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Home My WebLink About201-117 • • 11 Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, March 10, 2016 2:25 PM To: Juanita Lovett; Dan Marlowe Cc: Carlisle, Samantha J (DOA) Subject: RE: Please withdraw Sundry# 315-469/PTD: 201-117 - King Salmon K-18RD Juanita, The AOGCC will withdrawn sundry 315-469 as requested.. work scope was to replace ESP on well K-18RD. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell , ik 907-793-1226 office , ° ` i ', ��,, . the Alaska Oil and Gas Conservation CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Juanita Lovett [mailto:jlovett@hilcorp.com] Sent: Thursday, March 10, 2016 1:50 PM To: Schwartz, Guy L(DOA); Dan Marlowe Subject: Please withdraw Sundry # 315-469/ PTD: 201-117 - King Salmon K-18RD Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jlovett@hilcorp.com 1 RBDMS LA, !AR 2 2 2016 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ‘A4- DATE: 9/24/2015 P. I. Supervisor FROM: Matt Herrera SUBJECT: SVS Testing Petroleum Inspector TBU K-18RD Hilcorp Alaska LLC PTD 2011170 9/23/2015: Brian Bixby (new Inspector) and I traveled to TBU King Salmon plafform to witness well safety valve system tests. Performance tests all passed (7 wells, 14 components); refer to Inspection Report sysMFH151003171254 for details. All of the King Salmon plafform producers have the annulus outlet on the production tree is tied into production (annular vent) - see attached photo of TBU K-18RD as an example. I asked them about why it didn't have an automated shut in on the annulus side along with the SSV. Brian provided technical support with his background dealing with annular vents at Milne Point. The Operations Supervisor assured me they did NOT need an automated valve due to the fact the wells had a "No Flow" status. The annular vents has a check valve and a manual valve for shut-in capability. We were also told the wells were "always" tested while they were shut down due to fact they cannot be tested on line. Hilcorp is to my knowledge the only operator in Alaska who does not test their ESP's on line. It may be time to re-evaluate their testing procedures. Summary: Observed annulus vent lines on the TBU King Salmon producing wells (ESP completions); none of the wells have an actuated valve on the annulus side. Attachments: Photo (1) , IUu�e - 1c6 rf Txtvak otA 31z01,s --}-b SatAt4 SEP 2 3Z016 reca1cawpe_ U. `s (-wi ct vvy_ Etc, SE'S Tess- o r c xLlf e t,,tAtL 2015-0924 SVS TBU K-18RD mh.docx Page 1 of 2 • • TBU K-18RD (PTD 2011170) -Annulus Vent Line Photo by AOGCC Inspector M. Herrera 9/23/2015 ®' r ii Ef I i f s 'SMS+". ' ,. , it 44 !t t-- Stu r� 1� ter 4,, r7E7.--- - IP, ,, ithet. , - -,__-"`": 4 ,:i or,„ App.. A ;*!.°4, 0 \' ,.r 4 1 t 1//,' ' i / t 4 4 .--40' , ..„,...*14 f i ai' la ed r 2015-0924 SVS TBU Kf-18RD mh.docx Page 2 of 2 • • V71//T/44'6.41 -z------- THE STATE Alaska Oil and Gas ti 0 ,, r, of�T j\ J( 4 Canservatian Commission __,_„„,__ 1 t ___ - 333 West Seventh Avenue F/ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 viFI "M7 Main 907.279 1433 Op,ALAS”- ,t +1.09 Fax: 907.276 7542 b www.aogcc alaska.gov Ted Kramer I - t , 7 Sr. Operations Engineerao Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-18RD Sundry Number: 315-469 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, "9124..i.(7 . Cathy P. F erster Chair DATED this ( day of August, 2015 Encl. FJ�d V ED STATE OF ALASKA IUi 3 1 415 ALASKA OIL AND GAS CONSERVATION COMMISSION PTS 8 /!5 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request' Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q • Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑tip'' Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well [ ' Re-enter Susp Well ❑ Other. Change-out ESP 0 2.Operator Name. 4.Current Well Class: 5 Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q• 201-117 ' 3.AddressStratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-733-20254-01 ' 7. If perforating 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay Unit/K-18RD 9 Property Designation(Lease Number): 10.Field/Pool(s). ADL0018777 • McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,540 ' 9,552 • 12,496 • 9,520 - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 369' 24" 369' 369' Surface 2,477' 13-3/8" 2,477' 2,295' 3,450 psi 1,950 psi Intermediate Production 6,740' 9-5/8" 6,740' 5,559' 8,150 psi 7,100 psi Liner 5,982' 7" 12,540' 9,552' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size Tubing Grade: Tubing MD(ft). See Attached Schematic' See Attached Schematic 3-1/2" 9.2#/L-80 10,879 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): None None 12 Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development ❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work. 8/15/2015 Commencing Operations: OIL Q d WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval' Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Ted Kramer Email tkramer@hilcorp.com Printed Name TedddK-raammeerr Title Sr. Operations Engineer Signature V ` Phone 777-8420 Date 7/31/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 5 _ `t coq Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ \ Other: 1-,ZS-60 os' &V' S CS (tSP = �',r, 1 Spacing Exception Required? Yes ❑ No LTJ Subsequent Form Required. / Zj —'.j t APPROVED BY Approved by: �� COMMISSIONER eh COMMISSION Date -6 �S aRiepRinik, v' I'� S4 1!S Submit Form and Form 10-403 Revised 5/2015 lid for 12 months from the date of approval. Attachm in Duplicate ,er er(eLf— RBDMS AUG 1 4 2015 Well Work Prognosis Well: K-1Rrd IHlcorp Ala.ka,i.i.c Application Date: 07/30/2015 Well Name: K-18rd API Number: 50-733-20254-01 Current Status: Oil Producer(SI) Leg: Leg#1 (NE corner),Slot#3 Estimated Start Date: August 15, 2015 Rig: Moncla Rig 404 Reg.Approval Req'd? _ 10-403 Date 10-403 submitted: Regulatory Contact: Juanita Lovett Permit to Drill Number: 201-117 First Call Engineer: Ted Kramer Office: (907)777-8420 Cell: (985)867-0665 Second Call Engineer: Dan Marlowe Office: (907)283-1329 Cell:(907)398-9904 AFE Number: Budgeted Cost: Brief Well Summary: The K-18rd well is an ESP producer that was completed earlier this year. This month the pump licked up for unknown reasons would not restart. The workover plan involves removing the ESP Completion, Making a bit and scraper run to tag for fill, and then run a replacement ESP on smaller tubing. Note: Casing was tested on 3-25-2015 to 1,500 psi for 30 minutes on chart,Good test. Current Bottom Hole Pressure: 3,000 psi at 9,636'ND(Mid-pert) Maximum Expected BHP: 3,600 psi @ 9,636'TVD(Mid pert—based on offset K-12RD2 in 2009) Max.Anticipated Surface Pressure:0 psi,Well will not flow based on an expected oil and water gradient of 0.437 psi/ft. '�`� Procedure: "t rz 1. Move In and Rig up Moncla 404 Pulling unit. 2. ND Wellhead, NU bop and test to 250 psi low/ 2,500 psi high according to the attached BOP Test Procedure— Attachment 01 (Note: Notify AOGCC 24 hours prior to conducting BOP test to allow them the opportunity to witness). 3. POOH with tubing and ESP completion standing back 3-1/2"tubing string. 4. PU Bit and scraper. RIH same on 3-1/2 production tubing picking up additional pipe to tag fill or PBTD @ 12,496. 5. POOH with work string laying down pipe. 6. PU 2-7/8"tubing string and stand back in the derrick. 7. MU and RIH with ESP Assembly. 8. Hang off tubing. ND BOP,NU wellhead and test. 9. Turn Well over to production 10. RDMO Moncla 404 Pulling unit. Attachments: 1. BOP Test Procedure(Including Rolling BOP Test) 2. Current Well Schematic 3. Proposed Well Schematic 4. Current Wellhead Diagram(will not change) Moncla Rig 404 BOP Test Procedure IIIlrorp,lla.kn,i.i.r. Attachment 01 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, King Salmon WO Program ®Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots,notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up ROPE b) With stack out of the test path,test choke manifold per standard procedure Moncla Rig 404 BOP Test Procedure A,,,kn,,,.,. Attachment 01 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/RPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear hushing. a) Use inverted test plug to pull wear busing. MU to 1 jt.of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross)and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. Moncla Rig 404 BOP Test Procedure �,,,,�� ,,, Attachment#1 ,,,r , d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test,open same. ii) Valves, 3,4,9. After test, open valves 3&4. Leave 9 closed. iii) Valves 5, 6,9. After test,open valves 5&6, leave 9 closed. iv) Valves,7,8,9. After test,open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in)side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW(or Lower Kelly Valve)and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer, the Pipe Rams,and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Moncla Rig 404 BOP Test Procedure 111►narp,llaaka,in: Attachment#1 Diagram A-1: King Salmon BOP stack and Riser Arrangement--Typical for Single Completion t1LIl1111111111111111111L 3.74' Sheltie 11 ARA iil iil ifi 111 !II Ill III i!I tVariable 2 7/8-5 4.6T • . �I 11 SOBD '� -:Blind Rams Jrrinthasurtitii l I ChoSe and Kdl Valves 2 1/16 SM w/Un bolt connections for ��'��j`}��( '�';,�[ hoses ►BrH(t 2.00' « `��/E I1 FY it, I I U�S000 ::J +1 LIi1Ji1111 it Ill pll! UI Irl Riser,13 5/8 SM 13(135/8 SM API 813 hub 13.70' Moncla Rig 404 BOP Test Procedure IUlenrpAla'Ma,r.Lc Attachment#1 Diagram B: King Salmon Choke Manifold To Gas Buster All National typo To Panic lino 2 1110 5M 1502 Union ball valvos iI1uii 2. 41,. +ice. 11 Chokes are 90 degrees off in drawing in order to show Idetail s •111,s -11 3 l!r 41 limo [waco l i I l. �m, II )63. .11 From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3 '/:" Ball port,6000psi working pressure #2 National Ball Valve B3260,3 'A"Ball port,6000psi working pressure #3 National Ball Valve B2650,2 9/16" Ball port,5000psi working pressure #4 National Ball Valve 82650,2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650,2.9/16" Ball port,5000psi working pressure #6 National Ball Valve B2650,2 9/16"Ball port,5000psi working pressure #7 National Ball Valve B2650,2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve 82650, 2 9/16"Ball port,5000psi working pressure #9 National Ball Valve B3260, 3'A" Ball port,6000psi working pressure #10 National Ball Valve B1560, 1 '/2'Ball port,6000psi working pressure Moncla Rig 404 BOP Test Procedure Attachment 01 1104-n1p Mad n,LLC. 2 z--(Y Ii..) I . ggt 8 vg es u.0 �._. 1 III1poi*LQ,QJ m n � r U' I A a - t•) ); w Z a O OU' F-- — ;c� �z �( U O h •L C� I-- --+•1-�-{•F C 0C� a `Co a .. W Vey A O O V 0 L J y W r= a � � � n1.4 , ozW fa L� Z n. V V II Moncla Rig 404 BOP Test Procedure Attachment#1 Hilton()A13,10,1.11.1: 3h JPU I1,1, q 71 z :::1 I, I1 I .,F--+ii d$ srt r U VC. In ria E. :. ,..,--- .--111 l I I I' _ 0C 7 'i.?- — tn Q. 6 / HO C Iz VI ug I Ik � a I Z �_� <, <� SUJ <[ L... ap �} Q o ( a z{ a - wz0 sn. — z O O m 0 0 _ D _J . F- w GW 0271 `3t'nn JOO fn u_ Z o 0 Z C D 0 CY U McArthur River Field SCHEMATIC Well: K-18RD Completed: 04/01/2015 Mewl)Alaska,LLC PTD: 201-117 RKB to Sea Level(MLW)=100' CASING DETAIL i) SIZE WT GRADE CONN ID TOP BTM. 24''_ ) , 24" 186 X-56 Weld 22.313 Surf 369' ' 44 l+ 13-3/8" 68 K-55 BTC 12.515 Surf 2477 ka , '5 %, 9-5/8" 47 S-95 BTC 8.681 Surf 6740' 4,4, V_ 7" 29 L-80 BTC-KC 1 6.184 6558' 12540' 13-W-z47 TUBING DETAIL 3-1/2" 9.2 L-80 Supermax 2.992 Surf 10,879' NO. Depth ID Item 34.85' 3.958" Tubing Hanger 1 10,879' - Discharge,Bolt-On 2 10,881' - Pump(x3)-Summit 125 Stage,SF1750 3 10,949' - Seals r_esssIP 4 10,966' Motor- Summit 456 Series ss/s'-e,7w l 5 10,996' Anode ltPERFORATION DETAIL p zP" Zone Top(MD) Btm(MD) (TVD) Btm(TVD) SPF Date l4 i GO-4 11,045' 11,061' 8,385' 8,398' 5 SPF 03/27/15 it, l41 GO-4 11,078' 11,111' 8,411' 8,437' 5 SPF 03/27/15 91:ii GO-5 11,128' 11,138' 8,450' 8,458' 5 SPF 03/27/15 G111,239' 11,322' 8,538' 8,605' S SPF 03/26/15 2 t G3 5 SPF 03/26/15 � 11,410' 11,427 8,675' 8,689' ma' GS5 SPF 03/26/15 11,590' 11,642' 8,820' 8,862' 3 G5 11,593' 11,655' 8,822' 8,872' 6SPF 4 G5 11,680' 11,710' 8,892' 8,916' 12SPF `` G5 11,648' 11,684' 8,866' 8,895' 5 SPF 03/26/15 WOES 5 `I G5 11,688' 11,708' 8,898' 8,914' 6SPF 2/23/2008 G5 11,692' 11,711' 8,902' 8,917' 5 SPF 03/26/15 ' GO G7 11,807' 11,848' 8,993' 9,025' 12SPF Benches G7 11,808' 11,848' 8,993' 9,025' 6SPF 03/26/15 1 HK1 11,848' 11,886' 9,025' 9,055' 5 SPF 03/26/15 GZone It=Benches HK1 11,878' 11,888' 9,048' 9,056' 6SPF HK2 11,917' 12,000' 9,079' 9,143' 12SPF HK-2 11,925' 12,000' 9,285' 9,143' 6SPF 2/23/2008 sHK2 11,928' 11,955' 9,087' 9,108' 5 SPF 03/26/15 HK3 12,041' 12,081' 9,175' 9,206' 12SPF '#. ..�Hemlock sP Benches HK3 5 SPF 03/26/15 Note: 12,046' 12,059' 9,179' 9,189' tx Perforation HK4 12,108' 12,131' 9,227' 9,244' 6SPF Gun Debris 7"-12,540possible @ HK5 12,224' 12,241' 9,315' 9,328' 6SPF ail'. 12,384' HK6 12,241' 12,261' 9,328' 9,343' 12SPF PBTD=12,496' TD=12,540'MAX HK7 12,261' 12,270' 9,343' 9,350' 6SPF Hole Angle=53°@ 8,761' Updated by: 1LL 04/29/15 McArthur River Field II SCHEMATIC Well: K48RD Proposed IIilcarnAlaska,HA: PTD: 201-117 RKB to Sea Level(MEW)=100' CASING DETAIL i 1,, ,I ,I SIZE WT GRADE CONN ID TOP BTM. 2.V- '4 24" 186 X-56 Weld 22.313 Surf 369' i, 7 13-3/8" 68 K-55 BTC 12.515 Surf 2477' 9-5/8" 47 S-95 BTC 8.681 Surf 6740' • > 7" 29 L-80 BTC-KC 6.184 6558' 12540' 113/8'-7,4" TUBING DETAIL 2-7/3" 6.5 I.-30 s,.;.:.1,:,r. 2,441 Surf (=r ) NO. Depth ID Item 34.85' 3.958" Tubing Hanger 1 10,879' - Discharge,Bolt-On 2 10,881' - _ Pump(x3)-Summit 125 Stage,SF1750 3 10,949' - Seals 7,_6,sss 4 10,966' .. Motor- Summit 456 Series -- 9y8 6740. 5 10,996' - Anode 'i rr ! PERFORATION DETAIL t; ;;.4 Zone Top(MD) Btm(MD) (Np) Btm(TVD) SPF Date • '; GO-4 11,045' 11,061' 8,385' 8,398' 5 SPF 03/27/15 r1 60.4 11,078' 11,111' 8,411' 8,437' 5 SPE 03/27/15 l •1 60-5 11,128' 11,138' 8,450' 8,458' 5 SPF 03/27/15 !,. - - t 615 SPF 03/26/15 11,239' 11,322' 8,538' 8,605' 2 4^ G3 11,410' 11,427' 8,675' 8,689' 5 SPF 03/26/15 r irir 1 1 3 r 65 11,590' 11,642' 8,820' 8,862' 5 SPF 03/26/15 r ! G5 11,593' 11,655' 8,822' 8,872' 6SPF RI 4 V,it 6511,680' 11,710' 8,892' 8,916' 12SPF I. 1' 5 G5 11,648' 11,684' 8,866' 8,895' 5 SPF 03/26/15 1,• yA G5 11,688' 11,708' 8,898' 8,914' 6SPF 2/23/2008 }%( 65 11,692' 11,711' 8,902' 8,917' S SPF 03/26/15 ' 3 GO G7 11,807' 11,848' 8,993' 9,025' 12SPF Benches --- G7 11,808' 11,848' 8,993. 9,025' 6SPF 03/26/15 i. HK1 11,848' 11,886' 9,025' 9,055' 5 SPF 03/26/15 i GZara j' Berthas HK1 11,878' 11,888' 9,048' 9,056' 6SPF aE (. HK2 11,917' 12,000' 9,079' 9,143' 12SPF !' ;' HK-2 11,925' 12,000' 9,285' 9,143' 6SPF 2/23/2008 HK2 11,928' 11,955' 9,087' 9,108' 5SPF 03/26/15 i f HK3 12,041' 12,081' 9,175' 9,206' 125PF Fienlock 2' *:Bcnct-s Note: HK3 12,046' 12,059' 9,179' 9,189' 5 SPF 03/26/15 �; Perforation HK4 12,108' 12,131' 9,227' 9,244' 6SPF I.I%i . Gun Debris 7'-12,540' 1 )i possible @ HK5 12,224' 12,241' 9,315' 9,328' 6SPF l'i�htl'(i:�f.S%/Si V- 12,384' HK6 12,241' 12,261' 9,328' 9,343' 12SPF ..��a-L:11-�,..� � PBTD=12,496' TD=12,540'MAX HK7 12,261' 12,270' 9,343' 9,350' 6SPF Hole Angle=53'@ 8,761' Updated by: 111 04/29/15 • King Salmon Platform H K-18RD Current 7/30/15 PTI)201-117 11111-nrp Alndru,1,1.1. King Salmon Tubing hanger,FMC-TC-BEC, K-18RD 13 5/8 X 3 Y TC-2 lift and 13 3/8 X 9 5/8 X 3 1/2 susp,w/3"type if BPV profile,300-4 pkt,2-CCt, 3,266'centers,Alloy material BHTA,Bowen,31/8 SM X 2 SS Bowen Union 11 1.1 Valve,Swab,WKM-M, ni it 3 1/8 5M FE,tiWO,OD trim m®, 1 . ' O I) m e Valve,SW,WKM-M, L 3 1/8 SM FE,Omni open, EE trim Valve,Wing,WKMDM, 3:(. .4:0�0)0�I •31/8 SM FE,HW0,DD trim0 i 110111, Valve,Master,WKM-M, �t'';10' Q 31/8SM FE,HWO,OD trim ', 00 Adapter,FMC A-5-EC, 13 5/8 5M rot 1Ig btmX X2 3 1/8 5M stdd top,w/300.4 .-,•:,,i,.I f; pkt,w/2-CCI,prepped 1/ 3 BIW penetrator,3.266 Tubing head,FMC-OBS, �I �e i centers 13 5/8 SM Stdd buttons x gri' ■ _`1 I 135/8SM FE,w/2-3 1/8 5M �l� fr� 550,IP style lockpins =B 1�� ■ �_BI.■3 ISI , ISI O 6;11 ( '1)1111 illtir,•;4'111hil 111 i•- ik, 'ii- tri. • Casing head,F MC-0E15, .- All casing valves 3 1/8 SM 13 5/8 5M FE X 13 3/8 SOW, OCT-20 w/2-3 1/8 SM 550,IP style :a +�IMF a= lockpins lel I A IiI .s!"-;OF T� 6,4i 77,cs, THE STATE Alaska Oil and Gas ofALAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907.279 1433 01"ALAS Fax 907 276 7542 www.aogcc alaska gov June 19, 2015 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 K-18RD scol4E0 JUN 2 6 2015 PTD 2011170 Dear Mr. Golis: On April 14, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit K-18RD located on the King Salmon 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 K-18RD prior to the test. The well performance was monitored for 3 hours with resulting flow rates (oil and gas) below the regulatory limits, passing the no-flow test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit K-18RD 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 King Salmon Platform. Sincerely, Jti . rec James B. Regg l( Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg )(The1 i IRi�S DATE: 4/14/2015 P. I. Supervisor FROM: Johnnie Hill SUBJECT: No Flow Test Petroleum Inspector TBU K-18RD Hilcorp Alaska LLC PTD 2011170 4/14/2015: I traveled to the King Salmon platform located in the Trading Bay Unit (offshore Cook Inlet) to witness a no flow test. The well was recently worked over to add perforations. I found the test equipment rigged up to the tree cap as follows: a 1/2-inch by %-inch by 1-inch flow tee (0-30psi calibrated pressure gauge installed on the tee) to a 1-inch ball valve. Downstream of the ball valve was a calibrated no-flow test meter with the meter outlet plumbed to a bleed bucket through a 1-inch hose. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:45 0/0/0 0 0 closed 11:15 0.5/0/0 0 0 closed 11:45 1.0/0/0 1200 0 gas/bleed for 6 min & stop 12:15 0.2/0/0 0 0 verry little 12:45 0.1/0/0 0 0 Dead 13:15 0/0/0 0 0 Dead 13:45 0/0/0 0 0 Dead 1 Pressures are T/IA/OA Summary: The TBU K-18RD test was one of the best examples I have witnessed of a no-flow designation. Attachments: Test Pressure Gauge Calibration • Flow Meter Calibration SCANNED JUL 0 2 2015 2015-0414_No-Flow_TBU K-18RD_jh.docx Page 1 of 1 HILCORP CALIBRATION CERTIFICATE Test Equipment Traceable to NIST -1- - Gauge type: Pressure range: — 9, iumber: Date: v.. . :— TEST PRESSURE INDICATION ,.; - - 1 r 4‘_ • , Calibr,-,-...ted. by: , , Test equipment S/N: • - _-; This catticate expires in 90 days on For recertification, contact Gina Bogart or Cathy Marshall at KGF 776-6825_ Test Equipment Traceable to NEST Pressure range: - e.. Date: -_. P- E.ESSURE Test equipment JIN: pis ss:t7, expires in 90 days on contact Gina Bogart or Cathy Mardi li i KG1- f---`ILCORP CALIBRATION CERTIFICA -E 'lest Equipment Traceable to NIST Gauge type: Pressure range: r7:111ther: Date: TEST °RESSURE INDICATION by: -- Test equipment SIN: — - -- - This c,,r..:rca,te expires in 90 days on l-or recertificatio7., contact Gina Bogart or Cathy Marshall at KGF 776-6825. • d w N c H 2 E . E aE0 = I- c oma aC `i° yzvn _ 0., �.1 N• = «. c .� o c �, d2a) >.o ° I. 0. 0co N ... cc C to 3 " o U � I Cj moo ° co ° ° °_' � �� o +r "' •p 'C w • t b •L O c 0 It u. ,�• ,� � � � �, � _ �,`1E Via , �' i�o � •i4 N E el aN eco �VI �p „` z 0pwH : To- U c t1 :- i-' ci) U di1Di yA to▪ 'amid -' cEd \ \ c ; .., Y riMkeiMIVCIJ STATE OF ALASKA /\P R 3 0 2015 AL __KA OIL AND GAS CONSERVATION COM. JSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate❑r Other❑� Install ESP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development E Exploratory❑ 201-117 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20254-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018777 Trading Bay Unit/K-18RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,540 feet Plugs measured N/A feet true vertical 9,552 feet Junk measured N/A feet Effective Depth measured 12,496 feet Packer measured N/A feet true vertical 9,520 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 369' 24" 369' 369' Surface 2,477' 13-3/8" 2,477' 2,295' 3,450 psi 1,950 psi Intermediate Production 6,740' 9-5/8" 6,740' 5,559' 8,150 psi 7,100 psi Liner 5,982' 7" 12,540' 9,552' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet scANNED MAY 2 0 2015 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 10,879'(MD) 8,256'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure • Prior to well operation: 0 0 0 155 418 Subsequent to operation: 167 45 620 63 57 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development LI Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil E Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-231 &315-132 Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature �� Phone (907)777-8420 Date 4/30/2015 54 ? l3 RBDMSV MAY - 6 2015 Form 10-404 Revised 10/2012 � S bmit Original Only McArthur River Field SCHEMATIC well: K-18RD Completed: 04/01/2015 Hilcorp Alaska,LLC PTD: 201-117 RKB to Sea Level(MLW)=lar - - _ CASING DETAIL i. 'sA '' 4 SIZE WT GRADE CONN ID TOP BTM. za_ s r ?. 24" 186 X-56 Weld 22.313 Surf 369' '4 13-3/8" 68 K-55 BTC 12.515 Surf 2477' s . 9-5/8" 47 5-95 BTC 8.681 Surf 6740' 7" 29 L-80 BTC-KC 6.184 6558' 12540' 13-3/8"-2477 TUBING DETAIL 3-1/2" 9.2 L-80 Supermax 2.992 Surf 10,879' NO. _ Depth _ ID Item 34.85' 3.958" Tubing Hanger 1 10,879' - Discharge,Bolt-On 2 10,881' - Pump(x3)-Summit 125 Stage,SF1750 3 _ 10,949' _ - Seals _ T 4 10,966' Motor- Summit 456 Series gs,g, Ca740' ". 5 10,996' - Anode I y4,11 � 0 1..14 PERFORATION DETAIL * k4;, Top .-, i-a Zone Top(MD) Btm(MD) Btm(ND) SPF Date ND 0 4. GO-4 11,045' 11,061' 8,385' 8,398' 5 SPF 03/27/15 1 GO-4 11,078' 11,111' 8,411' 8,437' 5 SPF 03/27/15 ;� GO-5 11,128' 11,138' 8,450' 8,458' 5 SPF 03/27/15 1 G1 11,239' 11,322' 8,538' 8,605' 5 SPF 03/26/15 r G3 11,410' 11,427' 8,675' 8,689' 5 SPF 03/26/15 Int: ,4. _` 4', G5 11,590' 11,642' 8,820' 8,862' 5 SPF 03/26/15 i.' 3 >�, G5 11,593' 11,655' 8,822' 8,872' 6SPF 14 11, 4 t" G5 11,680' 11,710' 8,892' 8,916' 12SPF 5 4" G5 11,648' 11,684' 8,866' 8,895' 5 SPF 03/26/15 y+' t,,? � G5 11,688' 11,708' 8,898' 8,914' 6SPF 2/23/2008 't • G5 11,692' 11,711' 8,902' 8,917' 5 SPF 03/26/15 itii aile GO G7 11,807' 11,848' 8,993' 9,025' 12SPF ,.. 4., Berxfies G7 11,808' 11,848' 8,993' 9,025' 6SPF 03/26/15 i HK1 11,848' 11,886' 9,025' 9,055' S SPF 03/26/15 IA E G Zaie - .1 Bandies HK1 11,878' 11,888' 9,048' 9,056' 6SPF HK2 11,917' 12,000' 9,079' 9,143' 12SPF l r, HK-2 11,925' 12,000' 9,285' 9,143' 6SPF 2/23/2008 HK2 5 SPF 03/26/15 i� 11,928' 11,955' 9,087' 9,108' HK3 12,041' 12,081' 9,175' 9,206' 12SPF : Herr1odc i' HK3 5 SPF 03/26/15 Note: 12,046' 12,059' 9,179' 9,189' < '41 Perforation HK4 12,108' 12,131' 9,227' 9,244' 6SPF +: 4 Gun Debris 7'-izsaa possible @ HK5 12,224' 12,241' 9,315' 9,328' 6SPF __ _!p'" , 12,384' HK6 12,241' 12,261' 9,328' 9,343' 12SPF PBTD=12,496' TD=12,540'MAX HK7 12,261' 12,270' 9,343' 9,350' 6SPF Hole Angle=53°@ 8,761' Updated by: JLL 04/29/15 Hilcorp Alaska, LLC _1Lt-Li.1.1.1. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-18RD 50-733-20254-01 201-117 3/14/2015 4/1/2015 Daily Operations: 03/14/15-Saturday PTSM WITH PRODUCTION,CRANE AND RIG CREW.CONTINUED PREPARING FOR RIG AUDIT AND WITNESSED BOPE TEST BY MR.LOU GRIMALDI w/AOGCC. MR.GRIMALDI ON BOARD AT 0830 HRS. WALKED THRU MONCLA 404 WORKOVER SETUP AND RECEIVED PERMISSION TO CONTINUE ON WITH K-18RD WORKOVER OPERATION. INSTALLED 4 1/2" BUTTRESS TEST JT W/XO,SAFETY VALVE& IBOP ON TOP. BLANK PORTED SUB ON BTM.SCREWED INTO 4 1/2"BUTTRESS HANGER. FILLED STACK.CLOSED ANNULAR AND BEGAN WITNESSED BOPE TEST TO 250#S LOW/2500#S HIGH AS PER HILCORP AND AOGCC REQUIREMENTS.COMPLETED 8 TESTS INCLUDING ACCUMULATOR DRAW DONE SUCCESSFUL. PULLED 4 1/2"TEST. ATTEMPTED TO REMOVE BPV AND HAD PRESSURE UNDER VALVE.CLOSED BLINDS AND BEGAN PUMPING AT 1 BPM 0 PSI.AT 15 BBLS AWAY PRESSURE INCREASED TO 1000#s. BLED OFF PRESSURE AND OPENED BLINDS.ATTEMPTED TO PUMP INTO STACK AND PRESSURED UP AGAIN. BEGAN SEARCHING AND FOUND ICE PLUG IN HOSE BETWEEN CIRC MANIFOLD AND KILL VALVES. BLED DOWN WELL THRU BPV WHILE CLEARING LINES.PULLED BPV. INSTALLED 2-WAY CHECK AND FILLED STACK.BEGAN TESTING BLINDS.FAILED TEST.FOUND LEAK AT UNIBOLT CONNECTION (TWICE) AND NEEDLE VALVE AT TEST MANIFOLD.REPAIRED SAME.BAKED OUT 2-WAY CHECK TO INSURE PRESSURE WAS NOT BUILDING. REINSTALLED 2-WAY AND ATTEMPTED TO TEST AGAIN. HIGH PRESSURE LEAK AT HCR.REARRANGED TEST PATH IN EFFORTS TO TEST BLINDS.FAILED. COULD NOT FIND LEAK. DECISION WAS MADE TO REPLACE HCR AND REALIGN TO ORIGINAL TEST PATH. MR. GRIMALDI LEFT INSTRUCTIONS TO COMPLETE TESTING AND NOTIFY HIM OF RESULTS.HE DEPARTED LOCATION AT MIDNIGHT. 03/15/15-Sunday PTSM WITH PRODUCTION,CRANE AND RIG CREWS. FINISHED TESTING BOPE W/3 1/2"&4 1/2"TB 250#S LOW/2500#S HIGH AS PER HILCORP&AOGCC REQUIREMENTS. NOTIFIED MR.GRIMALDI/AOGCC OF TEST COMPLETIi3N 7ND RESULTS.RECEIVED PREMISSION TO CONTINUE FORWARD WITH WORKOVER OPERATIONS. HELD PJSM WITH RIG AND E/L CREW. R/U E/L W/FULL LUBRICATOR.BUILT TOOL STRING(1 3/8"ROPE SOCKET,2-1 11/16"WT BARS,CCL,XO,SPANG JAR,XO,2.70"GAUGE)AND PULLED INSIDE LUBRICATOR.M/U TO STRING AND TEST LUB TO 1000#S. TIH TO 10,790'WITH NO TROUBLE.SOLID SETDOWN,CLEAN PICKUP. WORKED TOOL BUT COULD NOT GET DEEPER. POOH. B/O 2.70"GAUGE AND M/U 2.56"GAUGE.TIH TO 10,790'WITH SAME RESULTS.COULD NOT GET DEEPER. POOH. RIGGED E/L TO SIDE.SET NIGHT CAP IN PLACE. PUMPED DOWN TB IN EFFORTS TO PUSH OBSTRUCTION AWAY.PRESSURED UP TO 500#S AFTER 11 BBLS. PUMPED ANOTHER 10 BBLS. SHUTDOWN PUMP AND FLOWED BACK 10 BBLS. M/U 2 1/8"CCL AND PULLED INSIDE LUBRICATOR. M/U TO STRING.TIH TO 10,790'(SAME AS PREVIOUS DEPTH.COULD NOT GET DEEPER). POOH. RIGGED E/L TO SIDE AND LATCHED ONTO PIPE.CHECKED CASING PRESSURE AND BACKED OUT HOLDDOWN PINS.P/U ON STRING AND HANGER MOVED AT 114K.CONTINUED PICKING UP TO 140K.SET SLIPS AND CLOSED ANNULAR.FILLED BACKSIDE WITH 22 BBLS. P/U LUBRICATOR AND M/U 2.70"CERAMIC BTM JET CUTTER.PULLED INSIDE LUBRICATOR AND M/U TO STRING.TIH TO 10,790'(TIEING INTO GLM @ 10,346'). SETUP TO MAKE CUT AT 10,760'(MID JT).W/20K OVERPULL.ATTEMPTED TO FIRE CUTTER BUT NO FIRE. POOH AND REARMED. RIGGED E/L TO SIDE AND PICKED UP ON STRING 5'TO VERIFY CUT. 03/16/15-Monday PTSM WITH PRODUCTION,CRANE&RIG CREWS. RIGGED DOWN E/L EQUIPMENT. LINED UP TO PUMP TO TRADING BAY AND WAITED ON PRODUCTION AND TBF CHANGE OUT. ONCE OK WAS GIVEN TO PUMP WE CIRCULATED 1100 BBLS FIW AT 1-2 BPM 200 PSI-RATES STIPULATED BY PRODUCTION PERSONNEL. STOPPED CIRC,CHECKED FOR FLOW AND R/D LINES.REMOVED FLOOR SECTION AND N/D 11"X 13 5/8"ADAPTER SPOOL.N/U 13 5/8"SPACER SPOOL.ATTEMPTED TO PULL TBG HANGER THRU ANNULAR BUT ELEMENT WAS NOT RELAXED.PUT TRUNK LINES ON ELEMENT UNTIL IT HAD OPENED FULLY. PREPARED SSSV LINE AND B/O TBG HANGER. LAID DOWN 8 JTS 4 1/2" BUTTRESS PRODUCTION TBG+HARDWARE TO SSSV USING ABSORBENT PADS IN ATTEMPTS TO CLEAN ROUGH OILY SCALE OFF PIPE. DECISION WAS MADE TO CIRC IN REVERSE AT HIGH RATE IN ATTEMPTS TO CLEAN OD OF TBG. CLOSED PIPE RAMS AND CIRC 260 BBLS AT 4 BPM 100#S PSI. MODIFIED 3 1/2"STRIPPING RUBBER TO USE ON 4 1/2"TBG. CONTINUED PULLING OOH WITH PRODUCTION STRING STRAPPING SAME AND BUNDLING. 30 JTS OOH AT PRESENT. Hilcorp Alaska, LLC HBcorp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-18RD 50-733-20254-01 201-117 3/14/2015 4/1/2015 Daily Operations: 03/17/15-Tuesday PTSM W/PRODUCTION,CRANE&RIG CREW.CONTINUED LAYING DOWN 4 1/2"BUTTRESS PRODUCTION STRING AND HARDWARE. PUMPING DISPLACEMENT EVERY 30 JTS,FOUND HOLE AT^ 3,235',PLUS SEVERAL SHALLOW WASHS.CLEANED PIPE WITH ABSORBENT PADS AND STRIPPING RUBBER. STOPPED PULLLING TO CIRC LONG WAY INORDER TO FLUSH OIL AROUND.PUMPED 90 BBLS AT 2 BPM 100 PSI. CONTINUED PULLING/LAYING DOWN RECOVERED PRODUCTION STRING. STOPPED PULLING AND SECURED WELL DUE TO BACKUP OF PIPE ON DECK.WORKED BOAT OFFLOADING FLYING PIPE RACKS.LOADING RECOVERED PRODUCTION STRING THEN BACK LOADING SAME.PULLED PRODUCTION STRING TO 4 1/2"X 3 1/2"X-OVER.WHILE ATTEMPTING TO LOWER PIPE BACK IN HOLE 4 1/2"SLIPS CAUGHT ON X-OVER AND BROKE SEGMENT OFF AIR SLIPS.DROPPING ONE SLIP SEGMENT IN HOLE. PUT 3 1/2"INSERTS IN SLIPS AND BROKE OFF LAST JOINT OF 4 1/2"TBG.SECURED WELL. INVESTIGATED CAUSE.CONTINUED POOH WITH RECOVERED PRODUCTION STRING.HAD TO STOP AND CIRCULATE OIL OUT AT 1700 HRS. E/L CALLED TO ASSIST IN RECOVERING SLIP SEGMENT DROPPED IN HOLE. 03/18/15-Wednesday PTSM W/PRODUCTION,CRANE&RIG CREWS. SERVICED RIG.CONTINUED POOH WITH 3 1/2"PRODUCTION STRING FILLLING HOLE EVERY 30 JTS. ALL JTS AND HARDWARE ACCOUNTED FOR.RECOVERY DEPTH=10,756'. ELINE EQUIPMENT ONBOARD AT 1000 HRS. CLEAR AND CLEAN RIG FLOOR AND CATWALK. R/U E/L EQUIPMENT WITH LUBRICATOR.M/U 4 1/2"MAGNET,CENT,SPANG JAR,XO, 3 1/8"CCL,CENT,1-1 11/16"WT BAR,ROPE SOCKET. TIH TO TOP OF LINER AT 6,558'AND SET DOWN.WORKED TOOL SLIGHTLY AND POOH. RECOVERED SLIP SEGMENT AND BROKEN BOLT. R/D/E/L. M/U BHA#1(5 3/4"HOLLOW MILL GUIDE DRESSED F/3 1/2",5 3/4"LOWER EXT,5 3/4"BOWL LDD W/MCP+3 1/2"BASKET GRAPPLE,5 3/4"x 2 3/4"TOP SUB,4 3/4"x 2 1/4"BUMPER JAR,4 3/4"x 2 1/4"OIL JAR,4 3/4"x 2 1/4"DRILL COLLARS x 6,4 3/4"x 2 1/4"ACC JAR,4 7/8"x 2 1/4"X-OVER). BEGAN P/U 3 1/2"12.95#P110 PH-6 WORKSTRING OFF DECK STRAPPING&RABBITING SAME. 112 JTS+BHA IN HOLE AT REPORT TIME=3,686'. 03/19/15-Thursday SERVICED AND FUELED WORKOVER EQUIPMENT. CONTINUED TIH W/BHA#1(OVS/JARRING ASSM=228.01')PICKING 3 1/2"PH6 WORKSTRING OFF DECK. R/u swivel to dress off top of fish. 90k p/u rotating weight 76k s/o rotating weight.Tag tof @10,750'unable to keeping rotating due to torque 8000 ft/lbs.Decided to r/u halls head to circulate while rotating. Break circ,60 bbls to fill,pumping 2 bbls/min @ 300 psi 7800 ft/#torque having to continue working tubing to keep rotating.CFS50 on board and added to system. Began pumping same downhole. 03/20/15-Friday Serviced rig. Rig crew added CFS 520 to active tank. Began circulating down tbg at 3 BPM 300 PSI to get friction reducer in place. Once CFS 520 made turn(2240 stks)we began attempting to rotate tbg with power swivel.At 8,224 stks we could rotate at 7500 FPT. Dressed off TOF at 10,750'(PM)and latched same. Broke off/laid down power swivel.Latched onto string and tied elevators. Worked pipe from 60k to 130k three times tripping jars each time,started hitting jars at 150k then pulling to 170k.Second time we pulled to 170k packer sheared. Slacked off 15'then pulled up 30'to connection.Broke off single and installed valve. Lined up to pump down casing. Began circulating in reverse at 1.3 BPM 700#s PSI. Circulated two tbg volumes,minimal gas at btms up,stopped pumping and checked for flow,none. Began POOH slowly,filling backside every 20 stands.Fill-up's were not right,started pumping down tbg displacement plus.Well U tubing up ws circulate well out.No flow on ws,continue pooh. 85k p/u weight pulled up to 102k coming out of liner,fell to 68 k p/u weight.R/d halls head and continue pooh with fish. Change out Knight tongs with Moncla's tongs due to sheared bolts. Continue B/D BHA assembly. B/D L/0 remaining production tbg plus Baker FHL pkr and assem. Hilcorp Alaska, LLC Hilcorp Alaska,LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-18RD 50-733-20254-01 201-117 3/14/2015 4/1/2015 Dalt Options: : 03/21/15-Saturday Serviced workover equipment.Strapped recovery.Cleared and cleaned rig floor and catwalk. M/U BHA#2(8 1/2"rock bit,casing scraper f/9 5/8",bit sub)on 3 1/2"12.95#P110 PH6 workstring. TIH to 6,514'&checked weights. 47k 5/0 58k P/U. M/U stand#106 and tagged top of liner at 6,559'(PM). P/U to 6,545'and B/O single.R/U to transfer fluid to TBPF+flush—50 bbls of oil out of rig tanks. Pumped 500 bbls around sending returns to TBPF at 2.5 BPM 600 PSI.Drained oil in active and shaker tanks to production holding tank. Stopped circulating and B/O lines. POOH w/BHA#2(9 5/8"cleanout run). Ooh with BHA#2.Clean and clear rig floor. M/u xover subs on test plug. M/u BHA#3 6.00"Bladed mill,bumper/oil jars,6-4-3/4"drill collars,Acc jars,xover=218.94'. TIH and tag top of liner at 6,559'.P/u turn 3 rounds and mill went through.Continue TIH 7,720'.R/d x-over spool above annular.M/u test plug and land same. 03/22/15-Sunday PTSM with production,crane&rig crews. Serviced workover equipment. Landed test plug and M/U pumping,safety valve and IBOP to test jt. Filled stack and closed Hydril. Lined up to test. Tested BOPE following Moncla 404 procedure to 250#s low 2500#s high using remote actuator as per Hilcorp&AOGCC requirements. Witness of test was waived by Jim Regg,AOGCC.Gas alarms test by production personnel. Screwed back into test plug.B/O pumping,safety valve and IBOP and pulled test plug.Laid down same. N/U 11"adapter flange. Continued in hole with BHA#3(7"clean out assem)to 10,691'(169 stands). Moved all needed singles to catwalk, swivel and Hall's Head adapter flange near catwalk because East crane was being shut down. Began strapping and rabbiting singles in hole. 121k p/u weight,66k s/o weight.Tag 12,421',R/u halls head and swivel. Start washing,reversing @ 2bbls/min @ 480 psi from 12,421'to 12,427'tagging hard.Circ btm up.Lots of paraffin in returns.Plugged up at low-torque at shakers.Work valve,all clear, continue circulating till clean returns. R/d swivel and pooh to install 7"scraper. 42 stds ooh=9,880'in well. 03/23/15-Monday PTSM w/production,crane and rig crew. Serviced workover equipment.POOH leaving BHA+15 stands in hole(1,144.03'). M/U BHA #4(added 4 3/4"x 2"X-over,4 3/4"x 1 9/16"X-over,5 1/4"casing scraper,4 13/16"x 2 1/2"X-over,4 7/8"x 2 1/2"X-over=219.93'). TIH to 12,414'(122k P/U 62 5/0)(scraper at 11,279'). R/U lines to push fluid to TBPF. Begin circulating to TBPF 2bbls/min @ 600 psi- pumped total of 720 bbls. R/D lines.L/D 33 singles,then POOH standing back in derrick.74 stands OOH. 03/24/15-Tuesday PTSM w/production,crane and rig crew30 hrs). Serviced workover equipment. Continued pulling OOH w/mill/scraper assem. Broke off scraper and continued pulling to BHA. B/D BHA-laying down DCs and jars. M/U RTTS pkr f/7"29#casing on 3 1/2"12.95#P110 PH6 workstring. TIH to 11,013'(177 std+1-single)103k P/U 56k S/0.Set RTTS with 25k down. Filled annulus and closed pipe rams, pressured up to 1500 psi.Released pressure and fixed leaks on 2 hanger hold down pins. Pressured up annulus to 1500 psi&held for 30 mins on chart.Good test and bleed down same. Drained stack. N/D and reposition casing valve as per production personnel request. Filled stack and retested,good.Bled off pressure. Drains overflowed FIW on top deck.Cleaned area before POOH. Released RTTS. Pulling OOH. 52 of 174 stands OOH. 03/25/15-Wednesday PTSM w/production,crane&rig crew. Serviced workover equipment. POOH w/RTTS tool. Well control drill held at 0900 hrs. B/D L/O tools. Filled hole w/FIW. Cleared and cleaned floor. Held PJSM with TCP,crane and rig crew covering M/U and running of guns. M/U TCP assembly to perf as per procedure.Added intervals GO4&5 will be perfed by EL. TIH w/TCP assm(drifting pipe)at 2 stands per min on 3 1/2"PH-6 workstring to 12,011'. Hilcorp Alaska, LLC IIileorp:Uaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-18RD 50-733-20254-01 201-117 3/14/2015 4/1/2015 Daily Operations: 03/26/15-Thursday PTSM held w/production,crane and rig crew. Serviced workover equipment. Spaced out TCP assembly to be 3'deep. Filled hole w/FIW. R/U EL w/full lubricator. M/U GR/CCL and pulled inside lubricator.M/U to string and tested lubricator to 1500#s. TIH to 11,180',pulled correlation strip and determined that guns were 6'deep. POOH and R/D EL. Marked pipe and pulled uphole 6'.Broke off pup and M/U safety valve w/pumping.Dropped bar-5 mins 33 secs to detonation,perforating 12,046'-12,059',11,928'-11,955', 11,848'-11,886',11,808'-11,848',11,692'-11,711',11,648'-11,684',11,590'-11,642',11,410'-11,427',11,239'-11,322' w/4 1/2" EHC Idd w/4039 Razor XDP 39.0 grm chrg 5 SPF 60 degree phase(.42 EH 62.90"). Monitored fluid level for 30 min. Opened well& pulled OOH laying down 30jts of 3 1/2"PH6 workstring. Circulated in reverse 120 bbls @ 3 BPM 600 PSI. Monitored well for 15 mins. No flow. POOH laying down 3 1/2"PH-6 workstring to TCP assembly,filling hole every 20 jts. Held well control drill with night crew. 33 seconds to secure well. B/D L/O TCP assembly.PJSM with Expro,crane and rig crew on laying down shot guns. 03/27/15-Friday PTSM w/production,crane and rig crew.Finished POOH w/TCP assembly. Cleared and cleaned rig floor of gun debris and well fluid. R/U EL.N/U 7 1/16"5M adapter to lubricator knockup.Held PJSM w/Expro rep,Pollard EL,production and rig crews.Explosive safety checklist will be followed. M/U 1st run and pulled inside lubricator.Tested same to 1500#s. Opened well. Run#1 TIH w/GR/CCL+ 10'4 1/2"EHC Idd 5 SPF 60 degree phase w/4039 Razor XDP 39.0 grm HMX chrg(.44 EH 62.90"Pen)to 11,270'.Pulled correlation strip and positioned top shot at 11,128'.Perf'd 11,128-38'(GO 5 Zone). POOH and laid down shot gun.All shots fired.M/U next gun and pull inside lubricator. On&off radio silence. Run#2 TIH w/GR/CCL+15' 4 1/2"EHC Idd as previous gun to 11,270'.Pulled correlation strip and perf'd 11,097-11,111'(G04 Zone). POOH and laid down shot gun.All shots fired.M/U next gun and pulled inside lubricator. On&off radio silence. Run#3 TIH w/GR/CCL+15' 4 1/2"EHC Idd as previous gun to 11,270'.Pulled correlation strip and perf'd 11,083-11,097'(G04 Zone). POOH and laid down shot gun.All shots fired.M/U next gun and pulled inside lubricator. On&off radio silence. Run#4 TIH w/GR/CCL+6' 4 1/2"EHC Idd as previous gun to 11,270'.Pulled correlation strip and perf'd 11,078- 11,083'(G04 Zone). POOH and laid down shot gun.All shots fired.M/U next gun and pulled inside lubricator. On&off radio silence. Run#5 TIH w/GR/CCL+6' 4 1/2"EHC Idd as previous gun to 11,270'.Pulled correlation strip and perf'd 11,051'-11,061'(G04 Zone). POOH and laid down shot gun.All shots fired.M/U next gun and pulled inside lubricator. On&off radio silence. Run#6 TIH w/ GR/CCL+6' 4 1/2"EHC Idd as previous gun to 11,270'-pulled correlation strip and perf'd 11,045-11,051'(G04 Zone). POOH and laid down shot gun.All shots fired.On&off radio silence. R/d e/line.Prepare equipment for backload.Clean and clear rig floor. M/u half m/s to 3-1/2 Supermax completion tubing.Continue TIH with tubing torqueing connection to 2000 ft/#.Drifting and tallying while TIH. Fill well due to gas at surface(30 bbls). Fill well due to gas at surface(31 bbls).Hold BOP drill 35 seconds. Continue TIH with tubing- at—3300'decision was made to POOH racking prod tb back to P/U test plug. 03/28/15-Saturday PTSM held w/production,crane and rig crews. Serviced workover equipment. POOH with 50 stands of new 3 1/2"9.2#SuperMax production string racking back in derrick. N/D 11"x 13 3/8"adapter spool and landed test plug on 3 1/2"tbg. Filled stack and lined up to test.Tested all BOPE to 250#s low/2500#s high+accum draw down test as per Hilcorp and AOGCC requirements following Moncla 404 test procedure. Witness of test waived by Jim Regg,AOGCC.Pulled test plug and N/U 11"x 13 3/8"adapter spool. Continued running 3 1/2"9.2#SuperMax prod string in hole as needed to ESP depth. 232 joints in well 7,750'pooh in stands total depth 11,000'.Held BOP Drill with night crew(69 seconds due to crew being on catwalk). Spot/R/U equipment in preparation to run ESP assm. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-18RD 50-733-20254-01 201-117 3/14/2015 4/1/2015 Daily Operations. 03/29/15-Sunday PTSM w/production,crane,rig&Summit crews. Serviced workover equipment. P/U Summit 4.5"motor/gauge/anode section and filled with oil.M/U seal sections w/gas separator/intake and 1st pump.Hung sheaves in derrick and pulled assm up to attach all lines. Took readings(intake pressure/PSI-21.0,intake temp/F-65.0,discharge press/PSI-32.7,motor temp/F-69.5,vibration x G-.16,line voltage-33.3,vibration y G-1.11,current leakage-.22,phase to phase,2.0). Purged seals sections w/oil and M/U remainder of ESP assm. TIH w/ESP assm on 3 1/2"9.2#SuperMax production tb testing motor every 1,000'. Installed cable clamps every connection for 1st 10 stands then every other connection from there on. Change out spoolers and make splice @ 5,250'.Reading of test:Press Intake:1817.7psi,Temp Intake:105.3F,Press Disch: 1827.2,Temp Motor:110.2F,Vibration X G:0.61,Line Voltage:36.2,Vibration Y G:0.08,Current Leakage:5.70,Phase to Phase:4.2,Phase to Ground:2.41. Continue TIH with ESP assembly installing Cannon clamps every other connection and testing cable every 1,000'. 2nd splice made at 8,938'. 03/30/15-Monday PTSM w/production,crane&rigs crews.Serviced workover equipment while Summit built 2nd splice at 264 jts in(@ 2,313'when landed). Continued TIH w/ESP assembly on new 3 1/2"9.2#SuperMax tb drifting and torqueing to 2200 ft/lbs to 326 jts in+BHA= 10,959'. N/D 11"x 13 5/8"adapter spool.M/U FMC-TC-B-EC 13 5/8"x 3 1/2"TC2 box x box hanger and plumb 2-chem lines and motor lead. Check readings on motor. Open casing valve and landed hanger 120k p/u,80k s/o. 326 total joint in well.192 total Cannon Clamps.Ran in hold down pins. N/d landing joints.R/d wind walls,stairs,tarps and rig floor. N/d annular,double gate,flow cross with hcr,13-5/8"riser. Clean wellhead and penetrator.Lower wellhead and rn/u same.M/u surface safety and choke valve. Line up welder to make adjustments. 03/31/15-Tuesday PTSM w/production,crane&rig crews.Serviced workover equipment. Continued R/D Moncla 404 workover equipment while production assembled K-18RD tree.Fabricating flow and equalization lines and wiring in motor lead.Tested hanger void 5 min @ 500#s 15 mins @ 5000#s. Slipped&cut 75'of drill line. Pull BPV and install 2-way check and pressure up to 3000 psi for 10 mins. Good Test. Turn well over to production and continue clean and moving equipment. Having issue currently with the drives/reactor on K-18RD ESP System on surface,everything checks fine downhole. 04/01/15-Wednesday PTSM w/production,crane&rig crews. Continue preparing Moncla 404 for transfer to Bruce platform.Continue prepping equipment for demobe.Rig released from K-18 @ 1600 hrs. Turn over to Production. of Tb I//j,'sr THE STATE Alaska Oil and Gas ofALASK.A Conservation Commission t #} t ;_ _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 LASV").- \;;�r, „ % , Fax 907.276.7542 G � ' www.aogcc.alaska.gov Ted Kramer Sr. Operations Engineer !� Hilcorp Alaska, LLC a 0 I I 1 / 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-18RD Sundry Number: 315-132 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this /2 day of March, 2015 Encl. • RECEIVED • STATE OF ALASKA MAR 1 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate 0• Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ After Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC , Exploratory ❑ Development 0 . 201-117 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. I Anchorage,AK 99503 50-733-20254-01 , 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 El 1 Trading Bay Unit!K-18RD 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL0018777• McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools • I 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 1 12,540• 9,552- 12,496 - 9,520 • N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 369' 24" 369' 369' Surface 2,477' 13-3/8" 2,477' 2,295' 3,450 psi 1,950 psi Intermediate Production 6,740' 9-5/8" 6,740' 5,559' 8,150 psi 7,100 psi Liner 5,982' 7" 12,540' 9,552' 8,160 psi 7,020 psi I Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): I See Schematic., See Schematic 4-1/2"&3-1/2" 12.6#/L-80&9.2#/L-80 6,528&10,992 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Model FHL Pkr&TE-5 TR SSSV 10,926'(MD)8,292'(ND)&296'(MD)296'(TVD)• 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: 3/21/2015 Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ 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 Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer A Signature �/s (,,,'''Z�-"\._ Phone (907)777-8420 Date 3/10/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 35- 13a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test r Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Y Subsequent Form Required: /Q-104 APPROVED BY Approved by:12167 COMMISSIONER THE COMMISSION Date: d 2 -1Z -/S 3. U Submit Form and Form 10-403(Revise 012) Approved application Is vanforl g rtifrlte ofal. Attachments in Duplicate RBDMS. MAR 1 6 2015 l ,'rr(_`] II I NN AlA .3 -42.-)5 • Well Work Prognosis • Well: K-18rd Hilrmp Alaska,LLCDate: 03/10/15 Well Name: K-18rd API Number: 50-733-20254-01 Current Status: Oil Producer(SI) Leg: Leg#1 (NE corner),Slot#3 Estimated Start Date: March 21, 2015 Rig: Moncla Rig 404 Reg.Approval Req'd? 10-403 Date 10-403 submitted: Regulatory Contact: Juanita Lovett Permit to Drill Number: 201-117 First Call Engineer: Ted Kramer Office: (907)777-8420 Cell: (985)867-0665 Second Call Engineer: Dan Marlowe Office: (907) 283-1329 Cell: (907) 398-9904 AFE Number: Budgeted Cost: Brief Well Summary: Hilcorp requests a Sundry to add perforations to the above well. Perforations to be added are: GO-4 ±11,045—±11,061' (16') GO-4 ±11,078—±11,111' (33') GO-5 ±11,128—±11,138' (10') All other well work and the re-perforating of existing intervals will be performed under Approved Sundry#314-231. Current Bottom Hole Pressure: 3,000 psi at 9,636'ND(Mid-perf) Maximum Expected BHP: 3,600 psi @ 9,636'ND(Mid perf—based on offset K-12RD2 in 2009) Max.Anticipated Surface Pressure:0 psi,Well will not flow based on an expected oil and water gradient of 0.437 psi/ft. Procedure: 1. PU TCP guns and RIH with same. 2. RU E-line and Run in tubing with GR,CCL and correlate TCP guns on depth. Fire Guns. 3. Pick up guns above perforations. Shut down(+/-) 1 hour monitoring fluid level with Echometer. 4. Once the well is stable, POOH with TCP guns. 5. MU and RIH with ESP Assembly. 6. Hang off tubing. ND BOP, NU wellhead and test. 7. Turn Well over to production 8. RDMO Moncla 404 Pulling unit. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic fliMcArthur River Field • Well: K-18RD SCHEMATIC Last Completed: 08/18/01 Hilcorp Alaska,LLC PTD: 201-117 CASING DETAIL RKB to Sea Level(MLVV)=100' SIZE WT GRADE CONN ID TOP BTM. KB ' e, 24" 186 - X-56 Weld 22.313 Surf 369' t�.';� 13 3/8" 68 K-55 BTC 12.515 Surf 2477' 24" 364' - - 14i 9-5/8" 47 S-95 BTC 8.681 Surf 6740' t."4 7" 29 L-80 BTC-KC 6.184 6558' 12540' D a • TUBING DETAIL Iv 33/8' 14/1 4-1/2" 12.6 L-80 BTC 3.958 34.85' 6528' 3-1/2" 9.2 L-80 BTC 2.992 6528' 10992' D b D c _ NO. Depth ID Item 34.85' 3.958" 12"x 4-1/2"OCT Type UH-TC-1A Buttress Tubing HGR D d 1 296' 2.81" Baker TE-5 TR SSSV,PB in top of valve 7'-6,55a Ili 2 a 2413' 3.833" 4-1/2"WFD SFO-2;R2 VLV,RK Latch,w/dummy valve 9-5/8 4740 b 4134' 3.833" 4-1/2"WFD SFO-2;R2 VLV,RK Latch,w/dummy valve D e c 5478' 3.833" 4-1/2"WFD SFO-2;R2 VLV,RK q Latch,w/dummy valve 1.0 4+ d 6483' 3.833" 4-1/2"WFD SFO-2;R2 VLV,RK i' D f 1! Latch,w/dummy valve s 1 s e 7388' 2,867" 3-1/2"WFD SFO-1,R2 VLV,BK DI 9 Latch w/dummy valve f 8205' 2,867" 3-1/2"WFD SF0-1,R2 VLV,BK ' Latch w/dummy valve D h g 9023' 2.867" 3-1/2"WFD SF0-1,R2 VLV,BK Latch w/dummy valve :' I f h 9724' 2,867" 3-1/2"WFD SF0-1,R2 VLV,BK h Latch w/dummy valve +'° D I i 10645' 2,867" 3-1/2"WFD SF0-1,R2 VLV,BK Luil Latch w/dummy valve Az j 10877' 2.867 3-1/2"WFD SFO-1,R2 VLV,BK " 1 Latch w/dummy valve :" 2 Baker ZXP 7"Liner Top Packer 3 10926' 2.920" Baker 7"Model FHL Retrievable I 3Packer 4 4 10980' 2,812" Baker 3-1/2""X"Nipple w/Otis Profile at 5 5 10993' 2.992" EOT(Wireline Re-entry Guide) i, i I N GZaieBenches - PERFORATION DETAIL Zone Top Btm SPF Condition 7fr 4 G5 11,593' 11,655' 6SPF • i { ''.( 11,680' 11,710' 12SPF '!' r G5 11,688 11,708' 6SPF 2/23/2008 G7 11,807' 11,848' 12SPF i 1� G7 11,808' 11,848' 6SPF 2/23/2008 HB-1 11,878' 11,888' 6SPF Heniock HB-2 11,917' 12,000' 12SPF i' 4131Benches HK-2 11,925' 12,000' 6SPF _ 2/23/200.8_ r. " HB-3 12,041' 12,081' 12SPF 1,', 10 HK-3 12,041' 12,081' 6SPF 2/23/2008 1 1 HB-4 12,108' 12,131' 6SPF 7'-12,540' i, �I�' :1 HB-5 12,224' 12,241' 6SPF a HB-6 12,241' 12,261' 12SPF Note: HB-7 12,261' 12,270' 6SPF PBTD=12,496 TD=12,540'MAX Perforation Gun Debris possible @ 12,384' HK-5 12,241' 12,261' 6SPF 2/23/2008 Hole Angle=53'@8,761' Updated by: JLL 11/14/13 McArthur River Field . 14 PROPOSED Well: K-18RD Completed: Future Hilcorp Alaska,LLC PTD: 201-117 RKB to Sea Level(MLU)=100' B CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24'-�r r 24" 186 X-56 Weld 22.313 Surf 369' '; 13-3/8" 68 K-55 BTC 12.515 Surf 2477' ,.: 9-5/8" 47 S-95 BTC 8.681 Surf 6740' > '. 7" 29 L-80 BTC-KC 6.184 6558' 12540' tat W 13-3/8'-2,47 TUBING DETAIL 3-1/2" 9.2 L-80 Supermax Surf ±11,030' NO. Depth _ ID Item 34.85' 3.958" Tubing Hanger 1 ±11,189' Bottom of ESP r'-6sss' y1 35/8'-vas 9 ' 11 lrhy t,, i, W;t PERFORATION DETAIL 1` Zone Top(MD) Btm(MD) (TV Btm(ND) SPF Date ?' >' GO-4 ±11,045' ±11,061' ±8,385' ±8,398' Future t y7 0 GO-4 ±11,078' ±11,111' ±8,411' ±8,437' Future ;I GO-5 ±11,128' ±11,138' ±8,450' ±8,458' Future G1 ±11,239' ±11,322' ±8,538' ±8,605' Future us a r 3 G3 ±11,410' ±11,427' ±8,675' ±8,689' Future �: G5 ±11,590' ±11,642' ±8,820' ±8,862' Future illi '`' G5 11,593' 11,655' 8,822' 8,872' 6SPF 46114 6:, i'` init 41 G5 11,680' 11,710' 8,892' 8,916' 12SPF to G5 ±11,648' ±11,684' ±8,866' ±8,895' Future Amer t :iv G5 11,688' 11,708' 8,898' 8,914' 6SPF 2/23/2008 mom' 2: G5 ±11,692' ±11,711' ±8,902' ±8,917' Future G7 11,807' 11,848' 8,993' 9,025' 12SPF 1" Go tie G7 ±11,808' ±11,848' ±8,993' ±9,025' 6SPF Future/Re-perferf , HK1 ±11,848' ±11,886' ±9,025' ±9,055' Future #G3 ane HK1 11,878' 11,888' 9,048' 9,056' 6SPF ', # HK2 11,917' 12,000' 9,079' 9,143' 12SPF b HK-2 11,925' 12,000' 9,285' 9,143' 6SPF 2/23/2008 ♦+ 4 r. HK2 ±11,928' ±11,955' ±9,087' ±9,108' Future '+ i HK3 12,041' 12,081' 9,175' 9,206' 12SPF r, Henlcdt HK3 ±12,046' ±12,059' ±9,179' ±9,189' Future Benches Note: HK4 12,108' 12,131' 9,227' 9,244' 6SPF '4 Perforation 14 ;.) HK5 12,224' 12,241' 9,315' 9,328' 6SPF a Gun Debris 7'-12s4o' ' d'^ possible @ HK6 12,241' 12,261' 9,328' 9,343' 12SPF ': iieAO , 12,384' HK7 12,261' 12,270' 9,343' 9,350' 6SPF PBTD=12,496' TD=12,540'MAX Hole Angle=53`@ 8,761' Updated by: ILL 03/10/15 Ima(' Project Well History' File Covei' age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~. 0 [- 4 ~ '~ Well History File Identifier Organizing RESyi;~ Color items: DIGITAL DATA Diskettes, No. R[3"'"~~esca n Needed OVERSIZED (Scannable) [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] BY: BEVERL~~/INCENT SHERYL MARIA WINDY Project Proofing Other items scannable by large scanner OVERSIZED (Non-Scannable) ~ious kinds [] Other BY; BEVERL~INCENT SHERYL MARIA WINDY Scanning Preparation x 30 = '- TOTAL PAGES BY: BEVERL~INCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BEVERL~'~,OB.~N? VINCENT SHERYL MARIA WINDY BY: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BEVERLY O~ VINCENT SHERYL MARIA WINDY DATE/~).-~_~_~/S/~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIvIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB~'~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: /(~ FILE # ~~ « ~ ~ f ~~ a <, To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission = 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 1a' ••'`.. •h` f... .e. T Erna c 1.;1 W.., y,.. w®vaa..�.�'!�xrs®i. _ .. .. . af.mrn�aime—•.a ....._. .. w ,. .. • 333 Wes' Seventh Avenue ..., -1-------= Ancnorogc, A asrc~ 99501 3572 C�OV'1.RNoR SLAN t A_iRNIJLL ~ /c 9C7 279 'z-.73 •...9.,:, wutuk ,t �_, Ep MAY 0 7 2014, sco Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC a0 "- l I 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-18RD Sundry Number: 314-231 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1/41" P' e_t4(74, _ -/fathy . Foerster Chair 1 DATED this 22 day of April, 2014. Encl. • RECEIVED STATE OF ALASKA ;,,", i T 2S14 ALASKA OIL AND GAS CONSERVATION COMMISSION Ors 144— APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well 0 Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate 0• Pull Tubing 0. Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing 0 Other. install ESP ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC . Exploratory ❑ Development 9 . 201-117 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service 0 6.API Number: Anchorage,AK 99503 50-731120254-01 • 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 0 No 0 4 _Trading Bay Unit I K-18RD• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018777 McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,540 9,552 12,496 • 9,520 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 369' 24" 369' 369' Surface 2,477' 13-3/8" 2,477' 2,295' 3,450 psi 1,950 psi Intermediate Production 6,740' 9-5/8" 6,740' 5,559' 8,150 psi 7,100 psi Liner 5,982' 7" 12,540' 9,552' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 4-1/2"&3-1/2" 12.6#/L-80&9.2#/L-80 6,528&10,992 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Model FHL Pkr&TE-5 TR SSSV 10,926'(MD)8,292'(TVD)&296'(MD)296'(TVD) - 12.Attachments: Description Summary of Proposal 9 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/1/2014 / Oil 9 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramerta�hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature •-)/7--4,6--44-7.----1"-------- Phone (907)777-8420 Date 4/10/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S‘L-t.- 23\, Plug Integrity ❑ BOP Test MechanicalIntegrityTest D Location Clearance 0 Other: lI 2500 ere 60P —1-Zs 1- / RBDMS' MAY U 7 2014 Spacing Exception Required? Yes 0 Nod Subsequent Form Required: /O— b y APPROVED BY Approved by: P4e..4.24-1,------ _is., COMMISSIONER THE COMMISSION Date: I._ ZZ— i y 1/12' Lilliiri ;(J Submit Form and Form 10-403(Revise 10/2012) Appr aRhuIa o NI f 1 months from the date of a Tov�! Attachments in Duplicate • • Well WoPrognosis Well: K-18rd Hilrorp Alaska,LLC Applicationrk Date: 04/10/2014 Well Name: K-18rd API Number: 50-733-20254-01 Current Status: Oil Producer(SI) Leg: Leg#1 (NE corner),Slot#3 Estimated Start Date: June 1, 2014 Rig: Moncla Rig 404 Reg.Approval Req'd? 10-403 Date 10-403 submitted: Regulatory Contact: Juanita Lovett Permit to Drill Number: 201-117 First Call Engineer: Ted Kramer Office: (907)777-8420 Cell: (985)867-0665 Second Call Engineer: Dan Marlowe Office: (907) 283-1329 Cell: (907)398-9904 AFE Number: Budgeted Cost: Brief Well Summary: The K-18rd well is a Shut-in producer. This well had a coil tubing deployed jet pump installed until a hole developed in the production tubing in March of 2013. The coil tubing string has since been removed. The workover plan involves removing the current gas lift completion, cleaning out to PBTD (12,496'), and perforating. The well will then be placed on ESP artificial lift. Current Bottom Hole Pressure: 3,000 psi at 9,636'ND(Mid-perf) Maximum Expected BHP: 3,600 psi @ 9,636'TVD(Mid perf—based on offset K-12RD2 in 2009) Max.Anticipated Surface Pressure:0 psi,Well will not flow based on an expected oil and water gradient of 0.437 psi/ft. Procedure: 1. Move In and Rig up Moncla 404 Pulling unit. 2. ND Wellhead, NU bop and test to 250 psi low/ 2,500 psi high according to the attached BOP Test Procedure— Attachment #1 (Note: Notify AOGCC 24 hours prior to conducting BOP test to allow them the opportunity to witness). - > R (1 a A-0-...(C • ) C. . 3. RU E-line. TIH with Jet Cutter to 10,920(6'above FHL packer). Pull tension in tubing,cut same. POOH with E-line. 4. Circulate hydrocarbon off the well to production. • 5. POOH with tubing string laying down the same. 6. PU Workstring. RIH with overshot on 3-1/2"work string. Latch onto tubing stub,pickup 60K over string weight to release packer(if packer will not release, rotate 15-18 turns to release). 7. POOH with work string laying down packer. 8. PU RIH with p-5/8"cleanout assembly to 6,558'. POOH. • 9. PU RIH W/7"cleanout assembly cleaning out 7" 29#liner to 12,496'(PBTD). Circ. Hole clean, POOH with C/O assembly. 10. PU 7" RTTS packer. RIH and set at 11,200' (+/-). Pressure test casine to 1,500 psi and chart for 30 minutes. POOH with same. cr 11 PLL.R1H wit .Storm_packe_to 150'. S nd pressure+es+ sa+ e to 500 psi. ND BP, E .•-_ • _-:• - .- - ' -• - - 'g. ? e.f (4.r.a&Pe 12. PU TCP guns and RIH with same. V-(7•IV 13. RU E-line and Run in tubing with GR,CCL and correlate TCP guns on depth. Fire Guns. 14. Pick up guns above perforations. Shut down(+/-) 1 hour monitoring fluid level with Echometer. 15. Once the well is stable, POOH with TCP guns. 16. MU and RIH with ESP Assembly. 17. Hang off tubing. ND BOP, NU wellhead and test. 18. Turn Well over to production 19. RDMO Moncla 404 Pulling unit. Well Work Prognosis Well: K-18rd HilcoryAlaska,l.LC Application Date: 04/10/2014 Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Drawing McArthur River Field Well: K-18RD SCHEMATIC Last Completed: 08/18/01 Ilileorp Alaska,LLC PTD: 201-117 CASING DETAIL RKB to Sea Level(MLVV)=100' SIZE WT GRADE CONN ID TOP BTM. KB 4.:' 124" 186 X-56 Weld 22.313 Surf 369' q 1 13-3/8" 68 K-55 BTC 12.515 Surf 2477' 24"-365'' I '" 9-5/8" 47 5-95 BTC 8.681 Surf 6740' r •H 4 ,,. 7" 29 L-80 BTC-KC 6.184 6558' 12540' ' a ' TUBING DETAIL 13-3/r-Z477 4-1/2" 12.6 L-80 BTC 3.958 34.85' 6528' 3-1/2" 9.2 L-80 BTC 2.992 6528' 10992' b D D c NO. Depth ID Item 34.85' 3.958" 12"x 4-1/2"OCT Type UH-TC-1A Buttress Tubing HGR d 1 296' 2.81" Baker TE-5 TR SSSV,PB in top of valve DV.' 4-1/2WFD 2;R2 VLV,RK r'-6,sss 2 a 2413' 3.833" Latch,"w/dummySFO valve 9-50-6,744 4-1/2"WFD SFO-2;R2 VLV,RK b 4134' 3.833" Latch,w/dummy valve 4-1/2"WFD SFO-2;R2 VLV,RK e 5 c 5478' 3.833" Latch,w/dummy valve a h d 6483' 3.833" 4-1/2"WFD SFO-2;R2 VLV,RK Latch,w/dummy valve t re r' 1, r e 7388' 2.867" 3-1/2"WFD SFO-1,R2 VLV,BK Latch w/dummy valve 3-1/2"WFD SFO-1,R2 VLV,BK f 8205' 2.867" Latch w/dummy valve D h3-1/2"WFD SFO-1,R2 VLV,BK g 9023' 2.867" t` Latch w/dummy valve h 9724' 2.867" 3-1/2"WFD SFO-1,R2 VLV,BK Latch w/dummy valve 3-1/2"WFD SFO-1,R2 VLV,BK i 10645' 2.867" Latch w/dummy valve j 10877' 2.867" 3-1/2"WFD SF0-1,R2 VLV,BK Latch w/dummy valve j 2 Baker ZXP 7"Liner Top Packer o �� Baker 7"Model FHL Retrievable -- 3 a) 10926' 2.920" Packer Baker 3-1/2""X"Nipple w/Otis 4 4 10980' 2.812" profile 5 5 10993' 2.992" MT(Wireline Re-entry Guide) G Zine PERFORATION DETAIL Be rhes Zone Top Btm SPF Condition G5 11,593' 11,655' 6SPF ,' 11,680' 11,710' 12SPF 65 11,688 11,708' 6SPF 2/23/2008 G7 11,807' 11,848' 12SPF • G7 11,808' 11,848' 6SPF 2/23/2008 o+ HB-1 11,878' 11,888' 6SPF 4... r Hemlock HB-2 11,917' 12,000' 12SPF aly Benches HK-2 11,925' 12,000' 6SPF 2/23/2008 HB-3 12,041' 12,081' 12SPF HK-3 12,041' 12,081' 6SPF 2/23/2008 V HB-4 12,108' 12,131' 6SPF Z-12,540' _ t! HB-5 12,224' 12,241' 6SPF - HB-6 12,241' 12,261' 12SPF Note: HB-7 12,261' 12,270' 6SPF PBTD=12,496' TD=12,540'MAX Perforation Gun Debris possible @ 12,384' HK-5 12,241' 12,261' 6SPF 2/23/2008 Hole Angle=53°@ 8,761' Updated by: .ILL 11/14/13 McArthur River Field PROPOSED =e8dFDFuture Hileorp Alaska,LLC PTD: 201-117 RKB to Sea Level(MLW)=100' KB ;. CASING DETAIL ; t ' SIZE WT GRADE CONN ID TOP BTM. 24"-369 P 24" 186 X-56 Weld 22313 Surf 369' ., ?I,1, "w 13-3/8" 68 K-55 BTC 12.515 Surf 2477' rel k=. 9-5/8" 47 S-95 BTC 8.681 Surf 6740' i9?61 7" 29 L-80 BTC-KC 6.184 6558' 12540' 13-3/8"-2,47' TUBING DETAIL 3-1/2" 9.2 L-80 Supermax Surf ±11,030' NO. Depth ID Item 34.85' 3.958" Tubing Hanger r-6,558 1 ±11,189' Bottom of ESP 9-5/8"-6,740 tA ft PERFORATION DETAIL Eti ) Zone Top(MD) Btm(MD) (ND) Btm(ND) SPF Date a G1 ±11,239' ±11,322' ±8,538' ±8,605' Future G3 ±11,410' ±11,427' ±8,675' ±8,689' Future G5 ±11,590' ±11,642' ±8,820' ±8,862' Future 1 • G5 11,593' 11,655' 8,822' 8,872' 6SPF I.-1::11-1 Y. t G5 11,680' 11,710' 8,892' 8,916' 12SPF - G5 ±11,648' ±11,684' ±8,866' ±8,895' Future G5 11,688' 11,708' 8,898' 8,914' 6SPF 2/23/2008 1 G5 ±11,692' ±11,711' ±8,902' ±8,917' Future G7 11,807' 11,848' 8,993' 9,025' 12SPF G7 ±11,808' ±11,848' +8,993' ±9,025' 6SPF Future/Re pert T tw HK1 ±11,848' ±11,886' ±9,025' ±9,055' Future 4r N HK1 11,878' 11,888' 9,048' 9,056' 6SPF 47 HK2 11,917' 12,000' 9,079' 9,143' 12SPF k GZane - Benches HK-2 11,925' 12,000' 9,285' 9,143' 6SPF 2/23/2008 HK2 ±11,928' ±11,955' ±9,087' ±9,108' Future HK3 12,041' 12,081' 9,175' 9,206' 12SPF M't HK3 ±12,046' ±12,059' ±9,179' ±9,189' Future 0 „^ 4;" Hemlock Future HK4 12,108' 12,131' 9,227' 9,244' 6SPF Benches -t K Note: HK5 12,224' 12,241' 9,315' 9,328' 6SPF Perforation HK6 12,241' 12,261' 9,328' 9,343' 12SPF Gun Debris 7-12,540' possible @ HK7 12,261' 12,270' 9,343' 9,350' 6SPF 12,384' PBTD=12,496' TD=12,540'MAX Hole Angle=53°@8,761' Updated by: JLL 04/10/14 King Salmon Platform K-18RD Current 04/11/2014 Hilnirn Abeam.LIU: King Salmon Tubing hanger,FMC-TC-IA- K-18RD EN,12 X 4 Y:BTC top and 13 3/8 X 9 5/8 X 3 1/2 bottom,w/4"type H BPV,1- Y.Non continuous control line Jet Pump Manifold u+ re: u: 7 1* Valve,swab,WKM-M, ' 4 1/16 5M FE,HWO, •_r 7) T-24 ) -,1 III nr "Mrtit imp use � 1 ,4c Coiled Tubing head,Vetco _ 2 1/16 5M Wing section w/ Gray,41/16 5M FE X Pneumatic SSV 4 1/16 5M stdd,w/1- 2 1/16 5M SSO ii*A. o No Coiled tubing in head i 1 • 0 eye e-nmNrnrrn '.,... � iiiift— in ,+ Valve,lower master,WKM- M,41/165MFE,HWO,T-24 - +1 , • Adapter,A-4,13 5/8 5M FE X 4 1/16 SM stdd top,7.125" 'e r "' slick pocket,control line exit AIIMIIMIts Tubing head,FMC-OBS, ---- _ ------- 13 5/8 5M Stdd bottom x 0: _ ,<>.135/8 SM FE,w/2-31/SSM • -11 I I SSO,IP style lockpins 3irt ,moi �; • ,♦ i Casing head,FMC-OBS, 13 All casing valves 31/8 SM 13 5/8 5M FE X 13 3/8 SOW, OCT-20 w/2-3 1/8 SM SSO,IP style 1-1 ■ i 1 lockpins J1LiliLl ■ King Salmon Platform K-18RD Proposed 04/11/2014 Ifileorp:uaika-1,IA. King Salmon Tubing hanger,FMC-TC-B-EC, K-18RD 13 5/8 X 3 Y.TC-2 lift and 133/8X95/8X31/2 susp,w/3"typeHBPV profile,300-4 pkt,2-CCL, 3.266"centers,Alloy material BHTA,Bowen,3 1/8 5M X 2 Y Bowen Union lit in1111 Valve,Swab,WKM-M, w OR.as 3 1/8 5M FE,HWO,DD trim 6 1: 1 �I� °= Valve,SSV,WKM-M, 3 1/8 5M FE,Omni oper, EE trim Valve,Wing WKM-M, ■� 3 1/8 SM FE,HWO,DD trim Ii aV ell I u1OFR 1.1 Valve,Master,WKM-M, -t 0 I 31/8SMFE,HWO,DDtrim 1Q Adapter,FMC A-5-EC, 13 5/8 5M rot flg btm X X2 3 1/8 5M stdd top,w/300-4 Control line pkt,w/2-CCL,prepped f/ BIW penetrator,3.266 Tubing head,FMC-OBS, II centers 13 8/SM ESw2-3 dbottom 1 8 5M �c• 550,IP style lockpins 311-— ��MN Ott ! m °e `a 1 I' :�1' Casing head,FMC-OBS, _ - 13 5/8 5M FE X 13 3/8 SOW, All casing valves 31/8 5M • Dom'°. w/2-31/8 5M SSO,IP style u • _ _ OCT-20 lockpins lal Iilei di „ii-----:= .„.:F1, IIIIII°F'-'" '4 iiii ILI 1:1--- F ^ aI King Salmon Platform 2013 BOP Stack(Moncla) 09/19/2013 Hilecirp %14,nka.r.11A, It rill - 3.74' Shaffer 13 5/8 5M !i I IIi 4 ittl1U H CIW-U '1 Variable 27/8-5 4 C7' 13 5/8-5000 H Blind Rams ti Iii III ill Iii III Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses n; III If Iil I!1 lil m -�� ::� 2.00' 4 +°I�+ �`" 40.0 III I11 Iil Iil lil ' I!I III III III III Riser,13 5/8 5M FE X 13 5/8 SM API 813 hub 13.70' 111 Moncla Rig 404 BOP Test Procedure Hilrnrp Alaska,I. Attachment#1 u; Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, King Salmon WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,111: Attachment#1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. Moncla Rig 404 BOP Test Procedure Hilrorp AIaake, Attachment#1 ii) Valves, 3,4,9. After test, open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test,open valves 5 &6, leave 9 closed. iv) Valves, 7, 8, 9. After test,open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Moncla Rig 404 BOP Test Procedure Hilcorp Alaska, LLC #1 Diagram A-1: King Salmon BOP stack and Riser Arrangement—Typical for Single Completion • • lit til tit ill lit til tiItii 3.74' lit iii III 111 111 Ill III 111 III III Clw-U Variable 2 7/8-5 135/8-5000 1 ,_ .c Blind Rams 111 iii Iii III i11 _ Choke and Kill Valves 2 1/16 5M w/Unibolt connections for iopik t 11 111 11 I IRI 111 _ hoses IOU W 4 aQ 41111.0 III til iii III iii ' iii111111ill III Riser,13 5/8 5M FE X 13 5/8 5M API#13 hub 13.70' Moncla Rig 404 II BOP Test Procedure Hitcorp Alaska,Lit. Attachment#1 Diagram B: King Salmon Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves IMO III." ,---30 III III III _In MILI C---2'. '. III III Chokes are 90 degrees off in drawing in order to show / detail It Ea— : ' I: t- -1-J- E;. l,-, .-,.. I: ItI.c • Swaco 1. i1i G . 'Ii Lill __ IIIA .: 11 1 U ili tr �A■ n� iii 111 111 :.. _--'L�_— III-III ..._ 1 �111 III III 1i. .4 -I From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3 '/4' Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3 '/4" Ball port, 6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure i #6 National Ball Valve B2650,2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650,2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3 1/4" Ball port, 6000psi working pressure . #10 National Ball Valve B1560, 1 '/z" Ball port, 6000psi working pressure ... . . Moncla Rig 404 II BOP Test Procedure Hilsorp Alaska,Ilk Attachment#1 1 -----0 i I A' ) z 2 — -:.'- ) -----.... --- ..--- ..---...1'Thal I 11111r•I!*I*Ep ...II "........................ 1 1 1 0. E 0 z 145 (1)4111111111.. co - .-- CD Z - I I— 0 -_-= L,.. o_ b .I • X a , WC) 12 0_ 0 0 5 (7) z .,-.) ii_ < o (/) C.) api •= -=-• '— < - _....1 D 0 0 Moncla Rig 404 BOP Test Procedure HilcorpAlaska,LLC Attachment#1 ss V ►7 $ I' W G --_-_ ► - - III..: f - 1— a • • rte^ U c ^L J J - LL z _ ,) O 2 Q d O } o V ¢ 4o1= S- Q -rq----eo-- o � wzz A oomo fd1- w �w 2 N U^ J Lrl J _100 z RECEWED , STATE OF ALASKA AL-. A OIL AND GAS CONSERVATION COMMiaSION NOV 2 1 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon El Repair Well El Plug Perforations 0 Perforate El Other El Pull Velocity String. Performed: Alter Casing El Pull Tubing❑ Stimulate-Frac ❑ Waiver El Time Extension❑ Change Approved Program El Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development CI Exploratory El 201-117 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20254-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018777 • Trading Bay Unit/K-18RD • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,540 feet Plugs measured N/A feet true vertical 9,552 feet Junk measured N/A feet Effective Depth measured 12,496 feet Packer measured 10,926 feet true vertical 9,520 feet true vertical 8,292 feet Casing Length Size MD ND Burst Collapse Structural Conductor 369' 24" 369' 369' Surface 2,477' 13-3/8" 2,477' 2,295' 3,450 psi 1,950 psi Intermediate Production 6,740' 9-5/8" 6,740' 5,559' 8,150 psi 7,100 psi Liner 5,982' 7" 12,540' 9,552' 8,160 psi 7,020 psi Perforation depth Measured depth 11,593-12,261 feet True Vertical depth 8,822-9,343 feet 6,528'(MD) 10,992'(MD) Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 5,388'(ND) 3 1/2"9.2#/L-80 8,344'(ND) 10,980'(MD) 296'(MD) Packers and SSSV(type,measured and true vertical depth) Model FHL Pkr 8,335'(ND) TE-5 TR SSSV 296'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 1NED i ; e 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El - Service El Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil El• Gas ❑ WDSPL❑ GSTOR ❑ WINJ El WAG El 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: Contact Ted Kramer Email tkramer @hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature � ;#2.-----. Phone (907)777-8420 Date 11/21/2013 •Dt / �/ MY . 9 P NUV 2 1 77 -Form 10-404 Revised 10/2012 t • �•! ` Submit Original Only Hilcorp Alaska, LLC ►:,.�:,. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-18RD 50-733-20254-01 201-117 _ 10/21/2013. 10/24/2013 Daily Operations: 10/21/13-Monday SIMOPS,PTW and JSA.Notified AOGCC of BOP test.Finish rigging up coil tubing.Test BOP 250 psi low/3500 psi high.Witness of test waived by Jim Regg,AOGCC.Rig up slickline,pressure test to 250 psi low and 2500 psi high.RIH and pull standing valve at 10,762'. POOH with valve.Rig down slickline. 10/22/13-Tuesday Finished testing of BOP's.Waiting on crane repairs. 10/23/13-Wednesday Repair crane.Pull coil tubing hanger.Cut off tubing hanger and MU coil roll on.Pull velocity string from well.Had paraffin problem first 800'before it cleared and could pull coil at a steady speed.Had 2 pin holes in coil approx.1,615'and 1,724'from surface.Got coil and BHA from well.Rig off well and will complete rig down in AM.Pulled(+/-)10,571'plus BHA. 10/24/13-Thursday PTW,JSA and SIMOPS.Rig down coil equip and prepare for boat.Turn well over to production. McArthur River Field Well: K-18RD SCHEMATIC Last Completed: 06/30/2012 llilcorp Alaska,LLC PTD: 201-117 CASING DETAIL RKBto Sea Level(MLW►=100' SIZE WT GRADE CONN ID TOP BTM. 24" 186 X-56 Weld 22.313 Surf 369' -1 13-3/8" 68 K-55 BTC 12.515 Surf 2477' 24"-36g - :f 'i 9-5/8" 47 5-95 BTC 8.681 Surf 6740' ,' 7" 29 L-80 BTC-KC 6.184 6558' 12540' ■' a .. TUBING DETAIL PO 133/8'-2,477 4-1/2" 12.6 L-80 BTC 3.958 34.85' 6528' 3-1/2" 9.2 L-80 BTC 2.992 6528' 10992' imi■■ b II c NO. Depth ID Item 34.85' 3.958" 12"x 4-1/2"OCT Type UH-TC-1A Buttress Tubing HGR ■■ d Baker TE-5 TR SSSV,PB in top of INIE 1 296' 2.81" valve r-6ssa 2 a 2413' 3.833" 4-1/2"WFD SFO-2;R2 VLV,RK Latch,w/dummy valve sVa-474 ': 4-1/2"WFD SFO-2;R2 VLV,RK b 4134' 3.833" Latch,w/dummy valve 4 ∎∎ e "" c 5478' 3.833" 4-1/2"WFD SFO-2;R2 VLV,RK le' Latch,w/dummy valve 7-, rS d 6483' 3.833" 4-1/2"WFD SFO-2;R2 VLV,RK ": t Latch,w/dummy valve 0 t 2.867" 3-1/2"WFD SFO-1,R2 VLV,BK t 9 ho e 7388 Latch w/dummy valve 'f 3-1/2"WFD SFO-1,R2 VLV,BK :4� f 8205' 2.867" A Latch w/dummy valve t' ■■ h g 3-1/2"WFD SFO-1,R2 VLV,BK 9023' 2.867" Latch w/dummy valve ,di'i 3-1/2"WFD SFO-1,R2 VLV,BK 2i 4 h 9724' 2.867" Latch w/dummy valve s'' i t i 10645' 2.867" 3-1/2"WFD SFO-1,R2 VLV,BK 4i y! Latch w/dummy valve y, 1 3-1/2"WFD SF0-1,R2 VLV,BK j 10877' 2.867" Latch w/dummy valve 4' , 2 Baker ZXP 7"Liner Top Packer +� l e' Baker 7"Model FHL Retrievable 3 3 10926' 2.920" Packer ;; Baker 3-1/2""X"Nipple w/Otis q 4 10980' 2.812' Profile y; 6 ,,1 5 10993' 2.992" EOT(Wireline Re-entry Guide) ri x± )1 1 -. GZcne PERFORATION DETAIL a A Benches Zone Top Btm SPF Condition y GS 11,593' 11,655' 6SPF 11,680' 11,710' 12SPF • G5 11,688 11,708' 6SPF 2/23/2008 G7 11,807' 11,848' 12SPF 0 G7 11,808' 11,848' 6SPF 2/23/2008 r' HB-1 11,878' 11,888' 6SPF Hemlock HB-2 11,917' 12,000' 12SPF HK-2 11,925' 12,000' 6SPF 2/23/2008 1 14 HB-3 12,041' 12,081' 12SPF 4 HK-3 12,041' 12,081' 6SPF 2/23/2008 '-12540 3 �7104 HB-4 12,108' 12,131' 6SPF HB-5 12,224' 12,241' 6SPF `.. + 1 - HB-6 12,241' 12,261' 12SPF Note: HB-7 12,261' 12,270' 6SPF PBTD=12,496' ID=12,540'MAX Perforation Gun Debris possible @ 12,384' HK-5 12,241' 12,261' 6SPF 2/23/2008 Hole Are=53°@ 8,761' Updated by: JLL 11/14/13 Cev~~n ~- ~ _- • Francisco Castro Technical Assistant DATE Tune 28, 2010 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 • Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ~: {.- - . , h (~'~~ Transmitted herewith is one DVD containing the following data. • D-48L1 ~ ~ .~a~I • Formation evaluation logs -LAS j9j~j O~ f • Gamma ray logs -LAS K-12RD2 ~~~- i'S~~ / ~ ~~~ • K-12RD2_Final_Survey.xls • K-12RD2_Tops.xlsx ~~~ _D~ l 4! ~ ~ j° • MPR-Gamma ray logs -LAS, CGM, PDF • K-18RD ~D/_//~ /9~~~ • K-18RD_Final_Survey.doc _ • Density Neutron logs -LAS ~~!_,~ ! 1 ~ ~Sd ~S • K-18RDP61 • UBI log -LAS, PDS, DLIS ~~~,~ ~ y qj ~~ ~} • survey.xls / ~ ~ 10 • K-24RD2 c~a3-/fSc~ • Density Neutron logs -LAS • Final Mudlog Report -LAS, DOC c~0~ ~l~ ~ 1 ~ $~/ • M-06 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS M-10 c~d'~S -/(o ~ l ~ ~~c7 • M-10Tops.xlsx • USIT log -PDS ~U9 -(~`}j 3 !~ ~,C~ • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-10PB1 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-16RD_Tops.xlsx • Final logs; Cement Bond Log, Completion Record -PDS • M-17 M-17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report -LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: l0'1 • Fage 1 of 1 - 1/13/2010&u • McMains, Stephen E (DOA) From: Kanyer, Christopher V [Chris.Kanyer@chevron.com] Sent: Wednesday, January 13, 2010 1:10 PM To: McMains, Stephen E (DOA); Aubert, Winton G (DOA) Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett); Tyler, Steve L Subject: Cancellation of open sundries/permits After reviewing the following open permits to drill (form 10-401)/sundries (form 10-403) for Union Oil Company of California, it has ', been determined these open AOGCC permits/sundries should be cancelled: PTD Sundry API Well Name/Number 209-011 N/A 50-233-20025-00 Panthera 21-6-9 208-207 N/A 50-287-20026-00 Stegodon 24-6-8 209-058 N/A 50-733-20586-00 Trading Bay Unit M-08 197-067 308-252 50-733-20043-02 A-08RD2 195-083 30 - -733-20097-04 208-184 309-198 50-283-20130-00 Please let me know if you have any questions. ra ing ay nit K=~6RD Ivan River Unit (IRU) 11-06 Thanks, Chris Kanyer ~• Technical Assistant Wellbore Maintenance Team Office: (907) 263-7831 Cell: (907) 250-0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 }.. }~~'~w~ tl~iv {. ~ ~~ k4 1/13/2010 ~~QVrO#1 Debra Oudean Chevron North America Exploration and Production -• Technical Assistant 909 W, 9th Avenue .~`" " Anchorage, AK 99501 ~~"'"` Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand@chevron.com September 29, 2008 To: AOGCC Howard Okland 333 W. 7th Ave. Ste#100 tF<< ' ~ ~'~~~~ ~~~~ €} r,~ ~ L~~i~i Anchorage, AK 99501 :,;,~~ ~ . CD # WELL LOG TYPE. NOTES 1 ~TBU K 18 ~K-18RD-VISION SERVICES RM.LAS LAS _ ~K-18RD Final Survey.doc doc aCSI- 6th { K-18RD Final Survey.txt txt ;Vision Density Neutron-CDR and Log _K-18RD.pds(Pds i ,~~, lG~,(o EOW Letter Unocal King Salmon K-18RD.doc k~Doc i ~Pdsview20kit.exe i ~Exe 2 ;SCU 42-05XSCU 42-05X TCP Guns Correlation 16Ju106.pdf ! Pdf :SCU 42-05X TCP Guns Correlation 16Ju106.pds '' Pds 3 ''sSCU 42-05XDML DATA Dbraw.dbf 'DBF Dbraw.mdx 'MDX SCU 42-05X.dbf !.DBF SCU_42-05X.hdr HDR UDC 20Co'O~"L/ I ~ SCU_42-05X.mdx :MDX SCU_42-05X 20060625.mdx MDX ~ ~.-(~ SCU 42-05X 20060710. mdx MDX _ _ SCU_42-05X_20060711.mdx 3 MDX j'a-~ "i ~ SCU_42-05X SCL.DBF -DBF ~ ,} lai c~ SCU_42-05X_SCL.MDX MDX SCU_42-05X TVD.DBF 'DBF ~ ~.c7~ SCU 42-05X TVD.MDX 'MDX _ SCU_42-05X xr.DBF 'DBF SCU_42-05X xr.DBF -MDX ':;FINAL WELL REPORT SCU 42 05X W l! R df t PDF e - epor .p SCY 42-05X Well Report.doc DOC ', 'LAS FILE SCU 42-05X.dat jDAT ;LOG PDF FILES SCU 42-05X DRILLING MD.PDF PDF SCU 42-05X DRILLING TVD.PDF PDF SCU 42-05X LWD COMBO MD.PDF ,PDF S(.:l.J 42-05X LWD C;OIVIBO TVD.PDF ;PDF SCU 42-05X MUDLOG MD.PDF PDF SCU 42-05X MUDLOG TVD.PDF PDF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: l \j d jl , ~ Date: • • ~~/~"~~ ®ebra Oudean Chevron fVorth America Exploration and Production °~ Technical Assistant 909 W. 9th Avenue ~~~`` ~ ' ~ ~ Anchorage, AK 99501 '" Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand@chevron.com jco #! wELL ~ LOG TYPE ~NOTES~ .MORNING REPORTS 20060623.htm 'HTML 20060624.htm HTML 20060625.htm HTML 20060626.htm ;HTML 20060627.htm ;HTML I - - 20060628.htm 'HTML 20060629.htm HTML ' 20060630. htm :HTML :'= 20060701.htm HTML 20060702.htm HTML 20060703.htm CHTML 20060704.htm JHTML 20060705.htm :,HTML 20060707.htm ;HTML 20060708.htm ;HTML 20060709.htm HTML 20060710.htm rHTML ? 20060711.htm HTML t `s 20060712.htm HTML 20060713.htm HTML z ? ;REMARKS FILE 3 SCU 42-05X REMARKS. LAS ;LAS 4 ;SCU 42 05X ASCU 42-05X USIT 15JUL06.PDF 'PDF t ;SCU 42-05X USIT 15JUL06.POS _. ~PDS 5 ASCU 42 05X :SCU42-05X EOW Report.pdf ~PDF 3 .. =Survey Text.txt (TXT _. 6 :ASCU 42-05X SOH WIRELINE LOGS DLIS ` AIT_DSI_TLD_MCFL_020PUC DLIS 7 =SCU 42 05X OH WIRELINE LOGS DLIS AIT_DSI_TLD_MCFL_021PUC.DLIS AIT_DSI TLD_MCFL_022PUC.DLIS I 8 ASCU 42 05X .OH WIRELINE LOGS Borehole Profile.PDS .IPDS Dsi print.PDS }PDS DSI TVE Print.PDS IPDS ` PEX TVD print.PDS IPDS Tcom print.PDS ~PDS 9 `HV 2 `PRESS TEMP LOG FINAL PBMS.PDS ~ ~PDS ~ x'03' F,t3 PSP 066PUP.DLIS :;DLIS ` _ PSP_066pup.las ..: ;,LAS ,~_:~._ ,:._ -.....:. . _,~ _ ,. _. . ! ~-ao! 10 _ HV 2 "POWERJET EJ ~ 1'~26~ COMBINED PERF.PDS PERFO 050LUP.DLIS IPDS !DLIS '` l~aQ3 _ PERFO_051LUP.DLIS DLIS !'~aocl PERFO 069LUP.DLIS o~ Gn m^ 11D :'DLIS `~a~~ g L .DLIS ,jDL1S ~- 11 'HV 2 ~POWERJET PJ 2006 (` Combined.PDS IPDS Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: A • , ~"!+~$/~'Q~ ®elsra ®udean Cteewron North America Exploration and Production °' -~ Technical Assistant 909 W. 9th Avenue ~ Anchorage, AK 99501 ~`""~`~ Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand@chevron.com CD # WELL LOG TYPE NOTES] Combined.PDS.FMA IFMA PERFO 005PUP.DLIS ~DLIS _ PERFO_005PUP.DLIS.FMA jFMA PERFO_006LUP.DLIS IDLIS PERFO_006LUP.DLIS.FMA }FMA PERFO_007LUP.DUS 'DLIA _ PERFO_007LUP/DLIS.FMA ~FMA 3HV 2 12 'POWERJET BP PERFOCombined.PDS 'PDS PERFOCombined.PDS.FMA Pl C bi d PDS FMA ' om ug ne . PDS _ _ '= PlugCombined.PDS.FMA _ _ ~FMA .__ 13 HV 2 €SCMT_iiV2 j ~ Combined.PDS PDS --- SCMT_PSP_007PUP.DLIS IDLIS SCMT_PSP_007PUP.LAS 'LAS ` f SCMT_PSP_007PUP_NEW.TXT TXT ` SCMT_PSP_008PUP.DLIS ! DL-S Le t me know if there is anything you need. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: • • ~~ ~ ~..'~ ~~ ~ ~~~ ~ ~ -~~ ~~ -~ ~~ SARAH PALIN, GOVERNOR L',i~t~-7~ OIL L~l~i/ tZLla7 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1`IOl~ COrIIKI55IOrT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 O,'' Anchorage AK 99519 Re: McArthur River Field, Hemlock Oil Pool, TBU K-18RD Sundry Number: 308-269 Dear Mr. Brandenburg: ~~~'~~~~' AUC '- r~ 2008 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of August, 2008 Encl. ,~1~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMII~ION ~/ APPLICATION FOR SUNDRY APPROaIfa~~~ 20 AAC 25.280 .~ (~ Q~ 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver^ Other^~ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Conversion to Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ jet pum 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 201-117 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20254-01 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No 0 Tradin Ba Unit K-18RD 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0018777 Kin Salmon Platform 34.85' 100' MSL McArthur River /Hemlock Oil /Middle Kena~ Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,550' 9,559' 12,384' 9,436' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 369' 24" 369' 368' Surtace 2,447' 13-3/8" 2,447' 2,272' 3450 psi 1950 psi Intermediate Production 6,740' 9-5/8" 6,740' 5,559' 8150 psi 7100 psi Liner 5,982' 7" 12,540' 9,552' 8160 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1/2" & 3-1/2" L-80 6,528' & 10,992' Packers and SSSV Type: Packers and SSSV MD (ft): ZXP Liner Top & Baker FHL Retrievable Packers /Baker TE-5 TRSSSV 6,558' and 10,926' / 296' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 10/14/2008 16. Well Status after proposed work: Commencing Operations: Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell 263-7832 Printed Name -Timothy C. Brandenburg Title Drilling Manager Signature - Phone 276-7600 Date 7/28/2008 y ~'' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other. > P ~ Subsequent Form Required: ~~ APPROVED BY ~y Approved by COMMISSIONER THE COMMISSION Date: (S)(' , S :: ~~._ Dui, Form 10-403 Revised 06/2006 n ~ ~ ~D~B Submit in Dupl" i ~~ ~ ` ORIGlAL ~~~~°~ ~~~~~ Chevron • • Trading Bay Unit Well # K-18 RD Actual Completion RKB to TBG Head = 34.85' 2 CASING AND TUBING DF,TAIL SIZE W'C GRADE CONN ID TOP BTM. 24" Driven Surf. 369' 13-3/8" 68 K-55 Butt 12.515" Surf 2,477' 9-5/8" 47 USS-95 Butt 8.681" Surf 6,740' 7" Liner 29 L-80 BTC-KC 6.184 6,558' 12,540' Tubing: 4-1/2" 12.6 L-80 BTC 3.958 34.85' 6528' 3-l/2" 9.2 L-80 BTC 2.992 6,528' 10,992 NO. Depth JEWELRY DETAIL. ID Item 34.85' 3.958 12" x 4-1/2" OCT type "UH-TC-IA" Butt Tbg Hngr 1. 296' 3.182 Baker TE-5 TRSSSV 2. 4-I/2"Gaslift Mandrels ~~~/ RK latches (mas OU 7.063") 3. 6526' Crossover, 41/2" x 3-l/2" BTC (1.92') 4. 6558' ZXP Liner Top Packer 5. 3-I/2" Gaslift Mandrels ~~~/ RK latches (maz OD x.968") 6. 10,926' 2.920 7" Baker Model FHL Retrievable Packer 7. 10,980' 2.812 Baker "X" Nipple w/Otis Profile 8. 10,993' 2.992 EOT (WL Re-entry) Gas Lift Mandrels NO. UCpIh ID Item 1 2413' 3.833" 4-1/2" SFO-2 GLM; R-2 Valve/RK Latch 2 4134' 3.833" 4-1/2" SFO-2 GLM; R-2 Valve/RK Latch 3 5478' 3.833" 4-1/2" SFO-2 GLM; R-2 Valve/RK Latch 4 6483' 3.833" 4-1/2" SFO-2 GLM; R-2 Valve/RK Latch 5 7388' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 6 8205' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 7 9023' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 8 9724' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 9 10345' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 10 10877' 2.867" 3-1/2" SFO-1 GLM; R-2 Orifice/BK-2 Latch v~~utinu:~~rrnN ne•re Zone Interval FT SPF G-5 11,593 - 11,665 72 6 11,680 - 11,710 30 12 G-7 11,807 - 11,848 41 12 HB-1 11,878 - 11,888 10 6 HB-2 11,917 - 12,000 83 12 HB-3 12,041 - 12,081 40 12 HB-4 12,108 - 12,131 23 6 HB-5 12,224 - 12,241 17 6 HB-5 12,241 - 12,261 20 12 HB-5 12,261 - 12,270 9 6 SCHEMATICS_K18RDActualSchem0901 [ 1 ].doe REVISED: 3/12/08 PBTD = 12496' TD = 12550' MAX HOLE ANGLE = 53° Ca? 8781' RKB tea Level tIG1 KB 34.85' za^ ~ 3.3 OCTG Rotating Hours 24" x Rotating Hours 13-3/8" x Rotating Hours 9-5/8" x Rotating Hours 7" x Rotating Hours Tubing "0" Rotating Hours ig Platform K-18 Proposed Sept 2008 Trading Bay Unit Well K-18 RD Last Completed 08-18-01 ~` Size Type Wt/ Grade/ Conn ID Top Btm Cement Cement Sacks To 24" Structural 186#, X-56, Weld _22.313. 0 369 Driven _.. 13-3l8" Surface 68#, K-55, BTC .................... 12.515 ........................................ 0 ....................................... 2477' ........................................ 1550 ............................................ Surf ............................................ .................................................. 9-5/8" ........... ............................................... Surface ............................................................................. 47#, S-95, BTC 8.681" 0' 6740' 1000 7" Liner 29#, L-80, BTC-KC 6.184" 6558' 12,540' 1130 6558' Completion 4-1/2" P roduction 12.6#, L80, BTC 3.958 34.85 6528' In Casing 3-1/2" P roduction 9.2#, L80, BTC 2.992 6528' 10,992' In Casing Completion Jewelry Detail # Depth Length ID OD Item 34.85' 3.958" 12" x 4-1/2" OCT Type UH-TC-1A Buttress Tubing HGR 1 296' 3.182" 4-1/2" Baker TE-5 TR-SSSV, a 2413' 3.833" 4-1 /2" WFD SFO-2; R2 VLV, RK Latch, Blank b 4134' 3.833" 4-1/2" WFD SFO-2; R2 VLV, RK Latch, Blank c 5478' 3.833" 4-1/2" WFD SFO-2; R2 VLV, RK Latch, Blank d 6483' 3.833" 4-1/2" WFD SFO-2; R2 VLV, RK Latch, Blank e 7388' 2.867" • 3-1 /2" WFD SFO-1, R2 VLV, BK Latch Blank f 8205' 2.867" 3-1/2" WFD SFO-1, R2 VLV, BK Latch Blank g 9023' 2.867" 3-1/2" WFD SFO-1, R2 VLV, BK Latch Blank h 9724' 2.867" 3-112" WFD SFO-1, R2 VLV, BK Latch Blank i 10,345' 2.867" 3-1/2" WFD SFO-1, R2 VLV, BK Latch Blank j 10,877' 2.867" 3-1/2" WFD SFO-1, R2 VLV, BK Latch Install Circ VLV 2 Baker ZXP 7" Liner Top Packer 3 10,926' 2.920" Baker 7" Model FHL Retrievable Packer 4 10,980' 2.812" Baker 3-1/2" "X" Nipple w/ Otis Profile 5 10,993' 2.992" EOT (Wireline Re-entry Guide) Proposed CT Jet Pump and Related Add itional Subsu rface Equipment A 0 10, 790' 2" 2" CT HS-90 10, 790' 1 ' 2.750" 2"Coil Tubing Connector 10, 791 ' 7' 2.500" Pup Joint & x-over to Jet Pump B 10, 798' 6' 2.260" Jet Pump Cavity C 10, 804' 15' 2.750" Locator Sub Seal Assembly 10 805 15' 2.80" Top of PBR (approximately 16' Seal Bore f/ 15' " , Nominal) movement (2.780 D 10, 820' 5' 2.740" Packer Assembly (E-Line or Slickline Set/ Retrieve) E 10, 825' 20' 2.295" Screen Assembly (20/40 Mesh, Rated 1200 BPD) 2.50" Bull Plu Perforation Data Dog legs ZONE TOP BTM Shot Condition G5 11,593' 11,655' 6SPF _ _ 11,680' 11,710' 12SPF _ G5 - 11,688 - 11,708' 6SPF 2-23-2008 G7 11,807' 11,848' 12SPF G7 11,808' 11,848' 6SPF 2-23-2008 HB-1 11,878' _ 11,888' 6SPF HB-2 11,917' 12,000' 12SPF HK-2 11,925' 12,000' 6SPF 2-23-2008 HB-3 12,041' 12,081' 12SPF HK-3 12,041' 12,081' 6SPF 2-23-200__8__,,.,__ HB-4 12,108' 12,131' 6SPF HB-5 12,224' 12,241' 6SPF HB-5 12,241' 12,261' 12SPF _ HB-5 12,261' 12,270' 6SPF HK-5 12,241' 12,261' 6SPF 2-23-2008 Fish: Perforation Gun Debris possible @ 12,384' WBD K-18RD Proposed doc Paae 1 of 2 JRN PBTD =12,496' TD =12,550" MAX HOLE ANGLE = 53° (rD.8761" Chevron OBJECTIVE: ding Bay Unit -18RD CT Jet Pump Recomplletion Revision #0: 07/24/2008 Evaluate the suitability of the wellbore by Slickline work, E-line work to set the packer, Coil Tubing Unit to convey a Jet Pump at depth. Work to be completed with tree on below the swab valve. PROCEDURE SUMMARY: • PJSM -Prepare well for workover operations coordinating with platform operations. • PJSM - MI RU Slickline unit to mechanically LO TR-SSSV, Pull bottom live GL valve, circulate hole with filtered produced water -Change out "live" GL valves for "blanking" GL valves, set plug in X-profile nipple, pressure test production tubing, pull x-nipple plug, pull blanking valve from bottom GL mandrel, install large bore pocket protector. • PJSM -Circulate well bore with filtered produced water -monitor for 30 minutes for static loss rate -Install BPV into tree. • PJSM - ND Swab valve, install 4-1/16" ID coil tubing hanger head on production cross - NU swab valve - body pressure test assembly -Pull BPV - RU to circulate well with filtered produced water. • PJSM - MI RU E-Line -RIH -Set and Pressure Test CT PBR /packer w/ screens assembly in production tubing - RD E-line • PJSM - MORU CT Unit, perform AOGCC BOP test - PU Jet Pump Assembly - RIH w assembly -land into PBR, pressure test hanger seal. -Pull up, cut coil, install CT slip type connecter for hangar landing -Land slip type CT Hanger -Pressure test assembly - RD CT Unit • PJSM - RU Slickline Unit -Pull isolation sleeve -set standing valve -launch jet pump to cavity - RD wire line. • TURN OVER TO OPERATIONS -Operate well as CT conveyed Jet Pump artificial lifted oil producer. K-18RD WO Objective and Procedure Summary.doc REVfSEO BY: JRiV 07/24/08 ~~~y~(~~ ncisco Castro Chevron IVorth~erica Exploration and Production ~, l`echnical Assistant 909 W. 9th Avenue ,~, r~r~ Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ~~~1NEC~ JUN ~ ~. 2008 DATE Tune 9, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ~ ~ ~ WELL LOG TYPE SCALE LOG DATE INTERVAL LOGGED RUN # B-LINE CD PdOTES -LAS; PDS, DLIS COMPLETION TB ST A-25RD RECORD 5" 4-Mar-08 6660-7092 1 1 1 PDS COMPLETION TB ST A-01 RD RECORD 5" 5-Mar-08 5697-6140 1 1 PDS COMPLETION TBU K-18RD RECORD 5" 21-Feb-08 10800-12400 1 1 PDS COMPLETION TBU K-26 RD RECORD 5" 24-Feb-08 10303-10323 1 1 PDS PERFORATING TBU G-22 RECORD 5" 3-Ma -08 10122-10229 PS-2 i i -DLIS-PDS PERFORATING TBU M-17 RECORD 5" 16-Feb-08 7298-7381 PS-11 1 1 PDS PERFORATING TBU M-17 RECORD 5" 14-Feb-08 7296-7391 PS-9 1 1 PDS POSISET PLUG SETTING TBU M-17 RECORD 5" 11-Feb-08 6889-7430 PS-8 1 1 PDS PRESSURE TEMPERATURE TBU M-17 LOG 5" 15-Feb-08 5636-7398 PS-10 1 1 PDS DEPTH TBU M-17 DETERMINATION 5" 3-Feb-08 5782-7374.5 PS-7 1 1 PDS PERFORATING TBU M-17 RECORD 5" 19-Feb-08 5832-5856 PS-12 1 1 PDS POSISET PLUG SETTING TBU M-01 RECORD 5" 7-Jan-08 4792-5151 PS-2 1 PDS PERFORATING TBU M-01 RECORD 5" 18-Jan-08 4532-4580 PS-3 1 PDS HAPPY CEMENT BOND PDS, LAS, VALLEY B-12 LOG - SCMT 5" 18-Mar-08 3559-10315 1 1 1 DLIS COMPLETION PDS, DLIS, LRU C-01 RD RECORD 5" 14-Ma -08 4679-4759 1 1 FMA 1 1 1 I 1 I I SRU 32A-15 I SHOOT RECORD 15" 10-Mar-08 5554-5582 1 1 PDS fg0~ly~ /o<l~'~ ~~`~/~ plaaca acknnwledae receipt by sianina and returning one copy of this transmittal or FAX to'907 263 7828. Received eye ~ Date: . STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~: r' ~ • r ~~~+~~~~ MAR 2 0 200 Alaska (lit & Ga_a t^nr~s_ ('.cfrttlffllisci 1. Operations Abandon Repair Well Plug Perforations Stimulate Oth ~ Performed: ~~ Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q ~ Exploratory^ 201-117 • 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20254-01 7. KB Elevation (ft): 9. Well Name and Number: 34.85' ~ K-18RD 8. Property Designation: 10. Field/Pool(s): ADL~ King Salmon Platform . •f~t- /y"h"1 ,,~ 5=~'~`t3~' MacArthur River Field; Hemlock/G Intervals ' 11. Present Well Condition Summary: Total Depth measured 12,550 ~ feet Plugs (measured) tlOrle true vertical g,559 feet Junk (measured) NOne Effective Depth measured 12,416 feet true vertical 9,459 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 369' 24" 369' 368' Surface 2477' 13-3/8" 2477' 2295' 3450 psi 1950 psi Intermediate Production 6750' 9-5/8" 6750' 5567' 8150 psi 7100 psi Liner 5982' 7" 12,540' 9552' 8160 psi 7020 psi t~~ Perforation depth: Measured depth: See attach SChematlC ~lC~.~,~~~~ ~PR ®~ ~~~~ True vertical deptn: See Attach Schematic Tubing: (size, grade, and measured depth) 4-1/2"; 3-1/2" L-80 6528'; 10,992' Packers and SSSV (type and measured depth) 7" FHL Pkr - 10,926' Baker TE-5 SSSV - 296' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 80 0 220 900 100 Subsequent to operation: 117 0 253 900. 80 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: OilO Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg ~_„_,, Title Drilling Manager J Signature ~' Phone 907-276-7600 Date 3/12/2008 Form 10-404 Revised 04/2006 r /'~ ~ ubmit Ori mal Onl ~ I A L ~-~ ~ _ ~ ~+ -~3~r~ .~~ ; y~. ~~ Trading Bay Unit V N ~ ~A ~ 76 Well # K-18 RD Actual Completion RKB to TBG Head = 34.85' 2 CASING AND Tl'BING DETAIL SIZE VI'T GRADE CONN ID TOP BT~1. 24" Driven Surf. 369' 13-3/8" 68 K-~5 Butt 12.515" Surf 2,477' 9-5/8" 47 USS-95 Butt 8.681" Surf 6,740' 7" Liner 29 L-80 BTC-KC 6.184 6,558' 12,540' Tubing: 4-1/2" 12.6 L-80 BTC 3.958 34.85' 6528' 3-1/2" 9.2 L-80 BTC 2.992 6,528' 10,992 NO. Depth JEWELRY DETAIL ID Item _ 34.85' 3.958 12" x 4-1/2" OCT type "UH TC-lA" Butt Tbg Hngr 1. 296' 3.182 Baker TE-5 TRSSSV 2. ~-1/3" Gaslift ~~tandrels w/ R1: latches (mas OD 7.063") 3. 6526' Crossover, 4-1/2" x 3-1/2" BTC (1.92') 4. 6558' ZXP Liner Top Packer 5. 3-I/3" Gaslift ,ti~landrels w/ RK latches (max OD >.968") 6. 10,926' 2.920 7" Baker Model FHL Retrievable Packer 7. 10,980' 2.813 Baker "X" Nipple w/Ottis Profile 8. 10,993' 2.992 EOT (WL Re-entry) PF.RFORATInN nATA Zone Interval FT SPF G-5 11,593 - 11,665 72 6 11,680- 11,710 • 30 12 G-7 11,807 - 11,848 41 12 HB-1 11,878 - 11,888 10 6 HB-2 11,917 - 12,000 83 12 HB-3 12,041 - 12,081 40 12 HB-4 12,108 - 12,131 23 6 HB-5 12,224 - 12,241 17 6 HB-5 12,241 - 12,261 20 12 HB-5 12,261 - 12,270 9 6 Gas Lift Mandrels NO. Depth ID Item 1 2413' 3.833" 4-1/2" SFO-2 GLM; R-2 Valve/RK Latch 2 4134' 3.833" 4-1/2" SFO-2 GLM; R-2 Valve/RK Latch 3 5478' 3.833" 4-1/2" SFO-2 GLM; R-2 Valve/RK Latch 4 6483' 3.833" 4-1/2" SFO-2 GLM; R-2 Valve/RK Latch 5 7388' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 6 8205' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 7 9023' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 8 9724' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 9 10345' 2.867" 3-1/2" SFO-1 GLM; R-2 Valve/BK-2 Latch 10 10877' 2.867" 3-1/2" SFO-1 GLM; R-2 Orifice/BK-2 Latch SCHEMATICS K18RDActualSchem0901[1].doc REVISED: 3/12/08 PBTD = 12496' TD = 12550' MAX HOLE ANGLE = 53° CD 8761' r1 LJ • SARAN PAUh'. GOVERfdGR March 12, 2008 Mr. Clu•is Myers Field Superintendent Unocal PO Box 19624? Anchorage, Alaska 9919 338 LV ,-" inV~NUE, ~h~ITr Ah!CFIJR;~,GE,.u._+~SKA 48~:)': ~:.,_. RE: No-Flaw Verification MQ~ °~ ~ ~~d~ Trading Bay Unit K-18RD, PTD 201-1 ~~ ~ ~ ~- ~ ~~ Dear Mr. dyers: On March 5, 2008 an AOGCC Petroleum Inspectar witnessed a "no floGV test" at Unocal's King Salmon platform, Trading Bay Unit Well K-18RD. The well was opened to atmasphere through flaw measurement equipment with suitable range and accuracy and monitored. This well demonstrated minor pressure build-up during the shut in phase of the test. Pressure dissipated rapidly with no sustained gas or fluid flow while open to atmosphere. The subsurface safety valve may be removed from. service in Well K-18RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncantralled flow must be maintained in praper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the we11 demonstrates an ability to flaw 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 King Salmon platform. Sincerely, (}~ f , ,, T , rc .. ~ ~ ~, (.~.~ ~~ :r", James B. Regg Petroleum Inspection Supervisor cc: Bob Fleckenstein • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg `~~ c ~~,~~ U~~ DATE: March 5 2008 P. I. Supervisor ~ ~ FROM: Chuck Scheve, SUBJECT: No Flow Petroleum Inspector Trading Bay Unit King Salmon Platform K-18RD PTD# 2011170 Wednesday, March 5, 2008: I traveled to Chevron's King Salmon Platform and witnessed a no-flow test on well K-18RD. I arrived on location and found the well bled off and opened to atmosphere with no flow of gas or fluid evident. The well was then shut in and observed for three hours with a minor pressure build up (<5psi) noted, when reopened the pressure dissipated rapidly with no sustained flow of gas or liquids. I recommend Well K-18 RD on the King Salmon Platform be approved continued no flow status. SUMMARY: Well K-18RD meets the AOGCC requirements for no flow status. ~ APR ~ ~ Z~O~ e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill 2011170 DATA SUBMITTAECOMPLIANCE REPORT 8~25~2003 Well Name/No. TRADING BAY UNIT K-18RD Operator UNION OIL CO OF CALIFORNIA APl No. 50-733-20254-01-00 MD 12550 --- TVD 9559 __._ Completion Dat 8/28/2001 ~ Completion Statu 1-OIL Current Status 1-OIL UIC Y REQUIRED INFORMATION Mud Log Nc) Sample Nc) Directional Survey N__9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ,l~edia Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments 'l~a~ing Retainer 5 FINAL 8731 8873 ch 8/30/2001 8731-8873 BL, Sepia Setting tool C..C. emeht Retainer GR 5 CCL Azimuthal Density 1 o~....-~'' Cn See Notes 2 Col ~ ,E. aeies Analysis 1 J' ,.Ge~nt bond tool 5 I~" Cn See Notes Lo Cn See Notes 2 Col ~ Cn See Notes 2 Col .l,e~'''' Azimuthal Density 1 Le~ ~c~l'lmages and Dips 112 Lo .B. oj~hole Breakout 2 ~ Cn See Notes 2 Col FINAL 6550 6950 ch 8/30/2001 6550-6950 BL, Sepia FINAL 6500 11845 oh 8/30/2001 6500-11845 BL, Sepia FINAL 9000 11850 oh 8/30/2001 9000-11850 Color Print 1 10245 12550 ~[f~('¢-- 5/6/2002 Formation Log ST 1 FINAL 9000 11850 oh 8/30/2001 9000-11850 Color Print FINAL 7000 8865 ch 8/30/2001 7000-8865 BL, Sepia 1 6785 12442 ~ 5/6/2002 Final Well report 1 6785 12442 C~se-~f(. 5/6/2002 Formation Log PB 1 1 6785 12442 Ca,se0~ 5/6/2002 Formation Log PB 1 FINAL 9000 11850 oh 8/30/2001 9000-11850 Color Print FINAL 9000 11800 oh 8/30/2001 9000-11800 Color Print FINAL 9000 11850 oh 8/3/2001 9000-11850 Color Print 1 10245 12550 ~ ~-~ 5/6/2002 Formation Log ST 1 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments I.... Cutt~ ............................ S-f-S¥ ......... ~¥4---4¥ ............................................................................................. ~ -:'¥ ¥(~';;~-:-~-~-~'~ ~ ............................... ADDITIONAL INFORMATION '~6 ~f ,~.,~ Y'~ ~ (~v%~ DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Permit to Drill 2011170 Well Name/No. TRADING BAY UNIT K-18RD Operator UNION OIL CO OF CALIFORNIA MD 12550 TVD 9559 Well Cored? Y ~ Chips Received? '"-Y i N Analysis ~ R~r. eiv~.d ~ Completion Dat 8/28/2001 Completion Statu 1-OIL Current Status Daily History Received? ('~ N Formation Tops ~_~ N 1-OIL APl No. 50-733-20254-01-00 UIC Y . / Comments: ~/~,,;:... ¢. ,~ ...., ~.. Compliance Reviewed By: TBU K-18RD Subject: TBU K-18RD Date: Fri, 03 Oct 2003 11:23:16 -0800 From: Howard Okland <howard_okland@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To: harrisonb@unocal.com Bev, Greetings. Help...I've been looking over TBU K-18RD (API 50-733-20254-01) data submitted to the Commission. The completion report indicates "Schlumberger Anadrill MWD/LWD GR, Resistivity, Neutron Density" logs were run. Apparently we never received open hole log digits. In addition, we do not have sepias of the open hole logs. At your earliest convenience, please submit these data to my attention. TNX Howard ALAS~ OIL AND GAS CONSERYA~ION COPlPl~SSION Dwight Johnson UNOCAL Field Superintendent PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification TBU Well K-18RD PTD 201-117 May15,2003 FRANK H. MURKOWSKI, GOVERNOR 333 W. Tr" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Johnson: On May 8, 2003, our Inspector Lou Grimaldi witnessed a "no-flow test" on Unocal's King Salmon Platform. Well K-18RD was tested. Mr. Grimaldi arrived on King Salmon Platform and found the well isolated from the production system and "flowing" to the girder tank at 30 psi and making no fluid. The well was changed to the cleanup tank and the gas bled off. After approximately 90 minutes, the FTP had decreased to about 1 psi with a measured gas rate of 400 scf/hr. The well was SI for 45 minutes and opened to flow for 10 minutes, followed by another 45 minute SI period and then the well was left open of 2.5 hours. In each case the well built to 5 psi. When opened to flow both initial gas rates exceed the meter threshold of 1800 scf/hr but declined to 425 and 350 scf/hr by 3 minutes. In the final extended flow period, the well maintained a flow of about 180 scf/hr. No liquid was produced from the well. Although this well did not "die" as others tested today, it does meet the established "no flow gas rate" of < 900 scf/hr. It has been concluded that TBU well K-18RD (201-117) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. The well's performance meets the criteria at 20 AAC 25.265 (b). Therefore the well is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board King Salmon. Sincerely, Thomas E. Maunder, PE Sr. Petroleum Engineer Beverly Harrison Business Ventures Assistant Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mai]: harrisonb{~tmocal.com UNOCAL ) May 3, 2002 To: Lisa Weepie AOGCC 333 W. 7th Ave, #100 Anchorage, AK 99501 DATA TRANSMITTAL - KING SALMON PLATFORM · W~Li""'"!'::'" '.'i: .":l"~.~Pi~:~.';:'.'i..i';."?""'...' :'..'.'5"'i'. 'SCALE.-'. I.'DATE :' .', · ' BO" MEi~iUM . K-13RD2 EPOCH FINAL WELL REPORT 6/16/2001 1 PAPER K-17 COMPLETION RECORD / BRIDGE PLUGS 5 INCH 4/26/2002 2300-2603 1 Film -~ K-17 COMPLETION RECORD / BRIDGE PLUGS 5 INCH 4/24/2002 6780-7035 1 B-Line ~)K-17 COMPLETION RECORD / BRIDGE PLUGS 5 INCH 4/24/2002 6780-7035 1 Film i~, K-17 COMPLETION RECORD / BRIDGE PLUGS 5 INCH 4/26/2002 2300-2603 1 B-Line K-17 TCP CORRELATION / GR 5 INCH 4/2/2002 10200-10710 1 B-Line '"'~ K-17 TCP CORRELATION / GR 5 INCH 4/2J2002 10200-10710 1 Film ,¥~'~ K-18RD EPOCH FINAL WELL REPORT 8/2/2001 1 PAPER p . K-18RDST1 EPOCH FINAL WELL REPORT 8/2/2001 1 PAPER pK-19 HALLIBURTON TCP CORRELATION 5 INCH 3/20/2002 12050-12450 1 B-Line _ K-19 HALLIBURTON TCP CORRELATION 5 INCH 3/20/2002 12050-12450 1 Film HALLIBURTON TCP CORRELATION / GR / CCL / ' K-20 COMPLETION RECOR 5 INCH 4/10/2002 5750-6830 1 Film ..9 HALLIBURTON TCP CORRELATION / GR / CCL / .~ K-20 COMPLETION RECOR 5 INCH 4/10/2002 5750-6830 1 B-Line ~ HALLIBURTON TCP GUN CORRELATION / GR / (3- K-20 CCL / COMPLETION RECOR 5 INCH 4/13/2002 6400-7140 1 B-Line ~ HALLIBURTON TCP GUN CORRELATION / GR / K-20 CCL / COMPLETION RECOR 5 INCH 4/13/2002 6400-7140 1 Film /--- K-24RD2 CEMENT BOND LOG ' 5 INCH 9/29/2001 7900-14143 1 Film K-24RD2 CEMENT BOND LOG 5 INCH 9/29/2001 7900-14143 1 B-Line K-24RD2 COMPLETION RECORD / 2.5" HSD 6 SPF 5 INCH 10/16/2001 13200-13565 1 Film K-24RD2 COMPLETION RECORD / 2.5" HSD 6 SPF 5 INCH 10/16/2001 13200-13565 1 B-Line Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. D r~ P ,~ l ~ l r' r% Received ~ Date: [,~^V,-,,, 2002 ~ .J ~ ~',,i~"~ i V r~ Alaska Oil a Gas Cons. Cormniaeen Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99..501 Tele: (907) 263-7651 Fax: (9,07) 263-7828 E-mail: harrisonb@ unocal.com UNOCA, Beverly Harrison Business Ventures Assistant DATA TRANSMITTAL November 16, 2001 To: Lisa Weepie 333 W 7th Ave, #100 Anchorage, AK 99501-3539 Alaska Oil & Gas From: Beverly Harrison 909 W. 9th Avenue Anchorage, AK 99501 Unocal Alaska Transmitting the following: I LOGTYPE I SCALE I LOG i INTERVAL ICOJ Well Mediu~ PACKER CORRELATION 5 INCH 9~8~200 i6780-7138 1 lEU 4'4-36~il~ ...... TCP CORRELATION GR/CCL 15 INCH 9/4/200 i5970-6300 1I IRU 44-36 Film COMPLETION RECORD 5 INCH 9~9~200 11700-12300t1 TBU K-18RD 'Film RECEIVED NOV 20 DO1 PleQse acknowledge r. Leceipt by signing Qn,d returning one copy of this tronsmitfQI or~leC:~t~)[l~~~mdSsion Received ~ Date: . Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@ unocal.corn UNOCA, Beverly Harrison Business Ventures Assistant DATA TRANSMITTAL November 16, 2001 To: Lisa Weepie 333 W 7th Ave, #100 Anchorage, AK 99501-3539 Alaska Oil & Gas From: Beverly Harrison 909 W. 9th Avenue Anchorage, AK Unocal Alaska 99501 Transmitting the following: VISION 'DENsITY NEUTRON : '2/5 INCH 8/1/2® 10160-12551' 1 MRU K-18RD B-Line i "~'i'§"i'~'~"'"'Ei~'~"§'i'¥~' 0'~'~6~'"'": ........... ~"""i"~"~'~ ............................ ............. ................................. i'"'"'""~"~"O"'"'~:"i""~'"~"~ ~:i'""i"~'~ ..................... COMPLETION RECORD 15 INCH 8/28/20 i6300-12550 1 MRU K-laRD Fi m i"~b'~'iEE'E':~'i'~'~'"'F~ ~'~'i~'~ ................................... ~""i"~'~'R ........................... ~/~'~'~) ........ i'"i"8'b'~:'i'"i"~'~ ................... i'"l"~'~'O"'~':'i"~'~'~ .............................. Di'i'~ ....................... "~ ~'~'iEi'""E ~'i'6 'i~'"'i~'E'~ 6'~'i~ ................................. ~'" 'i"i~'~ ~ ......................... ~/~'~ ~ .......... ~"i"§ 6'f 7i"i"~i'~ § ................... i'" "~'i~'O" "k':'i"~'~'i~ ............................... i~':'i~i~'~ ............ "~6'~'~'E'E¥i'6~""~'E'~6'~'~ !' ~'"i'~'~'~ §/~'~/~'~'"'"' "~'~'~':'i"~ ~'~'6 i'"i"~"~'O'"~':'i"~'~ ~ ~'L' ~'ir~'~ ........... ~'Di'§'i'6~'"'~'E'~'§'i'~'""~E'O'~'~'6~'":'"'"i"~/~'"'i'~'6'~ ............... ~/i'/~6'0 ........ i"6'i"~6:i"~'~'~'i'""! .............. i'"'i"~"~'O'"'k':i"~'~'~'"§'~'i ........... ~':Ei'~"~ ........... t"~"~i"~'~"E'"'"'~"E'0'~ i'"~'""'i"~"~'i:i' ................................ i'"'§/~"i"/~"8 ............... i'"'8'~'~"8':i'"8~'~'''''''' ........................... i'"i'"'~'~"0"'"'~:~'~ i""~'i"i~ .................................... Please acknowledge receipt by signing and returning one copy of this transmittal or FAX tS i~9i~'~) ~3- Received ~,pr3,~'"'/. G/"~ Date: NO'V 1~ 200~ I A~c~e Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com UNOCAL Beverly Harrison Business Ventures Assistant DATA TRANSMITTAL November 16, 2001 To: Lisa Weepie 333 W 7th Ave, #100 Anchorage, AK 99501-3539 Alaska Oil & Gas From: Beverly Harrison 909 VV. 9th Avenue Anchorage, AK 99501 Unocal Alaska Transmitting the following: LOG TYpE SCALE I LOG DA,TEI,,INTERVAL [CO Well Medium, l Survey.,. Re.p..,ort 7/31/01 2:~ MRU K-18RD Paper §'~"~'i'~"~'i~'~'i~"i"'"~'~'~'~'~''''''''''' i ' i~'i i"'"'"'~' ~': 5 ~'~'~'~'"i ....................... .... §'~'"~"'"'~'~'~"~ ~/i'"'~"i~'"'"'~'"~'0'""'~:"i'"~'"~"~'""~'~'i ................ ~"~"~'~"i ................... "§'~'~'i'~'~'~'~'i~'~'i'"~'~'~'~"'"'i ~/i"~"i I ................ i'""~'~'0'"~:'i"~'~5'"'~¥i ............ i~'~'~'i .............. "§' ~'"~'~'~ ~/~i~'i ~'~'~'i .............. RECEIVED Please acknowledge receipt by signing and returning one copy of this transmittaN:~AX~ t~ (~1~2 63-7828 , A~ct'~orage STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION 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 California (UNOCAL) 201-117 3. Address 8. APl Number P.O. Box 196247 50- 733-20254-01 4. Location of well at surface .................. -: ~'" .'--:7,'~ .~ ~ '.~ 9. Unit or Lease Name 691' FSL, 82' FEL Sec 17, TgN, R13VV, S.M. i ~';~,'V~;:i.L-T!q'" !! ~J":':~'~"~ ~[~II~?'~ i~ Trading Bay Unit At Top Producing Interval t :'" ''?: ~-,,~""- !; 10. Well Number At Total Depth i 'h-~':-:~:', !! ~ II;il'~;r,,~',~""~ ~ 11. Field and Pool 1964' FEL, 460' FNL, SEC 19, TgN, R13W ;i McArthur river Field 5. Elevation in feei (indicate KB, DF, etc.) i .............. I.E Lease Designation and Serial No. Hemlock/G Intervals 34. 85'I ADL 18772 , - 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 7/8/01 8/12/01I ~ ~' Z ~',Ot .,,~'~ 62 feet MSLI 1 , 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) ]19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12550'/9559' 12540'/9552'I Yes: X No:I 296 feet MD N/A 22. Type Electric or Other Logs Run Schlumberger Anadrill MWD/LWD GR, Resisitivity, Neutron Density 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 24" SURF 369' Driven Driven 0 13-3/8" 68 K-55 SURF 2477' 17-1/2" 1800 sx 0 9-5/8" 47 USS-95 SURF 6750' 12-1/4" 1000 sx Cut 9-5/8" Window 7" 29 L-80 6558' 12540' 8-1/2" 371 sx (78.5 bbls) 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ~,,~ i O~TH~MO> I ~AO~s~T,MO' G-5 11604 ~ 11624; 11624 - 11654; 11654 - 11674; 11687- 11717 2-1/2" PJ 6spf 4-1/2" 6,528' G-7 11807- 11842 2-1/2" PJ 6spf 3`1/2" 10992' 7" Baker Ret. @ 10930' HK-1 11878 - 11888 2-1/2" PJ 6spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. HK-2 11917 - 11937; 11935 - 11960 2-1/2" PJ 6spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATER IAL USED HK-3 12040- 12052; 12053 - 12070 2-1/2" PJ 6spf HK-4 12108 - 12131 2-1/2" PJ 6spf HK-5 12224- 12241; 12262 - 12270 2~1/2" PJ 6spf Top Perf 8822' TVD Bot Perf 9350' TVD 27. PRODUCTION TEST ,,, Date First Production I Method of Operation (Flowing, gas lift, etc.) 8/27/01I GAS LIFT Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 9/22/01 12 TEST PERIOD => 160 79 229I 490 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY-APl (corr) Press. 80 1020 24-HOUR RATE => 320 157 457 34 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ORIGINAL RECEIVED OCT 0 2 Z001 Alaska 0il & Gas Cons. Commissio~ Anchorage Form 10.407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. . G 1 11235 8535 G-2 11347 8625 ~G-3 11401 8668 G-4 11434 8695 G-5 11584 8815 G-6 11768 8962 G-7 11786 8976 HK-1 11843 9021 HK-2 11914 9077 HK-3 12013 9153 HK-4 12090 9213 HK-5 12223 9315 HK-6 12297 9371 HK-7 12371 9426 W. FO R ELAN D 12462 9494 31. LIST OF ATTACHMENTS 32. I hereby certify that the for_ego~ng is true and correct to the best of my knowledge Sig ned~~/~lJ~,/~P~ Title ~ [///,~ V~ ?rJ.~/J INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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". ORIGINAL Trading ga) Unit %'ell ¢¢ K-ii8 RD Comp[eeed 9122101 RKB to TBG Head = 34.85' Tree connection: CASING AND T4 BING DETAIL SIZE '~5, 'l' GP, ADE CONN fl) TOP BTM, 21" Driven Sm £ 369' 1%3/8" 68 K-55 Butt [2 515" Smf 2,477' 9-~/8" 47 USS-95 Butt 8681" Surf 6,740' T' ~ ,,~-, 29 L-80 BIC-KC 6 184 6.558' 12.540' 126 L-80 BTC 3 958 34 85' 6528' 92 L 80 B['C 2992 6,528' I0,992 3485' 3958 12" x 4-1/2" O( T type ~/'ft-TC-iA'' Butt [bg tlngr I. 296' 3182 Baker FE-5 TRSSSV 3. 6526' CrossoveL ,4-1/2'* x 3- I/2- Bi C ( 1 92') 4. 6558' ZXP Liner ['op Packer 6. 10,930' 2920 7" Baker Model FIll Retrievable Packer 1 2413' 3.833" 4-1,/2' SFO-2 GIM; R-2 --7~: _3.833' i 4-1,,'2" $FO-2 ©I,M; R-2 3 5478' 3.833" I 4-1/2" SFO-2 GLM; &l 6483' 3.833" [ 4-1/'2" 5FO-2 GLM; R-2 ~.i ..... 2.867" I 3-1'2" SFO-1 (ii.M; R-I 6 [ 8205' 2.86T' 3-i/2' SFO-I GLM; R-I 719023, -l-5]g~7; I 3-~,"2" sFo-i dLM; Valve/RK Latch Valve,/RK Latch Valve/P,K Latch Valve/RK I ,atcl~ Valve/'BK-2 [,arch Valve/BK-2 Latch Valve/'BK-2 L,atch Valve/BK~2 Latch Valve/BK-2 Latch 3-I,'2" SFO-1 GL, M; R-I Orifice,,'BK-2 Latch E Proposed _--G zone Perfs Proposed _Hemlock =Perfs PBTD = 12496' TD = 12550' MAX HOLE ANGLE = 53° (~ 8761' 3 11,604 11.62~ II.624 11,654 30 I I1,687 11,717 (:~7~7~ I I~807 I1 842 937 11.935 11.960 HK-3 !12,040 IZ052 i 12,053 12,070 HK-4 I 12,108 12.i31 HK-5 i 12,224 I2,241 3¢ 25 6 12 ! 6 17 i6 23 ] 6 K- 18RID ST1 Actual REVISED By RAW': 09/26"0 ! UNOCAL K-18RD Re-Drill Daily Summary Unocal Alaska Drilling Daily Summary Report K-18RD Re-drill 7/8/01- 9/22/01 7/8/01 7/9/01 7/10/01 7/11/01 7/12/01 7/13/01 7/14/01 7/15/01 7/16/0i 7/17/01 7/18/01 7/19/01 7/20/01 7/21/01 7/22/01 7/23/01 7/24/01 ' CIRC 1 DP volume. RD Dowell and POOH & LD cement stinger. MU whipstock bha & RIH, tag cement retainer at 6774' and set whipstock (25R, TOW 6750', BOW 6766'). Swap to OBM and start milling window (WOM=3K, TORQ=10K, RPM=60). Continue milling the window with OBM 6759' to 6785', and with no losses. POOH and LD milling assembly. MU drilling BHA #1 and RIH. Slide out through the window to'6770'.. DRLG 8-1/2" Hole to 6880'. MWD failed, POOH to change out MWD. RIH to resume DRLG 8-1/2" Hole. DRLG/Slide 8-1/2" Hole to 7843'. 859' of hole in 24hrs with average ROP of 35.8 ft/hr. DRLG/Slide 8-1/2" Hole to 8444'. 601' of hole in 15.5 hrs, Avg. ROP 38.8 ft/hr. POOH for Bit change. Test BOPE. RIH with BHA #5 and Bit #3 = HYC PDC. Drill 8-1/2" Hole from 8,444' - 8575'. 131'/2.5 hrs ROP=52.4 DRLG/Slide 8-1/2" hole from 8575' to 9315'. 740' in 24 hrs; ROP 46.6 ft/hr. DRLG/Slide 8-1/2" hole from 9315' to 9666'; 351' in 15.98 drlg hrs, ROP 22 ft/hr. POOH w/BHA #5 bit #3. Tight @ 7098' (Pull 30K over Pickup weight). DRLG 8-1/2" hole from 9666' to 9900'; 234' in 10.7 drlg. Hrs at 21.9 ft/hr. DRLG/Slide 8-1/2" hole from 9900' to 10,411'; 511' in 19.5 drlg hrs at 26.2 ft/hr. .' DRLG/Slide 8-1/2" hole from 10411' to 10696'; 285' in 17.14 hrs at 16.6 fl/hr. DRLG/Slide 8-1/2" hole from 10696' to 10789', 93' drilled in 10.14 hrs at 9.2 ft/hr; POOH to change out bit #4/BHA #6. RIH with Bit #5/BHA #7; DRLG/Slide 10,789' to 11,049'; 260' drilled in 12.13 hrs with a ROP of 21.4 ft/hr. DRLG/Slide 8-1/2" hole from 11,049' to 11,272'; 223' drilled in 18.56 hrs with a ROP of 12.0 ft/hr. DRLG/Slide 8-1/2" hole from 11,272' to 11,438'; 166' drilled in 19.82 hrs with a ROP of 8.4 ft/hr. DRLG 8-1/2" hole from 11,438' to 11582; 144' drilled in 16.08 hrs with a ROP of 9.0 ft/hr. POOH with dulled bit #5 which drilled a total of 793' in 66.6 hrs with a ROP of 11.9 ft/hr. 25K over pull @ 7150' normal drag for deviated hole. Continue POOH; Test BOPE, Iow 250 psi, high 3000 psi BOPE TEST OK; RIH with Bit #6; DRLG 8-1/2" hole from 11,582' to 11628'; 46' drilled in 3.60 hrs with a ROP of 12.8 ft/hr. K-18RD Daily Summary.doc ! 09/26/01 K-18RD Re-Drill UNOCAL( Daily Summary 7/25/01 DRLG 8-1/2" hole from 11,628' to 11,888'; 260' drilled in 20.18 hrs with a ROP of 12.9 ft/hr; POOH with dulled bit #6. 7/26/01 Present Depth 11,888'. Condition Hole to run Wireline UBI log and POOH with BHA #8/Bit #6. Run UBI log from 11,852' back to 9000' MD with no problems. 7/27/01 PU BHA #9/Bit #7 (LWD-ADN6/CDR). Tight @ 7174' - 7251' work through same, 9550 - 9580' had to kelly up & ream through & fired jars twice, 11,249 - 11,279' caught on slips, stand back std & PU working single, fire jars & ream. DRLG 8-1/2" hole from 11,888' to 11,897'; drilled 9' in .71 hrs at 12.7 ft/hr. 7/28/01 Drill 8-1/2" hole from 11,897' to 12,195'; drilled 298' in 21.56 hrs at 13.8 ft/hr. 7/29/01 Drill 8-1/2" hole from 12,195' to 12,208'; drilled 13' in 1.43 hrs at 9.1 ft/hr; POOH with BHA #9/Bit #7. RIH with BHA #10/Bit #8 with no problems. 7/30/01 Cont. RIH; Set dn@ 10,400 fire jars 7 times to free pipe. Drill 8-1/2" hole with LWD from 12,208' to 12,379'; drilled 171'in 18.9 hrs at 9ft/hr. 7/31/01 Drill 8-1/2" hole and LWD from 12,379' to 12,440'; drilled 61' in 7.1 hrs at 8.6ft/hr. TD called do to .Geological problems of drilling through fault and missing the bottom sections of the Hemlock. Circulate & POOH to sidetrack. PU cement Stinger and RIH to lay in sidetrack plug. 8/01/01 Pump and balance 55bbl cement plug from 10487' to ~9800'. POOH with no problems. Test BOPE, OK. MU Kick off BHA and RIH. 8/02/01 Continue RIH. Wash at a min. rate f/9184' t/9848', tag cement top. Drill cement plug and jump plug/cut trough f/10220 t/10240. Time drill f/10240' t/10273 @ 150 deg left. Slide f/10273 t/10290 @ 135 deg left. Drilled 136' in 13.5 hrs at 10.1 ft/hr. 8/03/01 Drill/slide 8-1/2" hole f/10290 t/10731. 441' in 15.41 hrs at 28.6 ft/hr. 8/04/01 Drill/slide 8-1/2" hole f/10731' t/11,105, 374' in 15.02 hrs at 24.9 ft/hr. 8/05/01 Drill/slide 8-1/2" hole f/11,1 05 t/11479'; 374' in 18.7 hrs at 20.0 ft/hr. 8/06/01 Drill 8-1/2" hole f/11,479' t/11,663'; 184' in 7.98 hrs at 23.1 ft/hr. PDC Bit pulled on ROP's. TOH clean. L/dh BHA #1 & MU BHA #2. 8/07/01 RIH (Clean Trip). Drill/Slide 8-1/2" hole f/11,663' t/11,852. 189' in 14.0 hrs at 13.5 ft/hr. 8/08/01 Drill 8-1/2" hole f/11,852 t/12,025'; 173' in 13.88 hrs at 12.5 ft/hr. Pull bit on hrs (Clean Trip). RU for BOPE test. 8/09/01 Finish BOPE test (OK); RIH to Btm. Drill 8-1/2" hole w/LWD f/12,025 t/12,173; 148' in 12.0 hrs at 12.3 ft/hr. 8/10/01 Drill 8-1/2" hole w/LWD f/12,173' t/12,431'; 258' in 13.9 hrs at 18.6 ft/hr. POOH making "MAD Pass" f/12,025' t/11,061 '. 8/11/01 8/12/01 Continue "MAD Pass" and finish TOH; RIH with new bit and Slick LWD tools. Drill 8-1/2" hole (LWD) f/12,431' t/12,470'; 39' in 2.5 hrs at 15.6 ft/hr. Drill 8-1/2" hole (LWD) f/12,470' t/12,550'; 80' in 5.11 hrs at 15.7 ft/hr. TD well at 12,550'. Made a MAD -- Pass f/12,100' t/11,900' to compare slick ADN6 tool with stabilized ADN6 that was on previous MAD Pass. Pump weighted sweep to condition hole and POOH. 8/13/01 LD BHA & RU to RIH with 7" Liner. K-18RD Daily Summary. doc 2 09/26/01 UNOCAL K-18RD Re-Drill Daily Summary 8/14/O 1 Continue to RIH with 7" Liner on 3-1/2' X 5" DP. Tag bottom @ 12,550'; Break circulation at 78 GPM increase rate slowly to 155 GPM @ 500 psi. PU to 12,540' space out for cementing. Pressure up to 2000 psi to set liner hanger and release. Pump 40 bbls of chemical wash followed by 50 bbls MudPush XLO spacer. Mix and pump 78.5 bbls of 15.8 ppg cement slurry. Displaced with 5 bbls of water followed by 118 bbls of OBM. Bumped plug increased pressure to 1600 psi and held for 2 minutes. Floats held CIP @ 19:30 hrs. Set ZXP liner packer and pressure test liner to 1500 psi - 5 Min. OK. Reverse circulate 2 drillpipe volumes. No cement returns observed. RD cement equipment. Pump dry job and POOH. 8/15/01 Continue POOH/LD 5" DP. LD Liner running tools. RU to test BOP's Test OK. RU to RIH with 3-1/2"X 5" DP and liner clean out BHA. 8/16/01 Continue RIH with Clean Out BHA on 3-1/2" DP. Tag cement at 12,408 drill cement and Landing collar to 12,453. Continue to RIH f/12453 t/12,497 (float collar). No indication of cement between baffle plate and float collar. Circulate and Swap out OBM to KCL. 8/17/01 Continue displacing OBM with KCL. POOH LD 5" X 3-1/2" DP. 8/18/01 Continue LD DP. RU to RIH with 3-1/2" Tbg & GLM. 8/19/01 Continue RIH with 3-1/2" X 4-1/2" Tbg & GLM completion string. RU to land tubing hanger. 8/20/01 Land Tubing Hanger. Spot CRW0132 w/3% KCL pill in the annuls from top of production packer to liner top. Drop Baker shear out ball Pressure up t/3000 psi to set the Baker HS packer- Bleed off Tbg. To 1000 psi. Pressure up Tubing to 3850 psi while monitoring annulus sheared out the ball seat. Pressure dropped to 0 psi and circulation up the annulus. Packer did not set. Pulled hanger pu 2 joints and rih 10 past where packer should have been with no tag. POOH with completion string (LD GLM & Packer). 8/21/01 Inspect Packer, and visual inspection confirmed that the packer did not set. MU new packer, RHC plug installed in X nipple, and RIH with 3-1/2" X 4-1/2" GL Completion changing out seal rings. 8/22/01 Land hanger. RIH with setting bar on slickline and land in RHC plug @ 10980' (WLM RKB). Pump down tbg & pressure up in 500 psi increments t/3000 psi held 15 min. for tbg test (OK). Noticed pressure bobble at 2250 pis which indicated shear of packer shear screws to set packer. Pull setting bar up 30' & Pump down tbg to test packer and had full returns on annulus. Re-set setting bar and pressured up t/5000 psi & held for 10 min. Bleed off pressure & PU setting bar 30'. Pump down tbg w/full returns on the annulus @ 60 psi. POOH w/SL and L/dn setting bar. RIH w/GS pulling tool & pull RHC plug. POOH & recover RHC plug. RD SL and pumping equ. ipment. POOH standing back TBG and L/dn GLM's Visual inspection of Packer was the same as the 1sT failure. Cut and Slip while waiting on Baker FHL packer which was flown down from Prudhoe Bay. MU new FHL packer and RIH out of derrick w/3-1/2" X 4-1/2" tbg and change out seal rings & reinstall GLM's. 8/23/01 Continue to RIH with tubing. P/up tbg hanger & landing jt & test control line. Land tbg w/pkr @ 10926' and run in LDS. RU SL and rih w/setting bar & land in RHC plug @ 10971' wlm rkb. Pump down tbg & pressure up in 500 psi stages t/3000 psi & held for 15 min for tbg test (OK) bleed of pressure. Noticed a good indication of pkr set while increasing pressure @ 2050 psi. Unseat setting bar pooh 30' w/SL. Pump down tbg & pressure up to 1500 psi for 15 min w/no pressure loss indicating a good pkr test. POOH w/SL and RIH to retrieve RHC plug. R/dn SL. R/dn GBR & set BPV. N/dn Tree. Released Rig @ 2400 hrs. to leg move AFE # 150942. 8/24/01 On Leg move AFE. 8/25/01 No costs. Production continued to unload well. 8/26/01 R/up SWS rih w/GR CCL. L/interval f/12,700' t/6100' & POOH. K-18RD Daily Summary. doc 3 09/26/01 UNOCAL K-18RD Re-Drill Daily Summary 8~7~1 M/up & arm gun run #1 30' 2-1/2" Power Jet loaded @ 6-SPF & CCL. RIH and Tie in to place gun on depth, Perforate G-5 interval f/11687' t/11717'. POOH and shutdown for rest. M/up run #2 20' PJ loaded @ 6- SPF. Tie in place gun on depth and perforate G-5 interval f/11654' t/11674'. POOH. M/up run #3 30' 2- 1/2" PJ @ 6-SPF. 8/28/01 RIH w/gun run #3 tie in place gun on depth and perforate G-5 interval f/11624' t/11654'. POOH. M/up gun run #4 20' 2-1/2" PJ @ 6-SPF. RIH, tie in to place gun on depth and perforate f/11604' t/11624'. POOH. R/dn SWS & install tree cap. Suspend perforating operations and turn well over to production for test, GL survey and 3 day PBU survey. 9/9/01 R/U SWS. M/U Gun run #1, 2-1/2" Power Jets loaded @ 6spf. RIH and tie in to place guns on depth. Perforate HK-5 f/12,262 t/12,270. POOH L/D fired guns, and POOH. 9/10/01 M/U Gun Run #2, 2-1/2" Power Jets loaded @ 6spf. RIH and tie in to place guns on depth. Perforate HK-5 f/12,224 t/12,241. POOH w/Gun Run #2. M/U Gun Run #3, 2-1/2" Power Jets loaded @ 6spf. RIH and tie in to place guns on depth. Perforate HK-4 f/12,108 t/12,131. POOH. R/Dn SWS. Turn well over to production for test. 9/17/01 R/U SWS. M/U gun run #1, 2-1/2" Power Jets loaded @ 6spf. RIH and tie in to place guns on depth. Perforate HK-3 f/12,053 t/12,070. POOH. M/U gun run #2, 2-1/2" Power Jets loaded @ 6spf. 9/18/01 RIH and tie in to place guns~'on depth. Perforate HK-3 f/12,040 t/12,052. POOH. R/D SWS. Secure well and release to production. 9/20/01 R/up SWS. M/up gun run #1, 2-1/2" Power Jets loaded @ 6spf. Rih and tie in to place guns on depth. Perforate HK-2 f/11,935 t/11,960. POOH. M/up gun run #2, 2-1/2" Power Jets loaded @ 6spf. Rih and tie in to place guns on depth. Perforate HK-2 f/11,917 t/11,937. POOH, R/dn SWS, and turn well over to production for test. 9~2~1 R/up SWS. M/up gun run #1, 2-1/2" Power Jets loaded @ 6spf. Rih and tie in to place guns on depth. Perforate HKol f/11,878 t/11,888. POOH. M/up gun run #2, 2-1/2" Power Jets loaded @ 6spf. Rih and tie in to place guns on depth. Perforate G-7 f/11,807 t/11,842. POOH, R/dn SWS, and turn well over to production. FINAL REPORT K-18RD Daily Summary.doc 4 09/26/01 o o o I 0 o (',,1Lf') u'-) 0 '~'~ ~ 0 ,--I ~ .-F + -t.- fi.) ...... ~> *~ ;::::I-- . .,--t '4.4 'J,-.I '+4 mQ~ ~ 0 0 0 E rJ 0 r.J 0 r,J r,J (L) ~ (L) d d I · G G 0 0 0 ~q0 0ooo f~ ,-I o o o q) ~ · ~ ,:::; ,:::; o ~ ..... ~ · · q.) - - ~ 4-~ ~ O - - o o o o II ,-t ,--t ~ II 0 r~ ~ II 0 ;~ ::>. II ~ 13-~J..J II I I I I I I I I I I LD kD LO LD LD LD kD kD LO L.O 0 > ~0 o o c0 ~0 0 0 00C'~ II $ ~ II II m .P ...--. II o o o oa u~ II ~q ~ II o o o ~ ~ II ~ ~ ~q II ..... 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((I3AIAI) 6 ptre 8 um uo ut um sm~ 0od!leD o!uosmllfl/~x Ll.!suoo-oql!'I uo~lnoN Ieqlnm!zv) NCI~ puc (Xelt emtueD puc Xl!~!ls'!so~l lunO polusuodmoD):803 '(OAklN) £ um uo popnlouoo sm~ pu~ Lull mumeD (0tIN) oSlnd ~OAXOd qlm (OAXlAI) gum uo tre, i~oq uo.nunleAO uo!lv, ut/o2t NOI~I,VflqVA~ NOI&VIA~O~I dODdOqlUnlq:ls Schlumberger Anadrill Date: Well Name: Company: API Number: Oil Pool: Field: Rig: 13-Aug-01 K-18RD ST1 UNOCAL 50-733-20254-02 McArthur River King Salmon Platform / Nabors Rig 58 Anadrill Field Crew: Carlos Pacheco Mark Brown Wisam Chan Anadrill Field Support: Ope:rations Manager Field Service iManager Joseph LeBlanc Nate Rose SERVICES PROVIDED Service Service Dates Directional Survey Service (DSS) Power Pulse (Real time) Gamma Ray Compensated Dual iResisfivi'ty (CDR) Azimuthal Neutron Density (ADN6) Mad Pass (CDR, ADN6) Mad Pass (CDR, ADN6) 01 -.Aug-01 - 12-Aug-01 01-Aug-01 - 11-Aug-01 09-Aug-0 l. - 12-Aug-01 09-Aug-01 - 12-Aug-01 10-Aug-01 - 11.-Aug-01. 12-Aug-01. - 1. 2-Aug-01 Depth Interval (',17t3 10240'- 12551' 10160'- 12431' 11997'- 12523' 11939'- 12466' 1.2025'- 10800' 12100'- 11900' OPERATING STATISTICS Total MWD Pumping Hours: 179.83. Total MWD Below Rotary Hours: 255.3 Total MWD Footage: 231.1 Total MWD Runs: 4 Total iLWD Pumping Hours: 53 Total LWD Below Rotary. Hours: 90.3 Total LWD Footage: 526.25 Total LWD Runs: 2 JOB PERFORMANCE DIRECTIONAL The final survey point was 12489 ft with an inclination of 41.92 degrees and an azimuth of 242.29 degrees. This survey was projected to TD, giving the final bottom hole location: Measured Depth: True Vertical Depth: Displacement at Azimuth: 12551 ~ 9559.0 7343.84fi: Page 1 of 2 Schlumberger FORMATION EVALUATION Formation evaluation began on mn I with Power 'Pulse (M10) Gamma Ray and was concluded on run 3. CDR (Compensated Dual Resistivity and Gamma Ray) and ADN (Azimuthal Neutron Litho-Densi .ty w/ Ultrasonic Caliper) was run in on run 3 in Recorded only, in run 4 the LWD tools were used in Real Time and Recorded Mode. All measuremems were recorded in real ti:me and at the conclusion of 'the LWD runs the tools were dumped and recorded memory data generated. The real time data (Power Pulse M10) Gamma Ray (real time only), CDR , ADN was of good quality, iMad Pass mn with CDR, ADN (recorded only) was preformed on the way out of the hole run 3 from top of Hemlock back up to the (G sands) and was of good quality. The real time and recorded logging data was e-mailed to Unocal Geologist -iMatt Frankforter at the conclusion of the well. Final data was presemed :in Ascii format and the primed PDS log files were generated using the requested :formats. TRANSVERSE SHOCK. Transverse shock is monitored in the MWD. Shocks were i~ffrequem and moderate in severity. Anadrill appreciates the opportu:nity 'to provide 'Unocal - Alaska, with MWD and LWD services. Sincerely, MWD/LWD Cell Manager Page 2 of 2 Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd@unocal.corn UNOCAL Debra A. Childers Technologist DATA TRANSMITTAL August 30, 2001 To: Lisa Weepie From' Debra Childers 333 W 7th Ave, #100 909 W. 9th Avenue Anchorage, AK 99501-3539 Alaska Oil & Gas Anchorage, AK 99501 Unocal Alaska Transmitting the following: TBU K-18RD PR1 AZIMUTHAL DENSITY INAGE/DIP 1:600 7/29/01 11750-12200 1 B-Line TBU K-18RD RD1 AZIMUTHAL DENSITY INAGE/DIP 1:600 / 1:120 7/29/01 11750-12200 1 B:Li~e TBU K-18RD PB1 FACIES ANALYSIS 8/21/01 9000-11850 1 B-Line TBU K-18RD PB1 BOREHOLE BREAKOUT 8128101 9000-11850 1 B-Line TBU K-18RD PB1 UBI IMAGES AND DIPS 7/26/01 9000-11850 1 B-Line TBU K-18RD CEMENT RETAINER 5 INCH 7/7/01 6550-6950 1 B-Line TBU K-18RD CEMENT RETAINER 5 INCH 7/7/01 6550-6950 1 Film TBU K'18'RD ULTRASONIc B~'REHO'i~'E"IMAGER 5 INCH 7/26/0i' 6500-1i'845 1 B-Line ~TBU I~:i"sRD ULTRASONIC BOREH'OEE IMAGER 5 INCH .... 7/26/01 6500-11845 1 Film TBU K-13RD CEMENT BOND TOOL 5 INCH 5/10/01 7000-8865 1 B-Line TBU K-13RD CEMENT BOND TOOL 5 INCH 5/10/01 7000-8865 1 Film TBU K-13RD CASING RETAINER SETTING TOOL 5 INCH 5/10/01 1 B-Line TBU K-13RD CASING RETAINER SETTING TOOL 5 INCH 5/10/01 1 Film Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received by~ ~ G] l.~,, / Date: ~t~"~O -' O / STATE OF ALASKA {,' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: __ Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: X Puii tubing: Variance: Perforate: Other: -- 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 100 KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Anchorage, AK 99519 Stratigraphic: Trading Bay Unit/McArthur River Unit Service: 4. Location of well at surface Conductor No.3, Leg 1 8. Well number 690' FSL, 82' FEL Sec 17, T9N, R13W, SM K-18RD At top of productive interval 9. Permit number 549' FNL, 1099' FEL, Sec 19, T9N, R13W, SM 201-117 At effective depth 10. APl number N/A 50-733-20254-01 At total depth 11. Field/Pool 250' FNL & 2394" FEL, Sec 19, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 12440' feet Plugs (measured) None true vertical 9144' feet Effective depth: measured N/A feet true vertical N/A feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 369' 24" Driven 369' 369' Surface 2477' 13-3/8" 1800 sx 2477' 2293' Intermediate Production 6750' (window) 9-5/8" 1000 sx (From 12,116') 12116' 9639' Open Hole measured 6750'- 12,440' true vertical 5567' - 9144' 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 1-Aug-01 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Jane Williamson Date 7/31/01 Service: (water injector) 17. I hereb~hat the for/~loin[j/~f~and correct to the bestof my knowledge.//~,, ~. ,, Signed:~_ ~/~//~ ~j~lf/~_.//~~~~ Title: //~,/~"/,//~ J/']¢¢/~//~;//'~ t Date.'~//~¢~t / FOR COMMISSION USE ONLY' / Conditions of approval: Notify Commission so representative may witness ,/ Approval No. Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- t-~__'~'t_.~ r,,l~y.~,~,.-~-, ~ ,~,~ t l, ' Ol~lOl~ ,SIGNED BY '~- ~. Heusser ' e "ltl ¢' Approved byorderoftheCommission,~' A~~~I~'~I9"O c°mmi.._ssion--e,l',~ ,,-,r'"'~ Date /~'r/7~/ Form 10-403 Rev 06/15/88 RECEIVED ORIGINAL Alaska Oil & Gas Cons. Commission Anchorage SUBMIT IN TRIPLICATE UNOCAL King Pl'~._orm K-18RD ST1 Drilling Summary Revised 8/02/01 K-18RD ST1 Summarized Procedure Set Cement Plug to Sidetrack · See attached procedure for details Kick off of Cement Plug and Drill 8-1/2" Hole · RIHWith BHA · Drill 8-1/2" Hole to 12,120' · Log 8-1/2 Hole section with LWD Run 7" Liner · Change out top pipe rams · Test BOPE · RU casing crews for 7" liner · RIH with 7" liner · Continue to RIH with Liner on drill pipe · Set liner hanger and release running tool · Cement liner · Set isolation packer · POOH with running tool. Clean out 7" liner and displace to 3% KCI using FIW as base fluid · RIH with 3-1/2" liner clean out string · Displace liner to 3% KCI · POOH LD excess pipe Run Completion · Pull wear bushing. · RU to run 4-1/2" X 3-1/2" GL completion · PU rabbit and run completion · Space out, install SCSSV and PU hanger · Land hanger, displace well to inhibited water and set packer. · LD landing joint. · RD tubing running equipment. · ND BOPE · Install tree and test. · Install Flow lines. · Prepare for rig move. · Perforate well after rig move. K-18RD ST1 Summary 1 08/02/01--9:33 AM ._1Z7 ...a. 00000 00000 00000 ~0~ ~~0 ..... ~0~ ~0~ ..... ~00 .... ~o~ ..... 00000 00000 ~0~ ..... 00000 ~~o ~0~ ZZZZZ ~0~ ~~0 ~0~ 0~0~ 0 0 O~ Client: Unocal Well: K-18RD (P4) Pield: McArthur River Unit SEructure: King Salmon Scale: I in = 500 ft Date: 01~Aug~2001 Schlumberger A A A F- O Z -500- -1000- W -1500 -2000- -8000 -7500 -7000 ~6500 -6000 -5500 -5000 -4500 500 .... ~____ I I ~ ~ ~ ~ - 5OO · -500 --1000 -~1500 -~2000 -8000 -7500 -7000 -6500 -6000 -5500 -5000 -4500 <<< WEST EAST >>> VERTICAL SECTION VIEW Client: Unocal Wei]: K-18RD Schlumberger 6500. 7000, 7500. 6000, 6600. 9000, 9500. 10000. '%,, H0id Angle 36,32° 5000 5500 6000 6500 7000 7500 Vertical Section Departure at 253.97 deg from (0.0, 0.0). (1 in = 500 feet) UNOCAL ALASKA RESOURCES, INC. K-18RD & K-18RD-ST#1 McARTHUR RIVER FIELD Section 17. TgN-RI3W Cook Inlet, Alaska August 2, 200f Brian O'Fallon- Sr. Logging Geologist Ralph Winkleman - Logging Geologist Chris Ornt- Logging Geologist Barry Wright- Logging Geologist Dick Ebright- Logging Geologist Peter Ramsey- Logging Geologist Jerry Stafford- Logging Geologist EPOCH UNOCALe K-18RD & K-IBRD-ST#1 UNOCAL ) Unocal Alaska Resources, Inc. K.18RD & K-18RD-ST#1 McArthur River Field Cook Inlet, Alaska TABLE OF CONTENTS WELL RESUME ..................................................................................................................... 3 LITHOLOGY SUMMARY (K-18RD) ........................................................................................ 4 LITHOLOGY SUMMARY (K-18RD-ST#1) ............................................................................. 18 DAILY CHRONOLOGY ........................................................................................................ 25 MUD RECORD (K-18RD) ..................................................................................................... 29 MUD RECORD (K-18RD-ST#1) ............................................................................................ 30 SURVEY RECORD (K-18RD) ............................................................................................... 31 SURVEY RECORD (K-18RD-ST#1) ...................................................................................... 33 BIT RECORD (K-18RD) ....................................................................................................... 34 BIT RECORD (K-18RD-ST#1) .............................................................................................. 35 DAILY REPORTS ................................................................................................................ 36 WELL LOGS (K-18RD) ...................................................................................... APPENDIX 1 WELL LOGS (K-IBRD-ST#I) ............................................................................ APPENDIX 2 [::l EPOCH 2 UNOCALe K-18RD & K-18RD-ST#1 WELL RESUME UNOCAL ALASKA KING SALMON PLATFORM K-18RD WELL NAME: K-18RD & K-18RD-ST#1 FIELD: McARTHUR RIVER FIELD REGION: LOCATION: COOK INLET, ALASKA SEC. 17 T9N R13W SM BOROUGH: KENAI BOROUGH STATE: ALASKA ELEVATION: RKB: 100.0' AMSL APl NUMBER: #50-733-20254-01 OPERATOR: Operator Representatives: Company Geologist: CONTRACTOR: UNOCAL ALASKA RESOURCES, INC. SHANE HAUCK, TERRY COLEMAN MATT FRANKFORTER NABORS ALASKA DRILLING DRILLING RIG: Toolpusher: MUDLOGGING COMPANY: Logging Geologists: MUD COMPANY: Mud Engineers: MWD COMPANY: MWD Engineer: DIRECTIONAL COMPANY: Directional Driller: CEMENT COMPANY: KING SALMON PLATFORM EPOCH WELL SERVICES, INC. BRIAN O'FALLON, RALPH WINKELMAN, CHRIS ORNT, BARRY WRIGHT, DICK EBRIGHT, PETER RAMSEY, JERRY STAFFORD MI JIM BROWN, MONTY KANTA, MIKE FORMAN ANADRILL/SCHLUMBERGER MARK BROWN, CARLOS PACHECO ANADRILL/SCHLUMBERGER MIKE WARD, M.VERY. CORKER DOWELL/SCHLUMBERGER WIRELINE COMPANY: SCHLUMBERGER EPOCH UNOCALe K-18RD & K-18RD-ST#1 LITHOLOGY SUMMARY (K-18RD) DRILLED TYONEK AND HEMLOCK (6785-12442') TYONEK (COMMEMCE LOG TO 12442') 6785 Sand = light gray overall with common salt and pepper appearance, individual grains dominantly light gray to light greenish gray to translucent gray, clear to frosted, white, common black lithics, rare dusky red; fine to scattered very coarse broken fragments, dominantly fine to medium; angular to subangular; poorly sorted; unconsolidated to very loosely consolidated with clayey supporting matrix; moderate to strong calcareous; trace to common black carbonaceous material; oil indicators masked by oil base mud. 6890 Sand = medium gray to medium light gray; very fine to fine to some medium to rare very coarse; subrounded to subangular and some angular mostly bit broken fragments; moderately to poorly sorted with clay and slight silt matrix; clays overall slightly organic; clasts mostly quartz and minor clay, coal, feldspar, and trace green; interbedded with claystone and coal and locally conglomerate; estimate mostly poor to fair porosity and permeability; very faint greenish yellow fluorescence and cut; oil indicators obscured by oil bas mud. 6985 Coal = black; very firm to hard; brittle smooth to occasionally striated surface texture; glossy vitreous luster; irregular to blocky wedge shaped cuttings; dominantly planar fracture with occasional birdeye and conchoidal fracture; present as thin interbeds and clasts in dominant tuffaceous claystone/sandstone formation; no visible gas bubbles present; lignitic 7035 Tuffaceous Claystone = light gray to light brownish gray with light greenish gray secondary hues; firm; rounded, irregular shaped cuttings; silty to gritty texture; dull to earthy luster; hydrophilic; very expansive when hydrated; soluble in water; trace black, microthin carbonaceous laminations and pieces; non calcareous; common thin coal beds and abundant sloughing coals. 7090 Sand = light to medium gray overall with varicolored individual grains dominantly light gray, translucent, frosted white, scattered light greenish gray lithics and rare reddish pink lithe; very fine to very coarse broken fragments, dominantly fine to medium; angular to subangular; moderately to poorly sorted; disaggregated to very loosely consolidated with clayey to silty supporting matrix; estimate poor to fair porosity and permeability; faint greenish yellow sample fluorescence and yellowish white cut fluorescence; oil indicators continue to be masked by oil base mud. [::1 EPOCH 4 UNOCAL ) K-18RD & K-18RD-ST#1 7170 Tuffaceous Claystone = light gray to light brownish gray with light greenish gray secondary hues; firm; rounded, irregular shaped cuttings; silty to gritty texture; dull to earthy luster; hydrophilic; very expansive when hydrated; soluble in water; trace black, microthin carbonaceous laminations and pieces; non calcareous; common thin coal beds and abundant sloughing coals. 7225 Sand = light gray overall with common salt and pepper appearance, individual grains dominantly light gray to light greenish gray to translucent gray, clear to frosted, white, common black lithe, rare dusky red; fine to scattered very coarse broken fragments, dominantly fine to medium; angular to subangular; poorly sorted; unconsolidated to very loosely consolidated with clayey supporting matrix; moderate to strong calcareous; oil indicators masked by oil base mud. 7290 Sand = light to medium gray overall with varicolored individual grains dominantly light gray, translucent, frosted white, scattered light greenish gray lithe and rare reddish pink lithe; very fine to very coarse broken fragments, dominantly fine to medium; angular to subangular; moderately to poorly sorted; disaggregated to very loosely consolidated with clayey to silty supporting matrix; estimate poor to fair porosity and permeability; faint greenish yellow sample fluorescence and yellowish white cut fluorescence; oil indicators continue to be masked by oil base mud. 7375 Claystone = medium gray to dark brownish gray to medium bluish gray to medium light gray; slightly firm; slightly to some moderately hydrophilic; subplaty to wedge often with rounded edges as reworked in part; overall slightly to some moderately organic; common flaky to very thin coal/carbonaceous lamina; some coal clasts and interbedded with platy to angular moderate to Iow grade coal; minor interbedded sand and conglomeratic sand and conglomerate; kaolic/ashy in part especially associated sand; noncalcareous; some slight very finely disseminated mica. 7455 Conglomeratic Sand = light gray to light bluish gray to bluish white; fine to coarse grains and coarse to pebble size grains and fragments; loosely scattered in sample to occasionally in clay matrix; clasts translucent to clear gray to occasionally green and red including quartz, chert, siliceous grains, and coal, and possibly include rounded clay clasts; clays ashy/kaolic and variably organic; poorly to very poorly sorted grading conglomerate and probably thinly bedded; estimate very poor porosity and permeability. 7520 Sand = light gray; fine to coarse grain; subangular to subrounded; moderate sphericity; moderately sorted with slight clay matrix; 80% quartz, and 20% light to dark gray to trace red and green clasts including partly siliceous clay, coal, and trace feldspar; estimate EPOCH 5 UNOCALe K-18RD & K-18RD-ST#1 poor to fair porosity and permeability; even dull greenish yellow fluorescence and instantaneous bluish white cut fluorescence; oil indicators obscured by oil based mud contamination. 7595 Claystone = medium gray to medium dark gray, some with brownish hue; slightly firm; smooth to moderately silty/gritty texture; subplaty to wedge shaped commonly with rounded edges as possibly reworked; slightly to very slightly hydrophilic; slightly to moderately organic grading carbonaceous shale with interbedded coal; occasionally grading poorly sorted sandstone and conglomerate; non calcareous; very slight very finely disseminated mica. 7660 Coal = black to some grayish black; very firm to slightly firm; hackly subplaty to angular fracture; Iow to moderate grade; smooth dull to polished luster; occasionally brownish black grading carbonaceous shale; slight microspecs of isolated pyrite crystals; interbedded in claystone and sandstone; slight bleeding gas. 7710 Claystone = medium gray to medium dark gray, some with brownish hue; slightly firm; smooth to moderately silty/gritty texture; subplaty to wedge shaped commonly with rounded edges as possibly reworked; slightly to very slightly hydrophilic; slightly to moderately organic grading carbonaceous shale with occasional interbedded coal and thin laminations; occasionally grading poorly sorted sandstone and conglomerate; non calcareous; very slight very finely disseminated mica. 7800 Coal = black with scattered dark, dusky brown secondary hues; firm to moderately hard; brittle at times; dominantly planar fracture with common birdeye and rare conchoidal fracture; blocky to platy; smooth to slightly micro gritty texture; polished to resinous luster; occasionally grading to carbonaceous shale; slight visible outgassing bubbles present. 7850 Sand = light gray overall, individual grains dominantly white, translucent, light gray and frosted, rare light green gray lithics; fine to occasional coarse fragments, dominantly fine to medium; angular to subangular; poor to moderate sorted; dominantly disaggregated, occasionally loosely consolidated with clay matrix; estimate poor to fair porosity and permeability; minor thin interbedded coals and abundant sloughing coal; gold sample fluorescence; instantaneous bright yellow cut fluorescence; oil indicators continue to be masked by oil base mud. 7925 Claystone = medium gray to medium dark gray, some with brownish hue; slightly firm; smooth to moderately silty/gritty texture; subplaty to wedge shaped commonly with rounded edges as possibly reworked; slightly to very slightly hydrophilic; slightly to moderately organic grading carbonaceous shale with occasional interbedded coal and thin laminations; EPOCH 6 UNOC, K-18RD 8, K-18RD-ST#1 occasionally grading poorly sorted sandstone and conglomerate; non calcareous; abundant sloughing coal. 7990 Coal = black to some grayish black; very firm to slightly firm; hackly subplaty to angular fracture; Iow to moderate grade; smooth dull to polished luster; occasionally brownish black grading carbonaceous shale; slight microspecs of isolated pyrite crystals; interbedded in claystone and sandstone; slight bleeding gas. 8040 Sand = light gray overall, individual grains dominantly white, translucent, light gray and frosted, rare light green gray lithe; fine to occasional coarse fragments, dominantly fine to medium; angular to subangular; poor to moderate sorted; dominantly disaggregated, occasionally loosely consolidated with clay matrix; estimate poor to fair porosity and permeability; minor thin interbedded coals and abundant sloughing coal; gold sample fluorescence; instantaneous bright yellow cut fluorescence; oil continue to be masked by oil base mud. 8115 Tuffaceous Claystone = medium to dark gray with scattered dark grayish brown secondary hues; firm to very firm; irregular shaped with rounded edges; silty to gritty texture; dull to earthy luster; good cohesiveness; poor adhesiveness; hydrophilic; expansive when hydrated; soluble in part; non calcareous; common thin interbedded coal and sloughing coal 8165 Coal = black with scattered dark, dusky brown secondary hues; firm to moderately hard; brittle at times; dominantly planar fracture with common birdeye and rare conchoidal fracture; blocky to platy; smooth to slightly micro gritty texture; polished to resinous luster; occasionally grading to carbonaceous shale; slight visible outgassing bubbles present. 8215 Sand = light gray; fine to coarse grain; subangular to subrounded; moderate sphericity; moderately sorted with slight clay matrix; 80% quartz, and 20% light to dark gray to trace red and green clasts including partly siliceous clay, coal, and trace feldspar; estimate poor to fair porosity and permeability; even dull greenish yellow fluorescence and instantaneous bluish white cut fluorescence; oil indicators obscured by oil based mud contamination. 8280 Tuffaceous Claystone = medium to dark gray with dark grayish brown secondary hues; firm to moderately hard; irregular rounded cuttings; silty to clayey texture dull earthy luster; hydrophilic; very expansive and soluble when hydrated; microthin black carbonaceous laminations non calcareous. [:1 EPOCH 7 UNOCALe K-18RD & K-18RD-ST#1 8330 Sand = medium light gray to very light gray to bluish white; grains very fine to medium and scattered coarse and pebble; subangular to angular including some bit broken fragments; moderately to poorly sorted in slight to moderate clay matrix; overall very slight calcareous cement and soft calcareous matter; clasts 80% quartz, and 20% very light gray to gray to black to red and green both soft and clayey and hard and siliceous lithics; probable interbedded clayey zones and conglomerate; estimate mostly poor to fair porosity and permeability; dull even greenish yellow fluorescence and instantaneous bluish white cut; oil indicators masked by oil based mud contamination. 8455 Coal = black to blackish gray; dense and brittle to moderately brittle; platy to angular fracture common along apparent laminations; Iow to moderate grade; dull polished luster; slight evenly scattered microspecs of isolated pyrite crystals; occasionally with brownish hues grading carbonaceous shale; massive to interbedded and interlaminated with claystone, sandy and silty claystone, and carbonaceous shale; slight bleeding gas. 8540 Tuffaceous Claystone = medium to dark gray with light brownish medium gray secondary hues; massive tabular cuttings and finely ground due to PDC bit action; clayey to silty texture; earthy to slight microsparkly luster; hydrophilic; very expansive and soluble when hydrated; moderate to very calcareous; good cohesiveness; poor to fair adhesiveness; trace black, microthin carbonaceous laminations; common coarse broken pebbles throughout; abundant sloughing coal. 8605 Sand =light gray overall with individual grains dominantly light gray to translucent, frosted to white, light greenish rare dusky red and dark gray lithe fine to very coarse broken pebbles, dominantly fine to medium grain with coarse fragments being varicolored lithe; angular to subrounded for larger lithe, dominantly angular to subangular; fair to moderately well sorted; unconsolidated to loosely consolidated with clayey supporting matrix; moderate to very calcareous; estimate poor to fair porosity and permeability; dull bluish yellow sample fluorescence; instant bright bluish yellow cut fluorescence; oil indicators indistinguishable from oil base mud. 8695 Tuffaceous Claystone = medium to dark gray with dark grayish brown secondary hues; firm to moderately hard; irregular cuttings from PDC; silty to clayey texture; dull earthy luster; hydrophilic; very expansive and soluble when hydrated; microthin black carbonaceous laminations slightly to moderately calcareous. 8740 Coal = black, very firm to moderately hard; finely ground to irregular shaped cuttings due to PDC bit cutting action; dominantly planar fracture; smooth to matte texture; earthy to vitreous luster grading to carbonaceous shale; firm to pulverulent; black to very dark [:1 EPOCH 8 UNOCALe K-18RD & K-18RD-ST#1 dusky brown; massive to very thin interbedded in dominantly sand and claystone formation; no visible outgassing present. 8795 Sand =light gray overall with individual grains dominantly light gray to translucent, frosted to white, light greenish gray, rare dusky red and dark gray lithe; fine to very coarse broken pebbles, dominantly fine to medium grain with coarse fragments being varicolored lithe; angular to subrounded for larger lithe, dominantly angular to subangular; fair to moderately well sorted; unconsolidated to loosely consolidated with clayey supporting matrix; moderate to very calcareous; estimate poor to fair porosity and permeability; dull bluish yellow sample fluorescence; instant bright bluish yellow cut fluorescence; oil indicators indistinguishable from oil base mud. 8890 Sand = very light gray to light gray; mostly fine to medium grains, slightly scattered coarse to pebble size grains and fragments; angular to subangular with occasional bimodal subrounded grains in coarser fraction; estimate moderately to poorly sorted in mostly slight clay matrix with slight overall calcareous cement and matter; clasts 80% quartz, 20% black to gray mostly coal and clay lithics, and trace green; estimate mostly poor to fair porosity and permeability; even dull greenish yellow fluorescence and instantaneous bluish white cut fluorescence; oil indicators obscured by oil based mud contamination. 8975 Claystone = medium light gray to medium dark gray to some brownish black; slightly firm to moderately firm and brittle to crumbly; abundant PDC bit markings and occasionally with visible planar lamina; mostly moderately to occasionally slightly hydrophilic; variably organic often grading carbonaceous shale; occasionally light gray sandy kaolic clays and sandstone; very slightly calcareous; some interbedded coal. 9040 Sand = very light gray to light gray; very fine to coarse lower and locally scattered very coarse and pebble; angular to subangular; moderate to poorly sorted with slight to locally moderate clay matrix and thinly bedded sandy clays; overall trace to slightly calcareous; clasts 80% quartz, and 20% black to gray to trace red lithics including coal, clay, chert to siliceous grains, and minor feldspar; estimate mostly fair to poor porosity and permeability; dull even yellowy fluorescence and bluish white cut indistinguishable from oil mud contamination. 9120 Claystone = dark gray to medium gray, to very dark gray with brownish hues; slightly to moderately firm and brittle to crumbly; abundant PDC bit markings; smooth to silty/gritty texture grading argillaceous siltstone and sandstone; variably organic often grading carbonaceous shale and coal; moderately hydrophilic expanding light brown to light gray; very lightly to lightly evenly scattered microspecs of isolated micropyrite increasing relative to carbonaceous matter; non to some slightly calcareous. [:1 EPOCH 9 UNOCALe K-18RD & K-18RD-$'r#1 9195 Sand/Sandstone = medium light gray to light gray; very fine to coarse and scattered very coarse to pebble; angular to subangular; poorly to moderately sorted in slight overall clay matrix; some interbedded sandy to silty clays; clasts 80% quartz, and 20% gray to black to trace red lithics including clay, coal, chert and siliceous lithics, and minor feldspar; estimate mostly poor to fair porosity and permeability; dull even greenish yellow fluorescence and instantaneous bluish white cut indistinguishable from oil mud contamination. 9290 Tuffaceous Claystone = medium to dark gray with dark brownish gray secondary hues; irregular shaped cuttings due to PDC bit cutting action; firm to very firm silty to slightly gritty texture; dull to earthy to microsparkly luster; grading to very silty sandstone to very fine sandy siltstone; hydrophilic; very expansive and soluble when hydrated; non calcareous; trace black, microthin, carbonaceous laminations throughout. 9350 Coal = black with very dark gray to dark grayish black secondary hues, grading to carbonaceous shale; very firm to moderately hard; brittle at times; finely ground cuttings due to PDC bit action; dominantly planar fracture with rare birdeye and conchoidal fracture; smooth to slightly gritty texture; earthy to resinous luster; no visible outgassing bubbles present. 9405 Sand = very light gray to light gray; very fine to coarse lower and locally scattered very coarse and pebble; angular to subangular; moderate to poorly sorted with slight to locally moderate clay matrix and thinly bedded sandy clays; overall trace to slightly calcareous; clasts 80% quartz, and 20% black to gray to trace red lithics including coal, clay, chert to siliceous grains, and minor feldspar; estimate mostly fair to poor porosity and permeability; dull even yellowy fluorescence and bluish white cut indistinguishable from oil mud contamination. 9485 Tuffaceous Claystone/tuffaceous siltstone = medium to dark gray with scatter light brown secondary hues; firm to very firm, occasionally moderately hard; irregular shaped cuttings due to PDC bit cutting action; smooth to slightly gritty texture; dull to slightly microsparkly luster; moderately hydrophilic; very soluble and expansive when hydrated; non to slightly calcareous; trace black, microthin carbonaceous laminations and pieces throughout; claystone grading to very fine, silty sandstone and occasionally carbonaceous shale; common coal clasts and thin to massive beds; abundant sloughing coal. 9575 Sand = medium light gray to light gray some with light brownish hues; very fine to fine and slightly scattered medium to locally trace coarse and pebble; angular to subangular; moderately to poorly sorted with overall slight clay matrix; clasts 75% quartz, and 25% [:1 EPOCH 10 UNOr. ALe K-18RD & K-18RD-ST#1 coal and clay lithics; slightly calcareous; thinly interbedded in claystone and minor siltstone; estimate mostly poor to locally fair porosity and permeability; oil indicators masked by oil based mud. 9665 Carbonaceous Shale = dark gray to brownish black to medium light gray; moderately to slightly firm; smooth to gritty/silty texture; moderately organic overall; some interbedded coals and locally thinly bedded sands; abundant PDC bit markings; slightly calcareous overall; moderately hydrophilic; very slight evenly scattered microspecs of isolated pyrite crystals; trace with coarse to pebble sized quartz and coal clasts. 9725 Coal = black to some grayish black; firm to slightly firm; hackly subplaty to angular fracture; Iow to moderate grade; smooth dull polished luster; light even scattered microspecs of pyrite; grading carbonaceous shale and sandy to silty claystone and clayey fine sandstone. 9770 Sandstone = very light gray to yellowish gray; fine to very fine and locally scattered medium to trace coarse and pebble; angular to subangular; poorly sorted in clay and silt matrix; often grading white ashy claystone; slight overall calcareous cement; mostly quartz and some clay and coal clasts; estimate very poor porosity and permeability; oil indicators masked by oil based mud. 9825 Sand = light gray; very fine to medium and scattered coarse to rare very coarse grains; subangular to angular; moderately sorted in overall very slight clay matrix; clasts quartz and some coal and clay and trace calcareous matter and feldspar; estimate poor to fair porosity and permeability; dull even greenish yellow fluorescence and bluish white cut indistinguishable from oil mud. 9900 Coal = black with very dark dusky brown secondary hues grading to carbonaceous shale; firm to crunchy; very brittle; finely ground cuttings due to PDC bit action; platy; planar fracture; smooth to occasionally slightly gritty texture; dull to earthy to resinous luster; no to trace visible outgassing bubbles present abundant sloughing coal. 9950 Tuffaceous Claystone/tuffaceous siltstone = medium to dark gray with dark brown to dark brownish gray secondary hues; firm to occasionally hard; brittle at time; irregular, scooped shape cuttings due to PDC bit action; silty/clayey to slightly gritty texture; dull to earthy, occasionally microsparkly luster; hydrophilic; very expansive and soluble when hydrated; moderate to strongly calcareous; occasionally grading to carbonaceous shale and very silty sandstone and sandy siltstone. [::1 EPOCH 11 UNOr. K-18RD & K-18RD-~T#1 10020 Sand/Sandstone = light gray to light greenish gray to medium gray with rare dusky red lithe; fine to coarse, dominantly fine to medium; angular to subangular; poorly sorted; loosely consolidated in soft to slightly firm ashy / clayey supporting matrix; moderate to very calcareous; estimate poor porosity and permeability; dull gold sample fluorescence; instant bright bluish yellow cut fluorescence; oil indicators indistinguishable from oil base mud contamination. 10085 Coal = black with very dark dusky brown secondary hues grading to carbonaceous shale; firm to crunchy; very brittle; finely ground cuttings due to PDC bit action; platy; planar fracture; smooth to occasionally slightly gritty texture; dull to earthy to resinous luster; no to trace visible outgassing bubbles present abundant sloughing coal. 10135 Carbonaceous shale = medium dark gray to brownish black to dark gray; moderately to slightly firm; smooth to some silty/gritty texture; moderately organic overall; grading to and some thinly interbedded coal; abundant PDC bit markings; slightly calcareous overall; moderately hydrophilic; very slight to trace microspecs of isolated pyrite crystals. 10195 Coal = black to some grayish black; firm to slightly firm; hackly subplaty to angular fracture; Iow to moderate grade; smooth dull polished luster; very slight scattered microspecs of pyrite; grading carbonaceous shale and slightly organic silty to sandy claystone. 10235 Sand = light olive gray to light gray to olive gray; very fine to medium grains to slight and locally moderate coarse and very coarse grains and trace pebble; poorly to some moderately sorted in slight to locally moderate kaolic/ashy clay matrix; some matrix supported grading claystone; matrix slightly calcareous overall and trace with green hue; clasts 75% quartz and 25% clay and coal and trace other lithics; estimate poor to some fair porosity and permeability; dull even greenish yellow fluorescence and instantaneous bluish white cut indistinguishable from oil based mud contamination. 10320 Claystone = medium dark gray to brownish black to occasionally medium gray; slightly firm to moderately firm; abundant PDC bit markings; overall moderately organic grading carbonaceous shale; smooth to some silty to slightly gritty texture; probable thinly interbedded clayey sandstone; moderately to slightly hydrophilic; some slightly calcareous; trace very finely disseminated mica. 10395 Sand = light to medium gray with light green and light brown secondary hues; very fine to occasionally coarse, dominantly fine to medium; angular to subangular; poorly sorted; EPOCH 12 UNOr. K-18RD 8, K-18RD-ST#1 unconsolidated to very loosely consolidated with light gray to light greenish gray clayey/ ashy supporting matrix; moderate to very calcareous; estimate poor porosity and permeability; dull even bluish green sample fluorescence; instantaneous bright yellow cut fiuorescence; indistinguishable from oil base mud and mud additive contamination. 10470 Coal = black with dark dusky brown secondary hues that grade to carbonaceous shale; firm to crunchy, occasionally moderately hard; brittle; finely ground up cuttings due to PDC bit; generally planar fracture, rare birdeye and conchoidal fracture; smooth to matte texture; earthy to resinous luster; no visible outgassing bubbles present. 10525 Claystone = medium dark gray to medium gray to brownish black; slightly firm to firm; poor quality very fine cuttings with fibrous LCM; overall moderately organic grading carbonaceous shale; smooth to some silty to gritty texture; probable thin interbeds of coal and variably organic sandstone; moderately hydrophilic; slightly calcareous; very slightly scattered microspecs of pyrite. 10580 Coal = black to some grayish black; firm to slightly firm; hackly subplaty to angular fracture; Iow to moderate grade; smooth dull polished luster; very slight scattered microspecs of pyrite; grading to and interbedded with silty/gritty variably organic claystone. 10620 Sandstone/Sand = medium light gray to olive gray; fine to coarse especially fine to medium grains; angular to subangular; poorly sorted in often matrix supported ashy/kaolic clay; clasts 80% quartz and 20% coal, light and dark clays, siliceous grains, and trace red and green lithics; matrix very slightly calcareous; estimate poor to very poor porosity and permeability; dull even yellow fluorescence and bluish yellow instantaneous to diffuse cut fluorescence; oil indicators indistinguishable from oil mud contamination. 10715 Tuffaceous Claystone/Siltstone = medium to dark gray with medium to dark brown to brownish gray secondary hues; firm to crunchy; very brittle; finely ground up cuttings; silty to slightly gritty texture; dull to earthy luster; hydrophilic; expansive and soluble when hydrated; moderate to very calcareous; grading to carbonaceous shale; abundant fine, fibrous lost circulation material in samples. 10790 Sand=light to medium gray overall appearance; individual grains dominantly clear, translucent, light gray with rare dusky red liths, scattered light brown to yellowish brown stained quartz grains; very fine to medium, dominantly fine with rare coarse liths; poor to moderately sorted; disaggregated to very loosely consolidated in clayey supporting matrix; angular to sub angular; estimated poor to fair permeability and porosity; EPOCH 13 UNOCAL K-18RD & K-18RD-ST#1 abundant fine Icm in samples; dull bluish gold sample fluorescence; instantaneous bright bluish yellow cut fluorescence; oil indicators masked by oil base mud. 10875 Coal=black to brownish black; slightly to very firm and moderately brittle to crunchy; hackly sub planar to wedge shaped fracture along apparent bedding plane laminations; some grading carbonaceous shale; thinly bedded. 10910 Sand=light olive gray to medium light gray; fine to coarse lower grains and slightly scattered very coarse; angular to sub angular; poorly to moderately sorted with slight overall clay matrix and occasional matrix supported sandstone grading claystone; non to very slightly calcareous; clasts 70% quartz and 30% coal, clay and trace red and green including feldspar; estimate poor to some fair porosity and permeability; dull even yellow fluorescence and instantaneous to slow diffuse bluish yellow cut fluorescence indistinguishable from oil base mud contamination. 11010 Tuffaceous Claystone=medium to dark gray to dark brownish gray; slightly firm for lighter shades to moderately hard for darker shades; irregular shaped cuttings due to pdc bit scooping action; silty to slightly gritty texture; dull to earthy luster; occasionally grading to very silty sandstone and fine sandy siltstone and carbonaceous shale; slight to moderately hydrophilic; moderately expansive and soluble when hydrated; slight to non calcareous; trace micro thin black carbonaceous laminations. 11080 Sand=light gray to light brownish gray to light yellowish gray, individual grains varicolored; very fine to occasionally coarse fragments, dominantly fine; angular to sub angular; moderately well sorted; unconsolidated to very loosely consolidated with clayey/ashy supporting matrix; estimate fair to good porosity and permeability; strong bluish green sample fluorescence; light to dark brown staining on individual sand grains; instantaneous bright bluish yellow cut fluorescence; oil indicators obscured by oil base mud and tar like mud additives. 11160 Sand=very light gray; fine to very coarse grains including scattered pebble fragments; angular to sub rounded and rare rounded edge on pebble fragments; estimate poorly to moderately sorted with mostly slight clay matrix; probable thin clay and clayey zones; clasts 75% quartz and 24% black to gray coal and clay lithics, and 1% mostly red feldspar commonly altered to clay and trace green lithics; abundant diesel contaminated light to medium brown to maroon Icm matter; trace calcareous matter; estimate fair to poor porosity and permeability; dull to moderate even yellow fluorescence and bluish yellow instantaneous cut indistinguishable from oil mud. [:1 EPOCH 14 UNOCALe K-18RD & K-18RD-ST#1 11270 Tuffaceous Claystone=medium to dark gray with medium to dark brown to brownish gray secondary hues; firm to crunchy; very brittle; finely ground up cuttings; silty to slightly gritty texture; dull to earthy luster; hydrophilic; expansive and soluble when hydrated; moderate to very calcareous; grading to carbonaceous shale; abundant fine fibrous lost circulation material in samples. 11330 Sand=medium light gray to light olive gray; fine to coarse and slight very coarse and trace pebble; angular to sub rounded including slight fragments; poorly to moderately sorted; 70% quartz, and 30% black to gray to rare green and red lithics including coal, clay, siliceous grains and trace feldspar; slight overall ashy/kaolic clay matrix and some interbedded clay and clayey zones; estimate poor to fair porosity and permeability; dull to moderate fluorescence and cut indistinguishable from oil mud. 11400 Coal=black to brownish black; very to slightly firm and slightly brittle to brittle; angular to hackly sub platy fracture; polished to dull luster; thinly bedded in variably carbonaceous claystone and conglomeratic sand. 11455 Sand=medium gray to medium dark gray; upper to lower medium grain size; fair to poorly sorted; angular to sub angular; Iow to very Iow sphericity; unconsolidated; grain/matrix supported; black carbonaceous material present; estimate poor to some fair porosity; no visible hydrocarbon indicators present due to oil base mud. 11515 Tuffaceous Claystone=medium light gray to medium gray; crumbly tenacity; irregular fracture; massive occasionally pdc grooved cuttings habit; dull to earthy occasionally waxy luster; clayey to silty texture; moderately hydrophilic; variably organic some grading carbonaceous shale; slight calcareous matter; some interbedded coal and some sandy grading conglomeratic sandstone. 11595 Coal=black to grayish black; dense to brittle tenacity; irregular to conchoidal fracture; massive to wedgelike cuttings habit; polished to sparkling luster; smooth to matte texture; thin bedding structure. 11630 Sand=medium light gray to medium gray with medium dark gray secondary hue; upper medium to lower coarse occasionally bit fractured pebble grain size; poor to very poorly sorted; angular to sub angular; Iow to very Iow sphericity; dominantly quartz; unconsolidated; black carbonaceous material present. [:1 EPOCH 15 UNOCAL K-18RD & K-18RD-ST#1 11680 Tuffaceous Claystone=medium light gray to medium gray with medium dark gray secondary hue; crumbly tenacity; irregular fracture; massive cuttings habit; dull to earthy occasionally waxy luster; clayey to silty texture; massive bedding structure; black carbonaceous material present. 11725 Coal=black to grayish black; dense to brittle tenacity; irregular occasionally conchoidal fracture; massive cuttings habit; polished luster; smooth to matte texture; thin bedding structure; 11770 Sand=medium light gray to medium gray; fine to coarse sand; fair to moderately sorted; angular to sub rounded; very Iow to moderate sphericity; dominantly clear to shite translucent quartz grains; occasional pink and green lithic grains; hydrocarbon shows masked by oil base mud. 11805 Tuffaceous Claystone=medium to dark gray, occasionally brownish gray; moderately to very brittle; clayey to silty texture; dull to earthy luster; slightly calcareous; common interbedded silty layers; occasional black carbonaceous streaks. 11840 Sand=medium gray to medium dark gray; very fine to coarse grains, occasionally very coarse; fair to moderately well sorted; angular to sub rounded; occasional bit impacted grains; dominantly unconsolidated; occasionally consolidated silty sandstone; dominantly quartz, occasional red, green and blue grains. 11910 Sand=medium gray to medium dark gray, with medium light gray secondary hue; upper fine to lower coarse grain size with bit fractured pebbles present; poor to very poorly sorted; angular to sub angular; very Iow to Iow sphericity occasionally irregular; unconsolidated; matrix/grain supported. 11955 Tuffaceous Claystone=medium light gray to medium gray; pasty consistency; crumbly tenacity; irregular fracture; massive cuttings habit; dull to earthy to occasionally waxy luster; clayey to silty texture; black carbonaceous laminations present throughout sample. 11995 Tuffaceous Siltstone=medium gray to medium dark gray; crumbly texture; irregular fracture; massive cuttings habit; dull to earthy luster; silty to gritty texture. EPOCH 16 UNOr. ALe K-18RD & K-18RD-ST#1 12035 Sand=medium gray to dark gray; dominantly translucent white, clear, and gray grains, occasionally opaque; very fine to coarse size grains; occasional bit impacted pebbles; very poor to fair sorting; angular to sub rounded; moderate to very Iow sphericity occasionally irregular; slightly calcareous; unconsolidated; matrix/grain supported; oil indicators masked by oil base mud. 12085 Coal=grayish black to black; hard to brittle; irregular to blocky cuffings; conchoidal fracture; dull to resinous luster; smooth to slightly gritty texture; trace visible degassing from surface. 12115 Sand=medium gray to medium dark gray; dominantly fine to lower coarse occasionally very coarse and bit impacted pebble grains; moderately to poorly sorted; angular to sub rounded grains; dominantly unconsolidated; occasional slightly consolidated with interbedded silty layers; consists of 70% quartz and 30% coal, clay and lithics. 12230 Tuffaceous Claystone=medium gray to medium dark gray with greenish gray secondary hue; crumbly to crunchy tenacity; irregular fracture; massive to flaky cuttings habit; waxy to dull occasionally earthy luster; clayey to silty texture. 12280 Sand=medium gray to medium dark grey; dominantly fine to lower coarse and bit impacted pebble grains; moderate to poorly sorted; angular to subrounded grains; dominantly unconsolidated, occasional slightly consolidated with interbedded silty layers; consists of 70% quartz and 30% coal, clay and lithic fragments, occasionally chloritized. 12330 Tuffaceous Claystone=light olive gray to greenish gray, occasionally dark greenish gray; stiff, crumbly occasionally brittle cuttings; dull to waxy luster; clayey to gritty texture; non to slightly calcareous. 12385 Sandstone=medium to dark gray; very fine to fine grain, dominantly fine grain; sub angular to sub rounded; moderately well sorted; Iow to moderate sphericity; appears in sample as approximately 50% loose disaggregated grains and 50% cemented clusters; consists of 70% clear to cloudy quartz, 30% gray chert, coal fines, structural clay and miscellaneous chloritized lithic fragments; trace light colored clay matrix, probably kaolinite; generally non calcareous; occasionally grades to siltstone; probably poor to fair insitu porosity especially in non conglomeratic zones; oil indicators masked by oil base mud. EPOCH 17 UNOCAL$ K-18RD & K-18RD-ST#1 LITHOLOGY SUMMARY (K-18RD-ST#1) DRILLED TYONEK AND HEMLOCK (10,240-12,550) TYONEK (COMMEMCE LOG TO TD) 10245 Sand/Sandstone=light gray to medium gray with some greenish gray; very fine to medium grain with rare coarse; poorly sorted; composed of 80% clear to cloudy to occasionally translucent quartz, 20% coal fines, structural clay and undifferentiated lithic fragments; occasional to moderate light clay matrix probably kaolinite; grades into silty, ashy claystone; slightly to non calcareous; estimate poor to occasionally fair insitu porosity with better porosity in cleaner intervals; entire sample fluoresces dull light green-yellow and gives a slow weak light yellow cut due to oil base mud. 10325 Tuffaceous Claystone=medium to dark gray to occasionally brownish gray; firm to occasionally slightly brittle; smooth to occasionally gritty/silty texture; occurs as curved PDC bit grooved cuttings; expansive when exposed to water; slakes and probably contains thin interbeds of very fine grain sand and ashy siltstone; occasional inclusions of glass shards and finely disseminated mica giving a sparkly appearance. 10400 Sandstone=light gray to medium gray; very fine to fine grain, dominantly very fine grain; sub angular to sub rounded; moderately well sorted; poor to moderate sphericity; consists of 80% clear to cloudy quartz, 20% gray chert, coal fines, argillaceous material and lithic fragments; occasional light clay matrix, but generally grain supported; commonly loose and disaggregated; grades to siltstone; hydrocarbon shows obscured by oil base mud. 10455 Coal=black to dusky brown; generally hard to very brittle; dull to shiny and vitreous luster on fresh break; very slightly rough to smooth surface texture; occurs as tabular and bladed cuttings; rare visible bubbles of bleeding gas. 10490 Claystone=medium dark gray to brownish gray; brittle and crumbly when dry, soft and mushy when wet; gritty silty texture; moderately expansive when hydrated; abundant micro laminations of silt and rare carbonaceous material; very slightly calcareous; visible glass shards. 10530 Sand/Sandstone=light gray to medium gray with some greenish gray; very fine to occasionally translucent quartz; 20% coal fines, structural clay and undifferentiated lithic fragments; [::1 EPOCH 18 UNOCALe K-18RD & K-18RD-ST#1 occasional to moderate light clay matrix probably kaolinite; grades into silty, ashy claystone; slightly to non calcareous; estimate poor to occasionally fair insitu porosity with better porosity in cleaner intervals; entire sample fluoresces dull light green-yellow and gives a slow weak light yellow cut due to oil base mud. 10610 Claystone=medium dark gray to brownish gray; brittle and crumbly when dry, soft and mushy when wet; gritty silty texture; moderately expansive when hydrated; abundant micro laminations of silt and rare carbonaceous material; very slightly calcareous; visible glass shards. 10650 Sand= light to medium gray; fine to trace coarse; angular to sub angular; poor sorting; 80% quartz, 20% lithics; coal =black to dark brown; firm to occasionally hard; brittle conchoidal fracture; smooth texture; earthy to resinous luster; no visible out gassing bubbles present. 10690 Coal=black to dark brown; firm to brittle; hackly; conchoidal fracture; earthy to resinous luster; smooth texture; trace dark brown carbonaceous shale; grading to and interbedded with silty, gritty claystone. 10740 Tuffaceous Claystone=light gray to light gray brown; firm to brittle; mushy when wet; gritty silty texture; waxy resinous luster; occurs as fine PDC bit shavings; expansive when hydrated; abundant shards and micro laminations of silt and carbonaceous material giving a varved appearance; probably grades into carbonaceous shale and siltstone; common sparkled appearance from reflective mica, shards, and possibly feldspar. 10795 Siltstone=medium gray to medium light gray; slightly firm to brittle; ashy and moderately argillaceous; grades to very fine grain sand and sandy silty claystone; occasional micro laminations of black to brown carbonaceous material; trace mica and possible feldspar; non to slightly calcareous. 10835 Sand/Sandstone=light to medium gray; grains clear to translucent; light gray to dusky red lithe; fine to medium grained; some lower coarse grains; poor sorting; angular to occasionally sub angular; unconsolidated; oil indicators masked by oil base mud. 10875 Coal=black to very dark brownish black; firm to hard; brittle, hackly to conchoidal fracture; trace dark brown carbonaceous shale; no visible out gassing bubbles present. [::1 EPOCH 19 UNOCALe K-18RD & K-18RD-ST#1 10905 Claystone=medium dark gray to brownish gray; brittle and crumbly when dry, soft and mushy when wet; gritty silty texture; moderately expansive when hydrated; abundant micro laminations of silt and rare carbonaceous material; very slightly calcareous; visible glass shards. 10945 Coal=black to dark brown; firm to brittle; hackly to conchoidal fracture; earthy to resinous luster; smooth texture; trace dark brown carbonaceous shale. 10975 Tuffaceous Claystone=medium to dark gray to brownish gray; firm to moderately firm; dull earthy luster; silty to slightly gritty texture; moderately hydrophilic; trace dark brown to black carbonaceous shale. 11005 Coal=black to dark brown; firm to brittle; hackly conchoidal fracture; earthy to resinous luster; smooth texture; trace dark brown carbonaceous shale; grading to and interbedded with silty, gritty claystone. 11055 Sandstone=light to medium gray; very fine grain to occasionally medium grain, dominantly fine grain; angular to sub rounded; moderately well sorted; moderate sphericity; occurs in sample as 80% loose grains with occasional clusters of poorly indurated grains; 20% of sample is conglomerate of bit shattered chert and quartz pebbles with sharp edges and points; sample is composed of 80% quartz, 10% gray chert and 10% coal fines and lithic fragments; generally non calcareous; occasional matrix of light kaolinitic clay; rare interbeds of cream colored ashy clay with visible shards; infer fair insitu porosity and permeability; all hydrocarbon indicators masked by oil base mud. 11130 Sandstone=light gray; very fine grain to fine grain, dominantly fine grain; generally sub angular; 80% clear to cloudy quartz 20% gray chert, coal fines and trace red feldspar; moderate conglomerate of bit shattered pebbles and coarse grains; generally grain supported with no visible cement; rarely very slightly calcareous; occasional cream colored clay matrix, probably kaolinite; occurs as 90% loose floating grains with few cemented clusters; grades to siltstone and possibly claystone; infer fair to moderate insitu porosity; oil indicators masked by oil base mud. 11205 Claystone = brownish gray; brittle to crumbly; moderately expansive on fresh surface when hydrated; occurs as small, broken pdc bit shavings; non to slightly calcareous; common micro lenses of carbonaceous material; occasionally becomes carbonaceous and fissile; [::1 EPOCH 20 UNOr. ALO K-18RD & K-18RD-ST#1 grades to siltstone and occasionally light gray silty, sandy ash; occasionally partings of very fine grain sand. 11250 Sandstone = light gray to medium gray; very fine to fine grained dominantly very fine; sub angular to sub rounded; moderately well sorted; poor to moderately sphericity; consists of 80% clear to cloudy quartz, 20% gray chert, coal fines, argillaceous material, but generally grain supported; common loose disaggregated grades to siltstone; up to 10- 15% conglomerate present in some samples; oil shows masked by oil base mud. 11300 Sand = light to medium gray; fine to lower coarse grained; angular to sub angular; poorly sorted; 80% quartz, 20% black to gray to red lithics; including coal, clay, siliceous grains and trace feldspars; oil shows masked by oil base mud. 11350 Sand/Sandstone = light to medium gray; grains clear to translucent; light gray to dusky red lithics; fine to medium grained; some lower coarse grained; poor sorting; angular to occasionally sub angular; unconsolidated; oil indicators masked by oil base mud. 11400 Tuffaceous claystone = medium to dark gray to brownish gray; firm to moderately firm; dull earthy luster; silty to slightly gritty texture; moderately hydrophilic; trace dark brown to black carbonaceous shale. 11430 Sand = light to medium gray; fine to lower coarse grained; angular to sub angular; poorly sorted; 80% quartz, 20% black to gray to red lithics; including coal, clay and trace feldspars; oil shows masked by oil base mud. 11480 Sandstone = medium gray; very fine to occasionally medium grain; dominantly fine; angular to sub rounded, rarely nearly rounded; generally moderately well sorted; moderately to rare good sphericity; 0-10% of sample is conglomerate of bit broken chert and quartz pebbles, occurs as 80-90% disaggregated loose grains with occasionally clusters of poorly indurated cemented grains; sample is 90% clear to milky quartz, 10% undifferentiated lithic fragments, some chloritized, coal fines and trace brick red feldspar; non to very slightly calcareous; occasional matrix and thin laminae of cream clay, probably entire sample fluoresces even light yellow from oil base mud. 11550 Coal = black to dusky brown; generally hard to very brittle; dull to shiny vitreous luster on fresh break; very slightly rough to smooth surface texture; occurs as tabular and bladed [:1 EPOCH 21 UNOCALe K-18RD & K-18RD-ST#1 cuttings; common thin partings of silt and very fine grained sand; occasionally grades into very dark brown carbonaceous shale; no visible bleeding gas; probably lignite. 11600 Conglomeratic Sandstone = light gray to medium gray; fine to upper medium grained with rare coarse; angular to sub rounded, rarely almost rounded; moderately sorted; moderate sphericity; predominantly loose grains with occasionally clusters in a light gray ashy silty matrix; clay is white to light gray occasionally greenish; slightly to moderately hydrophilic; clasts 80-90% quartz, 10-20% chert, coal fines, lithic fragments and rare feldspar. 11680 Sandstone = light gray to medium gray to clear; fine to lower coarse; angular to sub angular; poor sorting; poor to fair sphericity; occasionally white to translucent quartz grains; occasionally green to red lithics; common coal; (possibly coal cavings); and carbonaceous material; oil indicators masked by oil base mud. 11720 Coal = black to dusky brown; generally hard to very brittle; dull to shiny vitreous luster on fresh break; very slightly rough to smooth surface texture; occurs as tabular and bladed cuttings; common thin partings of silt and very fine grained sand; occasionally grades into very dark brown carbonaceous shale; no visible bleeding gas; probably lignite. 11770 Sand/Sandstone = light gray to medium gray; fine to medium grained; grading to lower coarse; trace very coarse; angular to sub angular; poor sorting; moderate sphericity; unconsolidated; 80% quartz, 20% chert/lithics; red to occasionally green chert; oil indicators obscured by oil base mud. 11820 Sandstone/Conglomerate = dark gray; fine to upper medium grained, rarely to coarse; angular to sub angular; poorly sorted; Iow sphericity; generally grain supported with indurated clusters having a light gray silty ashy clay matrix probably kaolinite; majority of sample is loose disaggregated grains; conglomerate fraction is clear to milky bit shattered quartz pebbles non conglomerate fraction is composed of 80% clear to translucent quartz; 10% gray chert; 10% undifferentiated lithic fragments chloritized in part, coal fines, argillaceous detritus, and rare pink feldspar; non to very slightly calcareous; grades to thin interlaminations of gray ashy siltstone; infer fair insitu zones; abundant coal cavings 11780 to 11840; entire sample fluoresces light bluish yellow and gives a weak pale yellow cut due to oil base mud. 11930 Sandstone = dark gray; very fine to lower medium grain; subangular to sub rounded; poor to fair sorted; moderate sphericity; easily friable to slightly firm; both grain and matrix supported; commonly clay packed with light ashy clay matrix; up to 20% conglomerate EPOCH 22 UNOCAL ) K-18RD & K-18RD-ST#1 fraction of bit broken quartz pebbles; clean zones have fair to moderately insitu porosity; clay filled have poor porosity; oil shows masked by oil base mud. 11980 Sand/Sandstone = light gray to medium gray; fine to medium grained; grading to lower coarse; 80% quartz, 20% chert/lithics; red to occasionally green chert; oil indicators obscured by oil base mud. 12040 Sand/Conglomerate = light gray to medium gray; fine to lower coarse grained; angular to sub angular; poor sort; poor sphericity; 80% quartz, 20% chert/lithic fragments; oil indicators masked by oil base mud. 12070 Sandstone = dark gray; very fine to medium grained; angular to sub rounded; poorly sorted; fair sphericity; sample is 80% clear to gray opaque quartz; 20% coal fines, argillaceous clasts, undifferentiated lithic fragments some chloritized, and rare feldspar; easily friable to slightly firm; grain and matrix support; commonly clay packed with cream to light gray ashy silty clay matrix giving an overall dirty appearance; common thin interbeds of silt; up to 30% of sample is conglomerate of bit broken quartz and chert pebbles; infer poor to occasionally fair insitu porosity; entire sample fluoresces light yellow and gives weak yellow white cut from oil base mud. 12200 Conglomeratic Sandstone = light gray to medium gray; fine to upper medium grained with rare coarse; angular to sub rounded; moderately sorted; moderately sphericity; predominantly loose grains with occasionally clusters in a light gray ashy silty matrix; clay is white to light gray occasionally greenish; slightly to moderately hydrophilic; clasts 80-90% quartz, 10-20% chert, coal fines, lithic fragments and rare feldspar; estimated poor to fair insitu porosity; oil indicators masked by oil base mud. 12270 Coal = black to dark brown; firm to brittle; hackly; conchoidal fracture; earthy to resinous luster; smooth texture; trace dark brown carbonaceous shale; grading to and interbedded with gray siltstone and ashy clay. 12310 Sandstone = light to medium gray; very fine grained to rare medium grained; sub angular to sub rounded; poor sorting; poor to moderate sphericity; common cream to light gray clay matrix and thin interlaminations; ashy in part; appears reworked in part; up to 20% of sample is conglomerate, composed of bit broken quartz, chert, and occasionally lithic pebbles. [:l EPOCH 23 UNOCALe K-18RD & K-18RD-ST#1 12350 Sand/Conglomerate = white to light gray to dark gray to transparent; fine to lower coarse grained; angular to sub rounded; poor sorting; poor to occasionally fair sphericity; 5-10% coal in samples (possibly cavings); 80% quartz, 20% lithic/chert fragments; red to light green chert fragments; trace tuff/ash; common clay matrix. 12390 Tuffaceous Siltstone = light gray to dark gray; soft to moderately firm; crumbly; irregular fracture; massive cuttings habit; dull to earthy luster; silty to very gritty texture; occasionally black carbonaceous lams; slightly to non calcareous. 12440 Sandstone=light gray to medium gray; very fine to fine grain, dominantly very fine grain; sub angular to sub rounded; moderately well sorted; poor to fair sphericity; consists of 80% clear to cloudy quartz, 20% gray chert, coal fines. Argillaceous material and lithic fragments; occasional light gray matrix, but generally grain supported; commonly loose and disaggregated; grades to siltstone; up to 10-20% conglomerate present in some samples; oil shows masked by oil base mud. 12500 Siltstone=medium gray to medium light gray; slightly firm to brittle; ashy and moderately argillaceous; grades to very fine grain sand and sandy silty claystone; occasional micro laminations of black to brown carbonaceous material; trace mica and possibly feldspar; non to slightly calcareous. [::1 EPOCH 24 UNOCALe K-18RD & K-18RD-ST#1 DAILY CHRONOLOGY 07109/2001: 6785' Epoch arrived on location at 10:30 AM, dgged up and prepared to log on when return to drilling at 6785'. Displaced bad mud while tripping in and circulated above window displacing out of hole for SWACO. Tripped in and circulated below window, maximum 14 units of gas. 07110/2001: 6785-6986' Finished displacing bad mud in hole for SWACO injection and circulated and conditioned mud. Reamed from window to bottom. Drilled ahead from 6785 to 6880', MWD tool failure, and circulated out. Pulled out of hole and changed MWD tool and bit. Ran in with bit #2 and drilled ahead, rotating and sliding from 6880' to 6986'. 07/11/2001: 6986-7845' Drilled ahead, rotating and sliding, from 6986' to 7845'. 07112/2001: 7845-8444' Drilled ahead, rotating and sliding, from 7845' to 8445', and circulated out. Pulled out of hole to shoe and sheared pump out sub. Pulled out of hole and laid down stabilizer, MWD, motor, and bit. Rigged up and begin test BOPE. 07/1312001: 8444-8580' Tested BOPE, and changed out air boot on pitch nipple. Pickup BHA with new PDC bit #3, tested MWD, and picked up 5" drill pipe. Ran in hole to shoe, cut and slipped drill line, and serviced rig. Ran in hole to bottom, and drilled ahead from 8444' to 8490'. Worked pipe while working on pumps. Drilled ahead from 8490' to 8580'. 07/1412001: 8580-9319' Drilled ahead, rotating, from 8580' to 8732', and worked on pumps. Drilled ahead, rotating and sliding, from 8732' to 9319', 07/15/2001: 9319-9666' Drilled ahead, rotating, from 9315' to 9385', and worked on pumps. Drilled ahead, rotating and sliding, from 9385' to 9665'. Pulled out of hole to window. 07/1612001: 9666-9900' Finished pulling out of hole and changed bit, and pump out sub, and ran in with BHA. Serviced rig and top drive and tested MWD. Tripped in hole with heavy weight and changed air tool in pitcher nipple. Tripped in hole with drill pipe, and reamed to bottom from 9573' to 9665'. Drilled ahead from 9665' to 9900'. EPOCH 25 UNOCAL K-18RD & K-18RD-ST#1 0711712001: 9900-10413' Drilled ahead, rotating and sliding, from 9900' to 10413'. 07118/2001: 10413-10696' Drilled ahead, rotating and sliding, from 10413' to 10696'. 0711912001: 10696-10789' Drilled ahead, rotating and sliding, from 10696' to 10789'. Circulated out and pulled out of hole, pumping dry job and shearing pump out sub at shoe. Began making up BHA. 0712012001: 10789-11049' Finished making up BHA with new bit #5 and pump out sub. Tripped in hole with heavy weight drill pipe and tested MWD. Tripped in hole to 10712', and reamed to 10789'. Drilled ahead, rotating and sliding, from 10789' to 11049'. 07/21/2001: 11049-11276' Drilled ahead, rotating and sliding, from 11049' to 11276'. 0712212001: 11276-11439' Drilled ahead, rotating and sliding, from 11276' to 11439'. 07/2312001: 11439-t 1582' Drilled ahead, rotating, from t 1439' to 11582'. Circulated out, pumped dry job, and pulled out of hole. 0712412001: 11582-11629' Rigged up and tested BOPE. Made up BHA with new mud motor and new bit #6 and cut drill line. Tested MWD tool and tripped in hole. Drilled ahead from 11582' to 11629. 07/2512001: 11629'-11889' Drilled ahead, rotating, from 11629' to 11889'. Pumped high vis sweep, circulated out, and pulled out of hole. 0712612001: 11889-1t889' Pulled out of hole. Ran in Hole with wireline for UBI and Gamma ray logs from 11850' to 6766'. Pulled out of hole with wireline. Made up BHA with new bit #7, CDP, tool, MWD and ran in hole. EPOCH 26 UNOCALe K-18RD & K-18RD-ST#1 07127/2001: 11889-11899' Made up BHA with new bit #7, CDR tool, nuke source, and MWD. Waited on part/boat. Fit BHA with new jars and ran in hole; breaking every connection. Drilled ahead from 11889 to 11899'. 0712812001: 11899-12200' Drilled ahead, rotating from 11899' to 12200'. 07/29/2001: 12200-12212' Drilled ahead, rotating, from 12200 to 12212'. Pulled out of hole, running MAD tool from 11807 to 10782' (stands 118 - 107), to change bit #7 for new bit #8. Picked up new bit and motor and ran in hole. Cut drill line and continued in hole. 07/3012001: 12212-12381' Ran in hole. Drilled ahead from 12212 to 12381' 07/3112001: 12381-12442' Drilled ahead from 12381 to12442' (TD). Pumped dry job. Pulled out of hole. Laid down BHA, MWD, CDR, stab, motor and bit. Picked up 28 joints of 2 7/8" tubing with stinger. Ran in hole with drill pipe. 08/0112001: 12442-12442' Rig up pump and cement lines and run cement. Pump 4 bbl mud push test to 3000 psi. Pull out of hole (slowly out of cement) with drill pipe. Lay down cementing equipment. Test BOPE. Pick up BHA and new bit #1 for sidetrack #1. 0810212001 Run in hole to 9571. Wash from 9571 to 10080. Looking for cement from 10080 to 10240. Attempt to kick off at 10240. Change out swabs on pump #2. Kick off at 10240. Work on both pumps. Clean suction screens. Kick off at 10240 to 10273. Slide from 10273 to 10290. 0810312001 Rotate and slide from 10290 to 10731. Trouble shoot top drive and brake. 0810412001 Trouble shoot top drive. Rotate and slide from 10731 to 10879. Trouble shoot top drive. Rotate and slide from 10879 to 11009. 08/0512001 Rotate and slide from 11105 to 11479. EPOCH 27 UNOCALO K-18RD & K-18RD-ST#1 0810612001 Rotate from 11479-11663; Back ream 10975-10226; Circulate bottoms up, check flow, pump dry job; Pull out of hole to shoe-no tight spots; Trouble shoot and repair top drive; Pull out of hole; Work BHA, lay down motor & stabilizer; Pick up motor, drill collars, stabilizer. 08107/2001 Work BHA and check pulse; Run in hole to top of window; Cut/slip drilling line; Trouble shoot top drive; Run in hole to 11574; Ream from 11574 to 11663; Circulate out junk at bottom; Drill and slide from 11663 to 11852. 08/0812001 Drill from 11582 to 12025. Pump dry job. Survey. Monitor well for 10'. Pull out of hole, monitor well at shoe 10". Lay down BHA. Clean floor. Pull wear ring. Rig up for BOP test. 08/09/2001 Make up test plug and set. Test BOP's to 250/300#. Pull test Plug. Set wear ring. Lay down test equipment. Pick up BH^, load nuclear tools, check pulse. Run in hole to top of window filling pipe twice. Repair Iow drum clutch valve. Run in hole to 11960. Ream from 11960 to 12025. Drill from 12025 to 12056. Change swab and liner in #2 pump. Drill from 12056 to12128. Change swab, check valves, clean suction and discharge screens. Drill from 12128 to 12170. 0811012001 Drill from 12170 to 12386. Drill with one pump from 12386 to 12389. Fix rod oiler and pump on #1 mud pump. Drill from 12389 to 12431. Circulate bottoms up, pump survey, monitor well. Pull out of hole--MAD pass from 12100 to 11061. 08111/2001 MAD pass 11761-10800. Pump pill. Pull out of hole. Work BHA, Down load data from logging tool. Run in hole. Check pulse from MWD tool. Grease top drive, draw works, and crown sheave. Run in hole. Ream from 12348 to 12431. Drill from 12431 to 12470. [:1 EPOCH 28 c~ m C Z 0 C: Z UNOCALe K-18RD & K-18RD..ST#1 SURVEY RECORD (K-18RD) MD Incl Azim 'I'VD VSec NS EW BLS Course Closure (Jr) (°) (°) (ft) (ft) (f~) (ft) (°/~OOft) (f9 6700.00 36.20 258.00 5526.80 3195.21 -1012.51 -3217.50 3373.05 252.53 0.00 6750.00 36.10 258.00 5567.17 3223.93 -1018.64 -3246.35 3402.41 252.58 0.20 6766.00 37.87 259.24 5579.95 3233.32 -1020.54 -3255.79 3411.99 252.60 12.00 6791.12 37.91 260.36 5599.78 3248.44 -1023.27 -3270.97 3427.29 252.63 2.74 6885.27 41.64 264.56 5672.19 3307.89 -1031.08 -3330.59 3486.54 252.80 4.79 6982.02 46.38 268.68 5741.83 3374.79 -1034.93 -3397.59 3551.72 253.06 5.81 7075.92 49.66 272.83 5804.64 3444.55 -1033.95 -3467.35 36t 8.23 253.40 4.79 7170.03 50.94 276.42 5864.77 3516.81 -1028.09 -3539.50 3685.78 253.80 3.23 7264.20 51.84 280.95 5923.55 3589.73 -1016.96 -3612.20 3752.63 254.28 3.88 7354.71 52.04 281.04 5979.35 3659.96 -1003'.37 -3682.16 3816.42 254.76 0.23 , 7449.48 51.75 281.07 6037.83 3733.44 -989.07 -3755.35 3883.41 255.24 0.31 7543.58 51.62 282.24 6096.17 3806.05 -974.16 -3827.66 3949.67 255.72 0.99 7638.15 52.12 282.52 6154'.56 3879.03 -958.21 -3900.32 4016.29 256.20 0.58 7731.54 52.47 282.81 6211.68 3951.45 -942.01 -3972.40 4082.57 256.66 0.45 ' 7829.04 52.75 279.82 6270.89 4027.70 -926.82 -4048.35 4153.09 257.11 2.45 7923.99 52.12 279.20 6328.78 4102.18 -914.38 -4122.58 4222.76 257.49 0.84 8018.80 51.67 279.30 6387.29 4176.05 -902.39 -4196.21 4292.14 257.86 0.48 , 8111.36 51.70 279.40 6444.67 4247.94 -890.59 -4267.87 4359.80 258.21 0.09 8204.56 51.51 279.32 6502.56 4320.25 -878.71 -4339.94 4428.01 258.55 0.21 , , ,, 8294.28 51.56 278.17 6558.37 4389.90 -868.03 -4409.38 4494.00 258.86 1.01 , 8388.11 51.73 278.23 6616.59 4462.93 -857.53 -4482.20 4563.50 259.17 O. 19 8480.69 52.22 279.53 6673,63 '4535.20 -846.27 -4554.25 4632.21 259.47 1.23 8576.02 52.95 280.53 6731.55 4610.02 -833.08 -4628.81 4703.18 259.80 1.13 8671.97 53.31 280.60 6789.12 4685.76 -819.01 -4704.27 4775.03 260.12 0.38 8761.97 53.65 280.39 6842.68 4757.15 -805.84 -4775.39 4842.90 260.42 0.42 8853.26 52.63 278.69 6897.44 4829.41 -793.72 -4847.41 4911.96 260.70 1.86 8946.07 5i .40 277.61 6954.56 4902.03 -783.35 -4919.82 498'1.79 260.95 1.61 '9040.00 50.33 277.37 7013.84 4974.45 -773.85 -4992.05 5051.68 261.19 1.16 9139.14 50.62 277.21 7076.94 5050.49 -764.15 -5067.91 5125.19 261,43 0.32 9227.63 51.07 277.21 7132.81 5118.73 -755.53 -5135.98 5191.26 261.63 0.51 9323.34 50.77 277,20 7193.15 5192.62 -746.22 -5209.69 5262.86 261.85 0.31 9417.29 50.70 276.78 7252.61 5264,99 -737.36 -5281.89 5333.11' 262.05 0.35 9509.88 50.86 277.59 7311.15 5336.34 -728.39 -5353.06 5402.39 262.25 0.70 9605.33 51.20 278.26 7371.18 5410.04 -718.16 -5426.56 5473.87 262.46 0.65 9694.59 50.81 277.74 7427.35 5478.92 -708.50 -5495.25 5540.74 262.65 0.63 9788.17 50.77 278.22 7486.51 5550.93 -698.44 -5567.06 5610.70 262.85 0.40 9882.54 50.44 278.75 7546.40 5623.27 -687.68 -5639.19 5680.97 263.05 '0.56 9974.90 50.58 278.69 7605.14 5693.94 -676.87 -5709.64 5749.63 263.24 0.16 10068.86 49.74 278.07 7665.33 5765.52 -666.36 -5781.02 5819.30 263.42 1.03 10162.11 49.40 278.96 7725.81 5835.93 -655.85 -5851.22 5887.86 263.60 0.81 10257.86 49.02 279.71 7788.36 5907.69 -644.09 -5922.75 5957.67 263.79 0.71 10349.73 49.67 277.53 7848.22 5976.80 -633.65 -5991.65 6025.06 263.96 1.93 [:l EPOCH 31 UNOCAL ) K-18RD & K-18RD-ST#1 MD Incl Azim TVD VSec NS EW Closure CI Azim DLS (ft) (°) (") (ft) (ft) (ft) (ft) (ft) (°) ("/lOOft) 10~,'!,.24 51.67 274.32 7908.12 6049.64 -626.14 -6064.35 6096.58 264.11 3.37 10541.19 52.47 270.74 7967.73 6126.07 -622.77 -6140.72 6172.22 264.21 3.03 10632.85 52.85 266.10 8023.34 6198.82 -624.79 -6213.53 6244.87 264.26 4.05 10726.59 52.15 262.64 8080.42 6272.64 -632.07 -6287.52 6319.21 264.26 3.02 10838.63 52.04 258.36 8149.27 6359.47 -646.66 -6374.68 6407.39 264.21 3.02 10932.40 54.26 254.72 8205.52 6432.02 -664.15 -6447.62 6481.74 264.12 3.91 11027.07 54.28 254.26 8260.80 6505.62 -684.70 -6521.67 6557.52 264.01 0.40 11119.04 52.60 254.54 8315.58 6576.32 -704.57 -6592.82 6630.36 263.90 1.84 11214.58 52.39 253.61 8373.75 6648.75 -725.36 -6665.70 6705.05 263.79 0.80 11309.53 51.94 254.41 8431.99 6720.38 -746.02 -6737.79 6778.96 263.68 0.82 11403.20 51.89 255.21 8489.77 6791.10 -765.34 -6808.94 6851.82 263.59 0.67 11497.74 52.42 254.90 8547.78 6862.80 -784.59 -6881.07 6925.65 263.50 0.62 11589.45 52.13 254.68 8603.92 6932.37 -803.63 -6951.06 6997.39 263.41 0.37 11682'.06 51.73 255.43 8661.03 7002.40 -822.43 -7021.50 7069.50 263.32 0.77 11773.68 52.10 256.76 8717.54 7072.01 -839.76 -7091.50 7141.05 263.25 1.21 11845.51 51.83 257.22 8761.80 7126.85 -852.49 -7146.62 7197.29 263.20 0.63 11938.98 51.34 257.90 8819.88 7198.01 -868.27 -7218.14 7270.17 263.14 0.77 12029.18 51.06 258.26 8876.40 7266.47 -882.79 -7286.92 7340.20 263.09 0.44 12123.45 50.45 258.72 8936.04 7337.68 -897.36 -7358.46 7412.97 263.05 0.75 12222.51 49.64 259.22 8999.65 7411.89 -911.89 -7432.99 7488.71 263.01 0.90 12316.48 48.65 260.32 9061.12 7481.54 -924.52 -7502193 7559.67 262.98 1.38 12373.09 47.37 259.98 9098.99 7522.84 -931.71 -7544.38 7601.70 262.96 2.30 EPOCH 32 UNOCAL ) K-18RD & K-18RD-ST#1 SURVEY RECORD (K-18RD-ST#1) MD Includin Azim TVD VSec NS EW DLS Course Closure g 10162.11 49.40 278.96 7725.84 5804.80 -655.85 -5851.21 - 0.00 5887.85 10266.05 45.19 278.29 7796.32 5874.20 -644.38 -5926.71 4.08 103.94 5961.63 10359.06 42.85 276.88 7863.20 5933.41 -635.84 -5990.76 2.73 93.01 6024.41 10451.12 42.49 274.17 7930.89 5991.43 -629.83 -6052.86 2.03 92.06 6085.54 10541.98 43.02 267.50 7997.64 6050.39 -628.95 -6114.46 5.02 90.86 6146.72 10634.90 41.73 261.45 8066.32 6111.90 -634.93 -6176.74 4.60 92.92 6209.29 10731.75 39.24 254.58 8140.01 6174.53 -647.87 -6238.18 5.27 96.85 6271.73 10823.55 37.68 250.11 8211.90 6231.57 -665.14 -6292.57 3.47 91.80 6327.62 10917.35 38.62 247.76 8285.67 6289.28 -685.98 -6346.63 1.84 93.80 6383.59 11011.79 38.89 245.53 8359.32 6347.90 -709.41 -6400.89 1.51 94.44 6440.08 11109.45 38.82 244.83 8435.37 6408.45 -735.13 -6456.50 0.46 97.66 6498.21 11204.39 36.77 244.73 8510.39 6465.89 -759.92 -6509.13 2.16 94.94 6553.34 11295.17 36.56 244.74 8583.21 6519.39 -783.06 -6558.16 0.23 90.78 6604.74 11391.36 36.50 244.39 8660.50 6575.88 -807.65 -6609.86 0.23 96.19 6659.02 11485.75 36.83 242.11 8736.22 6631.25 -833.02 -6660.18 1.48 94.39 6712.08 11580.48 36.48 242.73 8812.22 6686.65 -859.20 -6710.31 0.54 94.73 6765.09 11689.28 36.88 243.35 8899.47 6750.47 -888.66 -6768.24 0.50 108,80 6826.33 11782.58 38.08 240.27 8973.52 6805.94 -915.49 -6818.25 2.38 93.30 6879.44 11878.38 38.56 240.09 9048.68 6863.63 -945.03 -6869.79 0.51 95.80 6934.48 11968.59 38.91 240.16 9119.05 6918.44 -973.15 -6918.73' 0.39 90.21 6986.84 12034.85 39.31 241.50 9170.43 6959.09 -993.53 -6955.17 1.41 66.26 7025.78 ' 12128.49 40.03 241.01 9242.50 7017.40 -1022.28 -7007.58 0.84 93.64 7081.76 12221.49 40.52 241.52 9313.46 7076.05 -1051 .'18 -7060.30 0.64 93.00 7138.12 12312.53 41.09 241.28 9382.37 7134.12 -1079.66 -7112.53 0.65 91.04 7194.01 12368.97 41.52 241,87 9424.77 7170.50 -1097.40 -7145.30 1.03 56.44 7229.08 12406.44 41.70 241.90 9452,78 7194.83 -1109. t2 -7167.24 0.48 37.47 7252.55 12489.16 41.92 242.29 9514.44 7248.80 -1134.93 -7215.98 0.41' 82.72 7304.68 ,, , , , EPOCH 33 0 ,. C: Z 0 UNOrJI. K-18RD & K-18RD-ST#1 DALLY REPORTS EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 10, 2001 12:01 AM DEPTH: 6785' ROP (FT/HR): CURRENT BIT INFORMATION: DALLY COST: $1715 CUM COST: $1715 YESTERDAY: NA' 24 HR FTG: 0' PRESENT: 0 24 HR AVE: 0 NO.: 1 MAKE: SMITH TYPE: MF10TODGPS 8.5" DEPTH IN: 6785' Footage Hours On Bottom Off Bottom TOTAL: 0 0 0 0 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS: 0 0 0 0 GAS SUMMARY ,, BACKGROUND GAS: Max:I 14u(~' Average: I 2u Current: I 2u CONNECTION GAS: Max: u Average: u Current: u(~' TRIP GAS: 14u(~6785' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: SAND: 0 % CLAYSTONE: CONGLOMERATE: 0 % 0 % 0 % COAL INTERVALS: NA COAL ANTICIPATED: 7170' SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C..~1 C._~2 C_~3 Ca, C..~5 REMARKS: Epoch arrived on location at 10:30 AM, rigged up and prepared to log on when return to drilling at 6785'. Displaced bad mud while tripping in and circulated above window displacing out of hole for SWACO. Tripped in and circulated below window, maximum 14 units of gas. EPOCH 36 UNOCAL ) K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 11, 2001 12:01 AM DEPTH: 6986' ROP (FT/HR): CURRENT BIT INFORMATION: NO.: I MAKE: SMITH DALLY COST: $1715 CUM COST: $3430 YESTERDAY: 6785' 24 HR FTG: 201' PRESENT: 44 24 HR AVE: 23.1 TYPE: MF10TODGPS 8.5" DEPTH IN: 6785' DEPTH OUT: 6880' FoOtage Hours On Bottom Off Bottom TOTAL: 95 10.0 6.1 3.9 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS: 95 10.0 6.1 3.9 NO.: 2 MAKE: SMITH TYPE: 15MFFDGPS 8.5" DEPTH IN: 6880' Footage Hours On Bottom Off Bottom TOTAL: 106 4.3 2.6 1.7 YESTERDAY'S TOTAL: 0 0 0 0 , , PAST 24 HOURS: 0 0 0 0 GAS SUMMARY CONNECTION GAS: Max: 0u Average: 0u current: 0u(~6940' TRIP GAS: 12u@6880' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SILTSTONE: 10 % SAND: 30 % CLAYSTONE: 40 % CONGLOMERATE: 10 .% COAL INTERVALS: THIN BEDS AND CLASTS COAL ANTICIPATED: 7170' SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C._~1 C._~2 C_~3 C~4 C~5 REMARKS: Finished displacing bad mud in hole for SWACO injection and circulated and conditioned mud. Reamed from window to bottom. Drilled ahead from 6785 to 6880', MWD tool failure, and circulated out. Pulled out of hole and changed MWD tool and bit. Ran in with bit #2 and drilled ahead, rotating and sliding from 6880' to 6986'. EPOCH 37 UNOCAL ) K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 12, 2001 12:0t AM DEPTH: 7845' ROP (FTIHR): CURRENT BIT INFORMATION: DAILY COST: $1715 CUM COST: $5145 YESTERDAY: 6986' 24 HR FTG: 859' PRESENT: 39 24 HR AVE: 45.9 NO.: 2 MAKE: SMITH TYPE: 15MFFDGPS 8.5" DEPTH IN: 6880' 'FoOtage Houm On Bottom Off Bottom TOTAL: 965 28.3 21.3 7.0 YESTERDAY'S TOTAL: 106 4.3 2.6 1.7 PAST 24 HOURS: 859 24 18.7 5.3 GAS SUMMARY CONNECTION GAS: Max: 4u(~7788' Average: 3u Current: 4u@7788' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 15 % SlLTSTONE: 10 % SAND: 15 % CLAYSTONE: 55 % CONGLOMERATE: 5 % COAL INTERVALS: 7130-45', 7390-7400', 7460-65', 7575-85', 7650-70', 7740-50'. COAL ANTICIPATED: Correlating approximately 35' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: BEFORE DURING MAXIMUM AFTER TOTAL: ROP WOB MWt GAS C1 C2 NET C_~3 C4 c_~s REMARKS: Drilled ahead, rotating and sliding, from 6986' to 7845'. [::1 EPOCH 38 UNOC. K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 13, 2001 12:01 AM DEPTH: 8444' ROP (FTIHR): CURRENT BIT INFORMATION: DAILY COST: $1715 CUM COST: $6860 YESTERDAY: 7845' 24 HR FTG: 599' PRESENT: 38 24 HR AVE: 38.6 NO.: 2 MAKE: SMITH TYPE: 15MFFDGPS 8.5" DEPTH IN: 6880' DEPTH OUT: 8444' FOotage Hours .... On Bottom Off Bottom TOTAL: 1564 43.8 33.0 10.8 YESTERDAY'S TOTAL: 965 28.3 21.3 7.0 PAST 24 HOURS: 599 15.5 11.7 3.8 GAS SUMMARY BACKGROUND GAS: Max: 103u~8048' Avera~te:I 19u Current:I 32u CONNECTION GAS: Max: 19u(~8165' Avera~le: 3u Current: 0u~8352' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SlLTSTONE: 10 % SAND: 40 % CLAYSTONE: . 40 % CONGLOMERATE: 5 % COAL INTERVALS: 7950-60', 8035-50', 8155-65', 8220-30', 8275-80', 8425-40'. COAL ANTICIPATED: Correlating approximately 17' high to type log, SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C...~1 C_.~2 C~3 C_~4 C_~5 REMARKS: Drilled ahead, rotating and sliding, from 7845' to 8445', and circulated out. Pulled out of hole to shoe and sheared pump out sub. Pulled out of hole and laid down stabilizer, MWD, motor, and bit. Rigged up and begin test BOPE. [:l EPOCH 39 UNOCAL ) K-18RD & K-18RD~ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 14, 2001 12:01 AM DEPTH: 8580' ROP (FTIHR): CURRENT BIT INFORMATION: DAILY COST: $1715 CUM COST: $8575 YESTERDAY: 8~.~.~.' 24 HR FTG: 136' PRESENT: 135 24 HR AVE: 104.6 NO.: 3 MAKE: HYCLOG TYPE: DS75HGJNW 8.5" DEPTH IN: 8444' Footage Hours On Bottom Off Bottom TOTAL: 136 5.2 1.3 3.9 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS: 136 5.2 1.3 3.9 NO.: 2 MAKE: SMITH TYPE: 15MFFDGPS 8.5" DEPTH IN: 6880' DEPTH OUT: 8444' , ,, Footage Hours On Bottom Off Bottom TOTAL: 1564 43.8 33.0 10.8 YESTERDAY'S TOTAL: 1564 43.8 33.0 10.8 PAST 24 HOURS: 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max:I 70u(~8490' Average:I 30u Current: 38u CONNECTION GAS: . Max: 0u~8543' Average: 0u Current: 0u~8543' TRIP GAS: 119u~.8444' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 40 % SlLTSTONE: 5 % SAND: 10 % CLAYSTONE: 40 % CONGLOMERATE: 5 % COAL INTERVALS: 8425-40', 8480-8515'. COAL ANTICIPATED: Correlating approximately 21' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C._~1 C..~2 C_~3 C_~4 C...~5 REMARKS: Tested BOPE, and changed out air boot on pitch nipple. Pickup BHA with new PDC bit #3, tested MWD, and picked up 5" drill pipe. Ran in hole to shoe, cut and slipped drill line, and serviced rig. Ran in hole to bottom, and drilled ahead from 8444' to 8490'. Worked pipe while working on pumps. Drilled ahead from 8490' to 8580'. EPOCH 40 UNOCALe K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC K-18RD DATE: JULY 15, 2001 12:01 AM DEPTH: 9319' ROP (FTIHR): CURRENT BIT INFORMATION: DALLY COST: $1715 CUM COST: $10290 YESTERDAY: 8580' 24 HR FTG: 739' PRESENT: 11.5 24 HR AVE: 46.5 NO.: 3 MAKE: HYCLOG TYPE: DS75HGJNW 8.5" DEPTH IN: 8444' Footage Hours On Bottom Off Bottom TOTAL: 875 29.2 17.2 12.0 YESTERDAY'S TOTAL: 136 5.2 1.3 3.9 PAST 24 HOURS: 739 24.0 15.9 8.1 GAS SUMMARY BACKGROUND GAS: MaX: 73u~8631' Average:[ 20u Current:I 13u CONNECTION GAS: Max: 16u(~8918' Average: 3u Current: 0u~9291' TRIP GAS: u(~' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 5 % SlLTSTONE: 20 % SAND: 35 % CLAYSTONE: .35. % CONGLOMERATE: 5 % COAL INTERVALS: 8630-35', 8840-50', 8945-60', 9000-05', 9020-35', 9085-9100'. COAL ANTICIPATED: Correlating approximately 45' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C.~1 C._~2 C~3 Ca, C..~5 REMARKS: Drilled ahead, rotating, from 8580' to 8732', and worked on pumps. Drilled ahead, rotating and sliding, from 8732' to 9319'. [::1 EPOCH UNOr. K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 16, 2001 12:01 AM DEPTH: 9665' ROP (FTIHR): CURRENT BIT INFORMATION: DAILY COST: $1715 CUM COST: YESTERDAY: 9319' 24 HR FTG: PRESENT: 7.1 24 HR AVE: $12005 346' 21.9 NO.: 3 MAKE: HYCLOG TYPE: DS75HGJNW 8.5~ DEPTH IN: 8444' DEPTH OUT: 9665' Footage Hours On Bottom Off Bottom TOTAL: 1221 48.2 33.0 15.2 YESTERDAY'S TOTAL: 875 29.2 17.2 12.0 PAST 24 HOURS: 346 19.0 15.8 3.2 GAS SUMMARY CONNECTION GAS: Max: 0u@9571' Average: 0u Current: 0u(~9571' TRIP GAS: u(~' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 25 % CLAYSTONE: 40 % CONGLOMERATE: 5 % COAL INTERVALS: 9350-60', 9410-20', 9515-45', 9570-80', 9630-40', 9655-60'. COAL ANTICIPATED: Correlating approximately 45' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C_~1 C_.~2 C_.~3 C_~4 C.._~5 REMARKS: Drilled ahead, rotating, from 9315' to 9385', and worked on pumps. Drilled ahead, rotating and sliding, from 9385' to 9665'. Pulled out of hole to window. EPOCH 42 UNOCALe K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 17, 2001 DAILY COST: $1715 CUM COST: $13720 12:01 AM DEPTH: 9900' YESTERDAY: 9666' 24 HR FTG: 244' ROP (FTIHR): PRESENT: 26.9 24 HR AVE: 22.8 CURRENT BIT INFORMATION: NO.: 4 MAKE: SMITH TYPE: MGR35SPX 8.5" DEPTH IN: 9666' Footage Hours On Bottom Off Bottom TOTAL: 244 13.3 10.7 2.6 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS: 244 13.3 10.7 2.6 NO.: 3 MAKE: HYCLOG TYPE: DS75HGJNW 8.5" DEPTH IN: 8444' DEPTH OUT: 9666' Footage Hours On Bottom Off Bottom TOTAL: 1222 48.2 33.0 15.2 YESTERDAY'S TOTAL: 1222 48.2 33.0 15.2 PAST 24 HOURS: 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max:I 89u(~9891' Average:I 14u Current: 86u CONNECTION GAs: Max: 0u(~9853' Average: 0u Current: 0u(~9853' TRIP GAS: 221 u(~9665' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SILTSTONE: 15 % SAND: 30 % CLAYSTONE: 40 % CONGLOMERATE: 5 % COAL INTERVALS: 9720-35', 9795-9800'. COAL ANTICIPATED: Correlating approximately 105' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C.~1 C_.~2 C_~3 Ca, C_.~5 REMARKS: Finished pulling out of hole and changed bit, and pump out sub, and ran in with BHA. Serviced rig and top drive and tested MWD. Tripped in hole with heavy weight and changed air tool in pitcher nipple. Tripped in hole with drill pipe, and reamed to bottom from 9573' to 9665'. Drilled ahead from 9665' to 9900'. EPOCH 43 UNOr. ALe K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 18, 2001 12:01 AM DEPTH: 10413' ROP (FTIHR): CURRENT BIT INFORMATION: NO.: 4 MAKE: SMITH DAILY COST: $1715 CUM COST: $15435 YESTERDAY: 9900' 24 HR FTG: 513' PRESENT: 19.0 24 HR AVE: 22.8 TYPE: MGR35SPX 8.5' DEPTH IN: 9666' Footage Houm On Bottom Off Bottom TOTAL: 747 37.3 29.9 7.4 YESTERDAY'S TOTAL: 234 13.3 10.7 2.6 PAST 24 HOURS: 513 24 19.2 4.8 GAS SUMMARY BACKGROUND GAS: Max: 185u~9924' Average:I 24u Current:[ 18u CONNECTION GAS: Max: 155u(~9946' Average: 32u Current: 0u(~10319' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SlLTSTONE: 10 % SAND: 30 % CLAYSTONE: 35 % CONGLOMERATE: 5 % COAL INTERVALS: 9885-9905', t0000-15', 10990-95', 10115-30', 10200-15', 10360-75'. COAL ANTICIPATED: Correlating approximately 195' Iow to type log (fault). SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C_~1 C..~2 C~3 C_~4 c_~s REMARKS: Drilled ahead, rotating and sliding, from 9900' to 10413'. [:l EPOCH 44 UNOCAL K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 19, 2001 DALLY COST: $1715 CUM COST: $17150 12:01 AM DEPTH: 10696' ROP (FTIHR): YESTERDAY: 10413' 24 HR FTG: 283' PRESENT: 10.2 24 HR AVE: 16.2 CURRENT BIT INFORMATION: NO.: 4 MAKE: SMITH TYPE: MGR35SPX 8.5" DEPTH IN: 9666' Footage Houm On Bottom Off Bottom TOTAL: 1030 61.3 47.4 13.9 YESTERDAY'S TOTAL: 747 37.3 29.9 7.4 PAST 24 HOURS: 283 24 17.5 6.5 GAS SUMMARY BACKGROUND GAS: Max:I 47u(~10574' Avem~le:I 17u Current:' 7u CONNECTION GAS: Max: 72u(~10601' Average: 38u Current: 72u(~10601' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 15 % SlLTSTONE: 10 % SAND: 40 % CLAYSTONE: 35 % CONGLOMERATE: 0 % COAL INTERVALS: COAL ANTICIPATED: 10440-50', 10505-15', 10600-10'. Correlating approximately 257' Iow to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET ROP WOB MWt GAS C_~1 C_~2 C_.~3 C._~4 C_~5 BEFORE DURING MAXIMUM AFTER REMARKS: Drilled ahead, rotating and sliding, from 10413' to 10696'. EPOCH 45 UNOCAL ) K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 20, 2001 t2:01 AM DEPTH: 10789' ROP (FTIHR): CURRENT BIT INFORMATION: DAILY COST: $1715 CUM COST: YESTERDAY: 10696' 24 HR FTG: PRESENT: 9.5 24 HR AVE: $18865 93' 10.5 NO.: 4 MAKE: SMITH TYPE: MGR35SPX 8.5' DEPTH IN: 9666' DEPTH OUT: 10789' Footage Hours On Bottom Off Bottom TOTAL: 1123 75.1 56.3 18.8 YESTERDAY'S TOTAL: 1030 61.3 47.4 13.9 PAST 24 HOURS: 93 13.8 8.9 4.9 GAS SUMMARY BACKGROUND GAS: Max:I 31u~10719' Average:I 8u Current:I 8u CONNECTION GAS: Max: 0u~10696' Average: 0u Current: 0u~10696' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 15 % SILTSTONE: 20 % SAND: 20 % CLAYSTONE: 55 % CONGLOMERATE: 0 % COAL INTERVALS: COAL ANTICIPATED: 10715-25'. Correlating approximately 295' Iow to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C._~1 C_~2 C.~3 Ca, C._~5 REMARKS: Drilled ahead, rotating and sliding, from 10696' to 10789'. Circulated out and pulled out of hole, pumping dry job and shearing pump out sub at shoe. Began making up BHA. EPOCH 46 UNOr. ALe K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 21, 2001 DAILY COST: $1715 CUM COST: $20580 12:01 AM DEPTH: 11049' YESTERDAY: 10789' 24 HR FTG: 260' ROP (FTIHR): PRESENT: 3.4 24 HR AVE: 21.7 CURRENT BIT INFORMATION: NO.: 5 MAKE: SMITH TYPE: MGR35SPX 8.5" DEPTH IN: 10789' Footage Hours On ~ottom Off Bottom TOTAL: 260 18.0 12.1 5.9 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS: 260 18.0 12.0 5.9 NO.: 4 MAKE: SMITH TYPE: MGR35SPX 8.5" DEPTH IN: 9666' DEPTH OUT: 10789' Footage Houm On Bottom Off Bottom TOTAL: 1123 75.1 56.3 18.8 YESTERDAY'S TOTAL: 1123 75.1 56.3 18.8 PAST 24 HOURS: 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: I 32u(~10898' Avera~le:l 12u Current: 17u CONNECTION GAS: Max:I 7u@10993' Avera~le:I 2u Current: 7u~10993' TRIP GAS: 115u(~10789' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SILTSTONE: 10 % SAND: 55 % CLAYSTONE: 25 % CONGLOMERATE: 0 % COAL INTERVALS: t0890-900', 10965-80'. COAL ANTICIPATED: Correlating approximately 330' Iow to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET ROP WOB MWt GAS C._~1 C..~2 C3 C._~4 C_.~5 BEFORE DURING MAXIMUM AFTER REMARKS: Finished making up BHA with new bit #5 and pump out sub. Tripped in hole with heavy weight drill pipe and tested MWD. Tripped in hole to 10712', and reamed to 10789'. Drilled ahead, rotating and sliding, from 10789' to 11049'. EPOCH 47 UNOF. AL( K-lSRD 8, K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 22, 2001 DAILY COST: $1715 CUM COST: $22295 12:01 AM DEPTH: 11276' YESTERDAY: 11049' 24 HR FTG: 227' ROP (FTIHR): PRESENT: 27.7 24 HR AVE: 12.1 CURRENT BIT INFORMATION: NO.: 5 MAKE: SMITH TYPE: MGR35SPX 8.5" DEPTH IN: 10789' ,, Footage Hours On Bottom Off Bottom TOTAL: 487 42 30.9 11.1 YESTERDAY'S TOTAL: 260 18.0 12.1 5.9 PAST 24 HOURS: 227 24 18.8 5.2 GAS SUMMARY BACKGROUND GAS: Max:I 30u(~11' Average:I 16u Current:I 6u CONNECTION GAS: Max: 0u(~l 1181' Average: 0u Current: 0u(~l 1181' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SILTSTONE: 5 % SAND: 45 % CLAYSTONE: 30 % CONGLOMERATE: 10 % COAL INTERVALS: COAL ANTICIPATED: 11210-30'. Correlating approximately 315' Iow to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET ROP WOB MWt GAS c__~ c._~2 c_~3 c_~4 c_~s BEFORE DURING MAXIMUM AFTER REMARKS: Drilled ahead, rotating and sliding, from 11049' to 11276'. [:1 EPOCH 48 UNOCAL K-18RD & K-18RD-ST#1 DATE: JULY 23, 2001 12:01 AM DEPTH: 11439' ROP (FTIHR): CURRENT BIT INFORMATION: NO.: 5 MAKE: SMITH EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DALLY COST: $1715 CUM COST: $24010 YESTERDAY: 11276' 24 HR FTG: 163' PRESENT: 2.8 24 HR AVE: 8.2 TYPE: MGR35SPX 8.5" DEPTH IN: 10789' FOOtage Hours On Bottom Off Bottom TOTAL: 650 66 50.8 15.2 YESTERDAY'S TOTAL: 487 42 30.9 11.1 PAST 24 HOURS: 163 24 19.9 4.1 GAS SUMMARY BACKGROUND GAS: Max: 23u~11294' Average:I 10u Current:I 12u CONNECTION GAS: Max: 19u~11276' Average: 19u Current: 19u~11276' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SILTSTONE: SAND: 50 % CLAYSTONE: CONGLOMERATE: 10 % COAL INTERVALS: COAL ANTICIPATED: 5 % SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: 25 % 11355-60', 11405-15'. Correlating approximately 310' Iow to type log. INTERVAL: TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C...~1 C_.~2 C~3 C_~4 C_.~S REMARKS: Drilled ahead, rotating and sliding, from 11276' to 11439'. [::1 EPOCH 49 UNOCAL K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 24, 2001 DALLY COST: $1715 CUM COST: $25725 12:01 AM DEPTH: 11582' YESTERDAY: 11439' 24 HR FTG: 143' ROP (FTIHR): PRESENT: 3.4 24 HR AVE: 8.9 CURRENT BIT INFORMATION: NO.: 6 MAKE: SMITH TYPE: 20MFDGPS 8.5" DEPTH IN: 11582' Footage Hours On Bottom Off Bottom TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: 5 MAKE: SMITH TYPE: MGR35SPX 8.5" DEPTH IN: 10789' DEPTH OUT: 11582' F~0ta'ge ' Hours ........ On Bottom Off Bottom TOTAL: 793 84.5 66.8 17.7 YESTERDAY'S TOTAL: 650 66 50.8 15.2 PAST 24 HOURS: 143 18.5 16 2.5 GAS SUMMARY BACKGROUND GAS: Max: 47u~11477' Average:I 14u Current:I 10u CONNECTION GAS: Max: 9u~11464' Avem~le: 5u Current: 2u~11558' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SlLTSTONE: 10 % SAND: 45 % CLAYSTONE: 25 % CONGLOMERATE: 10 % COAL INTERVALS: 11545-55'. COAL ANTICIPATED: Correlating approximately 290' Iow to type log. SHOW SUMMARY: NONE INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C__1 C._~2 C__3 C__4 C_..~5 REMARKS: Drilled ahead, rotating, from 1t439' to 11582'. Circulated out, pumped dry job, and pulled out of hole. EPOCH 50 UNOCAL K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 25, 2001 12:01 AM DEPTH: 11629' ROP (FTIHR): CURRENT BIT INFORMATION: NO.: 6 MAKE: SMITH DALLY COST: $1715 CUM COST: $27440 YESTERDAY: 11582' 24 HR FTG: 47' PRESENT: 7.4 24 HR AVE: 15.2 TYPE: 20MFDGPS 8.5" DEPTH IN: 11582' Footage Hours On Bottom Off Bottom TOTAL: 47 7.0 3.9 3.1 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS: 47 7.0 3.9 3.1 NO.: 5 MAKE: SMITH TYPE: MGR35SPX 8.5" DEPTH IN: 10789' DEPTH OUT: 11582' .......... FoOtage. Hours On Bottom Off Bottom TOTAL: 793 84.5 66.8 17.7 YESTERDAY'S TOTAL: 793 84.5 66.8 17.7 PAST 24 HOURS: 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max:I 28u(~11603' Average:I 23u Current:I 24u CONNECTION GAS: Max: NA(~' Average: NA Current: NA~' TRIP GAS: 55u@11582' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: COAL INTERVALS: COAL ANTICIPATED: 30 % SILTSTONE: 5 % 35 % CLAYSTONE: 25 % 5 % 11583-95'. Correlating approximately 290' Iow to type log. SHOW SUMMARY: NONE INTERVAL: [ TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C._~ C_~2 C3 C_~4 C._~5 REMARKS: Rigged up and tested BOPE. Made up BHA with new mud motor and new bit #6 and cut drill line. Tested MWD and tripped in hole. Drilled ahead from 11582' to 11629'. [::1 EPOCH 51 UNO .AL K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 26, 2001 12:01 AM DEPTH: 11889' ROP (FTIHR): CURRENT BIT INFORMATION: DALLY COST: $1715 YESTERDAY: 11629' PRESENT: 0 CUM COST: $29155 24 HR FTG: 24 HR AVE: 260' 19.1 NO.: 6 MAKE: SMITH TYPE: 20MFDGPS 8.5" DEPTH IN: 11582' Footage Hours On BOttom Off Bottom TOTAL: 306.5 30.3 24.1 6.2 YESTERDAY'S TOTAL: 47 7 3.9 3.1 PAST 24 HOURS: 260 23 20.2 3.1 GAS SUMMARY BACKGROUND GAS: Max:I 28u~11864' Average:I 14 Current:I 12u CONNECTION GAS: Max: 19u~11831' Average: NA Current: NAg' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 15 % SILTSTONE: 5 % SAND: 50 % CLAYSTONE: 25 % CONGLOMERATE: 5 % COAL INTERVALS: COAL ANTICIPATED: 11720-57'. Correlating approximately 250' Iow to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C_~1 C__~2 C~3 C~4 C_~5 REMARKS: Drilled ahead from 11629' to 11889'. Pumped high vis sweep, circulated out, and pulled out of hole. gl EPOCH 52 UNOr. K-18RD & K-18RD-ST#1 DATE: JULY 27, 2001 12:01 AM DEPTH: 11889' ROP (FTIHR): CURRENT BIT INFORMATION: EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DALLY COST: $1715 YESTERDAY: 11889' PRESENT: 0 CUM COST: $30870 24 HR FTG: 0' 24 HR AVE: 0 NO.: 7 MAKE: Hughes TYPE: MX-RS20DD 8.5' DEPTH IN: 11889' Footage Hours On Bottom Off Bottom TOTAL: 0 0 0 0 YESTERDAY'S TOTAL: NA NA NA NA PAST 24 HOURS: 0 0 0 0 NO.: 6 MAKE: SMITH TYPE: 20MFDGPS 8.5" DEPTH IN: 11582' FoOtage Hours On Bottom Off Bottom TOTAL: 306.5 30.3 24.1 27.4 YESTERDAY'S TOTAL: 306.5 30.3 24.1 6.2 PAST 24 HOURS: 0 0 GAS SUMMARY CONNECTION.GAS: Max: NAu(~' Average: NA Current: NA~' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 15 % SILTSTONE: 5 % SAND: 50 % CLAYSTONE: 25 % CONGLOMERATE: 5 % COAL INTERVALS: 11720-57'. COAL ANTICIPATED: Correlating approximately 250' Iow to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C._~1 C_.~2 C_~3 C_~4 C_.~5 REMARKS: Pulled out of hole. Ran in Hole with wireline for UBI and Gamma ray logs from 11850' to 6766'. Pulled out of hole with wireline. Made up BHA with new bit #7, CDR tool, MWD and ran in hole. EPOCH 53 UNOr. JtLe K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 28, 2001 12:01 AM DEPTH: 11899' ROP (FTIHR): CURRENT BIT INFORMATION: DAILY COST: $1715 CUM COST: $32585 YESTERDAY: 11889' 24 HR FTG: 10' PRESENT: 9.2 24 HR AVE: 0 NO.: 7 MAKE: Huqhes TYPE: MX-RS20DD 8.5" DEPTH IN: 11889' " Footage Hours On Bottom Off Bottom TOTAL: 10 .56 .56 0 YESTERDAY'S TOTAL: NA NA NA NA PAST 24 HOURS: 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: 20u(~' Average:INA Current:I 23 CONNECTION GAS: Max: NAu(~' Average: NA Current: NA(~' TRIP GAS: 348u WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 15 % SILTSTONE: 5 % SAND: 50 % CLAYSTONE: 25 % CONGLOMERATE: 5 % COAL INTERVALS: NONE. COAL ANTICIPATED: Correlating approximately 250' Iow to type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: I TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C._~1 C_.~2 C.~3 Ca, C._~5 REMARKS: Made up BHA with new bit #7, CDR tool, nuke source, and MWD. Waited on part/boat. Fit BHA with new jars and mn in hole; breaking every connection. Drilled ahead from 11889 to 11899'. [::1 EPOCH 54 UNOr. ALe K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 29, 2001 12:01 AM DEPTH: 12200' ROP (FTIHR): CURRENT BIT INFORMATION: DAILY COST: $1715 CUM COST: $34300 YESTERDAY: 11899' 24 HR FTG: 301' PRESENT: 3.8 24 HR AVE: 15.4 NO.: 7 MAKE: Hughes TYPE: MX-RS20DD 8.5" DEPTH IN: 11889' Footage Hours On 'Bottom Off Bottom TOTAL: 310 24.5 22.3 2.2 YESTERDAY'S TOTAL: 10 .56 .56 0 PAST 24 HOURS: 300 25.1 22.9 2.2 GAS SUMMARY BACKGROUND GAS: Max: 16u(~' Average:I 10 Current:I 8 CONNECTION GAS: Max: 15u(~' Average: NA Current: NA(~' TRIP GAS: NAu WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: SAND: 70 % CLAYSTONE: CONGLOMERATE: 10 % COAL INTERVALS: COAL ANTICIPATED: 12105 to 12110'. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: 10 % 10 % INTERVAL: TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C1 c2 c3 c4 cs REMARKS: Drilled ahead, rotating, from 11899 to 12200'. [:1 EPOCH 55 UNOCAL K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 30, 2001 12:01 AM DEPTH: 12200' ROP (FTIHR): CURRENT BIT INFORMATION: DALLY COST: $1715 YESTERDAY: 12200' PRESENT: 0 CUM COST: $36015 24 H R FTG: 0' 24 HR AVE: 0 NO.: 8 MAKE: Hu§hes TYPE: MX-RS20DD 8.5" DEPTH IN: 12212' ~ Footage Hours O'n Bottom Off Bottom TOTAL: 0 0 0 0 YESTERDAY'S TOTAL: NA NA NA NA PAST 24 HOURS: 0 0 0 0 NO.: 7 MAKE: Hu§.hes TYPE: MX-RS20DD 8.5" DEPTH IN: 11889' Footage Hours O~n Bottom Off Bottom TOTAL: 323 26.6 23.4 3.2 YESTERDAY'S TOTAL: 310 24.5 22.3 2.2 PAST 24 HOURS: 12 1.1 1.1 1.0 GAS SUMMARY BACKGROUND GAS: Max: NA Avera!~e:I Current:I NA CONNECTION GAS: Max: NA Avera~le: NA Current': NA@' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 10 % SAND: .70 % CLAYSTONE: 10 % CONGLOMERATE: 10 % COAL INTERVALS: COAL ANTICIPATED: 12205 to 12210'. Running approx. 180' Iow of type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C._~ C_~2 C3 C4 C._~5 REMARKS: Drilled ahead, rotating, from 12200 to 12212'. Pulled out of hole, running MAD tool from 11807 to t0782' (stands 118 - t07), to change bit #7 for new bit #8. Picked up new bit and motor and ran in hole. Cut drill line and continued in hole. [::1 EPOCH 56 UNOr. AL(IJ K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: JULY 31, 2001 12:01 AM DEPTH: 12381 ' ROP (FTIHR): CURRENT BIT INFORMATION: DALLY COST: $1715 YESTERDAY: 12212' PRESENT: 4.5 CUM COST: $37730 24 HR FTG: 169' 24 HR AVE: 14 NO.: 8 MAKE: Hu§hes TYPE: MX-RS20DD 8.5" DEPTH IN: 12212' Footage Hours On Bottom Off Bottom TOTAL: 169 21.9 19.5 2.40 YESTERDAY'S TOTAL: NA NA NA NA PAST 24 HOURS: 169 21.9 19.5 2.4 GAS SUMMARY BACKGROUND GAS: Max: 8 Average: I 5 Current: ] 4 CONNECTION GAS: Max: 8(~12288' Avera~le:I NA C'urrent:.I NAg' TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 5 % SILTSTONE: 5 % SAND: 70 % CLAYSTONE: 10 % CONGLOMERATE: 10 % COAL INTERVALS: COAL ANTICIPATED: None. Running approx. 180' Iow of type log. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C~1 C2 C3 C4 cs REMARKS: Ran in hole. Drilled ahead from 12212 to1238t'. EPOCH 57 UNOCAL ) K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: August 1, 2001 12:01 AM DEPTH: 12442' ROP (FTIHR): CURRENT BIT INFORMATION: DALLY COST: $1715 CUM COST: $39445 YESTERDAY: 12381' 24 HR FTG: 61' PRESENT: 0 24 HR AVE: 0 NO.: 8 MAKE: Hughes TYPE: MX-RS20DD 8.5" DEPTH IN: 12212' Footage Hours On Bottom Off Bottom TOTAL: 230 30.1 26.5 3.6 YESTERDAY'S TOTAL: 169 21.9 19.5 2.4 PAST 24 HOURS: 61 8.2 7 1.2 GAS SUMMARY BACKGROUND GAS: Max: NA Average:I NA Current:I NA CONNECTION GAS: Max: NA Avera~le: NA Current: NA TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 5 % SILTSTONE: 5 % SAND: 70 % CLAYSTONE: 10 % CONGLOMERATE: 10 % COAL INTERVALS: None. COAL ANTICIPATED: NA. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAL: TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C...~1 C._~2 C_~3 C.~4 C._.~5 REMARKS: Drilled ahead from 12212 to12381' (TD). Pumped dry job. Pulled out of hole. Laid down BHA, MWD, CDR, stab, motor and bit. Picked up 28 joints of 2 718" tubing with stinger. Ran in hole with drill pipe. EPOCH 58 UNOC, K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD DATE: .Au.qust 2, 2001 12:01 AM DEPTH: 12442' ROP (FTIHR): CURRENT BIT INFORMATION: DALLY COST: $1715 CUM COST: $41160 YESTERDAY: 12442' 24 HR FTG: 0' PRESENT: 0 24 HR AVE: 0 NO.: 8 MAKE: Hughes TYPE: MX-RS20DD 8.5" DEPTH IN: 12212' Footage 'Hours On Bottom Off Bottom TOTAL: 230 30.1 26.5 3.6 YESTERDAY'S TOTAL: 230 30.1 26.5 3.6 PAST 24 HOURS: 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: NA Average:I NA Current:I NA CONNECTION GAS: Max: NA Avera~le: NA Current: NA TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 5 SAND: 70 CONGLOMERATE: COAL INTERVALS: None. COAL ANTICIPATED: NA. SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: % SILTSTONE: 5 % % CLAYSTONE: 10 % 10 % INTERVAL: TOTAL: NET BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C_.~1 C_~2 C_~3 C~4 C._~5 REMARKS: Rig up pump and cement lines and run cement. Pump 4 bbl mud push test to 3000 psi. Pull out of hole (slowly out of cement) with drill pipe. Lay down cementing equipment, Test BOPE. Pick up BHA and new bit #1 for sidetrack #1. EPOCH 59 UNOCAL K-18RD & K-18RD-ST#1 UNOCAL ALASKA RESOURCES, INC. K-18RD-ST#1 DATE: Fri August 3, 2001 Report for pedod Aug 2,01 12:01 AM DEPTH: 10285' ROP (FTIHR): DAILY COST: $1715 CUM COST: YESTERDAY: NA 24 HR FTG: NA PRESENT: 20 24 HR AVE: 25 $1715 CURRENT BIT INFORMATION' NO.: I MAKE: SECURITY TYPE: FM2843 8.5" DEPTH IN' 10241' Footage Hours on Bottom Off Bottom TOTAL: 44 11.66 8.08 3.58 YESTERDAY'S TOTAL: NA NA NA NA PAST 24 HOURS: 44 11.66 8.08 3.58 GAS SUMMARY CONNECTION GAS: Max: NA Average: NA Current: NA TRIP GAS: 56u WIPER TRIP GAS: I GROSS LITHOLOGY: COAL: % SILTSTONE: % SAND: 60 % CLAYSTONE: 30 % CONGLOMERATE: 10 % COAL INTERVALS: NONE COAL ANTICIPATED: 10360-375 SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAI L: NET Rop WOB BEFORE DURING MAXIMUM AFTER TOTAL: MWt GAS C._~1 C..~2 C.~3 C.~4 C...~5 REMARKS: WASH FROM 9571 TO 10080; LOOK FOR CEMENT FROM 10080 TO 10240; ATT TO KICK OFF @ 10240; WORK ON PUMP #2; WORK ON BOTH PUMPS; KICK OFF AT 10240; TO 10273; SLIDE FROM 10273 TO 10290. EPOCH 60 UNOCAL ) K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD-ST#1 DATE: ~SAT August 4, 2001 Report for pedod Aug 3,01 12:01 AM DEPTH: 10732' ROP (FTIHR): DALLY COST: $1715 CUM COST: YESTERDAY: NA 24 HR FTG: 447' PRESENT: 9.8 24 HR AVE: 18.6 $3430 CURRENT BIT INFORMATION' NO.: 1 MAKE: SECURITY TYPE: FM2843 8.5" DEPTH IN' 10241' Footage Hours On Bottom Off Bottom TOTAL: 447 36.41 23.75 12.66 YESTERDAY'S TOTAL: NA NA NA NA PAST 24 HOURS: 403 11.66 8.08 3.58 GAS SUMMARY BACKGROUND GAS: Max:, 9 Average: I 8 Current: 7 CONNECTION GAS: Max: 8 Average:I NA Current: 8 TRIP GAS: NA WIPER TRIP GAS: I GROSS LITHOLOGY: COAL: 10 % SILTSTONE: SAND: 10 % CLAYSTONE: CONGLOMERATE: % COAL INTERVALS: COAL ANTICIPATED: 10700-10705 10750-10755 SHOW SUMMARY: NONE 4O % 40 % Lithology Descriptions: Bit Type: INTERVA L: NET TOTAL: BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C~1 C._~2 C_~3 C_~4 C_~S REMARKS: DRILL, SLIDING & ROTATING FROM 10300 TO 10732. TOTAL MUD LOSSES FOR 24 HOURS = 122 BBLS. EPOCH UNOCALe K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD-ST#1 DATE: MON August 6, 2001 Report for period Aug 5,01 12:01 AM DEPTH: 11475 ROP (FT/HR): DAILY COST: $1715 CUM COST: YESTERDAY: 11095' 24 HR FTG: 380' PRESENT: 28 24 HR AVE: 15.8 $6860 CURRENT BIT INFORMATION' NO.: 1 MAKE: SECURITY TYPE' FM2843 8.5" DEPTH IN: 10241' ...... Footage Hours "On Bottom Off Bottom TOTAL: 1234 84.48 57.68 26.8 YESTERDAY'S TOTAL: 363 23.99 14.95 9.04 PAST 24 HOURS: 380 23.99 18.98 5.1 GAS SUMMARY BACKGROUND GAS: Max: 60 Average: I 10 Current: 13 CONNECTION GAS: Max: 12 Average:I 5 Current: NA TRIP GAS: NA WIPER TRIP GAS: I GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 20 % SAND: 50 % CLAYSTONE: 20 % CONGLOMERATE: 10 % COAL INTERVALS: 11389-11395 COAL ANTICIPATED: 11520-11555 SHOW SUMMARY: NONE Lithology Descriptions: Bit Type: INTERVAI L: NET BEFORE DURING MAXIMUM AFTER TOTAL: ROP WOB MWt GAS C._~1 C..~2 C_~3 C~4 cs REMARKS: DRILL, SLIDING & ROTATING FROM 11105 TO 11479'.. TOTAL MUD LOSSES FOR 24 HOURS = 67 BBLS. EPOCH 62 UNOCALe K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD-ST#1 DATE: WED Auqust 8 2001 Report for period Aug 7,01 12:01 AM DEPTH: 11852 ROP (FTIHR): DALLY COST: $1715 CUM COST: $10,290 YESTERDAY: 11665 24 HR FTG: 187 PRESENT: 28 24 HR AVE: 15.8 CURRENT BIT INFORMATION' NO.: I MAKE: SECURITY TYPE: FM2843 8.5" DEPTH IN: 10241' Footage Hours On Bottom off Bottom GRAND TOTAL: 1234 84.48 65.89 28.00 YESTERDAY'S TOTAL: 380 23.99 18.98 5.1 PAST 24 HOURS: 190 23.99 8.21 1.2 NO.: 2 MAKE: HUGHES TYPE: MX-RS20DD 8.5" DEPTH IN: 11665' ......... Footage ' Hours .... On Bottom Off Botto'--"-'~--- GRAND TOTAL: 187 13.67 12 1.67 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS 187 13.6'7 12 1.67 GAS SUMMARY BACKGROUND GAS: Max: 20 Average:I 10 Current:I 9 CONNECTION GAS: Max: 9 Average: 8 Current: 9 TRIP GAS: 157 WIPER TRIP GAS: I 63 GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 20 % SAND: .40 % CLAYSTONE: 30 % CONGLOMERATE: 10 % COAL INTERVALS: COAL ANTICIPATED: 11710-11785 Lithology Descriptions: Bit Type: INTERVA L: NET TOTAL: BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C...~1 C_.~2 C.~3 C_~4 C...~5 REMARKS: Work BHA and check pulse; run in hole to top of window; cut/slip drilling line; trouble shoot top drive; run in hole to 11574; ream 11574 to 11663 & circ. Out junk at bottom; rotate and slide from 11663 to 11852. EPOCH 63 UNOr. K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD-ST#1 DATE: Thurs Aug 9,2001 Report for period Wed Aug 8,01 12:01 AM DEPTH: 12025 ROP (FTIHR): DALLY COST: $1715 CUM COST: $12005 YESTERDAY: 11852 24 HR FTG: 173 PRESENT: 0 24 HR AVE: 7.._~2 CURRENT BIT INFORMATION: NO.: 2 MAKEHUGHES TYPE: MXRS20DD 8.5" DEPTH IN' 11665' Footage ' '/--/oUrs On Bottom Off Bott°m GRAND TOTAL: 359.8 29.4 25.93 3.47 YESTERDAY'S TOTAL: 187 13.67 12 1.67 PAST 24 HOURS: 169.8 15.73 13.93 1.8 NO 3 MAKE: TYPE: 8.5" DEPTH IN: 12025' Footage Hours On Bottom Off Bottom GRAND TOTAL: 0 0 0 0 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS 0 0 0 0 GAS SUMMARY CONNECTION GAS: Max: 9 Average; 8 Current: 9 TRIP GAS: NA WIPER TRIP GAS: I '63 GROSS LITHOLOGY: COAL: 0 % $1LTSTONE: 20 % SAND: 40 % CLAYSTONE: i0 % CONGLOMERATE: 30 % COAL INTERVALS: COAL ANTICIPATED: 1171O-11785 Lithology Descriptions: Bit Type: INTERVAI L: NET TOTAL: BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS Ct C._~2 C._~3 C~4 C...~5 REMARKS: Drill from 11582 to 12025; pump dry job; survey @ monitor well 10"; pull out of hole, monitor well 10" at shoe; lay down BHA; clean floor; pull wear ring, rig up for BOP test. [:1 EPOCH 64 UNOCAL K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC K-18RD-ST#1 DATE: Thurs FR110,2001 Report for pedod THUR Aug 9,01 12:01 AM DEPTH: 12165 HOP (FTIHR): DALLY COST: $1715 CUM COST: $13720 YESTERDAY: 12025 24 HR FTG: 140 PRESENT: 0 24 HR AVE: 7.2 CURRENT BIT INFORMATION: NO.- 2 MAKE HUGHES TYPE: MXRS20DD 8.5" DEPTH IN: 11665' Footage H~)u'r$ ....... On Bottom Off Bott°m GRAND TOTAL: 359.8 29.4 25.93 3.47 YESTERDAY'S TOTAL: 187 13.67 12 1.67 PAST 24 HOURS: 169.8 15.73 13.93 1.8 NO 3 MAKE: HUGHES TYPE: MXRS20DD 8.5" DEPTH IN: 12025' Footage Hours On'Bottom Off Bottom' GRAND TOTAL: 140 12.7 1 i .3 1.4 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS 140 0 0 0 GAS SUMMARY BACKGROUNDGAS: Max: 15 Average:I' 10 Cu.e'nt:I 12 CONNECTION GAS: Max: 0 Avera~le: 0 Current: 0 TRIP GAS: 47 WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: SAND: 40 % CLAYSTONE: CONGLOMERATE: 30 % COAL INTERVALS: COAL ANTICIPATED: 2O % 10 % Lithology Descriptions: Bit Type: INTERVA L: NET TOTAL: BEFORE DURING MAXIMUM AFTER HOP WOB MWt GAS C_~1 C2 C3 C._~4 C...~5 REMARKS: Make up test plug and set; Test BOP's 250/3000; pull test plug; set wear ring; lay down test equipment; pick up BHA, load nuclear tools, check pulse; run in hole to top of window; filling pipe two times; repair Iow drum [::1 EPOCH 65 UNOCALe K-18RD & K-18RD-ST#1 clutch valve; run in hole to 11960; ream from 11960 to 12025; drill from 12025 to 12056; change swab and liner #2 pump; drill 12056 to 12128; change swab, check valves, clean suction and discharge screens; drill from 12128 to 12170. EPOCH 66 UNOr. J Le K-18RD & K-18RD-S'I'#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD-ST#1 DATE: SAT, AUG 11,2001 Report for pedod FRI Aug 10,01 12:01 AM DEPTH: 12431 ROP (FTIHR): DAILY COST: $1715 CUM COST: $15435 YESTERDAY: 12165 24 HR FTG: 266 PRESENT: 0 24 HR AVE: 11.08 CURRENT BIT INFORMATION: NO.' 2 MAKE HUGHES TYPE: MXRS20DD 8.5" DEPTH IN' 11665' Footage ' 'Hours "'On Bottom Off BottOm GRAND TOTAL: 359.8 29.4 25.93 3.47 YESTERDAY'S TOTAL: 187 13.67 12 1.67 PAST 24 HOURS: 169.8 15.73 13.93 1.8 NO 3 MAKE: HUGHES TYPE: MXRS20DD 8.5" DEPTH IN: 12025' ' Footage Hours On Bottom Off BOtt°m GRAND TOTAL: 406 12.7 27 4.5 YESTERDAY'S TOTAL: 140 0 11.3 1.4 PAST 24 HOURS 266 0 15.7 3.1 GAS SUMMARY BACKGROUND GAS: Max: I 15 Average: I 10 Current: 12 CONNECTION GAS: Max:I 4 Average:I 4 Current: 0 TRIP GAS: '0 WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 30 % SAND: 40 % CLAYSTONE: 0 % CONGLOMERATE: 30 % COAL INTERVALS: COAL ANTICIPATED: Lithology Descriptions: Bit Type' INTERVA J L: NET BEFORE DURING MAXIMUM AFTER TOTAL: ROP WOB MWt GAS C.~1 C:2 C._~3 C~4 C_~5 REMARKS: Drill from 12170 to 12386. Drill with one pump from 12386 to 12389. Fix rod oiler and pump on #1 mud pump. Drill from 12389 to 12431. Circulate El EPOCH 67 UNOCAL K-18RD & K-18RD-ST#1 bottoms up, pump survey, monitor well. Pull out of hole---MAD pass from 12100 to 11061 .. (iL. [::1 EPOCH 68 UNOCAL ) K-18RD & K-18RD-ST#1 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-18RD-ST#1 DATE' SUN AUG 12,2001 Report for pedod SAT Aug 11,01 12:01 AM DEPTH: 12468 ROP (FTIHR): DALLY COST: $1715 CUM COST: $17150 YESTERDAY: 12431 24 HR FTG: 3_Z7 PRESENT: 0 24 HR AVE: 14.8 CURRENT BIT INFORMATION: NO.:3 MAKE HUGHES TYPE: MXRS20DD 8.5" DEPTH IN' 12025' Footage Hours On Bottom Off Bottom GRAND TOTAL: 406 12.7 27 4.5 YESTERDAY'S TOTAL: 140 0 11.3 1.4 PAST 24 HOURS: 266 0 15.7 3.1 NO 4 MAKE: SMITH TYPE: MF15TODPS 8.5"DEPTH IN: 12431 Footage Hours on' BOttom Off Bottom" GRAND TOTAL: 37 3.25 2.5 .75 YESTERDAY'S TOTAL: 0 0 0 0 PAST 24 HOURS 37 3.25 2.5 .75 GAS SUMMARY BACKGROUND GAS: Max: 24 Average: I 10 Current: I 15 CONNECTION GAS: Max: NA Average:I NA Current:I NA TRIP GAS: . . 46 WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SILTSTONE: SAND: 30 % CLAYSTONE: CONGLOMERATE: 30 % COAL INTERVALS: COAL ANTICIPATED: 30 % 0 % Lithology Descriptions: Bit Type: INTERVA L: NET TOTAL: BEFORE DURING MAXIMUM AFTER ROP WOB MWt GAS C_.~1 C_.~2 C_.~3 C.~4 C_.~5 REMARKS: MAD pass 11761-10800. Pump pill. Pull out of hole. Work BHA, down load data from logging tool. Run in hole. Check EPOCH 69 UNOCAL~) K-18RD & K-18RD-ST#1 pulse from MWD tool. Grease top drive, draw works, and crown sheave. Run in hole. Ream from 12348 to 12431. Drill from 12431 to 12470. EPOCH 70 [Fwd: K-I 8RD Cement Sidetrack ['lug] Subject: [Fwd: K-18RD Cement Sidetrack Plug] Date: Wed, 01 Aug 2001 12:59:48 -0800 From: Jane Williamson <Jane_Williamson~admin.state.ak.us> Organization: Alaska Oil & Gas Conservation Commission To: Julie M Heusser <julie heusser~admin.state.ak.us> Subject: Re: K-18RD Cement Sidetrack Plug Date: Wed, 01 Aug 2001 12:56:13 -0800 From: Jane Williamson <Jane_Williamson~admin.state.ak.us> Organization: Alaska Oil & Gas Conservation Commission To: John D Hartz <jack_hartz~admin.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Robert P Crandall <bob_crandall~admin.state.ak.us> Jack Hartz and I gave Dan Williamson verbal approval for plugging back K-18RD. They need to follow up with additional sundry within 3 days. See 20 AAC 25 (b) (2) of our regulations. Synopsis The redrill of K-18 was a sidetrack of an original wellbore to test a fault block to the NW within G and Hemlock. Redrill was appoved 6/19/01 (Permit Number 201-117). The open hole section encountered non-reservoir quality rock in these zones and lack of zones in the Hemlock. They requested verbal approval to set a cement plug (isolating the G and Hemlock zones). They then plan to kick off of the plug to a location between the existing K-18 and the initial proposed location (less than 500' laterally from approved plan). Applicable Regulations: 20 AAC 25. O15(b) (2) Changes to a program in a permit to drill Per their initial conversation, they indication that the sidetrack bottom location will be less than 500' from the original, and will not require spacing exception. If true, 403 request is needed. 20 AAC 25. 112 (a) Plugging of the uncased portion of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are confined to their repective indienous strata and are prevented from migrating into other stata or surface. The plug appears to accomplish this goal, based upon their representation. The plug isolates G and Hemlock from the new sidetrack. My first reading of the regulation made me think that a plug to bottom of wellbore required. However, with discussion with Jack and Dan Williamson, we came to the conclusion that the plug will accomplish the intent of the Reg. I have forwarded to Tom the cement procedure, and have a rough sketch of the plug depth/thickness compared to the tops G and Hemlock. Comments? I of 2 8/1/01 1:22 PM [Fwd: K-I 8RD Cement Sidetrack Plug] .. . > > "Wagstaff, Russell A -Contract" wrote: > >> Jane, >> >> As per our phone conversa~_ion we are requesting permission to plug >> back to >> sidetrack K-18RD as a remedial action to get away from the fault >> that was >> drilled through. Please find the proposed cement plug below: >> >> 45 bbls of 17 ppg cement slurry (~ 500' of 8-1/2" hole volume) >> Top of Plug between 10,000 and 10,550 depending on the final kick of >> point >> determined by the directional plan which will follow. >> >> K-28RD current: TD is 22,440 ' bid >> >> Please let me know if you need any additional information. >> > > Thanks, >> > > RUSS > >> Jane, >> >> Here is revision 2 of the sidetrack cement procedure. >> > > Thanks, >> > > Russ >> >> <<K-18RD Cement Plug Rev 2.doc>> >> >> >> >> >> Name: K-18RD Cement Plug Rev >> 2. doc >> K-18RD Cement Plug Rev 2.doc Type: WINWORD File >> (application/msword) >> Encoding: base64 > 2 of 2 8/I/01 1:22 PM UNO£AL King Piai~ m K-18RI) Cemen! Plug Rev 2.doc Revised 08/01/1) 1 Proposed Cement Sidetrack Plug Objective: Set a cement plug to sidetrack well due to geologic problems with the current TD at 12,440' MD. A new directional plan is being revised with a kickoff point of+/- 10250' MD and a maximum KOP of 10,400' MD. Status: Bottom of open hole = 12440' MD. (Drilled through a fault and some of Hemlock pay was missed. Proposed sidetrack will avoid fault and drill through all of Hemlock.) Cement Plug Procedure: 1 RIH with cementing BHA: - Cement stinger will consist 27 joints (-860') of 2-7/8" tubing from top of fish to above window. Orange-peel bottom of stinger with twenty-five ½" dia holes cut near bottom to allow for good plug placement with minimal mud contamination caused by j erring down below stinger bottom. Put slight bend in bottom joint to assist in finding hole. - 2-7/8" x 4-1/2" IF crossover (Full bore id crossover). - 5" drill pipe from above window to surface. 2 Break circ as needed on trip in to keep pipe full and to keep any floating coal out of stinger. RIH to - 10,750' and establish circ rate similar to rate to clean out cement. Note circ pressure to compare with pressure later on while circ out cement. 3 Build 20 bbl viscous WBM pill weighted to 9.2 ppg per MI instructions (if possible while RIH) 4 Pump 10 bbls of base oil ahead 5 Pump and balance 20 bbl viscous pill. 6 Pump 1 bbl of base oil behind 7 Balance plug and POOH slowly to 10,500', and circulate bottoms up. 8 Rig up Dowell and pressure test lines to 3000 psi. 9 Build at least 11 bbls "pumpable' 11.0 ppg MudPUSH XLO Spacer K-I 8RD Cement Plug Rev 2.doc 1 Revised 08/01/01 UNO£AL ) 10 Batch mix on the fly 55 bbls of 17.0 ppg cement blend. King Piali .ii K-I 8RD Cement Plug Rex' 2.doc Rcx'iscd {18/l} i/t} i Class G cement with: 0.130 gal/sk D168 Fluid Loss 0.350 gal/sk D 145A Dispersant 0.080 gal/sk D110 Retarder Yield = 1.02 cft/sk Mix water = FIW at 3.556 gal/sk Mix Fluid = 4.116 gal/sk set time = __ at 170 deg BHCT (Note: verify set time from the lab report that will be e-mailed to the Drilling Foreman) The 55 bbls of cement will give a TOC of 9,717' if 8-1/2" hole is in gauge The 55 bbls of cement will give a TOC of 9800' if hole is washed out to average of 9" The above calcs are based on cement in the 8-1/2" open hole with no pipe displacement. 860' of 2-7/8" displacement is only 1.93 bbl. 11 Pump 10 bbl 11.0 ppg MudPUSH XLO spacer followed by 55 bbl cement followed by 1 bbl MudPUSH XLO spacer. The two spacers should balance each other in height in the 2-7/8" tubing and the 2-7/8" x 8-1/2" (gauge hole, highest-worst case) annulus. 12 Displace cement and MudPUSH XLO spacers with Dowell Cement Pump using oil-based mud. PU slowly after cement exits stinger but do not overrun cement top. Underdisplace cement slightly (2-3 bbl) so that drill pipe is on a vacuum when finished pumping. 13 POOH slowly from 10,500' to safety 9217' (500' above "in gauge hole" TOC). Circulate BU at max rate while rotating and reciprocating drill pipe. Note any cement returns. 14 Drop DP dart (make sure it will pump through min id of the cement stinger which should be 2.441" ID) 15 POOH with cement BHA. 2-7/8" capacity = .00579 bbl/ft 5" dp capacity = .01776 bbl/ft 2-7/8" x 8-1/2" = .0622 bbl/ft (in gauge hole) 9" average hole = .07066 bbl/ft 8-1/2" gauge hole = .0702 bbl/ft 9" avg hole = ..07861 bbl/ft K-18RD Cement Plug Rev 2.doc 2 Revised 08/01/01 Jul ,31, 2001 10'17PM UNOCAL CORP, Unocal Ala~ka IIIIIIII I . . IIII No, 0844 p, 1 III Unocal Drilling Date: 713112001 10:13 PM Number of pages including cover sheet: To: AOGCC Jane Williamson ~hone~ Fax phone: CC: 276.7542 From: Dan Williamson Phone: 90%263-7677 Fax .phone: 907-263-7884 REMARKS: [-] Urgent 1~ For your review [2 Reply ASAP F"} Please comment Sid,e_t_ra,ck Plugs for K,.18 8D Attached you will find a drawing and procedure for the laying of the plUgs In Well K- 18RD for the sidetraok of this well, We had sent you a procedure earlier In the evening with plugs at deeper depths in the well, After a closer review of the directional plan for this deeper kickoff point (1 1,100) it was determined that I.t was not advisable to drill the sidetrack with the doglegs required to reach the target, After several Iterations it was decided to kick off at 10,250', The plug procedure attached has been modified to reftecf his change, As I mentioned In my phone conversation of today, the Hemlock and G zones present In this we'll exhibited lower than normal porosity, which may be due fo the dose proximi~ of the fault to these zones, A major fault actually passed through the lower part of the Hemlock, Thank you for your cooperation, sor~ for any confusion, Regards Dan Williamson Jul,31, 2001 lO'18PM UNOCAL CORP, No,0844 P, 2 / , :: .. /1/K ~..L: o~ por~ ! Cy ,,,,,,o ~ - co ~-~,",..;,, ~ Jul,31, 2001 ]O'18PM UNOCAL CORP, P, 3 UNOCAL ) II No,0844 Kin~ Platf~' ~ K-18RD Ci:ment Plug Rev 2 Revised 07/31/01 Ill Proposed Cement Sidetrack Plug Objective: Set a cement plug to sidetrack well due to geologic problems with the current TD at 12,440' MD. new directional pla~ is being revised with a kiekoffpoint of+/- 10250' MD and a maximum KOP of 10,400' MD. A Status: Bottom of open hole -- 12,440' MD. (Drilled through a fault and some of Hemlock pay was missed. Proposed sidetrack will avoid fault and drill through all of Hemlock.) cement plug Procedure: 1 RIH with cementing BHA: Cement stinger will consist 27 joints (,,,860') of 2-7/8" tubing from top of fish to above window. Orange-peel bottom of stinger with twenty.fi~re lA" dia holes cut near bottom to allow for good plug placement with minimal mud contamination caused by jetting down below stinger bottom. Put slight bend in bottom joint to assist in finding hole. 2-7/8" x 4-1/2" IF crossover (Full bore id crossover). drill pipe from above window to surface, Break circ as needed on trip in to keep pipe full and to keep any floating coal out of stinger. RIH to ~ 10,750' and establish eke rate similar to rate to clean out cement, Note eke pressure to compare with pressure later on while cite out cement. 3 Build 20 bbl viscous WBM pill weighted to 9.2 ppg per MI instructions (if possible while RIH) 4 Pump 10 bbls of base oil ahead Pump and balance 20 bbl viscous pill, 6 Pump 1 bbl of base oil behind 7 Balance plug and POOH slowly to 10,500', and circulate bottoms 'up. 8 Rig up Dowell and pressure test lines to 3000 psi, 9 Build at least 11 bbls '¥umpable" 11.0 ppg MudPUSH XLO Spacer K-18RD Cement Plug Rev 2 1 Revised 07/31/01 Ju!,31, 2001 10'18PM UNOCAL CORP, UNOCAL ) Ii iiii i iii 'l 10 Batch mix on the fly 55 bbls of 17,0 ppg cement b~end. No,0844. King Platfj .... ~. K-18RD C~ment Plug Re~, 2 Revised 07/31/01 · P. 4 Class G cement with: 0.130 gaFsk D168 Fluid Loss 0.350 gal/ak D145A Dispersant 0.080 gal/ak D 110 Retarder Yield -- 1.02 cfr/ak Mix water = FIW at 3.556 gal/ak Mix Fluid = 4.116 gal/ak set time -- at 170 deg BHCT (Note: verify set time from the lab report that will be e-mailed to the Drilling Foreman) The 55 bbls of cement will give a TOC of 9,717' if 8-1/2" hole is in gauge The 55 bbls of cement will give a TOC of 9800' if hole is washed out to average of 9" The above oalcs 'are baSed'ion cement in the 8-1/2" open hole with no pipe displac'ement. 860": of 2-7/8" displac .cment is only 1.93 bbl. 11 Pump 10 bbl 11.0 ppg MudPUSH XLO spacer followed by 5S bbl cement followed by 1 bbl MudPUSH XLO spacer. The two spacers should balance each other in height in the 2-7/8" tubing and the 2-7/8" x 8-1/2" (gauge hole, highest-worst case) annulus. 12 Displace cement and MudPUSI-I XLO spacers with Dowell Cement Pump using oil-based mud. PU slowly after cement exits stinger but do not overrun cement top. Underdisplace cement slightly (2-3 bbl) so that drill pipe is on a vacuum when finished pumping. 13 POOH slowly from 10,500' to safety 9217' (500' above "in gauge hole" TOC), Circulate BU at max rate while rotating and reciprocating drill pipe, Note any oement returns. ,, 14 Drop DP dart (make sure it will pump through rain id of the cement stinger which ,~hould be 2,441" ID) 1 $ POOH with cement BHA, 2-7/8" capacity = .00579 bbl/ft 5" dp capacity -- .01776 bbl/ft 2-7/8" x 8-1/2" = ,0622 bbl/ft (in gauge hole) 9" average hole -- ,07066 bbl/ft 8-1/2" gauge hole - ,0702 bbl/ft 9" av$ hole -- ..07861 bbl/ft ~:.~ ~R~ comen~ P~us R~v 2 2 Revised 07/31/01 ALASKA OIL AND GAS CONSI~RYA~ION COH~IlSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Williamson Drilling Manager Union Oil Company of California PO Box 196247 Anchorage AK 99519 Re: Trading Bay Unit K- 18RD Union Oil Company of Califomia Permit No: 201-117 Sur Loc: 691' FSL, 82' FEL, SEC. 17, T9N, R13W, SM Btmhole Loc. 5096' FSL, 2251' FEL, SEC. 19, TgN, 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. Annular disposal has not been requested as part of the Permit to Drill appliCation for Trading Bay Unit K- 18RD. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Trading Bay Unit K- 18RD must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Permit No: 201-117 Page 2 of 2 Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this I v~ day of June, 2001 jjc/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 corvl vllSSlON PERMIT TO DRILL la. Typeofwork Drill: Redrill: X I lb. Typeofwell Re-Entry: Deepen:I Service: 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247, Anchorage AK 99519 4. Location of well at surface Conductor No.3 Leg 1 King Salmon 691' FSL, 82' FEL Sec 17, T9N, R13W, S.M. At top of productive interval 46' FSL, 1157' FEL, Sec 18, T9N, R13W, S.M. At total depth 5096' FSL, 2251' FEL, Sec 19, T9N, R13W, S.M. 12. Distance to nearest property line 2310' W 300'S of NE corner Sect 19 13. Distance to nearest well '~" at 9800 'MD feet 16. To be completed for deviated wells Kickoff depth: 6000' feet Maximum hole angle: 52 deg 18. Casing program size Specifications 2O AAC 25.005 Coupling Butt. Butt. Butt. Exploratory: StratigraphicTest: Development Oil: X Developement Gas: Single Zone: Multiple Zone: 5. Datum Elevation (DF or KB) 100' KB above MSL feet 6. Property Designation ADL 18777 7. Unit or property Name Trading Bay Unit 8. Well number K-18 RD 9. Approximate spud date 7/1/2001 14. Number of acres in property 1902 10. Field and Pool McArthur River Field Hemlock/G Intervals 11. Type Bonc (see 20 AAC 25.025) AK Statewide Oil & Gas Bond Number U-629269 Amount $200,000 15. Proposed depth(MD and TVD) 12210' MD, 9030' TVD feet 17. Anticipated pressure(see 20 AAC 25.035 (e)(2)) Maximum surface 2799 psig At total depth (TVD) Top Setting Depth Bottom Hole Casing Weight Grade Length MD TVD MD TVD Existing 24" Driven surf surf surf 369' 369' Existing 13-3/8" 68 lb K-55 2477' surf surf 2477' 2294 Existing 9-5/8" 47 lb USS-95 9709' surf surf 6000' KOP 4883' 8-1/2" 7" 29 lb N-80 6360' 5850' 4768' 12210' 9030' 3702 psig Quantity of cement (include stage data) Driven 2608 sx 1321 sx 300 SX 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measu red 12130' feet true vertical 9650' feet PBTD (measured) 12105' Effective depth: measu red 11326' feet Fill (measured) 11326' true vertical 9081' feet Casing Length Size Cemented Measured depth Structural Conductor 369' 24" Driven 369' Surface 2477' 13-3/8" 1800 sx 2477' Intermediate Production 12116' 9-5/8" 1000 sx 12116' ECEIVED JUN J. 3 2.001 Alaska 0il & Gas Cons. Commission Anchorage True vertical depth 369' 2294' 9636' Perforation depth: measured See attached schematic true vertical See attached schematic 20. Attachments: Filing fee: X Property Plat: BOP Sketch: X Diverter Sketch: Drilling program: X Drilling fluid program: X Time vs. depth plot:. Refraction analysis: Seabed report: 20 AAC 25.050 requirements: Approved by OR[GI[~/~ SIGNED ,JL ~¢. Heusser Form 10-401 Rev. 12-1-85 21. I herby c~dj.~ that the foregoing is true and correct to the best of my knowledge: Sign ed: ~~/[/~'" ~ ~~~L Commission Use Only Permit Number I APl number I Approval date * .t / , I See cover letter I Oil¢/OIIf°r°therrequirements Conditions of approval Samples required: [ ] Yes '~'No Mud Icg required: I[ ] Y~s ~"No Hydrogen sulfide measures ~/Yes [ ] No l~irectional survey required/~Yes [ ] No Required working pressure forBOPE [ ]2M; 'r~3M; [ ]5M; [ ] 10M; [ ] 151vt Other: by order of Commissioner the Commission Date: ORIGINAL Submit in triplicate Attachment to Form 10-401 Permit to Drill King K-18 RD Hazard Analysis The proposed drilling of King K-18RD will entail sidetracking the well from 6000' and drilling an 8-1/2" hole to 12030' This interval encompasses the Tyonek D, E, F and top G sands. These sands are expected to be normally to subnormally to normally pressured. We plan on drilling this interval with an oil base mud system in the weight range from 9.0 to 9.3 ppg. If sloughing coals prove troublesome we have the ability to increase the mud weight to 10.0 ppg. A potential for lost circulation exist whilst drilling the 8-1/2" hole interval. Measures have been taken to ensure that adequate supplies of LCM is available onboard before drilling this hole section. The 8-1/2" hole section will encounter the G and Hemlock 1-7 intervals. There is potential for coal sloughing. The Hemlock is expected to have a pressure gradient of .42 psi/ft. We plan on using an oil based mud system for drilling this interval with mud weights in the range of 8.8 ppg to 9.4 ppg. If sloughing coals prove troublesome we have the ability to increase the mud weight to 10.0 ppg. The maximum expected downhole pressures that may be encountered is based on offset well information which indicate that at 9350' TVD a pressure of 3800 psi may be expected. This equates to.a gradient of .41 psi/ft. The maximum surface pressure which may be encountered assumes full evacuation of the wellbore to a depth of 9030' TVD and a methane gas gradient of. 1 psi/ft. Thus 2799 psi surface pressure is assumed as the worst case. The Hemlock zones which are offset to this well have been producing with an H2S content of up to 400 ppm. Prior to the drilling of K- 18RD a full cascade system and individual SCBA's will be rigged up and placed in strategic locations on the platform. In addition a H2S Safety Technician will be onboard to service the equipment, conduct drills and refresh crew members in the proper use of this equipment. Preliminary Procedure King K-18 RD Mill Window and Drill 8-1/2" hole 1 MU one trip whipstock assembly. 2 3 4 5 6 7 8 9 10 11 RIH with one trip whipstock assembly. Orient whipstock with MWD. Set packer/whipstock @ 6000'. Change over to OBM sytem. Mill window in 9-5/8" casing. Circulate bottoms up. Perform FIT to 11.0 ppg POOH with setting tool. LD mills and MU drilling BHA. RIH with BHA. Drill 8-1/2" hole to 12210' Log 8-1/2" hole section with LWD Run 7" Liner 12 Change top pipe rams 13 Test BOPE. ~\o.~~' 4~ "~t3~ 14 RU casing crews for 7" liner 15 RIH with 7" liner. 16 Continue to RIH with liner on drillpipe. 17 Set liner hanger and release running tool. 18 Cement liner 19 Set isolation packer and circulate string clean. 20 POOH with running tool. Clean out 7" liner and displace to 3 % KCI - filtered inlet water 21 RIH with 3-1/2" liner cleanout string 22 Displace liner to 3% KC1 - Filter inlet water. 23 POOH laying down excess pipe Run Completion 24 25 26 27 28 29 30 31. Pull wear bushing. RU to run 4-1/2"/3-1/2" GL completion PU, rabbit and run completion. Space out, install SCSSV and PU hanger Land hanger, diplace well. to inhibited water and set packer. Lay down landing joint RD tubing running equip. ND BOPE. 32 33 34 35 Install tree and test. Install Flowlines Prepare for rig move Perforate well after rig move. K-18 RD BOP Stack Leg # 1 Table 2,22' Btm of Trolly beam Graylock Hub Top of drilt deck Top of FMC Type 3 Unihead 4,75' 0 CHOKE c' 0 CASING AN]{) TI BING DETAIL SiZE wq GRADE (@NN ID MD TOP MD BTM. 24" Driven Surf, 369' 13-3/8" 68 K-SS Butt 12.515" Surt 2,477~ 9-5/8" 47 I SS-95 Butt 8.681" Surf 12,116~ Tubing: 4-1/2" 12.6 L-8O But 3.958 35 11373' JEWELRY DETAIL NO, l_)_t?g~ 11) Item l 6050' 9-5/8" Bridge Plug 2 Gas I,itl Mandrels 4-l/? G1,M at 6295~ 7302', 7922', 8496L 9030L t0223', 10879' 3 Straight Liicator / Seal assembly 11329' 4.55" Locaior Seam Assy, w/ 18' of seals, 4 /tt,642 5' @l~s ~ ~del WD packe~ w/2{~' sea~ b~>re ext~ Wireline set iHB-2 HB-2 HB-3 HB-4 H8-6 HB-7 Perf~ No, Top Bottom Zone lnterval SPF t 2 3 4 5 6 ? 8 9 10 11 11350 11491 11523 11571 11599 11690 11762 11867 11948 12065 11390 11501 11556 11587 11659 [1753 11845 11907 11978 12085 Bench t Bench 2 Bench 2 Bench 3 Bench 4 Bench 5 Bench 6 Bench 7 40 40 33 16 6(t 63 83 40 30 20 0 4 SQZD SQZD SQZD SQZD 4-20 8-20 16-20 6 6 TD = 12,130 ETD = 12,025 MAX HOLE ANGLE = 47,1 @ 10,800' K 18 Abal~donment.doc REVISED: 5/27/00 DRAWN BY: LDD Bay Unit # K-18 RD PROPOSED RKB to TBG Head = 34' Tree connection: CASING AND TUBING DEl'Ali SIZE WT GRADE CONN ID TOP BTM. 24" Driven Surf 369' I3 3/8" 68 K 55 Butt i2.415' Sud 2.477' 95/8" 47 [ SS~95 Butt 8.68 I" Surf 6000' T' t,in, t 29 k-80 BT(' KC 6.184 5850' 12,210' Tubing: 4 I/2" 12.6 I. 80 BT( 3.958 35 5700' 31/2" 9.2 I.-80 BTC 2.992 5700' JE~5 ELR5 DETAIL 34 12" x 4 1/2" OCT type "IJH TC IA- BuIl Tbg Ilngr L Baker TE-5 TRSSSV PERFORATION DAT4~ Zone Top Btm Amount Condition G-Zone Depths to be determined from Open Hole logs Iqemlock Depths to be determined from Open Hole logs -Proposed EG zone Peds Proposed _Hemlock =Pen's PBTD = 12170' TD = 12210~ MAX HOLE ANGLE = 52° @ 12000' 18RD Proposed.doc REVISE[): 5/3 1/01 0 "0 0 I I m Z~Z~ ^ ~ ITl '--I ITl V V V <<< SOUTH NORTH >>> 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ rb ..L o --.,. o o o 0 CZ> o o o UNOCAL V~RTICAL SECTION VIeW Client: Unocal Well: K-18RD (P7L) Field: McArthur River Unit Structure: King Salmon Section At: 269.86 deg Date: May 18, 2001 Schlumberger 2000 400O 6000 8000 10000 1200~ __ ~ / Tie-in Suwe 5900 MD 4882 TVD '~ ~ / 36'13° 257. 0° az 2758 departure \\ ~ / /Top of W ,~owSOOO MO ~2 ~0 End of Cu~e6289 MD 5q75 ] VD 48,~" 275.87" az 3009 depar ure ................ ~ Angle 48.54° / C~ 41100 10:75 MD 7881 / ,, ........... ';:~-H)ld Ang~~ -18 s~.~9" 2 ,. 2RD 'FVD ~a~ure 8135 TVD ,a~ure 51.59° 9030 T'VD 255.64" az )a~ure 0 2000 4000 6000 8000 Vertical Section Departure at 269.86 de§ from (0.0, 0.0). (1 in = 2000 foet) Drilling Fluids Program UNOCAL King Salmon Platform Well K-18RD Prepared by: Reviewed by: Presented to: Lee Dewees L D Davis M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax June 1, 2001 BRILLINI~ FLUlBS DRI ING FI. UIDS M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 Phone (907) 274-5564 Fax (907) 2709-6729 June 1, 2001 UNOCAL 909 West 9th Avenue Anchorage, Alaska 99501 ATTN: L D Davis LD; Enclosed is a recommended mud program for the K-18 RD Well to be drilled on the King Salmon Platform. Included is a project summary, interval summary, an economic summary, and the project team. The 8.5" interval will be drilled with OBM (oil based mud). This program is based on using the OBM from the K-13RD2 well. The K-18 RD wellbore should be displaced to OBM prior to milling the window. This well is similar to the K1RD2 well. The production interval will be completed with a 7" liner. The liner will be displaced to base oil (Mapco 200). Oil mud should be conditioned (centrifuged) prior to storage for future use. Please call if you have any questions regarding the mud program. Lee Dewees Project Engineer M-I Drilling Fluids 907 274-5533 ,Project Summary Well KI8RD Casing Hole Casing Depth 'FVD Mud Mud Sum Cumulative Size Size Program System Weight Days Mud Cost Existing Window ~ Versadrill 8.5-9.0 20 $155,000 9 5/8" 8.5" 5900' 4882' 12209' 9030' Comple- 12209 9030' Mapco Base Oil 7.4 5 $180,000 tion K'ey Iss u e NO. ,1 Sloughing Coal · Increase mud weight if required to stabilize coals and well- bore. Unstable well-bore conditions in K1RD2 improved when the mud weight was increase to 10.0PPG. Key Iss u e ,No. 2 Hole Cleaning · Maintain sufficient 3 RPM reading in 8 1/2" interval to in- sure adequate hole cleaning. Sweep hole as needed to avoid cuttings buildup. Pump weighted sweeps to aid in hole cleaning. ,Key .Iss u e .No. 3 Drill Solids · Run as fine a mesh shaker screen as possible. Run centri- fuge during trips and as required to reduce drill solids in mud. Key ls s u e .No. 4 ,Lost Circulation · Follow lost circulation program. Safe Carb and Lowate should be used for seepage losses. · Excessive LCM in cuttings could plug the injection well. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS Interval Summary (8.5" hole) Well K18RD 5900' - 12,209' Drilling Fluid System Key Products Solids Control Potential Problems Versa&ill Oil Mud Mapco 200 / Versawet / Versacoat / Versa HRP / VG-69 / Versa- mod / Lime / Calcium Chloride / MI Bar / Ventrol 401/Borax Shale Shakers / Desilter / Centrifuge Coal sloughing, hole cleaning, drill solids buildup .. ii . . .Interval Drilling:..Fl'uid"'..PropertieS · · · . · .. ,,, , Depth Mud Plastic Yield HTH P Interval Weight Viscosity Point Fluid Loss O/W Gels (ft) (PPg) (cP.) (Ib/100fF) (ml/30min) Ratio (Ib/100ft 5900'-10200' 8.5-9.4 20 - 25 18 - 22 4 - 5 cc's 85/15 15 - 30 10200 - 12209 9.2-10.0 23 - 28 18 - 22 4 - 5 cc's 90/10 20 - 30 · st : to Insure no spacer or oil based mud is discharged. · Set whipstock and mill window. · Drill ahead, maintain low shear rate values with VG-69, Versamod, Versa HRP, and Alc°mer 274. · Run centrifuge as needed to reduce solids buildup. · Pump weighted sweeps to aid in hole cleaning. · If sloughing coal or unstable well-bore conditions occur consider increasing mud weight. · Run 7" liner. Treat cement returns with Borax. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS Interval Summary (8.5" Hole) LOST CIRCULATION Lost Circulation Problems Key Products Recommended LCM Pill Formulas Drilling Fluid / OM Seal / SafeCarb Fine, Medium, Coarse / Versa- HRP Volume MIX II Fine SafeCarb SafeCarb Versa HRP of Mud Fine Medium (barrels) (ppb) (ppb) (ppb) (ppb) 30 10 10 10 1/4 Lost. Circulation Pill (Moderate LoSses) Volume OM B Seal/M IX II SafeCarb SafeCarb Versa H RP Fine of Mud Medium Coarse (barrels) (ppb) (ppb) (ppb) (ppb) 40 15 15 10 1/2 '"...'..........: · s.t' Circulat~.on...P:~ll.'.':...('.Severe., Losses)....'...... · ..'.. '.' ....:..... Volume"' I OM S~al I Sal;eC'~rb' I SafeCar'b I Versa HRP of EaU I I Medium I Coarse I Polymer (barrels) [ (ppb) [ (ppb) [ (ppb) [ (ppb) 50 / 15 / 20 30 1 ~ ¥~3 11¥~27 ~ .............. ~ .................. · 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 theft zone. (Do not exceed previous E.C.D. of circulation fluid). · Note: Excessive LCM in cuttings to plug injection well. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ORILLIltlC; FLUIBS Oil Base Mixing Instructions VERSADRILL FORMULATION MUD WEIGHT PRODUCT 7.8 PPG 9.0 PPG 12.0 PPG 14.0 PPG VERSACOAT 5.0 PPB 5.0 PPB 5.0 PPB 5.0 PPB VERSAWET 2.5 PPB 2.5 PPB 3.0 PPB 3.0 PPB LIME 2.0 PPB 2.0 PPB 2.0 PPB 2.0 PPB IMG 400 8.0 PPB 8.0 PPB 6.0 PPB 4.0 PPB VERSA HRP 2.0 PPB 2.0 PPB 1.0 PPB 1.0 PPB OIL/WATER 90/10 80/20 90/10 90/10 CACL2 25% 25% 25% 25% MIXING PROCEDURE 1. CLEAN PITS 2. FILL PITS WITH MAPCO 200 3. ADDIMG400 4. ADD VERSACOAT 5. ADD LIME 6. MIX FOR 1 HOUR 7. ADD CACL2 BRINE 8. .ADD VERSAWET 9. ADD BARITE 10. ADDVERSA HRP 11. MIX FOR MINIMUM 1 HOUR DISPLACEMENT PROCEDURE 1. HOLD PRE JOB SAFETY MEETING 2. HAVE ALL OBM ON LOCATION 3. PUMP SPACER 30 BARREL OF BRINE 4. PUMP SPACER 30 BARREL OF MAPCO 200 5. PUMP OBM 6. IF POSSIBLE PUMP IN TURBLULENT FLOW 7. ROTATE AND RECIPROCATE DRILL PIPE IF POSSIBLE 8. PLACE BIT ON BOTTOM AS OBM CLEARS THE BIT 9. USE LARGE MESH SCREENS ON THE SHAKER 10. INJECT SPACER AND ANY CONTAMINATED FLUID M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS Mixing Pit U 10" Suction 10" Overboard 140 Bbls 248 Bbls 16 bbls/ft 31 bbls/ft 1.4 bbls/inch 2.6 bbls/inch ~ Ia I ~ o bbls/ft 10" Equalizer ~__ 172 Bbls 248 Bbls 10" Equalizer 19 bbis/ft 31 bbls/ft 1.6 bbls/inch 2.6 bbls/inch 10" Equalizer ~lixing Pump Mixing Pump esandE ~ump M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS Project Team Well K18RD Monte Kanta Field Engineer Jim Brown Field Engineer Lee Dewees / '." Craig'Bieb~r: ...": './ Paul Hanson · MI Project Engineer and Tech Service Engineer will coordinate between the Unocal office, rig, ware- house, and the M-I field engineers. · Well progress will be monitored to look for any changes which will improve the efficiency of the opera- tion or avert trouble.. Project Team Title Work Cellular Craig Bieber District Manager 907 274-5051 907 229-1196 Paul Hanson Tech Service 907-274-5564 907-360-0388 Lee Dewees Project Engineer 907 274-5011 907 227-2412 Gus Wik Warehouse Manager 907 776-8680 907 252-4218 Jim Brown Field Engineer 907 274-5564 Monte Kanta Field Engineer 907 274-5564 M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Dl~lLLIlilfi FLUlBS Unocal Corporation 909 W. 9th Avenue Anchorage, AK 99501 907-263-7660 UNOCAL( Dan Williamson Drilling Manager 4 June 2001 Ms. Julie Heusser Chairman Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Dear Ms. Heusser: Enclosed, please find the application for the Permit to Drill (Form 10-401) for the King Platform Well K-18 RD. The intent of this well is to exploit the G zone formation in 'the TBU Northwest Feature. Additionally Hemlock potential exists in the proposed target location. UNOCAL plans to spud this well approximately 1 July 2001. K-18 RD will consist of approximately 6200' of 8-t/2" hole drilled with oil based mud. We plan on injecting the OBM liquid waste into King K-6 and K-19's 9-5/8" x 13-3/8" casing annulus. A permit has been approved for annulus waste injection. Please contact the undersigned with any questions regarding this application. Sincerely, Dan Williamson Drilling Manager enclosure ORI®tNAL FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED VENDOR NO., . .,.".,' ?DATE?.?! i.:i.. '".'. 'CHECK NO. .' i031548 ].2-,]'ON-O i 2004690 ':: ::'~" I':'DATE Il "INVOiCE/cREDIT. MEMO NO. mm : :m :'::'.!'?!'='~';'~,:VOUCHER.NO.. m m G~~ DISCOUNT m m m m m m m m N~ -- i 08-3UN-O'I DR'rT,T,I:'RRMTTK'I 8 060'1300033'1 '100 . O0 '100 . O0 :ORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. 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',".":::'!-::".: ' ' TR~NSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 CHECK WHAT APPLIES STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL ~/~ EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR D~POSAL ( V)NO ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS / ( ~YES + SPACING EXCEPTION "CLUE" The permit is for a new welibore segment of existing well , Permit No, ~ AP1 No. __. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY ~-~'~c~// WELL NAME ~ -/~"~]~ PROGRAM: exp FIELD&POOL ~c_Jc~/_~,//~e ?oc~ INITCLASS ~)e~z.x /-~..~/ GEOLAREA ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... · 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can. be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. . ~j/[ DATE 26. ~((q 27. 28. 29. GEOLOGY Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive hodzons ..... ' ..... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. 30. 31. 32. 33. 34. DANTE j ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate freShwater; or cause drilling waste... Y N to surface; ' (C) will not impair mechanical integrity of the well used for diSposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ,, GEOLOGY: N dev ~ redrll ~ serv wellbore seg 'ann. disposal para req ON/OFF SHORE If diverter required, does it meet regulations .......... ~ I:~ ~ --. -- Drilling .fluid program schematic & equip list adequate ..... (~ N BOPEs, do they meet regulation ................ ~ N BOPE press rating appropriate; test to psig. N Choke manifold complies w/APl RP-53 (May 84) ........ N ' ' Work will occur without operation shutdown ........... N .~., Is presence of H2S gas probable ................. N ~A,, ., ~5'~:,,~."~ ~ ~.. ~,,c~,5~- ~,t..~--~q.,,, ~-,.3\~,.e..ct~e_ ~,,F>-~:_~,,. ~)\c~.~..~, Permit can be issued wlo hydrogen sulfide measures ...... Y N Data presented on potential overpressure zones ....... Y Seismic analysis of shallow gas zones... .......... /Y/N Seabed condition survey (if off-shore) ............. Contact name/phOne for weekly progress reports [exploratory ?~rfly] Y N ENGINEERING:, ' UlC/Annular COMMISSION: JM~~;~_ " , '"'" l~,"~l~ Comments/Instructions: c:~nsoffice\wordia n~iana\checklist (rev. 11101//00) :Z Z ....I rn (