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194-124
STATE OF ALASKA ALIIIL OIL AND GAS CONSERVATION COMMI SION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Run,GeCompletionl] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: .3Er ei.t_ p Name: Hilcorp Alaska,LLC Development l] Exploratory❑ 194-124 ,...---_ 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: c.- Anchorage, ,Anchorage,AK 99503 50-733-20048-0 ECEI VE(S 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 11 RD C 1 1 2016 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: AOGCC Total Depth measured 11,469 feet Plugs measured N/A feet true vertical 9,559 feet Junk measured N/A feet Effective Depth measured 11,351 feet Packer measured N/A feet true vertical 9,567 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 629' 20" 629' 629' Intermediate 3,196' 13-3/8" 3,196' 2,976' 2,730 psi 1,130 psi Production 9,510' 9-5/8" 9,510' 8,777' 6,870 psi 4,760 psi Liner 2,122' 7" 11,469' 9,599' 8,160 psi 7,020 psi Perforation depth Measured depth 8,760-11,282 feet SCANNED Lb ab a LJ aha True Vertical depth 8,232-9,548 feet LS 2-7/8" 6.4/L-80 8,670'(MD) 8,165'(ND) Tubing(size,grade,measured and true vertical depth) SS 2-7/8" 6.4/L-80 8,623'(MD) 8,130'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 5 36 86 83 Subsequent to operation: 0 0 135 93 73 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 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: 316-455 Contact Dan Marlowe(907)283-1329 Email dmarlowe( hilcorD.com Printed Name Stan W.Golis Title Operations Manager Signature ..► t/3 A Phone (907)777-8356 Date %0/ t 1 'L01 4`' !c,El, IL' / Form 10-404 Revised 5/201571:4- b(//7�BDMS Submit Original Only �`�d�'� ! 1 "[016 • Anna Platform Well No. 11 RD n • SCHEMATIC Completion: 09/28/16 PTD: 194-124 Hikorp Alaska,LLC API: 50-733-20048-01 Size(in) Wt(ppf) Grade Conn ID(in) Top(ft) Btm(ft) 20 85 B - 19.124 Surface 629 API#50-733-20048-01 13-3/8 54.5 J-55 - 12.615 Surface 3,196 RKB to TBG Head = 34' 9-5/8 47 L-80 BTC 8.681 Surface 9,510 7 Liner 29 L-80 BTC 6.184 9,347 11,469 Long String 2-7/8 I 6.4 I L-80 18 RD EUE I 2.441 I Surf I 8,670' z '. Short String 2-7/8 6.4 L-80 8 RD EUE 2.441 Surf 7,154' 2-7/8 6.4 L-80 SuperMax 2.441 7,154' 8,623' L Ref I MD(ft) I TVD(ft) I ID(in) I OD(in) I Item Long String 34' 34' Tubing Hanger,Vetco,Dual-Spit,CWC-FSH,11x3-1/2"IBT 1 8,660' 8,158' 2.441 5.875 2.5"Accelerated JP BHA MVSR 2 8,663' 8,160' 2.441 2.680 Standing Valve Shoe Extension 3 8,664' 8,161' 3.438 RN Nipple 4 8,670' 8,165' 2.438 3.625 WLEG Short String A 7,153' 6,866' 2.441 3.500 X0 2-7/8"SuperMax P x 2-7/8"EUE 8 RD Box 8,623' 8,130' 2.441 2.875 X0 Pup 2-7/8"8RD x 2-7/8"SuperMax 8,626' 8,132' 1.995 3.680 X0 2-7/8"8RD B x 2-3/8"SuperMax Pin 8,659' 8,157' 1.500 2.390 X0 1-1/4"NPT Box x 2-3/8"SuperMax B 8,661' 8,158' - 5.875 2.5"Accelerated JP BHA MVSR Top Btm Top Btm A Zone (MD) (MD) TVD TVD Amt SPF Date Comments i C5A 8,760 8,763 8,232 8,235 3 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 1 B C5B 8,784 8,793 8,250 8,257 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns I I 11I I C6 8,850 8,885 8,299 8,325 35 5 5/14/2015 Super DP BOX 60 degree Ph 4-1/2"Guns C7A 8,998 9,004 8,406 8,411 6 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 2 I I I II 1 C7B 9,185 9,216 8,542 8,564 31 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C7C 9,237 9,253 8,580 8,591 16 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 3 RN l C7D 9,343 9,361 8,656 8,669 18 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns yy.�� 4 C7E 9,405 9,429 8,701 8,718 24 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns Y{ C8C 9,492 9,499 8,764 8,769 7 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C8D 9,648 9,694 8,877 8,909 46 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns ?y C8C 9,735 9,746 8,937 8,945 11 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns �r� C9A 9,921 9,973 9,058 9,089 52 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C9A 10,078 10,087 9,147 9,151 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C-8 10,232 10,255 9,218 9,227 23 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-8 10,285 10,345 9,239 9,260 60 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C7E 10,497 10,506 9,312 9,315 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns L C-7 10,585 10,600 9,341 9,346 15 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-7 10,665 10,750 9,367 9,393 85 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-7 10,759 10,784 9,396 9,404 25 6 12/8/1994 HRS 4-5/8"Tbg.Cony. M C7A 10,833 10,845 9,419 9,423 12 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C6 10,950 10,955 9,455 9,456 5 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C6 10,981 10,986 9,464 9,465 5 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C-5 11,084 11,106 9,493 9,499 22 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-5 11,119 11,156 9,503 9,513 37 6 12/8/1994 HRS 4-5/8"Tbg.Cony. M C-5 11,200 11,282 9,525 9,548 82 6 12/8/1994 HRS 4-5/8"Tbg.Cony. Fish: 8/2016:2-7/8"8 round EUE 31'Tubing tail w/42'screen oVr • x:51 PBTD=11,351ft (9,627ft TVD) Updated:10/06/16 by 1LL TD=11,469ft(9,666ft TVD) • • • Hilcorp Alaska, LLC Hilcorp.Ata ka,LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742#11RD Moncla 404 50-733-20048-01 194-124 9/20/2016 9/28/2016 09/20/16-Tuest Mobilized WSMs,expeditor,crane and rig crews to Anna Platform.Laid out koomey and flow lines,hooked up rig pump lines.Offloaded construction equipment. Monitored well(static).NOS rep installed BPVs and blanking plugs.N/D tree,N/U 13 5/8"5M BOPs w/2 3/8"x 3 1/2"dual CIW Type'U'Flex Packers in pipe rams.Raised and scoped out derrick securing all guy lines. Connected koomey and flow lines to BOPS. Received KCL from M/V Titon. Began torqueing BOP stack. Positioned driller's shack,steps,Swaco mixing tank and charger pump.Mounted rig floor.Installed floor supports and hand rails. Moved S/L unit and overpacks to clear area for laying down tubing. Set off-driller side steps in place.M/U two 2 7/8"test jt and screwed into blanking plugs in hanger/assistance from NOS rep. 09/21/16-Wednesday Finished M/U dual 2 7/8"test jts w/pumpin,SV&IBOP.Screwed into blanked ported subs in dual hanger. Moved test pump inside due to weather. Changed out one 2 7/8"test jt to 2 3/8". Filled stack and test jts w/DW. Pretested BOPS working thru minor leaks.Tested all BOPE to 250#s low 2500#s high as per Sundry in accordance to AOGCC and Hilcorp requirements(test witnessed by Matt Herrera/AOGCC).Performed successful accum draw down test.R/D test equipment.NOS rep screwed into primary packoff seal w/dual jts and pulled same. Pulled BPVs and closed blinds.R/U Weatherford's dual handling equipment. Mixed 70 bbls of 6%KCL in Swaco tank then transferred to active tank.Mixed another 60 bbls and held in mixing tank.Due to winds gusting 40 MPH+decision was made to shutdown operations(blocks is hitting side of derrick as it travels,hydraulic hoses on dual elevators,man on stabbing board in derrick while POOH,crane operator voiced concern moving pipe to and from floor). 09/22/16-Thursday Housekeeping while waiting on weather.M/U landing jts,pull hangers,unseated @ 93k stringy moving @ 110k.R/u dual slips,L/D hangers&lay down landing jts.POOH I/d duals,I/d 64 jts.Wind picked up t/48MPH unable to operate,secured well.Operation shutdown due to high winds(over 50 MPH). Wind speed registering 22-31 MPH. Pumped 4 bbls 6%KCL and began pulling tb again from 7,900'. 142 total jts of 2 7/8"8rd production tb out at report time=6,821'EOT(weighs 80k). 09/23/16-Friday Continued POOH w/dual production strings and BHA,pumping 4 bbls 6%KCL every 40 jts laid down.Broke off X0s to 2 3/8"and 2 7/8"SuperMax then M/U same on safety valves.Change out Weatherford handling tools to B/0 L/D 2 3/8"tb.Continued POOH w/dual production strings and pump cavity BHA(changing tong dies each connection f/2 3/8"&2 7/8"tb).Five jts from btm strings were wrapped.R/D Weatherford dual handling equipment. 09/24/16-Saturday C/O pipe rams t/2 7/8 x 5"VBR.Start R/U handling tools,m/u 2 7/8"T.I.Fill stack w/drill water,test 2 7/8"x 5"VBR rams 200 low,2500 high 5 min each, good.Break down pump cavity assy,finding standing valve missing&pump wedged into standing valve seat.Break down recovered w/I tools.Pull test plug,I/d test jt.Finish rigging up 2 7/8 handling eq.P/U c/o BHA-6"deep throat mill,3 1/2"x 2 7/8"xo=4.05'.Rih p/u 2 7/8 EUE 8rd tubing t/9,260'(P/U 60k 5/0 43k). Went thru top of 7"liner(9,347')without seeing it. 2230 hrs set down at 9,515'(306 jts+7'). Took 20k to pull free.Picked up to 9,508'and B/O single.M/U safety&pumpin w/Kelly hose-lined up to send returns to facility.Began pumping 6%KCL LW at 3 BPM 0 PSI sending returns to production. Caught returns at 232 bbls pumped-reduced rate to 2 BPM in order to keep up with KCL mixing.Reduced pumping rate to 1 1/2 BPM at request off production(level in vessel getting too high-increased shipping rate to GPTF.Returns clean at 696 bbls pumped-weighs 8.6#. Lined up to rev. circ. • • Hilcorp Alaska, LLC 1Iikorp Alaska.IAA- Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742#11RD Moncla 404 50-733-20048-01 194-124 9/20/2016 9/28/2016 09/25/16-Sunday Rev.CBU x3 @ 140 GPM 430 psi.R/D circulating head.POOH standing back string.Up wt 56k,dragging until out of liner,I/d BHA.P/U BHA#2-4 5/8 bit, bt sub,xo 2 7/8 PH-6 x 2 7/8 EUE 8rd=4.92'.TIH t/9327'up wt 58k,do wt 44k,cont.tih t/9389'get up wt in liner&hung up having op of 20-25k.Appears to be tubing collars hanging up near liner top(9347').Decision made to POOH.POOH 1/d 2 7/8 EUE tubing,pumping 3 bbls 6%KCL every 20 jts. B/O bit& bit sub.Closed/locked blinds and changed out 2 7/8"single pipe rams to dual flex packers 2 3/8"x 3 1/2". M/U test plug,ported sub,'Y'block and dual 2 7/8"test jts w/SVs-opened blinds&landed test assy,filled stack and test jts-tested pipe rams to 250#s low 2500#s high. B/D L/O test equipment. 09/26/16-Monday R/D Moncla single handling equipment(slips,elevators,tongs)and R/U Weatherford dual handling equipment.P/U pump cavity assy on dual strings of 2 7/8"tb and lowered in hole. TIH running in 8rd on LS and SuperMax on SS to 1,504'then 8rd on both sides drifting w/2.36 drift,depth of 5,645' at report time. 09/27/16-Tuesday Finished RIH w/dual 2 7/8"6.5#N-80 production strings(1500'of 6.4#N-80 SuperMax tb on btm of SS)w/pump cavity BHA to 8,670.03'EOTs.M/U dual hanger w/assistance from NOS rep-landed same and installed primary sealing plate on top of hangers.Ran in lock down pins.M/U SVs in top of tb strings. R/U Pollard S/L w/full lubricator. M/U rope socket,2-5'1 1/2"stem,knuckle,oil&spang jars+2.33"gauge. M/U to LS side and TIH to 8,707(SLM)and tagged-POOH. B/O gauge and M/U running tool and standing valve.TIH and shook off standing valve at 6,000'. POOH-R/D S/L.Lined up to pump down long string,taking returns up short string side. Pumped 1.15 BPM-got returns at 37 bbls pumped. Pressured up to 3500#s f/30 mins on chart. Good test- released pressure.B/D landing jts and NOS set BPVs. R/D/R Weatherford's dual handling equipment.Cleared rig floor,removed windwalls,V-door and floor supports-dismounted floor. 09/28/16-Wednesday Finished R/D floor. Disconnected guys lines.Scoped down/laid over derrick.Moved driller's shack back.Prepped the derrick to be removed from carrier. Unstrung catlines and drill line from derrick.Removed draw works from carrier while N/D BOPE.Continued prepping equipment for rig move while N/U tree.Tested void to 500#s f/5 mins.5000#s f/15 mins,Good. Pulled BPVs then N/U tree and flow lines.Turned well over to production. • • • OF T� • 4,1,'\ �7 AA THE STATE Alaska Oil and Gas ti !''�� OfALA KA Conservation Commission 5 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 F-71*'�`� Main: 907.279.1433 ALAS*P' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager SCANNED FEB- 5 ZO1 Z Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Granite Point Field,Middle Kenai Oil Pool, GPS 18742 11RD Permit to Drill Number: 194-124 Sundry Number: 316-455 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, 7)99,-4-7(1 . Cathy P. Foerster Chair DATED this /ay of September,2016. RBDMS 1A/SEP 1 6 2016 • • • RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 6 2016/ APPLICATION FOR SUNDRY APPROVALS O r$ ?I ( i!.E• 20 AAC 25.280 c� 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate❑ Repair Well ❑ ® gl'St shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 t Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: Run Gil_Completion 0 4 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0• 194-124 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20048-01 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes ❑ No 0/ Granite Pt St 18742#11RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 Granite Point Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11,469 - 9,559 • • 11,351 • 9,567 1,720 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 629' 20" 629' 629' Intermediate 3,196' 13-3/8" 3,196' 2,976' 2,730 psi 1,130 psi Production 9,510' 9-5/8" 9,510' 8,777' 6,870 psi 4,760 psi Liner 2,112' 7" 11,469' 9,599' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): 8,760-11,282 I 8,232-9,548 LS-2-7/8" 6.4/L-80 8,665 SS-2-7/8"&2-3/8" 6.4&4.6/L-80 8,665 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/21/2016 Commencing Operations: OIL 0 • WINJ 0 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 Dan Madowe(907)283-1329 Email dmadowenhilcorp.com Printed Name Stan W.Golis� Title Operations Manager Signature 1", ren Phone (907)777-8356 Date ( G (<' COMMISSION USE ONLY I Conditions of approval: Notify Co mission so that a representative may witness Sundry Number: - L156. Plug Integrity ❑ BOP Tes( Mechanical Integrity Test ❑ Location Clearance ❑ Other: ( zce° fr% i (1:0V , % ASF 11,3 )1 L Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No [j Subsequent Form Required: 10 v-40 A RBDMS vL- SEP 16 2016 Approved by: , / g4.___ COMMISSIONER Date:9. /4/ 1441 . ' APPROVEDBY (^/� A' AarM 1116 y Kr. Form 10-403 Revised 11/2015 OpRvdlaIIc4 12 month fro the date of appy vAttachments in Duplicate • • • • Well Prognosis Well: An-11RD Hilcorp Alaska,LL Date:09/01/2016 Well Name: Granite Point State 18742#11rd(AN-11rd) API Number: 50-733-20048-01 Current Status: Hydraulic Lifted Oil Producer Leg: Leg#1 -NW Corner Estimated Start Date: September 21,2016 Rig: Moncla 404 Reg.Approval Reqd? N/A Date Reg.Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 194-124 First Call Engineer: Dan Marlowe (907)283-1329 (907)398-9904(M) Second Call Engineer: Stan Golis (907)777-8356 Current Bottom Hole Pressure: --2,543.psi at 8,232 ft TVD 0.309 lbs/ft(5.94 ppg)based on 01/05/16 static fluid level Maximum Expected BHP: -2,543 psi at 8,232 ft TVD 0.309 lbs/ft(5.94 ppg)based on 01/05/16 static fluid level Maximum Potential Surface Pressure: 1,720 psi ✓ Using 0.1 psi/ft gradient per 20 MC 25.280(b)(4) Note:This is a no-flow Well(05/28/15) Brief Well Summary An-11 RD was worked over in 2015 lowering the pump cavity deep into the perforations. In August 2016 the cavity was pulled up-hole and re-landed but plugged off again within 3 days. This workover will pull the completion string, cleanout the well, and rerun the completion. Currently the pump and standing valve (hung open—presumably with solids) are stuck in the hole -* LAST CASING TEST: 05/10/2015 8,716' DPM, 1500 psi for 30 minutes Procedure 1. Bleed well off(casing/tubing). 2. Shoot fluid levels on back side. 3. Circulate fluids down short and long strings as needed to balance well.Work over fluid is 6% KCL, BOP's will be closed as needed to circulate the well. 4. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 5. POOH laying down completion. 6. RIH with 7"cleanout assembly to top of tubing tail fish+/-11,300'. ✓ 7. PU and RIH with completion placing cavity at+/-8,660' 8. Set BPVS and test. 9. ND BOP, NU wellhead and test. 10. Turn well over to production. 11. Conduct SVS tests 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 III Anna Platform • Well No. 11 RD Completion: 08/17/2016 Schematic PTD: 194-124 API: 50-733-20048-01 Hilcorp Alaska,LLC Size(in) Wt(ppf) Grade Conn ID(in) Top(ft) Btm(ft) 20 85 B - 19.124 Surface 629 API#50-733-20048-01 13-3/8 54.5 J-55 - 12.615 Surface 3,196 RKB to TBG Head =34' 9-5/8 47 L-80 BTC 8.681 Surface 9,510 7 Liner 29 L-80 BTC 6.184 9,347 11,469 Long String 2-7/8 6.4 1-80 8 RDL EUE 2.441 Surf 4,396' L 2-7/8 6.4 1-80 Supermax SC 2.441 4,396' 8,665' Short String 2-7/8 6.4 L-80 8 RD EUE 2.441 Surf 6,514' 2-3/8" 4.6 L-80 Supermax SC 1.995 6,514' 8,665' L Ref 1 MD(ft) I TVD(ft) I ID(in) I OD(in) I Item Long String 34' 34' Tubing Hanger,Vetco,Dual-Spit,CWC-FSH,11x3-1/2"IBT 1 7,042' 6,758' 2.441 3.500 X0 2-7/8"Supermax P x 2-7/8"EUE 8Rd Box 2 8,660' 8,158' 2.441 2.875 XO 2-7/8"8RD EUE X 2-7/8"Sprmx SC A 3 8,663' 8,160' - 5.875 2.5"Accelerated JP BHA MVSR 4 8,666' 8,162' - 2.680 Standing Valve Shoe Extension Short String A 7,070' 6,786' 1.995 3.680 XO 2-7/8"EUE X 2-3/8"Sprmx SC B 8,660' 8,158' 1.500 2.390 XO 2-3/8in Sprmx SC X 1.25in NPT Box C 8,662' 8,159' - 5.875 2.5"Accelerated JP BHA MVSR Zone Top(MD) Btm(MD) Top ND NtmD Net SPF Date Comments C5A 8,760 8,763 8,232 8,235 3 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C5B 8,784 8,793 8,250 8,257 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 2 B C6 8,850 8,885 8,299 8,325 35 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C7A 8,998 9,004 8,406 8,411 6 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 3 C C78 9,185 9,216 8,542 8,564 31 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2'Guns inillt,NM1I1 C7C 9,237 9,253 8,580 8,591 16 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns RIPF C7D 9,343 9,361 8,656 8,669 18 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 4 mein C7E 9,405 9,429 8,701 8,718 24 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2'Guns I l C8C 9,492 9,499 8,764 8,769 7 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C8D 9,648 9,694 8,877 8,909 46 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C8C 9,735 9,746 8,937 8,945 11 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C9A 9,921 9,973 9,058 9,089 52 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C9A 10,078 10,087 9,147 9,151 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C-8 10,232 10,255 9,218 9,227 23 6 12/8/1994 HRS 4-5/8"Tbg.Cone. C-8 10,285 10,345 9,239 9,260 60 6 12/8/1994 HRS 4-5/8'Tbg.Cons. 0 C7E 10,497 10,506 9,312 9,315 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C-7 10,585 10,600 9,341 9,346 15 6 12/8/1994 HRS 4-5/8"Tbg.Cons. C-7 10,665 10,750 9,367 9,393 85 6 12/8/1994 HRS 4-5/8"Tbg.Cony. L- C-7 10,759 10,784 9,396 9,404 25 6 12/8/1994 HRS 4-5/8"Tbg.Conv. C7A 10,833 10,845 9,419 9,423 12 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C6 10,950 10,955 9,455 9,456 5 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C6 10,981 10,986 9,464 9,465 5 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C-5 11,084 11,106 9,493 9,499 22 6 12/8/1994 HRS 4-5/8'Tbg.Cony. C-5 11,119 11,156 9,503 9,513 37 6 12/8/1994 HRS 4-5/8'Tbg.Conv. C-5 11,200 11,282 9,525 9,548 82 6 12/8/1994 FIRS 4-5/8"Tbg.Conv. 0 0 Fish: 8/2016:2-7/8"8 round EUE 31'Tubing tail w/42'screen PBTD=11,351ft (9,627ft TVD) Updated:08/29/16 by JLL TD=11,469ft(9,666ft TVD) • • Anna Platform Well No. 11 RD . li PROPOSED Completion: Future PTD: 194-124 Hneor,,Alaska,LLC API: 50-733-20048-01 Size(in) Wt(ppf) Grade Conn ID(in) Top(ft) Btm(ft) 20 85 B - 19.124 Surface 629 API#50-733-20048-01 13-3/8 54.5 J-55 - 12.615 Surface 3,196 RKB to TBG Head = 34' 9-5/8 47 L-80 BTC 8.681 Surface 9,510 7 Liner 29 L-80 BTC 6.184 9,347 11,469 Long String 2-7/8 6.4 L-80 8 RD EUE 2.441 Surf ±4,396' L , 2-7/8 6.4 L-80 Supermax SC 2.441 ±4,396' ±8,660' 2-7/8 6.4 L-80 8 RD EUE 2.441 ±8,660' ±8,702' Short String 2-7/8 1 6.4 I L-80 1 8 RD EUE I 2.441 I Surf I ±8,665' L Ref I MD(ft) I ND(ft) I ID(in) I OD(in) I Item Long String 34' 34' Tubing Hanger,Vetco,Dual-Spit,CWC-FSH,11x3-1/2"IBT 1 ±7,040' ±6,756' 2.441 3.500 X0 2-7/8"Supermax P x 2-7/8"EUE 8Rd Box 2 ±8,660' 158' 2.44 7.875 X0 2-7/8"8RD EUE X 2-7/8"Sprmx SC 3 ±8,665' ±8,161' ,.875 2.5"Accelerated JP BHA MVSR 4 ±8,666' ±8,162' 3.680 Standing Valve Shoe Extension 5 ±8,696' ±8,185' X Nipple 6 ±8,702' +8,189' WLEG Short String s` A ±7,070' ±6,786' X0 2-7/8"EUE X 2-3/8"x 1.25"NPT Box B ±8,665' ±8,161' 2.5"Accelerated JP BHA MVSR Zone Top Btm Top Btm Amt SPF Date Comments (MD) (MD) TVD ND CSA 8,760 8,763 8,232 8,235 3 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C5B 8,784 8,793 8,250 8,257 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 2 • A C6 8,850 8,885 8,299 8,325 35 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C7A 8,998 9,004 8,406 8,411 6 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 3 B C7B 9,185 9,216 8,542 8,564 31 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns MEM i•BI■ C7C 9,237 9,253 8,580 8,591 16 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C7D 9,343 9,361 8,656 8,669 18 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 4viiimMIME C7E 9,405 9,429 8,701 8,718 24 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C8C 9,492 9,499 8,764 8,769 7 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 5 X 1 C8D 9,648 9,694 8,877 8,909 46 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C8C 9,735 9,746 8,937 8,945 11 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns '�y rr 6 C9A 9,921 9,973 9,058 9,089 52 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C9A 10,078 10,087 9,147 9,151 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns 0 C-8 10,232 10,255 9,218 9,227 23 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-8 10,285 10,345 9,239 9,260 60 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C7E 10,497 10,506 9,312 9,315 9 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C-7 10,585 10,600 9,341 9,346 15 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-7 10,665 10,750 9,367 9,393 85 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-7 10,759 10,784 9,396 9,404 25 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C7A 10,833 10,845 9,419 9,423 12 5 5/14/2015 Super OP RDX 60 degree Ph 4-1/2"Guns C6 10,950 10,955 9,455 9,456 5 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C6 10,981 10,986 9,464 9,465 5 5 5/14/2015 Super DP RDX 60 degree Ph 4-1/2"Guns C-5 11,084 11,106 9,493 9,499 22 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-5 11,119 11,156 9,503 9,513 37 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-5 11,200 11,282 9,525 9,548 82 6 12/8/1994 HRS 4-5/8"Tbg.Cons. r> Fish: 8/2016:2-7/8"8 round EUE 31'Tubing tail w/42'screen or PBTD=11,351ft (9,627ft TVD) Updated:09/01/16 by JLL TD=11,469ft(9,666ft TVD) s •• • fiAnna Platform An-11RD Current 01/18/2016 Hilrurp:tlarka.l.IC: Anna Platform Tubing hanger,Vetco,CWC- An#11 FSCH split dual,11 X 3 Y:IBT 20X133/8X95/8X suspx3%EUElift,w/3" 2 7/8 X 2 7/8 type H BPV,2-Y.control line nipples Valve,Master,OCT-20, 3 1/8 5M 5 bolt,FE,HWO Qty 2 4 it $/1®_ ,46: iffaii% �®_ Adapter,Vetco-dual,11 5M FE X dk��� ,. �„ 3 1/8 5M 5 bolt top,prepped f/ i i 3"nom flex neck Tubing head,Vecto CWC-T, __ , 5 3/64 centers 13 5/8 3M X 11 5M,w/ s=ue �_r'` 2-2 1/16 5M SSO _ I 2-MC alignment pins 'I, , 1 III 11 �J 1'1 Valve,Vetco,2 1/16 5M FE, • I I HWO _/-",, -, k It' Aiiiiii,:t It Iii 1. rut RI I a Casing spool,OCT-22-BP, =�'! in I� ®'�= 211/4 2M X 13 5/8 3M, III 6 ill Valve,OCT-20,2 1/16 5M FE, w/2-2 1/16 5M SSO, a, _ O HWO 00 bottom prep ' !.! IIll- _ II si Casing head,OCT-22, me 211/2 2M X SOW,w/ 1�1 ave, - , 5M FE, /16 5M EFO iI ,.� ` HWO Anna Platform An-11RD Proposed Hilcurp.'t}allka,ILIA, 01/18/2016 Anna Platform Tubing hanger,Vetco,CWC- An#11 FSCH split dual, 11 X 3%IBT 20X133/8X95/8X susp x 3'A EUE lift,w/3" 3 1/2 X 3 1/2 type H BPV,2-'A control line nipples Valve,Master,OCT-20, 3 1/8 5M 5 bolt,FE,HWO Qty 2 ® I _®'�Cl®r�/I(Di //il ,i, '- J Adapter,Vetco-dual,11 5M FE X I, �� �11rd maw- 3 1/8 5M 5 bolt top,prepped f/ 1111 3"nom flex neck Tubing head,Vecto CWC-T, 5 3/64 centers 135/83MX115M,w/ I =� � �' r 2 2 1/16 SM SSO a Z ir'1..� —1_ 2-MC alignment pins , , Jijiiii li —`+ 1I1 IValve,Vetco,2 1/16 5M FE, 4101171111 ,z! 1 - HWO PIiii al U_ Casing spool,OCT-22-BP, ="MI. 1+ i..'.z 21'A 2M X 13 5/8 3M, gValve,OCT-20,2 1/16 5M FE, III III .1 w/2-2 1/16 5M SSO, _ - O HWO 00 bottom prep 1 M��►l� tirel".4�, 1 1-I• 1.1 1.1 1. z Casing head,OCT-22, ME `+ 21'''A2MXSOW,w/ 2-2 1/16 5M EFO al Valve,OCT 20,2 1/16 5M FE, ii j• _ jaill" i 0 HWO d. • S Anna Platform , ll Moncla BOP 01/18/2016 Ilily urp:16411.1.1A. ill Ill Iii ,ii`ii iii it . asa O' Hydril J GK 135i°-5 Y10MI, Iti fit iil lIIIii 4 Ill iII III Iii III __ _ ----- ._.. ,,... _ Variable rams _ - OW-U Or © "" _— Dual Flez rams 4.67' - MINS _ 135/8-50W ...II *__ Blind Rams Ill 1/1III III ill Choke and Kill valves 2 1/16 5M p,,.,,* eft. t I I' II III a oirmilo a 2 26' e AIN" ` Iii:iTiii Ii1. ia1--•'• , III III I!l III I!I Rise 135/8 SM FE%135/85M FE 11.00' - rtli rtfirtfi rt 1!11/1 1!1 1!1 111 Sol 2.00' 8 5M Xr 13 5/ — ' 13 5/8 5M%13 5/8 5M III III lit III III .41111 Spacer:pool III III L I I til Ill 2'75 13 5/85M FF X 115M 'i I III lit iii Iii • • C CC T C c C c o r D .0 m � z „ Z O r O70c m � ) -1: X W 0 D p 0 m < � rn 73 0D7) � 0 C o > 5 D2 -- 0 V � K -I NW � c HC r � I- - o W m0 Z o 0 z cn 1111 _D Z 0 D m m m „ n -0 b ? •• : .]Dl 0 sio- _ .m , D S c): . 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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.) • • Moncla Rig 404 BOP Test Procedure Haeor��Alaska.LACAttachment#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 15`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 15t 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 Us 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. • Moncla Rig 404 BOP Test Procedure Hacar,,Alaska,In, Attachment#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. . • 23 I -0 Cl) > > 0 Cl) To' = CD 0< § CS / \ � a \ O CO p 2 o 0 .8 § 0 » k � 0 $ oto kCl) CD / ID 0 � � >< 2 / _ k X $ 9 o § f § 0 f 2 0 2m D o O0 -, 2 0 ¢ co xi < a Cl) CD ƒ 0 . a CO C / = - c22..�Q o. CD co 2f 0 0 CD2 ( 0 , 0 co-0 % 8 2 0 C 2 - a > = o c QE 0 00ƒ \ 0 CD 3 §, 0) - co 2 /\ 13 / / O _ = 0 0 \ o Co CD C o ■ CD 20 CD a) / al ( 2 %3 41, -02 41) mm IV C * 0 Cn v COal a Z O " CD E O. e %' 7 a kk Z o ��� k rn CD / o v a_ oc \Q D D = ¥. \ �� $ ƒ & / iso CX0 IV a co ] D m 220 \ R D0, 0 / / - n o ate * J O0. ) 3 m P.- 0.� STATE OF AIL OIL AND GAS CONSERVATION ON COM ION # �w REPORT OF SUNDRY WELL OPERATIONS `,iii: 3 0 2016 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 A •• tdown CI Performed: r Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Appro a rogram ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well❑ Other: Move existing completion uphole0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 194-124 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20048-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 11 RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,469 feet Plugs measured N/A feet true vertical 9,559 feet Junk measured N/A feet Effective Depth measured 11,351 feet Packer measured N/A feet true vertical 9,567 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 629' 20" 629' 629' Intermediate 3,196' 13-3/8" 3,196' 2,976' 2,730 psi 1,130 psi Production 9,510' 9-5/8" 9,510' 8,777' 6,870 psi 4,760 psi Liner 2,112' 7" 11,469' 9,599' 8,160 psi 7,020 psi Perforation depth Measured depth 8,760-11,282 feet True Vertical depth 8,232-9,548 feet LS 2-7/8" 6.4/L-80 8,667'(MD) 8,163'(TVD) Tubing(size,grade,measured and true vertical depth) SS 2-7/8"&2-3/8" 6.4&4.6/L-80 8,665'(MD) 8,161'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): pp `EE ( 3 2 17 t,;:_1KO N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 4 40 85 80 Subsequent to operation: 0 0 0 94 0 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 Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 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: 316-049 Contact Dan Marlowe(907)283-1329 Email dmarlowe( hilcorp.com Printed Name Stan W.GolisTitle Operations Manager Signature 340.,,,.. J\\ 4 Phone (907)777-8356 Date eV 30/14, • / 6.4/./ A /yob Form 10-404 Revised 5/2015 RBDMS 1/1/ SC 1 CP - 1 2016 Submit Original Only • • Schematic Anna Platform Well No. 11 RD Hileorp Alaska,LLC Completion: 08/17/2016 Size(in) Wt(ppf) Grade Conn ID(in) Top(ft) Btm(ft) 20 85 B - 19.124 Surface 629 API#50-733-20048-01 13-3/8 54.5 J-55 - 12.615 Surface 3,196 RKB to TBG Head = 34' 9-5/8 47 L-80 BTC 8.681 Surface 9,510 7 Liner 29 L-80 BTC 6.184 9,347 11,469 Long String J I,. 2-7/8 6.4 L-80 8 RD EUE 2.441 Surf 4,396' 2-7/8 6.4 L-80 Sprmx SC 2.441 4,396' 6,547' 2-7/8 6.4 L-80 8 RD EUE 2.441 6,547' 8,667' Short String 2-7/8 6.4 L-80 8 RD EUE 2.441 Surf 6,514' 2-3/8" 4.6 L-80 Sprmx SC 1.995 6,514' 8,665' L , Ref I r MD(It) I TVD(ft) I ID(m) I OD(In) I Item , Long String 34' 34' Tubing Hanger,Vetco,Dual-Spit,CWC-FSH,11x3-1/2"IBT ( i. 1 7,042' 6,758' 2.441 3.500 XO 2-7/8"Supermax P x 2-7/8"EUE 8Rd Box 2 8,660' 8,158' 2.441 2.875 XO 2-7/8"8RD EUE X 2-7/8"Sprmx SC A 3 8,663' 8,160' - _ 5.875 2.5"Accelerated JP BHA MVSR 4 8,666' 8,162' - 2.680 Standing Valve Shoe Extension Short String A 7,070' 6,786' 1.995 3.680 X0 2-7/8"EUE X 2-3/8"Sprmx SC B 8,660' 8,158' 1.500 2.390 XO 2-3/8in Sprmx SC X 1.25in NPT Box C 8,662' 8,159' - 5.875 2.5"Accelerated JP BHA MVSR D 8,665' 8,161' - 2.680 Standing Valve Shoe Extension Zone Top(MD) Btm(MD) Top TVD Btm TVD Amt SPF Date Comments Super DP RDX 60 degree Ph CSA 8,760 8,763 8,232 8,235 3 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C5B 8,784 8,793 8,250 8,257 9 5 5/14/2015 4-1/2"Guns 2 B Super DP RDX 60 degree Ph I C6 8,850 8,885 8,299 8,325 35 5 5/14/2015 4-1/2"Guns 3 '' C Super DP RDX 60 degree Ph idli. C7A 8,998 9,004 8,406 8,411 6 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph Milks. -'J, C7B 9,185 9,216 8,542 8,564 31 5 5/14/2015 4-1/2"Guns ills4 Super DP RDX 60 degree Ph ' C7C 9,237 9,253 8,580 8,591 16 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C7D 9,343 9,361 8,656 8,669 18 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C7E 9,405 9,429 8,701 8,718 24 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8C 9,492 9,499 8,764 8,769 7 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8D 9,648 9,694 8,877 8,909 46 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8C 9,735 9,746 8,937 8,945 11 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph X XC9A 9,921 9,973 9,058 9,089 52 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph Z-- C9A 10,078 10,087 9,147 9,151 9 5 5/14/2015 4-1/2"Guns C-8 10,232 10,255 9,218 9,227 23 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-8 10,285 10,345 9,239 9,260 60 6 12/8/1994 HRS 4-5/8"Tbg.Cony. Super DP RDX 60 degree Ph C7E 10,497 10,506 9,312 9,315 9 5 5/14/2015 4-1/2"Guns C-7 10,585 10,600 9,341 9,346 15 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-7 10,665 10,750 9,367 9,393 85 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-7 10,759 10,784 9,396 9,404 25 6 12/8/1994 HRS 4-5/8"Tbg.Cony. Super DP RDX 60 degree Ph C7A 10,833 10,845 9,419 9,423 12 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C6 10,950 10,955 9,455 9,456 5 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C6 10,981 10,986 9,464 9,465 5 5 5/14/2015 4-1/2"Guns 0 C-5 11,084 11,106 9,493 9,499 22 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-5 11,119 11,156 9,503 9,513 37 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-5 11,200 11,282 9,525 9,548 82 6 12/8/1994 HRS 4-5/8"Tbg.Cony. Fish: ctAaallit 8/2016:Tubing tail 31'w/42'screen PBTD=11,351ft (9,627ft TVD) Updated:08/29/16 by JLL TD=11,469ft(9,666ft TVD) • I Hilcorp Alaska, LLC 1Hik.orpAl.«ka,LL(.: Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742#11RD Moncla 404 50-733-20048-01 194-124 8/15/2016 8/17/2016 Daily Operations:` 08/15/16-Monday Continued spotting/setting up accessory equipment and electrical. Transferred 120 BBL FIW to active pits.Mounted gas buster vent.Set up test pump and driller's side walkway steps.Quadco and Total Safety wired in their systems. NOS rep checked tubing and casing,well is static. N/D upper portion of tree and Installed BPVs.Moncla mechanic onboard servicing mud pump.Off load MV Titan spotting equipment on deck.Make up crossover spool on bottom of riser,remove tree,inspect tubing hangers and exercised lock down screws to ensure integrity.Install blanking test subs in both long and short string lift threads.Note: (Long String is on Outside of Circle!).Install riser and adapter spool assembly,mud cross,double gate BOP,and annular,and torque all connections.The double gate was orientated one bolt hole off of the dual hanger alignment pin position,to allow for double gate ram doors to open. Install off drillers side walkway on carrier.Raise and scope derrick,install all guide wires,connect derrick lights,run and install accumulator lines, change pipe rams from 2 3/8"fixed rams to 2 3/8"-3 1/2"x 2 3/8"-3 1/2"Dual VBR rams(CIW Type"U"Flex Packer),and replaced door seals.Hang rig floor and install supports,connect choke and kill lines,connect pump hose from pump to stand pipe manifold,make up 2 7/8"EUE test joints,and screw onto tubing hanger test subs.Rig up test equipment and prep to pretest BOP to 2500 PSI. AOGCC witness was waived by Mr.Regg at 9:43 hrs 8/15/16. 08/16/16-Tuesday Pretested BOPE to 250#s low 2500#high.Tested BOPE to 250#s low 2500#s high as per Sundry in accordance to AOGCC and Hilcorp requirements. Performed successful accumulator draw down test.Witness waived by Mr.Regg 9:43 8/15/16 by email.Pulled both blanked&ported subs from hanger. NOS rep pulled BPVs-fluid dropped out on both side.Installed spool on top of annular to set dual slips on.Backed out hold down pins and pulled primary seal plate from top of dual hanger.R/U Weatherford with dual elevators,slips and tongs.Make up dual 2 7/8"6.5#N-80 EUE landing jts-screwed into hanger. Fluid level shot at 1530 hrs=1,760'. Pulled dual hanger to surface at 120-140k.Rig up stabbing board,had to make a couple of adjustments to board for proper fit.Pulled tubing hangers off seat and to rig floor,140K up weight to get pipe moving travelling at 130K. Remove tubing hangers and landing joints,lay down same.Pull out of hole with 2 7/8"x 2 7/8"dual (Note:pulling dual strings simultaneously).Pulled from 10849'to 8696'filing hole with twice metal displacement.Pulled a total of 138 joints&2 pups(69 per side).Made up dual tubing hangers and landed same-up weight 95K down weight 73K,laid down landing joints,installed primary pack off seal on top of hangers and energized same. 08/17/16-Wednesday NOS technician set dual 3"CIW type"H"BPVs.Rig down Weatherford dual handling equipment.Cleared and removed rig floor.Detached guy lines, scoped down derrick,and laid over same on carrier.Nipple down BOPE.Nipple up tree,tested hanger void to 250 PSI low for 5 minutes,and 5000 PSI high for 15 minutes. Pulled BPV's and set TWC's,shell tested tree to 250 PSI low,5000 PSI high. At 15:30 hours turned well over to production. OF 7,4 • • .0* \ I%i s, THE STATE Alaska Oil and Gas ofAT JAS KA Conservation Commission - = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \Tti •• Main: 907.279.1433 ALAS�� Fax: 907.276.7542 t- ® °�� www.aogcc.alaska.gov Stan W. Golfs Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 11 RD Permit to Drill Number: 194-124 Sundry Number: 316-049 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, io26k44/-C.L._ Cathy '. Foerster Chair DATED this 2-ftica7 of January, 2016. RBDMS cit- JAN L 9 2016 • • RECEIVED STATE OF ALASKA JAN 2 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION Q7.S if 28//(L APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 1 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run new completion 2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC • Exploratory ❑ Development Li' 194-124 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service DI 6.API Number. Anchorage,AK 99503 50-733-20048-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No CI / Granite Pt St 18742 11RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 Granite Point Field/Middle Kenai 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): 11,469 9,599 _ 13,351 9,567 1,720 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 629' 20" 629' 629' Intermediate 3,196' 13-3/8" 3,196' 2,976' 2,730 psi 1,130 psi Production 9,510' 9-5/8" 9,510' 8,777' 6,870 psi 4,760 psi Liner 2,122' 7" 11,469' 9,599' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic LS 2-7/8" 6.4#/L-80 10,849' SS 2-7/8"&2-3/8" 6.4#&4.6#/L-80 10,816' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&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 L • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/15/2016 OIL L WINJ ❑ WDSPL ❑ Suspended Cl 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 thallett@hilcorp.corn Printed Namee�� Stan W.Golis Title Operations Manager Signature Phone (907)777-8356Date / ZS. ( I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ k-t- O4{q Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: X ,, Yoe, /7 y-, / - .L2 '- .�, r Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 71 Subsequent Form Required: r •- 1 0,'g RBDMS �LJAN 1 g 2016 Approved by: P3APPROVED BY(/_, COMMISSIONER THE COMMISSION Date:/- E-/ 7 I ��'I €/�' 1_2e4 Submit Form and Form 10-403 Revised 11/2015 ofiriveligA alid for 12 months from the date of approval. v Attachments in Duplicate • • Well Prognosis Well: An-11RD Hilcorp Alaska,LL Date: 01/25/2016 Well Name: Granite Point State 18742#11 rd(AN-11 rd) API Number: 50-733-20048-01 Current Status: Hydraulic Lifted Oil Producer Leg: Leg#1 -NW Corner Estimated Start Date: February 15,2016 Rig: Moncla 404 Reg.Approval Reqd? N/A Date Reg.Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 194-124 First Call Engineer: Trudi Hallett (907)777-8323(0) (907)301-6657(M) Second Call Engineer: Dan Marlowe (907)283-1329 (907)398-9904(M) Current Bottom Hole Pressure: -2,543 psi at 8,232 ft TVD 0.333 lbs/ft(6.42 ppg)based on 01/05/16 static fluid level Maximum Expected BHP: -2,543 psi at 8,232 ft TVD 0.333 lbs/ft(6.42 ppg)based on 01/05/16 static fluid level Maximum Potential Surface Pressure: 1,720 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Note: This is a no-flow Well(05/28/15) Brief Well Summary An-11 RD was worked over in 2015 lowering the pump cavity deep into the perforations. We have been unsuccessful keeping the current completion online due to solids fouling and frictional losses. This workover will re-run a larger completion string and move the pump cavity up-hole. ; LAST CASING TEST: 05/10/2015 8,716' DPM, 1500 psi for 30 minutes Procedure 1. Reverse out Jet Pump 2. Bleed well off(casing/tubing). 3. Shoot fluid levels on back side. 4. Circulate fluids down long string taking returns up short string until clean. Work over fluid 6% KCL. 5. Rig up slick line on long string and run in hole and remove standing valve. %' 6. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). ft<tlt•t,S C � 7. Circulate hydrocarbons from well to production. 8. POOH laying down completion. 9. Contingent if needed - RIH with 7" cleanout assembly to +/-11,364'. 10. PU and RIH with completion placing cavity at+/-9,200' 11. Set BPVs and test. 12. ND BOP, NU wellhead and test. 13. Turn well over to production. 14. Conduct SVS and No-Flow tests 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 • •• ' SCHEMATIC Anna Platform Well No. 11 RD Hilcorp Alaska,LLC r Completion: 05/18/2015 Size(in) Wt(ppf) Grade Conn ID(in) Top(ft) Btm(ft) API#50-733-20048-01 20 85 B - 19.124 Surface 629 13-3/8 54.5 1-55 12.615 Surface 3,196 RKB to TBG Head = 34' 9-5/8 47 L-80 BTC 8.681 Surface 9,510 7 Liner 29 L-80 BTC 6.184 9,347 11,469 Long String 2-7/8 6.4 L-80 8 RD EUE 2.441 Surf 9,193' 2-7/8 6.4 L-80 Sprmx SC 2.441 9,193' 10,811' 2-7/8 6.4 L-80 8 RD EUE 2.441 10,811' 10,849' Short String 2-7/8 6.4 L-80 8 RD EUE 2.441 Surf 9,221' 2-3/8" 4.6 L-80 Sprmx SC 1.995 9,221' 10,816' Ref I MD(ft) I TVD(ft) 1 ID(in) I OD(in) I Item Long String 34' Tubing Hanger,Vetco,Dual-SpA CWC-FSH,11x3-1/2"IBT 1 9,193' 2.441 3.500 X0 2-7/8"Supermax P x 2-7/8"EUE 8Rd Box 2 10,811' 2.441 2.875 _ XO 2-7/8"8RD EUE X 2-7/8"Sprmx SC 3 10,814' 2.441 5.875 2.5"Accelerated JP BHA MVSR 4 10,817' _ 2.441 2.680 Standing Valve Shoe Extension 5 10,849' 2.441 4.000 Ratcheting Mule Shoe Short String A _ 9,221' 1.995 3.680 _ XO 2-7/8"EUE X 2-3/8"Sprmx SC B 10,811' 1.500 _ 2.390 X0 2-3/8in Sprmx SC X 1 25in NPT Box C 10,813' 2.441 5.875 2.5"Accelerated JP BHA MVSR D 10,816' 2.441 2.680 Standing Valve Shoe Extension Zone Top(MD) Btm(MD) Top ND Btm ND Amt SPF Date Comments 0 0 Super DP RDX 60 degree Ph CSA 8,760 8,763 8,232 8,235 3 5 5/14/2015 4-1/2"Guns t Super DP RDX 60 degree Ph G p C5B 8,784 8,793 8,250 8,257 9 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph ' C6 8,850 8,885 8,299 8,325 35 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C7A 8,998 9,004 8,406 8,411 6 5 5/14/2015 4-1/2"Guns 1 /.. `' Super DP RDX 60 degree Ph X A C7B 9,185 9,216 8,542 8,564 31 5 5/14/2015 4-1/2"Guns res Super DP RDX 60 degree Ph 'w+ C7C 9,237 9,253 8,580 8,591 16 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C7D 9,343 9,361 8,656 8,669 18 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C7E 9,405 9,429 8,701 8,718 24 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8C 9,492 9,499 8,764 8,769 7 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8D 9,648 9,694 8,877 8,909 46 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph 0 C8C 9,735 9,746 8,937 8,945 11 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C9A 9,921 9,973 9,058 9,089 52 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C9A 10,078 10,087 9,147 9,151 9 5 5/14/2015 4-1/2"Guns C-8 10,232 10,255 9,218 9,227 23 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-8 10,285 10,345 9,239 9,260 60 6 12/8/1994 HRS 4-5/8"Tbg.Cony. L 2 B Super DP RDX 60 degree Ph C7E 10,497 10,506 9,312 9,315 9 5 5/14/2015 4-1/2"Guns C-7 10,585 10,600 9,341 9,346 15 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C -.'N C-7 10,665 10,750 9,367 9,393 85 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-7 10,759 10,784 9,396 9,404 25 6 12/8/1994 HRS 4-5/8"Tbg.Cony. �^'� Super DP RDX 60 degree Ph 'r^' iiMiit=slit D C7A 10,833 10,845 9,419 9,423 12 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph 11 C6 10,950 10,955 9,455 9,456 5 5 5/14/2015 4-1/2"Guns .� Super DP RDX 60 degree Ph ,....-; C6 10,981 10,986 9,464 9,465 5 5 5/14/2015 4-1/2"Guns 0 C-5 11,084 11,106 9,493 9,499 22 6 12/8/1994 HRS 4-5/8"Tbg.Cony. :n C-5 11,119 11,156 9,503 9,513 37 6 12/8/1994 FIRS 4-5/8"Tbg.Cony. «yi C-5 11,200 11,282 9,525 9,548 82 6 12/8/1994 HRS 4-5/8"Tbg.Cony. PBTD=11,351ft (9,627ft TVD) Updated:06/16/15 by JLL TD=11,469ft(9,666ft TVD) • • , tiPROPOSED Anna Platform Well No. 11 RD Hilcorp Alaska,LLC Completion: FUTURE Size(in) Wt(ppf) Grade Conn ID(in) Top(ft) Btm(ft) API#50-733-20048-01 20 85 B 19.124 Surface 629 RKB to TBG Head = 34' 13-3/8 54.5 1-55 - 12.615 Surface 3,196 9-5/8 47 L-80 BTC 8.681 Surface 9,510 7 Liner 29 L-80 BTC 6.184 9,347 11,469 Long String 3-1/2" 9.2 L-80 2.992 Surf ±9,240' Short String 3 1/2" 9.2 L-80 2.992 Surf ±9,205' Ref ] MD(ft) I TVD(ft) I ID(in) I OD(in) I Item Long String 34' Tubing Hanger 1 ±9,200' 3.5"Accelerated JP BHA MVSR 2 ±9,205' Standing Valve Shoe Extension 3 ±9,240' Ratcheting Mule Shoe Short String A ±9,200' 3.5"Accelerated JP BHA MVSR B ±9,205' Standing Valve Shoe Extension Zone Top(MD) Btm(MD) Top ND Btm TVD Amt SPF Date Comments Super DP RDX 60 degree Ph C5A 8,760 8,763 8,232 8,235 3 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph s c C5B 8,784 8,793 8,250 8,257 9 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C6 8,850 8,885 8,299 8,325 35 5 5/14/2015 4-1/2"Guns L Super DP RDX 60 degree Ph C7A 8,998 9,004 8,406 8,411 6 5 5/14/2015 4-1/2"Guns 1 A Super DP RDX 60 degree Ph IMINNI=Oli C7B 9,185 9,216 8,542 8,564 31 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph 2 mem B C7C 9,237 9,253 8,580 8,591 16 5 5/14/2015 4-1/2"Guns imit. Super DP RDX 60 degree Ph ' C7D 9,343 9,361 8,656 8,669 18 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph X C7E 9,405 9,429 8,701 8,718 24 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph 3 C8C 9,492 9,499 8,764 8,769 7 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8D 9,648 9,694 8,877 8,909 46 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8C 9,735 9,746 8,937 8,945 11 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C9A 9,921 9,973 9,058 9,089 52 5 5/14/2015 4-1/2"Guns P Super DP RDX 60 degree Ph C9A 10,078 10,087 9,147 9,151 9 5 5/14/2015 4-1/2"Guns C-8 10,232 10,255 9,218 9,227 23 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-8 10,285 10,345 9,239 9,260 60 6 12/8/1994 HRS 4-5/8"Tbg.Cony. Super DP RDX 60 degree Ph C7E 10,497 10,506 9,312 9,315 9 5 5/14/2015 4-1/2"Guns C-7 10,585 10,600 9,341 9,346 15 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-7 10,665 10,750 9,367 9,393 85 6 12/8/1994 HRS 4-5/8"Tbg.Conv. 3* C-7 10,759 10,784 9,396 9,404 25 6 12/8/1994 HRS 4-5/8"Tbg.Cony. Super DP RDX 60 degree Ph C7A 10,833 10,845 9,419 9,423 12 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph r: C6 10,950 10,955 9,455 9,456 5 S 5/14/2015 4-1/2"Guns w� Super DP RDX 60 degree Ph C6 10,981 10,986 9,464 9,465 5 5 5/14/2015 4-1/2"Guns C-5 11,084 11,106 9,493 9,499 22 6 12/8/1994 HRS 4-5/8"Tbg.Cony. C-5 11,119 11,156 9,503 9,513 37 6 12/8/1994 HRS 4-5/8"Tbg.Cony. V C-5 11,200 11,282 9,525 9,548 82 6 12/8/1994 HRS 4-5/8"Tbg.Conv. PBTD=11,351' (9,627'TVD) Updated:01/15/16 by JLL TD=11,469'(9,666'TVD) • •• Anna Platform . iiAn-11RD Current 01/18/2016 Ililrnrp Atarka,l.l.t; Anna Platform Tubing hanger,Vetco,CWC- An#11 FSCH split dual,11 X 3 Y:IBI 20X133/8 X95/8X suspx3'/2EUElift,w/3" 2 7/8 X 2 7/8 type H BPV,2-'/<control line nipples Valve,Master,OCT-20, 3 1/8 5M 5 bolt,FE,HWO Qty 2 _l0rd0 �i`jf, ," ' ,, �`.v... Adapter,Vetco-dual,11 5M FE X iii -111�l�„ 3 1/8 5M 5 bolt top,prepped f/ f11 If1 3"nom flex neck Tubing head,Vecto CWC-T, 13 5/8 3M X 11 5M,w/ .�_ �'� 5 3/64 centers 2-21/16 SM SSO ' I—.=I14 2-MC alignment pins "i .....I 111�j�.- ®"- 111 Ili Valve,Vetco,2 1/16 5M FE, HWO E' F,„„1- ,..1?-> 4 1,-,Ar:',11 i • tr,47. 111 m • t ° r' III in LL in IP i "5 Casing spool,OCT-22-BP, m"� illA is" 21'/4 2M X 13 5/8 3M, �� �: Valve,OCT-20,2 1/16 5M FE, III ® I!! w/2-2 1/16 SM SSO, - i _ - `. . ® HWO 00 bottom prep 111111 Mill 111, /1111111-1.E. III 1.1 II m.. Casing head,OCT-22, il 21%2M X SOW,w/ II i = riii , Valve,OCT-20,2 1/16 5M FE, 2-2 1/16 5M EFO - ' HWO it .i I■,' I'''r 01 ' '�I®1 r I •• Anna Platform . IIAn-11RD Proposed I18rarp:tIa.I.-1,1.1: 01/18/2016 Anna Platform Tubing hanger,Vetco,CWC- An#11 FSCH split dual,11 X 3%IBT 20 X 13 3/8 X 9 5/8 X suspx3'''AEUElift,w/3" 3 1/2 X 3 1/2 type H BPV,2-%control line nipples Valve,Master,OCT-20, 3 1/8 5M 5 bolt,FE,HWO Qty 2 ?----,_;, J tic i VG IV ,t $ Adapter,Vetco-dual, 11 5M FE X �� - �„ 3 1/8 5M 5 bolt top,prepped f/ ini 3"nom flex neck Tubing head,Vecto CWC-T, 13 5/8 3M X 11 5M,w/ ,r —� —�� 5 3/64 centers 2-21/165MSSO iiiw- _i ' 21 i 2-MC alignment pins �I I, j J1 1� I IEI Valve,Vetco,2 1/16 5M FE, F,00-'17-7111 :1 I _E.e"� _Iil $II*- III HWO N • AI I. fill ill= ',: Casing spool,OCT-22-BP, ="'� ' R. Imo - ril 21%2M X 13 5/8 3M, i[1 — Valve,OCT-20,2 1/16 5M FE, w/2-2 1/16 5M SSO, _ - lil = (,) HWO 00 bottom prep 'li( � IIi��71 'la I 1!1 '* _ 11 Casing head,OCT-22, Fp I li 21'/<2M X SOW,w/ I i i — = Irl Valve,OCT-20,2 1/16 5M FE, 2-2 1/16 5M EFO _ E. L �,� E ® HWO = Oil 40::iiilk _ f P. • Anna Platform • ll Moncla BOP 01/18/2016 Harnap tlaBkta.ii( lil III!lil!lil!Iil AM/ 454' P Iii iii I iTi 1 IIIS ILI II IL l ilt .`" _— ■ Variable rams �`=-■`I" CI® Or r y✓✓ l Flex rams 4.67' fly- Blind Rams .11 Itl 1 Viiia Choke end Kill oelvnn 21/S65M 11111"Ill'Ill'l 1'111 2.26' r Mud Cross i l i 'Y"� 1 ' N_���[I I�4 1/16 5M EF0 1 �/ _1 — �/ I LliMIMIlal 1 11111. 1 If!'III III III I I Riser 135/85M FE X135/85M FE 11.00' 1 1 III III lit I I 1�1 1111111 III 1I1 2OD' Spacer spool ` 13 5/8 5M X 13 5/8 5M Il I III ill l lit spacer sp 111 I II I II I!I I l I 2'75 13 5/85M FE/7111 5M I it lil ill lit ill o • O p O O 0 O U 0 O O U O O O O u O u U O u U 0 . o .-1 N m O Uf .---1- - N m Cl Vl l0 n CO CO 5 0+ F 2 2 2 2 2 2 f 2 V 0. 0. 0. 0. 0. 000000000 0 .-I N m V 0f 0 .i N It Cr Ol l0 N CO CO e-1 v v 0 a v c V 0 V V O 0 0 0 0 5 w 0 0 0 . .O w C L L C L U C, L L L L L L C L LL Y L j '55553 N N > J 555555 '55356 ,2 > y a 6 a n d £ C > Y Y Y Y Y Y Y Y Y Y `y J ' 0) 3 3 3 £ =. =c -8 0 0 0 0 0 0 0 0 0 o n A N� n J n n n — — U U L L L L L L L L U L J g ,71 01 n a y v 03 C m m v ° w0 O n 's H 0/ I", . 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CO . in _ co U W z z ■: ,f� Q cc Lli Q a o rn . -4, , z o COU 2U w w o h �> O UU INN \�.N, M1717 I � fir • P � � d CL 0 0Q m I— (.0 0) w l U CL ET_ 1111 0 z cn z O O ~w Z amZ D H D j All _1 CO J H ❑ a 1 Z aOi= ZQ a::W O o $ Z () y D4 N z• u-- QO � C O pg � � 25EOw ,_ J OMy rn� �N LLZ m z < 0 J o D U 1111 U- Ce M. D4 ►- U • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,IAA 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 • • Moncla Rig 404 BOP Test Procedure Hileorp%Iaeka,LL(; Attachment#1 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.) 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 ft 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 • • Moncla Rig 404 BOP Test Procedure Hacurp Alaska,1.I.0 Attachment#1 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. 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 2"d 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 • Moncla Rig 404 BOP Test Procedure Hileorp Alaska,LEAAttachment#1 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. • • = °' °r a) .>_ a: v 0 a) CL c at o a) V � oaN .L-.)• U aaa =• a) Q ....0 E E Y E I V• C N Q) a) Y > Ts Q E Q 2m+0 = a) 2Q c >, E a U 6 m i) Y CO >JO o _ 2 c L ._ a Q 0- CO ED N ,N CI a) O w .1 L. Z cC L. U) C .7 0 0 C O Z W X -C -C 0 iX 45o X 10 X o> Tli a W Q) 0 O a a) � LX o C a X °� X ca• m x 3 a as0 .° � Q as 0 i cmaa)i L a) ms d c) a ca d U c L.,-(7, to = .� 7 c v-- C 1:r -0 0, O c W U a a) 1 0 N El cow a-1 4 Q L. Io 0 a dol.' N c3 ` E 0 X 0 O 3 _� ,� Q Of X ._0) - U Q < ,o as X o ` a) u) ... G ,. Cl) 0 X ca 0 Q it itU 0 w ma 0 Tv .� ,--4 = 0 a E U o) o co 03 0_ V u) �n a 0 a a 23 0 a) OF 7� //jj- THE STATE Alaska Oil and Gas mw --sem—'a ofALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1433 OFALAS-14M. Fax 907.276 7542 v✓ww.aogcc.alaska gov June 19, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 s Ep N 2 12010 RE: No-Flow Verification Granite Point State 18742 #11 RD PTD 1941240 Dear Mr. Golis: On May 28, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Granite Point State 18742 Well #11 RD located on the Anna Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004—was rigged up on Granite Point State 18742 Anna#11 RD prior to the test. The well performance was monitored for 3 hours with resulting flow rates (oil and gas) below the regulatory limits, passing the no-flow test. A fail-safe automatic surface safety valve system 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 Granite Point State 18742 Anna #11 RD 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 Anna Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA RECEIVED AL KA OIL AND GAS CONSERVATION COL .SIGN REPORT OF SUNDRY WELL OPERATIONS SUN 1 7 2015 1.Operations Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Aoisosh tdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Togram ❑ Plug for Redd! ❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well❑ Other: Jet Pump Completion 0 2 Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 194.124 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20048-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 11 RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,469 feet Plugs measured N/A feet true vertical 9,599 feet Junk measured N/A feet Effective Depth measured 13,351 feet Packer measured N/A feet true vertical 9,567 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 629' 20" 629' 629' Intermediate 3,196' 13-3/8" 3,196' 2,976' 2,730 psi 1,130 psi Production 9,510' 9-5/8" 9,510' 8,777' 6,870 psi 4,760 psi Liner 2,122' 7" 11,469' 9,599' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet LS 2-7/8" 6.4#/L-80 10,849'(MD) 9,424'(ND) Tubing(size,grade,measured and true vertical depth) SS 2-7/8"&2-3/8" 6.4#&4.6#/L-80 10,816'(MD) 9,414'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 1 N/A SCANNED ,i.L. 9 9 ',T,Ii U11 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: 161 90 4 87 87 Subsequent to operation: 0 0 20 89 87 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 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: 315-212 Contact Trudi Hallett Email thalletthilcorp.com Printed Name Trudi Hallett Title Operations Engineer I'lltkiiSignature Phone (907)777-8323 Date 6/17/2015 RBDMS J JUN 2 5 2015 Form 10-404 Revised 5/2015 74 7`� ✓ Sf Submit Ori inal Only , ll SCHEMATIC Anna Platform Well No. 11 RD 11iitor,r Alaska,LLC Completion: 05/18/2015 Size(in) Wt(ppf) Grade Conn ID(in) Top(ft) Btm(ft) API#50-733-20048-01 20 85 B 19.124 Surface 629 13-3/8 54.5 1-55 12.615 Surface 3,196 RKB to TBG Head = 34' 9-5/8 47 L-80 BTC 8.681 Surface 9,510 i \ 7 Liner 29 L-80 BTC 6.184 9,347 11,469 Long String 2-7/8 6.4 L-80 8 RO EUE 2.441 Surf 9,193' 2-7/8 6.4 L-80 Sprmx SC 2.441 9,193' 10,811' 2-7/8 6.4 L-80 8 RD EUE 2.441 10,811' 10,849' Short String 2-7/8 6.4 L-80 8 RD EUE 2.441 Surf 9,221' 2-3/8" 4.6 L-80 Sprmx SC 1.995 9,221' 10,816' Ref MD(ft) ID(in) OD(in) Item Long String Tubing Hanger,Vetco,Dual-Spit,CWC-FSH,11x3-1/2"IBT 1 9,193' 2.441 3.500 _ XO 2-7/8"Supermax P x 2-7/8"EUE 8Rd Box 2 10,811' 2.441 2.875 XO 2-7/8"8RD EUE X 2-7/8"Sprmx SC 3 10,814' 2.441 5.875 2.5"Accelerated JP BHA MVSR 4 10,817' 2.441 2.680 _ Standing Valve Shoe Extension 5 10,849' 2.441 4.000 Ratcheting Mule Shoe Short String A 9,221' 1.995 3.680 XO 2-7/8"EUE X 2-3/8"Sprmx SC B 10,811' 1.500 2.390 XO 2-3/8in Sprmx SC X 1.25in NPT Box C 10,813 2.441 5.875 2.5"Accelerated JP BHA MVSR D 10,816' 2.441 2.680 Standing Valve Shoe Extension Zone Top(MD) Btm(MD) Top TVD Btm TVD Amt SPF Date Comments _ Super DP RDX 60 degree Ph CSA 8,760 8,763 8,232 8,235 3 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph L , CSB 8,784 _8,793 8,250 8,257 9 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C6 8,850 8,885 8,299 8,325 35 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C7A 8,998 9,004 8,406 8,411 6 5 5/14/2015 4-1/2"Guns 1 Super DP RDX 60 degree Ph A C7B 9,185 9,216 8,542 8,564 31 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C7C 9,237 9,253 8,580 8,591 16 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph X C7D 9,343 9,361 8,656 8,669 18 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C7E 9,405 _ 9,429 8,701 8,718 24 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8C 9,492 9,499 8,764 8,769 7 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph ' C8D 9,648 9,694 8,877 8,909 46 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C8C 9,735 9,746 8,937 8,945 11 5 5/14/2015 4-1/2"Guns 40 Super DP RDX 60 degree Ph C9A 9,921 9,973 9,058 9,089 52 5 5/14/2015 4-1/2"Guns M Super DP RDX 60 degree Ph C9A 10,078 10,087 9,147 9,151 9 5 5/14/2015 4-1/2"Guns C-8 10,232 10,255 9,218 9,227 23 6 12/8/1994 HRS 4-5/8"Tbg.Cony. M C-8 10,285 10,345 9,239 9,260 60 6 12/8/1994 HRS 4-5/8"Tbg.Cony. 2 B Super DP RDX 60 degree Ph C7E 10,497 10,506 9,312 9,315 9 5 5/14/2015 4-1/2"Guns C-7 10,585 10,600 9,341 9,346 15 6 12/8/1994 HRS 4-5/8"Tbg.Cony. .3 -.'. C C-7 10,665 10,750 9,367 9,393 85 6 12/8/1994 HRS 4-5/8"Tbg.Cony. 411kC-7 10,759 10,784 9,396 9,404 25 6 12/8/1994 HRS 4-5/8"Tbg.Cony. Super DP RDX 60 degree Ph ' if;. D C7A 10,833 10,845 9,419 9,423 12 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph * C6 10,950 10,955 9,455 9,456 5 5 5/14/2015 4-1/2"Guns Super DP RDX 60 degree Ph C6 10,981 10,986 9,464 _ 9,465 5 5 5/14/2015 4-1/2"Guns M C-5 11,084 11,106 9,493 9,499 22 6 12/8/1994 HRS 4-S/8"Tbg.Cony. C-5 11,119 11,156 9,503 9,513 37 6 12/8/1994 HRS 4-5/8"Tbg.Cony. ' „ . , , :.1. ' C-5 11,200 11,282 9,525 9,548 82 6 12/8/1994 HRS 4-5/8"Tbg.Cony. PBTD=l 1,351ft (9,627ft TVD) Updated:06/16/15 by JLL TD=11,469ft(9,666ft TVD) Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742 #11RD 50-733-20048-01 194-124 5/4/15 5/18/15 Daily Operations: 05/04/15- Monday R/U TO CIRCULATE DOWN LONG STRING AND TAKE RETURNS ON ANNULUS. PUMPED 310 BBLS BEFORE GETTING RETURNS. CONTINUE CIRCULATING OUT OIL AND GAS SENDING RETURNS TO PRODUCTION. GOT BACK APPROX. 150 BBLS OF OIL. PUMPED TOTAL 750 BBLS. MIXED AT 3% KCL 8.5 WT MONITOR WELL. WELL STATIC. DISCONNECT FLOWLINES. REMOVE PRODUCTION EQUIPMENT OFF TREE. REMOVE FLOOR PLATES AND H-BEAM. INSTALL HANDRAIL. SET BPV'S. N/D TREE. N/U RISER. N/U BOPS AND TORQUE SAME. INSTALL H- BEAM AND FLOOR PLATES. CHANGE OUT DUAL RAMS TO VARIABLE RAMS. R/U SCAFFOLDING AROUND BOPS. M/U TEST JOINT AND FILL STACK .TEST BOPE ACCORDING TO SUNDRY, HILCORP AND AOGCC PROCEDURES AND GUIDELINES. FIX LEAK ON RAM DOOR AND HANGER PINS. LEAKING BY HANGER DECIDED TO DO ROLLING TEST. TEST CHOKE MANIFOLD PRIOR TO ROLLING TEST. R/U BELL NIPPLE WHILE TEST MANIFOLD. 05/05/15-Tuesday AOGCC WITNESS WAIVED BY JIM REGG SATURDAY MAY 02 2015 @ 11:12 FOR INITIAL BOP TEST. CONTINUE PRETESTING CHOKE MANIFOLD WHILE WAITING ON AOGCC APPROVAL FOR ROLLING TEST DUE TO HANGER LEAKING. APPROVED AND WAIVED BY JIM REGG WITH AOGCC ON MAY 05 2015 @ 10:26 AM FOR ROLLING TEST. TEST ANNULAR, PIPE RAMS, HCRS AND MANUAL VALVES LOW 250 AND HIGH 3000 PSI. PERFORMED ACCUMULATOR TEST, PULL TEST JOINT AND REMOVE BPV FROM SHORT STRING. INSTALL 2-WAY CHECK.TEST BLINDS LOW 250 HIGH 3000 PSI ALL ON CHART 5 MIN EACH. R/D TEST JOINTS. M/U 3-1/2" SAFETY VALVE AND I.B.O.P. TEST LOW 250 HIGH 3000 PSI. REMOVE FLOOR PLATES AND H- BEAM. INSTALL POLLUTION PAN, H BEAM AND FLOOR PLATES. R/U FOSTER TONGS. PULL BLANKING SUB AND BPV OUT OF LONG STRING. CUT 2'TARGET NIPPLE FOR BELL NIPPLE. M/U LANDING JOINT, SAFETY VALVE, SIDE DOOR SUB. BOWEN CONNECTION TO SHORT STRING SIDE. R/U ELINE. PRESSURE TEST LUBICATOR TO 1500 PSI, GOOD TEST. BLEED OFF PRESSURE AND TIH WITH 1-13/16" SPECTRA JET CUTTER TO 9,166'. TAG RIGHT AT XOVER 3-1/2" X 2-3/8" WORK STRING THRU. CUT SHORT STRING @ 9,181' ELM. NO INDICATION OF CUT, POOH. OOH WITH CUTTER. SHOWS CUT WAS MADE. RIG ELINE TO SIDE AND P/U SHORT STRING TO 140K TWICE. WEIGHT FELL OVER TO 124K. PULL HGR TO SURFACE AND CONTINUE R/D ELINE. POOH WITH SHORT STRING, 3-1/2" 9.2# L-80 BUTTRESS TUBING. 4,384' LAID DOWN AT 06:00. 05/06/15 -Wednesday CONTINUE POOH WITH SHORT STRING 3-1/2" L-80 9.2#TUBING. OOH WITH TUBING, 286 JOINTS AND 1-8' 2-3/8" CUT PIECE W/X-OVER. M/U LANDING JOINT INTO HANGER ON LONG STRING SIDE. P/U, THREADS PULLED OUT OF CONNECTION. M/U INTO HANGER MADE UP 5-1/2" ROUNDS. R/U ELINE AND TEST LUBRICATOR TO 1500 PSI. TIH WITH V1-11/16" 10 SHOT TUBING PUNCH, SAT DOWN @ 9,214' P/U AND FIRE PERF GUN @ 9,153' POOH. TIH WITH 2.50 rct TO 9,155' FIRE CUTTER POOH. P/U 3-1/2 PH-6 AND M/U SPEAR AND SPEAR TUBING STING BELOW HANGER. P/U TUBING AT 100K, PULL HANGER TO FLOOR AND RELEASE SPEAR AND POOH 9 JOINTS OF LONG STRING. M/U XOVER, KELLY VALVE, XOVER TO 3-1/2 BUTTRESS LONG STRING, M/U TEST PLUG ON LANDING JOINT AND LAND TUBING ON TEST PLUG, FILL HOLE AND TRY TO TEST, NO GOOD. PULL TEST PLUG, CHANGED 0 RING AND LAND SAME. FILL STACK AND CLOSE ANNULAR AND TRY TO TEST. ANNULAR LEAKING, WORK ANNULAR SEVERAL TIMES NO GOOD. CLOSE PIPE RAMS, GOOD TEST. (NOTE AOGCC WITNESS WAIVED BY JIM REGG MAY-6- 2015 @11.29 AM). PULL LANDING JOINT AND REMOVE FLOOR AND H-BEAM TO CHANGE OUT ANNULAR RUBBER. HAVING ISSUES TRYING TO BREAK TOP CAP OFF ANNULAR. Hilcorp Alaska, LLC • Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742 #11RD 50-733-20048-01 194-124 5/4/15 5/18/15 Daily Operations: 05/07/15-Thursday Attempt to test pipe rams, test plug leaking, pull test plug to floor and install new seal. Lower and land test plug, attempt to retest, no good. Pull test plug to floor and 1/d. Housekeeping while waiting on storm packer. M/u 9-5/8" 47#storm packer to 3-1/2" buttress completion tubing. Tih 120' set packer and test to 1500 psi for 30 mins, good test. M/u 3-1/2" test joint and land same. Test BOPE as per Hilcorp &AOGCC regulations, witness was waived by Jim Regg on 5-6-15 @ 11:19.Test 250 low, 3000 high, tested choke manifold valves, mud cross valves, safety valves, pipe rams, blinds all good, Annular failed. L/D test joint and p/u potato masher and try to break annular top cap, No Go. R/d floor and n/d annular and n/u new 13-5/8" annular. Install bell nipple, flow line, drip pan &floor plates. M/u 2 7/8" test joint, fill stack. Test pipe rams t/250 low, 3000 high, annular 250 low, 2500 high, all good. L/d TJ. M/u running tool f/storm packer, rih & m/u t/ packer @ 120', pull packer t/floor& I/d. 05/08/15- Friday Continue pooh. L/d Long String, 3-1/2" 9.2# Buttress tubing. L/d 271 jts, 286 jt's total &cut jt 14.98. M/u BHA#1. 7" O.D. Overshot dressed for 3-1/2", bumper jar, oil jar, 6-4-3/4" drill collars, acc jars, x-over= 224.08'TIH to 1,947'. Continue TIH with 7" O.D. Overshot dressed for 3.5". t/9,093' up wt 140k- 160k,dn wt 80k- 102k dragging in/out hole. RIH, Tag tof @ 9,205' latch fish p/u to 185k. Fish is free, continue pooh, dragging. L/D BHA& Kobe assy. 05/09/15 -Saturday Service equipment and change out air hoist cable. Continue pooh I/d 32 jts 2 7/8 tubing, 39 jts 4 5/8 guns, & 3 3/8 spacer guns. Install wear bushing and r/u e-line. TIH with CBL 10,135' WLM, tag, try to work through, no good. Continue logging up, 8,075' -9,320' appears good cmt. 10,000' - 10,135' appears good cmt. R/D eline. M/u BHA#2 9-5/8" cleanout assy: 8- 1/2" bit, 9-5/8" Csg Scraper, Bit Sub, Bumper& Oil Jars, x-over to 3-1/2" PH-6 = 31.80'. TIH to 5,513'. up wt 98, dn wt 80. 05/10/15-Sunday Continue TIH with 9-5/8" C/o assy to 9,334' DPM & work scraper. Pooh with 9-5/8" C/O assy. L/D bha. M/u 9-5/8" test packer and TIH to 8,716' 160k p/u, 92k s/o. Set packer with 20k down. Fill annulus 232 bbls to fill. Test 9-5/8" casing to 1500 psi for 30 mins, charted, Good Test. Pooh with test packer& I/d. M/u BHA#4 7" C/O assy: 6" bit, 7" CSG Scraper, Bit Sub, Bumper/Oil Jars, x-over= 30.52 tih to 527'. 05/11/15 - Monday Cont. TIH, p/u singles t/3,095' up wt 60, dn wt 55. Service rig, cut & slip drill line 120', change DW oil. Cont. TIH saw light bobble at liner top, cont t/tag @11,364' up wt 178k, dn wt 100k. R/U POOH I/d 34 singles t/10,287'. Right angle box chain came apart, unable to repair. Moncla has parts coming from Portland, should arrive 1500 hrs on 5/12/15 t/ Anchorage. Clean rig and platform. 05/12/15-Tuesday Housekeeping & rig maintenance while waiting on parts. Continue cleaning rig and upper& lower decks. Parts arrived. Install new Drive chain &covers. Continue pooh I/D singles t/8,862'. Rih w/stands in derrick t/ to 10,536.13' up wt 175, dn wt 92. • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742#11RD 50-733-20048-01 194-124 5/4/15 5/18/15 Daily Operations: 05/13/15-Wednesday 111k p/u weight, 95k s/o weight. Pooh and 1/d 135 joints of 3-1/2" PH-6. Continue stand back 142 stands. L/D 7" c/o BHA. Clean & clear floor. C/o handling eq. t/p/u TCP guns. M/u safety jt. P/U 4.5" TCP gun assembly= 4.5 bull plug, TCP guns, 4.5 safety spacer, safety mech. firing head, 2 7/8 EUE pup, 2 7/8, tubing jt, ported debris sub, xo, 2-jts 3 1/2 PH6, Radioactive sub = 2332.27' up-dn wt 56k. RIH w/3 stands 4 3/4" drill collars. POOH 1/d same. PJSM for p/u TCP guns and shackles with both crews. 05/14/15-Thursday TIH w/4.5" TCP guns on 3 1/2" PH-6 wk string t/11,049', p/u t/ 11,019', up wt 184, dn wt 98. R/U e-line. Rih w/1 11/16" GR/CCL, log up f/8,750' send log to town for evaluation. Move assembly up 10'. Rih w/GR/CCL log to verify on depth. Pooh and r/d eline. Drop bar, guns fired 2mins 10 sec from dropping bar. Top Shot 8,760' and bottom at 10,986' Good indication at surface, guns fired. Monitor well, no pressure or vacuum noticed. Pooh in stands to above TOL. 33 stands. End of guns 9,047'. Shut in well and monitor while servicing rig. Well Static. POOH 1/d 218 jts 3 1/2 PH-6 wk string. C/o handling eq. M/u safety jt. L/d 4.5" TCP guns. L/D 3 guns all shots fired. Perforated depths w/SUPER DP RDX, 5 spf, 60deg phasing, .42 entry, 59" penetrating, 4 1/2" guns- 8,760-8,763/8,784-8,793/8,850-8,885/8,998-9,004/9,185-9,216/ 9,237-9,253/9,343-9,361/9,405-9,429/9,492-9,499/9,648-9,694/9,735-9,746/9,921-9,973/ 10,078-10,087/ 10,497-10,506/ 10,833-10,845/ 10,950-10,955/ 10,981-10,986. 05/15/15- Friday Cont. POOH 1/d 2,166'4.5"TCP guns, all fired. L/d handling eq. TIH w/33 stands 3 1/2" PH-6 wk string t/2,063'. POOH L/d 66 joints of 3-1/2" PH-6 workstring. C/O variable rams to dual variable rams. M/u test plug to dual test fixture and land same. Test BOPE as per Hilcorp &AOGCC regulations, witness was waived by Jim Regg on 5-13-15 @ 13:08. Tested w/2 3/8 & 2 7/8" TJ's. Test 250 low, 3000 high, test annular 250 low 2500 high, all good. R/D test jt, clear floor. 05/16/15 -Saturday R/U dual handling eq. Had some gas at annulus valve, pumped 190 bbls 3% kcl. Monitor well f/30 min,good. M/U "Accelerated MVSR- Parallel BHA Hilcorp special" pump cavity& pup's.TIH w/4.6# L-80 2 3/8" sprmx, SC collars short string/ 6.4# L-80 2 7/8 sprmx, SC collars long string, dual completion. M/u xovers on long string 2-7/8" Supermax Pin x 2- 7/8" EUE box(@ 1,658'), short string 2-3/8" Supermax pin x 2-7/8" EUE box(@ 1,594'). Continue tih with 2-7/8" EUE Dual Completion. 6,258' @ 0600. 05/17/15 -Sunday Continue tih f/6,258' with 2-7/8" 8rd L-80 6.4#8rd Dual Completion t/10,814', up wt 184, dn wt 98. Even out strings putting 12k extra tension in long string. M/U Vetco CWC-FSCH split hanger& landing jts. Flush surface eq. &stack w/drill water. Blow down lines. Land hanger placing tubing tail @ 10,851' & pump cavity @ 10,816'. L/d landing jts, M/u 1.5 CS dual tbg into Tbg hanger. Pack off land same and lock down. L/d 1.5 CS and install 3" Type "H" BPV in dual hangers. R/d Weatherford dual equipment and load out same. R/d rig floor, H-Beam &drip pan. Install hand rails and n/d bell nipple, BOPE, mud cross and riser. • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742 #11RD 50-733-20048-01 194-124 5/4/15 5/18/15 Daily Operations: 05/18/15 - Monday N/U tree, test void 500 low & 5000 high f/30 min good. Pulled BPV set TWC.Tested tree 250 low 5000 high w/no visual leaks,good. Pull TWC, turn well over t/ production. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 17,. q X61 15 DATE: 5/28/15 P. I. Supervisor l t I FROM: Johnnie Hill SUBJECT: No Flow Test Petroleum Inspector Granite Pt State 18742 Anna #11 RD Hilcorp Alaska LLC PTD 1941240 - 5/28/2015: I traveled to Granite Point Field Anna Platform (Cook Inlet) to witness a no- flow test of Well #11 RD. This well is a jet pump completion (recently worked over to replace the failed jet pump completion). The jet pump operates with power fluid down - the short string tubing and produces up the long string. Test was rigged up as follows: Tubing-Casing Annulus: 2-inch ball valve; tie-in "tee" for tubing; camlock-style quick connect reducing line from 2-inch by 3/4-inch; calibrated pressure gauge; calibrated no-flow meter. Tubing (Long string): Line coming off long string was 3/8-inch diameter with gauge and quarter turn valve, tied in upstream of the calibrated 0-30psi pressure gauge. Outlet from the no-flow meter was rigged to an open top drum. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 11:00 a.m 0/0/420 - 0 0 start with valve closed 11:30 0.5/0/420 - 0 0 shut in 12:00 0.75/0/420 1800 0 opened pn -it took 5min to bleed opened -it 1.75/0/420 500 0 down to 500 scf/hr 13:00 0.5/0/420 - 300 - 0 opened/some gas 13:30 0.2/0/420 250-300 0 opened/some gas 14:00 0/0/420 250-300 - 0 - opened no fuild/some gas 1 Pressures are T/IA/OA Summary: Everything went very well on the no flow. 5 LIED JUL 0 2 2015 Attachments: none 2015-0528 No-Flow GranitePt State 18742 Anna-II RD J'h.docx _ _ Page 1 of I Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, May 11, 2015 1:20 PM To: 'Daniel Taylor' Subject: RE:An-11RD RWO (PTD 194-124) Thanks for the copy... you are good to go ahead and perf. Nice to see the cement there. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Daniel Taylor [mailto:dtavlor@hilcorp.com] Sent: Monday, May 11, 2015 1:18 PM To: Schwartz, Guy L(DOA) Cc: Trudi Hallett %AHMED MAY' 2 2 2015 Subject: RE: An-11RD RWO (PTD 194-124) Guy, Please see the attached CBL for An-11RD. Our TOC was found at -8,075ft. We will not need to perform a cement squeeze before our perforations (Top Perf at 8,760ft MD). Please let me know your thoughts. Thank you. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, April 29, 2015 2:52 PM To: Daniel Taylor Subject: RE: An-11RD RWO (PTD 194-124) Give me a call Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 1 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Daniel Taylor [mailto:dtaylor@hilcorp.com] Sent: Wednesday, April 29, 2015 2:37 PM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T(DOA) Subject: RE: An-11RD RWO (PTD 194-124) Guy, Welcome back sir. I wanted to follow up with you on the Sundry for An-11RD. We are planning on running a CBL on this well within the 9- 5/8in casing. Once we establish where the TOC is located we will provide you with the plan forward. That plan may include removing the additional perforations or a block squeeze cement job should you approve. Thank you sir. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Daniel Taylor Sent: Friday, April 24, 2015 10:38 AM To: 'Ferguson, Victoria L(DOA)' Cc: 'Schwartz, Guy L(DOA)' Subject: FW: An-11RD RWO (PTD 194-124) Victoria, Mr.Schwartz had some question regarding our procedure. I answered them below. Please let me know if there is anything else you need. Thank you. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Daniel Taylor Sent: Friday, April 24, 2015 10:27 AM 2 . To: 'Schwartz, Guy L(DOA)' Subject: RE: An-11RD RWO (PTD 194-124) Guy, This casing will need to be tested as it has not been since it was set in November of 1994(4,800psi for 30min). We are also planning on running a CBL as this well does not have one on file. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, April 22, 2015 3:04 PM To: Daniel Taylor Subject: An-11RD RWO (PTD 194-124) Dan, Looking at RWO for Jet pump install. When was the casing on this well tested last? Also please verify TOC in the 9 5/8" casing. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 3 11.- - I I , ■I I { ...„: j ..... 8000 }1 I mil Tim 1- •1 _i- ti} 1 r f 41 . t --F-- ■ -I- :. 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Grt fie P+ e ►1674z-ti(,R- 'r . 194 IzAo Regg, James B (DOA) From: Terry Lopez - (C) <tlopez@hilcorp.com> Sent: Tuesday, May 05, 2015 5:02 PM � 716 To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Juanita Lovett; Trudi Hallett Subject: Rolling bop test results momcla 301 Granite PT 18742 #11RD (PTD 194-1240) Attachments: ROLLING TEST 5-5-15.pdf; 10-424 RIG 301 5-5-15.xlsx SCANNED .JUN 0 8 2015 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 4411(4 BOPE Test Report Submit to: jim.reqqalaska.qov AOGCC.Inspectorsalaska qov phoebe.brooks(a�alaska.qov Contractor. Moncla Rig No.: 301 DATE: 5/5/15 - Rig Rep.: Jerry Guidry Rig Phone: 776-6754 Operator: Hilcorp Op. Phone: 776-6751 Rep.: Terry Lopez E-Mail tlopez@hilcorp.com Well Name: Granite PT18742#11 RD - PTD# 1941240 . Sundry# 315-212 - Operation. Drilling: Workover: x Explor.: Test: Initial. x Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3000 - Annular: 250/3000 - Valves: 250/3000 MASP: 1545 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 1 P • PTD On Location P . Hazard Sec. NA Ball Type 1 P - Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" P • Pit Level Indicators P • P _ #1 Rams 1 2 7/8x5"var P - Flow Indicator P P - #2 Rams 1 Blind • P - Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln Valves 1 3 1/8 P Inside Reel valves 0 NA HCR Valves 2 - 3 1/8 P Kill Line Valves 2 ' 3 1/8 2 1/16 P - Check Valve 0 _ NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 P . CHOKE MANIFOLD: Pressure After Closure(psi) 1950 P . Quantity Test Result 200 psi Attained(sec) 29 P - No.Valves 11 . P . Full Pressure Attained(sec) 133 _ P Manual Chokes 1 • P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 . P Nitgn Bottles Avg. (#and psi): 4@2250 P - CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time 5.0 ' Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska gov Remarks: Performed rolling test on bop's due to split hanger leaking,tested annular while pumping@1/4 bblper/min .2900psi,pipe rams pumping @ 1/4bbl/min 3000 psi, blind rams pumping 1/4bbl per/min 3000 psi.pumped through bpv to hold enough back pressure,due to both strings on vaccum.tested gas system AOGCC Inspection 24 hr Notice No Date/Time 5/5/15 6am _ Waived By Jim Regg Test Start Date/Time: 5/5/2015 10.30am (date) (time) Witness Test Finish Date/Time. 5/5/2015 15:30 Form 10-424(Revised 06/2014) 10-424 RIG 301 5-5-15.xlsx • . f A / / / -- f - v0 0'0 ' 7 / / N\\ �' _r- 3500 `• / / 5°° i_ -— _ ' \00 \ • \ \ 0 o\ /; 2° - \ /500 0 . / \. .00 -,. ,N\ - \ . . . • O °° ,'- _kill , 500 . p , ,.. / ///// ` ,• 1 p ' 1 . \ , \' ,310' \ . . ‘ \. \ 1 1Ap aSpOo �! 1 '' 1_, / thr'-' V\C)..r ' •• . >' -- \ \ \ \ \ 0 - R�• � G , \ ,o ooo , N . I 0 L._ - � 1 1 O PSE `* . � o . 0 0o u .1 - . _i- fl O OU A , \,,,,,PL 014 IA 4 0181414. p ^r ; i 1, ` 04'9'1G�►0�PM• 1 ,00 \ . \ V).5 / . y 1 \ --__ . / I ' / / ' p oos ,l i .63."\: E Z / 4v 0. , �; / O°�\ j ' ' / : - �\� 00 �/ •/ `UI .\\ 141111141Wkw 0,0 ' • : : .._:_..--- '2-' \ //// ____i----1--- , ./r. pO \ SS\ - ' /\/oo z //OOOb � ----. --- ` Cw/ , - " OQ / / �b Y / -i 't — - / /i L__ • ti OF Tiff, �w\���I�j, s THE STATE Alaska Oil and Gas �,;,s-.AZ, of Conservation Commission - == ALASI�;A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 A907.279 1433 LASY'� p U LQ�� MFax. 907.276 7542 CA�+� a1ain:5 www.aogcc alaska.gov Dan Taylor I a'4- Operations Engineer 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Pt Field, Middle Kenai Oil Pool, Granite Pt St 18742 11 RD Sundry Number: 315-212 Dear Mr. Taylor: 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, Cat y P Foerster �� Chair �7- DATED this ' day of April, 2015 Encl. RECEIVED STATE OF ALASKA APR 0 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION CIS `-)2,61.i t-S APPLICATION FOR SUNDRY APPROVALS AOGCC 2Q MC 25.280 1.Type of Request: Abandor❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ i...t Perforate 0 Pull Tubing 0 Time Extension❑ Operations Shutdowr❑ Re-enter Susp.Well ❑ Stimulate El Alter Casing❑ Other Jet Pump Completion CI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory El Development 0 194-124 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service F] 6.API Number: Anchorage,AK 99503 50-733-20048-01 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 76- ,Q 0, r_ Will planned perforations require a spacing exception? Yes ❑ No El Granite Pt St 18742 11RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 Granite Pt Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,469 9,599 11,351 9,567 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 629' 20" 629' 629' Intermediate 3,196' 13-3/8" 3,196' 2,976' 2,730 psi 1,130 psi Production 9,510' 9-5/8" 9,510' 8,777' 6,870 psi 4,760 psi Liner 2,122' 7" 11,469' 9,599' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2"Dual 9.2#/L-80 LS 10,246'/SS 9,175' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development CI Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/20/2015 Commencing Operations: Oil El Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR Cl SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor(cr�.hilcorp.com Printed Name t�Da�n Taylor Title L� Title Operations Engineer itt- Signature /ILL !�Irt ' Phone (907)777-8319 Date 4/8/2015 -f-ioY Dan TGA,J C C'r COMMISSION USE ONLY Conditions of approval: Notify Com ssion so that a representative may witness Sundry Number: 3\5- 212 Plug Integrity ❑ BOP Test l Mechanical Integrity Test ❑ Location Clearance ❑ Other: 360U r Set' % 'f ( hlA3i - i -' 1SS p5 k I o r-1 - ._.1._p-s+ re-b""',e,� Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /0 ._41 c1-4 APPROVED BY A Approved by: COMMISSIONER THE COMMISSION Date: - -30--7.5" 14, 1_, R I NVAL u d jai Form 10-403(Re ed 10/2012) A e o12 months from the date of approval. RBDM AttachmeAPRnts in Duplicate Well Prognosis Well: An-11RD Hilcarp Alaska,Lb Date:04/8/15 Well Name: GRANITE PT ST 18742#11 RD API Number: 50-733-20048-01 Current Status: Oil Producer Leg: _ 1 Estimated Start Date: April 20, 2015 Rig: Moncla 301 Reg.Approval Reqd? N/A Date Reg.Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 194-124 First Call Engineer: Dan Taylor (907) 777-8319(0) (907)947-8051 (M) Second Call Engineer: Reid Edwards (907) 777-8421 (0) AFE Number: Current Bottom Hole Pressure: —2,040 psi at 9,240ft TVD Based on surrounding well data. Maximum Expected BHP: —2,330 psi at 7,842ft TVD Based on surrounding well data. orjz Max.Allowable Surface Pressure: -- 1,545 psi Based on 0.1 psi/ft gradient to 7,842ft TVD. Brief Well Summary An-11 RD was completed in the Tyonek C sands in 1994 as an oil producer. The well is currently on line producing 134bopd and 10bwpd. The below procedure outlines pulling the current completion with hanging TCP guns,cleaning out to PBTD, perforating upper C sands and running back in hole with a dual string jet pump completion. Procedure 1. Reverse out Jet Pump 2. Bleed well off(casing/tubing). 3. Shoot fluid levels on back side. 4. Circulate FIW down long string taking returns up short string until clean. a. Work over fluid 3% KCL. 5. Rig up slick line on long string and run in hole and remove standing valve. 6. Run in hole on long string with 2in bailer to tag and pull sample. 7. Ensure well is dead. 8. Set BPV. 9. Nipple down tree/Nipple up BOPE. a. Function test BOPE (notify AOGCC of test 48hrs prior to expected test). 10. Test BOPE: a. Test BOPE 250psi low and 3,000psi high and chart. 11. Remove BPVs. 12. Rig up e-line on short string. p >- a. Run in hole with cutter making cut above BHA. ;(� 13. Unseat short string hanger and POOH with short string to cut. 14. Pull out of hole with long string and hanging TCP guns. 15. Pick up and run in hole with clean out assembly cleaning out to PBTD. �� t-" 16. Pick up and run in hole with tubing conveyed perforating guns spacing out over the following intervals: it 77. / 7 Well Prognosis Well: An-11RD Hilcorp Alaska,LL Date:04/8/15 Zone TopMD BtmMD - TopTVD:" BtmTVD - Mit SPF - Date T C5A 8,760 8,763 8,232 8,235 3 5 Future C5B 8,784 8,793 8,250 8,257 9 5 Future C6 8,850 8,885 8,299 8,325 35 5 Future C7A 8,998 9,004 8,406 8,411 ' 6 5 Future C7B 9,185 9,216 8,542 8,564 31 5 Future C7C 9,237 9,253 8,580 8,591 _ 16 5 Future e C7D 9,343 9,361 8,656 8,669 18 5 Future ./(.:,/ C7E 9,405 9,429 8,701 8,718 24 5 Future C8C 9,492 9,499 8,764 8,769 _ 7 5 Future e' C8D 9,648 9,694 8,877 8,909 46 5 Future C8C 9,735 9,746 8,937 8,945 11 5 Future C9A 9,921 9,973 9,058 9,089 52 5 Future C9A 10,078 10,087 9,147 9,151 9 5 Future C7E 10,497 10,506 9,312 9,315 9 5 Future C7A 10,833 10,845 9,419 9,423 12 5 Future C6 10,950 10,955 9,455 9,456 _ 5 5 Future C6 10,981 10,986 9,464 9,465 5 5 Future 17. Pick up and run in hole with ratcheting mule shoe,XN nipple,jet pump BHA, and dual strings setting BHA at+/- 10,800ft MD. 18. Land hanger. 19. Set BPVs and test. 20. Nipple down BOP, nipple up tree and test. 21. Turn well over to production. 22. Complete'No Flow'test in accordance with AOGCC regulations(20 AAC 25.265.Well safety valve systems, section.h). -- Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram (same) 4. BOP Stack Anna Platform Well No. 11RD UNOCALe Actual Completion 12/8/94 CASING AND TUBING DETAIL API #50-733-20048-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head = 51.45' 20" 85# B - 19.124" Surface 629' 13-3/8" 54.5# J-55 - 12.615" Surface 3,196' 17 A 9-5/8" 47# L-80 Buttress 8.681" Surface 9,510' 2 B 7"Liner 29# L-80 Buttress 6.184" 9,347' 11,469' TUBING PBTD 11,351' Long String 3-1/2" 9.2# L-80 Buttress 2.992" 59' 10,246' Short String 3-1/2" 9.2# L-80 Buttress 2.992" 61' 9,175' JEWELRY DETAIL NO. Depth ID OD Item 51' Tubing Hanger,Vetco Gray CWC-FD 3-1/2" Dual 1 52' 2.992 3.500 Pup,3-1/2"Buttress x 1.5' 2 53' 2.992 3.500 Pup,3-1/2"Buttress x 6' 3 9,171' 2.992 3.500 Pup,3-1/2"Buttress x 6' 4 9,178' 2.992 3,500 Pup,3-1/2"Buttress x 6' 5 9,184' 2.687 7.250 Kobe,3" `Double D' Cavity 6 9,213' 3.000 4.250 X-Over,3-1/2"8rd EUE x 3-1/2"Buttress 7 9,214' 2.992 3.500 Ported Sub-3-1/2"x 2' 8 9,216' 2.992 3.500 Pup,3-1/2"8rd EUE x 10' 9 9,226' 0 4.500 Blank Sub X-over,3-1/2"8rd x 2-7/8"8rd 10 9,227' 2.375 4.688 Pressure Transfer Sub 11 9,228' 2.441 3.125 X-over,2-7/8"8rd x 2-7/8"BTC L , 12 9,228' 2.441 2.875 32 Jts.2-7/8" 6.4#,L-80,BTC Tubing 13 10,246 2.441 3.500 X-over,2-7/8"BTC x 2-7/8"8rd /1 '1/' V 14 10,247 2.630 4.750 Pressure Transfer Sub 3 C 15 10,247 0 3.38 Mod K-II Firing Head 16 10,249 0 3.700 APF-C Firing Head 4 D 17 10,253 0 4.625 HRS 4-5/8 6spf 32 Gram RDX Perf Guns 18 11,308 0 4.625 Bull plug -I. 5 SHORT STRING ... A 52' 2.992 3.500 Pup,3-1/2"Buttress x 1.5' 6 B 53' 2.992 3.500 Pup,3-1/2"Buttress x 8' 7 0 0 Note:St.Valve stuck C 9,175' ? ? X-over,3-1/2"Buttress x 2-3/8" Buttress in BHA.Debris in St. D 9,176' 1.995 2.375 Pup,2-3/8"4.6#L-80 Buttress x 10' 8 Valve. Pump seat 9 fluid washed-must PERFORATION HISTORY 10 use special bottom 11 plug on jet pump Interval Accum. Date Zone Top Btm Mit spf Comments 12 12/8/1994 C-8 10,232' 10,255' 23' 6 HRS 4-5/8"Tbg.Cony. I 1312/8/1994 C-8 10,285' 10,345' 60' 6 HRS 4-5/8"Tbg. Cony. 14 � 12/8/1994 C-7 10,585' 10,600' 15' 6 HRS 4-5/8"Tbg. Cony. 15 16 12/8/1994 C-7 10,665' 10,750' 85' 6 HRS 4-5/8"Tbg.Cony. 12/8/1994 C-7 10,759' 10,784' 25' 6 HRS 4-5/8"Tbg.Cony. 17 12/8/1994 C-5 11,084' 11,106' 22' 6 HRS 4-5/8"Tbg.Cony. 12/8/1994 C-5 11,119' 11,156' 37' 6 HRS 4-5/8"Tbg.Cony. - 18 12/8/1994 C-5 11,200' 11,282' 82' 6 HRS 4-5/8"Tbg.Cony. PBTD=11,351' MD (9,627'TVD) TD=11,469'MD(9,666'TVD) O:\Alaska\Fields\Granite Point\Anna\Wells\An-11RD\Schematics\An-11RD Schematic.doc DRAWN BY:bga 7/20/0 Haterity Anna Platform Proposed��«+bb p Well No. 11 RD tl: Anna Platform ., fli An-11 RD Current 03/16/2015 Hiliorp %Iarkn.I.1.(. Anna Platform Tubing hanger,Vetco,CWC- An#11 FSCH split dual,11 X 3%2 IBT 20 X 13 3/8 X 9 5/8 X susp x 3.725 MCA lift,w/3" 3'/X 3'/z type H BPV,2-'/4 control line nipples Valve,Master,Vetco, 3 1/8 5M 5 bolt,FE,HWO Qty 2 ati0 1 00�0. :ec,100017iii� %o ,c`0 0Y Adapter,Vetco-dual,11 5M FE X L1 3 1/8 5M 5 bolt top,prepped f/ III 111111111111 III 3"nom flex neck Tubing head,Vecto CWC-T, 5 3/64 centers 135 83MX115M,w/ r nis 2-2 1/16 5M SSO i—a_ •— 2-MC alignment pins .171— ( 1 III I = _ + III - 41I Valve,Vetco,2 1/16 5M FE, I :� > �� HWO I-- ,• -O AI • '.��� •O 11 i s�-�.:, ISI �• •1%I 11111 PP Casing spool,OCT-22-BP, "-il 11111 7 Im-- 21%2M X 13 5/8 3M, II Ill Valve,OCT-20,2 1/16 5M FE, w/2-2 1/16 5M SSO, - 0 a. _ HWO 00 bottom prep ' j - ...4c;1111 r;►. I 11111 '11— o 111 �1.I`' IIIIII •.,.- . . ___, , . Casing head,OCT-22, I' 11 Iii 21'/<2M X SOW,w/ I I I r. Vah/eoCT2o21/l65M FE, 2-2 1/16 5M EFO HWO 111' sil _i_1, 7;i1INA. Anna Platform Moncla BOP 03/16/2015 Ililrnrp %Nate.Ili. VENNI opriluflufllfl) \ / asa' 111 I ff111T1111 111 I I I VI 11 III 11.1 °w-u asr 135/8.5000 • 111 111 111 II1 Choke and Kill valves 31/85M r�1.' 1 11 I 1.111, 46: 4 Iii Iii lit III III' ` Iloill" III III I!1 IjI I11 283 _ 111 III 111 111 111 MID III III III I I III 135/85M FE X 13 5/8 5M FE 1100• (fir,„„tf,n, 1.00. Spacer spool 135/85M X 13 5/8 5M I i 1I•I neat 2]5 spare.spool III 111 III 111 I I 135/85M FE X 11 5M lil 111111111 III Moncla 301 BOP Test Procedure Hileorp Alaska,IAA, 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 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. 2) 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 Moncla 301 BOP Test Procedure Hilcarp Alaska,1.1.11: Attachment#1 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.) 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. 3) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 4) 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. Document both the rolling test and the follow up tests. Schwartz, Guy L (DOA) From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Friday,April 24,2015 10:27 AM To: Schwartz, Guy L(DOA) Subject: RE:An-11RD RWO (PTD 194-124) Guy, This casing will need to be tested as it has not been since it was set in November of 1994(4,800psi for 30min). We are also planning on running a CBL as this well does not have one on file. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, April 22, 2015 3:04 PM To: Daniel Taylor Subject: An-11RD RWO (PTD 194-124) Dan, Looking at RWO for Jet pump install. When was the casing on this well tested last? Also please verify TOC in the 9 5/8"casing. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 1 i ' Bettis, Patricia K (DOA) From: Daniel Taylor[dtaylor@hilcorp.com] Sent: Friday, April 17, 2015 2:04 PM To: Bettis, Patricia K(DOA) Subject: RE: Granite Pt St 18742 11RD Attachments: AA 76.27 from CO 76 -Spacing Exception 11RD.pdf Patricia, This well has previously had an exception. Please see the attached. Will this suffice? Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC, 0: 907-777-8319 C: 907-947-8051 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, April 10, 2015 11:13 AM To: Daniel Taylor Subject: Granite Pt St 18742 11RD Good morning Dan, CO 76, Rule 2 states that not more than two completed wells shall be allowed in any government quarter section; and no pay opened to the wellbore shall be nearer than 500 feet to any property line nor nearer than 1,000 feet to any well I drilling to or capable of producing from the same pool. Please provide a spider map for Granite Pt St 18742 11RD that shows the proposed perforation intervals within the Middle Kenai Oil Pool and the perforation intervals within the Middle Kenai Oil Pool for the surrounding wells. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 G if n .. 8stu WALTER J.NICKEL,GOVERNOR • ALASKA OIL AND GAS 3001 PORCUPINE DRIVE • CONSERVATION COMMISSION ANCHORAGE,ALASKA 995014192 PHONE: (907)279-1433 TELECOPY:(907)278-7542 September 19, 1994 ADMINISTRATIVE APPROVAL NO. 76.27 Re: The application of Union Oil Company of California to drill and, • , complete the Granite Point 11RD well as a Middle Kenai Oil Pool production well. G. Russell Schmidt Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, Ak 99502-0247 • 11, Dear Mr. Schmidt: Your application of September 13, 1994 for a permit to drill and complete the Granite Point 11RD well requires exception to spacing requirements set forth in Conservation Order No. 76. The drilling and completion of the Granite Point 11RD well is expected to increase oil recovery from the Middle Kenai Oil Pool in the Granite Point Field. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the Granite Point 11RD well pursuant to Rule 7 of Conservation Order No. 76. Sincerely, • Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION Printed on recycled papa I. '• . Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, April 10, 2015 11:13 AM To: dtaylor@hilcorp.com Subject: Granite Pt St 18742 11RD Good morning Dan, CO 76, Rule 2 states that not more than two completed wells shall be allowed in any government quarter section; and no pay opened to the wellbore shall be nearer than 500 feet to any property line nor nearer than 1,000 feet to any well drilling to or capable of producing from the same pool. Please provide a spider map for Granite Pt St 18742 11RD that shows the proposed perforation intervals within the Middle Kenai Oil Pool and the perforation intervals within the Middle Kenai Oil Pool for the surrounding wells. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 XHVZE Pages NOT Scanned in this Well History File This. page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~Vincent Nathan Lowell Date: [] TO RE-SCAN Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ oN ggFO W G e o .... ~-. ,~ , ~ ~ 1%.i! ~. ., ~ og'¥ca i Ha~h,.%r'{a i s Inven'tor'y Oake ~ i i/05/96 !:' E R M i T D A'1' A T D A T A .... P L U S 7'",~ / (""/,~ { ~ D t.::: t.I J'"..I D/:,.. 'F Ii ..... F;-: [.:i ,C V D .... /,, ................................. , 1~:. ~: '2 ~ ~85"'i'i375 'i 04//28,,,'95 9 4 ...... i 2 4 -'.', u b L ¢¢ .~..E-'~9 4 8 5 1 I 3 7 5 1 0/~ / 2. o ~;/' ~.q 5 9~ .... 126 BHC/AC/',SR/'CAL ~"~090 9460 E', I-.I c j A C / G R j C A L ~-~090 --- 9460 i 02/' 0'? / 95 I 02 / 0 '? / 95 94...- '12 a- B t.-.1,2 / S L ~/~ ~ L--~ 85 ..- / 'i 375 'i 02 / 0 '? / 9 94 -.- 12 a B I-.I P ...4¢~ 9485 -- I i 4 i 0 1 9a.--- i 2a C;DN/CN L/G R,/' EAL~ ..--k'-~O 90 .... 9432 '1 02 / 07 / 95 0 '2 / 07 / 95 94 .... 1~. ~'4 ,SN.L ~9685--1 i3 ~'~,4 I 02/.' 0 '?/' 95 9 ~ "' 'J 24 02/0'?/9S 02 / O '? / !:ii 5 9A....i2L,,- HUD (FORHATION) ~'-'~6500---'i'1869 '1 94 ..... i24 F'I/SFL ~ _-4¢~9485 11404 1 02/' 07 / 95 0, 4 ,,,' 2 o '~ / g 5 ~9485 .... 1 i40a I 04/' 2! 8/9 5 ~ 9485 .... 11404 r - r"equi I"ed'~ yes t~CJ r'ece'¥ ved'? ye s Unocal Energy Resourc~,,~-.~Jivision 909 West 9th, P.O. BO i ~247 Anchorage, AK 9951g-62.~. Telephone (g0g) 276-7600 · Fax (907) 263-7828 UNOCALd Debra Childers Clerk DATA TRANSMITTAL #15 To: From: Larry Grant Debra Childers 3001 Porcupine 909 W, 9th Avenue April 26, 1995 Anchorage, AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal Enclosed, please find the data as described below: GRANITE POINT 50 5" BLUELINE I SEPIA DUAL LATEROLOG I MICRO LATEROLOG / GAMMA RAY GRANITE POINT 50 2' BLUELINE I SEPIA DUAL LATEROLOG I MICRO LATEROLOG / GAMMA RAY 'GRANITE POINT 50 5' BLUELINE) SEPIA COMP DENSILOG I NEUTRON I GR I CALIPER ,, GRANITE POINT 50 2' BLUELINE / SEPIA COMP DENSILOG I NEUTRON I GR I CALIPER GRANITE POINT 50 5' BLUELINE i SEPIA GAMMA RAY LOG / &ARM CALIPER GRANITE POINT50 BLUELINEISEPIA. FORMATION MUDLOG GRANITE POINT 50 TAPE (~ O' ~ G.P. 18742 - 11 RD 5' BLUELINE I SEPIA PHASOR INDUCTION - SFL G.P. 18742 - 11 RD 2" BLUELINE I SEPIA PHASOR INDUCTION - SFL G.P. 18742 - 11 RD 5' BLUELINE / SEPIA BOREHOLE COMPENSATED SONIC LOG G.P. 18742 - 11 RD 2' BLUELINE / SEPIA BOREHOLE COMPENSATED SONIC LOG RECEIVED APR 2 8 1995 Alaska 011 & Gas Cons. C0mmissl0n Anchorage Please acknowlec~e,&eip,,kby signing re[Mining one copy of ~is transmittal or FAX to (907) 263-7828, , STATE OF ALASKA ALAS 31L AND GAS COr~ISERVATION COM SION ?- ,.,' ~.. WELL OOMPLET uN OR REOOMPLETION Hi--'PORT?AN.D LOG 1. Status of Well Classification of Servic~'Welh OIL J~ GAS L--J SUSPENDED J--J ABANDONEDJ--J SERVICE J--J 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 Anna Platform, Leg #1, Slot #1 729' FN L & 636' FEE Section 12, T1 ON, R12W, SM.~--~'i~?":'?'? i '~;'.~.'~-i At Top Producing Interval 10232' MD / 9218' TVD 158' FSL & 2494' FEL SECTION 1, T1 ON, R12W, SM. J '~'. t ~ At Total Depth 11469' MD/' 9612' TVD . 441' FSL & 1649' FWL SECTION 1, T10N, R12W, SM..:._ ~'_~':~; ~ 5. Elevation in feet (indicate KB, DF, etc.) 127' KB 12. Date Spudded 10/14/94 17. Total Depth (MD+TVD) 11469' / 9612' -.~ J 6. Lease Design~J~r~ and Serial No. ADL 18742 7. Permit Number 94-124 8. APl Number 50-733-20048-01 9. Unit or Lease Name 10. Well Number 11RD 11. Field and Pool Granite Point Middle Kenai "C" Sands J13. DateT, D. Reached J14. Date Comp., Susp. orAband. J15. Water Depth, ifoffshore J16. No. of Completions 11/21/94 12/08/94 77 Feet MSL I 1 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11351'/9577' JYES .O I .A I 22. Type Electric or Other Logs Run DIFL/BHC- AC/GP,/SPICHT/CN/FMT/DITE/CNL/LDT/BHC/SHDT/CET 23. CASING, LINER AND CEMENTING RECORD J J SETTING DEPTH MDI CASING SIZE WT. PER FT. GRADE TOP J BO'I-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 - 5/8" 47 L- 80 36' 9510' 12-1/4" 893 cu. ft. 7" 29 L-80 9320' 11469' 8-1/2" 696 cu.ft. 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 10232'- 10255' MD / 9218'-9227' TVD 10285'-10345' MD/ 9238'-9259' TVD 10585'- 10600' MD / 9341'-9346' TVD 10665'-10750' MD / 9366'-9392' TVD 10759'-10784' MD / 9395'-9403' TVD 11084'-11106' MD/ 9495'-9502'TVD 11119'-11156' MD / 9506'-9517' TVD 11200'-11282' MD/ 9530'-9555'TVD 25. TUBING RECORD SIZE I DEPTH SET (MD) I PACKER SET (MD) 3-1/2". 9.2#, L-80 @ 9184' (Top of Kobe BHA) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) J AMOUNT & KIND OF MATERIAL USED NA 27 PRODUCTION TEST Date First Production N/A Date of Test Hours Tested Flow Tubing Press. JMethod of Operation (Flowing, gas lift, etc.) PRODUCTION FOI~ OIL-BBL ITEST PER~°D | Casing Pressure J CALCULATED ! OIL-BBL I 24-HOUR RATE / GAS- MC F GAS-MCF 28. CORE DATA WATER- BBL WATER- BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ~,~R --9 1995 Ai~sk~ 0ii & Gas Cons. Commission Anch0rc ' Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed G. RUSSELLSCHMIDT T~e DRILLING MANAGER Date 03/01/95 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental recordsfor 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'. 1 30" Structural @ 83' BLM 20" Surface @ 629' 85# 13-3/8" Intermediate @ 3196' 54.5 & 61# BTC RECEIVED .~ Ai~.ska 0il & Cas Cons. Cor[~rn Anchoa COMPLETION DESCRIPTION 1) Dual 3-1/2", 9,2#, L80, SOBTC 2) Kobe BHA F/9158'-9187' DIL 3) 3-1/2" Ported Sub @ 9190'DIL. 4) 4-5/8" TCP guns @ 4 spf F/10232'-1 1282' DIL. RKB = 127', TBG MEAS.=DIL + 27' TOL @ 9320' 9-5/8" Production @ 9510'MD 47#, L-80, BTC 11351' ETD, cmt on LC 7" L @ 11469' 29#, L80, BTC Tyonek Peffs (C8, C7, C5) 10232'-10255' DIL 10285'-10345' 10585'-10600' 10665'-10750' 10759'-10784' 11084'-11106' 11119'-11156' 11200'-11282' ANNA 11 Redrill ACTUAL COMPLETION UNOCAL ENERGY RESOURCES ALASKA DRAWN: CLL DATE: 01-12-95 FILE: ANNA11 RD.drw sion ANNA PLATFORM ANNA 11 RD DAY 1-3 (10/14-16/94) 13-3/8" @ 3196' 9-5/8" @ 7873' 8.4 PPG (FIW) SKID R428 TO WELL #11. REM TREE & INSTALL BOPE. TEST BOP TO 3000 PSI. RU WL, PULL TBG PLUGS F/BOTH LS & SS TBG. GAUGE SS TO KOBE BHA, POOH. RU CUT SS TBG AT 7604' WLM. CBU. POOH, LAY DN SS TBG. PULL & LAY DN LS TBG, KOBE BHA & TAIL PIPE, FULL RECOVERY. CHG RAMS & TEST. RIH W/5" DP X 3-1/2" TBG. M&P BAL CMT PLUG(S) F/9872'-9222' & 9222'-8800'. POOH. RIH W/6" BIT & 9-5/8" CSG SCRAPER, FOUND GRN CMT F/8927'-8965'. TOC @ 8980'. PRESS TEST CSG TO 2000 PSI F/30 MINS. POOH. DAY 4 (10/17/94) 13-3/8" @ 3196' 9-5/8" @ 7873' 9.2 PPG RIH, SET EZSV AT 3455' DPM. TEST SAME W/2000 PSI, OK. POOH. RU ATLAS AND RUN CBL/VDL FROM 3450' TO SURFACE. ATTEMPT TO BLEED OFF 9-5/8" X 13-3/8" ANNULUS. PRESSURE WOULD NOT GO BELOW 350 PSI. RIH W/OPEN ENDED DRILL PIPE. CHANGE WELL OVER TO 9.2 PPG MUD. PJU WIRELINE. RIH THRU D.P. PERFORATED 9-5/8" CASING FROM 3445' TO 3442' 10 SHOTS TOTAL. 0 PRESSURE ON 9-5/8" CASING, 350 PSI ON 9-5/8" X 13-3/8". ATTEMPT TO EST. CIRCULATION THROUGH PERFS NO SUCCESS PUMP 50 BBLS MUD IN PERFS. 3425' ETD (EZSV) DAY 5 (10/18/94) 13-3/8" @ 3196' 9-5/8" @ 7873' 9.2 PPG BULL HEAD 9.2 MUD DOWN 9-5/8" X 13-3/8" ANNULUS. PRESSURE START AT 350 PSI PUMP 187 BBLS. RIH W/EZSV RET, SET SAME AT 3425'. POOH. ND TBG SPOOL. NIPPLE UP, TEST BOP. MU CSG CUTTER RIH. CUT 9-5/8" @ 3345', PU CUT CSG AGAIN AT 3146'. BREAK CIRC ON 13-3/8" X 9-5/8" ANNULUS. CBU. ANNA 11 REDRILL 3425' ETD (EZSV) DAY 6 (10/19/94) 13-3/8" @ 3196' 9-5/8" @ 7873' POOH W/CSG CUTTER. MU SPEAR ASSY. RIH, ENGAGE 9-5/8" CSG. PULL CSG. FREE & CBU. POOH L/D CASING FROM CUT AT 3345'. RIH W/CEMENT STINGER. RECEIVED ~:~u. ug.a,_'~, -, 0il & Gas Cons. Commission Anchor" Well Summary Anna 11 P&A plus Redrill Page 2 3425' ETD (EZSV) DAY 7 (10/20/94) 13-3/8" @ 3196' 9-518" @ 7873' 9.2 PPG COULD NOT PASS 3254'. POOH. RIH W/12-1/4" CLF_.AN OUT ASSY CLEAN OUT HOLE TO CASING STUB AT 3345'. POOH. RIH W/CEMENT STINGER LAY CEMENT PLUG FROM 3418'-3000'. POOH TEST BOP'S. M/U BHA. 3425' ETD (EZSV) DAY 8-10 (10/21-22/94) 13-3/8" @ 3196' 9-5/8" @ 7873' 9.2 PPG RIH TAG CMT AT 3076' TEST CASING TO 1500 PSI FOR 30 MIN. CLEAN OUT CMT TO 3162'. WOC 3 HRS. DRILL CMT TO 3268'. HOLE SLOUGHING IN, LARGE AMT OF COAL IN CUTTINGS. INCREASE MUD WT FROM 9.2 PPG TO 9.8 PPG. CLEAN OUT TO 3313' HOLE STILL UNSTABLE. POOH W/DRILLING ASSY. RIH LAY 81 BBL CMT PLUG FROM 3313' TO 2975'. REV OUT, NO CMT. RIH W/12-1/4" DRILLING ASSY. TAG CMT AT 3216' WOC 12.5 HRS. CLEAN OUT SOFT CMT TO 3245'. POOH W/DRILLING ASSY. RIH LAY 84 BBL CMT PLUG FROM 3220' TO 2951'. ATTEMPT TO REVERSE OUT, STINGER PLUGGED. RIH W/12-1/4" DRILLING ASSY. TAG CMT AT 3053' WOC 9 HRS. CLEAN OUT SOFT CMT TO 3080'. DRILL FIRM CMT FROM 3080' TO 3207'. KICK OFF WELL TO 3360' PERFORM LOT (~ 17.1 PPG. DIRECTIONALLY DRILL FROM 3360' TO 3495'. ~...-----This completes the plug and abandonment of Anna 11. 4413'/ DAY 11 (10/24/94) 13-3/8" @ 3196' 9.7PPG DRILLED 12-1/4" HOLE F/3495'-4345'. ST TO 13-3/8" SHOE. DRILLED TO 4413'. 5295'/882' DAY 12 (10/25/94) 13-3/8" @ 3196' 9.7PPG DRILLED F/4345'-5295'. CBU. POOH F/BIT & BHA CHG. 5625'/ DAY 13 (10/26/94) 13-3/8" @ 3196' 9.TPPG CMPT POOH. MU BHA & RIH. REAM OPEN HOLE AS REQ'D. DRILLED TO 5625'. ,ECEIVED Oas Cons. Commission Well Summary Anna 11 P&A plus Redrill Page 3 7328'/1203' DAY 15-17 (10/28-30/94) 13-3/8" @ 3196' 9.5 PPG DRILLED 12-1/4" HOLE F/6165'-6998'. POOH, MU BIT & BHA. RIH, DRILLED F/6998'- 7328'. SLOW ROP & DIFFICULTY W/TOOL FACE. POOH, LOST BEARING ON ONE CONE. MU BIT & BHA. RIH. 7725'/397' DAY 18 (10/31/94) 13-3/8" ~ 3196' 9.5 PPG CONT RIH, SPOT REAM F/7069'-7328'. DRILLED F/7328'-7725' 8007'/282' DAY 19 (11/01/94) 13-3/8" (~ 3196' 9.4 PPG DRILLED TO 7886', POOH. MU BIT & BHA. RIH, DRILLED TO 8007'. 8340'/333' DAY 20 (11/02/94) 13-3/8" (~ 3196' 9.4 PPG DRILLED F/8007'-8340' 8437'/97' DAY 21 (11/03/94) 13-3/8" @ 3196' 9.4 PPG DRILLED F/8340'-8437'. POOH FOR BIT/ASSY CHANGE. TEST BOP'S. RIH W/ROTARY ASSY. REAM FROM 8314' TO 8437'. 9204'/767' DAY 22-24 (11/04-06/94) 13-3/8" @ 3196' 9.6 PPG DRILLED 12-1/4" HOLE F/8437'-8963'. POOH, STUCK BHA AT 8804'. JAR BHA FREE AND WORK TIGHT HOLE TO 7628'. CONT POOH, POSSIBLE KEY SEAT AREA F/3645'-3426'. CHG BIT & BHA. RIH, STOP AT SHOE TO CUT & SLIP DRILL LINE, TURBINE DOWN DUE TO HIGH GAS PRESSURE (CAUSED BY PLATFORM). CONT RIH, REAM F/8859'-8963'. DRILLED F/8963'-9144'. ST TO 7465', HOLE CONDITIONS FAIR. DRILLED TO 9204'. 9479'/275' DAY 25 (11/07/94) 13-3/8" @ 3196' 9.6 PPG DRILLED F/9204'-9479'. ~:,!-~ -' 9 '~'~ i¢," -' 0ii & Gas Cons. Commission Anchor; Well Summary Anna 11 P&A plus Redrill Page 4 DAY 26 (11/08/94) 13-3/8" @ 3196' 9.6 PPG DRILLED F/9479'-9510'. ST TO 13-3/8" CSG SHOE, TIGHT HOLE AT INTERVALS. RIH, TO 9510' & CBU. POOH, TIGHT HOLE BUT HOLE CONDITION FAIR. RU ATLAS WL & RIH W/LOG RUN #1 (DIFL/BHC-AC-CDL/CN/GPJCHT). SET DN W/TOOLS AT 13-3/8" CSG SHOE. PU & CONT RIH TO 9491' SET DN 5 TIMES BTWN 7975'-8361'. LOG UP F/9491'. 9510' ETD DAY 27 (11/09/94) 13-3/8" @ 3196' 9.6 PPG CONT TO LOG UP TO 13-3/8" CSG SHOE. RU, RIH W/LOG RUN #2 (FMT/GPJCHT), LINE SHORT FAILURE AT 6500' WHILE RIH. POOH, STUCK TOOL AT 4636', WORK SAME FREE W/4500# (MAX) OVER PULL. CONT POOH, OTHER INTERVALS REQ'D 2000# OVER PULL. MU C/OUT BHA. RIH, TO BTM, 8' OF FILL. C/OUT FILL & CCH. POOH. CHG PIPE RAMS & RU TO RUN CSG. RIH W/9-5/8" 47# LB0 CSG. 9510' ETD DAY 28 (11/10/94) 9-5/8"@ 9510' 9.6 PPG TAG BTM AT 9510', CCH WHILE RECIPROCATING PIPE. M&P 159 BBLS OF 15.8 PPG CEMENT W/ADDITIVES. UNABLE TO MOVE CSG DURING JOB (MAX PULL ACHIEVED). CIP @ 1330 HRS. BUMPED PLUG & FLOATS HELD. PU BOP & SET CSG. SLIPS. INSTALL TBG SPOOL W/PACKOFF, TEST SAME OK. NU BOP & TEST SAME. MU DRGL. BHA. 10099'/589' DAY 29-31 (11/11-13/94) 9-5/8" @ 9510' 9.6 PPG CONT MU BHA. RIH, TAG AT 9417'. PRESSURE TEST CSG TO 4800 PSI Fl30 MINS, OK. C/OUT CMT, FLOAT EQUIP & NEW HOLE TO 9520'. PERFORM FIT TO 3500 PSI, NO LEAK OFF. DRILLED NEW HOLE TO 9530', PERFORM FIT TO 3700 PSI (EMW 17.7 PPG) NO LEAK OFF. DRILLED 8-1/2" HOLE F/9530'-9788'. POOH, MU NEW BIT & LAY DN DP & HWDP W/EXCESSIVE WEAR. RIH, DRILLED F/9788'- 9885' & MWD FAILED. POOH, REPLACE MWD & INSTALL DP RUBBERS AS REQ'D. RIH, DRILLED F/9885'-10099'. PROBLEMS W/DN HOLE DRLG MOTOR. POOH. 10776'/259' DAY 34 (11/16/94) 9-5/8" @ 9510' 9.2 PPG RIH. SAFETY REAM 10490'-10517'. DRILLED 8-1/2" HOLE 10517' -~. "7~ RO~ ~.~/'~ ~ ~) i,.~¢~¢~,~ ()il & Gas Cons. Commissio~t Anchor~ ', Well Sunmmry Anna 11 P&A plus Redrill Page 5 10330'/231' DAY 32 (11/14/94) 9-5/8" (~ 9510' 9.3 PPG POH. CHANGED OUT BIT & MUD MOTOR. RIH. SPOT REAMED 10031'-10099'. DIRECTIONALLY DRILLED 8-1/2" HOLE 10099'-10330'. 10517'/187' DAY 33 (11/15/94) 9-5/8"@ 9510' 9.2 PPG DIRECTIONALLY DRILLED 8-1/2' HOLE 10330'-10517'. EXPERIENCED SUSPECTED MUD-MOTOR PROBLEMS. M/U ROTARY BHA. RIH. 10937'/161' DAY 35 (11/17/94) 9-5/8"@ 9510' 9.3 PPG DRILLED 8-1/2" 10776'-10937'. CIRCULATE AND START SHORT TRIP. EXPERIENCED TIGHT HOLE FROM 10,722'; WORKED AND BACK REAMED TO 10,245'. (MADE DECISION TO POH TO SURF). 11453'/516' DAY 36-38 (11/18-20/94) 9-5/8" (~ 9510' 9.5 PPG BACKREAMED 10,245'-9663' . ADJUST DP RUBBERS. MU BHA & RIH. DRILLED 6- 1/2" HOLE F/10937'-11075'. ST TO 9800', TIGHT HOLE AT INTERVALS. DRILL F/11075'-11261'. ST TO 9500', TIGHT HOLE & BACKREAM AS REQ'D. DRILL F/11261'-11409'. ST TO CSG SHOE, TIGHT HOLE. RIH, DRILL TO 11453'. 11469'/16' DAY 39 (11/21/94) 9-5/8" @ 9510' 9.6 PPG DRILL TO 11469' TOTAL DEPTH. POOH. STUCK BHA AT 10657' & KNOCKED LOOSE. CONT TO WORK THRU TIGHT HOLE F/10626'-10084'. STUCK BHA AT 9659', JAR FREE & PULL TO SHOE. MONITOR WELL & POOH. MU BHA & RIH TO 11469'. CCH & PUMP HI-VISC SWEEP. PULL TO 9-5/8" CSG SHOE, TIGHT HOLE AT INTERVALS. UNABLE TO LOAD LOGGING TOOLS AT DOCK DUE TO HIGH WINDS. RIH TO 11469', CCH. POOH, HOLE CONDITIONS IMPROVED SLIGHTLY. DAY 40 (11/22/94) 9-5/8" @ 9510' 9.6 PPG CONT TO POOH. MU SCHLUM DP CONVEYED LOGGING EQUIP. RIH W/DITE/CNL/LDT/BHC/GR. LOG F/11435'-9510'. POOH, TOOLS OK. MU SHDT/GR Well Summary Anna 11 P&A plus Redrill Page 6 11,351' ETD DAY 41-45 (11/23 - 11/27/94) 9-5/8" @ 9510' 7" L F/9330' - 11,469' 8.5 PPG LOG F/11,432' - 9510' W/DIPMETER. POOH, RIG DN E-LINE EQUIP. MU BHA & RIH TO 11,469', CCH. POOH, RU TO RUN 7" LINER. RIH W/7" 29# LB0 CSG & HANGER ASSY. RIH W/LINER TO 11,469'. CCM WHILE REClP LINER. M&P 124 BBLS OF 15.8 PPG CMT & ADDITIVES. BUMPED PLUG & SET HYD HANGER W/3500 PSI. ClP 0100HRS 11-25-94. REL LINER & SET LINER TOP PKR. REV OUT F/LINER TOP, NO CMT. POOH. MU 6" BHA & CSG SCRAPERS, RIH, TAG GRN CMT AT 11,242' & C/OUT TO 11,351' ETD. PRESS TEST 7" & 9-5/8" CSG TO 3500 PS1 F/30 MINS, OK. POOH. RU SWS WL & RIH W/CET/GR TO 10,260' WLM. LOG F/10,260' TO TOC IN 9-5/8. POOH. RU DP CONVEYED EQUIP & RIH W/CET/GR TO 11,330'. LOG INTERVAL F/11,330'- 10,174'. POOH. RIG DN E-LINE. PU 3-1/2" 9.2~ LB0 COMPLETION TOG & RIH TO 11,351' ETD. POOH, STD BK TBG AS REQ'D. CONT PU TBG & RIH. DISPL MUD TO 3% KCL WATER. POOH, LAY DN 3-1/2" DP. DAY 46 (11/28/94) 9-5/8" @ 9510' 7" L F/9330' - 11,469' 8.5 PPG AFE #7412O9 CONT POOH STD BK TBG. PU BAL OF TBG FOR COMPLETION. MU & RIH W/4- 5/8" TCP GUNS LOADED AT 6 SPF, 2-7/8" TBG, 3" KOBE BHA TYPE "D" & DUAL 3- 1/2", 9.2#, L80 SCBTC COMPLETION TBG. DAY 47 (11/29/94) 9-5/8" @ 9510' 7" L F/9330' - 11,469' 8.5 PPG CONT TO RIH. PREP & RU SCHLUMB F/GR CORRELATION. RUN TIE-IN LOG, CORRECT TBG AS REQ'D. SPACE OUT, INSTALL DUAL TBG HANGER AND LAND SAME. RUN PACKOFF AND INSTALL BPV. ND BOP & INSTALL TREE. TEST PACKOFF & TREE TO 5M. DAY 48 (11/30/94) 9-5/8"@ 9510' 7" L F/9330' - 11,469' 6.'/PPG POWER OIL INSTALL PROD FLOWLINE & SURFACE EQUIPMENT. DISPLACE WELL WITH POWER OIL. DROP STANDING VALVE. NOTE PRESSURE ON ANNULUS 300 PSI , L/S 40. ATTEMPT TO BLEED OFF W/O SUCCESS. MONITOR PRESSURE INCREASED TO 860 PSI ON ANNULUS, 550 ON S/S, 485 ON L/S. RECEIVED ivlAf:i --'9 199,5 /,.,~s!(;~ 0il .& (:-'}as ¢,ons. (':ornrnissior; Well Summary Anna 11 P&A plus Redrill Page 7 DAY 49 (12/01/94) 9-5/8" @ 9510' 7" L F/9330' - 11,469' 8.8 NACL BRINE PULL STANDING VALVE DISPLACE POWER. OIL W/FILTERED INLET WATER. SHUT IN MONITOR PRESSURE BUILD UP TO 190 PSI. INCREASE DENSITY TO 8.8 PPG WELL STABLE. N/D BOP'S. N/U TREE. DAY 50-52 (12/02-04/94) 9-5/8" @ 9510' 7" L F/9330' - 11,469' 8.8 NACL BRINE L/D DRILL PIPE. PULL BPV. NU & TEST BOP. PULL DUAL TBG COMPLETION & LAY DN SAME. TCP GUNS DID NOT DETONATE, LEAK APPEARS TO BE IN 9-5/8" X 7" LINER LAP AREA. MU LINER TOP PKR ASSY &RIH. SET PKR AT TOE TEST DN DP & 7" LINER TO 3500 PSI, OK. TEST BACKSIDE TO 4700 PSI, OK. REL SETTING TOOL & POOH TO 7697'. FAST-LINE SHEAVE IN CROWN FAILED DUE TO SNAP RING BREAKING THUS SH, EAVE BEARINGS LOCKED-UP. INITIATE REPAIRS AS REQ'D. DAY 53 (12/05/94) 9-5/8" ~ 9510' 7" L F/9330' - 11,469' 8.8 NACL 13R!?-.~E RECEIVED NEW SHEAVE, BEARINGS & SEALS. INSTALL ON CROWN. CONT POOH W/SETTING TOOL. MU RTTS PKR & MULTI-SERVICE VALVE. RIH AND SET PKR AT 9099'. ACTUATE VALVE W/t600 PSI ANNULUS PRESS & PERFORM DRAW DOWN "DRY TEST" TO 1500 PSI, POSITIVE TEST NO LEAK AT LINER LAP. REV CIRC, NO OIL OR GAS. POOH & LAY DN TOOLS. 11,351' ETD DAY 54 (12/06/94) 9-5/8" ~ 9510' 7" L F/9320' - 11,469' 8.8 NACL I3RII'-.!E RIH W/TBG X DP TO 11351'. REV CIRC WELL CLEAN TO 3% KCUFIW. POOH. CHG RAMS TO 3-1/2" DUAL & TEST SAME. RE-RUN TCP GUNS, KOBE CAVITY DUAL 3-1,2" TBG COMPLETION. R E E E IV DAY 55 (12/07/94) 9-5/8" @ 95i 0' 7" L F/9320'- il,469' 6.9 PPG CRUDE OIL Gas Cons. Commission Anchort LAND TBG HANGER, INSTALL BPV'S & PACKOFF. REM BOPE. INSTALL TREE, MANIFOLD & SURFACE LINE, TEST ALL TO 5000 PSI. DISPL WELL W/CRUDE OIL. INSTALL STD VALVE & PUMP. RELEASE RIG AT 2000 HRS. PUMP WELL (FLUID LEVEL) DN. TO OBTAIN UNDERBALANCE. PREP R428 TO SKID TO ANNA 3 RD. Well Summary Anna 11 P&A plus R¢¢h'ill Page 8 DAY 56 (12~08~94) 9-5/8" @ 9510' 7" L F/9320' - 11,469' 6.9 PPG CRUDE OIL PUMP FLUID LEVEL DN TO 8100'. DETONATE TCP GUNS AT 0920 HRS, IN ONE HR FLUID LEVEL RISE 514'. PERF TYONEK AT INTERVALS F/10,232'-11,282', NET 349'. i I SURVEY CALCULATION AND FIELD V', ,~RKSHEET Job No. 0450-01391 Sidetrack No. 1 .................. Pa~e ...._1 ..... of _. ,_[~_,i=[....~ Company __UN___~OCA__~L Rig Contractor & No. Pool Arctic Alaska - Rig: #428 ...................... Field _G_R__~ANI_T_.E_P_O!_N..T_.F!E_LD Well Namo & No. ANNA PlaTFORM/Il RD#1 Survoy Soction Namo Definitive Survoy BHI Rep. TOM DUNN '7 'W ~ ~ WELL DATA Target TVD (F3) Target Coord. N/S Slot Coord. N/S -724.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. EJW -637.00 Magn. Declination 22.880 Calculation Method MINIMUM CURVATURE Target Direction .............................. !D_.~ ............ Build\Walk\DL per: 100fl[)~ 30m[-] 10m[~I Vert. Sec. Azlm. 294.37 Magn. to Map Corr._ ..... 22.880 ........ Map North to: .O__T~!L_:R SURVEY DATA .................... Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (FT) ........ (DO) ....... {DO) ........ _{~_~__ ......(ET) ............................. (__~.~ ................... (_FI!___ ~P_e!.!OOF~` Drop(-) ............ _Left(_-) G MS 3203.00 30.00 15.00 2981.83 159.50 908.70 236.62 TIE IN POINT .............................................................................................. ............................................................................................ 23-OCT-94 MWD 3269.00 27.20 14.90 66.00 3039.77 164.59 939.22 244.77 4.24 -4.24 -0.15 8" M1C 1 DEG AKO . ,. . ..... 23-OCT-94 MWD 3363.00 25.70 13.80 94.00 3123.93 171.86 979.78 255.16 1.68 -1.60 -1.17 __ -. , .................... ~ .......................... 23-OCT-94 MWD 3458.00 22.00 7.00 95.00 3210.82 180.96 1017.46 262.24 4.85 -3.89 .7.1~ · 23-ocT-94 MWD 3552.00 19.50 3.30 94.00 3298.72 191.85 1050.61 265.29 3.00 -2.66 -3.94 24-OCT-94 MWD 3645.00 18.80 2.50 93.00 3386.57 203.02 1081.08 266.84 0.80 -0.75 -0.86 24-OCT-94 MWD 3739.00 15.60 1.70 94.00 3476.36 213.53 1108.85 267.88 3.41 -3.40 -0.85 24-OCT-94 MWD 3832.00 12.30 359.50 93.00 3566.60 222.52 1131.26 268.16 3.59 -3.55 -2.36 "--.~ 24-0CT-94 MWD 3925.00 8.80 354.50 93.00 3658.02 230.23 1148.25 267.39 3.89 -3.76 -5.38 L,~... - 2.59 ~2~~ ,, , 24-OCT-94 MWD 4018.00 6.40 353.00 93.00 3750.19 236.47 1160.48 266.08 ~ ..................................................... ; ". ' .'. 24-OCT-94 MWD 4113.00 4.60 351.40 95.00 3844.75 241.30 1169.50 264.86 ! , _ 24-OCT-94 MWD 4207.00 3.00 353.30 94.00 3938.54 244.62 1175.67 264.01 1.71 -1.70 24-0CT-94 MWD 4302.00 2.60 319.90 95.00 4033.44 247.85 1179.79 262.33 1.74 -0.42 ~-'-- 25-OCT-94 MWD 4396.00 3.50 296.20 94.00 4127.31 252.64 1182.69 258.39 1.63 0.96 ........................................................ ~).~ "~'~._, ~=.~ ~ - 25-0CT-94 MWD 4490.00 3.30 283.60 94.00 4221.14 258.17 1184.59 253.18 -0.21 ?,~,": ,~,,~ ....... ~-~--'-~11~- ....................... 25-OCT-94 MWD 4584.00 2.10 257.10 94.00 4315.04 262.20 1184.84 248.87 1.81 -1.28 '~:~ 25-0CT-94 MWD 4679.00 2.00 257.30 95.00 4409.98 264.91 1184.09 245.56 0.10 -0.10 ~ . 25-0CT-94 MWD 4772.00 2.40 260.10 93.00 4502.91 267.81 1183.40 242.06 0.44 0.43 .... ,,~ ~.,,.? ,.~ . 25-0CT-94 MWD 4864.00 2.90 261.00 92.00 4594.81 271.35 1182.70 237.86 0.54 0.54 ,.~ .~,- c,u~?,,~. ,_ 25-OCT-94 MWD 4957.00 2.20 242.50 93.00 4687.72 274.41 1181.51 233.95 1.15 -0.75 25-OCT-94 MWD 5049.00 2.10 234.30 92.00 4779.65 276.34 1179.71 231.02 0.35 -0.11 25-OCT-94 MWD 5145.00 2.10 240.60 96.00 4875.59 278.26 1177.82 228.06 0.24 0.130 __ 25-OCT-94 MWD 5239.00 2.70 245.80 94.00 4969.51 280.74 1176.07 224.54 0.68 0.64 26-OCT-94 MWD 5272.00 3.00 248.00 33.00 5002.47 281.86 1175.43 223.03 0.97 0.91 iiiii iiiii i i i i i i SURVEY CALCULATION AND FIELD ..,RKSHEET .,ob No. Sidetrack No. Pau of Company _U..N_.O__C_AI: Rig Contractor & No. ~P_o_o.! A_r_ct!_c A!a_s.k__a- .R..!~! ~__4_2._. Field .G_~_A__.N_!T.E- .P. ~!.N..T .F!.E..[.~ Well Name & No. ANNA PLATFORM/11 RD#I Survey Section Name P_~e!!_nl_t!_v._e S_u__rv_e_y ............................ BHI Rep..T_O__M _D_.U.~_N_ mi · I I I I ' i i iii i I I i il i i ~ ~ ~ ': - - WELL DATA Target TVD ............................. (_FT)_ ...................... Target Coord. N/S Slot Coord. N/S -724.00 Grid Correction .......... _0:000 .............. Depths Measured From: RKB ~J MSL Target Description ................................. Target Coord. E/W .............................. Slot Coord. F_JW -637.00 Magn. Declination ........ 2__~2:88__0_ ............ Calculation Method M_M_!N!_M_.U_M- ~.U_R___V_A_~_U_.R_E. Target Direction (OD) Build~Walk\DL per: 10Oft[~ 30m[~ lOm[~i] Vert. Sec. Azim. 294.37 Magn. to Map Corr. 22.880 Map North to: O__T~_IER ........................ $Ui~1¥£¥DAIA ...... Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section --~i'~')-~-~-)- E(+)/'~)- DL Build (+) Right (+) Comment 26-OCT-94 MWD 5365.00 3.30 248.70 93.00 5095.33 2t'.~5.40 1173.54 218.28 0.32 0.32 Re I"ARY ASSI ;Mi_{I Y w/ 26-OCT-94 MWD 5460.00 3.60 251,30 95.00 5190.15 209.50 1171.59 212.91 0.36 0.32 26-OCT-94 MWD 5553.00 3.90 252.50 93.00 5282.95 293.98 1169,71 207.12 0.33 0.32 26-OCT-94 MWD 5647.00 4.30 252.60 94.00 5376.71 298.99 1167.69 200.71 0.42 0.42 27-OCT-94 MWD 5741.00 4.50 252.80 94.00 5470.44 304.38 1165.55 193.83 0.21 0.21 27-OCT-94 MWD 5835.00 4.60 253.50 94.00 5564.14 309.99 1163.39 186.69 0.12 0,11 27-OCT-94 MWD 5929.00 5.10 255.90 94.00 5657.80 316.11 1161.30 179.02 0.57 0.53 2.55 27-OCT-94 MWD 6023.00 5.70 258.00 94.00 5751.38 323.14 1159.31 170.41 0.67 0.64 2.23 27-OCT-94 MWD 6116.00 6.10 260.80 93.00 5843.89 330.98 1157.56 161.01 0.53 0.43 3.01 28-OCT-94 MWD 6210.00 6.90 264.90 94.00 5937.29 340,05 1156.26 150.46 0.98 0.85 4.36 . 28-OCT-94 MWD 6304.00 7.60 268.00 94.00 6030.54 350.54 1155.54 138.62 0.85 0.74 3.30 28-OCT-94 MWD 6396.00 8.30 269.60 92.00 6121.65 362.02 1155.28 125.90 0.80 0.76 1.74 28-OCT-94 MWD 6491.00 8.40 270.60 95.00 6215.64 374.59 1155.31 112.10 0.18 0.10 1.05 28-OCT-94 MWD 6584.00 8.80 270.60 93.00 6307.60 387.32 1155.45 98.20 0.43 0.43 0.00 28-OCT-94 MWD 6679.00 9.10 271.70 95.00 6401.44 400.90 1155.75 83.42 0.36 0.32 1.16 28-OCT-94 MWD 6773.00 9.70 273,00 94,00 6494,18 415.14 1156.39 68.08 0.68 0.64 1.38 29-OCT-94 MWD 6864.00 10.30 275.50 91.00 6583.80 429.98 1157,57 52.33 081 0.66 2.75 29-OCT-94 MWD 6958.00 10.90 277.50 94.00 6676.19 446.43 1159.53 35.15 0,75 0.64 2.13 . 29-OCT-94 MWD 7015.00 11.70 275.00 57.00 6732.09 457.04 1160.74 24.05 1 64 1.40 -4.38 8' MlC 1 DEC AKO 29-OCT-94 MWD 7111.00 14.00 272.40 96.00 6825.68 477.00 1162.07 2.75 2.47 2.40 -2.71 30-OCT-9~, MWD 7206.00 16.10 268.40 95.00 6917.42 499.50 1162.19 -21.90 2.46 2.21 -4.21 31-OCT-94 MWD 7299.00 17.40 269.50 93.00 7006.47 523.71 1161.71 -48.70 1.44 1.40 1.18 31 -OCT-94 MWD 7394.00 20.00 265.80 95.00 7096.45 550.87 1160.39 -79.11 3.01 2.74 -3.89 31-OCT-94 MWD 7488.00 22.70 262.40 94.00 7183.99 580.38 1156.82 -113.13 3~16 2,87 -3.62 SURVEY CALCULATION AND FIELD V'...,RKSHEET Job No. 0450-01391 Sidetrack No. 1... Parle 3 of Company _U_N_QCA.L_ Rig Contractor & No..P__~oo_l Arctic Alaska- R!g! ~42__~.8 Field .G_RA.N_I_T_E _PO!.N.T_ .F.!E!:D Well Name & No. ANNA PLATFORM/Il RD#1 Survey Section Name Definitive Survey' BHI Rep. _TOM DU_N..N_ ii i ii i iii ii i ii ii ii iii i i iii i1~ ii ~ ~ ,' , WELL DATA Target TVD (FT) Target Coord. N/S ......................... Slot Coord. N/S -724.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLI_1 SSI.'j Target Deacrlption Target Coord. EJW ....................... Slot Coord. E/W -637.00 Magn. De~linatlon 22.880 __ Calculation Method M!N!M.U.M C.__.U..R._V_A_T~R_E Target Direction (DD) Build~Walk\DL per: lOOft~ 30m~ lomE] Vert. Sec. Azim. 294.37 Magn, to Map Corr. 22.880 Map North to: OTHER SURVEY DATA ... Survey Survey Incl, Hole Course Vertical Total Coordinate 3uild Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-)- DL Build (+) Right (+) Comment Type (F13 (DO) {DD) (FI') (FT) (F'r) (,Er) .... Per 100 FI-)Drop (-) Left (-) .... 31-OCT-94 MWD 7581.00 25.80 259.40 93.00 7268.78 612.20 1150.72 -150.82 3.58 3.33 -3.22 31 -OCT-94 MWD 7675.00 28.20 257.80 94,00 7352.53 646.80 1142.26 -192.64 2.67 2.55 -1.70 01 -NOV-94 MWD 7768,00 29.70 258.10 93.00 7433.91 683.03 1132.86 -236.66 1,62 1,61 0.32 -- __ 01 -NOV-94 MWD 7861.00 31.00 255.70 93.00 7514.16 720.30 1122.20 -282,42 1.91 1,40 -2.58 01 -NOV-94 MWD 7955.00 32,40 254.20 94.00 7594.14 758.45 1109.36 -330.11 1.71 1.49 -1,60 02-NOV-94 MWD 8049.00 33.40 252.90 94.00 7673.06 797.08 1094.90 -379.07 1.30 1.06 -1,38 02-NOV-94 MWD 8143.00 34.50 252.10 94.00 7751.04 836.17 1079,11 -429,14 ~.26 1.17 -0.85 02-NOV-94 MWD 8236.00 35.60 251.30 93.00 7827.17 875.43 1062.33 -479.84 1.28 1.18 -0.86 , 03-NOV-94 MWD 8330.00 37.20 252.20 94,00 7902.83 916.48 1044,87 -532.82 1.79 1,70 0.96 , , 03-NOV-94 MWD 8392.00 38.40 251.40 62.00 7951.82 944.47 1033.00 -568.91 2.09 1,94 -1.29 04-NOV-94 MWD 8467.00 39,10 251.70 75.00 8010.31 978.90 1018.14 -613.44 0.97 0.93 0.40 ROTARY ASSEMBLY -- 04-NOV-94 MWD 8560.00 40.10 251.80 93.00 8081.97 1022.52 999.58 -869.74 1.08 1.08 0.11 04-NOV-94 MWD 8655.00 41.30 251.80 95.00 8153.99 1068.14 980,23 -728.59 1.26 1.26 0.00 04-NOV-94 MWD 8749.00 41.80 253,00 94.00 8224.33 1114.50 961.38 -788.02 1.00 0.53 1,28 --. 05-NOV-94 MWD 8843.00 42.50 253.70 94.00 8294.03 1162.09 943.31 -848,45 0.90 0.74 0.74 05-NOV-94 MWD 8937.00 43.80 255.00 94.00 8362.60 1211.33 925,98 -910.36 1.68 1.38 1.38 06-N OV-94 MWD 8992.00 44,00 258.00 55.00 8402.24 1241.02 916.43 -947.28 1.31 0,36 1.82 O6-N OV-94 MWD 9084,00 43.50 256.20 92.00 8468.69 1290.97 901.1 5 -1009.03 0.56 -0.54 0.22 .... 07-NOV-94 MWD 9176.00 43.40 258,10 92.00 8535.49 1341.34 887,08 -1070.71 1.42 -0,11 2.06 07-NOV-94 MWD 9271.00 43.80 258.30 95.00 8604.28 1394,23 873.68 -1134.84 0.44 0.42 0.21 07-NOV-~ MWD 9365,00 43,80 259.70 94,00 8672.13 1447.28 861,27 -1198,71 1.03 0.130 1,49 __ 08-NOV-94 MWD 9450.00 43.50 260.00 85.00 8733,63 1495,62 850.93 -1256.46 0.43 -0.35 0.35 -i 11-NOV-94 MWD 9549,00 43.30 260.10 99.00 8805,56 1551.80 839.17 -1323.46 0.21 -0.20 0.10 6 3/4' M1C 1.15+ DEG AKO ! 1 -NOV-94 MWD 9643.00 44,70 265.60 94.00 8873,20 1607.44 831.09 -1388,20 4,33 1.49 5.85 i i i i i ii i i ii i i i i i i ii i i i ii i ii · _=|![~_, Company UNOCAL ................................................................... Rig Contractor & No. Pool Arctic Alaska- Rig: #428 Field GRANITE POINT _F.!E__L_D Well Name & No. ANNA PLATFORM/11 RD#1 Survey Section Name Definitive Survey BHI Rep. TOM DUNN ~ ~ ~ ' WELL DAlA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -724.00 Grid Correction ...... _0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W -637.00 Magn. Declination 22.880 Calculation Method MINIMHM C[JRVAT[JRE Target Direction (DD) ......... Build\Walk\DL per: lOOft[)~ 30mi] 1Omi. ii Vert, Sec. Azim. 294.37 Uagn. to Map Corr. 22.880 Map North to: _O_T~!_E_.R' ................· ., ..,..c:Un~r:'{/DATA .............. Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section .... ~I-~'-~)--/-S(-~) E(+) / W--~:)- .... DE Build (+) Right (+) Comment _Type iF~__ (DD) {DD) _ . t.FT)__ ........ ~ ....... ~ <FT)__.. (Pe~ mo ~ Drop (-) ..... Le___~ff (_-) ................................................................ 12-NOV-94 MWD 9737.00 46.70 268.40 94.00 8938.86 1667.18 827.60 -1455.37 3.01 2.13 2.98 12-NOV-94 MWD 9836.00 49.50 272.50 99,00 9004.98 1734,53 828.23 -1529,02 4.18 2.83 4.14 13-NOV-94 MWD 9926.00 53.00 277.20 90,00 9061.33 1800.67 834.24 -1598.90 5.63 3.89 5.2.2 ! 3-NOV-94 MWD 10021.00 56.10 279.40 95,00 9116.42 1875,02 845.43 -1675.46 3.77 3.26 2.32 14-NOV-94 MWD 10110.00 60.70 281.40 89,00 9163.05 1948.57 859.14 -1749,99 5.51 5.17 2.25 14-NOV-94 MWD 10204.00 64.60 282.30 94.00 9206.23 2030.06 876.30 -1831.68 4.24 4.15 0.96 14-NOV-94 MWD 10297.00 69.20 282.00 93.00 9242.71 2113.64 894.29 -1915.28 4.96 4,95 -0.32 15-NOV-94 MWD 10389.00 70.18 284.40 92.00 9274.64 2198.28 914.00 -1999.28 2.67 1.06 2.61 15-NOV-94 MWD 10468.00 69.90 286.90 79.00 9301.61 2271.67 934.03 -2070.77 3.00 -0.35 3.16 16-NOV-94 MWD 10578.00 70,76 285.10 110.00 9338.64 2374.14 962.57 -2170.33 1.73 0.78 -1.64 ROTARY ASSEMBLY 16-NOV-94 MWD 10623.00 71.53 283.91 45.00 9353.18 2416.09 973.24 -2211.56 3.03 1.71 -2.64 16-NOV-94 MWD 10671.00 71.98 283.95 48.00 9368.21 2460.93 984.21 -2255.81 0.94 0.94 0.08 16-NOV-94 MWD 10727.00 71.88 283.68 56.00 9385.58 2513.26 996.92 -2307.51 0.49 -0.18 -0.48 17-NOV-94 MWD 10856.00 72.20 283.80 129.00 9425.36 2633.87 1026.07 -2426.71 0.26 0.25 0.09 -- , UNOCAL Debra Childers 909 W 9th Avenue Anchorage AK 99519-6247 Slate of Alaska Oil Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9950!-3! 92 907-279-1433 The following data is hereby acknowledged as being received: Well Name Granite Point 18742-11rd Description Formation Log Stratigraphic High Resolution Dipmeter Log (SHDT/GR) Phasor induction-SFL I IVI~; I IVIII~;~ ~--~,~'~ Borehole Compensated Sonic Log Compensated Neutron Log Compensated Densilog/Compensated Neutron Log/GR/CAL Dual Induction Focused Log/GR Dual Induction Focused Gamma Ray BHC/AC/G~C~ BHC/AC/GR/CAL Unocal Energy Resourc I Jivision g09 West 9th, P.O. BOX 1~o-'247 Anchorage, AK 995196247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL ) Debra C.hilders Clerk ~ - DATA TRANSMITTAL #5 Larry Grant 3001 Porcupine Anchorage,, AK 99501 Alaska Oil & Gas February 7, 1995 From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal One blueline and sepia of the following Granite Point 18742-11RD BHC Acoustilog / GR / Caliper 2" & 5" Dual Induction Focused Log / GR 2" & 5" Comp Densilog / Neutron / GR / Caliper Comp Neutron Log Borehole Compensated Sonic Log Hole Profile Log Phasor Induction - SFL Stratigraphic High-Resolution Dipmeter Log (SHDT/GR) Formation Mudlog tapes and listings RECEIVED FEB 0 7 1995 Alaska 0il & Gas Cons. Commission Anchorage URU~ML - Unocal- 76 I Il _ I .__ I . [ FAX Date, 10/1~/94 ... Number ofpa~$ including cover sheet: ~ To: Phone: Fax phone: CC: ack Itam FrOlll: C, Lee Lohoffer Senior Drill'..rog Engineer _ph. oit~: ___Fax phone: '-~- (907)_263.788~-~ RE~: F] Urgent IR] /For your r~icw F] Reply ASAP I~] Please comment · la reference to ~ 11 (AppHc of S'~' Approv~ No, 94-254 ~d Pe~t to Drill No.94-124) co~d you ple~e ~swcr ~e 1) Is it necess~ to tsg ~e cement ab~do~ent plug ~1 a prussic ~st ~ th~ casing bc s~cient? t'~*,~ ~ ~ ...... q~ s 1) Th~ ~b~g ~i which ~e BOPE ~U be ins~ upon is pr~cn~y a 3000 psi rating, ~c BOPE ~gn~ c~l~ for in ~e Pc~t is a 50~ psi rating. Uno~ ~ten~ to ab~don ~c e~s~ weUbore ~d ~ ~e 12-1/4" hole s~on ~th ~c 3000 psi w~llh~d ~em ~ a ~000 ~i BOP ~ted to 3~0 pa, once 9-5/s' ~sin~ is ~mentM ~ pl~ a 5000 psi ~bing s~l ~ ~ ~~ a w~ch ~c ~e 5~ psi ~ for ~e BOPE co~d ~ ~~, ~s is ~c~ble pl~se ad~. ~ ~. , I ~4~ ~1 tomo~ow ~g~y ~to~r 14 to ~s~s ~er in dc~l. Th~s, M~ L, P.S, i ~11 pl~ to ab~t mo~e i~o~fion on ~ 3 ~11, probably sombre ne~ week. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 27, 1994 G. Russell Schmidt Drilling Manager Union Oil Company of California (UNOCAL) P O Box 196247 Anchorage, AK 99519 Re: Granite Pt Field. llRD UNOCAL Permit No. 94-124 Sur. Loc. Leg 1, Slot 1, GP Pltf Anna 729'FNL, 636'FEL, Sec. 12, T10N, R12W, SM Btmnhole Loc 680'FSL, 3624'FEL, Sec. 1, TiON, R12W, SM. Dear Mr. Schmidt: 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. 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 petroleum field inspector on the North Slope pager at 659-3607. Chairman~By ORDER OF THE ~~SSION dlf/Enclosures cc: DePartment of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA STATE OF ALASKA .AND GAS CONSERVATION COMi .~SlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work" Drill ~] Redrill ~ Ilb. Type of well. Exploratory ~ StratigraphicTest [-] Development Oil Re-Entry ~ Deepen ~I Service [-I Development Gas [-] Single Zone rl Multiple Zone 2. Name cf Operator 5. Datum Elevation (DF or t~) 10. Field and Pool Union Oil Company cf California (UNOCAL) 105 KB, MSL feet Granite Point Field 3. Address 6. Property Designation Middle Kenai "C" Sands I.P.O. Box 196247, Anchorage, AK 99519 ADL 18742 4. Location cf well at sLrface Leg 1, Slot 1, GP Platform Anna 7. Unit or property name 11. Type Bond (SE~ ~ACC 729' FNL, 636' FEL, Sec. 12, T10N, R12W, SM Granite Pt Field AK Statewide Oil & Gas Bond At top cf productive interval 8. Well number Number 264' FSL, 2704' FEL, Sec 1, T10N, R12W, SM 11RD U62-9269 At total depth 9. Approximate spud date Amount 680' FSL, 3624' FEL, Sec. 1, T10N, R12W, SM $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth 0v~ and'rVD) property line 2576 feet (Well #26) 750 feet 5060 11,700'/9711' feet 16. To be completed for deviated wells 17. Anticipated Pressure(,~ ~0 Mc 25.o35 (~(a) Kickoff depth 3300 feet MaximLrn hole angle 70.57 Ma~murn,u~ce 1800 pslg At totaldepth ~/D) 4000' pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 13-3/8" 81,54.5 3196' 0 0 3196 2969 Existing Csg (2400 sx) 12-1/4 9-5/8" 47 L80 BTC 8550' 0 0 8550 8075 985 sx D I: 8-1/2" 7" 29 1_80 BTC 3350' 8350 7915' 11700 9711' 6508xI~ F. ~L.! V L ,~FP ]9 1904 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary A~ska 0il & Gas Cons. Cor Total depth: measured 10,264' feet Plugs (measured) Abandonment Plugs An~.hnr~, ,.>. true vertical 9206' feet 10105'-9600' MD 9057" "8~'F4~ 9600'-8950' MD 8574'-6280' TVD Effective depth: measured 8950' feet Junk (measured) Fill @ 10105' MD (1989) true vertical 6280' feet Casing Length Size Cemented Measured depth True vertical depth Structtxal Conductor 629' 20" 585 sx 629' 629' Surface 3196' 13-3/8" 2400 sx 3169' 2969' Intermediate 7873' 9- 5/8" 425 sx 7873' 7026' Production Liner 2582' 7" 675 sx 7681 '- 10263' 6853'-9205' Perforation depth: measured See attached table true vertical 20. Attachments Filing fee E~ Property plat [~ BOP Sketch[~ Oiverter Sketch ~ Drilling program E~ Drilling fluid program [~ Time vs del~h plot E~ Refraction analysis ~] Seabed report ~ 20 AAC 25.050 requirements 21.1 hereby certify tl~~~o the best of my knowledge Signed G. RUSSELL SCHMIDT Title DRILLING MANAGER Date 09/07/94 Commission Use Only Permit Number I API number I Y'~es See cover letter Approv~_,d~a:~e 7- for other requirements ~-/~ ~ 15o- ?~ ~ - .2_.o~ ~'2,-- o / Condition's of appro(/al Samples required r"1 Yes .~ No Mud Icg required E] .~ No Hydrogen suffide measures r-1 Yes ,~ No Directional survey required ,~ Yes E] No Required working pressure for DOPE Fl 2M; E] 3M; [~ SM; r-] 10u; ["1 15M Other: Original Signed By by the order of Approved by David W. Johnston Commissioner the commission Date ?//'~. ?//~ ~missi0n Form 10-401 Rev. 12-1-85 Submit in triplicate Anna 11 Perforation Intervals Prior to Abandonment RECEIVED SEP 1 9 i994 Alaska Oil & Gas Cons. Commission Anchora,j~: 11 PROCED.XLS ANNA 1 1RD Outline 1. Rig up 2. Abandon existing completion. 3. Cut and pull 9 5/8" casing at 4. If (3) successful continue, if 5. Set KOP plug. · 9. 10. 11. 3500' not cut & pull & mill to 3500'. 6. Control, directionally sidetrack off of plug. 7. Directionally drill 1 2.25" hole to base C3 (8550) See attached directional program for details Run & cement 9 5/8" casing. Directionally drill 8.5" hole to TD. (11 700') Run and cement 7" production casing or liner Completion (TCP w/dual string tbg & Kobe pump) RECEIVEE SEP '~ 9 Gas Cons. Commisstor Anchora,,,¢ Page 1 11 P ROCED.XLS TimeEst. 0.33 1 0.13 0.25 1 1 0.5 0.75 0.75 0.33 0.5 0.13 2 1 19.12 1 1 19.1 1 1.94 1.5 0.67 0.75 0.33 1.12 1 Cum Time 0.33 1.33 1.46 1.71 2.71 3.71 4.21 4.96 5.71 6.04 6.54 6.67 8.67 8.67 9.67 9.67 9.67 28.79 28.79 29.79 30.79 49.89 50.89 52.83 54.33 55 55.75 56.08 57.2 58.2 58.2 ANNA 11 RD Preliminary Procedure: 1. MIRU, Leg #1, Conductor#, 0Nell 11). 2. Pump FIW to kill well.Set BPV. Nipple down tree. Nipple up 13 5/8" 5000# BOP's. 3. Rig up and pull simultaneously on both strings (simply ensure they're "moveable"). 4. RIH and cut short stdng. 5. POOH wi short stdng. 6. POOH w/long stdng. 7. RIH open ended. Should tag fill (~ 10105' 8. Lay cement abandonment plug form 10105'-9600' 9. Lay second cement abandonment plug from 9600'-8950' 10. RIH and set EZSV inside 9 5/8" casing ~ 3650'. 11. POOH. Rig up to cut 9 5/8" casing 12. RIH and cut 9 5/8" casing @ 3500' 13. Pull 3500' of 9 5/8" casing from well bore. If cut & pull unsuccessful may need to mill some. 14. Place top cement abandonment plug from 3650'-3100' Top of plug is 100' inside sfc csg. Have enough excess to squeeze sfc csg shoe. 15. Directionally ddll 12 1/4" hole from 3400'-8550' (50' below base of C3) 270 fpd 16. Run open hole logs conventionally. 17. Run and cement 9 5/8" casing to 8550' (Clean out & circ & cond pdor to run csg) 18. Directionally drill 8 1/2" hole to 11700' TI;). 165 fpd 19. Run open hole ddll pipe conveyed logs. 20. Run & cement 7" liner from TD- 8400'. 21. Clean out inside of liner. 22. Circulate well over to 3% KCI fluid. 23. Run SBT/NEU/GR log from ETD to TOC in 9 5/8" csg. 24. Make up TCP guns on bottom of dual completion w/Kobe BHA. 25. RIH wi TCP/Completion. Land in place. (guns 10630-11530'+/-) 26. Set BPV. Nipple down BOP's. Install wellhead. 27. Release dg & turn well over to production. Rev. 1 9/2/94 RECEIVE_r) SEP 19 19~4 Ai~,$ka V;I & Gas Cons. Anchor~.~.~, Page 2 2OO0 6O0O 80OO 1O0OO 12OOO Anna 11/11RD Days 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 33 35 37 39 41 43 45 47 49 51 53 55 57 Days 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 22 23 24 25 26 27 28 29 3O 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 5O 51 52 53 54 55 56 57 58 Depth 0 9800 9800 10105 9600 8950 3500 3500 3100 3400 3671 3942 4213 4484 4755 5026 5297 5568 5839 6110 6381 6652 6923 7194 7465 7736 8007 8278 8549 8550 8550 8716 8882 9048 9214 9380 9546 9712 9878 10044 1O21O 10376 10542 10708 10874 11040 11206 11372 11538 11700 11700 11700 11700 11700 11700 11700 11700 11700 End P&A Start Drilling 12 1/4" hole Int Csg point Drill 8 1/2" hole TD RR 11 DAYDEP.XLS Anna 11/11RD Days 7 13 19 25 31 37 43 49 55 RECEIVED S EP 19 1994 Alaska UIt & Gas Cons. Commission Anchora.~: . 3FLOW FILL- UP {;> ~ ANNULAR BOP 13~/~5000 psi PIPE RAMS 13s/~'' 5000 psi BLIND RAMS 3"- 10M 13%"5000 pm CHECK VALVE HC~ HCR ~ MANUAL I DRILLINGi MANUAL ~-~ KILL __.>~...~ 7r-..l~/r~ SPOOL LINE ~~ x~ill~3~ooo ~ ~~J/~~~ CHOKE 3,'_lOM// ''[ GATE VALVES [ PIPE RAMSI GATE VALVES 13%"5000 psi LINE~ RISER 13%" 5000 psi RECEIVED SEP 19 i994 Alaska 0il & Gas Cons. Uommissi~ CHAKACHATNA RIG 428 BOPE STACK 13 '%" 5000 psi VENT OUTSID£ OF WlNDWALLS PANIC LiNE "~ q' 5,000 PSI BALL BUND WlLLI$ ADJ. 1/16-514 HUB VI/BXI55 514 TARGET BLIND HUB t5 CLA~P W/ BX!55 4 I/1~' -514 AG. 10,000 PSI HYD. CHOKE VENT UP DE~RICK 3' RELIEF VALVE SET AT 40 PSI I0' VENT LINE CLA~P HUB CONNE~ON BUFFER TANK TO PRODUCTION SEPARATOR SE]aERATOR UNOCAL CHOKE YANIFOLD COOK INLET DWG. CM-I:12592 150 lb. BUND FLANGE ('/YP'~g~S~E {~ & GAS COBS. 10' 150 lb. FLANGE SIPHON LINE 150 lb. FLANGE I TO 8' MUD RETURN UNE I I V 2700 3900 4200 45O0 69OO 72OO 78OO 8100 87OO 950O 10200 SECTION $;dlTmck F~! 13 ,I/8 C~r*q Z6.68 23.69 I DROP ~J~GLE 20.71 I 17.75 ORIENT HOLE TO 247 AZ i*.76 11.81 8.68 )A - uOlOR ASSEMBLY I 6.05 B - PENDULUM AS,~[uBLY 3.45 End Drop SECTION ~2 M~NTAIN LOW ANGI r CONTROL AZIMUI~ DRIFT · -- PACKED HOLE ASSEMBLY B - PENDULUM ASSEMBLY SECTION UNOCAL Structure ' ANNA Platform Well · llRd#1 Field · Granite Point Field Location : Cook Inlet, Alaska I BUILD ANGLE I CORRECT I.IOLE D~R"ECTIOH T0 247 ATJMUTH +/- j A - MOTOR ASSEMBLY .25.00 B - ANGLE BUILD ASSEMBLY 32.50 ~ Buikl id~JNTAIN ANGLE / DIRECTION I SECTION f4 ~, A - PACKED HOL~ ASSEMBLY - SUCHT ANGI.[ BUILD ASSEMBLY TURN AZIMUTH RIGHT 47 sE ,,o, f5 .j,,, IA- MOTOR ASSEMBLY ~,,,.~.~ I, - 'NOir BUILD ASSE'BLY [ TARGET ~1 (C7 Top) / EOC OR TARGET f2 (C5 ~t)~'"'"-.,. I OEOLOGICA~Y ~ I J B - MOTOR ASS~"BLY 9 ~ 600 g~ 12~ 1~ 18~ 21~ 2400 2700 ~ 3300 Scole I - 150.00 Vertical Section on 295.65 azimuth with reference 0.00 N, 0.00 E from slot WELL PROFILE DATA Point UD Inc Oir ~ North East Deg/100; 3qe on 3300 28.74 13.77 3066 955 248 0.00: End of Drop 4320 3.00 247,31 4046 1188 283 3.00. KOP 6700 3,00 247.31 6423 1140 168 0.00' End of Build 8046 36,65 247.31 7671 967 -247 2.50' End of Hold 8654 36.65 247.31 8159 827 -582 0.00 Target 10630 70.57 294.30 9355 993 -2068 2.50' Tarqet 11531 70.57 294.30 9655 1343 -2843 0.00' <-- West Scale 1 : 150.00 3000 2700 24-002100 t800 I I i i [ I I I 15~30 1200 ! I I 600 30O 0 3OO I I I I I I [ I f2 600 I I _~200 A I - I · 900 g o _,.300 - Created by : jones iDate plotted : 25-Aug-94 ',Plot Reference is l lRd Version #¢. ',Coordinates ore in feet reference slot #1-1. lrue Vertical Depths are reference wellhead. --- Baker Hughes tNT£Q --- Anticipated Pressure: Maximum Surface Pressure Calculation; Mud Weight ............................................. Shoe (13 3/8") Depth ................................ Estimated Fracture Gradient (13 3/8" shoe) Total Depth .............................................. Bottom hole pressure gradient ................... Gas gradient (assume worst case) ............. ANNA 11 RD 9/14/94 8.5 ppg 3196 feet MD 11700 feet MD 0.442 psi/ft 2969 feet TVD 1.1 psi/ft 9711 feet TVD 0.42 psi/ft 0 psi/fi` Wellbore volume with gas kick situation: 3/4 mud & 1/4 gas Maximum surface pressure=Bottom hole pressure-hydrostatic pressure MSP = BHP - (3/4 mud + 1/4 gas) MSP = (9711'.42)-((0.75'(9711'.442)),(.25'(9711'0))) MSP = 859 psig Therefore the greatest hydrostatic pressure at the 13 3/8" shoe (HPsh) is when the gas bubble reaches the shoe, if a constant BHP is applied. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the casing depth (HP csg) HPsh = MSP + HPcsg HPsh = 859 + (2969*.442) HPsh = 2172 psi This (HPsh = 2172 psig) is less than the fracture pressure at the same shoe. (FPsh = 1.1 psi/ft * 2969' = 3266 psig) and thus sufficiently adequate to handle a well kick. This scenario is considered extreme since actual well kicks have seen maximums of 300 psig on the shut in casing. RECEIVEF) SEP 3 9 '~99~ Alaska iaii & Gas Cons. L;gll~,lmlSS~o," Anchora~.?. Unocal Energy Res, -~, ' Division Unocal Coroorat~on 909 West 9th Avenue. ~.O. Box 196247 Anchorage, AlasKa 99519-6247 Yeiepnone 1907) 276-7600 UNOEAL., :-asKa July 1, 1994 Environmental Protection Agency Region X 1200 Sixth Avenue Seattle, WA 98101 Attention' Kris Flint NPDES Permit Cook Inlet/Gulf of Alaska AKG 285004 Anna Platform Dear Ms. Flint: Unocal plans to drill six wells: 3RD, 11RD, 50, 51, 52, and 17RD on Anna Platform. The anticipated spud date for the first well is August 1, 1994. Wells 50, 51 and 52 will be batch drilled. The same mud formulation will be used on each well. Unocal requests approval of these fluids for each of these wells. Three drilling fluid types are proposed for use on the Anna Platform wells. The first is Generic Mud #1 from Table 1, page 50 of 54, of the Cook Inlet/Gulf of Alaska permit, with additives from Table 2, pages 51-53. The second is Generic Mud #2 from Table 1, page 50 of 54, of the Cook Inlet/Gulf of Alaska permit, with additives from Table 2, and additional materials. The third drilling fluid is a Non-Generic KCi mud also approved and used by Unocal on the Bruce and King Salmon Platforms. Unocal has requested approval for the Granite Point Platform. Unocal anticipates using only one mud system per well. However, two of the three mud systems may be used on the same well. An example of how this would work is as follows - we would use mud system (1) on the intermediate hole section and mud system (2) on the production hole section. We would have mud system (1) circulated from the wellbore and removed from the mud pits prior to mixing mud system (2). Under no circumstances would mud systems be mixed or combined. P~ ~ (~ E IV ~ ,~[:~p 1 9 i994 Gas cons. C0mmissior' Anch0ra: ;~ July 1, 1994 Ms. Flint Page 2 The Generic Mud Cf 1 proposal uses only those products listed in Table Cf 1 and Table cf2. The Generic Mud cf2 proposal is identical to the muds and additives authorized for Baker #28, 29, 30, and King Salmon K-26. Note' The original request for 3 ppb of XC Polymer/Xanvis/Biozan was only authorized at 2 ppb. Mud #3 is a Xanvis FLO-PRO, Non-Generic Potassium Chloride mud system which is already authorized for use on Bruce 42-2, B-30, and King Salmon K-24. Xanvis FLO-PRO is used to drill the production interval. Generic Mud #1 Permit Component Name M-I Trade Name Maximum Allowable Concentration KCi KCl 50 PPB Starch Polysal, FL7+, Biolose 12 PPB Cellulose Polymer Drispac, Polypac Reg., Drispac SL. Polypac UL Thermpac UL 5 PPB Xantham Gum Polymer XCD Polymer, Xanvis 2 PPB Drilled Solids 100 PPB Caustic Caustic 3 PPB Barite M-I Bar 575 PPB Seawater/Freshwater As Needed July 1, 1994 Ms. Flint Page 3 Permit Component Name Aluminum Stearate Gelex Flakes of Silicate mineral Mica Nut Hulls, crushed, granular Sodium Chloride Sodium Acid Pyrophosphate Chrome free organic mud thinner containing sulfomethylated tannin Vegetable Plus Polymer Flakes & Granules Resinex Oleates in mixed alcohol Scitex Fatty Acid esters aikyi phenalic sulfides in a solvent base Organophyllic clay Glass beads Plastic spheres (Generic Mud # 1) Table 2 M-! Trade Name Maximum Allowable Concentration Aluminum Stearate 0.2 PPB Gelex Mica 1 PPB 45 PPB Nut Plug Stock Salt As Needed 50,000 mg/I chloride SAPP 0.5 PPB Desco CF 0.5 PPB Kwik Seal 50 PPB Resinex 4 PPB Lube 106 2 PPB Scitex 6 PPB Bit Lube II VG-69 2 PPB RECE VEC) 12PPB SEP '~ 9 '/99~ 8 PPB A!ask~ Oil & Gas Cons. Commission 8 PPB Anchor~...?; July 1, 1994 Ms. Flint Page 4 Generic Mud #2 Permit Component Name M-I Trade Name Maximum Allowable Concentration Bentonite M-i Gel 50 PPB Lignosulfonate Spersene CF 15 PPB Lignite Tannathin 10 PPB Caustic Caustic 5 PPB Lime Lime 2 PPB Barite M-I Bar 575 PPB Drilled Solids 100 PPB Soda Ash/Sodium Bicarb. Cellulose Polymer Seawater/Freshwater Soda Ash/Sod. Bicarb. Drispac/Poly Pac Reg. Drispac SL/Poly Pac UL/ Thermpac UL, Polysai 2 PPB 5 PPB As Needed July 1, 1994 Ms. Flint Page 5 (Generic Mud #2) Table 2 Permit Component Name Aluminum Stearate M-I Trade Name Aluminum Stearate Maximum Allowable Concentration 0.2 PPB Gelex Gelex 1 PPB Flakes of Silicate mineral Mica Mica 45 PPB Nut Hulls, crushed, granular Sodium Chloride Nut Plug Stock Salt As Needed 50,000 mg/I chloride Sodium Pyrophosphate SAPP 0.5 PPB Chrome free organic mud thinner containing sulfomethylated tannin Desco CF 0.5 PPB Vegetable Plus Polymer Flakes & Granules Kwik Seal 50 PPB XC Polymer Resinex Xanvis/Biozan Resinex 2 PPB 4 PPB Soltex Soltex 6 PPB Organophillic clay Sulf-X ES VG-69 Zinc Oxide 12 PPB As Needed RECEIVED SEP 19 1994 Ataska Uil & Gas 6ons. Oommission Anchor~,~,¢ July 1, 1994 Ms. Flint Page 6 (Generic Mud #2) Additional Materials Product Maximum Allowable Concentration Defoam X Polyplus (PHPA dry) Tackle PH-6 SP-101 Lube 167 or Tek Mud 8588 0.3 PPB 3 PPB 1 PPB 1 PPB 3 PPB 2% v/v Mineral Oil Spotting Fluid Component Name M-I Trade Name Kwik Spot Kwik Spot Mineral Oil Conoco LVT SEP 1 9 199~ Gas Or)ns. Commission Anchoragu July 1, 1994 Ms. Flint Page 7 Mud #3 Xanvis FIo-Pro Product Maximum Allowable Concentration Xanvis 4 PPB Caustic 1 PPB NaCl 50,000 mg/I chloride KC! 3 % V/V FL7 + 3 PPB Lowate (calcium carbonate) 75 PPB Please see the Cook Inlet/Gulf of Alaska permit for additional details pertaining to substitution of products and handling of mineral oil pills. Bioassay data for the additional materials is available on request. If you have any questions, please do not hesitate to contact me at (907) 263-7832. Sincerely, G. Russell Schmidt Drilling Manager AZRB/kpm RECEIVED S EP 19 1994 Aiaska. Oil & Gas Cons. Cornrnissior~ Anchora:~ July 1, 1994 Ms. Flint Page 8 bcc Lee Lohoefer Jamie Ressler Bob Haagensen, M-I Drilling RECEIVED SEP 19 i994 Alaska 0ii & Gas Cons. 6olnrnission Anchor~,~ NTAL PROTECTION AGENCY )N 10 1Avenue ~lngton98101 Rep~y To At'tn Of: WD-137 Alice Z_R. Bullington Unocal Corporation Post Office Box 196247 Anchorage, AJaska 99519-6247 Re: NPDES AKG285014, Anna Platform, Well Nos~ 3RD, 11RD, 50, 51, 52, 17[=1D Dear Ms. Bullington: We have completed review of your July 1, 1994, request for au[hortzazion to discharge any one of three. proposed mud/additive systems from Well Nos. 3RD, 11 RD, 50, 51, 52, and 17RD on the Anna Platform. Au[horization to discharge for each of me proposed mud/additive systems follows. Genedc Mud 1 Based on our evaluation of the proposed combination of generic mud I and additives from Table 2 of the permit, only some of the additives may be discharged In generic mud 1. Additives for discharge in generic mud I are limited as shown below because our wors~-case cumulative toxicity estimates Indicate that toxicity of the discharged mud (with all proposed additives) is likely to exceed the Agency's toxicity criterion of 30,000 ppm SPP. The following mud additives may be discharged in generic mud 1 at the concentrations listed on Table 2 of the permit. ° Aluminum stearate ° SAPP ° Vegetable plus polymer fiber, flakes and granules Flakes of silicate mineral mica Inert spheres (glass, plastic) Generic Mud 2 Discharge of ~he following additives is aubhorized in generic mud 2, with additives from Table 2 of zhe permit, as requested. You must notify EPA if any additives from Table 2 ot~ than those li~ted in your July 1, 1994 request w~! be present in the discharged mud. ° $P-101 (acrylic polymer), maximum discharge concentration shall not exceed 3 Ib/bbl ° Tackle (Iow molecular weight polycarboxylic acid salt), maximum discharge concentration shall not exceed i lb/bbi PHPA (also known as Poly Plus, high molecular weight anionic polymer), maximum discharge concentration shall not exceed 3 Ib/bbl Defoam X (blended defoaming agen[s), maximum discl'arge concentration shall not exceed 0.3 Ib/bbl PH-6 (carboxylic acid buffer blend), maximum discharge concentration shall not exceed 1 Ib/bbl Lube 167 or Tekmud 8588 (lubricants), maximum discharge concentration shall not exceed 2% v/v R ECE IV E S EP '1 9 1994 Alaska 0il & Bas Cons. Commission -2- ° XC Polymer and/or Xanvis and/or Eliozan (xan[tan gum and wetan gum polymers, respec~e~y), zota~ product concentration in discharge shaJl not exceed 2 I/bbl No~e that bioassay tes~ repo~s submi~ed pursuant to Part II.B.l.k. of ~ permit, should include an inventory of mud components and adcr~fives present in the sample. The un~ repotted on the inventory for the sampled mud should be the same as the units of aufl3orizat~on (e.g., "lb/bbl,' ' % v/v,' ' rng/i chloride'). We also give interfm authorizazion for the discharge of residual amounm of Kwiksp~ mineral oil pill, formulated with Conoco LVT mineral oil, in generic mud 2. Should this formulation be used, we require that as much of [he pill as possible be removed prior to discharge of the mud. Residual mineral oil concentration in the discharged mud Shouid nc~ exceed 2% v/v. Tt~ discharged mud must comply wi[h Pans II.CA.f., g., and J. of the pennk which also pertain to the discharge of residual mineral oil pal. -.. ° the dale of discharge ° the results of the On'lling Fluids Toxicity Test on a sample of the discharged mud which conlains the maxfmum concentration of mineral oil discha .rc~ed ° the mineral oil product used ° v~lumes of Kw]'kspot spotting compound, mineral olt, water and barite in the pill ° total volume of the pill. total mud volume ° __~mated Kwik, spot spotting compound and oil content of the above sample, as determined from amounts added and total mud volume ° measured oil content of the above oil samite, as determined by the AP! retort method ° totaJ volume of dnlling mud contair~ng pill recovered ° estimated percent recovery of the piti (indude calcula~r~) ' an l~emization of other drilling fluld specialty additives contained in me discharged mud Also note that Part ILC. I.j. of the peru-fit requires that chemical anaJyses for metals shall be provided for eaoh discharged mud sy~em that has comained mineral oil additive& Nongenerio Xanvis Flo-Pro Mud We authorize the discharge of the following potassium-based mud/additive system on an interim basis. Since the following formulation is nongenertc, additives from Table £ of the permit may not be discharged v~hol~ prior authorization from Region 10. This interim auth~ is based upon Our previous evaluation of the proposed mud/addi~ve system and upon end-of, well bloassay data ~ discharge of this same nongenerlc mud/additive system from ot~er platforms in Cook Inlet. The nongeneric mud/add~Jve system shall be sampled for bioassay when the maximum anticfipated number of mud components and add~iv~ are in use. A list of mud componen[s and additive present in the saml~e_mus~ accompany trrte bioassay report. Product concentrations may be reported in I;erms of me same units as authorized below. (E.g., report pom~um chloride in '% v/v', n~ 'lb/bbl'.) I I iii RECEIVED S EP ]9 199~ Ai~ska. Oil & Gas Cons. Cornmissiop. Anchora!~,~ -3- The following table lists authorized mud components and additives. The concentrations shown are maximum vaJues and are not to be ~xceecled in ~he discharged mud. Component/Additive Maximum Authorized Concentration (Ib/bbl unless stated otherwise) Xarwis (xanthan gum polymer} Causth3 (potassium hydrox~e) Sodium chlodde FL7 + (crossllnked deriv~ized starch) Lowate (calcium carbonate) Potassium chloride 4.0 50,000 rng/I chloride 3.0 75.0 5% v/v Any questions concerning this letter may be addressect to Kris Rint at (206) 553-8155. Sincerely, Charles W. Rice, Chief Ocean Programs Sec[ion co: Robert Dolan, ADEC/Anchorage RECEIVED SEP I 9 1994 Alaska Oil & Gas Cons. Commission Anchorage Reply To Attn Of:. WD-137 MEM. O .RANpU UNITED STATES ENVIRONMENTAL PROTECTION AGENCY REGION 10 1200 Sixth Avenue Seattle, Washington 98101 SUBJECT: TO; FROM: Backgroun~l Specialty Mud/Additive EvaluatJon and AuthodzaZion - Cook Inlet · 5O, 51, 52, 17RD On July 1.1994. Unoc~ requested authoriza~on to discharge both generic and non-generic dn31ing mud/additive systems from wells 3RD. 11RD, 50, 51, 52, and 17RD on the Anna platform. UnocaJ proposes to use 3 separate mud/additive systems. ~J're tru~ two systems are based on generio muds 1 and 2 (as aut13orlzed on Table 1 of the perrnk), while the third system is nongeneric. Of these three proposed mud/additive discharges. Region 10 has prevloush/evaluated and authorized two. Each proposed mud/additive system is discussed in detail below. Evaluation - Generic Mud I Based on the cumulative discharge toxicity estimaZed below, Region 10 cannot authorize the disctarge of any additives In this generic mud except for those which do not exhibit any apparent effec[ on the tox/city of discharged mLMS. 1/LCSOca. = 1/LCS0eM~ + 1/LC50. + 1/LC50..~ .+ .... where 1/LC50o~m = the estimated ctlmulatWe to3dcity of the proposed discharge, 1/LCS0~M~ --- the toxicity of the base mud (generic mud 1), and 1/LC50. & 1/LC~.+~ = respective toy/city of proposed additives to the base mud 1/LC50~. = (1/30,000) + (1/26,100) + (1/662.000) LC50~M~ = 30,000 ppm SPP (EPA 1984) LCd0.= 261,000 ppm SPP (California Mud, El-lA ~Z64, 4/84 con~ning Res/hex, Bit Lube II, aJurrdnum stearate, mica & nut hulls as proposed) LCS0.+~ = 662,000 ppm SPP (Alaskan Mud, EHA ~84399, 5/84 containing Desco CF, Benex, Durenex. $oltex, as proposal~ plus other additives) 1/LC50cu,. = 3.86753 X 10.~ so, estimated 96-hr LCS0 for 1~3e proposed discharge is 25,856 ppm SPP_ This level is below the Agency's [oxicity crimrion of 30,000 ppm SPP (i.e., i[ is more toxic)~. In the besl: professional judgement of Region 10 only those additives which have not demonstrated any effect wilh respect to discharge toxicit~ may be discharged in generic mud 1. Of the additives proposed for discharge in this mud, only the following are authorized: ° Aluminum stearate ° SAPP ° Vegetable plus polymer fiber, flakes and granules Rakes of silicate mine~l mica Ine~ spheres (glass, plastic) O~ &._ ~,~:Gas Cons.~.~ -2- Evalue. t~on - Generic Muds 2 W'¢h Additives The generic mud/additive system proposed by Unocal has been eval[~ted and authorized by Region 10 for discharge from the Baker and KTmg Salmon platfor[~ tn the past. (See attai:hed memos for Baker Wells 28, 2g & 30 and ICing Salmon K-26), Based on these prior evaluations and bioassay da~ for the disc~e of used muds (see AEa~e~ A: Mud Comparison Table: UNOCAL Anna), in ~ bes~ professional judgement or'legion 10, it is unlikely thai: the discharge of this mud/add'~ve system v~ql exceed the Agency's toxicity criterion of 3o,~00 ppm SPP. EvaluaUon - Noageneric Xanvis/FIo-Pro Mud As with the generic mud/add~ive system above, the system proposed ~y UnocaJ has been evaluated and authorized by Region 10 for discharge from other 1:;~2f~ in Cook Inlet. (Seer attached memos for Bruce Wells B-3RD & 42-2 and Dolly Varden Well DT-RD2.) /~achment B compares the propesed mud/additive system ('in the column labelled '1~tasic Feb'mCa') ~ the cr~scharged ¢_.or~ena'ations of this system from other wells. 9643r LCS0 values are also provided on this table. Note that toxicity of this nongeneric mud system ranges from 23,724 ppm SPP (when mud was not ~ged) to 279,483 ppm SRP. Whl~e the range of toxicJty exhlbEed by the mud/additive system is broad, no discharge of the mud at a toxicity of less mn 30,000 ppm SPP occurred. Thus, ba~ed on prior evaluations and bioa_'-_<~y data for the ~scharge of this mud/additive system as a used mud, Region lO authorizes the dLscharge of the nogeneric XANVIS or FLO-PRO mud/additive system. Attachments:. Atmchmem A: Mud Comparison Table for UNOCAL Anna; Mud Type Gemeric Mud 2, T2 Additives & Other Additives Comparison Table for XANVIS ~ FLO-PRO Muds, Nongeneric, Potasslum-CHi~~ Used Muds Memo to NPDES File AKG285005, Unocal, Baker Wells 28, 2~ & 30 (dated 7/6/93) Memo m NPDES Fi~e AKG285008, Unoc¢, i~Tmg Salmon Well K-26 (da~ed 10/20193) Memo to NPDES File AKG285(X~ Unocal, Bruce Well B-3RD (dated 10/20/93) Memo ~o NPDES File AKG295006, Unocal. Bruce Well 42-2 (dated 6/4/94) Memo to NPDES File AKa, Marathon. Dolly Varden OT-RD2 (dated 2/2/93) The mud represented by fffis bioassy datum contained Benex ('instead of the requesled Gelex) and Ourenex (instead of the requested Resinex). Region 10 regards bo'¢ of these produc~ pairs (',-e., Getex~ and Durenex/R~) as functional ecr¢. ivalents and, in editions of Table 2 in the Beaufort Sea II and Chuk~ Sea general permits (issued subsequent to the Cook Inlet permit), Itmse addil~ves am authorized as being interchangeable. Other additives represented by this bioassay report' (but not proposed by Unocal) are XC Plymer (xanthan gum), Pact. (pdyanionic cellulose polymer), and Bara Brine Defoam. Toxicity is the inverse of an LCSO value; so. as the LCS0 value Increases, the tox~ associated with them~i/additive decreases. For example, an LC50 of 1,000,000 ppm SPP is less toxic than the Agency criterion of 30,000 ppm SPP. ' RECEIVED SEP 19 1994 Alaska 0i1 & (~a's Cons. Cot~mission ~?~ 46.1 0.7 03 O..2 2.4 &O.] 67 0,2 o.1 0,9 & 1~ 0.6 O.2 PACa fo~ B-29 &-28 lis~xl ~y Additives i-om Table 2 ofl:~rmi~ Almninum Mica ;alt ;APP D~,co CF O..7. 1 4~ o,~ $o 0.02 0,01 xc Polym,= (~mlhm gum) Rc~inax goltex VO,69 ^0kiitiv~ NOT on T~ble 2 o£ .]~nit , 2 4 6 12 4.[ 0,2 7..6 L~t'oam.X Polyplus (PHPA dry) Tackle ' PH.6 SP. IOl Lul~ 167 or T~.Mud tL~g8 ~ Kw'~'pol (w~:a-~ Lv'r) 0.3 1.8 05 0.3 3 o.~ & 0.2~ Information 0.3 1,6 Z7 RECEIVED ~G285005, ~, ~2g, ~v~t~ ~~ " > 1,~0,0~ ~m SPP ~~ ~20, ~ ~ ~1 ~4, ~la ~ 3/1704 (~~g r~ NOT a ~n~ ~0 ~ ~1 m~ ~i~ t~)) NOt AKG285~ ~ ~m~ 26, ¢,!aska u, & Gas Cons. Commi Anchorabo ion Gonc~tzatiom (in Ih/bbl) ~ ~ as"MAX/PPB" mmninglh~soar~ I1~ maximmn c~amnlrafiom u.~lnta~y lim~ du~ well. The~ arc not ~y pt'~ in th~ tao~m~-x~ mod. ha'thor mm:: This mini w~ NOT disdmg~ it was "lose ~o (atrg)t0~ by) fl~o formago~, ./ 1 3 lo.ooo rt~ c Bmca B-3RD Ost tarsi) 1/17/94 I 7,/6~94 2/22/94 '"1~ ^ 10F2A'~3 0.~ ~,) 2,: 0.2 (~) ~.~ ~'~ ~ ,,.,,.,, .:~.:..~,.~ 11.6 1.7 21.9 1.6 (++) 0.1 1.7 ', 9.1' (.~,-) ~1.' .... · '. . .:'.. 5.1 0-2 (.~-) ~,~ , I o.58 7,-g [I 1.~6 C") 10.~[ (*) ~4.0~ 33.9Jl 7-32 NOT DLSC~D · · NOT DL~:~*z,J~GED RECEIVEE RFP '~. 9 i9'-'4,, Anchora CUTI?N¢$ DI$CI~.RGE ? ....... ~-~,-N ............... -~1 ...... , Ill ~ ~.~ ........ ~1 " ' i /1/ ~.--tt1: ~ ,rill ,~iI/ ] ..... i / / ........... /Fss ; I/II //m~/===/ I / i//lJ.~~~_lll / / ~:~ / :: ' :'::' :: / I / ~ ~//I I~ ~r, ill ' // ~~l~/ ........ / / Jl ~',~.._._~..~ ./~:.q'.z&~/ ....... ~ ....... i .............................. .................... / I ~.~ 1 ~ CUIrlNGS DISCII4RG£ 'ID .% LOW PRESSURE UUD ~ UNOCAL CHAKACHAINA PROJECT PM RIG 4.28 -~tdd;-%1--1,T,I .,.~o,, 100 1100 2100 3100 4100 5100 6100 7100 8100 9100 10100 11100 11700 Anna 11 New Status (Post-Redrill) Z 0 TCP GUNS 10629'-11531' RECEIVED SEP 19 1994 Gas Cons. Commission Anchore~o Unocal North America,? Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region September 13, 1994 Alaska Oil & Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501-3192 Dear Sir: Attention: Mr. David Johnston, Commissioner Re: Anna Platform - Well 11/11RD Unocal Oil & Gas Operations hereby makes application to plug and abandon the existing well (Anna 11) back to 3500'. This depth (3500' MD) is the kick off point for the new well (Anna 11RD). Anna 11RD will be drilled and completed in the Tyonek C5 and C7 sands. The proposed bottom hole location of Anna 11RD is approximately 750 feet away from the closest well (Anna 26). Due to the close proximity of Anna 11RD to Anna 26 we are requesting Administrative Approval, pursuant to Rule 7 of Conservation Order No 76, of Unocal's placement of this well closer than 1000 feet to any well drilling to or capable of producing from the same pool (Rule Z, Co. No. 76). The proposed location of 11RD is reasonably designed to further the purposes of our drilling program into the Granite Point Field, Middle Kenai Oil Pool. We are submitting our application in two parts. The first part is the Sundry application. This will cover the plugging and abandonment operations. The second part is the Permit to Ddll. The permit covers the ddlling portion of the proposed operations. We are proposing to conduct the two operations consecutively. SEP I 9 ]994 Gas cons. Commission Anch0r~v r= Alaska Oil & Gas Conservation Commission September 13,1994 Page 2 In support of the Sundry application please find the following enclosed; a) completed "Application For Sundry Approvals" b) table of existing perforations c) an outline of the proposed abandonment program d) wellbore schematic of the present completion status e) wellbore schematic of the proposed abandonment f) diagram of our proposed BOPE configuration In support of the Permit to Drill application please find the following enclosed; a) completed "Permit to Drill" b) Cheque for $100.00 (application fee) c) table of existing perforations d) an outline of our proposed drilling program e) a plot of the Projected days versus Depth f) diagram of our proposed BOPE configuration g) schematic of the choke manifold h) a copy of the proposed directional plan i) calculation of anticipated pressures j) a copy of the mud program(s) that was filed with EPA k) schematic of the Anna mud system I) wellbore schematic of the new configuration (post redrill) RECEIVED S EP 19 1994 Aiaska b~ & Gas Cons. Commission Anchor~,ue All of the aforementioned documentation is submitted in triplicate. If you have any questions or comments with regards to our application(s) please do not hesitate to call Jamie Ressler or Lee Lohoefer at 263-7800 or 263-7642, respectively. Attachments Sincerely, G. Russell Schmidt Drilling Manager STATE OF ALASKA · ALAS ,-)IL AND GAS CONSERVATION COMMI, APPLlCAI'-ION FOR SUNDRY APF ',tOVALS 1. Type of request: Abandon X_ Suspend __ Operal~ons shutdown__ Re-enter suspended wellm Alter casing__ Repair well __ Plugging __ Time extansion __ Stimulate __ Change approved program __ Pull tubing _ _ Variance Perforate Other 2. Name of Operator 15. Type of Well: I 6. Datum elevation (DF or KB) Development X_ UNION OIL COMPANY OF CALIFORNIA (UNOCAL) . .. Expk~ratory __ 3. Address I Otrattgraphic __ P.O. BOX 196247 ANCHORAGE, AK 99519 1 Senace. 4. Location of well at surface Log #1 Slot #1, Granite Pt, ~r~a'~ 729' FNL, 636' FEL, Sec. 12, R10N, R12W, SM At top of productive interval At effective depth At total depth 1828' FNL, 473' FEL, Sec. 1, T10N, R12W, SM 105' KB, MSL feet 7. Unit or Property name Granite Pt. ADL 18742 8. Well number Well 11 9. Permit number 67 -59 10. APl number 50-733-20048-00 Granite Pt/Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured true vertical 10,264' feet Plugs (measured) None 9,206' feet Effective depth: measured 10,140' feet true vertlcai 9,086' feet Junk (measured) Fill @ 10105' (1989) Casing Length Size Cemented Measured depth Structural Conductor 629' 20" 585 sx 629' Surface 3196' 13-3/8' 2400 sx 3196' Intermediate 7873' 9-5/8" 425 sx 7873' Production Liner 2582' 7' 675 sx 7681 '- 10263' Perforation depth: measured See attached table true vertical Tubing (size, grade, and measured depth) Long string: 3-1/2", BTC, landed @ 9136' Short string: 2-7/8', BTC, landed @ 7615' Packers and SSSV (type and measured depth) None True verticaldepth 629' 2969' 7026' 6853'-9205' REC£1y D Cons. Commi., Anchor~e 13. Attachments Description summary of proposal _ _ Detailed operations programX__ BOP sketch X_ Wellbore Schematic - Pre Abandonment X Wellbore Schematic - Post Abandonment x 14. Estimated date for commencing operation 115, Status of well classification as: October 15, 1994 16. If proposal was verbally approved Oil X_ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby ce(~y~g~orrect to the best of my knowledge. ~-,.. ~ Signed G. RusselISchmidt Title Drilling Manager Date FOR COMMISSION USE ONI,)~~, \'~ . Conditions of approval: Notify Commission so representative may witness ~ ~ I Approval No. Plug Integrity __ BOP Test __ Location clearance I ? ~/'- -,~ ..~-'-~4/ Mechanical Integrity Test Approved by the order of the Commission Form 10-403 Rev 06/15/88 Subsequent form required 10- Commissioner September 13,199, D at e SUBMIT IN TRIPLICATE ;ion WELL PERMIT CHECKLIST FIELD & POOL GEOL ~ F'-Z-C~ UNI~# /~'~ ON/OFF s~o~ ,~3',j~ %DMINISTRATION LPPR ~. 1. Permit fee attached ................... ~ N 2. Lease number appropriate ................ ~ N 3. Unique well name and number ............... ~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary.. ~ N 6. Well located proper distance from other wells ...... ~ N 7. Sufficient acreage available in drilling unit ...... Y ~ 8. If deviated, is wellbore plat included ......... ~ N 9. Operator only affected party .............. ~_ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order .... ~ N 12. Permit can be issued without administrative approval...~\ N 13. Can permit be approved before 15-day wait ........ Y~ N ENGINEERING ~PR 14. Conductor string provided ................ Y 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg. . Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed .......... ~ N D 23. If diverter required, is it adequate ........... ~N~-' 24. Drilling fluid program schematic & equip list adequate . Y~ N A 25. BOPEs adequate N 26. BOPE press rating adequate; test to---~O~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N ~/~ 28. Work will occur without operation shutdown ....... ~-~ N 29. Is presence of H2s gas probable ............. Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/~' 32. Seismic analysis 9f shallow gas zones .......... /Y/ N 33. Seabed condition survey (if off-shore) ......... / Y N 34. Contact name/phone for weekly progress reports ./ Y N [exploratory only] ' ' ? ' GEOLOGY: ENGINEERING: COMMISS ION: - Comments/Instructions: TAB · IOW/jo - A:~ORMSIcheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process. but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. UNOCAL g.P. 18742 NO. 11RD (ANNA) GRANITE POINT KENAI ALASKA LOGGED: RUN 1 - 08 NOVEMBER 1994 LIBRARY TAPE LISTING ATLAS WIRELINE SERVICES RECEIVED FEB 0 7 t995 Alaska 0it & Gas Cons. Commission Anchorage Anchorage, Alaska ', iqlCROF iLMED Tape Subfil~ 2 ~s type: LIS CN : UNOCAL CORPORATION WN : G.P. 18742 NO. llRD FN : GRANITE POINT COUN : KENAI STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 AC AC 68 1 US/F 2 ACQ AC 68 1 3 CHT AC 68 1 LB 4 GR AC 68 1 GAPI 5 SPD AC 68 1 F/MN 6 TTEN AC 68 1 LB 7 CAL CDL 68 1 IN 8 CORR CDL 68 1 G/C3 9 DEN CDL 68 1 G/C3 10 CN 2435 68 1 PU-L 11 CNC 2435 68 1 PU-S 12 CNCF 2435 68 1 PU-S 13 LSN 2435 68 1 CPS 14 SSN 2435 68 1 CPS 15 RFOC DIFL 68 1 OHMM 16 RILD DIFL 68 1 OHMM 17 RILM DIFL 68 1 OHMM 18 SP DIFL 68 1 MV 19 VILD DIFL 68 1 MV 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 06 969 49 6 4 61 094 30 1 4 95 558 30 1 4 87 374 67 0 4 34 168 75 6 4 59 047 24 5 4 52 326 75 5 4 98 211 23 1 4 98 211 23 1 4 84 023 70 1 4 83 368 34 1 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 04 522 10 6 * DATA RECORD ( TYP E# 0 ) 966 BYTES * 76 Total Data Records: 1587 Tape File Start Depth = 9515.000000 Tape File End Depth = -6.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 380861 datums Tape Subfile: 2 Minimum record length: Maximum record length: 1591 records... 62 bytes 966 bytes Tape Subfile 3 is type: LIS **** TAPE TRAILER **** 01 **** REEL TRAILER **** 94/12/ 7 01 Tape Subfile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 7 DEC 94 10:42a Elapsed execution time = 12.25 seconds. SYSTEM RETURN CODE = 0 RECEIVED EEB 0 7 Alaska Oil & 6as Cons. Commission Anchorage [, t, ,5 ~r r;' ,j 'r,., %: q'!F' "-' C-~,STix;r: ?; . ..... i. 1 .::'. r.:,,', W 17 T t,~ E: $ ,$: , r': ! ?~'. (,L ; ;;,'J'f,L,i"i-, L,f.'?T:'i {')F ", ':'L.~ 319F' I !.[,i.'..": r-~i.,lt,'! k~ C"[: ~.~ 'l'O, o5! 0 A .~,:[) !,~OGCF.:P D~':PTH O.F 0 TF: g4P5 P AGE.:; F'I 1 i 1 .!. .L ]. .t. i, ..1. 1 .1,.. ,, .,ne Vorif~cation t,i$~:~i,o !o-Ja~,!-l. gq5 11 mm mm mmmm GP TF. NS H TEN MRES NPHT "TNpH NPOP TNR~ RTNP RCFT RCNT CFTC CNTC H RHC US g ~ P 543 0 n F,C n () 0 (.: I I 1 4 68 0 O0 O fl 00000 B H C (.i g 54854. 3 0 r, 00 r', (~ 0 (,' 1 ~. 1 ~ 68 0000 O 0 O 000 Bt-lC GAPI 54~543 0n r ('; (~ ~.)r~ (~ 1 ~ ! 4 68 O0000000OO ,HC bR 5q ~54.'3 0° 090 CC' 0 ! 1 ~ 4 68 0000000000 RHC LB ~4~5~ 3 (,n c, L) r: or~ (, 1 !. 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DT~:$ 50.719 CIl.,~4. UTE 23.063 ~F,.. OTF: '! 7.553 S P. DTE -9.016 TENS.. DT~7 2 9.6 f', 0 ".,[' T 2. ~:'; ~"~ C 2 9 !.. 2 t' 0 T T 3. ~'~,'H C 4, 3 4.0 0 0 T T 4. B l,,{ C 77.563 ':t3 i{. ?,; ,5. ~,~ ~': C: 12 [~ 0. t') 0 ('> ~,~ T E ['..,. }:39 C 839.000 kl R E S. ~ }i C 2 4.2'2 "";'~';~; {"~ ...... , ......... ......... . z . ~.~¢'~. GR.r'~,~T~ 77 . 563 ,[RNS.CNT,, ~ 39. u(~,t,' '" ~.< F't.~. (:' 'r ~',:. 1, 3 6 ~'~',1' F: F~. C ~:" T 166.000 173.500 169,.500 20,,.000 180,000 1270.000 71',.500 339.200 .0.136 32.391 2579.195 1270.000 47,.500 56.781 20.000 59813 80i000 1267 200 304.000 0~36 2995.574 1280.000 ,'ane Verf~ication T,ist:il~r, · . ., ~ ~ , , CTNP. b'l' ~: 3 5. > ! 9 T .[~'~ K,. IIX~ nTW 4 8°5 Ti.,,9[-' !:.~}.,' H T E ~'. V, T F: ! {; 93. t:' (' t.; ."' h: ~'' L;. ~,: 'F TT 1 . ~HC g.~ ~. ~,,0(' TT2. ~".7-~C ......... ~..?', ~' C TNRA.Ct'.!T 3.1 ~ !:: o'r~ i(,C'"'[}.' 1 ()-J?q';-1995 11 15.914 -I .136 O. PoO 16.75n - 1 ~. 750 1.65.625 483.?00 ,~99.000 16.571 2!74.R75 56.500 1.65.625 28.391 -2,318 0.000 3! .82~. -159,500 :'164.125 451.600 :1.093.000 36.590 596.750 9~.875 164..1.25 13.453 0.2.,91 0.000 22. 313 1,9.484 162.375 499.4,0(') (:i 77.00 O 37.9'78 610.9@3 6'3,656 162.375 1950.000 -397. :750 0.000 80.063 -46.,?..50 16!.125 397.600 1114.000 37.669 527.~45 2~, 3.!,3 1(51. 125 C!DP. P].'K j F'.RW. C T !..~'~. ]'Fl F: $. OT.F}tC 'rT4 · k., P t~.: S. 1'~ P [] R. C f',: T C I 0 P D '"" ~: i I R ~";, !) T ~] I F E ~,"'. F: [1,' ~ C l g.~,,t. DTE '.].' 1, ~',; S. DTF, D T. ~, bi C. TT4. B ~C N P 0 ',c,. C ~',' 'r' CIDP. DTE I I R~,~. DTE (') T . ~ H C TT4. ~t,iC ~RE',$. BHC NC[,~T.CNT TENS.Cf('? PAGE: !.4.320 52.125 20.000 54.875 1465.000 71.800 336.800 0.138 ~7.369 4004.000 ~465.000 29.578 35.781 20.000 37,625 1.295.000 64.900 338.800 0.138 34.357 1976.778 1295.000 1.2,172 82,625 20,000 87,188 810.000 95..800 360,800 0,137 46.496 1.908,292 810~000 77..813 -466,000 20.000 -472,750 730,000 55,300 289,200 0,137 37,391 1794.308 730.000 ~pe Verification f,ist.~,~ 1.1:33 PAGE: FILF N A~,E SERVICE D~TE ~tAX R~C FILF TYPE bAST wILE t,,t w L L BORg S T A ? APl LOG i','i E A S d f'~ E,, D E[,EV&TIn~'iS l,{n: .1.?7 L:,F: 12~:, G[..,: 12v, .aDe ver~ficatIon [ ist]r?~ .,lumbercer AlasKa c¢.:n outJ. r'~e Center :1. c~-JA:'~-I995 11:33 PAGE~ ,~ 5/'F~h t >; ,;'t r',~.'.Ti.:f.F'K' r)..?:t':T.'.I FI}: L: .!.'(~ qSlf': Ai':l'? LOGCER DEPTH ,q..F ',"; Trh. ~4~5 BIT STZP: BTT STZ~ ?: .~.5" ,., TYPE' 2UD RWSISTIVi~'Y: [:' ][ [J'¥ R A T ~. M[~D C/tKF' 0.(~{;5 r,, 58 L tn G G I I~.~ G D T $ .T ~ T C -r: !.52 127 1. 25 4.750 1427 267 FIELD LOGS ~;iEPl{'. ').)!'go., T~"~rl'[)'.['H~3 [)T[*"L I_,OGC'F<D BY ~;ES'I'ERN ATI,AS, 8 ~OV 94', CURVE GR ,. , DAT.F. ,JOR STARTEP,: ,,e Verif~,catiof~ f,istl, r~n .dmberc;er ~'~]asKa Comp~tlno Center PAGE]: ** DATA mm m~ m ~m~ m m ~ m. m m~ m m, m mm m m~ m m ~,~ m ,m m m m m mm m ~ m ! ** SET -.... ........ ..... 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S.S. ,.I t' In., :.' LJ '.'! [:; S. i:, ''~ P T. L, T ¢'~ I Ill IIlI! II CIMP.DTF~ .t. 9 j..375 l: I P O. ?':'ri', I 53.250 TIXO. OTE 15.3'28 IIRN.DTE I l X u. O',!,' F 1 !,. 539 :'.[ ~::,, r', F. t,),' [,: 3.0 <.) 0 ! F, O F, t.) T E 2.000 I F t~'. ~. P, T E ILD.DTE 5.6;'?(; J'.l,~. DT[:: 5.4.41' C I [1, O . [)?t:; ~.7fi.875 CILM.DTE HTE~.BTF -llS!.OOC ~,;~ k V:5. l;q [.,? n.135 ~fTFI,4. [)T E 1.65.1.25 DT.BftC TT1.Bt, tC 426. S,::o 'i.,'? 2. k: :',~' c 28~.4. oc) TT3. i.,~MC 4:8S.o00 TT4.BHC " , J, E. ,',! i3 i,.l r, . ..... T[!R/h .CNq' 2.863 ~ ".i,' ~",: (-!. L' r ' :;.; 2.97° RCWT. Ct'~T R76.085 RCNT.CNT C~TC. C~'~' baO.t;75 C ~,~C. C ~q"[' 24.8 ~. 6{.,4, G ~. C {",~ :'!/ 106.1,,88 TE;NS. C?,~T H T E [~. C N T - t J, 51. (,,, 0 u '*,," a ~ 5. C t,t 2' 0,1 35 ~','~ T E }~. C N T 165.125 C!MP. PI,'? 79.I~8 l JiP (). Oq"E; 37,~13 I I XI,). D'rE 0.355 'IIRm.DTE IIX~.~TF 3.969 '! i,)aF. [~"ra ().000 TF~QF'. DTE 0.000 IFRE.DTE I h D. D T ~ 23.93 ~ l I, ;',~. i) T E 12. ~ 5 2 C I L f). D · E: 41.750 C I 1'., ~. D T ~ SFLU,DTw t2,b28 ~¢(. r:>*E, 53.938 SP.DTE -16.000 TENS.DT~ H T E [~ . P T ~ !, 93.25 {., ~,,," a r F;. ~.,'r' [:; o, 1 37 t4 T E f4. !) T E 165.250 O ~7. B H C TT ~. Et,it ,~o6.40~' T?2. ~::,~;C 3.',2. o()0 TT3,9HC 501,. 600 TT4. BHC g T E m. n t.i, C 1. ~ 5.2 ~ (~ r,,! p !.; :[.. C r,,: T 2 re. 8 b 5 · ?. P t-t. C [~ t!:' 25.234 ~,,i P O R. C N T Tf,IR ~. Ci',,: T 2,7al r~ ':r':' d,. C ~.~ '}' 3.389 RCWT. Ct,rT 9'78.4,9a I:{C¢¢T. CN T H T E ~' C N T 1 P 3 2 ~ {; '~ *; [': S C, *" "" r"~ 1,3" ;'4 "r [;., ¢'..~ C i,t T 16 ~ 250 173:,'750 172.875 20,.000 183.625 1280,000 70,400 344.800 0.135 32.099 2647.158 1,280.000 40,094 76,688 20..000 ¢0,938 1.345,000 77-200 347,200 .0.137 31,407 1345.000 ra~.e Ver~ication T.,ist.ir,(~ ~lumberqer A]aska PAGE: 10 **** S~RvIc}~ VFRSI~r': DATE M~X R~C SIZ~ FILE TYPE L~ST FII,E C:.,RAI'..iI'fF PL.]IHT, API GR t~¥ T'IE POT i,~T, API 50-7 3 3- 2 f'~() 4 8-0 l 50-733-2004a-01
