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Home My WebLink About198-099 STATE OF ALASKA ' ' .,, ALIRA OIL AND GAS CONSERVATION COMMON ` 2016 REPORT OF SUNDRY WELL OPERATIONS • 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulatdj Pull Tubing El A �p�eshutdown ❑ Performed: Suspend ❑ Perforate ❑ Other StimulatC] Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Wel❑ Re-enter Susp Well❑ Other:Run New G/L CompletiofE 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory❑ 198-099 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20149-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018777 Trading Bay Unit G-15RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil Pool 11.Present Well Condition Summary: Total Depth measured 15,114 feet Plugs measured N/A feet true vertical 9,170 feet Junk measured 14,700 feet Effective Depth measured 15,070 feet Packer measured 10,291 feet true vertical 9,181 feet true vertical 8,072 feet Casing Length Size MD TVD Burst Collapse Conductor 600' 17 3/4" 600' 599' Surface 5,802' 13-3/8" 5,802' 4,640' 3,090 psi 1,540 psi Intermediate 10,845' 9-5/8" 10,845' 8,483' 6,870 psi 4,760 psi Tie Back 10,525' 7-5/8" 10,525' 8,249' 6,890 psi 4,790 psi Production 1,849' 7" 12,365' 9,407' 8,160 psi 7,020 psi Liner 2,815' 4-1/2" 15,072' 9,134' 8,430 psi 7,500 psi Perforation depth Measured depth 12,257-15,114 feet True Vertical depth 9,353-9,170 feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 10,361`(MD) 8,125'(TVD) 10,291'(MD) Packers and SSSV(type,measured and true vertical depth) Liner Top Hyd Perm Pkr 8,072'(TVD) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED MAR : Cal Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 46 30 1725 1270 196 Subsequent to operation: 49 33 1669 1040 157 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-287 Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature Phone (907)777-8356 Date 101 1 1/2 o r b 4)tr A jz -6, 4- ` Form 10-404 Revised 5/2015 / ,I L! Lf lit.,1.i L q 1 L016 Submit Original Only H . • McArthur River Field SCHEMATIC well: G-15RD .H Completed: 10/06/2016 Ink.p kt.,--l.,..I.t r PTD: 198-099 API: 50-733-20149-01-00 RKB=42.9'Rig Floor to DCB TBG Spool Casing/Tubing SIZE(in) WT GRADE CONN ID(in) TOP BTM HS CMT Cement Top 4.,, :,- jr. (Ib/ft) (ft) (ft) (W " A2s" Spiral Lost returns as cement 17 3/4 .312W Surf. 600 22 700 SKS G Weld reached surf v� 173/4" 13 3/8 61 J-55 Buttress 12.15 Surf. 5,802 15 4,19E SKS Good returns to surf I 9 5/8 47 N-80 Buttress 8.681 Surf. 67 Poor to surf csg Shoe 9 5/8 40 N-80 Buttress 8.835 67 5,883 12.25 1,000 SKS G * 9 5/8 43.5 N-80 Buttress 8.755 5,883 7,900 Good to 6,150ft(USIT Log) 13-3/8" INC:42' N 9 5/8 47 80/ P Buttress 8.681 7,900 10,845 Window 10,845 10,857 7 29 L-80 TKC-Butt 6.184 10,516 12,365 8.50 437 SKS 10,516ft Estimated 1 2-13 41/2 12.6 N-80 Hydril 511 3.958 12,257 15,072 6 I Tie-Back Liner 7 5/8 29.7 L-80 Hydril 521 6.875 Surf 10,525 258 SKS 7,441ft off Temp Log 51.6bbls pumped Tubing: 7 5/8in X 9 5/8in ® 4-1/2" I 12.6 I L-80 I Supermax I 3.958 I Surf I 10,361' I I I TOC=7,441ft **4-1/2"pre-drilled liner has 14"predrilled holes-8 hpf 40o 401 B ', B Jewelry 14 Item Depth Depth ID OD Item MD TVD .. 1 42.9 42' Hanger–4%"BTC Lift&Susp w/4"type"H"PBV Profile 15 $ ,,r, 2 2,915' 2,538' 3.958 6.470 GLM#1–PSPO-2R-6.466 Csg Punch: •J 16 3 4,601' 3,847' 3.958 6.470 GLM#2–PSPO-2R-6.466 10,487ft to / % 4 5,617' 4,503' 3.958 6.470 GLM#3–PSPO-2R-6.466 10,497ft; 17 - 5 6,141' 4,895' 3.958 6.470 GLM#4–PSPO-2R-6.466 68bbls cmnt S • (6/07); 6 6,690' 5,303' 3.958 6.470 GLM#5–PSPO-2R-6.466 Test Good * 7 7,229' 5,699' 3.958 6.470 GLM#6–PSPO-2R-6.466 8 7,773' 6,101' 3.958 6.470 GLM#7–PSPO-2R-6.466 ' 9 8,293' 6,503' 3.958 6.470 GLM#8–PSPO-2R-6.466 10 8,807' 6,902' 3.958 6.470 GLM#9–PSPO-2R-6.466 lin Liner11 9,325' 7,306' 3.958 6.470 GLM#10–PSPO-2R-6.466 Top MD:10,525ft ,•'• "Bad Spot" 12 9,771' 7,657' 3.958 6.470 GLM#11–PSPO-2R-6.466 Top TVD:8,246ft 10,525ft to 13 - 10,193' 7,995' 3.958 6.470 GLM#12–PSPO-2R-6.466 INC:43° ? 10,584ft(MD) 14 10,241' 8,032' 3.958 4.800 Chem Injection Mandrel 15 10,291' 8,072' 3.993 _ 6.250 _ 7 5/8"24-39#Liner Top Hyd Perm Packer 16 10,328' 8,100' 3.725 _ 5.200 XN-Nipple 3.812"w/3.750"No Go "Bad Casing" 17 10,361' 8,125' 3.958" 5.200 4-1/2"IBT WLEG + MD=10,857ft - TVD=8,489ft INC=43° Doglegs>=4°to ESP Rotating Hours Set Depth 4 1/2in Liner Depth(ft) °/100ft Csg Sz(in) Hours Top MD: 12,257ft 800 5.03 22 8.5 Top TVD: 'sem 900 4.54 17 3/4 84 9,350ft 7 I 1,050 4.50 13 3/8 304 INC: 1,100 5.62 95/8 350 59° 1 1,150 4.66 7 110 I I 1,200 5.04 Ported 4.5in linerClean Out 1,250 5.25 HB{2,3,4,5} I I to 14,700ft 1,300 4.09 ID=3.958in I I (6/8/07) Avg INC:94° 4,500 5.32 Max INC:108' I I Could not progress further 4,550 6.52 Min INC:59° than 13,066ft due to clean 4,600 7.42 I I out string catching on bad 4,650 6.58 casing spot uphole at 4,700 6.27 1I L 10,857ft(6/13/08). 4,750 6.36 TD=15,114';ETD=15,070' 4,800 4.08 4,900 4.86 91°/12,805';99°/13,281';104°/15,049' 4,950 5.02 5,000 4.58 5,300 5.13 5,350 5.04 9,776 8.77 Updated by: .ILL 10/12/16 10,087 2.38 • • • Hilcorp Alaska, LLC HiIcorp Alaska.IAA Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-15RD Slickline 50-733-20149-01-00 198-099 9/23/2016 10/7/2016 Daily Operations: 09/23/16-Friday POLLARD ARRIVED ON GRAYLING.JSA/TGSM TEST WIRE(GOOD)5OPPM H2S RIG UP(CALL FOR KOT).P/T 3000PSI FAIL.CHANGED 0-RING,RE TEST GOOD (TOOLS ARRIVED).RIH W/SLS TO 6120KB SEE SCALE W/T 6315KB FALL TO 9700KB SEE TUBBING TAIL @ 9680KB. BRUSH GLM @ 9438KB POOH.RIH W/2 1/2 DANIELS KOT W/1 1/4 JD TO 7225KB SET DOWN W/T 7230KB,CANT PASS.TALK W/TOWN,PULL UP TO 6976KB W/T CAN'T LOCATE POOH.RIH W/BLB TO 6976KB,BRUSH GLM RUN TO 9500KB,BRUSH GLM @ 9438. POOH ADD 3'STEM.RIH W/2 1/2 DANIELS KOT W/1 1/4 JD TO 7230KB SET DOWN PULL UP TO 6976KB W/T CAN'T LOCATE,POOH TAKE OFF 3'STEM.RIH W/2 1/2 OK-6 KOT W/1 1/4 JD ON KJ TO 7230KB SET DOWN PULL UP TO 6976KB W/T CAN'T LOCATE POOH.OOH CAP WELL FOR NIGHT. 09/24/16-Saturday JSA/TGSM.RIG UP SHUT IN WELL.RIH 2.29 G-RING TO 7220KB W/T CAN'T PASS POOH ADD 5'STEM.RIH W/2"G-RING TO 7225KB W/T 7316KB POOH.RIH W/SPIRAL SLS. START PUMPING W/WATER FLOOD TO 6394KB W/T 7336KB PACKING ICING UP,CAN'T FALL.POOH(STOP PUMPING)DE ICE PACKING.RIH W/SPIRAL SLS TO 4696KB STUFFING BOX STARTS ICING UP AGAIN CANT FALL POOH.OOH FLOW WELL.LAY DOWN RE HEAD AND RE BUILD STUFFING BOX. SHUT WELL IN.RIH W/SPIRAL SLS TO 7320KB W/T 7334KB LIGHT TO 9200KB.WORK TUB TILL CLEAR.BRUSH GLM#4,5,6,7,8 POOH.RIH W/2.29 G-RING TO 9000KB W/T 9006KB POOH.RIH W/2 1/2 DANIELS KOT W/1 1/4 JD TO 2548KB SET DOWN WIT.CAN'T PASS SHEAR OFF.POOH.RIH W/2 1/2 DANIELS KOT W/1 1/4 JD TO 2548KB.SET DOWN W/T CAN'T SHEAR OFF.POOH W/VALVE.RIH W/2 1/2 OK-5 W/1 1/4 JD TO 8961KB W/T.LOCATE AND LATCH AND PULL GLV.POOH W/VALVE.RIH W/2 1/2 OK-5 W/1"GLV TO 2548KB W/T.LOCATE AND SET VALVE POOH.OOH RIG DOWN FOR NIGHT. 09/29/16-Thursdays wv '„# Place the rig beams on deck and mount the carriage to substructure and place the draw works and A-frame.Place derrick on top the carriage,torque up the bolts on the draw works,torque up the bolts on drive shaft.Make up the hoses and circulate well G-15RD and continue spotting rig equipment on deck.Continued attempting to circ well LW thru tree sending returns to well-clean tank while waiting on 3rd load of W/0 equipment.Offloaded mud pump and active tank,carrier walkways,koomey unit,electrical panel,choke house,catwalk,13 5/8"riser,hyd power unit,skidding jacks,unit& extensions,misc baskets from M/V Titon.Stopped flushing with waterflood and shut well in(never got full returns).Pressures dropped to zero on both sides.Set carrier walkways in place.Mounted skidding jacks and moved rig into position. Checked well pressures after 1 1/2 hrs,zero pressure on gauges. Opened annulus to a slight blow that bled off.Tbg on a vacuum.NOS rep set BPV and checked hanger void to 3500#s f/5 mins.N/D tree.Currently prepping derrick to be raised,organizing connexs and housekeeping.Awaiting arrival of last load of W/O equipment. 09/30/16-Friday Prep derrick for standing,spot choke house,accumulator,&eq.Unload boat.Adjusted boom angle indicator on West crane.N/U 13 5/8"5M BOPE.R/U accumulator lines.R/U PVT and gas alarm systems.Prepped derrick to be raised.Raised and scoped out derrick attaching all guy lines as needed.Running pump lines,connecting accum and flow lines to BOPs.Installing walkways.Changing out pipe rams to 2 7/8"x 5"VBRs.Spotted test pump.Working on electrical.Mounted rig floor,supports,wind walls and steps to floor. 10/01/16-Saturday Modify&install slide,hand rail on DS landing.R/u FIW to pits&fill.Finish running circulating lines.M/u 2 7/8"test jt&install.Fill test eq.with FIW,shell test.Repair stem packing on manifold valve,cont.shell test 250/2500 on annular,3000 on rams&all other eq.Called AOGCC,Inspector Guy Cook to .__OPE?50#s 3 high(annular come witness test.Cont.workon housekeeping,organizing decks while waiting for inspector to arrive.TestedBOPE 250#s low 3000#s tested to 250#s low 2500#s high)as per Sundry in accordance to Hilcorp and AOGCC requirements.Performed successful accumulator draw down test. Test witnessed by Mr.Guy Cook/AOGCC.R/D test equipment.Configure 4 1/2"IBT to pull pkr loose. R/U 4 1/2"handling equipment.Screwed into hanger while NOS backed out hold down pins.Pulled hanger off seat at 42k.Pulled pkr loose at 82k.Pulled hanger to surface at 65k.Lined up to circ FIW LW sending returns to well-clean tank.Currently circulating well clean at report time. • • a Hilcorp Alaska, LLC Hilrurp Alaska,LLC ri 1 ems` Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-15RD - is ine 50-733-20149-01-00 198-099 9/23/2016 10/7/2016 10/02/16-Sunday Cont.circulate clean taking returns to production @ 2.5 BPM,660 psi.Monitor well, good.Pull hanger I/d.Up wt 65k.R/u cap line spooler&hang sheave. POOH standing back in derrick.Tubing started pulling oily.R/u circulate oil cap off to production.Cont.POOH standing back 2 7/8"6.5#L-80 8rd production string.Total of 143 stands and one single=9,354.08'.Crud on O.D.of tbg,damaged/washed out chem line on inj mandrel.Retrieved pkr and WLEG.Cleared and cleaned rig floor.M/U BHA#1(6 1/2"x 1 3/4"Varel Rock Bit,5 1/2"x 1 5/8"scraper f/7 5/8"casing,4 3/4"x 2 3/8"bit sub,4 3/4"x 2 3/8"X-over sub=7.11'.TIH checking P/U&5/0 every 1000'.Installed SV w/pumpin at 5,018'and reversed 2-tbg volumes(60 bbls)at 2.67 BPM 470 PSI. Sample caught(paraffin and scale). Continued in hole to 7,009'and installed SV w/pumpin.Reversed 2 tbg volumes(80 bbls)at 2.84 BPM 500 PSI. Sample caught(more of the same).Continued in hole to 9,361'.M/U SV w/pumpin.Reversed 108 bbls FIW at 2.71 BPM 520 PSI.Sample collected(same stuff). Shut down pump and rih t/9890. 10/03/16-Monday Cont.tih p/u singles t/10014'.Attempt to get pick up weight.Lost upward movement,attempt to circulate,no go.Work pipe,was able to get movement &worked through.Pulled up to 9890'attempt to circulate,no go.Cont.working on circulating&cleared plug.Circulated clean reversing,2.6 bpm,500 psi.Cont.tih,t/10110'wiping each jt,up wt 67k,dn wt.36k.CBU reverse clean @ 3bpm,600 psi,getting scale scrapings at b/u.Cont.rih p/u singles wiping each t/10400'up wt 69k,dn wt 37k,last 120'appeared clean.Circulate hole clean @ 3 BPM,600 psi.POOH 1/d 2 7/8 tubing.B/D bit&scraper BHA. Cleared and cleaned rig floor.Crane operator shut down to slip,cut and rehead cable on fast line. Test pulled same before going back to work.Changed out handling equipment to 4 1/2"(R/U Knight McCoy tongs).Offloaded 2 7/8"tbg onto M/V Titon.M/U new 6.250"Hyd set pkr w/tail pipe assy w/ assistance from Tripoint rep.Continued in hole running production string as proposed. 10/04/16-Tuesday Stopped operations to check on crane repair protocol and procedures.Production personnel investigated boom brake issues and discovered that secondary braking was inoperable.W/O operations halted until repairs are made. Rig crew drained and cleaned active tank and performed housekeeping and Hilcorp/Moncla equipment segregation. Mechanics resolved problem and put East crane back in service.Plumbed 1/4"control line into chem inj mandrel and continued in hole w/4 1/2"12.6#L-80 SuperMax production tubing spacing GLM as designed(strapping,drifting and torqueing to mark). Currently at-1,840'in hole at report time. 10/05/16-Wednesday Continued running in hole w/new 6.25"hyd set perm pkr on 41/2 12.6#L 80 SuperMax tubing,strapping,drifting and torqueing to specs. TIH to 10,328'.M/U and plumbed hanger w/assistance from NOS hand. 10/06/16-Thursday Landed hanger,run in lockdown pins,up wt 130k,dn wt 66k,placing 4 1/2"tubing tail @ 10,361'.Ran 320 jts 4 1/2"L-80,12.6#SuperMax tubing,12 PSPO-2R-6.466"GLM,chem inj.sub,"XN"nipple 3.812"profile w/3.75"NG,WLEG.Installed 172 cannon clamps f/1/4"chemical inj. line.Drop Dart.R/u circ lines,pressure up t/3800 hold f/30 min tosetpacker @ 10290'.,R/U test annulus/packer t/1500 psi,had leak in manifold,bleed off,repair,re-test f/30 min good.R/U w/l.Rih retrieve Prong.Rih t/retrieve plug,POOH GS tool was sheared.Re-dress w/steel pin&re-run.POOH retrieving plug.R/D w/l. Pull&breakdown landing jt.Install BPV.Cleared rig floor,removed windwalls,handrails and supports and R/D same. Crane crew supported mechanics in West crane repair.N/D BOPE.N/U tree as directed by production and NOS rep. Void tested hanger to 500#s f/5 mins 5000#s.Prepped derrick to be laid down. Scoped down/laid over derrick.Presently prepping derrick to be removed from carrier and shell testing tree to 500/5000#s. 10/07/16-Friday Finished shell test on tree-5000#s,pulled TWC. Turned well over to production. • 0 I.,OF Tit, THE STATE Alaska Oil and Gas N �;� of Conservation Commission WI ALASI�:A333 West Seventh Avenue Anchorage, Alaska 99501-3572 -, GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALASlgj.' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager SCANNED SEP 2. 8 2016 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU G-15RD Permit to Drill Number: 198-099 Sundry Number: 316-287 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P22.A...4.,1/4,4„ Cathy P. oerster Chair DATED this l s day of June, 2016. RBDMS 1.'`' Ju.'J 0 1 2016 • RECEIVED STATE OF MAY � 2016/ ALASKA OIL AND GAS CONSERVATION COMMISSION 0--ii FOR SUNDRY APPROVALS ce 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run New G/L ID Compomaletion 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 0 , 198-099 - 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20149-01-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay Unit/G-15RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018777 . McArthur River Field/Hemlock Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,114 9,170 _ 15,070 2,665si N/A 14,700 9,181 . p Casing Length Size MD TVD Burst Collapse Conductor 600' 17-3/4" 600' 599' Surface 5,802' 13-3/8" 5,802' 4,640' 3,090 psi 1,540 psi Intermediate 10,845' 9-5/8" 10,845' 8,483' 6,870 psi 4,760 psi Tie Back 10,525' 7-5/8" 10,525' 8,249' 6,890 psi 4,790 psi Production 1,849' 7" 12,365' 9,407' 8,160 psi 7,020 psi Liner 2,815' 4-1/2" 15,072' 9,134' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12,257-15,114 * 9,353-9,170 2-7/8" 6.5#/L-80 9,577 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): DLH Ret.Packer and N/A • 9,499(MD)7,443(ND)and N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7/1/2016 OIL 0 - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallettehilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 5L-- w Sz.c �Phone (907)777-8356 Date / ro COMMISSION USE ONLY Conditions of approval: Notify Commis ion so that a representative may witness Sundry Number: / "' ‘(_t / 4 Plug Integrity ❑ BOP� Test Mechanical Integrity Test 1:1 Location Clearance ❑ Other: 3 Ode) ,,f.,. 15C)P ' Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS (,1 JUN0 2 2016 Spacing Exception Required? Yes ❑ No 2r. / Subsequent Form Required: 0•—y04-1 PAPPROVED � BY Approved by:067 ,/ COMMISSIONER THE COMMISSION Date: 6 -t-f „ lKa 5Iz.II`, s�-2 6 74, .----.�;-�c‘ . ubmit Form and Form 10-403 Revised 11/2015 OfttOtrIA slid for 12 months from the date of approval. Attachments in Duplicate • Well Prognosis • Well: G-15RD Hilcorp Alaska,LL Date:05/25/2016 Well Name: G-15RD API Number: 50-733-20149-01 Current Status: Oil producer(Gas-Lift) Leg: Leg# Estimated Start Date: 07/01/16 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 198-099 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) 31-Jv Current Bottom Hole Pressure: 3,600 psi @ 9,350' TVD (12,257' MD) 'L-° 7.`'Ire) -µms Maximum Expected BHP: ^'3,600 psi @ 9,350'TVD No new perfs being added. Maximum Potential Surface Pressure: 2,665 psi Using 0.1 psi/ft per 20 AAC 25.280(b)(4) No-Flow Well (09/18/2014) Brief Well Summary The G-15rd well was completed with 2-7/8" gas-lift August 2014. This work over will install a larger gas-lift string. Last Casing Test: 08/08/2014 10,500' 1,500 psig Brief Procedure: 1. MIRU Moncla Rig#404. 2. Rig up E-line and shoot holes in tubing above packer 3. Kill well and circulate Hydrocarbon off of well. Work over fluid to be FIW. 4. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250psi low and 3,000psi high. 5. Monitor well to ensure it is static. 6. Unseat hanger and POOH with completion. 7. Run new Gas-Lift completion. P r' 8. Set BPV. NU tree, test same. 9. Turn well over to production. 10. Conduct SVS per AOGCC regulations. Attachments: 1. Well Schematic/Current 2. Well Schematic/Proposed 3. Wellhead Schematic/Current 4. Wellhead Schematic/ Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form 0 , McArthur River Field . SCHEMATIC Well: G-15RD Completed: 08/12/2014 I1ilr..rit iln..1.4.1.11 PTD: 198-099 RKB=42.9'Rig Floor to DCB TBG Spool Casing/Tubing l SIZE(in) WT GRADE CONN ID(in) TOP BTM HS CMT Cement Top *." 1 r 26" (Ib/ft) (ft) (ft) (in) 17 3/4 .312W Spiral Surf. 22 700 SKS G Lost returns as cement Weld 600 reached surf =I 13 3/8 61 1-55 Buttress 12.15 Surf. 15 4,198 SKS Good returns to surf r*i a'' 17-3/4^ 5,802 G 1' a 4° F 9 5/8 47 N-80 Buttress 8.681 Surf. Poor to surf csg Shoe 67 '. 9 5/8 40 N-80 Buttress 8.835 67 12.25 1,000 SKS 13-3/8" 5,883 G INC:42° 9 5/8 43.5 N-80 Buttress 8.755 5,883 Good to 6,150ft(USIT Log) 7,900 1.,._..1 9 5/8 47 N-80/P- Buttress 8.681 7,900 2rui 110 10,845 Window 10,845 10,857 7 29 L-80 TKC-Butt 6.184 10,516 8.50 437 SKS 10,516ft Estimated 12,365 ( , 41/2 12.6 N-80 Hydril 3.958 12,257 15,072 6 ( w Tie-Back 511 75/8inX95/8Mf I 0; TOC= 7,441ft Liner 7 S/8 29.7 L-80 Hydril 6.875 Surf 10,525 258 SKS 7,441ft off Temp Log 5 I 521 51.6bbls pumped 11l1 Tubing: . -' 2 7/8 l 6.5 I L-80 i EUE I 2.441 I Surf I 9,577' 4' **4-1/2"pre-drilled liner has'''A"predrilled holes-8 hpf "+ C II -`CI . Jewelry ,,,' Item Depth ID OD Item 4 �� ®,�� `,, (ft) (in) (in) Csg Punch *, Ell 5 *. 1 42.9 3.958 Hanger 10,487ft to ■ 2 2.441 4.750in 3-1/2in Gaslift Mandrels(OD Wide=5.313in,OD flat= 10,497ft, Ma 6 "� 4.125in) 68bbls cmnt : Total of 9 mandrels:(2,534ft,4,008ft,5,265ft,6,293ft, (6/07)1 i� 7 r: ,%' Test Good 6,958ft,7,627ft,8,294ft,8,930ft,9,435ft} s* Ak a 1r 3 9,450' 2.441 Chem Injection Sub i r ' 4 9,499' 2.441 6.670in 7-5/8"29.79 DLH Retrievable Packer 4, 5 9,543' 2.310 X-Nipple 6 9,577' 2.620 3.700in WLEG 7in Liner •:', lei - Top MD:10,525ft 'r-. "Bad Spot" Top TVD:8,246ft - t 10,5258 to INC:43° ``` .` 3 %Al 10,584ft(MD) +at" 1D 9t" /1, Doglegs>=4°to ESP Rotating Hours .', `-" "Bad Casing Set Depth *44 'w MD=1o,a57n Depth(ft) °/100ft Csg Sz(in) Hours 'i1 TVD=8,489ft 800 5.03 22 8.5 ,,F , , INC=43° 900 4.54 17 3/4 84 1,050 4.50 13 3/8 304 ;' ?` 1,100 5.62 9 5/8 350 41/2in Liner`x: 0 Top MD: . 1,150 4.66 7 110 12,2578 ..,'0 1,200 5.04 Top TVD ,i :.t't 1,250 5.25 9,3508 1,300 4.09 NC: 11 89° 4,500 5.32 4,550 6.52 I I 4,600 7.42 Ported 4.5in linerClean Out 4,650 6.58 HB{2,3,4,5} I I to 14,700ft ID=3.958in I I (6/8/07) 4,700 6.27 Avg INC:94° 4,750 6.36 Max INC:108° I I Could not progress further 4,800 4.08 Min INC:59° than 13,066ft due to clean 4,900 4.86 I I out string catching on bad 4,950 5.02 casing spot uphole at 5,000 4.58 1 L 10,8578(6/13/08). 5,300 5.13 TD=15,114',ETD=15,070' 5,350 5.04 9,776 8.77 91°/12,805';99°/13,281';104°/15,049' 10,087 2.38 Updated by: JLL 09/11/2014 0 . McArthur River Field . 11 PROPOSED Well: G-15RD Completed: Future Ilii....p 1ta.La.1.1$ PTD: 198-099 Casing/Tubing RKB=42.9'Rig Floor to DCB TBG Spool SIZE(in) WT GRADE CONN ID(in) TOP BTM HS CMT Cement Top �� • iw (lb/ft) (ft) (ft) (in) 1 P 26" 17 3/4 .312W Spiral Surf. 22 700 SKS G Lost returns as cement ., -4^-1 ,t Weld 600 reached surf 13 3/8 61 J-55 Buttress 12.15 Surf. 15 4,198 SKS Good returns to surf .kms ,,' 17-3/4" 5,802 G 9 5/8 47 N-80 Buttress 8.681 Surf. Poor to surf csg Shoe a'0. _ ,, 67 x r°, 9 5/8 40 N-80 Buttress 8.835 67 12.25 1,000 SKS `• 6.13.3/8" 5,883 G _' INC:42° 9 5/8 43.5 N-80 Buttress 8.755 5,883 Good to 6,150ft(USIT Log) 7,900 9 5/8 47 N-80/P- Buttress 8.681 7,900 110 10,845 2-10 .....11: Window 10,845 10,857 7 29 L-80 TKC-Butt 6.184 10,516 8.50 437 SKS 10,516ft Estimated ill 12,365 41/2 12.6 N-80 Hydril 3.958 12,257 15,072 6 511 , Tie-Back 7 5/8in X 9 5/8in ' Liner TOC=7,4410 7 5/8 29.7 L-80 Hydril 6.875 Surf 10,525 258 SKS 7,441ft off Temp Log •"1• ° 521 51.6bbls pumped -r Tubing: xt4-1/2" I 12.6 l L-80 I IBT I 3.958 I Surf I ±9,580' l l " k'. . **4-1/2"pre-drilled liner has Y:"predrilled holes-8 hpf „r U r '• " 11 'N Jewelry Item Depth ID OD Item ,r t* (ft) (in) (in) 12 ,* 4 �i A" 1 42.9 Hanger 1. 2 ±2,535' GLM#1 Csg Punch ,,. M• ' 13 3 ±4,010' GLM#2 10,487ftto `° 4 ±5,265' GLM#3 10,497ft; r 0 1' A 68bbls cmnt ;^ ' 5 ±6,295' GLM#4 (6/07); r ) 6 ±6,960' GLM#5 Test Good . w{ 7 ±7,630' GLM#6 *,. 4,, if ,F 8 ±8,295' GLM#7 4, r. 9 ±8,930' GLM#8 t,, 10 ±9,435' GLM#9 lin Liner - yi11 ±9,450' Chem Injection Sub / Top MD:10,525ft 'QIP" ;t.. "Bad Spot" 12 ±9,500' Packer Top TVD.8,2460 _./ F. INC:43° '� a 10,5ftto 13 ±9,545' X-Nipple 10,58484ft(MD) 14 ±9,580' WLEG 60* ei, -; .4 "Bad Casing MD=10,857ft Doglegs>=4°to ESP Rotatin Hours Set Depth g TVD=s,assft INC=43° Depth(ft) °/100ft Csg Sz(in) Hours 800 5.03 22 8.5 +" 900 4.54 17 3/4 84 4 1/2in Liner 1,050 4.50 13 3/8 304 Top MD:' i Li 1,100 5.62 9 5/8 350 Top TVD: > 1,150 4.66 7 110 9,350ft ^Al 1,200 5.04 INC: 1,250 5.25 6 59° 1 1,300 4.09 I I 4,500 5.32 Ported 4.5in linerClean Out 4,550 6.52 HB{2,3,4,5} I I to 14,7000 4,600 7.42 ID=3.958in I I (6/8/07) 4,650 6.58 Avg INC:94° 4,700 6.27 Max INC:108° I I Could not progress further 4,750 6.36 Min INC:59° than 13,0660 due to clean I I out string catching on bad 4,800 4.08 casing spot uphole at 4,900 4.86 A 1 L 10,8570(6/13/08). 4,950 5.02 5,000 4.58 TD=15,114';ETD=15,070' 5,300 5.13 91°/12,805';99°/13,281';104°/15,049' 5,350 5.04 9,776 8.77 10,087 2.38 Updated by: JLL 05/24/16 • • 11 Grayling Platform G-15RD Current 05/13/2016 Grayling Tubing hanger,C-EN-IA-CU, G-15RD 11 X 311EUE 8rd lift and 13 3/83 9 5/8%7 5/8% susp,w/3"type H BPV 27/8 profile,2-X control lines, 6 h extended neck BHTA,Bowen, 3 1/8 5M FE X 3"Bowen Quick Union as Valve,swab,WKM-M, 0 rig 31/85M FE,HW0, ‘( DD trim 1 • Valve,WKM-M,31/85M FE,w/ MA-16 operator,EE trim 11111 il r3= Valve,upper master, WKM-M,31/85M FE,HWO, ' DD trim a Im- Valve,lower master, ��'�sr WKM-M,31/8 SM FE,HWO, - \ DD trim .`. .- Adapter,Cactus-EN-CCL, -4\ ` 11 5M stdd X 31/8 5M,w/ 6 X pocket,2-1"CCL exits W. Attachment spool, -`! �11111..- FMC-TC-60-ET, acmen11 5M FE btm X 11 SM FE 'ill _ Tubing head,CIW-DCB, p-a 135/83M X115M, w/2-21/16 5M 550, 1 XVRProfile - n ■■l[ f ,11 . . _. i,t Ili AM insomi'! In I u i !I ®- 1i ��KM 1 „,ye- 11_��. ® i Il' s III t Casing head, 111 1 -.6 Shaffer KD, ■ 135/83MX IIS ! I-II 133/8 SOW,w/2-2” ! -411 PA, LPO, a yI11�14s1le • • II Grayling Platform G-15RD Proposed 05/19/2016 HJrnrp:»AMkp,I.l.L. Grayling Tubing hanger,C-EN-1A-CCL, G-1SRD 11 X 4 A EUE and lift and 133/8X95/8%75/8X cusp,w/4"type H BPV 41/2 profile,2-'h control lines, 6 Y.extended neck BHTA,Bowen, 41/16 SM FE X 7"stub acme Bowen Quick Union S Valve,swab,WKM-M, �� ... 41/165M FE,HW0, cp DD trim Valve,WKM-M,31/8SM FE,w/ x' 1e MA-16 operator,EE trim lllIllMF 4 WIMP li Valve,upper master, �i®,•, WKM-M,41/16SM FE, d 40 HWO,OD trim s':' 111.10r C ' Valve,lower master, '•, ,, WKM-M,4 1/16 5M FE HWO,DD tern ��... Alia •'1,, _:: Adapter,Cactus-EN-CCL, i -‘ A115M stdd X4 1/16 5M,w/ 6 Y pocket,2-1"CU exits mi. Attachment spool, -.• l'IIlic 'E9-a' FMC-TC-60-ET,11 5M FEbtm X115M FE Tubing head,CIW-DCB, roil �:ig_ 135/83M X11SM, 1 w/2-2 1/16 SM 550, %-hSKotto prep, _ , VRp file _ .■y(�]yI` = ® ' 1 Iii � It' 111 5. II I- I 1 1 I11 ImiiIlo' - III p - mI';F 9 5/8 4-0 bushing in head di r. .. Ill III 1111 Casing head, II Shaffer ND, 1'I - i ItI 13 5/8 3M X 133/8 S0W,w/2-2" I -I V �.., 1P0, '4 O • • Grayling Platform 2016 BOP Stack Moncla 05/13/2016 Harrup Atsesk,,.LTA, ---1.1611111111 4.54' 0 0 s ti 1!I iii Iii h Iil 2 7/8-5.5 Shaffer SL variables (Lk r 2.83' 135/85M ) Blinds 000 d Choke and Kill valves 2 1/16 5M r�44jjj, ,II'Ilri! '111-111 226 i• Mud Cross � c 41/165MEF0 � r -J_�� *:f l�l.l�l.li6l�l.lfI • N _ MIS Is 11111 I!I III III Riser 135/85M FE X 13 5/8 5M FE 14.20' uI Ii�� Spacer spool I!I I!1 1!I I!I I!I 135/8 SM FE X11 SM 2.75' Ilt tit tit lft tit _l1 I o • ..---6, ----. 00u0 ..., 0 o O O u O U 0000 0 ,..,'6 u O u O u u O u u 0 o N m 7 Ul ..-71 N m . Ul 10 n CO 01 5 0_ 0 0 0 0 5 u U U U U U U U U 0 .-I N on V U1 y ."- N m V ut t0 n 00 01 - -0 "0 0 -0 p 10 -0 U U -0 -0 -0 0 10 0 0 0 0 0 0 U N 2 0 0 0 0 0 0 0 O Y Y C C C C C ccccct _d p j C C , 0) 0) 01 41 01 W 0J 0J 0) Y Y ..„7,u •+ E E E E E J N o 0 0 0 0 0 0 0 0 0 0 a g w 19 0 0 0 0 = U L L L L L L L L L .0 L 0 d a a O. a Y Y 2 U U U U U U U U U U U UI Z co 01 a o Y 0 Ift m CO u 10 m O f 11 r1 CNI CT) qk N. . 00 . In . (O . Uw ELd'w aw CL r7 . NI" . o E w a aCD E W �> J K y • .V => 11 • QIP o o0_ OQ mH co w H a a • 0 z z 0 O RW Z ajz CO— a s I J fn J CL b LT Z_ o02OOH Z- J 000LLQU rt W O UU- Q0U O a2oC 2DCtOw , _IOZ �j My LO aN LLZHQ om z a = J 0 J c ' Q r 0 41110 O o u o o u o O o u o 0 uU o u o u u o u u'` 0 0. — o _ • N en v rn '" .� N m to in tO n 00 m a a a a a u u u u u u u u u o • N m v of N ./> ry m y L/) t0 N 0001 ,1 U -0 -0 V 0 V V 'O 'O 'O 'O 0 t "O t 00000 U N 0 0 0 _O O O O O O O Y E E E C E E E E C C O t j N N N N N N C N t0 t0 2 0 EEEEE E E E E > Y o o o o o 0 o o o Y ° W E E E E E J -' 0 0 0 0 0 0 0 0 0 0 0 0 0 > 0. 0. 0_ 0. 0. X X m u 000000000001 2 Vf 62 0 Y w — G u q N f OC ivQ >4 >4 N N . 00 . 4k U) . D D . U Z Z r�•I" :-..4-1J I a cew aw 0_0 rn . `,1" _ zO yU 2U I, w _> 0 O ce0 LuI LL aw N= ■ :U Si fTi ill...- ile. i" _1_{[ ? g I] .1 .X 717 7k v CL OQ mH U) w a CL— C3 0 Z a H CO a J Z z ° Z ~ w Q aDZ Z H Da � cn � n 7 ? • � a A og0_ U >- 0a 00 Q � amZ Jp0 � 0 O O Z = Cif— 1 F- • J 00 v.)O M - Inv ay Z Quo c9m Z 0 H z 0 J J N ►- w D 0 cc 0 • Moncla Rig 404 BOP Test Procedure Hileorp Alaska.LLC Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump,(monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) i Moncla Rig 404 BOP Test Procedure Hilcm•p Alaska.LLC Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close ft valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open 1st valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^'1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • S Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLCAttachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record"Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form(10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • • , a C d °r m > iii . � 0 Ol o 6V 7,3 s 0 o u, as 2 U U Q aQ.s 7 N Q ... E• co O d N C N = fl.m C ?j a Q v C L .a O N N >O N = L C Q 5 Q 0- as N al .N el -0 °2 °' oar � LZ CO of \ CD C d a'>- CU Z W Cr N N o 0 o aL � o 7 o ,5 o ✓ n- -a Q O ) o aoC a L• 2 thas C a 0 73 coo cu � o o c `° Q 0 0 a) U o-o 'E = C.) wt L O` 0 L 3 �' 3 U4303 �'tq t0 C .ri)= C O) -a cnp C w U s o o � as o 7 LO CQ f° o a, c .� Q 0 o a 0 0 3 ,.-1K .D) lo' 0 Q `O <D O N Q N L L e- +, - N .. Q 0 o U N N as O CA L Q- �i 0 in Q < a Q a Z% U a) N ~«<"" I .1...__ , ,,::~. '.¡..: ".," Ima»rroject Well History File coverlge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a speCial rescan activity or are vièwable by direct inspection ofthe file. ' 1 q <3. - 0 9 9 Well History File Identifier Organizing (dolle) REJCAN vzf Color items: ~ ~ Grayscale items: I o Poor Quality Originals: 11111111111111/11/1 . ~Rescan Needed III 111/111111 1111/1 " , Two~Sided DIGITAL DATA OVERSIZED (Scannable) o Diskettes, No. o Other, NolType o ~aps: o Other items scannable by large scanner NOTES: o OVERSIZED (Non-Scannable) Logs of various kinds DATE~ Þ 6 tt 'rJ +d0 = TOTAL PAGES SS;- o Other: BY: BEVERLY ROBIN VINCENT SHER~INDY, o Other DATE:4~ Ot(/SI ,. Project Proofing . . BY: BEVERLY ROBIN VINCENT SHERYLElrylNDY Scanning Preparation ~ x 30 = 00 BY: BEVERLY RDBIN VINCENT SHERYL BWINDY DATE: Y-a O~/SI ProçJuction Scanning /' Stage 1 PAGE COUNT FROM SCANNED FILE: . 8' b . / PAGE COUNT MATCHES NUMBER'IN SCANNING PREPARATION: V YES 'v: "''''RCY RO",N V'NC'NT SHeRye MW,:O:W'NDY f{2) DATE 6/;/01'" Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WER~ FOUND: YES i;,./ BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY 151 DATE: (SCANNING IS COMPLETE AT THIS POINT UNlESS SPECIAL ATTENTION IS REQUIREO ON AN INDIVIDUAL PAGË bASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) , ReScanned (individuallugC) {spcc:'.JI .Jf/()/lfi(¡/lj $ca'Jlli/lg complelcd) 11111111111111/1111 RESCANNED ay: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: "'SCANNED JUL 1 32004 WJ;p 11/11111111111" III vvtP V\1P NO NO 11111111111111 "'II Quality Checked (dOIl(;') /111111111111111111 12/1 OlO2Rev3NOTScanned. wpd TITZ E _ ..�/ / „)", IC,\'t.", <} 1�� j <.1 L;.t. V�jl_ Anc ola AlasKa 99/ 357., A Es ,\4\.\\'':01\1.€ NN0) SQL Sia Stan Porhola 5 -0 Operations Engineer U Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field/Hemlock Oil Pool, Trading Bay Unit/G-15RD Sundry Number: 314-316 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. •oerster Chair DATED this�day of May, 2014. Encl. t STATE OF ALASKA MA'( 1 4 2614 ALASKA OIL AND GAS CONSERVATION COMMISSION S11-8 / 4, APPLICATION FOR SUNDRY APPROVALS , O 2QAAC 25230 1.Type of Request: Abandon El Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 9 , Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well El Stimulate❑ Alter Casing❑ Other: Install ESP 9 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska,LLC Exploratory ❑ Development I]. 198-099 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic 1:1 Service CI6.API Number. Anchorage,AK 99503 50-733-20149-01 • 7.If perforating: 8.Weil Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A / Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay Unit 1 G-15RD' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018777 • McArthur River Field/Hemlock Oil Pool- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): 9/j Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 15,114 ' 925 QI60 15,070'. 9,177' N/A 14,700(fill) Casing Length Size MD TVD Burst Collapse Structural 600' 17-3/4" 600' 599' 1,340 psi Conductor 5,802' 13-3/8" 5,802' 4,640' 3,090 psi 1,540 psi Surface 10,845' 9-5/8" 10,845' 8,483' 6,870 psi 4,760 psi Intermediate 10,525' 7-5/8" 10,525' 8,249' 6,890 psi 4,790 psi Production 1,849' 7" 12,365' 9,407' 8,160 psi 7,020 psi Liner 2,815' 4-1/2" 15,072' 9,134' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted liner 12,257'-15,114'• 9,353'-9,125' 3-1/2" 9.2#/L-80 10,207' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): None None 12.Attachments: Description Summary of Proposal 9, 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 9, Exploratory ❑ Stratigraphic 0 Development 0 -. Service ❑ 14.Estimated Date for 5.Well Status after proposed work: 5 4 S'iz W`I Commencing Operations: - ' Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylortu�hilcorp.com Printed Name Dan T:.. Title Operatins Engineer _ �� Signature .� Phone (907)777-8319 Date 5/13/2014 _i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test II" Mechanical Integrity Test ❑ Location Clearance ❑ Other: II— ., Spacing Exception Required? Yes ❑ No U3/1 Subsequent Form Required: /1? LI Q 4 / r APPROVED BY Approved by: `7/-�_` COMMISSIONER THE COMMISSION Date: S_22_1 F. v >�I / A t'14 s- yet �! l �� /.� /i/ �ly�i� Submit Form and �}r Form 10-403(Revised 10/2012) Approved a C tl 1 li r12ma from the d to O{ap royal. EMSDAMe 23 Well Prognosis Well: G-15 Iiilcorp Alaska,LI) Date:5/13/2014 Well Name: G-15RD API Number: 50-733-20149-01 Current Status: Producer Leg: 4 Estimated Start Date: May 18,2014 Rig: Moncla 301 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 198-099 First Call Engineer: Dan Taylor (907) 777-8319(0) (907)947-8051 (M) Second Call Engineer: James Young (907) 777-8421 (0) AFE Number: Current Bottom Hole Pressure: 4,092 psi @ 9,450ft TVD/12,360ft MD Based on SBHP survey Sep 2009. Maximum Expected BHP: 4,092 psi @ 9,450ft TVD/12,360ft MD Based on SBHP survey Sep 2009. Maximum Potential Surface 2,112 psi MBHP—(2/3 TVD 0.1 psi/ft+ 1/3 Pressure: TVD*0.435psi/ft) Brief Description Grayling G-15 is currently producing on GL within a primary ESP completion (Apr 2014 well test: —200 bwpd&0 bopd). ESP was shut off March 2010 due to suspected inflow issues. During previous work over operations large amounts of scale/ asphaltenes were found both inside and outside of tubulars. These same deposits are suspected to be choking off the well in the'sump'section of the well bore(MD= 12,700ft, INC=77°). The plan forward on the G-15 is to pull the current completion, clean out to—15,000ft MD, and run a new ESP completion. Procedure: 1. Bleed off well. 2. Circulate off hydrocarbons with filtered inlet water taking returns to production`' 3. Nipple down well head, Nipple up BOP. P 3 s, rS / a. Test BOP to 250psi low and 00-psi high and chart(notifying AOGCC 48 hours in advance). 4. Pull out of hole with tubing string,gas lift completion, and ESP laying down the same. a. While pulling out of hole check for NORM. 5. Pick up and run in hole with 7in X 7 5/8in clean out assembly. a. Clean out to top of 4 1/2in ported liner at—12,257ft. 6. Pick up and run in hole with staggered—1.5in X27/$in work string with jetting mule shoe and wash to+/-15,000ft. a. Maximum anticipated bottom hole pressure is 4,092psi. b. Hydrostatic pressure at>80° hole section(+/-9,550ft TVD)with filtered inlet water is—4,154psi. c. If poor hole cleaning is observed nitrogen may be applied to assist. 7. Pick up and run in hole with 7in test packer to+/-10,600ft. ✓ a. Test casing and 7in X 7 5/8in liner lap to+/-1,500psi. ✓ Ciz c,,,f —3 c n•. ) 8. Pick up and run in hole with ESP, nipple, sliding sleeve,and gas lift mandrels. a. Land ESP with bottom of assembly at+/-10,000ft. 9. Land and test hanger. 10. Nipple down BOP and nipple up the tree. 11. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Well Head(same) 4. BOP Stack Schematic Grayling Platform I Ili Well No.G-15RD Completion Date:6/17/2008 Ilikorp,ttu,ka.1.1.0 RKB=42.T Rig Floor to DCB TBG Spool Casing/Tubing SIZE(in) 'wr(lb/ft) GRADE CONN ID(in) TOP(ft) BTM(ft) HS(in) CMT Cement Top 'I , -. t 26„ 173/4 .32W Spiral Weld Surf. 600 22 700 SKS G Lost returns as cement reached surf 12 :� r '). 133/8 61 J-55 Buttress .15 Surf. 5,802 15 4,198 SKS G Good returns to surf 4 • <' y1 -c 95/6 47 N-80 Buttress 8.681 Surf. 67 Poorto surf csg Shoe ' „t 17-3/4” y9 9 5/8 40 N-80 Buttress 8.835 67 5,883 1225 1000 SKS G ic- 11 int, 95/8 43.5 N-80 Buttress 8.755 5,883 7,900 Good to 6,150ft(USIT Log) ', et95/8 '47 N-80/P-113 Buttress 8.681 7,900 13,845 '... X 13-3/8" 1A4ndow 10,845 10,857 7 29 L-80 TKC-Butt ' 6.184 '0,516 72,365 8.50 437 SKS 10,5'6ft Estimated 4 Y212.6 N-80 Hydril 511 3.958 12,257 15,072 6 Tie-Back Liner 75/8 29.7 L-80 Hydril 521 6.875 Surf 10,525 258 SKS 7,441ft off Temp Log 51.6bbls pumped Tubing: 3 92 92 I L-80 Imp Butt 2.992 42.9 10,060 Cable a• ESP Reda#1 13207 7 5/8in Liner Y TOC=7,441ft '1 4 , 4 4 "4-N2"pre-drilled liner has'A"predrilled holes-8 hpf i, ,. 1i :,-,. mJewelry � r; 2 1 •• Item `Depth Length ID OD Item 1 (ft) (ft) (in) (in) y R 1 42.9 3.958 CIW4-N2in DCB Tubing Hanger:4-N2in LTC top&btm w/XO to 3-N2in IBT t; pin,with B IWfeed thro ugh penetrator,2 x 3/8in injection line 4 ;t a 0 » ,-J I( 2 2.992 5.313 3-N2in Gaslift M andrels w/1Dft pups bucked on i7 II r' 4.125 Total of 7 mandrels:{2,940ft,4,657ft,6,312ft,7,095ft,7,782ft,8,284ft,9,071t} ell Csg Punch 11aa a ` 3 9,976 42 2.992 Otis 3-N2in Sliding Sleeve w/pups bucked on. 5/2007 *t 10,487ft to s' . 5 4 10,018 0.7 2.750 5.63 3-N2in XN-Nipple w/2.63in NO GO 10,4978' 5 10,060 144.0 2.630 5.62 Centrilift ESP w/Phoenix Gauge(From 10,060ft to 10,204ft) iw 3� 1?6 4, 6 10,202 Bull Nose Centralizer w/8 Fins(ESP BTM @ 10,204ft) lin Liner ir 7 10,507 1.0 6.188 XO 71N x 7-5/8in Top MD. 1p,5258TVD: V'-, 8i 8 10,509 20.7 6.188 BakerJM-ZXP tie-back seal assembly w/hlds w/7ftx7in pup TVD: -: [/I1453ro11L�f Y P P 8,246ft INC: 9 12,256 3.850 Knock out Isolation Valve(3.85in ID after drill out) 43° ett 4 1/2in Liner wj Doglegs>=4°to ESP Top MD: tr� "a Rotating Hours 12,257ft +pA. fa Set Depth Top TVD. », ? 1 1 Depth(ft) 7130ft Csg Sz(in) Hours 9,3508 t- 800 5.03 22 8.5 ' INC: 900 4.54 173/4 84 59° 1 r 7 1050 4.50 13 3/8 304 1,130 5.62 95/8 350 I I Clean Out 1150 4.66 7 110 Ported linerto 14,700ft 1200 5.04 Hemlock Bench I I (6/8 /07) 1250 525 2,3,4,&5. I I 1300 4.09 I I Could not progress further 4,500 5.32 than 13,0668 due to clean 4,550 6.52 I I out string catching on bad 4,600 7.42 casing spot uphole© 4,650 6.58 J L 10,857'(6/13/08) 4,700 6.27 4,750 6.36 'ID=15,114';ETD=15,070' 4,800 4.08 4,900 4.86 91°/12,805';99°/13,281';104°/15,049' 4,950 5.02 5,000 4.58 5,300 5.13 5,350 5.04 9,776 8.77 13087 2.38 Proposed Grayling Platform lit ose p Well No.G-15RD Completion Date:6/13/2008 I Iikorp tla..la.1.1.A: RKB=42.9'Rig Floor to DCB TBG Spool Casing/Tubing IJSIZE(in) WI(@/ft) GRADE CONN ID(in) TOP(ft) BTM(ft) HS(in) CMT Cement Top r • 26„ 173/4 .312W Spiral Weld Surf. 600 22 700 SKS G Lost returns as cement reached surf 133/8 61 J-55 Buttress 4.15 Surf. 5,802 15 4,178 SKSG Good returns to surf a' -.rl 95/8 47 N-80 Buttress 8.681 Surf. 67 Poorto surf csg Shoe Gx .«.a 17.3/4" 95/8 40 N-80 Buttress 8.835 67 5,883 12.25 1000 SKSG F4' ��r". 95/8 43.5 N-80 Buttress 8.755 5,883 7,900 Good to 6,150ft(USIT Log) '^ 95/8 47 N-80/P-110 Buttress 8.681 7,900 1,845 koh "13-3I8" Window 1,845 1,857 INC:42° 7 29 L-80 TKC-Butt 6.184 1,518 2,365 8.50 437 SKS 10,52ft Estimated 4112 2.6 N-80 Hydril 511 3.958 12,257 15,072 6 Tie-Back Liner 2 75/8 29.7 L-80 Hydril 521 6.875 Surf 1,525 258 SKS 7,441ft off Temp Log 51.6bbls pumped Tubing: 3 V2 92 L-80 Supermax 2992 42.9 1,060 Cable P. #lRound 5kv/EPDM/Lead/20-Galvanized '0,000 sr 7 5/8in X 9 5/8in M, •, "4-'82"pre-drilled liner has%"predrilled holes-8 hpf TOC=7,441ft 4* V ,i Jewelry 1, 3x Item Depth Length ID OD Item ( (ft) (ft) (in) (in) 3 1 42.9 3.958 Hanger 4r - ESP Btm: 2 2.992 5.313in 3-12in Gaslift Mandrels(OD Wde=5.313in,OD Flat=4.125in) MD= Total of 13 mandrels:{2,543ft,3,768ft,4,412ft,5,202ft,5,899ft,6,569ft,7,243ft, 5�`at,w, w!i 10,100ft TVD= 7,908ft,8,552ft,9,135ft} i• 7,918ft 3 9,300 2.992 Otis 3-12in Sliding Sleeve Csg Punch: ' .4, .I4 13,016 2.750 3-12in XN-Nipple(2.81n profile with a 2.75in nogo) 10,487ft to 11; ,: 10,497ft; 5 13,060 Summit ESP 68bbls cmnt.4,;,r, a , (6/07); i6 6 13,507 1.0 6.188 XO71Nx7-5/8in M Test Good � 7 13,509 20.7 6.188 Baker JM-ZXP tie-back seal assemblyw/hlds w/7ft x7in pup / 7 8 et+ 8 12,256 3.850 Knock out Isolation Valve(3.85in ID after drill out) t ' 7in Liner Top MD:10,525ft ';a "Bad Spot" Top TVD:8,246ft10,525ft to INC:43° kii w 10,584ft(MD) w>g 1," "Bad Casing" MD=10,857ft N:'a ilr TVD=8,489ft Doglegs>=4°to ESP INC=43° Set Depth Rotating Hours ` ..�; Depth(ft) 710ft CsgSz(in) Hours 800 5.03 22 8.5 4 1/2in Liner it' 10 900 4.54 173/4 84 Top MD: : .r ;f 12,257ft i,i 1050 4.50 133/8 304 Top TVD: :, .1 1100 5.62 9 5/8 350 9,350ft �1 1150 4.66 7 11 INC: qq,, ��ppp 1200 5.04 59° 11 fr 7 1250 5.25 1300 _ 4.09 I I 4,500 5.32 Ported 4.5in liner , Clean Out 4,550 _ 6.52 HB(2,3,4,5) I to 14,700ft 4,600 7.42 ID=3.958in I I (6/8/07) 4,650 6.58 Avg INC:94° Max INC:108° Could not progress further 4'700 627 Min INC:59° I I than 13,066ft due to clean 4,750 6.36 I I out string catching on bad 4,800 4.08 casing spot uphole at 4,900 486 I I 10,857ft(6/13/08). 4,950 5.02 5,000 4.58 5,300 5.1 TD=15,114';ETD=15,070' 5,350 5.04 91°/12,805';99°/13,281';104°/15,049' 9,776 8.77 13087 2.38 • Grayling Platform G-15RD Current 05/14/2014 Hilcur-p,Ilaxku,l,HA; Grayling Tubing hanger,FMC-TC-B- G-15RD ESP,11 X 3'A NSCT lift and 133/8X95/8X75/8X susp,w/3' typeHBPV 31/2 profile,3-''/.control lines,4- 300 seal pocket,ported for BIW mandrel BHTA,Bowen, 3 1/8 5M FE X 3"Bowen Quick Union i a Valve,swab,VG-M, Js 31/8 5M FE,HWO, 1• DD trim Pq�® '�-a Valve,WKM-M,31/8 5M FE,w/ MA-16 operator,EE trim Il llli; O Valve,upper master, • VG-M,31/8 5M FE,HWO, eln(o'' DD trim 0',:e MR Valve,lower master, 0 � VG-M,31/85M FE,HWO, 11 DD trim ,, :,,: Adapter,FMC-ESP,11 SM Rotating Flange X 3 1/8 5M Rotating flange,w/3-control line exits,4-300 pocket prep, ni ,. . III alloy material Attachment spool, let�i� l FMC-TC-60-ET,11 5M FE btm X 11 5M FE las NI II. III lel anal Tubing head,CIW-DCB, 1 13 5/8 3M X 11 5M, " ra1 _ rat Valve,wing,WKM-M, w/2-2 1/16 5M SSO, 2 1/16 SM FE,HWO, X-bottom prep, t "9 0• `gip; o•\,.� ' 0 DD trim 13 VR profile cis ■� i1 i; -'�,,l�l .-i. c III 111 t+ Casing spool,C-29, Ill 41 13 5/8 3M X 13 5/8 3M, iii - — lel w/2-21/165MEFO, 4414 9 5/84-0 bushing in head lll r >tllll4r■■r�,yi■�It ,,4 iI .I- III III livi 7,1 Casing head, Shaffer KD, 13 5/8 3M X i t t `–Ji 'ql 13 3/8 SOW,w/2-2" I lU 2 i Grayling Platform BOP Stack Moncla 3i 04/24/2014 Rarorp Atimk t,i u: Grayling Platform 2014 Workovers BOP Drawing Moncla III III III lit III • tit lit lit 111 ICI III III lit 3.75' Shaffer 135 85M tit tit lit tit li IF UI III III III 4.67' : l ,yc° # _ — 2 7/8-5 variables 111 Nile _ Blinds In in Illtil tit .!tf miff 111. Kill Side Choke side 2.00' 3 1/8 5M w/HCR `> ; II1 i , 3 1/8 5M w/HCR tiE tit lil til 11t 1.00'to 2.00' III Milt tit Ill Drill deck 14.20' Riser 13 5/8 5M FE X 13 5/8 5M FE tit til lil in lit IR in Itl I11 lit Spacer spool 3.00' 13 5/8 5M FE X 13 5/8 5M FE III lit lit til tit I11 Ill lit111 tit 2.83' Spacer spool 13 5/8 5M FE X 11 5M FE in tit III 111 lit Moncla BOP Test301 Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Moncla 301, Grayling Platform WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test.Contact Mr.Guy 1_ Schwartz and Mr.Jim Regg with the AOGCC prior to rolling test. AOGCC may elect to send„ y inspector. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing(test)joint to lift-threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) ,.. II Moncla 301 BOP Test Procedure Hilcorp Alaska,LLCAttachment#1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same,and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder. 3) Test all Rams and Valves 1) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 2) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. ~ ,. , `, ~ `, ~ SARAN PALIN, GOVERNOR ilt l t>wt> • DiL t'>•isi~ S ~~7 333 W 7ihAVENUE, SUITE 100 - ~s r x T ` Cd~~'a.~R~A1101` Cd~'1~I(~` 7`I~~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 JUIy 28, 2008 FAX (907) 276-7542 Mr. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 ~1r~~~~ .~U~. ~ ~ ZQ~B Rr: No-Plow Verification Trading Bay Unit G-15RD, PTD 198-099 Dear Mr. Myers: On July 1, 2008 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a "no flow test" at Unocal's Grayling platform, Trading Bay Unit Well G-I SRD. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. During the 3 hour monitoring period, unassisted flow of gas and liquid did not exceed the allowable flow rates (900 standard cubic feet per hour gas and 6.3 gallons per hour liquid). Less than 1 cup of liquid was produced to surface during the test. The subsurface safety valve may be removed from service in Well G-15RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Grayling platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ec: Bob Fleckenstein • NiE~il®RA6V®IJnA TO: Jim Regg ~~ J ~ Z~ f Z~,ti ~• P.I. Supervisor r FROM: Jeff Jones Petroleum Inspector ~~yy „a~r~AV~~ ~UL. L+ ~ 2~d0 • State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: July 1, 2008 SUBJECT: No-Flow Test Unocal /Grayling PLT G-15RD ' PTD-1980990 - Trading Bay Unit July 1, 2008: I traveled to Unocal's Grayling Platform in Cook Inlet to witness a No-Flow Test on well G-15RD. On my arrival on the platform I met with Unocal Lead Operator John Leibenthal and we discussed the operational details of the test. Mr. Leibenthal indicated that the well pressure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Unocal representative Chad Ebenecer performed the test today in a safe and proficient manner. Well G-15RD has an electric submersible pump (ESP) installed and was lined up from the tree top swab valve through an Armor-Flow model # 3461-03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. Since the tubing X casing IA did not bleed down completely the hydrocarbon flow from the casing was also routed through the flow meter. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test and as the data below indicates, well G-15RD meets the AOGCC requirements fora No- Flowstatus determination. Summary: I witnessed a successful No-Flow Test on Unocal's Trading Bay Unit well G-15RD on the Grayling Platform. r-- ~ Welt No-Flow .Test t?ata Operator: Unocal /Chevron O erator Rep: J. Leibenthal / C. Ebenecer AOGCC Rep: Jeff Jones Field/UniUPad TBU / Graylin PLT Well: G-15RD Time jf'el! Flow CUriI/)ZBiZ~S Gas Li uid 1100 am 200 scfh No significant amount Start Test 1130 am 190 scfh No si ificant amount 1200 pm 190 scth No si ificant amount 1230 m 190 scfh No significant amount 1300 m 190 scfh No significant amount 1330 m 190 scth No significant amount 1400 m 190 scfh No significant amount End Test Produced to open top container through Armor-Flow meter model #3461-03T0 calibrated 6/27/08 Total liquid produced: less than 1 cup. This well has an ESP (electric submersible pump) installed. Attachments: none CC: Chris Meyers, Wayne Johnson (Unocal) :i RJF 09/19/02 Page I of 1 No-Flow TBU Grayling PLT G-I~RD 7-]-08 J.l.xls STATE OF ALASKA ~~. ,_ ALA OIL AND GAS CONSERVATION COMII~ION a ~°' REPORT OF SUNDRY WELL OPERATIONS -'~~- ,~ ~ 20pg ., 1. Operations Abandon Repair Well Plug Perforations Stimulate ~O'ther ~. Performed: Alter Casing ^ Pull Tubing^ ~ Perforate New Pool ^ Waiver^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: ~ Name: Development Q ~ Exploratory^ 198-099 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20149-01 ' 7. KB Elevation (ft): 9. Well Name and Number: 42.9' ' Trading Bay Unit G-15RD 8. Property Designation: 10. Field/Pool(s): Cook Inlet ADL0018777 [Grayling Platform] McArthur River Field /Hemlock Oil 11. Present WeII Condition Summary: Total Depth measured 15,114 ~ feet Plugs (measured) N/A true vertical 9,125 feet Junk (measured) 14,700' (6/8/07 fill) Effective Depth measured 14,700 feet true vertical 9,206 feet Casing Length Size MD TVD Burst Collapse Structural 600' 17-314" 600' 599' 1340 psi Conductor 5,802' 13-3/8" 5,802' 4,640' 3090 psi 1540 psi Surface 10,845' 9-5/8" 10,845' 8,483' 6870 psi 4760 psi Intermediate 10,525' 7-5/8" 10,525' 8,249' 6890 psi 4790 psi Production 1,849' 7" 12,365' 9,407' 8160 psi 7020 psi Liner 2,815' 4-1/2" 15,072' 9,134' 8430 psi 7500 psi Perforation depth: Measured depth: slotted liner 12,257'-15,114' ~~~3~~G AU G 3 ~- 2008 True Vertical depth: 9,353' - 9,125' Tubing: (size, grade, and measured depth) 3-1/2" L-80 9.2# 10,203' Packers and SSSV (type and measured depth) none none 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 400 0 8900 40 95 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: 308-180 Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ ^:- ~ Phone 263-7600 Date 7/21/2008 Form 10-404 Revised 04/2006 i~ ~ ~ ~ [~~~ ` Submit Original Only Chevron • ~RAYLING PLATFORM WELL #: G-15RD AS Run ("r)ntrlla~t;e,1, ^r/1 ~iti4 RI TC Csg F 10,48 TOI CASING AND TUBING DETAIL NO De th Len th ID OD Item CIW 4-1/2" DCB Tubing Hanger: 4-1/2" LTC top & btm w/ 1. 42.9' 3.958" XO to 3-1/2" [BT pin, with BIW feed through penetrator, 2 x 3/8" in'ection line 5.313" 3-1/2" Gaslift Mandrels w/ 10' pups bucked on 2.992" 4.125" 2940', 4657', 6312', 7095', 7782', 8284', 9071' 2. 9,976' 4.15' 2.992" Otis 3-1/2" Slidin Sleeve w/ u s bucked on. 3. 10,018' 0.73' 2.750" 5-5/8" 3-1/2" XN-Ni le w/ 2.63" NO GO 4 10,060' 144' 2.63" 5.62" Centrilift ESP w/ Phoenix Gauge 10,204' 5. -10,507' 1.0' 6.188" XO 7" x 7-5/8" 6. 10,509 20.68' 6.188" Baker JM-ZXP tie-back seal assembl w/ hlds w/ 7' x 7" u 7. 12,256' 3.850" Knock out Isolation Valve 3.85" ID after drill out ~7 I Clean Clot Ported finer I to 14,700' I Hemlock Bench (6/e/o7) 2,3,4,85. I I I Could not progress fu rther than 13,066' due to clean I out stung catching on bad casing spot uphole (d I ~ 10,857' (6/13/06) TD = 15,114'; EI'D =15,070 91 ° / 12,805'; 99° / 13,281'; 104° / 15,049' Rotating Hours 22" ...................8.5 hrs 17-3/4" ............. 84 hrs 13-3/8" .............304 hrs 9-5/8" ............... 350 hrs 7" ..................... 110 hrs Doglegs >= 4° to ESP Set Depth 800' .. ................5.03° / 100' 900' .. ................4.54° / 100' 1050' ................4.50° / 100' 1100' ................5.62° / 100' 1150' ................4.66° / 100' 1200' ................5.04° / 100' 1250' ................5.25° / 100' 1300' ................4.09° / 100' 4500' ................5.32° / 100' 4550' ................6.52° / 100' 4600' ................7.42° / 100' 4650' ................6.58° / 100' 4700' ................6.27° / 100' 4750' ................6.36° / 100' 4800' ................4.08° / 100' 4900' ................4.86° / 100' 4950' ................5.02° / 100' 5000' ................4.58° / 100' 5300' ................5.13° / 100' 5350' ................5.04° / 100' 9776' ................8.77° / 100' 10,087' .............2.38° / 100' REVISED: 7/18/2008 REVISED BY: CVK Chevron Chevron -Alaska Daily Operations Summary Well Name G-15RD Field Name MCARTHUR RIVER, API/UWI 507332014901 Lease/Serial ADL0018777 CHEVNO AR4367 License No./Prope... 1980990 Orig KB Elev (ftK6) Water Depth (ft) 155.00 Jabs -- _ Job Cat _ Type AFE No. QO Eng Workover ESP UWDAK-R8039 ~~_. __ Dail O ra#lons 5/22/2008 00:00 - 5/23/2008 00:00 Operations Summary Transport personnel to Grayling Platform -Perform pre-tour safety meeting with crews 5/23/2008 00:00 - 5/24/2008 00:00 Operations Summary Pre-job Safety Meeting (PJSM) -Sim-ops with production personnel -Perform environmental walk around - No issues, incidents or near misses 5/24/2008 00:00 - 5/25/2008 00:00 Operations Summary PJSM -Prepare rig for ESP changeout operations -Checkout Koomey Unit and associated equipment 5/25/2008 00:00 - 5/26/2008 00:00 Operations Summary PJSM -Sim-ops meeting with production personnel -Continue to prepare rig for ESP operations -Stage materials and equipment from shore to platform 5/26/2008 00:00 - 5/27/2008 00:00 Operations Summary PJSM -Continue to prepare drilling rig -test drilling and mud equipment - IFO Operations 5/27/2008 00:00 - 5/28/2008 00:00 Operations Summary PJSM -Platform Orientation for new rig crew - NU Dbl Gate, mud cross outer valves, and annular -Performed environmental walk around, no issues, incidents - IFO operations to date. Notified AOGCC of upcoming BOP test. 5/28/2008 00:00 - 5/29/2008 00:00 Operations Summary PJSM -Open well -Circulate 3% KCL down tubing with returns to tank -Took 17 bbls to catch pressure - IFO Operations. future BOP test vwitness waived by AOGCC Jim Regg 5/29/2008 00:00 - 5/30/2008 00:00 Operations Summary Monitored fluid losses to the well. 20 bbl/hr. ND Tree. NU BOP. Begin Testing BOPs - 5/30/2008 00:00 - 5/31/2008 00:00 Operations Summary Mobe. Test BOPs 250 psi low and 3000 psi high. 5/31/2008 00:00 - 6/1/2008 00:00 Operations Summary Finish testin BOPs. Circulate 531 bbls of fluid FIW (filtered Inlet water) until returns cleaned up. Pull hanger to rig floor. Laid Down (LD) same. 6/1/2008 00:00 - 6/2/2008 00:00 Operations Summary POOH with ESP completion. Rack back 3-1/2" tbg. LD GLM, sliding sleeve, and X nipple. onitor loss rates (28 bph). 6/2/2008 00:00 - 6/3/2008 00:00 Operations Summary LD ESP and prep for shipping. Prep for handling drill pipe. MU 6" bit, 7" scrapper 6/3/2008 00:00 - 6/4/2008 00:00 Operations Summary Trip in hole. Circulate, continue TIH. 6/4/2008 00:00 - 6/5/2008 00:00 Operations Summary Circ and condition hole. TIH to 10,322. Hole packed off. Loss rate down to 2 bph. Worked pipe free. Circ high vis pill. No increase in cuttings. Continue in hole to 10849'. Pipe stuck. Worked free. Pipe restuck in same spot. Pump hi-vis sweep. 6/5/2008 00:00 - 6/6/2008 00:00 Operations Summary Cont to POOH laying down DP. LD 7-5/8" scrapper BHA. 16" piece of Chem inj line wrapped around blades. PUMU BHA #2 with 6.725" junk mill, and 7-5/8" csg scraper, bit sub, jars and drill collars. Hole losses avg 3 bph. RIH to 10509' and work pipe and circ clean. AOGCC given 24hr notice of upcoming BOP test. 6/6/2008 00:00 - 6/7/2008 00:00 Operations Summary Trip out of hole. Stand back drill pipe and LD clean out assembly. Test BOPs 250 psi low and 3000 psi high. AOGCC Jim Regg waived witness of BOP test. 6/7/2008 00:00 - 6/8/2008 00:00 Operations Summary PUMU BHA #3. 6"junk mill, drill collars, 6" string mill. drill collars. RIH to 10528'. tight spot. worked through. Continued in hole washing down to 10855'. Work on obstruction at 10856'. No Joy. Static well loss for 9 bph. Chevron Chevron -Alaska Daily Operations Summary Well Name G-15RD Field Name MCARTHUR RIVER, API/UWI 507332014901 Lease/Serial ADL0018777 CHEVNO AR4367 License No./Prope... 1980990 Orig KB Elev (ftK6) Water Depth (ft) 155.00 D811 0 eratfons -^ - - - ~_- _ __ __ ___ _ 6/8/2008 00:00 - 6/9/2008 00:00 Operations Summary Trip out of hole. LD BHA #3. PUMU BHA #4, 3.875" junk mill and bit sub and drill collars. PU 2-7/8" drill pipe. 6/9/2008 00:00 - 6/10/2008 00:00 Operations Summary BHA #4 added XO 'ars m r n ill (total length=3393') continue to RIH on 3-1/2" drill pipe. Worked through bad spot at 10856' Saw no indication. Circ well. 2 bph loss rate (static). CBU. RIH and tagged liner top at 12015'. worked pipe to 12230'. Circ and conditioned hole. 13 BPH loss rate. Pumped hi vis sweep. 6/10/2008 00:00 - 6/11/2008 00:00 Operations Summary Washed to 12448'. Trip out of hole to 12128' Run back down and work to 12475' pipe stuck. Work free. pump hi-vis sweep. Wash to 12485'. no progress. TOOH 6/11/2008 00:00 - 8/12/2008 00:00 Operations Summary POOH LD BHA #4. PU tools for BHA #5. 6/12/2008 00:00 - 6/13/2008 00:00 Operations Summary Make u (MU) BHA consisting of 2-7/8" tbg, 3-1/2" DP, jars, bumper subs, DC, intensifiers. TIH working to 10,789'. 6/13/2008 00:00 - 6/14/2008 00:00 Operations Summary Continue to work in hole to TOL at 12,272'. Work into liner, to 13,066', no Ion er able to ro ress due to setting down on the bad casing spot with the 4-15/16" XO in the upper string at 10,857'. Pump hi-vis sweep. ontinue to arcu ate an con I Ion until returns clean. Notice given to AOGCC Jeff Jones of upcoming BOP test. 6/14/2008 00:00 - 6/15/2008 00:00 Operations Summary Fill hole tripping in to 13,055'. Displace well to clean 3% KCL. Well at 26PH losses. POOH laying down 3-1/2" DP. 6/15/2008 00:00 - 6/16/2008 00:00 Operations Summary TOOH LD DP (drill pipe) and BHA. Test BOPS 250 si low and 3000 psi high. Witnesses by AOGCC Jeff Jones. 6/16/2008 00:00 - 6/17/2008 00:00 Operations Summary PUMU ESP Equipment. Set up cable. Check equipment. RIH with ESP completion. Testing cable and pumping through chem injection line. 6/17/2008 00:00 - 6/18/2008 00:00 Operations Summary Continue RIH with ESP completion on 3.5" BTC tbg with gas lift design. Meg cable periodically. MU hanger. NU ESP penetrator and cable splice for same. RI lock down pins on hanger. ND bell nipple. 6/18/2008 00:00 - 6/19/2008 00:00 Operations Summary ND BOPE and riser. Final check on ESP equipment. Good. NU tree. Turn well over to production. 6/19/2008 00:00 - 6/20/2008 00:00 Operations Summary Demob 6/20/2008 00:00 - 6/21/2008 00:00 Operations Summary Demob 6/21/2008 00:00 - 6/22/2008 00:00 Operations Summary Demob 6/22/2008 00:00 - 6/23/2008 00:00 Operations Summary Demob 7/1/2008 00:00 - 7/2/2008 00:00 Operations Summary AOGCC witnessed no flow test. Passed without any problems per lead operator Dave Owen. G15 RD BOP test • • Regg, James B (DOA) From: Regg, James B (DOA) ~~~ _ 6 ~~~d~ Sent: Thursday, June 12, 200$ 1:24 PM ~~ To: 'Menapace, Michael Sam' Cc: Harness, Evan; Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: G15 RD BOP test Page 1 of 1 Your request for an extension of the time to complete a BOPE test on TBU G-15RD is approved until Jun 15 (Sunday) or until your next trip out of the hole, whichever comes first. It appears from the information provided to me that there was an opportunity to test BODE when you tripped to change out the work string and pump liners. As you know, AOGCC requires BOPE to be tested at an interval not to exceed 7 days for workover operations (test due 6113 in this case). Chevron should take advantage of those opportunities proximate to the test due date to remain iri compliance with AOGCC requirements instead of relying on a waiver/test extension. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 S~A-~}t~E6~ JUN ~. 7 2008 Anchorage, AK 99501 From: Menapace, Michael Sam [mailto:MQIK@chevron.com] Sent: Thursday, June 12, 2008 12:15 PM To: Regg, James B (DOA) Cc: Harness, Evan Subject: G15 RD BOP test Jim, We are attempting to clean out 1000' of 4 1 /2" slotted liner. Our first attempt we used 2 7/8"drill pipe and a mill to clean this section out but found we were pressure limited with the pumps. We could not get the pump rate to clean the hole properly. We came out and changed the liners in the pump and changed the drill pipe to 2 7/8" tubing with a open mule shoe and are in the way back in. Our plan, if possible, is to clean this section out and come out laying down our pipe. Then test the BOP's and run completion. Thanks, Sam Menapace Grayling platform 907-776-6639 MOIK@cheveron.com 6/12/2008 Variance for G15RD Page 1 of 1 • Regg, James B (DOA) ~ ~~~._ ~~ From: Menapace, Michael Sam [MOIK@chevron.com] / ~ J ~~ ~,y,~ Sent: Thursday, June 12, 2008 11:09 AM ~ E~ c..r` To: Regg, James B (DOA); t.maunder@alaska.gov Cc: Harness, Evan; Lucas Ken Subject: Variance for G15RD Jim, Tom I would like to get a variance for Well# G15 RD for my BOP test due on June 13 until Sunday, June 15. My last test was done on June 6. I am presently tripping in the hole to do a clean-out run and then coming out laying down the drill string. And then test the BOP's Thanks Sam Menapace /Chevron Grayling platform 1-907-776-6639 MQIK@chevron.con 6/12/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 27, 2008 11:41 AM To: 'Walsh, Chantal [Petrotechnical]' Cc: Rasch, Brad J; Fowler, Don P; Harness, Evan • ~9~-ory~ Subject: RE: Alteration to the BOP Stack for the G-15RD ESP changeout (#308-180) Chantal, et al, As I understand, the change results in 3 rams rather than 2 which is an improvement. Also, you indicated that the choke and kill outlets are larger than the 2-1116" given. Changing to the 3 ram stack with a 3000 psi annular is not an issue for this low pressure workover. Tom Maunder, PE AOGCC From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Tuesday, May 27, 2008 10:21 AM To: Maunder, Thomas E (DOA) Cc: Rasch, Brad J; Fowler, Don P; Harness, Evan Subject: Alteration to the BOP Stack for the G-15RD ESP changeout (#308-180) Tom, The BOP stack diagram, that was sent in with the 403 Sundry approval, is not the BOPs we are able to use on the G-15RD ESP change out workover. We have been unable to get a test on the blind shears in the shop. Therefore, we are proposing the attached BOP stack. The annular is a 3M. In the upper gate are the pipe rams, the shear rams are in the middle cavity, and in the lower gate are the blind rams that will be tested. Please let me know if you need further information. Chantal Walsh 263-7627 ~~~~~~ MAY ~ ~ 2D08 si27~2oos • • G-15RD stack up ,,~,,;; .....,. ,.a ~ ~,.. ~...~ ~._~._ ........ ~ .,...~ G ALASSIfr, OII, AI~TD GAS CONS~R'QATIOI~T COMl-II55IOlY Timothy Brandenburg Drilling Manager ConocoPhillips Alaska Inc. ~~ NE® MAY ~ ~ 200$ PO Box 100360 Anchorage, AK 99510 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: McArthur River Field, Hemlock Oil Paol, Trading Bay G-15RD Sundry Number: 308-180 / Q ~~~ Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90~ 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for goad cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely ff it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair `..~.. DATED this Z~ day of May, 2008 Encl. STATE OF ALASKA • ~,AL.A'~A OIL AND GAS CONSERVATION COMMISSIO ~~ MAY ~ 5 !~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 2s.2so laska Oil & Gas Cons. mission 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Waive orage OtherO Alter casing^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ ESP Replacement , Change approved program^ Pull Tubing ^~ - Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ _ Exploratory ^ 198-099 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20149-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q Tradin Ba Unit G-15RD ! 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Gra lin Platform/Cook Inlet ADL0018777 • 42.9 McArthur River Field /Hemlock Oil ° 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15,114' '^ 9,169' 14,700' 9,206 n/a 14,700' (previous CO) Casing Length Size MD TVD Burst Collapse Conductor 600' 17-314" 600' 599' 1340 psi Surface 5,802' 13-3/8" 5,802' 4640' 3,090 psi 1540 psi Intermediate 10,845' 9-5/8" 10,845' 8,483' 5750 psi 3090 psi Production 10,525' 7-5l8" 10,525' 8,249' 6890 psi 4790 psi Liner 1,849' 7" 12.365' 9,404' 8160 psi 7020 psi Pre-drilled Liner 2,815' 4-1 /2" 15,072' 9,178' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): n!a n/a 3-1 /2" L-80 10,067' Packers and SSSV Type: Packers and SSSV MD (ft): none none 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development^ Service ^ 15. Estimated Date for May 22,08 16. Well Status after proposed work: Commencing Operations: Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh - 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date 5/14/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~-° ~ g~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: -~~oO eS \ ~~~ ~~~ c e ~, ~U ~\~ W Sac- ~ ~~-~~ „~ ~- ~!cE~c--S~ O ~ C-~~-J ~~.+^ ~ ~ `~ c~~vC"~® ~ v~E S . ~ Subsequent Form Required: NCO APPROVED BY ~ ~~ Approved by: COMMISSIONER THE COMMISSION Date: R I G I NA L s°~g.°,$~r Form 10-403 Revised 06/2006 Submit in D ~ey~i9~~ a Chevron Dolly Varden Platform Well G-15RD '08 ESP Workover OBJECTIVE: Replace the failed ESP assembly currently in Well G-15RD. Clean out wellbore. PROCEDURE SUMMARY: 1. R/U Slickline. Open Sliding Sleeve above ESP. 2. Circulate oil out of annulus and load well w/ 3% KCL. 3. Activate Grayling Rig. 4. Spot sized salt pill (if necessary) to manage losses and keep hole full while POH. 5. Set BPV and N/D tree on Well G-15RD. N/LT BOPE. Test BOPE. 6. Verify well dead. 7. POH w/ tubing, cable & failed ESP. LD GLMs. Stand-back tbg. LD ESP BHA. 8. Clean out wellbore into the 4-1/2" slotted liner. 9. R/U to run the ESP completion. 10. RIH w/ replacement ESP assembly on tubing. 11. Install BPV. N/D BOPE. N/U & test tree. 12. Turn well over to production. AOGCC G-15RD ESP WO Procedure Summary.docl of 1 May 14, 2008 - ~~evron • GRAYLING PLATFORM WELL #: G-15RD As Run Completion 6/13/07 RKB = 42.9' Rig Floor to DCB TBG Spool CASING AND TUBING 1 SIZE WT GRADE CONti ID MD To 2 17-3/4" .312W Spiral Weld t7-314 ' 13-3/8" 61 J-55 Buttress 9-5/8" 47 N-80 Buttress . 9-5/8" 40 N-80 Buttress t3 3/8" 9-5/8" 43.5 N-80 Buttress . 9-5/8" 47 N-80/P-110 Buttress TOC ~ 7,441' IS !i 2~ 3~ ;~ 4 4-1/2" ~ 12.6 ~ N-80 ~ Hydri1511 4-1/2" tre-drilled liner has'/:" ~redrilled holc~-8 h tf Tie-Back Liner 7-5/8" 29.7 L-80 Hydril Tubin 3-1/2" 9.2 L-80 Im Butt Cable 1.611"x2.361" 3.37 1/OSOLBC SRV 90 b'B 185 JEWELRY 22 700 sxs Lost returns as ce reached surf 15 4198 s CiOOd returns to s 12-1/4 1000 sxs G oor to SC Shoe ood @ 150' USIT 8-1/2 437 szs 10,516' Est 6" 51.6 bb 258 sx 7,431' Tem NO De th Len th ID OD Item CIW 4-I/2" DCB Tubing Hanger: 4-1/2" LTC top & btm w/ X 1. 42.9' 3.958" 3-1/2" IBT pin, with BIW feed through penetrator, 2 x 3/8" in'ection line TBD 2 867" 5.313" 3-1/2" Gaslift Mandrels w/ ]0' pups bucked on 4.125" 2931', 4687', 6283', 7094', 7772', 8354', 9062' 2. 9,971' 4.15 2.813" HES "XD" 3-I/2" Slidin Sleeve w/ u s bucked on. 3. 10,015 0.73' 2.750" 3-1/2" XN-Ni le w/ 2.75' NO GO 10,067' ' 4 10,210' 595.53 5.62" Centrilift ESP w/ Phoenix Gauge 5. 10,507' 1.0' 6.188" XO 7" x 7-5/8" 6. 10,509 20.68' 6.188" Baker JM-ZXP tie-back seal assembl w/ hlds w/ 7' x 7" u 7. 12,256' 3.850" Knock out Isolation Valve 3.85" ID after drill out 9' Bad Spot f/ 10,525' to 10,584' `. TOL ~ 12,257' ~' ,~ ~7 Ported liner n 0ut fil~ I Hemlock Bench I o 7 to 1a,7oo' 2,3,4,&5. I I TD = 15,114'; ETD =15,070,' 91 ° / 12,805'; 99° / 13,281'; 104° / 15,049' Rotating Hours 22" ...................8.5 hrs 17-3/4" ............. 84 hrs 13-3/8" .............304 hrs 9-5/8" ...............350 hrs 7" ..................... 110 hrs Doglegs >_ -I° to ESP Set Depth 800' .................. 5.03° / 100' 900' .................. 4.54° / 100' 1050' ................ 4.50° / 100' 1100' ................ 5.62° / 100' 1150' ................ 4.66° / 100' 1200' ................ 5.04° / 100' 1250' ................ 5.25° / 100' 1300' ................ 4.09° / 100' 4500' ................ 5.32° / 100' 4550' ................ 6.52° / 100' 4600' ................ 7.42° / 100' 4650' ................ 6.58° / 100' 4700' ................ 6.27° / 100' 4750' ................ 6.36° / 100' 4800' ................ 4.08° / 100' 4900' ................ 4.86° / 100' 4950' ................ 5.02° / 100' 5000' ................ 4.58° / 100' 5300' ................ 5.13° / 100' 5350' ................ 5.04° / 100' 9776' ................ 8.77° / 100' 10,087' ............. 2.38° / 100' ESP set depth REVISED: 8/6/2007 REVISED BY: SLT • G-15RD BOP Stack Leg #4 Afe #164546 ToD of Rotarv Table. RKB = 42.97' RT o Bea, tm of flow box I 4.14' 13 5/8" Hydril 5M Type "GK" 4.54' 14,800 1bs 17'25 13 518" 5M B C Mud Cross D E 530 367 2.23' 320# 32i 1850# ~:; ~3 1/16"SM x4 /16"SM DSA 13 518" 5M Riser 21.25' g~700# 3.39' Top of drill deck A 4-1/16" 5M targeted 90 Deg B 41/16" 5M Shaffer "B" HCR Valve C 41/16" SM Manual gate valve D 3 1/16" SM Manual gate Kill line E 3 1/16" SM Manual gate KIII line F 3-1/16" SM targeted 90 Deg Greylock Hub xo spo 1.73' 1475# Chevron ~ncisco Castro Chevron North A•ica Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 5, 2007 To: AOGCC Howard Okland 333 W. 7t" Ave. Ste# 100 Anchorage, AK 99501 ' PERMIT# APINIIMRFR i~ WFI_I_ I~TYpF- SCALE LC~GDATE INTER~drl~ ~R'_!'J ! ~- ' =iL'.' :,D NOTES- ~ L0~ ;ED N LI~~E i '~ LAS, ' Pf1S j ~ ~ I 1 I - ~ ~ J I ~'~I; - - ~ - - _ ~ - - - - - -- -- - - _ - _ - - -- ULTRA-SONIC TBU G- IMAGING TOOL 198-099 507332014901 15RD GAMMA RAY /CCL 5" 16-Mar-07 45 - 10420 2 1 1 PDS MULTI-FINGER TBU G- CALIPER TOOL 198-099 507332014901 15RD GAMMA RAY /CCL 5" 15-Mar-07 0 - 3880 1 1 1 1 PDS DEPTH i9~~~ TBU G- DETERMINATION LOG GAMMA RAY / 10390 - 4&5~96• 507332014901 15RD CCL 5" 21-Ma -07 10550 1 1 1 1 PDS _ ~ ~~ DEC ~. ~. 2007 Please acknowledge receipt by signing and returning one copy of this trarksm~atta[ ~r-~fiX to 94-7263 7828. Received By: Date: l`l$" °qq Chevron ~cisco Castro Chevron North A~ica Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tefe: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 5, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTA P~ ERMIT #~PI NUMBER -- -i 4':'ELL-~ LOG TYPE I l~~'"d~ ~~ SCgLE~ L r n~-TE--~I IPITc°,V~L ~ F,!Jf i 8 ~ FIL";1 ~ ~D ~~~ i~CTE~;- ~~ LGGGED i ~ ~ LINE ~ ~~ i i~,S FCS i I i i ULTRA-SONIC M TBU G- IMAGING TOOL 198-099 507332014901 15RD GAMMA RAY /CCL 5" 16-Mar-07 45 - 10420 2 1 1 PDS ~ MULTI-FINGER TBU G- CALIPER TOOL 198-099 507332014901 15RD RAY i CCL GAMMA 5" 15-Mar-07 0 - 3880 1 1 1 1 PDS _ DEPTH DETERMINATION TBU G- LOG GAMMA RAY / 10390 - 198-100 507332014901 15RD CCL 5" 21-Ma -07 10550 1 1 1 1 PDS ~~~ ~~c ~ ~ 2~~~ Please acknowledge receipt by signing and returning one copy of this tr sc~fi1'tal or SAX to 907 263 7828. Received By: ~~ Date: ~. RECEIVED . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission 1. Operations Abandon Repair Well .¡ Performed: Alter Casing 0· Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 42.9 / 8. Property Designation: ~1>&. 1&171 &4.1 Grayling Platform/Cook Inlet /' f·t . 11. Present Well Condition Summary: Total Depth measured 15,114' , feet true vertical 9,169' , feet Effective Depth measured 15,070' feet true vertical 9,178' feet Casing Length Size Conductor 600 Surface 5802 13-3/8" Production 10845 9-5/8" Intermediate 10,478' 75/8" Liner 1849 7" Pre-drilled Liner 2815 4-1/2" Perforation depth: Measured depth: NA True Vertical depth: NA Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) AUG 1 4 Z007 :a IESP Replacement - WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 198-099 . Service 0 6. API Number: 50-733-20149-01 / 9. Well Name and Number: G-15RD 10. Field/Pool(s): McArthur River Field / Hemlock " Plug Perforations Perforate New Pool 0 Perforate 0 4. Well Class Before Work: Development 0 Stratigraphic 0 Plugs (measured) NA Junk (measured) NA MD TVD Burst 1340 psi 3,090 psi 5,750 psi 6,890 psi 8,160 psi Collapse 600' 5,802' 10845 10,525' 12,365' 15,072' 599' 4,640' 8483 8,248' 9,404' 9,178' 1 ,540 psi 3,090 psi 4,790 psi 7,020 psi SCANNED AUG 2 02007 3-;/;'1 10,067' 9.2 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cmt sqz'd 15 bbls (75 sx) @ 10,525'. Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl RBDMS 8Fl AUG 151007 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 Subsequent to operation: 496 /' 489 7459 92 100 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service 0 Daily Report of Well Operations Yes 16. Well Status after work: Oi10· Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-158 Contact Steve Tyler @ 907 263-7649 Printed Name Tim Brandenburg Signature ~ Form 10-404 Revised 04/2006 Title Drilling Manager Phone 907263-7657 Date 8/6/2007 h:-~ I ~S- Submit Original Only ~ 8.1(1.67 "1 '7 I I Ported liner I I Hemlock Bench 2, 3, 4. & 5. I I I I I I J l TD = 15,114'; ETD =15,070,' 13-318" 61 J·55 Buttress 12.15" Surf. 5802' 15'~ 4198 sxs 9-5/8" 47 N·80 Buttress 8.681 67' 9-5/8" 40 N·80 Buttress 8.835 5883' 12-1/4 1000 sxs G 9-5/8" 43.5 N·80 Buttress 8.755 7900' 9-5/8" 47 N·80/P-110 Buttress 8.681 10,845' Window 10,857' 7" 12,365' 15,072' L 5. 6. 7. 1.0' 20.68' XO T' X 7-5/8" Baker JM-ZXP tie-back seal assembly w/ hlds w/ 7' x T' u Knock out Isolation Valve (3.85" ID after drill out) 22" ................... 8.5 hrs 17-3/4" ............. 84 hrs 13-3/8" ............. 304 IIrs 9-518" ...............350 hrs 7" ..................... HO IIrs 800' ...................5.03° 1 100' 900' ...................4.54° / 100' 1050'.................4.50° 1100' noo'.................5.62° / 100' H50'.................4.66° 1100' 1200' .................5.04° / 100' 1250' .................5.25° 1 100' 1300' .................4.09° / 100' 4500'.................5.32° 1 100' 4550' .................6.52° / 100' 4600' ................. 7.42° 1 100' 4650' .................6.58° / 100' 4700' .................6.27° 1 100' 4750'.................6.36° 1100' 4800' .................4.08° 1 100' 4900'.................4.86° /100' 4950'.................5.02° 1100' 5000' .................4.58° / 100' 5300'.................5.13° 1100' 5350'.................5.04° / 100' 9776'.................8.77° 1100' 1 91°! 12,805'; 99° 1 13,281'; 104° ! 15,049' REVISED: 8/6/2007 REVISED BY: SL T Primary Job Type ESP Jobs Primary Job Type -----~ --~--.. ESP Daily Operations 2/26/200700:00 - 2/27/2007 00:00 Operations Summary ----- Worked boat. Installed & Inspect mise equipment. 2/27/200700:00 - 2/28/2007 00:00 Operations Summary Mobe Rig#55. Stack BOPE componets. 2/28/200700:00 - 3/1/2007 00:00 Operations Summary ... Continue Mobilizing Rig #55 ---~----~---- 3/1/2007 00:00 - 3/2/2007 00:00 Operations Summary Continue Mobilizing Rig #55 3/2/2007 00:00 - 3/3/2007 00:00 Operations Summary Continue Mobilizing Rig #55 --~._~--~.-.. 3/3/2007 00:00 - 3/4/2007 00:00 Operations Summary Continue Mobilizing Rig #55 3/4/2007 00:00 - 3/5/2007 00:00 Opêrations Summary .-~... Continue Mobilizing Rig #55 3/5/2007 00:00 - 3/6/2007 00:00 Operatiõns Summary '''-~-''-..--' . ... _ ---"" . Continue to Mobilize Rig #55. Circulate well with FIW/3% KCI. Returns to surface at 50 bbls away. Displaced hydrocarbons from well bore. Pumped 763 bbls total. No change on Phoenix gauge. (causes some concern). ---.-----'.'------- 3/6/200700:00 - 3/7/2007 00:00 Operations Summary Circulate well (again) at 5.9 bpm. Returns to surface at 2 bbls away. Pumped a total of 38 bbls. No pressure change noted on Phoenix gauge. ND surface flowlines and tree. NU BOPE. Install choke and kill lines. Set mouse hole. ----_...._~ _ '.. ... _w_·_.__.__~___,~_ - -,--~----~.-._-- ~---_._--~-~---- ---.,------- 3/7/2007 00:00 - 3/8/2007 00:00 Operations Summary--" Conduct BOPE Test. 3/8/2007 00:00 - 3/9/2007 00:00 OperatIons Summary --~--- Finish BOPE testFW ESP_EJguipment. Pull tbg hngr to rig floor. LDsame. Pulling OOHw./ ESPcornple.ti<>~_~ 3/9/200700:00 - 3/10/2007 00:00 Operations Summary Contillue to pull OOH w/ ESP completion. Standi~g back 4-1/2" tbg. Checking NO~M"s. 3/10/2007 00:00 - 3/11/2007 00:00 Operations Summary Cont. pulling ESP completion. found tbg plugged 2 jts. under tbg punched holes. Remediated an estimated of 200+ psi of pressure in plugged tbg. Fished 8' section of flat guard and 2 super bands from BOPE. Recovered all 168 cannon clamps. All 6 protectorlizers. All 6 section(s) of rotten flat guard (43.62' total). All 39 full & 2 partial super bands. -------- ._-------_..~-_.._~-----~.,-,_._----- --~--~~ RU Slickline RIH wi Junk Basket/GR. Weight limt depth to 9000'. POOH recoved (1) super band and some scale. RIH w/ 1-3/4" DD bailer. Set down @ 10,377' (61' above liner top pkr). Worked tools loose. POOH. Recovered full bailer of grease, scale & other emulsion substance. -----,---- _ ________'_'.w_..O" _._ 3/11/200700:00 - 3/12/2007 00:00 Operations Summary RU to handle 5" DP. PUMU Cleanout BHA. PU/RIH on 5" DP. --------." 3/12/200700:00 - 3/13/2007 00:00 Operations Summar"--~-~-" Continue PU RIH wi DP. At 10,281' CBU. Asp~ltines in ~turns. Ream & wash to 10,408' @ 12.5 bpm rate. Increase in asphaltines & silt on bottoms up. 3/13/200700:00 - 3/14/2007 00:00 Operations Summary Continue to cleanout from 10,408' to 10,444'. Tag top of "F" pkr @ 10,444'. Pump high vise sweep. POOH. Boot baskets found to be full of metal, scale, super bands and pieces of flatbar. PU BHA #2. ._--._~._---"--------'--'~-~--- --"----------~_._-- Daily Operations 3/14/200700:00 - 3/15/2007 00:00 Operations Summary --. Finish making up BHA. Ran in hole with 4 3/4" venturi basket assy to 10,436'. Clean-out to 10,471'. Work BHA, pick up weights kept climbing, set down depths changing as well. Indication of dragging junk up & down well bore. PU above TOL. Worked BHA. Pumped sweep. POOH. Not much losses noted. ( total fluid loss the last 24 hrs= +or- 40 bbl) 3/15/200700:00 - 3/16/2007 00:00 Operations Summary Continue, Pooh, work BHA, Recovered about 10 Ibs of waded up Super Bands & small pieces of flat Guard. RU Schlumberger. RI w/8 1/2" GR & Junk Basket. Set down @ 9,902'. POOH. Recovered small piece of super band. RI 83/8" GR & Junkbasket to TOL @ 10,446' ELM. POOH. Recovered 1 piece of superband. RIH w/ Caliper tool. Tool failure on bottom. Was able to get caliper log f/4000' to surface. Made deeper attemp (no-go). POOH. ___'___~__'~__'_.___",~___..__,___._ _____.._____.~__.___~..~.__ ___.__.~~__'u 3/16/200700:00 - 3/17/2007 00:00 Operations Summary RIH w/ USIT Log tool. Log from 10,420' to surface. Possible hole @ 6426'. Casing still showed 50%-80% wall thickness gone from 1650' - 650' (build section of well) in reference to Casing caliper log. PU/RIH w/ burn over shoe. 3/17/200700:00 - 3/18/2007 00:00 Operations Summary ---.----- RIH with burn over shoe. Tag pkr @ 10,444'. Burn over packer F/ 10,444' - TO/ 10,449.5'. Pump 50 bbl HI-VIS Sweep. POOH. Service boot baskets, all three full of packer debris. Shoe had 4.8" ware groove on inside. PU overshot wi spiral 7" grapple. ." , -. -~--------- -- 3/18/200700:00 - 3/19/2007 00:00 Operations Summary RIH, to 10,325' pick up kelly. Latch pkr@ 10,444' swallow 51/2'. Pulled free @ 60 kip over. Droped bar shear out cir sub, CBU. POOH. No Recovery. Found grapple broken. Lost 1/4 of spiral grapple in hole. Load overshot w/ 6-7/8" grapple. Redress pump-out sub. 3/19/200700:00 - 3/20/2007 00:00 OperatiOnsSummary ---- -------~_._- -- RIH. Latch & swallow fish @ 10,449'. Work from 35 kip over to 75 kip over. Up & down with out using jars. Fish appeared to pull free. Drop bar shear out sub & CBU. POOH. No recovery. Grapple broken, again. Make up BHA # 6 - 5 7/8" tapper mill assy, & junk baskets. RIH. --_.-.. ..._--_.--,--,_.._-~._-----~-----~ 3/20/2007 00:00 - 3/21/2007 00:00 Operations Summary Continue RIH wi tapper mill assy, & junk baskets. Tag @ 10,451'. Mill to 10,459'. Seem to be pushing something downhole. Pump Hi-Vise sweep. CBU @ 13 bpm. POOH. Recovered pieces of superbands, 2-1/2 gals of asphaltines & scale from boot baskets. PU BHA #7 Spear Assy. RIH. 3/21/2007 00:00 - 3/22/2007 00:00 Operations Summary ._, --------------~----- Cont RIH with Spear to 10,434' dpm. Pick up Kelly establish circulation. Work into top of Fish at 10,444' dpm. Set Grappel 8' below top of fish (Setting below milled section) - Jarred on Fish for +/- 6hrs worked weights up slowly to a max jar tripping weight of 175k over and a max over pull of 200k over. No movement. Release from Fish. POOH. --_._-~ _.__._--~- ---- --,----_._,..,~_.~-----_.__._- ---.----.....--..- 3/22/200700:00 - 3/23/2007 00:00 OperaÜons Summary ---.-- _n_____ Cont POH with Spear. Break Down BHA. Make up 4" Wash Pipe Assembly. RIH with same to 10,434' rkb dpm. PU Kelly establish cir. Tag Fish at 10,444'. Wash down to 10,477' rkb dpm. Pumped high vis sweep. CBU. Cont washing down from 10,477' rkb dpm to 10,500'. Worked down to 10,547' rkb dpm . Pump high vis sweep. CBU @ 15.5bbl/min. POOH. --------------- 3/23/200700:00 - 3/24/2007 00:00 Operations Summary Worked down to 10,547 rkb dpm with no measurable losses. Circ high vis sweep at 15.5bbl/min. POOH LD BHA #8. Found that the Shoe had been wadded up and tore up (+1- 1 ¿ of broken shoe left in hole). Junk baskets full of asphaltines. Found 1 piece of super-band, 1 piece of grapple, and 1 piece of metal. Test BOPE's. ..,------. ---,~--- 3/24/2007 00:00 - 3/25/2007 00:00 Operations Summary - -..-- Complete pressure test of BOP Equipment. MU BHA #9 for Jaring on Fish. RIH with same to 10,434 rkb dpm. Work into top of Fish. Set spear. Firing Jars at +/- 200k over and pulling to 210k over. No movement in 1 Yz hrs. Released spear. Trip out for wash pipe assembly. ---------- ---- ------- 3/25/2007 00:00 - 3/26/2007 00:00 Operations Summary LD BHA #9 (Spear Assy). PU BHA #10 Wash Pipe assembly. RIH with same. Work to wash over Fish. Washed over from 10,444' to 10,440'. POOH with assembly #10. Daily Operations 3/26/200700:00 - 3/27/2007 00:00 Operations sumniãïY"----~---~·~--·---·-~--··-- -.----- Found a good deal of Packer Junk & pieces of grapple in Boot Baskets. Shoe had a good deal of wear at the Cutright. No damage to the OD & ID of shoe. PU BHA #11 8 1/2" OD Burnover Shoe, 1-Jt 8 1/8" Wash pipe & 3 boot baskets. RIH To 10,431'. Up weight 240 kip, dn wt 180 kip, Rotate wt 200 kip. Break circulation & wash down to top of fish & set down @ 10,449'. Burn over F/ 10,449' - to 10,454'. CBU. Pump hi-vis sweep around, POOH. -,~_.- ~--,._-,-,~-- 3/27/200700:00 - 3/28/2007 00:00 Operations Summary POOH & LD BHA #11 wash pipe Assy. Service boot baskets. No metal or junk in baskets. PU BHA# 12 6" Spear assy. RIH. Engage fish with spear @ 10,444'. Run spear in to seal bore ext to 10,453'. PU to 300 kip then weight dropped of quickly to 275 kip. CBU. POOH. Noted light flow out bell nipple. CBU. POOH. ---~~--_..__._._-,--- 3/28/200700:00 - 3/29/2007 00:00 Operations Summary POOH with Fish. Recovered Complete BOT Model F Packer + seal bore extensions + 51/2" tubing + 8" tie back seal Assy. LD same. Lay down 3 stds of 6 1/4" drill collars. RIH w/4 1/2" Tubing. Recovered 1 drum of scale from tubing ID. Norm Reading 60 MR. Fish = readings under 50 MR. 3/29/2007 00:00 - 3/30/2007 00:00 Operations Summari----·~-·~·--·--··-·---··-- -.-.-----~-----.~-------"..-------. RIH w/4 1/2" tubing to 9672' Pooh & Lay down same. Make up BHA # 13 Jet Basket Assy + boot baskets + bumper sub jars + 6 43/4" Drill collars. + Enough 3 1/2" Drill pipe to cover 7" liner. Rih on 5" Drill pipe from derrick. ---_.~----_. 3/30/200700:00 - 3/31/2007 00:00 Operations Summary RIH w/ jet Basket. Tag up 15' inside 7" liner @ 10,531'. Work jet basket to 10,615'. Pump 20 bbl sweep. CBU. POOH. Service boot basket &jet basket. Jet basket full, recovered large pieces of scallop shoe junk, bands & packer rubber. + 4 gallons asphaltene's. Pull Ware bushing. 3/31/200700:00 - 4/1/2007 00:00 Operations Summary Test BOP'S & all other surface equipment 250/3000 psi. AOGCC Waived witnessing test. Had 3 valves fail on choke Manifold. Recieved verbal permission from AOGCC to continue work. Will make repairs next trip out. Set ware bushing. Make up BHA # 14. Shoe & finger basket + wash pipe extensions. RIH w/ same. -~-- -_._---_._,-_._,---~-._--_.~._._--_._-------_.. -----. ~--_._----- -.--.--- 4/1/2007 00:00 . 4/2/2007 00:00 Operations Summary Tag up @ 10,503'. Wash & Rotate to 11,075'. Appeared to be pushing junk. Pump 20 bbl hi-vis sweep oily sand & packer rubber in returns. Continue clean out to 11,100'. Hole took 200 bblloss. Losses slowed to 24 .6 bbls per hr. 4/2/200700:00 - 4/3/200700:00 Operations Summary Wash & ream F/ 11,510 - TO/ 12270'. Tag top of liner @ 12,270' DPM. Pump sweep(s) @ 11,886' . 20% fill in returns. POOH. Recovered one large chunk of packer rubber, 1 piece of band, & about two gallons of scale & asphaltenes. Fill Recovered on this trip 15 bbls. Fluid loss to well today 161 bbls. Total loss to well 668 bbls. Static loss rate this AM 3.5 bbls per hr. ----.------.- ,--.---.. ---------.,-.----------..'-- _._-".~._----_... 4/3/2007 00:00 . 4/4/2007 00:00 Operations Summary Make up 3-3/4" jet basket assy +36 joints 2 7/8" DP (1161.96') + 3 JTS 3 1/2" dp + bumper subljars + 643/4" Dc + pump out sub + 3 1/2" dp. (total tools below 5"= 3080.68'). RIH to 10,527'. Work past liner top. Continue RIH to 12.235' " Wash down through TOL @ 12,270'. Wash down F/ 12,270' - 12,670' with out rotation. Minumum fluid losses ----- -----..- ---- 4I~/ªº-o.?ºº.:ºº~ '4!!)l?OO"Lº(): O(J__~ . .~.. Operations Summary .. Continue clean out to 12,829' w/ 6.5 bbl per min @ 3000 psi. Not getting much back across shakers. Noted bridges & tight spots fl 12,672' spuded tight spots w/ 3-8 kip" At 12,829' stopped making progress & lost 800 psi pump pressure. POOH to 12,141' drop dart & shear pump out sub. POOH. 3.75" Jet basket packed with band debris along with asphaltiens. LD jet basket assy & pick up 3 Bladed Mill. RIH PU more 2 7/8" Drill pipe. Will have (2263' of 2 7/8" DP) max clean out depth will be 14,533'. -.. ----_.------ ~---_._._._-._---_._. 4/5/200700:00·4/6/200700:00 operations Summary """--...... n._. .-'- Pick up 5 Bladed Mill. RIH w/ 2263' of 27/8" DP. Max clean out depth will be 14,533'. RIH 3 1/2" Drill pipe & 5" Drill pipe to 12,800'. PU kelly. Wash f/ 12,800' - 12, 829' no exceptions. Continue clean out to 13,000' washing down with out pipe rotation. ,.------......---...------ - ---.,-----------------...'-- 4/6/200700:00·4/7/200700:00 Operations Summary Clean out 41/2" liner to 13,839'. Not seeing much work f/ 13,700' - 13,839'. Safety clamp to cut into kelly hose. Change out kelly hose. Test same to 4500 psi. RIH 13,829'. Clean out to 14,312'. Daily Operations 4/7/200700:00·4/8/200700:00 Operations Summary Cont to clean out from 14,312' to 14,542' @ 7.2 bbls per min. CBU 2.25 times. PU to 59' above 41/2" liner. Pumped 37 bbl 300 vis sweep. Drop dart. Shear out sub. CBU 3 times @ 16 bbls per min. Trash in returns after sweep. POOH. Seeing a great deal of black goop on 3 1/2" & 5" drill pipe. -"~."-.._~'---"------ 4/8/200700:00·4/9/200700:00 Operations Summary Conduct BOPE pressure test. AOGCC waived witnessing test. RIH 15 STDS 5" dp, Make up RTTS. RIH & set @ 630'. Pressure up on 9 5/8" to 500 psi 3x, with quick bleed offs. Established injection at 0.7 bpm @ 600-700 psi. Pumped 5.2 bbls. 133/8" slowly build to 200 psi during injection. Set RTTS @ 427'. Pressure tested 9-5/8" to 1100 psi for 30 min. Set RTTS @ 525'. Tested 1150 psi for 30 min ( good test). Re-set @ 630' with same leak results. POOH. MU bridge plug. RIH attempt to set Bridge plug @ 2800'. No Joy. POOH. Found loose cir valve on RTTS. RIH attempt to set RBP @ 2804' (No Joy). POOH found pass through mandrel was loose. RIH. Set Bridge plug @ 2800'. 4/9/200700:00·4/10/200700:00 Operations Summary Released from RBP @ 2800'. PU to 480'. Set RTTS. Could not get a packer test. Release pkr. Close BOPE. Pressure up on 95/8". Pumped 14 bbl into well at 0.7 bpm @ 950 psi on 133/8" x 9 5/8" annulus. POOH. Chk pkr. RIH w/RTTS. Set @ 2770'. Test RBP down drill pipe to 1000 psi. Had 200 psi bleed off in 30 min. Test 9 5/8" to surface against pipe rams. Pressure up csg to 1100 psi. 1180 psi on 133/8" x 9 5/8" annulus. Lost 200 psi in 30 min on both annulus's. POOH RTTS. MU RBP pulling tool. RIH latch RBP @ 2800'. POOH. No recovery. RIH w/ Pulling Tool. 4/10/200700:00·4/11/200700:00 Operations- Summary Continue to RI engage RBP @ 4751'. Release same. POOH. tools completely covered with sludge. PUMU RTTS. RIH set RTTS @ 6360'. Pressure test csg to 500 psi. Lost 21 psi in 30 min. Pressure test to 1012 psi. Lost 42 psi in 30 min. Release RTTS. RIH set pkr @ 10,404'. Pressure test csg to 500 psi. Lost 39 psi in 30 min. Pressure test to 1038 psi. Lost 61 psi in 30 min. Release RTTS. POOH. 4/11/200700:00·4/12/200700:00 Öperations Summary'" -------"',,- Cont POOH w/ RTTS lay down same. DSM Comment on sludge. RIH with 31/2" D.P. to cover 7" liner. PU 9 5/8" csg scr. Cont RIH with 5" D.P. Breaking cir often to keep form pileing anything up infront of us. Cir at 13.5 bpm for 30 min at 7" liner top. ,'.,__'._____.,_ _,_.._..__..m"____...._...___ 4/12/200700:00·4/13/200700:00 Operations Summary Stage in hole to 11,909'. Wash down to 12,270' and tag top of 4-1/2" liner. Circulate and work pipe. Work to treat fliuid with polymer breaker and bleach prior to sending to production. 4/13/200700:00·4/14/200700:00 Operations Summary'· .. Clean pits. Mix 3% KCI / FIW. Change well over. 4/14/200700:00·4/15/200700:00 op-ëratlOns Summary-- -----." Finish CBU. Monitor Well. POOH LD 5" DP. 4/15/200700:00·4/16/200700:00 Operations Sumrrïary---- ---. ----~----- RIH w/ 10,194' of 3-1/2" Kill. Land same. Install 3" BPV. Close & Lock Blind rams. Secure well. 4/16/200700:00·4/17/200700:00 Operations Summary Prepar:.~rig to suspend op~ations 0.'2. w~1I work. 4/17/200700:00·4/18/200700:00 Operations Summary ~emobe Equip fr()rT1 Grayling to Beach. 4/18/200700:00·4/19/200700:00 Operations Summary Cleaning Work area. 4/19/200700:00·4/20/200700:00 Operations· Summary Finish Demobe. 5/12/200700:00·5/13/200700:00 Opera(¡ons Summary .-. Reorganized Pipe Racks and Decks. Service Rig. -_.._---~-- - -.- ------------ --..-.------------....- - -- ------,------- -~_._--------- ---- Daily Operations 5/13/200700:00·5/14/200700:00 Operations Summary Service & repair rig equipment. 5/14/200700:00·5/15/200700:00 Operations Summary Rig Maintenance with 1/2 day crew. 5/15/200700:00·5/16/200700:00 Operations Summary _~g Maintenan~_\f\IÌ~~1/2 day crew. 5/16/200700:00·5/17/200700:00 Operations Summary Pull BPV. Install TWC. Test Blind Rams 250 - 3000 psi. Pull TWC. Circulate oil cap to production. Set BPV. Test BOPE 250-3000 psi. Fill well. Static loss rate @ 13 bph. Pull hngr to rig floor. LD same. RIH with DP out of derrick to 12,228'. 5/17/200700:00·5/18/200700:00 Operations Summary _._______M___m____~_.___m_.___ - ---~.~--- Continue RIH w/ 3-1/2" tbg on DP to 12,251'. CBU @ 12 bpm 2x. Loss 20 bbls while pumping. Static loss rate @ 7.8 bph. POOH. LD all SCC tbg. RIH w/ 19 stnds of 5" DP. PUMU RTTS storm pkr. RIH set same @ 396'. POOH. Jug test wellbore, against RTTS, to 1500 psi. ND BOPE & DCB. _._-~- 5/18/200700:00 - 5/19/2007 00:00 Operations Summary ND DCB. NU csg spool. NU BOPE. Install test plug. Shell & Funtion test BOPE. Pull test plug. Install wear bushing. RIH latch RTTS. Release same. Fill hole. 5/19/200700:00 - 5/20/2007 00:00 Operations Summary ------- _____.m.__ Static loss rate @ 6.5 bph. POOH LD DP & RTTS. CO rams to 7-5/8". Pull WR. Set test plug. Shell test BOPE. RU csg handling equip. PUMU JMZXP Single Grip Isolation pkr onto 7-5/8" liner. RIH wl7-5/8", 29.7#, L-80, Hydril 521 csg to 4116'. ~'_...'-'-------~-~--- 5/20/200700:00 - 5/21/2007 00:00 Operations Summary Continue RIH w/ 7-5/8", 29.7#, L-80, Hydril 521 Liner from 4115' to 10,360'. Static loss rate @ 3.6 bph. Circulate wellbore w/ 3% KCI/FIW w/ 1 % Corrosion inhibitor. RI while circulating at low rate to 10,516'. Set down 15k. No loss of returns. Pressure increased 60 psi. _~!?J!?º_ºI_O_o.:º0..:§!??l2007 OO:ºº-____ __~______ Operations Summary - ----- ---- Wash down from 10,515' to 10,519'. Slight pressure increase. Rotate pipe. Slack off. Same results. MIRU Eline. RIH w/ CCUGR. Log from 10,800'- 10,090'. Move pipe up 40'. Relog same interval. CCL depicted JMZXP Tie-Stem was stabbed into receptacle. RD Eline. RI set JMZXP w/ 55k down wt. PU to pull test hlds slip. Saw movement @40kover. RI reset JMZXP. Pressure test in neutral wt. 5/22/200700:00·5/23/200700:00 Operations Summary Slack-off 7-5/8" to neutral (250k). Pressure test to 500 psi against zone. No returns to surface. Break BOPE stack @ spool. install csg hngr slips. Hang csg w/ 115k on slips. NU BOPE stack. Close rams. Pressure test pack-off to 250 & 3000 psi for 30 min. RD csg handling equip. RI set RTTS Storm pkr @ 470' wi 3032' of 3-1/2" tail. Test 7-5/8" against storm valve to 1500 psi for 15 min. ND BOPE stack. 5/23/200700:00·5/24/200700:00 Operations Summary Break stack @ 7-5/8" csg spool. Cut csg. LD Csg stub. Install DCB tbg spool and packoff. Test to 3000 psi for 30 min. NU BOPE stack. Shell test same. Test attachment spool & DCB spool against blinds to 3000 psi for 30 min. Conduct full BOPE test (AOGCC waived witness). 5/24/200700:00·5/25/200700:00 Operations Summary'--- . ----- Set Wear bushing. Release RTTS. POOH LD same. PU 6" bit & String mill. RIH. Static Loss Rate @ 3.3 bph. 5/25/2007 00:00 . 5/26/2007 00:00 Operations Summary RIH to 12,261'. CBU. POOH. No Issues. .----- ----- ----- -.----- -_.-----~---~-~- .----.------.-.- .'.".---_. -----. ".-."----.- --_._-~- ----- -----..---.---.-------- -~._- -----'.----- Static Loss Rate @ 3.6 bph. ----- ---- ----"-----.,------..--- Daily Operations 5/26/200700:00 - 5/27/2007 00:00 Operations Summary Continue POOH. LD CO BHA. PUMU 7" RTTS. RIH Set same @ 11,110'. Attempt to Jug Test Wellbore. Note returns on 7-5/8" x 9-5/8" Annulus. Establish injection rate @ 0.7 bpm w/ 2300 psi. Static Loss Rate @ 3.0 bph. 5/27/200700:00 - 5/28/2007 00:00 Operations Summary POOH LD RTTS. PU 2506' of 2-7/8" tbg. RI on DP to 14,698'. Pump 117 bbls Diesel sweep. CBU. On bottoms up diesel sweep appeared to be very black & dirty. Static Loss Rate @ 3.1 bph. 5/28/200700:00 - 5/29/2007 00:00 Operations Summary Pumped 2nd diesel sweep. CBU. Sweep returned w/ fines and dissolved Hydrocarbons. Monitor losses @ 2.8 bph. POOH LD 2-7/8". PU RTTS. RIH set RTTS @ 10,482'. Attempt to jug test 7-5/8" liner to 2500 psi. Lost 250 psi in 30 min. Reset pkr. Same results. No returns on 7-5/8" x 9-5/8" Annulus. 5/29/2007 00:00 - 5/30/2007 00:00 Operations Summary ~ ~ ._~,--_._.~~---------,.".- Retest same results. POOH. LD RTTS. Conduct BOPE test. PU FastDrill Bridge Plug. RIH on DP. Avg Static Loss Rate @ 2.3 bph. 5/30/2007 00:00 - 5/31/2007 00:00 Operations Summary Continue to RIH. Set FasDrill @ 10,690'. Attempt to pressure test same. Establish injection rate of 3 bpm @ 2100 psi. No returns on 7-5/8" x 9-5/8" annulus. Monitor Losses @ 11.6 bph. POOH. PU 17 joints of 2-7/8" tbg & XO. RIH on DP to 10,689'. Spot 50 bbls of sized salt pill. Squeeze same away. 5/31/2007 00:00 - 6/1/2007 00:00 Operátions Summary Monitor losses @ 8.0 bph. CBU condition fluid. Mix 2nd size salt pill. checked losses again @ 0.8 bph. Abort pumping size salt pill. Mix/pump/Lay-in 15bbls of LXT cmt on top of BP. POOH 7 stands. Monitor well @ 3 bph losses. CBU. POOH. ----------.-. 6/1/2007 00:00 - 6/2/2007 00:00 Operations Summary Monitor losses @ zero bph. Continue to POOH wi DP. PUMU 6-3/4" bit & 7-5/8" scraper. RIH w/ C/O assy to polish TOC down to XO. Tagged XO @ 10,503'. No cmt tagged. Pressure 7-5/8" to 1000 psi. Leaked off to 825 psi in 30 min. Pressure to 1800 psi. Leaked off to 1300 psi in 30 min. 6/2/200700:00 - 6/3/2007 00:00 OperatlOns'Summary --.-.---..-.--.. .. ....~...- POOH wi DP. LD C/O assy. RU Eline. RIH punch 7-5/8" csg 2x @ 10,487' to 10,497' w/ csg punch gun. RD Eline. Establish circulation rates & pressures. PUMU FastDrill retainer on DP. RIH wi same. n _ _ _ ._..~__.,__",__,,_,_,,_ --_.-._---- ------,---_.,_..-._."._-~._"._--------------_._--~---- - --'-----,-- ----...------- -,------...-.-- 6/3/200700:00 - 6/4/2007 00:00 Operations Summary Continue RIH w/ FastDrill Retainer on DP. Set same @ 10,400'. Establish circulation rates & pressures thru retainer. Attempt to pressure test DP x csg annulus to 2500 psi. Leaked to 200 psi in (1) hr. PU above retainer. Jug tested 7-5/8" to 2500 psi for 30 min. RI stab into retainer. RU cementers. Pumped 100 bbls of FIW/3% KCI w/ 1 % corrosion inhibitor. Followed by 67.6 bbls of LXT 15.8 ppg cmt. Displace DP to within 1 bbls of retainer. PU CBU. POOH w/ DP. RU wireline. RIH w/ temp/pressure tool. Log from 4000' to 10,400'. POOH w/ tools. _._~-~-- 6/4/2007 00:00 - 6/5/2007 00:00 Operations Summary Finish Pressure Temp Log. RD slickine. Temp anomaly depicted TOC @ 7,441 rkb slm. PU 75/8" CO assy (6 %" Bit + 7 5/8" csg scr + 2ea Boot Subs + Bit sub w/float + 94 %" D.C. + 3 Y:z" IF 13.3 S-135 D.P. to surface). RIH to 10,390 started seeing cement stringers. Jug test 7-5/8" to 2500 psi for 30m in. RI Clean out cement & drill Retainer at 10,400dpm. Good hard cement to 10,488 rkb dpm. Very little or no cement from 10,498 to 10,503 rkb dpm (7" cross Over). Circulated around high vis sweep. 6/5/200700:00 - 6/6/2007 00:00 -Öperations Summary ---'- -----.- Cont POH w/ 6-3/4" clean out assembly. LD CO assy. Clean boot subs. Pressure test BOP equipment to 250psi low & 3000psi high. Had trouble with one Kill Line valve. Change out same. Pull test plug and set wear ring. MU 6" clean out assembly (6" bit + 6" string mill + 2ea Boot Subs + 9 4 %" DC). RIH on 3 %" IF 13.3 S-135 DP. -------.--.- 6/6/200700:00 - 6/7/2007 00:00 Operations Summary Continue RIH. Tag TOC at 7" x 7-5/8" XO @ 10,503'. CO rotten cmt to BP @ 10,690'. Drill up FastDrill BP @ 10,690'. Continue CO of rotten cmt to 10,720'. Found hard cmt @ 10,720'. Continue CO of hard cmt stringers from 10,720' to 11,357'. Pump vise sweep around. CBU. Daily Operations 6/7/2007 00:00 - 6/8/2007 00:00 Operations Summary . -----------..-..--.-.-----~----- -.~-~-- Continue pumping 25 bbls sweep around. RI tag TOL @ 12,260'. No problems. Monitor well. No static losses. POOH. LD BHA. Clean boot subs. PU 2506' of 2-7/8" tbg & MS. RIH on DP. Wash to 12,322'. Plugged pipe. -~,_._----,~--~------~.._------~----- 6/8/200700:00 - 6/9/2007 00:00 Operations Summary Worked to unplug pipe. Continue to wash to 14,700' @ 5.7 bpm. Monitor well. Static losses @ 5.6 bph. PU to 12,228'. Change well over to clean 3% KCI/FIW. 6/9/200700:00 - 6/10/2007 00:00 Operations Summary Clean Mud pits. Monitor well. Static losses at 2.8 bph. POOH laying down DP. 6/10/200700:00·6/11/200700:00 Operations Summary - - ---~--~~-- Continue to LD DP. PUMU Lower tandem motor. 6/11/200700:00·6/12/200700:00 Operations Summary . ----.----~-.---~---- .------..- Continue to PU ESP_motor and pump. RIH on 3-1/2" tbg. Install Clamps &~LM's a~ per GLM_gesign. ___ 6/12/200700:00 - 6/13/2007 00:00 Operations Summary Splice at 5995'. Pressure test chem inj line to 5000 psi. Meg and test phoenix tool before and after splice. TIH w/ ESP on tubing. Splice cable and test chem inj lines and meg and test phoenix gauge before and after. While splicing pump 45 bbls of 3% KCL down tbg. Continue to trip in hole with BHA. PU MU 11" FMC Tbg Hgr w/ penetrator and two 3/8" NPT control lines. Make final pig tail splice. Install check valves. Run tests. Land ESP assembly at 10209'MD. Test cable LD landing joint. Rig down WOTCO. Remove rams from double gate. _.~--_._- --,_..__._---~--_.~- _._~~ ---~.- --~--_.~_.__.,._-------------_._--_._~_.._-_.__..._,.-_.,._--~....__.-. 6/13/200700:00 - 6/14/2007 00:00 Operations Summary ND BOPE. Test Cable NU Tree. ------------.,--.--,--,-----..----.-,.----'---"..----- ------.------.- -.'----- 6/14/200700:00·6/15/200700:00 Operations Summary Continue NU tree. Pressure test same. Demobe rig and equipment. 6/15/200700:00·6/16/200700:00 OperationS-Summa~--~-------- __n_ ---.------ --~- .continue Demobe and house cleaning. 6/1ß/2007 00;00·6/17/2907 QO:OO Operations Summary - ------- -----,.-,---.----- Continue Demobe and house cleaning. 6/17/200700:00 - 6/18/2007 00:00 Operations SÙmma~------'--------- -------------- Continue [)emobe afld house clean~n~ 6/18/200700:00 - 6/19/2007 00:00 Operations Summary COfltinueDemobe and CleanuL___ ______ __~_ . ________ 6/19/200700;00 - 6/20/2007 00:00 Operations Summary Finish demobilizing from platform. ".'- --- --..--_._------'-,.- ----.-.------- _.,----.-----.-----,- -,---_.." --- --~-'- -,--_.'--- .---'" -_._--_.__._-_._~-- "'FINAL REPORT'" -~--_._-_._-~._--_._.._-- ~_.-.._._.._._.-_._----~--.._._-- . ----,,-------.....--.-.-.-------- o o 1000 2000 3000 4000 - ... (,) ~ 5000 - C :æ I .r::. ... 6000 Q,. (,) C 7000 8000 9000 10000 11000 60 Report date: 8/6/2001 400 800 70 80 1200 Pressure (psia) 1600 2000 2400 2800 3200 3600 4000 90 100 110 120 130 140 150 160 170 Temperature (Deg. Pressure . . SARAH PALIN, GOVERNOR AIßAtliJiA OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 , ..... 0- ~ ..~ ..._~ ......- V\l'õ J oqq Re: McArthur River Field, Hemlock Oil Pool, G-15RD Sundry Number: 307-158 5~NED MAY ·2' 2 Z007 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissioner DATED this/2 day of May, 2007 Enc!. . . Chevron -= Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com May 9,2007 Re~E Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 99501 MAY 0 9 2007 Alaska & Gas Cons. Commission Anchorage Re: Grayling G-15RD, Application for Sundry Approval Dear Mr. Maunder, Attached for your approval is an Application for Sundry Approval (Form 10-403) for the above referenced well. The proposed work will be undertaken to perform workover operations and restore the ESP in well G-15RD. / G-15RD has communication between the 9-5/8" PC and the 13-3/8" SC. After removing the tubing and cleaning out the wellbore, a USIT log indicated that the 9-5/8" casing has significant wear from 600' to 1650' through a high "dog leg" area. A RST test packer substantiated the casing leak between 600' and 1650'. Operations were suspended on G-15RD to move resources over to Monopod to remedy / an integrity event on A-11. This proposed reinstatement of operations on G-15RD is to continue the workover to restore wellbore integrity by running a tie-back from surface to 7" liner top @ 10,516' and complete the well with an ESP. / If you have any questions, please call me at 263-7657 or Mr. Steve Tyler at 263-7649. For Timothy C. Brandenburg Drilling Manager Attachment TB:sk Cc: Well File Steve Tyler Union Oil Company of California I A Chevron Company http://www.chevron.com . STATE OF ALASKA (flY ~'81·.::cEIVED ALA Oil AND GAS CONSERVATION ëdM~IÒN "" _I "'. APPLICATION FOR SUNDRY APPROVAl,.¡$( 0 9 2007~"\ 20 MC 25 280 1. Type of Request: Abandon D Alter casing 0 Change approved program D 2. Operator Name: Union Oil Company of California , 3. Address: PO Box 196247, Anchorage, AK 99519 Suspend D Repair well 0 Pull Tubing 0 . Operational shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 ' Stratigraphic D peAlàatw[[lll & Gas CaMUliommission Other 0 Stimulate D Ymelfintagwon D ESP Replacement Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 198-099 / Service D 6. API Number: 50-733-20149-01 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? YesD No 0 G-15RD - 9. Property Designation: tb _.., 1 O. KB Elevation (ft): 11. Field/Pool(s): Grayling Platform/Cook Inlet AJ)c, Iß711 I"'Ç.l1·Ø 1 42.9 / McArthur River Field / Hemlock / 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15,114' ~ 9,169' / 15,070' 9,178' n/a n/a Casing Structural Conductor 600' 17-3/4" Surface 5,802' 13-3/8" Production 10,845' 9-5/8" Liner 1,849' 7" Pre-drilled Liner 2,815' 4-1/2" Perforation Depth MD (ft): Perforation Depth TVD (ft): Length Size MD TVD 600' 599' 5,802' 4,640' 10,845' 8,483' 12,365' 9,404' 15,072' 9,178' Tubing Size: Tubing Grade: 4-1/2" L-80 Burst Collapse 1340 psi 3,090 psi 5,750 psi 8,160 psi 1,540 psi 3,090 psi 7,020 psi n/a n/a Tubing MD (ft): 10,194' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: Description Summary of Proposal l.jJ Detailed Operations Program D BOP Sketch 0 15. Estimated Date for 14. Well Class after proposed work: Commencing Operations: May 11, 2007 Exploratory D Development 16. Well Status after proposed work: Oil 0 / Gas D WAG D GINJ D o Service D 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg Title Drilling Manager Signature-?. ~ C r'5_ ~hone 907-276-7600 // L.---" Date: Plugged WINJ D D Abandoned WDSPL D D Contact Steve Tyler 263-7649 Date 5/8/2007 ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2f) '7 - I 59 Plug Integrity D BOP Test % Mechanical Integrity Test D Location Clearance D Olhe' '!.t1OO~->, 'ß(:>ç>~~. ß\·,~....~ \'\:. \-.c~~~ <>--~, % \:\ ..." ~ \)\~ ,-~\.i. ~",~\ð ~~,,~\-~\--...., o...~~\\~ \. ~~ ~~~~ t . \-.:3o~\.O~ \t:..~-\- ~~'\~ ""h "-\~~'i~C\-~"->'-.)~\~ ~ro~\;.)d~t',. Subsequent Form Required: ~ (J '-\ r7 /..,- RBDMS BFL MAY 2 1 2007 APPCO"dbyØY~~ COMMISSIONER :::~:'~':;'ON O,re. 5/17/7 / Form 10-403 Revised 06/2006 nRIGtNAL ""~L Submit in Duplicate ,~~?:6?~$""'D1 .. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 . . G-15RD Workover Summary Pull ESP, Restore Wellbore Integrity, CO t/ 14,700', Run ESP #' Activate Rig on G-15RD. Test BOPE. Remove BPV. PUMU Land joint. BO LDS. PU tbg hngr to rig floor. Remove tbg hngr. PU an additional 400' of 3-1/2" tbg. RIH to 7" liner top @ 10,516'. CBU 2x. POOH std back 3-1/2" tbg. RI set test plug. Test BOPE Blind Rams. PU RTTS storm pkr plug. RIH set same. ND BOPE. NU 7-5/8" csg spool. NU BOPE. Test same. RI latch retrieve RTTS storm pkr. POOH. PU/MU Tie-back seal assy wi hngr onto 7-5/8" liner. RIH wi 7-5/8" liner. Stab into 7" tie-back receptacle. Install csg slips. Land liner. Pressure test body seals. ... ~\\-\ ~-,"\l\ 'Q.\\~ -\-0 ~* ~~f>~ -\-0 astor' PU 2500' of 2-7/8" tbg. RIH on 3-1/2" tbg. CirculatelCO to 14,700'. Pump multiple diesel ~S ~ ~ sweeps. CBU each sweep. '~ r POOH LD 3-1/2" Spcl butt joints, only., ~51\",\ RU to run ESP. PU pump and motor. PIU ESP and TIH on 3-1/2" IBT tubing. PIU replacement joints. Splice cable as needed PIU Tbg hanger, Land tubing with control line and cable spliced through hanger. LID landing joint and RID tbg tools. Install BPV. / NID bell nipple. NID BOPE & Riser. NIU adaptor & tree. Pull BPV, Install TWC and Shell test tree. Turn well over to production. Demobe well . . Grayling G-15 ESP Workover to Replace Failed ESP- Unocal Alaska requests Sundry Approval to peñorm workover operations on Grayling G-15 with the following exceptions to suñace equipment requirements: 1.) To employ use of 2" dual manual choke manifold, as per attached diagram, downstream from 4" 5m HCR valve on choke line (outer of two valves will be an HCR valve). From HCR, system will be stepped down to 2" 5M flanged hose to 2" 5M manifold with dual 2" 10m chokes. No chicksans or swivels will be utilized. 2.) To take returns to the production low pressure separator and/or a poor-boy de-gasser as required. 3.) Test Blind/Shear Rams after tubing is retrieved from well bore. A 4-1116" SM targeted 90 Deg B 41116" SM Shaffer "¡:¡" HCR Valve C 4 1116" SM Manual gate valve I) 3 1116" SM Manual gate Kill line E 3 1116" 5M Manual gate Kill line F 3-1116" SM targeted 90 Deg \3 111S"SM x 4 11S"SM DSA 3.39' Top of drill deck Graylock Hub GRADE 17-3/4" .312W Spiral Weld surf 13-3/8" 61 J-55 Buttress 12.15" 4198 sxs surf 9-5/8" 9-518" 9-5/8" 9-5/8" Window 7" Buttress Buttress Buttress Buttress 8.681 8.835 8.755 8.681 1000 sxs G TOL@ TOL @ 12,257' 7 , f8 I I Ported liner I I Hemlock Bench 2, 3, 4, & 5. I I I I I I .J l 22" ................... 8,5 Ius 17-3/4"............. 84 hrs 13-3/8" ............. 304 hrs 9-5/8" ...............350 hrs 7" ..................... 110 hrs 800'...................5.03° /100' 900' ...................4.54° /100' 1050'.................4.50° /100' 1100'.................5.62° /100' 1150' .................4.66° /100' 1200'.................5.04° /100' 1250'.................5.25° /100' 1300' .................4.09° /100' 4500' .................5.32° /100' 4550' .................6.52° /100' 4600' ................. 7 ,42° /100' 4650'.................6.58° /100' 4700'.................6.27° /100' 4750' .................6.36° /100' 4800' .................4.08° /100' 4900'.................4.86° /100' 4950' .................5.1)2° /100' 5000' .................4.58° /100' 5300'.................5.13° /100' 5350' .................5.04° /100' 9776' .................8.77° /100' TD = 15,114'; ETD =15,070,' 91° /12,805'; 99° /13,281'; 104° /15,049' @ 7 " I Ported liner I Hemlock Bench 2, 3,4, & 5. I I I .J '8 I I I i I l TD = 15,114'; ETD =15,070,' 91° 112,805'; 99° 113,281'; 104° 115,049' 13-318" 61 J-55 Buttress 12.15" Surf. 5802' 15" 4198 sxs 9-5/8" N-80 Buttress 8.681 9-5/8" N-80 Buttress 8.835 12-1/4 1000sxs G 8452' Calc 9-5/8" N-80 Buttress 8.755 9-5/8" N-801P-110 Buttress 8.681 Window 7" 6.184 3.958 JEWELRY 4. ~1O,125' ~ 10,217' 5. 6. 12,256' 6.188" 3.850" Centrílíft ESP wi Phoenix Gauge Baker JM-ZXP tie-back seal assembl wi hlds Knock out Isolation Valve (3.85" ID after drill out) 22" ................... 8.5 IIrs 17-3/4" ............. 84 IIrs 13-3/8" .............304 IIrs 9-5/8" ............... 350 IIrs 7" ..................... 11 0 Ius 800' ...................5.03° I 100' 900' ...................4.54° I 100' 1050'.................4.50° I tOO' 1100'.................5.62° 1100' 1150' .................4.66° I 100' 1200'.................5.04° 1100' 1250' .................5.25° 1100' 1300' .................4.09° 1100' 4500' .................5.32° I 100' 4550'.................6.52° 1100' 4600'.................7,42° 1100' 4650'.................6.58° 1100' 4700'.................6.27° I 100' 4750'.................6.36° 1100' 4800'.................4.08° 1100' 4900'.................4.86° 1100' 4950'.................5.02° 1100' 5000' .................4.58° I 100' 5300'.................5.13° 1100' 5350' .................5.04° I 100' 9776'.................8.77° 1100' I REVISED: 5/8/2007 REVISED BY: SLT . . SARAH PALIN, GOVERNOR AI.lASIiA OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg UNOCAL PO Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Hemlock Oil Pool, G-15RD Sundry Number: 307-061 \6\Ib/OQ9 Dear Mr. Brandenburg: SCANNED FEB 1 6 2007 Enclosed is the approved Application for Sundry Approval relating to the above referènced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ISday of February, 2007 Encl. 1. Type of Request: Abandon ~~uspend D Operational shutdown D Perforate D Waiver D "0- Other 0 Alter casing Repair well 0 Plug Perforations D Stimulate D Time Extension D ESP Replacement Change approved program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory D 198-099 , 3. Address: Stratigraphic D Service D 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20149-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes D No 0 G-15RD , 9. Property Designation: ¡tþ'- /1>"177 J1;:..I<loO 10. KB Elevation (ft): 11. Field/Pool(s): GravlinQ Platform/Cook Inlet 42.9 McArthur River Field / Hemlock t 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15,114' 9,169' 15,070' 9,178' n/a n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 600' 17-3/4" 600' 599' 1340 psi Surface 5,802' 13-3/8" 5,802' 4,640' 3,090 psi 1,540 psi Production 10,845' 9-5/8" 10,845' 8,483' 5,750 psi 3,090 psi Liner 1,849' 7" 12,365' 9,404' 8,160 psi 7,020 psi Pre-drilled Liner 2,815' 4-1/2" 15,072' 9,178' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): n/a n/a 4-1/2" L-80 10,189' Packers and SSSV Type: Baker Model F Permanent Packer with 18' seal Packers and SSSV MD (ft): 10,440' bore extension. 13. Attachments: Description Summary of Proposal l,;J] 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch 0 Exploratory D Development 0 Service D 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 22, 2007 Oil 0 Gas D Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Comm ission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ( - ?9- -C./S 4hone 907-276-7600 Date 2/12/2007 ~~ -:- /' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ð) 7 - D ÚJ I Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D othe, ~ 000 """ ,",-\..., ....."''''- ßC)\> ~. \':, \ \.:¡j., -<>.--t 1".«. \<:<, r <>- ~-\<: '\ ~ \-\ ""' I i,,,\:,\ "" <:..~~ ~N.\ro\..~ ~&J\~\<:..ú.\-"oc-....~ (J..C-CCè~'o\<ê:: "o..~ bcë ' ~,. . ~o.ç.\E;)~ks\- ~u\~<0 '-4.sh'^' \L\~v..'i~ Ó\-- ~<>\JII~~ ,?ro~~~~ S''''",'eot Fo"" R""""", '\C)~ ,...} ~~ COMMISSIONER APPROVED BY Date: tfI-j),d¡-- Approved by: THE COMMISSION Form 10-403 Revised 06/200~ b(p T'C;..Ÿ\!.!~ - wnl 1~~ Dr". HJj J Ii ZUU! Submit in Duplicate ¡!;..Jf;.., ¡ ,L '-' ..¿þ 1.. ." Ð'T:S .z~ Kt:\.,.,t:IVCU . STATE OF ALASKA '/.:L7 f. efP ALA OIL AND GAS CONSERVATION COM.ON µ"''''1 FEB f~ ¿DOl APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cons. Commission 20 MC 25 280 iV I; · Grayling G-15RD Cover Sheet '. ',. Brief Discussion: G-15RD has an apparent breach in the 9-5/8" PC with communication to the 13-3/8" SC. .., Currently the well is shut in due to inflow performance from the reservoir. This proposed workover is to restore wellbore integrity, establish connectivity with reservoir and change-out the ESP. . . Grayling G-15 ESP Workover to Replace Failed ESP Unocal Alaska requests Sundry Approval to perform workover operations on Grayling G-15 with the following exceptions to surface equipment requirements: 1.) To employ use of 2" dual manual choke manifold, as per attached diagram, downstream from 4" 5m HCR valve on choke line (outer of two valves will be an HCR valve). From HCR, system will be stepped down to 2" 5M flanged hose to 2" 5M manifold with dual 2" 10m chokes. No chicksans or swivels will be utilized. 2.) To take returns to the production low pressure separator and/or a poor-boy de-gasser as required. 3.) Test Blind/Shear Rams after tubing is retrieved from wellbore. !15RD Workover summarft Pull ESP, Restore Wellbore Integrity, CO t/ 14,700', Run ESP MIRU Pumping equipment Eline and slickline. RI perforate tbg below "X" nipple @ 10,042'. Pump FIW down tbg while taking returns out csg annulus. RU to pump FIW down 13-3/8" while taking returns out 9-5/8". Run temp log on SL while circulating wellbore. 2 Mobe Rig onto G-15RD. Set Bpv. ND tree. NU BOPE. Test same. 3 Remove BPV. PUMU Land joint. BO LDS. PU tbg hngr to rig floor. Remove tbg hngr. 4 Cont POOH wI tbg. Stand-back same. LD ESP BRA. 5 RI set test plug. Test BOPE Blind Rams. 6 PUMU 7-3/4" reverse or venturi junk basket w/ 8-W' shoe (7-3/8" body). RIH on 5" DP to 10,300'. Wash down to "FB" pkr @ 10,438'. POOH. 7 PUMU 9-5/8" tandem csg scrapers w/ 4-%" reverse or venturi junk basket (wI 3-5/8" body) w/ 3- 12" tbg. RI 10,440' on 5" DP. POOH. 8 RU Eline. PUMU USIT Logging tool. RIH log from TOL @ 10,440' to Surface. PUMU csg caliper log tool. RIH log from TOL to surface. POOH RD Eline. 9 PUMU 6" LSA. RIH on 4-W' completion tbg. Stab into pkr @ 10,438'. Land tbg. ND BOPE. NU Tree. Test same. Release Rig. Suspend Rig Operations 10 MIRU Slickline. Gauge, fish bands and misc equipment from well. RD Slickline 11 MIRU CTU. Accept same off Turnkeyed Demobe. 12 RIH to 14,700'. CO any encountered Fill. POOH. Demobe CT Restart Rig Operations. Mobe cementers. Mobe Enventure 13 Set BPV. ND tree. NU BOPE. Test same. Remove BPV. PUMU Land joint. BO LDS. PU tbg hngr to rig floor. Remove tbg hngr. POOH wI tbg. LD same. (Send tbg to beachfor inspection) 14 RI set test plug. Test BOPE Blind Rams. 15 PUMU pkr plug. RIH. Latch plug into pkr @ 10,438'. POOH wI running tool. 16 PUMU RTTS. RIH. Set RTTS below established csg breach. Test PC below RTTS. PU above csg breach. Set &, ~est PC above RTTS. POOH. Items 17 thru.Jrarho~~{;,feJt...... \E.r ~(\, 17 P UMU HES Retrievable Bridge plug & RT1:~. RlH on DP. Set BP below esg breach. P U spot 15 sx of sand on top of BP. P U above csg breach. Set RTT.S. Establish in) rates & pressures. 18 Mix pump/squeeze 500 sx of cmt into csg breach. 19 CBU. POOH WOC 12 hrs. 20 PUCO as,~J' (8-0" string mill). RIll. Drill/CO emt. Pressure test 9-5/8" csg to 1500 psijl30 min. 21 Continue RIH. CO to RBP. POOH. PU RES Ret tool. RIH ret RBP. POOH. LD same. 22 PU Eventure 200' expandable csg wI associated tools. RIH. Expand csg across breach. POOH. LD tools. 23 PU Drill/CO assy. RIH drilllCO Launcher @ end of expanable liner. Pressure test wellbore to 1500 psi. POOH. LD BRA 24 PUMU Pkr plug retrieving tool. RIH CO to plug. Latch & retrieve same. POOH. LD DP. 25 RU to run ESP. PU pump and motor. PIU ESP and TIH on 4-1/2" tubing. PIU replacement joints. Splice cable as needed 26 PIU Tbg hanger, Land tubing with control line and cable spliced through hanger. LID landing joint and RID tbg tools. Install BPV. 27 NID bell nipple. NID BOPE & Riser. NIU adaptor & tree. Pull BPV, Install TWC and Shell test tree. Turn well over to production. 28 Demobe well TOL @ 12,257' 7 , f8 i I Ported liner i I Hemlock Bench 2, 3, 4, & 5. I i i i i i .J l TD = 15,114'; ETD =15,070,' 91° /12,805'; 99° /13,281'; 104° /15,049' WT GRAm~ Hole Cml Cml To .312W Spiral Weld 22" 700 sxs G Lost returns as cement reached surf 13-318" 61 J-55 Butkess 12.15" Surf. 5802' IS" 4198 sxs Good returns to surf 9-518" 47 N-80 Buttress 8.681 9-518" 40 N-80 Buttress 8.835 12-114 1000 sxs G 8452' Calc 9-518" 43.5 N-80 Buttress 8.755 13·3/8" 9-5/8" 47 N-801P-1l0 Buttress 8.681 Window 7" NO 1. De Ih 42.9' m 3.958" crw 4-112" DCB Tubing Hanger: 4- 112" LTC top & btm with BIW feed throu h enetrator, 2 x 3/8" in'ection line 4-112" L-80 12.6 Ib/ft Imp Butt Tubing (spc- 4.915") Note: Cannon Clam s. Mixture ofre ular & SCC cis 7 ea. 4-1/2" SF-02 McMurry GLM SFO-2RK wI Dummy 1- !/2" R-2 va!ve 7.063" x 6.141" Actual measured depths = 2,987',4,590',6,194',7,240',7,916',8,502',9,090'; 2. +1-10,192' 3.958" 3. 3.833" 2000: Lost (3) Anti-blowup tool arms (6"L x V,"T x 2-W'W) Lost (4) %" SS Bands off Control line. Lost 6 Super Bands and small pieces of armor. 2002: Lost 5 Super Bands. 2006: Lost 13 Super Bands (I V.") and 25' of Flat Guard. Total LIH: (3) 6"L x V,"T x 2·V,"W Anti-Blowup tool arms. (4) %" SS Contro! Line Bands. (24) Super Bands (1) 25' piece ofF!at Guard 800' ..................5.03° /100' 900' .................. 4.54° /100' 1050' ................4.50° 1100' 1100' ................ 5.62° /100' 1150' ................ 4.66° /100' 1200' ................5.04° /100' 1250' ................5.25° /100' 1300' ................4.09° /100' 4500' ................ 5.32° /100' 4550' ................ 6.52° /100' 4600' ................7.42° /100' 4650' ................ 6.58° /100' 4700' ................6.27° I 100' 4750' ................ 6.36° /100' 4800' ................ 4.08° 1100' 4900' ................4.86° 1100' 4950' ................ 5.02° 1100' 5000' ................ 4.58° /100' 5300' ................ 5.13° 1 100' 5350' ................5.04° 1100' 9776' ................ 8.77° /100' I 22" ................... 8.5 Ius 17-314"............. 84 hrs 13-3/8" ............. 304 hrs 9-5/8" ............... 350 hrs 7" ..................... 110 hrs REVISED: 2/1/2007 REVISED BY: BCA RKB :: 42.9' Rig Floor to DCB TBG Spool SIZE 17-314" 2 7 , &f8 I I Ported liner I I Hemlock Bench 2,3,4, & 5. I I I I I I J l TD = 15,114'; ETD =15,070; 91° 112,805'; 99° 113,281'; 104° 115,049' 13-3/8" 9-5/8" 9-5/8" 9-5/8" 9-518" Window 7" WT Hole Cmt To .312W 22" 700 sxs G Lost returns as cement reached surf 61 J-55 Buttress 12.15" Surf. 5802' 15" 4198 sxs Good returns to surf 47 N-80 Buttress 8.681 67' 40 N-80 Buttress 8.835 5883' 12-1/4 1000 sxs G 8452' Calc 43.5 N-80 Buttress 8.755 7900' 47 N-80/P-1I0 Buttress 8.681 10,845' 10,857' 12 365' I JEWELRY NO De ill 1. 42.9' :1.0 3.958" 6. 7. 8. 22" ................... 8.5 hrs 17-3/4" .............84 hrs 13-3/8" .............304 hrs 9-5/8" ............... 350 hrs 7" ..................... no hrs 800'...................5.03° 1100' 900' ...................4.54° 1100' 1050'.................4.50° 1100' 1100'..............,..5.62° 1100' 1150'.................4.66° 1100' 1200'.................5.04° 1100' 1250' .................5.25° 1100' 1300' .................4.09° 1100' 4500'.................5.32° 1100' 4550' .................6.52° 1100' 4600' ................. 7.42° 1100' 4650' .................6.58° 1100' 4700' .................6.27° 1100' 4750' .................6.36° 1100' 4800'.................4.08° 1100' 4900' .................4.86° 1100' 4950'.................5.02° 1100' 5000' .................4.58° 1100' 5300'.................5.13° 1100' 5350' .................5.04° 1100' 9776'.................8.77° 1100' 1 REVISED: 2/1/2007 REVISED BY: BCA \ 3 1116"SM x 4 116"SM DSA 3.39' Top of drill deck A 4-1116" SM targeted 90 Deg B 41116" SM Shaffer "B" HCR Valve C 41116" SM Manual gate valve D 31116" SM Manual gate Kill line E 3 1116" SM Manual gate Kill line F 3·1116" SM targeted 90 Deg Graylock Hub (if of drill deck A 41/16" 5M CIW"I=" HCR Valve B 41/16" 13M Marlllal gate valve C :3 1/16" 5M MarllJal gate Kill line D 31/16" 5M M.uma! gate Kill line RECEIVEU ) STATE OF ALASKA ) ALAS..., OIL AND GAS CONSERVATION COMM~v"ION .IAN 2 7 2006 REPORT OF SUNDRY WELL OPERA TIO_ka Oil & Gas Cons. Commission U D D 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 42.9' 8. Property Designation: Grayling Platform/Cook Inlet 11. Present Well Condition Summary: Total Depth measured 15,114' true vertical 9,169' Effective Depth measured 15,070' true vertical 9,178' Casing Structural Conductor Surface Intermediate Liner Pre-drilled Liner Length Size 600' 5,802' 11,210' 1,849' 2,815' 17-3/4" 13-3/8" 9-5/8" 7" 4-1/2" Perforation depth: Measured depth: n/a True Vertical depth: n/a Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 0 Stratigraphic D feet feet ^ß£hor~08 Stimulate U Other L::J E:'SP Workover Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 198-099 Service D 6. API Number: 50-733-20149-01 9. Well Name and Number: Trading Bay Unit G-15RD 10. Field/Pool(s): McArthur River Field/Hemlock Oil Plugs (measured) n/a Junk (measured) n/a feet feet SCANNE(v JAN ~Th 1 2005 MD TVD Burst Collapse 600' 599' 5,802' 4,640' 3,090 psi 1,540 psi 11,210' 8,733' 5,750 psi 3,090 psi 12,365' 9,404' 8,160 psi 7,020 psi 15,072' 9,178' 4-1/2", L-80 @ 10,280' Baker Model F Permanent Packer with 18' seal bore extension @ 10,440' Treatment descriptions including volumes used and final pressure: n/a Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 454 5,068 80 234 9,346 5 15. Well Class after proposed work: ExploratoryD Development 0 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 369 514 x Contact Larry Buster 263-7853 Printed Name Timothy C. Bra. nd~nb~ ...--'"'\ 7;øc~ ~/ Signature - ~_ ~ -- /" r -7 /' ;- ~ Form 10-404 Revised 04/2004 RBDMS BFl JAN 3 0 2006 Tubing Pressure 110 100 Service D GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 305-300 Title Drilling Manager Date 1·- 2)-~ AFE 164546 Phone 907-276-7600 Submit Original Only ._".'- -... .................. Well Name G-15RD Primary Job Type ESP Jobs Lease/Serial ADL0018777 I Primary Well bore Affected Main Hole AFE No. I Buster QC Eng 164546 Daily Operations 12/19/200500:00 -12/20/200500:00 Operations Summary Rig Repair 12/20/200500:00 -12/21/200500:00 Operations Summary Work on BOP Stack 12/21/200500:00 -12/22/2005 00:00 Operations Summary Rig Repair 12/22/2005 00:00 - 12/23/2005 00:00 Operations Summary Rig Repair 12/23/200500:00 -12/24/2005 00:00 Operations Summary Rig Repair 12/24/200500:00 -12/25/2005 00:00 Operations Summary Shut Down for Holiday Weekend 12/25/200500:00 - 12/26/2005 00:00 Operations Summary Shut Down for Holiday Weekend 12/26/200500:00 -12/27/2005 00:00 Operations Summary Rig Repair and Rig-Up 12/27/200500:00 -12/28/2005 00:00 Operations Summary Rig up Slickline and run pressure temperature survey 12/28/200500:00 -12/29/2005 00:00 Operations Summary Shut well in for 24 hr. and re-run pressure temperature survey 12/29/200500:00 -12/30/2005 00:00 Operations Summary Keep well shut-in 12/30/200500:00 -12/31/2005 00:00 Operations Summary Keep well shut-in 12/31/200500:00 -1/1/2006 00:00 Operations Summary Run pressure and temperature survey. 1/1/200600:00 -1/212006 00:00 Operations Summary General rig-up 1/21200600:00 -1/3/2006 00:00 'Operations Summary General rig-up 1/3/200600:00 -1/4/2006 00:00 Operations Summary General rig-up 1/4/200600:00 - 1/5/2006 00:00 Operations Summary Mix 3% KCL and rig up. 1/5/200600:00 -1/6/2006 00:00 Operations Summary Mix sized salt pill and general rig-up 1/6/200600:00 -1/7/2006 00:00 Operations Summary ,Test lines to 3400 psi. Circulate well with 3% KCL. Daily Operations 1/7/200600:00 -1/8/200600:00 Operations Summary Nipple down tee, Nipple up BOP. 1/8/200600:00 -1/9/200600:00 Operations Summary Shell test BOP and test choke manifold. Repair leaks. Test BOP with AOGCC representative observing to 3,000/250 psi, circulate well with 3% KCL, pump and bullhead into place sized salt pill. Pull hangar to floor, rig up to pull ESP 1/9/200600:00 -1/10/200600:00 Operations Summary POOH w/ ESP assembly. Static fliud losses 3% KCL at 8 BPH 1/10/200600:00 -1/11/2006 00:00 Operations Summary Continue to POOH wi ESP assembly. UD failed ESP. P/U replacement assembly. 1/11/2006 00:00 - 1/12/2006 00:00 'Operations Summary RIH with new ESP assembly. Static 3% KCL fluid losses at - 10 BPH. 1/12/200600:00 -1/13/2006 00:00 Operations Summary P/U and M/U tubing hanger. Make final splice and land hanger. Start to N/D BOPE. 1/13/200600:00 -1/14/2006 00:00 Operations Summary Continue to N/D BOPE. N/U seal flange and tree. Test void, seals and tree to 250/5,000 psi. Identify missing cable penetrator seal. Will be necessary to N/U BOPE again. 1/14/200600:00 -1/15/2006 00:00 Operations Summary NID tree. N/U and test BOPE to 3,000/250 psi. Pull tubing hanger to floor. Install penetrator seal. Re-Iand hanger. 1/15/200600:00 -1/16/2006 00:00 Operations Summary N/D BOPE. N/U seal flange and tree. Test void, seals and tree to 250/5000 psi. Turn well over to production group. 1/16/200600:00 -1/17/2006 00:00 Operations Summary Offload equipment and demob. rig. 1/17/200600:00 -1/18/2006 00:00 Operations Summary Continue to demob rig. Release rig. Last report. L "" "" L 2 3 I I I I I I j I I I I I I L 17~3/4" .3J2W Spiral W{;!ld Surf. 600' 13·3/8" 61 Buttress Surf. 5,80Z' 9~5/8" 47 N~80 Buttress 8.681 Surf. 67' ~ 9~5/8" 40 1'1-80 Buttress 8.835 67' 5,883' 9~5/8" 43.5 1'1-80 8.755 5,883' 7,900' 9·5/8" 47 N-80/P-110 8.681 7,900' 11,210' Window 10,845 10,857' 7" 29 L~80 TKC~Butt 6.184 10,516 4~1I2" 12.6 1'1-80 Hydril 511 3.958 12,257' 15,072' 4-112" 12.6 L-80 Imp Butt. 3.958 42.9 10,280' (Spc/Std) ::::.. :::.. 1 42.9' 3.958" CIW 4~t!2" DCB Tubing Hanger: 4~112" LTC top & btm with BIW feed through penetrator, 2 x 3/8" injection line 1: +1-10,192' 3.958" 4-112" L-80 12.6lb/ft Imp Butt Tubing (spc- 4.915") Note: Cannon Clamps. Mixture of regular & SCC cplgs 3 3.833" 7 ea. 4-112" SF~02 McMurry GLM SFO-2RK wi Dummy 1-112" R~2 valve 7.063" x 6.141" Actual measured depths = 2,987', 4,590', 6,194', 7,240', 7,916', 8,502" 9,090'; 4 10.042' 3.813" 4-112" X~Nipple 5 10,179' CentrUift 600 hp 725 series ESP wi Phoenix Gauge 6 10,440' 6.00" Baker Model F Permanent Packer with 18 ft seal~bore extension 7 10,456' 4.937" Baker tubing seal assembly (L= 20 ft) 8 10,516 6.188" Baker tie~back seal assembly (L= 6.70 ft) 9 l2,256' 3.850" Knock out Isolation Valve (3.85" m after drill out) 6 ::::.. I Ported liner produces Hemlock Benches 2.3.4. and 5. I TD = 15,114'; ETD =;}5,070,' 91 °1 12,805'; 99°/13,281'; 104°115,049' REVISED: 01123/06 REVISED BY: DED e e Y~ri\ß' 'l~ p i I. ... .....!\ \. ! Î. '... ".1 J. H \ U'i? "i 'ni H Ur Ù.. ~ .1;-;; ! ! /lP) ILl' w'lJ FRANK H. MURKOWSKI, GOVERNOR AIfASHA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 ~~ Re: Trading Bay Unit G-15RD Sundry Number: 305-300 Dear Mr. Brandenburg: ~AN~E[) ¡~O\f 082005 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED tbiS4 day of October, 2005 Encl. Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 1. Type of Request: ~.~-o( ~~C . STATE OF ALASKA 1.:>~ /0 (<il C '12/' ì ALAS OIL AND GAS CONSERVATION COMMI~N S OCr v'I2D APPLICATION FOR SUNDRY APPROVALS Alal*aOlllJ& 032005 20 MC 25 280 ~J.. ,., Operational shutdown U PerforateD waiverlAnch -V"S. ~ther.~. Plug Perforations D Stimulate D Time Extension D 'rff,PtlsOrko~/SS" 'fl Perforate New Pool D Re-enter Suspended Well D :e~~;~::::1I c~s: Exploratory D ~ ,:;;t tO~1 Number: Stratigraphic D Service D 6. API Number: . J 50-733-20149-01 Suspend U Repair well D Pull Tubing D 3. Address: PO Box 196247, Anchorage, AK 99519 7. KBElevation (ft): 42.9' 8. Property Designation: Grayling Platform/Cook Inlet 11. Total Depth MD (ft): 15,114' Casing Structural Conductor Surface Intermediate Liner Pre-drilled Liner Perforation Depth MD (ft): n/a Packers and SSSV Type: 9. Well Name and Number: Trading Bay Unit G-15RD 10. Field/Pools(s): McArthur River Field/Hemlock Oil PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 9,169' Length I Effective Depth MD (ft): I 15,070' Size Junk (measured): n/a Collapse Effective Depth TVD (ft): 9,178' Plugs (measured): n/a MD TVD Burst 599' 600' 17-3/4" 600' 5,802' 13-3/8" 5,802' 11,210' 9-5/8" 11,210' 1,849' 7" 12,365' 2,815' 4-1/2" 15,072' Perforation Depth TVD (ft): rTUbing Size: n/a 4-1/2" Baker Model F Permanent Packer with 18' seal Packers and SSSV MD (ft): bore extension. 4,640' 8,733' 9,404' 9,178' 3,090 psi 5,750 psi 8,160 psi 1,540 psi 3,090 psi 7,020 psi Tubing Grade: Tubing MD (ft): 10,189' L-80 10,440' 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program D BOP Sketch [] 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry Buster 263-7853 Printed Name Timothy C. Brandenburg '"¡ Title Drilling Manager Signature? ~ C ~ S:.L~ Yhone 907-276-7600 Date , 0 - "2 - 0 t?ï ¿/ /f COMMISSION USE ONLY 13. Well Class after proposed work: Exploratory D Development [] 15. Well Status after proposed work: 11/15/2005 Oil [] Gas D Plugged D WAG D GINJ D WINJ D WDSPL Service D Abandoned D D Date: 1 0/3/2005 ~ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,3:, s;-:- ~ oc:J BOP Test .~ Mechanical Integrity Test D Location Clearance D Olhe, 3000p,,>" ßaV~..\-. 0 ~=~....... ~ ~ a1clù~ a.c-ue>tÇ¡::h.....S.\Q \)N)CQ\:; ~((..«!..\o.\ ~s 'Ñ(),~~~\ V~~~.. RBDMSB < , "' ~ . FlOC! 052005 S"~q"rjj~ Approverup.. -/ /"'/VI \..../" (./" '--'" Plug Integrity D APPROVED BY ~QJI~~ ~\, lJ iHE COMMISSION ,ÞNhš-' I I Date: . ,. "'- Form 10-403 Revised 07/2005 Submit in Duplicate Abandon Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: 1. Type of Request PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 42.9' 8. Property Designation: Grayling Platform/Cook Inlet 11. Total Depth MD (ft). 15,114' Casing Structural Conductor Surface Intermediate Liner Pre-drilled Liner Perforation Depth MD (ft): n/a Packers and SSSV Type: Total Depth TVD (ft): 9,169' Length STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Other ..! ESP Workover Suspend Repair well D Pull Tubing D Development Stratigraphic o D Exploratory Service 9. Well Name and Number: Trading Bay Unit G-15RD 10. Field/Pools(s): McArthur River Fiel Burst Junk (measured): n/a Collapse 600' 17-3/4" 5,802' 13-3/8" 11,210' 9-5/8" 1,849' 7" 2,815' 4-1/2" Perforation Depth TVD (ft): n/a 599' 4,640' 8,733' 9,404' 9,178' Tubing Grade: 4-1/2" L-80 Packers and SSSV MD (ft): 10,440' 12. Attachments: Description Summary of Proposa Detailed Operations Program D BOP Sketc 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true an Printed Name Timothy C. Brandenbur. Signature Conditions of approval: 3,090 psi 5,750 psi 8,160 psi 1,540 psi 3,090 psi 7,020 psi Tubing MD (ft): 10,189' 13. Well Class after proposed work: Exploratory D Development [] Service D 15. Well Status after proposed work: 11/15/2005 Oil 0 Gas D Plugged D Abandoned D WAG D GINJ D WINJ D WDSPL D correct to the best of my knowledge. Contact Title Drilling Manager Larry Buster 263-7853 Phone 907-276-7600 Date 9/30/2005 -30 - DS' COMMISSION USE ONLY Mechanical Integrity Test D sion so that a representative may witness Plug Integrity D Other: Approved by: Form 10-403 Rev Location Clearance D COMMISSIONER APPROVED BY THE COMMISSION Date: / I !- Submit in Duplicate 109 Upper well Bay Floor G~15RD BOP Stack OBJECTIVE: Pull the failed ESP and run a replacement ESP assembly. PROCEDURE SUMMARY: 1. Rig up on Well G-15RD. 2. Punch hole in tubing just above ESP. Circulate well with filtered inlet water (3% KCL). 3. Set BPV and NID tree on Well G-15RD. N/U and test 13-5/8" BOPE (see attached diagram) to 250/3,000 psi. 4. Verify well dead. Circulate and Pump LCM Pill if required. 5. POH wi tubing, cable & ESP. 6. Rill wi ESP assembly and gas lift mandrels. 7. Install BPV. NID BOPE. N/U & test tree. 8. Install flow line and surface facilities. 9. Startup ESP. AOGCC G-15RD ESP W orkover Summary lofl September 27,2005 . . RKB := 42.9' Rig Floor to DCB TBG Spool 17-3/4" Spiral Weld Surf. 600' 13~3/8" 61 J-55 Buttress Surf. 5,802' 9-5/8" 47 N-80 Buttress 8.681 Surf. 67' 2 9-5/8" 40 N-80 Buttress 8.835 67' 5,883' 9-5/8" 43.5 N-80 Buttress 8.755 5,883' 7,900' 9-5/8" 47 N-80/P~110 Buttress 8.681 7,900' 11,210' Window 10,845 10,857' 7" 29 L-80 TKC-Butt 6.184 10,516 12,365' 4-112"* 11.6 N-80 Hydril511 3.958 12,257' 15,072' 4-112" 12.6 L~80 Imp Butt. 3.958 42.9 10,189' (Spc/Std) 3 4 5 I I I I I I I I I I I I j L TD = 15,114'; ETD =15,070,' 91"/12,805': 99"/13,281': 104"/15,049' G-15RDSchematìc030310 1 42.9' 2 10,189' 3 8,730' 8,241' 7,753' 7,175' 6,689' 6,113' 5,256' 4,030' 2,898' 10,280' 10,440' 10,456' 10,516 12,256' 10,143' 4 5 6 7 8 9 3.958" 3.958" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" N/A 6.00" 4.937" 6.188" 3.850" 3.813" CIW 4-112" DCB Tubing Hanger: feed through penetrator 4-112" L-80 12.6Ib/ft IBTC Note: Mixture of regular & special clearance cplgs throughout string. 4-112" SF-02 RK w/ McMurry GLM SFO-2RK wI dummy 4-112" SF-02 RK w/ McMurry GLM SFO~2RK w/ dummy 4~1I2" SF~02 RK w/ McMurry GLM SFO-2RK wI dummy 4-112" SF-02 RK w/ McMurry GLM SFO-2RK wI orifice 4-112" SF-02 RK w/ McMurry GLM SFO-2RK wI R-2latch 4-112" SF-02 RK w/ McMurry GLM SFO~2RK w/ R~2 latch 4-112" SF-02 RK wI McMurry GLM SFO-2RK w/ R-2latch 4-1I2" SF~02 RK w/ McMurry GLM SFO-2RK wI R~2 latch 4-112" SF-02 RK w/ McMurry GLM SFO-2RK w/ R~2 latch Centrilift 600 hp 725 series ESP w/ Phoenix & 8 W' centralizer Baker Model F Permanent Packer with 18 ft seal~bore extension Baker tubing seal assembly (L= 20 ft) Baker tie-back seal assembly (L= 6.70 ft) Knock out Isolation Valve (3.85" ID after drill out) 4 W' 'XN' nipple REVISED: 3/11/03 DRAWN BY: JFB a STATE OF ALASKA a ALAsWOIL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: 1. Type of Request: Abandon Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: Suspend Repair well D Pull Tubing 0 Development Stratigraphic o D PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 42.9' 8. Property Designation: Grayling Platform/Cook Inlet 11. Total Depth MD (ft): 15,114' Casing Structural Conductor 600' 17-314" Surface 5,802' 13-3/8" Intermediate 11,210' 9-5/8" Liner 1,849' 7" Pre-drilled Liner 2,815' 4-1/2" Perforation Depth MD (ft): Perforation Depth TVD (ft): Total Depth TVD (ft): 9,169' Length n/a n/a Packers and SSSV Type: Baker Model F Permane bore extension. 12. Attachments: Description Sum[T1ary of Pro Detailed Operations Program D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true an Printed Name Timothy C. Brandenbur Exploratory Service Burst Junk (measured): n/a Collapse 599' 4,640' 8,733' 9,404' 9,178' Tubing Grade: 3,090 psi 5,750 psi 8,160 psi 1 ,540 psi 3,090 psi 7,020 psi Tubing MD (ft): 10,189' L-80 10,440' 13. Well Class after proposed work: Exploratory D Development 0 Service D 15. Well Status after proposed work: 11/15/2005 Oil 0 Gas 0 Plugged D Abandoned D WAG D GINJ 0 WINJ D WDSPL 0 Signature correct to the best of my knowledge. Contact Title Drilling Manager Phone 907-276-7600 Date COMMISSION USE ONLY Conditions of approval: Plug Integrity D Larry Buster 263-7853 - ~O - t::>S 9/30/2005 Sundry Number: F?ECEIVED Sfp 3 Alaska . 0 2005 Oil & Gas Anc~' Corn Mechanical Integrity Test D Location Clearance D Other: §CANNEU NmV 032005 Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: DLJPLI CA-rE Submit in Duplicate Rig 5u~ Grating Upper well Bay Floor e e G-15RD 13518" BOP Stack up To of Rota Table , "- -- - .~ ,. e ............. I-----·~ _._ ALASKA ."ILLlNG UNOCALf; Grayling Pltorm Well G-15RD ESP Workover OBJECTIVE: Pull the failed ESP and run a replacement ESP assembly. PROCEDURE SUMMARY: 1. Rig up on Well G-15RD. 2. Punch hole in tubing just above ESP. Circulate well with filtered inlet water (3% KCL). 3. Set BPV and N/D tree on Well G-15RD. N/U and test 13-5/8" BOPE (see attached diagram) to 250/3,000 psi. 4. Verify well dead. Circulate and Pump LCM Pill if required. 5. POR wi tubing, cable & ESP. 6. Rill wi ESP assembly and gas lift mandrels. 7. Install BPV. N/D BOPE. N/U & test tree.'H 8. Install flow line and surface facilities. 9. Startup ESP. AodCC G-15RD ESP Workover Summary 10f1 Septernber27,2005 ~ ." ~ m_. ...~_ --, j'f9- ~--- - ALASKA _fIII!ILLlNG UNOCAL8 e GRAYLIN~LATFORM WELL #: G-15RD Actual Schematic 12-23-02 RKB = 42.9' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL 1 SIZE wr GRADE CONN ID MD TOP MD BTM. 17-3/4" .312W Spiral Weld Surf. 600' 13-3/8" 61 J-55 Buttress Surf. 5,802' 9-5/8" 47 N-80 Buttress 8.681 Surf. 67' 2 9-5/8" 40 N-80 Buttress 8.835 67' 5,883' 9-5/8" 43.5 N-80 Buttress 8.755 5,883' 7,900' 9-5/8" 47 N-80/P-110 Buttress 8.681 7,900' 11,210' Window 10,845 10,857' 7" 29 L-80 TKC-Butt 6.184 10,516 12,365' 4-112"* 11.6 N-80 Hydril511 3.958 12,257' 15,072' *4-112" pre-drilled liner has '12" predrilled holes--8 hpf Tubing: +J/2" 12.6 L-80 Imp Butt. 3.958 42.9 10,189' (Spc/Std) 3 4 5 TOL @ 12.257' I 8 I I I I I I I I I I I j L TD = 15,114'; ETD =15,070,' 91°/12,805'; 99°/13,281'; 104°/15,049' G-15RDSchernatic030310 NO 1 Depth 42.9' 2 10,189' 3 8,730' 8,241' 7,753' 7,175' 6,689' 6,113' 5,256' 4,030' 2,898' 10,280' 10,440' 10,456' 10,516 12,256' 10,143' 4 5 6 7 8 9 ID 3.958" 3.958" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" N/A 6.00" 4.937" 6.188" 3.850" 3.813" JEWELRY Item CIW 4-112" DCB Tubing Hanger: 4-112" IBTC top & btm with BIW feed through penetrator 4-112" L-80 12.6 lb/ft IBTC Note: Mixture of regular & special clearance cplgs throughout string. 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI dummy 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI dummy 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI dummy 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI orifice 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch 4-112" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch CentrUift 600 hp 725 series ESP wI Phoenix & 8 14" centralizer Baker Model F Permanent Packer with 18 ft seal-bore extension Baker tubing seal assembly (L= 20 ft) Baker tie-back seal assembly (L= 6.70 ft) Knock out Isolation Valve (3.85" ID after drill out) 4 14" 'XN' nipple REVISED: 3/11/03 DRAWN BY: JFB " a STATE OF ALASKA a ALASKA Ol'AND GAS CONSERVATION ~MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Pull tubing: Stimulate: Alter casing: 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. Box 19-6247 Anchorage, AK 99519-6247 4. Location of well at surface 1,835' FSL, 1,491' FEL, Sec. 29, T9N, R13W, SM At top of productive interval 878' FSL, 1,990' FEL, Sec. 19, T9N, R13W, SM At effective depth At total depth 1,866' FNL, 2,444' FWL, Sec. 19, T9N-, R13W, SM 12. Present well condition summary Total depth: measured true vertical 15,114 feet 9,166 feet Effective depth: measured true vertical 15,070 feet 9,170 feet Casing Length Structural 377' Conductor 600' Surface 5,820' Intermediate 11,210' Window in 9-5/8" 10,845' Production Liner 12,365' 2nd Production Liner 15,072' Perforation depth: measured Slotted Liner from 12,257' to 15,072' Size 26" 17-3/4" 13-3/8" 9-5/8" 9-5/8" 7" 4-1/2 " Plugs (measured) Junk (measured) Cemented Driven 700 sx 4,198 sx 1,000 sx 437 sx Pre Drilled Liner Plugging: Repair well: X 5. Type of Well: Development: X Exploratory: Stratigraphic: Service: Perforate: Other: ESP Repair 6. Datum elevation (DF or KB) 42.9 RKB 7. Unit or Property name Trading Bay feet 8. Well number G-15RD 9. Permit number/approval number 198-99 10. API number 50-733-20149-01 11. Field/Pool McArthur River Field/Hemlock Measured depth 377' 600' 5,802' 11,212' 10,857' 12,365' 12,257' True vertical depth 377' 600' 4,564' 8,997' 10,516' 15,072' Tubing (size, grade, and measured depth) 4-1/2",12.6#, L-80 IBTC Tubing. Surface to 10,189' Packers and SSSV (type and measured depth) Baker Model F Permanent Packer with 18' seal-bore extension set at 10,440' (NOTE: This packer below the tubing completion). 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Dailv Averaae Production or Iniection Data Oil-BBL Gas-Mcf Water-Bbl Casing Pressure 335 229 4133 1370 612 1304 8796 80 16. Status of well classification as: Prior to well operation Subsequent to operation 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Jerry Bowen L Form 10-404 Rev 06/15/88 Title: Drilling Engineer Tubing Pressure 180 115 Suspended: p -'\,:(~"'_-lP~> ~$riiçer - ~' Date: R80MS 8FL SUBMIT IN DUPLICATE UNOCAL . GRAYLJPLATFORM WELL #: G-15RD Actual Schematic 12-23-02 RKB = 42.9' Rig Floor to DCB TBG Spool 1 2 3 4 TOL @ 10,516' 5 TOL @ 12,257' I I I I I I j 8 I I I I I I l TD = 15,114'; ETD =15,070,' 91°/12,805'; 99°/13,281'; 104°/15,049' G-15RDSchematic030310 CASING AND TUBING DETAIL SIZE WT GRADE CONN In MD TOP MD BTM. 17-3/4" .312W Spiral Weld Surf. 600' 13-318" 61 J-55 Buttress Surf. 5,802' 9-5/8" 47 N-80 Buttress 8.681 Surf. 67' 9-5/8" 40 N-80 Buttress 8.835 67' 5,883' 9-5/8" 43.5 N-80 Buttress 8.755 5,883' 7,900' 9-5/8" 47 N-80/P-110 Buttress 8.681 7,900' 11,210' Window 10,845 10,857' 7" 29 L-80 TKC-Butt 6.184 10,516 12,365' 4-1/2"* 11.6 N-80 Hydril 511 3.958 12,257' 15,072' *4-112" pre-drilled liner has W' predrilled holes-8 hpf Tubing: 4-1/2" 12.6 L-80 1m p Butt. 3.958 42.9 10,189' (Spc/Std) NO 1 Depth 42.9' 2 10,189' 3 8,730' 8,241' 7,753' 7,175' 6,689' 6,113' 5,256' 4,030' 2,898' 10,280' 10,440' 10,456' 10,516 12,256' 10,143' 4 5 6 7 8 9 In 3.958" 3.958" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" N/A 6.00" 4.937" 6.188" 3.850" 3.813" JEWELRY Item CIW 4-1/2" DCB Tubing Hanger: 4-1/2" IBTC top & btm with BIW feed through penetrator 4-1/2" L-80 12.61b/ft IBTC Note: Mixture of regular & special clearance cplgs throughout string. 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI dummy 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI dummy 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI dummy 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI orifice 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI R-2 latch 4-1/2" SF-02 RK wI McMurry GLM SFO-2RK wI R-2latch Centrilift 600 hp 725 series ESP wI Phoenix & 8 %" centralizer Baker Model F Permanent Packer with 18 ft seal-bore extension Baker tubing seal assembly (L= 20 ft) Baker tie-back seal assembly (L= 6.70 ft) Knock out Isolation Valve (3.85" ID after drill out) 4 W' 'XN' nipple REVISED: 3/11103 DRA WN BY: JFB . . 12/09/02: Skeleton crew, arrived and started rig activation. 12/10/02: Dressed #1 MP w/ 6 1/2" liners. Tested rig gas detection sytem, OK. Tested tubing hanger to 500 psi. Set BPV. Bled well to well clean tank. 12/11/02: Installed pressure sensor manifold. RU rig watch system, breathing air system. 12/12/02: Installed 2" Gate valve under gauge on 2" portable choke. Hook up mud line shock hose from drill deck to rig. Removed gas lift line & loop. Moved Air actuated valves. Installed 2" 5m flange x 1502 union on stand pipe. Rigged up on 95/8" annulus with valves. Prep to circulate well. Finished R/up rig watch system. 12/13/02 Production test of fire water system in well rooms. 12/13/02: Full crew on location. Rig up Air lines to flow line & trip Tank valves. Remove tree connection & nipple up Flange x 1502 connection & install HP circulating hose. Rig up test. Test all surface line to swab valve on tree to 3000 psi. Continued circulating. Set CIW Type "H" BPV. Rig up to pump down chemical injection line. Nippled down tree & production flow line. Nipple up tree connection & made up landing joint on top of master valve. Rigged up 2" hose off annulus. Set riser. Nippled up adapter spool & set riser. Pre spud meeting. 12/14/02: Nippled up riser, kill line valves & choke line valves. Rigged up flow line. Function test BOPS start changing rams in dbl gate. Pulled BPV & Install TWC. Tested annular, top & bottom pipe rams, choke line valves, choke manifold valves and kill line valves, to 250 /3000 psi. 12/15/02: Continue testing BOPS. Installed valve and circulated wedge. Rig down test equipment. Ran back hanger 5' above tubing spool. Shut annular & left casing valve open to well clean tank. Rigged up APRS on 4 1/2" tubing landing joint. Tag top of pump, & POOH. RIH w/4 1/2" K-l Retainer & flapper valve. POOH, E-Line stranded about 1500' pull pack off & removed wire. Rig down APRS. Rigged up circulating hose & head pin. Circulated. Rigged down circulating hose, head pin & valve. Connected ESP Cable, to cable snake, POOH. 12/16/02: Continued POOH Cleaning cable & standing back pipe changing out joints & collars as needed (7 joints & 6 collars) 12/17/02: Continue to POOH to pump. Installed X nipple with Check Valve pre- installed. RIH with ESP assembly. Rabbit pipe as it was run out of derrick 12/18/02: Continued RIH with ESP. RIH with rabitting cable. 12/19/02: RIH with 41/2" ESP to 10,237'. Installed BPV. Pulled BPV and install two way check, hook up test pump to tree. . . 12/20/02: Test tree to 250 and 4500 psi (OK). Pulled two way check. RIH with 3.83 gauge ring to plug in XN nipple at 10143', POOH. RIH and retrieve check valve. Rigged down wireline. 12/21/02: Continued rig down. 12/22/02: Released well at 12:00hrs ,""" ..-..... Á.dtllJ /^-v/) n-I f/ I () t.. I)~ /2jI¡þ Cðu.1...j""," ¿ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon: - Suspend: - Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: - Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforãtë: Other: ESP Workover 5. Type of well: 6. Datum elevation (DF or KB) Development: ~ 99' to MSL Exploratory: - 7. Unit or Property name Stratigraphic: Service: Measured depth 377' 600' 5,802' 11,212' 10,857' 437 sx 12,365' Pre Drilled Liner 12,257' RECEIVED DEC 0 9 2002 1, Type of Request: 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247 Anchorage, AK. 99507 4. Location of well at surface ..¡ / ../ 1,835' FSL, 1,491' FEL, Sec. 29, T9N, R13W, SM At top of productive interval 878' FSL, 1,990' FEL, Sec. 19, T9N, R13W, SM At effective depth At total depth 1,866' FNL, 2,444' FWL, Sec. 19, T9N-, R13W, SM 12. Present well condition summary Total depth: measured true vertical 15,114' feet ~ Plugs (measured) 9,166' feet Effective depth: measured true vertical 15,070' feet 9,170' feet Junk (measured) Casing Length Structural 377' Conductor 600' Surface 5,820' Intermediate 11,210' Window in 9-5/8" 10,845' Production Liner 12,365' 2nd Production Liner 15,072' Perforation depth: measured Slotted Liner from 12,257' to 15,072' Size 26" 17-3/4" 13-3/8" 9-518" 9-5/8" Cemented Driven 700 sx 4,198 sx 1,000 sx 7" 4-1/2 " feet Trading Bay 8. Well number G-15RD 9. Permit m~er 98-99 10. API number /" 50- 733-20149-01 11. Field/Pool McArthur River Field, Hemlock True vertical depth 377' 600' 4,564' 8,997' 10,516' 15,072' Tubing (size, grade, and measured depth) 4-112",12.6#, L-80 Tubing. Surface to 10,129' ,. Go Commission Packers and SSSV (type and measured depth) Alaska 011 & Gas, OS. Baker Model F Permanent Packer with 18' seal-bore extension set at 1 0,440' (NOTlt.~~rØer below the tubing completion). 13. Attachements Description summary of proposal: Detailed operations program: X BOP & Choke Manifold sketct X Wellbore Schematic diagram:X 15. Status of well classification as: Name of approver Date approved Service: 17. I hereby certify t t the foregoin;! true and correct to the best of my knowledge. Signed: ( l/~ Title: Consulting Drilling Engineer J ry F, Bo en, P,E, FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~aao ~~'\ 'S't)~ ~~~ Plug integrity- BOP Test~ Location clearance Mechanical Integrity Test- Subsequent form required 10- ~ 14. Estimated date for commencing operation 12/15/2002 16. If proposal well verbally approved: Oil: X Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY M L. Bi" Gas: Suspended: - Date: 12/912002 APproval NO., (. 3/1 'L- <7.1., ¿, t/ ~,,) SCANNEr) DEC 1 92002 Commissioner ~ I: LRBDMS BFl Date ' ~l\ \ )Ö& SUBMIT IN TRIPLI ATE DEC I 2 ?n"r;. , ,.",Jr, ,~ ,.-...., Grayling G-15 ESP Workover to Replace Failed ESP Unocal Alaska requests Sundry Approval to peñorm workover operations on Grayling G-15 with the following exceptions to suñace equipment requirements: 1.) To employ use of 2" dual manual choke manifold, as per attached diagram, downstream from 4" 5m HCR valve on choke line (outer db ~"'<:....~ 'd<rss ~ of two valves will be an HCR valve). From HCR, system will be , . stepped down to 2" 5M flanged hose to 2" 5M manifold with dual . o:.\\o~ ~ ~,,~ 2" 10m chokes. No chicksans or swivels will be utilized. 2.) To take returns to the production low pressure separator and/or a poor-boy de-gasser as required. ~'N'.~~\~ \. ~ ~~ ~q ~~~ '" C \- ~Cè'~G:.~~<.t\ o\~~~ \ - " \ l\ \ \...)~~ \.\--c) 't"'~T1è. b\ '1 o,-- ~c-""C;'f ,~\'-.),\ ~ ~ O-~'\ ç~C)~~~\,~~~~\--~ s(\r,\'~ """~. $~~~~\~ .ç.~Q\\\\-"CC~ ~~ ~~<t$c;o..~l~ ~~~~'i\~ Q:\\"CtX- \ ~ ~~ ~<t.~\-~~ ~ \ ~(t.:c:t~~ð~. \l)~~~\ ? \~~~\- CÀ?\;<-G--~~ \-(J '-()~}..~\'-.f \JV I ~ ~~Ld<6' D $ '-~"') ~~~'\~~ G'V~~'-.'\~\-\~~ at ~ ~\\'Ð~~ ~\....s\~ v~'J ~C, ~'~"^'~"'\ ~\(\,~~\~ \ :JO t>..t-..c.. ð S- ,0 ~ "-.1..'-\"') \<?~~ ',. <èY\\~'è~ \0 '-'<:.'Y ~\-Q 'ð.. ~ \\."'-"'-~~ c.o.$J\\.,<:> , ().> ö- \(\'\"C> ~ ~,+"'Q: ¿)~, \ "- '\ ~ ~ ~<t ~ ~~~ tJ 'è '\ \--'",. ~ ~ '-.) ~~ ~. The< <;Jè: F\Ð~ ~ ~ Q';Lf~ ";>":,<1- -- a. ,QC ?~ a 4- ~ ~ "'9r \J \ ~~ ~ h~~~ \'>r I ( D -O;?f SCANNED DEC 1 9 2002 UNOCAL8 RKB = 42.9' Rig Floor to DCB TBG Spool L 2 ::::,. "'" 3 "'" ~ 4 Toe", w.",' ~ ~ 6 5 1 ~J L. ~ TOL i(i) IZ.Z57'.JI ~ I 8 I I I I I I I I I I I j L TD "" 15,114'; ETD =15,070,' 91°/12,805'; 99°/13,281'; 104°/15,049' /--, ~ GRA YLIN G PLA TFO RM WELL #: G-15RD As Built (11-14-00) WT .312W 61 47 40 43.5 47 CASING AND TUBING DETAIL GRADE CONN ID MD TOP Spiral Weld Surf. Buttress Surf. Buttress 8.681 Surf. Buttress 8.835 67' Buttress 8.755 5,883' Buttress 8.681 7,900' 10,845 10,516 12,257' MD BTM. 600' 5,802' 67' 5,883' 7,900' 11,210' 10,857' 12,365' 15,072' ~ SIZE 17-3/4" 13-3/8" 9-518" 9-5/8" 9-5/8" 9-5/8" Window 7" 29 L-80 TKC-Butt 4-112" 11.6 N-80 Hydril511 4-112" pre-drilled liner has W' predrilled holes-8 hpf Tubing: 4-112" 42.9 10,129' J-55 N-80 N-80 N-80 N-80/P-llO 6.184 3.958 3.958 12.6 L-80 Imp Butt. (Spc/Std) JEWELRY NO Depth ID Item 1 42.9' 3.958" CIW 4-112" DCB Tubing Hanger: 4-112" LTC top & btm with BIW feed through penetrator, I-wire, 114" injection line 2 10,150' 3.958" 4-112" L-80 12.61b/ft Imp Butt Tubing (spc- 4.915") Note: Standard 4-112" couplings beneath LaSalle clamps 3 3.833" 9 ea. 4-112" SF-02 McMurry GLM w/l-1I2" R-2 valve 7.063" x 6.141" 9558',9075',8588',8193', 7706' 6944',6182',5047',2895' 4 10,129' Baker Sentry Gage 4 10,138 6.750" 3 each Centlift pumps Type 024HC9000 (Upper pump), 028HC9000 (Lower and Middle pump) 4 10,177 6.750" Tandem seal section Model HST3 DBHLG 4 10,254' 5.620' CentrUift motor assembly ( 2 x300 HP) KMEUG1I300HP and KMELG1I300HP 4 10,255 6.250 Centralizer (6 fin) 5 10,440' 6.00" Baker Model F Permanent Packer with 18 ft seal-bore extension 6 10,456' 4.937" Baker tubing seal assembly (L= 20 ft) 7 10,516 6.188" Baker tie-back seal assembly (L= 6.70 ft) 8 12,256' 3.850' Knock out Isolation Valve (3.85" ID after drill out) SCANNED Df:C 1 9 200l REVISED: 11/14/00 DRAWN BY: NM ,~ ~, UNOCAL8 Grayling Platform Well No. G-15RD ESP Workover 12/06/02 OBJECTIVE Pull the completion and replace the failed 600 hp 562 series ESP. WELL HISTORY & STATUS Well G-15 was sidetracked and re-drilled, as Well G-15RD, horizontally in Hemlock Benches 2,3,4 and 5 in 1998. A 4 %" pre-drilled liner was run into the 2816' x 6" horizontal completion interval. There are no G-zone perforations. In late-2000, the well was converted from gas lift to ESP. Problems with slipping LaSalle ESP cable clamps resulted in a one month delay. The workover was stopped and a temporary gas lift completion was re-run into the well, after the LaSalle clamps (and the ESP cable) started to slip downhole due to not being correctly sized for the 4 %" special clearance couplings. One month later, after modifying each of the LaSalle clamps with a weld bead, the workover was resumed and the 600 hp ESP assembly was successfully run into the well. A significant of workover fluid was lost in the well during the two workovers and there was evidence of formation damage initially. The ESP produced for approximately 23 months, until it failed in October 2002. Centrilift has performed diagnostic tests on the failed ESP system which indicate that the electrical failure might be at (or immediately below) the tubing hanger (possibly a failed BIW penetrator). The well produced approximately 9000 BFPD with a 91% watercut (810 BOPD) when the pump failed. The well is currently on gas lift, producing approximately 4200 BFPD with a 93% water- cut (300 BOPD). A No-Flow Test witnessed by the AOGCC in March 2000 resulted in AOGCC approval to produce without a SSSV or packer. This No-Flow Test is still valid since the same horizontal completion interval remains open to production and no perforations have been added. The reservoir pressure of the Hemlock is estimated to be 4070 psi, with a pressure gradient estimated to be 0.42 psi/ft. However, the pressures and gradients in each sub-layer are not likely to be uniform. Because the well is horizontal, a significant loss rate is anticipated. SPECIAL HAZARDS The mixture of produced gas and gas lift gas coming from well G-15 has an H2S concentration of 275 ppm. When on ESP production, and H2S concentration was measured at 220 ppm. The Grayling Platform is designated as an H2S facility. The site-specific Grayling H2S Drilling & Workover H2S Contingency Plan should be reviewed during the pre-spud meeting. NORM contamination may be present on Well Components. WELLHEAD CONDITION (Inspection by Steve Lawrence requested but not yet received. Steve has confirmed that all required back-up equipment is available, but the wellhead needs to be inspected and the questions raised in the attached e-mail need to be addressed before starting the workover.) $CANNED DEe 1 $)2002 1 G-15 ESP WO Proc.doc 12/09/02 ~ ~ UNOCAL8 Grayling Platform Well No. G-15RD ESP Workover 12/06/02 PRE-WORKOVER PREPARATION Production Four days prior to skidding rig, shut off gas lift gas and slowly de-pressurize the tbg/csg annulus, at a rate of approximately 50 psi/hr to minimize damage to the ESP cable insulation. Flush the single chemical injection line with FIW to eliminate the risk of corrosion inhibitor or paraffin inhibitor being sprayed into eyes while POH during the workover. Centrilift All Centrilift supplied equipment, including all of the primary and back-up ESP equipment, all required protectolizers, flat cable guard, flat cable, centralizer and anode, should be pre- assembled at Centrilift's Anchorage warehouse at least one week prior to the start of the workover. The back-up and primary equipment should then be clearly labeled, disassembled into convenient sections (which can be handled safely and without risk of damage), and loaded into the aluminum transport basket. The back-up equipment should be palce don bottom and the primary equipment of top, to avoid confusion on-site. The fully loaded basket should be available at OSK at least three days prior to the start of operations to allow convient shipping of the equipment offshore without an extra dock worker call-out. Drilling The following Unocal Alaska Drilling Department Standard Operating Procedures have been prepared to minimize HES risks, streamline operations and ensure job quality. The Drilling Foreman must verify compliance with the following documents pertaining to ESP workovers: 1. SPS 7.24 Simultaneous Operation Policy & Checklist 2. Management of Change (MaC) For Drilling Operations Procedure A) MOC Form 5 Unexpected Change or Occurrence at the Well Site Checklist (only if required) B.) MOC Form 6 ESP Workover Checklist 3. SPS 7.11 H2S Facility Requirements & Drilling Department's Site-Specific Steel head Drilling & Workover H2S Contingency Plan 4. Drilling Dept. SOP - ESP Workover Pre-Rig Arrival Procedure* 5. Drilling Dept. SOP - ESP Workover Pill Setting Procedure* 6. Drilling Dept. SOP - ESP Workover Rig Startup Procedure 7. Drilling Dept. SOP - ESP Workover NU BOPE Procedure 8. Drilling Dept. SOP - ESP Workover Tripping Pipe & Cable Procedure 9. Drilling Dept. SOP - ESP Workover Emergency Shut-In Procedure *NOTE: Due to the plan to re-Iand the completion without POH or changing the pump, if the only electrical failure is found at or immediately below the BIW penetrator and the remainder of the cable and motor are determined to be electrically sound, the 4 %" tubing will not be G-15 ESP WO Proc.doc 2 8CANí\lED DEC 1 9 2002 12/09/02 ,~ ~ UNOCAL8 Grayling Platform Well No. G-15RD ESP Workover 12/06/02 perforated above the pump as required in the ESP Workover Pre-Rig Arrival Procedure, and the GaGOs LGM pill will not be spotted as required in the ESP Workover Pill Setting Procedure, provided it is determined that an adequate fluid level can be maintained to conduct the workover safely. This deviation from Standard Operating Procedures is documented and approved via the attached ESP Workover MOG Checklist. Have pill mixing materials on hand in case needed to control well. Procedure 1. Prep well and facility by ensuring full compliance with Standard Operating Guideline - ESP Workover Pre-Rig Arrival Procedure. 2. Two days before starting operations, circulate well dead w/ 3% KGI through choke manifold to Production's well clean tank, and/or load well w/ 3% KGI and determine loss rate. Discuss results Spot GaGO3 LGM pill as per Standard Operating Procedure - ESP Workover Pill Setting Procedure. Note: Discuss fluid loss rate with Drilling Superintendent. Spot CaCO3 pill as per ESP Workover Pill Setting Procedure if necessary to reduce loss rate to a manageable level, and obtain approval of Superintendent before proceeding to step #4 or NU BOPE. 3. Mobilize crews, activate rig & skid over well G-15 as per Standard Operating Procedure - ESP Workover Rig Startup Procedure. 4. Install BPV. NU & test 13 5/8" 5m BOPE to 250/3000 psi as per attached diagram & as per Standard Operating Procedure - ESP Workover NU BOPE Procedure. Note: No waiver should be required to utlize the 2" portable manifold which was used on GP-50. The BOP stack-up, except for the choke manifold & kill line, will be a standard triple 5000 psi configuration with only a 3000 psi test. 5. Unland hanger & pull to rig floor. Inspect penetrator and ESP cable to determine cause of failure. If failure is located, and cable and/or motor are not shorted, replace failed penetrator, splice new pigtail to cable, re-Iand completion, and skip to step #11. Note: Be prepared to re-dress hanger on rig floor. Also need to be prepared to switch from Sentry to Phoenix gauge (i.e. with two chemical lines instead of one and an I-Wire). 6. POH w/4 Y2" ESP completion as per Standard Operating Procedure - ESP Workover Tripping Pipe & Cable Procedure. Visually inspect tubing while POH & stand in derrick to be re-used. Note: Existing tubing apparently a mixture of 4 %" regular IBTC and special clearance IBTC cplgs. This should not be a problem since we are switching to cannon clamps. G-15 ESP WO Proc.doc ,~ANNEO DEC 1 92002 12/09/02 '- ~ ~ UNOCAL8 Grayling Platform Well No. G-15RD ESP Workover 12/06/02 7. LID & inspect ESP assembly for evidence concerning the cause of the failure. EQuipment Disposition. assumina POH to replace failed ESP Tree and tbg hanger: Inspect re-dress and re-run (Oriented hanger should match flowline) Tubing: Visually inspect, replace scaled/damaged jts & re-run Power cable: Replace w/ used-inspected cable, send used cable to OSK for inspection/repair Replace w/ used/inspected/tested SPMs/GL Vs from Pollard Replace w/ full set of Cannon clamps Replace Replace & send to Centrilift for inspection/repair Replace & send to Centrilift for inspection/repair Replace & send to Centrilift for inspection/repair Replace with Phoenix system & send to Centrilift (have two Phoenix systems on location) Centralizer: Replace with centralizer designed for anode Aluminum Anode: None was run. Run anode with new system (have two on location) SPMs/GLM's: La Salle clamps: Flat guards: Pumps: Seal sections: Motors: Sentry Equipment: 8. M/U new ESP assembly as per attached diagram, and in accordance with ESP OA/OC Checklist. 9. RIH w/ ESP assembly & refurbished SPMs (refer to attached gas lift design) on the original 4 Y2" 12.6 ppf L-80 IBTC SCC tbg, as per Standard Operating Procedure - ESP Workover Tripping Pipe & Cable Procedure. Position base of ESP at +/-9000' (ESP setting depth to be re-confirmed after surveys received from Anadrill and check with team) 10. Make up tubing hanger. Splice ESP cable to BIW hangar penetrator pig tail. Make up chemical injection lines to upper check valves and to hanger. Test conductivity of the ESP cable while landing hanger in tbg head. 11. Install BPV. ND BOPE & NU X-mas tree as per Standard Operating Procedure - ESP Workover NU BOPE Procedure. 12. Recover BPV and set TWC valve. Pressure test tree, hanger body and neck seals, and ring gasket to 5000 psi. Recover two way check. 13. Install flowline and surface facilities & turn well over to Production. The Asset Team will provide a procedure to bring well on-line. G-15 ESP WO Proc.doc 4 SCANNED DEC 1 9 2002 12/09/02 • • G -15 13 5/8" BOP Stack up Top of Rotary Table • Drip Pan 13 5/8" 3M Hydril Annular r 13 5/8" 5M 2718 "x5 "VBR I Blind /Shear Rams i 13 518" 5M HCR Mud Cross ALL Wing valves 3" 5M 13 5/8" 5M Single Gate 4 1/2 "Pipe Rams i Rig Sub Grating 13 5/8" 5M Riser 1' • Upper well Bay Floor • • • TSGSpool 11111 SCANNED DEC 1 9 2002 SC NE Jul_ 1 3 2004 • • UNOCAL Portable 2" Dual Manual Choke Manifold 2" 1502 Hook up to Production separator or poor -boy gas buster (if needed) ( ) : , H 011. smi , I • 2" 2 , Manual Manual Choke Choke MEM 411111* 4 2" HP Hose w/ 4 1/16" 5M Flange SIA From Drilling Spool SCANNED JUL 1 3 2004 Unocal Corporation • P.O. Box 196247 • Anchorage, AK 99501 Telephone (907) 263 -7660 UNOCAL Tim Billingsley 8/21/2002 Drilling Engineer Alaska Oil and Gas Conservation Commission 333 West 7 Avenue o p '4 Anchorage, Alaska 99501 Attn: Tom Maunder \ Re: Report on Annulus Disposal /y Trading Bay Unit, Grayling Platform, l� Well Grayling G -22 6. Mr. Maunder: Enclosed is the final report on annulus disposal of A -29RD oil base mud (OBM) liquid waste into the G -22 annulus as required by the Sundry Application Approval #301 -304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G -22 annulus while at A -29RD. The following is the total volumes disposed in G -22 annulus by drilling well source. � ..� WPI OBM, bbls Seawater Flush, bbls Total Bbls q�� G -15RD 1269 2160 3429 *Ci ° a G-28 D 203 700 903 1 -4.4 2 - 0(96 G -26RD 823 2155 2978 aol - iti A -15RD 1374 5067 6441 4? G -12RD3 366 1050 1416 aoa 1 A -29RD 856 - 1494 2350 Total 17517 This concludes all presently scheduled disposals into the G -22 annulus. If there are any questions, please contact myself at 263 -7659. Sincerely, .� APR 15 2011 Ti m Billingsley Drilling Engineer AOGCC -22A -29RD waste annular disposal final r G sp report Created on 8/21/2002 10:13 AM Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G -22 Drilling Wastes From Monopod A -29RD Maximum Allowable Injection Pressure 2000 psi TVD 13 3/8" Casing Shoe Depth 4977' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry's Flushes 6/29/2002 1 2.0 1600 10.2 205 0 205 0 6/29/2002 2 2.0 1400 10.2 146 351 0 6/29/2002 3 1 2.0 1800 10.2 60 357 411 357 7/15/2002 2 2.0 1550 20 411 377 7/15/2002 4 2.0 1850 8.7 125 536 377 7/15/2002 3 2.0 1800 357 536 734 8/5/2002 4 2 1400 8.3 20 536 754 8/5/2002 5 2 1750 8.5 170 706 754 8/5/2002 5 2.5 1850 8.3 350 706 1104 8/10/2002 6 2 1500 8.3 20 706 1124 8/10/2002 6 2 1750 8.5 150 856 1124 8/10/2002 7 2.5 1850 8.3 370 856 1494 • *Injection pressure is the highest injection pressure observed while injecting • • Unocal Corporation • P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263 -7660 UNOCAL Jim Harrison 7/3/2002 Drilling Manager Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Attn: Tom Maunder Re: Report on Annulus Disposal Trading Bay Unit, Grayling Platform, �� / Well Grayling G -22 'o Mr. Maunder: \ �/ Enclosed is the final report on annulus disposal of G -12RD3 oil base mud (OBM) liquid waste into the G -22 annulus as required by the Sundry Application Approval #301 -304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G -22 annulus while drilling at G- 12RD3. The following is the total volumes disposed in G -22 annulus by drilling well source. Well OBM, bbls Seawater Flush, bbls Total Bbls �q>r -v94 G -15 1269 2160 3429 . $- G 203 700 903 G -26RD 823 2155 2978 poi - ig9 A -15RD 1374 5067 6441 a o G -12RD3 366 1050 1416 Total 15167 Unocal began disposing of drilling wastes from the A -29RD into the G -22 annulus on June 29, 2002. If there are any questions, please contact myself at 263 -7677 or Tim Billingsley at 263 -7659. Sincerely, 2 ; fi rg,,isee Jim Harrison Drilling Manager a �" `F` APR I 5 20 ry 1 Cutic Alaska Oit �xc £ r <a. I)!I)! AilliSS101 Anchorar p AOGCC G -22 G -12RD waste annular disposal fmal report Rl Tim Billingsley Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G -22 Drilling Wastes From Grayling G -12RD3 Maximum Allowable Injection Pressure 2000 psi TVD 13 3/8" Casing Shoe Depth 4977' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry's Flushes 6/10/2002 1 1 3 1800 9.1 170 350 170 350 • 6/15/2002 2 2 2 1800 8.3 11 350 181 700 6/17/2002 3 3 2 1750 8.4 185 350 366 1050 • *Injection pressure is the highest injection pressure observed while injecting ~ ~ tJ1'ð -C519 .. J Unocal Corporation P.O. Box 196247 Anchorage. AI< 99501 Telephone (907) 263-7660 UNOCAL8 Dan Williamson Drilling Manager 5/8/2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Tom Maunder Re: Report on Annulus Disposal Trading Bay Unit, Grayling Platform, Well Grayling G-22 Mr. Maunder: Enclosed is the final report on annulus disposal of A-15RD oil base mud (OBM) liquid waste into the G-22 annulus as required by the Sundry Application Approval #301-304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G-22 annulus while drilling at A-15RD. The following is the total volumes disposed in G-22 annulus by drilling well source. Well G-15RD G-28RD G-26RD A-15RD Total OBM, bbls 1269 203 823 1374 Seawater Flush, bbls 2160 700 2155 5067 Total Bbls 3429 903 2978 6441 13751 If there are any questions, please contact myself at 263-7677 or Tim Billingsley at 263-7659. ~:~ Dan WilYiamson Drilling Manager ~r"""¡-I.I...t) .;¡fIr E-~ . Ji",-l.i ~t r2 ..... v_"", ¡'iAY 0 9 2002 AOOCC 0-22 Monopod waste annular disposal final report Tim Billingsley Alaska o¡¡ &. Gas Cons. (;onUHiS5IUJ Anchorape Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G-22 Drilling Wastes From Monopod A-15RD -.\ , Maximum Allowable Injection Pressure 2000 psi TVD 133/8" Casing Shoe Depth 4977' BBlS BBlS BBlS BBlS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry's Flushes 12/9/2001 Inj-test 1 3 1600 FIW 0 338 0 338 12/9/2001 1 2 3 1600 9.9 450 338 450 676 12/10/2001 2 3 3 1750 10 198 338 648 1014 12/10/2001 3 X 3.5 1650 10 150 0 798 1014 ) 12/11/2001 Flush 4 3.5 1750 FIW 0 450 798 1464 2/14/2002 Flush 5 3.5 1650 FIW 0 338 798 1802 2/14/2002 4 6 4 1750 9 80 338 878 2140 2/27/2002 Flush 7 2.5 1100 FIW 0 40 878 2180 2/28/2002 Flush 8 3 1100 FIW 0 20 878 2200 3/2/2002 Flush 9 3 1200 FIW 0 20 878 2220 3/2/2002 5 X 3 1750 10.0 130 338 1008 2558 3/3/2002 6 X. 3 1750 10 100 338 1108 2896 3/5/2002 7 10 1.75 1750 10 50 360 1158 3256 3/19/2002 8 11 4 1750 9 76 360 1234 3616 3/24/2002 9 12 1750 70 351 1304 3967 4/3/2002 flush 13 FIW 0 20 .1304 3987 4/3/2002 10 14 4 1900 9.1 20 360 1324 4347 4/3/2002 11 15 4 1750 9.1 20 360 1344 4707 ) 4/3/2002 12 16 3.5 1800 9.1 30 360 1374 5067 Total bbls injected 6441 *Injection pressure is highest reading while injecting ~ i~ ,------- ,-- -----~---~---- ----- Well Compliance Report File on Left side offolder. ----- 198-099-0 TRADING BAY UNIT G-15RD 50- 733-20149-01 UNION OIL CO OF CALIFO , ~ D>.TTA MD 1511L~VD 09166 LCòmpletion Date: L-ß128/98 Completed Status: I-OIL - Current: --- Microfilm Roll I Roll 2 I Name Interval Sent Received T/C/D OH 8/6/98 8/6/98 OH 8/6/98 8/6/98 OH 8/6/98 8/6/98 OH 10/15/98 10/16/98 ¡>""O' OH 10/15198 10/16/98 OH 10/15/98 10/16/98 OH 8/6/98 8/6/98 OH 8/6/98 8/6/98 OH 8/6/98 8/6/98 OH 8/6/98 8/6/98 \ CH 5 10/15/98 10/16/98 ~",D L AST/GR-MD L AST/GR-TVD ~~ L AST/GR/VDL /' L CN/LDT~- L DlLlGR ~- L DSI~ FINAL MYLAR 10875-12060 FINAL MYLAR 10875-12060 FINAL MYLAR 10875-12060 11700-14928 12362-14994 11700-14959 L PEX-AIYIGR-MD 1.--- FINAL MYLAR 10875-12060 L PEX-AIT/GR-TVD ~NAL MYLAR 10875-12060 L PEX-NDT/GR ~ FINAL MYLAR 10875-12060 L PEX-NDT/GR ~ FINAL MYLAR 10875-12060 L RST-S ~ 1 12100-12350 Da.'ly Well ops1~)f~p -ej;, ~.!7ð L\ 'fJ4---!ß- Are Dry Ditch Samples Required? yes @---' And Received2 ~.tS 110 Was the well cored? ye~ Analysis Description Receiv~d? ves nQ- S'ample'Sét If ---~ Comments: ~ b:" 5 t:VJj b~ ~ ~ ,,~ [J \}\'fv\ I -'\ ~'^ l { : (j '"" ~ G K 5 -. ' \) \); Lt 'hJ í b f~ OV\., I...- 1\ SIT .~ k,! I/J~) Ò .- ~u/V' ~~ I Cw¡WV' 'í \ \I. . Ir K ! J j ~ II V:. v\. IJ) 2 )\~ ~_~-IJ--l t ~J c);/ - ctcJ)~ ~ (ti~J'NV>-,~.u:¡t- I ; ¡ I ch. ¡ l~e rxl ~ '------ \)\11.0 c_ú'.,l ' cOW\ Tuesday, August 01, 2000 Page 1 of 1 ~l r lE\!T fÇ :1) 'J ; if', \ ! I j! ,- -' ;,.; -..... ;,..::= .-.... n 1 i~ IF I '1'- 1-, j i ¡ "- ~;. '.-1 I í TONY KNOWLES, GOVERNOR /K\ r ,1K\ ~ r~ ~ '" \ I "..... - n I .J \"j ~ LJ :J ,Jd..) L Lr-j ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 14,2000 Chris Meyers\Dwight Johnson Field Superintendents UNOCAL 260 Caviar Street Kenai, Alaska 99611 Re: No-Flow V erificatio~ ~ MRF Well G-15RD~TD 198-099 ~ Gentlemen: On March 9, 2000 our Inspector, Louis R. Grimaldi, witnessed a "no-flow" test on UNOCAL's McArthur River Field well TBU G-15RD. Prior to the Inspector's arrival, gas lift had been shut off and the well had been allowed to die to a low-pressure separator. The annulus had also been bled off. After his arrival, the annulus and tubing were blocked in and over the course of 30 minutes a 2 psi build up on the tubing was noted with no build up on the casing. The tubing was then bled to a 55-gallon drum with no fluid observed. The inspector recommends the well be granted "no-flow" status. McArthur River Field well TBU G-15RD (PTD 198-099) meets the criteria of a "no-flow" performance test and as such is considered incapable of unassisted flow to the surface. Under the authority of20 AAC 25.265 (A) it is not required to have a fail-safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition. If for any reason, the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. Sincerely, h~ 7Y(~ Thomas E. Maunder Petroleum Engineer cc: Blair Wondzell Lou Grimaldi Wayne Johnson - Grayling /' . " ,.-'... MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson,~ Chairman DATE: March 9, 2000 THRU: Blair Wondzell, .æ~ P. I. Supervisor s(llt-rcXr FROM: Lou Grimaldt/d.VL Petroleum Inspector SUBJECT: No-Flow Test Unocal Grayling G-15RD McArthur River Field TBU - (PTD 198-QA9> NON-CONFIDENTIAL Thursday, March 9. 2000: I witnessed a No-Flow verification on UNOCAL's Grayling platform well #G-15RD in the McArthur River field. I had been in contact with Wayne Johnson (Lead Operator) during the day during which I was informed of the well status. The Gas lift had been shut off and the well was allowed to die to a low-pressure separator. The annulus was bled off and I arrived to find the well in this condition. The Tubing and annulus were blocked in and over thirty minutes I observed a 2 psi buildup on the tubing and zero on the casing. I had the tubing bled to a 55 gallon barrel with no fluid observed. This well has a tubing retrievable valve, which will remain in service. The well has exhibited its inability to flow to surface on its own. SUMMARY: I witnessed No-Flow verification on UNOCAL's Grayling platform well #G-15RD in the McArthur River field. NON-CONFIDENTIAL CC: Dan Williamson, Unocal Attachment: None ¿O~y~~ L~-f+.,¡ )~::{- No-Flow UNOCAL TBU G-15RD 3-9-00 LG '.,.-.'---'.'.. , "".--,.,".._H.. ..--,....._-,. :---- ,..,-..., Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd@unocal.com UNOCAL8 Debra Childers Geotech Assistant October 15, 1998 DATA TRANSMITTAL To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: 5' .o~~~~~ILIIl~~~~~~etermination Log c~m::tion I .1 lM U ¡ ¡Correlation I 9~~Ø1cr ~BU G-1SRD 1 12"/S" ¡Dual Induction Tool/Gamma Ray i , [TBU G-1SRD '1'-- 1 2"/S" ¡Sonic Digital Tool/Gamma Ray I ¡TBU G-1SRD 1 1 S" ¡Reservoir Saturation Tool ¡TBU G-1SRD I 1 1 12';/S" ¡,litho-Density/compensated -V i ! I !Neutron/Gamma Ray g 5 j tJ jAN-35 ¡ 11,s" ¡Completion Record w/Gamma 0-,al(18742-3S) I I i : Ray/CCL (/¿' o'1lTBU G-16 ¡ u.¡ c.... 1 ¡ 1 Is" ¡Completion 'Record ~ 75 'O(o¡'~~~-~~~.~R[f¡~~.~j,m+f~'::". i~~~~~~~FT~~~*f:1 Neutron -Öecay' I 1ß r is ûG:1~~î~~1 ~:P~:t~oñReOO~---~. qf' t~oITBU <!-5RD I~\,- 1, 1 S" ¡Completion Record 1 11-Aug-98IAlaska Oil & Gas I i ! j ¡ 1 20-Aug-98!Alaska Oil & Gas 1 20-Aug-98iAlaska Oil & Gas 1 20-Aug-98IAlaska Oil & Gas 1 20-Aug-98IAlaska Oil & Gas ¡ ! 1 29-AU9-98Alaska Oil & Gas , ¡ 11 OS-Sep-98Alaska Oil & Gas 1 ¡ 1 ~~~E=~~J~!~~~a Oil & G~~" 1 12-Sep-9 laska Oil & Gas 1 12-Sep-98¡Alaska Oil & Gas ¡ ¡ 1 14-Sep-98!Alaska Oil & Gas I j." Please ackn'tt,ge receipt by signing and returning one copy ofthis transmittal or F~El)l~D I Reœivedby:d~h1 I Date: OCT ,h '1998 , ,I Aiæka Oü & Gas eons. CommiS6\OR And\Q1898 STATE OF ALASKA ALASKA OIL í\ND GAS CONSERVATION Cúl\lIMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG OIL: X GAS: 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface côijp¡:Ër¡Òrj ') 1835' FSL, 1491' FEL, Sec. 29 9N, R13W, SM..C: 8~;r¡lCt'3~.. At Top Producing Interval! ('r . 878' FSL, 1990' FEL, Sec. 198, 9N, 13W, SM;' 'FiED ~ , f At Total Depth ~, . .- . . ,- ..,. 1866' FNL, 2444' FWL, Sec. 19, 9N, 13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 42.9 ADL 18777 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No, of Completions 7-14-98 8-19-98 8-28-98/ 90 feet MSL One 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 15,114'/9,166' 15070'/9170' Yes: X No: 304 feet MD NIA 22. Type Electric or Other Logs Run Run 1, AIT, LDT, CNL, Sonic, GR Run 2 DITE, LDT, CNL, Sonic, GR 23. < -..... 1. Status of Well SUSPENDED: ABANDONED: SERVICE: .... ~ ~'- CASING SIZE WT. PER FT, 29 12.6 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM 10,516' 12,365 12,256' 15,072' HOLE SIZE 8-1/2" 7" GRADE L-80 L-80 6" 4-1/2" 24. Perforations open to Production (MD+TVD otTop and Bottom and interval, size and number) 25. SIZE 5-1/2" NIA ORIG!NAL 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NIA .~ Classification of Service Well 7. Permit Number 98-99 8. API Number 50- 733-20149-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number G-15RD 11. Field and Pool McArthur River FieldlHemlock CEMENTING RECORD 437 sx Pre drilled liner AMOUNT PULLED NA NA TUBING RECORD DEPTH SET (MD) 10,516' PACKER SET (MD) 10,440' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 8-29-98 Gas Lift Date otTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 8-31-98 24 TEST PERIOD => 625 229 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF Press, 520 1330 24-HOUR RATE => 625 229 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Hemlock Benches 2, 3, 4, 5 Bench 2 - Sand, pebbly sand Bench 3 - Sand, sandy gravel Bench 4 - Gravel, gravelly sand Bench 5 - Sandy gravel, gravelly sand Form 10--407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE WATER-BBL 2353 WATER-BBL 2353 CHOKE SIZE I GAS-OIL RATIO 48/64" 366 OIL GRAVITY-API (corr) 31.8 RECEIVED SEP 111998 A1aska on & Gas Cons. Commission Anchorage Submit in duplicate r". ,--- 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH rRUE VERT. DEPTH GOR, and time of each phase. HKT HK2T HK3T HK4T HKST HKST HK4T HK3R TO 12,133 12,186 12,370 12.592 12,726 13,306 13,617 13,964 15,114 9,288 9,316 9409 9515 9556 9523 9439 9347 9169 31. LIST OF ATTACHMENTS Wellbore diagram, summary of Daily Operations, dir~tional survey. 32. I hereby certify that the foregoing is true â~d cor.:~ÏfJ1. he.! bas..' t of my knowledge Dan R. Williamson~.".r1{........... ~WI¡(tt4flI1 Drilling Manager Signed . WVitle Date åcSep-98 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection. steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in iwm 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such inier\lål!. Item 21: Indicate whether fwm ground level (GL) or other elevation (OF, KB, etc,). Item 23: Attached supplemântal records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken. indicate "none". Form 10,407 , -,' ..I.l.. ~ ---- UNOCAL8 RKB = 44.3' Rig Floor to DCB TBG Spool L ~ 1 3 <II!. :::.. <II!. ~.'~ 4~ 5 1;>1 6 1'OL @ 10,516' ............ 1 7 r L. :::.. TOL @ 12,257'JII rl. I I I I I I I I I I I I I I .d t:.. 'I'D = 15,114'; ETD =15,070,' 91 °/12,805'; 99°/13,281'; 104°/15,049' G-lSRD ActUaI8-28-98.doc .-- ..- GRA YLING rLA TFORM WELL #: G-15RD Actual Completion: 8/28/98 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 17-3/4" .312W Spiral Weld Surf. 600' 13-3/8" 61 J-55 ButtrèSs Surf. 5,802' 9-5/8" 47 N-80 Buttress 8.681 Surf. 67' 9-5/8" 40 N-80 ButtrèSs 8.835 67' 5,883' 9-5/8" 43.5 N-80 ButtrèSs 8.755 5,883' 7,900' 9-5/8" 47 N-801P-110 Buttress 8.681 7,900' 11,210' Window 10,845 10,857' 7" 29 1.-80 TKC-Butt 6.184 10,516 12,365' 4-1/2" 11.6 N-80 Hydril 511 3.958 12,257' 15,072' 4-1/2" pre-drilled liner has Yi' predrilled holèS-S hpf Tubing: 5-1/2" 17.0 1.-80 LTC 4.892 42.9 10,516' ~ NO 1 2 3 Depth 42.9' 304' 2,875' 5,064 5,629 6,150' 6,212' 6'690' 6,751' 7,231' 7,287' 7,723 7,821 8,257' 8,814' 9,336' 9,857' 10,339' 10,504' 10,440' 4 5 6 7 10,456' 10,516 ID 4.930" 4.562 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.892" 4.455" 6.00" 4.937" 6.188" JEWELRY Item CIW 5-1/2" DCB Tubing Hanger: 5-112" LTC top & btm Baker TE-5 TBG Retrievable SCSSSV #16 5-1/2" SF-02 McMurry GLM wI 1-1/2" R-2 valve #15 5-1/2" SF-02 McMurry GLM wI 1-1/2" R-2 valve #14 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #13 5-112" S]1'-02 McMurry GLM wI 1-112" R-2 valve #12 5-1/2" S]1'-02 McMurry GLM wI 1-112" R-2 valve #11 5-112" SF -02 McMurry GLM wI 1-112" R-2 valve #10 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #9 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #8 5-1/2" SF-02 McMurry GLM wI 1-1/2" R-2 valve #7 5-112" SF-02 McMurry GLM wI 1-1/2" R-2 valve #6 5-1/2" SF -02 McMurry GLM wI 1-112" R-2 valve #5 5-1/2" SF-02 McMurry GLM wI 1-112" R-2 valve #4 5-1/2" SF -02 McMurry GLM wI 1-112" R-2 valve #3 5-1/2" SF-02 McMurry GLM wI 1-112" R-2 valve #2 5-1/2" SF-02 McMurry GLM wI 1-1/2" R-2 valve #1 5-1/2" SF-02 McMurry GLM wI orifice Baker 'XN' Nipple Baker Model F Permanent Packer with 18 ft seal-bore extension Baker tubing seal assembly (L= 20 ft) Baker tie-back seal assembly (L= 6.70 ft) r:q: r E I \ I [C, " ~\, £.. \.." ,V L c:: CrJ 1 1 l~Q;:; ,;C "'--"'", Alaska OJ] & Gas Cons. Cmnmlsswn Anchorage REVISED: 9/01/98 DRAWN BY: MWD ~ ,-. UNOCAL GRAYLING Platform G-15Rd#2 slot #4-16 McArthur River Field TBU, Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref: PMSS <12376-15114> Our ref: svy5821 License: Date printed: 27 -Aug-98 Date created: 4-Aug-98 Last revised: 27 -Aug-98 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 3618.018 Slot location is n60 50 22.899,w151 3648.078 Slot Grid coordinates are N 2502387.654, E 212196.311 Slot local coordinates are 1837.70 N 1489.80 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North G 15rd Final Surveys.doc 09/01/98--9:56 AM ~ UNOCAL SURVEY LISTING Page 1 GRAYLING Platform,G-15Rd#2 Your ref: PMSS <12376-15114> McArthur River Field,TBU, Cook Inlet, Alaska Last revised: 27 -Aug-98 Measured IncHn. Azimuth True Vert RECTANGULAR Dogleg Vert Depth Degrees Degrees Depth COORDINATES Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 377.00 0.00 0.00 377.00 0.00 N 0.00 E 0.00 0.00 672.00 0.25 284.00 672.00 0.16 N 0.62W 0.08 0.33 713.00 2.25 270.00 712.99 0.18 N 1.52W 4.90 0.62 776.00 5.25 294.00 775.85 1.35 N 5.39W 5.27 2.88 807.00 6.50 288.00 806.69 2.47 N 8.35W 4.49 4.83 838.00 8.25 281.00 837.43 3.44 N 12.20 W 6.34 6.89 1255.00 26.25 281.00 1234.04 26.93 N 133.09 W 4.32 65.09 1447.00 34.00 283.00 1399.98 47.14 N 227.22 W 4.07 112.23 1541.00 37.00 283.00 1476.50 59.42 N 280.40 W 3.19 139.68 1602.00 39.50 282.00 1524.40 67.58 N 317.27 W 4.22 158.38 1964.00 39.50 285.00 1803.75 121.32 N 541.11 W 0.53 275.91 2310.00 39.50 286.00 2070.74 180.14N 753.19 W 0.18 394.80 2780.00 39.50 289.00 2433.44 270.01 N 1038.24 W 0.41 564.95 3344.00 38.50 288.00 2871.74 382,66 N 1374,81 W 0.21 772.09 4014.00 39.25 289.00 3393.35 516.12N 1773.56 W 0.15 1017.49 4417.00 39.50 289.00 3704.88 599.35 N 2015.29 W 0.06 1168.48 4782.00 57.75 292.00 3945.15 695.79 N 2270.35 W 5.04 1336.03 4877.00 58.50 295.00 3995.32 727.96 N 2344.32 W 2.80 1388.64 4965.00 55.75 294.00 4043.08 758.62 N 2411.56W 3.27 1437.81 5058.00 52.00 296.00 4097.91 790.33 N 2479.63 W 4.39 1488.23 5183.00 48.50 295.00 4177.82 831.71 N 2566.35 W 2.87 1553.41 5343.00 43.00 296.00 4289.43 880.99 N 2669.77 W 3.47 1631.06 5800.00 42.00 299.00 4626.40 1023.45 N 2943.60 W 0.49 1848.12 6020.00 41.75 301.00 4790.22 1096.86 N 3070.77 W 0.62 1955.86 6320.00 41.50 302.00 5014.47 1200.98 N 3240.68 W 0.24 2105.56 6790.00 42.00 306.00 5365.18 1375.95 N 3499.99 W 0.58 2349.39 7165.00 42.75 306.00 5642.21 1524.51 N 3704.46 W 0.20 2551.77 7782.00 40.50 310.00 6103.48 1776.46 N 4027.46 W 0.56 2887.97 8092.00 38.75 312.00 6342.25 1906.10 N 4176.69 W 0.70 3055.94 8272.00 38.75 313.00 6482.63 1982.21 N 4259.75 W 0.35 3153.21 8528.00 39.00 315.00 6681.94 2093.82 N 4375.31 W 0.50 3293.99 8725.00 39.00 317.00 6835.04 2182.99 N 4461.42 W 0.64 3404.64 8953.00 39.25 319.00 7011.92 2289.90 N 4557.68 W 0.56 3535.23 9303.00 38.25 321.00 7284.89 2457.67 N 4698.51 W 0.46 3737.15 9492.00 37.75 322.00 7433.83 2548.73 N 4770.95 W 0.42 3845.55 9686.00 38.75 324.00 7586.18 2644.65 N 4843.20 W 0.82 3958.55 9776.00 36.50 323.00 7657.46 2688.82 N 4875.87 W 2.59 4010.40 9882.00 34.25 317.00 7743.91 2735.83 N 4915.20 W 3.90 4066.95 10071.00 38.75 317.00 7895.80 2818.03 N 4991.85 W 2.38 4168.14 10320.00 38.00 322.00 8091.05 2935.46 N 5092.22 W 1.28 4309.99 10531.00 43.50 324.00 8250.85 3045.48 N 5174.96 W 2.68 4439.56 10654.00 43.00 326.00 8340.44 3114.51 N 5223.30 W 1.19 4519.79 10804.00 43.00 326.00 8450.14 3199.32 N 5280.50 W 0.00 4617.72 10845.00 42.56 326.43 8480.24 3222.46 N 5295.99 W 1.29 4644.41 10899.00 43.50 323.80 8519.71 3252.67 N 5317.06 W 3.75 4679.51 10969.00 46.30 325.10 8569.29 3292.88 N 5345.78 W 4.21 4726.40 11028.00 47.60 325.80 8609.57 3328.39 N 5370.23 W 2.37 4767.56 11092.00 48.40 321.80 8652.40 3366.75 N 5398.31 W 4.81 4812,50 11159.00 48.50 324.50 8696.85 3406.86 N 5428.38 W 3.02 4859.72 G 15rd Final Surveys.doc .--. 09/01/98--9:56 AM ~, ,-' UNOCAL SURVEY LISTING Page 2 GRAYLING Platform,G-15Rd#2 Yourref: PMSS <12376-15114> McArthur River Field,TBU, Cook Inlet, Alaska Last revised: 27-Aug-98 Measured Inclin. Azimuth True Vert RECTANGULAR Dogleg Vert Depth Degrees Degrees Depth COORDINATES Deg/100ft Sect 11251.00 49.60 328.60 8757.16 3464.83 N 5466.65 W 3.57 4926.41 11317.00 50.10 327.60 8799.71 3507.66 N 5493.31 W 1.38 4975.20 11371.00 49.70 329.80 8834.50 3542.94 N 5514.76 W 3.20 5015.26 11519.00 51.50 335.00 8928.47 3644.26 N 5567.65 W 2.97 5127.68 11562.00 51.90 335.00 8955.12 3674.84 N 5581.92 W 0.93 5161.11 11658.00 52.60 339.60 9013.92 3744.84 N 5611.18 W 3.86 5236.64 11752.00 53.90 339.80 9070.16 3815.48 N 5637.31 W 1.39 5311.84 11844.00 54.90 341.10 9123.71 3885.97 N 5662.34 W 1.58 5386.58 11879.00 54.80 341.50 9143.86 3913.08 N 5671.51 W 0.98 5415.19 11932.00 55.60 342.10 9174.11 3954.42 N 5685.10W 1.77 5458.70 12035.00 56.40 343.10 9231.71 4035.90 N 5710.63 W 1.12 5544.09 12100.00 56.90 344.00 9267.44 4087.98 N 5726.01 W 1.39 5598.38 12224.00 58.90 343.60 9333.33 4188.84 N 5755.32 W 1.64 5703.40 12322.00 60.20 344.30 9383.00 4270.03 N 5778.67 W 1.46 5787.87 12376.00 61.90 345.40 9409.14 4315.64 N 5791.01 W 3.62 5835.08 12410.00 61.90 345.10 9425.15 4344.64 N 5798.65 W 0.78 5865.05 12460.00 60.60 343.00 9449.20 4386.79 N 5810.69 W 4.51 5908.87 12514.00 59.40 342.70 9476.20 4431.47 N 5824.48 W 2.27 5955.63 12615.00 66.10 342.90 9522.42 4517.20 N 5851.01 W 6.64 6045.37 12667.00 73.00 346.50 9540.58 4564.17N 5863.83 W 14.77 6094.03 12742.00 83,20 348,20 9556.03 4635.68 N 5879.86 W 13.78 6167.09 12805.00 91.10 349.40 9559.16 4697.36 N 5892.06 W 12.68 6229.61 12874.00 92.90 349.10 9556.75 4765.10 N 5904.93 W 2.64 6298.13 12969.00 94.60 349.00 9550.54 4858.17 N 5922.93 W 1.79 6392.36 13062.00 95.50 347.80 9542.35 4948.91 N 5941.56W 1.61 6484.55 13157.00 92.30 347.60 9535.89 5041.50 N 5961.75 W 3.37 6578.98 13210.00 93.90 350.40 9533.02 5093.45 N 5971.85 W 6.08 6631.58 13240.00 96.50 351.10 9530.31 5122.93 N 5976.65 W 8.97 6661.17 13281.00 98.90 349.90 9524.81 5163.00 N 5983.35 W 6.53 6701.43 13313.00 101.60 349.60 9519.12 5193.99 N 5988.95 W 8.49 6732,68 13344.00 102.80 349.40 9512.57 5223.78 N 5994.48 W 3.92 6762.78 13376.00 103.70 349.70 9505.23 5254.41 N 6000.13 W 2.96 6793.71 13390.00 104.10 348.90 9501.87 5267.76 N 6002.65 W 6.24 6807.21 13481.00 107.40 345.60 9477.17 5353.17 N 6021.95 W 5.03 6894.50 13551.00 108.10 344.20 9455.82 5417.53 N 6039.32 W 2.15 6961.12 13598.00 107.00 341.90 9441.65 5460.39 N 6052.38 W 5.22 7005.93 13659.00 104.80 342.00 9424.94 5516.17 N 6070.56 W 3.61 7064.59 13731.00 104.30 342.50 9406.85 5582.54 N 6091.81 W 0.97 7134.27 13821.00 106.90 342.90 9382.65 5665.29 N 6117.58 W 2.92 7220.95 13924.00 105.50 340.90 9353.91 5759.30 N 6148.31 W 2.31 7319.84 13964.00 101.50 338.70 9344.58 5795.79 N 6161.75 W 11.34 7358.67 13995.00 98.50 338.70 9339.19 5824.23 N 6172.84 W 9.68 7389.12 14064.00 98.20 337.90 9329.17 5887.66 N 6198.08 W 1.23 7457.18 14159.00 99.60 337.50 9314.48 5974.50 N 6233.69 W 1.53 7550.66 14252.00 98.80 338.10 9299.61 6059.49 N 6268.38 W 1.07 7642.11 14279.00 99.40 339.00 9295.34 6084.31 N 6278.13 W 3.97 7668.70 14323.00 100.80 339.80 9287.62 6124.85 N 6293.37 W 3.65 7711.94 14402.00 99.50 339.00 9273.70 6197.64 N 6320.73 W 1.92 7789.56 14456.00 94.60 337.50 9267.07 6247.40 N 6340.58 W 9.48 7842.97 14541.00 94.70 335.90 9260.18 6325.21 N 6374.09 W 1.88 7927.20 G 15rd Final Surveys. doc 09/01/98--9:56 AM ~, ,,-. UNOCAL GRAYLING Platform,G-15Rd#2 McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 3 Your ref: PMSS <12376-15114> Last revised: 27 -Aug-98 Measured Inclin. Azimuth True Vert RECTANGULAR Dogleg Vert Depth Degrees Degrees Depth COORDINATES Deg/100ft Sect 14638.00 95.80 334.90 9251.31 6413.03 N 6414.30 W 1.53 8022.99 14661.00 96.10 335.40 9248.92 6433.79 N 6423.91 W 2.53 8045.66 14776.00 97.00 335.90 9235.80 6537.88 N 6471.02 W 0.89 8159.02 14806.00 97.30 336.00 9232.07 6565.06 N 6483.15 W 1.05 8188.58 14896.00 101.50 336.10 9217.37 6646.19 N 6519.19W 4.67 8276.73 14923.00 102.40 335.40 9211.78 6670.27 N 6530.04 W 4.19 8302.95 14955.00 103.00 335.80 9204.75 6698.70 N 6542.93 W 2.24 8333.92 14985.00 103.30 335.80 9197.92 6725.34 N 6554.91 W 1.00 8362.91 15017.00 103.60 336.40 919Q.48 6753.80 N 6567.52 W 2.05 8393.82 15049.00 104.60 337.40 9182.68 6782.34 N 6579.69 W 4.35 8424.69 15114.00 104.60 337.40 9166.30 6840.42 N 6603.87 W 0.00 8487.32 PROJECTION - No Survey Data All data is in feet unless otherwise stated. Coordinates from slot #4-16 and TVD from RKB (99.00 Ft above mean sea level). Bottom hole distance is 9508.01 on azimuth 316.01 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 342.80 degrees. Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment - ---------- ----- - - - ------- ------- --- - - - --- ----------- - -- ----------- - ---------- - - -------- 15114.00 9166.30 6840.42 N 6603.87 W PROJECTION - No Survey Data Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------- ----- - ------ --- ----- - ---- ------------- 0.00 0.00 O.OON O.OOE 11212.00 8731.75 3439.81N 5450.85W 95/8" Casing 11024.00 8606.87 3325.95N 5368.57W 12704.00 9549.83 4599.05N 5871.92W 7" Liner Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location TV.D. Rectangular Coordinates Revised -------------------------------- - - - ------------- ------------ - ----------- ------- G-15Rd - TD - 4 May 8898.00 7634.00N 6752.00W 4-May-98 G-15Rd - 2T - 4 May 8931.00 7546.00N 6729.00W 4-May-98 G-15Rd - 3T - 4 May 9285.00 6476.00N 6448.00W 4-May-98 G-15Rd - 4T - 4 May 9378.00 5924.00N 6292.00W 4-May-98 G-15Rd - PIT - 4 May 9431.00 4985.00N 5998.00W 4-May-98 G-15Rd - 4T - 4 May 9418.00 4567.00N 5865.00W 4-May-98 G-15Rd - 3T - 4 May 9372.00 4335.00N 5775.00W 4-May-98 G-15Rd - 2T - 4 May 9306.00 4215.00N 5729.00W 4-May-98 G-15Rd - HKT - 4 May 9276.00 4165.00N 5709.00W 4-May-98 G 15rd Final Surveys.doc 09/01/98--9:56 AM UNOCALG ~Unocal Corporation Detailed Activity Report -. UNOCALG 7/13/98 7/14/98 7/15/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 L2 P2 P2 L2 L2 P2 L2 L2 L2 P2 P2 P2 P2 P2 P2 45 45 45 6F 45 45 29A 45 0.50 45 4.00 45 45 45 45 0.50 6.00 45 45 5.50 5 1.00 17 1.00 1.25 12:00 1.25 13:15 2.00 14:30 5.00 16:30 0.50 21:30 2.00 22:00 9.50 00:00 09:30 10:00 1.00 14:00 1.50 15:00 16:30 17:00 1.00 23:00 00:00 05:30 06:30 13:15 14:30 16:30 21:30 22:00 00:00 09:30 10:00 14:00 15:00 16:30 17:00 23:00 00:00 05:30 06:30 07:30 11037.0 11037.0 11037.0 11037.0 11037.0 11037.0 10872.0 10872,0 10872.0 PU/MU Smith tri-mills, running tool, bypass, MWD. Test MWD and cycle test Smitch bypass tool and confirm cycles (two repeat cycels @ 5 times). PU whipstock adn attempt to attatch to starter mill, NOGO (Carbide on starting mill would not allow bolt attachment to whipstock). Grind carbide to allow attachment. RIH with packstock to 10,977'. Continue to RIH F/10,977' and tag 7" liner top 11,037' . Continue RIH F/10,977' and tag 7" liner top @ 11,037'. could not determine 9-5/8" CSG collar loacation, call project engineer and discuss and have engineer contact superintendenet and mobilize SWS unit and crew for GR tie in. Continue to wait on 12 hr boat, to rest & mobilize SWS crew to platform & go over logs for possible paper tie in. Pooh (176') & place smith packstock on depth btm @ 10867' dpm Bring pump on line for #1 cycle @ 174 GPM @ 1500 psi, 1st tool face l85R & orinted 45 deg left & worked pipe 8 time & mwd readings bad, circ DP volume & dn 'p),¡mp, cycle (3} more times & circ attempting to get tool face (all bad tool faces) call town & discuss options Mix & pump dry job & attempt to pooh (pulled 35k over & set dn 10k) prk set premature & call town Continue cycles for full set (ok) & cycled thru full six cycles to chk bypass funtion (ok) & on the first cycle mwd started working (ok) 45L Sheared off whipstock & called town Start cutting window at at 10,485',with 3 kip on mill,rpm = 80-90. pump pressure = 2900 psi at 230 gal per/min and top drive tq = 14,000 ft/lbs. with 1+' of window cut taddle tail broke off as planed and pump pressure fell to 2100 psi. Continue milling window to 10,857' with gradual increase in mill wt up to 25 kip and tq readings of 18,000 ft/lbs Have good cuttings returns, collected about about 40 lbs of cuttings on ditch magnets and 3/4 of a drum of cuttings at this point. Drilling rat hole f/10,857'- to/10,860' with 30 kip on mill & 16000-18000 ft lbs have cmt and clay stone showing up in returns. Continue drilling rat hole with Smith Tri-mill assy f/10860'-10872'. Circulate and work mill assy through window. Pull through window with no problems. Finish circulating btms up clean ditch and shakers and prep for LOT. Perform Leak-off test@10,872'MD.f)r: C. E I V,. D Did not breakdown formation--FIT: ~~t: . t psi and bleed down to 2,332 psi in 15 minutes. Uncorrected EMW = 14.73 PPG. ~~ u) 1 ¡ 199 S Alaska Oil 8: Gas Cons. Commission Anchorage UNOCALi) ~ Unocal Corporation Detailed Activity Report , ,--.. UNOCALi) 7/16/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 L14 P2 P2 P2 P2 P2 P2 3B 2A P2 L2 2A L14 L2 '- P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 10 2A 10 2B 2A 10 28 10 2A 10 28 18 68 6C 24 15A 15A 6C 6F 6F 5 2A 88 10 28 0.50 4.00 07:30 08:00 1.75 12:00 0.75 13:45 3.25 14:30 3.75 17:45 2.00 21:30 0.50 23:30 3.50 00:00 0.50 03:30 0.50 1.00 04:00 04:30 2.00 05:30 1.00 07:30 2.00 08:30 0.75 10:30 2.50 11:15 0.50 1.75 0.25 2.25 1.50 0.50 2.00 0.25 0.25 0.25 0.25 13:45 14:15 \ 16:00 16:15 18:30 20:00 20:30 22:30 22:45 23:00 23:15 08:00 12:00 13:45 14:30 17:45 21:30 23:30 00:00 03:30 04:00 04:30 05:30 07:30 08:30 10:30 11 :15 13:45 14:15 16:00 16:15 18:30 20:00 20:30 22:30 22:45 23:00 23:15 23:30 10872.0 10872.0 10872.0 10872.0 10872.0 10872.0 10872.0 10872.0 Pump dry job and monitor well. POOH with Smith one trip mills. Hole taking 4.4 bbls per 5 stds lay down MWD and tri mill assy.starter mill gauged at 7 7/8" center mill at 8" and string mill at 8 3/8" Make up test joint pull ware bushing & set test plug TEST BOPS, Test annular at 250-3500 psi tested top and bottom pipe and blind rams,choke and kill line valves at 250 -5000 psi. Run Koomey draw down test. Test gas detectors ( choke and floor valves were tested while milling window). Test top drive lBOP Valves. Manual valve failed test. Change out dual lBOP sub on top drive retest at 250-5000 psi (Good test) Rig down test equipment. Set ware bushing. Ran test on 13 3/8" x 9 5/8" annul as while working on TD (SEE COMMENTS). Make up BHA drilling assy #l,orient mtr hmang off MWD. Test mtr and MWD. Make up 8-1/2" Hycalog PDC Bit. Pick up hydraulic jars. (SEE COMMENTS ON BHA) Run in hole with 8-1/2" drilling assy # 1 'Run in hole with drilling assy # 1 to 10,860'.Filled pipe at 4556'& 8307' Break circulation slow and work up to 480-500 gpm setting derrick shakers to handle flow rate. Ream rat hole f/10860'-to/10872' Rotary drilling f/l0872'-to/10894' lost 600 psi pump pressure test both pumps at 60 stks per min # 1 runing at 1500 psi and # 2 running at 2100 psi. Rotary drill f/10894 - to/10913 with one pump while working on one # 1 pump changed out swab,had some ware but did not appear to be the problem. Continue rotary drilling to/ 10,922' p1and depth to start slide.not able to slide and get survey with one pump. Pull into casing and inspect valves and seats did not find much wrong with fluid end parts,looked in real good shape. Pump did have some trash in dis- charge and suction pots below seats. Not able to get survey from MWD. Work amd rotate pipe spud down and cycle pumps hard.MWD started sending surveys. Drilling, W/Motor f/10922 - to/ 10994 while holding toolface at 20-40 r connection and survey. Drilling, Rotary f/10994 - to/11024' Directional Survey Drilling, W/Motor f/1l024 - to/l1044' Drilling, Rotary f/l1044 - to/l1084' connection and survey Drilling, W/Motor f/ll,084 - to/ll,ll5' Directional Survey Drilling, Rotary f/ll,115'- to/ll,120' Directional Survey Drilling, W/Motor f/ll,120 - to/ll,125' UNOCALe ~Unocal Corporation Detailed Activity Report ,-..... UNOCALe 7/17/98 7/18/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 7 6C P2 6A '. P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 A2 3B 10 28 10 2A 10 28 28 2A 10 2B 428 10 28 10 2B 10 2B 2A 10 28 10 28 10 2B 10 38 28 2A 10 3B 2B 2A 10 28 28 5 6A 6A 6A 6C 0.50 1.00 4.00 0.50 0.50 2.25 0.25 1.25 0.25 0.25 1.25 1.00 0.50 0.50 0.50 0.50 23:30 0.75 0.25 0.75 0.25 1.50 1.50 0.25 3.25 0.50 0.50 00:00 00:45 01:00 01:45 02:00 03:30 05:00 05:15 08:30 09:00 0.50 09:30 1.50 0.50 0.25 0.75 1.75 0.25 0.75 1.25 1.00 0.50 10:00 11:30 12:00 12:15 13:00 14:45 15:00 15:45 17:00 18:00 1.00 18:30 1.50 19:30 1.00 2.00 21:00 22:00 0.50 2.50 0.50 00:00 00:30 03:00 03:30 04:00 05:00 09:00 09:30 10:00 12:15 '12:30 13:45 14:00 14:15 15:30 16:30 17:00 17:30 00:00 Directional Survey surveys have been long been having to cycle pumps several times to get surveys up. Drilling, W/Motor f/ll25'-to/lll35 @ 45r Directional Survey & clean out cuttings build up in mud ditch. Drilling, W/Motor f/lll35-to/ll145' 40r Directional Survey Drilling, W/Motor f/11145-t/11179' 45r Drilling, Rotary f/lll79'-to/ll2l4' Directional Survey Drilling, W/Motor f/ll214-t/11238 GOr Directional Survey,lost swab in #1 pump Drilling, W/Motor f/11238-t/1l243 GOr with one pump #2 (broke off swab on#l) Directional Survey and connection was able to pump up survey with one pump. Drilling, W/Motor f/11243-t/11263 60r ream and take directional survey ream and orient tool face. Drilling, W/Motor f/11263'-to/11272 60r Drilling, Rotary f/11272-t/1130G' Directional Survey ream and orient tool face. Drilling, W/Motor f/1130G-t/11335 70r Drilling, Rotary f/11335-t/11352' Directional Survey and connection and service top drive. D;rilling, W/Motor f/ 11352-t/ 11358' 75r 'o'rient and holding tool face is tuff. Drilling, W/Motor f/11358-t/11372 75r still having trouble holding tool face make 2-3' off hole and able to stack wait with not much differential.also pulling tight off btm. Circulate mix and pump dry job. POOH no problems in open hole.pulled 20-25 kip over in window with jars and and mtr.continue POOH. Pipe started pulling wet, Pump dry job. Continue POOH w/Dri11ing assy # 1. Lay down Hycalog DS6GH Bit & XL mtr. bit was 1/1G" out of gauge on cutting structure. and 20-25% flat crested ware on cutters.A portion of the body was still in gauge. Clean up rig floor of oil base mud. Make up BHA # 2 BIT # 2. Make up ADM MTR & change out MWD.Test mtr and MWD. Make up bit. Run in hole drilling assy #2 fill pipe at 454G'and 10154.Continue run in hole with no problems in open hole.No drag was noted at window (10845'-10857') Break circulation. Ream f/11330-t/11372' Directional Survey, orient mtr for slide. Drilling, W/Motor f/11372-t/11422 @ 45R Directional Survey & Connection. Drilling, Rotary f/11422'- t/ll45G' Directional Survey Orient tool face for slide. Drilling, W/Motor f/1l45G-t/11485 @ 45R Drilling, Rotary F/l1485-T/1l5l4' Connection & Dirrectional survey had to cycle pumps several times to get survey. Drilling, W/Motor f/11514-t/11534 @ 60R Gradual loss in pump pressure showing up. run slow pump rates.Have swab out in # 2 pump,isolate # 2 pump. 00:45 01:00 01:45 02:00 03:30 05:00 05:15 08:30 09:00 09:30 10:00 11:30 12:00 12:15 13:00 14:45 15:00 15:45 17:00 18:00 18:30 19:30 21:00 22:00 00:00 00:30 03:00 03:30 04:00 05:00 09:00 09:30 10:00 12:15 12:30 13:45 14:00 14:15 15:30 16:30 17:00 17:30 18:00 UNOCALfj .---. Unocal Corporation Detailed Activity Report ,-.. UNOCALfj 7/19/98 7/20/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 A2 L2 A2 L2 A2 P2 P2 P2 P2 P2 P2 P2 P2 A2 L2 P2 P2 2B 3B 2A 10 2A 10 2B 3B 8A ,10 2A 10 28 P2 P2 P2 P2 P2 P2 L14 P2 P2 P2 P2 P2 P2 P2 2A 42B 2B 10 3B 2A 3B 2A 2B 10 2B 2A 3B 3.75 0.25 10 0.50 10 0.75 1.75 0.25 1.25 0.50 3.50 0.50 1.25 0.25 0.25 0.25 1.25 0.25 0.50 2A 2.50 5 1.00 5 0.50 1.75 18:00 0.75 19:45 0.75 20:30 0.50 21:15 1.25 21 :45 0.50 0.50 23:00 23:30 1.50 0.25 0.25 00:00 01:30 01:45 1.50 02:00 03:30 07:15 07:30 08:00 08:45 10:30 10:45 12:00 12:30 16:00 16:30 17:45 18:00 18:15 18:30 19:45 20:00 20:30 23:00 00:00 19:45 Drilling, Rotary f/11534'-t/11564 with # 1 pump. started having pressure loss check pump, swab going cut. Isolate # 1 pump ant finish up changing out swab on # 2,prime up pump,put on line and get survey and tool face. Drilling, W/Motor f/11564-t/11584 @ 50R Wwith one pump while changing out swab in # 1 pump. Directional Survey, (no go, unable to pump up servey with both pumps or one pump, test pumps,both pUIT~s run at 2300 psi at 62 stks each. slide section is becoming sticky.) ream slide section f/l1500-t/11584. attempt to pump up survey, looked good. Drilling, Rotary f/11584-t/11587' ream f/11577-t/11587 appears to have cleaned up real well. Average ROP at 2400 hrs = 23.4 it/per actual on btm time = 9.2 hrs 2.75 hrs lost due to pUIT~ problems 2 hrs off btm survey and connections footage lost due to pump problems fig off average ROP = 63.25' could be more than than this due to hole made with one pump. Drilling, Rotary f/11587-t/11607' Drilling, W/Motor f/116l9-t/116l9 @ 55R 'donnection & dirrectional surrvey,lost liner gasket in # 1 pump. Drilling, W/Motor f/116l9-t/l1646 @ 55R with one pump change liner gasket out in # 1 pump. Drilling, Rotary f/l1646-t/11703'with both pumps back on line. ream drilling breaks f/11686-t/11697' (COAL;11700-ll7l0'ON TY?£ LOG) Connection & dirrectional survey. have trouble pumping up surveys. Directional Survey had to cycle pumps seven times and work pipe to get survey Drilling, W/Motor f/11703-t/11733 @ 70R Reaming Slide f/11728'-t/l1733'tight getting back to bottom. Drilling, Rotary f/11733-t/11773' Connection & dirrectional survey. Drilling, Rotary f/11773-t/11862' Connection & dirrectional survey Drilling, W/Motor f/11862-t/11892 @ 75R Ream slide f/11862-t/11992' Lost rig power put back on line. Directional Survey Drilling, Rotary f/11892-t/11925' Directional,orient tool face. Drilling, W/Motor f/11925-t/11937 @ 45R Started to drill into coal. (shows up on type log at 11965') pick up and start rotary drilling. REAM SLIDE F/11925-T/11937 RTY Drill Coals f/11937-t/11986' pick up every 2-3'while drilling coals. Circulate & Condition and survey. rotate and work pipe continuous while cire btms up;Hole is in real good shape. Circulate & Condition pump dry job. 20:30 21:15 21:45 23:00 23:30 00:00 01:30 01:45 02:00 03:30 07:15 07:30 08:00 08:45 10:30 10:45 12:00 12:30 16:00 16:30 17:45 18:00 18:15 18:30 19:45 20:00 20:30 23:00 00:00 00:30 UNOCAL(; ~ Unocal Corporation Detailed Activity Report ".......... UNOCAL(; 7/21/98 7/22198 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 P2 P2 L2 L14 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 2A 2A 10 2A 10 2A 10 2A 10 2A 10 2A 10 P11 36 P2 P2 6F P2 P2 6F 6C P2 28 11A P3 6A 7 6C 6A 2A 10 2A 2A 8B 10 0.50 3.00 1.00 0.25 1.00 0.25 1.25 0.25 2.25 0.25 4.25 0.25 0.25 0.25 0.25 5 2.25 2.00 1.00 4.00 00:30 0.50 0.50 04:30 05:00 3.50 05:30 1.75 0.25 3.50 09:00 10:45 11:00 1.00 14:30 5.00 15:30 20:30 21:00 00:00 01:00 01:15 02:15 02:30 03:45 04:00 06:15 06:30 10:45 11:00 11 :15 11:30 11:45 1.50 14:00 5.50 1.00 \ 15:30 21:00 22:00 00:00 04:30 POOH, With no problems in open hole or in window.noticed ware on drill pipe f/800'-t/llOO'this section of well has dog legs up to 6.34 degrees. Clean rig floor off OEM and ser/rig. Check mtr clearence,make up bit # 3 HTC.ATMGTRS18 (4,4,7) change out MWD Test mtr and MWD. run in hole to window break circulation continue in hole with no problems or fill ream f/11950-ll986' Drilling, Rotary F/11986'-T/120l6' Survey and work pipe. Drilling, Rotary f/120l6'-12080' withone pump change swab in # 1 while drilling HAD SWAB CHANGED OUT IN # 1 BROUGHT PUPM ON LINE AND AT 2000 PSI PUMP STARTED TO SEIZE UP,Sh~T DOWN PUMP. PULLED HEAD CAP,LOOKS LIKE SWAB HAD COME APPART AND SHOULDERED UP ON ROD. POOH,TO SHOE. ( CALLED OUT DOWELL FOR BACK UP ON CEMENT PUMP) change out swab in # 2 and inspect the rest of fluid end parts, (WORK ON # 1 See Comments) Run back in hole to 12080' (the swivel packing went out also changed out while up in shoe during mud pump work.) Directional Survey connection and ,take slow pump rate. 'Drilling, Rotary f/12080'-t/12l10' Drilling, Rotary F/12ll0-T/12l47' Directional Survey Drilling, Rotary F/12147'-T/12l75' Connection & dirrectional survey. Drilling, Rotary f/12l75'-t/12208' Directional Survey Drilling, Rotary f/1208'-t/12269' Connection and dirrectional survey Drilling, Rotary f/12269'-t/12364' Connection & dirrectional survey Drilling, Rotary f/12364'-t/12370' TD. Directional Survey. while taking survey We had a fire drill.had driller stay on floor and work pipe. Fire drill muster in galley and take head count.resume operations. Circulate & Condition, pump weighted sweep 14 Ibs per gallon when sweep around, Got alot of large cuttings back from sweep, continue circulate clean. rotate and reciprocate pipe continuous while circulate bottoms up.Record tq and drag readings(see comments) Pooh to 10,700' .pulled 20-25 kip over at l1976'continue pooh with no other problems in open hole or work window. Record torque and drag readings above window (see comments) Continue POOH. Lay down bit and BHA.Bit was 1/16" out of gauge with 10 broken inserts all on outer row, berings effective. Rig up Schlumberger,Hang sheave in crown for open hole logs. Rig up SWS. ( Lengthy rig up due to large open hole she eve in crown and subsequent line rubbing on top drive which required correction) 05:00 05:30 09:00 10:45 11:00 14:30 15:30 20:30 21:00 00:00 01:00 01:15 02:15 02:30 03:45 04:00 06:15 06:30 10:45 11:00 11 :15 11:30 12110.0 11:45 14:00 15:30 21:00 22:00 00:00 01:00 UNOCAL8 ~Unocal Corporation Detailed Activity Report ,~ UNOCAL8 7/23/98 7/24/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P3 A3 A3 11A A3 11A A3 11A A3 11A A3 11A A3 11A A3 11A A3 11A A3 P4 11A 13A P11 P4 37 13A P4 13A P4 13A P4 P4 13A 13A P4 13A P4 13A P4 5 11A 11A 3.00 6.00 01:00 4.00 07:00 4.50 11:00 3.50 15:30 0.50 19:00 4.50 19:30 2.00 00:00 2.50 02:00 2.50 04:30 6.00 07:00 1.00 1.00 13:00 14:00 0.50 1.75 15:00 15:30 2.75 17:15 0.75 20:00 3.25 2.50 20:45 00:00 1.00 02:30 2.50 03:30 06:00 07:00 Run DIT-E/LDT/CNT-H/SDT/GR/CC/MRES/MTEM Unable to pass 12005' (WLMj Work tools for 45 min without success. Log up and POOH. Remove bull nose on bottom of logging string and insert additional knuckle joint. Make up tool string and RIH. Unable to pass 12,050'. (Coal Stringer} Log back to shoe and POOH Lay down Density Neutron tools (20' /450 lbs)in an effort to shorten and increase limberness of string. RIH to 11,765' (coal) Unable to pass on repeated attempts. POOH (500 lbs additional drag observed) and lay down tools in preparation for pipe conveyed logging. Make up pipe conveyed logging assembly. (AIT-SDT-TCC-AMS-GR) Test tools with wet connect. (OK) Hold safey meeting prior to running in hole to discuss running/safety issues. RIH to shoe breaking circulation every 15 stands to ensure no debris build up on wet connect. Continue RIH with pipe conveyed logging suite to shoe at 10,845'. Make up wet connect and side-entry sub. RIH with wet connect and test logging tools. 'RIH at 1000'/hr to 12,047'. Attempt to pass bridge without success. (Maximum compressional loading on tool string 42001bs) POOH with pipe conveyed logging tools. (Lay out side entry sub and rig down Schlumberger at casing window) Lay down logging tools. Clear rig floor and rig up GBR to run casing. Hold pre-job safety meeting. Make up shoe track and test floats.GBR tong earn failed during make-up of first joint at 18K ft-lbs. Changed out tongs (15 min) Remainder of casing made up to 16K ft-lbs to preserve tongs. RIH picking up remainder of 7" TKC 29lb L-80 casing (45 jts). Make up Baker 7" Flex-lock liner hangar. Pick up first joint of hevi- wate and pump liner volume. Continue RIH with liner to 9000' Continue running 7" 291b TKC L-80 casing to 10764'(above casing window at 10,845') Circulate and take torque/weight readings. (10rpm = 12k ft-1bs, 20rpm = 13k ft-lbs) Continue into open hole with liner to TD at 12,370'. Worked pipe through tight spot at 12,050' for 30 minutes (same place logs stopped)Washed remaining stands to bottom. Hole attemting to pack-off. Circulate and condition mud prior to cementing casing (1-1/2 bottoms up). 11:00 15:30 19:00 19:30 00:00 02:00 04:30 07:00 13:00 14:00 15:00 15:30 17:15 20:00 20:45 00:00 02:30 03:30 06:00 09:00 UNOCALi> ~ Unocal Corporation Detailed Activity Report ,,-... UNOCALi> 7/25/98 7/26/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P4 13A L4 L4 29C 5 L4 5 P4 12A P4 12A P4 12A P4 P2 P2 P2 P2 P2 6F 9 6F 6F 15A 15A P2 6F A2 6F P2 2A A2 2A \ P2 P2 5 15F P2 2A P2 2A 1.75 2.25 1.00 5.00 0.50 3.00 1.50 1.00 5.00 0.50 0.50 3.50 8.00 09:00 10:45 13:00 14:00 19:00 19:30 1.50 22:30 00:00 01:30 02:30 07:30 08:00 08:30 12:00 1.50 20:00 2.50 21:30 8.00 00:00 1.25 0.50 08:00 09:15 7.25 09:45 1.50 17:00 10:45 Drop setting ball and circulate down to seat. Pressure up to 1500psi (setting pressure, 1800 psi and 2000 psi in attempt to set hangar.Appears hangar set at6 2000 psi. Pressure up to 2800 psi to release setting tool. Continue pressure up to 3400 to blow ball seat. Unable to circulate/rotate, hole packed off.Pump 10bbls OBM away Casing holding 1700 psi, can cir at 2000 psi with 4 bpm (no Confer with Anchorage Pressure broke back to 100 psi. Attempted to circulate and rotate with sucess. Circulate open hole volume. Mix and pump hi-vis pill. Observe returns to ensure circulating from liner shoe and not hangar. ~i-vis pill not observed returning at calculated 100% hole volume excess. Hold Safety Meeting prior to mixing cement. Mix and pumped 10 bbls CW-100 followed by 437 sx G neat + .8qps D300 + .135gps D145 at 15.8 ppg (71 bbl mixed in Batch Mixer, 24 bbls mixed on fly) Displaced cement with 201.75 by OBM. Observed dp wiper shear and atteITpted to bump plug. Pressure built to 4000 psi 36 bbls prior to bumping. :Bled off pressure and checked floats- OK. Picked up running tool and allowed pressure to equalize. (No differential) Layed down cementing head and reverse circulated pipe clean at 500 psi. (No cemen to surface) Pump slug and POOH 10 stands Slip and cut drill li~e POOH laying down excess drill-pipe and hevi-wate. Lay down cement manifold. Pull wear bushing and install test plug. Test BOP's. Test hydrill to 250/3500 psi. Test pipe rams and manifold to 250/5000 psi. Recover test plug and install wear bushing. Make up Sec 2643i PDC bit on clean-out assembly. M/U BHA and RIH picking up 3-/2" drill-pipe. RIH to 10,817' Wash down from 10,817' to wiper plug at 11,350' . Drill wiper plug (1.5 hours) Drill out firm cement to 11,350'. Drill out cement from 7" liner to 12,100' Circulate bottoms up for liner lap test. Pressure test liner lap. Pressure up to 2350 psi, pressure bled back to 2300 psi in 1 minute then stabilized at 2300 psi. (9-5/8" x 13-2/8" annulus pressure increased from 0 to 50 psi) Continue cleaning out shoe track from 12,100' to shoe at 12,366'. (Landing collar took 2 hours to drill out). Drill 5' new hole from 10,370 to 10,375' (25'/hr). Circulate hole clean for FIT. 13:00 14:00 19:00 19:30 22:30 00:00 01:30 02:30 07:30 08:00 08:30 12:00 20:00 21:30 00:00 08:00 09:15 09:45 17:00 18:30 UNOCALG .---.Unocal Corporation Detailed Activity Report ~ UNOCALG 7/27/98 7/28/98 7/29/98 7/30/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 L2 L2 L2 L14 L2 L2 17 6A 68 6C 6C 6C 6F 6F 5 1.00 1.00 1.50 0.50 1.50 4.00 0.50 28 8.50 5 68 68 6C 6C 4.00 1.50 0.50 2.00 68 23 68 1.50 1.50 3.50 9 68 1.00 12.50 38 10.00 2B 2.50 45 6F \ 6F 8B 6F 6F 0.50 18:30 5.00 19:00 00:00 01:00 02:00 03:30 04:00 05:30 09:30 10:00 1.50 18:30 20:00 00:00 01:30 02:00 04:00 05:30 07:00 10:30 11:30 00:00 10:00 5.00 12:30 1.00 17:30 1.50 . 18:30 20:00 1.00 3.00 21:00 1.50 00:00 19:00 00:00 01:00 02:00 03:30 04:00 05:30 09:30 10:00 18:30 20:00 00:00 01:30 02:00 04:00 05:30 07:00 10:30 11:30 00:00 10:00 12:30 17:30 18:30 20:00 21:00 00:00 01:30 12508.0 12539.0 12539.0 0.0 Conduct FIT test to 13.6 ppg EMW (2350psi surface pressure, 9404' TVD, 8.8 ppg MW) Pump slug and POOH. (second slug pumped as first slug innefective) Continue POOH. Lay down gea 4-3/4" drill collars. Make up BHA No.5 Test Motor and MWD - OK RIH picking up 29 jts 3-1/2" hevi-wate. Continue RIH to bottom at 12375'. Break circulation (mud thick) and orientate motor. (Pump pressure 3750 psi at 305 gpm) Slide from 12,375' to 12,508'. Oriente motor between 10 deg to right and straight up. ROP fell to 8'/hr and weight stacking evident indicating undergage/damaged bit. Circulate and work pipe while preparing slug. (Approximate 1/3 hole volume circulated. ) POOH for Neyrfor turbine assembly. Continue POOH with motor assembly. Lay down bit and mud motor. Pick up bit and turbine assembly. Test turbine and MWD- OK RIH with BHA # 6. Pick up 48 jts of 3-1/2" drillpipe. 'éontinue RIH with 5" drillpipe to 11,360' Cut Drill Line Break circulation and commence reaming turbine assembly into open hole.Ream to 12,451'. (7'/hr, 35 rpm, 2-4K WOB, 180 gpm at 3700 psi} Completed reaming from 12,451' to bottom @ 12,508' with bit #6, BHA #6, steerable Neyrfor turbine assembly. Drilled 6" hole with steerable turbine assembly from 12,508'-12,539' rotating. ROP drilling from 15'-35'/hr.. Attempted to survey with Inteq "Navi-Trac" MWD with negative results. Continued to try and survey with Inteq MWD. Tried varying pumps and rates. Tried modifying surface equipment parameters. Saw some pump noise errors, but the most continuous problem was inability of surface equipment to decode pulses. POH to just below shoe with no hole problems. Again attempted to survey with negative results. Slugged pipe and POH. Saw additional 25K overpull while pulling first three stands inside casing then freed up. Continued POH to change MWD tool and parameters. Shut down to adjust Tesco torque tube supports. Supports had allowed tube to become misaligned and cause fastline to start rubbing on tube. Checked crown attatchment and adjusted and retightened supports. Continued POH for MWD replacement @ 2400hrs.. Completed POH to change out MWD. 0.0 0.0 0.0 UNOCALe ,~Unocal Corporation Detailed Activity Report .---. UNOCAL8 7/31/98 8/1198 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 L2 L2 A2 A2 A2 A2 A2 P2 P2 L2 P2 L14 P2 P2 P2 P2 P2 6C 6B 10 5 68 6C 68 10 0.50 28 10.50 10 2B 8A 0.75 fB 2.25 1.50 01:30 4.50 03:00 2.00 07:30 1.00 5.50 2.00 09:30 10:30 16:00 5.50 18:00 23:30 00:00 1.00 10:30 1.00 11:30 12:30 13:15 6A 7.00 ' 15:30 1.50 \22:30 24 15A 0.50 2.00 00:00 00:30 03:00 07:30 09:30 10:30 16:00 18:00 23:30 00:00 10:30 11:30 12:30 13:15 15:30 22:30 00:00 00:30 02:30 12539.0 12539.0 '12539.0 12539.0 12539.0 12539.0 12539.0 12589.0 12591.0 12594.0 12594.0 12594.0 Changed out MWD and tested same. Decoded survey @ surface with 90 gpm. Increased pump rate to 150 gpm to check pulses, ok.. Bit had a couple small pieces of metal stuck in water courses in gage area. It showed to start of some core type wear in center blades and also some wear on face. Most water courses on face had some blockage, mostly coarse pebbles. Rerun bit and BHA #5. Completed RIH with rr bit 7r6 and BHA #7. Tagged bottom @ 12,539'. Survey @ 12,460' with Inteq "Navi-Trac" MWD. Survey decoding with no problems. Survey shows 60.6 deg. @ 343. Resurveyed and repeated three times. Pulled up and surveyed @ 12,410' and 12,376'. Appears that well was sidetracked while reaming. Mixed and pumped slug to dry pipe. POH for BHA. Changed out stabilizers and bent section of turbine. Made up BHA #6. Tested MWD. RIH with rr bit #8r6, BHA #8. Steerable turbine assembly. Took weight and had to rotate thru @ 12,276' (inside 7" casing) . Survey and orient turbine to high side @ 2400 hrs.. : :Drilled 6" hole with steerable turbine assembly oriented straight up from 12,539'-12,588'. First 15' of bit run drilled fairly steady 7-l0'/hr.. Then drilling became erratic stopping and having to pick up off bottom to clean up bit. Picked up and drilled rotating l' to 12,589' to clean bit. Attempted to survey with Inteq "Navi-Trac" MWD and reorient turbine. Had problems getting survey to decode. Varied pumps and rates and began getting good surveys with 130 gpm.. Increased flow and continued getting good tool face information @ 180 gpm.. Continued drilling 6" oriented high side to 12,591', lost pump pressure and drawworks throttle. Lost contol power to mud pump and drawworks due to ground fault in DC control panel. Found panel door was touching electrical connections. Adjusted door and reassigned power, ok.. Continued drilling 6" hole oriented straight up to 12,594'. Unable to keep bit drilling. Surveyed @ 12,514' 59.4 deg. 342.7 az.. Mixed and pumped slug to dry pipe. POH for bit and BHA. Pulled wet. Layed down BHA. Bit cored out in throat, 1/16" out of gage. Preparing to test BOPE @ 2400 hrs.. Pulled wear bushing and made up test joint. Performed weekly BOPE test. Tested annular preventer to 250 & 3500 psi., tested all valves, gates, and inside BOP to 250 and 5000 psi.. Choke manifold was tested while POH. UNOCALfi) .-- Unocal Corporation Detailed Activity Report i~ UNOCALfi) 8/2/98 8/3/98 8/4/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 L14 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 24 6C 68 38 5.00 0.50 10.00 28 5 6A 6A 6C 6A 4.50 38 0.50 28 28 6.50 5 0.50 6B 6B 6C 3.00 2.50 1.50 68 28 28 4.50 4.00 2.00 28 28 28 0.50 2.75 2.00 28 ~8 28 1.50 2.75 1.50 5 0.50 6B 5.00 6C 9 1.50 1.50 6C 6B 0.50 5.75 0.50 02:30 1.00 03:00 04:00 09:00 09:30 0.50 4.00 19:30 20:00 1.50 1.00 00:00 01:30 02:30 07:00 6.50 07:30 14:00 20:30 21:00 00:00 02:30 04:00 08:30 12:30 14:30 15:00 17:45 19:45 21:15 00:00 01:30 '02:00 07:00 08:30 10:00 10:30 03:00 04:00 09:00 09:30 19:30 20:00 00:00 01:30 02:30 07:00 07:30 14:00 20:30 21:00 00:00 02:30 04:00 08:30 12:30 14:30 15:00 17:45 19:45 21:15 00:00 01:30 02:00 07:00 08:30 10:00 10:30 16:15 12594.0 12594.0 12560.0 12594.0 12708.0 12708.0 12708.0 12708.0 12700.0 12708.0 12800.0 12915.0 12915.0 12915.0 12915.0 12915.0 13016.0 13041.0 13111.0 13138.0 13155.0 13195.0 13210.0 13210.0 13210.0 13210.0 13210.0 13210.0 13210.0 0.0 1aid down test joint and set wear bushing. Picked up 4 3/4" Navi Drill Mach l/ADM with ako @ 1.5 deg.. Hade up BRA and tested MWD. RIR with bit #8, BRA #7 to 12,560'. Reamed from 12,560-12,594', surveyed and oriented mud motor. Drilled from 12,594'-12,708' with steerable motor asseIT~ly oriented 151. Surveys and orietation with Inteq "Navi-Trac" MWD. Circulate and pump slug to dry pipe. POH for new bit #9 with no hole problems @ 2400 hrs.. Completed POH with bit #8, BHA #9. Changed bit and surface tested motor and MWD. Bit #8 had broken gage cutters and showed cone wear on outside edge of cones. Shank protection held up well. Inside cutters evenly worn. RIH with bit #9, BHA #10, steerable motor assemlbly, to 12,700'. Reamed undergage hhole from 12,700'-12,708'. Surveyed and oriented mud motor. Drilled 6" hole from 12,708'-12,800' oriented high side. Using Inteq ";Navi-Trac" MWD for surveys and 'o'rientation. Drilled 6" hole from 12,800'-12,915' rotating. Began seeing some torque increase. Surveys with Inteq "Navi-Trac" MWD. Surveyed and checked for flow. Mud weight in 8.7#/gal./ out 8.7 #/gal.. Pumped slug to dry pipe. POH for bit and BHA @ 2400 hrs.. Completed POH for bit #10. Made up bit #10, BHA #11, Steerable motor assembly with .9 deg. ako.. RIR with bit #10, B~~ #11 to 12,885'. Drilled 6" hole from 12,915'-13,016' with steerable motor assembly rotating. Drilled from 13,016'-13,041' oriented 251. Replaced o-ring on Tasco top drive that failed while making connection. Drilled from 13,041'-13,111' rotating. Drilled from 13,111'-13,138' oriented 251. Drilled from 13,138'-13,155' rotating. Drilled from 13,155'-13,195' oriented 251 @ 2400 hrs.. Drilled 6" hole with steerab1e motor assembly from 13,195'-13,210' rotating. Survey with Inteq "Navi-trac" MWD. Check for flow. Pump slug to dry pipe. POH for bit and BHA with no hole problems. Changed out bit, MWD and Motor. Slipped and cut drilling line 110'. Changed out saver sub on top drive. Completed making up BRA #12. Completed RIH with bit #11, BHA #12 to 13,210'. UNOCAL8 ,~Unocal Corporation Detailed Activity Report ,'-""'" UNOCALI> 8/5/98 8/6/98 8/7/98 8/8/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 2B 28 28 28 1.00 2.00 1.25 28 28 3.50 2B 2.00 28 0.50 28 6F 0.50 6B 6A 2.00 6A 6.00 2B 28 28 2.00 4.00 28 8.00 28 6F 6A 6C 6A 6A 4.00 2.50 2B ~8 28 28 2B 28 18 6A 6A 6A 1.75 16:15 1.75 18:00 19:45 20:45 22:45 00:00 03:30 05:30 HO 06:00 07:00 5.00 07:30 12:30 14:30 1,50 20:30 22:00 00:00 04:00 0.50 12:00 12:30 0.50 5.50 1.50 13:00 18:30 20:00 00:00 2.50 02:30 1.50 05:00 2.50 06:30 4.50 2.50 09:00 \ 13:30 2.00 16:00 0.50 1.00 4.50 2.00 18:00 18:30 19:30 00:00 18:00 19:45 20:45 22:45 00:00 03:30 05:30 06:00 07:00 07:30 12:30 14:30 20:30 22:00 00:00 04:00 12:00 12:30 13:00 18:30 20:00 00:00 02:30 05:00 06:30 09:00 13:30 16:00 18:00 18:30 19:30 00:00 02:00 13233.0 13259.0 13289.0 13322.0 13325.0 13393.0 13424.0 13427.0 13442.0 13442.0 13442.0 13442.0 13442.0 13460,0 13491.0 13536.0 13590.0 13600.0 13600.0 13600.0 13600.0 13600.0 13600.0 13630.0 13649.0 13679.0 13740.0 13767.0 13781.0 13781.0 13781.0 13781.0 13781.0 Drilled 6" hole with steerable motor assembly from 13,210'-13,233' oriented 301, surveys and and orientation with Inteq "Navi-Trac" MWD. Drilled from 13,233'-13,259' oriented 351. Drilled from 13,259'-13,289' rotating. Drilled from 13,289'-13,322' oriented 701. Drilled from 13,322'-13,325' rotating at 2400 hrs.. Drilling, W/Motor 13393' Connection Drilling, W/Motor 13424' @ 1151 Drilling, W/Motor 13427' Connection Drilling, W/Motor 13442' @ 1251 Work pipe & mointor well, survey & dry job Pooh w/ no problems (mtr plug w/ dry job) Remove mwd & l/dn bit & mtr, clean floor , P/up stab & mtr & orient, M/up bit & test mwd Rih & fill pipe (3) times & safty ream f/ 13412' w/ no problems Drilling, W/Motor Slide f/ 13442' t/ 'Ù460' @ 1201 Drilling, W/Motor Rotary f/ 13460' t/ 13491' Drilling, W/Motor Rotary, f/ 13491' t/ 13536' connection & survey Drilling, W/Motor Slide, f/ 13536' t/ 13590' @ 1601 & survey (having problem w/ MWD tool face going magnetic) Drilling, W/Motor Rotary, f/ 13590' t/ 13600' Work pipe & monitor well, survey & pump dry job Pooh w/ no problems 1/dn mwd probe, clout bit, Up ako on mtr, clout stab, orient mtr & install new mwd probe & test Rih & fill pipe twice Finish rih & fill pipe @ shoe, rih & set dn @ 12867', 13127' & 13256' kelly up on all knots & clean up same, set dn @ 13527' kelly up & ream t/ btm Drilling, W/Motor Slide, f/ 13600' t/ 13630' @ 180 deg & connection Drilling, W/Motor, Rotate f/ 13630' t/ 13649' Drilling, W/Motor, Slide f/ 13649' t/ 13679' @ 180 deg Drilling, W/Motor, Rotate f/ 13679' t/ 13740' connection & survey Drilling, W/Motor, Rotate f/ 13767' t/ 13781' & survey Drilling, W/Motor, Slide f/ 13767' t/ 13781' Chk mtr (no reactive torque) survey & monitor well Pooh to shoe wet (40k over @ 13204') Pump dry job & pooh wet Finish pooh (wet) Rotary, f/ 13325' t/ & survey Slide f/ 13393' t/ Rotary f/ 13424 t/ & survey Slide f/ 13427' t/ UNOCALe ~Unocal Corporation Detailed Activity Report ,~ UNOCALe 8/9/98 8/10/98 8/11/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 6C P2 P2 P2 6A 3B 28 P2 P2 P2 2B 10 28 P2 28 P2 28 P2 68 P2 P2 P2 68 68 45 P2 P2 P2 P2 15A 6C 15A 6C P2 P2 6B 7 68 P2 P2 28 2B 2B P2 P2 P2 28 2B P2 P2 2B 28 P2 P2 6A P2 5 P2 P2 6A ~c A14 42B P2 6C P2 6A P2 6A P2 6A P2 6A P2 P2 9 6F P2 28 4.00 1.50 0.50 0.50 1.00 5.00 2.00 4.00 3.00 0.50 3.50 1.75 2.25 3.00 0.50 6.50 1.00 2.50 1.50 1.00 1.00 1.50 2.50 1.00 3.50 6.50 2.00 02:00 5.00 0.50 0.25 04:00 09:00 09:30 1.75 09:45 0.25 3.25 11:30 11:45 15:00 3.00 0,75 18:00 1.25 18:45 20:00 00:00 01:30 02:00 02:30 03:30 08:30 1.50 1.00 10:30 12:00 13:00 17:00 20:00 20:30 00:00 01:45 1.75 04:00 05:45 1.25 08:45 10:00 10:30 17:00 18:00 20:30 22:00 23:00 " 00:00 01:30 04:00 05:00 08:30 04:00 09:00 09:30 09:45 11:30 11:45 15:00 18:00 18:45 20:00 00:00 01:30 02:00 02:30 03:30 08:30 10:30 12:00 13:00 17:00 20:00 20:30 00:00 01:45 04:00 05:45 08:45 10:00 10:30 17:00 18:00 20:30 22:00 23:00 00:00 01:30 04:00 05:00 08:30 15:00 13781.0 13781.0 13781.0 13782.0 13802.0 13802.0 13850.0 13874.0 13875.0 13875.0 13875.0 13875.0 13875.0 13875.0 13875.0 13875.0 13875.0 13875.0 13875.0 13875.0 13899.0 13899.0 13950.0 13972.0 13992.0 14012.0 14039.0 14039.0 14039.0 14039.0 14039.0 14039.0 14039.0 14039.0 14039.0 14039.0 14039.0 14039.0 14039.0 14164.0 1/dn mwd probe & mtr / p/up & m/up new mtr & bit, orient mwd probe & test & clean rig floor Rih & fill pipe (3) times (ok) Wash & ream last 70' (2'of hole under guage) Drilling, W/Motor, Rotary f/ 13781' t/ 13782' Drilling, W/Motor, Slide f/ 13782' t/ 13802' @ 180 deg. Directional Survey & connection Drilling, W/Motor, Slide f/ 13208' t/ 13850' @ 180 deg. & survey Drilling, W/Motor, Slide f/ 13850' t/ 13874' @ 180 deg. & survey Drilling, W/Motor, Rotate f/ 13874' t/ 13875' & survey & call town Monitor well (ok), Pooh to shoe (ok,wet) & pump dry job Take torque readings @ shoe & Pooh Continue pooh & brk & chk bit Chk mtr orientation & clean rig floor & std back same pull wear ring & m/up test jt Brk dn & l/dn mwd collar & mtr Test BOP's w/ state man p/up mtr, M/up bit, set ako, load mwd probe & test Rih 'Chg/out top drive saver sub & service rig Continue rih & fill pipe (3} times &b wash & ream f/ 13850' t/ 13875' (w/ no problems) Drilling, W/Motor, Slide f/ 13875' t/ 13899' @ 180 deg. Ream, connection & survey Drilling, W/Motor, Slide f/ 13899' t/ 13950' @ 180 deg. Drilling, W/Motor, Slide f/ 13950' t/ 13972' @ 1551 & survey Drilling, W/Motor, Slide f/ 13972' t/ 13992' @ 180 deg. Connection & survey Drilling, W/Motor, f/ 13992' t/ 14012' @ 180 deg. & survey Drilling, W/Motor, Rotary f/ 14012' t/ 14039' & survey Monitor well (ok), Pooh t/ shoe w/ no problems, Drop dart & sheer out pump out sub & pump dry job Pooh Remove mwd probe, brk & chk bit & l/dn mtr Chg/out top drive IBOP valve P/up bha H 17 & test mwd Rih & repair leek on top drive hose Continue rih Continue rih & P/up & Rabbit & strap (12) jts 3-1/2" dp Continue rih t/ shoe & fill pipe (3) times Cut & slip dr1g line (132') Tioh, Work wash & ream, Bha to btm ff 12825' Knots @ 12873', 13005', 1346h'- I V t'" D 13560', 13720', 13960: ~ lock Anderi{at'C E t stb ~n full guage pos~t~on Drilling, W/Motor, Rotary f/ 14039' tf 14164' ,';--¡-) 1'" 19°(1 ,'.. l í ! '" Ü. \iBsi(;1 ad 8, Ga$ Cons. CommissiOl ;\ncnorage UNOCAL(; ~,Unocal Corporation Detailed Activity Report --. UNOCAL(; 8/12/98 8/13/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 28 28 45 2B 2A 10 6A 6A 6C 6A 3B 2A 2A 10 28 2A 28 2A 10 1.00 0,50 68 3.00 15:00 3.00 18:00 0.50 2.50 21:00 21:30 8.50 0.50 00:00 08:30 1.50 09:00 5.00 1.00 10:30 15:30 g.25 16:30 1.00 22:45 0.25 23:45 0.25 0.25 3.50 00:00 00:15 00:30 0.75 3.25 04:00 04:45 08:00 09:00 1.00 09:30 0.50 ' 10:30 5 6B 6C 4.00 2.50 11:00 15:00 18:00 21:00 21:30 00:00 08:30 09:00 10:30 15:30 16:30 22:45 23:45 00:00 00:15 00:30 04:00 04:45 08:00 09:00 09:30 10:30 11:00 15:00 17:30 14182.0 14219.0 14219.0 14182.0 Drilling, W/Motor, Slide f/ 14164' t/ 14182' @ 180 deg. Connection & survey (good tool face) Drilling, W/Motor, Survey (having problems holding good tool face & bha slip stickin) close anderguage stb & slide f/ 14182' t/ 14219'@ 1651 & ream slide Connection, lock Anderguage in full guage position & survey Drilling, W/Motor, Rotate f/ 14129' t/ 14254' Drilling, Rotary f/14254'-t/14319'. Directional Survey, retract andergauge stab and monitor well. (Sensor depth at 14252'-incl 98.80, AZ- 338.10.) POOH to shoe at 12365'with no problems drop dart shear cir sub,pwmp dry job. POOH.BHA # 17 BIT # 16R4 lay dn bit # 16r4.sec fm2643I.pick up bit # 17 see fm2643I.Surface test MWD and mud mtr. Run in hole bit # 17 BHA # 18.rotate 5 stds 3 1/2"drill pipe from above HWDP to below HWDP and 5 from below to above. Continue run in hole.had to work through the following depths with 50 kip.12577' '~2869',12980',13380',13545',14104' . Break circulation and ream f/14259'-t/ 14319'working pipe and faning bottom open andergauge stab. Drilling, Rotary f/14319'-to/14326' with 3-4 kip on bit gpm 250-270, 80 rpm rty and 270 rpm mtr. Drilling, Rotary F/14326'-T/14330' Directional Survey, ORIENT TF for slide. Drilling, W/Motor f/14330-t/14349'spent .75 hrs orienting and attempting to hold tool face at 180 deg. Drilling, Rotary f/14349'-t/14354' Drilling, W/Motor f/14354'-t/14375' spent 1 hr orienting and attempting to hold tool face at 180 deg. had high differential pressure and mtr stalls. ROP tappered off to 0 with not much show of mtr work. Drilling, Rotary f/14375'-t/14387' Directional Survey ,angle still building sensor depth at 14323' angle 100.8 deg AZ = 339.8, work pipe and eire. POOH for BHA and bit change/ pull to shoe AT 12365' WITH NO PROBLEMS. Drop dart and shear out circ sub.pump dry job. Continue POOH with Bha # 18 bit # 17. LAY DOWN BIT + X1 mtr + THRUSTER + ANDER GAUGE STAB. pick up STR 20 D BIT + ADM MTR + stab and change out mwd.surfaee test mtr and MWD. UNOCAL(Ø ~Unocal Corporation Detailed Activity Report ",--...., UNOCAL(Ø 8/14/98 8/15/98 8/16/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 2A \ P2 P2 P2 P2 P2 P2 P2 6B 3B 2B 2B 36 2A 10 2A 5 6A 5 6A 6C 6A 6A 38 2A 2A 10 5 6A 5 6A 6A 28 24 5.50 17:30 0.75 23:00 0.25 23:45 4.50 00:00 0.50 2.50 0.50 04:30 05:00 07:30 1.00 08:00 1.50 09:00 1.00 10:30 0.50 4.50 2.50 11:30 12:00 16:30 5.00 19:00 1.50 00:00 0.50 6.00 4.50 0.50 01:30 02:00 08:00 12:30 5.00 13:00 1.00 18:00 1.50 0.50 3.00 1.50 \ 19:00 20:30 21:00 00:00 0.50 1.00 01:30 02:00 23:00 run in hole/ fill pie at 5068,8811,12294 continu in hole to 14281'.had no problem in open hole what so ever. Kelly up and wask and ream f/14335'- to/ 14387' pick up ant take dir survey orient tool face and prep for slide. Drilling, W/Motor f/14387'-t/14400' holding tool face at 180 deg. Drilling, W/Motor F/14400'-T/14450'at 180 deg.spent 1 hr picking up to orient while sliding. ream 63'mud mtr set f/14387'-t/14450' Drilling, Rotary f/14450'-t/14504' Connection and dirrectional survey. SENSOR DEPTH 14456'Incl 94.6 AZ 337.50 Drilling, Rotary F/14504'-T/14525' ROP stared to slow down to 10'per/hr.had small increase in rty torque. actual bit hrs = 8. Took directional survey, sensor depth 14478'Incl 94.30 AZ 334.9,Noticed bit starting to stear 1eft,a trend we have not seen in this section with a tri cone bit. suspected possible bearing failure. Circulate and mix dry job. POOH to 7"csg shoe at 12365' with no 'problems in open hole. Drop dart, shear circ sub, pump dry job. Continue POOH with BHA # 19 Bit # 18. Lay down bit and ADM mtr.bit was less than 1/8" all inserts gone on gauge row and seals failed on all 3 cones. Pick up Hycalog DS111 bit + new XL mtr set AKO to .8 + Andergauge Stab and thruster, change out MWD.Surface test MWD and mtr. Run in hole BHA # 20 Bit # 19.Pick up 12 jts 3 1/2" drill pipe, rotate 4 stds of 3 1/2"pipe from above and below the 36 jts of HWDP.Run in hole t/ SHOE Continue run in hole to/14508.had to work through several tight spots due to andergauge stab f/12660'-t/14508' Ream f/14508'-t/14525' Drilling, Rotary f/14525'-t/14646' 3/4 hrs spent on connection and surveys Drilling, Rotary f/14646'-t/14698' Directional Survey and connection. sensor depth 14638' Inc1 95.8 AZ 334.9 Drilling, Rotary F/14698'-T/14723' ROP Gradually tapered off to 2' per hr in the last three hrs of this run, take dirrectional survey, sensor depth 14661' Incl 96.10 AZ-335.4. circulate and mix dry job. POOH to shoe with no problems. Drop dart, shear circ sub, pump dry job. Continue POOH W/ BHA # 20 Bit # 19 Continue POOH,W/BHA # 20 BIT # 19. Break out bit, PDC cutting structure 100% worn bit was still full gauge. clean up rig floor of oil base mud. Drain stack.make up test jt,pul1 ware bushing and set test plug. 23:45 00:00 04:30 05:00 07:30 08:00 09:00 10:30 11:30 12:00 16:30 19:00 00:00 01:30 02:00 08:00 12:30 13:00 18:00 19:00 20:30 21:00 00:00 01:30 02:00 03:00 UNOCAL(; ~. Unocal Corporation Detailed Activity Report ~ UNOCALfj 8/17/98 8/18/98 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 P2 2A P2 P2 P2 28 '. 2A 10 P2 P2 2A 28 P2 P2 P2 P2 2A 10 2A 5 5 P2 15A 24 6C 6A 6A 38 2A 10 2A 10 0.50 6B 5 68 6C 2.00 0.50 3.50 1.00 6C 1.00 6B 9 68 3.50 1.00 0.50 3B 10 0.50 0.50 1.50 0.50 0.50 0.50 2.50 03:00 0.50 0.50 3.00 05:30 06:00 06:30 1.00 09:30 0.50 5,00 0.50 10:30 11:00 16:00 5.00 16:30 21:30 22:00 00:00 00:30 04:00 05:00 06:00 09:30 10:30 11:00 11:30 12:00 13:30 14:00 14:30 3.00 1.00 15:00 16:00 3.00 0.50 0.50 1.00 0.25 19:00 22:00 22:30 23:00 00:00 05:30 Test annular at 250-3500 psi.Test top pipe rams,btm pipe, rams,blind rams and wing valves at 250-5000 psi.Test floor valves and top drive IBOP,and manual valve at 250-5000 psi, run Koomey draw down test.A.O.G.C.C. Waved test.Tested choke manifold at 250-5000 psi on trip out. all surface equipment tested good. Pull ware bushing set test plug. Make up SEC FM2643I Bit,TEST MWD. Run in hole w/BHA # 21 BIT # 20 TO Shoe fill pipe and break circulation. Continue Run in hole,had to work ander gauge stab through several areas with 30-50 kip,with out rotating.f/12660'- t/14690'no hole problems noted.proper running speed Seems to be the key. Kelly up and ream f/14698'-t/14723'btm Drilling, Rotary f/14723'-t/14792' Directional Survey and connection. had trouble puming up survey(DID NOT GET SURVEY ON THIS CONNECTION.) Drilling, Rotary F/14792'-T/14822'.rop still falling off.having to run more wt but apears to be closing thruster then falls back to 2'per/hr. Directional Survey, pump up survey 4 times before we could get agood one. s.ensor depth 14759' Incl 97.20 AZ 332.60 'survey is still questionable getting very poor signal.plan on changing out MWD on trip out and take survey when back on bottom. POOH W/BHA # 21 BIT # 20 wino problems. Drop dart, shear circ sub, pump dry job. Continue POOH with BHA # 21 BIT # 20. lay down bit,XL mtr,thruster,andergauge stab and MWD. bit still in great shape can be rerun on future bit run. Make up HTC-STR20D bit + ADM mtr and 5 3/4" string stab. pick up MWD.Orient mtr to MWD,surface test and clean floor. Run in hole with BRA # 22 Bit 21 Sop at shoe, cut and slip 140'drlg line Continue to run in hole to l4760'had no problems in open hole, Kelly up and ream f/14760'- t/14822' Directional Survey, sensor depth 14776' Incl 97 AZ 335.9. Attempt to slide at 30R, no go still to tuff. Drilling, Rotary f/14822'-t/14839'start drilling break, orient for slide, Drilling, W/Motor f/14839'-t/1485l' at straight up to 30R. l2'SLIDE. Drilling, Rotary F/1485l'-T/14858' Directional Survey and connection Incl 97.30 AZ 336. Drillinq, Rotary F/14858'- T/14873' Drilling kelly down some for slide. Drilling, W/Motor f/14873'-t/14907' spent 3/4 hrs orienting tool face the majority of the slide was at 30-35 R Ream slide,rty drill f/14907'-t/14907' Directional survey, and connection depth 14896' Incl 101.5 AZ 336.10 Drilling, Rotary F/14947'-T/14962' Circulate & Condition and take survey sensor depth 14912' Incl 102.2 AZ 336.3 Continue circulate btms up. 06:00 06:30 09:30 10:30 11:00 16:00 16:30 21:30 22:00 00:00 00:30 04:00 05:00 06:00 09:30 10:30 11:00 11:30 12:00 13:30 14:00 14:30 15:00 16:00 19:00 22:00 22:30 23:00 00:00 14962.0 00:15 UNOCALfØ ,~Unocal Corporation Detailed Activity Report ,~ UNOCALfØ 8/19/98 8/20/98 7 7 7 7 7 7 7 7 7 7 7 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 P2 P2 P2 P2 6A 5 68 6C P2 6B P2 68 P2 2A P2 10 P2 L2 2A 2A P2 P2 P2 P2 2A 2A 2B 5 P2 6F P2 5 P2 P2 6F 6C P3 29A P3 P3 11A 11A P3 6F P3 11A P3 11A P3 11A P3 11A , P3 P3 11A 11A P3 11A 1.25 0,50 3,50 1.50 4.50 0,50 3,50 2,50 0,50 2,00 4,00 1,00 4,00 00:15 01:30 02:00 05:30 07:00 0,50 11:30 2.50 12:00 14:30 5.00 0.50 15:00 20:00 20:30 00:00 02:30 03:00 1.50 05:00 0.50 06:30 07:00 11:00 5.00 12:00 2.00 1.00 17:00 19:00 20:00 1.50 00:00 4.50 01:30 1.50 06:00 2.50 07:30 1.50 1.50 10:00 11:30 1.50 13:00 01:30 02:00 05:30 07:00 POOH to shoe 12365' with no problems Drop dart,shear circ sub,pump dry job Continue pooh w/BHA # 22 BIT # 21 Lay down bit + ADM mtr + 5 3/4" stab pick up sec fm2643I R1 BIT + XL mtr set at .8 deg + andergauge stab change out mwd pick up thruster.Test mtr+mwd. Run in hole w/BHA # 23 BIT # 22R1 TO shoe and fill pipe break circulation. Continue run in hole to 14900' with no problems in open hole. Ream f/14900'-t/14962'.DRILL with rty f/14962'-to/14981' Directional Survey and connection. Open andergauge stab to 6"( sensor depth= 14981' Incl 102.4 AZ 335.40) Drilling, Rotary F/14981 - T/15007' Lost pump presSure, change pumps had trash under valves. open andergauge. Drilling, Rotary f/15007'-t/15038' Drilling,rotary f/ 15038' to 15076' Slide f/ 15109' to 15114' Last 65' was coal,decision made to POH. Circulate bottoms up. POH to casing shoe.No over pulls hole slick.Strap pipe. Drop circulating sub dart,shift sleeve,pump dry job POH,strap pipe.Strap +6'. Day down jars,motor, thruster,Andergauge,MWD, 2 jts HW dri11pipe, break bit. Waiting on TLC tools.Change saver sub and TESCO 37 pin power cable to top drive.Schlumberger rigged up unit and layed out logging tools. Pick up Quad Combo. Plug wet connect into top of tools and turn on tools, calibrate same. Trip in hole wi Quad Combo and drift pipe. Circulate 5 minutes at 3600',p/U 32 jts 3 1/2" drill pipe,drift same,change e1avators TIH w/5" drill pipe,drift same,circulate at 8200' for 5 minutes,TIH to 11680' and circulate 5 minutes Held pre-job safety/operations meeting on TLC logging,hang wireline sheave in derrick,p/u side entry sub Run inside drill pipe with wet connect. Pump at @ 150 GPM while stabbing wet connect in. Power up tools.Got 120' of slack inside drill pipe. Clamp off line on side entry sub. Log down to @12,650, lost power to tool. Pull 2 stands into shoe, pump and attempt to get wet connect to stab back into socket by pumping at 200 gpm,POH to side entry sub. Remove wireline clamp,pick up wet connect 200',circulate and stab wet connect into socket. Pull test connection to 600 lbs (latch will release at @1600 Ibs) .Got @150' slack inside drill pipe.Reclamp line to side entry sub. 11:30 12:00 14:30 15:00 20:00 20:30 00:00 02:30 03:00 05:00 06:30 07:00 11:00 12:00 17:00 19:00 20:00 00:00 01:30 06:00 07:30 10:00 11:30 13:00 14:30 UNOCALG ..~ Unocal Corporation Detailed Activity Report "-"'. UNOCALG 8/21/98 8/22198 8/23/98 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 P3 P3 P3 P3 P3 P3 6F 11E 11E P3 P3 P4 P4 P4 11E 6C 6F 5 P4 9 P4 6F P4 5 P4 6F P4 P4 6F 5 P4 P4 P4 P4 P4 P4 P4 6F 5 6F 13A 13A 13A 13A P4 13A 13A L4 L4 13A L4 13A 11A 11A 11A 11A 15.50 2.00 0.50 4.00 0.50 3.50 0.50 2.50 1.00 0.50 4.50 1.00 6.00 1.00 4.50 1.00 1.00 2.50 0.50 6.50 14:30 3.00 1.00 21:00 00:00 1.50 01:00 3.50 2.50 02:30 06:00 08:30 00:00 02:00 02:30 06:30 1.00 07:00 1.00 08:00 09:00 1.50 12:30 14:00 14:30 17:00 18:00 18:30 23:00 00:00 06:00 07:00 " 11 :30 12:30 13:30 16:00 21:00 RIH with Quad combo.Had trouble at getting down at 12665'-12687', 12990'-13010' (spent @20 minutes working thru each of these spots, set up to 4500 lbs on tool) .Filled pipe every 10 stands. Logged down to 15000' and pulled 1 repeat pass to 14656'. POH logging up. Log out of hole(w/Quad combo)to side entry sub at 11652'. Remove clamp,pull wireline out,break and lay down side entry sub. Pump dry job, POH wi th Quad Combo. Lay down Quad Combo tools. Rig up sheave on blocks. Make up RST and RIH to 12350'.Log back to 12100'.Made 4 passes at 80 FPH. Logging w/Schlumberger running RST.POH and rig down. Pick up BHA. TIH,fill pipe at 7000'. Fill pipe and break circulation at 12000' . Cut drilling line, circulate while cutting line. TIR to 15020'. (Thought we were at 14925' but when pipe was counted had run 1 stand too many of 3 1/2" drill pipe in hole. confirmed when pulled out of :n~le.}Tagged bridge at 15020'.Broke circulation every 10 stands. Circulate, hole tried to pack off on bottom(15020').Pump 12.5+ ppg sweep.Began getting coal back as soon as we started circulating(nickel size pieces).Cleaned up to fine ground up size.When sweep came around slight increase in fine, ground up coal. POH tight at 14772'-14733'.Back reamed and work thru until we could pull thru wlo rotating.Hung up 1 time had to torque and slump to break free. POH to 14015'. Circulate and pump 12.5+ sweep.Minimal amount of coal on bottoms up. POH to shoe. Drop dart, shear sub,pump dry job. POH, lay down BRA. Rig up to run 4 1/2" perforated liner. Pick up and run 4 1/2" perforated liner. Rig up to run 2 7/8" PAC inner string. Pick up 2 3/8" Polished Nipple. p/u 2 7/8" PAC drill pipe and drift same wl1 3/8" drift. PAC pipe had dried mud scale,had trouble getting drift thru several jts and had to lay down 2 jts and recover drift. Fill pipe every 10 stds. Stab into packoff,pull out and space out with 2 7/8" pups. Pick up ZXP packer, could not stab ZXP assy in top jt of packer due to damage on top jt of 4 1/2" liner.Lay down ZXP assy. POR with PAC,wet,stand back in derrick.Lay down polished nipple assy.Lay down top blank jt and pick up new blank jt. Clean OBM from rig floor. 00:00 01:00 02:30 06:00 08:30 00:00 02:00 02:30 06:30 07:00 08:00 09:00 12:30 14:00 14:30 17:00 18:00 18:30 23:00 00:00 06:00 07:00 11:30 12:30 13:30 16:00 16:30 UNOCAL8 - ~Unocal Corporation Detailed Activity Report ---. UNOCAL8 8/24/98 8/25/98 8/26/98 8 8 8 8 8 8 8 8 8 8 8 8 10 10 10 10 10 10 10 10 10 10 10 10 L4 P4 P4 P4 13A 5 P4 P4 P4 45 P4 5 P4 P4 P4 6F 45 6F P4 15A P6 15A P6 P6 P6 6C 6F 5 P6 P6 45 318 P6 45 \ P6 45 P6 45 P6 P6 6F 6C 23 P6 13A 13A 13A 13A 6.00 0.50 3.50 2.50 1.50 1,50 5.00 4.50 0.50 6.50 4.50 7.50 0.50 4.50 0.50 2.50 2.50 16:30 1.00 4.00 19:00 20:00 3.50 00:00 1.00 03:30 2.00 04:30 3.00 06:30 2.00 09:30 11:30 17:30 18:00 21:30 00:00 01:30 03:00 08:00 12:30 13:00 19:30 00:00 07:30 08:00 12:30 13:00 19:00 RIH w/ PAC drill pipe, fill pipe every 10 stands. P/U Liner top packer.Make up same. RIH w/liner,pumped drill pipe volume after 1st stand of HW,fill every 10 stds,break circulation and circulate 15 minutes at 4000',8000'. RIH w/perforated liner, fill every 10 stands. Circulate at 7" shoe 12350',check p/U-S/O-RT wts and torque. RIH w/perforated liner, fill every 10 stands. Drop ball and pump down. Set packer. Test casing to 2400 psi for 10 minutes. Pressure up and release from liner(3500 psi). Shear ball seat(4000 psi). * Top of liner -12256' * Shoe - 15072' Displace w/diesel 6" x 4 1/2" and 4 1/2" x 2 7/8"(107 bbls). Reciprocate inner string while displacing (short stroke 6" x 4 1/2",long stroke 4 1/2" x 2 7/8") .Displace w/ mud and dry job(164 bbls) . POR to 2 7/8" PAC drill pipe. Rig up GBR and handling tools. Lay down setting tool, 2 7/8" drill pipe and slick stick. 'PUll wear bushing, run test plug,test annular to 250/3500,test remainder of BOP to 250/5000. Finish testing BOP to 250/5000 psi. Pull test plug and run wear ring. p/U up triple mill assy. RIH TO 12246'. Rig up and reverse circulate. While circulating rigged up line from choke manifold to slop tank and injection line to well G-22.Rig up to pump excess MAPCO to production. Held pre-job safety/operations meeting. Displace (reversed)w/ 50 bbl MAPCO,50 bbl "Kleen Up", 3% KCL water. (While displacing filled Isotanks and loaded on boat, pressure tested injection line, pumped away 80 bbls water(as a rate test),mixed KCL on the fly in pill tank.)Displaced at 3.5-4.0 bbl/min at 800-1000 psi.Didn't see much separation of MAPCO and OBM.Pumped an excess 250 bbls of KCL until displacement became cl Circulate thru choke line, gas buster, choke manifold to slop tank.Inject 517 bbls to G-22.Clean reserve tank,drip pan,trip tank. Finish cleaning reserve pit, rig floor, trip tank & lines, & reserve tank suction line & build 200 bbls volume in reserve tank Knock out KOIV at 12077' w/ 28k set down wt.,polish & dress tie back receptacle (no losses to formation). POR fltie back assy. L/dn 9-5/8" esg scraper & std back 3-1/2" drill pipe. L/D 36 jts RWDP, 5 jts 2-7/8", PAC drill pipe & mill. 20:00 00:00 03:30 04:30 06:30 09:30 11:30 17:30 18:00 21:30 00:00 01:30 03:00 08:00 12:30 13:00 19:30 00:00 07:30 08:00 12:30 13:00 15:30 UNOCALG /,""",Unocal Corporation Detailed Activity Report ..~ UNOCALG 8/27/98 8/28/98 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 P6 P6 P6 P6 P6 P6 P6 P6 P9 P9 P9 P9 P9 A9 P9 A9 A9 \, 6C 6F 45 45 23 23 23 24 28 13A 10.50 2.00 3.00 0.50 1.00 7.00 4.50 13A 13A 13A 14C 14A 14C 2.50 14C 1.50 15:30 4.50 1.50 17:00 21:30 1.00 23:00 00:00 10:30 12:30 15:30 16:00 17:00 00:00 4.00 04:30 1.00 08:30 1.50 09:30 5.50 11:00 16:30 5.00 19:00 17:00 P/U & M/U Baker tie back seal assy + xo +lO'pup jt + XN nipple + jt + pup jt + xo + seal bore ext + model "F" packer + running tool + bumper sub RIH Stab seal assy. & test back side t/ 2300 (ok} drop 1-7/16" ball, test csg tl 2400 psi for 30 min (ok) Set prk @ 10438' & blowout ball seat @ 4000 psi & release running tool. Pooh & I/dn 5" dp & back load boat Chk & I/dn bha & rih w/ 3-1/2" dp Pooh & I/dn 3-1/2" dp Pull wear ring R/up GBR & PJSM Run, rabbit & strap 5-1/2" gas lift completion Run, rabbit & strap 5-1/2" gas lift completion P/up SSSV & control 1 line & test to 500/5000 psi (ok) I Reverse circ 60' above prk & chk SSSV (ok) I circ & stab seals & test (ok) I space out & m/up hanger & test control line (ok, total 11 SS bands) Stab seals & Land hanger & test seals (ok) Backed out one lock dn pin to insure hanger was set properly, installed new :lúck dn pin & packing & ran in all lock dn pins, Chg/out one bad inner chk valve in packing port & pack off hanger Pulled landing jt & set BPV & nip/dn, kill line, choke line, flowline, drip pan, mouse hole, Bag, Hung double gate, mudcross & single gate on trollys & pulled riser. Tree unable to clear drip pan (disassemble tree) & lower into well head room Reassemble & nip/up tree & test neck seals tl 5000 psi (ok) (the tub. head adapter does not have profile for inner chk valve) pulled BPV & installed two-way chk valve & shell tested tl 250/5000 psi (ok) & released well to production 21:30 23:00 00:00 10:30 12:30 15:30 16:00 17:00 00:00 04:30 08:30 09:30 11:00 16:30 19:00 00:00 r---. .~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnc:t~ Chairman ~ Blair Wondzell, æ~ P. I. Supervisor ~ /«(qe Larry Wade~ Petroleum I~r DATE: August 8, 1998 THRU: FILE NO: .DOC FROM: SUBJECT: BOP Test Poole 55 UNOCAL Grayling PTD 98-99 August 8,1998: I drove to Kenai OSK after the drill bit unexpectedly failed on UNOCAL's Grayling platform to witness a BOP test on Poole rig #55. The rig looked to be in order and despite drilling with oil-based mud was as clean as could be expected. The rig was drilling with a tapered tool string, thus the test on two TIW and Dart valves. The test was a little longer than usual because of the rigging up needed to test the floor valves and top drive valves. Other than a couple of needle valve failures the testing went well. SUMMARY: Witnessed a BOP test on Poole 55, 0 failures, 5 hours. Attachments: a59ghife.xls cc; NON-CONFIDENTIAL r'- ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial x Workover: Poole Rig No. 55 PTD # Rep.: Rig Rep.: 12,366 Location: Sec. X Other 98-99 DATE: ~W98 Rig Ph.# 776-6638 Shane Hauck Donnie Fowler 9N R. 13W Meridian Seward 7" UNOCAL G-15RD Set @ Weekly 29 T. TEST DATA Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure PIF Location Gen.: ok Well Sign Upper Kelly IIBOP 1 250/5,000 P Housekeeping: ok (Gen) Drl. Rig ok Lower Kelly IIBOP 1 250/5,000 P PTD On Location X Hazard Sec. X Ball Type 2 250/5,000 P Standing Order Posted X Inside BOP 2 250/5,000 P BOP STACK: Quan. Test Press. PIF Test Annular Preventer 1 250/2500 P CHOKE MANIFOLD: Pressure PIF Pipe Rams 1 250/5,000 P No, Valves 13 250/5,000 P Lower Pipe Rams 1 250/5,000 P No. Flanges 28 250/5,000 P Blind Rams 1 250/5,000 P Manual Chokes 1 Functioned P Choke Ln. Valves 1 250/5,000 P Hydraulic Chokes 2 Functioned P HCR Valves 1 250/5,000 P Kill Line Valves 2 250/5,000 P ACCUMULATOR SYSTEM: Check Valve 250/5,000 System Pressure 3,000 Pressure After Closure 1,425 MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 43 sec. - Trip Tank X X System Pressure Attained 3 minutes 0 sec. Pit Level Indicators X X Blind Switch Covers: Master: X Remote: X Flow Indicator X X Nitgn. Btl's: 2100-2100 Meth Gas Detector X X 2100-2200 Psig. H2S Gas Detector X X TESTREStJLTS Number of Failures: 0 ,Test Time: ~ Hours. NUmber of valves tested ~ Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO Waived By: Witnessed By: Larry Wade 24 HOUR NOTICE GIVEN YES X NO FI-O21L (Rev.12/94) A59ghife.xls '--"" ~, Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage,_AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 IE-mail: childersd@unocal.com UNOCAL8 Debra Childers Geotech Assistant August 6, 1998 DATA TRANSJVlITT AL To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items:. ~'~,<" U G,.15RD ;';;1 - Array Sonic Tool TVD -1 ~m2j198 ",..¥",."" TBU G-15RD 1 Array Sonic Tool/Gamma Ray VDL log 1~7121198 TBU G-15RD 1 15",2" Array Sonic Tool 1 7121/98 TBU G-15RD 1 15",2" Density-Neutron/Gamma Ray TVD 1 7/21/98 TBU G-15RD 1 1 5",2" Array Induction Tool/Gamma Ray 1 7/21/98 TBU G-15RD 1 1 5",2" Array Induction Tool/Gamma Ray TVD 1 7/21/98 '-/" TBU G-15RD 1 1 5",2" Density-Neutron/Gamma Ray 1 7/21/98 Q1'0t.4 TBU G-21RD 1 15" Cement Evaluation/Gamma Ray Log 1 5/30/98 ~ TBU G-21RD 1 15" Compensated Cement Bond/Gamma Ray Log 1 5/30/98 "ß~ '1..0 TBU G-5RD 1 1 5",2" Platform Express/Array Induction Imager/Gamma Ray 1 7/1/98 ().,'- TBU G-5RD 1 15" Gamma Ray Tie in Log 1 7/6/98 TBU G-5RD 1 15" Cement Bond Log 1 7/5/98 TBU G-5RD 1 15" Cement Evaluation Log 1 7/5/98 TBU G-5RD 1 1 5",2" Platform ExpresslThree Detector LithoDensity 1 7/1/98 Compensated Neutron/GR TBU G-5RD 1 15",2" Thermal Decay Time Log 1 7/5/98 .....,. TBU G-5RD 1 15" Digital Sonic Array/Gamma Ray 1 7/1/98 """" <j -,'. ,,-'"" - E r"',~' '~V;r Ii- ., 11 K, - ;¡, .",- ," æ-W ! -='" e~¿¡ :¡..,., ,; _so ack~. receipt by signing and returning one copy of th;s transmittal 0' FAX '" (907) 263-7828 , I_d by: ~. ~ - I Daœ~a$<aŒ~~~asO~':~~1,~J Anchorage ",""",, ....... TONY KNOWLES, GOVERNOR ALAS IiA 0 IL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 29, 1998 Dale Haines Drilling Manager UNOCAL POBox 196247 Anchorage, AK 99519 Re: Trading Bay Unit G-15RD UNOCAL Permit No. 98-99 Sur. Loc. 1835'FSL, 1491'FEL, Sec. 29, T9N, RI3W, SM Btmnhole Loc. 1075'FNL, 2302'FWL, Sec. 19, T9N, RI3W, SM Dear Mr. Haines: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval of annular disposal of drilling wastes is contingent on obtaining a well cemented surface easing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 to ensure the requirements of 20 AAC 25.080 are met prior to initiating disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole, Notice may be given by contacting the Commission at 279-1433. Robert N. Christenson, P,E. Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section wlo enc!. Department of Environmental Conservation wlo encl. 1a. Type of work Drill: Re-Entry: 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface Leg 4, Conductor 16, Grayling Pitt. 1,835' FSL, 1,491' FEL, Sec 29, T9N, R13W, S.M. At top of productive interval 740' FSL, 1,907' FEL, Sec 19, T9N, R13W, S.M. At total depth 1,075' FNL, 2,302' FWL, Sec 19, T9N, R13W, S.M. 12. Distance to nearest 13. Distance to nearest well property line 1,070' to Unit Boundr feet 16. To be completed for deviated wells Kickoff depth = 800' feet 18. Casing program size Casing 7" >, Hole 8-1/2" 6" 4.5" STATE OF ALASKA ALASKA Oh... .-\ND GAS CONSERVATION CvMMISSION PERMIT TO DRILL 20 AAC 25.005 Redrill: X 1b. Type of well Deepen: Service: . , /"", 140' to K-19 feet Maximum hole angle: 109 Weight 291b 12.61 Ib Specifications Grade Coupling L-80 Butt. TKC L-80 Butt. TKC 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12,885' feet true vertical 9,899' feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Liner Perforation depth: measured 12,621' feet true vertical 9,707' feet Length Size 377' 26" 600' 17-3/4" 5,820' 13-3/8" 9-518" ~. Exploratory: Stratigraphic Test: Developement Gas: X Single Zone: 5. Datum Elevation (DF or KB) 10. Field and Pool 99' KB above MSLfeet McArthur River Field 6. Property Designation JfJ¿ Hemlock ADL ~ /<; 77 '7 7. Unit or property Name Trading Bay Unit 8. Well number G-15RD 9. Approximate spud date 6/1/1998 14. Number of acres in property Development Oil: X Multiple Zone: 11. Type Bone (see 20 MC 25.025) AK Statewide Oil & Gas Bond Number U62-9269 Amount $200,000 15. Proposed depth(MD and TVD) feet 16,640 ac. 15,900' MD 18,898' TVD 17. Anticipated pressure(see 20 MC 25.035 (e)(2)) Maximum surface 2,572 psig At tctal depth (TVD) Setting Depth Length 3,400' 3,650' MD 10,700' 12,250' Plugs (measured) Top Bottom MD TVD 12,350' 9,372' 15,900' 8,898' TVD 8,312' 9,350' Rl:CtI'JED '( (j 0 1998 3,500 psig Quantity of cement (include stage data) 712 sx Slotted Liner ORIGINAL Junk (measur~~asl<a Oil & Gas Cons. Commission Anchorage Cemented Driven 700 sx 4,198 sx 11,210' 1,678' 1,382' measured true vertical 20. Attachmen'ts: Filing fee: X Property Plat: X BOP Sketch: X Drilling fluid program: X Time vs. depth plot: X Refraction analysis: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Title: Drilling Manager Commission Use Only Permit Number I API number I Approvalj.ate 1 0 91) I See cover letter '17"'99 50- 733- 2..01'19- of 5 /' c:f" /.... V forotherrequirements Conditions of approval Samples required: [] Yes 'H No Mud log required: [] Yes ]XI No Hydrogen sulfide measures ~] Yes [] No Directional survey required 1>4 Yes [] No Required working pressure for BOPE [] 2M; P4 3M; [] 5M; [] 10M; [] 15M Other: Signed: )JJ/.. Approved by 7" 5" See attached schematic ð)\~ Dale Haines ORIGINAL SIGNED BY RobQrt N. Chriatonsoo Form 10-401 Rev. 12-1-85 1,000 sx 350 sx Commissioner Measured depth 377' 600' r- 5,802' -1.1 ,212' 11,024' - ßZO2' 11,216' - 12,598' - Diverter Sketch: Seabed report: by order of the Commission True vertical depth 377' 600' 4,564' 8,997' 8,614' - 9,832' 8,759' - 9,758' Drilling program: X 20 AAC 25.050 requirements: Date: 5/6/1998 Date: 5"' d7 - ffJ Submit in triplicate ~---~ --------,--------. WOCA:.-60,.. ~UNOCAL-l00~ FO*CENE~GY-50% . . ~ If---. ----If' . 16 IWMJ I 14 . IOOX I . aö.G.r.1H)". I ---= T9N R13W~'---" 640 AC ~ 19M. AC ;f: æp I i~ r. ¥--_.. 1 20 21 æ 384;' AC / ~L An.. PA HSlP 21f!68 187',7 INTEREST ADLi8772 321Q ~ ~ ~ 30 .. 20 . ~~¡", V TR ~R~NI G .::.~ 1600 AC ¡ I rm! UNIT I æ? . I ,JßL-1d758 ..:.._--~ I UNOCAL-I0¡% - .ßI' - 31 51H' AC 32 33 384031c I 35 5:M6 AC I H3P HBP: HBP : ADIr-:. 7594 aDL-1873~_J ADL-1769f '--, I UNot:AL UNOCIJ,-50" UNOCAL-l00" 1'" FOR~.R<;Y ~50" . 6 5 ..: 3 . I . I . --_.: : i . . . . It 7 308óAC 8 ~ . KW . : ADL-.8729 : \---, : I . I . I . 14 13 I 18 17 ,...-"ft¡ 3840 AC I . I B3P: I ___~L_~:'7602 ~ : TON R 13W UNOC~-lDO" : 24 ~--"!~ "-5itD AC 21 ,: : ~P I I . I ,-....' .---.1 I 31l& AC HBP ADL-3B1204 -" MARAT¡..o.:,...I00" 3 2 1 MARATHtJ.-I01m 10 11 12 McARTHUR 5647 ACl4 RIVER . -31-98 FI E[.'D ADI.-374028 TUN R14W 15 STEVART æ P£TRJLEUM 23 27 34 r. ----..-----. --', ' ,~STEVART : PETR UUM I 4 3: ~.8?X . t"Jk;&j-..t-a.88JI WEST M :ARTHUR I ~locm RIVI:R UN I I . r./ IMUlDIR SHOAL , <....... 9 . ~~ : -1C.:1> JœIIIIIIft' I 11-1-' I. F þ . Ii! . I I I .175 Aa.'J : HBP I A~--359111 I O~- R14YT- STEVART Pf:TRDLEUM 22 23 fa 296. AC HB~ ADL-3~1~ - -- I STEVART : 100% : e6 I I I . I I I I I I I I f7 PHILLJPS-l :10'" --,--057 AC HIP k:O3SO1ì 33 192) AC 3-3><-00 ADL-381012 35 36 2 MILES ~ ~ ADL-391216 ADL,...~7597 L_- J.--~ ,A:~~374046 UNOCAL-50% . MARATHDMIIDL-1B776 kARATHON'-50~ ADL-18776 .. 3 2 1 6 5 JNOCAL,...50:C i'ORCENERGY 5°" 7 8 3MB AC HBP ADL-16731 10 11 12 13 24 SH£LL-66.6i7X SDI-33.3:r" 2 10 11 3746 At HBP ~-18754 15 SHELL-66.67X SDI-33.33'1. 14 æ 23 UNOCAL-l00'; 25 é!9 28 27 é!6 5120 AC HBP ADl-18756 UnOCGl Alaska Resources J 31 32 38C8 AC 33 ~p ADL-1B716 34 COOl: INUIT IIcIJmIIJJt IDYll J'IIU 100'1' omm: EXHIBIT "A If ~...~....-- I~~"-' DANCa-1OO"," .1 "., .," 5;- ~ -_\ ~, MARA T¡.o.,..1OOX ADL.-j7597 Lh L__>.J "' ~~~374046 UNOCAL-5~ MA,RATHIJN "DL-18776 ItARATHON-50'= ADL-18776 .. 3 2 1 r---' -~-' ----.- ------., ro~~~o~ .--_._---W ffi . . . ---" 640 AC : 19<.2 AC IIBP I ElP ¥.... 1.1 / 2tJk8 1~~7 . UNOCAL UN;!. AT lOa"; 'ì.cu. 10"" æ . . . . . . . . æ-.--- I I I .--, UN~AL lot" . . . . . . . 1t . . . . ---, :UNOC.u..-l00" .. IWIAJ : 1OOX I Œ.G.t. IW¡I. I T9N R13Wt---1 /' : æ 384;1 AC ~ ADL1:772 . 'F=~~~~¡O" V: TRADING 29 27 t 8sA Y I / ru_! UNIT¡ : UNOCAL-l, OJ'' 3840 31c I 35 51\§6 AC ImP ~ HBP aDL-1B73~_1 ADL-1759f I UNOC!!'-100" .. : 3 I I I , - -- ~ . . . ~ . . . . . I I . I I . I . .175 Aè-5 : 14 3840 AC 13 :. 18 17 rn."ft; HBP ,I B3P I I ~-3591U 1-, ADL-:.7602: I TON R13W O~' R14' -------- UNOC 1-100" :." , " STE\o'ART PETROLEUM ~ I 22 23 24 ~--"!" "-5it~ AC 21 296~ AC :: ælP HIP I I . ADL-~9_U~__, I '---..--_.J I 31~ AC 29 HBP ADL-361204 ADL-381216 3 2 1 6 5 MARATID-10lm JNOCAL-50X ì'ORCENERGY 5~ 7 10 11 12 8 3MB AC HBP ADL-16731 McARTHUR ~~r-:4 ~I~~ ADI.-374028 T9N R14W 15 STEVART e2 P£TRJLEUM 23 20 27 26 30 29 3200 N:. 3-31-00 ADL - )81030 34 1600 AC lIB? ~L-ld756 o.::ö:I 31 5118 AC 32 B3P ADrr-:.7594 UNOCAL-50" FORCEN.J,RGY -:-5°" 6 5 or, ----"-----.--, , 'STE\lART : "'-'" PETR LEUM I 4 3: ~.m: , t,)Jk).,8_t-8.8S:C WEST M :ARTHUR I 11!fOCM~1I)fm RIVI:H UNII , r./ BOULDIR SIIOAL .""... ~ 9 ":=4r ~ aX. 1 ÀORIIIIIIft' I 11-1 -- t ,..r. 7308C5ACs H3P ADL-.8729 I STE'WART I 100;( I 28 27 I é!6 25 I I I PHILLJPS-l)O'" I 1)57 AC . .HBP I 192) AC -C..::O3501; I 3-31<-00 I I ADL -~1012 33 I 35 36 I 2 MILES I I 31 32 38C8 AC33 ~P ADL-18716 Una Alaska Resources 34 COOl: INJIr IIaØ'lIIUIt IIUI Jœ1 UIIlT OO'IUHI EXHIBIT "A" ..I".~~ ~-'..,-- I~~"- DANCtI-100:r. 10 11 12 14 13 21 24 33 SHELL-""," 801-33.371. 2 10 11 3746 N:. HBP ADL-18754 15 SHELL-66.67X SDI-33.33Y. 14 e2 23 UNOCAL-l00~ 28 27 26 5120 AC HBP ADL -18756 ,I ..'.' /.' ~ ~ ..,.,-. DRILLlNe; r ~ FLUIDS M-I Drilling Fluids loL.C. UNOCAL GRAYLING PLATFORM G-15 OILMUD DEPTH INTERVAL - - 11,000-14,000 (8-1/2") 14,100-15,800 (6") MAPCO 200 OIL BASE VG-69 / M-I BAR / MAPCO 200 / LOWATE/VERAWET/VERSACOAT/ VERSA HRP / VERSAMOD / ALCOMER 274 / LIME / CACL2 MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS HOLE CLEANING / LOST CIRCULATION / WATER KICKS / HIGH GELS/SLOUGHING COAL TREATMENTS/PROCEDURES 1. Transfer oil mud from Granite Point. Condition as required. Use eithefFIW or oil mud to set whipstock and mill casing. Use this mud to drill the 8 Y2" interval. Mixing procedure for additional volume: a. Premix and store 10.8 ppg calcium chloride brine. b. Place Mapco 200 oil in clean mixing tank. c. Add VG-69 and lime slowly through shear pump to minimize balling. Shear for 30 minutes. d. Add primary emulsifier, Versa coat. e. Blend for a minimum of 30 minutes. f. Add calcium chloride brine. Blend for a minimum of 30 minutes. h. Add Versawetlcheck rheology/add Versamod. MI-377 S NOTE: SEE REVERSE SIDE FOR UABlUìY CLAUSE I-' ~ i. Add barite to required mud weight. Anticipated mud weight in the 8-1/2" hole should be approximately 9.3 ppg. j. Blend for a minimum of 30 minutes. NOTE: The most important aspect in mixing an oil mud is the amount of mixing energy put into the fluids while the brine is being added. The more shear put into the fluid the smaller the water droplets become and the more viscous the fluid. The emulsions become more stable as more shear is put into the fluid. 2. Displacement Procedure NOTE: Use large mesh shaker screens (30 - 40) during displacement and for up to two circulations thereafter. Monitor pump strokes and pump rates continuously during displacement. a. Conduct a rig team meeting discussing all aspects of displacement. NOTE: Rig operations should dictate optimum displacement time. b. Dilute and lower mud weight of water base mud. Pump a 75 bbl brine XCD polymer viscous sweep. Pump a 25 bbl Mapco 200 oil viscous sweep. Pump oil mud system. c. Displace in turbulent flow if possible. d. Reciprocate and rotate drill pipe. Make sure the bit is on bottom as the spacers and oil mud clear the bit. 3. Drill the 8-1/2" lateral section to T.D. If there are indications that a cuttings bed has been deposited in the well bore, the most effective method to clean the cuttings bed is with mechanical agitation by rotating and reciprocating the drill string. Maintaining high low shear rate rheologies will minimize the formation of a cuttings bed. Low shear rate rheologies can be elevated with Versamod, Versa HRP, Alcomer 274 and VG-69. If required, pump low/hi viscosity sweeps. The 6 and 3 rpm should be maintained at values greater than 10. / 4. Optimize mixing of "dry jobs" in order to minimize the number of wet trips. 5. After reaching TD, condition the hole for logging by rotating and reciprocating the drill string. If required, pump low/hi viscosity sweeps. 6. Run and cement the 7" liner. ~, ~ 7. Clean out 7" liner and drill 6" hole. Mud weiohts should be kept as low as possible. Centrifuge 8-1/2" hole mud and add Mapco 200 to reduce mud weight to 8.2 ppg. Conduct cost estimate prior to reducing mud weight. 8. Maintain low shear rate values with VG-69, Versamod, Alcomer 274 and Versa HRP. Run and cement 5" liner. 9. Displace well to diesel after running tubing. 10. Store Mapco 200 oil mud for use on next well in sequence. Mud Weight ppg PV YP Gels Olw ES. HTHP @ 2250 F 3 rpm 6 rpm 6" hole 8.2 15 - 22 15 - 20 10/25 80/20 800+ 4-6 cc > 12 > 12 8 %" hole 9.0-9.3 25 - 35 15 - 20 1 0/40 80/20 800+ 4-6 cc > 12 > 12 RtÜWt.Ð ,,;" (¡~) ,\<j9¡\') ""do. l . .0'" . S\ ," t' CG\\\\\\\ß . , Gas con". j\\a.s\\a. 0\\ & þ.,t\cnoralje ~ ~ Mapco 200 bbl VG-69 ppb Lime ppb Versacoat ppb Versawet ppb Versamod ppbNersa HRP/Alcomer 274 CaCh Barite/Lowate ppb Varies w/MW & O/W ratio 4-8 2 4-6 1 - 2 0 - 1 34 As Required COST ESTIMATE ~ INCH INTERVAL = $37,500.00 6 INCH INTERVAL = $145,000.00 ENGINEERING COST = $18,750.00 TOTAL COST = $201,250.00 Estimate based on using Granite Point Oil Mud System in 8 W' hole - Building substantial new volume in 6" hole to reduce mud weight. "..-..., UNOCAL RKB = 44.3' Rig Floor to DCB TBG Spool SIZE WT "---/ 1 17-3/4" .312W 13-318" 61 9-5/8" 47 9-5/8" 40 2 9-5/8" 43.5 9-5/8" 47 7" 29 5" 18 L '::::. 3"17 Tubing: -¡jp 4-112" 12.6 3-112" 9.2 3 1(51\.. L :::"b~f NO Depth 1 44.3 2 310' 3 2,584' 3,463' 13 3¡ß L :::.. $802. 4,384' 5,384' 6,105' 6,866' \ 7,588' 8,310' 8,991' þ~ 9,713' 10,395' " 4 11,054' 5 11,091' 6 11,125' 7 11,126' 8 11,130' \ / TOL @ 11,024' 9 11,167' 10 11,198' q.5ì8 L :::.. \ \ I 2..1-e. ID 3.958" 3.813" 2.813" 3.10" 3.25" 3.937' 2.813" 3.0 ~ GRAYLINL. PLATFORM WELL # 15 Completed: 8/1/92 CASING AND TUBING DETAIL GRADE CONN ID MD TOP Spiral Weld Surf. Buttress Surf. Buttress 8.681 Surf. Buttress 8.835 67' Buttress 8.755 5,883' Buttress 8.681 7,900' Buttress 6.184 11,024 Buttress 4.276 11,216' MD BTM. 600' 5,802' 67' 5,883' 7,900' 11,210' 12,702' 12.598' J-55 N-80 N-80 N-80 N-80/P-ll 0 N-80 P-110 L-80 TDS 4.5" OD Butt 3-7/8" 00 3.958 2.992 10,994' 11,197 44.3 10,995' JEWELRY Item CIW 4-112" DCB Tubing Hanger: 4-112" TDS bottom Baker FVLE TBG Retr SCSSSV (14 bands on control line) #12 4-112" Gas-Lift Mandrel #11 4-112" Gas-Lift Mandrel #10 4-112" Gas-Lift Mandrel #9 4-112" Gas-Lift Mandrel #8 4-112" Gas-Lift Mandrel #7 4-112" Gas-Lift Mandrel #6 4-112" Gas-Lift Mandrel #5 4-112" Gas-Lift Mandrel #4 4-112" Gas-Lift Mandrel #3 4-112" Gas-Lift Mandrel #2 4-112" Gas-Lift Mandrel #1 3-112" Gas-Lift Mandrel Baker CMU sliding Sleeve Baker CH Anchor Tubing Seal Assembly Baker 3-H Hydro-Set Permanènt Packer Baker Mill-out Extension Baker 'X' Nipple Baker Shear out sublRe-entry Guide PERFORATIONS Date Zone Top BTM Comments 7/27/92 HB-l 12,015 12,035 3-3/8" TCP then Frac Stirn 7/30/92 HB-l 12,012 12,038 3-3/8" TCP I \ , -2-\ <G> 7/30/92 HB-3 12,204 12,238 3-3/8"TCP TOL 7/30/92 HB-4 12,238 12,369 3-3/8" TCP 7/24/92 HB-4 12,250 12,270 3-3/8" TCP then Frac Stirn 7/24/92 HB-4 12,260 12,290 3-3/8" TCP then Frac Stirn \ -2-.-Sq<V , ./"., l' (-2-,1ß v TD = 12,704; PBTD = 12,621' MAX HOLE ANGLE = 58° @ 4,877' G-15 8-1-92.doc REVISED: 4/23/98 DRAWN BY: MWD /----' UNOCAL RKB = 44.3' Rig Floor to DCB TBG Spool L L. L. Top of Cement @ 10,990' ¿ SIZE WT 17-3/4" .312W 13-318" 61 9-5/8" 47 9-5/8" 40 9-5/8" 43.5 9-5/8" 47 7" 29 5" 18 ~ Tubing: 4-112" 12.6 3-112" 9.2 :::... NO Depth 1 11,000 2 11,040 3 11,054' 4 11,091' :::... 5 11,125' 6 11,126' 7 11,130' 8 11,167' 9 11,198' 1 TOL @ 11,024' :::... /~ GRAYLIN, PLATFORM WELL # 15 PROPOSED ABANDONMENT CASING AND TUBING DETAIL GRADE CONN ID MDTOP Spiral Weld Surf. Buttress Surf. Buttress 8.681 Surf. Buttress 8.835 67' Buttress 8.755 5,883' Buttress 8.681 7,900' Buttress 6.184 11,024 Buttress 4.276 11,216' J-55 N-80 N-80 N-80 N-80/P-llO N-80 P-110 L-80 TDS 4.5" OD Butt 3-7/8" OD 3.958 2.992 44.3 10,995' MD BTM. 600' 5,802' 67' 5,883' 7,900' 11,210' 12,702' 12.598' 10,994' 11,197 PERFORATIONS Date Zone Top BTM Comments 7/27/92 HB-l 12,015 12,035 3-3/8" TCP then Frac Stirn 7/30/92 HB-l 12,012 12,038 3-3/8" TCP 7/30/92 HB-3 12,204 12,238 3-3/8"TCP TOL@ 11,217' 7/30/92 HB-4 12,238 12,369 3-3/8" TCP Cannot access 5" 7/24/92 HB-4 12,250 12,270 3-3/8" TCP then Frac Stirn liner thru tubing 7/24/92 HB-4 12,260 12,290 3-3/8" TCP then Frac Stirn TD = 12,704; PBTD = 12,621' MAX HOLE ANGLE = 580 @ 4,877' G-15RD Aban Proposed. doc JEWELRY ill Item Cement Retainer Top of 3-112" tubing: cut with jet cutter #1 3-112" Gas-Lift Mandrel Baker CMU sliding Sleeve Baker CH Anchor Tubing Seal Assembly Baker 3-H Hydro-Set Permanent Packer Baker Mill-out Extension Baker 'X' Nipple Baker Shear out sub/Re-entry Guide 2.813" 3.10" 3.25" 3.937' 2.813" 3.0 REVISED: 4/23/98 DRAWN BY: MWD UNOCAL RKB = 44.3' Rig Floor to DCB TBG Spool L :::. 1 2 3 "" :::. "" .5 6 TOL @ .",. ~ 16/ L. I I :::. TOL@~""'~ I -12.,05° ~!:/: : I I I I I I I I I q ð'Î) Vd"Ll I:>.. \~ TD = 15,900'; ETD =15,770' 90°/12,579'; 100°114,500'; 109°115,100' G-15RD Proposed B.doc ~ .~ GRAYLIN,- PLATFORM WELL #: G-15RD Proposed Completion ~ CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 17-3/4" .312W Spiral Weld Surf. 600' 13-318" 61 J-55 Buttress Surf. 5,802' 9-5/8" 47 N-80 Buttress 8.681 Surf. 67' 9-5/8" 40 N-80 Buttress 8.835 67' 5,883' 9-5/8" 43.5 N-80 Buttress 8.755 5,883' 7,900' 9-5/8" 47 N-80/P-llO Buttress 8.681 7,900' 11,210' Window 10,950 11,000 7" 29 L-80 TKC-Butt 6.184 19,700 12,350 4-112" slotted 12.6 L-80 TKC-Butt-SC 3.958 12,250' J5,900 4-112" slotted liner has Yz" predrilled holes-4 hpf Tubing: 5-112" 12.6 L-80 LTC 4.892 44.3 10,994' JEWELRY NO 1 2 3 Depth 44.3 310' ID 3.958" 3.813" Item CIW 5-112" DCB Tubing Hanger: 5-112" LTC top & btm Baker TBG Retrievable SCSSSV #16 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #15 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #14 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #13 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #12 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #11 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #10 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #9 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #8 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #7 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #6 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #5 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #4 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #3 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #2 5-112" SF-02 McMurry GLM wI 1-112" R-2 valve #1 5-112" SF-02 McMurry GLM wI orifice Baker 'X' Nipple Baker Permanent Packer with seal-bore extension Baker seal assembly 4 5 6 10,550' Date Proposed Proposed Zone HR-l HB-2 PERFORATIONS Top BTM SPF Comments 12,632 12,663 6 4-5/8" TCP 12,691 12,931 6 4-5/8" TCP REVISED: 4/23/98 DRAWN BY: MWD Grayling Plàtforni .~ G-15 Redrill PreliminalJ Procedure Kill Well and Cut Tubing RU APRS wire line unit. RU lubricator and pressure test. RIH with cutter and cut 4-1/2" long string @ 11,000'. RD APRS unit. Kill well with FIW. Pull Completion 1 Set BPV in hanger. 2 ND Tree. 3 NU BOPE. 4 Pull BPV and set two-way check. 5 Test BOPE. 6 RIH with landing joint and engage tubing hanger. 7 Pull hanger loose and circua1ate well. 8 LD tubing hanger and POOH and LD tubing. 9 Run wear bushing. Abandon G-30 ~ 10 PU 9-5/8" cement retainer. 11 RIH with cement retainer on drillpipe. . 12 Set cement retainer @ 1O,980'.~ 13 Unsting from retainer and pressure test retainer. 14 Sting into retainer and establish injection rate and pressure. 15 Unsting and mix cement. 16 Pump abandonment cement slurry. 17 Sting into retainer and squeeze cement below retainer. 18 Unsting from packer. 19 Spot 50 ft of cement on top of retainer. 20 POOH to 10,900' and circua1ate. 21 POOH with drillpipe. 22 LD retainer stinger and PU bit and csg scraper. 23 RIH to 10,950' with casing scraper. 24 POOH and LD tools. Mill Window and Drill 8-112" Pilot Hole to 12,350' 25 MU packer on MWD. 26 RIH with one trip whipstock assembly. 27 Orient whipstock. Set packer/whipstock @ 10,950'. 28 Mill window in 9-5/8" casing. Perform LOT. 29 Circulate bottoms up. 30 POOH with setting tool. 31 LD mills and MU drilling BRA. - 32 Test BOPE. 33 RIH with BHA. 34 Drill 8-1/2" hole. G-15RD Proced.xls Page 1 of 4 ~ ~ . Î UNOCAL 5/5/98--3:39 PM Grayling Plátform ~. G-15 Redrill Preliminal.! Procedure 35 36 37 38 39 40 41 42 43 43 44 45 46 47 48 Circulate and condition mud system. POOH with BHA. BHA handling. RIH with BHA. Ream to bottom. Drill 8-1/2" hole. Circulate and condition mud system. POOH with BHA. Test BOPE. BHA handling. RIH with BHA. Ream to bottom. Drill 8-1/2" hole. Circulate and condition mud system. POOH with BHA. Log 8-112" Hole 49 RU SWS WLU for DP conveyed logs. 50 RIH with logging tools: DIL, FDC, CNL, DT, GR, CCL 51 Install side door entry sub. RIH with wet connect. 52 Log Hemlock zones. 53 ND side-door entry sub. POOH with wireline. 54 POOH with logging tools. 55 RD SWS WLD. Run 7" Liner 56 57 58 59 60 61 62 63 RU casing crews for 7" liner Change casing rams and test BOPE RIH with 7" liner. Continue to RIH with 7" liner on 5" drillpipe. Circulate and condition hole for cement. RU for cement job. Pump cement job and set liner hanger. POOH and circulate out cement. Continue to POOH. Drill 6" hole to 15,900' 64 MU 6" BHA. 65 PU 3-1/2" Drillpipe while RIH 66 RIH with BHA. 67 Drill 10' of 6" hole and perform LOT 68 Drill 6" hole. 69 Circulate and condition mud system. 70 POOH with BHA. 71 Test BOPE. 72 BHA handling. 73 RIH with BHA. G-15RD Proced.xls Page 2 of 4 ~ .i ", UNOCAL 5/5/98--3:39 PM Grayling Platform ,~ G-15 Redrill Prelimina. oJ Procedure 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 Log 6" Hole 104 105 106 107 108 109 110 Ream to bottom. Drill 6" hole. Circulate and condition mud system. POOH with BHA. BHA handling. RIH with BHA. Ream to bottom. Drill 6" hole. Circulate and condition mud system. POOH with BHA. BHA handling. RIH with BHA. Ream to bottom. Drill 6" hole. Circulate and condition mud system. Test BOPE. POOH with BHA. BHA handling. RIH with BHA. Ream to bottom. Drill 6" hole. Circulate and condition mud system. POOH with BHA. BHA handling. RIH with BHA. Ream to bottom. Drill 6" hole. Circulate and condition mud system. POOH with BHA. BHA handling. RU SWS WLU for DP conveyed logs. RIH with logging tools: DIL, FDC, CNL, DT, GR, CCL Install side door entry sub. RIH with wet connect. Log Hemlock zones. ND side-door entry sub. POOH with wire line POOH with logging tools RD SWS WLU. Run 4-1/2" Slotted Liner III Change top pipe rams 112 Test BOPE. 113 RU casing crews for liner 114 RIH with slotted liner. 115 Continue to RIH with liner on drillpipe. G-15RD Proced,xls Page 3 of 4 5/5/98--3:39 PM Grayling Platform r-- G-15 Redrill Prelimina.lJ Procedure 116 117 Set liner hanger and release running tool. POOH with running tool. Clean out 4-112"/7" Liner and TCP Perforate 7" liner 118 MU stinger, 6" bit, 7" csg scraper, and 9-5/8" cg scraper. 119 RIH with cleanout assembly. 120 Wash down to top of5" slotted liner. 121 Circulate hole clean. 122 POOH with scrapers 123 LD 6" bit and scrapers and PU 4-3/4" stinger 124 PU 2-7/8" drilpipe 125 RIH with stinger. 126 Stab into 7" shoe and change well over to diesel. 127 POOH with drillpipe 128 PU 650 ft of 4-5/8" TCP guns andjewerly. 129 RIH with TCP guns on 3-1/2" DP. 130 RU SWS wireline. PU Gamma Ray and CCL 131 RIH and locate RA sub and place guns on depth. 132 POOH and RD SWS 133 Set packer. RU surface EQ. Fire guns. Circulate Well. 134 POOH with TCP Guns 135 LD TCP Guns and PU 4-3/4" bit and 5" csg scraper. 136 PU 3,000' of 2-7/8" PAC drillpipe. 137 RIH with bit and scraper. 138 Circulate hole. 139 POOH with BHA. 140 LD 2-7/8" PAC drillpipe. 141 LD BHA. Run Completion 141 RU SWS WLU. 142 PU 9-5/8" by 5-1/2" permanent packer. 143 RIH with packer on wireline. Set packer@ 10,950" 144 POOH 145 RD SWS WLU. 146 Pull wear bushing. 147 RU to run 5-1/2" gas lift completion. 148 PU, rabbit and run gas lift completion. 149 Space out, install SCSSV, control line, and PU hanger. 150 Land hanger. 151 ND BOPE. 152 Install 6" block tree and test. 153 Turn well over to Production. G-15RD Proced.xls Page 4 of 4 5/5/98--3:39 PM 10,000 11 ,000 12,000 - ~ Q) .æ - .c ~ c. Q) C 13,000 'tJ 2! :::t 1/1 CIS Q) :E 14,000 15,000 16,000 UNOCAL ~ G-15RD AFE EST 4.xls 5 Grayling McArthur Field: G-15RD Depth vs. Time Summary 10 15 20 Time (Days) 25 -AFE -Optimum - - Actual ) ) 30 35 40 4/23/98--4:34 PM " 23'-9":I: " f-------: --. I I~ I : : I BOTTOM OF SEAL HOUSING" ~ AIR BOOT ~ DRIP PAN " 10" MUD FLOW LINE ~ TO SHAKERS (TY? 2) '- 5'-8":1: 16"Ø RISER 7" I "I 0 ~ HYDRIL 13-5/6" 6K ANNULUR PREVENTER 18'-2":1: 1 I l I l' [ SHAFFER DOUBLE GATE BOP r 0 1'-4~" " {I ' G 1'-3" ~ ~ 3'-91G" I I 2'-7~" I ) ( SHAFFER SINGLE GATE BOP , G ' 2'-2&":1: ) [ 1'-gjî":I: I 1 ~ CELLAR FLOOR " DRill DECK ~ ...- .. SDL --. ..~ ..~~ -A- -, NTS 1130/98 ~ " - 'lOOR f 1'-5i" 4'-10~":I: " 4'-6~" , , 2'-10" " 1'-g" " 2'-9~" 1 g~":I: " GRAYLING PLATFORM COOK INLET, ALASKA C~~R I GOg S¿åB2 NO. GRA YLiNG PLATFORM SHAFFER BLOW OUT PREVENTER STACK ELEVATION UNOCALfj I G-D-O33 -lour-I' III .,~ ~ - . ! r~ J ~ I I ð ~Ol m- ~ &.op- uoW-~O\P-IÁÞ-':)\6u!yoJ(\;"J W':-W' -[[þ= [ðJ ~ -W'-W' èk .. ~. "yo lQ €J W' :- [[þ= ~ '" ~ €J .... :! ... I . If" W':- [þ= o. "'yo ~ . . rT}¡--- W' .-W' - LUJ-- ~- ~ k K 1*1 . .:e ... ID C ...J 0 LL - Z « ~ w ~ 0 :r: u - en a. 0 0 0 10 (!) Z - ...J ~ (!) ---! ~ .;œ . t; k I ,- If" . . -W' -~ . ~ .. I ...J <C U 0 Z :J . -~ ~ ~ Created by 50therland For: M Damm Date platted: 7-May-98 Plat Reference is G-15Rd Version il7. Coordinates are in feet reference slat H4-16. True Vertical Depths are reference wellhead. UNOCAL UNOCAL8 Structure: GRAYLING Platform Well: G-15Rd ~ INIlfJQ Lacatian : TBU. Cook Inlet, AIQska Field: McArthur River Field <- West (feet) 6800 6400 6000 5600 5200 4800 8000 ---- WELL PROFILE DATA ---- ----- Paint ----- MD Inc o;r TVD North East V. Sect De9/100 KDP t0950.00 41.43 327.56 8558.28 3281.36 -5334.26 47t 2.00 0.00 Continue Buil'/fum 10975.00 43.59 330.63 8576.71 3295.B6 -5342.93 472B.40 12.00 End of 8uild/furn 11325.02 53.2B 336.07 BBOB.75 3529.B9 -5459.34 4986.40 3.00 End or Hold 11570.69 53.2B 336.07 89"".64 3709.88 -5539.22 5181.96 0.00 Target G-15Rd - HKT - 12153.14 60.00 342.76 9276.00 4165.00 -5709.00 5666.93 1.50 G-15Rd - 4T 1234".14 60.00 342.76 9372.00 4323.81 -5758.28 5833.21 0.00 End 01 Build/Turn 12575.73 90.00 342.80 9431.00 4534.14 -5B23.46 6053.41 13.01 Torget 13047.69 90.00 342.80 9431.00 49B5.00 -5963.00 6525.37 0.00 End of Build/Turn 13281.05 93.50 342.72 9423.87 5207.74 -6032.12 6758.58 1.50 Torget 14032.59 93.50 342.72 9378.00 5924.00 -6255.00 7508.72 0.00 End of Build/Turn 15113.11 109.71 342.81 9161.39 6931.52 -6567.65 8563.64 1.50 T.D. & Torget 15B94.2D 109.71 342.BI BB9B.00 7634.00 -67B5.00 929B.97 0.00 Et G-15Rd - TO - 4 Moy 98 \~- "Rd - " - , Uo, " , - 6000 s::" - " - , "", - :::: G-15Rd - PIT - 4 May 9B 0, \\ G-IORd - 4T - 4 May 9B "\ ~ G-15Rd - 3T - 4 Moy 98 - 4400 \ - \<"d" - HKT - 4 May 9B - 4000 - 3600 r--. ...... CD CD -+ '-" - 7600 - 7200 - 6800 - 6400 ^ I Z 0 """I -+ ::r - 4800 8400 - ~ ~ ò-\ d;'P ~ ~ d; ~ ò-\ d; ~'P d;'P d; ~ò-\ / ~~ ~ ~ò-\ ~ò-\ ~o-\ ~o-\ ~ ", .,'\ / ~ ~ ~ ~ / " ~":'\ / / ~ ", '].. " / / '\ B "'" / / ':, ¡},,~ ~ / --~- '" ~ò Ò / /' / g,.ò ------ ~'P "'" ,,'Z.;,<f g,.ò Ò aÒ / g,.ò ,,<d --------- ~'P ò-\ ", e:/ / ,<d.;,<f.;,y ,,<d C/ ----- ~ ~ "-u. c;, r:/ / "" C/ -~-------- ~ò ~ .""--,,-_o':_--------.~-----------------------.-------------- / ~ '\<;) / rV / / s¡..Ò g,.ò ,,<d ,,<d r:/ C/ - 2800 - 3200 ,,--.... -+- Q) Q) -- .......... 8000 - ..c -+- 0... Q) 0 8800 - 0 U 9200 - -+- .... Q) > 9600 - Q) :::¡ L I-- 10000 - I V 10400 4000 4800 7600 8000 8400 8800 9200 9600 10000 10400 6400 6800 7200 5200 5600 6000 4400 Vertical Section (feet) -> Azimuth 342.80 with reference 0.00 S, 0.00 E from slot #4-16 ~ "..--.... UNOCAL GRAYLING Platform G-15Rd slot #4-16 McArthur River Field TBU, Cook Inlet, Alaska PRO P 0 S A L LIS TIN G by Baker Hughes INTEQ Your ref: G-15Rd Version #7 Our ref: prop2724 License: Date printed: 7-May-98 Date created: 14-Jan-98 Last revised: 5-May-98 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.899,w151 36 48.078 Slot Grid coordinates are N 2502387.654, E 212196.311 Slot local coordinates are 1837.70 N 1489.80 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North ia True North ~ r-"\ UNOCAL PROPOSAL LISTING Page 1 GRAYLING P1atform,G-15Rd Your ref: G-15Rd Version #7 McArthur River Fie1d,TBU, Cook Inlet, Alaska Last revised: 5-May-98 Measured Inc1in. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 10950.00 41. 43 327.56 8558.28 3281. 36 N 5334.26 W 0.00 4712.00 10975.00 43.59 330.63 8576.71 3295.86 N 5342.93 W 12.00 4728.40 11000.00 44.27 331. 08 8594.71 3311. 00 N 5351.37 W 3.00 4745.37 11100.00 47.02 332.77 8664.61 3374.10 N 5385.00 W 3.00 4815.59 11200.00 49.79 334.31 8731. 00 3441. 05 N 5418.30 W 3.00 4889.39 11300.00 52.58 335.73 8793.67 3511. 67 N 5451.18 W 3.00 4966.58 11325.02 53.28 336.07 8808.75 3529.89 N 5459.34 W 3.00 4986.40 11500.00 53.28 336.07 8913.38 3658.09 N 5516.24 W 0.00 5125.69 11570.69 53.28 336.07 8955.64 3709.88 N 5539.22 W 0.00 5181. 96 11600.00 53.61 336.43 8973.10 3731. 43 N 5548.71 W 1. 50 5205.35 11700.00 54.74 337.64 9031.63 3806.08 N 5580.33 W 1.50 5286.02 11800.00 55.88 338.83 9088.55 3882.45 N 5610.81 W 1.50 5367.98 11900.00 57.04 339.98 9143.80 3960.47 N 5640.13 W 1.50 5451.18 12000.00 58.20 341.10 9197.36 4040.09 N 5668.26 W 1.50 5535.56 12100.00 59.37 342.19 9249.18 4121.26 N 5695.19 W 1. 50 5621.06 12153.14 60.00 342.76 9276.00 4165.00 N 5709.00 W 1.50 5666.93 G-15Rd - HKT - 4 May 98 12345.14 60.00 342.76 9372.00 4323.81 N 5758.28 W 0.00 5833.21 12400.00 67.14 342.77 9396.41 4370.70 N 5772.83 W 13.01 5882.31 12500.00 80.15 342.79 9424.51 4462.15 N 5801.17 W 13.01 5978.05 12575.73 90.00 342.80 9431.00 4534.14 N 5823.46 W 13.01 6053.41 13000.00 90.00 342.80 9431.00 4939.44 N 5948.90 W 0.00 6477.68 13047.69 90.00 342.80 9431.00 4985.00 N 5963.00 W 0.00 6525.37 13100.00 90.78 342.78 9430.64 5034.97 N 5978.47 W 1. 50 6577.68 13200.00 92.28 342.75 9427.96 5130.44 N 6008.09 W 1. 50 6677 . 64 13281. 05 93.50 342.72 9423.87 5207.74 N 6032.12 W 1.50 6758.58 13500.00 93.50 342.72 9410.51 5416.41 N 6097.05 W 0.00 6977.13 14000.00 93.50 342.72 9379.99 5892.94 N 6245.34 W 0.00 7476.19 14032.59 93.50 342.72 9378.00 5924.00 N 6255.00 W 0.00 7508.72 14100.00 94.51 342.72 9373.29 5988.21 N 6274.98 W 1.50 7575.97 14200.00 96.01 342.73 9364.12 6083.29 N 6304.55 W 1. 50 7675.54 14300.00 97.51 342.74 9352.35 6178.12 N 6334.02 W 1.50 7774.84 14400.00 99.01 342.75 9337.98 6272.62 N 6363.38 W 1.50 7873.80 14500.00 100.51 342.75 9321. 03 6366.74 N 6392.60 W 1.50 7972.35 14600.00 102.01 342.76 9301. 50 6460.41 N 6421.67 W 1. 50 8070.43 14700.00 103.51 342.77 9279.42 6553.55 N 6450.57 W 1.50 8167.95 14800.00 105.01 342.78 9254.79 6646.12 N 6479.27 W 1. 50 8264.87 14900.00 106.51 342.79 9227.62 6738.05 N 6507.75 W 1. 50 8361.11 15000.00 108.01 342.80 9197.95 6829.27 N 6536.00 W 1.50 8456.60 15100.00 109.51 342.81 9165.79 6919.72 N 6564.00 W 1. 50 8551.28 15113.11 109.71 342.81 9161.39 6931.52 N 6567.65 W 1. 50 8563.64 15500.00 109.71 342.81 9030.93 7279.47 N 6675.31 W 0.00 8927.86 15894.20 109.71 342.81 8898.00 7634.00 N 6785.00 W 0.00 9298.97 All data is in feet unless otherwise stated. Coordinates from slot #4-16 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 10213.43 on azimuth 318.37 degrees from wellhead. Total Dogleg for we11path is 71.95 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 342.80 degreea. Calculation uses the minimum curvature method. Presented by Baker Hughes INTBQ ,.,..-- ~ UNOCAL GRAYLING Platform,G-15Rd McArthur River Pield,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref: G-15Rd version #7 Last revised: 5-May-98 Comments in wellpath ==========---======= MD TVD Rectangular Coords. Commen t ----------------------------------------------------------------------------------------------------------- 12153.14 9276.00 4165.00 N 5709.00 W G-15Rd - HKT - 4 May 98 Casing positions in string 'A' ===-===--==============-====== TOp MD Top TVD Rectangular Coorda. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- n/a n/a 8558.28 8558.28 3281.36N 3281. 36N 5334.26W n/a 5334.26W 14100.00 8558.28 9373.29 3281. 36N 5988.21N 5334.26W 6274.98W 9 5/8" Casing 7" Liner Targets associated with this wellpath ===-===============================-= Target name Geographic Location T.V.D. Rectangular Coordinatea Revised ----------------------------------------------------------------------------------------------------------- G-15Rd - TD - 4 May 8898.00 7634.00N 6752.00W 4-May-98 G-15Rd - 2T - 4 May 8931. 00 7546.00N 6729. OOW 4-May-98 G-15Rd - 3T - 4 May 9285.00 6476.00N 6448.00W 4-May-98 G-15Rd - 4T - 4 May 9378.00 5924.00N 6292.00W 4-May-98 G-15Rd - PIT - 4 May 9431.00 4985.00N 5998.00W 4-May-98 G-15Rd - 4T - 4 May 9418.00 4567.00N 5865.00W 4-May-98 G-15Rd - 3T - 4 May 9372.00 4335.00N 5775.00W 4-May-98 G-15Rd - 2T - 4 May 9306.00 4215.00N 5729.00W 4-May-98 G-15Rd - HKT - 4 May 9276.00 4165.00N 5709.00W 4-May-98 r" ~. UNOCAL PROPOSAL LISTING Page 1 GRAYLING P1atform,G-15Rd Your ref, G-15Rd Version #7 McArthur River Fie1d,TBU, Cook Inlet, Alaska Last revised, 5-May-98 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/l00ft Sect 10950.00 41.43 327.56 8558.28 5119.06 N 6824.06 W 0.00 4712.00 10975.00 43.59 330.63 8576.71 5133.56 N 6832.73 W 12.00 4728.40 11000.00 44.27 331. 08 8594.71 5148.70 N 6841.17 W 3.00 4745.37 11100.00 47.02 332.77 8664.61 5211. 80 N 6874.80 W 3.00 4815.59 11200.00 49.79 334.31 8731.00 5278.75 N 6908.10 W 3.00 4889.39 11300.00 52.58 335.73 8793.67 5349.37 N 6940.98 W 3.00 4966.58 11325.02 53.28 336.07 8808.75 5367.59 N 6949.14 W 3.00 4986.40 11500.00 53.28 336.07 8913.38 5495.79 N 7006.04 W 0.00 5125.69 11570.69 53.28 336.07 8955.64 5547.58 N 7029.02 W 0.00 5181. 96 11600.00 53.61 336.43 8973.10 5569.13 N 7038.51 W 1. 50 5205.35 11700.00 54.74 337.64 9031.63 5643.78 N 7070.13 W 1.50 5286.02 11800.00 55.88 338.83 9088.55 5720.15 N 7100.61 W 1.50 5367.98 11900.00 57.04 339.98 9143.80 5798.17 N 7129.93 W 1.50 5451.18 12000.00 58.20 341.10 9197.36 5877.79 N 7158.06 W 1. 50 5535.56 12100.00 59.37 342.19 9249.18 5958.96 N 7184.99 W 1.50 5621.06 12153.14 60.00 342.76 9276.00 6002.70 N 7198.80 W 1.50 5666.93 G-15Rd - HKT - 4 May 98 12345.14 60.00 342.76 9372.00 6161. 51 N 7248.08 W 0.00 5833.21 12400.00 67.14 342.77 9396.41 6208.40 N 7262.63 W 13.01 5882.31 12500.00 80.15 342.79 9424.51 6299.85 N 7290.97 W 13.01 5978.05 12575.73 90.00 342.80 9431. 00 6371. 84 N 7313.26 W 13.01 6053.41 13000.00 90.00 342.80 9431.00 6777.14 N 7438.70 W 0.00 6477.68 13047.69 90.00 342.80 9431. 00 6822.70 N 7452.80 W 0.00 6525.37 13100.00 90.78 342.78 9430.64 6872.67 N 7468.27 W 1.50 6577.68 13200.00 92.28 342.75 9427.96 6968.14 N 7497.89 W 1.50 6677.64 13281.05 93.50 342.72 9423.87 7045.44 N 7521.92 W 1.50 6758.58 13500.00 93.50 342.72 9410.51 7254.11 N 7586.85 W 0.00 6977.13 14000.00 93.50 342.72 9379.99 7730.64 N 7735.14 W 0.00 7476.19 14032.59 93.50 342.72 9378.00 7761. 70 N 7744.80 W 0.00 7508.72 14100.00 94.51 342.72 9373.29 7825.91 N 7764.78 W 1.50 7575.97 14200.00 96.01 342.73 9364.12 7920.99 N 7794.35 W 1.50 7675.54 14300.00 97.51 342.74 9352.35 8015.82 N 7823.82 W 1. 50 7774.84 14400.00 99.01 342.75 9337.98 8110.32 N 7853.18 W 1. 50 7873.80 14500.00 100.51 342.75 9321.03 8204.44 N 7882.40 W 1. 50 7972.35 14600.00 102.01 342.76 9301. 50 8298.11 N 7911.47 W 1. 50 8070.43 14700.00 103.51 342.77 9279.42 8391.25 N 7940.37 W 1.50 8167.95 14800.00 105.01 342.78 9254.79 8483.82 N 7969.07 W 1.50 8264.87 14900.00 106.51 342.79 9227.62 8575.75 N 7997.55 W 1. 50 8361.11 15000.00 108.01 342.80 9197.95 8666.97 N 8025.80 W 1. 50 8456.60 15100.00 109.51 342.81 9165.79 8757.42 N 8053.80 W 1.50 8551. 28 15113.11 109.71 342.81 9161. 39 8769.22 N 8057.45 W 1.50 8563.64 15500.00 109.71 342.81 9030.93 9117.17 N 8165.11 W 0.00 8927.86 15894.20 109.71 342.81 8898.00 9471. 70 N 8274.80 W 0.00 9298.97 Coordinates All data is in feet unless otherwise stated. from SE Corner of Sec. 29, T9N, R13W SM and TVD from wellhead (99.00 Ft above mean Bottom hole diatance ia 10213.43 on azimuth 318.37 degrees from wellhead. Total Dogleg for we11path is 71.95 degrees. Vertical section is from N 1837.70 W 1489.80 on azimuth 342.80 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ,r-'- .~ UNOCAL GRAYLING Platform,G-15Rd McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref: G-15Rd Version #7 Last revised: 5-May-98 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 12153.14 9276.00 6002.70 N 7198.80 W G-15Rd - HKT - 4 May 98 Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coorda. Casing ----------------------------------------------------------------------------------------------------------- n/a n/a 8558.28 8558.28 5119.06N 5119. 06N 6824.06W n/a 6824.06W 14100.00 8558.28 9373.29 5119. 06N 7825.91N 6824.06W 7764.78W 9 5/8" Casing 7" Liner Targets associated with thia wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- G-15Rd - TD - 4 May 8898.00 9471.70N 8241. 80W 4-May-98 G-15Rd - 2T - 4 May 8931. 00 9383.70N 8218. 80W 4-May-98 G-15Rd - 3T - 4 May 9285.00 8313.70N 7937.80W 4-May-98 G-15Rd - 4T - 4 May 9378.00 7761. 70N 7781. 80W 4-May-98 G-15Rd - PIT - 4 May 9431. 00 6822.70N 7487.80W 4-May-98 G-15Rd - 4T - 4 May 9418.00 6404.70N 7354. 80W 4-May-98 G-15Rd - 3T - 4 May 9372.00 6172.70N 7264. 80W 4-May-98 G-15Rd - 2T - 4 May 9306.00 6052.70N 7218. 80W 4-May-98 G-15Rd - HKT - 4 May 9276.00 6002.70N 7198.80W 4-May-98 ~. ~. UNOCAL PROPOSAL LISTING Page 1 GRAYLING P1atform,G-15Rd Your ref: G-15Rd Version #7 McArthur River Fie1d,TBU, Cook Inlet, Alaska Last revised: 5-May-98 Measured Inclin Azimuth True Vert R B C TAN G U L A R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO RDINATBS Deg/100ft Sect Basting Northing 10950.00 41.43 327.56 8558.28 3281. 36N 5334.26W 0.00 4712.00 206943.95 2505798.49 10975.00 43.59 330.63 8576.71 3295.86N 5342.93W 12.00 4728.40 206935.64 2505813.19 11000.00 44.27 331. 08 8594.71 3311. OON 5351.37W 3.00 4745.37 206927.56 2505828.54 11100.00 47.02 332.77 8664.61 3374.10N 5385.00W 3.00 4815.59 206895.49 2505892.44 11200.00 49.79 334.31 8731. 00 3441. 05N 5418.30W 3.00 4889.39 206863.84 2505960.18 11300.00 52.58 335.73 8793.67 3511.67N 5451.18W 3.00 4966.58 206832.69 2506031.59 11325.02 53.28 336.07 8808.75 3529.89N 5459.34W 3.00 4986.40 206824.99 2506050.00 11500.00 53.28 336.07 8913.38 3658.09N 5516.24W 0.00 5125.69 206771. 24 2506179.55 11570.69 53.28 336.07 8955.64 3709.88N 5539.22W 0.00 5181. 96 206749.52 2506231.89 11600.00 53.61 336.43 8973 .10 3731. 43N 5548.71W 1. 50 5205.35 206740.57 2506253.67 11700.00 54.74 337.64 9031. 63 3806.08N 5580.33W 1. 50 5286.02 206710.78 2506329.07 11800.00 55.88 338.83 9088.55 3882.45N 5610.81W 1. 50 5367.98 206682.18 2506406.15 11900.00 57.04 339.98 9143.80 3960.47N 5640.13W 1.50 5451.18 206654.78 2506484.87 12000.00 58.20 341.10 9197.36 4040.09N 5668.26W 1.50 5535.56 206628.60 2506565.15 12100.00 59.37 342.19 9249.18 4121. 26N 5695.19W 1. 50 5621.06 206603.67 2506646.96 12153.14 60.00 342.76 9276.00 4165.00N 5709.00W 1. 50 5666.93 206590.93 2506691.02 12345.14 60.00 342.76 9372.00 4323.81N 5758.28W 0.00 5833.21 206545.55 2506850.99 12400.00 67.14 342.77 9396.41 4370.70N 5772. 83W 13.01 5882.31 206532.16 2506898.22 12500.00 80.15 342.79 9424.51 4462.15N 5801.17W 13.01 5978.05 206506.06 2506990.34 12575.73 90.00 342.80 9431. 00 4534.14N 5823.46W 13.01 6053.41 206485.54 2507062.85 13000.00 90.00 342.80 9431. 00 4939.44N 5948.90W 0.00 6477.68 206370.05 2507471.10 13047.69 90.00 342.80 9431. 00 4985.00N 5963.00W 0.00 6525.37 206357.07 2507516.98 13100.00 90.78 342.78 9430.64 5034. 97N 5978.47W 1.50 6577.68 206342.82 2507567.32 13200.00 92.28 342.75 9427.96 5130.44N 6008.09W 1. 50 6677.64 206315.55 2507663.48 13281.05 93.50 342.72 9423.87 5207.74N 6032.12W 1. 50 6758.58 206293.42 2507741.34 13500.00 93.50 342.72 9410.51 5416.41N 6097.05W 0.00 6977 .13 206233.61 2507951.54 14000.00 93.50 342.72 9379.99 5892.94N 6245.34W 0.00 7476.19 206097.03 2508431.55 14032.59 93.50 342.72 9378.00 5924.00N 6255.00W 0.00 7508.72 206088.13 2508462.84 14100.00 94.51 342.72 9373.29 5988.21N 6274.98W 1.50 7575.97 206069.73 2508527.52 14200.00 96.01 342.73 9364.12 6083.29N 6304.55W 1. 50 7675.54 206042.49 2508623.30 14300.00 97.51 342.74 9352.35 6178.12N 6334. 02W 1.50 7774.84 206015.34 2508718.81 14400.00 99.01 342.75 9337.98 6272. 62N 6363.38W 1. 50 7873.80 205988.31 2508814.01 14500.00 100.51 342.75 9321. 03 6366.74N 6392.60W 1.50 7972.35 205961.39 2508908.81 14600.00 102.01 342.76 9301. 50 6460.41N 6421. 67W 1. 50 8070.43 205934.62 2509003.16 14700.00 103.51 342.77 9279.42 6553.55N 6450.57W 1. 50 8167.95 205908.02 2509096.99 14800.00 105.01 342.78 9254.79 6646.12N 6479.27W 1.50 8264.87 205881.59 2509190.23 14900.00 106.51 342.79 9227.62 6738.05N 6507.75W 1.50 8361.11 205855.36 2509282.82 15000.00 108.01 342.80 9197.95 6829.27N 6536.00W 1.50 8456.60 205829.35 2509374.71 15100.00 109.51 342.81 9165.79 6919. 72N 6564.00W 1.50 8551. 28 205803.58 2509465.81 15113.11 109.71 342.81 9161.39 6931. 52N 6567.65W 1. 50 8563.64 205800.22 2509477.70 15500.00 109.71 342.81 9030.93 7279.47N 6675.31W 0.00 8927.86 205701.10 2509828.18 15894.20 109.71 342.81 8898.00 7634.00N 6785.00W 0.00 9298.97 205600.11 2510185.28 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4-16 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 10213.43 on azimuth 318.37 degrees from wellhead. Total Dogleg for wellpath ia 71.95 degrees. Vertical section is from S 0.00 B 0.00 on azimuth 342.80 degrees. Grid ia alaska - Zone 4. Grid coordinatea in FBBT and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTBQ ~~ ~ UNOCAL GRAYLING Platform,G-15Rd McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref: G-15Rd Version #7 Laat revised: 5-May-98 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 12153.14 9276.00 4165.00N 5709.00W G-15Rd - HKT - 4 May 98 Casing poaitiona in string 'A' ===========a================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coorda. Casing ----------------------------------------------------------------------------------------------------------- n/a n/a 8558.28 8558.28 3281. 36N 3281.36N 5334.26W n/a 5334.26W 14100.00 8558.28 9373.29 3281.36N 5988.21N 5334.26W 6274.98W 9 5/8" Casing 7" Liner Targeta associated with this wellpath ====aa===============a=============== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- G-15Rd - TD - 4 May 8898.00 7634.00N 6752.00W 4-May-98 G-15Rd - 2T - 4 May 8931.00 7546. DON 6729. COW 4-May-98 G-15Rd - 3T - 4 May 9285.00 6476.00N 6448.00W 4-May-98 G-15Rd - 4T - 4 May 9378.00 5924.00N 6292.00W 4-May-98 G-15Rd - PIT - 4 May 9431.00 4985.00N 5998.00W 4-May-98 G-15Rd - 4T - 4 May 9418.00 4567.00N 5865.00W 4-May-98 G-15Rd - 3T - 4 May 9372.00 4335.00N 5775.00W 4-May-98 G-15Rd - 2T - 4 May 9306.00 4215. DON 5729.00W 4-May-98 G-15Rd - HKT - 4 May 9276.00 4165.00N 5709.00W 4-May-98 ~ -~, Created by Sutherland For: M Damm Dote platted; 7-Moy-9B Plot Reference is G-15Rd Version #7, Coordinoles are in feet reference slat #4-16, True Verticol Depths ore reference wellhead, UNOCAL Structure: GRAYLING PlatfQrm Well: G-15Rd UNOCAL8 Field: McArthur River Field LocQtion : TBU, Cook Inlet, Alaska ~ 1NJJ3Q TRUE NORTH 240 350 10 340 20 330 30 320 40 310 50 300 60 290 70 280 80 270 90 260 100 250 110 120 230 130 220 140 210 150 200 160 190 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well Created by Sutherland For: M namm Dote plotted: 7-May-98 Plot Reference la G-15Rd Ye"lan #7. Coordinates are in feet reference alat #4-16. True Vertical Depths are reference wellhead. - ,- waaa "00 96aa 9"'0 9200 9000 86ea 8400- 6200- 8000- 7800- 76aa- 7400- 7200- 7000- 6800- 66ea - 6400- 02ao- 6000- 5800- ^ I 56ea- ~ Qj ~ 5400' .r: 1: 5200- 0 Z 5000- 4800- "'00- «00- 4200- "'00' 38ao- JOaa- J4aa- mo- Jaaa- " 0 zoao- 0 N II Z800- £ 0 C - 2400- 0 " tii ma WOoo 9800 9800 ""0 'zoo ~. ,------ \ UNOCAL .#'#~~;£~#~~~~~.¡JP~11 ~ -.cJ,,~""""-'¡;-4~""'. ~ . . . " ,#' ,#' ..#' Jf' / G-"Rd - JT - 4.",.. d .... ",.£~ ~ .' #~. ~ 8900£" \. ~""'~ 8Zoo . "'- 8700 Jf' \. #' >'0' >'ó' "'" "" "" "" .#' .#' ,# ,4' ^' .;: ~,,"'I>"" \ .";~~<'-' ^ ,"'1>""-6000 'I.~ - '> " ' 'b -58aa ,'1.'b'b - ^ "" I . 'oj¡, <¡, ",ea ,~ ~ , ",'oj¡, ... ,,"<¡, "" - 5400 :r ~ ,5200 m ~ "--'~.'\: , -- G-I5Rd-;r-4U"..,\ ""00 ~,f'/>4'# ""Jf" >.",,~;#ó'~ ",a \~:~~::':~.; ~ :::':~8 .. 0; . -<Eima "'" \ \'ZOO \:'00 \""" \..00 '000 \ 8"0 '~88Qa ...a ' 8700 87 Structure: GRAYLING PlaHQrm Field: McArthur River Field <- West (feet) 7"'0 9000 8200 7",a BOOO 7800 7800 8800 8600 8400 <- West (feet) UNOCAL8 Well: G-15Rd Location: TBU, Cook Inlet, Alaska Scale 1 Inch = 200 f\ 7200 5600 4400 5"'0 5200 5aaa 7000 6800 66aa 6400 6600 -8"'0 #' ~. ( .( .( .f. - 8200 '@ -8000 -7800 - 7600 '74<)0 72aa ,-~ '><¡, " -8800 ~~£ ~~ -8600 -6400 -4400 -4000 -3800 - JOaa -3"'0 -JOOO VI - '"00 8 " -2800 ~ II -2400 N 0 0 "00 '" 7200 6400 5400 «00 5200 5000 4800 4600 8200 6000 5800 58aa 7000 6800 8600 Scale 1 Inch ~ 200 f\ r---. 3-D M I N I MUM UNOCAL GRAYLING Platform G-15Rd slot #4-16 McArthur River Field TBU, Cook Inlet, Alaska D I S TAN C B ~ C L BAR A N C B R B P 0 R T by Baker Hughes INTBQ Your ref: G-15Rd Version #7 Our ref: prop2724 License: Date printed: 7-May-98 Date created: 14-Jan-98 Last revised: 5-May-98 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.899,w151 36 48.078 Slot Grid coordinates are N 2502387.654, B 212196.311 Slot local coordinates are 1837.70 N 1489.80 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Object wellpath DECRBASING CLEARANCBS of less than 1000 feet are indicated by an asterisk, e.g. 487.4* PGMS <0-12930'>"M-28,STEBLHEAD Platform PGMS <3700-11700'>"M-25,STBELHBAD Platform PGMS <12486-15276'>"M-27,STBELHBAD Platform MSS <1103-2265'>"M-26,STEELHEAD Platform PGMS <2700-9101'>"M-14,STEBLHEAD Platform PMSS <1006-7952'>"M-15 St,STEELHBAD Platform PMSS <1006-1449'>"M-15,STEELHEAD Platform MSS <1363-1859'>"RLF #2,STBBLHEAD Platform PGMS <0-2310'>"RLF #l,STEBLHEAD Platform PMSS <808-1165'>"RLF #2,STBBLHEAD Platform MSS <0-735'>"OB #2,STBBLHEAD Platform PGMS <0-857'>"Bl-8,STBBLHBAD Platform PGMS <0-785'>"Bl-6,STBBLHEAD Platform PGMS <0-7434'>"M-13,STEELHBAD Platform PGMS <500-928'>"Bl-2,STEBLHBAD Platform PGMS <0-5600'>"M-5,STEBLHEAD Platform PMSS <6595-6988'>..M-1.STBBLHEAD Platform PGMS <0-7250'>"M-1St#1,STEELHEAD Platform PGMS <0-7419'>"M-2,STEELHEAD Platform PGMS <0-7250'>"M-3,STEELHBAD Platform GSS <0-1421'>,,*M-4*,STEBLHBAD Platform PGMS <0-5185'>"M-19,STBBLHEAD Platform PGMS <0-6440'>"M-7,STBBLHBAD Platform PMSS <1535-4500'>"M-9,STBBLHEAD Platform PMSS <1334-3625>"M-16,STBBLHBAD Platform Closest approach with 3-D Last revised Distance 29-Jul-96 9369.8 29-Jul-96 9480.9 29-Jul-96 11061.4 29-Jul-96 11384.3 29-Jul-96 9574.8 29-Jul-96 11545.7 29-Jul-96 12002.9 29-Jul-96 11820.9 29-Jul-96 11447.0 29-Jul-96 12516.0 29-Jul-96 12858.5 29-Jul-96 12297.4 29-Jul-96 12348.6 29-Jul-96 8723.3 29-Jul-96 12267.6 29-Jul-96 10891.8 29-Jul-96 9260.5 29-Jul-96 9235.9 29-Jul-96 12109.8 29-Jul-96 11106.9 29-Jul-96 12009.0 29-Jul-96 8644.4 29-Jul-96 10888.6 26-Aug-96 11299.2 29-Sep-97 10989.8 Minimum Distance method M.D. Diverging from M.D. 10950.0 12800.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 15702.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 "...----.. PGMS <0-14575'>"M-30,STEELH~ Platfo~ PMSS <10247-10355'>"M-31,STEELHBAD Platfo~ PMSS <10741-12018'>"M-31St#1,STEELHBAD Platfo GSS <975-2660'>"M-29,STEELHBAD Platfo~ PGMS <0-10938'>"M-29,STEELHBAD Platfo~ PMSS <9365 - 10588'>"M32ST#1,STEELHEAD Platfo PMSS <1386 - 9833'>"M-32,STEELHEAD Platfo~ PMSS <8988 - 12583'>"M32St#2,STEELHEAD Platfo PGMS <0-927'>"Bl-l0,STEELHEAD Platfo~ PMSS <12281 - 12660'>"M32St#3,STEELHEAD Platt PGMS <0-13771'>"K-19,KING SALMON Platfo~ PGMS <2600-14548'>OLD"K-8Rd,KING SALMON Platt MSS <2622-13927'>OLD"K-8,KING SALMON P1atfo~ PGMS <0-2500'> NEW"K-8Rd,KING SALMON P1atfo~ GSS <492-855'>"K-26,KING SALMON Platfo~ PMSS <981-10956'>"K-26,KING SALMON Platfo~ EMS <8955 - 11078'>"K-26Rd,KING SALMON Platte Steering Tool"K-24,KING SALMON Platfo~ PGMS <9300-14384'>OLD"K-24,KING SALMON Platfo GMS <0-2300'>"K-1Rd,KING SALMON Platfo~ MSS <2380-12570'>"K-1Rd,KING SALMON P1atfo~ MSS <9725-13224'>"K-1,KING SALMON Platfo~ MSS <10249-14700'>"K-7,KING SALMON Platfo~ GMS <0-10150'>"K-7,KING SALMON P1atfo~ GMS <10125-13990'>"K-7Rd,KING SALMON Platfo~ GMS 0-11288'>"K-2,KING SALMON Platfo~ GMS <2403-12915'>"K-2Rd,KING SALMON Platfo~ GMS <0-12173'>"K-13Rd,KING SALMON Platfo~ MSS <5142-14016'>"K-13,KING SALMON Platfo~ MSS <2450-11094'>"K-11,KING SALMON Platfo~ GMS <0-2800'>"K-4,KING SALMON Platfo~ MSS <2910-11772'>"K-4,KING SALMON Platfo~ MSS <10683-11439'>"K-4Rd,KING SALMON Platfo~ GMS <0-12200'>"K-15Rd,KING SALMON Platfo~ MSS <10836-12447'>"K-15,KING SALMON Platfo~ MSS <5028-8580'>"K-20,KING SALMON Platfo~ GMS <0-14700'>"K-23,KING SALMON Platfo~ PGMS <0-12120'>"K-17,KING SALMON Platfo~ GMS<0-2100'>"K-30Rd,KING SALMON Platfo~ MSS <2170-12600'>"K-30Rd,KING SALMON Platfo~ MSS <11494-13196'>"K-30,KING SALMON Platfo~ GMS <0-13413'>"K-3Rd,KING SALMON Platfo~ GMS <2600-11767'>"K-3,KING SALMON Platfo~ GMS <0-12822'>"K-l0Rd,KING SALMON Platfo~ GMS <8900-13463'>"K-l0,KING SALMON Platfo~ MSS <5747-10904'>"K-22,KING SALMON Platfo~ PGMS <0-10400'>"K-22Rd,KING SALMON Platfo~ PGMS <0-11400'>"K-12Rd,KING SALMON Platfo~ GMS <2500-11240'>"K-12,KING SALMON Platfo~ GMS <0-13370'>"K-5,KING SALMON Platfo~ PGMS <0-12130'>"K-18,KING SALMON Platfo~ GMS <0-12900'>"K-21,KING SALMON Platfo~ GMS <10600-12540'>"K-21Rd,KING SALMON P1atfor GMS <0-12156'>"K-9,KING SALMON Platfo~ MSS <2063-10825'>"K-16,KING SALMON Platfo~ PGMS <0-14325'>"K-25,KING SALMON Platfo~ PGMS <0-13296'>"K-6Rd,KING SALMON Platfo~ MSS <2180-11319'>"K-6Rd,KING SALMON Platfo~ GMS <0-11905'>"D-26,DOLLY VARDEN Platfo~ GMS <0-13585'>"D-24A,DOLLY VARDEN Platfo~ MSS <2450-10125'>"D-31,DOLLY VARDEN Platfo~ GMS <0-10628'>"D-31Rd,DOLLY VARDEN Platfo~ GMS <0-11356'>"D-2ARd,DOLLY VARDEN Platfo~ MSS <6927-12557'>"D-2,DOLLY VARDEN Platfo~ MSS <9482-12425'>"D-2Rd,DOLLY VARDEN Platfo~ MSS <11209-14850'>"D-22,DOLLY VARDEN Platfo~ GMS <0-14600'>"D-16,DOLLY VARDEN Platfo~ PGMS <10000-14645'>"D-16Rd,DOLLY VARDEN P1atf MSS <1205-10506'>"D-20,DOLLY VARDEN P1atfo~ MSS <7866-12700'>"D-14,DOLLY VARDEN Platfo~ GMS <0-13600'>"D-14Rd,DOLLY VARDEN Platfo~ paNS <O-13700'>"D-6Rd,DOLLY VARDEN Platform MSS <6662-12195'>"D-6,DOLLY VARDEN Platfo~ MSS <11790-15510'>"D-6St,DOLLY VARDEN Platfor MSS <8722-13932'>"D-8,DOLLY VARDEN P1atfo~ PGMS <700-12250'>"D-8Rd,DOLLY VARDEN Platfo~ PGMS <0-13111'>"D-29Rd,DOLLY VARDEN Platfo~ GMS <100-13050'>"D-29,DOLLY VARDEN Platfo~ PGMS <0-11150'>"D-43,DOLLY VARDEN Platfo~ GMS <0-11510'>"D-25Rd,DOLLY VARDEN Platfo~ 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 10-Feb-98 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 10-Feb-98 9-Apr-98 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul- 96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 30-Dec-97 30-Dec-97 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 8427.1 9105.4 9105.4 11245.5 9484.5 9026.6 9017.9 8958.4 12266.2 8958.4 140.1 678.3 168.6 10177.5 11556.5 8165.1 8140.4 11377.7 9638.2 10205.1 878.5 1052.5 11184.4 11184.4 11184 . 4 10054.2 10618.1 10879.3 10879.3 5289.6 10371. 5 7757.1 7677.9 11012.5 11012.5 10431.1 10939.5 10791. 8 11126.9 10228.2 10228.2 352.0 3136.3 687.4 135.4 5650.7 6196.2 3139.7 3936.2 11101. 6 1693.7 9274.2 9274.2 9321. 5 8444.0 8050.8 11013.9 10745.7 12510.3 15182.2 12907.9 11831. 5 14801. 7 14590.3 14429.2 16923.8 16813.8 16813.8 12681.9 16649.0 16649.0 16611.6 16611. 6 16611.6 16801.1 16801.1 13112.3 13029.7 10779.7 16186.1 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 14400.0 14433.3 12358.9 15894.2 15894.2 15894.2 15894.2 10950.0 10950.0 15894.2 14666.7 14766.7 15819.0 15819.0 15819.0 10950.0 10950.0 15894.2 15894.2 13005.0 15894.2 10950.0 10950.0 15894.2 15894.2 10950.0 15894.2 10950.0 15894.2 10950.0 10950.0 13413.0 13320.0 15138.0 15894.2 15894.2 15894.2 15894.2 15894.2 15894.2 15654.0 10950.0 10950.0 10950.0 15654.0 10950.0 15894.2 15894.2 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 ~ 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 10950.0 13959.0 10950.0 13959.0 14400.0 14433.3 12358.9 15894.2 15894.2 15894.2 15894.2 10950.0 15531.0 15894.2 14666.7 14766.7 15894.2 15894.2 15894.2 13875.0 15894.2 15894.2 15894.2 13005.0 15894.2 13365.0 15390.0 15894.2 15894.2 15894.2 15894.2 15894.2 15894.2 15705.0 15705.0 13413.0 13320.0 15138.0 15894.2 15894.2 15894.2 15894.2 15894.2 15894.2 15654.0 15297.0 15297.0 15444.0 15786.0 15117.0 15894.2 15894.2 10950.0 10950.0 10950.0 10950.0 10950.0 11529.0 10950.0 15861.0 15645.0 15645.0 10950.0 10950.0 10950.0 11487.0 11487.0 11487.0 10950.0 10950.0 12327.0 10950.0 10950.0 10950.0 ~. ~ MSS <8330-11350'>"D-25,DOLLY V. .N Platform 29-Jul-96 16186.1 10950.0 10950.0 GMS <0-11600'>"D-41,DOLLY VARDEN Platform 29-Jul-96 13813.1 10950.0 10950.0 GMS <6100-12573'>"D-40,DOLLY VARDEN Platform 29-Jul-96 8487.8 10950.0 10950.0 PGMS <0-12520'>"D-40Rd,DOLLY VARDEN Platform 29-Jul-96 8624.7 10950.0 10950.0 MSS <2506-11160'>"D-32,DOLLY VARDEN Platform 29-Jul-96 13417.7 10950.0 10950.0 GMS <0-12445'>"D-28,DOLLY VARDEN Platform 29-Jul-96 9480.2 10950.0 10950.0 GMS <0-11000'>"D-27,DOLLY VARDEN Platform 29-Jul-96 11486.8 10950.0 10950.0 PGMS <0-10300'>"D-45,DOLLY VARDEN Platform 29-Jul-96 14759.6 10950.0 10950.0 MSS <2727-11000'>"D-13,DOLLY VARDEN Platform 29-Jul-96 16625.1 10950.0 10950.0 PGMS <6600-10920'>"D-3Rd2,DOLLY VARDEN Platfo 29-Jul-96 12637.4 10950.0 10950.0 PGMS <8700-11100'>"D-3Rd,DOLLY VARDEN Platfor 29-Jul-96 13343.3 10950.0 10950.0 GMS <0-10881'>"D-3,DOLLY VARDEN Platform 29-Jul-96 13468.3 10950.0 10950.0 PGMS <2100-10225'>"D-15Rd2,DOLLY VARDEN Platf 29-Jul-96 13858.5 10950.0 10950.0 GMS <0-10935'>"D-15Rd,DOLLY VARDEN Platform 29-Jul-96 11608.4 10950.0 10950.0 MSS <2642-10250'>"D-5,DOLLY VARDEN Platform 29-Jul-96 15109.5 10950.0 11535.0 GMS <0-10650'>"D-5Rd,DOLLY VARDEN Platform 29-Jul-96 14250.0 10950.0 10950.0 MSS <6059-16650'>"D-19St,DOLLY VARDEN Platfor 29-Jul-96 14476.1 10950.0 10950.0 MSS <2944-7950'>"D-19,DOLLY VARDEN Platform 29-Jul-96 14497.0 10950.0 10950.0 PGMS <0-12345'>"D-46,DOLLY VARDEN Platform 29-Jul-96 16449.2 10950.0 10950.0 GMS <5600-10700'>"D-9,DOLLY VARDEN Platform 29-Jul-96 16643.4 10950.0 10950.0 PGMS <0-10900'>"D-9Rd,DOLLY VARDEN Platform 29-Jul-96 16643.4 10950.0 10950.0 MSS <2701-11682'>"D-ll,DOLLY VARDEN Platform 29-Jul-96 9859.0 10950.0 10950.0 MSS <10665-11808'>"D-17,DOLLY VARDEN Platform 29-Jul-96 15401.1 10950.0 10950.0 GMS <0-10800'>"D-17Rd,DOLLY VARDEN Platform 29-Jul-96 15401.1 10950.0 10950.0 MSS <0-12071'>"D-l,DOLLY VARDEN Platform 29-Jul-96 10936.8 10950.0 10950.0 MSS <10156-13600'>"D-30,DOLLY VARDEN Platform 29-Jul-96 11100.1 10950.0 10950.0 GMS <0-12237'>"D-30Rd,DOLLY VARDEN Platform 29-Jul-96 11216.1 10950.0 10950.0 MSS <2220-8175'>"D-18,DOLLY VARDEN Platform 29-Jul-96 11992.0 10950.0 10950.0 MSS <9453-12381'>"D-12,DOLLY VARDEN Platform 29-Jul-96 16689.8 10950.0 15549.0 GMS <0-12050'>"D-12Rd,DOLLY VARDEN Platform 29-Jul-96 16689.8 10950.0 15549.0 GMS <0-11100'>"D-4,DOLLY VARDEN Platform 29-Jul-96 15546.0 10950.0 10950.0 PGMS <8000-12100'>"D-4Rd,DOLLY VARDEN Platfor 29-Jul-96 15546.0 10950.0 10950.0 GMS <9600-13300'>"D-7,DOLLY VARDEN Platform 29-Jul-96 11593.0 10950.0 11559.0 GMS <0-12900'>"D-7Rd,DOLLY VARDEN Platform 29-Jul-96 11334.7 10950.0 10950.0 PMSS <12052 - 12438'>"D-7Rd#2,DOLLY VARDEN Pl 29-Jul-96 11360.0 10950.0 13935.0 MSS <2730-13462'>"D-24,DOLLY VARDEN Platform 29-Jul-96 15448.9 10950.0 10950.0 GMS <0-11180'>"D-34,DOLLY VARDEN Platform 29-Jul-96 15283.6 10950.0 10950.0 PGMS <0-10450'>"D-42,DOLLY VARDEN Platform 29-Jul-96 10111.3 10950.0 10950.0 MSS <3550-16606'>"D-23,DOLLY VARDEN Platform 29-Jul-96 16859.6 10950.0 10950.0 MSS <3550-17010'>"D-21,DOLLY VARDEN Platform 29-Jul-96 16852.8 10950.0 10950.0 PGMS <0-12970'>"D-44,DOLLY VARDEN Platform 29-Jul-96 7587.5 10950.0 10950.0 MSS <10913-11930'>"D-47,DOLLY VARDEN Platform 29-Jul-96 10495.8 10950.0 10950.0 MSS <2742-13908'>"D-10,DOLLY VARDEN Platform 29-Jul-96 15762.5 10950.0 10950.0 GMS <800-2700'>"D-10,DOLLY VARDEN Platform 29-Jul-96 16225.8 10950.0 10950.0 PGMS <0-10873'>"D-48,DOLLY VARDEN Platform 29-Jul-96 12081.8 10950.0 10950.0 PGMS <0-9950'>"G-5,GRAYLING Platform 30-Jul-96 5227.6 10950.0 10950.0 MSS <0-12736'>"G-31,GRAYLING Platform 30-Dec-97 8609.1 10950.0 10950.0 MSS <630-11451'>, ,G-30 , GRAYLING Platform 30-Jul-96 8490.9 10950.0 10950.0 GMS <0-12425'>"G-28,GRAYLING Platform 30-Jul-96 4987.2 10950.0 10950.0 GMS <0-12366'>, ,G-25 ,GRAYLING Platform 30-Jul-96 8182.3 10950.0 10950.0 GMS <0-9600'>"G-6,GRAYLING Platform 30-Jul-96 8891. 9 10950.0 10950.0 PGMS <100-11000'>"G-6Rd,GRAYLING Platform 30-Jul-96 8891. 9 10950.0 10950.0 GMS <0-13800'>"G-12Rd2,GRAYLING Platform 30-Jul-96 9669.0 10950.0 10950.0 MSS <10250-13748'>"G-12,GRAYLING Platform 30-Jul-96 9669.0 10950.0 10950.0 MSS <10250-13700'>"G-12Rd,GRAYLING Platform 30-Jul-96 9669.0 10950.0 10950.0 PMSS <1395-12743'>"G-14A Rd,GRAYLING Platform 30-Jul-96 9297.8 10950.0 10950.0 MSS <0-10790'>, ,G-33 ,GRAYLING Platform 30-Jul-96 7560.9 10950.0 10950.0 GMS <0-10268'>"G-34Rd,GRAYLING Platform 30-Jul-96 6886.2 10950.0 13533.0 MSS <2284-11655'>, ,G-34 ,GRAYLING Platform 30-Jul-96 8072.6 10950.0 10950.0 PGMS <11100-13380'>"G-36DPN,GRAYLING Platform 30-Jul-96 9336.6 10950.0 10950.0 PMSS <11830-12453'>, ,G-36 ,GRAYLING Platform 30-Jul-96 9336.6 10950.0 10950.0 GMS <0-12948'>, ,G-27 ,GRAYLING Platform 30-Jul-96 3251.2 10950.0 10950.0 GMS <0-10642'>, ,G-20 , GRAYLING Platform 30-Jul-96 8274.5 10950.0 10950.0 GMS <0-10400'>, ,G-24 ,GRAYLING Platform 30-Jul-96 8221. 3 10950.0 10950.0 GMS <0-11544'>, ,G-26 ,GRAYLING Platform 30-Jul-96 8995.6 10950.0 14533.3 GMS <0-11335'>, ,G-22 ,GRAYLING Platform 30-Jul-96 7649.5 10950.0 10950.0 MSS <10070-10975'>, ,G-10, GRAYLING Platform 30-Jul-96 5140.8 10950.0 10950.0 PGMS <0-10700'>"G-2Rd,GRAYLING Platform 30-Jul-96 8250.1 10950.0 13296.0 MSS <9120-11278'>"G-3Rd,GRAYLING Platform 30-Jul-96 8515.6 10950.0 10950.0 GMS <0-8800' (11050»"G-3,GRAYLING Platform 30-Jul-96 8515.6 10950.0 10950.0 GMS <100-11050'>"G-3Rd2,GRAYLING Platform 30-Jul-96 8515.6 10950.0 10950.0 MSS <3991-15095'>, ,G-17 ,GRAYLING Platform 30-Jul-96 2295.9 10950.0 10950.0 GMS <0-11900'>"G-17Rd,GRAYLING Platform 30-Jul-96 3419.3 10950.0 10950.0 GMS <0-13661'>"G-16,GRAYLING Platform 30-Jul-96 9614.7 10950.0 10950.0 MSS <0-12291'>"G-19,GRAYLING Platform 30-Jul-96 3831. 9 10950.0 10950.0 MSS <0-12007'>"G-13,GRAYLING Platform 30-Jul-96 1961.3 10950.0 10950.0 PGMS <0-10100'>"G-7,GRAYLING Platform 30-Jul-96 7725.5 10950.0 13374.0 GMS <0-9000'>"G-4,GRAYLING Platform 30-Jul-96 7503.6 10950.0 15714.0 GMS <1400-10400'>"G-4Rd,GRAYLING Platform 30-Jul-96 7640.1 10950.0 15837.0 MSS <0-15330'>"G-9,GRAYLING Platform 30-Jul-96 9572.3 10950.0 10950.0 r----- /~ GMS <0-8860'>"G-18Rd,GRAYLI. 11atform 30-Jul-96 9429.4 10950.0 10950.0 MSS <0-16342 '>, ,G-14 ,GRAYLING Platform 30-Jul-96 9309.7 10950.0 11520.0 MSS <7709-12175'>"G-8,GRAYLING Platform 30-Jul-96 9397.3 10950.0 14007.0 GMS <0-11750'>"G-8Rd,GRAYLING Platform 30-Jul-96 9397.3 10950.0 14007.0 MSS <0-11570'>, ,G-32 ,GRAYLING Platform 30-Jul-96 7265.7 10950.0 10950.0 GMS <0-10115'>"G-11,GRAYLING Platform 30-Jul-96 8110.4 10950.0 10950.0 PGMS <0-11430'>"G-1Rd,GRAYLING Platform 30-Jul-96 8787.8 10950.0 15117.0 MSS <8491-11420'>"G-1,GRAYLING Platform 30-Jul-96 8787.8 10950.0 15117.0 GMS <0-11742'>"G-23Rd,GRAYLING Platform 30-Jul-96 9104.1 10950.0 15750.0 GMS <0-12075 '>, ,G-23 ,GRAYLING Platform 30-Jul-96 9104.1 10950.0 15750.0 GMS <0-11160'>"G-21Rd,GRAYLING Platform 30-Jul-96 8452.7 10950.0 10950.0 MSS <0-12885 '>, ,G-15 ,GRAYLING Platform 24-Apr-98 0.0 10950.0 10950.0 ,r-..,. .~ UNOCAL CLEARANCE LISTING Page 4 GRAYLING Platform,G-15Rd Your ref : G-15Rd Version #7 McArthur River Field,TBU, Cook Inlet, Alaska Last revised: 5-May-98 Reference wellpath Object wellpath : PGMS <0-13771'>"K-19,KING SALMON Platform Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 14000.0 9380.0 5892.9N 6245.3W 12959.6 9258.8 6226.2N 6477 . OW 325.2 423.6 14032.6 9378.0 5924.0N 6255.0W 12957.2 9257.2 6226.8N 6475.2W 324.0 393.4* 14066.3 9375.8 5956.1N 6265.0W 12954.5 9255.5 6227.5N 6473.4W 322.5 362.7* 14100.0 9373.3 5988.2N 6275.0W 12951. 7 9253.6 6228. 2N 6471. 3W 320.7 332.4* 14133.3 9370.5 6019.9N 6284.8W 12948.7 9251.7 6229.0N 6469.2W 318.6 303.0* 14166.7 9367.5 6051. 6N 6294.7W 12945.5 9249.6 6229.8N 6466.9W 316.0 274.4* 14200.0 9364.1 6083.3N 6304.5W 12942.1 9247.4 6230.7N 6464.5W 312.7 246.9* 14233.3 9360.5 6114. 9N 6314.4W 12938.6 9245.1 6231. 6N 6461. 9W 308.3 220.7* 14266.7 9356.6 6146. 5N 6324.2W 12934.8 9242.6 6232.6N 6459.3W 302.5 196.5* 757.0 14300.0 9352.4 6178.1N 6334.0W 12930.7 9240.0 6233.7N 6456.3W 294.4 175.1* 587.8* 14333.3 9347.9 6209.7N 6343.8W 12926.8 9237.4 6234.6N 6453.6W 282.8 157.7* 436.5* 14366.7 9343.1 6241. 2N 6353.6W 12922.8 9234.8 6235.7N 6450.7W 266.8 145.5* 290.9* 14400.0 9338.0 6272. 6N 6363.4W 12918.6 9232.1 6236.7N 6447.7W 246.9 140.1* 150.3* 14433.3 9332.6 6304.0N 6373.1W 12914.2 9229.2 6237.8N 6444. 5W 227.1 142.1 232.5 14466.7 9327.0 6335.4N 6382.9W 12909.6 9226.2 6239.0N 6441.2W 211.2 151. 2 427.9 14500.0 9321. 0 6366.7N 6392.6W 12904.8 9223.0 6240.2N 6437.8W 199.7 166.4 626.2 14533.3 9314.8 6398.0N 6402.3W 12899.8 9219.8 6241.4N 6434.3W 191. 5 186.0 814.4 14566.7 9308.3 6429.2N 6412.0W 12895.8 9217.2 6242.4N 6431.4W 185.9 208.8 980.8 14600.0 9301. 5 6460.4N 6421. 7W 12890.6 9213.8 6243.6N 6427.7W 181.6 233.9 1132.3 14633.3 9294.4 6491. 5N 6431. 3W 12885.2 9210.2 6245.0N 6423.9W 178.3 260.6 1266.6 14666.7 9287.1 6522.6N 6441. OW 12879.6 9206.6 6246.3N 6419. 9W 175.6 288.5 1382.9 14700.0 9279.4 6553.6N 6450.6W 12873.9 9202.8 6247.8N 6415.7W 173.5 317.2 1496.3 14733.3 9271. 5 6584.5N 6460.2W 12867.9 9198.9 6249.2N 6411.5W 171.7 346.5 1633.6 14766.7 9263.3 6615. 3N 6469.7W 12861.8 9194.8 6250.7N 6407.1W 170.3 376.2 1769.7 14800.0 9254.8 6646.1N 6479.3W 12855.4 9190.7 6252.3N 6402.6W 169.0 406.3 1924.6 14833.3 9246.0 6676.8N 6488.8W 12848.9 9186.4 6253.9N 6398.0W 167.9 436.7 2067.5 14866.7 9237.0 6707.5N 6498.3W 12842.4 9182.1 6255.5N 6393.3W 166.9 467.3 2186.4 14900.0 9227.6 6738.0N 6507.7W 12835.5 9177.6 6257.2N 6388.4W 166.1 498.0 2291.6 Vertical All data is in feet unless otherwise stated. Casing dimensions are not included. slot #4-16 and TVD from wellhead (99.00 Ft above Total Dogleg for wellpath is 0.00 degrees. section is from S 0.00 E 0.00 on azimuth 342.80 Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ mean sea level). Coordinates from degrees. / ~ ,/"", UNOCAL CLEARANCE LISTING Page 5 GRAYLING Platform,G-15Rd Your ref : G-15Rd Version #7 McArthur River Field,TBU, Cook Inlet, Alaska Last revised: 5-May-98 Reference wellpath Object wellpath : MSS <2622-13927 '>OLD, ,K-8,KING SALMON Platform Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 11800.0 9088.5 3882.4N 5610.8W 13335.4 9292.8 4259.3N 5383.0W 31.2 485.5 678.5 11833.3 9107.2 3908.3N 5620.7W 13356.9 9306.3 4262.1N 5399.5W 32.0 462.3* 650.1* 11866.7 9125. 6 3934.3N 5630.5W 13379.4 9320.3 4265.0N 5416.9W 32.9 439.2* 619.9* 11900.0 9143.8 3960.5N 5640.1W 13404.7 9335.9 4268.4N 5436.4W 33.5 416.2* 588.9* 11933.3 9161. 8 3986.8N 5649.6W 13439.3 9357.2 4272. 3N 5463.5W 33.1 392.8* 557.8* 11966.7 9179.7 4013.4N 5659.0W 13469.0 9375.2 4274.7N 5486.9W 33.4 369.0* 526.5* 12000.0 9197.4 4040.1N 5668.3W 13488.8 9387.3 4276.1N 5502.6W 35.1 345.3* 494.8* 12033.3 9214.8 4067.0N 5677.4W 13508.5 9399.2 4277.5N 5518.2W 37.1 321.9* 461. 6* 12066.7 9232.1 4094.0N 5686.3W 13527.5 9410.7 4278.8N 5533.3W 39.6 299.1* 428.9* 12100.0 9249.2 4121.3N 5695.2W 13546.2 9421. 9 4280.2N 5548.1W 42.8 277 . 0* 396.7* 12126.6 9262.7 4143.1N 5702.1W 13561.6 9431.2 4281.5N 5560.4W 45.7 260.1* 370.4* 12153.1 9276.0 4165.0N 5709. OW 13576.6 9440.2 4282.8N 5572. 3W 49.2 243.9* 342.9* 12200.0 9299.4 4203.8N 5721. OW 13603.9 9456.5 4285. 3N 5594.1W 57.3 217.8* 292.7* 12300.0 9349.4 4286.5N 5746.7W 13661. 2 9490.7 4290. 3N 5639.7W 88.0 177.2* 194.8* 12345.1 9372.0 4323.8N 5758.3W 13685.6 9505.4 4292.0N 5659.2W 107.8 169.2* 171.4* 12358.9 9378.7 4335.3N 5761. 8W 13693.3 9510.1 4292.5N 5665.3W 113.9 168.6* 168.6* 12372.6 9385.0 4346. 9N 5765.4W 13700.8 9514.6 4293.0N 5671.2W 119.7 169.1 171.0 12386.3 9390.9 4358.7N 5769.1W 13708.1 9519.0 4293.5N 5677.0W 125.3 170.8 179.2 12400.0 9396.4 4370.7N 5772. 8W 13713.8 9522.5 4293.9N 5681.5W 130.0 173.6 193.2 12416.7 9402.6 4385.5N 5777.4W 13722.2 9527.7 4294.5N 5688.2W 135.5 178.6 217.6 12433.3 9408.2 4400.5N 5782.1W 13730.4 9532.6 4295.1N 5694.6W 140.3 185.1 249.7 12450.0 9413.2 4415. 7N 5786.8W 13738.2 9537.4 4295.6N 5700.7W 144.4 193.0 12466.7 9417.6 4431. ON 5791. 5W 13745.7 9542.0 4296.1N 5706.6W 147.8 202.2 12483.3 9421.3 4446. 5N 5796.3W 13752.6 9546.3 4296.6N 5712.1W 150.7 212.6 12500.0 9424.5 4462.2N 5801.2W 13759.4 9550.5 4297.1N 5717.4W 153.1 223.9 12515.1 9426.8 4476.4N 5805.6W 13765.3 9554.1 4297.5N 5722.1W 155.0 234.9 12530.3 9428.7 4490.8N 5810.0W 13770.9 9557.5 4297.9N 5726. 5W 156.6 246.6 12545.4 9430.0 4505.2N 5814.5W 13776.2 9560.8 4298.2N 5730.6W 157.9 258.8 12560.6 9430.7 4519.7N 5819.0W 13781.2 9563.8 4298.6N 5734.6W 159.1 271.5 12575.7 9431. 0 4534 .1N 5823.5W 13785.9 9566.7 4298.9N 5738. 2W 160.1 284.6 12600.0 9431. 0 4557. 3N 5830.6W 13794.2 9571. 8 4299.5N 5744. 8W 161. 6 306.1 12700.0 9431.0 4652.9N 5860.2W 13824.1 9590.0 4301.6N 5768.5W 165.4 396.4 12800.0 9431.0 4748.4N 5889.8W 13855.4 9609.0 4303.7N 5793.2W 167.8 488.6 Vertical All data is in feet unless otherwise stated. Caaing dimensions are not included. slot #4-16 and TVD from wellhead (99.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. section is from S 0.00 E 0.00 on azimuth 342.80 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Coordinates from ,~ ,~ Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263.7660 UNOCAL8 Dalo Haines Drilling Manager Tuesday, May 19, 1998 Mr. Dave W. Johnston AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: UNOCAL plans to red rill G-15 on the Grayling platform utilizing oil-based mud (OBM). The base oil that will be used for the OBM is MAP CO 200. The cuttings will be collected, placed in sealed 55 gallon drums, and then shipped off the Grayling platform for future disposal. As per Dan Williamson's conversation with Blair Wondzell on April 30, 1998, UNOCAL is informing you of our plan to handle the OBM liquid waste. To reduce environmental exposure, UNOCAL is requesting approval to inject the OBM liquid waste, that is associated with OBM, down well G-15's 13-3/8" by 9-5/8" casing annulus. We are estimating to inject 3,000 BBlS of liquid down this annulus. If you have any questions or concerns with our proposal, please contact myself or Drilling Engineer Mitch Damm @ 263-7679. F"<?-1j: ~<; sr- ,.se-t Thank you for your time and cooperation. RECEIVED MAY 16 1998 Very truly, ~Jt &úaW\m~ Dale A. Haines Drilling Manager ,AIIIka Oil & GatCOns. ~n MdIII8t l/ I'd Zl9L'ON 'd~O) lV)ONn ~dvO:Z 8661 'LZ'^~~ ¡: Iì ~ Unocal Corporation P. O. Box 196247 Anchorage, AK 99519 (907) 263-7679 r-', UNOCAL8 Mitchell W. Damm Drilling Engineer May 6, 1998 Mr. Dave Johnston AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: Please find attached a 10-401 for Trading Bay Unit G-15RD to dispose of the drilling fluids down the annulus. Thank you for your time and cooperation. Sincerely, nc-.~ 6\1 CL"'- ~V\f'yn, )JCNVV- / Mitchell W. Damm Drilling Engineer MWD/leg REceIVED '( G D 1998 Alaska Oil & Gas Cons. COI1l!\îlSsiOn Anchorage .~, -,---\ Unocal Alaska Resources Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL8 Rick D. Cross Senior Landman April 30, 1998 Mr. Robert Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Permit to Drill G-15RD Trading Bay Unit Cook Inlet Area State of Alaska Dear Mr. Crandall, Union Oil Company of California (Unocal), as Operator for the Trading Bay Unit, requests your approval to red rill the Trading Bay Unit G-15 well in the Hemlock Oil Pool pursuant to Rule 5 Conservation Order No. 80. Drilling from the Grayling Platform, and completing the well in the Hemlock Oil Pool at a crestal final withdrawal point will result in additional recovery of Hemlock production. Enclosed is a check in the amount of $100.00 as required by 20 AAC 25.005(c)(1) to process an application for permit to drill. Unocal appreciates your review and approval of this application. Sincerely yours, d;¡ ¡[)~õ Rick D. Cross Senior Landman RECEIVED ,,;, ~. '/ r 11 1998 (',.h l v.. - ' Enclosed: Check No. Aìaska Oil & Gas Cons. Commission Anchorage -- :;-... FOR INQUiRiES CONTACT LOCATION WHERE INVOICES W~U8MITTED 1031548 04-30-98 2002665 29-APR-98 DRILLPERMITG15 0498300166E 100.0C 100.00 FORM 4-28181 (REV. 11-95) PRINTED IN U.S.A. DETACH STUB BEFORE DEPOSITING CHECK 100.00 100.00 -----.----, - - -- ,- ...-----_..--...._,c_---- - ---- ~---...---------...--' - - - ~ - - - -- -- - - - -- FIELD & POOL WELL PERMIT CHECKLIST COMPANY INIT CLASS WELL NAME GEOL AREA PROGRAM: exp 0 dev 0 redrll 0 serv 0 wellbore seg [J ann. disposal para req [J UNIT# ONIOFF SHORE . ADM I NISTRA TION APPR DATE ENGINEERING APPR DATE GEOLOGY APPR DATE ANNULAR DISPOSAL APPR DATE æ p,:., -4 ~ CJð 1.Permitfeeattached....................... 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . .......... 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21, If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . ' 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown, . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . ' 30. Permit can be issued wlo hydrogen sulfide measures. 31. Data presented on potential overpressure zones. . . 32. Seismic analysis of shallow gas zones. . . . . . . . . 33. Seabed condition survey (if off-shore). . . . . . . . . 34. Contact namelphone for weekly progress reports. . . . . . . [exploratory only] 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. GEOLOGY: ENGINEERING: COMMISSION: RPC BEW DWJ WM -==- JDH RNC CO M:cheklist rev 05198 dlf: C :Imsofficelwordianldianalchecklist Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Ct~ ~~ CÐN Comments/Instructions: 0 0 z 0 -1 ~ ;;0 ( - -1 m - z -1 I - (f) » ;;0 m » ( . WELL PERMIT CHECKLIST COMPANYC/~/ WELL NAME --.?;?Ú C -/5' ~/J PROGRAM: exp 0 dev)rredrlrytserv 0 wellbore seg D ann. disposal para r~~ FIELD & POOL S":¿o/¿d INITCLASS -/)P...-" /-ðJ I GEOLAREA 'if 70 UNIT# /¿O 70 ON/OFFSHORE ~~ ADMINISTRATION A.w Ç)I}TE ~ S/J/lqr ENGINEERING ~ ~ÞlE 5/{7 GEOLOGY f)f!.R DAT)5 /V<... 6/(//'f'è7 1.Permitfeeattached....................... 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Uniquewellnameandnumber... . . . . , . , . . . . . . . , 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . 11. Permit can be issued without conservation order. . . . 12. Permit can be issued without administrative approval. . 13. Can permit be approved before 15-day wait.. . . . . . ~N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N (jN REMARKS ~ 14. Conductor string provided. . . . . . . . . . , . . . . . . .. Y N] , 15. Surface casing protects all known USDWs. . . . . . . . . .. Y Nth- 16. CMT vol adequate to circulate on conductor & surf csg. . . .. Y N 17. GMT vol adequate to tie-in long string to surf csg. . . . . . .. Y N 18. GMT will cover all known productive horizons. . . . . . . . . . iJ 19. Casing designs adequate for G, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. .. '( N -CiA- ~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . CO N It- I (j 23, If diverter required, does it meet regulations. . . . . ' . . . . ""¥--t+ AI 24. Drilling fluid program schematic & equip list adequate. . . . .iN 25. BOPEs, do they meet regulation. . . . . "'2.' . . . . . . . . N 26. BOPE press rating appropriate; test to 7c::v-D psig. Y N 27. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of HzS gas probable.. . . . . . . . . . . . . . . . N ( 30. Permit can be issued wlo hydrogen sulfide measures. 31. Data presented on potential overpressure zones. . . 32. Seismic analysis of shallow gas zones. . . . . . . . . 33. Seabed condition survey (if off-shore). . . . . . . . . 34. Contact name/phone for weekly progress reports. . . . . . [expfora1ory only] GEOLOGY: I~P#¿ ENGINEERING: COMMISSION: BEW ~9,.::, S/(9hSDW J JDH --d¡.t-. RNC CO CD 12.'/ Comments/lnstructions: AIGEN. MisclFORMSlcheklist rev 09/97 dlf: C: Imsoffícelwordianldíanalchecklist ANNULAR DISPOSAL CHECKLIST COMPANY 1. Designation of well to receive waste. ......,.... 2. Depth to base of freshwater aquifers/permafrost. ' ..... 3. Depth/thickness of receiving and confining zone. . . . . . . . . 4. Sufficient information to demonstrate confinement. . . . . . . 5. List of all publicly recorded wells within 1/4 mile. . . . . . . . . . 6. List of all publicly recorded water wells within 1 mile. . . . . . . . 7. Estimate of max. volume & density of waste slurry. . . . . . . . 8. Description of drilling waste. ............... 9. Estimate of max. anticipated pressure at outer casing shoe. . . . 10. Outer casing shoe set below aquifer/permafrost base. . . . . 11. Outer casing shoe sufficiently cemented to provide isolation. . . . 12. Sufficient collapse/burst strength. . . . . , . . . . . . 13. Additionaldata.................. ...... Commentsllnstructions: ann. disposal para 1 [ WELL NAME Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ann. disposal para 2 II