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Home My WebLink About200-105 ti OF 711, yw\ s THE STATE Alaska Oil and Gas of Q T Conservation Commission 1 1 JkS}(i\. 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS'- Fax: 907.276.7542 www.aogcc.alaska.gov June 11, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification SCANNED JUL 0 12015 Trading Bay Unit G-26RD PTD 2001050 Dear Mr. Golis: On May 15, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit G-26RD located on the Grayling 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 Trading Bay Unit G-26RD prior to the test. The well performance was monitored for 1.5 hours with resulting flow rates (oil and gas) below the regulatory limits, passing the no-flow test. Verbal approval was granted by the AOGCC Inspector to return the well to production without a subsurface safety valve. 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 Trading Bay Unit G-26RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Grayling Platform. Sincerely, g. Kelc- James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM.-_SION REPORT OF SUNDRY WELL OPERATIONS 11.Operations Abandon 0 Plug Perforations ❑ Fracture Stimulate Cl Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate CI Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: (Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 200-105 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20295-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit/G-26RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,587 feet Plugs measured 10,700 feR E C E!V E D true vertical 9,734 feet Junk measured 10,638 feet . UN 05 2015 Effective Depth measured 10,638 feet Packer measured 10,194 feet true vertical 9,103 feet true vertical 8,737 feet AOC CC Casing Length Size MD ND Burst Collapse Structural 356' 26" 356' 356' Conductor 785' 20" 785' 758' 1,530 psi 520 psi Surface 5,611' 13-3/8" 5,611' 4,935' 3,090 psi 1,540 psi Intermediate Production 10,263' 9-5/8" 10,263' 8,797' 6,870 psi 4,760 psi Liner 1,466' 7" 11,587' 9,734' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED J U L 0 9 Z 015 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 10,242'(MD) 8,779'(ND) 10,194'(MD) Packers and SSSV(type,measured and true vertical depth) 7"29#Packer 8,738'(ND) SSSV:NA 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: 16 6 158 1106 156 Subsequent to operation: 27 21 187 1064 200 14.Attachments(required per 20 AAC 25 070.25.071,&25 283) 15.Well Class after work: Daily Report of Well Operations CI 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 0 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: 315-232 Contact Dan Marlowe Email dmariowe( hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature IIII. / / O Phone (907)283-1329 Date 6/5/2015 / RBDMS - \.-\ JUN 1 1 2015 Form 10-404 Revised 5/2015 ` ` ',7-/) / Submit Original Only McArthur River Field in Well: G-26RD SCHEMATIC Completed: 12-9-14 ttaeow.aiarka,1.1.1: PTD: 200-105 RKB to TBG Head=40.15ft Tree connection:4-1/16in 5,000# CASING DETAIL 1 SIZE WT GRADE CONN ID TOP BTM. 26" - - - - Surf 356' 20" 94 H-40 - - Surf 785' L I\ 61 K-55 Butt. 12.515 Surf 2,610' 2on 94#C: 13-3/8" MD=785ft 68 K-55 Butt. 12.515 2,610' 5,611' 47 N-80 Butt 8.681 Surf 7,979' .1) 9-5/8" 47 P-110 Butt 8.681 7,979' 9,523' 47 USS-95 Butt 8.681 9,523' 10,263' 7" 29 __ L-80 Butt 6.184 10,121' 11,587' TUBING DETAIL L 3-1/2" 9.2 L-80 Supermax 3.958 Surf 10,242' 13&8m 61866#Csg MD=5,611ft JEWELRY DETAIL No Depth ID(in) Item (A2aMs 1 40.15' CIW-DCBS-FBB,11 X 3.5 Hydril 563 SUSP X 3.5 EUE 8 RND W/Sin Type H BPV 2 2.992 3.5in SF0-1 Gas Lift Mandrels(OD:5.313in):2,078ft, 4,153ft,5,963ft,7,612ft,9,028ft,10,146ft 3 10,194k 5.160 Packer 7in 29# 9-5f8in 4 10,233ft 2.813 "X"Nipple TOC:8,22411_ a4C�n4x 5 10,242ft 2.992 WLEG 11-22-76 6 10,700ft - CIBP:Top of Cement 10,665ft X =10.121ft Tin 295 liner Top ) Inc=30° PERFORATION DETAILS #37n 29#Fkr -,. / Btrrl MD=10,194ft /xl Zone Top(MD) Btm(MD) Top(TVD) (TVD) Ft. Comments I x #4 XNipple MD=1Q23311 2-1/2"6 SPF L k =G-3 10,250' 10,260' 8,786' 8,795' 10 04/29/15 9-58n47#Csg . MD=1o,2Gilt #5M-eGG-4 10,296' 10,329' 8,826' 8,854' 33' 6SPF 2DP(%9/14) MD=1o,242ft =G-3 2-1/2"6 SPF =G-4G-5 10,467' 10,491' 8,969' 8,988' 241 04/27/15 2-1/2"6 SPF SarxYFll G-5 27 10,507' 10,534' 9,001' 9,022' 04/27/15 c'• ''.'.`° ' Ma 1o,so45 2-7/8"60 deg #6 GBP D= H-1 10,728' 10,743' 9,171' 9,182' 15' 6SPF(8/3/00) `-38° - 2-7/8"60 deg =F1-1 H-2 10,782' 10,787' 9,211' 9,215' 5' 6SPF(1/16/01) 2-7/8"60 deg H-2 10,792' 10,802' 9,219' 9,226' 10' 6SPF(1/16/01) = H-2 2-7/8"Power Jet - H-3 10,932' 10,942' 9,319' 9,326' 10' (11/18/00) - H-4 11,027' 11,103' 9,385' 9,437' 76' 2-7/8"60 deg "!, _I-1-3 1 P9r7s8- H-5 11,200' 11,210' 9,501' 9,508' 10' 2-7/8"60 deg 1o,7z6-n,446rt 6SPF(8/3/00) 2-7/8"Power Jet H-5 11,228' 11,235' 9,519' 9,524' 7' (11/2/00) -• - H-5 11,315' 11,325' 9,574' 9,580' 10' 2-7/8 Power Jet E - 1-1-5 (11/2/00) • - H-6 11,442' 11,448' 9,650' 9,654' 6' 2-7/8"60 deg 6SPF(8/3/00) = H-6 7 PBTD=11,535ft TD=11,587ft MAX HOLE ANGLE=54.6° Updated By:JLL 06/05/15 Hilcorp Alaska, LLC 11;1..0E,,.uaka.,.i.c Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-26RD 50-733-20295-01 200-105 4/27/2015 5/6/2015 Daily Operations: 04/27/15-Monday FLY TO GRAYLING. COMPLETE PTW/JSA AND CONDUCT PJSM. SPOT EQUIPMENT AND RIG UP ON WELL G-26RD. PRESSURE TEST LUBRICATOR TO 2000#GOOD TEST. RIGGED UP 30'OF 2.70" DUMMY GUNS(HAD TO SHUT IN WELL)AND RAN OUT OF TUBING TAIL @ 10,196'. POOH WITH DUMMY GUNS. RUN IN HOLE WITH 20'OF 2.5"GUNS 6 SHOT PER FOOT TO 10,560'. TALKED WITH TOWN AND POOH. RIG UP 27'OF 2.5"GUNS 6 SHOT PER FOOT RIH TO 10,534'. CORRELATE WITH TIE IN LOG,BRING WELL ON TO PRODUCTION AND STABILIZE,SHOOT GUNS AT 10,507'-10,534'. SHUT WELL IN AND POOH WITH GUNS. ALL GUNS FIRED. CURRENTLY RIGGING UP 24'OF 2.5"GUNS 6 SHOTS PER FOOT TO RIH TO 10,467'-10,491'.CORRELATE WITH TIE IN LOG,BRING WELL ON TO PRODUCTION AND STABILIZE,SHOOT GUNS AT 10,467'-10,491'. SHUT WELL IN AND POOH WITH GUNS. GUNS STUCK @ 4,000'WITH LOST COMMUNICATION. 04/28/15-Tuesday COMPLETE PTW/JSA AND CONDUCTED PJSM. TRIED PULLING ON TOOL STRING TO 1600#WITH NO LUCK. OPERATIONS STARTED BLEEDING DOWN BACKSIDE OF CASING AND STARTED INJECTING WATER DOWN TUBING. WATER WASHED DOWN PAST TOOL STRING AND FLUSHED FOR ONE HOUR. STOPPED BLEEDING CASING AND INJECTING WATER. WORKED TOOL STRING FOR SOMETIME �h AND DECIDED TO PULL OUT OF ROPE SOCKET. POOH WITH E-LINE WIRE. RIGGED DOWN E-LINE EQUIPMENT. CHANGED OVER TO SLICK LINE UNIT AND ASSEMBLED FISHING TOOLS.RIH TO 10,516'TRYING TO LATCH FISH.WORK TOOLS FROM 10,516'TO 10,540'. COULD NOT LATCH ONTO FISH. POOH WITH WORK STRING. MAKE UP BRUSH AND RIH TO 5,000'. BRUSH AREA FROM 3,000'-5,000' UNTIL CLEAN. POOH,LAY DOWN LUBRICATOR AND FLOW WELL TO TEST. 04/29/15-Wednesday COMPLETE JSA/PTW CONDUCT SAFETY MEETING. RIH WITH 15'OF 2.7"DUMMY GUNS TO 10,259'. POOH. RIG DOWN SLICK LINE. STRIP 4,075'OF BAD BRAIDED LINE.RIG UP E-LINE UNIT AND RIG UP 10'OF 2.5"GUNS WITH 6 SHOTS PER FOOT.RIH,CORRELATE GUNS,IN POSITION TO FIRE AND GAMMA STOPPED WORKING. POOH AND LAY DOWN GAMMA,MAKE UP WEIGHT BAR WITH COLLAR LOCATOR AND RIH.CORRELATE GUNS,FIRE GUNS.POOH,GUNS FIRED.RIGGED DOWN. 05/04/15-Monday Set up Spider Gauge-and P/T Gauges.P/T 2 times,First Attempt Fail C/O Oring.RIH/w Tandem P/T Gauges-at 60 FPM doing stops at hanger-10,465'KB then stopping 50'above and Below Gaslift Mandrels.OOH Download gauges.Data Good.RIH/w 2.7"LIB to 10,559' KB w/t Slip past Eline TS to 10,580'KB. Pooh-from 10,580'KB to 10,559' KB. Have 150 LBS overpull-OOH Impression of 1"Fishing Neck. RIH/w 2.5"JDC/w 2.7"Bell guide to Same w/Latch Bait sub.Connected to ELINE TS w/t multiple jar licks.Pooh free. Hang up at X nipple at 10,223'KB Wit Spang up thru multiple licks,come free,POOH. TGSM-Discuss laying Down Eline TS.Break down recovered Eline TS consisting of 24'Perf guns-/w Gamma CCL/w Rope socket.Break off Extra Lubricator. RIH/w 2.5" RB/w Bait Sub/w 2 5/16"Series 100(1 7/16"Grapple)Overshot/w 2.7" Bell Guide to 10,564' KB w/t.Set Grapple.Good Latch w/t Shear off Upward, Pooh. RIH/w 2.5"5' DD Bailer to 10,598'KB w/t to 10,601'KB POOH.FULL Perf sand-Frac Sand-Perf Debris.RIH/w Same to 10,601'KB w/t to 10,603'KB POOH.Full Same. 05/05/15-Tuesday Permits-JSA.TGSM.Pull TS out and Add Knuckle.Find 15'Ball of Eline in LUB. Rebuild Oil Jars. Rig UP Slickline.RIH/w 5'2.50" DD Bailer to 10,585'KB w/t to 10,588'KB pooh. Full Frac Sand-Perf sand.RIH/w 8'DD Bailer to 10,588'KB w/t to 10,595' KB Pooh.3/4 Full Bailer Same.RIH/w Same to 10,595'KB w/t to 10,603'KB POOH.1/2 Full Bailer Same. RIH/w Same to 10,595'KB w/t to 10,603'KB Sticky-Pooh.Flapper off Seat-WASH OUT. RIH/w Same to 10,598'KB w/t to 10,603'KB Lose Spangs POOH.Bailer 1/2 Full same. Clean out Spangs.RIH/w Same to 10,601'KB w/t to 10,604'KB.Fill seems very Hard Packed POOH.1/8 Cup Of Sand. Lay Down LUB and Cut 50'Wire Check TS Connections.Remove Knuckle Jar. RIH/w 2.5"5'Bailer to 10,602'KB w/t to 10,604'KB Pooh.Empty Bailer- One Chunk Of Perf Debris.Lay Down Lub.Clean and Secure area and Well for the Night. Hilcorp Alaska, LLC Hileorp Alaska,LLC Well Operations Summary Well Name API Number _Well Permit Number _Start Date End Date G-26RD 50-733-20295-01 200-105 4/27/2015 5/6/2015 Daily Operations: 05/06/15-Wednesday RIH/w 2.5"DD Bailer to 10,595'KB w/t to 10,598'KB.POOH.Empty Light Metal Marks on BTM. RIH/w 2.25"DD Bailer to 10,597'KB, 10,600'KB.POOH w/3/4 Full Bailer Sand-Frac Sand Perf Debris. RIH/w to 10,600'KB w/t to 10,602'KB.Very sticky.200 to 400 LBS overpull.POOH w/1/2 full bailer. RIH/w to 10,597'KB w/t to 10,604'KB.POOH w/1/2 Full Bailer,same Metal Marks on BTM. RIH/w 2.5"LIB to 10,595'KB. RIH/w 2.25"Centralizer/w 3'1 1/2"Stem w/3 1/2"Slickline Scratcher to 10,604'KB,pickup.Gain overpull at 10,598'KB drag to 10,582'KB,lose 500 LBS overpull.Multiple Set downs at Depths 10,587'KB,10,592'KB 10,585'KB and 10,601'KB losing overpull between 10,580'KB and 10,590'KB.POOH.Metal marks alongside of 3'stem and broken off piece of wire on slickine scratcher. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l t DATE: May 15, 2015 P. I. Supervisor FROM: John Crisp SUBJECT: No Flow Test Petroleum Inspector TBU G-26RD Hilcorp Alaska LLC SCANNED JUL 0 1201r PTD 2001050 May 15, 2015: I traveled to Hilcorp's Grayling Platform in Trading Bay Unit to witness a no-flow test on well G-26RD. The well is an electrical submersible pump completion with non-operable pump. Perforations were added 4/28/15 and resulting production was 200 - to 300 barrels of fluid per day (20 to 30 barrels of oil per day). Approximately 2.6 MCF of gas is used for artificial lift. When I arrived on the Grayling Platform I witnessed TBU G-26RD rigged up with no- flow test equipment required by AOGCC Guidance Bulletin 10-004, Appendix A. This " test was being initiated after 2 days preparation. The digital pressure gauge utilized for no-flow testing registered 0.01 psi while well was open thru 1-inch test equipment from the tree cap. A slight flow of gas was observed but would not register on flow meter. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr Initial 0.01 slight 0 Open to flow 1.5 hrs 1.79 0 0 Shut in 1000 C? Open to flow 1.75 hrs 0.01 0 0 Open to flow 2.75 hrs 0.01 0 0 Open to flow ' Pressures are T/IA/OA Summary: I witnessed a successful No-Flow Test performed on TBU G-26RD (per 20 AAC 25.265(k)) Attachments: Test Gauge and Flow Meter Calibration Certifications Ue,- .( AP :14 rri,j-e.e1y Ism(1s r irAt G-Z /z,3, M 2015-0515_No-Flow_TBUJ G-26RD jc.docx Page 1 of 1 C1 -Zf CDJ 1 v p-r) zap Certificate This is to certify that this instrument has been calibrated for the fluid conditions specified on the purchase order and embossed on the nameplate. Measuring devices that are traceable to the United States National Institute for Standards and Technology (NIST- formerly National Bureau of Standards) were used for this calibration. Technician Date Instrument Serial Number ERDCO Engineering Corporation 721 Custer Av ♦ Post Office Box 6318 Evanston, IL 60204-6318 USA • Kio -RAJ - -173cZ C z ()r-c "Zot 1050 Slls(ts Hilcorp Alaska LLC • Grayling Platform (907)776-6630 • - (907)776-6635 Fax *Ifi Dead Wt Tester# 000265 Test Gauge# S150415003-01-01 Date Tested 5/11/2015 Tech's Name Jon Collins Full Scale Range 300 Applied Pressue Indicated Press. % Of Scale % Error Q 0 0 0 75 75 25 0 150 150 50 0 225 225 75 0 300 300 100 0 225 225 75 0 150 150 50 0 75 75 25 0 0 0 0 0 Max Allowable error 0.249999999 Signature aelk - - - - - - 7- — - F-14,1 rres1-- --rgut D6 zoolos-c.) 5— d.".%rLiAT 3 R P CALIBRATION Lit:R. Hi Test Equipment Traceable to MST type: Pressure range: Date: . niN! • . - - • - , • _. : aed Test equipment S/N: f' • • This cat expires in 90 days on For recertificati.c.-., contact Gina Bogart or Cathy Marshall at KGF 776-5825. G-z&2b Z00 1050 Regg, James B (DOA) From: Regg, James B (DOA) 46\LL Sent: Friday, May 15, 2015 11:23 AM �Qi4k To: Crisp, John H (DOA) Subject: RE: No Flow Grayling G-26 You can give them verbal; I will follow up with formal letter after receive your report. Thank you for witnessing this and the misc SVS test! Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave,Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907-793-1236 or iim.reggCa@alaska.gov. Original Message From: Crisp,John H (DOA) Sent: Friday, May 15, 2015 11:16 AM To: Regg,James B (DOA) Subject: No Flow Grayling G-26 They re perforated this well April 28th 2015. Brought on same day making 200 to 300 BFPD with 20 to 30 BOPD. Well was shut in 5/13/15. 0.01 psi flowing thru 1" equipment at 0830 this morning. Shut in for 1 hour and built up 1.79 psi. Opened after 1 hour and had flow rate of 160 scfh for 8 minutes. Back to 0.01 psi with no flow on flow meter. Do we give them verbal approval to start producing after no flow is complete without SSSV? Sent from my iPhone 1 Mk �‘ OF Tye �w��1� 4' THE STATE Alaska Oil and Gas 1:7... .7.--.. i— ±... • o Conservation Commission _ _ ___ - fALASI�:A '. t Its -=— 333 West Seventh Avenue A GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *h' Main: 907.279.1433 OFALAS*P* Fax• 907.276 7542 www.aogcc.alaska gov Dan Marlowe CANNES APR 2 4 2015 Operations Engineer ) /� Hilcorp Alaska, LLC 02,0 Q 1 C/ 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU G-26RD Sundry Number: 315-232 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1 20-4-4.-7(4.-- Cathy P oerster Chair St- DATED this day of April, 2015 Encl. • RECEWED • STATE OF ALASKA APR 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20_AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well Cl Change Approved Program El Suspend❑ Plug Perforations❑ Perforate 0• Pull Tubing❑ Time Extension❑ Operations Shutdown El Re-enter Susp.Well❑ Stimulate El Alter Casing❑ Other. El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development 0 • 200-105, 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic CI Service El6.API Number. Anchorage,AK 99503 50-733-20295-01 , 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A' Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit/G-26RD • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 • McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,587 9,734 10,638 9,103 N/A 10,638 Casing Length Size MD TVD Burst Collapse Structural 356' 26" 356' 356' Conductor 785' 20" 785' 758' 1,530 psi 520 psi Surface 5,611' 13-3/8" 5,611' 4,935' 3,090 psi 1,540 psi Intermediate Production 10,263' 9-5/8" 10,263' 8,797' 6,870 psi 4,760 psi Liner 1,466' 7" 11,587' 9,734' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade: Tubing MD(ft): See Schmatic• See Schematic 3-1/2" 9.2#/L-80 10,242 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft). 7"29#Packer/SSSV(N/A) ` 10,194'(MD)8,738'(ND)/NA 12.Attachments. Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/27/2015 Oil 0 Gas ❑ WDSPL El Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@_hilcorp.com Printed Name Dam l(il. • - y jQr- j-� Title Operations Engineer Signaturrr-' / Phone (907)283-1329 Date 4/20/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315- 232 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No V Subsequent Form Required: 4 APPROVED BY �-. Approved by: -e'14--- �__ COMMISSIONER THE COMMISSION Date: 4_2...1 -/5 " / RA I ?At �{��al/S ,�0.„,14,,- -1"7 /,�'S S}� 4V: s PIE R \ l gpliicall A� Submn Form and Fom,10-4 (Rewsed 10/2012) p ro e a for 72 months from the date of approval. Attachments in Duplicate RBDMSJ\k APR 2 2 2015 Well Work Prognosis Well: G-26RD Hilrorp Alaska,LLC Date:04/17/15 Well Name: G-26RD API Number: 50-733-20295-01 Current Status: Gas-Lift Producer Leg: SE Leg (#3) Estimated Start Date: April 27, 2015 Rig: NA Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 200-105 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallet (907) 777-8323 (0) (907) 301-6657 AFE Number: Budgeted Cost: Current Bottom Hole Pressure: ^'2,550 psi @ 8,497'ND Based on static BHP reading 07-08-14 Maximum Expected BHP: -2,550 psi @8,497'ND Based on static BHP reading 07-08-14 Max Allowable Surface Pressure: 1400 psi Gas lift Pressure Brief Well Summary Well G-26RD is a gas-lifted oil producer completed in the G-zone bench 4.This project will add the G- zone benches 3, 5, &6 working from the bottom up and evaluating each sand. Procedure: 1. MIRU E-line unit, drift to top of cement at+/- 10,680'. 2. Gas-lift the well to achieve underbalance and ensure no-flow from Hemlock. 3. Add perforations in three stages conducting well testing in between adds a. 10,567'— 10,620' (Lower G-5 &G-6) b. 10,467'— 10,534' (Upper G-5) c. 10,250'— 10,260' (G-3) 4. Rig down E-Line. 5. Return well to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic McArthur River Field . ii Well: G-26RD Completed: 12-9-14 Hamel)Alaska,LLC PTD: 200-105 RKB to TBG Head=40.15ft Tree connection:4-1116in 5,0001* CASING DETAIL 1 SIZE WT GRADE CONN ID TOP BTM. 26" - - - - Surf 356' 20" 94 H-40 - - Surf 785' L zansaNC 13-3/8" 61 K-55 Butt. 12.515 Surf 2,610' MD=785ft 68 K-55 Butt. 12.515 2,610' 5,611' 47 N-80 Butt 8.681 Surf 7,979' 9-5/8" 47 P-110 Butt 8.681 7,979' 9,523' newmp 47 USS-95 Butt 8.681 9,523' 10,263' 7" 29 L-80 Butt 6.184 10,121' 11,587' TUBING DETAIL L ommo b 3-1/2" 9.2 L-80 Supermax 3.958 Surf 10,242' 13-38in 61868#Csg MD=5,61111 P #2 GL Ms JEWELRY DETAIL No Depth ID(in) Item D1 40.15' CIW-DCBS-FBB,11 X 3.5 Hydril 563 SUSP X 3.5 EUE 8 ss.&n RND W/Sin Type H BPV TOC:8,224ft3.5in SF0-1 Gas Lift Mandrels(OD:5.313in):2,078ft, �twi Hca ,; = D 2 - 2.992 4,153ft,5,963ft,7,612ft,9,028ft,10,146ft r 3 10,194ft 5.160 Packer 7in 2911 4 10,233ft 2.813 "X"Nipple '• N1Tin29#LinTc Q D=1121ft 121ft5 10,242ft 2.992 WLEG ® Inc=30' 6 10,700ft - CIBP:Top of Cement 10,665ft N3 in Tin 2, MD29#P1 OffIII - 1 x 10,2 leM WD=10,233 311 9-5'8in 47N Csg '; L PERFORATION DETAILS MD=10,2638 ?' / N5 AUG Zone Top(ft) Btm.(ft) Ft. Comments �k MD 10,242n GZN-4 10,296 10,329 33' 2-1/2"60 deg 6SPF DP(7/9/14) =G-4 H-1 10,728 10,743 15' 2-7/8"60 deg 6SPF(8/3/00) Total _oevar- H-2 10,782 10,787 5' 2-7/8"60 deg 6SPF(1/16/01) `,1 _10,29Eft-1Q329ft 10,792 10,802 10' 2-7/8"60 deg 6SPF(1/16/01) r H-3 10,932 10,942 10' 2-7/8"Power Jet(11/18/00) NsaeP H-4 11,027 11,103 76' 2-7/8"60 deg 6SPF(8/3/00) MD=10,700ft'' Inc=38° t:A11,200 11,210 10' 2-7/8"60 deg 6SPF(8/3/00) =H-1 H-5 11,228 11,235 7' 2-7/8"Power Jet(11/2/00) = 11,315 11,325 10' 2-7/8"Power Jet(11/2/00) ij H-6 11,442 11,448 6' 2-7/8"60 deg 6SPF(8/3/00) ; = H•2 =H3 Puts(MD) r 10,728-11,448t o E4 = H5 ?i = = H-6 PBTD=11,535ft TD=11,587ft MAX HOLE ANGLE=54.6° Updated By:DRT 12/16/2014 McArthur River Field 14Well: G-26RD PROPOSED Completed: 12-9-14 Ililcorp Alaska,LLC PTD: 200-105 RKB to TBG Head=40.15ft Tree connection:4-1/16in 5,000# CASING DETAIL 1 SIZE WT GRADE CONN ID TOP BTM. 26" - - - - Surf 356' 20" 94 H-40 - - Surf 785' L 20in94#C 13 3/8" 61 K-55 Butt. 12.515 Surf 2,610' AD=785ft 68 K-55 Butt. 12.515 2,610' 5,611' 47 N-80 Butt 8.681 Surf 7,979' D 9-5/8" 47 P-110 Butt 8.681 7,979' 9,523' 47 USS-95 Butt 8.681 9,523' 10,263' 7" 29 L-80 Butt 6.184 10,121' 11,587' TUBING DETAIL L =_y , 3-1/2" 9.2 L-80 Supermax 3.958 Surf 10,242' 13-3/8in 61&68#Csg MD=5,611ft JEWELRY DETAIL ---1' No Depth _ ID(in) Item u2s 1 40.15' CIW-DCBS-FBB,11 X 3.5 Hydril 563 SUSP X 3.5 EUE 8 RND W/Sin Type H BPV 2 2 992 3.5in SFO-1 Gas Lift Mandrels(OD:5.313in):2,078ft, 4,153ft,5,963ft,7,612ft,9,028ft,10,146ft 0 3 10,194ft 5.160 Packer 7in 29# _ 9-5/8in 4 10,233ft 2.813 "X"Nipple TOC:8,224f t_ 5 10,242ft 2.992 WLEG 11-2&78 ;, 6 10,700ft - CIBP:Top of Cement 10,665ft XTin 294 liner Top MI)=10,121ft s Inc=30° ' tt PERFORATION DETAILS #37in 29#Pkr . M0=10,194ft Zone Top(MD) Btm(MD) Top(TVD) (Np) Ft. Comments t x #4xNipple , tito 1o,233tt O G-3 ±10,250' ±10,260' ±8,786' ±8,795' ±10' Future L 2-1/2"60 deg 9.56&n47#Csg ,,,; G-4 10,296' 10,329' 8,826' 8,854' 33' MD=10,263ft sr #sv�lec 6SPF DP(7/9/14) MD=10,242ft G-5 ±10,467' ±10,491' ±8,969' ±8,988' ±24' Future s _Gd G-5 ±10,507' ±10,534' ±9,001' ±9,022' ±27' Future )N _G5 G-5 ±10,567' ±10,571' ±9,048' ±9,051' ±4' Future _ G-6 ±10,600' ±10,620' ±9,074' ±9,089' ±20' Future ! - 2-7/8"60 deg *wyot.,m. 4 #6 GBP r H-1 10,728' 10,743' 9,171' 9,182' 15' 6SPF(8/3/00) MD=10,700fto 2-7/8"60 deg Inc=38" t; H-2 10,782' 10,787' 9,211' 9,215' 5' 6SPF(1/16/01) =H-1 H-2 10,792' 10,802' 9,219' 9,226' 10' 2-7/8"60 deg 6SPF(1/16/01) x1 - 2-7/8"Power Jet j = H-2 - H-3 10,932' 10,942' 9,319' 9,326' 10' (11/18/00) ,T H-4 11,027' 11,103' 9,385' 9,437' 76' 2-7/8"60 deg - 6SPF(8/3/00) to __H-3 2-7/8"60 deg H-5 11,200' 11,210' 9,501' 9,508' 10' b Pafs(ND) 6SPF(8/3/00) y 10'728-11'449n _22-7/8"Power Jet :81 _ H-4 H-5 11,228' 11,235' 9,519' 9,524' 7' (11/2/00) ';`" H-5 11,315' 11,325' 9,574' 9,580' 10' 2-7/8 Power Jet (11/2/00) d1 1455 H-6 11,442' 11,448' 9,650' 9,654' 6' 2-7/8"60 deg ' 6SPF(8/3/00) i _ N PBTD=11,535ft TD=11,587ft MAX HOLE ANGLE=54.6° Updated By:1LL 04/17/15 T8 (cOF ,*Iy/, s THE STATE Alaska Oil and Gas \� =' of Conservation Commission -��_� AI AS}(i\ itt = 333 West Seventh Avenue � Anchorage,GOVERNOR BILL WALKER Alaska 99501-3572 T4 Main: 907.279.1433 OF ALAS' Fax: 907.276.7542 February 6, 2015 www.aogcc.alaska.gov Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit G-26RD ANN LU PTD 2001050 Dear Mr. Golis: Hilcorp Alaska LLC (Hilcorp) performed a no-flow test of Trading Bay Unit G-26RD on September 18, 2014. The Alaska Oil and Gas Conservation Commission issued the no-flow verification by letter dated January 6, 2015. On December 4-5, 2014 Hilcorp hydraulically fractured Trading Bay Unit G-26RD as authorized by approved Sundry 314-526, necessitating a new no-flow test. On December 22, 2014, an AOGCC Inspector witnessed the post-well stimulation no-flow test of Trading Bay Unity G-26RD. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to Trading Bay Unit G-26RD. The well performance was monitored for three hours with resulting flow rates (oil and gas)below the regulatory limits, passing the no-flow test. A subsurface safety valve is not required to be installed in this well based on the successful no- flow test result. 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 Trading Bay Unit G- 26RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Grayling Platform. Sincerely, Ne-77 James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Tuesday,January 27, 2015 10:00 AM To: Dan taylor(dtaylor@hilcorp.com) Subject: G-26RD Frac report (PTD 200-105) Dan, I have the 10-404 report for the frac on G-26RD. I see the FracFocus submission but there is not vendor report on the frac itself(pumped 12.5.14) Need plots and a comprehensive summary. Guy Schwartz Senior Petroleum EngineerA w . AOGCC SCANNED ! 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(Guv.schwartz@alaska.gov). 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 71��1 016(,,-; DATE: 12/23/14 P. I. Supervisor FROM: Jeff Jones SUBJECT: No Flow Test Petroleum Inspector TBU G-26RD Hilcorp PTD 2001050 - 12/22/14: I traveled to Hilcorp's Grayling platform in Cook Inlet to witness a No Flow test on well G-26RD. A passing no-flow test was performed 9/18/14 (AOGCC witness) but well was subsequently stimulated on 12/4-12/5/14 (Sundry approval 314-526) ' requiring a new no-flow determination. Scott Bumbaugh represented Hilcorp today and the test was performed in a safe and proficient manner. An Armor Flo model 3461-03-T033 flow meter with a 150-1500 scfh span was lined up from the well production to an open top container and monitored for 3 hours, passing the test. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 11:00 <150 none 11:30 <150 - none 12:00 <150 none • 12:30 <150 none 1:00 <150 none 1:30 <150 none - 2:00 <150 none ' Pressures are T/IA/OA Summary: Well G-26RD meets the AOGCC criteria for a No Flow designation. Attachments: None scosED t 1 Li 2014-1222_No-Flow_TBU_G-26RD_]j.docx Page 1 of 1 %Min Dec 5th, 2014 POST TREATMENT REPORT Hilcorp Alaska LLC G-26RD Treatment: Dec 4th-Dec 5th, 2014 Prepared for: Jim Young Senior Reservoir Engineer Cook Inlet Offshore, Hilcorp Alaska Ph: 907-777-8404 Jim Young, Please find attached our well report of the Fracture treatments on the G-26RD Well. The proppant and fluid used to complete each stage of the completion are displayed in the following table. Slurry Sand Volum Stage Sand type Mesh Pumped Fluid type a Rate Data-Frac None NA NA Spectra 2500 344.8 _ 19 bpm Main Frac CarboBond 20-40 30,494 Spectra 2500 659.3 23 bpm Baker Hughes Pressure Pumping Services appreciates the opportunity to perform pumping services for you in a cost-effective manner that focuses on safety, quality and the enhancement of your property's value. Please let me know if you have any questions ,41 Technical Support Engineer Kenai, Alaska (907) 398-8303 BAKER HUGHES Proposal No: 9415508131 HILCORP ENERGY CO TRADING BAY UNIT#G-26RD Greyling Platform Rig API # 50-733-20295-0000 MCARTHUR RIVER Field Kenai Offshore County,Alaska December 5th , 2014 Fracturing Post Job Report Prepared for: Prepared by: Jim Young Joshua Herald Senior Reservoir Engineer Region Engineer Cook Inlet Offshore Hilcorp Alaska LLC Email: Joshua.Herald@BakerHughes.com Bus Phone: 907-777-8404 Mobile: 907-398-8303 Email: jyoung@hilcorp.com Service Point: Service Representatives: PP, KENAI Kenneth Nix Bus Phone: 907-7764084 Account Manager (907)659-2329 Bus Phone: 907-267-3449 Fax: 907-776-5606 Mobile: 907-360-4737 Powered by PowerVision Gr4105 Fa STIMULATION TREATMENT REPORT ) BAKER HUGHES Date 05-DEC "4 District Keri,.., F.Receipt 10011121474 Customer HILCORP ENERGY CO Lease TRADING BAY UNIT#G-26110 Well Name TRADING BAY UNIT MG-2680 Field MCARTHUR RIVER Location ,.. County Kenai Offshore State Alaska Stage No�. 1 Well API -API 50733202950000 WELL DATA !Well Type: OLD Well Class: GAS Depth TD/PB: 11587 Formation: G Zone Geometry Type Tubular Type OD Weight ID Grade Top Bottom Perf Intervals TUBULAR CSG 7 32 6,094 L-80 10121 11587 1 Top Bottom SPF Diameter TUBULAR TBG 3.5 12.95 2 75 P-110 0 10141 10296 10329 6 Packer Type JS-3 Storm Packer Packer Depth 10100 FT TREATMENT DATA ! LIQUID PUMPED AND Fluid Type Fluid Desc Pumped Volume(Gals) Prop.Description Volume Pumped(Lbs) CAPACITIES IN BBLS. TREATMENT FUN° Unear Get Water CARBOBOND UTE 20/40 83.205 Tubing Cap. 75 PAD Linear Gel Water Casing Cap. 0 TREATMENT FLUID Linear Gel Water Total Prop Ory: 83 205 Annular Cap. 624,7 Open Hole Cap. 0 Fluid to Load 700 Pad Volume 76 Previous Treatment Previous Production Treating Fluid 629 Hole Loaded With Filtered Inlet Wa Treat Via:Tubing ® Casing 0 Anul. 0 Tubing&Anul.El Flush 151.4205 Ball Sealers _In� Stages Type Overflush 0 Auxiliary Materials Fluid to Recover 0 PROCEDURE SUMMARY Time Surface Slurry Slurry Rate AM/PM Treating Pressure-Psi BBLS.Pumped BPM Comments STP Annulus Stage,_ Total 12:00 0 0 0 0 _. 0 11/27/2014 12:00 0 0 0� 0- 0 ARRIVE ON LOCATION 13:00 0 0 0, 0 0 SPOT SNAD SILO _. 13:30 0 0 0 0 0 SPOT BLENDER , 14:30 1 0 0 i 0 0 0 SPOT HYDRATION UNIT _.. ___— ._ 16:00 0 0_ 0 0 0 DUMP SAND 17:30 . 0 0 0 0 0 FINISH DUMPING SAND 20 TOTAL 19:00 ± 0 0 0 ' 0 0 BOAT N2 ARRIVES _ 20:00 0 0 0 0 0 ,ALL 3 PUMPS ON DECK,0213,0206 HAVE BROKEN LIGHTS 23:30 0 0 0 0 0 FINISH MAKING ROOM ON TOP DEACK AND PIP RACK FOR EQUIPMENT,GO TO BED I 00:00 0 0 0 0 0 11/28/2014 04:00 0 0 0 0 0 ,MORING SIMOPS MEETING `_ 06:00 0 0 0 0 0 1RIG STILL MILLING OUT f 11:00 0 0 0 0 0 BRIG ON BOTTOM NOW CIRC.HOLE CLEAN 12:30 0 0 , 0 0 0 TRIG P.O.O.H. 13:00 0 0 0 0 0 BOAT ON ITS WAY TO PLATFORM 15:30 0 0 0 0 0 BOAT AT PLATFORM 16:00 0 0 0 0 0 SPOT N-2 PUMP 17:00 0 0 0 0 0 SPOT FLUID PUMP FOR COIL 17:20 0 0 0 0 0 PRE-JOB,RIG UP TANKS AND HOSES FROM TANKS TO ^—_ HYDRATION UNIT,HYDRATION UNIT TO BLENDER I, 22:30 0 0 0 0 0 tFINISH RIGGIN UP TANKS AND HOSES 23:00 0 0 0 0 0 MOVE EMPTY HOSE BASKET AND IRON RACKS AROUND TOP MAKE MORE ROOM FOR NEXT BOAT 00:00 0 0 0 0 0 11/29/2014 04'00 _ 0 _ 0 0 0 , 0 MORNING SIMOPS MEETING 06,00 0 0 0 0_ 0 RIG ON BOTTOM DISPLACING WELL WITH CLEAN FLUID 08:30 0 0 0 0 0 DISPLACING WELL 10:30 0 0 0 0 0 DISPLACING WELL 12:30 0_ 0 0 0 0 CALL FOR TWO MORE BHI PERSONNEL 14:00 0 0 0 0 0 BOAT ARRIVS WITH MORE EQUIPMENT notion Pnnloopn 0a.4214201412.24 PIA 203030 (... Treatment Report-Supplement 11 BAKER HUGHES Date 05•DEC-14 District Kenai _ F.Receipt 10011121474 Customer_HILCORP ENERGY CO Lease TRADING BAY UNIT#G Well Name TRADING BAY UNIT#( Field MCARTHUR RIVER Location PP KFNAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733202950000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 15:00 0 0 0 0 0 FINISHING SPOTI, • •„-; •R__ _23.44 0 0 n 0 FINISHING RIGGIN UEJ3E.1RON 00100 0 0 0 0 0 11/30/2014 04:00 0 0 0 0 0 MORNING SIMOPS MEETING .__06.00 0 0 0 0 0 GOT PERMITS FOR FIRING EQIPMFNT __,.0810 0 0 0 0 0 FIRE UP EQIUIPMFNT 10:15 0 0 0 0 0 0919 FUEOL UNE BLOWS OFF,BLENDER HYDRAULIC FILTER CRACKED _1.0:45 0 0 n 0 . <At I 1- „ CHANIC 10:50 0 0 0 0 0 FIRE REST OF EQUIPMENT UP,EVERYTHING LOOKS GOOD 11:30 0 0 0 0 0 MAKE MORE ROOM ON DECK FOR THE REST OF COILS EQUIPMENT AND IRON RUNS 12.00 0 0 0 0 • • E 0 ARRIVE TO BEGIN RIG UP 14:00 0 0 0 0 0 SPOT COIL ON PIPE RACK AND OPS CAB WITH B.O.P CAGE AND ENJECTOR CAGE _15 nn n n 0 0 0 HELP COIL RIG UP LINES FROM PUMPS ANOJIILUJNES 22:00 0 0 0 0 0 I• EBIG.G1hLUEUNES.AS.E9R AS WE CAN RUN THEM_ 00:00 0 0 0 0 0 12/01/2014 _-04:01 I I . I t L•:I. I. ,,,s• „ 4 06:00 0 0 0 0 0 RIG ON BOTTOM W/PACKFR CO 10146' 08:00 0 0 0 0 0 PRE-JOB RIG UP,DISCHARGE HOSES/IRON,AND STAND PIPSES 12.00 0 0 0 0 0 TANI)COIL STAND PIPS FOR KILLUNE AND FLOW BACK_ I r r r r I u ..:. :►• •/ - _ •:; ••!,r 1 II IIT 1 : LI : . I 14:30 0 0 0 0 0 HYDRAULIC FILTER HOUSING ON BLENDER CRACKED, BYPASS HYDRAULIC FILTER 15:15 0 0 0 0 0 RIG UP TO MONITOR THE FRAC STRING TEST _16'141 I r - •k . •:. : .•r �1 a 11111111111.111116111111111.11:411111111111111 : - I ON WORK STRING ,___1.6:14 0 0 0 0 0 RESTART TEST 9615 PSI _16' .0 0 I r t • = 8 •EEQ GOOD ST AS PER CO.MAN. 19;00 0 0 0 0 0 SLICK UNE RAN IN HOLE TO PULL PRONG+PLUG,PARTED SUCK UNE IN HOLE 0 SURFACE 20:30 0 0 0 0 0 BOAT ARRIVE DROPPED OFF MORE CREW MEMBERS, HEADING BACKT TO DOC WITH CHEMICALS 21:00 0 0 0 0 0 TALKED WITH CO.MAN,TURNED BOAT AROUND CAUSE IT HAS CHEMICALS THAT CAN NOT FREEZ ON IT 23:00 0 0 0 0 0 CHEMICALS ARRIVE AND SPOTTED IN HEATED ROOM, BOAT LEFT WITH REMAINING CHEMICALS 00:00 0 0 0 0 0 12102/2014 01:00 0 0 0 0 0 BOAT RETURNED WITH REST OF CHEMICALS,SPOTTED ON DECK 0400 r 0 0 , 0 0 .11.- G SIMOPS MEETING _06'00 a n a, a FT CREW UP FOR MDRJ ING_BAE EY.MFFTING 08:30 0 0 0 , 0 1 : TMV AND HAVE PRE-JOB Treating Pressure Injection Rates Shut In Pressures Customer Rep. Harold Soul Minimum 5700 Treating Fluid 23 ISDP 4286 BJ Rep, JORDAN E WATERS - Maximum 8539 Flush 23 5 Min. 0 Job Number 10011121474 Average 7119 Average 20.15 10 Min. 0 Rec.ID No. Operators Max.Pressure 15 Min. 0 Distribution 8539Final 921 In Min. 55 Flush Dens.Ib./gal. 8.4 Report Pnnled al.0¢m1Da 8.2014 12.2.PM h8001 FAR Treatment Report-Supplement BAKER HUGHES Date 05-DEC-14 District Kenai F.Receipt 10011121474 Customer HILCORP ENERGY CO Lease TRADING BAY UNIT#G Well Name TRADING BAY UNIT N( Field MCARTHUR RIVER Location PP KFNAI County Kenai Offshore State Alaska Stage No 1 Well API •API 50733202950000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 08:45 0 0 0 0 0 PICK ALL COIL EQUIPMENT AND SPOTT DUCK PONDS 1. ; - 10:00 0 0 0 0 •. . ; . - • , :: . /1 Q REST OF KILL LINE I• I 1 • I ira •l L : L ' • , :: . 1►DRESTOFKIL LINE _19;00 0 0 0 0 lininirl •• 1 ; c • - • A :1, . 1•QBF.ST OF KILL LINE 22;i I • I 5 1 11.111111111101 ► • : ► - ;OA • • A :: a L Di lLL.LINE_ 23:30 • 0 0 0 0 .• • • ► %,L . ►D_CBEW_IIIBED 151II I I • iiii • . • ••'IA 11111111111111111111111111111111111111MEE ll•:14 1 118• 1, a l 061. IIIIIIIIIIIIIIIIrIIIIIIIIIIIIIIIII17111111EE7MMIMIIIr q : I • • •1• IIIIIIIIIIIIIIIIIPIINIIIIIIIIIEINIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIEIIIIM 1,•:L L :a 14 a i. 0: MMINIMINIIIIIII1 Imo: l • : I, - - A . •II 12:00 0 0 0 0 0 RIG UP COIL FLOW BACK TO TANK AND B.O.P.ALONG A I. . LL LINE 14:00 0 0 0 00 COIL ON RIG FLOOR WITH INJECTOR READY TO STAB 19:4 • IIIIIIIIIIIIIIIIIIIIDII1dra • .-: . l • L .; 'II 1 IMMIIMINICIIIIIIIIIII - I - „- n0M• 111=1111111M111111111:111151 •' • • _03:00 0 0 I 0 imimin ;a, - . :• • :. ,c ; c,c N UP 11G..FIQOP _04:•• I • I I 111111111111111111111111113 • l : • - _06:0(1._ 0 . 0 0 0 0 RELEIVEGO1U It1_SOIf1IE HELP FROM THE FRAC HEW__.- _08:00_ __.0 0 0 0 0 TANDIIP 3-STAND PIPE TO RIGFLOOR '1,1 • • a I 1 •91 .1 - • •l • - •;14 12:30 0 0 0 0 0 COIL ATTEMPT TO MAKE IT DOWN PAST T.I.W.FAIL, SSI I •ILDOWNPASQT_FMFING UP ON B ANCYS _13:4 • • GANCYSAND T.LW.VALVE 14:00 0 0 0 0 0 FIRE UP PUMPS AND ALL EQUIPMENT,HYDRATION UNIT : •: A ► •.• A L . ll L I • IA • :.1 II • .1 11.1.1.1111111111.11,11.111111111naMMIIM:: ► •,► 11 ; • . 9;1 •1 I. 16:35 0 0 0 0 0 PRE-JOB WITH RIG CREW AND ALL PERSONNEL I. • / • A ■ •1 . :/ 16.20 0 0 0 0 E111111111111E3 u :: ■ : . ED 17:20 0 0 0 0 0 REPLACE WITH NEW BATTERY AND BACK UP AND LING 1130 0 0 0 0 I : • • •.► • •:• - L • :: i : -16:15 0 0 0 0 I ► . .LINEJQPRIMF UELINES TO SLOP TANK •.41.11 I I I • IIMMIII.rrll •:• 19:10 0 0 0 0 IIIIIMIIIII.ra • • • ; . ; I LES •. • • • • IIIINIIIIIIIIIIIWII 20:25 EIMIlli7. �_•1111.1.111111r4 -: :. • . 1_I - _SA�� a -•- . 21.20 0 •ME 0 0 FI IIP HYDRATION UNIT 21' .1 • •' NF OUT GROUND • • • _I.nniiiiira•- • • , 22=(ln n 1893 0 0 • POOL UP BLENDER Treating Pressure I Injection Rates Shut In Pressures Customer Rep. Harold Soul Minimum 5700 !Treating Fluid 23 ISDP 4286 BJ Rep. JORDAN E WATERS Maximum 8539 Flush 23 5 Min. 0 Job Number 10011121474 Average 7119 Average 20.15 10 Mn. 0 Rec.ID No. Operators Max.Pressure 15 MM. 0 Distribution 8539 Final 921 In MM. 55 Flush Dens.lb./gal. 8.4 RepOn Prxeo0 on oucvnO.r a 2011 12 2.1 PM Jr800t VAR Treatment Report-Supplement BAKER JIH ES Date 05•DEC-11 District Kenai F.Receipt 10011121474 Customer HILCORP ENERGY CO Lease TRADING BAY UNIT#G Well Name TRADING BAY UNIT 1I( Field MCARTHUR RIVER Location PP,KENAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733202950000 TIME Treating Pressure-Psi Surlace Slurry Slurry Rate Comments BBL..Pumped BPM STP Annulus Stage Total 22:02 3215 1934 14 3.4 3.4_PUMP_IN_GEAR.GOING DOWN 1101 F _22:08 51.10.._ 1$71 20.4 20 4 6 INCREAS RATE TO 6 BPM __.22:09 6430_ laZ4 26 4 26.4 10 INCREAS.RATE TO 10 BPM ._.22:12 6120 1786 50 50 10 RATE AND PRESSURE CHECK 2220 5737 1865 60 136 10.4 RATE AND PRESSURE CHECK 22:25 7168 1682. 13Q 236 20 INCRESED RATE 22: : a,. • e •,a a NCRESED RATE 2229 7634 1476 70 296 20 BEGIN STEP DOWN 2210 . 7634 1476 70' 296 0 SHUT DOWN 2232 3650 1476 76 302 0 ISIP 3650 22'44 940 1509 76 302 0 MONITORING PRESSURE _.23211_______158...___1564 76 31 a I/•,► •: 23:35 0 0 76 302 0 SHUT IN WFI L BLEED OFF LINES-AND WASH UP 00.00 0 0 0 0 0_12L052014 0010 0 0 0 0 0 FINISH WASHING UP ANDBLOWING DOWN GO TO BED .... 04.00 0 0 0 0 (LIMNING SIMOPS MEETING 07:00 0 0 0 0 0 CREW UP _07:30 0 0 0 0, Q.MOSN tia SAEIEYMEETIi4GYytTkt.CREW 08:00 0 0 0 0 0 FIRE UP EQUIPMENT AND STIL CHEM CAL S 10:00 0 0 0 0 0 REFRIMEALt LINES TO TANK _l ' a a a a a . ►_ •: . • : a •:u .. ii 1:30_. 0 0 0 0 0 NEW ALINATOR INSTALLED 14:00 0 0 0 0 0 PRE-JOB WITH RIG AND ALL ENVLOVED PERSONNEL FOR MAIN FRAC __14.10 0 0 0 0 a i, • .• • i, . •: : NJOB 14.40 0 0 0 0 BERING ON_WATER TO HYDRATION UNIT 1.4:42 0 0 0 0 . 0J3EPRIMETRUCKS 14'46 0 0 0 0 0 SET POP OFF _1.5'00 0 0 0 0 0,GEL UP HYDRATION UNIT 1525 0 2172 0 0 0 SET ANNULUS PRESSURE _15:30 0 2172 0 0- 0 OPEN TO WELL _15:35 5640 2172 10 10 10 PUMPING DOWN HOLE _15:40__ 6432 1964 50 50 202 RATE AND PRESSURE CHECK _15:41 7150 1925 103 103 23 RATE AND PRESSURE CHECK ___15:45_____6—: a_ .a .r . 15:50 6886 1947 40 280 23 SAND ON FORMATION 15:51 6681 1890 45 325 23 STAGE 2 LB 15:53 8577 1841 44 369 23,STAGE 3 LB ._15:555 8541 2201 44 413 23_SS,TAGE 4 LB 15:.67 6800 2134 66 479 23 STAGES LB _15.:19_____6893 .2101 50 529 23 CUT SAND INTO HOPPER _16:00 7201 23 552 23 STAGE FLUSH 16:04 8539 2042 76 629 0 FLUSH AWAY.SHUT DOWN ..16:05 4286 76 629 0_ISIP.4286 ,_16:15 921 76 629 0 SHUT IN WELL AND BLEED OFF 17:00 0 0 0 0 f 0 BEGIN BLOW DOWN AND RIG DOWN PRCEDURE TO GET COIL ON THE WELL Treating Pressure Injection Rates Shut In Pressures Customer Rep. Harold Soul Minimum 5700 Treating Fluid 23 ISDP 4286 BJ Rep. JORDAN E WATERS Maximum 8539 Flush 23 5 Min. 0 Job Number 10011121474 Average 7119 Average 20.15 10 Min. 0 Rec.ID No. Operators Max.Pressure 15 Min. 0 Distribution 8539 Final 921 In Min. 55 Flush Dens.Ib./gal. 8.4 nowt Piu,4oc o11 Ou:unwt6 2014 1224 Pu J•111,71 BAICER HES Proposal No: 9415508131 HILCORP ENERGY CO TRADING BAY UNIT#G-26RD Greyling Platform Rig API # 50-733-20295-0000 MCARTHUR RIVER Field Kenai Offshore County,Alaska December 5th , 2014 Data Frac Prepared for: Prepared by: Jim Young Joshua Herald Senior Reservoir Engineer Region Engineer Cook Inlet Offshore Hilcorp Alaska LLC Email: Joshua.Herald@BakerHughes.com Bus Phone: 907-777-8404 Mobile: 907-398-8303 Email: jyoung@hilcorp.com Service Point: Service Representatives: PP, KENAI Kenneth Nix Bus Phone: 907-7764084 Account Manager (907)659-2329 Bus Phone: 907-267-3449 Fax: 907-776-5606 Mobile: 907-360-4737 Powered by PowerVision Gr41 05 v (esd) VSd H8 (esd) VSd 113u18 0 o LO o v N T T in o 0 1 1 1 1 1 1 I 1 1 1 1 1 1 ' 1 1 1 1 1 I ani V CO a CO N- T N 4 t O o H M N N T @ 0 Q !h O O co O N IN v ---- N O II CAl- ,' •= i a) as CI p N oci a - N O L 6 co 6' _o Q N N CI- J E O co Q N—, co -0 N T d r i I` Lct � o O N ca yas CO CO E O .- o I N ovi �CO �v. � i ti Q CI 2Eaa) E Cr)O ti • Z Q -- I O LO I I I h m > VS 0 0 0 0 CO N (uadq) a eN M1 I 1 I I I I 1 I I I I Rime0 0 o o 0 ImIM2 Lr) 0 T T in D gI (!sd) sn!nuuy (!sd) d1H8 Paleln3Ie3 (!sd) dig y 03 m v 0 N ^, W O L E U 0a) CO a L CZ — > D • L 0 H O LL U) U) CL 0000 _. 0 E .0 CO Lf) C3) C7 CnNN- � MINN 0 c3) 00 N.. CD C i) Q co O N- r— 0) G) L CIS Q I 0 L a N C L C '�/= .N V/ � Gi }i E CO co CI 1 o co N aL U 0 , r 2 Jo II 1 2 CI caa y RI2 O e- C,G o 2 :• CO CU O t `- = C7 •Cf) ( CO 000 = E a 0ili M CD o CO �N 00 aoZo o co O H oO � ciO s 0 h 0 o M g X CD Y (0 021 ri- BAKER HUGHES Proposal No: 9415508131 HILCORP ENERGY CO TRADING BAY UNIT#G-26RD Greyling Platform Rig API # 50-733-20295-0000 MCARTHUR RIVER Field Kenai Offshore County, Alaska December 5`h , 2014 Main Frac Prepared for: Prepared by: Jim Young Joshua Herald Senior Reservoir Engineer Region Engineer Cook Inlet Offshore Hilcorp Alaska LLC Email: Joshua.Herald@BakerHughes.com Bus Phone: 907-777-8404 Mobile: 907-398-8303 Email: jyoung@hilcorp.com Service Point: Service Representatives: PP, KENAI Kenneth Nix Bus Phone: 907-7764084 Account Manager (907) 659-2329 Bus Phone: 907-267-3449 Fax: 907-776-5606 Mobile: 907-360-4737 Powered by PowerVision Gr41O v (uadq) area (esd) VSd H8 (esd) vSd apul8 N 0 0Lo � o 0 0 0 0 I I I 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 I cd O U O 0 -1411V (6 M L O C N CO N a O 0_ r co.00 0\ '` Q r � / ACO LOco In N u) Q Q .= cc c6 C N— a COCO 0_ NCh Q CI c ct (N o (0 / a) 0 Q M V CcC 2 I.U (N 0) CO r- O N CI- c) V ✓ JO N v %co - t\ .0 � Q 0, Q O .- Q.c - O —, , L = o � : O CA N d t 2C� f` _• E a E 1 MV d Z O Z 1 M C YJZIya 6N MI I I I I 1 m2izn N o in = gi (isd) snlnuuV (isd) d1H8 pe ein3le3 (!sd) dig Y CD CO RECEIVED STATE OF ALASKA ALt-.....A OIL AND GAS CONSERVATION COMMISSION JAN 0 9 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon El Repair Well El Plug Perforations 0 Perforate El Other El Run G/L Completion Performed: Alter Casing ❑ Pull Tubing❑] Stimulate-Frac 2 Waiver❑ Time Extension❑ Change Approved Program El Operat.Shutdown] Stimulate-Other El Re-enter Suspended WeU❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory❑ 200-105 3.Address: 3800 Centerpoint Drive,Suite 1400 StratigraphiC❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20295-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit/G-26RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,587 feet Plugs measured N/A feet true vertical 9,734 feet Junk measured 10,638 feet Effective Depth measured 10,638 feet Packer measured 10,194 feet true vertical 9,103 feet true vertical 8,738 feet Casing Length Size MD TVD Burst Collapse Structural 356' 26" 356' 356' Conductor 785' 20" 785' 758' 1,530 psi 520 psi Surface 5,611' 13-3/8" 5,611' 4,935' 3,090 psi 1,540 psi Intermediate Production 10,263' 9-5/8" 10,263' 8,797' 6,870 psi 4,760 psi Liner 1,466' 7" 11,587' 9,734' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet `I 1� True Vertical depth See Schematic feet 5COKED -- .cL i 1 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2*/L-80 10,242'(MD) 8,779'(ND) Packers and SSSV(type,measured and true vertical depth) Packer 10,194'MD/8,738'ND SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): G-Zone 10,296'-10,329' Treatment descriptions including volumes used and final pressure: Total fluid 1,303 bbls/Total propant 30,494 lbs/Final pressure 8,319 psi 13. Representative Daily Average Production or Injection Data 1 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 15 4 85 1000 444 Subsequent to operation: 26 7 284 1022 120 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil LI Gas ❑ WDSPL❑ GSTOR El WINJ ❑ WAG ❑ GINJ El 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: 314-510&314-526 Contact Dan Taylor Email dtavlor aAhilcoro.com Printed Name Dan Taylor. - ---) Title Operations Engineer Signature / I Phone (907)777-8319 Dt t 1/8/2015 Form 10-404 Revised 10/2012 /.Z 6 1 Submit Original Only McArthur River Field Well: G-26RD 14 Completed: 12-9-14 Hikorp Alaska,LLC PTD: 200-105 RKB to TBG Head=40.15ft Tree connection:4-1/16in5,000# CASING DETAIL 1 SIZE _ WT GRADE CONN ID TOP BTM. 26" - - - - Surf 356' 20" 94 H-40 - - Surf 785' 22Ofn 94#C 13-3/8" 61 K-55 Butt. 12.515 Surf 2,610' MD=785ft 68 K-55 Butt. 12.515 2,610' 5,611' 47 N-80 Butt 8.681 Surf 7,979' D 9-5/8" 47 P-110 Butt 8.681 7,979' 9,523' 47 USS-95 Butt 8.681 9,523' 10,263' 7" 29 L-80 Butt 6.184 10,121' 11,587' TUBING DETAIL L y L 3-1/2" 9.2 L-80 Supermax 3.958 Surf 10,242' 13-3?Bn 6186811 Csg MD=5,611ft D #2 GLM% JEWELRY DETAIL No Depth ID(in) Item 1 40.15' CIW-DCBS-FBB,11 X 3.5 Hydril 563 SUSP X 3.5 EUE 8 % " RND W/3in Type H BPV TM8,224ft _ 3.5in SF0-1 Gas Lift Mandrels(OD:5.313in):2,078ft, 2zc6*, 1. : 2 2.992 4,153ft,5,963ft,7,612ft,9,028ft,10,146ft r''. 3 10,194ft 5.160 Packer 7in 29# 410,233ft 2.813 "X"Nipple 7in 29#.r Tc 5 10,242ft 2.992 WLEG t ; MD=10,121ft - inc=306 10,700ft CIBP:Top of Cement 10,665ft #3 Tin 29#Piv V 111 MD=10,194ft 'J 1 x #4XNpole l' MD=1 IQL�233R 9y8in47#Csg u PERFORATION DETAILS MD=10,283ft i• / #5 vac Zone Top(ft) Btm.(ft) Ft. Comments ,{ MD 10,242R GZN-4 10,296 10,329 33' 2-1/2"60 deg 6SPF DP(7/9/14) 1 =G-4 H-1 10,728 10,743 15' 2-7/8"60 deg 6SPF(8/3/00) =TOS_Dev:31°-32° 10,782 10,787 5' 2-7/8"60 deg 6SPF(1/16/01) =1o,zssrt-1o,329ft H 2 10,792 10,802 10' 2-7/8"60 deg 6SPF(1/16/01) I' H-3 10,932 10,942 10' 2-7/8"Power Jet(11/18/00) #spt IsliblAS. H-4 11,027 11,103 76' 2-7/8"60 deg 6SPF(8/3/00) MD=10,700ftr Inc= $ - 11,200 11,210 10' 2-7/8"60 deg 6SPF(8/3/00) ,. =F{1 H-S 11,228 11,235 7' 2-7/8"Power Jet(11/2/00) 11,315 11,325 10' 2-7/8"Power Jet(11/2/00) +,a H-6 11,442 11,448 6' 2-7/8"60 deg 6SPF(8/3/00) '; _ H-2 r T' � =H3 1Parts(MD)�- 1Q728-11,448ft — s _ H.4 8 Vii° _ till = H-5 oil — H-6 N PBTD=11,535ft TD=11,587ft MAX HOLE ANGLE=54.6° Updated By:DRT 12/16/2014 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-26RD 50-733-20295-01 200-105 11/17/14 12/9/14 Daily Operations: 11/17/14-Monday HOLD SAFETY MEETING. RIG UP RISER AND BOPS,TORQUE SAME. START RIGGING UP LANDING ON BOTH DRILLER AND OFF DRILLERS SIDE. BUILD SCAFFOLDING AROUND BOPS AND RIG UP BELL NIPPLE AND RE-ROUTE PVC FLOWLINE.JOHNNIE r�(a HILL WITH AOGCC WILL WITNESS THE BOP TESTING AT 6PM. P`1 11/18/14-Tuesday HOLD SAFETY MEETING WITH DAYLIGHT CREW. INSTALLED POLLUTION PANS,CUT 4"OFF OF BELL NIPPLE AND INSTALL SAME WITH DRESSER SLEEVE. INSTALL H BEAMS AND FLOOR. MAKE UP 4-1/2"TEST JOINT AND FILL STACK. SHELL TEST AND BOP AND CIRCULATION SYSTEM, GOOD TEST.TEST ALL ROPE INCLUDED SURFACE VALVES WHILE WAITING ON AOGCC, GOOD TEST. JOHNNIE HILL WITH AOGCC ARRIVED.START TESTING BOPE INCLUDING GAS DETECTION AND PVT p SYSTEM ACCORDING TO SUNDRY 314-526 4-1/2"TUBING AND 3-1/2"TUBING 250 PSI LOW/2500 PSI HIGH. GOOD TEST. 0, REMOVE TEST JOINT AND PULL 2 WAY CHECK AND RIG UP TO PULL HANGER. SHUT DOWN DUE TO UNABLE TO TIGHTEN OFF DRILLERS SIDE MASTER SKID CLAMP.WE CANNOT PULL TUBING TILL CLAMP IS TIGHTENED. DUE TO WEATHER, SCAFFOLDING HAS BEEN AT THE DOCK FOR 2 DAYS.WHILE WAITING, CLEAN PIPE DECK AND COMPLETION TUBING AND OTHER WELL EQUIPMENT.SPOT HEATER FOR MUD TANK AREA. 11/19/14-Wednesday HOLD SAFETY MEETING. CLEAN WORK AREA AND OFFLOAD SCAFFOLDING. BUILD SCAFFOLDING AND TIGHEN REAR OFF DRILLERS SIDE MASTERSKID CLAMP. BACK OUT HANGER PINS AND WORK TUBING TO 160,000# 20,000#OVER.TUBNG BECAME FREE AFTER 30 MINS. POOH AT 142,000#HAVING TO USE BJ TONGS TO BREAK TUBING. AT SCSSV, BREAK OUT AND LAY DOWN SAME. RIG UP PUMP IN SUB. START PUMPING FIW AND TAKING RETURNS TO TRADING BAY. 800 BBLS PUMPED. START POOH WITH COMPLETION STRING 4-1/2"TUBING AND TALLYING SAME WHILE LAYING DOWN. 3,400' OUT OF WELL AT REPORT TIME. PUMPING METAL DISPLACMENT WHILE PULL OUT OF HOLE. MINIMAL SCALE IN TUBING SO FAR. 11/20/14-Thursday HOLD SAFETY MEETING AND SERVICE EQUIPMENT. CONTINUE POOH LAYING DOWN 4-1/2" I13T TUBING AND GLV'S.TALLEY SAME. SHUT IN WELL.SERVICE RIG. PJSM.CONTINUE POOH LAYING DOWN 4-1/2" IBT TUBING AND GLM. LAST 3 JOINTS OF 4-1/2" IBT HAD HOLE DEPTH 9,941'-10,064'. LAY DOWN SEAL ASSEMBLY AND 3 JOINT OF 4-1/2" HYDRIL 511.ALL COMPLETION STRING RECOVERED, 242 JTS,9 GLM, 1 SSSV, 16 SS BANDS. CLEAN RIG FLOOR AND PIPE DECK. BACK LOAD WORK BOAT OF TUBING. Make up Pioneer packer assembly. BHA#1, Packer retrieving spear assy, packer head mill,triple head bushing, 2-boot baskets, bit sub, string magnet, bumper jar, oil jar, 6-4 3/4 DC,xo=236.35. TIH w/Pioneer packer assy on 3 1/2 PH-6 work string t/1,482'. 11/21/14-Friday Cont TIH w/Pioneer packer milling assy. P/U 3 1/2 PH-6 wk string t/8,126',tagged, attempt to wk through no go,jarred free. POOH with Pioneer packer milling assy. Lay BHA and start rigging up slickline. M/up gamma and 40 finger caliper and TIH to 10,069'WLM. Open caliper and it failed, no indication that its closed. POOH. Change out caliper tools and trip back in hole to 10,069'WLM.Start logging up 8,104'to 8,122'WLM.Shows to have a ID of 6.80. Continue logging to surface. _ , Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-26RD 50-733-20295-01 200-105 11/17/14 12/9/14 Daily Operations: 11/22/14-Saturday R/D a/line. P/U BHA #2,8-1/2 taper mill, bit sub,xo, bumper jar,oil jar,6-4 3/4 DC,xo=217.60'. TIH t/8,121' up wt 130, dn 86. P/U&R/U power swivel. RIH tag @ 8,126',wash&ream dn t/8,133', break through.Work area till clean. Rot wt 100,tq 5-7k,pump 3.5 bpm, 300 psi.Cont ream t/8,143'. L/D swivel.Cont RIH. P/U 3 1/2 PH-6 wk string to 10,082',top of packer,close annular and start reverse circulating at 3 bpm at 100 psi. 106 total bbls. Pooh L/D BHA#2. P/U BHA#3 packer retrieving spear assy, packer head mill,xo, boot basket, bit sub, in-line magnet, bumper jar,oil jar,6-4-3/4"drill collar,ox, =236.37'.TIH t/2,500' up wt 52k,dn 46k. 11/23/14-Sunday Cont TIH w/Pioneer packer milling assy. Had tight spot @ 8,165'worked through.Tight @ 8,290' unable to wk through. P/U swivel,wash&ream through tight spot @ 8,290'-8,296'circ 3 bpm, 280 psi, rot wt 106, up wt 130,dn 83. L/d swivel. Cont TIH t/10,061'.Tight @ 8,857',9,090',9,772',9,861'. P/U swivel, mill on packer f/10,074'-10,077' up wt 140,dn 83, rot wt 120,tq 6-8k, pump 160 GPM,530 psi,changing parameters as needed till free. Pushed down t/10,092'. R/D swivel. POOH dragging off bottom 160,000#-190,000#. POOH t/1,979'. 11/24/14-Monday Cont POOH w/Pioneer packer milling asst'_Ld BHA. No recovery. Clear&clean floor. Rig maintenance&repair. P/u BHA #3,spear w/4.805 grapple,stop sub,xo, bumper jar,oil jar,(6)4 3/4 DC,accel.jar,xo=228.81'.TIH t/10,114'engaged fish,up wt 160,dn wt 94. POOH w/fish, hanging at several casing collars having to wk through. L/D BHA. Recovered packer &seal bore ext. Clean&clear floor. M/U 3 1/2 test jt. Fill hole&surface eq. 11/25/14-Tuesday Test BOPE as per Hilcorp&AOGCC regulations.Witnessed waived by AOGCC Inspector,Jim Regg @ 11: 01 on 11-24-14. Test 250 psi low and 2500 psi high.Tested w/3 1/2 jt, good. Pull test plug. Install wear bushing. L/d test jt. P/U BHA#4- 6" bit,7"CASING SCRAPER, BIT SUB, BUMPER JAR,OIL JAR,6-4 3/4 dc,XO=215.55.TIH t/10,257', up wt 168,dn wt 92,wk f/10195-10257 4x. CBUx2 @ 3.5 BPM,500 psi. POOH w/7"scraper assy. L/d BHA. P/U BHA- 7" 29# test packer,XO= 12.03'.TIH with same t/4,428', up wt 66,dn 54. Shut down f/crew change. Both crews c/o on boat.Choppers on weather hold since 17:00 11-26-14. 11/26/14-Wednesday Cont.crew change,orientate&PTSM. Cont.TIH w/7" RTTS,t/10,233', up wt 155,dn wt 90.Set packer. R/u t/test casing, pressure up t/2500 psi. Found leak on hanger pin. Bleed down&repaired. Pressured up t/2500 psi, pressure dropped. Bleed down. L/d single&repositioned packer @ 10,188'. Pressured up t/2500 found leak on ann.valve. Bleed down& repaired. Pressured up t/2500 held f/30 min good. Bleed down&R/D test eq. Unseat packer&POOH t/9,908'. Cut&slip drill line. Cont. POOH w/7" RTTS. L/d BHA. P/U BHA#7-cleanout assembly: 6" non-rotating cable shoe, 1-joint 5-3/4" wash pipe,xo, bumper jar,oil jar,6-4-3/4"drill collars,xo=247.57'.TIH t/9,582', up wt 140,dn 90. IIHilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-26RD 50-733-20295-01 200-105 11/17/14 12/9/14 Daily Operations: 11/27/14-Thursday Cont.TIH w/c/o assy,tag @ 10307', up wt 160,dn 98. P/U swivel,circ @ 3.5 bpm,430 psi, rot wt 112,tq 5-6k.Wash& ream t/10,392', had issues packing off,was able to clear. Pressure increased 300 psi.Attempt to clear, unable. Troubleshoot finding 1 1/2" metal piece lodged in return line. Cont.wash&ream t/10,694'circ @ 4 bpm 580 psi. Getting scale&sand returns. 11/28/14-Friday Cont.wash&ream t/10,750', up wt 170,dn 88,circ 4 bpm,580 psi. CBU x3 @ 4 bpm,580 psi. POOH t/9,956', up wt 160, dn 96, pulling wet. CBU x3 @ 4 bpm,430 psi, until clean. Getting sand&scale back. POOH. L/D BHA,wash pipe and cable shoe. Found .5 of a bucket of metal, rubber and scale. P/U BHA: Bit,7"scraper, bit sub, 12 joints 3-1/2"(373')xo,9-5/8" scraper, bit sub, bumper jar,oil jar,6-joints 4-3/4"drill collars,xo. =217.46'. Fishing tools total with tubing=590.63'. Moncla tongs broke down.Change out tongs. Continue TIH with workstring to 10,491'. R/U t/displace well t/clean fluid. Pump out pits&clean. 11/29/14-Saturday Displace well t/clean FIW. Pump 4 bpm,720 psi, pumped 1175bbls. POOH L/D BHA. R/U a-line. M/u and TIH with 5.80 gauge ring to 10,740'tag, POOH. M/u 7"CIBP and TIH to 10,688'CCL depth with top of plug at 10,700'.Set bridge plug and POOH. Mixing cement and load 30'5" bailer. RIH&tag TOP @ 10,700'. P/u&dump 13'+/-15.8 ppg cmt. POOH. 11/30/14-Sunday Cont. POOH w/a-line&r/d. P/U&m/u test jt. Pull wear bushing. Install test plug. Fill surface equip. Organize pipe rack. Clear floor. Finish filling 400 bbl upright tanks w/FIW&start heating. Test BOPE as per Hilcorp&AOGCC regulations. Witness waived by AOGCC Inspector,Jim Regg @ 12:29 on 11-30-14.Test 250 psi low and 2500 psi high.Tested w/3 1/2 jt. Lay out test joints. Prepare to run test packer and change out tongs. Change out tongs due to broken pin. Mu test assemblyxn nipple,xo, RTTS,xo,xo, pup joint with temp/pressure survey tool attached=22.48.TIH with assembly, torqueing every connection to 7000 ft/lbs. 154k pick up weight,92k slack off weight set packer @ 10,196'. 12/01/14-Monday R/U&_____test packer t/_2500 f/30 min,good. R/U W/LINE. RIH W/3"X-LINE W/RN PLUG TO 10,173' KB WT.SET PLUG, POOH. RIH W/2"SB W/PRONG TO 10,170' KB WT. SET PRONG, POOH. R/u t/test tubing.Start pressure up had leak on test hose.Change out hose, pressure up t/9615,hold for 30 min,final pressure 9465. R/D&blow down test eq. RIH W/2" JDC TO 10,173' KB WT. LATCH PRONG. 10X1200#OJ LICKS,CAME FREE. POOH. RIH W/3"GS TO 10,170' KB WT. 15X1000- 1400#OIL JAR LICKS. PART WIRE AT STUFFING BOX. RIG UP 1.5"TOOLSTRING. STANDBY FOR TOOLS. M/U 2.5 wire grab TIH to locate wire to 1,000'. No good. POOH. M/U 2.5 wire finder TIH to 2,000'tag. POOH. M/U wire grab and TIH to 6,200'. POOH,no wire. M/U wire grab TIH to 9,395'. No indication of wire. POOH. R/d wire line. Unseat packer. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-26RD 50-733-20295-01 200-105 11/17/14 12/9/14 Daily Operations: 12/02/14-Tuesday PTSM. Pooh 2 stands and found wire clamp wire and pull slack with air hoist. M/u go devil and drop same. Cut wire, pull till wire reaches slick line unit and start spooling up wire.All wire accounted for. TIH with 2 stand and pup joint. Set packer 10,224'dpm with 33k down on packer. Fill annulus and test to 2500 psi for 30 mins,good test,while unspooling wire from w/I unit. Rig up slickline TIH with 2-1/2"JDC pulling tool and latch go devil pooh with same.TIH and latch tool string,jar down and POOH. TIH with prong,fluid level 950'set prong at 10,170'and POOH with same. R/d slickline. M/u pump in sub and start filling tubing. Pressure test tubing 9500 psi for 30 mins. Bleed off and fix leak @ connection on TIW valve. Test t/9500 30 min good. Rig down test pump. R/u slick line with 2.25"tool string with 2"JDC,tag 7,835' POOH. M/u 1- 3/4"tool string and 2"JDC,TIH and latch prong 10,170'. Start working free. POOH with prong. R/d slickline. Wait on boat and offload slickline and pick eline unit. R/u eline and make up 2" PR pulling tool on 5/16"to pull plug.TIH to 9,800' pick up weight is 4500#. Decided to decrease slack off weight on packer. Clamp wire below lub. Hang sheave on winch line. Lower block, pick up to 100k,set weight in slip and remove clamp. 12/03/14-Wednesday Wk e-line. Fire jars. POOH w/plug. R/d e-line. Slack off string set 30k down. M/u companion flange t/tiw valve on string. R/u goat head,coil BOPE, pop off valve on IA set t/2500. Install goose neck on injector,set injector on floor& bind down. Hold safety meeting and service equipment. Rig up high pressure line for coil tubing.Offload boat and rig up 3"suction line to C pump. Rig up pump and flow back iron. Fill up all service line and shell test. Test Coil BOPE asper Hilcorp&AOGCC regulations.Witness waived by AOGCC Inspector,Jim Regg @ 12/1/2014 11: 28 AM.Test 250 psi low and 4500 psi high. Blow down lines. 12/04/14-Thursday P/u injector&stab t/BOPE.Attempt to drift coil t/TIW valve. Unable to pass blind sheers. Pull injector, re adjust BHA. Retry drift, nogo. Retry adjust&drift, no go. Pull injector c/o jet nozzel. Drift good. Install 3"frac stand pipe's&wheel valves. 4� PJSM f/PT lines&data frac. Prepare to start job.TMV was down&Hydration unit also.Troubleshoot&repair TMV, Hyd unit had bad alt. (parts are being shipped down from Anchorage). P/T lines. Repair leak on line t/cleanout tank. Pressure up t/9430 psi good. Set pop off&test. Pressure ann up t/2000 psi. Mix slurry. Pump data frac,step rate up t/20:2 bpm, 6800 psi, pump 393 bbls total. Monitor bleed off. Bleed down ann. Refill upright tanks w/fiw&heat. Rest frac crew while waiting on parts for HYD unit due in later this morning. Rig crew service& maint. on eq & housekeeping. 12/05/14-Friday Cont.fill up right tanks w/FIW, r/u t/pump from slop tank t/production. PJSM tested surface eq & pumped frac, @ 23 bpm, 7k psi on pad 240 bbls, 30k sand away,full flush, leaving 1181b in csg.Total pumped 625 bbls. Monitor well shut in @ 3,200 psi. Bleed down frac lines& blow down, r/d 3"frac lines on rig floor while flushing frac pumps&eq. RIH w/coil connector,4'straight bar& nozzle on 1-1/2"coil tubing @ 50fpm, pumping n2 @ 200 scf per min,t/8,003'getting no V returns, POOH t/4,400'start getting returns, cont. POOH t/4,000', RIH average speed 12 fpm pump n2 @ 250-300 scfpm, !n t/8,230',whp 61psi. v_ 12/06/14-Saturday Cont. rih w/coil pump 250 scfpm, 1,950 psi whp 43,tag @ 10,635', POOH t/10,193' pump remaining n2, POOH w/coil, total returns 156 bbls. R/D coil, pump fluids from slop tank&upright tanks t/trading bay,open cic valve on packer, release packer, up wt 154,dn wt 96, monitor well. POOH w/frac frac string,t/3,385', up wt 58, dn 50. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-26RD 50-733-20295-01 200-105 11/17/14 12/9/14 Daily Operations: 12/07/14-Sunday Cont. POOH t/2,888'. C/O re-pair foster tongs.Cont. POOH l/d 76jts 3-1/2" PH-6 of pipe, l/d BHA. RIH w/3 stands of 4-3/4" drill collars, POOH I/d same. M/U 3-1/2"tj, pull wear bushing,set test plug,fill surface lines&manifolds.Test BOPE as per Hilcorp&AOGCC regulations.Witness waived by AOGCC Inspector,Jim Regg @ 13: 15 on 12-7-14,Test 250 psi low and 2500 psi high.Tested w/3-1/2"jt.,good test.Clean &organize decks,wash out 200 bbl slop tank,general housekeeping (while waiting on weather, boat unable to get to dock to p/u completion.) 12/08/14-Monday Cont. service eq.wash BOPE stack&cellar, clean 200 bbl open top tank, prep backload for boat&clear deck for tubulars. Unload boat w/3-1/2"completion string&handling eq. PJSM&r/u handling eq.,talley tubulars. P/U completion jewlrey as per schematic, rih p/u 3-1/2"9.3#L-80 Supermax tubing spacing GLM as per design, p/u 236 jts, 5 GLM,t/7,920', up wt 84, dn wt 64. 12/09/14-Tuesday Cont. RIH pju 3-1/2"9.3#_L-80 Supermax tubing,_303 jts,6 GLM up wt 110,dn wt 66jDf u rn/u hanger&land,tubing tail @ 10,242'. Run in L/D pins,test t/5,000psi/15 min good. R/U t/circulate,drop bar, pressure up tubing t/4,000psi t/set packer @ 10,193', hold 8 min, bleed down, r/u pump down back side fill pressure up t/100 psi,swap back to tubing pressure up t/4,500 hold 15 min, bleed down, pump on back side t/200 bleed air off cont.work air out, pressure test anuulus t/2,500psi f/30 min good. R/D circ lines, r/u w/l, RIH w/JDC t/10,228'wlm, pull prong, POOH, rih w/GS t/ 10,233' wlm, POOH w/RHCP plug, R/D w/l. Pull landing jt,set BPV. Pull floor panels,&floor beams, install handrails, r/d drain hoses, pull drip pan &flow nipple, r/u strong back t/BOP stack, break flange t/riser p/u &hang stack under floor, pull riser & I/d;N/u tree, install valves,tq.flanges. Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date 12/4/201• Job End Date 12/5/201• State County State Waters-Kenai Quadra Frac Focus Number 50-733-20295-0' Operator Name Hilcorp Alaska, `` Chemical Disclosure Registry Well Name and Number Trading Bay Unit#G-2 . Longitude -151.6095: Latitude 60.8245' GROUNDWATER „14r,,.. Datum N•I �� Oil&Gas Federal/Tribal Well NONIMMINIMMEII True Vertical Depth 8, Total Base Water Volume(gal) 42, Total Base Non Water Volume .--_ Hydraulic Fracturing Fluid Composition: Chemical MEmum Maximum Abstract Service Ingredient Ingredient Trade Name Supplier Purpose Ingredients Number ,oncentration in Concentration in Comments (CAS#) Additive HF Fluid (%by mass)** (%by mass)** Filtered Sea Water Baker Hughes Carrier/Base Fluid Water 7732-18-5 100.00000 90.79113None Carbobond Lite 20/40 Baker Hughes )'roppant 'Proppant) Mullite 1302-93-8 85.00000 6.02105None Silcon Dioxide,amorphous as 7631-86-9 35.00000 2.47925None glass Silica Cristobalite 14464-46-1 20.00000 1.41672None Phenolic Resin 9003-35-4 5.00000 0.35418None High Perm CRB Baker Hughes Breaker Ammonium Persulphate 7727-54-0 100.00000 1.03741 None GLFC-5 Baker Hughes Gelling Agent Paraffinic Petroleum Distillate 64742-55-8 60.00000 0.25669None Petroleum distillates 64742-47-8 60.00000 0.25669None Guar Gum 9000-30-0 40.00000 0.17113None Quaternary Ammonium 68953-58-2 10.00000 0.04278None Compound Crystalline silica:Quartz(5102) 14808-60-7 10.00000 0.04278None Poly(oxy-1,2-ethanediyl) 24938-91-8 10.00000 0.04278None Sodium Bicarbonate 144-55-8 7.50000 0.03209None XLW-24 Baker Hughes Crosslinker • lyoxal 107-22-2 30.00000 0.06570None sodium Tetraborate 1303-96-4 30.00000 0.06570None sodium Glycolate 2836-32-0 10.00000 0.02190None BF-8L Bsker Hughes Buffer onoethanolamine 141-43-5 100.00000 0.14567None Flo-Back 30 Baker Hughes Surfactant ater 7732-18-5 75.00000 0.07600None -odium Chloride `7647-14-5 30.00000 0.03040None ocamidopropyl betaine 61789-40-0 30.00000 0.03040None lycerol 56-81-5 1.00000 0.00101 None Enxzyme G-I Baker Hughes Breaker ater 7732-18-5 97.00000 0.06149None emicellulase Enzyme 3025-56-3 3.00000 0.00190None oncentrate X-cide 207 Baker Hughes Biocide •iatomaceous Earth,Calcined b1053-39-3 60.00000 0.016l5None .-Chloro-2-Methyl-4-Isothiazolin-Q6172-55-4 10.00000 0.00269None c-One agnesium Nitrate 10377-60-3 10.00000 0.0026BNone agnesium Chloride 7786-30-3 5.00000 0.00135None '-Methyl-4-Isothiazolin-3-One 2682-20-4 5.00000 0.00135None rystalline Silica:Quartz(Si02) 14808-60-7 1.00000 0.00027None rystalline Silica:Cristobalite 14464-46-1 1.00000 0.00027None Ingredients shoe subject to 29 CFR 1910.1200(i)and appear on Material Safety Data Sheets(MSDS).Ingredients shollneMre Non-MSDS. *Total Water Volume sources may include fresh water,produced water,and/or recycled water **Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i)and Appendix D are obtained from suppliers Material Safety Data Sheets(MSDS) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~ - _/~_,~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) .,,~"flt~s: ~ Diskettes, No.// [] Maps: Grayscale items: D Other. No/Type [] Other items scannable by large scanner Poor Quality Originals: OVERSIZED (Non-Scannable) Other: [] Logs of various kinds TOTAL PAGES: ¢¢ NOTES: ORGANIZED BYi BEVERLY BRE~SHERYL MARIA LOWELL [] Oth er By: Date: ,ow,,. Scanned (done) PAGES: ~ (at the time of scanning) SCANNED BY: BEVERLY~ VINCENT SHERYL MARIA LOWELL RESCANNED BY~ BEVERLY ~ VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: PAGES:W ~ Quality Checked (done) Rev1 NOTScanned.~lXl ~El;E'VED _ STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COM~SION MAR 3 1 2006 REPORT OF SUNDRY WELL OPERATIONjaska 0'/ & G I as Cons. Commission 1. Operations Abandon Repair Well Plug Perforations Stimulate Other orag8CTco Performed: Alter Casing D Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 200-105 3. Address: PO Box 196247, Anchorage, AK 99519 StratigraphicD ServiceD 6. API Number: 50-733-20295-01 9. Well Name and Number: 7. KB Elevation (ft): RKB to TBG head 40.15' 8. Property Designation: Grayling Platform/Cook Inlet 11. Present Well Condition Summary: G-26RD 10. Field/Pool(s): McArthur River Field, Hemlock Total Depth measured 11,587' feet true vertical 9,734' feet Effective Depth measured 10,738' feet true vertical 9,178' feet Casing Length Size MD Structural Conductor 5,617' 13-3/8" 5,617' Surface 10,263' 9-5/8" 10,263' Intermediate Production 1 ,466' 7" 11,587' Liner Plugs (measured) Junk (measured) 10,738' TVD Burst Collapse 4,940' 3,090 psi 1,540 psi 8,797' 6,870 psi 4,760 psi 9,734' 8,160 psi 7,020 psi Perforation depth: Measured depth: 10,728 to 11,448' True Vertical depth: 9,171 to 9,653' Tubing: (size, grade, and measured depth) 4-1/2",12.6# @ 0-10,068' and 10,082 to 10,172' Packers and SSSV (type and measured depth) Baker Mod D 194-47 Packer @ 10,070' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 900 1,300 o 309 1 ,100 15. Well Class after proposed work: ExploratoryD Development 0 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl 85 16 Tubing Pressure 175 120 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 306-070 Contact Steve Tyler 263-7649 Signature Title Drilling Manager Printed Name Timothy C. Brandenburg Date 3-221-~ Submit Original Only RKB to TBG Head::: 40.15 Tree connection: 4-1/16" 5000# Butt. Butt. 2,610' 5,617' 9-5/8" Butt Surf 7,979' Butt 7,979' 9,523' 2 Butt 9,523' 10,263' 7" Butt 10,121' 11,587' Tubing: 4-I/2" 12.6 L-80 Imp Butt 3.958 Surf 10,068' 4-112" 12.6 L-80 Hydril 511 3.958 10,082' 10,172' 3 4 1 2-10 5 11 12 13 ]4 15 ]6 6 7 8 9 10 40.15' 288' 4-1/2" DCB Hanger 4-112" Butt Btm x 4-112" EUE top 4-112" Baker TE-5 WRSSSV 4-1/2"' Cameo MMG GLM's at 2389', 4237',5334',6427', 7388',8105',8744,9339',9928' Baker Locator/Seal Assembly. Baker Mod. 'D' 194-47 Packer (Set on DP) 10'Sealbore Extension 2 jt 4-112" 12.6 Ib/ft L-80 Hydri] 511 "X" Nipple 1 jt 4-1/2" 12.61b/ft L-80 Hydril 511 with wireIine re-entry guide 3.810 3.833 10,069' 10,070' 10,082' 10,082' 10,141' 10,172' 4.75" 4.75" 3.958" 3.813" 3.958" 8/13/00 Perfrecordlog indicates tubing taU at 10,142' (tied into CDR- ADN) B-1 10728 10743 15' 2-7/8" 60 deg 6SPF (S/3/00) B-2 10782 10787 5' 2-7/S" 60 deg 6SPF (1/16/01) 10792 10802 10' 2-7/S" 60 deg 6SPF (1/16/01) B-3 10932 10942 10' 2-7/8" Power Jet (11/18/00) B-4 11027 11103 76' 2-718" 60 deg 6SPF (8/3/00) B-5 11200 11210 10' 2-7/8" 60 deg 6SPF (S/3/00) 1122S 11235 7' 2-7/8" Power Jet (1112100) 11315 11325 10' 2-7/8" Power Jet (1112/00) B-6 11442 11448 6' 2-7/8" 60 deg 6SPF (8/3/00) PSTD ::: 11535' TD ::: 11,587' MAX HOLE ANGLE::: 54.60 REVISED: 3/17/05 Tagged up wi 3.72" OR on 3.75" OD Kick Over Tool Bajl~ttsa1l1P!~f8!~ salltt,)?% acid soluble) By: JHM Primary Job Type Clean Out Jobs AFE No. QC Eng Daily Operations 2/25/200600:00 - 2/26/2006 00:00 Operations Summary SpotlRU Coil Tubing Equipment NU BOPE. Thread CT through Injector. 2/26/200600:00 - 2/27/2006 00:00 Operations Summary Remove Ice-plug in CT w/ indirect heater. Pumped Hippo-Tripper through CT. Test BOPE. Drain lines. Blow CT down w/ N2. SDFN. 2/27/200600:00 - 2/28/2006 00:00 Operations Summary Fired up surface equipment. MU CTC. Pull and pressure test same. PUMU fishing BHA. SDFN to wait on Production to trouble shoot scrubber. 2/28/200600:00 - 3/1/2006 00:00 Operations Summary RIH w/ Fishing BHA on 1-3/4" coil tubing. Cleanout to KOT fish @ 10,745' CTM. Work CT. POOH. No recovery. 3/1/200600:00 - 3/2/2006 00:00 Operations Summary MIRU Slickline. RIH w/3.5" LIB. Set down @ 10,680'. Sticky. Jar to 10,640'. Pull free. POOH. No marks on LIB. RD slickline. RD CTU. SDFN 3/2/200600:00 - 3/3/2006 00:00 Operations Summary RD/MO. ) ) ,,0'~li-6 ,i ~ ¡Ii, ¡ ! ij i rUr \~~ !I (&ið\ :n· jf-;.'l /~'~ ¡~' :'~~' ji'71 " f I', Ii . i ;íì\ '\¡;~' .{ \ ',.J.,' :,' I".' ,i ,! (;~ '~ / : \ \ !I : 1'\ '1'\"-, U' i II !Pt' i ',It) ; '\ ii, 1...!Q '.\ I ¡ \ U ,\, Ii \ \ !L6l.rlJ \Ð : i\, / ¡ \1 / !/ I ¡ l / FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 ;)pO-/05 Re: McArthur River Field, G-26RD Sundry Number: 306-070 ,~ ~., \-~. c" c 'lnn5 ~' ,({, lfu~ \~~ \~ ~ tF II " .. I!, ~" (0) l:, {J (- - ',,, ~'~¡r \)n '1:) ß '~~.., ." ¡ ,'"' , Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a ,Commission decision to Superior Court unless rehearing has been requested. J Chai DATED thisi!/day of February, 2006 Encl. 11 '.' """...."".... V L.LJ CflJ.-2J14 6' , \ STATE OF ALASKA tJ.?s 2. .¡¡~ r-'I~B 2 3 2Uth ALA~ A OIL AND GAS CONSERVATION COMMk,Jf6~, ~/~~ APPLICATION FOR SUNDRY APPROVALS{1~~? Jirt;.: Gas Cons. Commission 20 AAC 25.280 fìnchoraoe Operational shutdown U Perforate U Waiver U Plug Perforations 0 Stimulate 0 Time Extension 0 Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: Development 0 Exploratory 0 200-105 vi" Stratigraphic 0 Service 0 6. API Number: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB to TBG Head 40.15' 8. Property Designation: Grayling Platform/Cook Inlet 11. Total Depth MD (ft): 11,587' 1. Type of Request: Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10,728 to 11,448' Packers and SSSV Type: Suspend U Repair well 0 Pull Tubing D Other L:J CTCO 50-733-20295-01 9. Well Name and Number: G-26RD 10. Field/Pools(s): McArthur River Field, Hemlock PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 9,734' Effective Depth MD (ft): 10,621 ' Effective Depth TVD (ft): 9,089' Plugs (measured): Junk (measured): 10,621 '; 10,738' Collapse Length Size MD TVD Burst 4,940' 3,090 psi 8,797' 6,870 psi 9,734' 8,160 psi 7,020 psi 5,617' 10,263' 13-3/8" 5,617' 9-5/8" 10,263' 7" 11 ,587' 1,540 psi 4,760 psi 1 ,466' Perforation Depth TVD (ft): 9,171 to 9,653' Tubing Size: 4-1/2" Tubing Grade: 12.6# Packers and SSSV MD (ft): Tubing MD (ft): 0-10,068'; 10,082 -10,172' 10,070' Baker Mod D 194-47 Packer 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg Title Drilling Manager ? ~ c- 0 Q. Phone 907-276-7600 -3/ / _"J Y COMMISSION USE ONLY 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: Signature 13. Well Class after proposed work: Exploratory 0 Development 0 Service D Date: 15. Well Status after proposed work: Jj24/2006 Oil 0 Gas D WAG 0 GINJ D WDSPL D o Abandoned o o Plugged WINJ Contact Steve Tyler 263-7649 Date 2 ""> '- "2.5 -c:.:;¿ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ?;oú ·07 Ò Plug Integrity 0 BOP Test ~ Mechanical Integrity Test D Location Clearance D ~OOu ~<;\',,",\~\~ÙM.. ~~~~\o ~(¿.\\ t.C~~~c\ «,,\~\~~c.,,-\ ~"r dO ~~c..dS(~ RBDMS BFl FEB 2 7 2006 SUbSeqUentForrnRe~ Approved by: _ / Form 10-403 Revised 07/2005 Other: APPROVED BY THE COMMISSION Date: :l-J¡f,oÞ COMMISSIONER R I ~I N A ~FE 164632 Submit in Duplicate ) ') G-26 RD Grayling Platform Coil Tubing Fishing and Cleanout AFE # 164632 Objective: Utilize Coil Tubing to make an attempt to fish LlH slickline toolstring. Then make one attempt to clean out suspected scale bridges in wellbore from 10,350' to 11,448'. WORK DESCRIPTION: · Turnkey MI & RU 1-3/4" CTU, BOPE and test same. · Coil tbg unit Acceptance. Hold pre-spud meeting. · RIH with Fishing BHA. Latch and retrieve KOT fish. POOH. · RIH wI CO Assy. Clean out suspected scale bridges in wellbore to 11,448' MD. CBU. POOH. · Turnkeyed Demobe. RD CTU. RKB to TBG Head::: 40.15 Tree connection: 4-1/16" 5,000# 13-3/8" 61.0 K-55 Butt, 12,515 Surf 2,610' 68 K-55 Butt. 12.515 2,610' 5,617' L ~ 9-5/8" 47 N-80 Butt 8.681 Surf 7,979' 47 P-IIO Butt 8,681 7,979' 9,523' - 2 47 USS-95 Butt 8.681 9,523' 10,263' T' 29 L-80 Butt 6,184 10,121' 11,587' Tubing: 4-1/2" 12,6 L-80 bnp Butt 3.958 Surf 10,068' 4-1/2" 12,6 L-80 Hydril 511 3,958 10,082' 10,172' - 3 L ~ I 2-10 40,15' 288' DCB Hanger 4-1/1" Butt Btm x 4-1/2" EUE top 4-1/1" Baker TE-5 WRSSSV 4-1/2" Camco MMG GLM's at 2389', 4237',5334',6427', 7388',8105',8744,9339',9928' Baker Locator/Seal Assembly. Baker Mod, 'D' 194-47 Packer (Set on DP) IO'Sealbore Extension 2 jt 4- I IT 12,6 Ib/ft L-80 Hydril 511 "X" Nipple I jt 4-111" 12,6Ib/ft L-80 Hydril 511 with wire!ine re-entry guide - 4 - 5 - 6 - 7 - 8 -" 9 10 3,810 3.833 !! 12 !3 14 15 16 10,069' 10,070' 10,082' 10,082' 10,141 ' 10,172' 4.75" 4.75" 3,958" 3,813" 3,958" 8/13/00 Perf record log indicates tubing tail at 10,142' (tied into CDR- ADN) 11 12 i~ H-l 10728 10743 15' 2-7/8" 60 deg 6SPF (8/3/00) 13/14 H-2 10782 10787 5' 2-7/8" 60 deg 6SPF (1/16/01) 15 x 10792 10802 10' 2-7/8" 60 deg 6SPF (1/16/01) L ~ H-3 10932 10942 10' 2-7/8" Power Jet (11/18/00) 16 H-4 11027 11103 76' 2-7/8" 60 deg 6SPF (8/3/00) H-5 11200 11210 10' 2-718" 60 deg 6SPF (8/3/00) H-1 11228 11235 7' 2-7/8" Power Jet (1112/00) H-2 11315 11325 10' 2-718" Power Jet (1112100) - H-3 H-6 11442 11448 6' 2-7/8" 60 deg 6SPF (8/3/00) = = = H-4 = - H-5 = H-6 10,738' 13/9105 ¡ Tagged up wi 3.72" GR. = 10785' 1/29/04 .l3ailedsarnple (8J~~ªnd, 15% acid soluble / " PBTD ::: 11535' TD::: 11,587' MAX HOLE ANGLE::: 54.60 REVISED: 3/17/05 By: JHM ) [In,.) 16 .~\'\ n h/~\ (~ il~Y7 , / tJ \ : :'\ ! ! ; \I f' --'. ~ ij i I ~ \ ':1U\~' í r. ~ !' \ " i,.j)1 ' :1 l in' \ ~ l_ ! ,nj\ n: I; '" I, '¡' I:,~ W !1-.J I, ß--Jw \~:,' " W,I,II ~ ') ALASIiA OIL A5D GAS CONSERVATION COMMISSION ;1 / I / j' FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 November 17, 2005 Mr. Chris Myers Field Superintendent U nocal PO Box 196247 Anchorage, Alaska 99519 ........ ...'.......'........~ I, : ':'"" ............. ~ ."', ,', RE: No-Flow Verification Trading Bay Unit G-26RD, PTD 200-105 Dear Mr. Myers: ~CANNED NOV·l 7 2005 On November 4, 2005 AOGCC Petroleum Inspector John Crisp witnessed a "no flow test" at Unocal's Grayling platform, Trading Bay Unit Well G-26RD. The well was opened to atmosphere through flow measurement equipment witþ· suitable range and accuracy and monitored for several hours. The well demonstrated""n'o 11ö'w at surface. The subsurface safety valve may be removed from service in Well G-26RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Grayling platform. Sincerely, --1i;¡,~\E .~6(?)'l James B. Regg Petroleum Inspection Supervisor cc: Bob Fleckenstein e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . 'r¡(é'4t1J 1/( lfo(()c; DATE: November 04,2005 P. I. Supervisor l l FROM: John Crisp, Petroleum Inspector SUBJECT: No Flow Test TBU Grayling G-26RD PTD 2001050 November 04,2005: I traveled to Unocal's Grayling Platform to witness a no-flow test on G-26RD I arrived on the platform & began the no-flow test by verifying the SSSV was open. The master tree valve & swab valve were checked & in the open position. The Inner Annulus valve was closed & IA was @ 0 psi. The Outer Annulus valve was open & OA was stable with 200 psi. Armor-Flo gas meter was installed on the tubing. Armor-Flo meter model number is 3461-03TO, SIN 031189. Meter range is 0-18 SCFHx100. The meter had a 1" open-end hose attached down stream of meter to open top container. During the six-hour period I monitored G-26 there was a very small amount of gas released thru meter & 1" hose. The small amount of gas would not register on the gas meter. The small amount of gas flow was effectively shut off when hose was placed 2 inches deep into a 5 Gal. Pail of fresh water. Summary: I witnessed a no-flow test on TBU Grayling G-26RD. The Operator was made aware my Supervisor would make a No-Flow Determination. Attachments: None Non-Confidential 2005-1104_llo-flow_ TBU _ G-26-.Jc.doc ) ') MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _I nserts\M icroft I m _ Marker.doc '1I¡!fJ1'" ...~,. ... Permit to Drill 2001050 MD 11587 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. TRADING BAY UNIT G-26RD Operator UNION OIL CO OF CALIFORNIA 9734 Completion Dat 8/13/2000.,~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-733-20295-01-00 UIC N REQUIRED INFORMATION Mud Log N._Qo Sample No Directional Survey ~ ~/~,~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Type Digital ~.pDigital Med.[e~ Fmt L L L L R R L L L L C L L L L Log Log Run Name Scale Media No (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop OH / Dataset CH Received Number Comments 8/30/2000 09706'~-0137-11565 10137 11565 Open ~~DN-MD 2/5 FIELD SRVY RPT ~~Record ,!.."' . ~ ~etion Record 5 ' ~etion Record 5 FINAL '-I~ERF/SPF/~Jo~ ~ !J0 t5 FINAL 1O137 11565 9800 11500 102O0 11587 11095 11326 11478 11500 10700 11270 98OO 10970 OH 8/30/2000 10137-11565 8/4/00 THRU CH 8/30/2000 9800-11500 OH 8/30/2000 SCHLUM 10200-11587 CH 1/5/2001 11095-11326 BL, Sepia CH 1/5/2001 11478-11500 BL, Sepia OH 8/30/2000 970E~'~CHLUM CDR/ADN CH 5/1/2001 10700-11270 BL, Sepia CH 5/1/2001 9800-10970 BL, Sepia Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? --Y Analysis Daily History Received? ~¢ N Formation Tops ~)/N Comments: Permit to Drill 2001050 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. TRADING BAY UNIT G-26RD Operator UNION OIL CO OF CALIFORNIA APl No. 50-733-20295-01-00 MD 11587 TVD 9734 Compliance Reviewed By: jetion Dat 8/13/2000 Completion Statu 1-OIL Current Status 1-OIL UIC N Date: Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALel Dan Williamson Drilling Manager 5/8/2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Tom Maunder Report on Annulus Disposal Trading Bay Unit, Grayling Platform, Well Grayling G-22 Mr. Maunder: Enclosed is the final report on annulus disposal of A-15RD oil base mud (OBM)liquid waste into the G-22 annulus as required by the Sundry Application Approval #301-304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G-22 annulus while drilling at A-15RD. The following is the total volumes disposed in G-22 annulus by drilling well source. Well OBM, bbls Seawater Flush, bbls Total Bbls G-15RD 1269 2160 3429 G-28RD 203 700 903 G-26RD 823 2155 2978 A-15RD 1374 5067 6441 Total 13751 If there are any questions, please contact myself at 263-7677 or Tim Billingsley at 263-7659. Drilling Manager AOGCC G-22 Monopod waste annular disposal final report Tim Billingsley Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G-22 Drilling Wastes From Monopod A-15'RD Maximum Allowable Injection Pressure 2000 psi TVD 13 3/8" Casing Shoe Depth 4977' ~' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry'si Flushes 12/9/2001 Inj-test 1 3 1600 FIW 0 338 0 338 12/9/2001 1 2 3 1600 9.9 450 338 450 676 12/10/20012 3 3 1750 10 198 338 648 1014 12/10/20013 X 3.5 1650 10 150 0 798 1014 12/11/2001Flush 4 3.5 1750 FIW 0 450 798 1464 2/14/2002 Flush 5 3.5 1650 FIW 0 338 798 1802 211412002 4 6 4 1750 9 80 338 878 2140 2/27/2002 Flush 7 2.5 1100 FIW 0 40 878 2180 2/28/2002 Flush 8 3 1100 FIW 0 20 878 2200 3/2/2002 Flush 9 3 1200 FIW · 0 20 878 2220 3/2/2002 5 X 3 1750 10.0 130 338 1008 2558 3/3/2002 6 X 3 1750 10 100 338 1108 2896 3/5/2002 7 10 1.75 1750 10 50 360 1158 3256 3/19/2002 8 11 4 1750 9 76 360 1234 3616 3/24/2002 9 12 1750 70 351 1304 3967 4/3/2002 flush 13 FIW 0 20 1304 3987 4/3/2002 10 14 4 1900 9.1 20 360 1324 4347 4/3/2002 11 15 4 1750 9.1 20 360 1344 4707 4/3/2002 12 16 3.5 1800 9.1 30 360 1374 5067 Total bbls injected 6441 *Injection pressure is highest reading while injecting Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd @ unocal, com UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL To: Howard Oakland 3OO1 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchor.age, AK Unocal i i 99519-6247 Transmitting the following items: December 7, 2000 :.'~:?:::ii:iWell: i:.,~,.~ .:~ ,.-.: ;:::.,i:: :-i~,~:: :LOG TYPE'::~'}: ::~.:;?.;-i: i;:~-~-~;~:!~%::~:.: SCALE LO(~ DATE INTERVAL 'cOPIES Medium IRU 13-31 1 11/16" ENERJET PJ / GR-CCL, PERFORATION RECORD 5 INCH 11/8/00 7322-7335 1 B-Line .................. IRU 13-31 11 11/16" ENERJET PJ/GR-CCL, PERFORATION RECORD 5 INCH 11/8/00 7322-7335 1 Film IRU 13-31 !2 7)8;' OWEN PATCH PERFORATING RECORD ' ~'iNCH 11/3/00 2950-2996 1 B~Line IRU 13-31 12 7/8" OWEN PATCH PERFORATING RECORD 5 INCH 11/3/00 2950-2996 " 1 Film .............. , ..... ilRU 13-31 BRIDGE PLUG 5 INCH 10/12/00 6500-7420 1 B-Line iRU 13-31 BRIDGE PLUG 5 INCH i0/12/00 6500-7420 1 Film SLU 41-33 COMPLETION'RECORD 2.5" HSD p~WERJETS ..... 5 INCH 10/8/~0 6000-7150 '1 B-Line SLU 41-33 COMPLETION RECORD 2.5" HSD POWERJETS 5 INCH 10i8/00 6000-7150 1 Film TBU D-12RD PERFORATING RECORD 2 7/8" PJ 5 INCH 11/'27/0010970-11950 1 B-Line .... TBU D-12RD PERFORATING RECORD 2 7/8" PJ 15 INCH 11/27/00 10970-11950 1 Film '~B'U'D-8RD ' ' COMPLETION RECORD 2.5" HSD POWER JET 5 INCH 8/24/00111100-12017 1 B-Line , TBU D-8RD COMPLETION RECORD 2.5" HSD POWER JET 15 INCH 8/24/00; 11100-12017 1 Film 'TBLJ G-18DPN TcP CORRELATION LOG / GAMMA RA'~', CCL i5 INCH 9/1/0014300-6120 1 B-Line ....... TBU G-18DPN TCP CORRELATION LOG / GAMMA RAY, CCL 5 INCH 8/29/00 5000-6120 1 B-Line TBU G-18DPN T'cP C'O'RRELATIO'~' LOG / GAMMA RAY, CCL ...... 5 INCH 8~29~00 5000-6120 1 Film TBU G-I~DPN TCp CORRELATION LOG / GAMMA RAY, ccL 5 INCH '"9/1/00 4300-6120 1 Film TBU G-18DF;N ULTRA SONIC IMAGING TooL / 'GAMMA RAY "' 5 INCH 8/28/00 47-6760 '" 1 B-Line' ' ........ TBu G-18DPN ULTRA SONIC IMAGING TOOL / GAMMA RAY 5 INCH 8/28/00 47-6760 1 Film TBU G-2® COMPLETION RECORD 2 7/8, pj 5 INCH 'i'0/26/00 9900-1'1'478 1 B-Line'" :rBu G-26RD ' coMP'~ETION RECORD 2 7/8" PJ .... 5 INcH'' 10/26/00 9900-11478 i'Film TBU G-26RD PERFORATING RECORD 2 7/8;' PJ 5 INCH 11/1/00 'i 1095-11326 1 B-Line ~BU G-26RD PERFORATING RECORD 2 7iS"'PJ ' 5 INCH 11/1/00 11095-11326 1 Film TBU G-28RD ULTRA SONIC IMAGER coRROsION % CEMENT " 5 INCH 6/1/00 50.9830 i B-Line TBU G-28RD , ULTRA SONIC IMAGER CORROSION % CEMENT 5 INCH 6/1/00 50-9830 .. 1 Film .... TBU M-19RD PRODUCTION PROFILE / PS PLATFORM 5 INCH 11/10/00 3800-4600 1 B-Line TBU M-19RD 'PRODUCTION PROFILE/PS PLATFORM 5 INCH 11/10/00 3800-4600 1iFilm TBU 'M-19RD' '.'PST GRAVEL PACK LOG, SIGMA .L. OG ....... 5 INCH 11/10/00 3800-4600 1 B-Line .". TBU M-19RD PsT GRAVEL PACK LOG, SIGMA LOG 5 INCH 11/10/00 3800-4600 1 Film ........... Please acknowledge receipt by signj_ng and returning one copy of this transmittal or FAX to (907) 263-7828. TBU M-2 CEMENT 'EVALU/~'TION CBL-VDL-GR 5 INCH 10/12/0060-4509 1 B-Line TBU M-2 CEMENT EVALUATION CBL-VDL-GR 5 INCH 10/12/0060-4509 1 Film TBU M'2 GR-CCL CORRELATION 5 INCH 10/17/003550-4113 1 B-Line TBU M-2 GR-CCL CORRELATION ,5 INCH 10/17/0013550-4113 1 Film TBU M-2L 3.5" BP / DUMP BAILER [5 INCH 10/8/00!4500-4900 1 B-Line TBU M-2L 3.5" BP / DUMP BAILER 5 INCH 10/8/00 4500-4900 1Film TBU M-2S 2 1/8" DUMP BAILER 5 INCH 10/7/00 4600-4979 1B-Line TBU M-2S 2 1/8" DUMP BAILER 5 INCH 10/7/00 4600-4979 1Film T'BU M-2S 3 1/2" BRIDGE PLUG / GR-CCL CORRELATION 5 INCH 10/7/00 4630-4980 1B-Line TBU M-2S 3 1/2" BRIDGE PLUG / GR-CCL CORRELATION 5 INCH 10/7/00 4630-4980 1Film TBU M-2S GR-CCL CORRELATION 5 INCH 10/31/00 3370-3735 1B-Line TBU M-2S GR-CCL CORRELATION 5 INCH 10/31/00 3370-3735 1Film TBU M-2S SCMT-PSP / CBL-VDL LOG 5 INCH 10/7/00 4500-4980 1! B-Line ,, TBU M-2S i SCMT-PSP / CBL-VDL LOG 5 INCH 10/7/00 4500-4980 1Film ,. TBU M-5 !PERFORATING RECORD 5 INCH 11/23/00 3500-4100 1B-Line ,,, IT.B,,U M-5, PERFORATING RECORD 5 INCH 11/23/00 3500-4100 1Film Please acknowledge~signing and returning one cop), ,of this transmittal or FAX to t907) 263-7828. Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd @ unocal, corn UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL August 28, 2000 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: Well:..:~ ~: '.LOG~PE : / SCALE LOG DATE INTERVAL LOGGED COPIES Medium ;iTBU D-08RD Correlation Log Gamma Ray-CCL 5 inch 6/11/00 10400-11930 1 B-Line TBU D-08RD Correlation Log Gamma Ray-CCL 5 inch 6/11/00 10400-11930 1 Film TBU D-08RD Perforating Record 2.5" Powerjet 5 inch 6/4/00 10900-11998 1 B-Line TBU D-08RD Perforating Record 2.5" Powerjet 5 inch 6/4/00 10900-11998 1 Film ~ TBU D-09RD Perforating Record 2" Powerjet t.,u\ (,-. 5 inch 5/31/00 9600-10180 1 B-Line TBU D-09RD Perforating Record 2" Powerjet q../" 5 inch 5/31/00 9600-10180 1 Film TBU D-46RD Mechanical Plug Back Tool 5 inch 5/25/00 10900-11405 1 B-Line TBU D-46RD Mechanical Plug Back Tool 5 inch 5/25/00 10900-11405 1 Film TBU D-46RD Perforating Record 2.5HSD Gun w/Powerjet 5 inch 6/7/00 10800-11330 1 B-Line TBU D-46RD Perforating Record 2.5HSD Gun w/Powerjet 5 inch 6/7/00 10800-11330 1 Film .~TBU G-26RD CD 8/6/00 1 CD TBU G-26RD CDR-ADN 2/5 inch 8/4/00 10137-11565 1 B-Line TBU G-26RD CDR-ADN 2/5 inch 8/4/00 10137-11565 1 Film TBU G-26RD Perforating Record 5 inch 8/13/00 9600-11500 1 B-Line TBU G-26RD Perforating Record 5 inch 8/13/00 9600-11500 1 Film TBU G-28 Ultra Sonic Imager Corrosion & Cement {,,b r.. 6/1/00 50-9830 1 B-Line TBU G-28 Ultra Sonic Imager Corrosion & Cement q,,- 6/1/00 50-9830 1 Film ['TBU G-28RD Measured Depth Log / GR 2/5 inch 6/5/00 9747-15357 1 ~B-Line TBU G-28RD Measured Depth Log / GR 2/5 inch 6/5/00 9747-15357 1 Film TBU G-28RD Measured Depth Log / VISION 475 2/5 inch 7/13/00 11800-15065 1 B-Line TBU G-28RD Measured Depth Log / VISION 475 2/5 inch 7/13/00 11800-15065 1 Film TBU K-03RD Completion Record 2 1/2 HSD PJ-5SPF !5 inch 7/11/00 12250-12700 1 B-Line TBU K-03RD Completion Record 2 1/2 HSD PJ-5SPF 5 inch 7/11/00,12250-12700 1 Film RECEIVE7D Please acknowled~ receipt by si, gning and returning one copy of this fr~nsmiff~l or F~ ~o (~7) 263- 828. I Received by: ~ ~~~~ r Date:AUG ~0 2.000 ~aska Oil & Gas 6o;~s. bu,,.;,mslon U Ancho[age Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCAL August 30, 2000 Mr. Dan Seamount AOGCC 3001 Porcupine Drive Anchorage, AK. 99501 Dear Mr. Seamount, Re: Summary of OBM Liquid Waste Injected into Grayling Unocal has completed the injection of Oil Base Mud (OBM) liquid waste in Grayling G-22. As required by the Permit to Inject, we have provided a daily summary of the fluids disposed of in the G-22 casing annulus during the drilling of G-26RD and G- 2$RDo The total waste injected during the drilling of the two wells was as follows: Well Name OBM Waste Seawater Grayling G-28RD 203 Bbls 700 Bbls Grayling G-26RD 823 Bbls 2155 Bbls Total 1026 Bbls Total 2855 Bbls Should you have any questions or concerns please contact myself or the Drilling Engineer assigned to the project; Neil Magee at 263-7671. Yours faith~lly, D.R. Williamson Drilling Manager Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings Summary for Drilling of G-26RD Day Date Hoie Size DePth Ft~0tageCalc'filated Cum calc Actual Cumulative "Whste'Tank G-22 ' G-22' Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) fit) (ft) (BBLS) (BBLS) (DRUMS) (DRUMS) (BBLS) (BBLS) (BBLS) 1 ' 7/22)00 Abandon ' , _ ....... _ 13.0 ..... 1~.0 ............ 72'.'0 ' .... 2 ....... 7?23/00 Abandon ......... - - 25.0 38.0 72.0 ........ 3" '7724/00' Abandon - _ ' ...................... _ "_ 38.0 '" 72.'0 ..... "4 ............ 7725~)0'0" AbandOn " - - ....... - - 3'8.0. 72.0 5 7/'26/00 Abandon ......... _ _ _ _ 38.0 '72.0 " 6" ~/27~00 Abandon ' "- - - 1~.0 50.0 .......... 106.0 7 7/28)00' Abandon - '7.0 ....5'7.0' 1'3'3.0 '1'06'.'00 350.00 7a 7/2'8/00'a 8.50 10,263 - ' .......... _ 57'.0 ..... 27.0 .............. 8 7/29/00 8.50 10,294 31 1.05' 1.05 - 5'7.0 41.0 9 7/30/00' 8.50 10,362 68 2.31 3.37 - 5'7.6' 56.0 .... 10 7/31/00 8.50' 10,760 '398 13.53' 16.90 37.0 94.'0 .... 5'6"...0 .......... 11 8/1/00 8.5© i0,87~ 1i8 4.01 .....20.91 '20.0 "i 1~.0 56.0 12 8/2/00 8.50 11,137 259 "'8.81 29.72 20.0 "134.0 62.0 ............ 13 8/3/00 8.50 11,366 229 7.79 37.50" 35.0 169.0 62.0 14 8/4/00 8.50' 11,425 59 2.01 ......... 39.51 12.0 181.0 '62.0 ............... 15 8/5/00 8.50 11,587 162 5.51 45.02 35.0 "216.0 '6210 Well TD ..... 16 .... 8/6/00 "Liner 11,587 - _ ~5.02 10.0 226.0" 62'.0 ....................... 17 8/7/00 Liner 11,587 - - 45.02 21.0 247.0 170.0 170.00 375.00 18. .. 8/8/00 Comp.' 11,587 - _ ~5.02 '10.0 .... 25T0 - 19 8/9/00 Comp. 11,587 - - 45.02 38.0 295.0 20 8/10/00 Comp. 11,58'/ 42.0 337.0 42.0 135.00 360.00 21 8/11/00 Demob 11,587 - 337.0 110.0 160.00 360.00 22 8/12/00 Demob 11,58~ - 337.0 110.0 23 8/i3/00 Demob '11,58~/' 13.0 350.0 157.0 24 8/14/00 Demob 11,587 19.0 369.0 157.0 25 "8/15/00 Demob 11,587 - 369.0 160.00 ~60".00 26 8/16/00 Demob 11,587 - 369.0 36.0 ,, OBM Injection Summary G-22 for G-26RD.xls 1/2 8/30/00--9:29 AM D'~y' Dat'e H01e Size Depth' F~otag~ Calculated 'Cum Calc Actual cumulative Was'te' Tank G-22 G-2~ Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (DRUMS) (DRUMS) (BBLS) (BBLS) (BBLS) 27 7/00 Demob 11,587 5.0 374.0 41.0 28 8~25)00 Demob" i11~87 ..... 374.0 '' i081'0 '" 2'9 8)29/00'' DemOb 11785 ............. 374.0 21.0 ...... 9i.50 350.00 ....................... To~al: " 374.0.. 823 "2,155 Drums full of OBM absorbents: 8.0 Note: Bruce/Dispose costs was estimated at $207/Drum. Flush injection is FIW Summary Total'DRuMs of C'uttin~s from G-26RD ' 374 Total ,,Fluid Injected into G-22's,, ,,, 13-3/8",, , by 9-5/8",, annulus (B 2,978, OBM Injection Summary G-22 for G-26RD.xls 2/2 8/30/00--9:29 AM Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings Summary for Drilling of G-28RD Day Date Hole Size Depth'!Foo'tagecalculated Cum Caic " Actual cumuiative' W"a's't'e Tank G-22 ........ G-22' Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) 0IBLS) 1 ' 6/18/00 '6100 '11,712 .... 12' 0.41 0.41 24.0 24.0 0 ....... 2 6/19/06 ..... 6.015 11,869 i'69' 5175' 6.15 4.0 28.0 62.0 3 6/20/00 6.00 11,923 54.. 1.84 7.99 9.0 '3710 62.0 4 6/2'1/06 6.00 12, i55' 2'32 "'7189 ....... 1'5.88 38.0 75.0 68.0 ........ 5 '~/'2'2/0'(~ .... 6.00''12,380 225 7.65 23.53 ...... 11.0 .... 86'i~) "' 68.0 6 6/23/00 6.00 12,597 2~7 7.38 30.91 18'10 i'04.0 .. 1.12.0 ............... 7 6/24/00 6.00 12,787 190 6.46 37.37 17.0 i2i.0 i'i2.0 .............. 8 6/25/00 " 6.00 12,986 199" 6.77' 44.13 17.0' 1'38.0 41'.0 71148 3~0.00 9 6/26/00 6.00 13,168 182''' 6.19 5'0.32 15.0' .. i53.0 411'0 ........... 10 6/27/00 " 6.00"' 13,237 69' 2.35 52.67 11.0 164.'0 41.0 ........ 1~ 6/28/00 6.00 13,357 120 4108' 56.75 14.0 178.0 46.0 12 '6/29/00 ... 6.00 13,455 98 3.33 "60.08 12.0 i90.0 " 46.0 ............. 13 6/30/00 6.00 13,580 ...... 125 4.25 64.33 15.0 205.0 64.© ........ 14 7/1/00 6'.00 13,660 80 2.72 67.05 7.0 212.0 "' 64.0 15 7/2/00 6.00 13,819 159 5.41 72.45 14.© 226.0 64.'0 ........ 16 7/3/00 6.00 i3,950 131 4.45 76.91 13.0 " 239'.0 64'.0 17 7/4/00 6100 14,160 210 7.14 84.05 18.0 257.0 77.0 18 5/5')00 6.00 14,203 '43' 1.46 85.51 5.0 262.0 92.0 19 7/6'/00 6.00 14,310 107 3.64 89.15 12.0 274.0 92.0 20 7/7/00 6.00 14,491 181 6.15 95.30 16.0 290.0 93.0 21 7/8/00 6.00 14,660 169 5.75 101.05 14.0 304.0 75.0 Reclaim 18 bbls 22 !' 7/9/00 6.00 14,746 86 2.92 103.97 14.0 318.0 75.0 23 7/10/00 6.00 14,914 1~58 5.71 109.68 10.0 328.0 75.0 24 7/11/00 6.00 15,065 151 5.13 114.82 16.0 344.0 75.0 25 7/1~/00 6.00 15,251 186 6.32 12i.14 18.0 362.0 86.0 ..... 26 7/13/00 Log 15,251 - - 121.14 12.0 374.0 86.0 27 7/14/00 Log 15,251 - " - '121.14 14.0 388.0 86.0 OBM Injection Summary G-22 for G-28RD.xls 1/2 8/22/00--3' 12 PM Day Date Hole Size Depth Footage Calculated Cum Carl: 'Actual" cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (£t) (BBLS) (BBLS) (BBLS) (BBLS) '(BBLS) (BBLS) (BBLS) ..... 0o................ 2 7/15/00 6. 15,416 - - 121.14 17.0 405.0 86.0 Well 29 7/16/00 6.00 15,416 - "' - 121.14 9.0 4'i4.0 "' 86.0 30 7/17200 'Liner 15,416 - _ 121.14 414.0 8610 31 7')'18)00 Liner 15,416 - - 121.14 414.0 8'6..0 .......... 32 7~19)00~ Liner 15,416 - ~ 121.14 12.0 426.0 86.0 ............. 33 7/20/00 Comp. 15,416 - - 121.14 "'426.0 86.0 ..... 34 7~21/00 Comp. 15,416 - " 121.14 426.0 - '' 132.00 350.00 35 "7/22/00 Comp. 15'1416 - ' ..... - 121.14 426.0 ....... - '" Total: 426.0 ~03' 700 Drums full of OBM absorbents' 10.0 Note: Bruce/Dispose costs was estimated at $207/Drum. Flush injection is FIW. Summary Tot"al DRUMS of Cuttings from G-'58'RD Total Fluid Injected into G-22's 13-3/8" by 9-5/8" annulus 42'6 903 OBM Injection Summary G-22 for G-28RD.xls 2/2 8/22/00--3:12 PM ..... STATE OF ALASKA ALASKA CL.,ND GAS CONSERVATION C,. ,IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Union Oil Company Of Califonia (UNOCAL) ~~ ~ O~ --"/~ ~ 3. Address 8. APl Number P.O. Box 196247, Anchorage, AK 99519 ~ 50-733-20295-01 4. Location of well at surface Conductor N~,g..~.-.-~. ~g Platform ~ t¢,,~,~ 9. Unit or Lease Name 1806' FSL, 1416' FEL,Sec 29,T9N, R13W,SM { ................ "~ Trading Bay Unit At Top Producing Interval ~; ~;,.!~¢O ;; ' 10. Well Number 2109' FSL, 427' FEL, Sec 32, T9N, R13W, SM i '~:;'.: ;:7 :;:';:~;?~'~!~ "' ~' G-26RD At Total Depth ! .... ..~' . i 11. Field and Pool 1566' FSL, 836' FEL, Sec 32, TgN, R13W,SM .:; ...........¢--*-,--.,..~**~-~,%,7 ~ McArthur River/Hemlock Zone 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 103' KB above MSLI ADL-17594 12. Date Spudded7/28/00 13' Date T'D' Reached I 14' Date C°mp" Susp' °r~/ba/~d' I 15' Water Depth' if °fish°re I 16' N°' °f C°mpleti°ns8/5/00 _8,'~ ,completed,/:t4-/O~( I ~//~//~b~j~ 125' feet MSL One 17. Total Depth (MD+TVD)11,587' MD/9734' TVD 18. Plug Back Depth (MD+TVD)11,535' MD/9704' TVD I 19' Directi°nal SurveY I 20' Depth where SSSV Setyes: X No: 288' feet MD J 21. Thickness of PermafrostN/A 22. Type Electric or Other Logs Run GR/Neutron Density/CDR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" Drive Pipe surf 356 Driven 0 20" 94 H-90 surf 740 26" 500 sx 0 13-3/8" 61/68 K-55 surf 5604 17-1/2" 3136 sx 0 9-5/8" 47 N-80/S-95 surf 10263' KOP 12-1/4" 1800 sx 0 7" 29 L-80 10121' 11587' 8-1/2" 400 sx 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 10,172' 10,070' Hemlock Benches 1,4,5 and 6 are open as shown: 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. HB-1 10729-10744' MD 9173-9185' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED HB-4 11028-11093' MD 9385-9430'TVD HB-5 11200-11210' MD 9502-9509' TVD HB-6 11422-11448' MD 9638-9653'TVD See attached completion schematic 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 8/8/2000'I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MOF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 8/18/2000 12 TEST PERIOD => 264 207 1106 196 783 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 100 1215 24-HOUR RATE => 528 414 2212 28.3 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORi~A rlON TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Hemlock Bench 1 10722 9166 Hemlock Bench 2 10779 9208 Hemlock Bench 3 10923 9311 ~Hemlock Bench 4 11025 9383 Hemlock Bench 5 11195 9497 Hemlock Bench 6 11435 9645 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe Title ~/~, Date Y ~-2/"'~ ~'~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Form 10-407 Item 28: If no cores taken, indicate "none". Daily Well Operations Summary G-26 Re-Drill 7/28/00 to 8/14/00 7/28/00 RIH with window milling assembly and Baker whipstock. Set whipstock on bridge plug at 10274' (WLM). Top of window at 10242'/bottom of window at 10260'. Mill whipstock to 10263'. 7/29/00 Mill window and new hole to 10294'. Perform FIT to 11.2 PPG EMW. POOH with milling assembly. 7/30/00 MU KO assembly, and RIH. Directional drill to 10362' 7/31/00 Continue drilling to 10760'. 8/1/00 Continue drilling to 10772'. POOH for bit. Encountered tight spots related to coal sloughing. Test BOP's MU BHA and RIH. Drill ahead to 10878'. 8/2/00 Continue drilling to 11137' while raising mud weight to 9.4 ppg. Spot Ventrol pill on bottom for coal sloughing. POOH for bit. 8/3/00 RIH and drill ahead to 11366' 8/4/00 Continue drilling to 11425'. POOH for LWD tools and bit. RIH to 10281' and begin 300'/hr MAD Pass. 8/5/0O Continue MAD Pass from 10281' to 11425'. Drill ahead to 11587'. Encountered tight hole at base of Hemlock Bench 6. POOH for liner. 8/6/00 Continue POOH and lay down LWD tools. MU 7" 29 lb/fi TKC, L-80 liner and RIH. Set liner at 11587' with liner top at 10121 '. Cement liner with 83 bbls of 14.5 ppg G cement slurry. Full returns and plug bumped. Release from Liner. Appears to be substantial amount (570') of excess cement on liner top. This would indicate rather than a 100% excess in open hole that approximately 30% excess would have been sufficient.) POOH with liner setting tools. 8/7/00 Continue POOH with liner setting tools. Make up 8-1/2" bit and scrapper assembly. RIH and drill cement from 9548' to 10,121' (TOL). Pressure test liner top to 2000 psi. POOH 8/8/OO 8/9/00 8/10/00 8/11/00 8/12/00 8/13/00 8/14/00 Continue POOH with 8-1/2" clean out assembly. PU 3-1/2" tubing and RIH with 6" clean out assembly. Tag landing collar at 11457' and drill landing collar and cement in shoe track to 11,535'. Displace well to 3% FIW/KCL. Clean surface mud system BOP's and choke manifold. Continue cleaning OBM from pits, flowlines and surface systems. POOH with cleanout assembly. PU 9-5/8" Baker Model D 192-47 packer and RIH with drill pipe. Continue RIH with packer on drill pipe. Set packer at 10,069'. Test annulus to 2000 psi for 15 minutes. POOH and lay down excess drill pipe. Pick up 4-1/2" single gas lift completion and RIH. Space out and land hanger with locator 1' above packer. ND BOP's and NU and test tree. Rid down Tesco top drive and re-string blocks. Prepare to perforate well. Perforate well from 11422-11448', 11200-11210', 11028-11093' and 10728'-10743' (6spf 60 deg phase, HC). Prepare for rig move to G-18. Hand well over to production and commence moving rig to G-18 at 12:00 hfs 8/14/00 UNOCAL ) RKB to TBG Head = 40.15 Tree connection: 4-1/16" 5,000# SIZE 13-3/8" 9-5/8" 7" Tubing: 4-1/2" 4-1/2" NO. 1 2-10 11 12 13 14 15 16 WT Trading Bay Unit Well G-2 /) As Built (8-11-00) CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 61.0 68 47 47 47 29 12.6 12.6 K-55 Butt. 12.515 Surf 2,610' K~55 Butt. 12.515 2,610' 5,617' N-80 Butt 8.681 Surf 7,979' P-110 Butt 8.681 7,979' 9,523' USS-95 Butt 8.681 9,523' 10,263' L-80 Butt 6.184 10,121' 11,587' L-80 Imp Butt 3.958 Surf 10,068' L-80 Hydril 511 3.958 10,082' 10,172' Depth JEWELRY DETAIL ID Item 40.15' 288' 10,069' 10,070' 10,082' 10,082' 10,141' 10,172' 3.810 3.833 4.75" 4.75" 3.958" 3.813" 3.958" 4-1/2" DCB Hanger 4-1/2" Butt Btm x 4-1/2" EUE top 4-1/2" Baker TE-5 WRSSSV 4-1/2" Camco MMG GLM's at 2389', 4237',5334',6427', 7388', 8105', 8744, 9339', 9928' Baker Locator/Seal Assembly. Baker Mod. 'D' 194-47 Packer (Set on DP) 10'Sealbore Extension 2jt 4-1/2" 12.6 lb/ft L-80 Hydril 511 "X" Nipple 1 jt 4-1/2" 12.6 lb/ft L-80 Hydril 511 with wireline re-entry guide 12 ZONE H-1 H-2 H-3 H-4 H-5 H-6 TOP PERFORATION DATA BTM AMT Comments 10729 TBD TBD 11028 11200 11442 10744 15 11093 65 11210 10 11448 6 2-7/8" 60 deg 6SPF (8/3/00) 2-7/8" 60 deg 6SPF (8/3/00) 2-7/8" 60 deg 6SPF (8/3/00) 2-7/8" 60 deg 6SPF (8/3/00) 16 --- H-2 ==_ H-3 ---- H-4 -- H-5 = H-6 PBTD -- TD = 11,587' MAX HOLE ANGLE = 54.6° G-26RD As Built.doc REVISED: 8/11/00 ANADRILL SCHLUMBERGER Survey report Client ................... : UNOCAL Field .................... : McArthur River Well ..................... : G-26RD API number ............... : 50-733-20295-01 Engineer ................. : Brown Rig: ..................... : Grayling / #54 State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller Pipe Tally GL above permanent ....... : -50000.00 ft KB above permanent ....... : 99.00 ft DF above permanent ....... : 99.00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 210.81 degrees 5-Aug-2000 17:34:17 Page ORIGINAL Spud date ................ : 28-Jul-00 Last survey date ......... : 05-Aug-00 Total accepted surveys...: 25 MD of first survey ....... : 10200.00 ft MD of last survey ........ : 11587.00 ft 1 of 2 Geomagnetic data -- Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 28-Jul-2000 Magnetic field strength..: 1104.77 HCNT Magnetic dec (+E/W-) ..... : 21.15 degrees Magnetic dip ............. : 73.53 degrees MWD survey Reference Criteria Reference G .............. : 1002.03 mGal Reference H .............. : 1104.77 HCNT Reference Dip ............ : 73.53 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 21.16 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.16 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0o00 RECEIVED Seq Measured # depth - (ft) 1 10200.00 2 10298.75 3 10329.92 4 10362.03 5 10392.11 6 10426.39 7 10456.33 8. 10484.38 9 10517.84 10 10552.75 11 10584.14 12 10611.41 13 10648.04 14 10677.97 15 10707.71 16 10800.60 17 10897.41 18 10991.99 19 11085.68 20 11178.89 21 11272.45 22 1~367o23 23 11450.95 24 11521.12 25 11587.00 Incl angle (deg) 30.00 31.43 31.98 32.65 33.86 34.48 35.65 37.28 37.83 38.18 38.51 39.22 40.15 40.19 40.46 43.85 44.62 46.14 46.67 49.27 51.22 53.09 53.84 54.24 54.24 Azimuth angle (deg) 183.00 190.65 189.81 190.42 169.94 192.29 195.52 194.08 196.25 200.34 202.52 204.32 207.17 210.28 213.64 215.02 214.52 214.76 216.00 216.33 215.10 215.03 215.71 215.43 215.43 Course length (ft) 0.00 98.75 31.17 32.11 30.08 34.28 29.94 28.05 33.46 34.91 31.39 27.27 36.63 29.93 29.74 92.89 96.81 94.58 93.69 93.21 93.56 94.78 83.72 70.17 65.88 TVD depth (ft) 8743.33 8828.26 8854.78 8881.91 8907.15 8935.62 8960.13 8982.69 9009.21 9036.73 9061.35 9082.58 9110.77 9133.64 9156.32 9225.17 9294.54 9360.97 9425.57 9487.97 9547.81 9605.95 9655.79 9697.00 9735.50 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 3441.64 -4580.93 3487.66 -4630.91 3503.00 -4647.03 3519.06 -4663.93 3533.04 -4680.21 962.12 956.07 953.16 950.14 950.14 3549.53 -4699.17 3565.99 -4715.86 3582.01 -4731.98 3601.64 -4751.66 3622.62 -4772.06 949.74 945.60 941.35 936.01 929.26 3641.83 -4790.18 3658.80 -4805.88 3682.09 -4826.94 3701.38 -4843.87 3720.62 -4860.19 922.15 915.35 905.18 895.91 885.72 3782.83 -4911.65 3850.20 -4967.13 3917.37 -5022.51 3985.00 -5077.83 4053.93 -5133.72 850.55 812.04 773.77 734.48 693.63 4125.59 -5192.12 4200.23 -5253.38 4267.28 -5308.23 4323.88 -5354.43 4377.17 -5397.99 651.65 608.65 569.71 536.68 505.68 4680.88 4728.57 4743.77 4759.73 4775.68 4794.19 4809.73 4824.70 4842.97 4861.69 4892.27 4911.08 4926.02 4940.24 4984.75 5033.06 5081.76 5130.67 5180.36 5232.85 5288.52 5338.71 5381.26 5421.62 168.14 168.34 168.41 168.49 168.52 168.57 168.66 168.75 168.86 168.98 169.10 169.22 169.38 169.52 169.67 170.18 170.72 171.24 171.77 172.31 172.85 173.39 173.87 174.28 174.65 0.00 TIP - 4.21 MWD 6-axis 2.26 MWD 6-axis 2.32 MWD 6-axis 37.41 MWD 6-axis 36.50 MWD 6-axis 7.33 MWD 6-axis 6.56 MWD 6-axis 4.28 '.MWD 6-axis 7.28 MWD 6-axis 4.43 MWD 6-axis 4.89 MWD 6-axis 5.58 MWD 6-axis 6.70 MWD 6-axis 7.37 MWD 6-axis 3.78 MWD 6-axis 0.87 MWD 6-axis 1.62 MWD 6-axis 1.11 MWD 6-axis 2.80 MWD 6-axis 2.32 MWD 6-axis 1.97 MWD 6-axis 1.11 MWD 6-axis 0.66 MWD 6-axis 0.00 MWD Project RECEIVED ALASKA OIL AND GAS CONSERYA~iON COPi~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 80.79 Re: The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill and complete .the TBU G-26 RD well as part of the pressure maintenance project approved by Conservation Order No. 80. Shannon W. Martin Land/Legal Analyst UNOCAL Corporation P O Box 190247 Anchorage, AK 99519-0247 Dear Ms. Martin: Your application dated July 12, 2000 for a "Permit to Drill" TBU well G-26 RD is proposed to recover additional oil from the Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU G-26 RD well pursuant to Rule 5 of Conservation Order 80 Done at Anchorage, Alaska and dated this Daniel T. Seamount, Jr. Commissioner / ~LY ~ of July, 2000. Camill60echsli Taylor Commissioner BY ORDER OF THE COMMISSION ALASI~A OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Williamson Drilling Manager Unocal P O Box 196247 Anchorage, AK 99519-6612 Re~ Trading Bay Unit G-26RD Unocal Permit No: 200-105 Sur Loc: 1806'FSL, 1416'FEL, Sec. 29, T9N, R13W, SM Btmhole Loc. 1656'FSL, 993'FEL, Sec. 32, T9N, R13W, SM Dear Mr. Williamson: 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 at 279-1433. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / ~ ~'~ day of June, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill X lb. Type of well Exploratory [] Stratigraphic Test E-I Development Oil X Re-entry [] Deepen [] Service [] Development Gas Single Zone [] Multiple Zone l-~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Unocal 99' RKB McArthur River Field 3. Address P.O. Box 196247 6. Property Designation Hemlock Anchorage. Ak 99519-6247 ADL-17594 4. Locatio, p of well at surface Leg 3, Cond. 3, Grayling Platform 7. Unit or Property Name 11. Type Bond (see 1,806',,F~..L, 1,416' FEL, Sec. 29, TDN, R13W, SM Trading Bay Unit 20AAC25.025) /~'"5/"..'Jt~ AK Statewide Oil & Gas Bond At top of productive interval 8. Well Number Number 2,505' FSL, 462' FEL, Sec. 32, TDN, R13W, SM G-26RD U 62-9269 At total dep_.th~ c./¢.¢Z, 9. Approximate spud date Amount 1,656' ,F~NE, 9~3I' FEL, Sec. 32, TDN, R13W, SM 7/23/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15 Proposed depth (MD and property line TVD) 462' 904' from Dolly Varden 42 @ Lease 5,116 acres 11,638' MD 9,741' TVD. 9,760' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Kickoff depth 10,247' feet Maximum hole angle 55° Maximum Surface 3280 paiD. At total depth (TVD) 4256 psig 18. Casing Setting Depth program size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD 81/2" 7" 29 L-80 Buttress 1,491' 10,147' 8,731' 11,638' 9,760' .,~, ~ .... ~,,% ~.~. ~,2~ ~,,% 19. To be completed for Redrill, Re-entry and Deepen OperationsJUL~ 42000 Present well condition summary Total depth: measured 11,544 feet Plugs (measured) True vertical 9,904 feet ~Ja~ka Effective Depth measured 11,415 feet Junk (measured) Perf Guns @ 11,073' and 11,038' True vertical 9,940 feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural 356' 26" Driven 356' 356' Conductor 740' 20" 500 sx 740' 740' Surface 5,604' 13-3/8" 3,136 sx 5,604' 4,929' Intermediate Production 11,540' 9-5/8" 1,800 sx 11,540' 9,887' Liner Perforation Depth: Measured 10,699'-10,729'; 10,873'-10,910'; 10,923'-11,058'; 11,088'-11,218'; 11,205'-11,280' True Vertical 9,173'-9,199'; 9,322'-9,354'; 9,365'-9,480'; 9,505'-9,615'; 9,643'-9,668' ~ kJl\lUIl~l 21. I h~~.~ify ti I~t t¢2¢t¢oi_ng is true a.nd correct to the best of my knowledge Signed~~l ~,~~--~~~~ Title: Drilling Manager Date Commission Use Only IAPl Number50- '~.~'~ '-'.~~"O/I Permit Number.,.,., _, _., ._. ~._~ /O Approval date ,,, See cover letter "~ -.~ / '~-"~ for other requirements Conditions of approval Samples required [] Yes ~No Mud log required [] ~'es ~No -- Hydrogen Sulfide measures [] Yes ~No Directional Survey required )i~Yes [] No Required working pressure for DOPE [] 2M [] 3M ~ff,~M [] 10M [] 15M Other: ORIG~NAL SIGNED BY by order of / Approved by ID Taylor Seamount. Commissioner the commission Date Form 10-401 Rev. 12-1-85 AFE# Submit in triplicate Hazard Section Application for Permit to Drill G-26RD Geopressure There are no known over-pressured intervals in the proposed drilling interval of G-26RD.The well will sidetrack from 10,271 adjacent to the Tyonek G-3 Sands. The well will proceed through Tyonek, into Hemlock Benches 1 through 6 and T.D. in the West Forelands. All of these intervals are expected to be at or below normal pressure. The well will be drilled with an Oil Base Mud system with mud weights in the range of 8.8 to 9.4 ppg. Lost Circulation Lost circulation is not anticipated to be a problem. However, LCM materials will be kept aboard during drill operations should losses be experienced. Lost circulation will be treated initially with Ventrol 401. If losses still occur, 100 ppb liquid casing and CaCO3 will be added to the oil based mud system. Hole Stability Coal intervals are present throughout the G-Zone interval (10,247' to 10,700' MD) and top of Hemlock. These intervals could be problematic while drilling. Mud weight may be increased to mitigate sloughing should it occur. Mud and Cuttings Disposal The cuttings generated by drilling G-26RD will be containerized for disposal in an approved injection well. Waste OBM fluids will be disposed of in the permitted 9- 5/8" x 13-3/8" annulus in Grayling Well G-/2~ ~ ~_ ,- Preliminary Procedure Grayling G-26 Re-Drill Mill Window and Drill 8-1/2" Hole 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) Make up one trip whipstock assembly RIH with one trip whipstock assembly n~ Orient whipstock. Set whipstock at 10,2L7~'. Change hole over from Filtered Inlet Water to Oil Base Mud. Mill window in 9-5/8" casing. Circulate bottoms up. POOH with millinh assembly. LD mills, PU drilling BHA. RIH with BHA. Drill 8-1/2" from 10,271' to 11,638' Run and Cement 7" Liner 11) 12) 13) 14) 15) 16) 17) 18) 19) Change top pipe rams. Test BOPE. RU casing crews for 7" liner. RIH with 7" liner. Cont. RIH with liner on drill pipe. Set liner hanger and release running tool. Cement liner. Set isolation packer and circulate string clean. POOH with running tool. Clean Out 7" Liner 20) RIH with Bit/Casing Scraper. Clean out 7" Liner. 21) POOH. LD BHA. Run Completion 22) 23) 24) 25) 26) 27) 28) 29) 30) 31) 32) 33) 34) 35) MU 9-5/8" Production Packer. RIH on drill pipe. Set at 10,000'. POOH. Pull wear bushing. RU to run 4-1/2" Gas Lift Completion. PU, rabbit and run completion. Space out, install SSSVLN and PU hanger. Land hanger. Lay down landing joint. RD tubing running equipment. ND BOPE. Install tree and test. Install flowlines. Release rig. UNOCAL ) RKB to TBG Head -- 36.44 Tree connection: 4-1/16" 5,000# 14 17 -- H-2 == H-5 == H-6 PBTD = TD = 11,850' O _ ~ ~[~'~)~'oEsI~GLE = 60° SIZE 13-3/8" 9-5/8" 7~, Tubing: 4-1/2" NO. 61.0 68 47 47 47 29 12.6 Depth WT Trading 1~¥ Unit Well Proposed CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 36.44' 1 283' 2 3 4 5 6 7 8 9 B 10 11 12 13 9,999' 14 10,000' 15 10,004' 16 10,046' 17 10,080' ZONE H-1 H-2 H-3 H-4 H-5 H-6 ID K-55 Butt. 12.515 Surf K-55 Butt. 12.515 2,610' N~80 Butt 8.681 Surf P-110 Butt 8.681 7,979' USS-95 Butt 8.681 9,523' L-80 Butt 6.184 10,147' N-80 Butt JEWELRY DETAIL Item 3.958 Surf 4-1/2" Type DCB Tbg Hngr 4-1/2" WLRSSSV Nipple GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" GLM, 4-1/2" Baker Locator/Seal Assembly. Baker Mod. 'F' Packer Millout/Sealbore Extension Nipple, "X" Wireline Entry Guide TOP PERFORATION DATA BTM AMT Comments TBD TBD TBD TBD TBD TBD REVISED: DRAWN BY: TCB 2,610' 5,617' 7,979' 9,523' 10,250' 11,638' 10,000' UNOCAL ) RKB to TBG Head -- 36.44 Tree connection: 4-1116" 5,000# 17 H-1 H-3 H-4 H-5 / H-0 PBTD = 11,416' TD = 11,544' 3.5'TD. Restriction in tubing at +/-10,297 Fill at 10,349' SLM SIZE WT Trading m~y Unit Well G-'-_ Proposed Abandonment CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 61.0 68 9-5/8" 47 47 47 Tubing: 4-1/2" 12.6 NO. Depth ID K-55 Butt. 12.515 Surf K-55 Butt. 12.515 2,610' N-80 Butt 8.681 Surf P-110 Butt 8.681 7,979' USS-95 Butt 8.681 9,523' N-80 Butt JEWELRY DETAIL Item 2,610' 5,617' 7,979' 9,523' 11,540' A 10,271' 9-5/8" Retainer (Cement may be squeezed below retianer pending inj. test) 14 10,553' 3.890 15 10,593' 3.75 16 10,629' 4.815 17 *'10,620' 6.00 18 10,630' 19 10,653' 3.687 20 10,654' GLM No. 13, Camco 4-1/2" MMG, 1-1/2", 7.031" O.D. Camco 4-1/2" Sliding Sleeve, 5.5" O.D. (Opens Down) Baker Mod. G Locator, 6.25" O.D. Baker Mod. 'F' Packer **(DIL) Seal Assembly, 20.94' Long Camco "DB" Nipple, 5" O.D. Wireline Entry Guide 21 11,060' 22 11,220' Isolation Packer, Baker Mod "FB" Wireline Set Isolation Packer, Baker Mod 'DB" Wireline Set Fill Tagged on 5/11/00 FISH: 2-1/8" x 44' Perf. Gun and toolstring 2/2/91 2-1/8" x 10' Strip left in hole 2/20/89 10,349' WLM 11,073' WLM 11,038' WLM ZONE TOP PERFORATION DATA BTM AMT Condition H-1 10,699' H-3 10,873' H-4 10,923' H-5 11,088' H-6 11,250' 10,729' 30' Isolated by fill 10,913 40' Isolated by fill 11,058' 135' Isolated by fill 11,218' 130' Isolated by fill 11,280' 30' Isolated by fill REVISED: DRAWN BY: TCB 3.958 10,300' 10,629' l [ I , . NIPPLE .~-5/~" ~000 ANNU~d:~ PIPE RAMS .t" KILL L,'NE Wrl'H ['" TWO ~," ~.~ VALVES ~ CEMEN? UNFF BLINO RAMS . . 2 FLOWLIN£ FLANGE DOUBLE GATE 5M CONNE~ TO CHOKE MANIFOLI3 DRAWINO) PIPE RAMS CHOKE LINE WITH ONE REMOTE 1 I~UAL 4,,, 5M V~VE RISER ' '1 10" 5M × 13-5//8" AOAPTER CAMERON 5M SPOOL 15-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dbcr UNO .CAL) 'l' '43RAWN: APP'O: S'C.~E: NONE / TO GAS EIUSTER /\ 1'00~RICK VENT 1 TO WELL CLEAN TANK '' "~: ' : ~ " :' ' ' ' AUTOMATIC AUTOI,,tATIC CHOKE CHOKE: · FROU CHOKE LINE · VALVES UPb-FREA,~ OF. CHOKES ARE 10,000 PSt GATE TYPE VALVES 00WN~U OF CHOKES ARE 5,000 PSI GATE TYPE CHOKE I~tANIFOLD GRAYLING PLATFORM UNION OIL COUF'ANY OF CALIFORNIA (db~ UNOC _) DRAWN: OAC AP P'O' 058 SC..tLE: NONE OATS: ~ ~/=~/ag MIXINO PIT 40 BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE 5-~STEM 1 a5 BBLS VOLUME PIT TRIP TANK 4-5 BBLS 185' BBLS SUCTION PiT 12.5 BBLS 67 BBLS DESILTER 2-'1-0 BBLS SHAKER SI-IAI(ER RESERVE PIT · 475 BI3LS 14GTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL INDIOATOR WITH AUDIO ~ VISUAL WARNING D~iCESi. ' EQUIPMENT ,LIST 1) RESERVE PIT 2) DEGASSER :s) Cz) 4) PIT LEVEL INDICATOR (VISLIAL & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK .. 7) PIT AGITATORS Fi) DESILTER 9) CENTRIFUGE 10) MIXING: PiT UNOCAL GRAYLING MUD PlY SCHEMATIC DRAWN ElY: DAE APP'D: GSI3 SCALE: NONE DATE: 11--30--~c3 iJNOCAL Schlumberger Proposed Well Profile - Geodetic Report Client: Unocal Field: Structure: Well: Borehole: UWIIAPI#: Date: Grid Convergence: Scale Factor: McArthur River Field Grayling G-26 G-26RD (P5) 507332029501 July 10, 2000 -1.40861812° O.99999421 Location: : Coordinate System: N 60 50 22.591, W 151 36 46.645 N 2502354.640 flUS,. E 212266.550 ftUS NAD27 Alaska State Planes, Zone 4, US Feet Survey Computation Method: Minimum Curvature DLS Computation Method: Lubinski Vertical Section Azimuth: 210.470° Vertical Section Origin: S 4580.930 ft, E 962,120 ft TVD Reference: KB 99.0 ft above Mean Sea Level Magnetic Declination: 21.158° Total Field Strength: 55236.921 nT Dip: 73.526° Declination Date: July 10, 2000 Magnetic Declination Model: BGGM 1999 North Reference: True North Coordinate Reference To: Well Head ii Srid Coordinates Geographic Coordinates {fl) (°) (°) ('fl) {fl) (fl) {fl) (°/100ft) {flUS) (flUS) ,,, Tie-In Survey 10200.00 30.00 183.00 8743.33 0.00 -4580.93 962.12 0.00 2497751.48 213115.76 N 6049 37.480 W 151 36 27.240 Top Whipstock 10263.00 29.84 183.63 8797.94 27.96 -4612.30 960.30 0.56 2497720.16 213113.17 N 6049 37.171 W 151 36 27.277 Base Whipstock 10275.00 31.59 185.54 8808.25 33.48 -4618.41 959.81 16.67 2497714.07 213112.53 N 6049 37.111 W 151 36 27.286 KOP Crv6/100 10288.00 31.59 185.54 8819.33 39.65 -4625.19 959.15 0.00 2497707.31 213111.71 N 6049 37.044 W 151 36 27.300 10300.00 31.50 186.90 8829.55 45.38 -4631.43 958.47 6.00 2497701.08 213110.87 N 60 49 36.983 W 151 36 27.313 End Crv Crv 6/100 10400.00 31.31 198.43 8914.99 94.78 -4682.06 947.11 6.00 2497650.75 213098.27 N 60 10448.69 31.59 204.00 8956.21 120.33 -4706.23 937.79 6.00 2497626.82 213088.36 N 60 10500.00 34.63 204.91 8999.18 148.20 -4731.73 926.18 6.00 2497601.61 213076.13 N 60 10538.32 36.90 205.50 9030.27 170.50 -4751.99 916.64 6.00 2497581.59 213066.09 N 60 10588.00 36.90 205.50 9070.00 200.22 -4778.92 903.80 0.00 2497554.98 213052.59 N 60 49 36.484W151 36 27.543 49 36.246W151 36 27.731 49 35.995W151 36 27.965 49 35.796W151 36 28.157 49 35.530W151 36 28.416 End Crv Crv 6/100 10600.00 37.32 206.47 9079.57 207.44 -4785.43 900.63 6.00 2497548.55 213049.26 N 60 10619.27 38.00 208.00 9094.83 219.19 -4795.89 895.24 6.00 2497538.23 213043.62 N 60 10657.56 38.00 208.00 9125.00 242.74 -4816.70 884.17 0.00 2497517.70 213032.04 N 60 10700.00 40.21 209.99 9157.93 269.50 -4840.11 871.19 6.00 2497494.61 213018.49 N 60 49 35.466W151 36 28.480 49 35.363W151 36 28.589 49 35.158W151 36 28.812 49 34.928W151 36 29.074 G-26RD (P5) report.xls Page 1 of 2 7/10100-2:45 PM Grid Coordinates Geographic Coordinates Station ID I MD I Incl I Azim I TVD I vSec I N/-S'I E/-WI DLS Northing I Easting Latitude Longitude (o) (o) (o loof ) (f us) (f us) , ,, 10800.00 45.55 214.04 9231.20 337.47 -4897.70 835.03 6.00 2497437.93 212980.92 N 6049 34.361 W 151 3629.804 Crv 1/100 10826.82 47.00 215.00 9249.74 356.80 -4913.67 824.05 6.00 2497422.24 212969.56 10900.00 47.72 215.00 9299.31 410.46 -4957.76 793.17 0.99 2497378.92 212937.60 11000.00 48.71 215.00 9365.94 484.79 -5018.84 750.40 0.99 2497318.91 212893.34 11100.00 49.69 215.00 9431.28 560.26 -5080.85 706.99 0.99 2497257.99 212848.42 11200.00 50.68 215.00 9495.31 636.83 -5143.77 662,93 0.99 2497196.17 212802.83 N 60 49 34.204W151 36 30.025 N 60 49 33.769W151 36 30.648 N 60 49 33.168VV151 36 31.511 N 60 49 32.557W151 36 32.386 N 60 49 31.938W151 36 33.275 End Crv / TD 11300.00 51.66 215.00 9558.01 714.49 -5207.59 618.25 0.99 2497133.47 212756.59 11400.00 52.65 215.00 9619.36 793.21 -5272.27 572.95 0.99 2497069.92 212709.72 11500.00 53.64 215.00 9679.34 872.97 -5337.82 527.06 0.99 2497005.52 212662.23 11600.00 54.62 215.00 9737.93 953.75 -5404.20 480.58 0,99 2496940:30 212614.13 11638.30 55.00 215.00 9760.00 984.95 -5429.83 462,63 0.99 2496915.12 212595.56 N 60 49 31.309W151 36 34.176 N 60 49 30.672W151 36 35.090 N 60 49 30.027W151 36 36.015 N 60 49 29.373W151 36 36.953 N 60 49 29.121 W151 36 37.315 Legal Description:, Surface: 1806 FSL 1416 FEL S29 T9N R13W SM Tie-In: 2505 FSL 462 FEL S32 T9N R13W SM BHL: 1656 FSL 963 FEL S32 T9N R13W SM No~hinq CY)[flUS] Eastinq 2502354.64 212266.55 2497751.48 213115.76 2496915.12 212595.55 G-26RD (P5) report.xls Page 2 of 2 7/10/00-2:45 PM UNOCAL ~RTiCALSECTIONVI~W Client: Unocal Well: G-26RD (P5) Field: McArthur River Field Structure: Grayling Section At: 210.47 deg Date: July 10, 2000 Schlumberger 9000 9250 9500 Tie-In Survey10200 MD 8743 TVD 30.00' 183.00° az 0 departure -- ;'up Wi,ipa[u~;k i 0263 ;vid 57~8 TVD Z9.84' 183.63' az 28 dep~ rture - Base Whipstock10275 ~ ID 8808 TVD 31,59° 185,54° az 33 Ceparture ~ KOP Crv $110010288 IJD 8819 TVD 31.59' 185.54' az 4Cdepartum -~ - Etd C~-: 105 !8 MD 0030 ,~;D ~ 36.90' 205. ,0' az 171 departure · C, r61100 10588 MD 9070% ) % ~-~....~ 38 90' 205.50° az 200 depar ~re . End Crv 10619 MD 909~ TVD 38.00" 208.00' az 219; ~partum ~ '~_ ~ Crv G/tO0 106-=, MD 9125TVD --'~~'~~~38'00' 208.00' az 243 departure ' \ \ i ~--~ c. 1,1°~10827M~ 9250w0 Survey __ End Crv I Ti) 11638 MD 9760 TVD 55.00' 215.00' az 985 departure ..... ,, -250 0 250 500 750 1000 1250 1500 Vertical Section Departure at 210.47 deg from (-4580.9, 962.1). (1 in = 250 feet) UNOCAL ) Client: Unocal Well: G-26RD (PS) Field: McArthur River Field Structure: Grayling Scale: 1 in = 200 ft Date: 10-Jul-2000 Schlumberger -4600 A -4800 A A 200 400 600 800 1000 1200 '1- -5200 F- O V V V -5400 -5600 -5800 200 I I= = Tiedn ~u~,uy i0200 k4D 6743 Tv'D 30.00" 183.00°az 4581 S 962~,E Top W l~ipsteck10263 MD 8798 T /D~ 29.84" 183.63' ~ ~12 S ~0 E ~se ~ips ~ock10275 MD 8808 ~D 31.59' 185.~'~ 4618S 960E KOP C~611~' 0288 MD 8819~D - - 31.5S' ;85.~"a~ 4825 End ~ 10538 MD D30 ~D 36.90' 205.~" ~ 4 r52 S 9~~ C~ ~10~ 10588 MD 90"0 ~D 36.90" 205.50' ~ 4779 S ~ _ J nd C~ 1~19 MD 9095 ~ D ~8.00' 208,~' az 47~S ~95 E C~ 61100 1~58 MD 9125 ~ /~ 38.(0' 208.00'az 4817S 8~ E C~11' 00 10827 MD 9250~D 47.00' 215.00°~ 4914S 824E G-26 11638 N D 9760 ~D 55.00' Z15.00' ~ ~ S 463 E ~ = Su~y J -4800 400 600 800 1000 1200 ~400 -5600 -5800 <<< WEST EAST >>> Project Summary Casing Depth Program TVD Well G-26RD _ I I III IIjJIll ~ Mud Mud Cumulative System Weight Mud Cost window 10240' N/A 4 1/2" 10240'- 11840' Versaclean 9.0-9.5 $74,635 Comple- tion 11840' Mapco Base Oil 7.4 84,635 3% KCL Key Iss~ e .No. 1 Sloughing Coal · For sloughing coal in the 6" interval (oil mud), spot Ventrol 401. For severe problems consider increasing mud weight. Key .[SSUe No. 2 Ho[e Cleaning ~ev ~sm~e 3o.~ · Maintain sufficient 3 RPM reading to insure adequate hole cleaning. Sweep hole as needed to avoid cuttings buildup. Pump weighted sweeps to aid in hole cleaning. Rotate and reciprocate drill string to remove cuttings beds. · Run as fine a mesh shaker screen as possible. Run centrifuge during trips to reduce drill solids in mud. Economics Summary Well G-26RD _.. 10,240-11,840 20 20 $62,135 $12,500 $74,635 Completion 5 25 $6875 $3,125 $10,000 , ~.,L. ~'' --. ~ ~ --~l--.. -- ----J~ . -- ~ ]L ___] I ~ I I I ~ * Well cost includes full time engineering service. * Completion fluid cost includes Mapco 200 and 3% KC1 brine. · Cost does not include any provisions for lost circulation, etc. * Cost is based on material usage on Using existing OBM system. * Cost assumes mud weight does not exceed 9.5 ppg Cost assumed 850 bbls of 3% KCI brine needed for completion. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Interval Summary (6-hole) Well G-26RD Drilling Fluid System Key Products $°iid~s control Potential problems Mapco 200 / Versawet / Versacoat / Versa H]~ / VG-69 / Versa- mod / Lime / Calcium Chloride / MI Bar / Ventrol 401 Shale Shakers / Desilter / Centrifuge : Depth Mud Plastic Yield HTHP Interval Weight ViScosity Point Fluid Loss O/W Gels (ft) (PPg) (cP.,) (Ib/100ft~) (ml/30min) Ratio (Ib/100ft=) "ib'1240-11,84o ' 9.0-9.5' 20- 25 18- 22 4- 5 cc's ' 80/20 ' 15 -- 30 L --2 ..... ~ ~-~ r After .running and setting whipstock, dump and clean all surface pits. Displace hole volume to production. Build 30 - 40 barrel Calcium Chloride brine spacer to pump between hole volume and oil based mud. · Displace hole to oil based mud. Insure no spacer or oil based mud is discharged. · Drill ahead, maintain low shear rate values with VG-69, Versamod, Versa HRP, and Aleomer 274. · Run centrifuge as needed to reduce solids buildup. · Pump weighted sweeps to aid in hole cleaning. · If sloughing coal becomes a problem, add 2 - 4 ppb of Ventrol 401 to mud system or spot a concentrated pill of 20 - 25 ppb Ventrol 401 across coal zone prior to trips. For severe coal sloughing consider raising mud weight. · Run 4 1/2" pre-drilled liner. Displace open hole volume to base oil (Mapco 200). · Displace well to brine after running tubing. Pump a Kleenup spacer for displacement to 3% KCL. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 9950 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS Interval Summary (6" hole) Well G-26RD i ilrlI i I ii I I I Lost CirculatiOn Problems Key p~-Odu-Cts Recommended LCM Pill Formulas Drilling Fluid / OM Seal / SafeCarb Fine, Medium, Coarse / Versa- Volume :OM Seal SafeCarb SafeCarb Versa HRP of Mud Fine Medium , (barrels) .. (ppb) (ppb) (ppb) (ppb) · 30 10 10 10 1/4 111 .... . ......... ~,~x~ _ -- ~ ~ Volume OM Seal SafeCarb SafeCarb Versa HRP of Mud . Medium Coarse · , ,,. (barrels) . (ppb) (ppb) , (ppb) (,ppb) 40 15 15 10 1/2 Volume OM Seal SafeCarb SafeCarb Versa HRP of Mud Medium Coarse Polymer (barrels) (ppb) (ppb) (ppb) (ppb) 50 15 20 30 1 Versa HRP should be added last, only after all lost circulation material has been mixed. If possible, spot pill across theft zone. Apply moderate pressure (50 - 100 psi) to squeeze pill into thief zone. ! M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS G--17 K-10RD K-! ADL-18777, Unocal Forcenergy G-15 uNOr. AL~ Trading Bay Unit Grayling Platform PROPERTY PLAT G.-13 G-L*7 30 · AD L-17594-1,A Unocal orcenergy G-.19 D-15 Trali~g Bay Unit. Boundary, D '- ADL.'17602-- '""~' Unocal Forcenergy 1 I I I . D-40RD D -~8 K-17 ADL-18730-~ I Unocal Marathon 8730-2,A Unocal' Forcenergy G--8 Unocal Marathon L-18729,2,A~=,~ Unocal Fo.r. cenergy ~-. TRADING BAY UNIT Top HEMLOCK STRUCTURE --9200 (; - :J R D,. , (.;- ;[1{I) I prOposed v/ G-26 Redrili / .,-:~ F~ ~, [ --9~: ~..~ .// ~ ~ G ~; .... 1.) .~ /~ _ ........ _..i. - / / / ! ~ /I . L~- "' ' ''~ ~" OIL WATER SHUT WELL INJECTOR IN G-ZONE PENET~AllON m m II ,500 I'1.. ' CONTOUR INTERVAL: Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager July 11, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Commissioner Robert N. Christenson Re: Request Approval Commissioner Christenson: Grayling Well G-22 is currently approved by the Commission for annular injection of Oil Base Mud (OBM) liquid waste generated from G-28RD, which is currently in progress. Grayling G- 26 has been added to the schedule as a re-drill to follow immediately after G-28rd completion (approximately 7/18/00). Unocal intends to utilize OBM on the G-26RD and requests that the current approval for injection be amended to include OBM waste liquids generated from G- 26RD. To date (7/11/00), 71 bbls of OBM waste and 350 bbls of sea water have been injected into G-22 from G-28rd and it is anticipated that an additional 450 bbls of OBM and 1,050 bbls of sea water will be injected by completion of the well. The estimated volume to be disposed of from G-26RD is 1,000 bbls OBM/Water and 3,000 bbls sea water. Should you have any questions or concerns, please contact me at 263-7677 or Tim Brandenburg at 263-7657. Sincerely, Dan Williamson Drilling Manager G-22 Injection Request Tim Brandenburg ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: X 103' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO BOX 190247 Anchorage Alaska 99519 Service: Trading Bay Unit 4. Location of well at surface Leg 3, Cond. 3, Grayling Platform 8. Well number 1,806' FSL, 1,416' FEL, Sec. 29, T9N, R13W, SM G-26 At top of productive interval 9. Permit number 2,257'FSL, 549'FEL, Sec. 32, TgN, R13W, SM At effective depth------. ~: ~ ~i ~,~ !,..~ 10. APl number 50-733-20295-00 At total depth JUL 1 4" 2000 11. Field/Pool 1,813' FSL, 559' FEL, Sec. 32, TgN, R13W, SM McArthur River/Hemlock 12. Present well condition summary~1 Total depth: measured 11,544' fee'~ Cons. C,0mm. issi ~'~ug¢ (r0easurs8} 'l~For~e true vertical 9,904' . feet Effective depth: measured 11,41 5' feet Junk (measured) Perf gun @ 11,073' and 11,038' true vertical 9,941' feet Casing Length Size Cemented Measured depth True vertical depth Structural 356' 26" Driven 356' 356' Conductor 740' 20" 500sx 740' 740' Surface 5,604' 13-3/8" 3,136sx 5,604' 4,929' Intermediate Production 11,540 9-5/8" 1,800sx 11,540' 9,887' Liner Perforation depth: measured 10,699'-10,729'; 10,873'-10,910'; 10,923'-11,058'; 11,088'-11,218'; 11,205'-11,280' true vertical 9,173'-9,199'; 9,322'-9,354'; 9,365'-9,480'; 9,505'-9,615'; 9,643'-9,668' Tubing (size, grade, and measured depth) 4-1/2", N-80, 12.6# @ 10,654' Packers and SSSV (type and measured depth) Baker "F" @ 10,631', "FB" @ 11,060', "DB" @ 11,220', Camco "TRB-6" SSSV @ 283' 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 7/20/00 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17.1 here.~bt~s,ertify that the~j~ing is true and correct to the best of my knowledge. U I L7 1 I~! L S ig ne(~~V~../~~(J~J ~f~,/~a n~' liam son Title: Drilling Manager Date: 7--/,~ ""~ v -- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity~ BOP Test Location clearance I Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED ~'~ 1031548 12-Jul-O0 2003598 11-JUL-O( DRTI, LPERMTTG261~ D 0?00300019!, 100. O0 100. OO FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. 100 O0 100. O0 DETACH STUB CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp 311 ONE PENN'S WAY NEW CASTLE, DE 19720 Pay Union Oil COmpany of California Accounts Payable Field Disbursing UNOCAL ) One Hundred Dollars And 00 *********************************** 20'0:5598 To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 Date V 12-JUL-00 Check Amount..... 1 0 0.0 0 Void after six months from above date, ," P-O0 3 5 q~3," I:0 3 l, &O0 HO q~: 3 q ]. i, 4{ ]. 3 ?," WELL PERMIT CHECKLIST COMPANY ~A,,/~;)~/-._ WELL NAME C'~-2_~ ~ PROGRAM: exp dev FIELD & POOL ~-~/' ~ INIT CLASS -~--~-~' t,,/ Y~)/~..~ GEOL AREA II~ ~ ~ redrll J serv wellbore seg ann. disposal para req UNIT# ON/OFF SHORE ~.,)/~'-/~' ADMINISTRATION 1. Permit fee attached ....................... N 2. Lease number appropriate ................... 3. Unique well name and'number .................. N 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ · 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N. 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ P,.,~ DATE 12. Permit can be issued without administrative approval ...... . "7- / :~ ~ 3. Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ,~'(3~(,..~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y N N N N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ~ N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ~'""~ I~Y N a~ DATE 33. Seabed condition survey (if off-shore) .......... .,~,../~ . _ ~- i~"(~::) 34. Contact name/phone for weekly progress reports~ratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan ,/M~ ,~-C1-(0~,.¢ ../~"~rjz:_(~., . .. ~ --~ (A) will contain waste in a suitable receiving zone' . ...... PPR DATE (B) will not contaminate freshwater; or cause drilling waste... _ ..,/._, to surf.ace; .... t~om -fllff|ZoDO (C) will not impair mecnanicai integrity of the well used for disposal; ky_) N .,. _ . _/' / ..... ' (D) will not damage producing formation or impair recovery from a __ pool; and (E) will not circumvent 20 AAC 25.252 or20AAC 25.412. ~_"")N N'~rv~ ...%R~u,t-J~ ~:: U~,O6L ~,,9, ~z:::)o 1::~::1[~5, ._ST~,U.. GEOLOG_Y: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: g _.w oo :Z -I -1- c:Vnsoffice\wordian\diana\checklist (rev. 02/17/00)