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Home My WebLink About168-027MEMORANDUM State of Alaska TO: FROM: Alaska Oil and Gas Conservation Commission Jim ReggI A 1 2, DATE: P. I. Supervisor/ Jeff Turkington SUBJECT: Petroleum Inspector 9/16/13: No Flow Test; Trading Bay State A-14 9/16/13 No Flow Test Trading Bay State A-14 Hilcorp Alaska PTD # 1680270 Summary: Performed a no -flow test of Monopod Platform well A-14 after a trip three days prior on 9/13/13 in which the well was found to be shut in and had built up tubing pressure to 180 PSI and IA to 50 PSI. The well was plumbed with '/2" hose from the top of the swab and annulus casing to a Barton chart recorder for a pressure trend. From a wing valve the tubing was plumbed with a'/2" hose and a'/2" ball valve, through a flow meter and out through a tee with a 0- 30 PSI gauge and 1/2" needle valve to an open top bucket. The meter was an Armor -Flo model 3461-03TO-13 scaled 0-1800 SCFH. See attached photos. --- After After initially opening up through the meter there was light gas flow with no liquid that dissipated within 10 minutes. I gathered a first set of readings and took additional readings every 30 minutes. After the first 30 minutes the tubing was shut in and allowed to pressure up for an hour, after which it was opened to vent for 30 minutes. This second time there was no measurable gas flow but a flow could be felt, which dissipated in less than 5 minutes. The tubing was again shut in for an hour after which it was opened to vent with the well again dissipated all flow and pressure in less than 5 minutes. There was no pressure indicated on the tubing, inner annulus or outer annulus immediately prior to an for the duration of the test. The test continued as follows: Time PSI(T/IA/OA) Meter Liquid 11:00 0/0/0 1.0* 0.0 Tubing open to vent 11:30 0/0/0 0.0 0.0 Shut-in at '/2" ball valve 12:00 0/0/0 0.0 0.0 12:35 0/0/0 0.0 0.0 13:05 0/0/0 0.0 0.0 Opened to vent 13:35 0/0/0 1 0.0 0.0 14:05 0/0/0 1 0.0 0.0 *Dissipated to zero within 10 minutes. Attachments: Photos (2) - 2013-0916—No-Flow—TB—State—A- I 4j t Page 1 of 2 O El 1 .. RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION SEP 12 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Repair Well Cl Plug Perforations ❑ Perforate El Other LJ Run ESP IjOxK Performed: Alter Casing ❑ Pull Tubing el Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory❑ 168-027 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20099-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 ' Trading Bay St A-14 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Trading Bay Field/Hemlock Oil,Middle Kenai B Oil,Middle Kenai C Oil,Middle Kenai D Oil Pools • 11.Present Well Condition Summary: Total Depth measured 8,068 feet Plugs measured 4,650&4,950 feet true vertical 6,641 feet Junk measured N/A feet Effective Depth measured 4,650 feet Packer measured 3,155 feet true vertical 4,048 feet true vertical 2,823 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,097' 13-3/8" 1,097' 1,054' 3,090 psi 1,540 psi Intermediate Production 7,108' 9-5/8" 7,108' 5,903' 3,950 psi 2,570 psi Liner 997' 7" 7,108'-8,068' 5,903'-6,641' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet ail, I4 11` `Q 1,; Tubing(size,grade,measured and true vertical depth) 3-1/2"-9.3#/L-80 2,889'(MD)2,593'(ND) 2-7/8" -6.5#/L-80 3,198'(MD)2,861'(TVD) 3,155'(MD) 318'(MD) Packers and SSSV(type,measured and true vertical depth) Model D Packer 2,823'(ND) Baker-SSSV 318'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 45 47 23 430 90 Subsequent to operation: 155 19 264 420 100 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development p ' Service ❑ Strabgraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil p r Gas El WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-379 Contact Ted Kramer Email tkramer( hilcorp.com Printed Name Ted Kramer �? Title Sr.Operations Engnieer Signature 'oi ! e[,,"�� Phone (907)777-8420 Date 9/12/2013 Form 10-404 Revised 10/2012 /o/y./3 i(°NO RBDMS SEP 1 7 2 ?` bmit Original Only II • • Trading Bay Unit SCHEMATIC Well #A-14 Completed: 08/09/2013 CASING AND TUBING DETAIL API#50-733-20099-00 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Hngr=41.23' 13-3/8" 61 K-55 Butt 12.515 37 1097' i . 9-5/8" 40 K-55 8rd LT&C 8.835 37 5586' . : I [ Stage Collar 4349' 4351' 9-5/8" 9-5/8" 40 N-80 8.835 5586' 7089' 43.5 N-80 8.755 7089' 7180' 7" 29 N-80 6.184 7071' 8068' Tubing: 3-1/2" 9.3# L-80 RTS-8 Surf 2,889' 2 2-7/8" 6.5# L-80 8rd EUE 2,889' 3,198' JEWELRY DETAIL NO. Depth ID Item 41.23' Tubing hanger 1 318' Baker-SSSV 2 2,205' 3-1/2"RTS-8 Side Pocket GLM 3 2,839' 3-1/2"RTS-8 Side Pocket GLM 3 4 2,889' Y Block 5 2,945' Bottom of ESP 6 3,124' Sliding Sleeve 7 3,140' Chemical Injection Mandrel 4 8 3,155' Model D Permanent Packer 9 9 3,187' X Nipple 10 3,198' WLEG } 11 4,650' Cement Retainer 12 4,950' Cement Retainer IR Wireline Summary 5 11/9/99 Tagged fill w/1.75"Scratcher Cal 4549' 6 A 7 2/22/00 Worked through Paraffin.Tagged Fill w/2.5"Scratcher @ 4695' 8 9/30/05 Tag Fill w/1.91"GR @ 4542' Ell 9 12/15/05 Holes in tubing @ 3104',3108'&3118'. Ran TP-2 Packoffs 3098'to 3121' 10 mr Perforation Detail Top Btm TOP Btm Accum. Date Zone (MD) (MD) (ND) (ND) Amt. SPF Last Opr. Present Condition - B 3,210' 3,340' 2,871' 2,985' 130' 08/05/2013 Open B 3,785' 3,815' 3,354' 3,378' 30' 08/05/2013 Open B 31-8 3,785' 3,918' 3,354' 3,458' 133' 8 11/22/1988 = B 3,826' 3,860' 3,386' 3,413' 34' 08/05/2013 Open B 3,884' 3,920' 3,431' 3,460' 36' 08/05/2013 Open B Zone B 33-6 3,954' 4,000' 3,487' 3,523' 46' 8 11/22/1988 Frac'd w/98700#of 20-40 B 3,968' 4,000' 3,498' 3,523' 32' 08/05/2013 Open _ B 41-3 4,080' 4,100' 3,587' 3,603' 20' 8 11/22/1988 Frac'd w/42200#of 20-40 - B 4,082' 4,104' 3,589' 3,606' 22' 08/05/2013 Open B 4,130' 4,180' 3,627' 3,667' 50' 08/05/2013 Open B 41-8 4,130' 4,230' 3,627' 3,708' 100' 8 11/20/1988 Frac'd w/42200#of 20-40 N U B 44-7 4,470' 4,565' 3,902' 3,979' 95' 8 11/16/1988 Frac'd w/45300#of 20-40 B 4,477' 4,550' 3,908' 3,967' 73' 08/05/2013 Open = B 4,568' 4,570' 3,982' 3,983' 2' 4 6/22/1988 WSO.Cmt sqz'd = B 4,605' 4,629' 4,012' 4,032' 24' 08/05/2013 Open C-2 4,672' 4,720' 4,065' 4,103' 48' 4 4/27/1984 Cmt sqz'd Isolated in 11/88 C-3 4,790' 4,815' 4,157' 4,176' 25' 4 4/27/1984 Cmt sqz'd Isolated in 11/88 t1 C-S 5,000' 5,030' 4,310' 4,331' 30' 4 12/3/1975 Isolated in 11/88 jC-7 5,230' 5,415' 4,479' 4,618' 185' 4 12/3/1975 Isolated in 11/88 / C 47-5 5,540' 5,585' 4,715' 4,750' 45' 4 12/75 Isolated in 11/88 D 53-8 6,510' 6,5225' 5,433' 5,444' 15' 4 12/3/1975 Isolated in 11/88 12 D 54-5 6,554' 6,562' 5,466' 5,471' 8' 4 12/3/1975 Isolated in 11/88 D 54-9 6,600' 6,642' 5,500' 5,532' 42' 4 3/70 Isolated in 11/88 ID 55-7 6,672' 6,732' 5,555' 5,603' 60' 4 12/75 Isolated in 11/88 Hemlock D 56-1 6,760' 6,866' 5,625' 5,709' 106' 4 12/75 Isolated in 11/88 //////////////////////////////////////////////////////. D 57-2 6,896' 7,020' 5,733' 5,832' 124' 4 12/75 Isolated in 11/88 D 58-7 7,190' 7,191' 5,969' 5,969' 1' 4 5/68 WSO.Isolated in 11/88 KB ELEV=101' 7,420' 7,421' 6,153' 6,154' 1' 4 5/68 WSO.Isolated in 11/88 Hemlock 7,436' 7,472' 6,166' 6,194' 36' 4 3/70 Isolated in 12/75.Isolated in 11/88 PBTD=4,650' TD=8,068' Hemlock 7,490' 7,600' 6,208' 6,291' 110' 4 3/70 Isolated in 12/75.Isolated in 11/88 ANGLE thru INTERVAL=39° Hemlock 7,680' 7,730' 6,351' 6,389' 50' 4 5/68 DST#1.Sqzd w/200 sx cmt.Isolated in 11/88 Hemlock 7,884' 7,934' 6,504' 6,541' 50' 4 5/68 DST#2.Isolated w/BP @ 7650'. Isolated in 11/88 Updated by: JLL 09/10/13 • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-14 50-733-20099-00 168-027 7/28/13 8/10/13 Daily Operations: 7/28/2013-Sunday Rig up slickline and test lubricator to 1500 psi. Run#1- Run Slick Line Scratcher to 313'. Pump 1 bbl diesel. Work scratcher up and down 50' above SSSV. POOH and break off scratcher. [0 psi on tbg, 220 psi on 9 5/8, 0 psi on 13 3/8]. Run#2- Run brush down to SSSV at 313'. POOH with brush and it had traces of paraffin. Run#3- Run 2.31 Gauge Ring to 313'. Pump 1 bbl diesel. POOH with no paraffin on tool. Run#4- Run GS w/Prong to SSSV at313'.Wouldn't latch in. Pumped another bbl of diesel while working tool through SSSV. Got latched in and worked SSSV free. POOH with full recovery. Run#5- RIH w/Slick Line Scratcher to 3098'top of patch. Run#6- RIH w/ Braided line brush to 3098' FL 200'slm. Run#7- RIH w/ GS to 3098' latch A-stop on tbg patch - hit jars 30 times patch moved up hole^'30'. POOH with out A-stop. Cut 100' wire line off spool- redress rope socket. Run#8- RIH w/GS to 3098' latch and pull A-stop, 1st section of patch. Run#9- RIH w/GS latch and pull packoff section of patch. R/U circ/kill equip. Run# 10 RIH w/GS latch and pull AD-2 stop. Run# 11 - RIH w/BO engage sliding sleeve at 3693' work jars with 10 hits-tool slipped out of SS. FL^ 100'slm. Run# 12 - RIH w/BO engage SS at 3693' -surface indication SS shifted. FL "1400'slm. RD slickline equip. RU to kill well. PT lines to 2000 psi. Start tbg 0 psi/ann 240 psi-on line with pump- pumping down 2 7/8 tbg with returns up 9 5/8 ann -with 175 bbls away tbg press 500 psi-ann 250 psi-gas returns- no fluid. Fluid loss today- 3% KCL 0 bbls.Total loss 0 bbls. Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls. Loss rate average=0 BPH. Recovered 0 lbs total of metal. 13 3/8" = 100 psi. 9 5/8" = 240 psi. 20" =0 psi 7/29/2013 - Monday Pumping dn tbg taking returns to production at 5 bph. Getting gas returns at ann until we got 310 bbls away and started getting back crude oil. Pump 360 bbls and spot 38 bbl size salt pill. [Total vol pumped so far 400 bbls]. Monitor well and build 3 % KCL to top off pits.Tbg=0 psi, Ann =0 psi.Start pumping dn tbg staging pump up to 4 BPM.At 16.5 bbls pump caught press and climbed to 220 psi w/22.4 bbls away. Shut dn pump and monitor well for 1 hr. Press went to 0 psi on tbg and ann. Start pumping dn tbg at 3 BPM. Pump 16 bbls and caught pressure. At 60 bbls we started getting oil returns out the ann. At 100 bbls we started getting water back and by 150 bbls it had cleared up. Shut dn. Monitor tbg and Ann. 0 psi on both. Start pumping dn tbg at 3 BPM. Caught pressure 3.4 bbls and tbg caught pressure,got returns from the ann at 23 bbls. Pump a total of 34.6 bbls. Spot size salt pill as a balanced plug. Monitor well for 1/2 hr. Fill pipe and it took 2 bbls to fill. Rig down circ lines and set BPV. Nipple down tree. Remove tree from cellar and put wellhead spool in cellar. NU BOPE - RU trip tank to 9 5/8 ann-43 bbls to fill-1st hr loss at 15 bph- install riser/tighten same- install BOPE stack/tighten same - 11 bph loss. Continue NU BOPE- install flow nip-air boot- mouse hole-clean well head rm- function Koomey. MU test tools. PU Kelly-fill all lines to be tested with water.Test BOPE (Witness of test waived by Jim Regg AOGCC Supervisor 12:37 am 7/30/13) as per HAK- Kuukpik-AOGCC procedures-charted with 250 psi low/2500 psi high. Fluid loss today-3% KCL 285 bbls.Total loss 285 bbls.Sized Salt Pill 75 bbls.Total sized salt pill loss 75 bbls Loss rate average= 13 BPH. Recovered 0 lbs total of metal. 13 3/8"/0 psi. 9 5/8"/0 psi. 20"/0 psi. • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-14 50-733-20099-00 168-027 7/28/13 8/10/13 7/30/2013-Tuesday Test BOPs.Test all BOP equip to 250 psi low and 2500 psi high. No failures. Rig dn test equip. Strap and PU 9-6 1/2" DCs and stand them back in the derrick. PU 2 7/8 landing jt and screw into hanger. Back out lock downs and PU on string. Pulled off hanger seat at 40k. Work up to 80k to attempt to pull seals out of pkr. No movement. Circ one full circ at 5 BPM and 600 psi. High on gas was 350 units. Rig up E-Line. RIH with Radial cutter and cut tbg just below sliding sleeve at 3697.75'. Good indication of cut. POOH and RD E-Line. Pull hanger to floor and secure well while rigging up lay dn tbg. POOH/LD 119 jts 2 7/8 tbg-SSSV/control line (recovered 11 stainless steel bands) 3 GLM -1 sliding sleeve-good even tbg cut^'2' below sliding sleeve. Pin hole in tbg in the patch area. RD tbg running equip-clean/clear rig floor- power wash floor and tbg tongs.Set wear ring. PU/ MU BHA# 1-8 1/8 Overshot-xo-bit sub-6 1/4 bumper sub-6 1/4 oil jar-xo-9 ea 6 1/2 DC-xo-xo- 312.18'. Fluid loss today-3% KCL 306 bbls.Total loss 591 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 75 bbls . Loss rate average= 13 BPH. Recovered 0 lbs total of metal. 13 3/8"/0 psi. 9 5/8"/0 psi. 20"/0 psi 7/31/2013-Wednesday RIH w/ BHA#1 to 3675' and Kelly up. Wash down over top of tbg cut at 3697'_Swallow tbg 8'. PU to 100k which is 20k over up wt and seals pulled free. Pull up 15'with a increase in up wt of 2k. Set back dn and pick up again with the same results. Set Kelly back and Lay dn 2 singles. Circ one full circ at 8 BPM and 825 psi.with a high of 230 units of gas. POOH laying dn 4" DP. Stand back 6 1/2 DCs and pull fishing assem above rotary. No recovery. Break dn overshot and look at grapple. Could tell that tbg stub had went into pack-off and about 1" into the grapple. Made tool back up without packoff so we could wash clear down over stub without pressuring up. RIH to DP. RIH with extra 4" DP we had in the derrick to 3675'. Wash dn over top of tbg stub at 3697' down to top of pkr at 3707'. PU to 45k over up wt and seals pulled out of packer. Work seals in and out several times with pump on to ensure that we still had fish. Everything indicates that we still have fish. Set Kelly back and start POOH laying dn the last of the 4" DP. LD BHA#1- recovered seal assy and tbg tail- pup jt above seal assy has erosion with holes. PU/MU BHA#2- PRT pkr mill assy-4 ea 7" boot bskt-xo-6 1/4 bumper sub- 6 1/4 oil jar-pump out sub-xo-9ea 6 1/2 DC-xo-6 1/4 accelerator jar-OAL 337.5'. RIH picking up 5" DP and dropping rabbit as picked up off deck. PU Kelly obtain parameters, puw 105k -sow 95k- rw 95k. Tag pkr at 3707'. Milling on pkr at 3707'. Fluid loss today-3% KCL 300 bbls.Total 3% KCL loss 891 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 75 bbls. Loss rate average = 13 BPH. Recovered 0 lbs total of metal. 13 3/8"/0 psi. 9 5/8"/80 psi. 20"/0 psi • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-14 50-733-20099-00 168-027 7/28/13 8/10/13 08/01/2013 -Thursday Mill packer from 3707'to 3710'. Packer moved down hole. Circ bottoms up 80 spm 550 psi. No gas. Start POOH, had to pump packer past every csg collar up to 3463'. POOH on elevators but had to work past tight spots at every csg collar up to 2516'.Then it started pulling free. POOH work pkr through tight spots- LD 3 sgl DP. LD BHA#3-pkr fish-accel jars-clean junk baskets-recover 129 lbs metal. PU/MU Clean out BHA#4-8 1/2 bit-5 ea boot bskt-bit sub(w/flt)-6 1/4 bump sub-6 1/4 oil jar-pump out sub-xo-9 ea 6 1/2 DC-xo-oal 320.14'. RIH with BHA#4, PU 5' DP off deck. Tag at 4308'. PU Kelly- obtain parameters- 10 bpm-400 psi-60 rpm @ 7k-15k trq-670 max trq- puw 116k-sow 97k-rtw 106k-wash/ ream from 4308'to 4496'. Light to heavy sand at shakers-sand color changed to a whitish color peppered with black spec's- fluid loss^'15 bph.Wash/ream from 4496'to 4645' rotary torqueing up 200 amps-230 amps. PU shut off rotary and pump. RIH tag at 4645' set 10k down. Retainer set at 4650' per program -tag is 5' high. Circulate and clean well up- heavy sand across shakers until cleaned up- max gas units 453, est 16 bbls sand returns. Make 5 std short trip to 4141'. Monitor well 15 mins- 14 bph loss. RIH -tag at 4645'- no fill. Circ clean well up. Fluid loss today-3% KCL 310 bbls.Total 3% KCL loss1201 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 75 bbls- Loss rate average- 15 BPH - 13 3/8"/0 psi. 9 5/8"/80 psi. 20" /0 psi 08/02/2013- Friday Circ hole clean while rigging up to displace well to production.Test lines to 500 psi. Pump with #2 pump to production header at 3 BPM and 200 psi. Use#1 pump to displace well with clean 3% KCL at 3.5 BPM. Got clean fluid back at shakers and shut down. [Continue pumping to production with#2 pump]. POH to BHA, L/D do tools and clean junk baskets. Recovered 100 lbs of sand and 12 lbs of metal from pkr. Rig up E-Line and run GR and CCL Log from 4645' up to 1097'. Rig down E-Line. MU - RIH with RTTS-set RTTS at 3224' (center of element)-test 9 5/8 csg to 1600 psi-30 mins on chart- good test. POOH with RTTS. MU/ RIH with RTTS and SSCV to 3 stds 6 1/2" DC on 1 std 5" DP and set at 98' -dis engage from SSCV and stand back DP. PT- RTTS/SSCV-9 5/8 csg-to 1500 psi/ 15 mins-good test. ND Riser, spacer spool. drain stack and remove flow riser. Install pick up slings, bridge slings and remove turn buckles. PU stack riser, lower spool, break lower spool- move to the side. Dress csg stub. Install new spacer spool-test void 2500 psi.lnstall ann vlv- NU riser. Fluid loss today-3% KCL 304 bbls.Total 3% KCL loss1505 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 75 bbls- Loss rate average- 12 BPH - 13 3/8"/0 psi. 9 5/8"/80 psi. 20"/0 psi • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-14 50-733-20099-00 168-027 7/28/13 8/10/13 08/03/2013 -Saturday Nipple up BOPs.Test against storm valve to test ann valves on new spool, 250 low and 1500 high. Set test plug and test stack to 250 low and 2500psi high. Make up storm valve and RIH. Engage and release pkr,fill hole, POOH. LID storm valve and pkr. Stand back 6 1/2 DCs. Set wear ring. Waiting on completion equip. Rig up to take returns off ann through rig choke manifold. Pump fresh water down tbg with returns to pits- pump at 1 bpm/300 psi-after 4 bbls pumped -clean water returns to shakers-suggesting tbg x ann communication close to surface. SD pump after 10 bbls pumped - verify all lines/vlvs lined up properly. Close ann vlvs- bullhead 15 bbls fresh water followed with FIW down tbg-start pressure /rate at 1 bpm -T-450/ IA-200/OIA 20-at 45 bbls pumped -T-900/IA-455/OIA-300-at 75 bbls pumped -T-830/IA- 450/OIA-400-SD pump tbg dropped to 750 psi -after 5 mins T-760/IA-450/01A-400-final SIP-T-760/ IA-425/OIA- 420.Total fluids pumped 29 FW+59 FIW= 88 bbls. Blow down lines- RD lines-start building pit vol. Continue build vol. RD circ lines . MU Scraper BHA#5-8 1/2 bit-9 5/8 scraper-bit sub-bumper sub-oil jar-xo-9 ea dc-xo-OAL 305.37'. Fill hole with 59 bbls - 30 bph fluid loss. Monitor well for fluid loss- 25 bph static for 30 min- prep and cut 60' drilling line-spot 40 bbl SSP followed with 42 bbls FIW at 3240'. Located and shifting sliding sleeve at 7403' (7366 slm). Fluid loss today-3% KCL 230 bbls.Total 3% KCL loss1735 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 75 bbls- Loss rate average-9.6 BPH - 13 3/8"/0 psi. 9 5/8"/80 psi. 20"/0 psi 08/04/2013 -Sunday POOH with csg scraper. Lay do tools. {Hole is taking 14 BPH}. Rig up to test BOPs,Witness of test was waived by Jim Regg on 8/3/13 19:59 hrs.Test all BOP equip to 250 psi low and 2500 psi high. Had one failure. Lower Kelly cock valve. Replaced with new valve and retested.Tested all gas alarms and they all passed. [Tested 5", 3 1/2", and 2 7/8".] LD test jts -clean/clear floor of test equip- pull test plug. Install wear ring. RU WOT power tongs and tbg running equip. PU/ RIH with 3 1/2 "tbg off deck- run rabbit thru tbg. 10 bph fluid loss. Finish PU/RIH with 3 1/2" tbg. 10 bph fluid loss. POOH with 3 1/2" tbg. Monitor well and prep to run TCP perf guns. 14 bph loss. Fluid loss today-3% KCL 447 bbls.Total 3% KCL loss 2182 bbls. Sized Salt Pill 41 bbls.Total sized salt pill loss 116 bbls- Loss rate average- 16 BPH - 13 3/8"/0 psi. 9 5/8"/80 psi. 20"/0 psi 08/05/2013 - Monday Prep to run guns. Build 3 % KCL vol for active system. Build 40 bbl size salt pill. Start running guns. Run 4 guns. Hole taking 13 BPH. MU(HES) 3 1/2"-6 SPF Millennium 25gr TCP perf guns and RIH on 5" DP+ 10' pup to 4640'. PU to 4638'- park in slips. RIH with e-line-run GR/CCL tie in from 3150'elm - 2760'elm- using GR/CCL dated 8-2-13 - not deep enough for bottom shot. PU 15' DP pup jt- RIH tag btm at 4644'. PU to 4643' - park in slips. RIH with e-line-run GR/CCL tie in from 3150'elm- 2760'elm-(using as tie in log GR/CCL dated 8-2-13) -tie into RA mkr at 3126' elm - places top shot,at 3210' elm -btm shot 4629' elm. RU circ lines- bar drop vls. Load and drop bar-good surface indication gun fired. Fluid level dropped slowly to btm of stack. CBU x 2 at 5 bpm/160 psi to get perf gas out. Monitor well -shooting fluid levels-fluid at surface- fluid at^'240'determined by pump strokes to fill- 20 psi on 9 5/8 ann. CBU -gas units at 45-26 bph loss. RD circ equip. MU stand back gun safety jt. POOH to perf guns-8 bbls to fill hole. Monitor well - prep to LD guns. LD TCP perf guns. Fluid loss today-3% KCL 283 bbls.Total 3% KCL loss 2465 bbls. Sized Salt Pill 41 bbls.Total sized salt pill loss 116 bbls- Loss rate average- 14 BPH -9 5/8"/80 psi./ 13 3/8"/0 psi. 20"/0 psi • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-14 50-733-20099-00 168-027 7/28/13 8/10/13 08/06/2013-Tuesday POOH laying down perf guns, all shots fired as per procedure. Well taking 26 bph. Picking up Packer BHA,Trip in hole to 3124' dpm, p/u 1 single, make up pump in sub, space out and putting packer at 3155' dpm, &wleg at 3199' dpm. Drop ball and let fall on seat, pressure up to 3000 psi in 500 psi increments. Shear off packer w/20k over pull, pressure bleed to zero. Lay out pump in subs and single pooh w/setting tools. Remove wear ring. MU completion equip-seal assy-inj vlv- sliding sleeve. RU ESP/Control line sheaves. Continue prep ESP. Attach CL to inj vlv and test- pumped thru inj vlv- no diaphragm in connection. RIH with lower section of completion assy making up ESP component's. 18 bph fluid loss. Continue RIH with lower completion assy making up ESP component's-install "Y" block- hook up/test control line connections to inj vlv/phoenix gauge. Connect/test ESP cable. PU 1 st jt of 3 1/2" tbg. Fluid loss today-3% KCL 454 bbls. Total 3% KCL loss 2919 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 116 bbls- Loss rate average - 19 BPH -9 5/8"/80 psi./13 3/8"/0 psi. 20"/0 psi 08/07/2013 -Wednesday Wait on 3 1/2 8rd x 3 1/2 IBT cross over - 15 bph loss. RIH with ESP on 3 1/2 tbg installing Canon clamps every other jt- Mag test pump every 1000'. Install GLM. R/U test pump to test 9 5/8 ann-17 bph loss. Cont RIH with completion string- SSSV-test to 5000 psi. Tag packer at 3145'.Attempt to engage pkr with seal assy- unsuccessful. M/U circ head -circ at 2 bpm/50 psi.Attempt to engage pkr-unsuccessful. R/D circ equip-cont to engage pkr with various methods cont to be unsuccessful-confer with Anc Eng-decision to POOH. PJSM. POOH with ESP/GL completion string. L/D ESP/GL completion assy. Mule shoe had damage to the non beveled side. L/D seal assy centralizer and redress damaged mule shoe. Re-service ESP for trip back in hole. Fluid loss today-3% KCL 448 bbls.Total 3% KCL loss 3367 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 116 bbls- Loss rate average - 19 BPH - Recovered 0 lbs ditch mags-0 lbs boot bskt total metal recovered 307 lbs-9 5/8"/80 psi./ 13 3/8"/0 psi. 20"/0 psi 08/08/2013 -Thursday Finished making up 3.25 locator seal assembly with 20 ft of seals. P/U 2-7/8 8rd tbg and RIH w/same. Make up ESP assembly. Waiting on slick line personnel. Remove the isolation plug f/the Y block, making up ESP pump and testing connections,trip in hole running w/3.5 RTS 8 9.2# production tbg testing lines every 1000 ft. Install canon clamps every other jt. Test control lines-good test. M/U SSSV-function vlv- pt 5000 psi - 15 min- lock in press. Cont RIH tag at 3155' - (Total 47 canon clamps installed). Engage seal assy into pkr SBR with 1/2 left hand turn- pull out of SBR-space out 17.8'. Install hgr- landing jt. Install SSSV control line and ESP splice to hgr. (Total 35 SS bands installed). Clean/organize rig floor of tools. Cut ESP cable/start making splice. R/D cable sheays. 15 bph loss. Cont with ESP splice and cleaning rig floor. Connect ESP cable and control lines to hgr. Land hgr. No problems entering SBR, p/u w 43k/s/o w 36k/land hgr w/22k. R/U slickline to set blanking plug to test pkr. Fluid loss today-3% KCL 429 bbls.Total 3% KCL loss 3796 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 116 bbls- Loss rate average-16 BPH - Recovered 0 lbs ditch mags-0 lbs boot bskt total metal recovered 307 lbs-9 5/8"/80 psi./ 13 3/8"/0 psi. 20"/0 psi • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-14 50-733-20099-00 168-027 7/28/13 8/10/13 08/09/2013-Friday RIH w/slickline X-Line setting tool and tagged up w/the R-Plug at 3129' MD. Could not get past sliding sleeve. POOH had sheared off tool. M/U GS tool and RIH latch plug. POOH and inspect same. Redress, RIH tool wt set plug at 3193' MD. POOH. Change out tools. RIH to set prong in plug at 3193', prong did not set. POOH. Change out packing and RIH w/same and set rod. Rig up to test the 9-5/8 Model D pkr and csg to 1500 psi for 30 min on chart, pressure up to 1500 psi shut down pump pressure bleeding to "0" in 1-1/2 minutes, made a couple more attempts to get a test with same results. Rig up slick line and retrieve prong and plug pack on prong was scared.Waiting on new plug and prong from wire line. Dress plug and prong. Set plug @ 3193' and shear off. RIH and set prong @ 3190'. POOH and R/D slickline. Rig up and test 9 5/8" Model 'D' packer and casing to 1500 psi for 30 minutes on chart. Good test. Rig up slick line. RIH and retrieve plug @ 3193'. Attempt to run 2.813" isolation sleeve but not able to get past SSSV @ 317'. Consult with town and agree to have isolation sleeve turned down to 2.780 and rerun. Monitor well. Perform rig maintenace and housekeeping while waiting on isolation sleeve to be modified. Grease choke manifold. Prepare to nipple down BOPE. Fluid loss today-3% KCL 141 bbls.Total 3% KCL loss 3937 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 116 bbls- Loss rate average-15 BPH - Recovered 0 lbs ditch mags-0 lbs boot bskt total metal recovered 307 lbs-9 5/8"/80 psi./13 3/8"/0 psi. 20"/0 psi 08/10/2013 -Saturday Monitor well while waiting on isolation sleeve modifications. Blow down and remove high pressure mud line. Install softener on HP mud line. Fluid loss rate= 12 BPH. Rig up slick line. Run#1: RIH with B-O self releasing slide to 3130'to insure sliding sleeve is closed. Run#2: RIH with x-line R-T to sliding sleeve @ 3130' and set plug as catcher sub. Run#3: RIH with kickover and retrieve dummy GLM valve @ 2217'. Run#4: RIH with kickover and retrieve dummy GLM valve @ 2853'. Run#5: RIH with kickover tool and set live GLM valve @ 2217'. Run#6: RIH with kickover and set live GLM valve @ 2853'. Run#7: RIH with G-S tool and retrieve plug @ 3130'. Rig down slick line unit.Set BPV. Nipple down BOPE and pull riser.Test ESP penetrator and meg same. Nipple up tree.Test void and tree to 250L/5000H. Fluid loss today 3% KCL 311 bbls.Total 3% KCL loss 4248 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 116 bbls- Loss rate average-13 BPH - Recovered 0 lbs ditch mags-0 lbs boot bskt total metal recovered 307 lbs-9 5/8"/80 psi./ 13 3/8"/0 psi. 20"/0 psi • • w��\or\I%%7 s9 THE STATE Alaska Oil Gas _ __ _ 1 \i ,orisery Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OpALAS�� Anchorage, Alaska 99501-3572 SCANNED 2 2D13 Main: 907.279.1433 Fax: 907.276.7542 Ted Kramer � O .‘,7 Sr. Operations Engineer / Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Hemlock Oil, Middle Kenai B Oil, and Middle Kenai C Oil Pools, Trading Bay ST A-14 Sundry Number: 313-379 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this /7 day of July, 2013. Encl. 1 1 1 .. . ,. e .` RECEIVED STATE OF ALASKA /(f1� JUL 1 7 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION ✓ ! 9//3 APPLICATION FOR SUNDRY APPROVALS AOUL;C 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate El Pull Tubing a. Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Run ESP' El 2.Operator Name: 4.Current Well Class: 5.Permit to Drift Number: Hilcorp Alaska,LLC Exploratory ❑ Development O- 168-027- 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20099-00- 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 93.2 Will planned perforations require a spacing exception? Yes ❑ No G Trading Bay ST A-14` g�A13 9.Property Designation(Lease Number): 10.Field/Pool(s): ,,n II`` \ ADL0018731 - Trading Bay Field/Hemlock Oil,Middle Kenai B Oil,Middle Kenai.0 Oil Pools,r1'�icJJi.. r,;� 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8,068'• 6,641'. 4,650'• 4,048' 4,650'and 4,950'. Casing Length Size MD TVD Burst Collapse • Structural Conductor Surface 1,097' 13-3/8" 1,097' 1,054' 3,090 psi 1,540 psi Intermediate . Production 7,108' 9-5/8" 7,108' 5,903' 3,950 psi 2,570 psi Liner 997' 7" 7,108'-8,068' 5,903' -6,641' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" N-80 3,759' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Model D Perm Pkr and Otis SSSV 3,707'(MD)/3,294'(ND)and 313'(MD)/313'(ND) 12.Attachments: Description Summary of Proposal 12 • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch C k Exploratory ❑ Stratigraphic❑ Development 12 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 7/28/2013 Commencing Operations: Oil CI • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ El 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 tkramertu-�.hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature ' 4..... Phone (907)777-8420 Date 7/16/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 , . Plug Integrity ❑ BOP Test V Mechanical Integrity Test I:1 Location Clearance CI Other: A 2 'S-06 /OS c, F rio 7i'- Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0— q Qy RBDMS JUL 2 3 201htJ° APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7_/1 3 jn/�1'RiiI3i AA Form 10-403(Revised 10/2012) Appr(QI I Nd(g' most the date of approval. Attachments in Duplicate vvVVV 1 //'"'�� 00- • • Well Prognosis Well: A-14 Hilcorp Alaska,LL Date:07/16/2013 Well Name: Monopod A-14 API Number: 507332009900 Current Status: Oil producer(Gas Lifted) Leg: N/A Estimated Start Date: July 28, 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: 168-027 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: 817 psi @ 4,650' (3,663'ND) Calculated From 2007 Gas Lift Survey. Maximum Expected BHP: 1,050 psi @ 4,650' (3,663' ND) Max.Anticipated Surface Pressure: 0 psi. (Using all oil in tubing from 4,650 to surface and a .37 psi/ft. oil gradient.) Brief Well Summary The A-14 well is currently is currently completed as a gas lifted oil well. The most recent well test shows that the well makes 76 bopd and 22bwpd. This well was last worked on in 2005 when a tubing patch was set to repair a hole in the tubing. The re-completion plan involves pulling the existing completion,cleaning out to the cement retainer at 4650'. The well will then per reperforated adding the attached shots in the B zone. A new completion string will then be ran which will consist of an SSSV, GLMs, and a small ESP above a permanent packer. Brief Procedure: 1. MIRU Monopod Platform Rig#56. 2. RU Slickline. RIH and remove tubing patch at 3,098'to 3121'. 4 3. RIH with GR to 3,707' Cut/Brush paraffin as needed. RD Slick line. 4. RU E-line and RIH with tubing punch and punch circulation holes at 3,695'.' 5. Circulate three percent KCL to kill well and to circulate Hydrocarbon off of the well. 6. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 24 hours in- advance of test to allow them to witness test). 7. RU e-line and RIH with tubing cutter to 3,700' (+/-), Unseat Hanger and pick up on tubing. Cut tbg. RD E-line. 8. POOH laying down production tubing. 9. PU RIH with overshot. Latch on and POOH with seal assembly. 10. PU RIH with Packer milling and retrieving assembly. Mill over and retrieve packer at 3,707'. 11. PU and RIH with 9-5/8"clean out assembly on work string. Clean out well to the Cement retainer @ 4,650'. Circulate hole clean, POOH with clean out assembly. 12. RU E-line. RIH With Gamma Ray CCL tool to 4,620'. Log hole from this depth up to 1,097'. POOH with E-line. 13. PU RTTS Packer. RIH to 3,200+/-and set packer. Pressure up on back side and pressure test casing to 1,500 psi. Chart same for 30 minutes. 4, • • Well Prognosis Well: A-14 Hilcorp Alaska,Lb Date:07/16/2013 14. RU TCP perforating Company. PU TCP guns building string into the well. Run guns into well on work string and Correlate on depth with E-line. Place guns on depth and fire guns. 15. PU on guns and circulate out perf gas. Monitor well for 1 hr shooting fluid levels to determine fluid loss. Fluid loss should diminish over time. 16. Once well is stable, POOH with TCP guns. 17. PU Permanent packer and RI well on work string to 3,160'+/-. Set packer. 18. PU completion string consisting of SSSV,2 GLMs,Y tool, ESP,sliding sleeve on 2-7/8"8rd EUE L- 80 production tubing. Space out and set seals into packer. Hang off tubing.19. ND BOPs,NU Wellhead and test. L-' 1: IA 1504 PS 7CAL 20. Turn well over to production. 30 .. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Proposed Wellhead. II • • Trading Bay Unit Well#A-14 Completed 11/88 API#50-733-20099-00 CASING AND TUBING DETAIL RKB to TBG Hngr=37.68' SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 37 1097' AI 9-5/8" 40 K-55 8rd LT&C 8.835 37 5586' o _ 1 Stage Collar 9-5/8" 4349' 4351' 7089' 40 N-80 8.835 5586' 9-5/8" 43.5 N-80 8.755 7089' 7180' 8068' 7" 29 N-80 6.184 7071' Tubing: 2-7/8" 6.4 N-80 1 Butt 2.441 37' _ 3759 M 2 JEWELRY DETAIL NO Death ID Item 37.40 10"x 4-1/2"Cameron 5M Tubing hanger,XO to 2-7/8"Butt 1 313 2.313 2-7/8"Otis,BV SSSV Nipple, 2 2216' GLV#3 Mb 3 3 2958' GLV#2 I 3098'-3121' 1.500 TP-2 Tubing Packoff Patch installed 12/15/05 4 3676' GLV#1 5 3693' 2.313 Otis"XA"Sliding Sleeve 6 3707' 4.75 Baker Model"DB"Retrievable Packer 7 3726' 2.313 Otis"X"Profile Nipple,2.313 IIM 4 8 3758' 2.5 WLEG btm 3759' 9 4650' Cement Retainer• 10 4950 Cement Retainer . CM 5 i .FL b Wireline Summary 6 11/8/99 Work 2.34"GR cutting paraffin&pumping Xylene @ 210' x 11/9/99 Tagged fill w/1.75"Scratchier @ 4549' 7 2/22/00 Worked through Paraffin.Tagged Fill w/2.5"Scratcher @ 4695' \ 9/30/05 Tag Fill w/1.91"GR @ 4542' 8 31-8 12/15/05 Holes in tubing @ 3104',3108'&3118'. Ran TP-2 Packoffs 3098'to 3121' 33-6 PERFORATION DATA - 41-3 Accum. Date Zone Top Btm Amt. SPF Last Opr. Present Condition B 31-8 3,785' 3.918' 133' 11/22/88 Frac'd w/98700#of 20-40 B 33-6 3,954' 4,000' 46' 11/22/88 B 41-3 4.080' 4,100' 20' 11/22/88 Frac'd w/42200#of 20-40 41-8 B 41-8 4,130' 4,230' 100' 11/20/88 B 44-7 4,470' 4,565' 95' 11/16/88 Frac'd w/45300#of 20-40 4.568' 4.570' 2' 6/22/88 WSO.Cmt saz'd C-2 4.672' 4.720' 48' 4/27/84 Cmt saz'd Isolated in 11/88 C-3 4,790' 4,815' 25' 4/27/84 Cmt saz'd Isolated in 11/88 ■ ■ C-5 5.000' 5.030' 30' 12/3/75 solated in 11/88 C-7 5,230' 5.415' 185' 12/3/75 solated in 11/88 C 47-5 5.540' 5,585' 45' 12/75 solated in 11/88 E 44-7 D 53-8 6,462' 6.502' 40' 12/75 solated in 11/88 I/ ----sr-' au_e=g344, D 53-8 6,510' 6.525' 15' 12/3/75 solated in 11/88 D 54-5 6,554' 6,562' 8' 12/3/75 solated in 11/88 D 54-9 6,600' 6,642' 42' 3/70 solated in 11/88 D 55-7 6.672' 6,732' 60' 12/75 solated in 11/88 . 9 D 56-1 6,760' 6,866' , 106' 12/75 solated in 11/88 D 57-2 6,896' 7.020' 124' 12/75 solated in 11/88 ;j D 58-7 7,190' 7.191' 1' 5/68 WSO.Isolated in 11/88 j Hemlock 7.420' 7.421' 1' 5/68 WSO.Isolated in 11/88 7.436' 7.472' 36' 3/70 Isolated in 12/75.Isolated in 11/88 10 Hemlock 7.490' 7.600' 110' 3/70 Isolated in 12/75.Isolated in 11/88 Hemlock 7.680' 7,730' 50' 5/68 DST#1.Scad w/200 sx cmt.Isolated in 11/88 Hemlock 7 884' 7.934' 50' 5/68 DST#2.Isolated w/BP ra 7650'.Isolated in 11/88 Hemlock //////////////////////////////////////////////////i KB ELEV=101' PBTD=4,650' TD=8,068' ANGLE thru INTERVAL=39° A-14 Schm 11-88 Comp Revl O:\Alaska\Fields\Trading Bay Fiel d\_Monopod\_Wells\A-14\Schematics\A-14 Schm 11-88 Comp Rev1.doc REVISED: 12/15/05 BGA DRAWN BY: SLT II • • Trading Bay Unit PROPOSED Well #A-14 Completed: Future API#50-733-20099-00 CASING AND TUBING DETAIL RKB to TBG Hngr=37.68' SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 37 1097' i 41.I.1 9-5/8" 40 K-55 8rd LT&C 8.835 37 5586' Stage Collar 4349' 4351' 9-5/8" 40 N-80 8.835 5586' 7089' - 9-5/8" 43.5 N-80 8.755 7089' 7180' 8068' 7" 29 N-80 6.184 7071' Tubing: _ 2-7/8" 6.5 L-80 8rd EUE Surf ±3,191' -) JEWELRY DETAIL 4 NO. Depth ID Item 37.40 10"x 4-1/2"Cameron SM Tubing hanger,XO to 2-7/8"Butt 1 ±300' SSSV 2 ±1,574' GLV 3 ±2,653' GLV 4 ±2,905' Y Block 5 ±3,060' Bottom of ESP 11 ±3,150' Sliding Sleeve 12 13,160' Packer 13 13,190' X Nipple I. 14 ±3,191' WLEG 15 4,650' Cement Retainer 16 4,950' Cement Retainer Wireline Summary 11/8/99 Work 2.34"GR cutting paraffin&pumping Xylene @ 210' 11/9/99 Tagged fill w/1.75"Scratcher @ 4549' r 2/22/00 Worked through Paraffin.Tagged Fill w/2.5"Scratcher @ 4695' trEi �, 3 I 4D 9/30/05 Tag Fill w/1.91"GR @ 4542' Es12/15/05 Holes in tubing @ 3104',3108'&3118'.Ran TP-2 Packoffs 3098'to 3121' =_- Perforation Detail = Top Btm TOP Btm Accum. Date Zone (MD) (MD) (TVD) (TVD) Amt. SPF Last Opr. Present Condition _ B ±3,210' ±3,340' ±2,871' ±2,985' ±130' Future --- B ±3,785' ±3,815' ±3,354' ±3,378' ±30' Future B 31-8 3,785' 3,918' 3,354' 3,458' 133' 8 11/22/1988 Frac'd w/98700#of 20-40 B ±3,826' ±3,860' ±3,386' ±3,413' ±34' Future B ±3,884' ±3,920' ±3,431' ±3,460' ±36' Future B 33-6 3,954' 4,000' 3,487' 3,523' 46' 8 11/22/1988 Frac'd w/98700#of 20-40 B ±3,968' ±4,000' ±3,498' ±3,523' ±32' Future B Zone B 41-3 4,080' 4,100' 3,587' 3,603' 20' 8 11/22/1988 Frac'd w/42200#of 20-40 B ±4,082' ±4,104' ±3,589' ±3,606' ±22' Future B ±4,130' ±4,180' ±3,627' ±3,667' ±50' Future B 41-8 4,130' 4,230' 3,627' 3,708' 100' 8 11/20/1988 Frac'd w/42200#of 20-40 B 44-7 4,470' 4,565' 3,902' 3,979' 95' 8 11/16/1988 Frac'd w/45300#of 20-40 • 111 B ±4,477' ±4,550' ±3,908' ±3,967' ±73' Future B 4,568' 4,570' 3,982' 3,983' 2' 4 6/22/1988 WSO.Cmt sqz'd = B ±4,605' ±4,630' ±4,012' ±4,032' ±25' Future C-2 4,672' 4,720' 4,065' 4,103' 48' 4 4/27/1984 Cmt sqz'd Isolated in 11/88 C-3 4,790' 4,815' 4,157' 4,176' 25' 4 4/27/1984 Cmt sqi d Isolated in 11/88 C-5 5,000' 5,030' 4,310' 4,331' 30' 4 12/3/1975 Isolated in 11/88 , .....' C-7 5,230' 5,415' 4,479' 4,618' 185' 4 12/3/1975 Isolated in 11/88 C 47-5 5,540' 5,585' 4,715' 4,750' 45' 4 12/75 Isolated in 11/88 D 53-8 6,462' 6,502' 5,398' 5,427' 40' 4 12/75 Isolated in 11/88 D 53-8 6,510' 6,525' 5,433' 5,444' 15' 4 12/3/1975 Isolated in 11/88 D 54-5 6,554' 6,562' 5,466' 5,471' 8' 4 12/3/1975 Isolated in 11/88 D 54-9 6,600' 6,642' 5,500' 5,532' 42' 4 3/70 Isolated in 11/88 D 55-7 6,672' 6,732' 5,555' 5,603' 60' 4 12/75 Isolated in 11/88 D 56-1 6,760' 6,866' 5,625' 5,709' 106' 4 12/75 Isolated in 11/88 Hemlock D 57-2 6,896' 7,020' 5,733' 5,832' 124' 4 12/75 Isolated in 11/88 D 58-7 7,190' 7,191' 5,969' 5,969' 1' 4 5/68 WSO.Isolated in 11/88 / , 7,420' 7,421' 6,153' 6,154' 1' 4 5/68 WSO.Isolated in 11/88 Hemlock 7,436' 7,472' 6,166' 6,194' 36' 4 3/70 Isolated in 12/75.Isolated in 11/88 KB ELEV=101' Hemlock 7,490' 7,600' 6,208' 6,291' 110' 4 3/70 Isolated in 12/75.Isolated in 11/88 PBTD=4,650' TD=8,068' Hemlock 7,680' 7,730' 6,351' 6,389' 50' 4 5/68 DST#1.Sqzd w/200 sx cmt.Isolated ANGLE thru INTERVAL=39° in 11/88 Hemlock 7,884' 7,934' 6,504' 6,541' 50' 4 5/68 DST#2.Isolated w/BP @ 7650'. Isolated in 11/88 Updated by: ILL 07/15/13 • • • Monopod Platform 2013 BOP Stack 03/12/2013 Flilrnrp Usiskn.LFA• Rig Floor Bottom of air boot flange • 5'below rig floor 16 14.72' 9.50' I1AI IMIll:ll Ili•With I II Ili !11,11 3,74' Shaffer 13 5/8 5M 111,_111 AI Ill Iti 26.25' Shaffer LXT -- 2 7/8.5 Variables 2.50' I © 135/85M —:- — Blind I I ,t ni p1�1 1.76 F 1101H—: J46,%1 + 1 I I 1' ■li' j 41. '1j35805MFEXFE w/31/85M EFO w/21/165M Choke and Kill valves w/Unibolt end connections for lines f I '1 I !t 2.83' — Dual Cameron Flex rams '1! 1 ii .70' Ii'- :I 1,. 11�'Ili Drill deck Riser 14.20' 135/85M FE X 135/85M FE Spacer spool 1.5' 135/85M FE X113M I I I ,I Wellhead @ 15.00' - • ii • • Monopod Platform A-14 Proposed Hilr•nrp 1,1:1411.1,1:1411.LLt. 07/16/2013 Monopod Platform Tubing hanger,CIW-DCB- A-14 FBB,11 X 3 1/2 EUE 8rd lift X 13 3/8 X 9 5/8 X 2 7/8 3 1/2 EUE bottom, w/3"type H BPV profile,6'/. extended neck,2-''/.CCL ports BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union a E I. n. Valve,Swab,WKM-M, o ln 3 1/8 5M FE,HWO,DD trim ° o a c; Valve,Wing,WKM-M,3 1/8 . 1.1 5M FE,w/15"OMNI Valve,Wing,WKM-M,2 1/16 g operator,DD trim 1 111 . 5M FE,HWO,DD trim I 11440;1 t ° ill MIME 00,,E Valve,Master,WKM-M, or 1^ 3 1/8 5M FE,HWO,OD trim o o Q uA e0 a Valve,Master,WKM-M, 011 o ., 3 1/8 5M FE,HWO,DD trim 0$0 loll ;. Adapter,Cameron,11 5M Stdd X 7 1/16 5M stdd, prepped for 6'A neck,2- ,__i 41. cont control line exit Tubing head,CIW-DCB, .� I 13 5/8 3M X 115M, III - I11 •' w/2-2 1/16 5M SSO, Valve,CIW-F,2 1/16 5M FE, �� HWO,AA X-bottom prep = /o�1�I III I "� Casing head, w Shaffer KD, _ 135/83MX III IP III 13 3/8 SOW,w/2-2" ! 2"LP CIW ball valve LPO, • Ihh t 1_r,l M.j. ill. lOgir ar • Monopod Platform A-14 Proposed ESP 07/l 9/201S--- Ilan,rp,ta*.L:ii,I.JL p 1 I Tubing hanger,CIW-DCB-ESP, Monopod 11 X 41/2 IBT lift and susp,w/ A-14 I /_ (f---• 4"type H BPV profile, 5'/EN, 13 3/8 X 9 5/8 X 2 7/8 lY 0 3-3/8 continuous control line ports, prepped for BIW penetrator SLIMED JUL 2 9 2D13. BHTA, Bowen,4 1/16 5M FE X 7"-5 Stub acme Bowen Union it l!1 lil Valve,swab,WKM-M, ` A ® Cross,stdd,4 1/16 5M X 4 1/16 5M FE, HWO, G1( p Q 3 1/8 5M X 2 1/16 5M T-24 ®®cy i i Iil Valve,wing,WKM-M, --6 1� O 11 I Valve,WKM M, 3 1/8 SM FE,w/ 2 1/16 5M FE, HWO, O�® O MA 16 operator T-24 D ' I: P : ray � 8 � Valve, lower master,WKM-M, joy.( -- 4, 4 1/16 5M FE, HWO,T-24 ®0 a % u ,nom{ '/I --- 1.. Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5 14 EN neck, 3- 1/2 npt continuous � control line ports, BIW penetrator •'° port Tubing head,CIW-DCB, � / 13 5/8 3M X 11 5M _»,I u 1r_ w/2-2 1/16 SM SSO, MI I II X bottom Valve,WKM-M, 2 1/16 5M FE, -� w HWO, DD ® ®c Ili I IN I r. _S! Unocal North America~ 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, Gar~S.(~ush Regional Drilling Manager GSB/lew Oil ii 6as Cons. Oommi~n CONDUCTOR 1 2 3 4 5 6 7 8 9 10 ll 12 13 14 15 16 17 18 19 20, 21 22 24 25 26 27 28 29 3O 31 32 MONOPOD CENTER FROM SOUTHEAST CORNER, SECTION 4, T9N, R13W · "Y" = 2,523,126 "X" -- 218,871 ,, LAT. = 60°53' 48.65 ~,~,_ ' 43 51" ~V~a~7't LON G. 151 ° 34 · ~ ~z~/,i~l~ "Y" COORD. "X" COORD. WELL # FS____~L 2,523,134.3 218,880.9 A-28 1621 2,523,130.2 218,883.2 A-25 1617 2,523,125.7 218,883.9 A-30 1612 2,523,121.7 218,883.2 1608 2,523,118.2 218,881.3 A-27 1605 2,523,114.4 218,876.8 A-23 1601 2,523,113.2 218,873.0 A-21 and RD 1600 2,523,113.2 218,869.0 A-22 1600 2,523,114.8 218,864.6 A-14 1601 2,523,117.7 218,861.1 A-13 1604 2,523,121.8 218,858.8 A-17 1608 2,523,126.4 218,858.1 A-8 1612 2,523,130.3 218,858.8 A-15 1616 2,523,133.8 218,860.7 A-24 and RD 1620 2,523,137.6 218,865.2 A-29 1624 2,523,138.8 218,869.0 A-9 and RD 1625 2,523,138.8 218,873.0 A-19 1625 2,523,137'.2 218,877.4 A-lB 1624 2,523,132.8 21 B, 875.7 A-11 1619 2,523,129.4 218,878.6 A-3 1616 2,523,132.0 218,870.8 A-1 1618 2,523,128.4 , 218,873.9 A-7 1615 Pl~. ~q'TA. q A-4 1611 ,2,523~.24. _~ .......... 2,523,133.9 218,867.0 A-6 1600 2,523,120.9 218,878.1 A-32 1607 2,523,131.4 218,863.9 A-12 and RD 1617 2,523,118.1 218,875.0 A-20 1604 2,523,127.2 218,865.1 A-2 1613 2,523,123.6 218,868.1 A-16 1610 2,523,120.0 218,871.1 A-26 1606 2,523,122.6 218,863.4 A-lO 1609 2,523,119.2 218,866.3 A-5 and RD 1605 l&2 FEL 554 551 551 551 '553 557 561 565 570 573 576 577 577 574 57O 566 562 558 559 556 564 561 558 · 568 556 571 559 570 566 563 571 568 STATE OF ALASKA AL~ ,A OIL AND GAS CONSERVATION COMMIS( JN REPORT OF SUNDRY WELL OPEF TIONS 1 Operations performed Operatmon sht~down ~ St, mulate ~ Plugg,ng __ Pull tubing __ Alter casing __ Repair well ~ Pull tut:,ng~][. 2 ~n~n ~il Company of Oalifornia (U~O~AEI~ Name 0 erato ]r.y of Well Development ]r~z Exploratory __ i~ Strabgraph~c __ 3 Addres~.o. BOX 190247, Anch, Ak., 99519- 47 Serwce__ 4 Location of well at sudace 1601' N & 579'W ?rom SE cot., Sec. 4, TgN, R13W, SM At top of producbve interval 3785' MD, 3355' TVD, 926' S & 1318' W ?/Sur?ace Location At effective depth 4650' MD, 4047' TVD, 1068' S and 1816' W ?/Sur?ace Local At total depth 8068' MD, 6641' TVD, 1313' S and 4016' W ?/Sur?ace Local Perforate]O[ Other __ 6 Datum elevabon (DF or KB) RT 101' MSL feet 7 Un~torPrqpertv me /raa].ng ~y State 8 Well number TBS A-14 9 Permit number/approval number 8-292 10 APl number .on 50-- 733-20099 11 Field/Pool .on Middle Kenai "B" -/ 12 Present well cond~bon summary Total depth' measured true vertical 8068' feet Plugs(measured) 6641 ' feet Cement Ret $ 4650' 4950' 5213 ' 6350 ' Effective depth measured true vertical 4650' feet Junk(measured) 4047' feet Casing Structural Conductor Surface Intermediate Production Liner Perforabon depth Length 1097' 7108 997' measured true vertical S,ze Cemented 13 3/8" 9 5/8' 7" See Attached Measured depth True verbcal depth 1200 sxs 1000 sxs list) 1000 sxs 2nd) 160 sxs 1097' 7108' 7108' - 8068' 1054 5902 ' Tub, ng (s,ze, grade, and measured depth) 2 7/8", N-80, 6.4#/ft, 0-3758' Packers and SSSV (type and measured depth) Baker Model "D" Perm SSSV: Otis $ 313' 13 Sbmulabon or cement squeeze summary Intervals treated (measured) See At tached Treatment descnpbon including volumes used and final pressure Alaska Oil & 6as Cons. Commission 14 Pnor to well operabon Subsequent to operation Representative Dml¥ Average Production or Injecbon Data O~l-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 Shut-in 336 182 2 930 Tubing Pressure 290 15. Attachments Cop~es of Logs and Surveys run f. JIL-VDL-GR Daffy Report of Well Operations .z~ 16. Status of well class~flcabon as Od .z~ Gas_ Suspended __ Service 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge. S,gned /~oI~D .~ Ro~b~ Title Environmental Engineer Form 10-404 Rev 06/15/88 Date02/3/89 SUBMIT IN DUPLICATE Perforating Detail Measured Depth 7884 - 7943 7680 - 7730 6893 - 6941 6818 - 6838 7420 7190 6970 - 7020 6896 - 6898 6941 - 6950 6774 - 6818 6838 - 6866 6760 - 6768 6672 - 6728 6600 - 6642 6510 - 6526 6462 - 6502 7438 - 7472 7490 - 7508 7508 - 7600 6896 - 7016 6760 - 6860 6672 - 6732 6654 - 6562 6554 - 6562 6462 - 6502 6510 - 6525 5540 - 5585 5230 - 5415 5000 - 5030 4790 - 4815 4672 - 4720 4565 - 4470 4230 - 4130 4100 - 4080 4000 - 3954 3918 - 3785 True Vertical Depth 6504 - 6548 6351 - 6388 5731 - 5769 5670 - 5686 6153 5968 5792 - 5832 5734 - 5736 5769 - 5776 5637 - 5670 5686 - 5710 5625 - 5631 5555 - 5599 5500 - 5532 5433 - 5446 5398 - 5427 6166 - 6194 6207 - 6221 6221 - 6291 5734 - 5830 5625 - 5704 5555 - 5603 5544 - 5472 5566 - 5472 5398 - 5427 5433 - 5445 4715 - 4751 4516 - 4619 4309 - 4331 4157 - 4177 4065 - 4103 3980 - 3902 3707 - 3627 3603 - 3587 3523 - 3486 3458 - 3355 Present Condition Abandoned II I! It !1 II I! I! Il !f !1 II II !! !! !! I! Rroducin~ Stimulation and Squeeze Summary Stimulation: Fracture Treatment Stage No. 1 Perforation Depth: Sand Volume: Fluid Volume: 4565' - 4470' 45300 lbs. 20/40 Ottawa BBLs Wellhead Pressure 262 3900 92 3400 145 3800 38 3600 Fluid Additives: 3% KCL with .225% HPG YF240 - (HPg w/50 lb. per lO00 bbls) Breaker and crosslinker YF240 - with 8.6 to 12.& ppg 20/40 Sand 3% KCL Stage No. 2 Perforation Depth: Sand Volume: Fluid Volume: 4230' - 4130' and 4100' - 4080' 42000 lbs 20/40 Ottawa BBLS Welli]ead Pressure 210 95 142 22 3500 3000 2700 2500 Fluid Additives: Same as above. Stage No. 3 Perforation Depth: Sand Volume: Fluid Volume: BBLS 3954' - 4000' and 3785' - 3918' 98700 lbs. of 20/40 Ottawa Wellhead Pressure 229 205 330 27 3300 3700 3400 2850 Fluid Additives: Same as above. Cement Squeeze Squeeze No. i Below cement retainer at 4650' to abandon perforations from 4672' to 4720' and 4790' to 4815' (C - zone). Cement: 105 sacks class "g" w/ 3% KCL, .1% LWL, .2% CFR-2 and 3% Halad 344 Squeeze No. 2 Squeeze holes: 4568' to 4570'. Cement: 250 sacks class "g" w/ 3% KCL, .i% LWL, .2% CFR-2 and 3% Halad 344 reversed out 140 sacks cement. Final pressure 2700 psi. Squeeze No. 3 Squeeze holes: 4228' to 4230' Cement: 250 sacks class "g" w/3% KCL, .1% LWL, .2% CFR-2 and 3% Halad 344. Reversed out 15 sacks cement Final pressure 2300 psi. ~'~ION OIL CO. OF CALIFORNI~ DRILLING RECORD PAGE NO. L E A S E TRADING BAY STATE WELL NO. A-14 FIELD TRADING BAY STATE DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1988 06-16-88 06-17-88 06-18-88 06-19-88 06-20-88 06-21-88 06-22-88 Feet 8068'TD 8068'TD 8068'TD 8068'TD 4650'TD 4650'TD 4650'TD Completed skidding the rig to A-14. Filled well w/64 PCF of FIW & 3% KCL. RIH up Myers wireline. Pulled ball valve @ 282'. Ran scratcher to 4600' & pulled out of hole. Ran shifting tool to 1800' (tool was floating @ 1'-2' per minute). Pulled out of hole. Re-ran scratcher to 4600' & pulled out of hole. Pumped down annulus taking returns from tubing. Ran shifting tool & opened XAsleeve @ 4523' WLM (4564 TBM). ttempted to pump down tubing taking returns from 9-5/8", unable to break circulation. Re-ran shifting tool, unable to get below 4325' WLM. Pumped down 9-5/8" taking returns up tubing. Attempted to kill well by pumping down 9-5/8" casing and taking returns from the tubing. Then attempted to pump down tubing taking returns from 9-5/8" (7 SPM @ 750 PSI). Rig up Dresser wireline with APRS tubing pumch and run in the hole. Set down at 4357'. Shot six holes from 4353'-4351'. Pull out of hole and down wireline. Pumped 70 PCF kill fluid down tubing taking returns from 9-5/8" (21 SPM @ 600 PSI) and killed well. Set back pressure valves, nippled down the tree and installed the BOPE. Tested BOPE and pulled seals clear of packer (40,000 # Max). Removed hanger, circulated bottoms up and pulled out of hole laying down tubing. Changed out pipe rams and performed complete BOPE test. Made up burn over shoe with and ran in the hole. Milled on packer from 4611'-4613' with packer release tool and packer came loose. Pulled out of hole to 4343' and hung up. Worked two hours to get stuck packer free at 4343', no success. Released from packer and pull out of hole. changed burn over shoe and run in the hole, milled on packer from 4343'-4344'. Released from packer and changed shoes. Milled from 4344'-4345' and packer came loose. Pull out of hole dragging junk. Recovered packer. Made up bit and scraper and run in hole, tagged fill at 4940'. Attempted to clean out. Appears to be junk. Circulate well. Pull out of hole with bit and scraper. Rigged up wireline and ran casing profile tool. Made up 9-5/8" "EZSV" cement retainer on wireline and set at 4650'. Rigged up lubricator and ran CBL/VDL/GR from 4650' to 3000'. Pumped active mud system to production. Began to clean the mud pits. Finished cleaning the pits & refilled with 64 PCF filtered inlet water with 3% KCL. Changed well ver to clean completion fluid. Run in hole and stabbed into the cement retainer @ 4650'. Attempted to establish a breakdown rate & pressure. Circulated around the cement retainer. Pull out of hole & made up a clean out assembly & run in hole. Drilled out the cement retainer @ 4650'. Made up a cement retainer on drill pipe & ran in hole. Set the retainer @ 4650' & squeezed 105 sacks of class "G" with 3% KCL, 1% LWL, 2% CFR-3 & 3% Halad 344 (cement in place @ 1942 HRS.). Abandoned the C-zone perforations from 4672' to 4720' & from 4790' to 4815'. Rigged up wireline & perforated (4 HPF) from 4568' to 4570' & 4228' to 4230'. Pull out of hole with wireline perforating guns. Run in hole & set 9-5/8" cement retainer on drill pipe & 4545' drill pipe measurement.Broke down perfs F/4568' to 4570' with 2300 psi. Pumped into perforating with 2.5 barrels per minute @ 2400 psi. Mixed ~ squeezed for isolation with 250 sx. Class "G" with 3% KC1, .3% Halad 344, .2% CFR-2, & .1% LWL. Had final rate of 2.5 barrels per minute @ 2700 psi. Rev. out 140 sx. Cement in place @ 0444 hrs. 6/22/88. Pull out of hole. Ran & set 9-5/8" cement retainer @ 4200' drill pipe measurement. Broke down perforations 4228' to 4230' with 2500 psi. Pumped intoperforations with 2.5 BPM @ 2300 psi. Mixed & squeezed with 250 sx class "G" with 3% KC1, .3% Halad 344, .2% CFR-2, & .1% LWL. Had final rate of 2 BPM @ 1950' psi. Rev out 15 sx cement. Cement in place @ 1233 hrs 6/22/88. Pull out of hole. Removed blow out equipment & secured well. Prepared to skid rig to A-19 RD. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO, L E A S E rI'r~ADTNC~ BAY STATE W E L L N O.-~ F I E L O TRADING BAY STATE DATE 1988 11-12-88 11-13-88 11-14-88 11-15-88 11-16-88 11-17-88 11-18-88 11-19-88 11-20-88 E.T.D. F~t 4650'TD 4650'TD 4650'TD 4650'TD 4650'TD 4650'TD 4650'TD 4650'TD 4650'TD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Skid rig from A-ii to A-16 & ran a temperature/gamma ray log from 6718'-6186'. Skid rig to A-14 and began to rig up. Removed wellhead flange and nippled up BOPE. Repaired bearing in draw works. Tested BOPE. Picked up 8-1/2" bit and junk basket and ran in hole. Drilled cement and cement retainer from 4200'-4245'. Washed down to 2nd retainer at 4545'. Tested casing to 1500 PSI and held for 15 minutes. Drilled cement and retainer at 4545'. Pushed junk to 4650'. Tested the casing to 1500 PSI. Pressure bled to 1380 PSI in 10 minutes. Pulled out of hole and picked up a 9-5/8" casing scraper and ran in hole. Pulled out of hole laying down 5" drill pipe. Began picking up 3-1/2" PH-6 workstring Finished picking up 3-1/2" workstring and ran in hole to 4650'. Built FIWand 3% KCL completion fluid volume but unable to change over due to shore facility. Pulled out of hole and rigged up wireline. Ran temperature and gamma ray log. Ran in hole with workstring and changed over to completion fluid. Pulled out of hole and rigged up wireline. Perforated from 4505'-4565' (60'). Guns = 5" OD, 8 SPF, 120° phase. Completed perforating the "B" zone from 4505' to 4470'. Ran in hole with open ended drill pipe and observed well. Off loaded the fracturing and associated equipment. Completed offloading equipment. Set up frac. equipment and gelled fluid. Rigged up wireline unit. Pulled out of hole with workstring. Made up BHA for fracturing and ran in hole. Ran in hole and set packer at 4374'. Pumped 500 gallons of 7-1/2% HCL to by pass then reversed out. Rigged up wireline and ran pressure and temperature tools. Performed data fracture. Pressure and temperature tools failed. Pulled out of hole with tools and reheaded line. Performed step rate test & flow back. Performed leak off test and monitored pressure. Pulled out of hole with pressure and temperature tools. Ran OCL-GR tools. Pulled out of hole with logging tools. Fracture the "B" zone from 4565'-4470' with 45,300# of 20/40 Ottawa sand. Monitored pressure then open by pass & reverse circulated the tubing clean. Released packer and pulled out of hole. Ran in hole with 3-1/2" tubing open ended and spotted sand to 4265'. Rigged up wireline & began perforating second zone. Perforated the "B" zone from 4230'-4130' & from 4100'-4080'. Well began to flow slightly. Shut in & pressure built to 35 PSI. Ran in hole with 3-1/2" workstring and circulated well. Built fluid weight to 68 PCF. Checked flow and pulled out of hole. Made up fracturing bottom hole assembly and ran in hole. Set packer at 3968'. Tested surface equipment and fracture stimulated second stage of "B" zone with 42,000# of 20/40 Ottawa sand. (4230'-4130' & 4100'-4080'). Cut fracture job short 20,000~ sand due to silo plugging. · UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. L E A S E rr"~,i')Thi~ P~Y ~TA"["R. W E L L N 0 .-~,~r..~ F I E L D TRADING BAY STATE DATE 1988 11-21-88 11-22-88 11-23-88 11-26-88 11-27-88 11-28-88 11-29-88 0592N E.T.D. Feet 4650'TD 4650'TD 4650'TD 4650'TD 4650'TD 4650'TD 4650'TD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Finished fracturing the "B' zone from 4230'-4130' and from 4100'-4080'. Pumped 42,000# of 20/40 Ottawa sand. Monitored well pressure and observed closer. Opened by-pass and reverse circulated. Pulled out of hole. Tested BOPE. Annular preventer failed and all gates and valves tested. Well flowing slightly. Ran in hole and tagged sand at 4097'. Circulate bottoms up with returns of small amounts of oil and gas. Pumped 45 sx sand plug and pulled out of hole to 3800'. Hung tubing off and changed out annular element. Tested annular to 1500 PSI. Ran in hole and tagged sand at 4070. Circulated and cleaned out sand plug to 4070'. Laid second sand plug to 4020'. Rigged up wireline and perforated from 3785'-3918' and from 3954'-3964'. Made up fracturing assembly and ran in hole. Ran in hole with fracturing assembly and set packer at 3688'. Performed data fracture. Fractured the "B" zone from 3954'-4000' and 3785'-3918' with 98,700# of 20/40 sand. Monitored pressure for closure. Opened by-pass and reversed out tubing. Released packer and pulled out of hole. Ran in hole with open ended tubing to 3780' and shut in well. Suspended operations at 2200 hours 11/23/88. Fractured through the wellhead on A-16. Rigged down fracturing equipment. Waiting on boat to off-load equipment. Off-loading equipment. Ran in hole and tagged sand at 4023'. Cleaned out sand to 4650'. Reverse circulated well clean. Changed over to FIW and 3% KCL (68 PCF). Checked flow and pulled out of hole. Ran in hole with 9-5/8" scraper to 3785'. Pulled out of hole and picked up a Baker Model "D" packer. Ran in hole and set packer at 3707'. Pulled out of hole and made up test seals and ran in hole. Stabbed into packer and tested to 1500 PSI. Pulled out of hole and laid down the 3-1/2" PH-6 workstring. Changed rams and tested all BOPE. Ran in hole with 2-7/8" production tubing and stabbed into packer. Tested seals to 500 PSI. Nippled down BOPE. Nippled down BOPE. Nippled up tree and tested to 5000 PSI. Pull BPV and set SSSV. Cleaned the mud pits. Released the rig 1200 hours 11/29/88. . STATE Of ALASKA I~, ALAS .. OIL AND GAS CONSERVATION COM ,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [3( Suspend f-I Operation Shutdown [] Re-enter suspended well '~ Alter casing ~ T~me extenmon [] Change approved program [] Plugging [] Sbmulate ~ Pull tubing [] Amend order [] Perforate ;~ Other 2. Name of Operator Union Oil Company of California 3. Address P. O. Box 190247, Anchorage, AK. . 99519-0247 Locahon of wellatsurface 1601'N, 579'W from SE Cor., Sec 4, T9N, R13W, S.M. Attop ofproduchve~nte~al 4672MD, 4065 TVD, 1071'S and 1827'W from Surface Location Ateffec,ve depth 4950 MD, 4274 TVD, 1116'S and 2006'W from Surface Location Attotaldepth 8068 MD, 6641TVD, 1313'S and 4016'W from Surface Location 5. Datum elevahon (DF or KB) RT 101' MSL 6. Umt or Property name Trading Bay State 7. Well number A-14 8. PermIt number 68-27 9. APl number 50-- 733-20099 10. Pool Trading Bay Field feet · Present well condition summary Total depth: measured 8068 true vertical 6641 Effechve depth: measured 4950' true vertical 4274' feet Plugs (measured) feet feet Junk (measured) feet Cmt Ret. 4950' , 5213', 6350' Casing Length Structural Conductor Surface 1097 Intermediate Production 7108 ' Liner ' Perforation depth: 7""' ' "-' ~n/e~a;s~ ~eU(jb 8' Size Cemented 13-3/8" 1200 sxs 9-5/8" 7" 1000 ~xs 1st Stage 1000 sxs 2nd Stage 160 sxs 4672'-4720' and 4790'-4815' true vertical 4054'-4103' and 4157'-4176' Measured depth 1097' 7108' 7071'-8068' Tubing (size, grade and measured depth) 2-3/8" 4.6~'/ N-80 4667'-308' 2-7/8" 6.4~/ N-80 308'- 0' Packers and SSSV (type and measured depth) Otis "~D" Packer @ 4610' SSSV - Otis BV ¢ 281' 12 Attachments True Verhcal depth 1054' 5902' 5872'-6641' RECEIVED APR1 9 ,~Naska 0, ~ Gas Cons. Commissio~l Anchorage Description summary of proposal [~ Detailed operahons program [] BOP sketch ~ 13. Estimated date for commencing operahon May 1, 1988 14. If proposal was verbally approved Name of approver Date approved 15 I hereby certlfy that the foregoing is true and~;r.~., to thebestofmyknowledge S'gned ~.,4 ~. ~¢~/~ ~ritle Environmental Engineer Ro/D. Roberts ~' O. ommission Use Only Date Condlhons of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Notify commission so representahve may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned/~ ~ Commissioner by order of the comm~smon Date Submit in triplicate Time extension ~ Change approved program t-] Plugging L3 .Shmuiate ~ Pull tubing ~ Amend order [] Perforate :j~ Other Name of Operator Union Oil Company of California 5. Datum elevation (DF or KB) RT 101' MSL feet Address P. O. Box 190247, Anchorage, AK. 99519-0247 Location of well at sgrface 1601'N, 579'W from SE Cor., Sec 4, T9N, R13W, S.M. ,~tG~O2D of product,ve ,nterval MD, 4065 TVD, 1071'S and 1827'W from Surface Location At effectwe depth 4950 MD, 4274 TVD, 1116'S and 2006'W from Surface Location At total depth - 8068 MD, 6641 TVD, 1313'S and 4016'W from Surface Location 7 Well number 8. Permit number 68-27 9. APl number 50-- 733-20099 10 Pool Trading Bay Field 11 Present well condition summary Total depth measured 8068 true vertical 6641 Effective depth: measured 4950 ' truevert~cal 4274' feet Plugs (measured) feet feet Junk (measured) feet Cmt Ret. 4950' 5213' 6350' Casing Length S~ze Structural Conductor Surface 1097 13-3 / 8" Intermediate Production 7108 ' 9-5/8" L~ner Cemented Measured depth True Vertical depth 1200 sxs 1097' 1054' 1000 sxs 1st Stage 1000 sxs 2nd Stage 160 sxs 7108' 7071' Perforat,on depth 7~Tela's~¢e0d68' 7" 4672'-4720' and 4790'-4815' true vertical 4054'-4103' and 4157'-4176' Tubing (size. grade and measured depth) 2-3/8" 4.6(! N-80 4667'-308' 2-7/8" 6.4# N-80 308'- O' Packers and SSSV (type and measured depth) Otis "gTD" Packer @ 4610 SSSV - Otis BV 0 2RI' 12 Attachments Description summary of proposal ~.. Detailed operations program -8068' 5902' 5872'-6641' BOP sketch 13 Estimated date for commencing operation May 1, 1988 14 If proposal was verbally approved Name of approver Date approved 15. I hereby cert,fy that the foregoing ~s true and\co,re, q1 to the best of my knowledge S,gned ~.~ /~. ~~.~.. ~,tle Environmental Engineer Roy D. Roberts Oomm~ss~on Use Only Date ,~g--.-~,f~ Conditions of approval Approved by Nohfy commission so representahve may w~tness Fl, Plug integrity [] BOP Test -; Location clearance Approved Copy Returned ORIGINAL SIGNED BY ~/ - 07 L'-' ¢ ¢ LONNIE C. SMITH ' Commissioner [ ApprovalNo. by order of the commlss,on Date-/// Form 10-403 Rev 12-1-85 Submit ,n t.pl~cate ® ® 3e e Se ® e Be e A~TACHMENT - TRADING BAY STATE A-14 DESCRIPTION SUMMARY OF PROPOSAL Move in and rig up. Install BPV, remove tree, install and test BOPE. Pull and lay down existing completion. RIH, mill over and recover the permanent packer at 4610'. RIH and set cement retainer and set at 4665'. Pump into perforations (4672 - 4815) and establish a breakdown rate and pressure. Pump a minimum of 150 cu. ft. of Class "G" cement with 10% sand. Pull out of cement retainer and leave 50 linear feet of cement on top of retainer. (Cement plug from 4665' to 4815', plus 100' below perforations and 50' above the cement retainer). Pick up 3 stands aN reverse circulate aH cement from the drill pipe. POOH. Run CBL-VDL-GR from 4600' to 3800' and cement squeeze for zone isolation. RIH with 8-1/2" bit and clean out to 4660'. Pressure test casing to 1500 psi. Perforate and individually fracture stimulate the following zones: Zone Depth FRACTURE NO. 31-8 3785'-3918' 4 33-6 3954'-4000' 3 41-3 4080'-4100' 3 41-8 4130'-4230' 2 44-7 4470'-4565' 1 10. Clean out wellbore and run a single string completion (2-7/8", 6.4 ppf, N-80, Butt tubing). 11. Rig down and move off. Place the well on production. 0488N (1) Gas Cons. Commission Anchorage ¢ ® ® e Be e e 8, ® ATTACHMENT - TRADING BAY STATE A-14 DESCRIPTION SUMMARY OF PROPOSAL Move in and rig up. Install BPV, remove tree, install and test BOPE. Pull'and lay down existing completion. RIH, mill over and recover the permanent packer at 4610'. RIH and set cement retainer and set at 4665'. Pump into perforations (4672 - 4815) and establish a breakdown rate and pressure. Pump a minimum of 150 cu. ft. of Class "G" cement with 10% sand. Pull out of cement retainer and leave 50 linear feet of cement on top of retainer. (Cement plug from 4665' to 4815', plus 100' below perforations and 50' above the cement retainer). Pick ~ 3 stands and reverse circulate any cement from the drill pipe. POOH. Run CBL-VDL-GR from 4600' to 3800' and cement squeeze for zone isolation. RIH with 8-1/2" bit and clean out to 4660'. Pressure test casing to 1500 psi. Perforate and individually fracture stimulate the following zones: Zone Depth FRACTURE NO. 31-8 3785'-3918' 4 33-6 3954'-4000' 3 41-3 4080'-4100' 3 41-8 4130'-4230' 2 44-7 4470'-4565' 1 10. Clean out wellbore and run a single string completion (2-7/8", 6.4 ppf, N-80, Butt tubing). 11. Rig down and move off. Place the well on production. 0488N (1) RECEIVED APR 1 Alaska Oil & Gas Cons, Anchor~qe 2-3/8", 4.6// & 2-7/8", 6.4 N-80 Tul)~ng 4,607' to 4,623' Otis Model "WD" Packer W/Seal Assembly 'C' ZONE ~ C-2 Sd. L. C-3 Scl. r--C- 5 Sd. Squeezed /c'7 Scl. 1~,47- 5 Scl. WEI. L TBS A-14 PROPOSED RECOIVIPLETION P ESENT PROPOSED Gl_IV ,. GLrvl GLM XA X' rF 13-3/8", 61#, J-55 Casing ~.~ 1,097' Cement Retainer ~ 4,950' Cement Retainer @ 5,213' Cement Retainer @ 6,350' ) 7", 29//, N-80 Liner ~ 7,071' 5/8", 401t & 43.5// N-80 Casing (h? 7, 18 O' tom 7", 291t, N-80 Liner @ 8,068 2-7/8", 6.4#, N-80 Tubing Packer @ _+3,850' 33-6 Scl.-' 4 1-3 Sd. 41-8 Scl. ) 'B' ZONE 44-7 Sd. _..,, Squeezed Squeezed / SqueezedJ 'C' ZONE ~ ANGLED FILL UP LINE , t., , ,,I [, HYDRIL ' ,?' ~o<~ *~ ~,~E ~A~S ,,~,,* 4,0 HYDRAULIC VALVE . C H 0 K E : "Iii'fl'Ill- ~ ! MANIFOLD ,__,)'.~'~ ' .~ -----'- SEE DRAWING KILL LINE '~' --- ~ ~Jr~'~cz'u~Lc~OM MUD PUMPS ~ i . ~ & CEMENT UNIT TO MUD PUMPS & CEMENTUNIT % ~ BLINDR. AMS - CONTRA~,TOR FURNISHED OPERA TOR FURNISHED NOTES- 1. HYDRAULIC VALVES OPEN WELL NAME: AUTOMATICALLY WHEN RIG CONTRACTOR: DIVERTER IS CLOSED. RIG: STACK PRESSURE RATING: 2. FLEX HOSE (~/~) IS TO BE USED CHOKE LINE SIZE & MSP; IF NECESSARY WITH DDS' APPROVAL. NOTE: ALL CHANGES MUST HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT APR 1 DEPT. APPROVAL Alaska Oil & Gas Oons. Comm~ss~o~ Anchor~c~ REV i DATE D~AWN B HE';~<D CGN s-~.,,,~z~._~,~ 13 5/8' BOPE STACK B,A.W.! 6/17/86 SCALE NONE i 5M OR 1 OM ~,, ~,~.,~ ALL WORKOVER OPERATIONS UNION OIL COMPANY OF CALIFORNIA .... i ANCHORAGE, ALASKA SME~TS i $~EET DATE FREE GAS KNOCKOUT q CHOKE MANIFOLD UNOCAL PLATFORM RIGS 4-1/16' & 3-1/8', 5M MSP UNION OIL COMPANY OF CALIFORNIA '~NCHORA(~E ~ ALASKA DRAWNB - A. W .CKO ~ APP'O SCALE .._N.__O__N_ E.~ 2-3/8", 4.6// & 2-7/8", 6.4 N-80 Tul)~ng 4.607' to 4,623' Ot~s Model "WD" Packer W/Seal Assembly {C-2 Sd. 'C' ZONE 0-3 Scl. Squeezed C-5 Sd. C-7 Sd. 7-5 Sd. WEI. L TBS A-14 PROPOSED RECOMPLETION PRESENT ,I f,~ · I 1,1 - 'r _ ot 13-3/8", 61//, J-55 Casing 1,097' Cement Retainer @ 4,950' Cement Retainer @ 5,213' Cement Retainer @ 6,350' p 7", 29//, N-80 Liner @ 7,071' /8", 40// & 43.5// N-80 Casing- (.~ 7, 180' tom 7", 29#, N-80 Liner @ 8,068'._ PROPOSED 2-7/8", 6.4//, N-80 Tubing Packer @ _+3,850' ...-33-6_o Sd.~ 41-o3 Sd. ~-4 1 Sd. 'B' ZONE 44-7 Sd. Squeezed1 Squeezed~ 'C' ZONE Squeezed_~ ,, ( ( ~ ANGLED FILL UP LINE } ~ HYDRIL :%~x~ .~0q "L., .._J PIPE RAMS VALVE ~] I~l ' (~ ~ "~PIP~RAMS, CHOKE ' II1¥111 ,, ~ ~ ' ' MANIFOLD /"~,", - ' ~::~ . SEE DRAWING . ~ KILL LINE i OM MUD PUMPS ~-- 1 .... ' __~~-~ & CEMENT UNIT TO MUD PUMPS& CEMENT UNIT E~ ~,,~ BLiNDRAMS CONTRACTOR FURNISHED OPERA TOR FURNISHED NOTES: 1. HYDRAULIC VALVES OPEN WELL NAME: AUTOMATICALLY WHEN RIG CONTRACTOR: DIVERTER IS CLOSED. RIG: STACK PRESSURE RATING: 2. FLEX HOSE {f//) IS TO BE USED CHOKE LINE SIZE & MSP; IF NECESSARY WITH DDS' APPROVAL. NOTE: ALL CHANGES MUST HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT DEPT. APPROVAL REVi DATE -~~~,,~ 13 5/8' BOPE STACK o~w. ~.~ ~ c~. B,A,W.I 6/17/86 APP'D sc^cE NONE ALL WORKOVER OPERATIONS UNION OIL COMPANY OF CALIFORNIA I ANCHORAGE, ALASKA SHEETS , FREE GAS KNOCKOUT _J -4 ,,~0 OAT E CHOKE MANIFOLD UNOCAL PLATFORM RIGS 4-1/16" & 3-1/8", 5M MSP UNION OIL COMPANY OF CALIFORNIA ANCHORAGE , ALASKA o~AwaB. A APP'D SCALE CEIVED & Bas Cons. Anchorage Umon 0~1 and Gas D~,v.~s~on Western Region Umon O~1 Company ~ ,.,ahforn~a P O Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 unl®n September 23, 1985 Nr. C.V. Chatterton Alaska Oil & Gas Conservation Commission ~OO1Rorcupine Drive Anchorage, Alaska 99502 Dear Nr. Chatterton: TRADING BAY FIELD A-14 Attached for your approval are three copies of Union's intention to pull tubing in Well A-14. Please return a copy of the approved Sundry Notice to the undersigned. Very truly yours, Candace Lockwo6d Environmental Department cwl Attachments RECEIVED SE? 2 19'85 Alaska 0il & Gas Cons Commission Anchorage (~ STATE OF ALASKA O~ ALASKA ,~. AND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator UNION 0IL COMPANY OF CALIFORNIA 3 Address PO BOX 6247 ANCHORAGE AK 99502 4 Location of Well Cond. #9, 1601'N & 570'W of SE Cor., Sec.4, TgN, R13W, SM. 5 Elevation m feet (~nd~cate KB, DF, etc ) RT 100' WSL Lease Designation and Serial No ADL-18731 7 Permit No 68-27 8 APl Number so- 733-9_0099 9 Umt or Lease Name Trading Bay State 10 Well Number TBS A-14 11 Fteld and Pool Trading Bay Field "C" Zone 12 Check Approprmte Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO (Submit m Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repmr Well [] Change Plans [] Repairs Made Pull Tubing ~, Other ]~ Pulling Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) SUBSEQUENT REPORT OF (Submit ~n Duplicate) [] Altering Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starttng any proposed work, for Abandonment see 20 AAC 25 105-170) 1.) Nove in and rig up on well A-14. 2.) 4.) 5.) 6.) 7.) 8.) 9.) 10. 11. Install BPV's, kill well, ND tree, NU and test BORE to +_3000 psi. Rull tubing completion. Squeeze the C-1 & C-3 sands to + 4672-4815'. Clean out squeezes and existing plugs to + 6350'. Run and cement a 7" liner from + 4450-635'0'. Frac as directed. - Complete as a single 3 1/2" completion assembly as directed. ND BORE, NU & test tree. Return well to production. Release Rig. RECEIVED SEP 2 5 ]985 Alaska 0ii & Gas Ct,ns 60;,~inlSSl0n 14 I here~a~tJ;I~ fo~and correct to the best of my knowledge E'~-~'~ S,gned Lawrence u. Cutt~g T,tle ENVIRONHENTAL SPECIALIST The space below for Commission use Da09-12-8.5 Condtt~ons of Approval, ~f any Approved by. lit LONHI£ C. Sl lTtl Approvec~ Returned By Order of COMMISSIONER the Commission Form 10-403 ~ Rev 7-1-80 Submit "Intentions" ~n Tnpltcate and "Subsequent Reports" m Duplicate _ STATE OF ALASKA ALASKA~ .AND GAS CONSERVATION C{~ ¢llSSION MONTHLY REPORT F DRILLING AND WORKOVER OPERATION 1 Drdhng well [] Workover operation [] 2 Name of operator 7 Permit No UNION OIL COMPANY OF CALIFORNIA 68-27 3 Address 8 APl Number PO BOX 6247 ANCHORAGE AK 99.502 50- 733-20099 4 Location of Well 9 Umt or Lease Name at surface Conductor #9, 1601' N. & 570' W. of S.E. Corner Section 4, TgN, R13W, S.N. 5 Elevat,on ~n feet (~nd~cate KB, DF, etc ) I 6 Lease Designation and Serial No RT !0!' MSLI ADL 18731 Trading Bay State 10 Well No TBS A-14 11 Fmld and Pool NcArthur Bay Field "C" Zone For the Month of May ,19 84 12 Depth at end of month, footage drdled, hsh~ng jobs, d~rect~onal drdhng problems, spud date, remarks (4952' ETD, 3unk on Cmt Ret) 13 Casing or hner run and quantities of cement, results of pressure tests None 14 Coring resume and brief description None 15 Logs run and depth where run None RECEIVED JUN 2 01t G b~ L ,s , 1 6 DST data, perforating data, shows of H2S, m~scellaneous data Released crews from TBS A-14 ~ 24:00 hrs, Zone producer, 5/02/84. Completed well as a single "C" 17 I hereby~y that the foregoing ~s true and correct to the best of my knowledge ~DISTRICT DRLG SUPT 06/15/84 ......... - --~Z'~ -~ DATE -~_ NOT port onth~sform ~s requ~redforeachcalendarmonth, regardlessofthestatu;of operations, and mustbefdedt~~~ththeAlaska Od and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Rev 7-1-80 Submtt in duphcate ALASI~ STATE OF ALASKA . MONTHLY REPORT OPERAT I Drdlmg well [] Workover operat,on ~ 2 Name of operator 7 Perm,t No UNION OIL COMPANY OF CALIFORNIA 68-27 3 Address 8 APl Number PO BOX 6247 ANCHORAGE AK 99502 50_733-20099 4 Locat,on of Well at surface 9 Un,t or Lease Name Trading Bay State Conductor I~9, 1601' N. & 570' W. of S.E. Corner Section 4, TeN, R13W, S.M. 10 Well No TBS A-14 1 1 F,eld and Pool 5 Elevat,on ,n feet (,nd,cate KB, DF, etc ) 6 Lease Des,gnat,on and Ser,al No McArthur Bay Field RT lOl' MSL ADL 18731 "C" Zone For the Month of April ,19~4 12 Depth at end of month, footage drdled, hsh~ng jobs, d~rect~onal drdhng problems, spud date, remarks (4952' ETD, DPM, Sunk on top of cmt ret)-Depth · end of month. Tested BOPE to 2800 psi 13 Casing or I~ner run and quantities of cement, results of pressure tests - Set retainer ~ 5075' & squeezed "C" zone w/ 375 sxs cl "G". Set retainer $ 4827' & squeezed "C-5" w/ 219 sxs ci "G". Perfd & sqzd F/ 4655-4657' DIL w/ i24 sxs ci "G" for isoiation above C-2 sand. 14 Coring resume and brief description None RECEIVED 15 Logs run and depth where run CBL-GR-VDL-CCL f/ 4853-1850' MAY 1 11984 Alaska Oil & Gas Cons. Commission Anchorage 1 6 DST data, perforating data, shows of H2S, m~scellaneous data Dst thru RTTS set ~ 4838' DRM showed that the formation is pressured up to an .944 __ psi/ft equivalent in the vicinity of the C-6 sand. z~. C-2 sand 4672-4720' DIL~ ~o. C-3 sand 4790-4815' DiL~~ Perforated for production, 8 HPF 17 I hereb~ that the foregom! ~s tru_~.Bnd correct to the best of my knowledge 05/11/84 Fo¢~i 10-404 t on th~s form ~s required for each calendar month, regardless of the status of operations, and must be f,led ,n duphcate with the Alaska ~ Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Submit m duphcate Rev 7-1-80 o /'" STATE OF ALASKA ALA~5. ,A OIL AND GAS CONSERVATIOI~ .~OMMISSION SUNDRY NOTICES AND REPORTS ON WE S ~. DRILLING WELL ~ COMPLETED WELL ~ ~ O~R 2 Name of Operato~NiON O'L ~M~ANTM ~F ~"''~" .... 7 P~Lm,L~o ,Address P, O. BOX 6247, ANCHORAGE, ALASKA 99502 4 Lo:a~,o. ofWeU ~nducto~ ~9, 1601~N & ~70'W of SE Co~ne~ TRADING BAY STATE Section 4~ T~N~ R13W~ S.H. 5. ElevaUon ~n feet (~ndlcate KB, DF, etc.) RT 101' MSL 6 Lease Designation and Serial No ADL 18731 10 Well Number TBS A-14 11 F~eld and Pool TRADING BAY FIELD "C" ZONE 12. (Submit ~n Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Sumulat~on Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubing (Note Report muluple completions on Form 10-407 w~th a submitted Form 10-407 for each complet,on ) Check Appropriate Box To Indmate Nature of Notme, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Duplmate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) 1. Moved rig over TBS A-14 & rigged up. 2. Kiiied weii, instaiied BPV, removed tree, instaiIed& tested BOPE to 2800 psi. 3. Pulled & laid down existing tubing. 4. Logged w/CBL-GR-VDL-CCL f/4853-1850'. 5. Cleaned out to 5170'. Sa. Tested the well thru an RTTS set $ 4838'. The mud weight was increased to 136 RCF to control the formation pressure. Set retainer at 5075' & squeezed "C" zone w/375 sxs cl "G". 7. Set retainer at 4827' & squeezed "C-5" w/219 sxs cl "G". 8. Cleaned out well to 5225' DRM. 9. Set retainer at 5220' DRM. Attempted to test well and bleed pressure off w/o success. ROOH w/test string. 10. Set retainer at 4950' DIL & abandon C-5 sand f/5000'-5030' DIL w/250 sxs cl "G". ll. Perf'd & sqzd f/4655-4657' DIL w/124 sxs cl "G" for isolation above C-2 sand. Cleaned out well to 4952'. Rerf'd C-2 sand (4790-4815'DIL) & C-3 sand (4672-4720' DIL) w/8 HPF. Set production packer at 4599' DIL. Ran 2 3/8" completion assembly. 12. 13. 14. 15. I 14 i~' ,,,a,:.~.hereb~e~~r~ S,gned ~ ' - -,SIN R, CALLENDER T,tle Thea~a~elow for Commission use of my knowledge J Co~uons of Approval, if any DISTRICT DRILLING SUPT. By Order of Approved by. COMMISSIONER the Comm~ssmon Date __ Form 10-403 Rev 7-1-80 Subm,t "I ntentlons" ~n Tr,phcate and "Subsequent Reports" in Duphcate ' SUNDRY NOTICES AND REPORTS ON WELLS MAY 1984 PAGE 2 16. Installed BPV, removed BORE, installed & tested tree to 5000 psi. 17. Brought A-14 onto production at 24:00 hrs, 4-29-84. A-14 well was not redrilled as originally planned due to high pressure zones encountered during preparation for abandonment. The well was recompleted as a C-2 & C-3 sands producer. Verbal approval per Blair Wondzell 4-27-84. RECEIVED MAY 1 1 1984 Alaska 0il & ~as Cons. Commission Anchorage STATE OF ALASKA ALASK~ ilL AND GAS CONSERVATION C~ AMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well [] Workover operation ~ Name of operator UN[ON 0TL COMPANY OF CAL[FORNIA 3 Address PO BOX 6247 4 I..ocat~on of Well at surface ANCHORAGE AK 99502 Conductor #9, 1601' N. & 570' W. of S.E. Corner Section 4, TgN, R13W, S.M. 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 6 Lease Designation and Serial No RT !Ol' MSL ADL 1873] 7 Permit No. 68-27 8 APl Number 50- 733-20099 9 Un,t or Lease Name TruMan0 B~y 10. Well No TBS A-14 11 F~eld and Pool McArthur Bay Field "C" 70ne For the Month of March ,19 84 12 Depth at end of month, footage drilled, fishing jobs, directional drdl~ng problems, spud date, remarks Commenced Operations e 02:00 Hrs, 3/31/84 ETD 6350' ~ 3/31/84 13 Casing or I~ner run and quantities of cement, results of pressur9 tests None 14 Coring resume and brief description None 15 Logs run and depth where run None 16 DST data, perforating data, shows of H2S, m~scellaneous data Tstd Coiled Tbg BOPE & Choke Manifold to 5000 PSI - OK. APR ~ 9 ~84 AIaska Oil G Gas C-:r~s fjOrn~iS3i;)n 17 I hereby~,fy that the for;g~.~s true and correct to the best of my knowledge / / / N~Ff.E~-Report on this form ~s required for each calendar month, regardless of the status of operations, and must be filed m duphcate w~th the Alaska Qr~'~nd Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Submit ~n duphcate Rev 7-1-80 K(~ STATE OF ALASKA ~.~ ALAS ulL AND GAS GONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2 Name of Operator 7 Perm,t No UNION 0IL COMPANY OF CALIFORNIA 68-27 3 Address 8 APl Number RO BOX 6247 ANCHORAGE AK 99502 Bo233-20099 9 Un,t or Lease Name TRADING BAY STATE 4 Location of Well Conductor #9, 1601'N & 570'W of SE corner, Section 4, T9N, R13W, SH. 5. Elevation in feet (,ndlcate KB, DF, etc ) RT 101' MSL 12 Lease Deslgnatmn and Serial No ADL 18731 10. Well Number TBS A-14 11 Field and Pool TRADING BAY FIELD "C" ZONE Check Appropriate Box To Indmate Nature of Not,ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF. (Submit ~n Tr,pl~cate) (Submit m Duplmate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~] Other [] Pulhng Tubing [] (Note Report multlplecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for each complet~on ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) To abandon "C" zone, TBS A-14, Honopod Platform, Trading Bay Field, Cook Inlet, Alaska. RROCEDURE: 1. Hove rig over TBS A-14 and rig up. 2. Kill well, install BPV, remove tree, install and test BOPE. 3. Rull and lay down existing 3 1/2" completion assembly. 4. Clean out to permanent packer ® 4860'. 5. Run CBL-VDL-GR from +4860' to surface. 6. Set cement retainer ~ +4810' and squeeze "C" zone perfs for abandonment. RECEIVED Workt~-e9°rtea oo JUN 2 ]983 Alas~ 0il & Gas Cons C0mm~ssJ0r~ Anchorage 14 I her~rtlfy that the forgoing Is true and correct to the best of my knowledge S,gned~~ ~~~~ ~~ T,tle D~S~C~ ~g ~pe~n~enden~ Date ~/~/8~ tonsof Approval, ~f any ORIGINAl SII~ED Approved Copy Returned BY LO~,>~IE C. SAI"T~I Bv Ordero' Approved by % COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" tn Triplicate and "Subsequent Reports" in Duplicate C STATE OF ALASKA C)( ALASKA IL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator UNION 0[L COMPANY OF CALIFORNIA 3 Address P. 0. BOX 6247, ANCHORAGE, AK. 99502 4 Location of Well 1601' N & 570' W from SE corner of Sec. 4; T9N, R13W, S.M. 5 Elevation in feet (~nd~cate KB, DF, etc ) 101' R.T. abnvP MSL: 12 7 Permit No 6R-27 8 APl Number 50- 133-20099 9 Umt or Lease Name Trading Ray I 6 Lease Designation and Serial No ADL !873! 10 Well Number A-14 11 F~eld and Pool Trading Ba~v "C" Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO (Submit in Triplicate) Perforate ~] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) SUBSEQUENT REPORT OF (Submit ~n Duplicate) [] Altenng Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) It is proposed to reperforate the following intervals: 5000 -- 5030 C-5 5250 - 5270 C-7 5280 - 5330 5350 - 5400 5540 - 5580 47-5 Subsequent Work Reported r~n Form No./_6~"/t o~ Dated .~_/~.~.~'/ .JUL. 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned C _~ ~'~5~'t~ ~I"~_..., ~u,x~---a~k--- T,tle DISTRICT FNG!NEER The space below for Commission use Co ~. CASE Date -2~J,NE 29, 1 Conditions of Approval, ~f any Approved by ORIGIN,q[ SIGNED BY I. ONNIE C. SMITH Approved Copy ~eturned By Order of COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duplicate October 11, 1978 UNION OIL CON[PANY P.O. Box 6247 Anchorage, Alaska 99502 Reference: A-14 Gent lemen: This report contains a summary of the drilling mud costs on the well referred to above. The record of drilling mud tests is provided for your information and is representative of the tests made on the mud system during the drilling of the well. The well cost summary and engineering report is filed in our Houston office. Should you require additional information, we will be pleased to furnish it. We look forward to an opportunity to serve your future needs with a complete line of drilling muds and services. Very truly yours, Market lng Adminis tra t ion IMCO SERVICES A O,v,s,0n of HALLIBURTON Company 2400 West Loop South · P O Box 22605 · Houston, Texas 77027 · 713/622-5555 · Telex 76-2433 ·Cable. IMCOSERV iWlCt) SERVICES A D~ws~on of HALLIBURTON Company 2400 West Loop South P O Box 22605 Houston, Texas 77027 A/C 713 671-4800 WELL DATA SUMMARY COMPANY UNION OIL COMPANY ADDRESS Anchorage, Alaska REPORT FOR MR WELL NAME & NO A-14 W/O STATE Alaska IMCO WAREHOUSE X Kenai ICOUNTY Kenai CONTRACTOR PARKER DRILLING COMPANY ADDRESS REPORT FOR MR FIELD Cook Inlet DESCRIPTION OF LOCATION Mono Pod Platform WELL DATA DATE SPUDDED 8-23-78 TOTAL DEPTH 7020' DATE TD REACHED 8-30-78 TOTAL DAYS 8 CSG SIZE FROM TO OD CSG SIZE FROM TO OD CSG SIZE FROM TO OD CSG SIZE FROM TO OD HOLE SIZE FROM TO HOLE SIZE FROM TO HOLE SIZE FROM TO HOLE SIZE FROM TO BITS NUMBER AND SIZE MUD UP DEPTHS TYPE MUD Drill-S, CaC12 COMMENTS Killed well with Drill-S - IMCO water - acidized three zones. Well started to flow. Acid reaction with weight made it necessary to discard system and use CaC12 to 81#/cu.ft. Jack Hall IMCO REPRESENTATIVE IMCO FORM 509 D IN ~t $ A 1OM · COST SUMMARY £'LS~C~, IA TOTAL DEPTH ~ 7,' ~'~' SERVICES A Dmsm of HALLIBURTON Company 2400 West Loop South, P O Box 22605 Houston, Texas 77027 A/C 713 622-5555 DATE PRODUCT UNITS 9.00 SIZE ~.OOLS 50L5 50LB 50L8 ~GAL DAY AMOUNT P. ,')jo 0 I I 2n',n 0 q77~4L~o RECORD OF comP^NY . UNION OIL COMPANY ,EliVICESDRILLIHG MUD TESTS wE,L N~~- --- .IBURTON Company A-14 W/O 0 5/8 ~ 7020 8 J__/ ! I-T ! FIELD COUN1.Y STATE ~ Cook Inlet Kenai Alaska CONTRACTOR Sec 1' R @ ~ Parker Drlg. Co., SALT wATER METHYLENE BLUE YIELD GEL HT HP CAKE ALKALINITY CHLORIDE CALCIUM SAND SOLIDS Oil CONTENT ,hSLOSITY PLASTIC VALUE STRENGTH pH FILTRATE FILTRATE 32nd O ppm ION % VOL % VOL % VOL % VOL me/mi Ibs/bbl sec ViS cps lbs/100 fl2 10S 10M mi TEMP___~uF500 psi ~ IN Pt Mt Pm E] gPg ppm --- · 'oxj--150 bbl. flukd with 8 #/klbl. Iril-S and 10 #/bbl Safe Seal and f;% KCI.. Ir inlet lon,g string and! bl,ock l:eufs. Below paker at 6883'. Mi:~ 65 /~/ft. sa~.t water. Pimp down weill to kill at 9.400 hrs. raisirg weight l o 661~ft, ~n aE nulus ! 30 2 3 1~1 2 8.2 with salt - addl 250 sx. IMCC Wate -weight ir. piill pit to 76 to 77 - highest at flbwli] .ng entrained airL I , I 30 2 3 II 2 6.0 , out preventer toIpull trbing. I 34 8 8 1! 2 6.0 190000 )ing - going in h?le with 5" trill pipe 'and retrieve packer· i I 34 7 7 11 2 6.0 190000 34 9 8 1~, 2 6.0 1 55000 ~erfs. acidi2e ~pper pe,rfs. -circ gas and air ~entrained mud - lowest weight 52. 32 7 3 1'~ 1 6.0 11.8 1 . ~ J 68000' 18 8 74 cut back weight ~o 66-6[ chl. content down to 13~000 ppm - started 'to bring mc.d back ~hen drill pipe p~uged w~th s~lt - shot hole - clean hole with inlet ~:ater and [,ack up. l I I I i i I I ~~~ FORM 514. considered, al]d may be u.,ed ii lhe ust.r so elect. However. nd qaaruntce ~ ol d,ly F Ihd die In.id(' ,, STATE OF ALASKA ALASK(r ~L AND GAS CONSERVATION ~ MMISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2 Name of Operator UNION 0IL COMPANY OF CALIFORNIA 3 Address P. O. BOX 6247, ANCHORAGE, AK. 99502 4 Locat,on of Well 1601I N & 570' W from SE corner of Section 4, T9N, R13W S.M. 5 Elevation in feet (~ndlcate KB, DF, etc ) l Ol' Rt above MSL Lease Designation and Serial No ADL- 1873] 12 7 Permit No 68-27 8 APl Number 5o-133-20099 9 Unit or Lease Name Trading Bay State 10 Well Number A-14 11 F~eld and Pool Trading Bay "C" Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF (Submit m Triplicate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13. Describe Proposed or Completed Operations (Clearly state all pert,nent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) The following intervals were reperforated in June 1981: 5,000 - 5,030 C-5 5,250 - 5,270 C-7 5,280 - 5,330 5,350 - 5,400 5,540 - 5,580 47-5 JUL ! ~J~81 AJaska 0il & Gat Cons. C0n~m~ssi0n Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned ~-------.._.~_~,{~_t._~ ~ ~,,~ T,tle DISTRICT ENGINEER The space below for Corem,ss,on use C. H. CASE Date June 24, 1981 Conditions of Approval, ,f any By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate Form No P-4 REV. 3-1-70 r'~s SUBMIT IN DUPLICATE ( STA E OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-20099 6. LEASE DESIGNATION AND SERIAL NO. ADL 18731 UNION OIL COMPANY OF CALIFORNIA TRADING BAY STATE 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 1601' N & 570' W from SE corner of Sec. 4, T9N, R13W, S.M. 9. WELL NO. TBS A-14 10. FIELD AND POOL, OR WILDCAT TRADING BAY -"£" "D" Sands 11. SEC. T. R. M. (BOTrOM HOLE OBJECTIVE) Sec. 4,T9N,R13W, S.M. 12. PERMIT NO. 68-27 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH TDAND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 10 11 9/1/78 9/2/78 8070' TD 6300' ETD 13 3/8"@1097' 9 5/8"@7180' 7"Liner @7071 ' - 8068' 8070' TD 6300' ETD 13 3/8"@1097' 9 5/8"@7180' 7"Liner @7071' - 8068' Killled well after acid work w/80 PCF CACL?. POOH w/ Baker Wash Tool. Ran Baker Model "D" Prod. Packer & Set @4890' for "C" Zone completion. Ran 3 1/2" Prod. Tubing. Packer failed to test. POOH w/3 1/2" Prod. Tbg. Ran Baker Model F-1 Prod. Packer & set @4860' WLM. Reran 3 1/2" Prod. Tbg. & locat, ed on packer @4860~ WLM. Removed BOPE & installed X-mas 'tree & tested to 5000 psi - OK. Displaced well w/ F.I.W. Put well on Production. Released rig @12:00 P.M. 9/2/78. Production Test: (Flowing Well) Gross Net Cut Choke FM. Gas Tbg/Csg. Press. 370 286-220% 17/64 91 MCF/D 590/575 RECEIVED OCT ;] 0 1978 '4. ' hereby _~l_fy_ ,h:..l t~. ~oi~jjmj~lll~ 10/17/78 SIGNED _,e~ _ TITLE DISTRICT DRILLING SUPT, DATE N~'eport on this form is required for each calendar month, regardless of the status of operation~, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form 104)03 GEV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) OiL ITl GAS I--I WELL Inl WELLt I OTHER 15. APl NUMERICAL CODE 50-133-20099 6. LEASE DESIGNATION ANO SEF ADL 18731 7. IF INDIAN, ALLOTTEE OR TRII 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME UNION OIL CO. OF CALIFORNIA TRADING BAY STATE 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247, ANCHORAGE, ALASKA 99502 TBS A-14 4. LOCATION OF WELL 10. FIELD AND POOL, ORWILDCI At surface 1601' N & 570' W. from S.E. Corner of Sec. 4, T9N, R13W S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 101' RT Above MSL 1.4. Check Appropriate Box To Indicate Nature of Notice, Re .__ TI~AI~TNR RAY - "'C."' 1.1. SEC., T., R., M., (BOTTOM HOLI-'__OB~J_I~,CTIVEI Sec. 4, T9N, R13W, S.M. 12. PERMIT NO. 68-27 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZlNG (Other) See Below REPAIRING V~/ELL ALTERING CASING ABANDONMENT* (NOTEt Report results of multiple completion on Well Coml~etion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent ~letlll& and give pertinent dates, incluchng estimated date of starting any proposed work. THE "D" ZONE SANLSWERE ABANDONED & THE "C" ZONE PERFORATIONS ACID/SOLVENT WASHED ON TBS A-14 AS FOLLOWS' · 2. 3. 4. . 1 Removed tree, installed & tested BOPE. Pulled & layed down 3 1/2" Production Equipment. Cleaned out 6360' w/ 8 1/2" bit & 9 5/8" csg. Scraper· Abandoned "D" Zone perfs 6462'-7020' w/ 350 sxs cmt. squeezed thru cmt. ret. @6350'. Acid solvent washed "C" zone perfs 5.0.lQ'-5000', 54~15'-5230', 5585'-5540' w/ 20 gal/ft. 5% HCL, w/ 7% Mutual Solvent· Ran 3 1/2" production equipment w/ Pkr. @4860'. RECEIVED Removed BOPE & installed & tested TREE. Placed well on gas lift producing from "C" zone. 1.6. I hereby certify that the foregoing is true and correct (This ~P~ee~_o~r S~ate office use) APPROVED BY, CONDITIONS OF APPROVAL, IF ANY: TITLE . Dist. Drlg. Supt. .,, DATE 9/29/78 DATE See Instructions On Reverse Side Form No. P-4 SUBMIT IN DUPLICATE REV. 3-1-70 STATE OF ALASKA ..... ' " · ' OIL AND GAS CONSERVATION COMMITTEE s. API NUMERICAL CODE 50-133-200qc,- -~--' - .. 6. LEASE DESIGNATION ND ~ERIAL N~. ~_~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ADL 18731 ...... 1. 7. IF INDIAN-ALOTTEE OIL IX=1 GAS F~ -- [. WELL WELL OTHER ' ..... UNION OIL COMPANY OF CALIFORNIA TRA.DZNG BAY 3. ADDRESS OF OPERATOR 9. WELL NO. [ F ' P.O. BOX 6247, ANCHORAGE, ALASKA 99502 TBS A-14 4. LOCATION OF WELL 10. FIELD AND POOL, OR ~ILI~AT Tradi n.q Bay .~:" & "-D~r-~ .nc 1601' N & 570'W from SE corner of Sec. 4,T9N, R13W, II. SEC. T.R.M.(BOTTOMHO'---L_E S.M. OBJF_LTFlVE) Sec. 4, T9N, R13W, S.M. 12. PERMIT NO. 68-27 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 8/23/78 7050' ETD (cmL. plug) 13 3/8" Csg. 1097' 9 5/8" Csg. 7180' Mud 66# Brine Commence operation 12:00 noon 8/23/78. Pulled ball valves from short and long strings. Bullheaded 55 bbls of 8 ppb Dril-s w/ 6% KCL & 10 PPB Safe-Seal down L.S. Ran shifting tool and attempted to open "XA" in L.S. @+6376', tool stopped @+6300'. Bullheaded 50 bbls 8 PPB Dril-s w7 6% KCL & 10 PPB Safe-Seal down S.S. (S.S. has hole in it.). 8/24/78 7050'ETD (cmL plug} 13 3/8" Csg. 1097' 9 5/8" Csg. 7180' Mud 66# Brine RECEIVED Divlsi0n ef Oil & ~) Oen~ervat~o,-. R.U.W.L. & opened "XA" in S.S. @4907' Circ. down S.S. & out annulus until clean returns. Jet cut S.S. @4912'. Circ. down S.S. taking returns out annulus (well still trying to flow). Circ. & condition W.O. f,~uid to 66 PCF. Took shut in pressures follows after circ. 66+PCF W.O. Fluid around: Shut in L.S. Press. 460psi Shut in S.S. Press. 250psi Shut in csg. Press. 250psi Perfed 2 holes in L.S.f/5990' to 5991'. Circ. W.O. fluid down L.S. taking returns out S.S. thru Swaco holding constant BHP for 1 circ. S.I.S.S. & opened annul us to Swaco. 8/25/78 7050' ETD (cmL plug) Complete full circ. out annulus w/ 66PCF 13 3/8" Csg. 1097' W.O. fluid, took shut in pressures I.E.L.S. 9 5/8" Csg. 7180' 125 psi, S.S. & annulus 200 PSI. Circ. & 77 PCF condition W.O. fluid to 74 PCF, and circulated around. Took shut in pressures, i.e.S.S., L.S. and annulus.+2OPSI. Circ. & Cond. fluid to 77 r~,-,r- --- J - ~ - .I ........ m 14. Ih~ce~tffythattlm~m~trueRdco~.t- ~_ rt~,-, o,,,., circul a,,.,u,mu. $1GNED~--~--,-----' ~"'""-'~~-~'~k..~.I~..K~'tTLEI'ITqT flPTI I TEI~ SUPT DATE 9/15/78 NOTE~on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succe{~ling month.unless otherwise d,rected. 8/26/78 8/27/78 8/28/78 8/29/78 ~/30/78 7050' ETD (cmt plug) 13 3/8" Csg. 1097' 9 5/8" Csg. 7180' 77 PCF 7050' ETD (cmt plug~ 13 3/8" Csg. 1097' 9 5/8" Csg. 7180' 77 PCF 7050' ETD (cmt plug) 13 3/8" Csg. 1097' 9 5/8" Csg. 7180' 77 PCF 6350' ETD (cmt ret.) 13 3/8" Csg. 1097' 9 5/8" Csg. 7180' 77 PCF Brine 6300' ETD(cmt plug) 13 3/8" Csg. 1097' 9 5/8" Csg. 7180' 66 PCF Brine Took shut in pressures 0 PSI. Installed B.P.V. Removed Tree. Installed & Tested BOPE. Pulled Dual 3 1/2" completion Assy. 1 Jt. & stuck triple PKR @ 4912'. Jet cut L.S. @ 4860'. Pulled & L.D. 327 Jts. of 3 1/2" TBG. R.I.H. w/ 3 1/2" grapple & engage fish. Jarred fish loose w/ 175 M#. Pulled fish up hole 18'. R.U. to circ. BTMS up. Finished Circ. BTMS up. Pooh & rec. Fish. (Triple PKR & 1 1/2" dip tube String & ' 2 7/8" L.S. below PKR.) NOTE: BTM 2 Jts. 1 1/2" Dip Tube full of san & BTM 2 Jts.- of 2 7/8" where scaled up, R.I.Ho, w/8 1/2". bit & 9 5/8" scraper & cleaned out to 6360' POOH R.I.H. w/Baker Retrievamatic & set @ 4990'. Tested 9 5/8" Csg. F/4990' to surface @3000 PSI - OK. Released PKR & Pooh set cmt. ret. @ 6350' Tested surface Equip. @ 4000 PSI Broke d~wn perfs, f/7020' to 6462' w/2300 PSI. Mixed & Pumped 350 sxs C1 "G" w/ .75% D-31, 5% D-19, & .1% D-6, 236 sxs below ret. left 8 sxs on top of ret. Rev. out 106 sxs. Final press. of 3000 PSI. C.I.P @ 09:45 Hrs. 8/29/78. Pooh R.I.H. w/Baker Mod. "B" Circ. Washier to 5602' & blanked tool - OK. Pulled up & located perfs @ 5585' Opened circ. ports & spotted acid to too]. Close~ circ. port & hydrill. Washed perfs f/5585 to 5540' with 20 gal/FT. 5,00' HCL w/7% mutual solvent. Bleed press, off csg. Opened hydril. Blanked tool below perfs @ 5420'. Pulled up & located perfs ~ 5415'. Opened circ. ports ~ spotted acid to tool. Closed Hydril & ports. Acid/Solvent washed perfs from 5415' to 5230' w/ 20gal Ft. 5% HCL w/ 7% mutual solvent. Bleed press off csg. opened hydril, pulled tool up to 5035' ~ blanked tool. Located perfs and @ 5030' & opened circ. ports & spotted acid to tool. Closed ports & hydril. Acid/Solvent washed perfs f/5030' to 5000' w/20 gal/Ft, of 5% HCL 7% mutual solvent. Blanked tool above perfs @5000'. Opened circ. ports circ. out gas mud. (Note' Mud cut back to 66 PCF f/76PCF due to acid contamination) Mixed 110 bbls. of Mud to 73 PCF w/salt. Pumped 80 BBls. down D.P & Circ. stopped. RIH w/Perf Gun down D.P. & tagged fill @+4655' (+345' above tool) Shot 5 Hole @+4625~-. Stilt unable to circ. Pooh w/gun. RIH w/ Perf gun & shoot 5 holes @4621'. Established circ. 8/31/78 6300' ETD 13 3/8" Csg 1097' 9 5/8" Csg. 7180' 80 PCF Brine Cent. circ. well w/FIW. Shipped acid contaminated mud to Production at beach. Circ. & Cond. W.O. fluid to · 80 PCF to kill well. - (S.I.C.P. + 440 PSI w/63 1/2 PCF FIW in hole. ) RECEIVED oEP 1 $ i~97§ Un~on O~1 and Gas D~ws~on: Western Region Un,on Od Company, ~ahforn~a P O Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 union August 9, 1978 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99510 Dear Mr. Hamilton: Transmitted for approval and information are the following duplicates of State forms that were not received in your office via our transmittal of July 26, 1978: TBUS G-12RD-2 Completion Report Subsequent Abandonment Sundry Notice TBS A-32 Sundry Notice TBS A-10 " " __TJ~.~ A?_I 1 " II II Si ncerel y yours, "Jim R. Callender Dist. Drl9. Supt. Form 10-403 REV. 1o10-73 f ' Subml t "1 ntentlons" In Triplicate /'~ & "SubseQuent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-J° for such proposals.) O,L E--I ~^s I--1 WELL I~_.1 WELLI I OTHER 2, N~M~ OF OPERATOR un]on 0il Company of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL At surface 1601'N & 570'W from SE corner of Sec. 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) lOl'RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20099 LEASE DESIGNATION ANO SERIAL NO, ADL ]873] 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. A-14 10. FIELD AND POOL, OR WILDCAT Trading Bay - "C" & "D" sands · 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. 12, PERMIT NO. 68-27 )ort, or Other Data NOTICE OF INTENTION TO'. FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) '~S~f3 bP1 qW SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE.. Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent details, and give pertinent dates, tnclud~ng estimated ciate of starting any proposed work. To abandon the "D" Zone sands and acid/solvent the "C" Zone perforations on TBS A-14. PROCEDURE- · 2. 3. 4. 5. Move rig over A-14 and rig up. Remove tree, install and test BOPE. Pull and lay down existing dual 3 1/2" production equipment. Clean out to ETD with bit & scraper. RECEIVED - g 1978 Division of 0~1 ~nd Ca,:~ Abandon "D" Zone perforations from 6462' to 7020' with 350 sx of cmt s~eh~s~KI thru cmt. ret. set at +.6350'. 6. Acid/solvent wash all "C" Zone perforations with 5% HCL and 7% solvent. 7. Run single 3 1/2" production equipment. 8. Remove BOPE, install and test tree. 9. Place well on gas lift producing from "C" Zone sands. ESTIMATED STARTING TIME' September 26, 1978 ESTIMATED OPERATING TIME- 14 days I hereby certify that the foregoing is true and correct (This/,si:~ace for State office u~) CONDITIONS ~PPROVAL, IF See Instructions On Reverse Side DATE .. 7/25/78 Approved ,Z Dp7 Returned tJmon Od and Gas~ ~s~on Western Region Union Oil Company of Cahforma P O Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 union December 13, 1977 Mr. O, K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 C ~', ;t 1 ~.'"L ? C"~' L 3 i - REV --t---DRA~1- - ~--'- $[C. CONF[R FtL[ RE' TBUS G-23,~ TBUS A-27L KU 33-30L Dear Mr. Gilbreth' Enclosed for your information are two copies of the Monthly Reports for the above captioned projects. Si ncerely yours, ~'~im R! Callender Dist. Drlg. Supt. sm Encl Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL ~] GAS [~] WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Co. of Calif. 3.ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4. LOCATION OFWELL 10. Conductor //9, Monopod Platform, Cook Inlet 160l'N & 570'W from the SE corner of Section 4' ii. T9N, R13W, S.M. 12. 5. APl NUMERICAL CODE __ 6. LEASE "~-.SI-GN"~I~ ~NO SERIAi~ N0. ] ADL 18731 ~? 7.IF INDIAN-ALO~EE OR TRIBE N~ME , 4 ~ [ .... 8. UNIT FARM OR LEASE NAME Trading Rny State 9. WELL NO. TBS A-141 FIELD AND POOL, OR WILDCAT ~ T~'nd'inn R~u ~4,.,1A , OBJECTIVE) Sec 4' T9N, R13W, S~M~ PERMIT NO. 68-27 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Sf~ 5 11/1/77 8070'TD 7050 'ETD (cmt plug) 9 5/8" csg. @7180' 7" 1 iner @8068' Finished circ. hole clean from 7050'. Pulled 1 1/4" tbg. to 6476' and waited 2 hrs w/ pump off. RIH and tagged sand @6950' (100' fill). Washed out sand fill from 6950' to 7050'ETD in 2 hrs. Circ. hole clean in 2 1/4 hrs and pulled up to 6476'. Waited 2 hrs w/ pump off. RIH and tagged sand @7020' (30' fill). Washed out sand fill from 7020' to 7050'ETD in 1 hr. Circ. hole clean in 2 1/2 hrs and added "XC" polymer to workover fluid for viscosity. Pulled up to 6476' and waited 2 hrs w/ pump off. RIH to 7050'ETD w/ no sand fill. Circ. btms up and pooh laying down 1 1/4" tbg. RD Otis hydraulic snubbing unit and shut well in. oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Umon O~1 and Gas I~ ~on Western Region Umon Od Company of Cahforma P Q Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 union November 18, 1977 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE' TBS A-14L & A-27L MONOPOD PLATFORM Dear Mr. Gilbreth. Enclosed for your files is the subsequent Sundry Notice for the above captioned projects. CC' Marathon Oil Co. USGS Harry Lee Sincerely yours, J.i_.m_..R~) Ca 11 ender Dist. Drlg. Supt. I)n~on O~1 and Gas('-" ~on Western Region Uruon Od Company of California P O Box 6247, Anchorage, Alaska 99502 lelephone (907) 276-7600 November 18, 1977 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE' ~-S_~& A-27L ~PLATFORM Dear Mr. Gilbreth' Enclosed for your files is the subsequent Sundry Notice for the above captioned projects. [),','AFT qEC -- CC' Marathon Oil Co. USGS Harry Lee Sincerely yours, " ~-e n~dd Jim R~-Ca~l e'r Dist. Drlg. Supt. Form 10-4~3 REV. 1-10-73 Subml t "1 ntentlons" in Triplicate "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proDosals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL L...J OTHER 2. NAME OF OPERATOR Union Oil Co. of Ca]if. 3. ADDRESS OF OPERATOR P. O. Box 6247~ Anchoraqer Al( 99502 4. LOCATION OF WELL At surface Conductor #9, Monopod Platform, Cook Inlet 1601'N & 570'W from the SE corner of Section 4' T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) lOl'RT to MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO-' PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS TEST WATER SHUT-OFF L__..J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) 5. APl NUMERICAL CODE 50-133-20099 6. LEASE DESIGNATION ANO SERIAL NO. ADL 18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq Bay State 9. WELL NO. TBS A-14L 10. FIELD AND POOL, OR WILDCAT Tradinq Bay Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 4: TgN, R13W, S.M. 12. PERMIT NO, 68-27 =ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER lNG CASING SNOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTE~ Report results of multiple completion on Well ¢omDletlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent details, and give pertinent dates, including estimated date of starting any proposed work. Work commenced 10/28/77. Rigged up slickline unit and pulled ball valve from 2 7/8" tbg. Rigged up Otis hydraulic workover unit. Mixed 250 bbl workover fluid with 5% KC1 and 8#/bbl Dril-S in FIW. ' Ran 1.979" od muleshoe on 1 1/4" tbg. to bridge @6289'. Circ. hole w/ W.O. fluid. Could not work muleshoe below bridge. Pooh and ran 1 7/8" tapered mill on 1 1/4" tbg. and reamed out 2 7/8" tbg. Cleaned out sand in 9 5/8" csg. from 6538' to 7050'ETD. Circ. hole clean and checked for fill after two hours. Cleaned out 100' fill and repeated procedure two times until hole remained clean. Pooh and laid down 1 1/4" tbg. Rigged down Otis workover unit. Work completed 11/1/77. Treated "D" zone perfs 6460'-7020' with 1200 bbls of Corco polymer for sand and water control on 11/8/77. 16. I hereby ce~ that the fo.r~;ioi, j~s tru~ and correct Dist. Drlq. Supt. (This s~a('for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE , DATE- 11/17/77 DATE.., See Instructions On Reverse Side Un~on Od and Gas D~ws~on Western Region Umon O~1 Company',, Cahforma P O Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 union November 15, 1977 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE' TBS A-14L MONOPOD PLATFORM Dear Mr. Gilbreth' Enclosed for your information are two (2) copies of the Monthly Report for the above captioned project. cc' Marathon Oil Co. Si ncerely yours, ~. Cal 1 ender Dist. Drlg. Supt. USGS Harry Lee Form No. P-4 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Co. of Calif. 3. ADDRESS OF OPERATOR P. O. Box 6247, ^nchorage, ^K 99502 $. AP! NUMERICAL CODE 50-133-20099 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay State 9 WELL NO. TBS A-14L 4. LOCATION OF WELL Conductor #9, Monopod Platform, Cook I et! 1601'N & 570'W from the SE corner of Section 4: T9N, R13W, S.M. ~.~!'~,"! 10. FIELD AND POOL, OR WILDCAT Trading Bay Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 4' T9N, R13W, S.M. - t 2¥,!~ERMIT NO. ~68-27 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 1 10/28/77 8070'TD 7050 'ETD (cmt plug) 9 5/8" csg @7180' 7" 1 iner 08068' Offloaded Otis 4 1/6" hydraulic workover unit on Monopod. RU Meyers slickline unit on A-14L and pulled ball valve from 2 7/8" tbg. Moved rig over A-14L and rigged up Otis workover unit. 2 10/29/77 8070'TD 7050'ETD (cmt plug) 9 5/8" csg. @7180' 7" 1 iner 08068' Mixed 250 bbl workover fluid w/ 5% KCl and 8#/bbl Dril-S in filtered inlet water. Ran 1.979" od muleshoe on 1 1/4" (1.66" od) 3.2# N-80 CS hydril tbg. to bridge @6289'. 10/30/77 8070'TD 7050'ETD 9 5/8" csg. @7180' 7" 1 iner 08068' Circ. hole clean w/ W.O. fluid. Worked and rotated pipe for 2 hrs w/ no success. Pooh w/ 1 1/4" tbg. Ran 1 7/8" od x 1' long Tri State tapered mill on 1 1/4" tbg. incomplete. 10/31/77 8070'TD 7050'ETD (cmt plug) 9 5/8" csg @7180' 7" 1 iner @8068' Finished RIH w/ 1 7/8" tapered mill on 1 1/4" CS hydril tbg to bridge in 2 7/8" tbg @6289'. Reamed out scale bridge and reamed out 2 7/8" tbg. to muleshoe @6416' in 7 hrs. RIH to sand fill @6538' in 9 5/8" csg. Washed out sand fill from 6538' to 7050'ETD in 7 1/2 hrs. Circ. hole clean in 2 1/2 hrs. 14. ! hereby c~t,fg that fl}e fore~olng ~iArue a$nd corr/~t .. SIGNED ~~'. ~~~ TITLEDist.Orlg. Supt DATE 11/14/77 / ' ~,~._~,cuuF~ NOTE-Rapo~ on thia ~o~m ia requir~ ~or each calendar month, regardle~ o~ the ~atus o~ operatiom, and mu~ be filed in duplicate ~i~h the oil and gas conservation commi~t~ b~ the l~th o~ the sue~ding month,unl~ otherwise dir~t~. UrllOn Oil and Gash,vision Western Region ~mon Oil Company of California Box 6247 Anchorage, Alaska 9950: ,;lephone (907) 276-7600 union October 27, 1977 C, l'q,. Mr. O. K. Gilbreth Union Oil Co. of Calif. 3001 Porcupine Drive j Anchorage, AK 99502 RE: TBS A-27L - T~BS~A-14L MONOPOD PLATFORM -- Dear Mr. Gilbreth- Enclosed for your approval above captioned projects. sm Encl is a Sundry Notice for the Sincerely yours, E i 6'naer Dis~. Drlg. Supt. Form 10-403 Submit °'1 ntentions" In Triplicate REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposalS.) O,L i~1 GAS l--'1 WELLi-~I WELL OTHER 2. NAM,I~ DJ= OPERATOR union 0il Co. of Calif. ADDRESS OF OPERATOR P. O. [lox 6247, Anchorage, Al( 99502 4. LOCATION OF WELL Atsu.ace Conductor #9, Monopod Platform, Cook Inlet 1601'N & 570'W from the SE corner of Section 4' T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) IOI'RT to MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20099 6. LEASE DF--~IGNATION AND SERIAL NO. ADL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME !8. UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. TBS A-14L 10. FIELD AND POOL, OR WILDCAT Trading Bay Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 4- T9N, R13W, S.M. 12. PERMIT NO. 68-27 )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF i"---'I REPAI RING WELL FRACTURE TREATMENTU ALTERING CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletlon Report ancl Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent detail& and give pertinent dates, inclucling estimated date of starting any proposed work, 0il production from "D" zone perfs 6462'-7020' through the long string tubing has declined by ]000 BOPD with a proportionate increase in water production due to sand fill and a possible breakdown of earlier polymer treatments to curb water-sand production. It is planned to clean out sand fill from 6790'-7050'ETD with 1 1/4" tubing run inside the 3 1/2" production tubing using a hydraulic workover unit. The "D" zone perfs will be given a water-sand control polymer treatment before returning the well to production. PLAN -- 1. 2. 3. 4. 5. 6. 7. OF PROCEDURE Rig up wireline unit to long string. Pull Otis ball valve at 310'. Rig up Otis hydraulic workover unit to long string. Run 1 1/4" CS hydril tubing and clean out fill from 6790' to cmt. plug at 7050' Rig down workover unit. Rig up Halliburton and treat "D" zone perfs with polymer solution. Rig up wireline to long string. Run Otis ball valve. Return long string to production Attachment #1 is a schematic of present wellbore condition. 16. I hereby certify that the foregoing is true and correct S,GNED ~im ~_ C__a.! ! enter /~T~) (This space for State office use) CONDITIONS OF/"~'~-PdOVAL, iF ANY.' TITLE-- Dist. Drlg..q,,p~. DATE- 16)/27/77 See Instructions On Reverse Side Approved Copy , Returned . /_ .4~43 -- · __ Io"2(.-77 I I i I I I _ _ m mm I I I I i I I I I I I .i..i,,, i .iii I .ii, I I I -_ I I I I ---- . .... SS- 7 __ 5&- I .-- 6'7-2 ---- _ 75o~ - 7~ oo/qz' d~r ?4 u ~ ~7 ~x 76 &o - 7750/5'0' Union Oil and Gas t~ 'ision: Western Region Union Oil Company~o[ California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union May 21, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: '~-~ S A- 14 W.~) TBS A-27 WO TBS A-8 WO MONOPOD PLATFORM Dear Mr. Hamilton: Enclosed for your files are two (2) copies each of the Well Repair Records for the above captioned workovers. Very truly yours, . Callender District Drilling Supt. sk Enc. (8) cc: Marathon Oil Co. Rodney Smith-USGS ' LL7 1 5 i9Y6 union Union Oil and Gas I~' s~on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone-(907) 279-7681 January 15, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99502 RE: STATE REPORTS Dear Mr. Hamilton: Enclosed for your files and listed below are the Monthly and Completion reports for Union Operated projects for the month of December. TBS A-14 (WO) TBS A-8 (WO) TBS A-27 (WO) TBUS D-34A (Drlg.) Monthly Report (P-4!~-~.~ Sundry Notice (10-403)- ~b~r~/~ ,Monthly Report (P-4) ,~'~'~, ~'' Sundry Notice (10-403), Monthly Report (P-4) ,, ~ ... Sundry Notice (10-403) Monthly Report (P-4) Big River Unit #1 (Expl.) Monthly Report (P-4) Well Completion Report (P-7) sk Encl. (18) Very truly yours, Jim R Callender District Drlg. Supt. I ~.,~ .o .--4 STATE OF ALASKA t', AND G~ CONSERVATION ~,~EE MON~LY REPORT OF DRILLI~ AND WORKOVER OPER~~~ 2 ~ O~ OP~ ~ . 3 ~S O~ OP~ ~0~ ~est ~t~ ~e~ue, ~c~o~e. ~. ~501 4 ~&~O~ ~ ~ Co~ucto~ ~, ~0~'~ & 570'~ ~om t~e S~ co~e~. 5 AP! NIJ~ERXCAL CODE 50-133-20099 1 6 LEASE DESIGNATION A\-D SERIAL NO ADL-18731 IF INDIA~ ALOTiJ:n~ OR TRIBE NAME '8 L,~IT F.Z~l OR LEASE NAME Trading Bay State g WF~.~ NO A-14 (14-4) 10 :u~i_.r) A_ND POOL OR WILDCAT Tradinf! Bay Field-C-D Zone 1t SEC T -R M (BO~TOM HOI.~ OBOZCTZV~ Section 4: TgN, R13W, S. M. 12 PEP, MIT NO 68-27 13 REPORT TOTAL DEPTH AT END OF MONTH CHANGES IN HOLE SIZE CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN~ VOLU1WES USED PERFOHATIONS TESTS ~ ~UL~ FISHING JO~ J~K ~ HO~ AND SIDE-~CK~ HO~ ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIONS 12/1/75 8070'TD 7650'ETD Cmt. Ret. (Footage 0') Ran CBL-VDL-GR Log. Ran & set cmt. ret, @ 7130' to abandon Hemlock perfs, from 7436' to 7600'. Stabbed into ret. & broke dwn. perfs. @ 2000 psi @ 16 cfm. Mixed 87 sx. Class "G" cmt. w/ .75% D-31 to a ll8#/cu, ft. slurry w/ 50 cu. ft. wtr. ahead & 5 cu. ft. wtr, behind. Stabbed into ret, Pumped 57 cu. ft. cmt, below ret. Pulled out of ret. Equalized 42 cu. ft. above ret. Pulled out-pipe dry. Made up 9 5/8" Baker RBP & set @ 1385'. Removed BOPE to change tbg, spool. 12/2/75 8070'TD 7050'ETD Cmt. Ret. (Footage 0') Changed tbg. spool & installed BOPE. Retrieved Baker RBP @ 1385'. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to top of cmt. @ 6975'. Drilled cmt. to 7050'. Circ. & cond. mud. Pooh. RU Go-Int'l. & perf. the "D" Zone w/ 4" carrier gun w/ 4-1/2" hpf. SAND INTERVAL FEET 57'-'2 6896;' ' 7016' ~20' 56-1 6760' - 6860' 100' 55-7 6672'- 6732' 60 180' 12/3/75 8070'TD 7050'ETD Cmt. (Footage 0') Continued perf. w/ Go-Int'l. 4" carrier gun @ 4-1/2" SAND INTERVAL FEET 54-5 6554'-6562' 8' 53-8 6462'-6502' 40' 6510'-6525' 15' 47-5 5540'-5585' 45' sm~r= ~~ ~%,, ~.-G~I,..~, ~ ~_~ Dist. Drlg. Supt. ~*~ 1/15/76 // .lie H [~11~ N~--Report on ~is foe is required for eO~ calendar ~th% regardless of the status of operation, Grid must ~ filed In dupli~te with otl and Oas conservatbn commiflee bythe 15~ of the suec~dmg mn~. ~leM Otherwise d~rected. Approv~ ReSumed BS A-14 (WO) CtqTHLY REPORT 12/7/75 12/5/75 8070'TD 7050'ETD Cst. Ret. 8070'TD 7050'ETD Cst. 12/6/75 8070'TD 7050'ETD Cst. 12/7/75 8070'TD 7050'ETD Cst, ( -2- January 15, 1976 SAND INTERVAL FEET C-7 5230'-5415' 185 C-5 5000'-5030' 30 Made trip w/ 8 1/2" bit & 9 5/8" csg. scraper to 7050'. Circ, btms. up-Pooh. Ran Baker gauge ring w/ Go-Int'l. Set 9 5/8" Baker Model "D" production pkr. @ 6380'DIL. RU to run 3 1/2" X 3 1/2" dual tbg. strings. (Footage 0') Ran 3 1/2" X 3 1/2" dual tbg. string as prograrned. (See tbg. detail). (Footage 0') Completed running 3 1/2" dual tbg. strings as program- ed. Located on Baker Model "D" WL pkr. set @ 6380'DIL & attempted to space out tbg. Unable to slack off due to premature set of Otis triple hyd. pkr. Pooh w/ tbg. Changed out Otis triple hyd. pkr. (Footage 0') Reran 3 1/2" dual tbg. strings as programed. Located on Baker Model "D" pkr. @ 6380' & spaced out Otis triple hyd. pkr. @ 4884'. Set Otis pkr. off LS tbg. w/ 2500 psi-held press, ok. Attempted to test pkr. thru SS tbg. & circ. to surface. Set plug in SS tbg, & tested to 2500 psi-held ok, Pulled tbg. plug & pkr. failed to test. Attempted to repress. LS & circ. to SS tbg. Checked "XA" sleeve between pkrs. in closed position-ok. Unable to get test on pkr. Pooh w/ tbg. (Footage 0') RIH w/ seal assy. on 5"DP to test Baker Model "D" WL pkr. set @ 6380'DIL. Had trouble stabbing into perm. pkr. Pooh, Mule shoe damaged from junk on top of WL pkr. 12/8/75 12/9/75 8070'TD 7050'ETD Cmt.Ret. 8070'TD 7050'ETD Cmt. (Footage 0') TIH w/ BO shoe & pkr. picker. Milled over Baker Model "D" pkr, @ 6380' & ret. same, RU Schl. & ran gauge ring & junk basket to 6500'-ok. Ran Baker Model "D" WL pkr. & set @ 6370'DIL. RU & ran 2 7/8" tbg. LS w/ dip tube assy. Tested to 2500 psi-ok. (Footage 0') Completed running 2 7/8" LS w/ dip tube assy. Installed Otis 9 5/8" triple pkr. Ran 3 1/2" dual string on prod. tbg, Located on Baker Model "D" pkr. @ 6370'DIL (6385'tbg. seas.) Spaced out tbg. w/ Otis triple pkr. @ 4944'tbg. seas. & landed tbg. strings. Set plug in LS 3 1/2" "XA" nipple @ 5007'tbg. seas. & set Otis hyd. pkr. w/ 2600 psi on LS tbg. Ran WL tool. Unable to retrieve "X" plug @ 500?'. Bailed tbg. scale & debris. ~S A'- 14 (WO) IONTHLY REPORT -3- January 15, 1976 ,4 12/10/75 8070'TD 7050'ETD Cst. 5 12/21/75 8070'TD 7050'ETD (Footage 0') Retrieved "X" plug in LS @ 5007'. Tested hyd. pkr. @ 4944'tbg. seas. & perm. pkr. @ 6385'tbg. meas.-ok. Installed BPV's. Removed BOPE. Installed dual 3 1/2" x-mas tree & tested to 5000 psi-ok. Opened "XA" sleeves in LS @ 6375' & 5880'. Displ. WO fluid in LS, SS & annulus w/ filtered Inlet wtr. Closed "XA" sleeves in LS. Ran & set ball valves in LS & SS. Released rig from TBS A-14 to TBS A-8 @ 12:00 Midnite, 12/10/75. (Footage 0') Skidded rig from TBS A-8 to TBS A-14. RU Schl. on LS. RIH w/ full bore pkr. & hold meter. Ran production profile log over "D" Zone. Profile survey showed _+ 80% wtr. production from 54-9 Sd. perfs. (6600'-6640'). Form 10-403 REV. 1-10-73 STATE OF RVA,T," N COt~vlI~EE" OIL AND GAS CONSE SUNDRY NOTICES AND REPORTS'OI~W'E~.~ tOo not u~ tills form for proDosals to QrlII or to Use "APPLICATION FOR PERMIT-~"~ for such proposals.) GAS ~ WELL~ OTHER ' . .~ Submlt"lntent~ns" In 'I rlpllcate -& "SOt)toque'n[ ~ei~orts" In Duplicate 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIF. 3- ADDRESS OF OPERATOR P. O. Box 6247 Anchorage. Alaska 99502 -- 4. LOCATION OF WELL At surface Conductor #9: 1601'N & 570'W from the SE corner Section 4: T9N, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 10l' RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re aUMERICAL CODE 50-!33-20099 6. LEASE DESIGNATION AND SERIAL I~O. ADL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. A-] 4 (14-4) 10. FIELD A'ND POOL, OR WILDCAT Trading Bay llCIl & lID II 1]. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 4:T9N0 R13W, S. M. 12. PERMIT NO. 68-27 )or,, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* tOther) See below* (NOTE: Reoort results of multiple completion on Well Completion or Recomplet~on Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ail perhnent details, and g~ve pertinent dates, ~ncludlng est~matecl date of starting any proposed work. *To recomplete A-14 to a Dual "C"-"D" Zone oil producer. The well was producing from the "D" Zone w/ the Hemlock temporarily abandoned. PLAN OF PROCEDURE: 1. Killed well w/ Dril-S completion fluid & installed BPV, 2. Removed x-mas tree. Installed & tested BOPE. 3. Released 9 5/8" Baker Model "A-5" & 7" "S-H" Hydrostati~ pkrs. 4, Pulled & laid dwn. 2 7/8" dual tbg. string & accessories, 5. Ran in w/ 6" bit & CO to 7650'ETD. 6. Ran Gamma-Ray Log fran 7650'ETD to 4500'. 7. Abandoned Hemlock Zone by setting a 7" cmt, ret. @ 7130'. Sqz'd, 57 sx. of cmt. below ret, & laid 30 sx. of cmt. on top of ret. CO well 7050'ETD (cmt.plug), 8. Reperf. selected "D" Zone Sds. as follows: S_AND INTERVAL FOOTAGE 53-8 6462' - 6502' 40' 6510' - 6525' 15' 54-5 6554' - 6562' 8' hereby c,~"{Vy that the forego[lng Is true and correct //J' R. Calle~der ~-~ TITLE .... Dist. Drlg. Supt. DATE ]/]4/76 . . TITLE DATE See Instructions On Reverse Side ,.,pproved Copy' Returned TRADING BAY STATE A-14 (14-4) SUNDRY NOTICE -2- January 14, 1976 PLAN OF PROCEDURE: (cont...) 8. SAND INTERVAL 55-7 6672' - 6732' 56-1 6760' - 6860' 57-2 6896'- 7016' 9. Perf. "C" Zone Sds. as follows: SAND INTERVAL FOOTAGE 60' 100' 120' 343' FOOTAGE C-5 5000' - 5030' 30' C-7 5230' - 5415' 185' 47-5 5540'- 5585' 45' 10. Completed well as a Dual "C" TOTAL 603' - "D" oil producer w/ 3 1/2" tbg. & redesigned gas lift assy. Union Oil and Gas( ,is~on: Western Region Union O~1 Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union December 10, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99514 RE: TBS A-19 (43-5) ,,."' TBS A-14 (14-4~ TBrJS- D-34A (14-5) Dear Mr. Marshall: Enclosed for your files are two (2) copies each of the Monthly Reports of Drilling & Workover Operations (Form P-4) for each of the above captioned workovers. Also enclosed is the Sundry Notice & Reports on Wells (Form 10-403) for TBS A-19 workover. sk Encl. Very truly yours, . Callender District Drlg. Supt. CC: Marathon Ozl Co. Atlantic Richfield Co. Rodney Smith-USGS l~rm No l~ S- 1-70 ( STATE OF ALASKA SUBMIT IN DUPLICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF D AND WORKOVER OPERAI~_~C~ UNION OIL COMPANY QF CAL~ORNIA "' ~o~s o~ o~~ 909 West 9th Avenue, Anchorage, Alaska 9950] ~CA~ON ~ W~ Conductor ~9, 1601'N ~ 570'W froa the SE corne~. Hection 4: T9N, R13W, H. M. API NLrMERICAL CODE 50-133-20099 LEASE DESIGNATION AND SEiRIAL NO ADL-18731 IF INDIAN ALOTTEE OR TRIBE NAME L.~IT FA. riM OR LEASE NAMe. Tradi,,ng Bay State WELL NO A-14 (14-43 l0 FLEL~ A_ND I:~)OL- OR %VILDCAT . Tradin~ Bay Field-"C"-"D" Zone 1t S~..C T R-M (BOTTOM HOLE oa.mcTrv~ Section 4: T9N, R13W, S. M. 12 PERMIT N'O 68-27 13 REPORT TOTAL DEPTH AT END OF MONTH CHA.NGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED PERFORATIONS TESTS AND RESULTS FISHING JOBS JL~"NK IN HOLE AND SIDE-TRACKED HOLE A2qD A.NY OTI-IER SIGNIFICANT CHANGES IN HOLI~ CONDITIONS 11/26/75 8070'TD 7650'ETD Cmt. Ret. (Footage 0') Commenced rig move from TBS A-19 to TBS A-14 @ 12:01 am, 11/24/75. Completed skidding rig @ 12:00 Midnite, 11/26/75. 11/27/75 8070'TD 7650'ETD Cmt. Ret, (Footage 0') Commenced W@ operations @ 12:01 am, 11/27/75. Pulled bail valve & gas lift valves in LS. Displ. LS, SS & annulus w/ 65#/cu, ft. 5% Dril-S W@ fluid. 11/28/75 8070'TD 7650'ETD Cmt. Ret. (Footage 0') Installed BPV's. Removed x-mas tree, Installed & & tested BOPE to UOCO specs. PU on dual tbg. strings. Unable to release 9 5/8" dual pkr. @ 6398'. PU on SS & unlatched from dual pkr. @ 6398'. Pulled & laid dwn. SS. RU Go-Int'l. Ran free pt. & cut 2 7/8" LS below dual pkr. @ 7112'. 11/29/75 8070'TD 7650'ETD Cmt. Ret. (Footage 0') Pulled & laid dwn. LS. Left 327' of 2 7/8" tbg. & accessories in hole w/ 7" single hyd. pkr. @ 7366'. RIH w/ 5 3/4" OS. Latched onto tbg, fish @ 7112'. Worked & jarred on fish. Tbg. moved dwn. hole to 7120'. Unable to work fish free. Released OS. Pooh. RIH w/ 5 3/4" wash pipe. Washed over fish from 7120' to 7259'. 11/30/75 8070'TD (Footage 0') Washed over fish from 7259' to 7377' (top of pkr. 7650'ETD should have been @ 7374'). Top sub bumping up on top of fish @ Cmt. Ret. 7120'. Pooh w/ wash pipe. TIH w/ 5 3/4" OS & 2 7/8" grapple. Engaged top of tbg. fish @ 7120'. Jarred & worked fish to top of 7" liner @ 7071'. Pooh. Rec, total fish (327' of 2 7/8" tbg. & 7" sgl. hyd. pkr, less rubbers). TIH w/ 6" bit & 7" csg. scraper. CO 7" liner to 7230'. Circ. &cond, WO fluid. Pooh. RU Go-Int'l. 14 1 hereby ce m true ~ c, olTec~ sm~ _<zz~,,-,~/~-~4~-~ ~ Dq~*_ Drlu, Supt. -*~ 12/8/75 oil and gas conmervatbn commiflfl bythe 15~ of the suoc~difl9 mn~, ~le~ Otherwis~ ~r~cted. Form 1- 0-403 REV. ! 10-73 Sul3mlt *'Intentions'* In Triplicate "Subsequent Reports" In Duplicate STATE O( _ASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WEL'LS (Do not usi~ this form for proposals to drill or to deepen Use '°APPLICATION FOR PERMIT--" for such proposals.) WELL1 I OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIF. 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL Atsurface Conductor #9, 1601'N & 5701W from the SE corner. Section 4: T9N, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 101'RT above MSL. 14. Check Appropriate Box To Indicate Nature of Notice, Re NUMERICAL CODE 50-133-20099 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. A-14 (14-4) 1_0. FIELD AND POOL, OR WILDCAT Trading Bay-"C"-"D" Zone 1-1. SEC.,T., R.0 M.. (BOTTOM HOLE OBJECTIVE) Section 4: T9N, R13W, S.M. 12. PERMIT NO. 68 -27 )OFt, or Other Data NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) *See below SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recomplet~on Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, includmng estImated date of starting any proposed work. *'~o recomplete A-14 to a Dual "C"-"D" Zone oil producer. The well is currently producing from the "D" Zone w/ the Hemlock temporarily abandoned. PLAN OF PROCEDURE: 1. Kill well with Dril-S cc~mpletion fli~id & install BPV. 2. Remove x-mas tree. Install & test BOPE. 3. Release 9 5/8" Baker Model "A-5" & 7" "S-H" Hydrostatic Pkrs. 4. Pull & lay d~vn. 2 7/8" dual tbg. string and accessories. 5. Run in w/ 6" bit & CO to 7650'ETD. 6. Run Gamma-Ray Log from 7650'ETD to 4500'. 7. Abandon Hemlock Zone by setting a 7" perm. BP @ 7350'.' 8. Reperf. selected "D" Zone Sands as follows: SAND INTERVAL FOOTAGE 53-8 6462'-6502' 40' 6510'-6530' 20' 54-5 6554'-6562' 8' 54-9 6600'-6640' 40' 55-7 6672'-6732' 60' hereby certify that the foregoing is true and correct __ $1GNE Jim R. Ci4]]ender U z __TITLE ~St. Drlg. Supt. APPROVED BY ,/~ , TITLE- . . ~~ Af , CONDITIONS OF~PPROVAL. IF ~YY f DATE Q/1R/TG DATE See Instructions On Reverse Side Trading Bay State A-14 Sundry Notice -2- September 18, 1975 PLAN OF PROCEDURE: (cont...) 8. sAN~ INTERVAL FOOTAGE 56-1 6760'-6868' 108' 57-2 6896'-7016' 120' 396' 9. Perf. "C" Zone Sands as follows: SAND INTERVAL FOOTAGE C-2 4672'-4722' 50' C-3 4790'-4815' 25' C-5 5000'-5030' 30' C-7 5230'-5425' 195' 47-5 5540'-5590' 50' 350' TOTAL = 746' 10. Co~nplete well as a Dual "C"-"D" oil producer w/ 3 1/2" tbg. & redesigned gas lift assembly. ESTIMATED TIME OF OPERATION: Ten (10) Days_._ SE? 1 9 1975 TBS A- 14 September 17, 1975 PRESENT PRODUCTIVE INTERVALS Short String "D" Zone SAND INTERVAL FOOTAGE 53-8 6462'-6502' 53-8 6510'-6526' 54-5 6554'-6560' 54-9 6600'-6642' · 55-7 6672'-6732' 56-1 6760'~6768' 56-1 6774'-6866' 57-2 6896'-6958' 57-2 6970'-7020' Long String-Hemlock 7436'-7472' 7490'-7600' Short String "C" Zone 40' 16' 6 42 60 8 92 62 5O 376 36 110 146 SAND INTERVAL FOOTAGE C-2 4672'-4722' 50' C-3 4790'-4815' 25' C-5 5000'-5030' 30' C-7 5230'-5425' 195' 47-5, 5540'-5590' 50' 350' Long String "D" Zone To be selectively perforated pending Gamma-Ray Log analysis. SEP 1 9 1975 DIVISION n~: "' '~: ~.,L ANJ) (145 53-8 6462'-6502' 40' 54-5 6554'-6562' 8' 54-9 6600'-6640' 40' 55-7 6672'-6732' 60' 56-1 6760'-6868' 108' 57-2 6896'-7016' 120' Total "C" & "D" Zone Perfs. = 746' STATE Of: ALASKA Suhm/t "Int. ntions" in Tri~li~mU~ "Subsequent Reports" m Du~hcs~e OIL AND GAS CONSERVATION CONU~ITTEE SUNDRY NOTICES AND REPORTS ON WELLS (DO ~ot use thru form for proposals to drill or to deepen or plug back to a dt~flerent reservoir Use "APPMCATION FOR PERMIT--" for such proposals ) I OIL [] GAS [] WELL WELL OTH'ER NAME OF OPERATOR Union 0il Company of California ADIYRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4 LOCATION OF ~ At surface 1601' N and 570' W from TgN, R13W, SM. _SE corner Section 4, RE, E VED APR 13 _~L~.F. VATIONS (Show whether DF, RT, GR, etc RT to NLLW 112' DIVISION CF ~ ~~ia~ ~x To~~tum ~ ~tice, Re NOTICB OF INTI~NTION TO: OKG API I~CAL CODE KLV' 50-113-20099 HWK ~ T-~-&SE DI~IGNA~ION A-ND SEH/A~ ~...-~ ADL 18731 7. iF INDIA.H, AJ.J.~'l-r~:~: OR TH/BE ~E ~ . -- TF~T WATS BHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDONs CHANGE PLANS 8 UNIT, FA-P.M OR LEASE NAME , Trading Bay State 9. W~.L,L NO. A-14 (14-4) 10 F_~.r~ A/VD PCK)L, OR w1LDCAT Tradin$ Bay 11. SIDC , T , R , M , (BOTTOM HOLE OBJECTIVE) Sec. 4, TgN, R13W, ~. 12' PER/t~T NO 68-27 SUB~QUBNT REPOIIT OP: FRACTUR~ TH]ZATMENT ALTERING CASINO 8HOOTING ~R ACIDIZING ABANDONMENTS (Other) (NOTE: Report results of multiple completion on Well (Other) Completion or Reeompletion Report and Log form ) DESCRIBE PROPOSED OR COMPLETED oPERATIONS (CleaHy state all pertinent details, and give pertinent dates, lncludin~ estimated date of starting an~ proposed work, Trading Bay State A-14 was originally completed as dual Renal "D" Zone and Hemlock Zone Producer. It was proposed to reperforate and test Hemlock Zone,, and if tim test did not indicate commercial production, to abandon it, ami recomplete as a Middle Kenai "C" and "D" Zone producer. If the test was found to be adequately productive, it was proposed that the well would be returned to production as a dual _~m-_lock and "D" producer. PROCEDUKE: . 9. 10. 1. Moved rig over A-14 @ 12:01 pm 3/14/70 2. Killed well w/Invermul, removed xmas tree, instld & tstd BOP. 3. Pulled both strings of tbg & pkrs & CO to 7665'. 4. Perfd 4 hpf in Hemlock 7436-7472, 7490-7502, 7508-7548~ 7558-7600. 5. Ran DST on above intervals. Well stab @ 576 BOPD thru 1-1/2" bean raise~;trap press ts 120 psi thru 45/64 bean. Produced 330 BOPD 0.7 cut, 618 GOR. 6. Reperfd "D" Zone as follows: 6464-6502, 6510-6526, 6554-6560, 6602-6642, 6674-6730, 6760-6768, 6774-6808, 6814-6866, 6898-6958, 6974-69'90, 6996-7008, 7012-7016. 7. Ran 237 its 2-7/8" 6.4t sealock tbg to 7439 w/F1 pkr @ 7366 & dual pkr 8 6~0~. ~n 203 its 2-7/8" 6.4t N-80 ASL the in short string, stabbed into d~l pkr. ~d ~P. Instld ~s tree. Displaced Invemul w/diesel. Set & tstd Both pkrs. Released tie 8 6:00 ~ 3/20/70. Returned well to production w/lonE str~E producinE from H~lock Zone and short strint producinE fr~ Hiddle Kenai "D" Zone. SIGNED ' (This specs f0rVSt~te off'ce use)// TITLE Dist. DrlK. Supt. DATE 3/30/70 TITLE DATE ,~ppruved Copy Returned See Instructions On Reverse Side Form REV 9-30-6? Submit "Intentions" in Triplicate & "Subsequent Reports" m Duphcate STATE OF ALASKA OIL AND GAS CONSERVATION COMAAITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use th~s form for proposals to drill or to deepen or plug back to a dfffierent reservoir Use ' ~PPLIC~TION FOR PEi~MIT--" for such proposals ) OIL ~. GAS [] WELL WELL OTHER 2 NAME OF OPERATOR Union Oil Co. of California 3 ADDRESS OF OPERATOR 507 Northern Lights Blvd., Anchorage~ Alaska 4 LOCATION OF WELL At surface 1601 'N and 570' W. from SE Corner Section 4, T9N, R I3W SM. t HLB ~ Ti~ zL - API ~CAL CODE OKG ~ 50-I 13-20099 KW -~_ LEASE DESIGNATION AND S~O ~ ADh-18731 ~EL ~ ~ k IF ~I~. ~~ OR ~BE N~ FIE , -- 8 UNIT, FA_RA~ OR LEASE NA/~E Tradin9 Bay State 9 W~ELL NO A-14 (14-4) I0 FIELD A~rD i~OOL, OR WILDCAT Trading Bay-Middle Kenai-Hemlock 11 SEC , T , R , M , (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, RI3W, SM 13 ELEVATIONS (Show whether DF, RT, GR, ere 12 PERi~IT NO RT to MLLW 112' 68-27 Check Appropriate Box To Indicate N~ture af N~oti'¢e, I~e 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT I [ MULTIPLE COMPI ETE SHOOT OR ACIDIZE ~ ABANDONS REPAIR WELL CHANGE PLANS (Other) Recomp lotion ~UBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING ABANDONMENTS (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form ) 15 DESCRIBE PROPOSED OR COMPLETED 0PERATIO.%S (Clearly state all pertinent details, and give pertinent dates, including e~timated date of starting any proposed work. Trading Bay State A-14 is currently completed as a dual Middle Kenai "D" Zone & Hemlock Zone producer. The well produced 900 BOPD from the "D" interval & O BD fm HeEl. It is proposed to reperforate and test the Hemlock Zone for increased productivity. If the Hemlock Zone does not indicate commercial production the zone would be abandoned and the well recompleted as a dual Middle Kenai "C" and "D" Zone producer. If the Hemlock Zone is found to be adequately productive, the well would be returned to production as a dual Hemlock, "D" producer. Plan of Procedure I. Move rig to well A-14. 2. Remove xmas tree, instl and test BOP & kill well w/Invermul. 3. Pull tbg. 4. Reperforate Hemlock Zone. 5. Test Hemlock Zone. 6. Abandon Hemlock if indicated by test. 7. 8. 9. RECEIVED 27 If abandoned, block squeeze top of "C" and "O" Zone for segregation. Perforate "C" and "D" Zones and complete as a dual producer. If Hemlock is productive, perforate "D" Zone and return well to production as a dual Hemlock, "D" producer. Estimated Date to Start Work oR this Project: April I~ 1970. 16 I hereby eert~at/t~f,~eloln, Is true and correct SIGNED ~ __ __ __/3 H ; hll"'~ TITLE Dist. Ori I ling Supt. APPROVED('hi' 'Pace i~r ~tat' ~ee u~~ ;~~~I ~ ~~ ~ TLE ~ B~F , IF A CONDITIONS DATE 2-26-70 DATE See lnstrucfions On Reverse Side Returned U×iOX OIL CO. OF Tran3nit DATE' June 26 of California ate thc follo:~i~t?,' ;,;I'LL T_ra__d_i..n_g_~_ay State "A" #14 Trading Bay Unit D-4 (run #1) Trading Bay Unit K-5 (14-22) .un No. __L~_L_ Sepia Blue Scale Induction Electrical t.og Dual Induction Latero!og BtlC Sonic/Caliper l.og BtlC Sonic/Gw~:n-.~ Ray BHC Soni.~/ Caliper/Gnmma Ray Log Fornation Sonic Log (Fs) l)ensity-Gar,na Log [orn'~ation Density t, og (Fd) Neutron Log Formation Neulron CDSI or tligh Resolution Dipn~eter CD'.I Safety Print CDM or Printout CI;5I PolaF Plots Proximi ty..51icrolcg/Caliper I,og Gamma Ray Gan~sa Ray Collar Log Cement Bond Log M~d } og Core Descriptions, Cc, nventlonxl, No. Core DCscrlplior,5, Side<nil Core An'~lysis Core Chips Dri i ] 3tc:n Diruzt~onal Survey.: RE£EIV[D J U N 2 7 OIL AND OAS CONSERVA"ON WELL <OMPLETION OR RE<OMPLETION r' ,, ~,' 4,,- ~ ,,.g~ ~L-18731 , NEW ~ WORK DEEP- WgLL 9 ~L NO Union Oil Company of California , , ? · .... (1~ ~) ' 507 W. Northern Lights Blvd..~ ~chora~e, ~aska: -' . __ ~0. .. ~. ~CAX~OS O~ WALL (Repo~l Ioo~ttoa cleo~I~ ~ ia occordsaoe with ~ ~Zste r~=~r~g~},)* ,Trading ~ ~y ' 'Hemlock At,u~ace 1601'N and 570'W from SE corner,;Sec. ~. T9~ R13W, 11 ~,T,R',~.(~MHO~ ~_ ~ ~ O~~) . '~ ' SM - At top prom l.t..l re~rt~ below 1303' S & 3618'W o~ ~a!f i,,TgN~ R13W, SM At tota~ depm 1315'S and 4039'W of Surface~Lodat$en , Section ,,, 12 P~IT .... ~ ~' · ~'~68-~7 ........ {'i~ '~. 6-4-68 [ 5-13-68 [ 6-1-68 . '. 'r I ,RTl ~o~gcean Floor-174.. a,R~: to,,,USL - 101 / I ~OW ~Y* ',? q 1 t PROTARY TOOLS 0--8070 ~ C , CABLE TOOLS 80~0' - 6630' [ 7650, 6321 { : ~; 9,2 c;'" ~"{ ;' ii,'w~ P~ODUCINO ~V~(S), O~ ~S eo~O~--~,' ~O~, N~"(~ 7438--7584'~ (He~ock) (6164-6280'V9) ' ~ ' ' ~' '~ Yes :i ~ · ~, ' . ~,{ DIL, Sonic, C K,_HRD, BL ~rin~%er'm~ ;' w,~l{ ~ ', ",'~13-3/8'' 61' /J-55 ~! 1097 . : ~-5/8" { 60~,43.5 1J-55 I 7~80 . 1~-8o 1 26 LINER ~CO~ ' C]~K~'TIATG RECORD ~00 Class ~G sx ,~000 sx Class G { I l 27 TUBING RECORD [ 7071, [ [ 160 2-7/8" ' 7~35 :" ' 7" 8068 ..... C,, 7368 - , 28 PE~O~TIONS OP~ ~ PRODU~ON (Inte~al, szze and number) 23 ' kCID, S,tiOT, F~CTU~, C~ENT SQU~E, ~C 7438-7472 '; 7490-7508 '; 7516-7584 ' m~n~ ~v~ mm ] ~io~'r r~ xm~ O,F ~A~ u~ 7680--7730.[ 300 SX Class G - squeeze 1/2" - 4spf 7420 ] 50 sx Class G - squeeze ~ODU~ON D~TE FIRST P~ODUC~ON [ ~ODUC~ON ME'IIfO'D (Flowing, gas hit, pum9mE~mze and tyre of ~) [WELL ~TA~B (~oduc~ or ~ anut-m) 6-4-68 [ Gas Li~ ] Pzoducinz ~m o~ ~ms~. [~s T~ '[~oxE sm~ ~'~ ~o~ o~ ~c~ WA~~ [~As-om ~o i TEdT WITNES8~D Vented B.G, Spradlin t/~, /~]~ Dist. Dr}lling SuPerintendent SIGNED TITLE " DATE 6/10/68 *(See [.,t~c~io., ~.d $~ce, [o, Addifio.~[ D~ o. Reve,se Side) [ A.MOLrNT PULJ~ED ] r INSTRUCTIONS , General Th~s form ~s designed for submitting ~ complete and correct .well corrfplet~on report and log on -all types of lands and leases ~n A.laska - ,- Item: 16: Indicate which elevat~o.n ~s used as reference (where not otherwise s'hown) for depth measure- ments g~ven ~n ether spaces on this form and ~n any ettachments .Items 20, and 22:: If th~s well ~s-compteted for separate production from more than one ~nterval zone -(multipleZcomplehon), so state ~n ~tem 20, and ,n ~ter:n 22 show the prczluc~ng ~nt¢rval, or ~nterv.nls, top(s), bottom(s) and name (s) 0f any) for only-the ~nterv~'! reported ~n ~tem 30 Submd a separate report (page) on-th~s farm, adequately idenhfied, for each additional interval to be seperately produced, show- ~ng the a~d~honal data pertinent' to sdch ~nterval _ Item2&: "~acks Cement". Attached supplemental records for this well should show the details of any rnul- tiple stage cemenhng 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 ~tems 20 and 22 above) 34 SUMMARY Ol~ FO~.MATION ~-~TS rNCL~DINC, INTERVA'L +ESTED, PRESSURE DATA AND RECOVERIES OF -- ~s o~oLomc MA~r~S WATER AND MUD i i i i ii i i i i · NAMrr~ DST t/1: 7680-7730', PSA 7630', IF 15 m±n, IST 90 min, Flor 8 hr, FSI 8 hr. . HFTS, tee ~630' salt ~r (32,0_00 ppm), no shov, lltP 30341/, IFP '1663t~-2119#, ISIP 28021~, FFP 18911~-2802t/, FSIP: 2802/~, Flip 30341~. Hemlock 7128 615 DST {~2: 7884-7934', PSA 7831;. F~uid communicated w/sqzd perfs 7680-7730', P0~ DST I~3: 788&-7934'm PSA 7818; F'F 15 min, ISI 90 min, Flow 8 hr, FSI 8 hr. NFTS, tee 1529' muddy salt vtr (70,000 ppm C1), no oil; IHP 3057#, IFP 601- 653t/; ISIP 2848#; FFP 601#-2'61~/; FSIP 2632~/; FHP 38 CORE DATA, XTTACI[ 13RIE~' D~_~CRIPI~ONS OF IITIIOLOGY POROSITY FIiACTURE~ APP~A~NT DIPS , AND DEI'EL~'EI) SHOWS OF OIL, GAS OR WAT]~ m I ' ' · CORE t/,1: 7496-7514', cuC 18', recovered 14-1/2' - 4' congl, and ss, poor P&P, no sho~, 10-1/2' con~ and ss', fair P&P, oil stained. CORE t~2: 7514-7527', cut and recovered 13' _ 13' cong and ss, fair P & P, oil stained. ~. Form P--7 STATE OF ALASKA "R , , , , strtletlon~ on i OIL AND GAS CONSERVATION"COMMi,TT_EiE , ~' ,'.,.~l'~ ~0-~ ~200~ ....... WELL COMPLETION OR RECOMPLETION la. TYPE OF WELL. On, ~ ~As ~ D~g ~ ELL ~ WELL b. TYPE OF COMPL~ON WVELL O~ ER E~ BACK nEsvR Other ~. ~..~ or o~...~o~ ~ ~ , Trading .- Bay State Union 0il Company of Calffornfa ,, 3 .....~. o. o~..~. -.' ' A-14 (14-4) 507 W. Northe~ Lights Blvd., ~choraA~. ~l~ska ' 99~03 ' to F~D~~L. OHW~T ~. LOCATION OF WELL-(Repori location clear]~ and'in accordance wsth it.u~,~, 1601'~ ~ 579~ from SE corner Sdct~on ~ TgN,~13~,~ · t to~ 9rod l~t~rv~l reyorted below ~28~S & 2986 ~ At total dep~ Middle _,Kenai 1.3115'S & 4039'~ of Surface Loca{ion ' ~ ~., ';~ "'" / 68-27 ~a ~.~ ~D~ [14 D*~ · D ~C~ [tS D.~ CO~ S~S~ 4--4--68 [ 5--13--68 [ 6--1--68 -- [ ',RT 'tO ,0c~ad Floo~ - 174~ RT to ~SL - 101 18 T~ D~, ~ & TVD~9. PLUG, ~ MD & ~. ~ , , , , ~ow~ .... 8070 ~, 6630 TVD] 7650 ~, 6321TVDI ,. m. mmODO~ ~v~(s). o~ ~s co~o~. ~. Trading iBay - Middle Kenai 11. SEC. T. R, ~, (BOTTOM HOLE OBJECTIVe, 6462-7020 (Middle Kenai) (5390-5828'VD) , , ,, [ SURVF_,VbI2~DE -- " ' ~ Yes 24 TYPE ELECTRIC AND OTHEI{ LOGS RUN " ~-i ........ t ' DIL, Sonic, FDC-GR, CBL, HRD o - ' ~--, ' CASING / A3IOUNT PULL'm') 26 LIN'ER lq.EC(}P,~D SIZE TOP (MD) [ BOTTO~(~D) Is.ct~s C~T* 28 PE~O~TIONS OPEN ~ PRODU~OH (Inte~l, szze and number) 6462-6502 '; 6510-6526 '; 6600-6642 '; 667~-6728'; 6760-6768'; 6774-6866'; 6896-6950'; 697.0-7020'. 3/8" - 4 spf P~6DUC~ON ACID,'m!bT, F~CT~, C~ENT SQU~ZE, ~C 6898-6941 275 sx class G cmt - sqeeze i DATE FIRST PRODUCTION 6.1-68 BATm OF TEST. II-iOURS TESTED [C~OXE SIZE IPROD'N FOR ! I ITEST PE~,ZOD 6-1-68 , [ ,20 i 20 [ ~ FLOW, TUBING' ~SING PRESSUR~ [CALCULATED OIL--BBL ~m~ss I p~-~ou~ rc~ 42} / a4 ......! > , 606 31 DISPOSITION OF G*S (Sold, used for fuel, vented, ere ) ...... Ve~ted PRODUCTIO'N METtiO'D (Flowm.g, gas hf~, pumpmg~s~f.e and type o£ pump) Flowing ] V~ELL STATUS (Producm~ or ~'~") Producing ........ OI~BBL GA~CF WA~B~ I GAS-O~ ~O I I1.5 t 364 GA~ W~B~ ! OIL G~VITY-~ (C~) . I i I ~ [TE~T WITNESSED BY t B.G. Spradlin ~2. LIST OF ATTACHMENTS 33 I hereby certify tlr~/{he for,~o~t~ and attached information is complete and.,~orrect as determined from all-available records ~.///_ [~ ~rrLEDiSt' Drilling, Superintendent DA~m 6/10'88 SIGNED ~ s .,~,., ia~-ey *(~/e Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS ~C~eneral. Th,s form ,s des,cj.ned ~f~r subm,tt,r~cj a comp!.ete, and correct-well CO~l~iiet~;3~rel~ort an~l Io(:j.~on all types of lands and leases.~n Alaska'.' : Item:' 16: Indicate which elevahan ~s used as-reference (where not otherw~se"sh~bw'n) for depth measure- ments g~ven in athe~ spaces on thais form and ~n any attachments , -.Items~20,-and 22:: Cf thru well ~.f comp~leted for separato I~roduchon from moi'e. Jh~n one ~nterval zone (mul~tple complehc~n), so state ~n' ~ter~ 20, an~l ~n Item ~22 show the prcduchng interval, or ~ntervals, top(s), bottom(s) and name (s) 0f any) for only the ~nt-~rval reported in'~tem 30 Sub. m~t a separate report (page) on.th~s form, adequa, tely i~Jentrf~ed, for-each add, tional intel v~'[' to be sep'erately produced, show- ~ng the add~honal data perhnent to such interval Item26: "Sacks Ce~nent": Attached supplemer~tal records for this well should show the details of,~ny mul- tiple,stage cemenhng and the location of the cemenh,ng t6ol. 'Item ~8: Sul~r~t a .separate completion report on this form for each ~nterval to be separately produced. (See ~nstruction for~items 20 and 22 a'bove) · · . . 34 SUMMARY OF FORMATION TE~TS I'NCL~JDIN(] INTERVAL T~-~TED PH~-~SSURE DAq'A ~ ~OV~ OF OIL GAS - 35 G~IC MAR~ WA~ AND MUD ,, )ST I/4: 6898'-6941' PSA 6856'- IF 15 min, ISI 90 min, Flow 7-3/4 hr, FSI 7-3/4 hr Fluid Surfaced in one hr. ~-low~d 1400 B/D, cut fluctuating 20-60%, rate declinc to 580 B/D, cut increased '~o 90%. 'IHP 2714t~; IFP 1028t~-1598t~; ISIP 2511~; FFP ,. ' L630~-2266~1 FSIP 2495t~; ~P 2707t~, fluid co~unication w/line~ lap. ~ST t[5: 6898-6941' PSA 6856' IF 15 min, ISI 90 min, Flow 4 hr, FSI 4 hr. Middle Kenai 6462' 53~7' ?TS 15 min. Flowed 1500-B/D 32°. API, 0.2% cut, 500t/ TP, 26/64 ch, 400 GOR. '-, IHP 2747~, IFP 735~ to 1533~, ISIP 2485~, FFP 2083t~-2183~/, FSI~. ~482t~, FHP 2731~ )ST ~[6: 6818-6838' PSA 6761' BP ~ 6870' IF 15 min, ISI 90 min, Flow 8 hr,E~I ~ hr. NFTS. Rec. 2 B0 and 6 B~i water emulsion. IHP 27~t~;' IFP 535t~-635~; '~P 2482t~; FFP 635-142/~, FSIP 2482t~; FHP 2711t~. '" 38 CORE DATA, A~ACII BRIEP.,D~CRIPI~NS OM LITHOLO~Y, POROSITY, FRACWR~. ~APP~NT DIPS 'AND DETEr'El) SHOWS OF OIL, G~ OR WAM - No cores in Middle Kenai , ,\ API CODE 50-133-20099 Date .. _.7-1-?0 State of Alaska Depart~,ent of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch INDiVIDUAL~ELL RECORD Sec, 4 T. 9N S Meridian Permit No. 68-27 Issued 4-9-68 Operator Union Oil Co. of Calif. Location (Surface) 160!'FSL & 570'FEL, Sec. 4 Lease No.ApL t8731 or Owner T__r~_d_~iDg B~y__S.t_~e ..... Loc. (Bottom)_k21'_._F~_L ~_&__l_9~YD_'F%%.;_~_S_e~_._~ 4 Well No. A-14 (14-4) Area Spud Date 4-4o67 Drilling ceased S u sp ended Ab andoned ___-_ F 6-1-68 _IK) 606 Completed ~GL~)_f~ 220 20/64 .... 22 /64 G a s ~~. MC F/D, Be ~ ~ Casing: Size Elevation 31.0° B/D~ Grav__~API 34 425 Depth Sx Cat Perf: Ken,i= 6_~.2'__._=_._- Plugs: PBD 7650 Total Dapth8_~_ t01 RT 0.3% Cut psi 13 3/8" 1097' 9 5/8" - 40&43.5# 7180~ 7071'" 7~' liner 8068' 6502' ;6510~-26~; 6600~'42 6774~-6866 ~ ~ 6896' '6950 2000 69~0 ~-7020 ~. 160 Hemlock: 7438~-72 7508 ~ ~ 7516 ~ -84 ~. GEOLOGIC FORF~kT IONS Surf.i~ce Lowest Tested Hemlock Year Jan Feb Mar ~_~ PRODUCTIVE HORIZONS Nz~me Depth Contents Kenai 6462 ~ -7020 ~ WELL STATUS May june July Aug Sept Oct Nov Dec ~emarks: Contractor: Caldril Off course @ 4860. P.~_~_w/___cmt. & redri!!ed from 3217' UNIO OIL CO. OF CALIFO IIA DRILLING RECORD [~E TRADING BAY STATE V~ELL NO. A-14 i~iELD -Fading Bay If)CAnON Conductor /~9, 1601'N and 570'W of S E corner Section 4, T9N, R13W, SM Kenai Boro.ugh, Alaska SHEET PAGE NO. DEVIATION (B.H.L.) COMPANY ENGINEER. ELEVATIONS: WATER DEPTH 62 PEBRMIT NO. 68-27 SERIAL NC~.~DL-18731 1~ T. TO OCEAN FLOOR 174 R.T. TO MLLW 112 8070' T.V.D. 6630' P~T. TO DRILL DECK 22.07 R.T. TO APPROVED: 40.82 I '~ ~ /' ]V~U]:::~ V~..L. DEPTH & DI~-VIATION BIT R~--CORD BIT JET DEPTH / VERTICAL DATE DEPTH NO. SIZE MA~g TYPE SiZE OUT' FEET HOURS ANN. JET DIRECTIONAL ,,, ~/4/68 184 1 12-1/4 Reed ~T3A 3-3/4 585 401 6 92 350 5 585 2 ,, ,, ,, 3_14 1100 515 5 92 300 5 184 ~0 17-1/2 Smitil 6 Pt 1100 916 8-3/4 6 1100 2RR 12-1/4 Reed ST3A 3-14 2289, 1189 15 117 435 F3B2 7 2289 3 " " " " 3021 732 %5-1/2 115 4.20 [~B2 ,, 8 3021 4 '" " " " 3602 581 12-1/2100 372 r3R2 .... , 9 3602 5 " HTC X3A " 4057 455 11-1/2 100 372 F3B1 10 4057 6 " Reed ST3A " 4356 2.99 6-3/4 100 372 F2B]. 11 4356 7 " Reed " " 4746 390 9 %00 372 F3B2 1/4" OG 12 4746 8 " " STIAG 3-12 4860 114 3-%/2, %00 372 r2B1 13 3217 9 " " " 3-24 3349 ,132 13 100 372 4B2 ]./R" oG CDynadr~]l.; 14 3349 10 " Sec S3S 3-12 3485 136 3 100 372 rlnl . 15 3485 1l " HTC X1G " 3954 469 9.-1/2.100 372 ¥2B2 16 3954 .ORR " Sec S3S " 4273 319 8-1/2 100 372 r3B2, .. 17 4273 12 " Reed ;T3A " 4649 376 8-1/.2 100 372 73R1 18 4649 13 " HTC X1G " 4895 246 6-3/A 100 372 ?2B.~ P0H to c_b~ DA 18 4895 14 " Reed STIAG " 5104 209 10 98 480 ~B~ 19 5104 15 " }iTC XIG " 5500 396 11-3'/4 99 485 ?3R1 , 5500 16 " hTC X1G " 5740 240 1'0 99 485 20 574.0 17 " Reed ;TIAG " 6061 321 12-3/4 98 480 ?2B1. 21 6061 18 " Sec ;4TG " 6~00 2~9 11 98 480 22 Working on Rotary T~blLe 23 Working on Rotary TablLe - 24 6300 19 12-1/4 HTC X],G 3-12 6502 202 11-3/4 94 470 T3B? . 25 6502 20 " " ~CI(; " 6687 ]_85 6-1/21 94 470 T2B2 PO.q ~o ~BC ~A .. 26 6687 21 " Reed ;TIAG " 6850 163 8 94 470 T2+B2 ]./2" OC- _ 6850 22 " HTC XDG " 70~0 %80 9-1/2 94 470 t292._ I/~" DC, 27 7030 23 " " " " 7228 198 10-]/2 97 AR5 t4,P,] 1/&" DC - 28 7228 24 " " " " 7496. 268 8-3/4 97 4g. 5 TAP,] ] /&" 29 7496 Ci~i 7-~/$ Chris Dia. - 75]4 18 7-]/2 76 - Tn.~H~ g~-gP~ 7514 CH2 " " " - 7527 1~. ~-1/4 44 - Cood For RR - Cor~ 30 7527 25 12-1/4 HTC X55R }-12 7971 444 Z6-3/4 97 485 5/3/68 7971 26 " Sec S-4TG Open ..... C, le~n o,,r ~,~,ove 4 Fishin,l 5 Fishin~ and I 6 6120 J~.6RR 12-1/4 Sec S4TG Ooen ..... Dre~ o~f ~t 7 Runnin~ Casin: TM 8 27 8-1/2 HTC XIG O~en - ,_ ,- - - - Dr~. n:~.~ ~C 9 7280 27R1~ " " " Open 7~2~ 43 6-1./2 150 - [)ynmdr~ 1 ! TAB~ _ 10 7323 28 " Reed STIAG ~-9 7435 112 5 135 450 PO}{ tn c.b? DA tl~ _ 7435 29 " " " }-,1,0 750] 66 3 1.RE 5!0 TAR1 7501 30 " HTC ×DR " 7570 69 &-3/4 leg ~10 T~+ gl. 1,1 7570 ~l " " X55R " 801.5 A45 1 g.-I/A 1 gg ~!0 t2B~ 12 ~015 28R1 " " STTAG " 8070 55 1-'t/Z, 1RR 510 . -~ SPUD DATE 4/4/~8 COMP. DATE 6/1/68 CONTRACTOR. Caldrill Alaska Inc. RIG NO. ~ZPE UNIT 5" t{TC X-Hole Oilwell 860 DRILL PIPE DESCRIPTION .' 5" HTC X-Hole, LEASE TRADING BAY STATE TYPE Lignosulfonate UNIC, OIL CO. OF CALIFO IIA MUD RECORD FIELD Trading Bay SHEET B PAGE NO. ,, [DEPTH WEIGHTI VISC. W.~. P~ SALT OIL SAND SOLIDS REMARKS DAT~ ~1 575 75 ~5 8 q_~ 7500 4 Tr 12 Spud Mud 5 ..~100 74.5 39 10 8,0 9000 2 Tr 20 Surf Cs~ P~nt 6 Waiting on Cement 7 2183 76 43 10 9.0. 9000 4 3[4 16 .. 8 3023 79 40 4.6 9.5 7500 3 Tr 17 9 3720 78 46 4,4 9.5 9000 3 3/4 ].7 ._ 10 4353 79,~ 40 3.8 9.5 6500 5 Tr 15 .. 11 4829 80 45 ~.8 9.5 60~0 7 ~/a 15 13 3230 76 39 3.8 1A.O 50~ 7 Tr 12 Pml~h riFF pl,,C - Rmr~ p!~C 14 3485 77 40 3.5 11.0 6000 8 Tr 12 15 3960 78 43 4.4 11.0 6000 6 Tr 16 16 4500 79 45 4.8 9.0 6000 8 ,1/4 18 17 4898 78 45 4.0 9.0 7000 8 Tr 16 18 5314 79 45 4.8 9.0 6500 8 1/4 18 i.. 19 5730 78 45 4.0 9.0 7000 8 Tr 16 20 6135 77 41 4.8 9.5 7400 8 Tr 14 21 6310 78 44 5.0 9.0 7500 6 Tr 16 Repair Rotary Table .... 22 6425 78 45 5.0 9.5 7000 8 1/X 16 ii. 25 6730 78 45 4.4 10.0 7500 6 Tr 18 26 7000 77 40 4.8 9.5 7000 8 Tr 16 .. 27 7322 78 43 4.8 9.5 7000 9 Tr 17 28 7510 78 45 4.7 9.5 7000 8 Tr 17 _ 29 7575 77 45 4.5 9.5 7000 8 Tr 17 _ 30 7680 78 41 4.8 9.5 7000 8 Tr 18 5/1/68 7071 77.5 45 5.0 9.5 7000 6 1 16 T.D. Cond hole for logs .... 2 7971 77 59 4.4 9.0 7500 8 3/4 16 Raised Vis to work thru tight spol 3 7971 76 55 4.6 9.0 7500 10 1 20 Ream key seats above fish 4 7971 76 60 4.4 9.0 7800 14 3/4 16 Fishing 6 ,7 7180 76 47 8.0 12.5 8000 8 1 18 Ran and cmtd 9-5/8" cs~ 8 7180 75 40 7.5 12.5 8000 8 '1/2 16 Drld out DV & FS, .dressed off ~lu~ 9 7325 75 37 4.8 !12.0 8500 9 Tr 14 10 7540 76 38 4.5 11.0 9500 8 Tr 14 11 7984 75.5 39 4.6 10.0 9000 8 Tr 14 12 8070 75 43 4.8 10.0 9500 8 Tr 13 T,D, Pre~ to run liner 13 8070 75 43 4.8 10,0 9500 8 Tr 13 Ran and " ' __ __ __ _ __ -- __ __ ,.. _ _ _ __ _ _ _ _ , __ WELL NO. A-14 DISTRIBUTOR ' Baroid LEASE C'AADING BAY STATE UNION OIL CO. OF CALIFORNIA SHEET C ~,,, WELL RECORD ~ PAGE NO. WELL NO. A-!4 FIELD · Trading Bay - Monopod Conductor #9 CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS .3-3/8" 61# Seal Lock J-55 1097 Cmtd w/1200 sx G neat - last 2001 sx 2% CRC12 9-5/8" 40~43.5# Buttress J-55 & N-80 7180 Cmtd w/lO00 sx 1st stage, 1000 sx 2nd stage 2-7/8" 6.5# Seal Lock N-80 6327 Short string - prod. from Kenai Zone 2-7/8" 6.5# Seal Lock N-80 7344 Long string - prod. from Hemlock Zone PERFORATING R~CORD DATE 'IB¥~RVAL E.T.~.' REASON pRESENT CONDITION ~/16 7680-7730' 8020' DST #1 Sqdeezed W/2'00 Sx + 2% CRC12 ~/18 7884-7934' 8020' DST #2 Isolated w/BP @ 7650' ~/21 6898-6941' 7650' DST #s 3&4 Open for production 5/25 6818-6838 7650 DST #5 " " 5/28 7420 7650 WSO Squeezed with 50 sx 5/28 7190 7650 WSO Squeezed w/50 sx ... 5/28 . 6970-7020:6896 7650 Production Opep for production -6898';6941-6950' g~74-._6818r;6838- 6866'; 6760-676~' 6672_6728';6600 .... 6642';6510-6526' III 6462-6502' ~/31 7438-7472 7650 Production Open for production 7490-7508 75k6-7584 INITIAL PRODUCTION DATE ll~k;RVAL NET OIL CUT GRAV, C.P, T,P. CHOKE MCF GOR I REMARKS 6/1/68 6462-7020' 604' 0.3 31.( 34 425 '20/64 220 364 Short string pro- ducing from r~enai Zo Flowing. 6/4/68 7438-7584' 156 25.] 260 22/64 Long string proOucin'~ 6/6/68 7438-7584' 213 7.2 25. 470 50 90/64 96 450 ~y ~as 1££t ~rom _ Hemlock zone ,.. _ TYPE: CASING HEAD: CASING HANGER: Shaffer Model KD 12" Series 900 WP w LP screwed side outlets, btm to SOW 13-3/S" csg. Shaffer 12" Nominal 9-5/8" Model K.D.K.S. · Cameron Dual Model DCB, 12" series 900x 10" ser 900 w/21500# studded outlets CASING SPOOL: TUBING HEAD: TUBING HANGER: o ,,,~. TUBING HEAD TOP' Cameron S9%id Block w/ma.~t~r vnlvo, 2-9/16" Bore MASTER VALVES: UNION OIL GO. OF CALIFOrNIa DRILLING RECORD SHEEt d PAGE NO. LEAS~.~.\DING BAY STATE V~ELL NO. A-14 FIELD TRADING BAY DATE £. T. D. 4/4/68 8-11 12 13 14 15-20 21 22-24 471 1100 1100 22O4 484~ 3065 3258 6061' · 6319 6502 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Moved and rigged up over Conductor #9. SPUDDED 12-1/4" hole @ 3:00 PM. Drilled to 250', POH, picked up Dyna Drill, RIH, oriented and drilled and surveyed to 471' Dynadrilled and surveyed to 1100' POH RIH w/17-1/2" hole opener Opened hole to 11,00'. POH. Ran and cemented 13-3/8" casing, set @ 1097 w/1200 sc "G" cement , last 200 sx had 2% CaC12 A~ded. diP @ 12:15 PM 4/6/68. 13-3/8" CASING DETAIL Baker Flexiflow Shoe 13-3/8, 61#, J-55, Seal Lock Csg Baker Flexiflow Collar 13-3/8", 61#, J-55, Seal Lock Csg XO Buttress to Seal Lock Shaffer Fin Joint Landed below rotary table 1 Jt 26 Jts 27 Jts 2.09 1097.89-1095.80 39.52 1095.80-1056.28 1.94 1056.28-1054.34 1003.74 1054.34- 50.60 2.40 50.60- 48.20 9.20 48.20- 39.00 39.00 39.00- 00.00 1097.89 Nippled down mud riser and installed Shaffer "KD" head Tested KD head to 3000# for 15 mins - OK. Rigged up riser and BOPE. Tested blind rams to 1500# for 15 mins - OK. RIH and tested hydril to 1500# for 15 mins - OK. Drilled directional 12-1/4" hole to 2204' Drilled 12-1/4" directional hole to 4849'. Drilled and surveyed hole to 4860'. Ran Sperry Sun Multishot Survey from 4843' to 1100'. Found bottom of hole 200' south of earlier indi- cated bottom. RIH w/open ended drill pipe to 3450'. Mixed and pumped 200 sx regular class "G" cement using Inlet water, plus.3% CaC12, plus 45 sx dry sand. Preceeded cement w/50 cu ft water and followed with 10 cuft water. Displaced w/290 cuft mud. CIP @ 7:30 PM. PO w/DP and WOC. Tagged plug @ 3065' after 12 hrs WOC. Plug top soft. Picked up and WOC 4 hrs. Tagged plug and drilled 26' soft cement. WOC 4 hrs. Tagged plug and drilled firm to hard cement from 3091-3217'. POH, picked up Dyna Drill, ran in and oriented. Dynadrilled to 3349' turning hole to the right. RI w/DA and drilled~and surveyed 12-1/4" hole to 3485'. Drilled directional 12-1/4" hole tol606I[ Drilled to 6319'. At 10:00 PM 4/2~ transmission in rotary table drive tore up Sent for repair, waited on parts. Ran Sperry Sun Multishot Survey on sand line, unable to get below 4725' - surveyed from 4725 to 1200', @ 4700' indicated hole to be 25' left of single shot survey. Gear reducer arrived on platform 5:30 A3[ 4/24. Installed same and RIH, started drilling @ 9:15 AM. UNION OIL CO. OF CALIFORNIA DRILLING RECORD \ SHEET D PAGE NO., i 2 LEASE TRADING BAY STATE A-14 TRADING BAY V~ELL NO. . FIELD DATE 4/25/68 28 29 3O 511168 E. T. D. 7318 7514 7579 7946 7971 7971 7545 7545 DETAILS ~F OPERATIONS, DESCRIPTIONS & RESULTS Drilled directional 12-1/4" hole to 7318' Drilled to 7496' circulated up samples.land POH to pick up core barrel. Cored 7-5/8" hole from 7496-7514' Core barrel jammed @ 7514', laid down Core No.1. Cut 18' and recovered 14-1/2' (4' conglomerate and ss with no shows; 10-1/2' conglomerate and ss with show). Serviced core barrel and RIH with new core head. Cored 7-5/8" hole from 7514-7527' when barrel jammed. Laid down Core #2. Cut 13' and recovered 13' (comglomerate and ss with show). RIH w/12-1/4" bit and reamed 7-5/8" core hole to 7527' from 7496'. Drilled and sur- veyed 12-1/~" hole from 7527-7579'. Drilled and surveyed 12-1/4" hole to 7946' Drilled to 7971' TD. Circ. samples and conditioned hole for logs. PO to 6126 and pulled into tight spot. Could not get above 6126'. Put on Kelly and broke circulation w/3000 psi. Pressure dropped to normal 2500 psi while circulating. Attempted to drill and pull up through tight spot without success. Free movement downward. RIH to bottom and circ "bottoms up". POH but still could not pull through tight spot @ 6126'. Raised viscosity to 60 sec and continued to work pipe. Moved pipe up 5' with bit @ 6121' and top of tools @ 5680'. Continued to work pipe Could not pull bit above 6126', top stabilizer @ 5680'. Ran to bottom, backed off (Dia Log) leaving 1 joint flex with d.p., 12-1/4' stabilizer, 1 DC, sub, Monel DC, 12-1/4" stab, monel, 12-1/4" stab~ and bit in hole. Top of fish 7507'. Pulled out , ran in with 12-1/4" bit, 12-1/4" stab, 1-8" DC, 12-1/4" stab, 2-8" Dcs, 12-1/4" stab, XO, mechanical jars, 14 jts flex wt. DP. Cleaned out hole, reamed~@ 4390'; 4475-4598'; 4780, 6200'. Ran in to top of fish, conditioned mud, pulled out. RI w/1 jt flex wt d.p., BS, hyd. jars, 3-8" DCs, 12-1/4" stab, flex wt d.p. Screwed into fish, attempted to drill up - unsuccessful. Ran back~to bottom and Dia log backed off below B.S.. PO, RI w/bit, CO bridges 4474-4598'. CO to top of fish @ 7507', circ and conditioned hole. PO, RI and screwed into fish, jarred one hr, mixed and pumped 100 bbl Skot free w/diesel oil spotted around fish, moving oil 5 bbl/hr. Jarred on fish, hole in bad shape, could not load jars and no action on bumper sub, circ oil out of hole and cleaned up and restored jarring action, jarred for 4 hrs, no movement. Ran Dia Log, located free point @ 7545' - backed off and recovered XO sub and 12-1/4" stabilizer off top of fish. Circulated hole and conditioned mud, rigged up Schlumberger. Ran DIL, HRD, FDC-GR, SNP logs. Attempted to run sidewall sample gun - could not get below 3524' - shot 4 cores @ 3462',3455', 3330' and 3312'. RI w/open end drill pipe to 7540' and circulated one hour. Mixed and pumped 350 sx "G" cement with 45 sx sand and 2% CaC12 mixed w/Inlet wtr and preceeded by 100 cu ft caustic wtr. CIP 12 noon. Pulled up to 6882' and attempted to back scuttle. Pulled out of hole. UNION OIL CO. Of CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE VV-ELL NO. A-14 FIELD TRADING BAY DATE 5/7/68 10-12 13 14 E.T~ D. 7545 7180 7330' 8070'TD 8020' 8020 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RIH, found top hard cement @ 7089'. Drilled cement to 7220', circ and conditioned mud and prepared to run 9-5/8" casing. Ran 9-5/8" to 7180' w/Baker "G" shoe @ 7177' and ~aker G collar @ 7132, Howco DV collar @ 4350'. Circulated 1 hour, cemented through shoe w/lO00 sx CFR-2. CIP @ 10:30 PM 5/7/68. Dropped opening bomb and circulated thru DV collar @ 4350' for 3 hours. Cemented thru DV w/1000 sx CFR-2, no cement returns to surface on either job. CIP @ 2:50 AM 5/8/68 9-5/8" CASING DETAIL Jts Baker G Diff. Fill Up Shoe 9-5/8" N-80 43.5# Buttress, new Smls csg 1 Baker G Diff Fill UP Collar 9-5/8" N-80 43.5# Butt, ~ew Smls csg 1 9-5/8" N-80 40#, Butt, new Smls csg 37 9-5/8" J-55 40#, Butt, new Smls csg 31 Howco DV Collar 9-5/8" J-55 40# Butt New Smls csg 108 Below RT 2.60 7180.29-7177.69 43.57 7177.69-7134.12 2.00 7134.12-7132.12 42.90 7132.12-7089.22 1502.75 7089.22-5586.42 1235.70 5586/47-4350.77 2.15 4350.77-4348.62 4312.02 4348.62- 36.60 36.60 36.60- 00.00 Picked up BOP, set slips in Shaffer KD head, cut off 9-5/8" casing. Set Cameron 12' X 900# tubing head. Installed packing, tested same to 3000~~ for 15 min$ - OK. Nippled up BOP. Made up DA, WOC, tested blind rams to 1000 psi - OK. RIH and conditioned mud. Drilled out DV collar @ 4349', float collar @ 7132' and float shoe @ 7180'. . Polished off cement plug from 7180-7280'. POll and picked up DD. RIM and oriented to go around fish. Dynadrilled 8-1/2" hole from 7280-7323'. RI with standard DA an~ drilled directional hole to 7330'. Drilled and surveyed 8-1/2" hole to 8015'. Circulated samples for geologists. PO to run Schlumberger logs. Ran DIL, ttRD~ FDC-GR, SNP logs. Ran and shot 18 sidewall samples, recovered 16. RD Schlumberger and RI w/DA. Drilled 8-1/2" hole to 8070'. Circulated to condition hole for running 7" liner. Ran 23 joints 7", 29'~, N-80 Buttress casing with TIW liner hanger on 5" d.p. Set shoe @ 8068' with float collar @ 8021' and plug landing nipple @ 8020'. Top of liner @ 7071'. Mixed and pumped 160 sx (15% excess) CFR-2 blend cement using Inlet water. Preceeded cement with 100 cu ft wtr. Dropped plug and displaced cement with mud using rig pump No.2. After displacing full d.p. plus liner ivolume of mud (742 cuft) plug still ,h, ad not bumped. Pulled out of liner/and cont to circ until obtaining bottoms up . Some contaminated mud~returned, but no evidence of cement returns while circulating. CIP @ 12:115 PM. POll w/dp and liner setting tool. Found both swab cups and retaining collar missing from double inverted swab assembly. WOC. WOC to 12:15 PM, RIt[ w/8-1/2" bit to 7061' (10' above liner top) and tagged cement. Cleaned out soft cement from 7061-7068'. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO .... 'i ~ LEASE TRADING BAY STATE V~ELL NO. A-14 FIELD TRADING BAY DATE 5115168 16 17 18 E. T. D. 8O2O 8020 8020 8020 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7" LINER DETAIL Baker Model "G" Float Shoe 7" 29# N-80 Butt. Csg w/SPC 1 Jt Baker Model "G" Float Collar TIW Plug Landing Nipple 7" 29# N-80 Buttress Csg~ w/SPC 22 Jts Buttress Pin to 8rd Box X-over' TIW Liner Hanger Assembly 2.45 8067.59-8065.14 42.82 8065.14-8022.32 1.80 8022.32-8020.52 1.00 8020.52-8019.52 925.87 8019.52-7093.65 1.00 7093.65-7092.65 21.56 7092.65-7071.09 Cleaned out cement from 7068-7078 (7' inside liner). RIH, free for one stand the pipe took weight. R~tated w/Kelly for 6' then fell freely. RIH to bottom then circulated hole clean mixing salt to weight Inlet wtr to 68.5# per cu 'ft. POH w/6-1/8' bit. Ran Lane Wells Ga~.~.a Ray Cor- relation log and CBL. Spotty bonding behind 7" liner ra~ging from 40% to 15% of free pipe signal. No areas, however, show 100% free pipe sig- nal. Bonding does appear adequate. Perforated interval 7680-7730' w/4spf for DST #1. Made up HOWCO DST ~ools . Set packer @ 7630' w/bottom of stinger @ 7643'. Pressured up w/500 psi gas cushion and opened tool for 15 min. Tool opened @ 9:25 PM. Pressure increased 230 psi in 15 min. Closed tool for 90 min. Reopened tool for final flow and bled off gas cushion. Blow off bottom of bucket through bubble hose. Blow continued. Continued with final flow period for 8 hrs. NFTS. Closed tool @ 7:10 ~[ for final shut-in. Opened reversing ports but ports apparently were plugged and could not reverse while obtaining 8 hr final shut-in. Recovered 4630' (71 bbls) salt water (32,000 ppm el) no oil. IHP 3034#, IFP i663#, FFP 2119#, ICP 2802#, IFP (2) 1891#, FFP (2) 2802#, FCP (2) 2802#, FHP 3034#. Picked up RTTS and RI and set ~. 7585' · Pumped water @ 2600# @ 20 cu ft/min. Mixed and pumped 200 sx cement w/2% CaC12. Cement on formation @ 2200# increased to 3500#. Released press. Pressured up to 3500#, held OK, CIP @ 2:00 AM 5/17/68, back scuttled and PO~. Standing cemented 12 hrs. RIH w/bit found top of cement @ 7579'. Drilled cement to 7730', RI to 8020', circ hole clean. POti. RU Lane ~'~**,~ and perforated from 7884-7934'. RIH w/Howco test tools for DST #2. Set packer @ 7831' packer would not hol~ Pulled up to 7799' . , set packer - would not hol~. l~ade up another string of test tools and RiH w/packer set @ 7818'. Opened tool and fluid fell in annulus. Picked up to 7600', set packer, held OK. RIH to 7818' set packer. Opened tool and fluid fell in annulus - indication of communication between two sets of perforations. POH, RU Lane Wells and set Howco Eze Drill Bridge Plug @ 7780'. RD Lane Wells and RIH w/Howco RTTS set @ 7585' Pumped wtr in formation @ 4200# broke to 3600# @ 20 cu ft/min. Mixed and pumped 100 sx cement w/l% CaC12. Cement on formation @ 3600# increasing to 4800#, SD for 15 mins. P6mped 4 cuft pressure, inc. to 5600#. Bled off pressure, pressured up to 5600# - held OK. CIP @ 7:00 P:~ 5/18/68. Picked up to 7580 and back scuttled, recovered less than ! sack cement. POH. WOC. UNION OIL CO. OF CALiFORNiA DRILLING RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE ~ArELL NO. A-14 FIELD TRADING BAY DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5119/69 2O 21 22 23 24 8O2O 8020 765O 765O RIH w/6-1/8" bit, found top of cement 7582'. Drilled 5' soft cement WOC 6 hours. Cement still soft. WOC 2 hrs. Drilled fairly hard cement all the way to BP 6'7793'. Closed rams and pressure~ up to 2400# - held OK. Pushed plug to 8020'. POH. Picked up Howco test tools, RIH w/RTTS and set @ 7818', tail pipe @ 7831' - 500# gas cushion. IF 15 mins, ICIP 90 min, 8 hrs flow and 8 hrs CIP. Weak blow through test - no fluid to surface. Reversed out and recovered 1529' (14 bbls) muddy, salty water (70,000 ppm Cl) no oil. IHP 3067#, IFP (1) ~01#, FFP (1) 653#, CIP (1) 2843#, IFP (2) 601#, FFP (2) 261#, FCIP (2) 2632#, FHP 3067#. POH, RU Lane Wells and set HOWCO BP @ 7650' Perforated 4 hpf 6898-6941'. RI w/Howco test tools w/packer @ 6856'. tail pipe @ 6868' for DST #3. 15 min IF, 90 min CIP, 7-3/4 hr flow, 7-3/4 ht CIP - 500# gas cushion. Fluid to surface in one hour. Flowed 220 BF/7-3/4 hrs, 47-100% water - 24,000 ppm Cl. IHP 2714#, IFP 1028#, FFP i598#, ICP 2511#, IFP (2) 1630#, FFP (2) 2266/~, FCP(2) 2495#, YHP 2707#. Max temperature 135°F. POH. Laid down test tools. RI~ w/Howco RTTS set @ 6817'. Pumped water in formation @ 23 cu ft/min @ 3200#, broke to 3000#. Mixed and pumped 225 sx cement w/2% CaC12 and sea water. Cement on formation @ 2500~ inc. to 3200#. Shut down for 10 mins. Pumped 8 cu ft and press inc to 4500#. Bled off pressure. Pressured up to 4500#, bled off. Pressure held OK. CIP @ 4:30 AM. Picked up and back scuttled. POH. WOC 12 hours. RIH w/8-1/2" bit and casing scraper. Found top of cement @ 6810'. Drilled hard cement to 6960' (25' below bottom of perforations), still in hard cement', possibly squeezing liner ~ap. POH, picked up tlowco RTTS, RIH and set @ 6818'. Pumped water in formation @ 2 cu ft /min @ 4300#. Mixed and pumped 50 sx cement mxd w/Inlet water and 1% CaC12. Cement on formation @ 3800#, increased to 4300# @ 2 cu ft/min. Shut down for 10 mins. Pressured up to 4600#, bled off pressure. Pressured up to 5000#, bled off pressure - held OK. CIP 7:30 A~[ 5/23/68. Picked up and backscuttled. POH and WOC 12 hours. RIH, found top of cement @ 6825'.' Drilled soft cement to 6875', WOC 4-1/2 hrs. Drilled firm cement to 6925' . Pipe dropped to 6966' , stringers to 6440' . POH. Lane Wells perforated 6898-6941' w/4 spf. Picked up Howco test tools. RIH w/Howco tester, set @ 6856' loaded 500# gas cushion DST #4 (6898-6941): Opened tool for 15 min flow period, pressure inc- reased to 950 psi, closed tool for'90 min shut in. Opened to well clean tank for 1-1/2 hrs, switched into separator and flowed on 26/64" choke @ 1400-1500 BPD rate for 2 hrs 15 ~in. Cut 0.4% after cleaning up, tubing pressure 515 psi, GOR 400, ~2.3~ API Gravity. IHP 2747, IF 735, FF (1) 1533, ICIP 2485, IF (2) 208~, FF (2) 2183, FCIP 2482, FHP 2731. Tool open total of 4 hours, closed, tool for 4 hours, shut in, reversed out, pulled loose, ran in 100' and reversed out rat hole oil. POH. Lane Wells perforated 6818-6838' w/4JHPF. Picked up Howco tester and retrievable bridge plug, set BP @ 6870' With tester @ 6761' loaded 500 psi gas cushion. DST #5 (6818-6838') Opened tool for 15 min flow, noted !0 psi pressure increase. Closed tool for 90 min,shut in. Opened tool for second flow period. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAge NO .... 6 LEASE TRADING BAY STATE IYELL NO. A-14. FIELD TRADING BAY DATE 5/25/68 26 27 28 E.T.D. 7650 7650 7650 7650 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Bled' off gas cushion; good blow decreasing to light during 8 hour test, surface pressure 8 to 10 psi.. Closed tool for shut-in period, reversed out. Recovered: ~2Bbl, 24.1° AP1 oil w/8% water, 2.5% sd, 4.5% emulsion cut, 6 Bbl emuslified oil and completion fluid. All water was 68.5#- completion fluid. IH 2711, IF (1) 535, FF (1) 635, ICIP 2482, IF (2) 635, FF (2) 142, FCIP 2482, FH 2711. After 8 hr shut in pulled loose. Attempted to retrieve BP, backed off DP near surface while applying LoH. torque. Screwed in, POH, found perforated tail pipe below tester twisted off, left part of tail pipe, bottom recorder, retrieving tool on top of BP (engaged). RIH w/8-1/2" concave bottom mill. RIH w/mill. Milled 7" in 3 hours. PO, marks on mill indicated short run on 7" dia object, long run on 3" dia object at center. PU and Rill w/overshot. Engaged bottom recorder, released Howco retrievable tool, POH and RI w/retrieving tool on d.p. Picked up BP and pulled out RI w/8-1/2" bit, sub, csg scraper and started to drill out cmt @ 6966'. Cleaned out cement to 7065', no cement from 7065-1ap @ 7071'. RI w/HOWCO RTTS tool, set @ 6970' and pressured annulus to 975#. Tested liner lap to 4500 psi, decreased to 4100 psi in 10 min. Increased pressure to 4600 psi, decreased to 4200 psi in 10 min. Released pressure and rigged up Lane Wells. Ran tubing gun through d.p. but could not get below 7073'. Rigged down Lane Wells and POll w/DA. RI w/6" bit and found cement inside liner @ 7073'. Drilled from 7073-7084'. Circ. hole clean and PO. Lane Wells perforated 4-1/2" holes @ 7420 (above top of Hemlock for WSO. RIH w/pkr - Howco RTTS and set @ 7305'. Prep to cement squeeze. Pumped into formation @ 10 cu ft/min w/3700 psi. Mixed 50 sx neat cmt w/l% CaC12 using Inlet water and spotted @ pkr. Pumped 25 sx into formation @ 4 cu ft/min w/4300 psi, staged additional 15 sx w/max press 4700 psi. Pressure held OK for 10 mins. CIP @ 1:20 md. Released tool and reversed circulation with no cement returns. POH and rigged up Lane Wells. Perforated following intervals using 4" carrier guns w/Lane Wells NCF II charge: 6970-7020'; 6896-6898'; 6941-6950'; 6774- 6818'; 6838-6866'; 6760-6768'; 6672-6728'; 6600-6642'; 6510-6526'; 6462-6502'. Also shot 4 holes @ 7190' for WSO. Rigged down Lane Wells and RIH w/IiOWCO 9-5/8" RTTS tool. Set pkr @ 7056'. With annulus pressured to 800# pu~ped into formation Q 8 cu ft/min w/4000#. Bled pressure off and released pkr. Mixed and pumped 50 sx class G cmt using Inlet water. Spotted cement @ tool and re-set pkr. Pumped cmt to perforations w/4000#. Pumped 29 cuft cmt into formation w/pressure increase from 4000#-4500#. Shut down and pressure decreased to 2500# in 17 min. Repressured and staged additional 15 cuft @ 5 cuft per stage w/press decrease from 4500-3500# in 10 mins between stages. Pumped additional 10 cuft w/increase to 4500# (850~ on annulus). Shut down and pressure bled to 2000# in 35 min. Pumped additional 4 cuft w/ pressure increase to 4500:#. Pressure bled to 2500f~ in 25 mins. Released pressure and pulled tool loose w/40,000~ shear. Attempted to reverse, bu~ unable to pump. Attempted to pump do~m d.p. w/Halliburton but unable £o pump @ 4000#. POH and found 180' cmt in d.p. above tool. D.p. apparently leaked while displacing cmt after closing tool. Theoretical volumes of cmt as follows: 6.5 sx left in 3-1/2" d.~. and tools; 26 sx from tools to perfs; 17.5 sx pumped int6 form @ perfs. CIP 5:30.PM. WOC. UNION Oil GO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE TRADIN$ BAY STATE IVELL NO. A-14 FIELD .TP~JDING BAY DATE 5/2.9/68 3O E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7650 7650 While WOC, RIH w/8-1/2" bit, breaking each jr, in order to locate bad joint, k~ile Rill found partially washed out box w/cement in threads 42 stands above previous tool position. Tagged firm cement @ 7056' and drilled to 7069'. POH to pick up 6-1/8" bit to clean out liner. RIH and drilled cement from 7069-7195', no cement 7195-7273'. Drilled cement 7273 to 7380', no-cememt 7380-7648, Circulated 1-1/2 hrs. POH, laid down 3-1/2" d.p. and Rigged up to run tubing. Ran dual strings of 2-7/8" tubing with jewelry TUBING DETAIL Baker Trip Sub 2-7/8" N-80 Armco Seal Lock Tbg Otis X Landing Nipple 2-7/8" N-80 Armco Seal Lock Tbg Baker 7" Model F-1 Single Pkr 2-7/8" N-80 Armco Seal Lock Tbg Otis X-O sliding sleeve 2-7/8" N-80 Armco Seal Lock Tbg Baker A-S Dual Pkr 9-5/8" 2-7/8" N-80 Armco Seal Lock Tbg Otis CX Gas Lift Mandrel 2-7/8" N-80 Armco Seal Lock Tbg Otis CX 2-7/8" N-80 Armco Seal Lock Tbg Otis CX 2-7/8" N-80 Armco Seal Lock Tbg Otis CX 2-7/8" N-80 Armco Seal Lock Tbg Otis Ball Valve Mandrel Otis Flow Coupling X-O Seal Lock * 8rd EUE 2-7/8" N-80 Armco Seal Lock Tbg X-O Pup Joint Cameron Tubing Hanger' Landed below RT - Long String 1 Jt 1 Jt 1 Jt 30 J ts 1 Jt 34 Jts 46 Jts 56 Jts 58 Jts 9 Jts 237 Jts 1.87 7438.70-7436.83 30.55 7436.83-7406.28 1.00 7406.28-7405.28 29.78 7405.28-7375.50 7.20 7375.50-7368.30 30.22 7368.30-7338.08 3.00 7338.08-7335.08 921.21 7335.08-6413.87 12.75 6413.87-6401.12 31.26 6401.12-6369.86 5.50 6369.86-6364.36' 1048.85 6364.36-5315.51 5.50 5315.51-5310.01 1419.36 5310.01-3890.65 5.50 3890.65-.3885.15 1740.77 3885.15-2144.38 5.50 2144.38-2138.88 1811.83 2138.88- 327.05 2.20 327.05- 324.85 3.00 324.85-321.85 .80 321.85-321.05 280.05 321.05- 41.00 3.00 41.00- 38.00 1.00 38.00- 37.00 37.00 37.00- 00.00 7343.88 UNION Oil CO. OF CALIFORNIA DRILLING RECORD _- SHEET D PAGE NO. LEASE TRADING BAY STATE DATE E.T.D. llrELL NO.. A-14 FIELD TRADING BAY 5/31/68 - 6/;/68 DETAILS OF OPERATIONS, 'DESCRIP~:IONS & RESULTS TUBING DETAIL - Short StrinK Baker Trip Sub Otis "N" Landing Nipple Baker A-5 Packer Slack Off On Packer Baker Seal Assembly 2-7/8" N-80 Seal Lock Tbg Otis "CX" Mandrel 2-7/8" N-80 Seal Lock Tbg Otis "CX" 2-7/8" N-80 Seal Lock Tbg Otis "CX" 2-7/8" N=80 Seal Lock Tbg Otis "CX" 2-7/8" N-80 Seal Lock Tbg Otis Ball Valve :[andrel Otis Flow Coupling X-O Seal Lock x 8rd EUE 2-7/8" N-80 Seal Lock Tbg 2-7/8" Seal Lock Pup Jt 2-7/8" Seal Lock x 8rd EUE Cameron Itanger Landed below RT 1.30 1.10 10.35 3.22 8.98 2 Jts 63.07 5.50 34 Jts 1074.51 5.50 45 Jts 1410.43 5.50 56 Jts 1748.82 5.5O 58 Jts 1810.15 2.20 3.OO .80 7 Jts 220.52 3.10 2.30 1.00 37.00 202 Jts ~327.50 6417.41-6416.11 6416.1].-6415.01 6415.01-6404.66 6404.66-6407.88 6407.88-6398.90 6398.90-6335.83 6335.83-6330.33 6330.33-5255.82 5255.82-5250.32 5250.32-3839.89 3839.89-3834.39 3834.39-2085.57 2085.57-2080.07 2080.07- 269.92 269.92- 267.72 267.72- 264.72 264.72- 263.92 263.92- 43.40 43.40- 40.30 40.30- 38.00 38.00- 37.00 37.00- 00.00 Rigged down BOP, set Cameron dual tkee. Tested hanger to 3000# for 15 mins - OK. Displaced salt water w/diesel (447 Bbls). Dropped setting balls and set Baker packers Rigged up Lane ~ells and perforated Iiemlock Zone thru tubing 7438-72 (34'), 7490-7508 (18'), 7516-84 (68'). Flowed Kenai Zone 667 B/D on 20/64" choke, TP 430#, CP 0#, 32.2°API, 1.2% cut. Hemlock Zone would not flow. Opened sleeve @ 7338' to flow Kenai Zone th=ough long string. Flowed approximately 30 Bbl diesel and died. Opened short string and pressured' up on long string w/1500~ gas. · Attempted to flow long string, would not flow. Flowed Kenai through long string. Closed sleevc ~ 7338', long string would net flow. Opened sleeve @ 3885' and started unloading diesel-from annulus w/gas lift. RIG RELEASED @ 12:00 Midnight 6/1/6i. Moved rig to A-5. ~Form No F---4 REV 9-30-6'; IN DEPLICATE O~L AND GAS CONS[I~VATION COMMITT~%~ 1 Q ~%%% ~ONTrHLy REPORT OF DRILLING o~ ~g~'N~ AND WORKOVER OPERATI~°~ ~c~ APl N~ERICAL CODE 50-133-20099 6 LF~kSE DESIGNATION AND SERIAL NO ADL-18731 IF INDI AN, AL~D'I rE£ OR TRIBE NAME 0IL ~ 0aS ~ oTMz~ WELL ~ wELL 8 LrNIT,FAR-M OR LEASE NAAIE NA_ME OF OP~TOR Union 0il Company of California Trading Bay State ADDRESS OF OP~TOR 9 WELL NO 507 W. Northern Lights Blvd., ~chorage, Alaska 99503 A-14 (14-4) 10 FIEI,D iND P~L OR WILDCAT ~CA~ON OF W~ 1601'N & 570'W from SE corner Section 4, T9N, R13W, SM Tradin~ Bay-Middle Kenai-Hemlock i1 SEC , T , R, M (BOTTOM HOLE OBJF~3TIVE) Section 4, T9N, R13W, SM 12 PERMIT NO 68-27 13 R~ORT TOTAL D~TH AT END OF MONTH, CI{A. NG~ IN HOLE SIZE, CASING AND CEMEN~NG JOBS INCLUDING DEPTH SET ~ VOLUATES USED, pF~FORATIONS, T~.STS ;al%rD RESULTS, FIS~NG JOE, JU/~K ~ HOLE AND SIDE-~CKED HOLE AND A_NY O~d~R SIGNIFICANT CI-LANG~ ~ HOI.~ CON-DITIONS TRADING BAY STATE A-14 (14-4), MAY 1968 - CONTINUED Page 2 DST #3: Ran in w/HOWCO DST tools w/500# gas cushion to retest interval 7884-7934'. Set packer @ 7818', tail @ 7831'. Open for 15 min IF, 90 min ISI., 8 hr flow, 8 hr FSI. Recovered 1529' muddy salt water, 70,000 ppm C1 - no oil. IHP 3067', IF (1) 601, FF (1) 653, ISI 2848, IF (2) 601, FF (2) 261, FSI 2632, FH 3067. Set HOWCO permanent bridge plug @ 7650'. Perforated four 1/2" hpf 6898-6941' Kenai zone. DST #4: Ran in w/HOWCO DST tools w/500# gas cushion, set packer @ 6856' (perfs 6898- 6941). Open for 15 min IF, 90 min ISI, open for flow, fluid surfaced in one hour. Flowed 1400 B/D with cut fluctuating 20-60% water. Rate declined to 580 B/D - cut increased to 90%. SI for 7-3/4 hr. IHP 2714, IF (1) 1028, FF (1) 1598, ISI 2511, IF (2) 1630, FF (2) 2266, FSI 2495, FH 2707. Ran in w/RTTS tool, set packer @ 6817'. Squeezed perfs 6898-6941' w/225 sx neat cement. Found top of cement 6810' drilled to 6966', pressured perfs - broke down. Ran in w/RTTS, set packer @ 6818'. Resqueezed perfs 6898-6941' w/50 sx neat cement. Found top of cement 6825', drilled to 6966' Reperforated four 1/2" hpf 6898-6941'. RI w/HOWCO DST tools, set packer @ 6856' - ~00# gas cushion. Open 15 mins IF, 90 mins ISI. Open for flow period, fluid to surface in 15 mins. DST #5: Well flowed 1500 B/D rate, 32" gravity, 0.2% cut, 500# TP, 26/64 choke, 400 GOR. SI for 4 hr FSI. IH 2747, IF (1) 735, FF (1) 1533, ISI 2485, IF (2) 2183, FF (2) 2183, FSI 2482, FH 2731. Perforated four 1/2" hpf 6818-6838' Kenai zone. RI w/HOWCO DST tools on retrievable BP. Set BP @ 6870' and packer @ 6761' - 500# gas cushion. DST #6: Open 15 mins IF, 90 min SI, 8 hr flow, 8 hr FSI. Pulled out w/tools and ret. BP. Recovered 2 bbls oil and 6 bbl oil/water emulsion. IH 2711, IF (1) 535, FF (1) 635, ISI 2482, IF (2) 635, FF (2) 142, FSI 2482, FH 2711. Cleaned out cmt 6966-7071' (top liner). RI w/RTTS tool, set pkr @ 6870'. Pressure tested liner lap to 4500#, bled to 4200#. Cleaned out cement inside liner 7071-7084'. Circ clean @ BP 7650'. Perfd. four 1/2" holes @ 7420'. RI w/RTTS tool, set packer @ 7305'. Sqz for WSO above top of Hemlock w/50 sx cmt. POH. Cleaned out. Lane Wells perforated Kenai zone four 1/2" hpf: 6970-7020; 6896-6898; 6941-6950; 6774-6818; 6838-6866; 6760-6768; 6672- DRILLING R}ECORD ~ '.'r,:td.h.,S Eay SLato FIELD WELL !4'O."'-'14 W.0. LOCATION ]601'N & 570'W from SE corner Sec. 4, T9N, R13W, SM. PERMIT NO. 68-27 __SERIAL NO. ADL ]8731 T.D. 8068'__ T.V.D. 6630' DEVIATION (B.H.L.) 41°30' COMPANY ENGINEER Shell - Stinnett SPUD DATE CONTRACTOR_, WODEC0 TYPE UNIT 0__ilwell 860 DRILL PIPE DESCRIPTION COMP. DATE '20# 3/20/70 RIG NO._ 5% ELEVATIONS: WATER DEPTH 62 I~T. TO OCEAN FLOOR 174 R.T. TO MLL%V 112 IR. T. TO DRILL DECK 22.07 R.T. TO PRODUCTION- DEGK 4 0.8 2 APPROVED: /' ' : ,5 /~/, ', (B.E. Talley) ..... BIT RECORD ~' , MUD VEL. DEPTH & DEVIATION BiTI JET DEPTH ;' ' VI~RTICAL [] DATE DEPTH NO. SIZE , .MAK,..E TYPE ,,SIZE OUT FEET HouRs ANN. /JET DIRECTIONAL O 3/16/70 76~- 1 6" Smith K2 open 7650 Cleared out fill. ,,, , ,. ,. .... A~'q ?, J' ,, ~ ,. I ,. I ,,. , , _ , ., ., ., ,. . ,, . ,. ,J' I .... , . . ,. ,, .... , , , -- , ~ '" ,, -- ...... I .... ....... .... ,.. .............. ..... . ..... ----z ......... I ...... LEASE Trading Bay Unit State DATE 3/14/70 15 16 17 18 19 2O ETD 8068' 7650' UIqI:ON OIL CO. OF CALIFO' RNIA DRILLING G-14 ~.~0F-IELD ,, 3~ding Bay DETAILS OF OPERA%IONS, DESCRIPTIONS ~ RESULTS SHEET D 2 PAGE NO Raised mud wt to 71.5#. Instld N plugs. Rmvd xmas tree, instld BOP's. Tstd pipe rams w/1000 psi. Pulled short string, 202 jts of 2-7/8" 6.4# sealock tbg. Took hold of long string. Pulled hydraulic pkr @ 6401. Unable to pull Baker F-1 hyd pkr @ 7368'. Circ. RI Lane-Wells close @ 6364'° Circ thru sleeve @ 7335'. Cont RI Lane-Wells. Closed sleeve @ 7335'. Pulled 130,000#. Press up to 1000 psi underneath pkr. Pkr released. Circ. PO 237 jts 2-7/8" 6.4# sealock tbg. RI w/6" bit & 7" csg scrpr to top of fill @ 7498. CO to bridge plug @ 7665'. Circ clean. PO. Ran Lane-Wells 4" NCF II carrier gun. Perfd 4 hpf 7436-7472, 7490-7502, 7508-7548, 7558-7600. Made up DST tools. · For DST on perfs 7436-7600, Ran Howco RTTS tools on dry 3-1/2" & 5" dp. Instld 1500 psi gas cushion. Set pkr @ 7340'. Opened tool @ 6:15 for 15 min IF. No build up. Closed for 1 hr ISI. Opened tool @ 7:30 am for FF. Oil to surface in 20 min @ 200 psi . 8 am press 50 psi. Dead @ 9 am. Well started flowing @ 9:30 am. Well cleaned up. Press stab btwn 75 & 90 psi thru 1-1/2" bean, 576 BOPD, 0.7% cut, 562 GOR, 29.7° gravity. For 9 hr test, raised trap press to 120 psi thru 45/64 choke,well stab @ 9 pm to 330 BOPD, 0.7% cut, 618 BOR, 29o9° gravity. Tool open 13-1/2 hrs. Closed tool @ 9 pm for 8 hr final shut in. Back scuttled oil & gas total oil recovered 307 bbls. Circ. Pull pkr @ 5 am. RIH to 7430. Backscuttled out gas. PO DST tools. Charts as follows: Top Inside: IH 3114, IF 2399, FL 2446, ISIP 2422, FF 1108, FCIP 2208, FHP 3090 (48 hr clock). Top Inside: IHSMP 3136, IF 2634, FF2649, ICIP 2620, IF1027, FF 1070 (24 hr clock). Btm Outside: IHS 3134, IF 2682, FF 2682, ISIP 2668, FF 1063, 1106 (24 hr clock). Btm Outside: IHS 3123, IF 2638, FF 2687, ISIP 2663, FF 1083, 1107, FCIP 2201, FHP 3172 (48 hr clock). Ran 4" NCF II jet gun~ Perfd 4" hpf in "D" Zone: 6464-6502, 6510-6526, 6554-6560, 6602-6642, 6674-6730,6760-6768, 6774-~808, 6814-6866, 6898-6958, 6974-6990, 6996-7008, 7012-7016. Chngd to 2-7/8" pipe rams. Ran 237 its of 2-7/8" sealock t~g w/Baker F-1 pkr @ 7366. Dual hyd @ 6404' in long string. Ran 203 its 2-7/8" N-80 sealock tbg in short string, stabbed into dual pkr. Landed both strings w/B.P.V, instld. Laid down surplus tbg & 3-1/2" dp standing in derrick. Removed riser & BOE. Instld Cameron xmas tree. Removed B.P.V. RU Howco. Displaced Invermul w/diesel. (See Attached Tubing Detail). Completed displacing Invermul w/diesel & pumped Invermul aboard boat. Dropped balls both strings. Set single thru long string w/800 psi. Sheared out w/2500 psi. Tested to 2000 psi OK. Set dual pkr thru short string w/1500 psi. Sheared out w/2500 psi. Tstd to 800 psi OK. Turned to production. RIG RELEASED to move to A-il @ 6:00 am 3/20/70. Long String returped to producing from Hemlock Zone and Short String from Middle Ke:~ai "D~' Zone. Moved rig over TBS A-14 at 12:01 pm 3/14/70. Pumped invermul dowm tbg to kill well. P O [~o, ii("; U,,ll,~, Texas 75221 Prepared ['or MR. Looso Size Slzo CASING Size LINER TUBING SECOND STRING THIRD STRING PART NUt,~BER DESCRIPTION Size C,~ o[~ ?. ; '"1 L~~. 5 ~", ,?,, ~ Work over --, ,, Thread Depth Thread JThread JThread IT hre ad Depth Depth Depth D ep th 3o,6 ES]'i~ I, T ,_ TOTAL ESTIMATE CompIotmn Procedure Loo~o I~/I Nz¢?. IF,old ICe or Par,sh IStote I~,,*~ [ -I--:-- ' S Ze ~--t- ' J FIRST S,zo' ' IWe'ght ' ~ --~! i ' ~ " · ~ . ~., -~ ~ ....... S zo IWo,ght IGrode Zhread Dep h ~/ TUBING o~u,,u , . I I t '-'~-- STRING +F ,,. . 1___ J__ --5: .... :~'"~ '~L~-- PART NUM,3ER DESCRIPTION i FFTfh,A', ............................... , ,, _ _ J -~.. - ~ 0/6x~-' x Z '," ~-- .r-,~,:~/.. z, ~¢ .~ ~..~.~. -~ ~~ ~'7 ~ ':~ '-~." m : . : :: : l ~::" """:"":,. =. -. ,, ""' "'~'~'.-' ~ ,~x52 /¢/ '~' ~? -' ' , . ~ .', 5, /~> ~7' ' /"' : ~ "~ : _, .. ,.~ . , ~OTAL ESTIMATF Complot,on Procedure S~z~D CASING SI ze LINER FIRST STRING TUBING STRING P AR'i' NUMGER (~,;x',,-:,..-.,-.,-- ,'/../.':., .,L~.) -- ~/ .... w/: / L: .(_ ,".~./ ' - j Compony //, . ,<!,,/' ,., ~- - .~/_¥/...C.¥_2' ._. ~ · , ~.~_t, Well No. F,eld6, iCa or Par,sh [State / iWe i gh t IG rode j T hre od I SiTe S'zo jWetght IGrode JThread JWelght J Grade J Thread JWotght JGrade [ Thread Size IWel ght I Grade [ T hre ad ,' DESCRIPTION I L~-) /_z_Z.: ....... New Campier,o- Workover Depth Depth Depth Depth Depth dt /2 ,x .~. c/ ?'/_/?-.'" ' TOTAL ESTIMATE Completion Procedure / ~ ~'~ ' -'~ OP,- TOR _~ ~..~. ,,.,, .-.,%.: /*,.)' ),_') ,.,, ~ ~ ,. ~' STATE i, ~, ~%, , I f , I I , COMMENTS. Worksheet No. 523 \S~NG LINER AND SERVICES ! I / I/ II ' , '7:/:"" :"' ' .¢,,- --" "">?; TOTAL ESTIMATE ioFFicE IPHONE SAVE TIME AND MONEY W'ITH ESTIMAT£ o-:oo,-A UNION OIL CO. OF CALIFO IA SHEET A REPAIR RECORD PAGE NO. .EASE ,'IELD Trading Bay Field 3EGAN: 11124/7q COMPLETED 12/21/75 ELEVATIONS: 'ERMIT NO. 68-27~SERIAL NO. ADL-18731 ~OMPANY ENG[~EER t. ~ester/Watson ~E ~351033 kPPROVED ,~~ ~' .... ~m-~. C~ll~nder I ' I C ~ S ~ N G & TUBING sIZE I DEPTH 3 3/8" 1097' 9 5/8" 7180' 2 3/8' 32' 2 7/ 1111' 3 1/,2.] 5046' 2 "1 i 1/ 1 ,99' TRADING BAY STATE .... WELL NOA-14WO CONTRACTOR Parker Drilling Company TYPE UNIT__ Oilw~ll g~0 F,]ecfric WE:GHT___ 61# 40#, 43.5# 4.6# 9.4# 6.4# 9.4# DATE ~/16/70 5/18/70 %/21/70 ;/25/70 5/28/70 5/28/70 5/28/70 INTERYAL 7680'-773(~ 7884'-7943' 6893'-6941' 6818'-6838' 7420' 7190' 6970'-7020' 6896'-6898' ~/6941'-6950' 6774'-6818' 6838'-6866' 6760'-6768' GROUND CASING HEAD TUBING HEAD ROTARY DRIVE BUSHING GRADE J-55 [-55 ,N-80 N-80 N-80 N-80 N-80 , E.T.D. 8020' 8020' 7650' 7650' 7650' 7650' 7650' REMARKS Cm~'d w/1200 sx G neat-last 200 sx~2% CaC12. Cmt'd w/1000 sx 1st stage, 1000 sx 2nd stage. Short string-prod, from Kenai Zone. Short string-prod, from Kenai Zone. Long string-prod. Long string-prod. Dip Tube. ,,. PERFORATING RECORD REASON DST #1 DST #2 DST 3-4 DST #5 WSO WSO Production ]PRESENT CONDITION Sqz'd w/ 200 sx. + 2% CaCl2. Isolated w/ BP @ 7650'. Open for production. Open for production. Sqz'd. w/ 50 sx. Sqz'd. w/ 50 sx. Open for production. Il Il il 6672'-6728' SHORT 2/21/7, LONG S :Z/21/7 STRING: FRING: fl II ' II l! fl INrl 1123 0. ~- 324 84 6~ II II II II II II II II II II II II II II Il . 26.6 950 80 ,07 485 432 NA 950 115 07 416 1284 WE.r.r. HISTORY PRIOR TO REPAIR LAST COMPLETION NO. 2 COMPLETION DATE:_ 6/11/70 PRODUCING INTERVAL: 7438'-7584'. 6502'-6970' INITIAL PRODUCTION:- "C," Zone ] _].24/1 I'D" Zone 2022/324 B./D LAST REGULAR PROD. & DATE: 11/27/75 "D" Pool 619/470 B/D Hemlock SI CUMULATIVE PRODUCTION' "D" Pool-3,553,184 bbld, Hemlock-253,509 bbls. REASON FOR REPAIR: Abandon Hemlock Zone-recomplete well as a Dual "C"-"D" Zone Oil ~:orm D-1001-B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO. LEASE TRADING BAY STATE SOMPLETION DATE:L 12/21/75 ,~-~ ~'--~-).~T E J INTERVAL ETD 5/28/70 6600'-6642' 7650' 6510'-6526' " 6462'-6502' " 5/31/70 7438'-7472' " 7490'-7508' L2/2/75 6896'-7016' 7050' 6760'-6860' " 6672'-6732' " i2/3/75 6554'-6562' " 6462'-6502' " 6510'-6525' " 5540'-5585' " 5230'-5415' " 5000'-5030' " TYPE: .WELL No.A-14WO FIELD_Trading Bay Field APPROVED , Jim R. Callender DETAILS OF OPER.ATIONS, DESCRIPTIONS 8: RESULTS REASON Production Squeezed Production PERFORATING RECORD (cont. ,) PRESENT CONDITION Open for production I1 I1 II 11 II Sqz'd. w/ 87 sx. Class O cmt. w/.75% D-31 to a ll8#/cu, ft. slurry w/50 cu. ft. wtr. ahead & 5 cu. ft. behind. 57-2 Sd, - Open (4 hpf). 56-1 Sd. - Open (4 hpf), 55-7 Sd. - Open (4 hpf), 54-5 Sd, - Open (4 hpf), 53-8 Sd. - Open (4 hpf). 53-8 Sd. - Open (4 hpf). 47-5 Sd. - Open (4 hpf). C-7 Sd. -.Open (4 hpf). C-5 Sd. - Open (4 hpf). Cam eton / Shaffer -------- Shaffer Model KD 12" 900 series WP w/ 2-2" LP screwed slide outlets btm. to CASING HEAD: SOW 13 3/8" csg. 8" CASING HANGER: Shaffer 12" Nom. 9 5/ Model KD KS CASING SPOOL: TUBING HEAD: Cameron DCB 12" 3000~ WP X 10" 5000# WP ye~ 2-2" 5000~ UP studded outlets. DCB 10" Nora w/ 3 1/2" EUE top X 3 1/2" Nat. Butt. btm. TUBING HANGER: TUBING HEAD TOP: 10" 5000# WP. MASTER VALVES: 2 3 1/8" bore master & 2 ea. 3 1/8" boare swab valves w/3" 5000g studded outls 3 1/2" EUE FEM. CHRISTMAS TREE TOP CONN' S!ILLt LI PAGE UNI011 0IL CCICNY OF CALIFOR tIA i',?2LL t EC0,RD LEASE TRADING BAY STATE I'~ELL IIO, A-14 (wo) FIELD TRADING BAY FIELD DATE 4 11/24/7~ 11/25/7~ 11/26/7~ 11/27/7 11/28/7 11/29/75 11/3o/75 12/1/75 1212175 ElD 8070'TD 7650'ETD Cmt, Ret, 8070'TD 7650'ETD Cmt. Ret, 8070'TD 7650'ETD Cmt, Ret, 8070'TD 7650'ETD Cmt. Ret, 8070lTD 7650'ETD Cmt. Ret. 8070'TD 7650'ETD Cmt. Ret, 8070'TD 7050'ETD Cmt. Ret. DETAILS OF OPERATIONS, DESCRIPTIOI.IS & RESULTS (Footage Q') Commenced rig move from TBS A-19 to TBS A-14 @ 12:01 am, 11/24/75, Completed skidding rig @ 12:00 Midnite, 11/26/75. (Footage 0') Commenced W@ operations @ 12:01 am, 11/27/75. Pulled ball valve & gas lift valves in LS. Displ. LS, SS & annulus w/ 65#/cu. ft. 5% Dril-S W@ fluid. (Footage 0') Installed BPV's. Removed x-mas tree. Installed & & tested BOPE to UOCO specs. PU on dual tbg. strings. Unable to release 9 5/8" dual pkr. @ 6398'. PU on SS & unlatched from dual pkr. @ 6398'. Pulled & laid dwn. SS. RU Go-Int'l. Ran free pt. & cut 2 7/8" LS below dual pkr. @ 7112'. (Footage 0') Pulled & laid dwn, LS. Left 327' of 2 7/8" tbg. & accessories in hole w/ 7" single hyd. pkr. @ 7366'. RIH w/ 5 3/4" OS. Latched onto tbg, fish @ 7112'. Worked & jarred on fish. Tbg. moved dwn. hole to 7120'. Unable to work fish free. Released OS. Pooh, RIH w/ 5 3/4" wash pipe. Washed over fish from 7120' to 7259'. (Footage 0') Washed over fish from 7259' to 7377' (top of pkr. should have been @ 7374'). Top sub bumping up on top of fish @ 7120'. Pooh w/ wash pipe. TIH w/ 5 3/4" OS & 2 7/8" grapple. Engaged top of tbg. fish @ 7120'. Jarred & worked fish to top of 7" liner @ 7071'. Pooh. Rec. total fish (327' of 2 7/8" tbg. & 7" sgl. hyd. pkr, less rubbers). TIH w/ 6" bit & 7" csg. scraper. CO 7" liner to 7230', Circ. & cond. W@ fluid. Pooh. RU Go-Int'l. (Footage 0'.) Ran CBL-VDL-GR Log. Ran & set cmt. ret. @ 7130' to abandon Hemlock perfs, from 7436' to 7600'. Stabbed into ret. & broke dwn. perfs. @ 2000 psi @ 16 cfm. Mixed 87 sx. Class "G" cmt. w/ .75% D-31 to a ll8#/cu, ft. slurry w/ 50 cu. ft. wtr. ahead & 5 cu. ft. wtr. behind. Stabbed into ret. Pumped 57 cu. ft. cmt. below ret. Pulled out of ret. Equalized 42 cu. ft. above ret. Pulled out-pipe dry. Made up 9 5/8" Baker RBP& set @ 1385'. Removed BOPE to change tbg. spool. (Footage 0') Changed tbg. spool & installed BOPE. Retrieved Baker RBP@ 1385', RIH ~v/ 8 1/2" bit & 9 5/8" csg, scraper to top of cmt. @ 6975', Drilled cmt. to 7050'. Circ. & cond. mud. Pooh. RU Go-Int'l. & perf. the "D" Zone w/ 4" carrier gun w/ 4-1/2" hpf. SAND INTERVAL FEET 57-2 6896' - 7016' 120' 56-1 6760' - 6860' 100' 55-7 6672' - 6732' 60 180' PA6 -lb, UNION OIL CCFtPAYff OF CALIFOP NIA CLL RECO LEASE TRADING BAY STATE I'fLL II0, A-14 (wo) FIELD TRADING BAY FIELD ~TE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7 12/3/75 12/7/75 1215/75 12/6/75 12/7/75 12/8/75 12/9/75 8070'TD 7050'ETD Cmt, 8070'TD 7050'ETD Cmt. Ret. 8070'TD 7050'ETD Cmt. 8070'TD 7050'ETD Cmt. 8070'TD 7050'ETD Cmt, 8070'TD 7050'ETD Cmt, Ret, 8070'TD 7050'ETD Cmt, (Footage 0') Continued perf, w/ Go-Int't, 4" carrier gun @ 4-1/2" SAND INTERVAL FEET 54-5 6554'-6562' 8' 53-8 6462'-6502' 40' 6510'-6525' 15' 47-5 5540'-5585' 45' C-7 5230'-5415' 185' C-5 5000'-5030' 30' Made trip w/ 8 1/2" bit & 9 5/8" csg. scraper to 7050', Circ, btms. up-Pooh. Ran Baker gauge ring w/Go-Int'l. Set 9 5/8" Baker Model "D" production pkr. @ 6380'DIL. RU to run 3 1/2" X 3 1/2" dual tbg. strings. (Footage 0') Ran 3 1/2" X 3 1/2" dual tbg. string as programed. (See tbg. detail). (Footage 0') Completed running 3 1/2" dual tbg, strings as program- ed. Located on Baker Model "D" WL pkr. set @ 6380'DIL & attempted to space out tbg. Unable to slack off due to premature set of Otis triple hyd. pkr. Pooh w/ tbg. Changed out Otis triple hyd. pkr. (Footage 0') Reran 3 1/2" dual tbg. strings as programed. Located on Baker Model "D" pkr, @ 6380' & spaced out Otis triple hyd. pkr. @ 4884'. Set Otis pkr. offLS tbg, w/ 2500 psi-held press, ok, Attempted to test pkr, thru SS tbg. & circ. to surface. Set plug in SS tbg, & tested to 2500 psi-held ok. Pulled tbg. plug & pkr, failed to test, Attempted to repress. LS & circ. to SS tbg, Checked "XA" sleeve between pkrs. in closed position-ok, Unable to get test on pkr, Pooh w/ tbg, (Footage 0') RIH w/ seal assy, on 5"DP to test Baker Model "D" WL pkr. set @ 6380'DIL, Had trouble stabbing into perm. pkr. Pooh. Mule shoe damaged from junk on top of WL pkr. (Footage 0') TIH w/ BO shoe & pkr. picker. Milled over Baker Model "D" pkr. @ 6380' & ret. same. RU Schl. & ran gauge ring & junk basket to 6500'-ok. Ran Baker Model "D" WL pkr, & set @ 6370'DIL. RU & ran 2 7/8" tbg. LS w/ dip tube assy. Tested to 2500 psi-ok, (Footage 0') Completed running 2 7/8" LS ~v/ dip tube assy. Installed Otis 9 5/8" triple pkr. Ran 3 1/2" dual string on prod. tbg. Located on Baker Model "D" pkr. @ 6370'DIL (6385'tbg. meas.) Spaced out tbg. w/ Otis triple pkr. @ 4944'tbg. meas. & landed tbg, strings. Set plug in LS 3 1/2" "XA" nipple @ 5007'tbg. meas. & set Otis hyd. pkr. w/ 2600 psi on LS tbg. Ran WL tool, Unable to retrieve "X" plug @ 5007~. Bailed tbg. scale & debris, OFi[-L ! L/ UNION OIL CCF£AI',,IY OF CALIFORNIA WELL t ECORD "J_AgE TRADING BAY STATE I'E~- l'10, A- 14 WO FIELD TRADING BAY FIELD 14 12/10/75 15 12/21/75 ETD 8070'TD 7050'ETD Cmt, 8070'TD 7050'ETD DETAILS OF OPERATIONS, DESCRIPTIOHS & RESULTS (Footage 0') Retrieved "X" plug in LS @ 5007'. Tested hyd, pkr. @ 4944'tbg. meas. & perm. pkr. @ 6385'tbg. meas.-ok. Installed BPV's. Removed BOPE. Installed dual 3 1/2" x-mas tree & tested to 5000 psi-ok. Opened "XA" sleeves in LS @ 6375' & 5880'. Displ. WO fluid in LS, SS & annulus w/ filtered Inlet wtr, Closed "XA" sleeves in LS. Ran & set ball valves in LS & SS, Released rig from TBS A-14 to TBS A-8 @ 12:00 Midnite, 12/10/75. (Footage 0') Skidded rig from TBS A-8 to TBS A-14. RU Schl. on LS. RIH w/ full bore pkr. & hold meter. Ran production profile over "D" Zone. Profile survey showed +_ 80% wtr. production from 54 Sd. perfs. (6600'-6640'). UHIO OIL CCFPANY OF CALIFOPC IIA WLLL IICORD PAGE LEASE TRADING BAY STATE WELL II0, A- 14 WO FIELD Tradin~ Bay F~eld ~_ATE ETD JTS. ,, _ 23 27 4O 34 24 163 1 DETAILS OF OPERATIONS, DESCRIPTIOrlS g, RESULTS TUBING DETAIL SHORT STRING D ES CRIPTI ON LE N____G T___H 2 3/8" Otis "N" nipple 1.975"OD, 2.710"ID 2 3/8" 8rd Pup Jts. Otis Tripple 9 5/8" X 3 1/2" X 2 7/8" X 2 3/8" Btm. to Top 2 3/8" dble, pin X-over 2 3/8"-10 rd, X 2 3/8"-8 rd. 2 3/8" 8rd tbg, collar 2 5/8" OD 2 3/8" 4.6# N-80 Butt. Tbg, 2 3/8" Butt. X 2 3/8" 8rd. X-over 2 5/8" OD 2 3/8" 8rd. tbg. collar 2 5/8"OD 2 3/8" Otis XA sleeve 3.125"OD, 1.875" ID 2 3/8" 8rd tbg. collar 2 5/8"OD 2 3/8" X 3 1/2" Butt, X-over 3 1/2" 9.4# Butt. Tbg. 3 1/2" Camco KBUG #4 3 1/2" 9.4# Butt. Tbg. N-80 3 1/2" Camco KBUG #3 3 1/2" 9.4# Butt. Tbg. 3 1/2" Camco KBUG #2 3 1/2" 9.4# Butt. Tbg. N-80 3 1/2" Camco KBUG #1 3 1/2" 9.4# Butt. Tbg. N-80 3 1/2" 9.4# Butt Pup Jt. N-80 3 1/2" 9.4# Butt. Tbg. N-80 3 1/2" 9,4# Butt. Pup Jr. N-80 3 1/2" 9,4# Butt. Tbg. N-80 3 1/2" Otis Ball Valve 3 1/2" 9,4# Butt. Tbg. N-80 Cameron Hgr. 3 1/2" Butt. btm. X 3 1/2" 8rd. Top. Elevation .8O 8.20 5.31 3.90 .5O .71 31.29 .55 .41 2.48 ,41 1,00 28.43 6,6O 646.85 6.6O 792.67 6.60 1175.90 6,60 1007,90 5.32 722.99 6,06 215.59 4.40 235.25 1,00 37.40 Total jts. of 3 1/2" N-80 Buttress Tbg, (9.4#) Total its. of 2 3/8" N-80 Buttress Tbg, (4.6#) BOTTOM 4961.72 4960.92 4952.72 4947.41 4943.51 4943.01 4942,30 4911.01 4910.46 4910.05 4907.57 4907.16 4806.16 4877.73 4871.13 4224.28 4217.68 3425.01 3418.41 2242.51 2235.91 1228.01 1222.69 499.70 493.64 278,05 273.65 38,40 37.40 TOP 4960.92 4952.72 4947.41 4943.51 4943,01 4942,30 491t,01 4910,46 4910.05 4907.57 4907,16 4906,16 4877,73 4871.13 4224.28 4217.68 3425,01 3418.41 2242,51 2235,91 1228.01 1222.69 499.70 493,64 278.05 273.65 38,40 37.40 --0-- LEASE TRADING BAY STATE UIiIOIl OIL CCFPA h' OF CALIFORHIA ',SLL I(ECORD l'~LL II0, A-14 WO FIELD Trading B.,ay ,Field ~ATE ETD JTS. i6 DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS TUBING DETAIL LONG STRING DESCRIPTION LENGTH Mule Shoe 2 9/16"ID X 3 3/16"OD 1.20 2 7/8" 8rd pin X 2 7/8" Butt. box X-over 3 7/32" X 2 7/16" .49 3 7/8" Otis N nipple 3 7/32"OD X 2.205"ID .65 2 7/8" Butt. collar 3 7/32"OD .71 2 7/8" 6.4# N-80 Butt. Pup Jr. 10,15 2 7/8" Baker btm. Sub-2 7/8" Butt. pin .35 Baker Seal Assy 3 17/32"OD, 2 7/16"ID 1840. 1.20 6.06 .42 ,43 .42 .71 28.67 ,54 .43 2,73 .72 28.53 .54 6.44 .54 .72 246.52 6.05 271.36 10,10 .54 6.28 .95 476.58 20.20 20.18 20.18 3 1/2"OD Baker Locator Sub 2 7/8" 6.4# N-80 Butt. Pup Jr. 2 7/8" Butt. pin X 2 7/8" 8rd pin X-over 3 1/16" X 2 15/16" 2 7/8" 8rd collar 3 5/8"OD 2 7/8" Otis "X" nipple 3 1/4"OD 2 7/8" 8rd X 2 7/8" Butt, X-over collar 3 ll/16"OD 2 7/8" 6.4# N-80 Butt. Tbg. 2 7/8" Butt, pin X 2 7/8" 8rd pin X-over 3 1/16" X 2 15/16" 2 7/8" 8rd collar 3 5/8"OD 2 7/8" Otis "XA" sleeve 3 3/4"OD X 2. 313"ID 2 7/8" 8rd box X 2 7/8" Butt. box X-over 3 ll/16"OD 2 7/8" 6.4# N-80 Butt. Tbg, 2 7/8" Butt. pin X 2 7/8" 8rd pin X-over 2 7/8"OD 2 7/8" Camco KBMG gas lift mand. 2 7/8" 8rd pin X 2 7/8" Butt. pin X-over 2 7/8"OD 2 7/8" Butt. collar 3 7/32"OD 2 7/8" 6.4# N-80 Butt. Tbg. 2 7/8" 6.4# N-80 Butt. Pup Jr. 2 7/8" 6.4# N-80 Butt. Tbg. 2 7/8" 6.4# N-80 Butt. Pup Jt. 2 7/8" Butt. pin X 2 7/8" 8rd pin X-over 2 7/8" OD 2 7/8" Camco KBMG gas lift mand. 2 7/8" 8rd pin X 2 7/8" Butt. box X-over 3 1/8" OD 2 7/8" 6.4# N-80 Butt. Tbg. 3 11/16" OD Blast jts. 2.441" ID 3 11/16" OD Blast jts. 2.441" ID 3 11/16" OD Blast jts. 2.441"ID Continued on page #8 BOTTOM 6416.16 6414.95 6414.46 6413.81 6413.10 6402.95 6402.60 6384.20 6383.00 6276.94 6376.52 6376.O9 6375.67 6374.96 6346.29 6345.75 6345.32 6342.59 6341.87 6313.34 6312,80 6306.36 6305.82 6305.10 6058.58 6052.53 5781.17 5771.07 5770.53 5764.25 5763.30 5286.72 5266.52 5246.34 TOP 6414.95 6414.46 6413.81 6413.10 6402.95 6402.60 6384,20 6380,00 6376.94 6376.52 6376,09 6375.67 6374.96 6346.29 6345.75 6345.32 6342.59 6341.87 6313.34 6312.80 6306.36 6305.82 6305.10 6058.58 6052,53 5781,17 5771.07 5770.53 5764.25 5763.30 5286.72 5266.52 5246.34 5226.16 UHIOI1 OIL CCFP/ tY OF CALIFOPC,IIA ¥&LL I',LCORD PAGE i~O, LEASE TRADING BAY STATE l'~_ IlO, A-14 WO FIEKD Trading. Bay F~eld DATE ElD JTS. 18 2O 4O 48 ]61 37 DETAILS OF OPERATIONS, DESCRIPTIOHS & RESULTS TUBING DETAIL LONG STRING DESCRIPTION LENGTH 30.38 .40 6.4O 2 7/8" 6.4# N-80 Butt. Tbg. 2 7/8" 8rd pin X 2 7/8" Butt, Pin 2 7/8" Camco KBMG gas lift mand. 2 7/8" 8rd pin X 2 7/8" Butt. Pin X-over 3 1/8"OD ,32 2 7/8" Butt. collar 3 7/32"OD ,72 2 7/8" 6.4# N-80 Butt. Tbg, 28,70 2 7/8" Butt. Pin X 3 1/2" 8rd box X-over 4 1/2"OD ,75 3 1/2" 8rd pin X 3 1/2" Butt, pin X-over 3 3/4"OD ,54 3 1/2" Butt. collar 4 1/4"OD ,71 3 1/2" 9,2# N-80 Butt, Tbg. 172.11 3 1/2" Otis X-nipple 3 ll/16"OD .74 3 1/2" Butt, collar 4 1/4"OD ,71 3 1/2" 9.2# N-80 Butt, Tbg. 30,52 3 1/2" Butt. pin X 3 1/2" 8rd pin X-over 3 3/4"OD .53 3 1/2" 8rd collar 4 3/4"OD .43 3 1/2" 8rd pin X 3 1/2" 8rd box 4 1/2"OD.54 to Otis pkr-9 5/8" X 3 1/2" X 2 7/8" X 2 3/8" hyd. top to Otis pkr. 9 5/8" X 3 1/2" X 2 7/8" X 2 3/8" hyd. 3 1/2" 9.2# N-80 Butt, Tbg, 3 1/2" Otis "XA" sleeve 3 1/2" 9.2# N-80 Butt. Tbg 3 1/2" Camco KBUG gas lift mand. 3 1/2" 9.2# N-80 Butt. Tbg 3 1/2" 9.2# N-80 Butt. Pup Jr. 3 1/2" 9.2# N-80 Butt, Tbg 3 1/2" Camco KBUG gas lift mand. 3 1/2" 9,2# N-80 Butt, Tbg 3 1/2" 9.2# N-80 Butt, Pup Jr. 3 1/2" 9.2# N-80 Butt. Tbg 3 1/2" Camco KBUG gas lift mand. 3 1/2" 9.2# N-80 Butt. Tbg 3 1/2" Camco KBUG gas hft mand. 3 1/2" 9.2# N-80 Butt. Tbg. 3 1/2" 9.2# N-80 Butt. Pup Jt. 3 1/2" 9.2# N-80 Butt. Tbg. 3 1/2" Otis Ball Valve 3 1/2" Otis Blast Jr. 3 1/2" 9.4# Butt. Tbg. N-80 Cameron Tbg. Hgr. 4,25 4.40 58.24 4.37 30,76 6,6O 115.25 10.15 520.18 6.6O 589.46 6.08 198.64 6.60 1177.92 6.60 1426.08 6,11 459 .gl 3.75 4 '~ 267.08 1.00 37.40 Total its. of 3 1/2" N-80 Butt. Total its. of 2 7/8" N-80 Butt. BOTTOM 5226,16 5195.78 5195,38 5188,98 5188.66 5187,94 5159.24 5158.49 5157.95 5157.24 4985,13 4984,39 4983,68 4953.16 4952.63 4952.20 4951.66 4947.41 4943.01 4884,77 4880,40 4849.64 4843.04 4727.79 4717,64 4197.46 4190.86 3601.40 3595.32 3396.68 3390.08 2212.16 2205.56 779.48 773.37 313,46 309.71 35.48 38.40 37.40 TOP 5195.78 5195.38 5188.98 5188.66 5187,94 5159.24 5158.49 5157,95 5157.24 4985,13 4984.39 4983,68 4953,16 4952,63 4952.20 4951.66 4947,41 4943.01 4884,77 4880.40 4849,64 4843.04 4727,79 4717,64 4197.46 4190.86 3601,40 3595 32 3396 68 3390 08 2212 16 2205 56 779 48 773 37 313.46 309.71 305.48 38.40 37.40 --0-- UI'lIOll OIL Cff'IPANY OF CALIFOR ,IIA I,, _LL tiLCORD ~.,)1 ILL I 1.,I PAGE rb, LEASE TRADING BAY STATE I'ELL l lO, A- 14 WO FIELD Trading Bay' :F:,elct DATE ETD JTS. 16 14 DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS DIP TUBE 1 1/2" DESCRIPTION LENGTH 1 1/2" Bull Plug .30 1 1/2" Pup Jr, 2,96 2 7/8" Camco 8.13 1 1/2" Tbg, 519.00 1 1/2" telescoping jr. 16.16 Travel Open 1,33 1 1/2" Camco KBM 8,13 1 1/2" tbg. 455.15 1 1/2" Pup Jr. 6,04 1 1/2" Pup Jr. 6,00 1 1/2" Pup Jr. 3.08 1 1/2" Pup Jr. 3.06 1 1/2" Pup Jt. 3.06 1 1/2" E, last Jr. 19.19 1 1/2" Blast Jr, 19.17 1 1/2" Blast Jr, 19.20 1 1/2" Pup Jr. 3.06 1 1/2" Pup Jr. 2,03 1 1/2" Otis telescoping it. 16.16 Travel 12.03 2 7/8" Camco 8.13 1 1/2" tbg. 225.11 ,35 3.45 .84 1.15 9 5/8" X B 1/2" X 2 7/8" X 2 3/8" Otis RTH Pkr, 2 3/8" Tbg. 31.10 BOTTOM 6313,93 6313.63 6310.67 6302.54 5767.38 5767.38 5766.05 5757.92 5302.77 5296.73 5290.73 5287.65 5284.59 5281,53 5262,34 5243.17 5223,97 5220,91 5218.88 5202.72 5190,69 5182.56 4957,45 4957.10 4953.65 4952,81 4951.66 4943.01 TOP 6313.63 6310.67 6302.54 5783 54 5766 05 5766 05 5757 92 5302 77 5296 73 5290 73 5278.65 5284.59 5281.53 5262,34 5243,17 5223.97 5220.91 5218.88 5202.72 5190.69 5182.56 4957.45 4957.10 4953.65 4952,8] 4951,66 4943.01 4911.91 I ? LONG STRIKG SHORT STRING 10. i. 3 1/2" Otis ball valve nipple 2.760'ID, 4.75"OD @ 309.71'. 2. 3 1/2" Camco KBUG gas lift mand. @ 2205.56'. 3 3 1/2" Camco KBUG gas lift mand. @ 3390.08'. 4 3 1/2" Camco KBUG gas lift mand. @ 4190.86'. 5 3 1/2" Camco KBUG gas lift mand @ 4843.04' . 6 3 1/2" Otis XA sleeve 2.75"ID, 4.28"OD @ 4880.40'. 7 9 5/8"X3 1/2"X2 7/8"X2 3/8" Otis RTH pkr. @ 4930.01'. 8 3 1/2" X 2 7/8" Butt. X-over @ 5158.49'. 10. 2 7/8" Camco KBMG-lt. gas lift mand @ 5188.98'. 11. 2 7/8" Otis Blast jr. 60' @ 5226.16' 12. 2 7/8" Camco KBMG-lt. gas lift mand @ 5764.25' . 13. 2 7/8" Camco KBMG-lt. gas lift mand @ 6364.25'. 14. 2 7/8" Otis XA sleeve 2.205"ID, 3.24" OD @ 6375.67'. 15. Baker Locator Sub @ 6383.00'. 16. Baker 9 5/8" X 3.25 Model D perm. pkr. @ 6385.00'. 13 17. 2 7/8" Otis N nipple @ 6413.81'. 18. Cmt. plug @ 7050.00'. 19. 7" Baker cmt. ret. @ 7150.00'. 15 REMARKS: 1. PU tbg. wt. 105,000#. 2. Slack off wt. 65,000#. 3. 60,000# over tbg. wt. to release Otis RTH pkr. H III IV V 14 16 17 WELL SCHEMATIC TRADING BAY STATE A-14 WO Start date-Il/24/75 Completion date- 12/10/75 A. 3 1/2" Otis ball valve nipple 2.760"ID,4.75"OD @ 273.65'. B. 3 1/2" Otis KBUG gas lift mand. @ 2235.91'. C. 3 1/2" Otis KBUG gas lift mand. @ 3418.41'. D. 3 1/2" Otis KBUG gas lift mand. @ 4217.68'. E. 3 1/2" Otis KBUG gas lift mand. @ 4871.13'. F. 3 1/2" X 2 3/8" Butt. X-or @ 4906.16'. G. 2 3/8" Otis XA sleeve 1.875"ID, 3.125"OD @ 4907. n. 9 5/8" X 3 1/Z" X Z 7/8" X 2 3/8" Otis RTH pkr. @ 4943.00'. I. 2 3/8" Otis N nipple 1.791" ID, 2.710"OD @ 4960.92'. DIP TUBE 1 1/2" I. 1 jt. 2 3/8" tbg. w/ collar removed 28' above @ 4911.91'. II. 1 1/2" Otis telescoping jt. 2' travel @ 4953.65'. III. I 1/2" Otis telescoping jr. 2' travel @ 5202.72'. !V. 1 i/2" Blast it. (60') @ 5262.34' . V. 1 1/2" Otis telescoping jr. 16.16'.closed @ 5767.38'. UP. iON O,L CwMrAN( Or- CALIFO.-,NI s~,t~s I ~'.'-"-; .Form D-IOO1-A - ORIGIfiAL UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET A l~, Page No. WELL NO. A-14 WO CONTRACTOR CONSERVATIVE DRILLING TYRE UNIT OILWELL 860 COMPLETED 5/2/84 ELEVATIONS: GROUND CASING HEAD TUBING HEAD ROTARY DRIVE BUSHING LEASE TRADING BAY STATE FIELD TRADING BAY FIELD BEGAN )/)1/84 PERMIT NO. SERIAL NO. ADL 187)1 COMPANY ENG~I~ER, WAGE~HOF~FJER/~3 APPROVE~,~,"~ CASING & TUBING RECORD SIZE DEPTH WEIGHT GRADE REHARKS 5/8" 1097' 61# 0-55 5/8" (7180') 40#/45.5# 0-55/N-80 5/8" 4667 ' 4.6# N-80 Cmtd w/ 1200 sx "G" last 200 sx 2% CaC12 Cmtd w/ 1000 sx 1st stage, 1000 sx 2nd s~age Production: Rkr at 4611' ,. PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION I. 5/16/70 7680-7750' 8020 DST #1 5/18/70 7884-7945' 8020 DST #2 5/21/70 6895-6941' 7650 DST #3/4 5/25/70 6818-6858' 7650 DST #5 5/28/70 7420' 7650 WSO 5/28/70 7190' 7650 WSO 5/28/70 6970-7020' 7650 Production 5/28/70 6896-6898' 7650 Production 5/28/70 6941-6950' 7650 Production 5/28/70 6774-6818' 7650 Production '5/28/70 6858-6866' 7650 Production 5/28/70 6760-6768' 7650 Production 5/28/70 6672-6728' 7650 Production 5/28/70 6600-6642' 7650 Production 5/28/70 6510-6526' 7650 Production 5/28/70 6462-6502' 7650 Production 5/51/70 7458-7472' 7650 Sqzd 5/51/70 7490-7508' 7650 Sqzd 5/51/70 7508-7600' 7650 Sqzd 12/2/75 6896-7016' 7050 Production 12/2/75 6760-6860' 7050 Production 12/2/75 6672-6752' 7050 Production 12/5/75 6554-6562' 7050 Production 12/5/75 6462-6502' 7050 Production 12/5/75 6510-6525' 7050 Production 12/5/75 5540-5585' 7050 Production 12/5/75 5250-5415' 7050 Production 12/5/75 5000-5050' 7050 Production 4/27/84 4790-4815' 4950' Frodqction 4/27/84 4672-4720' 4950' Production Sqzd w/ 200 sx - 2% CaC12 Iso w/ BP ~ 7650' & PB at 4950 PB at 4950' PB at 4950' Sqzd w/ 50 sx & RB at 4950' Sqzd w/ 50 sx & RB at 4950' RB at 4950' RB at 4950' RB at 4950' RB at 4950' RB at 4950' RB at 4950' RB at 4950' PB at 4950' PB at 4950' PB at 4950' Sqzd w/ 87 sx "G" (50 CF water ahead, 5 CF behinc PB at 4950' 57-2 Sd PB at 4950' 56-1 Sd PB at 4950' 55-7 Sd RB at 4950' 54-5 Sd PB at 4950' 55-8 Sd PB at 4950' 55-8 Sd RB at 4950' 47-5 Sd PB at 4950' C-7 Sd (575 sx Sqzd) PB at 4~ C-5 Sd (425 sx Sqzd) PB at 4~ C-5 Sd Open C-2 Sd Open WELL HISTORY PRIOR TO REPAIR COMPLETION DATE: 12/21/75 LAST COMPLETION NO. 2 PRODUCING INTERVAL: C & D Zones INITIAL PRODUCTION: 1125 Net Oil - Short Strin§/ 524 Net Oil -Lonc LAST REGULAR PROD. & DATE: CUMULATIVE PRODUCTION: REASON FOR REPAIR: % Form D-iOO1-B LEASE TRADING BAY STATE COMPLETION DATE 5/02/84 UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO. 2 WELL NO. A-14 FIELD TRADING BAY FIELD APPROVED DATE E.T.D. DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS OTS DESCRIPTION 15 53 69 TUBING DETAIL Mule Shoe 2 3/8" 4.6# N-80 Tbg 2 3/8" Otis "X" Nipple 2 3/8" 4.6# N-80 Pup X-Over 4 1/2" Eue Box X 2 3/8" Butt Pin Seals Otis WD Pkr (15.92' Seals) Seals Locator X-Over 2 3/8" Butt Box X 4 1/2" Eue Box 2 3/8" 4-6# N-80 Pup 2 3/8" 4.6# N-80 Tbg 2 3/8" X-A Sleeve (Otis) 2 3/8" 4.6# N-80 Tbg 2 3/8" KBMG/ GLM 2 3/8" Coupling 2 3/8" 4.6# N-80 Tbg 2 3/8" KBMG/ GLM 2 3/8" Coupling 2 3/8" 4.6# N-80 Tbg 2 3/8" KBMG/ GLM 2 3/8" Coupling 2 3/8" 4.6# N-80 Tbg X-Over 2 7/8" Butt X 2 3/8" Butt 2 7/8" Coupling 2 7/8" 6.4# N-80 Pup 2 7/8" Otis BV Nipple 2 7/8" 6.4# N-80 Tbg 2 7/8" 6.4# N-80 Pup 2 7/8" 6.4# N-80 Pup CIW 2 7/8" X 10" Hgr RT-DCB LENGTH BTM TOP .70' 4666.80' 4666.10' 31.25' 4666.10' 4634.75' .50' 4634.75' 4634.25' 10.86' 4634.25' 4323.39' · 75' 4623.39' 4622.64' 7.92' 4622.64' 4614.72' 4.00' 4614.72' 4610.72' 4.00' 4610.72' 4606.72' .85' 4606.72' 4605.87' .80' 4605.87' 4605.07' 6.10' 4605.07' 4598.97' 32.12' 4598.97' 4566.85' 2.60' 4566.85' 4564.25' 32.27' 4564.25 4531.98' 5.82' 4531.98' 4526.16' .71' 4526.16' 4525.45' 470.23' 4525.45' 4055.22' 5.82' 4055.22' 4049.40' .71' 4049.40' 4048.69' 1651.27' 4048.69' 2397.42' 5.82' 2397.42' 2391.60' .71' 2391.60' 2390.89' 2082.71' 2390.89' 308.18' .77' 308.18' 307.41' .71' 307.41' 306.70' 22.83' 306.70' 283.87' 2.02' 283.87' 281.85' 215.75' 281.85' 66.10' 23.20' 66.10' 42.90' 4.50' 42.90' 38.40' 1.O0' 38.40' 37.40' 37.40' 37.40 .00' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-14 WO ' FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS COMMENCED OPERATIONS 8 02:00 HRS, 3/31/84. 1 DAY 3/31/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071'-8086 FIW DAILY COST: $ 7,370 ACC COST: $ 7,370 AFE AMOUNT: $2,500,000 RU OTIS COILED TBG UNIT OVER TBS A-14. RU 2 5/8", 3 BLADED MILL ON i 3/4" DYNA-DRILL. TSTD COILED TBG BORE & CHOKE MANIFOLD TO 5000 PSI, OK. RIH PUMPING FIW ~ 1/2 BRM/ 3500 RSISURFACE PRESS ON HOWCO RUMPS. RI & HIT HARDSROT ® 3465'. RU TO 3400' & CIRC BTMS UR. GETTING COAL & FIW RETURNS. RIH 3606' & STUCK COILED TBG. SURFACE PUMPING RRESSBUILT TO 5000 PSI. PRESS BLED F/ 5000-4300 PSI IN 70 MIN. 2 DAY 4/01/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. ® 7071'-8086 95 PCF 660 PSI/lO00' DAILY COST: $ 37,783 ACC COST: $ 45,153 AFE AMOUNT: $2,500,000 WORKED COILED TBG. PULLED 11,000 LBS W/O SUCCESS. INCREASED PUMP PRESS TO 6500 PSI AND BROKE CIRC. CIRC 1/2 BPM/3500 PSI WHILE WORKING PIPE. RETURNS CONSISTED OF COAL W/ SLIGHT GAS BREAKOUT. MIXED GEL IN FRESH WATER AND WEIGHTED SYSTEM TO 95 PCF. CIRC ~ 1/2 BPM/5400 PSI. CLEANED OUT 3 1/2" X 1" ANNULUS W/ 95 PCF MUD. RETURNS CONSISTED OF LARGE QUANTITIES OF COAL. CIRC ANN CLEAN. CIRC & WORK COILED TBG TO 14,500 LBS PULL. GAINED 12' (3606'-3594') IN 1 HR. 3 DAY 4/02/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. $ 7071'-8086 95 PCF 660 PSI/lO00' DAILY COST: $ 33,137 ACC COST: $ 78,290 AFE AMOUNT: $2,500,000 CONT CIRC & WORKING COILED TBG. MIX 95 PCF MUD & INCREASE SURFACE VOLUME. SI WELL & RU TO PUMP DOWN 1" COILED TBG AND 3 1/2" X 1" ANNULUS SIMULTANEOUSLY W/ HOWCO TAKING RETURNS F/ THE 9 5/8" X 3 1/2" ANN. GETTING COAL IN RETURNS. PUMP 265 BBLS OF 95 PCF MUD & RECEIVED MUD BACK ~ THE SURFACE. SHUT WELL IN. 4 DAY 4/03/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071'-8086 101PCF 701 PSI/lO00' DAILY COST: $ 25,806 ACC COST: $ 104,096 AFE AMOUNT: $2,500,000 OBSERVE SICP OF 110 PSI OVER 6.5 HRS. CIRC & COND MUD TO 101PCF. RU WL LUBRICATOR ON 1" COILED TBG. RIH W/ 2.5' OF PRIMER CORD. SHOT ~ 3549' WLM (2 5/8" MILL STUCK ~ 3596' TBG MEAS) WHILE HOLDING 9500 LBS PULL ON COILED TBG. WORKED COIL TBG W/O SUCCESS. RAN SHOT #2 TO 3485' WLM & SHOT INSIDE COILED TBG WHILE PULLING 14,500 LBS ON COILED TBG. WORKED COILED TBG FOR 2 HRS W/O SUCCESS. FREE POINT CALCULATED F/ STRETCH DATA INDICATES COILED TBG STUCK ~ +_.3500'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-14 WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6 DAY 4/05/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. $ 7071'-8086 101RCF 701 PSI/1000' DAILY COST: $ 23,793 ACC COST: $ 153,706 AFE AMOUNT: $2,500,000 INVENTORY DRLG EQUIPMENT. PERFORMED GENERAL RIG UP OF RIG #56. CIRC WELLBORE W/ 101 PCF FLUID. 7 DAY 4/06/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071-8086' 101PCF 701 PSI/1000' DAILY COST: $ 37,963 ACC COST: $ 191,669 AFE AMOUNT: $2,500,000 RU & RIH W/ 3RC COILED TBG CUTTER TO 2539' WLM AND MAKE CUT INSIDE COILED TBG. WORKED COILED TBG W/O SUCCES. RIH W/ 2ND SRC CUTTER AND FIRED CUTTER ~ 1500' WLM. POOH W/ 1500' OF COILED TBG. INSTALLED BRV, ND TREE, NU BORE AND TEST TO 2800 PSI, OK. 8 DAY 4/07/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071-8086' 101PCF 701 PSI/lO00' DAILY COST: $ 20,620 ACC COST: $ 212,289 AFE AMOUNT: $2,500,000 PULLED ON 3 1/2" PROD TBG W/ 130M LBS PULL. TBG CAME FREE W/ 50M-60M LBS DRAG. POOH W/ 3 1/2" TBG & LAY DOWN 8' PUP BEFORE GETTING STUCK. WORKED PIPE & CIRC BTMS UP GETTING EGG-SIZED PIECES OF COAL OVER SHAKER. HUNG 3 1/2" TBG IN PIPE RAMS. FREE POINT CALCULATIONS SHOW THAT THE 3 1/2" IS STUCK ~ 3533'. RU TO FISH FOR COILED TBG INSIDE OF 3 1/2" TBG W/ 1 1/4" HYDRIL TBG. RIH W/ OVERSHOT (BHA #2) ON 1 1/4" TBG. TAG TOP OF FISH ~ 1945'. DRESS AND CHASE SAME TO 2444'. ENGAGE FISH AND POOH. RECOVERED 996' OF 1" COILED TBG. RIH W/ SAME FISHING ASSY (BHA #2) TO 2914'. DRESS AND ENGAGE FISH. POOH W/O FISH. 9 DAY 4/08/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071-8086' 101PCF 701 PSI/1000' DAILY COST: $ 18,530 ACC COST: $ 230,819 AFE AMOUNT: $2,500,000 MU & RIH W/ BHA #3 TO 2914'. WORK OVER FISH AND POOH W/O FISH. MODIFY FISHING TOOL & RIH W/ BHA #4. WORK OVER FISH AND POOH W/O FISH. RAN 2 5/8" IMPRESSION BLOCK TO (2944' WLM) ON WL WHICH SHOWED NOTHING. MU & RIH W/ BHA #5, ENGAGE FISH ~ 2944'. PU W/ 5000 LBS EXTRA DRAG & POOH. NO RECOVERY. RERAN BHA #5 TO 2944', WORK OVER FISH AND POOH W/ NO RECOVERY. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-14 WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS l0 DAY 4/09/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. 8 7071-8086' lO1 PCF 701 PSI/lO00' DAILY COST: $ 24,499 ACC COST: $ 255,318 AFE AMOUNT: $2,500,000 RAN SET CUTTER INSIDE 3 1/2" PROD TBG TO 2940' WLM AND CUT 3 1/2" TBG. WORKED TBG FREE, POOH W/ SAME. MU & RIH W/ BHA #6 (HOLLOW MILL), TAG AND DRESS TOP OF 3 1/2" FISH ~ 2944' DRM. POOH. MU & RIH W/ BHA #7 (7 5/8" WASH RIPE W/ RACKER SHOE). WORK OVER FISH ~ 2944' DRM AND RIH TO 3237'. WASH TO 3648'-N0 FILL. 11 DAY 4/10/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. · 7071-8086' 101RCF 701 PSI/1000' DAILY COST: $ 32,313 ACC COST: $ 287,631 AFE AMOUNT: $2,500,000 POOH W/ WASH PIPE. PU OUTSIDE CUTTER ON BHA #8 AND RIH. CUT 3 1/2" TBG ~ 3621' DPM. POOH. RECOVERED 680' OF FISH. FOUND WHAT LOOKED LIKE COLLAPSED TBG ~ 3522'. FOUND DYNA DRILL ~ 3591'. PU OVERSHOT ON BHA #9 AND RIH. LATCH ONTO FISH ~ 3619' DRM. UNABLE TO CIRCULATE (2500 PSI). OARRED ON FISH W/O SUCCESS. RELEASE FROM FISH AND POOH. RU 2 7/8" TBG TAIL ON 5" DR & RIH. 12 DAY 4/11/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. · 7071-8086' 101RCF 701 PSI/1000' DAILY COST: $ 109,245 ACC COST: $ 396,876 AFE AMOUNT: $2,500,000 RIH W/ 2 7/8" TBG TAIL ON 5" DP. PU KELLY 3918' DPM. CIRC WHILE RUNNING IN HOLE. COAL BRIDGE ~ 3967' DPM. WASH TO BTM ~ 4863' CIRC BTMS UP. POOH 15 STANDS. RIH (NO F~LL) CIRC BTMS UP. POOH & LD 2 7/8" TBG TAIL. MU OVERSHOT (BHA #10) AND RIH TO 3671' DPM (FISH HAD DROPPED BACK INTO PERM PKR). ENGAGE 3 1/2" FISH ~ 3671'. POOH W/ 1258' OF 3 1/2" TBG. 3 1/2" TSG PLUGGED W/ COAL. RECOVERED ALL 3 1/2" PROD TBG FROM WELBORE. 13 DAY 4/12/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071-8086' 101 PCF 701 PSI/lO00' DAILY COST: $ 35,851 ACC COST: $ 432,727 AFE AMOUNT: $2,500,000 14 DAY 4/13/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071-8086' lO1 PCF 701 PSI/lO00' DAILY COST: $ 29,633 ACC COST: $ 462,360 AFE AMOUNT: $2,500,000 RIH W/ BHA #11 (8 1/2" BIT & 9 5/8" CSG SCRAPER). CSG TIGHT ~ 3944-3894' AND 4396- 4862'. TIGHTEST AREA F/ 4445-4453'. NO FILL ON BTM. RIH W/ 8.25" GAUGE RING. UNABLE TO GET TO DOWN PAST 3924'. POOH & LD GAUGE RING. RU SCHLUMBERGER CET. RIH FOR TEST. UNABLE TO GET WORK IN 6 HRS. RIG DOWN SCHLUMBERGER AND LOAD OUT. RU ARRS W/ DIALOG MIN ID CALIPER. LOGGED CSG F/ 4830' TO SURFACE. UNABLE TO DETERMINE THAT COLLAPSED CSG EXISTS F/ LOG. RD DIALOG. RUN SPERRY SUN GRYRO TO 4850' WLM. POOH & RD SPERRY SUN. RU DRESSER ATLAS. RU CBL-GR- VDL-CCL F/ 4853'-1850' WLM. POOH AND RD DRESSER ATLAS. RIH W/ 8 1/2" BIT TO PERM RKR ~ 4862' DRM. CIRC AND POOH. RU 9 5/8" RTTS AND RIH. TESTED 9 5/8" CASING TO 2000 PSI ~ 3900'. WHILE TESTING ~ 4087' FLUID STARTED LEAKING AROUND RTTS. STOPPED TEST & POOH. CHANGE RUBBERS ON RTTS. RIH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-14 WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 DAY 4/14/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. 8 7071-8086' RAISING MUD WT F/ 108 RCF TO 136 PCF DAILY COST: $ 84,813 ACC COST: $ 547,173 AFE AMOUNT: $2,500,000 RIH W/ RTTS. TEST 9 5/8" CSG TO 2000 PSI ~ 4838'. LOADED DP W/ FIW (63+PCF) THRU BYPASS VALVE. SHUT IN DP FOR BHP TEST ~ 05:00 HRS W/ INITIAL SI PRESSURE OF 1200 PSI. PRESS BUILT TO 2150' IN 5 HRS 10 MIN. BLEED PRESS OFF TO 750 PSI. PRESS BUILT TO 1500 PSI IN 6 HRS 10 MIN. RAISING MUD WT TO 136 PCF. PUT 2000 PSI ON ANNULUS & ATTEMPT TO INJECT DOWN DP. NO BREAKDOWN ~ 4000 PSI DP PRESS. WORK PRESS ON DP F/ 500-4000 PSI W/ NO BREAK DOWN. BLED DP PRESS TO 1000 PSI. SI DP. PRESS ON DP BUILT TO 2100 PSI IN 15 MIN. PUMPED INTO FORMATION ~ 3000 PSI AND BROKE DOWN FORMATION. INJECT FIW ~ 10-12 CFM ~ PUMP IN PRESS OF 2500 TO 3000 PSI. SI DP 8 2500 PSI. PRESS DROPPED AND STABILIZED 8 2150 PSI. 16 DAY 4/15/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. $ 7071-8086' 136 PCF 944 PCF/ 1000' DAILY COST: $ 68,085 ACC COST: $ 615,258 AFE AMOUNT: $2,500,000 BUILT MUD WT TO 136 PCF. KILL WELL. CIRC & COND MUD. INSTALL NEW CATHEAD (MAKE-UP). RU MUD BOX. RELEASE RTTS. CIRC. POOH. LD RTTS AND PU TSA SHOE AND PRT. RIH. MILL OVER PERM PKR (BAKER F-l) PKR ~ 4862' DPM. POOH W/ PKR. 17 DAY 4/16/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. $ 7071-8086' 136 PCF 944 PCF/ 1000' DAILY COST: $ 35,231 ACC COST: $ 650,489 AFE AMOUNT: $2,500,000 POOH. LD "F-i" PERM PKR. CHANGE PRT AND SHOE. RIH. TAG & WASH COAL F/ 4873-4897'. TAG & MILL ON MODEL "D" PERM PKR 8 4897' DPM. POOH. LAY DOWN PKR & PRT TOOLS. TEST BOPE, HYDRIL TO 2500 PSI, PIPE RAMS BLIND RAMS, KILL & CHOKE LINES TO 3000 PSI. MU BHA #15 (8 1/2" BIT W/ STABLIZER). RIH & TAG COAL ~ 5014' DPM. CO TO 5190'. WELL BEGAN TAKING FLUID. LOST 80 BBLS IN 30 MIN. MOST PROBABLY LOST CIRCULATION ZONE LIKELY TO BE THE (C-7) 5230-5415' DIL. SHUT RUMPS DOWN & MONITORED ANNULUS. HOLE STATIC W/ RUMP OFF. BEGAN PULLING DP UP WHILE PUMPING 1.3 BPM ~ 450 PSI - LOST 19.5 BBLS IN 5 MIN. PUMP DRY 30B & POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE ND. LEASE TRADING BAY STATE WELL NO. A-14 WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 18 DAY 4/17/84 6350' ETD (CMT RET) 9 5/8" 7180' 7" L. 8 7071-8086' 137 PCF 951 PCF/ 1000' DAILY COST: $ 38,392 ACC COST: $ 688,881 AFE AMOUNT: $2,500,000 POOH W/ DP TO 3580'. CONDITION MUD IN PITS TO ACHIEVE BETTER FLOW PROPERTIES (LOWER THE YIELD POINT). STAGE BACK INTO HOLE CIRCULATING EACH STAND IN. RIH W/ DP TO 5170' CIRC BTMS UP TWICE RECEIVING FULL RETURNS. POOH W/ DP. RIH W/ HOWCO CMT RET ON DP TO 5075'. ATTEMPT TO SET CMT RET WITHOUT SUCCESS. 19 DAY 4/18/84 5075' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071-8086' 136 PCF 944 PCF/ 1000' DAILY COST: $ 28,105 ACC COST: $ 716,986 AFE AMOUNT: $2,500,000 POOH W/ HOWCO CMT RET THAT WOULDN'T SET. NOTHING VISUALLY WRONG W/ CMT RET. MU NEW HOWCO CMT RET ON DP & RIH. MU TEST HEAD & SET RET 8 5075' DPM. TEST SURFACE LINES TO 2500 PSI. STABBED INTO CMT RET AND BROKE DOWN FORMATION (C-7 OR 47-5 SANDS) ~ 100 PSI SURFACE PRESS W/ 136 PCF MUD IN DP & HOLE. INJECT 13 CFM 8 500 PSI. SIDPP STABILIZED 8 2075 PSI AFTER AN INITIAL PUMP IN PRESS OF 2250 W/ FIW IN THE DP. BLED DP SURFACE PRESS TO 1970. SIDPP STABILIZED 8 2060 PSI AFTER 1 HR 25 MIN (ESTABLISHED BHP TO BE + 3980 PSI). INJECTED 200 CU FT OF FIW ® 15-17 CFM 8 2600 PSI. SHUT DP IN. PRESS BLED TO 2300 PSI BEFORE GETTING WORD TO SQZ OF THE C-7 & 47-5 SANDS. SQZ THRU CMT RET ~ 5075' BROKE DOWN PERFS W/ 22 CFM ® 2600 PSI. ~IZED 400 SXS CLASS "G" W/ .75% CFR-2 .4% HALAD 22A, 1% CACL2. DISPLACED 375 SXS BELOW TOOL W/ FINAL PUMPING RATE OF 2.5 BPM ~ 1000 PSI. DISPLACED CMT W/ 136 PCF MUD. SQZ JOB HELD 250 PSI W/ PUMPS OFF AFTER 5 MIN. CIP ~ 5:00 PM 4/18/84. REVERSE OUT EXCESS CMT. CIRC & COND MUD. POOH W/ DP. MU HOWCD CMT RET & RIH. 20 DAY 4/19/84 4827' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071-8086' 134 PCF 931 PSI/lO00' DAILY COST: $ 45,692 ACC COST: $ 762,678 AFE AMOUNT: $2,500,000 RIH W/ HOWCO CMT RET & SET ® 4827' DPM. RU HOWCO PUMPS. ESTABLISH CIRC. TEST SURFACE EQUIP TO 4000 PSI, OK. BROKE DOWN C-5 (5000- 5030' DIL) PERFS W/ 3000 PSI & FIW IN DP. MIXED 300 SXS CLASS "G", .75% CFR-2, .4% HALAD 22A, 1% CACL2. DISPLACED 219 SXS CMT BELOW TOOL W/ FINAL PUMPING RATE OF 8 CFM ~ 1300 PSI. SQZ JOB HELD 1000 PSI W/ PUMPS OFF AFTER 5 MIN. CIP 8 21:00 HRS. CIRC & COND MUD. POOH. MU DA #16 (8 1/2" BIT). RIH UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-14 WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 21 DAY 4/20/84 4827' ETD (CMT RET) 9 5/8" 7180' 7" L. ~ 7071-8086' 136 PCF 944 PSI/lO00' DAILY COST: $ 30,914 ACC COST: $ 793,592 AFE AMOUNT: $2,500,000 RIH TO 4800' DPM. CIRC & BUILD MUD VOLUME. RIH & TAG CMT RET ~ 4827'. DPM. DRL ON RET. 22 DAY 4/21/84 5225' ETD (CMT) 9 5/8" 7180' 7" L. ~ 7071-8086' 136 PCF 944 PSI/1000' DAILY COST: $ 23,906 ACC COST: $ 817,498 AFE AMOUNT: $2,500,000 CONT DRILL ON CMT RET - BROKE THRU ~ 2:30 AM (TOTAL TIME DRLG ON RET - 7 HRS). CO FIRM CMT F/ 4830 - 4899'. CIRC BTMS UP. TRIP FOR BIT #}. CHANGE BIT & MAKE UR DA #18. RIH TO 4895'. CO FILL F/ 4895' TO 4899'. CO CMT (FIRM) F/ 4899' TO 50}4' THEN FELL THRU. RIH & TAG RET ~ 5075' DPM. DRL ON SAME FOR 3 1/2" HRS). CO HARD CMT F/ 5078' TO 5225'. LOST APR l} BBLS MUD IN 40 MIN WHILE DRLG F/ 5203' TO 5212'. ALSO HAD TORQUE & OVER NORMAL RULL WHILE CO F/ 5185' TO 5189 MAX 800 AMPS & 50,000 OVER RULL. CIRC CLEAN. PUMR DRY SOB. TRIR FOR HOWCO TYRE SV EZ DRILL. (LOST NO MUD ON TRIP OUT). STRAR OUT. MAKE UP HOWCO EZ DRILL & SETTING TOOL. RIH SLOW. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 9 LEASE TRADING BAY STATE WELL NO. A-14 WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 23 DAY 4/22/84 5220' ETD (CMT RET) 9 5/8" 7180' 7" L. 8 7071-8086' 136 RCF 944 PSI/lO00' DAILY COST: $ 33,379 ACC COST: $ 850,877 AFE AMOUNT: $2,500,000 SET HOWCO CMT RET ~ 5220' OPM (5213' OIL, CBL). POOH. MAKE UP DST ASSY #1. RIH TO 5197' BTM OF ASSY. RU TST HEAD & LUBRICATOR. TST SAME TO 4000'. RIH W/ DRESSER & TIE TO CBL LOG (12-1-75 GO-INT). FOUND DR MEASURE- MENTS TO BE OFF 7'(DRM=5014' CBL=5OO7')(CBL= DIL). SPACED OUT & SET RA SOURCE ~ 5012' RKR ~ 5079'. WIRE WRAP ~ 5128' TO 5135' (6' OF SCREEN). TOP SHOT ~ 5188', BMT SHOT ~ 5192' CBL. RETEST LINES TO 4000 PSI. OPEN BY PASS & DISPLACE TEST STRING TO 4900' W/ FIW. LOAD BAR. TEST WELL. TIME 3:30 PM. SHUT IN PRES AFTER DISPLACING DP W/ FIW WAS 2250 PSI. BLED BACK lO CF & SHUT IN PRESS =200 PSI. IN i MIN SHUT IN HAD BUILT TO 2000 PSI & HELD FOR 3 MIN. BLED OFF 20 CF, SHUT IN PRESS=O PSI. BUILT TO 1000 PSI IN 2 MIN & HELD FOR 3 MIN. BLED BACK lO CF & SHUT DOWN PRES STARTED BUILDING AS SOON AS SHUT IN TO llO0 PSI & HELD FOR 4 MIN. BLED BACK lO MORE CF & SHUT IN. STARTED BUILDING PRESS AS SOON AS SHUT IN. TOOK i MIN TO BUILD TO llO0 PSI. 18 MIN SHUT IN =1200 PSI. 30 MIN=1300 PSI. 45 MIN=1450 PSI. i HR =1500 PSI ~ 5:00 PM. STARTED TO BLEED BACK l0 CF. PRES FELL TO 0 PSI & HELD AFTER APPROX 5 CF WAS PRODUCED. PUMPED 5 CF AWAY ~ 2250 PSI. BLED BACK 15 CF, PRESS BUILT TO lO00 PSI IN 3 MIN. 6 PM, SHUT IN PRESS=1200 PSI. TOOL APPEARED TO BE PLUGGED. PUMP AWAY 20 CF & SHUT IN W/ 2700 PSI. BLED BACK 20 CF PRESS 0 PSI & NO BUILD. PUMP 10 CF PRESS TO 2700 PSI. BLED BACK 10 CF TO 0 PSI. DID SAME THING APPROX 5 TIMES N/G. TOOL SEEMED PLUGGED. ATTEMPT TO FIRE GUNS WHILE HOLDING 1700 # BACK PRESS. COULD NOT TELL IF GUN HAD FIRED. BLED TEST STRING TO 0 PSI IN 500 PSI INCREMENTS. TOTAL BACK, 8 CF (TEST STRING PLUGGED). ATTEMPT TO OPEN BY PASS & DISPLACE TEST STRING W/ 136 PCF MUD. HAD MOVEMENT ~ BY PASS BUT COULD NOT CIRC THRU SAME. LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. A-14 WO SHEET D RAGE NO. l0 FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5220' ETD (CMT RET) 5184'(BAD SPOT W/ HIGH TORQUE 24 DAY 4/23/84 9 5/8" 7180' 7" L. 0 7071-8086' 136 PCF 944 PSI/lO00' DAILY COST: $ 83,586 ACC COST: $ 934,463 AFE AMOUNT: $2,500,000 COULD NOT CIRC THRU BYPASS ABOVE RTTS. PRESSURED UP TO 2800 PSI W/O CIRC. ATTEMPT TO UNSEAT RKR W/ 50,000 LBS OVER PULL W/O SUCCESS. PRESS UP DRL STRING (2800 PSI) & WORK BYPASS OPEN & CLOSE SEVERAL TIMES W/O CIRC. PULLED 60,000 LBS OVER PULL ON DRL STRING W/O SUCCESS. PRESSURED UR DR TO 4000 PSI & FLUID STARTED MOVING. RUT AWAY 10 CF & PRESS DROPPED TO 3000 PSI. CIRC 80 CF W/ SAME PRESS AT WHICH TIME THE RTTS CAME LOOSE W/ 15,000 LB EXTRA PULL OVER NORMAL STRING WT. OBTAINING INTERMITTENT RETURNS. RTTS WOULD MOVE UR BUT NOT DOWN. ATTEMPT TO REVERSE OUT TEST STRING. PUMPED 175% OF TEST STRING VOLUME 0 2 BBL/MIN & 300 PSI ON ANN, (0 PSI ON DR). LOOSING RETURNS. RTTS WOULD WORK UR & DOWN W/ ARRROX 15,000 LBS DRAG. POOH 35'. TEST STRING WAS NOT FULL & ANN WAS FLOWING INTERMITTENTLY. CIRC LONG WAY WHILE WORKING STRING. CIRC ~ +3 BBL/MIN W/ 200-500 PSI DR SURFACE PRESS. CIRC BTMS UR TWICE. WELL DEAD. RU DRESSER ATLAS W/ 7/8" OVER SHOT & SPANG OARS. TIED INTO RTTS W/ CCL. FOUND FIRING BAR STUCK IN 1ST RUR ABOVE FIRING HEAD. UNABLE TO ENGAGE FISH W/ 2 ATTEMPTS. POOH W/ WL. BUILD MUD WT TO 136 RCF. POOH W/ TEST STRING. FOUND FIRING BAR 3' ABOVE FIRING HEAD. RUR OOINT HAD A "S" SHARED BEND IN IT & FIRING BAR WAS SURROUNDED W/ BARITE. WIRE WRAPPED SCREEN (.013") HAD BEEN TORN UR ~ TOP WELD EXPOSING 3/8" HOLES. SCREEN ALSO SHOWED SIGNS OF DAMAGE F/ INTERNAL PRESS. SCREEN WAS PLUGGED W/ COAL & BARITE. MU BHA #19 (8 1/2" BIT) & RIH. HIT BAD SPOT IN 9 5/8" CSG 8 5184'. ROUGH DRLG F/ 5184-5192' DRM. MAX AMPS=ilO0 ~ lO,O00 LBS WT & 40-60 RRM. MUD RETURNS CONTAINED LARGE CHUNKS OF COAL & CMT. CIRC WELLBORE CLEAN. POOH. RU HOWCO CMT RET & RIH. 4623' OPM ETD (CMT RET) 4616' OIL 25 DAY 4/24/84 9 5/8" 7180' 7" L. ~ 7071-8086' 136 PCF 944 PSI/lO00' DAILY COST: $ 36,516 ACC COST: $ 970,979 AFE AMOUNT: $2,500,000 RIH W/ HOWCO CMT RET. SET RET ~ 4957' DPM. (4950' DIL). TEST ANN W/ 600 PSI & 136 PCF MUD. ABANDON THE WELLBORE FROM ABOVE THE C-5 SAND 5000-5030' DIL. MIXED 250 SXS CLASS "G", .75% CFR-2 .4% HALAD 22A, 1% CACL2. DISPLACED 206 SXS BELOW RET W/ A FINAL PUMPING RATE OF 9 CFM ~ 500 PSI. SQZ OOB HELD lO0 PSI W/ PUMPS OFF AFTER 5 MIN. CIP ~ 4:30 AM. POOH W/ DP. RIH W/ 8 1/2" BIT & 9 5/8" CSG SCRAPER. TAG RET ~ 4957' DPM. CIRC. POOH. RU DRESSER ATLAS & PERF F/ 4655-4657' DIL, 4 HPF, 90° PHASING. POOH & RD D/ATLAS. PU HOWCO CMT RET & RIH & SET ~ 4623' OPM (4616' DIL). TEST DP & SURFACE EQUIP TO 5000 PSI & ANN TO 500 PSI. BROKE DOWN RERFS W/ 400 PSI. LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. A-14 WO SHEET D PAGE NO. ll FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4623' DPM ETD (CMT) 26 DAY 4/25/84 9 5/8" 7180' 7" L. ~ 7071-8086' 128 PCF 944 PSI/lO00' DAILY COST: $ 34,965 ACC COST: $1,005,944 AFE AMOUNT: $2,500,000 MIXED & SQUEEZED FOR ISOLATION ABOVE C-2 SAND W/ 124 SX CL "G" W/ .75% CFR-2, .4% HALAD 22-A, & 2% CACL2. HAD FINAL RATE OF 6 CFM 8 550 PSI. CIR ~ 00:55 HRS, 4/25/84. REVERSE CIRC F/ TOP OF RETAINER & POOH. RIH W/ BIT #3 RR ON BHA #21 TO 4508'. CIRC & PERFORM RIG MAINTENANCE WHILE WOC. RIH TO 4623' & DRLD RET F/ 4623' TO 4626'. DRLD SOFT CEMENT F/ 4626' TO 4636'. CIRC & PULLED TO 4546'. CIRC & WOC. 4952' DPM ETD (JUNK ON RET) 27 DAY 4126/84 9 518" 7180' 7" L. ~ 7071-8086' 67 PCF 465 PSI/IO00' 6% KCL & FIW DAILY COST: $ 31,445 ACC COST: $1,037,389 AFE AMOUNT: $2,500,000 WOC. DRL FIRM CMT F/ 4636-4662' DPM. CIRC & PUSH JUNK TO 4952' DPM. TEST CSG W/ 800 PSI SURFACE PRESS W/ 128 PCF MUD IN THE WELLBORE. DISPLACE HOLE W/ FIW. CLEAN MUD PITS. MU 6% KCL SYSTEM IN FIW. MIX SAFE-LINK SATURATED SALT SYSTEM. 4952' ETD (JUNK ON CMT RET) 28 DAY 4/27/84 9 5/8" 7180' 7" L. ~ 7071-8086' 70 PCF 486 PSI/lO00' DAILY COST: $ 63,076 ACC COST: $1,100,465 AFE AMOUNT: $2,500,000 MIX SAFE LINK SYSTEM. DISPLACE 100 BBL SAT SALT COMP FLUID ACROSS THE C-2 AND C-3 SANDS. POOH W/ DR. RU DRESSER ATLAS. RERF THE C-'3 SAND (4790-4815') DIL & THE C-2 SAND (4672'- 4720') DIL, W/ 5" CSG GUNS, 8 HRF, 120° PHASING. RAN 8.31" GAUGE RING & JUNK BASKET TO 4645' DIL. RAN & SET OTIS "WD" PROD RKR ~ 4599' DIL. POOH W/ WL. RIH W/ TEST SEALS & LOCATORON DR. TESTED RKR ~ 4604' DRM (4599' DIL) TO 500 PSI, OK. CIRC OUT SAFE LINK SYSTEM ABOVE PERM RKR. POOH LAYING DOWN DP. 4952' ETD (JUNK ON CMT RET) 29 DAY 4/28/84 9 5/8" 7180' 7" L. ~ 7071-8086' DAILY COST: $ 111,072 ACC COST: $1,211,537 AFE AMOUNT: $2,500,000 LAY DOWN DP. CNG F/ 5" TO 2 3/8" RAMS IN DG. RU TO RUN 2 3/8" TBG. RUN COMP ASSY & STAB INTO OTIS "WD" PKR (5" BORE) ~ 4611' TBG MEAS. PULL UP, INSTALL BV NIPPLE & CONTROL LINE. SPACE OUT & TEST CONTROL LINE TO 5000 PSI. LAND TBG W/ LOCATOR 4' ABOVE PKR. TEST SEALS TO 500 PSI. INSTALL BPV. ND BOPE. INSTALL & TEST TREE TO 5000 PSI, OK. INSTALL SURFACE LINES TO TREE. CHANGE BLADDER IN ANNULAR PREVENTER. CLEAN RESERVE PIT. LOAD OUT DC & DP, TBG & RENTAL ITEMS. BEGIN INSTALLING NEW CHOKE MANIFOLD. LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. A-14 WO SHEET D PAGE NO. 12 FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4952' ETD (JUNK ON CMT RET) 30 DAY 4/29/84 9 5/8" 7180' 7" L. ~ 7071-8086' DAILY COST: $ 20,460 ACC COST: $1,231,997 AFE AMOUNT: $2,500,000 MU NEW CHOKE MANIFOLD & TEST TO 5000 PSI PRIOR TO INSTALLATION. TEAR OUT & CLEAN SUCTION LINES ON MUD RUMPS. DISMANTLE OLD CHOKE MANIFOLD. START INSTALLATION OF NEW CHOKE MANIFOLD. CLEAN RIG #56 & SUB-BASE. REMOVE OLD RUSTED LINES IN SUB-BASE. BRING ON A-14 8 24:00 HRS. 4952' ETD (JUNK ON CMT RET) 31 DAY 4/30/84 9 5/8" 7180' 7" L. ~ 7071-8086' DAILY COST: $ 19,345 ACC COST: $1,251,342 AFE AMOUNT: $2,500,000 FINISH CLEANING MUD PUMP SUCTION LINES AND REPLACING VALVE5 IN MUD MIXING MANIFOLD. REPLACE BOARDS IN CAT-WALK. TEST CHOKE MANIFOLD TO 5000 PSI. INSTALL EYE-WASH STATIONS. REBUILD SQZ MANIFOLD. CLEAN RIPE RACKS IN RRER FOR PAINTING. BRING ON A-14. 4952' ETD 32 DAY 5/01/84 9 5/8" 7180' 7" L. ~ 7071-8086' DAILY COST: $ 19,345 ACC COST: $1,270,687 AFE AMOUNT: $2,500,000 CLEAN SUBS & X-OVERS ON RIG FLOOR. PAINT CHOKE MANIFOLD & BORE. INVENTORY RAM BLOCKS. REPAIR ELECT LINES & CONTROL LINES TO DRAWWORKS. CLEAN & PAINT CAT ENGINES, SUB-BASE, AND AIR- RECEIVER. BUILD SAFETY CAGE FOR LADDER IN DERRICK AND BRING ON TBS A-14. 4952' ETD (JUNK ON CMT RET) 33 DAY 5/02/84 9 5/8" 7180' 7" L. ~ 7071-8086' DAILY COST: $ 21,544 ACC COST: $1,292,231 CONTINUE REPLACING LINES IN SUB-BASE. HANG SAFETY CAGE ON LADDER. RELEASE CREWS FROM AFE # 331004 8 24:00 HRS, 5/02/84/. AFE AMOUNT: $2,500,000 II WELL NT B&S A-1 i CASI ABANDONMENT DETAIL' III -- VI VIII IX ---.-- C-2 C-3 C-5 C-7 47-5 Io) Rotary Table Measurement at 0.00' II.) Cameron Tubing Hanger at 37.40' II1.) 13 3/8', 61~', J-55 Casing at 1097' IV.) Cement Retainer at 4950' V.) Cement Retainer at 5213' VI.) Cement Retainer at 6350' VII.) Top 7', 29~, N-80 Liner at 7071' VIII.) 9 5/8', 40~ & 43.5~, N-80 Casing at 7180' IX.) Bottom 7', 29~, N-80 Liner at 8068' 0 -- 1 ~ 2 GUM 3 GLM 4 GLM 5 _ XA 6 7 x ~__- ~ 10 ---- ---- --- iV ~~-~~-~~- TUBING DETAIL 2 3/8" 4.6# & 2 7/8 , 6.4# N-80 TUBING, 1.) Otis Ball Valve at 281.85' 2.) 2 7/8' x 2 3/8' Crossover at 307.41' 3.) Camco "KBMG' Gas Lift Mandrel at 2391.60' 4.) Camco 'KBMG' Gas Lift Mandrel at 4049.40' 5.) Camco 'KBMG' Gas Lift Mandrel at 4526.16' 6.) Otis ;XA' Sleeve at 4564.25' 7.) Locater Sub at 4605.87' 8.) Otis Model "WD' Packer with Seal Assembly from 4606.72' to 4622.64' 9.) Otis 'X' Nipple at 4634.25' 10.) Bottom of Mule Shoe at 4666.80.' PERFORATION RECORD DA TE INTERVAL 5000'-5030' 5230'-5415' 5540'-5585' 4672'-4720' 4790'-4815' CONDITION Squeezed Squeezed Squeezed C-2 Open Production C-3 Open Production BHE WwELL TBS A-1 . . ~/3j/85 ELL SCHEMATI iI F,F.. ~¥ Form D-IOO1-A ~ :; ~.;:, , LEASE TRADING BAY STATE FIELD TRAnINr, RAY BEG~kN: 8/23/78 UNION OIL CO. REPAIR RECORD -~ ~ ._~, >;- PAGE NO. WELL NO.~_ CONTRACTOR P~ D~ILL ING COMPANY TYPE UNIT~ILWELk 860 COMPLETED: 9/2/78 ELEVATIONS: GROUND PERMIT NO. 68-27 ~$F~RIAL NO. ADL 18731 CASING HEAD COMPANY F~;GINEER W SO GRAH A 3 17 ~ TUBING HEAD .APPROVED [{~ ~=-J~- · , ~ ROTARY DRIVE BUSHING ' ) ----- / - CASIN~--.1. ~ TUBTN~.1' RECORD, I I I %/ W GRADE REMARKS SIZE DEPTH, 13 3/8" 1097' 61# J-55 Cmt'd w/1200 SX "G" Neat - Last 200 SX 2% CaC1 9'5/8" 7180' 40#, 43 5# J-55 N-80 Cmt'd w/lO00 SX 1st stage, 1000 SX 2nd Stage ', 7" 8068' 29# N-80 Cmt'd w/160 SX "G" w/CFR-2 To~ 7,')71' 3 1/2" . 9~7 9.2# PERFORm,TING RECORD DATE INTERVAL ' E,T.D. REASON PRESENT CONDITION 5/15/68 7680'-7730' 8020' DST #1 Sqz'd w/200 SX 5/17/68 7884'-7934' 8020' DST #2-3 Isolated w/B.P. @ 7650' 5/21/68 6898'-6941' 7650' DST #4-5 Sqz'd 5/23/68 6818'-6838' 6966' DST #6 Sqz'd 5/27/68 7420' 7650' WSO Sqz'd w/50 SX 5/28/68 7190' 7305' WSO Sqz'd w/50 SX 5/28~68 6970'-7020' 7305' Production Sqz'd 5/28/68 6896'-6898' 7305' Production Sqz'd 5/28/68 6941 '-6950' 7305' Production Sqz'd - : ~,~ '> -~- 5/28/68 6774'-6818' 7305' Production Sqz'd " 5/28/68 6838'-6866' 7305' Production Sqz'd 5/28/68 6760'-6768' 7305' Production Sqz'd 5/28/68 6672'-6728' 7305' Production Sqz'd , DATE I1~ z-z~RVAL HET OIL CUT GRAV. C.P. T.P. CHOICE MCF GOR 9/2/78 5540'-5585' 286 22 7% 575 590 7/64 91 318 5230' -5415' ~? '~ 5000' -5030' ~ ~, - ~~ HISTORY pRIOR TO REPAIR COMPLETION DATE: 12/21/75 - PRODUCING INT~RVA.T-,: 5000'- 5585", 6462' - 7020' .... ' '-~ ' "' : ~-': ~" ~: :: .... '":::~'~:~.~, ...... INITIAL PRODUCTION: C Zone 370/286 B/D LAST REGULAR PROD. & DATE: 6/78 "D" Zone "~" Zone 1129/69 B/D 240/332 B/D CUMULATIVE PRODUCTION' REASON FOR REPAIR: Abandon "D" Zone, Acid/solvent wash the "C" Zone, and recompl~te a~ a single "C" Zone Oil Producer DATE :"-;':,, 4,.-; :iiNi nil nF CALIF ? TRADING BA~ STATE WSL~'~O A-14 pi~D' :TRADING BAY DATE 5/28/68 5/31/68 3/16/70 3/18/70 12/2/75 12/3/75 E.T.D. INTERVAL 6600' -6642' 6510'-6526' 6462'-6502' 7438'-7472' 7490'-7508' 7516'-7584' 7436'-7472.' 7490'-7502' 7508'-7548' 7558'-7600' 6464'-6502' 6510'-6526' 6554'-6560' 6602 -6642' 6674 -6730' 6760 -6768' 6774 -6808' 6814 -6866' 6898 -6958' 6974 -6990' 6996 -7008 7012 -7016 6896 -7016 6760 -6860 6672 -6732 6554 -6562 6462 -65O2 6510 -6525' 5540'-~585' 5230'-5415' 5000'-5030' CAMERON/SHAFFER TYPE: ETD ,:-~ ' ]:REASON 7305' Production 7305' - Production 7305' "' Production 7648' Product$on 7648' Production · 7648' Production 7665' DST #7 - 7665' DST #7 7665' , DST #7 7665' DST #7 7665' Production 7665' Production 7665' Production 7665' Production 7665' Production 7665' 'Production 7665' Production 7665' Production 7665' Production 7665' Production 7665' Production 7665' Production 7050' Production 7050' , Production 7050' · Production 7050' :~ Production 7050' ,- Production 7050' Production 7050' .-,.Production NG RECORD Con t. '-'~>::':~::: . PRESENT CONDITION Sqz'd w/87 SX Cl. "G" w/~75%. D-31 Th~u, i'~":- retainer ~ 7130' .,':'~:~ .... ?;.':?Y~m~ .."Same as above ' '-': .... ~"~' ...... ~qz'd w/350SX C1 "G" w/ 75% b~-31, D-19, and .1}; D-6 thru retainer Same as above ,. " II II · '~ '11 II II II II II 11 II II II II .Sqz'd 5qz' 47-5 SD Open C-7 SD ~ :~' Open C-5 SD 7050' ".~ ?f Production 7050' ,c_-~'Production ? - -~T.L M~An ASSEMBLY , ;~ · ~.¥ ,. ....... ,~- ~,.,~**,.~.,~:~., . ..... ..' slide outlets cASnIG'H~Ai): ,,"Shaffe'r Model ~'D 12" 900 S6fie§ WP w/2-2"~, LP screwed CASING I~NGER: Shaffer 12" No~. 9'5/8"' Model KD KS '~:~x~t~":~F~'~~-~'j TUBING HEAD~'amers°n DCB 12" 3000'~ WP ILO" 'i~0"J# W'P'~/2-2~"' 5000# uP Studded TUBING HEAD TOP' 10" 5000# WP ~: ; - ~r ~ '~ ~'";:- "'~'~ %"'- - -' ~, MASTER V~J~VES: 2 - 3 1/8" bore master and 2 ea. 3'~1/8'' b~re ~swab va~i~'es 5000# studded outl ets. CHRISTMAS TREE TOP CONN.: UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET O PAGE NO. LEASE WELL NO. FIELD DATE 8/23/78 8/24/78 8/25/78 8/26/78 8/27/78 8/28/78 ETD 7050' ETD (c . plug) 13 3/8" Csg. 1097' 9 5/8" Csg. 80' Mud 66= Brin 7050'ETD (cm plug) 13 3/8" Csg. 1097' 9 5/8" Csg. 80' Mud 66# Brin 7050' ETD it plug) 13 3/8" Csg 1097' 9 5/8" Csg. 180' 77 PCF 7050' ETD (cmt plug) 13 3/8" Csg. 1 ' 9 5/8" Csg. 71 )' 77 PCF 7050' ETD (cmt plug) 13 3/8" Csg. 1 9 5/8" Csg. 71 77 PCF 7050' ETD (cmt 13 3/8" Csg. 1 9 5/8" Csg. 71 77 PCF 197' ;0' plug) 197' ~0' DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS Commence operation 12'00 noon 8/23/78. Pulled ball valves from short and long strings. Bullheaded 55 bbls of 8 ppb Dril-s w/ 6% KCL & 10 PPB Safe-Seal down L.S. Ran shifting tool and attempted to open "XA" in L.S. @+6376', tool stopped @+_6300'. Bullheaded-50 bbls 8 PPB Dril-s w/ 6% KCL & 10 PPB Safe-Seal down S.S~ (S.S. has hole in it.). R.U.W.L. & opened "XA" in S.S. @4907' Circ. down S.S. & out annulus until clean returns. Jet cut S.S. @4912'. Circ. down S.S. taking returns out annulus (well still trying to flow). Circ. & condition W.O. ft_uid to 66 PCF. Took shut in pressures as follows after circ. 66+PCF W.O. Fluid around- Shut in L.S. Press. 460psi Shut in S.S. Press. 250psi Shut in csg. Press. 250psi Perfed 2 holes in L.S.f/5990' to 5991'. Circ. W.O. fluid down L.S. taking returns out S.S. thru Swaco holding constant BHP for 1 circ. S.I.S.S. & opened annul us to Swaco. Complete full circ. out annulus w/ 66PCF W.O. fluid. ~'ook shut in pressures I.E.L.S. 125 psi, S.S. & annulus 200 PSI. Circ. & condition W.O. fluid to 74 PCF, and circulated around. Took shut in pressures, i.e.S.S., L.S and annulus +20PSI. Circ. & Cond. fluid to 77 PCF and Tircul~-L-~rd ~ro~rnd. Took shut in pressures 0 PSI. Installed B.P.V. Removed Tree. Installed & Tested BOPE. Pulled Dual 3 1/2" completion Assy. 1 it. & stuck triple PKR @ 4912'. Jet cut L.S. @ 4860'. Pulled & L.D. 327 its. of 3 1/2" TBG. R.I.H. w/ 3 1/2" grapple & engage fish. Jarred fish loose w/ 175 M#. Pulled fish up hole 18'. R.U. to circ. BTMS up. Finished Circ. BTMS up. Pooh & rec. Fish. (Triple PKR & 1 1/2" dip tube String & 2 7/8" L.S. below PKR.) NOTE' BTM 2 its. 1 1/2" Dip Tube full of san & BTM 2 its. - of 2 7/8" ~e~e scaled up. R.I.H., w/8 1/2". bit & 9 5/8" scraper & cleaned out to 6360' POOIi R.I.H. w/Baker Retrievamatic & set @ 4990'. ll/1/7 U;I!C:I OIL CS CA, LIFC?CIIA SkF,CT D PAG: LS;CE ¥ ELL FIELD DATE 10 11 8/29/78 8/30/78 8/31/78 9/1/78 9/2/78 6350' ETD (ct 13 3/8" Csg. 9 5/8" Csg. 77 PCF Brine 6300' ETD (c~ 13 3/8" Csg. 9 5/8" Csg. 66 PCF Brine 6300' ETD 13 3/8" Csg 9 5/8" Csg 7 80 PCF Brine 6300' ETD 13 3/8"C.109; 9 5/8"C. 718( 6300' ETD 13 3/8" C. 9 5/8" C.718( 7"L. 7071', DETA';,_~ ° OF GPE?2~Ti,~,S, DESCRIPTIC~tS 2_, RESULTS ~t ret.) 1097' 180' t plug) 1097' 180' 097' 80' 97' -8068' Tested 9 5/8" Csg. F/4990' to surface @ 3000 PSI - OK. Released PKR & POOH set cmt. ret. @ 6350'. Tested surface Equip. @ 4000 psi Broke down perfs, f/7020' to 6462' w/2300 psi. Mixed & Pumped 350 sxs C1 "G" w/ .75% D-31, .5% D-19, & .1% D-6, 236 sxs below ret. left 8 sxs on top of ret. Rev. out 106 sxs. Final press. of 3000 psi. C.I.P. @09:45 hrs. 8/29/78. POOH RIH w/Baker Mod. "B" Circ. Washier to 5602' & blanked tool - OK. Pulled up & located perfs @ 5585'. Opened circ. ports & spotted acid to tool. Closed circ. port & hydril. Washed perfs f/5585' to 5540' with 20 gal/FT. 5% HCL w/7% mutual solvent Bleed press, off cs8. Opened hydril. Blanked tool below perfs @ 5420'. Pulled up & located perfs @ 5415'. Opened circ. ports @ spotted acid to tool. Closed Hydril & ports. Acid/Solvent washed perfs from 5415' to 5230' w/ 20 gal/ft. 5% HCL w/ 7% mutual solvent. Bleed press off csg. opened hydril, pulled tool up to 5035' & blanked tool. Located perfs @ 5030' & opened circ. ports & spotted acid to tool. Closed ports & hydril. Acid/Solvent washed perfs f/5030' to 5000' w/20 gal/ft, of 5% HCL 7% mutual solvent. Blanked tool ~bove perfs @ 5000'. Opened circ. ports circ. out gas mud. (Note: Mud cut back to 66 PCF f/76PCF due to acid contamination) Mixed 110 bbls of Mud to 73 PCF w/salt. Pumped 80 bbls. down D.P. & Circ. stopped. RIH w/Perf Gun down D.P. & tagged fill @+4655' (+__345' above tool) Shot I 5 holes @+4625'. Still unable to circ. POOH w/gun. RIH w/Perf gqn & shot 5 holes @4621'. Established circ. Cont. cird. well w/FIW. Shipped acid contaminated mud to Production at beach. Circ. & Cond. W.O. fluid to + 80 PCF to kill well. (S.I.C.P. + 440 PSI w/63 1/2 PCF FIW in hole.) Killed well w/80 pcf CaC1. fluid. POOH w/Baker wash too. Ran Baker Mod. "D" ~rod. pkr. and set-@ 4890' for "'C" zone completion. Ran 3 1/2" prod. tubing - pkr failed to. test. POOH w/ 3 1/2" prod. tbg. Ran Baker Model "F-i" prod. pkr. and set @ 4860' W.L.M. Reran 3 1/2" prod. tubing and located on pkr. @ 4860' W.L.M. Removed BOPE and installed x-mas tree an~ tested to 5000 . psi - OK. Displaced well w/FIW. Put well on production. Released rig @ 12:00 PM 9/2/78. Prod. Test: (Flowing well) GROSS NET CUT CHOKE 370 286 22.7% 17/64 FM. GAS TBG/CSG. PRESS. 91MCF/D 590/575 SHEET D P^ E UHIC!I OIL CCi iN CF CALIFOPCIIA ,ELL LEASE TRADING BAY STATE ~'~LL I:O, A-14 WO FIELD TRADING BAY FIELD ~ATE ETD JTS 15 28 44 64 8 161 DETAILS OF OPEP~TIONS, DESCRIPTiG~IS & RESULTS TUBING DETAIL DESCRIPTION LENGTH BOTTOM 3 1/2" Buttress Mule Shoe 3 1/2" 9.2# N-80 Buttress Tbg. 3 1/2" Otis "X" Nipple 3 1/2" 9.2# N-80 Butt. Tbg. 3 1/2" Butt X 4 1/2" Butt ×0 4 1/2" Seal Assembly Locator Sub (Top of Packer @ 4860') 4 1/2" Butt. × 3 1/2" Butt. ×0 3 1/2" 9.2# N-80 PUP Jt. 3 1/2" 9.2# N-80 PUP Jr. 3 1/2" Otis "×A" Sleeve 3 1/2" 9.2# N-80 PUP Jt. 3 1/2" 9.2# N-80 PUP Jt. 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt. Tb§. 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt. Tbg. 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt. Tbg. 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt. Tbg. 3 1/2" Otis Ball Valve 3 1/2" 9.2# N-80 Butt. Tbg. 3 1/2" 9.2# N-80 PUP Jt. 3 1/2" Butt. X 3 1/2" 8 Rd ×0 Cameron Hanger 3 1/2"8 Rd Btm X 3 1/2" 8 Rd top. E1 evati on .72 29.46 1.38 28.52 1 .ll 16.94 .94 1.10 6.11 8.19 4.03 8.08 8.10 6.54 443.65 6.52 834.11 6.47 1321.33 6.54 1908.53 2.42 239.1 5 8.12 .61 1.00 37.40' 4937.07 4936.35 4906.89 4905.~1 4876.99 4875.88 4858.94 4858.00 4856.90 4850.79 4842.60 4838.57 483O.49 4822.39 4815.85 4372.20 4365.68 3531.57 3525.10 2203.77 2197.23 288.70 286.28 47.13 39.01 38.40 37.40' joints of 3 1/2" N-80 Buttress Tb§. (9.2#) TOP 4936.35 4906.89 4905.51 4876.99 4875.88 4858.94 4858.00 4856.90 4850.79 4842.60 4838.57 4830.49 4822.39 4815.85 4372.20 4365.68 3531.57 3525.10 2203.77 2197.23 288.70 286.28 47.13 39.01 38.40 37.40 00' · i · I ii iiii I I ~ · i ii i _ I I i i I - - ......... TUBING STRING 1 3 1/2" Otis Ball Valve 2.760" ID, 4.75" O.D. @286. 2 3 1/2" Camco gas lift mandrel @219 7.23' 3 3 1/2" Camco gas lift mandrel @3525.10' 4 3 1/2" Camco gas lift mandrel @4365.68' 5 3 1/2" Camco gas lift mandrel @481 5.85' 6 3 1/2" Otis "XA" Sleeve 2.75" I.D., 4.28" O.D. @ 4838.57' · 7 4 1/2" Butt. X 3 1/2" Butt. X-over @4856.90' 8 4 1/2" Seal assembly and locator sub @4858.00' 9 9 5/8" X 3 1/2" Baker Model F-1 Prod. Packer @4860' l0 3 1/2" Butt. X 4 1/2" Butt X-over @4875.88' ll 3 1/2" Otis "X" Nipple @4905.88' 8 12 3 1/2" Butt. Mule Shoe @4936.35' 13 9 5/8" Cement Retainer @6350' L o , I ii i i i ii i WELL SCHEMATIC TRADING BAY STATE A-14 W.O. Starting Oate - 8/23/78 Completion Date - 9/2/7 co ?^ Y ..... D II~WN ~ AH"D. DA'TI~. ._ [i L " Spudded =omp,0 0d UNION OIL COMPANY OF CALIFORNIA t ; Log, Pwr { Co. Co. Rig Direct'l W.L. Cont Fuel Trans Trans. l,abor! Prod. Prod., Rtg Daily Accum. Dab, Op~'ration l.oc. Cont. glts Mud Cosinq Cement Drill. Perf, Lab Rentols Wtr. Pers Mat, Stim, ~Sup~ gquip, Foc, Fishing .Re~. Misc. Total Toro[ , , , , , , . ,,. .,, , ,,,,,, ., ,,, , , . ,,,, , =,, .... , ., . , ., ,,, . . , ,,.. , .. , , . , , , , , , ~ ,,. , ,, ~ ,,.,,, ,,, , , , ,, ..... ~ , ,. . , , , ..... ,, ,,. , , , , , ,,, , , , , , , ,, ..... .... , ,. , , , ,., , . . ,,, ,,. ,. , , , ,, ., . ,, , ,. , , , ,,, , ,, .,, ,, .., , , ~ . , , .... , , , , ., . , , ,, .... ~ , ., ,. . , ,, , . ,. ,,,, ,. ,,,, , , , I .,.i .... . ,, ,. ,, ,,., i ................. ---£-0 N~ p L-E T-I 0 N R-E P 0 R T - FAuE ...... UNION...OI-L CO.~PAN-~ ..... T-RADING--BAY-$T/kTE A !4-~ COOK IalLET---KENAI BOROUGH "~EASLJR= ' ~:-- - D--E-V I .A l--I O-F4-_- - ..D ....COL, R .... - DEPTH LENGTH ANGLE DIRECTION A,N' uU,~T V.D C---O U R- $ ~ E -- - -- .... - - ~-T--O T A EPTH LATITUDE DEPARTURL V,D~PTH LAFITUDm 274, 2C, 1 20' S 74 '4 0,55 2~.99 0,15 ....... ~3'?, 63, ........4---%0.'---S-~6 N -4,57 ........... 62.53 .... 1,86 400, 63, 6 45' S 64 W 7,49 62.56 3,24 .... 461,¥-%~ .... 6i,---I0--i-53 .... S-64--~ ..... 10,85 ............ 60,02 ...... 4,75 /'~24,- 63, 12 45' S 61W 13,90 61.44 6.74 ~-- 6~! ...... ii7.- 16-15' .... S_.SL W. 32.-73 ..... !-12,32 .... 20,6u 733, 92, 19 O' S 50 W 29.95 86.98 i9.25 ........ 861. ...... 128..--2g-.3C-'__£_5~0_~ ....... ~+s.gB ............. !18.25- 31.48 9a6, 125. 26 O' S 55 W ...... o F1 -. liOO. llao .... ~.. 0-- -S--58 .... W ...... 1209, I0~. 31 O' S 57 W _- 1357, ........ i48, ..... 21 .... 30_' ._$_57__W 1620, 263, ~2 O' S 56 W __ 2_022, ...... 402~o.. ~3 -1- -3 0- L__ S -55--~ ....... 2-12.65 .......... 347 2289, 262, 30 45' S 54 W 133,95 225 ....... 2530, ........ 241, .... 30.30!__ S_5_5_W ...... i22,31 29~B, 408, 30 0~ S 55 W 209,99 953 .... 302!, ..... 83,_.30 __.0' S_ 56_W ........ 41,49 ............. 71 9245, 224. 90 90~ S 52 W 119.68 193 ......... 1!72, .TZ,__J!__OA__S_52__W ........ 39_,65 ............. 66 ........ J5~. ~0~_~4.___~i___o ___ s_5o w ...... 48.41 1459, 94, 32 0 ...... IPS3, 94,_ __32 0 !6~7, 94, 31 45 ....... iZ4!, ........... ga.-~3L-3O 1835. 94. 31 30 - -L9-29, ..... 04,--31- 15~'- --S-50 w 2023. 94, 3! O' S 50 W ....... 2117. ...... 94, 30 45; S 51 W 2211. 94, 30 30I S 51 W 54,79 112.34 31.42 --56.99 ............. 98,72 ...... 30.20 56,13 93.43 30,57 77,32 ........ 126.19 ~ _ 42.11 199.36 223.03 77.93 S 50 W 49.~I 79 ~ S-50 7/ .......... 49.81 .... 79 S 5t W 49,46 79 ..... S~ 5i-w ....... 40.11 ............ 80 S 50 W 49,1i ~0 48.76 .... 80 48.41 80 48,06_ _ 80 '47,70 80 .02 ...... 121.97 · 16 78,73 · 65 __ 70.15 · 33 117.00 ,88 _.~ 23,20 · CO 69,99 · 00 ....... 24,41. ~57 30,46 · 57 ..... 31,ii_ · 71 32.01 · 71 32.01 · 93 31.12 · 14 ..... 30.90 · 14 31,57 .36 -- 31.34 · 57 31.11 · 7d ___ 30.24 · 99 30.02 L DLPA:<T U,<ta S 0.53 W 273.99 O.ib -S--- 4.18 W- - 336,82 .... Z.O1 S 6.05 W 39~.39 5.26 S--- 9.75-W .... 459.41-- 10.o2 S 12.16 W 520.~6 16.'/0 S- 25,44 W _ 633-id - - 37.36 S 22.94 W 720.17 56.61 S ...... 37.52 W 830.43. Sd.lO S 44.88 W 950.78 119.D3 S- 48.33 W .... i049.b0 149.73 S 47.06 W 1142.94 1UO.31 81 ,-'- 119 164 2!2 S 64.8b W_ . 1269.13-- 222.43 S S !15.b4 W 1492.16 300.36 S -'43') S ---174.i9- W ~839.19 .... 422.34 S S 108.37 W 2064.3D bOl.o7 S ~ 722 S 100.!9 W 2272.00 bTl.g~ S 167.1o W 262b.34 6d8,24 S 9~9 S 34.40 W __ 2697.2~__ 711,4D S 1024 S ~9.bU W 289U.23 S 37.62 W 119~.1i S 37.0~ ~ 127b.6~ S 38.15 W 1356.40 S 38.Ib W 1430.12 38.44 ,,.i 15!6.0b 38.i6- ;q !b~G.gO -- 37.62 W 167o.35 37'.~ W - 1766.71 - 37.08 'a' 1~37.2~ 37.35 W !91~.07 37.07 W 199~.06 7uI.44 S ZO4.b2 S Z~l 267.60 S jbo 299.0d S ~ 330.80 S 432 424.03 S 546 45b. Tb S ~ Omi 516.02 S ob/ .... W E--L- L .... C-.-O -.tI--P--L--E -T--I- O- N- -- R E P~~ 0 COMPANY___ T. RADING._BAY__ST/WTE A-,14 COOK i,NLET__ ' ._ UN ! O.~l _01L - D_.E_¥__I A_I__i__D_ M. - .... ANGLE D I R F. C T I 0',', A,~¥; 0 U,'' ' T ......... C -.-0 U R V,DEPTH LATITUDE 2305, 94, 30 30' S 51 W 47~70 80,99 3¢).02 S 2399, ...... 94,-_ 30__153.. _ S.__51__>L ...... 47,35 .......... 81,20 . .29,80 S 24q3, 94, 30 15' S 51 W 47.35 81.20 29,80 S 258._7, ....... 94,--30 ....... 0.~, .S_50__W .......... 46,99 ............ ~!.40----.~.0,21 S 2681. 94, 30 0~ S 50 W 46.99 81.40 30.21 S r~ZT-5,-Z-~:~---_ 94°___30 .... 0!--S__50_W ......... 46,.99 .......... 81.40 ...... B0,21_S .~69, 25"~7 94. 30 0' S 50 W 46.99 81.40 30.21 S S S 2953, 3057, _3"' ,,i., ~2~5, 3339 , ....... ~433, 94.. 2q.45'__S_51__W ........... 46,64 .... 81,61 94. 29 ~5' S 50 W 46.6a 8i,61 29.9d 94 .... 3~_.152 .... S_~O._?~ ......... b7,35 ............. U!,20 ..... 94, 30 30' S 52 W 47,70 80,99 29,37 94, _-ZO._30_L__S_. 51_W ......... 47,70 80,99 _._ 30,02 94. 31 0' S 52 W a8.41 80.57 29.E0 9a. ......32__ _~[_._~__52_W ........ 49,8] 79,7! ....... 30.66 94, 33 15' S 52 W 51.53 78.61 31.73 3527, 3621, R T ............ KENAI_ UORCUGH S- E .... - - - T .... O-T A b DEPA,<TUI-<E V,DL~' l'tt LAI 1 i OIDL 37.07 W 36.80 W -36,00 W 36.00 W ---36.G0 W 36.00 ~ 36.24 W___ 35.73 W 20bO.Cb ..... 216L..2~__ Z24Z,45 ...... 240b.~7 ---2486.67 - 250d,08 2649.69 2731,30 S _36.27 w .... 2~12,~0.. S 37.59 N 2~'93.4~ S ......37.07. N _ 2974.49 S 38.15 d b05b.d6 S, __ 39.25_ W _ 3134.7~ S 40.61 ',V 3213.39 b46.04 S 694.07 ,. b75.o4 S 655.b6 666.07 S 696.~ S- d7U.2m 720.4~ 765,d4 S 789.~ S V 9~4.Z7 dlo.ZT,S. 9UD.4 / S q--11.0~.36 936.14 S_ 1172.o2 957.d7 S 1213.2j ...... 3715, ...... 3809, ___ ~903, 39q7, _ _~Ogl. 94, 3'3 O' S 52 W __eL4._, .... 3_.7__3_D_' S 52 W 94, 37 45' S 51 ".q ........ _94 ,__ 37._1_5.'_. S__ 5 I_._~.I ........ ._.53,91 ............. 77,00 _ 33.19_5.. 57,87 74,07 35,62 51.22______ ........ 74,57 ..... 35.Z~ 57.54 74.32 36.21 ..5_6.~_9 ........... 74.82 ....... 35,~0 55.89 74,82 35,80 fi6,5Z_~ 7_5.07 ....... 3~,U2 56.24 7~.31 33,b4 'Zb.5~ 34.42 76.04 34.01 4561, 94, 36 0~ S 52 W 55.25 465~, ~a, 36 15~ $ 53_w ............ ,'_ .... 55,58 ....... Z5-~O .... 474g, 94, 36 45~ S 54 W 56,24 75,31 ._ ~a3., .............. 94, ....... 3.Z._ G'_.. S_5~2 $~ ........... 5Ao57 ........ 75,07_. q300, 55, 28 45' S 62 W 26,45 48,21 ---340r~, .... 1_00,. _2E_._O' _._S__2i 5'~ ........ 4~o9A_ 3500, 100, 31 15' S 73 ~i 51,87 85,49 33,45 33.05 _29,97 12.41 15.28__ 15,16 S_ __ 44.~7 W S 44.91 ~! S 44 · 06 W S 44,'39 W S 45.50 W S.. 47,9; ,V S 23.35 '^' S 44.3~5 'd S 49,61 W 3290.39 --10Ji.0u 336N.46 1030.09 _34JV.04_ 1071.9g 3513.36 1108.14 35d~.19 11~3.94 3663.01 I179. lb 373:~.Uo ldl4.bd 3o13.40 i~40,43 ~96b.01 1~16.~7 40,0,8d 13bo.32 41io.13 4191.=I g941./d 31£).49 12DS.TZ .... I~0i.02 ^ ~9!,!4 14/9.57 ,~ ipd,'+, +F-E L -L- --C-O-M--P L E T I O N. 3500. 3700 o 38.00. I00. 39 0' 3900. a000. 100. 37 0' ~ nO. ..... iO0. .... 36-45 -00.d'''''' 100. 35 30' REPORT ......... UNIO,N--QIL-_COMPA,NY__TRADING_BAY___STAT£ A-14 . COO;< --~"F-ASLJRFD.__CQ[JR..SF __-_...- D F.--V--.I-A~ -T-- I-.-O- N --- - - - '- C-- O - U ')FPTH L£'~]GTrd A.~'GLE I)IRFCTION A,vou~.T V.D~iPTH LATITUDE lO0, 3 5' S 73 W 57.71 81.66 16.87 S 100, .... $8 45' -S--73.W ........ 62,59 ....... 77,98 18.~0 S S 73 W 62.93 77.7! 18.39 S .... 5-.~3_~ ..... 62..25 .......... 78.26 ...... !8.20- S S 74 W 60.18 79.85 16.58 S ~S--73-W ....... 59.83 .......... 80.12- 17.49 $ S 74 W 59.4~ 80.3~ 16.39 S .... 5300. 5600. S _5500. ........ S 5600. 100° 38 O' S 81W 61.55 )0. lO(). 3~ O' S q2 W 61.55 6000. lO0° 44 15' S 83 W 69.77 .... 5100. .... 100.___4~ O' ._S 82 '/ 71.93 6200. lOC). 45 30' S 83 W 71.32 63~0. i0~, . 6400. lO0. 44 15' S 83 ~'7 69.77 ---65C0, ..... 10o° .... 43-15!_._S_.B4_W ....... 66.51 6581, 81. 41 30' S 87 W 53,67 430.9. ..... 100._. 35-45' .... S 7a-.W .......... 58.62 ................ 8,1.15 . 16.10 S /.400, 100, 35 z~5' S 75 W 58,42 81,15 15,12 S 4500. ....... ID0._ 35-45! .... S 7N--W ........ 5g..42 .......... ~1.15 -.- 15.12 S ~600. 100. 35 45' S 75 W 58.42 81.15 15.12 S ,70.~.. -10D.~_37__4~L_S 76 ~ .......... 61.22 -Y19.06 ..... 14.81 4800. !00. 41 0~ S 76 W 65.60 75.47 15.87 S 4900, ..... i0/},._ 44_451 S 76 W ...... 70,aO ........ 71,01 17,03 5000, 100, 4~ O~ S 77 W 59,~8 71.93 15,62 5100, ........ 10-0,~_~3. -~-' .... S--78~M ........ 68,19 ................ 7-3.1-3 ..... 14,17- 5200. ZOO. OZ ~5' S 78 W 66.58 7~.60 13.~4 75.47_ 13.64 S . 75.75 i3.57 S 77.71 12.00 S 78.b0 9.63 S 79.33 ..... 8.47 S 7d ,80 8,56 S 76.U4 9,03 S 71.63 8.50 S 69.46_ 10.01 S 7,3.09 8.69 S Zi,O1 ~ 8.b7_ S~ 71.63 8,50 S 72.83 . 7.16 S 60,66 2,80 S lO0. .... 41__0' 78 W ....... 65.60 100, 40 45~ 78 W 65,27 100. __39._ O~ 79 W 62,93._ INLET -KE,NA! P, OROI. JGH R S-.F - - - DEPAHTURE 55,19 w 59,85 W 60.!~ W --59.53 W -- 57.85 57,~1 ,~ -- 57-17 W 56.16 W 56,43 'W 56.43 '.' 56.43 W 59.40 W _ 63.65 W 6d.bl_W 67,6~ W 66,70 -W .... 65,13 W 64.17 63,84 61.77 ',,! 60.80 60.28 ,'.' 60 · 96 W 6 4. 'J 1 W 69.2b '.',' 7i.Z~ '.V 70 · 79 W 69 · g 7 ..: 69.2b 58.14 W 53,59 W PA~ j -526b.4b ';337.11 5470.61 - - - T - 0 T A L .... 319;.Io 3275.14 9/.3.68 S 1/90.54 3392,¢~0 942.0o S 13Pu.7~ ... 3431.1g - 960.gd b 3510.9~t 970.87 S <146S.11 ,, 3591.11 V~4.3o S 3671.49 1010. /6 5 375g.bb 1020.o6 S loeb.bO ..'___ 3833.81 1041.9~ S 169D.Io 3916.97 --lOb7.11 S x 1 lbi.p~ .: 407~.19 1057.04 b 1~67.57 ,',, ._ 4150.66 1iU2.91 42Z1.~o lll~j.~j4 S I99'J.j4 '/; 4293.6g 1135.57 S 4b16.BJ il /7.23 S ZZ63.0., 4592.5~ 4670.30 iZoz.ui S K230o.6~ .. 4R2U.44 122~.91 4907,24 lZz9.48 S 2~70. ~2 .. oOO4.~]l 1247.03 3 ~2704.2V .. 91Z4,37 lZ~7.04 5194.4o iZ(~b.-/5 b 2e4~,.;2 ,, .................~. ................. W 2 L_..L_ -C 0 .M_,._P__L 5---T I O._~N _it E-P-O.R UNION OIL COMPANY ._TRADI~]'~G _BAY_ST_ATE A-14 COOK INLET KENAI BO?~OUGft _Y£ASURED ..... _fOURSE_ _r .=_D.£._V J. A Z.. !. DrPTH LFX,GTH ANGLF l)I r~ECTION 5577, '-76, 6850, .... 173,.._ 37 ..... 0 7030, 180. 37 0 _7222 ...... 19~..._ 36 _ 0 7496. 268. 36 0 -z7270 ........... 231,___Z3_ ~ 0 80. 52, 71. 33 , ........ 62,__. 3 '' 6~, 3 70~, 69 , .... 4 72. 102. 4 _ .343, .55, 4 .0 _N._ - C~.O .... U R . 5__ E - - - __ _- - - AxlOU,,~ T V.DEPTH LATITUDE DgPARTURk .......... -=--,-- 104.11 ............ 13~.15 ..... 3.6~ S ' S 90 W 108.32 143.75 ' "" ~9_ W .... i1b,35 150.lA ' ,N 82 W 157.52 216.81 ' .... N_87 _W ...... 125.81 ............. 193,73 ' ;~ 85 t,/ lll.lb 18~.69 ' N 89 ' _,, ...... 30,56 ....... 42,06 ' S 85 W 5a,76 72.67 O,OO .... ?.03. 5.49 9.6~ __ 0.53 4.77 .... 2.66 2.Z7 2.36 2.37 ..... 3 · 95 0.63 37 0 8~ _ _0.' ..... S 8 &._ h' ....... 38,_17 ................ 48,~5 9 45' S 87 l; 43,4~ 52.28 !___0' __S 87__W ........ 4_5.Z6 .......... .52.0,7 1 45' S 88 W 67.91 76.09 i _3_0_' .....S__8_9_[z,' _ .... 227,27_ ........ ~56,89 1 30, S 89 W 36;44 41,19 73 ._. 74 75 76 qO70, 59.39 W i04.05 W 108,32 116,:36 lq7 125 110.72 30.56 54.55 :38.07 W 43 .42 '/,/ 45.20 W. 67.87 227.24 W_. 36.43 W -- PAGL-- 4 T .o T A L V.DLPTH LAT i TOPi: b546.00 i294.86 S --. W W W 6204,92 a~ -- 639N.ob /! 6587.3b W __ 6030.16 W 6102.U4 5684-,16----1298.49 S 'J27d.64 ,'.' 5~27,92 i29U.49 S ~ 3370.9 / ,,' 6/03.98 _ 6266.0b 6332,15 65d9,04 6630.23 S 7:1._-__5_8' W ~_ _ 1290,96 1274 .O9 129b,?Z 1300.o9 lJob.63 $ 1308,00 S _.3/07.15 1310.J7 $ 5 S 3052.70 ., S ~3ddV.!; ,', S 3b~.44 ,', ' , , . ~ ,,i~ ~ ~ ' '~'' ''1 I~ '- ~ ~"t' ~ ~.l~ ~ '''~ '~ " ~I , _'_,-~i ~ '~I''" ' L-~ ~t_~ ~._~ ~.I --~,~ ~ -~ - '' ~ ~ ' ' ~, ~ t''~ ' I,~ ' , * , 'r- r' L ......... ' .... ' ~ ~ ' ~' ~ ~ ~ ~ ~ ~ ' ~ ' ' - ~ ~ -~ ,/~'~,~ -'~ -'~ ', ~T · ~. 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'~.,i+ ~'"+'~1~..~'"'~'+'*+'*'i' "f~k;~:&::;~;..;{~ ~''~'i,~'~, it~] ~Form No REV 9-30-6~ STATE OF ALASKA SUB~rr OiL AND GAS CONSERVATION COMMITT,,IJJ~ #IONT'HLY REPORT OF DRII!~~ ~,~c~O~ AND WOR'KOVER OPERATIONS I OIL ~ GA8 [] NA/~IE OF OPER2~TOR Union 0il Company of California A~)~R~:SS o~ oP~TO~ 507 W. Northern Lights Blvd., ~chorage, Alaska LOCA~ON O'F W~ ~ 1601'N & 5?0'W from SE corner Section 4, T9N, R13W, SM 99503 APl NUAiERICA. L CODE 50-133-20099 LEASE DESIGNAIION A\'D SElqlAL NO ADL-18731 7 IF INDI-~N, %LO'i I ~'.~- OR TRIBE NA.AIE 8 I/NIT,F.~TLM OR LEASE NAAIE TradinJl; Bay State 9 %VEL/. NO A-14 (14-4) 10 FIET.V~ AND POOL OR WILDCAT .Tradtn~ Bay-Middle Kenai-Hemlock i1 SEC, ~, R, A-i i BOTTO.%i HOL~ OB.rECTIVE ) Section 4, T9N, R13W, SM 12 PERMIT NO 68-27 13 REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGES IN HOLE SIZE, CASING AND CEMEN~NG JOBS INCLUDING DEPTH SET ~N]) VOLI/NIF_~ USED, pF~v. FORATIONS, TESTS A/ND I{ESULTS FISHING JO~, JLrBIK ~ HOLE AA~D SIDE-/-P. ACKED HOLE AND A_NY OTHE!{ SIGNIFICANT CIiA~ ~ HOL~ CO1%rDITIONS TRADING BAY STATE A-14 (14-4)~ MAY 1968 Page 3 Perforated four 1/2" holes @ 7190' (below 9-5/8 shoe in 7" liner). Ran in w/RTTS tool, set packer @ 7056'. Squeezed liner lap for WS0 w/50 sx c~nt. Pulled out. Cleaned out cement in 9-5/8" and 7" liner. Circulated clean @ BP 7650'. Ran dual 2-7/8" N-80 tubing strings complete with gas lift mandrels. Set Baker F-1 7" packer @ 7368' and Baker dual 9-5/~" packer @ 6401'. Removed BOE. Installed Cameron Christmas tree. Displaced salt water w/~le~et oil. Set both packers - OK. Opened Kenai zone through short string. Rigged up Lane Wells and perforated Hemlock zone through 2-7/8" tubing: 7584-7544; 7490-7508; 7516-7584. Now attempting to produce long string with gas lift. RIG RELEASED 11:59 PM 6/1/68 hereby cert~/y~_ hefO~ m true and correct Dist. Drillins Superintendent s~sw~ _ m ~ v,.~ June 4 ~ 1968 NOTE--Report on th~form is reqmred for each calendar month, regardless of the status of operat,ons, anO must ~ fllea ,n duphcate w~th the Dw~s~on of Mme~l& Minerals by the 15th of the succeeding month, unless othe~se dtrected · -Form No. P--4 REV. 9-30-6'; STATE OF ALASKA O~L AND GAS CONSERVATION COMMITTEE SUBMIT IN DEPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS om ~ oas [-~ WELL WELL OTHER 2, NA/~IE OF OP~P,.~TOR Union Oil Company of California $ ADDRESS OF OPEP~ATOR 507 Id. Northern Lil~hts Blvd., Anchorage, Alaska 99503 4 LOCATION OF WELL 1601'N & 570'W from SE corner Section 4, T9N, R13W, SM '50-133-20099 ANCHORAGE ADL-18731 IF INDIAN, ALOTTEE OR TRIBE NA.%IE 8. U~'IT,F.~P~M OR LEASE N.~ME Trading Bay State 9. %VELL NO A-14 (14-4) 10 FIELD ~ND POOL, OR WILDCAT Trading Bay-Middle Kenai-Hemlock 11 SEC, T., R, M, ~BO'I~FOM HOLE OBJECTIVE ) Section 4, T9N, RlgW, SM 12. P~R2V[IT NO 68-27 13 REPORT TOTAL DE]PTH AT END OF MONqTH, CYL~%TGES IN HOLE SI~.E, CASING AND CF-LMENTING JOES INCLUDING DEPTH SET AND VOLUIVIES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS. JUNK IN HOLE AND SIDE-TI:LACKED HOLE AND A_NY OTHER SIGNIFICANT Ci-IA. NGF~ IN HOL~ CONDITIONS. TRADING BAY STATE A-14 (14-4), MAY 1968 Drilled 12-1/4" directional hole to 7971'. Could not pull out of hole, backed off @ 7507' leaving 464' tools in hole. Cleaned out to top of fish~ screwed into fish and jarred, unable to recover. Ran Free Point indicator, backed off fish @ 7545'. Ran Schlumberger DIL, HRD, FDC-GR and SNP logs. Ran in with open end drill pipe to 7540'. Plugged 12-1/4" hole w/350 sx cmt and 45 sx sand. Top of plug 7089'. Trimmed cement plug to 7220'. Ran 9-5/8" casing and cemented thru shoe @ 7180' w/1000 sx and thru DV @ 4350' w/1000 sx. Cleaned out to 7220' - top of cmt plug. Redrilled 8-1/2" hole to 797!', sidetracking fish. Drilled to 8015'. Ran Schlumberger DIL, HRD, FDC-GR, SNP logs and sidewall samples. Drilled to 8070'TD. Ran 23 joints 7" 29# buttress casing on TIW liner hanger. Cemented w/160 sx thru shoe @ 8068', with top of liner hanger @ 7071'. Found top of cement @ 7061'. Cleaned out cement to 7078', 7' inside liner. Circulated clean @ 8020'; pressure tested liner lap to 1800# - OK. Changed over to 68.5# weighted salt water. Ran G-R Correlation and Bond logs. Perforated w/4 spf 7680-7730'. Set HOWCO DST tool @ 7630' w/tail to 7643' - 500# gas cushion. Open 15 mins IF, closed tool 90 min ISI, open for 8 hour flow, closed for 8 hr FSI. Pulled out. DST #1: Recovered 4630' salt water (71 bbls), 32,000 ppm C1 (hole fluid -weighted salt water 85,000 ppm C1). Salt water slightly gas cut - no oil shows). IHP 3034#, IF (1) 1663#, FF (1) 2119#, ISI 2802#, IF (2) 1891#, FF (2) 2802#, FSI 2802#, FHP 3034#. Ran in w/RTTS tool, packer @ 7585'. Squeeze cemented perfs 7680-7730 w/200 sx cmt. Found top of cmt. @ 7579' Drilled cement 7579-7735'. Circ. clean @ 8020'. Pulled out. Perforated 7" liner 7884-7934' Hemlock Zone. DST #2: Ran in w/HOWCO DST tools, set packer @ 7831'. Annulus fluid dropped. Reset @ 7600' - packer held OK. Fluid communication between perfs 7884-7934' and sqz perfs 7680-7730'. Pulled out of hole. Set HOWCO bridge plug between perfs @ 7780'. RI w/RTTS - set @ 7600'. Resqueezed perfs 7680-7730' w/100 sx cmt. Found top cmt @ 7582', cleaned out to 7780'. Pressure tested OK. Cleaned out BP and circulated clean @ 8020'. Pulled out. (over) Form No ~'v..~-3o-6~ STATE O'F ALASKA SUBMIT IN DEPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS AP1 NUA[ERICAL CODE 50-133-20099 LEASE DESiG.X,'ATION AND SERIAL NO ADL-18731 WELL WELL OTHER 2. NAlViE OF OPERATOR Union 0il Company of California 3' ADDRESS OF OPER3~TOR 507 W. Northern Lights Blvd, Anchor~g~ Alaska 4 L4DCATION OF W~J-J~ 1601'N & 570'W from SE corner Section 4, T9N, R13W, SM. 8. I/N'IT,F.~I:~¥I OR LEASE N.~ME Tradin~ Bay State 9, WELL NO A-14 (14-4) 10 FID ~-ND POOL. OR WILDCAT Trading Bay-Middle Kenai-Hemlock 11. SEC, T., R, M. (BO/~FOM HOL~g OBJECTlXrE~ Section 4, T9N, R13W~ SM 12 PERMIT NO 68-27 13. REPORT TOTAL DE~TH AT END OF MONTH, CHJ~NGES IN HOLE SI~.E, CASING A_NqD CE1ViENTING JOES INCLUDING DEPTH SET A_N-D VOLLrMES USED, PERFORATIONS. TESTS A_N-D I%ESULTS, FISHING JOB~, JLrNK LN HOLE A_ND SIDE-TI~ACgJED HOLE AND ANY OTHER SIGNIFICANT ~GES IN HOL~ CONT)ITIONS, TRADING BAY STATE A-14 (14-4), APRIL 1968 SPUDDED 3:00 PM 4/4/68 Drilled to 1100' Cemented 13-3/8" casing @ 1097' w/1200 sacks. Drilled to 4860'. Pan Sperry Sun Multishot Survey, found previous surveys incorrect and hole not on course. Plugged w/200 sacks sand cement. Polished plug to 3217'. Redrilled to 4860' and drilled to 7653'. Now drilling. RECEIVED MAY ? 1968 DIVISION OF MINES & MINERAI~ ANCHORAGE i';~'~ //IlHIJ Dist. Drilling Superintendent 5/6/68 S~G~ /~f,~ ,~, NOTE--Report on this/orm' is reqmred for each calendar month, regardless of the status of operations, and must be hied in duplicate with the Division of Mine~& Minerals by the 15th of the succeeding month, unless othe~se directed. Robert T Andersor' Union Oil Comp/""~.of Callfor 2805 Denall Street, Anchorage Ai ~',~,,,, ',4q533 Telephone (907) 277-1481 April 12, 1968 Director D]xlsion of Lands 344 Sixth Avenue Anchorage, Alaska 99501 WEST FORELAND AREA State of Alaska ADL 18731, WFore-6 - Dear Sir' In accordance with the provisions of the captioned ()il and Gas Lease, Trading Bay State A-14 (14-4) drilling from th~ blonopod Platform located on State Lease ADL 18731 was spudded on April 4, 1968. The proposed bottom hole of said well is approximately 260' North and 630' East from the Southwest corner of Section 4, T9N, R13W, S.M. on captioned ]ease. Very truly yours, ._../ -/' Robert T. Anderson RECEIVED Hr. Robert ~. Amdormou 2805 ~ Street Very I:reZ. y 7euro, /// / It. HarmhmXX, Jr. PetroXeum Supervtoor FORM SA - I B ~ ~ 125 5M 8/67 /-~\ ~ MEMORANDUM TO: I-' FROM: State of Alaska DATE : SUBJECTt FORM SA - I B 12,5 SM 8/67 MEMORANDUM TO: r- FROM: State of Alaska SUBJECT= Form P--I ~ 9-30-67 SUBMIT IN TRIPLIC, (Other instructions on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK IlL TYPE OF WORK DRILL [] WELL WELL OTHER ZONE 2 NA1VLE OF OPEI:~TOR UNION OIL COMPANY OF CALIFORNIA DEEPEN l-'l PLUG BACK I-] MULTIPLE X~ ZONE 3 ADDRESS O~ OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4 LOCATION A.tsurface T6~~ N 570'W from SE corner Sec. 4, TgN., R13W API 50-133-20099 5. 6. LEASE D~'~IC, NATION AND S]~:tlAL NO. ADL 18731 9 IF IHDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT, FARM OR LEASE NAME Trading Bay State 9 W~LL NO A-14 [14-4) 10 FIELD AND POOL, OR WILDCAT Trading Bay - Middle Kenai~ -]¥ '~'2~-,-T~'~, M, (BOTTOM HOLE OBJECTIVE) At proposed prod zone Top Middle Kenai 475'N~ 1790'E from SW comer Sec. 4, TgN. R13W- Top Hemlock 330'N'99U'~ fromSWcorner j Sec. 4, TgN., R13W., S.M. 13 DISTANCE IN MILES ANI~ DIRECTION FXOM NEAREST TOWN OR POST OFFICE Approximately 27 air re}les NW, of Kenai: Alaska 14 BOND INFORMATION Statewide United Pacific Insurance Company ~B-553 TYPE Surety and/or No 15 DISTANCE FROM PROPOSED* - ~16 NO. OF ACRES IN LEASE LOCATION TO NEAREST (Also to nearest drlg. unit, If any) 4950' 38~' 18 DISTANCE FROM PROPOSED LOC~%TI~'I~* ~ ] i9 PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLET!~ID. OR APPLIED FOR, FT 1150' from A-t3 79 15 MD 15686 VD ~2 $100,000 Amount IT NO. ACRES ASSIGNgD TO THiS WELL 40 20 ROTARY OR CABLE TOOLS Rotary 21 ELEVATIONS (Show whether DF. RT, CR, etc ) P~ APPROX. DATE WORK WILL START* 10 1' R.T. above MSL 4/4/68 23 PI~OPOSEI) CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING} WEIGHT PER FOO~ GRAD~ SETTING DEPTH QUANTITY OF C[MEN~ ~v=~" !3-3~3,,' 61 t ~ 1080 1200 sx /~'~//' ~¢~,, o-~/~ 40 & 43.5 ~5 7935 1200 sx $zm'ff/Z, ~,~ ,. . Drill 12¼" directional hoI~ to 1100'. Open hole to 17½". Cement to surface 13 3/8 casing at 1080'. Ins'~ali and test B.O.P. Drill 12¼" directed bole to Top Hemlock. Core 30'. Drill 12i directed hole to total depth. Run D.I.L., FDC-GR with Caliper, HRD and SNP. Run 9 5/8 casing, cement and perferate for production by log and core determination. * Approximate BHL 260'N 630'E from SWcomer Section 4, TgN., R13W., S.M. IN ABOVE SPAC'~ DESCRIBE PROPOSED PROGRAM If proposal is to deepen or plug back, give data on present productive zone and proposed new producbve zone. If proposal is 'to drill or deepen d~rect.onally, give pertinent data on subsurface locatior~ and measured and true vertical depths Gxve blowout preven~r program 24 I hereby certify thlg~he Foregoing is True an~ Correct ED._ -- DATE April 9.- 19 6 8 (Th~s space for Sta~e 0ffu;~ use) / CONDITIONS OF APPROVAL, IF ANY j SA1VIPLES AND CORE CHIPS RF_~UIR~2) J ~ REQUIREMENTS [] YES [~ NO Executive Secretary APPROVED BY _ , . Tn'!.~. Alaska Clil *$~ I~clio~ O~tJJ~'~8i~ltltljll:J~:°mmittee District Land Manager DAT~ UNION TB ~:5 BAY UNIT UNION-MARATHON AOL 18731 R ISW N TEX TB STOl JO L5 JO J5 T I0 N T 9 N UN[ON OIL' COMPANY OF CALFO'RNI~A ALASKA DISTRICT LOCATION PLAT TRADING BAY FIELD TRADING BAY STATE A-14 (14-4) REV. DATE: APRIL 5, 1968 SCALE: I"= 2000'