. ay of Calif. Trad. i~g Bay gists 909 West 9th Avenue~ ~chorage, Alaska 99501 A-S0 (15-4) ::~~AFT J~_ .,,~.~c~ Trader ~y Field Conductor #3. 1612 ~N f 551'W of the SE comer, n. sEC.,o~E~v~) T'' R., ~., (B~OM HO~ Section 4' T9N~ R13W~ S.M. Section 4: T9N~ R13W, S. 13. ELEVATIONS C , 14. Check Appropriate Box To Indicate Niature of N~ti'ce, Re, NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANOE PLANS ~Other) zort, or Other D~ta ' SUBSEQUENT REPORT OF: WATER SI, UT-OF, I REPAXR,NG WELL FRACTURE TREATMENT ~.J ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR CO.MPLETED OPERATIONS (Clearly state all pertinent details, and gh'e pertinent dates, including estimated date of starting any proposed work. Please note the above surface location for Trading Bay State Well No. A-50. On past reports submitted to the State on this well, we carried for a surface location' Conductor #27' 1604'N ~ 559'W of the SE comer. This incorrect and the location should read as is stated above. Dist. Drlg. Supt. DATE DATE June 22, 1975 See JrnStrucfions On Reverse Side ~.~ ~To. ~'~ STATE 0t- -ALASKA l~%'V. ~- 1-70 OIL AND GAS CONSERVATION CON~AITTEE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS STjBM~"r I1~ DU'PLICA~ 0IL [] G~.O [] wI~LL w~LL OTHER TOR Union 0il Company of California 909 West 9th Avenue, Anchora e~ Alaska 99501 Conductor 27: 1604'N ~ 559'W of SE corner, Section 4: TgN, R15W, S. M. 50-133-20253 ~A~ON NO. TRIBE NAME Trading Bay State NO A-30 (13-4) T., 1%., M.. )M HOLE oB.mmuv~ Section 4: TgN, R13W, S. M. Ii. pERMIT NO. ~D OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND C~iENTING JOBS INCLUDING DEPTH IN HOLE A_ND SIDE-TRACKED HOLE R~ORT TOTAL D~ SET ~ VOL~ USED, p~O~TIONS. ~TS ~ ~SUL~ FISHING JO~ J~K ~D ~Y O~R SIGHIFIC~T ~G~ ~ ~O~ ~ITIONS. ed o erations at 12:01 ~; '5/5/75. ~erations from ~M 5th of ~y through ~~;~ ~-~ -ows: Installed 20 ~i-head on 20" ' d u 20" k dril, riser ~d choke d~verter assy. Drilled 12 1/4" drive pipe. N~pple p___ Y · ,' at 1255'. ~ 31 jts. of ' ' all to 1Z55'. ~ened hole to 22 to ~ . ~e~~~es;cas~ng ~d set,at 12~6'.. C~ented casing to surface w/ ~35 sx. class "G' cement w/ 1, CFR2 ~d 8, pre-hydrated gel. Followed by 250 sx. class ,, ,, ~ 'lled 12 1/4" hole directionally to 5225'. ~ened hole to 18" G w/ 3, CaC12. _DrI ..... . ~ ~,o,, ~ ~d 68~ K-55 Buttress casing to p194'~ · ~ ~ at 5225'. g~n l~u j~s. ox ~a ~/o ~. . ....... ,~ ~. ,nd 8~ hre-hydratea c~tad casin~ to surface w/~ ~. cla~_ ~ ~e .... ~ ,= ~,~,, ~w ~d tested to ~ion Oil Co~y specI~ca~lons. ~xxxuu ~., .... Now: Drilling ahead at 6894'. JUN DIVI$1CN (,F OIL AND GAS ANCHOR^~E 14. I hereby ce t the ,for i~ ' tru co · · __ _ $IGlg~D NOTE ---Report on this form is required for lOCh colendor ~flth~ regQrdlesS of the Ireful of operotiofls, Qfld must ~ filed in duplicate with th e oil Qfld gas conmervat~n commiflee by the IS~ of the suQc~ding ~n~, ~le~ otherwise directed. Form P--3 REV. 9-30-6 9 STATE OF ALASKA S~bmtt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATIO, N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APP-LICATION 'FOR ~-ElrC~i'['-L~' 'for such 'pi:o~osals~) _ . · . . 5. AP1 NU-ME, R/CAL CODE 50-133-20253 6. LEA~E DES,IGN~,TION A-ND SERIA. L NO. ADL - 18731 7. IF INDIA_N, ALLO'rT~:E OR TRIBE NANLE OiL ~ OaS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FAH1Vi O1{ LEASE NAME Union Oil Company 0£ California Trading Bay State 3, ADDRESS OF OPERATOR 9. Vf]~LL NO. 909 West 9th Avenue, Anchorage, Alaska 99501 A-30 (13-4) 4.LOCATION OF WELL Atsu,~ce Conductor #5: 1612'N ~ 5Si'W of the S. B. corner: Section 4: TgN, R13W, S. M. 10. FIELD AND POOL, OR WILDCAT Trading Bay' Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 4: TgN RISW, S. M. 13. ELEVATIONS (Show whether DF, RT, OR, etc. 12. PEH/VI/T N'O. RT 101 ' above MSL. 14. Cl~eck Appropriate Box To Indk~te N, ature of NOtice, 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 ABANDONs CHANGE PLANS Other) SUBSEQUENT REPORT OF: WATER 8HUT-OFF 1~_. REPAIRINO WELL '~.~~[ FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING ABANDONMZNTs (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DF. SCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. Casing setting depths have been extended, based on revisions of the directional program causing increased measured depths as compared to vertical depths. Revised program: 1. Drill a 12 1/4" h01e to K0P of 300' - Directionally .drill 12 1/4" hole to +_1250'~D. Open hole to 22". 2. Set 16" conductor at 1250'5D and cement to surface. 5. Drill a 12 1/4" hole directionally to 5100'MD. Open hole to 17 1/2". 4. Set 13 5/8" casing to 5100'MD and cement to surface. (61# ~ 68#-15 5/8" csg.). 5. Drill a 12 1/4" hole direction~lly to 7417'MD or 5927'TVD.~./ 6. Run required logs 7. Run 9 5/8" casing and cement as required at 7417'5D.~:/" 8. Complete well as a dual o ii.well. 16. I hereby c~r]ffy that the f~regoi~gais true and correct SIGNED I Ir~.,.~ ~ ~.~ __n__ ---- ~-- TITLE OlVi$1/>i'~ ·.. i"' OiL /:,ND OAS ANCHORAO~ District Drlg. Supt. D~TEMay 4.i 1975 (This 'space for State office use) APPROVED BY ~'' CONDITION8 OF ;APPROVAL, IF TITLE See Instructions On Reverse Side Union Oil and Gas Divip~q,n: Western Region Union Oil Company of California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 unl, n Spril 26, 1973 Hr. Gilbreth Oil ~ Gas Division State of Alaska S001 Porcupine Drive Anchorage, Alaska 99S04 RE- TBS A-SO Dear Hr. Gilbreth: Enclosed'please find one copy of the BOPE Program that should have been enclosed with the P-1 Form for the above captioned well. David Johnson Drilling Engineer DJ/sk Enclosures , , I !_?~_.~ 't' '~'"~'~" :~ J , ,s.~C -_~ C~FER~ FilE: APR 3 0 1973 DIV~$1ON ¢;F OIL AND GAS ANCHORAOE · :. · · CHECK V~L VE o. . I ._ · , . 'BLIND I · ,. o .o. ,~NGL ED FILL UP LINE · · · · - · .. HYDRIL · o ., . PIPE £A,VS HYDRAULIC OPER,4 TED VALVE . GATE OR LO-TO~?2U£ G~TE OR LO-TO£~JE · GATE VALVE PE~dlRED GATE VALVE " · _. __ · . __. .. ' ?iPE ~AI4S · -.- · · ' "~:k'-"" I ' , I AP'~· · :~~~"' i' ..... --- ' ' i ~- '~ ' · k~¢~O~A~. · . . . NOT~' ~ ' ' ALL ~HANGE~ N~UST HAVE WRITTEN , ' - - mAPPROVAL BY', THE DISTRICT -- ' DRILLING SUPERINTENDENT' CHOKE .o '~.~..-..- 'L.,e. VALVE ' ,, '° ...:L::t.t ' . . . - . ._ . - . o GAUGE L P. VALVES '.~ POSI17 VE CHOKE ..'. .. ADJUS T/, £L F CHOKE ~ If Vn~n ~!I fulni~h · · , ~,,.~.'. ~/,, _f~' lC' I I · - . '" 'ANCHORAge\ ' · NOTE: ' : ALL-' CHANGES ~',!UST HAVE V,"RITTEN APPROVAL BY'THE DISTRICT DRILLING SUPER',HTEI';DENT. I, tlHIIfU/,t STANI~AP, D C'tlOKE I,·~/.I,'IFOLD ASS£t,!£LY I I 1 , I i . ' ! : , i , ; I 1 i- , t l C {.-.~tc& - · I - . i 1 t 1 t J , i i I · i i · t ' i ._ L.),,u : /dP ?P--- /d ~ DtV~$1©N C,F OIL AND GAS ANCHORAGB Union Oil and ,C~-% Division: Western Region Union Oil Company of California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 unl. n April 24, 1973 State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 J"~CQNFER: _ TRADING BAY FIELD CONSERVATION ORDER NO' 93 Gentlemen: Union Oil Company of California, on behalf of itself and Marathon 0il Company, requests an exception to Rule 4 of Conservation Order 93 to allow the drilling of the Trading Bay State A-30 well. Said well will be completed in the Middle Kenai "B" and "D" Oil Pools of the II-A Fault Block. The upper completion of this well will be the only point of withdrawal in the II-A Fault Block "B" Pools and will provide primary oil production. The present status of the "D" Pools development in the I I-A Fault Block is three injection wells and nine producing wells and is shown on the attached plat. A-30 is proposed as the final p'roducing developement well for the "D" Pools. This well is to be located in the northwestern portion of the Pools and will drain an area of approximately forty acres. Due to the production decline and "watering out" of well A-19L, A-30 is a necessary replacement withdrawal point. Future plans to convert A-12RD to a "D" Pools injection well at the northwestern-most point in the Pools will provide a peripheral point of injection on the northern flank of the Pools. The injection point will increase sweep efficiency along the northern, flank. A-30 is a necessary withdrawal point to assure an easterly movement of the A-12 flood front. Absence of the A-30 withdrawal point could cause a southeasterly movement of the flood front. Such movement would greatly decrease the sweep efficiency of the "D" Pools waterflood. The proposed A-30 location brings the number of "D" Pools completions in the southeast quarter of Section 4, T9N,' R13W,S.M. to five, necessitating this request. State of Alaska Oil and Gas Conservation Committee Conservation Order No. 93 -2- April 24, 1973 Union and Marathon are the only affected parties. Your approval of this application under Rule No. 9 of Conservation Order 93 is respectfully requested. Very truly yours, UNION OIL COMPANY OF CALIFORNIA Attorney-in-Fact cc: Marathon Oil Company Attn: Mr. B.G. Howard APR 2 5 1973 DIVISION GF OiL AND GAS ANCHORAGE Union. Oil ~ o~ inehorage, AXasl~ ~501 ~sed is ~he approved applt~a~ion for pennt~ to drill ~he above referenced l~ell maples ag eot-e c~tps ar~ no~ r~tred, t directional survey is raquirad. ~r L. Su~rel,1 Chai~nan Alaska Oil ar~ Oao ~-~va~!on-~~ee ~ ~par~ o~ Fish ~ ~, ~abicac Section v/o erie1. State ~l-~ ~II ~ ~ T~~ Bay ~le ~ai "D" ~ at ~ho~e., ash ~nd dated April 26, 1973. ~v~..-P~. APl #50-~-ZUZ~ IlN e 'l? J/t STATE O'F ALASK~ ~ p ig7 OIL AND GAS CONSERVATION ,COMMITTEE i--l-t-I- AppLICATION FOR PERMIT TO DRILL, · ~J O~ WOJ~ DRILL ~ DEEPEN~ ~' PLUG BACK ;. IF INDIAN. A-L,LO~E OR TRIBE NAME 8. UNIT, FARM OR LEASE NAJ~IE Trading Bay State A-30 (13-4) 111. b. TYPI~ OF WiLL OIL [~ OAS r.-1 SINGLil [~] MULTIPI,'4~ W ~- LI, W~LL OTHER ZONI ZONE 2. NAME OF OPEI:I~TOR Union Oil Company of California 3.ADDRESS ~ OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 I0. FIELD AND POOL, OR WILDCAT LOCATION OF WELL Atsurface Conductor 27: 1604'N & 559'W of SE Corner Sec. 4, TgN, Rl~'oW,'Atp'posedS'M'prod. zo,e Top "B" Pool: 1330'N & 3050'W of SE Corner, Sec. TgN, R13W, S.M. Top I'D" Pool: 1740'N.& 4180 ' W. -..of SE Cor. Sec. 4 DISTANCE IN MILES AND DIRECT!ON F.~OM NEAREST TOWN OR POST OFFIC~~ T9N, R1 3W, S.M. Approximately 27 air miles North of Kenai, Alaska ]4. BOND INFOP,~ATION: Trading Bay Field 11. SEC., T.,R., M., (BOTTOM O EC ~ec~°LE. ~, ~, R13W, S.M., Btm hole 1874' N & 4349IW of ~"SE corner Sec. 4 TYPE Statewidesuretyand/orNo. United Pacific Insurance Co; B-55372 , 00i 18. DISTANCE FROM PROPOSED LOCATION* PROPOSE~D DEP/q-I ,417'MD & 5,927' TVD DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. ,Also to nearest drig, unit, if any) TO NEAREST WELL DRILLING, COMPLETED, Ott APPLIED FOH, FT. 1,160' 18. NO. OF A~ IN LEASE 3,840 ~.o-~t $100,000. O0 17.NO. ACHES ASSIGNED TO THiS WELL B Pool 40 - D Pool 32 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT~ C-R. etc.) 22. APPROX. DATE WORK WII,I, ~TART* 110' RT to MLLW April 25, 1973 23. P~OPOSED CASING AND CEMENTING PROGRAM iIGii ~,.~ ]Sll w/12% Ge] and 350 sx Class "G" W/18% SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT. GRA])~ S G DEPTH QUANTIT! 20" 133# Drive Pipe driven tc +250'. 22I' 16" . 75# J-55 -+1 ,,O00~"TV Cmt. to surface w/700 sx cJ~ss--~-rr[ . . 18% salt, 1'2% Gel & 250 cx clas~- - .. ' w/2%. CLCa,z,.; 17½" 1~-3/8 61)/ J-'~ +4,.000' Mi Cmt. to surface w/2000 sx ClasPs ' 12¼" 9-5/8 47# N-80 7,416'MD As. required. 1. Drill a 12¼" hole to KOP of 300' -Directionally drill 12¼" hole to +I,O00"TVD. Open Hole to 22". 2. Set 16" conductor' at IO00'TVD and cement to surface. 3. Drill a 12¼" hole directionally to 4000'MD. Open hole to 17½". 4. Set 13-3/8" casing to 4000'MD and cement to surface. 5. Drill a 12¼" hole directionally to 74.17'MD or 5927'TVD. 6. Run reou~red logs. 7. Run 9-5/8" casing and cmt. as required. 8. Complete well as a dual oil wel~ IN ABOVE SPACE DESCHIBE l~tOl~)SE~ PROGRAM: If /~opo~ml l~ to deepen or plug back, give d~ta on present productive zone proposed' rmw productive zorm. If proposal is to drill or deepen dire~t~ona11¥,, give pertinent data on subsurface locations and rneasu_~~i ~nd true vertical depths. Give blowout preventer program. hereby ce~ify that~z~ Ftbregoing is True~x~ Corrj~ct '~This~,space for State office u~) COND~ONS OF ~P~V~, ~ A~: I SAMPL~ AND CORE CI/IPS H.~U~ ~ ~U~S: Y~ ~ NO DI~IONAL SURVEY R~~ A.P.I. ~C~ COD~ Apr!. I AP~O~ Bv . _ . ."d , . ' _~t ~ ....... v R,v,., District Land Manager See Zr~nsmittal Letter 1973 April, 26, 1973 32 33 A-12 RD rMo ~47~ rvD6~ 7 A-19 T V0 6~2 T N ~ J A-6 ,~ A-I J ~A- 12 L '-- A-8 TMD 7417 ~ TMD 6748 :-,~j~'~ ~ .... ~ -~' ,/' , / a-~ ~ .;-~:-- ...-',M- Z ~ ~t ..... ~ ....... ~-'~ - ' "...'.'.'~I ~' /' / A-21 RD ,.,~,,,,/ '~""" _~-/'-~' L// DIVISION OF OIL AND ' 3 ~' .,--~, /,/J . ANCHORAGE ii i i Il I ii i · RI3W A-18 T V 0 ~O,2~a ' !* / /. l' ! /. .......... ...~~ A!elke_ Oi_Itrt(_t T~AD'ING BAY FIELD COOK INLET, ALASKA LOCATION PLAT TRADING BAY STATE A-30 (13-4) ~AT~ ADD I ~ ~ ill: iii i i i i ii i :~ £- TOP 'B' A-14 TRADING E¢/qY FtELD TOP 5'?-2 SAND ( O ZONE) Company _///~, ~ ~ Lease & Well CHECK LIST FOR NEW WELL PERMITS Yes No Remarks ,. Is well to be located in a defined pool ................. //pi/< Do statewide rul apply es ........................ Is a registered survey plat attached .................. Is wel 1 1 ocated proper distance from property Iine ........... ~x[ i. Is well located proper distance from other wells ............ y/~d~ i. Is sufficient undedicated acreage available in this pool ........ r. Is well to be deviated ................ . . . . . . . . . . /zey~ Is operator the only affected party ................... ~.~L.~,' ___ ). Can pe::.'"mit be approved before ten-day wait ............... A;44~ I0. Does operator have a bo,nd in force ................... Il. Is conductor-,, string pro'~ded ...................... 2. Is enough cement used t~ circulate on conductor and surface ...... 13. Will cement tie in surface and intermediate or production strings 14. Will cement cover a.ll p~ssible productive horizons ........... 15. Will surface casing cover all' fresh water zones ............ 16. Will surface csg. inter~al 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 ............... ¢~iroval, RecOmmended- OKG HHH JCM
