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170-007
THE STATE ®1 1� L GOVERNOR SEAN PARNELL September 16, 2014 Mr. Stan Golis Operations Manager — Cl Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Trading Bay Unit K-30 %ANNED PTD 1700070 Dear Mr. Golis: r A,"r, csk.a 0,1: iand Geri 333 West Seventh Avenue An horage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 On July 22, 2014 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay Unit K-30 located on the King Salmon Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail- safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to Trading Bay Unit K-30. The well flow was monitored for three hours and did not exceed the regulatory limits for a passing no -flow test. The subsurface safety valve must be returned to service if Trading Bay Unit K-30 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, James B. Regg C Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 2) Other Q Install ESP Performed: Alter Casing ❑ Pull Tubing❑✓ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well E] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development R] Exploratory ❑ Stratigraphic❑ Service ❑ 170-007 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20211-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 Trading Bay Unit / K-30 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Middle Kenai G Oil, West Foreland Oil, Hemlock Oil Pools 11. Present Well Condition Summary: Total Depth measured 12,600 feet Plugs measured N/A feRECRIV � true vertical 10,191 feet Junk measured 10,940 &11,476 feet AUG12 �OjQ Effective Depth measured 12,543 feet Packer measured 11,750 feet 00 true vertical 10,139 feet true vertical 9,423 feet At: Casing Length Size MD TVD Burst Collapse Structural Conductor 396 24" 396' 396' Surface 2,187' 13-3/8" 2,187' 2,024' 3,090 psi 1,540 psi Intermediate Production 12,074' 9-5/8" 12,074' 9,713' 6,870 psi 4,750 psi Liner 1,359' 7" 12,575' 10,168' 7,240 psi 5,410 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 10,696' (MD) 8,563' (TVD) Packers and SSSV (type, measured and true vertical depth) Packer 11,750' (MD) 9,423' (TVD) SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: w 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: 148 63 1136 22 50 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ DevelopmentE] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 7 Gas ❑ WDSPL❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 1314-328 Contact Ted Kramer Email tkramer(Whilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer �j Signature "G Phone 907-777-8420 Date 8/11/2014 Form 10-404 Revised 10/2012 Aj S-,y.,q Submit Original Only RSEWS AUG, 13 2 Hileorp Alaska, LLC RKB: 100' AMSL KB -THF: 33.76' KB 7396't� 24" 7 13-3/8" @ 2161' TOC: 9600' 1 2 3 4 5 {� k 1/ GO -6 y'. t0 G-1, 2,3 ;a TOL: 11216' G-3, 4 leolaton Squeeze 6 G-5 11985-11986 i -6 9-5/8'@1132,' �a HB -1 P* HB -3 Casing and Tubing Detail HB -4 PKR:11,750' Type iaoiaeon Squeeze HB -5,6,7 11985-11986'x%.'_ men / CONN / ID Cement 24" WF -3,4,5 94/1-140 WF -617 396' Welded/ 19" Driven TD =12600' PBTD = 12543' Directional Data: 36.4 2187 max = 42.5° at 6237' 9-5/8" SCHEMATIC King Salmon Platform Well K-30 Last Completed 07/12/2014 Fish: 07/08/14- 10,940' - Perf Gun 22.50, Gamma Ray 6.42, Rope Socket 1.00- Total Length 29.92' 05/01/14 -11,476' - Bottom Hole Assembly Updated by: JILL 08/11/14 Casing and Tubing Detail No. Size Type Grade TOP BTM men / CONN / ID Cement 24" Conductor 94/1-140 36.4 396' Welded/ 19" Driven 13-3/8" Surface 61/ K55 36.4 2187 BTC/ 12.515- 9-5/8" Intermediate 47/N80 36.4 10092' BTC/ 8.681" 9-5/8" Intermediate 47/ P110 10092 12074' BTC/ 8.681" 7" Liner 29/1-80 11216 12575 BTC -KC/ 6.184" Open G-2 10,955' Tubing 8,762' 8,792' 3-1/2" Prod. Tbg 9.2 / L-80 Surf 10,696' 1 Supermax Fish: 07/08/14- 10,940' - Perf Gun 22.50, Gamma Ray 6.42, Rope Socket 1.00- Total Length 29.92' 05/01/14 -11,476' - Bottom Hole Assembly Updated by: JILL 08/11/14 Jewelry Detail No. Depth ID OD Item Zone 35.22' 2.867" Hanger 1 10,696' - 5.13 Discharge, Bolt -On 2 10,702' 4.0 Pump (x2) 400 Series, 144 Stage, SF1000 3 10,748' 4.0 Seals 4 10,765' 4.56 Motor 4.56" Series Motor, FMP, 180 HP 5 1 10,800' 4.56 Centralizer/Anode 6 1 11,750' 1 3.9 1 6.184 E -Line Set Packer Fish: 07/08/14- 10,940' - Perf Gun 22.50, Gamma Ray 6.42, Rope Socket 1.00- Total Length 29.92' 05/01/14 -11,476' - Bottom Hole Assembly Updated by: JILL 08/11/14 Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Status G-06 10,802' 10,830' 8,644' 8,665' 28' Sqzd G-1 10,870' 10,895' 8,696' 8,715' 25' Open G-2 10,920' 10,945' 8,734' 8,754' 25' Open G-2 10,954' 10,994' 8,761' 8,792' 40' Open G-2 10,955' 10,994' 8,762' 8,792' 39' Open G-3 11,018' 11,050' 8,811' 1 8,836' 32' Open G-3 11,022' 11,040' 8,814' 8,828' 18' Open G-4 11,064' 11,129' 8,847' 8,897' 65' Open G-4 11,073' 11,114' 8,854' 8,886' 41' Open G-5 11,194' 11,224' 8,949' 8,973' 30' Open G-5 11,200' 11,222' 8,953' 8,971' 22' Open G-5 11,232' 11,264' 8,979' 9,004' 32' Open G-5 1 11,232' 11,268' 1 8,979' 9,008' 36' Open G-6 11,323' 11,357' 9,052' 9,080' 34' Open H-1 11,412' 11,472' 9,125' 9,177' 60'1 Open H-2 11,495' 11,590' 9,197' 9,280' 95' Open H-3 11,605' 11,650' 9,293' 9,333' 45' Open H-4 11,651' 11,720' 9,334' 9,396' 69' Open H-5 11,780' 11,790' 9,450' 9,459' 10' Open H-5 11,798' 11,820' 9,466' 9,485' 22' Open H-6 11,876' 11,964' 9,536' 9,614' 88' Open H-7 11,964' 11,988' 9,614' 9,636' 24' Open WF -1 12,008' 12,014' 9,654' 9,659' 6' Open WF -1 12,021' 12,026' 9,666' 9,670' 5' Open WF -2 12,030' 12,050' 9,674' 9,692' 20' Open WF -2 12,055' 12,068' 9,696' 9,708' 13' Open WF -2 12,081' 12,105' 9,720' 9,741' 24' Open WF -4 12,155' 12,184' 8,787' 9,813' 29' Open WF -4 12,208' 12,212' 9,834' 9,838' 4' Open WF -4 12,229' 12,241' 9,853' 9,864' 12' Open WF -4 12,258' 12,265' 9,880' 1 9,886' 7' Open WF -4 12,268' 12,272' 9,889' 1 9,893' 4' Open WF -6 12,360' 12,408' 9,973' 10,016' 48' Open WF -7 12,468' 12,480' 10,071' 10,082' 12' Open WF -7 12,500' 12,551' 10,100' 10,147' S1' Open Fish: 07/08/14- 10,940' - Perf Gun 22.50, Gamma Ray 6.42, Rope Socket 1.00- Total Length 29.92' 05/01/14 -11,476' - Bottom Hole Assembly Updated by: JILL 08/11/14 Hilcorp Alaska LLC Well Operations Summary Well Name M, Well Permit Number Start Date End Date K-30 50-733-20211-00 1 170-007 1 7/2/14 7/12/14 Daily Operations: 07/02/14 - Wednesday FINISH R/U AND CLEANING OUT SAND TRAPS. R/U AND PRE-TEST BOPE. TESTED BOPE 250 PSI LOW 2500 PSI HIGH ON ANNULAR, 250 PSI LOW AND 3000 PSI HIGH ON RAMS AND RELATED VALVES (ALL TEST GOOD). LOU GRIMALDI WITH AOGCC WITNESSED TEST. AFTER TESTING BOPE, MR. GRIMALDI CHECKED GAS MONITORING SYSTEM DRAW DOWN, LOW AND HIGH ALARM. THE STATIONS WERE NOT FUNCTIONING PROPERLY. RIG WAS SHUTDOWN UNTIL PROPER GAS MONITORING SYSTEM COULD BE INSTALLED. R/U POWER TONGS, PERFORM HOUSE KEEPING WHILE WAITING. 07/03/14 - Thursday CONTINUE CLEANING PLATFORM. NEW GAS SENSORS WERE INSTALLED, TESTED OK. CALLED LOU GRIMALDI W/ AOGCC AND WAS GIVEN OK TO GO BACK TO WORK. PJSM. PULL HANGER TO FLOOR L/D SAME. POOH WITH 3 1/2" BTC KILL STRING. LAYING DOWN SAME. INSTALLED WEAR BUSHING. MOVED FISHING TOOLS ONTO PIPE RACK. STRAPPED AND CALIPERED BHA. M/U, TIH WITH 5 3/4" OVS LDD W/ 3 1/2" BASKET GRAPPLE & MCP, 2- UPPER EXTs, PUMPOUT SUB, B & 0 JARS, DCs X 6, X0, TOTAL LENGTH 218.35. P/U 3.5 PH6 WORKSTRING TIH DEPTH AT 600 AM 8,090'. 07/04/14 - Friday TIH P/U 3.1/2" 12.95# PHIS TBG,TAG @11,465' PM. LATCHED ON FISH. R/U AND CIRC DOWN STRING. BLOW BALL SEAT W/ 2800 PSI, REVERSE OUT TBG VOLUME, HOLE TAKING VERY LITTLE FLUID. JAR ON FISH, NO MOVEMENT, JARRING 170K UP, 50K DOWN. R/U LANE VIBRATION SPECIALTY TOOL, BEGAN VIBRATING ON BHA LEFT IN HOLE AT 10K OVER STRING WT (145K). INCREASED OVER PULL WT TO 170K, IN 5K INCREMENTS, OVER A 2 HR PERIOD (STOPPED AFTER IST AND 2ND HR TO CHECK DERRICK LINES, FASTENERS & PINS). AFTER 2ND HR WE BEGAN WORKING PIPE FROM 145K TO 170K WHILE VIBRATING. NO HOLE MADE DURING THIS PERIOD. RIGGED DOWN VIBRATING EQUIPMENT. JARRED ON FISH, WORKING PIPE FROM 70K TO 190K LETTING JARS HIT THEN PICKING UP TO 200K. NO HOLE MADE. RIGGED UP POWER SWIVEL TO SHUCK OVERSHOT. WORKING TORQUE DOWN, ATTEMPTING TO SHUCK OVERSHOT FROM FISH. 07/05/14 - Saturday CONTINUE TRYING TO SHUCK OVERSHOT FROM FISH @11,465'. RIG DOWN POWER SWIVEL. MONITOR WELL. HELD PJSM. RIG UP E-LINE. RE-HEAD LINE, R/U SHEAVES ARM TOOL, TEST LUB TO 1500 PSI. RIH WITH WEIGHT BARS, CCL, OWEN DCST LOADED W/40 GRAIN SHOT. TOTAL LENGTH 15.96 TO 11,463' ELM. SET DOWN PULL UP AND SET DCST ACROSS PUMP OUT SUB AND BUMPER JAR. FIRE SHOT. POOH W/ E-LINE. LAID DOWN LUBRICATOR. WORKED PIPE FROM 50K TO 190K- DECIDED TO M/U POWER SWIVEL. JARRED AND TORQUED PIPE SIMULTANEOUSLY UNTIL PIPE CAME FREE (WEIGHS 135K- FISHING STRING WEIGHT). RIGGED DOWN POWER SWIVEL AND ELINE EQUIPMENT. BEGAN POOH, AT JOINT# 15 OOH (- 460') THERE WAS SEVERE WEAR ON 4 CONSECUTIVE JTS. HOLES IN TUBE & CONNECTION WEAR- JTS # 15 & 16 SLIGHTLY BENT AND CONNECTION WEAR. CONTINUED POOH. LAY DOWN BHA. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 1 170-007 1 7/2/14 7/12/14 Daily Operations: 07/06/14 - Sunday TRIP IN HOLE WITH 9 5/8" RTTS INSPECTING ALL PIPE. BREAK CIRC, SET PKR @11,750' TM. CLOSE PIPE RAMS,TEST 9 5/8" 29# L80 CSG TO 1500 PSI FOR 30 MIN ON CHART (TEST GOOD). RELEASE PACKER, CIRC HOLE CLEAN. POOH W/ RTTS TOOL. RUN IN / LAY DOWN 4 3/4" DCs. R/U ELINE W/ LUB TEST TO 1500 PSI. TIH W/ 1.70" GR/CCL+ CENTRALIZER ON BTM. COULD NOT GET DEEPER THAN 11,358' (CORRELATED TO DIGITAL PERF CORR LOG). POOH AND TOOK CENTRALIZER OFF. RAN BACK IN HOLE AND PULLED TIE IN STRIP. TD REACHED IS 11,447'. POOH AND R/D ELINE. 07/07/14 - Monday P/U 4 1/2" PERFORATING GUNS 6 SPF TOTAL BHA LENGTH 667.95',_ RA TAG TO TOP SHOT 107.72'. TRIP IN HOLE WITH PERFORATING GUNS ON 3.5 PH6 WORKSTRING TO 11,457' (TM). RIG UP E-LINE, TEST LUB TO 2000 PSI. TIH W/1.70" GR/CCL TOOL, CORRELATE GUNS ON DEPTH. POOH WITH E-LINE R/D SAME. RIG DOWN E-LINE LUBRICATOR AND M/U CIRC ASSEMBLY. PICK UP 22' POSITIONED TCP GUNS ON DEPTH. CLOSED PIPE RAMS (LINED UP THRU CHOKE). HELD PJSM. DROPPED BAR AND PERFORATED 10,870'- 10,895', 10,920'- 10,945', 10,955'- 10,994', 11,022'- 11,040', 11,073'- 11,114', 11,200'- 11,222', 11,232'- 11,264', 11,323'- 11,357', 11,412'7 11,428' W/ 4 12" EHC LDD 6 SPF 60* PHASE. WELL WENT ON VAC. AFTER WELL STABILIZED, REVERSED 2- TB VOLUMES AROUND MINIMAL GAS AND OIL AT BTMS UP. L/D CIRC ASSEMBLY AND PULLED ABOVE PERFS TO 10,384'(17 STANDS). WATCHED WELL FOR 1 HR. HOLE TAKING 5 BBLS PER/HR. POOH L/D 3.5 PH6 WORKSTRING. REPORT TIME 165 JTS L/D. 07/08/14-Tuesday POOH L/D 3.5 PH6 TBG WORKSTRING. L/D PERF GUNS "NOTE" ALL GUNS DID NOT FIRE. BOTTOM F/ 11,428'-11,412- TOTAL 16'. RIH W/23 STDS 3 1/2" TBG OUT OF DERRICK. POOH L/D SAME. PULL WEAR BUSHING, SET TEST PLUG TEST BOPE. TEST ANNULAR 250 PSI LOW 2500 PSI HIGH, VBR RAMS AND BLINDS AND RELATED VALVES 250 PSI LOW 3000 PSI HIGH. ALL TESTS HELD 5 MIN EACH ON CHART (ALL TEST GOOD). WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. R/D TESTING EQUIPMENT. R/U E-LINE WITH LUBRICATOR TO COVER PERF ASSM (FLANGED UP ADAPTER TO BOWEN LUBRICATOR). M/U GR/CCL+ 20' 2 1/2" EHC LDD 6 SPF AND GO ON RADIO SILENCE. CAP GUN AND PULL INSIDE LUB- PRESSURE TEST TO 2000#s. RIH AND PULLED CORR STRIP ABOVE PERFS. CONTINUED IN HOLE AND TAGGED AT 11,375'- COULD NOT GET DEEPER AFTER SEVERAL ATTEMPTS. STARTED OOH AND HUNG UP AT 10,940'. COULD NOT WORK TOOLS FREE. WORKED E-LINE, NEUTRAL WEIGHT TO 100#s OVERPULL, INCREASING PULL IN 100# INCREMENTS UNTIL WL PULLED OUT OF ROPE SOCKET AT 2800#s. POOH AND R/D E-LINE. LEFT IN HOLE 2.5' PERF GUN 22.50, GAMMA RAY 6.42,_ROPE SOCKET 1.00 TOTAL LENGTH 29.92'. BEGAN R/U ESP EQUIPMENT. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 1 170-007 1 7/2/14 7/12/14 Daily Operations: 07/09/14 - Wednesday RIG UP SUMMIT CABLE SHEAVES IN DRK. P/U SHROUD, SLACK OFF FIRST MOTOR INSIDE, UNABLE TO GET DOWN PAST 3'. L/D SHROUD. HAD ANOTHER SENT TO DOCK. BOAT ARRIVED @1800 HRS TO PLATFORM. PLACE NEW SHROUD ON DECK. 3 PIECES WELD TOGETHER MAKING 60' PIECE. P/U SAME LOWER IN HOLE. LOWERED CENT/ ANODE/ MOTOR SECTION INTO SHROUD TO — 20'- WOULD NOT GO FURTHER- PULLED MOTOR SECTION OUT AND REPLUMBED CHEMICAL LINES. STRIPPED PLASTIC SHEATHING FROM LINES. LOWER MOTOR SECTION INTO SHROUD AGAIN (MINUS PLASTIC SHEATHING) TO MOTOR HEAD. R/U TARP PRIOR TO ATTCHING MOTO LEAD CABLE. ATTACHED CABLE TO MOTOR, CONTINUED WITH BUILD OF ESP. CLAMP AT TOP OF SHROUD HAD TO BE MODIFIED TO FIT IN PLACE. TROUBLE SETTING ALIGNMENT SCREWS FROM SHROUD TO GAS SEPERATOR/ INTAKE ASSM. PICKED UP 1st PUMP AND M/U TO MOTOR ASSM. 07/10/14 - Thursday FINISH P/U ESP PUMP. TEST OK. P/U 3.5, 9.2# L-80 SUPERMAX TBG, TORQUE TO 2350 FT/LBS TESTING CABLE AND FLAT PACK EVERY 1000', DRIFTING EACH JT. MAKE SPLICE ON CABLE @ 4,016'. TEST SPLICE, OK. CONTINUE P/U 3.5 9.2# L-80 SUPERMAX TBG. DEPTH AT REPORT TIME @ 210 JTS, 7,075'. 07/11/14 - Friday CONTINUE P/U 3.5 9.2# L-80 SUPERMAX TBG. F/ 7,015' TO 8,025'. MAKE SPLICE ON CABLE @ 8,025',TEST SPLICE OK. CONTINUE P/U 3.5 9.2# L-80 SUPERMAX TBG, TOTAL OF 321 JTS IN HOLE. INSTALL CAMERON TBG. HANGER. SPLICE CONTROL LINES & FLAT PACK, TEST SAME. LAND HANGER @ 10,800' DPM & SET BACK PRESSURE VALVE. R/D FLOOR & POLUTION PAN & CAT WALK. N/D BOPE RISER & COMPONETS. ASSIST CAMERON PREP. WELL HEAD FOR TREE INSTALLATION. 07/12/14 - Saturday CONTINUE INSTALLING TREE. TEST VOID TO 5000 PSI FOR 15 MIN TEST GOOD. SHELL TEST TREE TO 250 PSI LOW 5000 PSI HIGH ON CHART. TEST GOOD. CLEANING AROUNG RIG LOADING BASKETS W/ EQUIPMENT TO BE SHIPPED IN. PLACING ALL PROTECTORS ON WORK STRING. PUMP 150 BBLS TO TRADING BAY. CLEAN MUD PIT OUT. BACKLOADING WORKBOAT WITH SUMMIT EQUIPMENT. RIG DOWN. MEMORANDUM TO: Jim Regg P.I. Supervisor ( % FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 22, 2014 SUBJECT: No -Flow Test Hilcorp / King Salmon PLT K-30 PTD 1700070 Trading Bay Unit July 22, 2014: 1 traveled to Hilcorp's King Salmon Platform in Cook Inlet to witness a No -Flow Test on well K-30. On my arrival on the platform I met with Hilcorp Lead Operator Dave Meyers and we discussed the operational details of the test. Mr. Meyers indicated that the well pressure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Well K-30 was lined up from the tree top swab valve through a recently calibrated Erdco flow meter (0 to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours and unassisted gas and liquid flow from , the well did not exceed 900 SCFH or 6.3 gallons, passing the test. Summary: The unassisted gas and liquid flow from well K-30 during this test did not exceed 900 SCFH or 6.3 gals. hourly flow rate and well K-30 meets the AOGCC requirements for a No -Flow status determination. Attachments: none , SCANNED NOV 20 2014 RJF 09/19/02 Page 1 of 1 2014-0722_No-Flow_TBU_K-30_jj.xlsx , O,t Tw, ,:4' �\�I/ ,v� T H E STATE 1� �. .wT --'`G.6ii�� "A i F A. �. 7' / J r E �^�-V--,---_,.--4-.4-,..,.\° i i i:4-z._, ,t _=__-:---_ -_,-1 6 �' 1 _ \ f �4tete _ ---- ---- -- 333 Vres1 Seventh Avenue li1,.....---.: :- - ( O\ RNR SEAN PARYEI.( AnchorageAlaska 99501 3572 n \' - '/')In' 90979 t/z" Ted Kramer SCANNED JUL 1 6 2014 Sr. Operations Engineer __. c:),, Hilcorp Alaska, LLC J 7 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil, West Foreland Oil, and Hemlock Oil Pools, Trading Bay Unit K-30 Sundry Number: 314-328 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, 7a.74644,4, _ Cathy P. oerster Chair DATED this�day of May, 2014. Encl. ' f V\ ' , w r` 4`*5� L—fir, *" STATE OF ALASKA �� / I'�1/- 21.-_,14 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations 0 4 Perforate 9 Pull Tubing❑ Time Extension El Operations Shutdown 0 Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Run ESP 9 2.Operator Name: 4.Current Well Gass: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 9 170-007• 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service a 6.API Number. Anchorage,AK 99503 50-733-20211-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A' Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit/K-30 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 . McArthur River Field/Middle Kenai G Oil,West Foreland Oil,Hemlock 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): 12,600 • 10,191 • 12,543 • 10,139, N/A 11,476 Casing Length Size MD ND Burst Collapse Structural Conductor 360' 24" 396' 396' Surface 2,151' 13-3/8" 2,187' 2,024' 3,090 psi 1,540 psi Intermediate Production 12,037' 9-5/8" 12,074' 9,713' 6,870 psi 4,750 psi Liner 1,359' 7" 12,575' 10,168' 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic 1 See Schematic 3-1/2" 9.2#/L-80 2,035 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): . 7"E-line Packer/SSSV N/A Packer 11,750'(MD)9,423'(ND)/SSSV-N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch 9 Exploratory ❑ Stratigraphic❑ Development 0 - Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/1/2014 Oil 9. Gas ❑ WDSPL ❑ Suspended 0 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 Signature -• /-/� ' v Phone 907 777-8420 Date 5/20/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �/ —6V-1-32 3 Plug Integrity CI BOP Test L� Mechanical Integrity Test ❑ Location Clearance 0 Other: -i`1 2 S D O 17.5 G30 6 ie5- (--- Spacing Exception Required? Yes 0 No /Subsequent Form Required: 6 - y 0L APPROVED BY Approved by: (0.1PCOMMISSIONER THE COMMISSION Date: 5-. 23 , /c„,/ /- C'ZZ-11 � b d/r' Submit Form and Form 10-403(Revised 10/2012) ApprovO� iLv� R \ At nths from the date of approval. �ents;apu 23 21,1 Well Work Prognosis Well: K-30 Hilcorp Alaska,LLC Application Date: 5/20/2014 Well Name: K-30 API Number: 50-733-20211-00 Current Status: Oil Producer(SI) Leg: Leg#1 (NE corner),Slot#2 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: 170-007 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-30 well is a Shut-in producer. The ESP failed in this well on November 13, 2013. A recent work over ending on 5/4/2014 was unsuccessful in that a bottomhole assembly was lost in the well due to fill dumping in on top of the assembly during a rig break down. Neither the proper tools to recover the fish nor a smaller ESP Pump were available in the State of Alaska to complete the workover so well work was temporarily stopped until a new work plan could be developed and the proper equipment brought in. The workover plan involves removing the kill string from the well and making an attempt to recover the lost BHA with an agitator tool. If successful, the well will be re-perforated and an ESP ran/If unsuccessful in removing the fish, the well will be re-perforated in the intervals above the BHA,and a smaller ESP ran! Current Bottom Hole Pressure: 3,514 psi at the Phoenix Gauge(8,000'TVD) Maximum Expected BHP: 3,820 psi @ 8,645'TVD(top perf)with water gradient of 0.442 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. Pump through kill string to circulate any hydrocarbon off the well to production 3. 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). 4. POOH with kill string. 5. PU Workstring. RIH with 7"clean out assembly to TOF at 11,476'. POOH with same. 6. PU over shot. RIH with same and latch on to fish at 11,476'. RU Agitator tool and vibrate BHA while pulling tension to free fish. POOH with BHA is successful. If unsuccessful, unlatch from BHA and POOH. 7. PU 9-5/8" RTTS packer, RIH to 10,750'. Set and pressure test casing to 1,500 psi. on chart for 30 min, Circ. hole clean, POOH W/same. 8. RU Perforating Company. PU RIH with TCP perforating Guns as per latest Approved Perforation Request Form. 9. RU E-line and Run in tubing with GR,CCL and correlate TCP guns on depth. Fire Guns. 10. Pick up guns above perforations. Shut down(+/-) 1 hour monitoring fluid level with Echometer. 11. Once the well is stable, POOH with TCP guns. 12. MU and RIH with ESP Assembly. 13. Hang off tubing. ND BOP, NU wellhead and test. 14. Turn Well over to production 15. RDMO Moncla 404 Pulling unit. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram(No Change) 4. BOP Drawing King Salmon Platform s . II SCHEMATIC Well K-30 Last Completed 5-27-2011 Hilcorn Alaska,LLC Ctk_Y'/'-e n Casing and Tubing Detail WV Size Type ement Grade TOP BTM CONN/ID C Other/ RKB:100'AMSL --- - KB-THF:33.75'KB 24" Conductor 94/H40 36.4 396' Welded/19" Driven 1 13-3/8" Surface 61/K55 36.4 2187 BTC/12.515" I - 9-5/8" Intermediate 47/N80 36.4 10092' BTC/8.681" 9-5/8" Intermediate 47/P110 10092 12074' BTC/8.681" 24"@396' - 4' 7" Liner 29/L80 11216 12575 BTC-KC/ 6.184" Tubing " 3-1/2" 1 IBT I 9.2#/L80 I Surf I 2,035' I Kill String Jewelry Details Z. # Depth Length ID (Drift) OD Item 13-3/8"@ 2151' 35.22' 1 2.867" Hanger 38.75' X-Over 11,750' 3.9 6.184" E-Line set Packer Fish: Bottom Hole Assembly at 11,476' Perforation Detail TOG:9600' Top Btm Top Btm Zone (MD) (MD) (TVD) (ND) Amt Status G-06 10,802' 10,830' 8,644' 8,665' 28' Sqzd G-01 10,870' 10,894' 8,696' 8,714' 24' Open G-02 10,920' 10,945' 8,734' 8,754' 25' Open G-02 10,954' 10,994' 8,761' 8,792' 40' Open 8-03 11,018' 11,050' 8,811' 8,836' 32' Open 8-04 11,064' 11,129' 8,847' 8,897' 65' Open 8-05 11,194' 11,224' 8,949' 8,973' 30' Open G-05 11,232' _ 11,268' 8,979' 9,008' 36' Open H-1 11,412' 11,472' 9,125' 9,177' 60' Open H-2 11,495' 11,590' 9,197' 9,280' 95' Open H-3 11,605' 11,650' 9,293' 9,333' 45' Open _ H-4 11,651' 11,720' 9,334' 9,396' 69' Open H-5 11,780' 11,790' 9,450' 9,459' 10' Open GO-6 H-5 11,798' 11,820' 9,466' 9,485' 22' Open H-6 11,876' 11,964' 9,536' 9,614' 88' Open 8-1,2,3 H-7 11,964' 11,988' 9,614' 9,636' 24' Open '' TOL:11216' G-3,4 WF-1 12,008' 12,014' 9,654' 9,659' 6' Open iaoiau°"sy°eeze :� G-5 WF-1 12,021' 12,026' 9,666' 9,670' 5' Open 11985-11986 yq 9-5/8"@ 11327' WF-2 12,030' 12,050' 9,674' 9,692' 20' Open a'-- ' HB-11G7 WF-2 12,055' 12,068' 9,696' 9,708' 13' Open HB-2 WF-2 12,081' 12,105' 9,720' 9,741' 24' Open } t{ N WF-4 12,155' 12,184' 8,787' 9,813' 29' Open . HB-3 WF-4 12,208' 12,212' 9,834' 9,838' 4' Open I t / HB-4 WF-4 12,229' 12,241' 9,853' 9,864' 12' Open 40 PKR:11,750' -a'- WF-4 12,258' 12,265' 9,880' 9,886' 7' Open IsoIasonsqueeze t. HB-5,6,7 WF-4 12,268' 12,272' 9,889' 9,893' 4' Open 11985-11986 :!' �s 1WF-6 12,360' 12,408' 9,973' 10,016'_ _48' Open WF-3,4,5 WF-7 12,468' 12,480' 10,071' 10,082' 12' Open -6'7 WF-7 12,500' 12,551' 10,100' 10,147' 51' Open TD=12600' PBTD=12543' Directional Data: max=42.5°at 6237' Updated by:JLL 05/20/14 King Salmon Platform II PROPOSED Well K-30 Last Completed 5-27-2011 Hilcorp Alaska,LLC Casing and Tubing Detail RKB:100'AMSL Size Type Grade TOP BTM CONN/ID C ement Other/ KB-THF:33.75'KB 24" Conductor 94/H40 36.4 396' Welded/19" Driven ® 13-3/8" Surface 61/K55 36.4 2187 BTC/12.515" It 1 9-5/8" Intermediate 47/N80 36.4 10092' BTC/8.681" frfe. 9-5/8" Intermediate 47/P110 10092 12074' BTC/8.681" 24"@ 396' 7" Liner 29/L80 11216 12575 BTC-KC/ pp 6.184" + + Tubing ix i 3-1/2" I Prod.Tbg I 9.2/L-80 I Surf I ±10,752' I Supermax I it t it A Jewelry Detail 13-3/8"@ 2151' No. Depth ID OD Item 35.22' 2.867" Hanger 1 ±10,752' Bottom of ESP Perforation Detail Top Top Zone (MD) Btm(MD) (TVD) Btm(TVD) Amt Status G-06 10,802' 10,830' 8,644' 8,665' 28' Sqzd G-1 10,870' 10,894' 8,696' 8,714' 24' Open 0-1 ±10,870' ±10,895' ±8,696' ±8,715' ±25' Future G-2 ±10,920' ±10,945' ±8,734' ±8,754' ±25' Future/Open v G-2 10,954' 10,994' 8,761' 8,792' 40' Open G-2 ±10,955' ±10,994' ±8,762' ±8,792' ±39' Future TOC:9600' G-3 11,018' 11,050' 8,811' 8,836' 32' Open G-3 ±11,022' ±11,040' ±8,814' ±8,828' ±18' Future G-4 11,064' 11,129' 8,847' 8,897' 65' Open l.' G-4 ±11,073' ±11,114' ±8,854' ±8,886' ±41' Future 0-5 11,194' 11,224' 8,949' 8,973' 30' Open G-5 ±11,200' ±11,222' ±8,953' ±8,971' ±22' Future tt G-5 ±11,232' ±11,264' ±8,979' ±9,004' ±32' Future 0-5 11,232' 11,268' 8,979' 9,008' 36' Open ` 111G-6 ±11,323' ±11,357' ±9,052' ±9,080' ±34' Future .a H-1 ±11,412' ±11,450' ±9,125' ±9,157' ±38' Future i' H-1 11,412' 11,472' 9,125' 9,177' 60' Open S. a H-2 ±11,471' ±11,543' ±9,176' ±9,238' ±72' Future H-2 11,495' 11,590' 9,197' 9,280' 95' Open S- -::1 - 1 H-3 ±11,554' ±11,625' ±9,248' ±9,311' ±71' Future H-3 11,605' 11,650' 9,293' 9,333' 45' Open ,t H-4 ±11,625' ±11,726' ±9,311' ±9,401' ±101' Future H-4 11,651' 11,720' 9,334' 9,396' 69' Open T., H-5 11,780' 11,790' 9,450' 9,459' 10' Open GO-6 H-5 11,798' 11,820' 9,466' 9,485' 22' Open , H-6 11,876' 11,964' 9,536' 9,614' 88' Open ': 0-1,2,3 H-7 11,964' 11,988' 9,614' 9,636' 24' Open WF-1 12,008' 12,014' 9,654' 9,659' 6' Open }n TOL:11216' G-3,4 WF-1 12,021' 12,026' 9,666' 9,670' 5' Open Isolation Squeeze " :4 -5 WF-2 12,030' 12,050' 9,674' 9,692' 20' Open 11985-11986:;_p: -J 01 1 WF-2 12,055' 12,068' 9,696' 9,708' 13' Open 9-5/8"@ 11327' Vii- HB-1 WF-2 12,081' 12,105' 9,720' 9,741' 24' Open si B-2 WF-4 12,155' 12,184' 8,787' 9,813' 29' Open WF-4 12,208' 12,212' 9,834' 9,838' 4' Open HB-3 WF-4 12,229' 12,241' 9,853' 9,864' 12' Open ''r HB-4 WF-4 12,258' 12,265' 9,880' 9,886' 7' Open WF-4 12,268' 12,272' 9,889' 9,893' 4' Open PKR:11,750 • _., WF-6 12,360' 12,408' 9,973' 10,016' 48' Open Isolation Squeeze 471,"- HB-5,6,7 1198511986 ,;= WF-7 12,468' 12,480' 10,071' 10,082' 12' Open V WF-3,4,5 WF-7 12,500' 12,551' 10,100' 10,147' 51' Open - WF-6,7 TD=12600' PBTD=12543' Directional Data: max=42.5°at 6237' Updated by:JLL 05/20/14 King Salmon Platform K-30 Current 11/14/2013 tiii...,-p ,1/41:14.4.IAA. King Salmon BHTA, B-11-A0,4 1/16 5M FE Tbg hanger, OCT-UH-TC- K-30 1A-ESP, 13 X 4% IBT lift 24 X 13 3/8 X 9 5/8 X 4'/z r R Il and susp,w/4" Type H in„ ���� BPV profile, 3/8 cont control line port anei 1 4 Valve, Swab, WKM-M, 4 1/16 / 1 Go 5M FE, HWO, EE trim s o1R1 > • Valve, Wing, OCT-120, 3 1/8 5M U v, FE, w/Axelson AM oper, EE trim au .p I nt Valve, Wing, AOP, 2 1/16 5M / FE, HWO, AA trim - - ;11111 �' Na -' i - 1.. B 't..� _ _ pill Valve, Master, WKM M, 4 1/16 * 0:403 5M FE, HWO, EE trim = 1 1104111,1 Le : Void test good _, Valve, Wing, CIW-FL, 3 1/8 5M FE, 5/12/2010 ' ' HWO, EE trim 250/5000psi ��! ,�� Iii Adapter, OCT-A5-ESP, 13 5/8 5M • lip 0 API hub X 4 1/16 5M stdd top, w/2- %control line exits, prepped w/OCT f ' m =1 400-4 pocket 5 ,,,'01 J It .�I F 111 \'�P dir) 1 WI All unihead annular valves, Unihead, OCT type 3, 13 5/8 5M 11P—I 1 , 2 1/16 5M FE OCT-20, API hub top X 13 3/8 BTC casing h 9 . , , 19 e IF I HWO bottom,w/ 1-2 1/16 5M SSO on t �.. , , ,vI lower section, 1-2 1/16 5M SSO - .2 ,,,u____________Void_ Void test good on middle section, 3-2 1/16 5M -.i 4 I 9.1 5/12/2010 SSO on upper section , IP 1 1 "1M,. 250/3500psi internal lockpin assya� ; I. 1T , - Valve, OCT-20, 3 1/8 2M Starting head, OCT, 21 1/4 2M II irIv", FE, HWO FEX24" SOW, w/ 1 31/82Mlik # EFO, full set of lockpins -I 24" X13 3/8" 9 5/8" 4 1/z" Moncla R BOP Test Proceig404dure Hilcorp Alaska,LLC Attachment#1 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. 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 Operations Engineer (Hilcorp), Mr. Guy Schwartz(AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLCAttachment#1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt.of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) 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 R BOP Test Proceig404dure xilcorp Alaska,LLC 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 Attachment#1 Diagram A-1: King Salmon BOP stack and Riser Arrangement—Typical for Single Completion • • al Ill Ill ill Ill Ill I1lIII 3.74' III III lit iii IIt • I LEI Ill III Ill CIVJ-U - Variable 2 7/8-5 13 5/8-5000 ®:Blind Rams III fil III Iii lil Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses 011110. I!I III III 111 Ill 2.00' 0 10 iii ill lit lil III '`f ' ` III 111 III III III Riser,13 5/8 5M FE X 13 5/8 5M API#13 hub 13.70' 7 • II Moncla Rig 404 BOP Test Procedure HilrnrpAlaska,LLC 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 ...-- 10.0 . ," AiE.- ' ,. _ __ 1\ lo 1 _... 0,i. ,__ , / .„ 1.1 \--- III - III / MILE C 3 o® 11 "' Chokes are 90 degrees off in drawing in order to show /l detail :: I . ill..:: IL , sw_co ::i1 it :11.. _ I: II S Elks" 0- 1 t! ye . III I liWit "-le_� III II' Wit alIII III Iti -y 111 From Bop Choke Line 2 1/16 5M Unbolt 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 #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 '/4" Ball port, 6000psi working pressure #10 National Ball Valve B1560, 1 '/2" Ball port, 6000psi working pressure • II Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 12 /IU 00 44 la V w 41J I) N It' W :s i} It. f effi Er L3 C7 B a CD I V) a E_ • 0 Q r C i' 0 e t O J oro Az m0 H go 0 o ci_ z_5- [ I.N N n Z gV g u. O o (xOU' R. 0 0 az 0 < W U U —f 4----Do-i► OO U • z W ? . J�z UI J 'r __I O z w m a LLzpc Q J D V CC V • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 y or f V W Z I. a J 14 � K U / 1' W G T IgsV >~ III ,IQII ?o 770 [jj�� CD CD 1.- H ET_ r¢ U) ( c, C�7 ii o z lu ca o ScnU' — Q aO Cowzc� o0mo i Q i w17- w LL _ _ N L l 1 G o ` _ le J O O u z 0 z I— Q J V 0 ' • King Salmon Platform 2013 BOP Stack(Moncla) I ilw,rp Abt kii.la,(; 09/19/2013 lir l i I tT li lNI 3.74' Shaffer ,.... .. ..,. 35/85 ...._,.. Wil. lit ill alai 141 !PI IP IP Ill If! CIW-U Variable 27/8-5 4.67' 6 o� 13 5/8-5000, 01.1..Blind Rams i i I III Iii III Ill Choke and Kill Valves 2 1/16 5M w/Unbolt connections for hoses 01.111110, Ili Ill Ill Ill III _ ,ll, l'ft.*.• .11‘'•O''' 0 1�P '; 2.00 • *Sr Ill lii iii iil di `f III IP If! III Iii Riser,13 5/8 5M FE X 13 5/8 5M API X13 hub 13.70' STATE OF ALASKA ALS A OIL AND GAS CONSERVATION COMA,.__..)10N - REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Repair Well❑ Plug Perforations El Perforate❑ Other 0 Run Kill String Performed: Alter Casing❑ Pull Tubing) Stimulate-Frac ❑ Waiver El Time Extension❑ Change Approved Program El Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development D Exploratory El 170-007 • `,^ '`� Aga s:._ 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20211-00' '',1/.'Y2 1 2014 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 " Trading Bay Unit/K-30 r A '"`G CC 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): t McArthur River Field/Middle Kenai G Oil,West Foreland Oil,Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured • 12,600 feet Plugs measured N/A feet true vertical 10,191 feet Junk measured 11,476 feet Effective Depth measured 12,543 feet Packer measured 11,750 feet true vertical 10,139 feet true vertical 9,423 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 360' 24" 396' 396' Surface 2,151' 13-3/8" 2,187' 2,024' 3,090 psi 1,540 psi Intermediate Production 12,037' 9-5/8" 12,074' 9,713' 6,870 psi 4,750 psi Liner 1,359' 7" 12,575' 10,168' 7,240 psi 5,410 psi Perforation depth Measured depth See Schematic feet 2 True Vertical depth See Schematic feet NGD MAY 7 2.014 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 2,035'(MD) 1,907'(TVD) Packers and SSSV(type,measured and true vertical depth) Packer 11,750'(MD)9,423'(ND) SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDM MAY 2 0 2014 Treatment descriptions including volumes used and final pressure: 'p 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 77 71 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Ex lorato 4 py p ry❑ Developments Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: • Oil D Gas o WDSPL❑ GSTOR ❑ WINJ 0 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: 313-608 Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature Phone 907-777-8420 Date 5/20/2014 Form 10-404 Revised 10/2012 c—ZZZ—/y Submit Original Only • (I fArd9 • • King Salmon Platform II SCHEMATIC Well K-30 Last Completed 5-27-2011 Hilcorp Alaska,LLC Casing and Tubing Detail Wt/ Size Type ement Grade TOP BTM CONN/ID C Other/ RKB:100'AMSL KB-THF:33.76'KB 24" Conductor 94/H40 36.4 396' Welded/19" Driven 13-3/8" Surface 61/K55 36.4 2187 BTC/12.515" , + !F-3 9-5/8" Intermediate 47/N80 36.4 10092' BTC/8.681" 9-5/8" Intermediate 47/P110 10092 12074' BTC/8.681" 24"@ 396' . 7" Liner 29/L80 11216 12575 BTC-KC/ 6.184" Tubing 3-1/2" I IBT I 9.2#/L80 I Surf I 2,035' I Kill String iJewelry Details # Depth Length ID (Drift) OD Item 13-3/8"@ 2151' 35.22' 1 2.867" Hanger 38.75' X-Over 11,750' 3.9 6.184" E-Line set Packer Fish: Bottom Hole Assembly at 11,476' '-roe C.S It /l`/oo 'Ht11 Perforation Detail _ TOC:9600' Top Btm Top Btm Zone (MD) (MD) (ND) _ (TVD) Amt Status 6-06 10,802' 10,830' 8,644' 8,665' 28' Sqzd 6-01 10,870' 10,894' 8,696' 8,714' 24' Open G-02 10,920' 10,945' 8,734' 8,754' 25' _ Open ' G-02 10,954' 10,994' 8,761' 8,792' 40' Open _ 6-03 11,018' 11,050' 8,811' 8,836' 32' Open 6-04 11,064' 11,129' 8,847' 8,897' 65' Open 6-05 11,194' 11,224' 8,949' 8,973' 30' Open G-05 11,232' 11,268' 8,979' _ 9,008' 36'_ Open H-1 11,412' 11,472' 9,125' 9,177' 60'. _ Open H-2 11,495' 11,590' 9,197' 9,280' 95' Open H-3 11,605' 11,650' 9,293' 9,333' 45' Open C( H-4 11,651' 11,720' 9,334'_ 9,396' 69' Open H-5 11,780' 11,790' 9,450' 9,459' 10' Open 60-6 H-5 11,798' 11,820' 9,466' 9,485' 22' Open H-6 11,876' 11,964' 9,536' 9,614' 88' Open �'' G-1,2,3 H-7 11,964' 11,988' 9,614' 9,636' 24' Open TOL 11216' G 3,4 WF-1 12,008' 12,014' 9,654' 9,659' 6' Open k' G-5 WF-1 12,021' 12,026' 9,666' 9,670' 5' _ Open IsolaSqueeze g-5/8" 11327 WF-2 12,030' 12,050' 9,674' 9,692' 20' Open 11985-11986 .: ti @ p #"5 ,HB-I/G7 WF-2 12,055' 12,068' 9,696' 9,708' 13' Open WF-2 12,081' 12,105' 9,720' 9,741' 24' _ Open _HB-2 WF-4 12,155' 12,184' 8,787' 9,813' 29' Open =HB-3 WF-4 12,208' 12,212' 9,834' 9,838' 4' Open _HB-4 WF-4 12,229' 12,241' 9,853' 9,864' 12' Open PKR:11,750' 'y _. WF-4 12,258' 12,265' 9,880' 9,886' 7' Open solation ti°" HB-5,6,7 WF-4 12,268' 12,272' 9,889' 9,893' 4' Open 11985-11986 _ =WF_3,4,5 WF-6 12,360' 12,408' 9,973' 10,016' 48' Open - WF-7 12,468' 12,480' 10,071' 10,082' 12' Open -6'7 WF-7 12,500' 12,551' 10,100' 10,147' 51' Open TD=12600' PBTD=12543' Directional Data: max=42.5°at 6237' Updated by:JLL 05/20/14 • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 03/19/14-Wednesday Rigging up. 03/20/14-Thursday Rigging up. 03/21/14- Friday Rigging up. 03/22/14-Saturday Rigging up. 03/23/14- Sunday Rigging up. 03/24/14- Monday Rigging up. 03/25/14-Tuesday Rigging up. INSTALL BPV. N/D 13-5/8" PRODUCTION TREE. INSPECT HANGER. INSTALL 13-5/8" 5M RISER WITH UNIHEAD OCT ADAPTER FLANGE & HUB. N/U 13-5/8" 5M RISER, MUD CROSS, DOUBLE RAM BOP, HYDRIL WITH SPOOL ADAPTOR FLANGE. HOOK UP UNIBOLT KILL LINE & COFLEX CHOKE LINE. RUN KOOMEY LINES & HOOK UP SAME. INSTALL DRIP PAN. INSTALL RIG FLOOR WITH WIND WALLS. P/U & LAND 3-1/2" TEST ASSEMBLY. 03/26/14-Wednesday R/U TEST HOSE & RUN ELECTRICAL TO KOOMEY. TEST BOPE PER AOGCC REGULATIONS,TEST WITNESS WAIVED BY JIM REGG.TEST VBR RAMS WITH 3-1/2" &4-1/2" TEST STRING,TEST BOPE TO 250 PSI LOW & 3000 PSI HIGH,TEST HYDRIL TO 250 PSI LOW & 1500 PSI HIGH. PERFORM KOOMEY DRAW DOWN TEST. OFFLOAD ESP EQUIPMENT FROM M/V RESOLUTION. CONTINUE SETTING WIND WALLS ON RIG FLOOR WHILE OFF LOADING BOAT. LINE UP PUMP LINES, PUMP DOWN TUBING, CATCHING RETURNS TO PRODUCTION SEPERATOR. AFTER 600 BBLS PUMPED, ACHIEVED RETURNS. DISPLACE ADDITIONAL 200 BBLS UNTIL RETURNS BECAME CLEAN. BACK OUT HOLD DOWN PINS, PULL 112K TO PULL OFF OF HANGER, STRING WT 130K. PULL HANGER TO RIG FLOOR. UNABLE TO FULLY CLOSE 4.5" SLIPS DUE TO RIG NOT BEING CENTER OVER HOLE. ADJUST RIG WITH HYDRAULIC JACKS & SET SLIPS AROUND 4-1/2" TUBING. RIG UP HYDRAULIC JACKS TO SKID RIG 6" DUE NORTH. 03/27/14-Thursday Prepare rig jacks to skid center over well. Skid rig to the North. Adjust rig floor legs, tarps and wind walls. Break out safety valve, break out tubing hanger, lay down tubing hanger and single joint of 4 1/2" tubing. RU ESP pulling equipment. Flat pack sheave, cable sheave, hydraulic spooler. POOH with 4 1/2" production tubing, cable, flat pack. Pump 20 bbls every 20 joints. Switched to hydraulic power pack. Continue to POOH with 4 1/2" tubing and cable/flat pack. Cut out splice at 4,100.36' to send to anchorage per engineer • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 03/28/14- Friday Continued POOH laying down in singles with ESP assembly, production tubing, GLM's and sliding sleeve._Recovered total of 310 joints 4 1/2" tubing, 7 GLM's, (1) sliding sleeve, 20 crossover pup joints. Lay down ESP assembly. Bundle tubing while laying down. Offload fishing tool baskets, washpipe and drill collars. Bleed down accumulator system and test bottles. Recharge, change hydraulic hoses and retest build up rate on accumulator unit. 210 seconds. Install wear bushing. Begin picking up packer milling assembly_BHA# 1 -5-3/4" OD x 4-1/2" ID Burning shoe, 5-3/4 Top bushing, crossover,4- 3/4" OD mud motor, crossover, (2)junk baskets, crossover,4-3/4" OD bumper,4-3/4" OD Oil, (6) 4-3/4" OD drill collars, 4-3/4" OD accelerator, crossover to 3-1/2" PH-6 workstring.Test motor in riser, observed working good.Total BHA 259.81' (1) seal assembly on the ESP had a 1" hole wash out and the motor assembly was full of water. Currently TIH with workstring and fishing BHA# 1. 03/29/14-Saturday TIH with BHA# 1 and 3-1/2" PH-6 work string PU in singles. Hook up suction manifold on tank. Install psi gauge to pump manifold for mud motor.Top of liner at 11,216'.Worked past with no problem.Tagged obstruction at 11,252' on joint 353. PU and down, pushed through to 11,274'. Worked pipe to 11,349' tagged hard 15' in on joint 357'. L/D joint 357. Set power swivel in place. Will use rig pump to turn motor to get past possible (2) corroded Canon clamps. Packer at 11,750'. 401' to packer. 03/30/14-Sunday RU to pump to Trading Bay. Pumped 300 bbls to Trading Bay cleaning mud tank. Spot cuttings tank. Secure. RU dead lines for power swivel. Make up saver sub to power swivel. PU and hang power swivel. Unit would not start. RD power swivel. MU safety valve to work string,fill up casing 65 bbls.Attempt to operate mud motor with pump. Kept pressuring up to 1800 psi.Went to move work string up and down. Work string stuck.Jarred 5 times at 45K over string weight of 115K. Freed up. Rack back 2 stands to put BHA above 7" liner top. Continue to attempt to unplug mud motor. Pressuring up and slow bleeding off. Surging and working workstring. No luck. Hook up pollution pan and jagger pump. Continue to attempt to unplug mud motor. Pressuring up to 3000 psi and bleeding off. POOH Lay down joint 351. Continue to POOH slowly. Waiting on charger blower from Moncla. Will swap out power swivel with rental unit. 03/31/14- Monday Rig shut down with electrical and mechanical problems. RD power swivel and load swivel into swivel cradle. POOH with 3 1/2" PH-6 work string and BHA#1. Stand back 3 stands 4-3/4" OD drill collars. Break out BHA. Motor, boot baskets, xovers and bumper sub plugged with fine oily sand. Clean ID of boot baskets, xovers and boot baskets. Replace bumper sub and mud motor. Make up BHA#2 and add 7.6' 5-3/4" OD extension. Continue RIH with packer milling BHA#2. Will test motor and circulation returns every 2000' until top of 7" liner, then circulate each stand down. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 04/01/14-Tuesday TIH with 3-1/2 PH-6 work string and BHA#2 packer milling assembly. Every 10 stands pump tubing volume to assure motor is working and tubing is clear.At 11,253' pump 40 bbls. PU power swivel and RU. Hook up hoses to transfer fluid from shaker to mud tank. Start washing every joint from 11,252'to 11,817'. Minimal resistance to none. Returns not showing any solids. Pressure on motor running at 200-300 psi.Stalls at 1000 psi.Tag hard at 11,817. Pressure now running at 300-500 psi. Will convert to water flood and pump to Trading Bay. 04/02/14-Wednesday RU lines from water flood to pump manifold.Adjust to 7 bpm. Reading 3200 psi. RU lines to Trading Bay to take returns. Install ditch magnet in shaker. Begin milling at 11,817 with 3200 psi, at 7 bpm with 2-4K weight. After 35 minutes, pressure fell off to 2600 psi. Indications of making 8-10 inches. No variation in pressure on motor showing milling. Spinning.Vary weights, pressures. PU/set down to attempt to change parameters. No luck after 6 hours of milling. POOH. RD power swivel. Begin pulling pipe. Had 50K over pull. Pulled slow. On 5th stand overpull fell off to string weight of 130K. Continue POOH. Radiator hose blew off. Reclamped back on and called for parts. Continue POOH slowly while waiting on parts. New actuator on deck. Install actuator that controls waste gate valve on turbocharger. Rig is working at full power again. POOH to BHA. Break out BHA. Cleaned boot baskets of scale sludge. Break out shoe. Found piece of top of packer shell wedged inside shoe. Found small pieces of metal and canon clamp retainer pin in boot baskets.Test mud motor appears to be working good. PU new 6" OD x 4.500 ID burning shoe and 4 7/8" OD mud motor.Test mud motor in riser. Operating good.TIH making up BHA#3 and (6)4 3/4" OD drill collars,jars and 3 1/2 PH-6 work string. 04/03/14-Thursday TIH with 3 1/2 PH-6 work string and BHA#3 to top of liner at 11,216'.Work through top of liner. Every 20 stands pump tubing volume to check motor and ensure BHA clear. BOPE test due today.Test witness waived by Jim Regg AOGCC.Tag obstruction at 11,375'. Pull two stands and lay out in singles. Run in single stand and pull out breaking out in singles for 5 stands. PU power swivel and wash down in singles to top of packer at 11,817'.Switch over to waterflood. Wait on Trading Bay to line up to accept returns.Tag packer at 11,817 on joint 372. Begin milling packer. Pumping 6 bpm at 1200 psi. stalls at 2000 psi.Shoe spinning on top of packer. Continue to pick up and set down to change parameters. Continue milling packer. At 6:18 slacked off made 6" and now have 150 psi increase in psi. 04/04/14- Friday Continue milling with 6_bpm from waterflood at 1400-1600 psi. Mill 8' with 3-5K weight. Shoe began spinning again. Change parameters for 3 hours. No luck. Shut down pump and spud.Start pump and pressure up to 3500 psi. PU with 40K over pull. Set down to work free, rig lost power.Attempt to trip jars, rig too slow picking up,jars are bleeding off before tripping. Continue to work pipe. Pulled 22' and laid out single on swivel. Continue to work free no luck.Swapped turbocharger from mud pump to rig. No luck. Waiting on turbocharger from Moncla and mechanic.Waiting on rig repair. Checked computer codes on electrical system of rig. Changed ECM and 4 sensors.Shows no problem. Now working on replacing clogged transmission filters to take pressure readings on transmission. Checking fuel pump also. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 04/05/14-Saturday Down for rig repairs. 04/06/14-Sunday Replace wiring harness. Hook up diagnostic computer. Checked injectors. Checked hydraulic pressure readings on transmission. Getting good readings. Showing insufficient power boost. Bypass boost sensor. Replace turbocharger. No luck. New turbocharger arriving this morning. 04/07/14- Monday Continue to repair rig. Replaced full wiring harness. Rig working. Worked work string 5 times and 5 teeth on right angle drive broke. Shut down for replacement. Replace right angle drive.Test hose blew off right angle drive. Reinstall with new gasket. Begin working work string and BHA#3. 170K up (40K) over string weight. (20K) down.Attempt to get jars to work. No luck.Attempt to pump mud motor. Pressured up to 3500 psi.Very slow bleed off. Put torque in wrk string with power swivel and work pipe. No luck. Continue to work pipe to free work string. 04/08/14-Tuesday Continue to work pipe to free while waiting on Eline unit. Continue to work BHA#3 and work string to 185K(55K over) and 60K down (25K under)to free up.With and without pump. When attempting to pump the motor pressures up. Hold 2000 psi while working pipe. Hold torque in work string while working pipe. Unsuccessful.Tubing is torqued up and ready for back off. Ordered out E-line to make back off. New turbocharger arrived. Installed on rig and moved turbocharger on rig to mud pump.Change out Moncla rental swivel to Moncla swivel. Priority E-line unit and personnel onboard and presently offloading E-line cutters from boat. RU Eline,work left hand torque into work string.Work up and down putting 6 1/2 rounds to the left.TIH w/Eline and to 11,461'top of 4 3/4" OD intensifier jar at crossover to 3 1/2 PH-6 tubing. with 130K pulled on work string. Fire string shot. NO back off. POOH. TIH with new string shot#2.Work torque left 6 1/2 rounds with 130K pulled on work string. String shot did not fire. POOH.TIH with new string shot#3. Work torque left 6 1/2 rounds with 130K pulled on work string. Fire string shot. No backoff. POOH, Rehead CCL and TIH with new string shot #4. Work torque left 7 rounds with 130K pulled on work string. Fire string shot. POOH pick up to 140K working pipe. Pipe_ came free with 20K weight 1544'. Backed off high. Now screwing work string back together. 04/09/14-Wednesday RD load out E-line unit. RU E-line unit with FPI. TIH with free point indicator. Moving pipe to check indicator every 2,000'. Showed free to 11,558'. Down to bottom of 2nd 4-3/4" OD drill collar. POOH w/E-line free point indicator. RU string shot, TIH to 11,461'.Tighten work string to the right. Work left hand torque in with 6-1/2 rounds to the left working torque every 2 rounds.TIH with string shot. Fire. No back off. Dogleg severity at 11,400'to 11,550' shows going from 0.93 to 5.48 to 1.85 to 4.17 and back to 0.35. POOH with String shot. MU/TIH with hole punch to 11,450'. 15'from bottom of last joint of 3-1/2" PH-6 tubing. Fire hole punch. POOH. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 04/10/14-Thursday Finish TIH to 11,445' with Eline hole punch. Fired hole punch. POOH LD hole punch assembly. PU Radial Torch cutter TIH to 11,445' Pull 20K over string weight. Fire RTC cutter. No indication of cut with loss of weight. RTC tool stuck.Attempt to work free, unsuccessful. Pull free from rope socket. POOH with Eline only. Wait on tools to complete hole punch assembly #2. Rig up pumps pressure to 1500-2000 psi. No indication of holes. Hole punch tools arrived. MU TIH to 11, 418'. Fire hole punch. POOH with Eline hole punch assembly. RU pump and pressure to 2500 psi. No indication of holes. Work pipe. Unsuccessful. Locate Chemical cutter. MU/TIH with Chemical cutter to 11,406'. Pull 20K overpull. Fire Chemical cutter. No indication of cut. Pull up to 165K. Still no indication. POOH with Eline Chemical cutter. Begin to work pipe to 185K. Work string began moving. Lay down joint 370. RU pump and work pipe. RD Eline. Began reversing. Pipe plugged with 1000 psi.Swapped to long way circulating. Unplugged pipe. Broke circulation. Circulate @ 300-400 psi for 20 minutes, then swapped to reversing. Circulate bottoms up. Wash joint 369 back down. MU joint 370 and wash down to top of cut 3- 1/2" tubing at 11,406'. Currently circulating hole clean. 04/11/14- Friday Finish reversing sand fill and bottoms up. Pump 35 bbl polymer pill and spot across top of fish and perfs. Chase with 75 bbls FIW. POOH recovered 184 stands and 11.63' cut piece of 3-1/2" PH-6 tubing. RU test BOPE.Test BOPE 250 psi low/ 2500 psi high. One leak at wellhead hub clamp.Tighten clamp. No leaks.Test waived by Jim Regg. Pumped 400 bbls to clean out mud tank in preparation for running the Rattler. PU MU BHA#4 consists of 5-3/4" overshot, 4-3/4" Rattler,4- 3/4" drilling jar, (6) drill collars xover to 3-1/2" PH-6 tubing.Test Rattler with 1/5 bpm at 700 psi. Working good.TIH with BHA#4 and 3-1/2" PH-6 tubing. 04/12/14-Saturday TIH with 5-3/4" overshot and 4-3/4" Rattler with 4-3/4" drilling jars and (6) drill collars.Tag fill at 11,400' DP measurement. Wash down to 11,415' DP measurement (11,406' ELM) top of 3-1/2" cut tubing. Up weight 123K down 88K. RU to pump to Trading Bay to displace hole with fresh FIW. Engage with overshot and over pull 20K to 143K.Work pipe to 160K. Put 10K overpull on work string and pump 2 bpm through Rattler tool. After 20 minutes weight started falling off in 5K increments. Pipe came free with 10K drag overpull then dropped off to string weight 123K. Work overshot to ensure still engaged at same depth with 18'fish top inside of overshot.Tagging same. Possible we have the first cut joint pulled. Stand back drill collars and break out drilling jars/Rattler and overshot. Found large chunk of old Annular rubber stuck inside of overshot. Redress overshot grapple. PU MU overshot/Rattler/drilling jars.Test Rattler, continue TIH with (6)4-3/4" drill collars and 3-1/2" PH-6 work string.TIH to top of 7" liner top. Currently attempting to get inside liner top.Attempt to turn with tongs. No luck. Laying down singles from derrick to work with inside 7" liner.Will PU power swivel to work overshot into 7' liner. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 04/13/14-Sunday Lay down 8 joints in singles on catwalk.TIH with BHA#5-5-3/4" Overshot/4-3/4" Rattler/4-3/4" drilling jar(6)4-3/4" drill collars to 11,216'top of liner. PU MU power swivel start circulating. Rotate power swivel and work through top of liner. Continue to 11,254'tagged fill washed in singles to 11,403'. Could not go any further. Sand fill coming in. We would pick up with drag and overpull and set down high. RD power swivel. Laid out 11 joints in singles. POOH. Break out lay down Rattler,jars and overshot. PU 6-1/8" OD full opening bladed mill,jars and (6) drill collars. RU hopper to mix salt pill. TIH with 3-1/2" PH-6 work string BHA#6 consist of 6-1/8" OD full opening bladed mill, 4-3/4" Bumper, oil and intensifier jars and (6)4-3/4" drill collars. 04/14/14- Monday Shut down twice (total 2 hours)to repair tongs while TIH with 6-1/8" OD Full opening mill,4-3/4" bumper, oil jars, (6)4- 3/4" drill collars, 4-3/4" intensifier. PU power swivel and wash down from 11,395" to 11,404" fill became harder. Continue reversing to 11,430'. Getting fine sand in returns. Run mill on top of tubing to attempt to dress off and mark mill with tubing stub. Power swivel stalling out at 6000 ft. lbs. RD power swivel. Line up manifold to pump and close off 9- 5/8" casing to establish injection rate. Closed annular and establish injection rate. Pump lbbl @ 200 psi, 1.5bbl @ 400 psi. Open 9-5/8" casing and displace 35bb1 pill 10.6 ppf to end of work string. Closed off 9-5/8" casing and injected 35 bbl salt pill @ EOT 11,429'. 1.5bbl @ 200 psi, 1.5 bbl @ 400 & 500 psi, 0.5 bbl @ 600&700 psi. Hold until bled off to 0 ps. Break off TIW valve and pull up hole 6 stands above top of pill. MU TIW valve and reverse out tubing. Mix(2nd) 35 bbl pill. Shut in well. Open pipe rams and TIH to 11,429'.TIH to 11, 429', MU TIW valve and standpipe hose, begin injecting salt pill.After injecting salt pill will pull up to 3,000' and shut in well to change out engine and transmission on Moncla Rig 404. 04/15/14-Tuesday Finish spotting 35 bbl salt pill. Beginning injection rate at 1.5 bpm @ 400 psi, ending injection rate at 0.5 bpm @ 800 psi. Let bleed off to 0 psi. POOH to 3,292.14' (130 stands in derrick, laid out 2 joints with 99 joints in the hole. Close pipe rams and lock, close Hydril, install TIW with night cap and gauge. Close K1, K2, C-1 and HCR. Pull rig engine,transmission and drive shaft. General maintenance and cleaning. 04/16/14-Wednesday Rig down for repairs. 04/17/14-Thursday MECHANICS ARRIVED ON PLATFORM. INSTALL 60 SERIES DETROIT ENGINE WITH 5860 ALLISON TRANSMISSION. WIRE UP HARNESS TO COMPUTER PANEL& MAKE TIE-INS. FILL RADIATOR& PREP ENGINE FOR INITIAL START UP. START UP ENGINE & LET IDLE. NEW RIGHT ANGLE DRIVE SHAFT ARRIVED ONTO PLATFORM AT 1945 HRS. INSTALL SAME & MAKE ENGINE ADJUSTMENTS.TEST RUN RIG ENGINE PACKAGE BY PULLING ON KILL STRING &WORKING PIPE.TIH FROM 3,000' TO 11,300'. P/U WT. = 116K, S/O WEIGHT= 82K.TIH TO TOP OF FISH AT 11,433'.TAG SAME WITH NO FILL. POOH TO TOP OF LINER AT 11,216'. REPAIRING RIG HYDRAULIC PUMP @ 0600 HRS. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 04/18/14- Friday CLEAN 80 BBL RIG MIXING TANK & SEND 136 BBLS OF NON PRODUCED FLUID TO TRADING BAY. TIH & PLACE END OF TUBING @ 11,368'. MIX 12 BBL SLURRY OF PFS POLY PLUG. PUMP 12 BBLS OF POLY PLUG, DISPLACE WITH 82 BBLS OF FIW, SQUEEZE TOTAL OF 5 BBLS OF FIW & 12 BBLS OF POLY PLUG INTO FORMATION F/ 11,395' - 11,430'. FINAL SQUEEZE PRESSURE 1 BPM @ 1000 PSI. SHUT DOWN PUMP & MONITOR PRESSURE. PRESSURE BLED TO 0 PSI AFTER 15 MINUTES. R/D PUMP LINES & POOH F/11,368 - 11,247'. PIPE BEGAN DRAGGING 50K OVER FROM 11,247'TO 11,216' (LINER TOP). OVER DRAG FELL OFF AFTER EXITING LINER TOP. CONTINUE POOH TO 11,058'. REVERSE CIRCULATE 144 BBLS OF FIW @ 2 BPM & 100 PSI MONITORING RETURNS OVER SHAKERS. POOH F/ 11,058'TO SURFACE. RACK D.C.'S INTO DERRICK& L/D SCRAPERS, X-O'S, & 6" BEAR CLAW BIT. CLEAR RIG FLOOR. PULL WEAR BUSHING. P/U BOPE TEST ASSEMBLY& LAND OUT SAME. BOPE WITNESS WAIVED BY JIM REGG ON 4-18-14 @ 19:06 HRS. 04/19/14-Saturday TEST BOPE PER AOGCC REGULATIONS, TEST HYDRIL TO 250 PSI LOW & 1500 PSI HIGH,TEST ALL OTHER BOPE TO 250 PSI LOW & 3000 PSI HIGH. HOLD ALL TEST ON CHART FOR 5 MINUTES. PERFORM KOOMEY DRAW DOWN TEST. VBR & HYDRIL WERE TESTED WITH 3-1/2" 12.95# PH-6 TUBING. WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. L/D TEST ASSEMBLY. CLEAN RIG FLOOR. REMOVE FOSTER MODEL 58 TONGS & R/U FOSTER MODEL 5402 TONGS. INSTALL WEAR BUSHING & LOCK DOWN SAME. P/U 10 JTS OF 5-3/4" WASHPIPE WITH 5-3/4" OCEAN WAVE BURN SHOE,TOP SUB, 4-5/8" DRILLING JARS, (6) 4-3/4" DRILL COLLARS, & X-O.TOTAL BHA LENGH OF 533.03'. WEIGHT BELOW JARS= 5K, TOTAL BHA WEIGHT= 16K.TIH WITH 3-1/2" 12.95#WORKSTRING. TAG @ 11,368'. POOH TO LINER TOP @ 11,216'. PUMP 170 BBLS OF DIRTY NON PRODUCED FLUID FROM ACTIVE RIG TANK TO TRADING BAY. LOADING OUT 13-5/8" 5M BY 7-1/16" 5M ADAPTOR FLANGE FROM DOCK TO BE INSTALLED ON HYDRIL FOR HALLS HEAD RUBBER TO REAM &WASH OVER FISH @ 05:30 HRS. 04/20/14-Sunday FINISH PUMPING 170 BBLS OF DIRTY INLET WATER TO TRADING BAY FROM 200 BBL RIG TANK. INSTALL 13-5/8" 5M BY 7- 1/16" 5M ADAPTOR FLANGE.TIH F/11,216'TO 11,368'. INSTALL HALLS HEAD STRIPPER RUBBER & P/U POWER SWIVEL. BREAK CIRCULATION IN REVERSE @ 2 BPM & 300 PSI. WASH FROM 11,368' TO 11,433, REVERSE CIRCULATING BOTTOMS UP BEFORE EACH CONNECTION & RECIPROCATING TUBING. TAG & ROTATE OVER FISH TOP @ 11,433'. WASH F/11,433' TO 11,510', PUMPING 3 BPM @ 325 PSI. MINIMAL FLUID LOSS. REVERSE CIRCULATING BOTTOMS UP BEFORE EACH CONNECTION.TOTAL FLUID LOSS OF 30 BBLS. MILLING ON DEBRIS & SWALLOWING FISH WITH WASHPIPE F/11,510'TO 11,575'. CIRCULATING BOTTOMS UP AFTER EACH CONNECTION. REVERSE CIRCULATING 3 BPM @ 325 PSI, TORQUE = 6K- 7K (STALLING OUT). MILLING ON DEBRIS F/11,575'TO 11,586'. POWER SWIVEL STALLING OUT, WASHPIPE ATTEMPTING TO MECHANICALLY STICK @ 11,586'.JARRING UP 50K OVER STRING WEIGHT TO FREE STRING. MIX, PUMP, &SPOT 15 BBL 9.6#SALT PILL F/11,200'TO 11,586'. L/D POWER SWIVEL& POOH WITH 3-1/2"TUBING. DEPTH @ 0600 HRS= 8800'. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 04/21/14- Monday POOH F/8,800'TO 5,205'. LOUD NOISE CAME FROM RIG ENGINE WHILE POOH WITH STAND & ENGINE LOST 50% PULLING POWER. SECURE WELL. RIG DOWN TIME: UNITED ENGINE MECHANIC TO ARRIVE IN STATE ON 4/22/14 @ 1530 HRS. 04/22/14-Tuesday MECHANIC INSPECTED 60 SERIES ENGINE &TRANSMITION (ALL O.K.) REINSTALLED OIL COOLER &TOPPED OFF FLUIDS. TEST RUN ENGINE & CHECKED TRANSMISSION PRESSURES (ALL O.K.). TEST ENGINE &TRANSMISSION UNDER LOAD OF 84K STRING WEIGHT(ALL O.K.)TRANSMISSION PULLING GOOD. POOH WITH 3-1/2" 12.95#TUBING FROM 5,205'TO BHA ASSEMBLY. SECURE WELL& PREPARE TO SLIP & CUT DRILL LINE. HANG BLOCK, SLIP & CUT 106' OF DRILL LINE. SECURE DRILL LINE TO DEAD MAN & PREPARE TO FINISH POOH WITH BHA @ 0600 HRS. 04/23/14-Wednesday SERVICE RIG & EQUIPMENT. POOH. L/D JARS, 5-3/4" WASHPIPE & OCEAN WAVE BURNING SHOE. CLEAR RIG FLOOR & PREPARE TO P/U BHA. P/U BHA#8, 5-3/4" OVER SHOT DRESSED WITH 3-1/2" BASKET GRAPPLE & PACK OFF, SAFETY JOINT, PUMP OUT SUB, BAKER RATTLER TOOL, DRILLING JARS, (6) 4-3/4" DRILL COLLARS &X-0 SUB. TOTAL BHA LENGH = 251.84'.TOTAL BHA WT. = 7K. SURFACE TEST BAKER RATTLER TOOL. PUMP 1 BPM @ 800 PSI TO INITIATE RATTLER TOOL. TIH WITH 3-1/2" 12.95#TUBING TO 11,210'. FILL HOLE & BREAK CIRCULATION. HOLE TOOK 5 BBLS TO FILL. TEST RATTLER TOOL,TOOL TEST O.K.TIH TO 11,410'. P/U POWER SWIVEL, PERFORM DERRICK INSPECTION FOR JARRING. ENGAGE FISH TOP @ 11,433'. BEGIN JARRING IN A DOWN STROKE WITH 50K DOWN. BREAK CIRCULATION @ 1BPM & 700 PSI. CONTINUE JARRING WITH 50K DOWN. RUPTURE DISC & BEGIN RATTLING WITH BAKER TOOL&JARRING. BEGAN SEEING MINIMAL FISH TRAVEL. FISH PARTED AFTER CONTINUOUS JARRING. POSSIBLE PARTED AT FAILED TUBING CUT DEPTH OF 11,469'. L/D POWER SWIVEL& PREPARE TO POOH. POOH WITH 3-1/2" 12.95#TUBING. DEPTH @ 0600 HRS= 3,686'. TOTAL FLUID LOST TO FORMATION LAST 24 HRS= 148 BBLS OF FIW. 04/24/14 -Thursday CONTINUE POOH WITH 3-1/2" 12.95#TUBING TO BHA. L/D VIBRATING TOOL. RECOVERED 2 CUT JOINTS OF 3-1/2" TUBING,TOTAL FISH RECOVERY OF 41.35'. DECISION MADE TO TRY& RETRIEVE WIRELINE FISH�V/1TL RADED_LINE. CALL OUT WIRELINE WITH BRADED LINE SPOOL. SPOT WIRELINE UNIT, POWER PACK, & EQUIPMENT. CHANGE OUT SLICKLINE SPOOL& INSTALL BRADED LINE SPOOL. RIG UP 60' OF LUBRICATOR & SHEAVES. RIH WITH 5-1/2" IMPRESSION BLOCK, BOW SPRING CENTRALIZER, OIL JARS, &SPANG JARS.TAG @ 11,153' WLM. POOH & HANG UP @ 10,960'. WORK WIRELINE TOOLS @ 10,960'. ABLE TO TRAVEL DOWN HOLE WITH TOOLS. CONTINUE WORKING WIRE LINE UP @ 10,960'. FILL HOLE WITH 64 BBLS OF FIW. FREE WIRELINE & POOH. HAD IMPRESSION OF LINER TOP ON LIB. R/D WIRELINE & EQUIPMENT. P/U 5-1/2" OVERSHOT WITH 2" BASKET GRAPPLE. LOAD DRAIN SUB WITH BLOW DISC.TIH WITH (6) 4-3/4" DRILL COLLARS & DRILLING JARS.TIH WITH 3-1/2" TUBING, DEPTH @ 0600 HRS= 6,473'. AOGCC WITNESS NOTIFICATION SENT ON 4/24/14 @ 11:57 HRS TO TEST BOPE ON 4/26/14. WITNESS WAIVED BY JIM REGG @ 12:46 HRS ON 4/24/14. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 04/25/14- Friday CONTINUE TIH F/6,473'T/11,450'. R/U POWER SWIVEL, BREAK CIRCULATION, WASH F/11,450 TO 11,464' PUMPING 1 BPM &100 PSI. PRESSURE BEGAN RISING TO 400 PSI ON TUBING AT 11,464' INDICATING WIRELINE FISH INSIDE GRAPPLE. SHUT DOWN PUMP. P/U TO 11,460', PRESSURE UP ON TUBING TO 1500 PSI & BLOW DISK. L/D POWER SWIVEL& PREPARE TO POOH. POOH WITH 3-1/2" TUBING (WET STRING) F/11,460'TO SURFACE, RACK BHA IN DERRICK. RECOVERED 8.18' OF WIRELINE FISH, WIRELINE ASSEMBLY PARTED AT CENTRALIZER BAR LEAVING 1.50' ABOVE TUBING FISH TO LATCH ONTO. SHUCK& L/D FISH, REDRESS OVER SHOT WITH 2.5" BASKET GRAPPLE,TIH WITH OVERSHOT, DRILLING JARS, (6) 4-3/4" COLLARS & 3-1/2"TUBING TO 11,450'. R/U POWER SWIVEL, FILL HOLE WITH 10 BBLS OF FIW & BREAK CIRCULATION. SLACK OFF OVER TOP OF FISH @ 11,474.50' & BOTTOM OUT @ 11,476'. PUMP PRESSURE REMAINED CONSTANT @ 1 BPM & 100 PSI. P/U WITH NO INDICATION OF FISH LATCHED. WORK PIPE OVER WIRE LINE FISH TOP WITH RIGHT HAND ROTATION & BOTTOM OUT AGAIN @ 11,476' (NO PUMP PRESSURE INCREASE). P/U OFF TUBING FISH TOP & MAKE DECISION TO POOH TO CHECK RECOVERY. L/D POWER SWIVEL& PREPARE TO POOH. 04/26/14-Saturday POOH WITH 3-1/2" 12.95#TUBING SLOWLY ON/OFF SLIPS TO SURFACE. NO FISH RECOVERY,_HAD MARKS ON CONTROL GUIDE FROM BOTTOMING OUT ON TUBING FISH. INDICATIONS OF SLIPPING OVER &OFF OF WIRE LINE FISH. PULL WEAR BUSHING, P/U TEST ASSEMBLY& PREPARE TO TEST BOPE, TEST HYDRIL TO 250 PSI LOW, 1500 PSI HIGH. TEST ALL OTHER BOPE TO 250 PSI LOW & 3000 PSI HIGH PER AOGCC REGULATIONS. TEST WITNESS WAIVED BY JIM REGG. R/D TEST ASSEMBLY & INSTALL WEAR BUSHING. P/U 5-3/4" OVERSHOT WITH 1-3/8" GRAPPLE & 1-9/16" CONTROL GUIDE. TIH WITH (6) 4-3/4" DRILL COLLARS, & DRILLING JARS. CONTINUE TIH WITH 3-1/2" 12.95#TUBING. DEPTH @ 0530 HRS = 8,822'. HOOK UP DIAPHRAM PUMP & LINES TO PUMP OVER RETURNS FROM PIPE DISPLACEMENT. 04/27/14-Sunday Service rig & equipment. Continue TIH with 3-1/2" 12.95#tubing F/8,822' to 11,456'. P/U power swivel, break circulation after pumping 10 bbls of FIW down tubing. Work over top of wire line fish @ 11,474', bottom out on 3-1/2" tubing stub fish @ 11,476'. Work grapple to ensure good bite on wire line fish. Bring rig pump on at 1.5 bpm & 150 psi. Had no pressure increase. Continue working grapple with right hand torque & bottoming out on 3-1/2" tubing fish top. Continue to check pump pressure, no pressure increase indicating fish latch. Set 50k down attempting to latch fish. L/D power swivel & prepare to POOH. POOH slowly with 3-1/2" tubing, easy on/off slips. POOH & rack back drill collars in derrick. No fish recovery, break down over shot & had imprint of 3-1/2" tubing fish stub on control guide from bottoming out. No indication of wireline fish entering control guide or 1-3/8" grapple. P/U & dress 5-3/4" overshot with 3-1/2" basket grapple & control guide, TIH with over shot, baker rattler tool, drilling jars, (6) 4-3/4" drill collars.TIH with 3-1/2" tubing. Depth @ 0600 hrs = 9,765'. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/141 5/3/14 Daily Operations: 04/28/14- Monday SERVICE RIG & EQUIPMENT.TIH F/9,765'TO 11,457' WITH 3-1/2" 12.95#TUBING. R/U POWER SWIVEL& INSTALL HALLS HEAD RUBBER. ENGAGE 3-1/2" TUBING FISH TOP @ 11,476'. LATCH ONTO FISH & BEGIN JARRING IN DOWNWARD MOTION. PRESSURE UP ON TUBING TO 1000 PSI, UNABLE TO PUMP THROUGH FISH. SHEAR DISK WITH 1500 PSI & BEGIN WORKING BAKER RATTLER &JARRING DOWNWARD WITH 50K.AFTER 2 HOURS OF JARRING, BEGAN SEEING LOWER FISH JARS WORKING. CONTINUE JARRING & RATTLING WITH BAKER RATTLER WITH 50K DOWN. CONTINUE TO SEE LOWER FISH JARS WORKING TANDEM WITH UPPER DRILLING JARS. CONTINUE WORKING BHA FISH,JARRING 70K OVER. UNABLE TO SEE LOWER JARS WORK WITHOUT RUNNING BAKER RATTLER TOOL. NO FOOTAGE MADE BY JARRING OR RATTLING. DECISION WAS TO SHUCK OVERSHOT& POOH. SHUCK OVERSHOT, L/D POWER SWIVEL& PREPARE TO POOH. POOH F/11,456'TO 9300'. POOH WITH 3-1/2" TUBING. DEPTH @ 0600 HRS = 7,011' 04/29/14-Tuesday SERVICE RIG & EQUIPMENT. POOH FROM 7,011' TO SURFACE WITH 3-1/2" 12.95#TUBING. RACK BACK 4-3/4" DRILL COLLARS IN DERRICK. L/D BAKER RATTLER TOOL &JARS. REDRESS OVERSHOT WITH 3-1/2" FULL OPEN GRAPPLE &TIH SAME. TIH WITH 3-1/2" TUBING TO 11,256'. P/U 7 JOINTS OF TUBING FROM CATWALK &TIH SAME. SPACE OUT TUBING. P/U WT= 108K, S/O WT.= 78K. ENGAGE 3-1/2" FISH TOP @ 11,476', PULL 30K OVER STRING WT. & SET IN SLIPS. SPOT SLICKLINE WITH BRAIDED CABLE. R/U LUBRICATOR &SHEAVES. REHEAD ROPE SOCKET& PREPARE TO RIH WITH 2" LIB. RIH WITH 2.25" LIB &TAG SAME @ 11,404' WLM. POOH & HAD IMPRESSION OF TUBING BURR. POSSIBLE CUT LIP PIECE OF TUBING FOLDED INSIDE OF FISH. P/U 2.25" BY 2.75" SWEDGE. RIH &ATTEMPT TO SWEDGE BURR FREE. POOH & HAD MARK ON OUTSIDE SWEDGE FROM TRYING TO FOLD BURR AS WELL AS MARK ON BOTTOM OF SWEDGE FROM BOTTOMING OUT ON WIRELINE FISH. RIH WITH 2.25" BLIND BOX & 2.75" SWEDGE TO 11,404'. ATTEMPT TO FOLD TUBING BURR OPEN WITH NO SUCCESS. POOH WITH WIRELINE & INSPECT TOOLS. 04/30/14-Wednesday POOH WITH BRADED LINE. HAD MARKS ON BLIND BOX INDICATING THAT WE WERE HITTING ON TOP OF TUBING BURR. UNABLE TO PENETRATE PAST BURR. R/D WIRELINE & LUBRICATOR. R/U POWER SWIVEL. RELEASE GRAPPLE FROM FISH. R/D POWER SWIVEL& PREPARE TO POOH. POOH WITH 3-1/2" TUBING TO 8,295'. BOLTS ON MCCOY TONGS HOLDING DIE BLOCKS BROKE. R/D MCCOY TONGS & R/U FOSTER 58-93 TONGS. UNABLE TO BREAK CONNECTIONS WITHOUT DAMAGING PIPE. WAITING ON 1/2" BY 7" BOLTS FROM MONCLA. POOH F/8,295' TO SURFACE. L/D OVERSHOT. P/U 5- 3/4" EXTERNAL FRICTION CUTTER WITH (1)JOINT OF 5-3/4" WASHPIPE. TIH WITH 3-1/2"TUBING. DEPTH @ 06:00 HRS = 3,218'. _P Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-30 50-733-20211-00 170-007 3/19/14 5/3/14 Daily Operations: 05/01/14-Thursday TIH F/3,218' TO 11,462' WITH 3-1/2" 12.95#TUBING. P/U POWER SWIVEL, INSTALL HALL'S HEAD RUBBER, FILL HOLE WITH 10 BBLS & BREAK CIRCULATION. ESTABLISH FREE ROTATING TORQUE OF 4800 FT/LBS. ENGAGE FISH TOP @ 11,476', SWALLOW FISH TO 11,480', ROTATE POWER SWIVEL @ 55 RPM, 6000 FT/LBS OF TORQUE, PUMPING 1 BPM WITH 0 PSI ATTEMPTING TO FRICTION CUT 3-1/2"TUBING FISH. HAD NO TORQUE DECREASE AFTER 8.5 HRS OF CUTTING. P/U ON WORKSTRING TO 11,478',TORQUE FELL TO 4800 FT/LBS. L/D POWER SWIVEL& REMOVE HALL'S HEAD RUBBER. PREPARE TO POOH. POOH F/11,462' TO SURFACE. HAD NO FISH RECOVERY. DISCUSS WITH ENGINEER & DECISION WAS MADE TO L/D WORK STRING &TIH WITH 3-1/2" IBT KILL STRING. 05/02/14- Friday TIH WITH (6)4-3/4" DRILL COLLARS & POOH LAYING DOWN SAME. L/D ALL FISHING ASSEMBLY& BREAK DOWN & LOAD OUT.TIH WITH 3-1/2" 12.95#WORKSTRING TO 6,350'. POOH LAYING DOWN 3-1/2" 12.95#TUBING. L/D TOTAL OF 135 JOINTS.TIH WITH REMAINING 86 STANDS OF 3-1/2" 12.95#TUBING OUT OF DERRICK. POOH LAYING DOWN 237 JOINTS OF 3-1/2" TUBING TOTAL OF 372 JOINTS LAID DOWN. CLEAR RIG FLOOR, SERVICE RIG & PREPARE TO P/U 3-1/2" IBT KILL STRING. 05/03/14-Saturday RETRIEVE WEAR BUSHING & PREPARE TO P/U KILL STRING. SLM, P/U, &TIH WITH 64 JTS OF 3_/2" IBT TUBING. P/U WT. _ 34K, S/O WT. = 25K. INSTALL 13-5/8" 5M TUBING HANGER WITH PENETRATOR. LAND OUT TUBING @ 2,034.93' KB. RUN IN LOCK DOWN PINS & INSTALL BPV. CLEAR TOOLS& EQUIP. FROM RIG FLOOR. R/D TONGS. REMOVE WIND WALLS, R/D RIG FLOOR. N/D 13-5/8 HYDRIL, DOUBLE BOP, MUD CROSS & RISER. INSTALL 13-5/8" 5M UNIHEAD OCT ADAPTOR HUB WITH 4-1/16"TREE TOP.TEST TUBING HANGER VOID TO 5000 PSI FOR 15 MINUTES,TEST TREE TO 3000 PSI FOR 15 MINUTES (ALL TEST GOOD). PREPARING RIG TO SKID TO K-17. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Sunday, May 04, 2014 4:18 PM To: Ted Kramer Cc: Ferguson, Victoria L (DOA); Juanita Lovett Subject: Re: K-30 Sundry # 313-608 PTD# 170-007 Thanks for update. Submit a 10-404 with work completed to date. Guy Sent from my iPhone On May 2, 2014, at 3:45 PM, "Ted Kramer" <tkramer@hilcorp.com> wrote: Guy and Victoria, I am writing to let you know that Hilcorp has gone as far as we can go on the above well and we will be running a kill string and temporarily getting off the well until a smaller ESP can be built. Attached is a schematic of the bottom hole assembly that we left in the well. Numerous attempts to fish the assembly out were unsuccessful. The plan forward is to move off the well until a smaller ESP can be built and then move back on and perforate what we can and run the smaller ESP. We believe we can still perforate the G -zones 1-5 and the Hemlock Bench 1. The Hemlock Bench 2 will be behind pipe of the fish but we did wash over the fish down to the start of bench 3 so bench 2 may still contribute some fluid as well. This is disappointing for us but sometimes it is better to take what one can get now and come back later when a larger rig is available to try to recover the fish. From K-30 we will be moving to K-17 (Sundry # 314-179) to try to return that well to production. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 <BHA Left in Well 2014.pdf5 I SCAM OCT 0 7 2014 i R0 1 1tools Date: 4/21/2014 Company Hilcorp Energy Co _--___FISHING SERVICES— 31/21112.95 PH -6 TRIP p: 3 TOOLS LEFT B.H.A.#: 3 Lease: Kin Salm D.P.IMIRING : Well #: K-30 K.I.H. / NEXT JT.: Job # : 115600121 TOTAL : iSupervisoriGLENN TOP OF FISH: IN HOLE... B.H.A.: 315.83' Co. Rep. Bobby Harrington B. .A. Pleturs, DESCRIPTION D .D. I.D. LENGTH -l� _ / r � -4 - -' � 1 - CUT JT. 31/2"PH-6 TUBING 12.95# 31/2" 3 112" 4. 1/4" 4. 3/4" 43/4" 4 314" 2.750 18.820 2.750 31.050 — 2 1/8" 1.580 2" 10.850 2 1/8' 186,850 -� )1/4" 2 12.700 2" 7.850 11,433' 1 - JT. 31/2"PH-6 TUBING 12.95# 11,451.82' CROSS-OVER SUB 31/2"PH-6 X 31/2"IF 11,482.87' SER. #K54652 11,484.45' 11,495.30' ACCEL. JAR 31/2"IF CONNS. SER. #2134 6 - DRILL COLLARS 31/2"IF CONNS. SER. #KP475222 Of SER. #K7475906 11,525.54' 11,556.09' 11,585.09' 11,614.45' 11,645.61'SER. _5ER. #KP47581 SER. #K475165 SER.#KP475269 #K1747563 OIL JAR 31/2"IF CONKS. SER. #9308018 BUMPER JAR 31/2"IF CONNS. SER. #4613 - OUBLE BOX SUB 31/2"IF X_ 31/2"REG #KP6804 BOOT BASKET 31/2"REG CONNS. _ SER. #KF1226 BOOT BASKET 112"REG CONNS. SER. #KF17500 DOUBLE PIN SUB 31/2"REG X 31/2"IF SER. #KF7616 MUD MOTOR 31/2"IF X 3 1/2"REG 50036266 DOUBLE PIN SUB 31/2"REG X 31/2"IF SER. #K5521 CANFIELD BUSHING 31%2"IF X 5 3/4"KHT SER. #KF14982 WASH -PIPE EXTENSION 5 3/4"KHT CONNS. SER. #KF16708 PACKER TYPE BURNING SHOE 5 3/4"KHT CONN.11,7485.58' SER.4KF657 - 11,676.60' 11,689.30' 4 314" 11,697' 4 314" 21/4" 1.450 11,698.60' 5" 1 1/2" 4.080 1 1/2" 4.230 13/8" 2.300 11,702.68' 5" 11,706.91' 11,709.21' _47/8" 11,733.69' 11,735.57' 11,737.98' 4 3/4" N/A 24.480 4 3/4" 1 1/2" 1.880 1 3/4" 2.410 5 3/4" _ 5" 7.600 5" E3.25)(0 53/4" 6" - 11,74.83' NWp 6�:/M K -V `JI QI - U U -' Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 12, 2014 9:49 AM To: 'Ted Kramer' Cc: Juanita Lovett; Bettis, Patricia K (DOA) Subject: RE: King Salmon - K-30 Sundry # 313-608 - (PTD 170-007) Ted, Your changes to the intervals are approved. I will update our well file with this email. No sundry is needed you may continue to perf under sundry 313-608. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Ted Kramer [--JIto:tkramer@hilcorp.com] Sent: Tuesday, March 11, 2014 3:54 PM To: Schwartz, Guy L (DOA) Cc: Juanita Lovett Subject: FW: King Salmon - K-30 Sundry # 313-608 - (PTD 170-007) Guy, Please see the changes below to the K-30 perforation plan. Is this enough to enact the needed change? H-2 falls within the Hemlock interval that is already perfed (see attached proposed schematic). No spacing exception is required as per CO 228A If you need any additional information, please let me know. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Juanita Lovett Sent: Tuesday, March 11, 2014 3:05 PM To: Ted Kramer Subject: King Salmon - K-30 Sundry # 313-608 - (PTD 170-007) Ted, !a1 See changes to perforations below: Deleted Added Top Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) H-7 ±11,953' ±11,971' ±9,610' ±9,627' WF -4 ±12,156' ±12,184' ±9,794' ±9,819' WF -4 ±12,207' ±12,241' ±9,840' ±9,870' WF -4 ±12,250' ±12,272' ±9,879' ±9,899' Added Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) H-2 ±11,471' ±11,543' ±9,131' ±9,163' Amt 18' 28' 34' 22' Amt 38' III • wP�� //7/" .s THE STATE w . , 9 Alaska it and Gas N� _=__=.� °fl 1L1 1SJ�\1 1 C l ser'va. io Commission L . " • ■:17 STATE OF ALASKA �` d i i ? 1 • ALASKA OIL AND GAS CONSERVATION COMMISSION ,y APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 v 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend El Plug Perforations❑ Perforate E - Pull Tubing E . Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ 'Other. Run ESP ❑. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory El Development E ' 170-007 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic El Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20211-00 " 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 E t, Trading Bay Unit/K-30 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 • McArthur River Field/Middle Kenai G Oil,West Foreland Oil,Hemlock Oil Pools , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,600 10,191 • 12,543 10,139 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 360' 24" 396' 396' Surface 2,151' 13-3/8" 2,187' 2,024' 3,090 psi 1,540 psi Intermediate Production 12,037' 9-5/8" 12,074' 9,713' 6,870 psi 4,750 psi Liner 1,359' 7" 12,575' 10,168' 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic - See Schematic 4-1/2" 12.6#/L-80 9,745' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7"E-line Packer/SSSV N/A Packer 11,750'(MD)7,821'(ND)/SSSV-N/A 12.Attachments: Description Summary of Proposal E . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E . Exploratory ❑ Stratigraphic❑ Development E • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/15/2013 Commencing Operations: Oil E ' Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned El 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 Signature v -�1_ Phone 907 777-8420 Date 11/18/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313 - (..e.oC Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ZSoo1054 13oP & Spacing Exception Required? Yes ❑ No il Subsequent Form Required: /0 / 041 r APPROVED BY Approved by ,� / ` COMMISSIONER THE COMMISSION Date: 7 - IX /•Z.4) •l 3 ?I/46 y (to/l ,.oeir Mk& D �1 1 Submit Form and ■ Form 10-403(Revised 10/2012) Approved R4iGsli o�2[ onths from the date of approval. nemi DualiC 12 ttt • • Well Work Prognosis Well: K-30 Hilcorp Alaska,LLC Application Date: 11/18/2013 Well Name: K-30 API Number: 50-733-20211-00 Current Status: Oil Producer(SI) Leg: Leg#1 (NE corner),Slot#2 Estimated Start Date: December 15,2013 Rig: Moncla Rig 404 V Reg.Approval Req'd? 10-403 Date 10-403 submitted: Regulatory Contact: Juanita Lovett Permit to Drill Number: 170-007 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-30 well is a Shut-in ESP producer.The ESP failed in this well on November 13, 2013. Prior ESP failures were due to scaling and restricted inflow starving the pump.This well was last worked over in May 2 011. The workover plan involves removing a junk packer at 11,750',cleaning out the well to PBTD,and re-perforating. Current Bottom Hole Pressure: 3,514 psi at the Phoenix Gauge(8,000'ND) Maximum Expected BHP: 3,820 psi @ 8,645'ND(top perf)with water gradient of 0.442 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. Pump through ESP to circulate hydrocarbon off the well to production 3. 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). 4. POOH with tubing string and ESP pump laying down the same. 5. PU Workstring. RIH with 9-5/8"clean out assembly to 11,216'. POOH with same. 6. PU RTTS packer.RIH and set at 10,500'(+/-). Pressure test casing to 1,500 psi and chart. it 7. PU 7" 29#C/O assembly and RIH cleaning out 7"casing to top of the junk packer at 11,750'. POOH with Cleanout assembly. 8. Fish junk packer. 9. PU 7"29#C/O assembly and RIH cleaning out 7"casing to PBTD 12,543'. 10. Change hole to clean fluid,PU TCP guns and RIH with same. 11. RU E-line and Run in tubing with GR,CCL and correlate TCP guns on depth. Fire Guns. 12. Pick up guns above perforations. Shut down(+/-) 1 hour monitoring fluid level with Echometer. 13. Once the well is stable,POOH with TCP guns. 14. MU and RIH with ESP Assembly. 15. Hang off tubing. ND BOP,NU wellhead and test. 16. Turn Well over to production 17. RDMO Moncla 404 Pulling unit. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram(No Change) 4. BOP Drawing • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 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,LLC 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 Hileorp Alaska,LLC 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 ioint 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. II • • Moncla R BOP Test Proceig 404 dure Alaska, Attachment#1 HilcorpAlae Diagram A-1: King Salmon BOP stack and Riser Arrangement—Typical for Single Completion o • 1 in ii du iii iii -. ni 3.74' Shaffer 13 5/8 5M rtil BI Itlittli Cu til . a.- ii s Clw-U 'r _ 0 or- __ Variable 27/8-5 4.67' 7 � . _ i^ 13 5/8 411 5000 'lII ....6 Blind Rams III III III lil lit Choke and Kill Valves 21/16 SM w/Unibolt connections for hoses �. i III IPI Ill I fl III - , ` I, Ilie ' 0 I ' - '`i- • lit Iii lit lit tic `f i ID III III ill l!l Riser,13 5/8 5M FE X 13 5/8 5M API#13 hub 13.70' • 0 II Moncla Ri g 404 BOP Test Procedure Hilcorp Alaska,LLC 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 NOM Ill �, - - \ 2 � c=0)13 ' • alai \ t•Ils II] Chokes are 90 degrees off VvVV in drawing in order to show /' 1 detail _ - .II ' - :1 1 ' E'r4II I lit .161- 1-610 Lill me iu Swaco ,,M, -161 ill III6111 I' II ::1 I ma Ili w � Ill' . III III ®II From Bop Choke Line 2 1/16 5M Unbolt Flange Valve Type #1 National Ball Valve B3260, 3 '/4' 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 B2650, 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 B2650, 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 Hilrnrp Alaska,LLC Attachment#1 u fJq V w z 11 1 Q. = 4 10 1HZ: = O.II II:X Ellifili a_ m� a-. . d - p� Q LL •U • 20 m _ z � c OC H v� U O a_ ,1 — � WUU ca 4a ► CC cL 5 C O O J U Q O O o 2 a Dz 5 a CD I1I J OZw z ! LL u � ct Q = J U a U • • II Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 u • 22 a u D4 I. 1 2 z__, 7,,a ,i � J Z <Y - 1 i n H t 01 It:1 it t Q�_ a -— O(4 d m, N a III 0 z a .... c.n .•-• fa a i. (j) -. A m Q J Z • Z Z 0 U o --+1 M o ao I 0 i= a d •11wo--yo0QQ cr W 0- 5n- - z 0 0 m 0 ,LQI— LU cl w S J(r)J D AI J 012 O i s LL z p O z I J D 0 CY U ., • • 1 II King Salmon Platform SCHEMATIC Well K-30 Last Completed 5-27-2011 Hilcorp Alaska,LLC Casing and Tubing Detail Size Type Wt/ TOP BTM CONN/ID Cement/ Grade Other RKB:100'AMSL ' KB••THF:33.76'KB 24" Conductor 94/H40 36.4 396' Welded/19" Driven 13-3/8" Surface 61/K55 36.4 2187 BTC/12.515" / 9-5/8" Intermediate 47/N80 36.4 10092' BTC/8.681" ® 9-5/8" Intermediate 47/P110 10092 12074' BTC/8.681" -24"@ 396' • 7" Liner 29/L80 11216 12575 BTC-KC/ 6.184" Tubing Hydril 563 4-1/2" Prod Tubing 12.6/L80 Surf 1707 SCC 260 Joints(New) 4-1/2" Prod Tubing 12.6/L80 1707' 9745' Hydril 503 50 Joints(New) Jewelry Details # (RKB) Length (Drift) OD Item 13-318"@ 2161' 33.8' 1 3.958" FMC Hanger Type"H",4-1/2"IBT Top and BTM X-Over-(4-1/2"IBT P x 4-1/2"Hydril 503 P) 1707' 3.883 4.5"" 4-1/2"L80,Hydril 503 Tubing 2784' 8.98' 3.833" 7.063' 4-1/2"GLM#7,IBT w/Hydril 563 Pups 4574' 8.97' 3.833" 7.063' 4-1/2"GLM#6,IBT w/Hydril 563 Pups e 5758' 6926' 8.98' 3.833" 7.063' 4-1/2"GLM#5,IBT w/Hydril 563 Pups 8.97' 3.833" 7.063' 4-1/2"GLM#4,IBT w/Hydril 563 Pups 7683' 8359' 9057' 9750' 8.77' 3.833" 7.063' 4-1/2"GLM#3,IBT w/Hydril 563 Pups 8.98' 3.833" 7.063" 4-1/2"GLM#2,IBT w/Hydril 563 Pups 8.98' 3.833" 7.063" 4-1/2"GLM#1,IBT w/Hydril 563 Pups 4.33' 3.813" 3.810" 4-1/2"SSD Sliding Sleeve 9798' 1.22' 3.725" 3.725" 4-1/2""XN"Profile Nipple 9851' 1.45' 3.830" 5.220" X-over to ESP Equipment 9852' 120.39' ND 5.650" Centralift ESP:Motor,Pump and Assembly 9911' ND 5.630" Centralift ESP:Pump Intake 9973' ND 8.00" Phoenix&w/4 Anodes Bull nose Assy TOC:9600' 11,750' 3.9 6.184" E-Line set Packer • Perforation Detail Top Btm Top Btm (Lt..' Zone (MD) (MD) (TVD) (TVD) Amt Status j (b G-06 10,802' 10,830' 8,644' 8,665' 28' Sqzd L �JJ G-0i 10,870' 10,894' 8,696' 8,714' 24' Open 0-02 10,920' 10,945' 8,734' 8,754' 25' Open z�_ G-02 10,954' 10,994' 8,761' 8,792' 40' Open G-03 11,018' 11,050' 8,811' 8,836' 32' Open G-04 11,064' 11,129' 8,847' 8,897' 65' Open G-05 11,194' 11,224' 8,949' 8,973' 30' Open G-05 11,232' 11,268' 8,979' 9,008' 36' Open H-1 11,412' 11,472' 9,125' 9,177' 60' Open H-2 11,495' 11,590' 9,197' 9,280' 95' Open H-3 11,605' 11,650' 9,293' 9,333' 45' Open I 0-6 1,2,3 H-4 11,651' 11,720' 9,334' 9,396' 69' Open H-5 11,780' 11,790' 9,450' 9,459' 10' Open TOL.1121 -3,4 H-5 11,798' 11,820' 9,466' 9,485' 22' Open tsqeeze @ 11327'� 5 H-6 11,876' 11,964' 9,536' 9,614' 88' Open -1/G7 H-7 11,964' 11,988' 9,614' 9,636' 24' Open WF-1 12,008' 12,014' 9,654' 9,659' 6' Open � Q -2 WF-1 12,021' 12,026' 9,666' 9,670' 5' Open '' s. -3 WF-2 12,030' 12,050' 9,674' 9,692' 20' Open ' -4 WF-2 12,055' 12,068' 9,696' 9,708' 13' Open PKR:11750' •ti WF-2 12,081' 12,105' 9,720' 9,741' 24' Open Isolation Squeze -5,6,7 WF-4 12,155' 12,184' 8,787' 9,813' 29' Open 11985-11986 WF-4 12,208' 12,212' 9,834' 9,838' 4' Open WF-4 12,229' 12,241' 9,853' 9,864' 12' Open F-6,7 WF-4 12,258' 12,265' 9,880' 9,886' 7' Open WF-4 12,268' 12,272' 9,889' 9,893' 4' Open TD=12600' PBTD=12543' ' WF-6 12,360' 12,408' 9,973' 10,016' 48' Open WF-7 12,468' 12,480' 10,071' 10,082' 12' Open Directional Data: WF-7 12,500' 12,551' 10,100' 10,147' 51' Open max=42.5° at 6237' Updated by:JLL 11/18/13 • • King Salmon Platform PROPOSED Well K-30 Last Completed 5-27-2011 Hilcorp Alaska,LL(: Casing and Tubing Detail Size Type wt/ TOP BTM CONN/ID Cement/ RKB:100'AMSL Grade Other KB-THF:33.75'KB ' 24" Conductor 94/H40 36.4 396' Welded/19" Driven Ai w-- = , \ / r I 13-3/8" Surface 61/K55 36.4 2187 BTC/12.515" 9-5/8" Intermediate 47/N80 36.4 10092' BTC/8.681" 9-5/8" Intermediate 47/P110 10092 12074' BTC/8.681" 24"@ 396' BTC-KC/ 7" Liner 29/180 11216 12575 6.184" Tubing ±1707' Hydril 563 260 Joints(New) 4-1/2" Prod Tubing 12.6/180 Surf SCC 4-1/2" Prod Tubing 12.6/1.80 1707' ±9850' Hydril 503 50 Joints(New) A U Jewelry Detail 13-3/8"@ 2151' No. Depth ID OD Item 33.8' 3.958" FMC Hanger Type"H",4-1/2"IBT Top and BTM 1 ±9,850 Top of pump 2 ±9,911 Pump Intake 3 ±9,935 Top of motor 4 ±9,973 Bottom of GLM Anode Perforation Detail Top Top Zone (MD) Btm(MD) (ND) Btm(ND) Amt Status G-o6 10,802' 10,830' 8,644' 8,665' 28' Sqzd G-1. 10,870' 10,894' 8,696' 8,714' 24' Open G-1 ±10,870' ±10,895' ±8,702' ±8,721' ±25' Future G-2 ±10,920' ±10,945' ±8,734' ±8,754' ±25' Future/Open 6-2 10,954' 10,994' 8,761' 8,792' 40' Open G-2 ±10,955' ±10,994' ±8,768' ±8,798' ±39' Future TOC.9600' G-3 11,018' 11,050' 8,811' 8,836' 32' Open G-3 ±11,022' ±11,040' ±8,820' ±8,834' ±18' Future G-4 11,064' 11,129' 8,847' 8,897' 65' Open G-4 ±11,073' ±11,114' ±8,860' ±8,892' ±41' Future 0-5 11,194' 11,224' 8,949' 8,973' 30' Open G-5 ±11,200' ±11,222' ±8,959' ±8,977' ±22' Future G-5 ±11,232' ±11,264' ±8,985' ±9,010' ±32' Future 1 ® 6-5 11,232' 11,268' 8,979' 9,008' 36' Open G-6 ±11,323' ±11,357' ±9,058' ±9,086' ±34' Future 2 r UJ J H-1 ±11,412' ±11,450' ±9,131' ±9,163' ±38' Future 3 j1''°,4' H-1 11,412' 11,472' 9,125' 9,177' 60' Open H-2 11,495' 11,590' 9,197' 9,280' 95' Open 4 H-3 311,554' ±11,625' ±9,254' ±9,317' ±71' Future H-3 11,605' 11,650' 9,293' 9,333' 45' Open 1-1-4 ±11,625' ±11,726' ±9,317' ±9,407' ±101' Future H-4 11,651' 11,720' 9,334' 9,396' 69' Open H-5 ±11,754' ±11,837' ±9,432' ±9,507' ±83' Future 1-6 H-5 11,780' 11,790' 9,450' 9,459' 10' Open H-5 11,798' 11,820' 9,466' 9,485' 22' Open G-1 2,3 11-6 11,876' 11,964' 9,536' 9,614' 88' Open H-6 ±11,882' ±11,935' ±9,547' ±9,594' ±53' Future TOL.11216' G-3,4 iy, H-7 ±11,953' ±11,971' ±9,610' ±9,627' ±18' Future Isolation squeeze -5 i(/ H-7 11,964' 11,988' 9,614' 9,636' 24' Open 11985-11986 = WF-1 ±12,008' ±12,014' ±9,654' ±9,659' ±6' Future/Open HB-1 WF-1 ±12,021' ±12,026' ±9,666' ±9,670' ±5' Future/Open 9-5/8"@ 11327' WF-2 12,030' 12,050' 9,674' 9,692' 20' Open = B-2 WF-2 ±12,032' ±12,040' ±9,682' ±9,689' ±8' Future -HB-3 WF-2 12,055' 12,068' 9,696' 9,708' 13' Open WF-2 12,081' 12,105' 9,720' 9,741' 24' Open - HB-4 WF-3 ±12,082' ±12,105' ±9,727' ±9,747' ±23' Future WF-4 12,155' 12,184' 8,787' 9,813' 29' Open Isolation Squeeze HB-5,6,7 WF-4 ±12,156' ±12,184' ±9,794' ±9,819' ±28' Future 11985-11986 -.- WF-4 ±12,207' ±12,241' ±9,840' ±9,870' ±34' Future WF-3,4,5 WF-4 12,208' 12,212' 9,834' 9,838' 4' Open WF-6,7 WF-4 12,229' 12,241' 9,853' 9,864' 12' Open WF-4 ±12,250' ±12,272' ±9,879' ±9,899' ±22' Future TD=12600' PBTD=12543' WF-4 12,258' 12,265' 9,880' 9,886' 7' Open WF-4 12,268' 12,272' 9,889' 9,893' 4' Open WF-5 ±12,282' ±12,344' ±9,908' ±9,964' ±62' Future Directional Data: WF-6 12,360' 12,408' 9,973' 10,016' 48' Open max=42.5° at 6237' WF-6 ±12,360' ±12,411' ±9,979' ±10,025' ±51' Future WF-7 12,468' 12,480' 10,071' 10,082' 12' Open WF-7 12,500' _ 12,551' 10,100' 10,147' 51' Open Updated by:la 11/18/13 , _ 1 • is . , ll King Salmon Platform K-30 Current 11/14/2013 Hihnrp:%Inak■,l.lA King Salmon BHTA, B-11-A0,4 1/16 5M FE Tbg hanger, OCT-UH-TC- K-30 1A-ESP, 13 X 4% IBT lift 24 X 13 3/8 X 9 5/8 X 4'/2 r R ) and susp,w/4"Type H 111111 ■�1 ��■� BPV profile, 3/8 cont control line port Valve, Swab,WKM-M,4 1/16 ""111;411n1 5M FE, HWO, EE trim ,c�� c �""' ° • Valve,Wing, OCT-120,3 1/8 5M % am MEE ma FE,w/Axelson AM oper, EE trim Valve, Wing,AOP, 2 1/16 5M \ FE, HWO,AA trim \e 1111 ' �' LI II mg mo.nonem 1.14(11 to Valve, Master,WKM-M,4 1/16 �- r�.r 5M FE, HWO, EE trim —\( `... J r v uu I !T:; Void test good _ Valve,Wing, CIW-FL, 3 1/8 5M FE, 5/12/2010 '' HWO, EE trim 250/5000psi • A� �� Adapter, OCT-A5-ESP, 13 5/8 5M I API hub X 4 1/16 5M stdd top,w/2- �� �_ IIr '/2 control line exits, prepped w/OCT I= • ' : =1 400-4 pocket c _ 0 1111 i`�� ..- ,,,,_ . i #1 E iU= III: All unihead annular valves, Unihead, OCT type 3, 13 5/8 5M , �_, 2 1/16 5M FE OCT 20, API hub top X 13 3/8 BTC casing IPA I=� � (►� `� 10..'.. HWO bottom,w/1-2 1/16 5M SSO on l="� -� ,�=� :oil r lower section, 1-2 1/16 5M SSO :'.. _ -.,. 4 Void test good on middle section, 3-2 1/16 5M .M. '0a 5/12/2010 SSO on upper section , IP 1 i ' ? 250/3500psi internal lockpin assy - rel 12"1. ° W'�i� _ `V7�: Valve, OCT-20, 3 1/8 2M Il I► sr∎ ip FE, HWO Starting head, OCT,21 '/4 2M iJ�„ �,.;, FEX24" SOW, w/1 31/82M =-�•v iA : EFO,full set of lockpins I �� . 13 3/8" 9 5/8" 4'/z" • • King Salmon Platform 2013 BOP Stack(Moncla) 09/19/2013 111 1►rorp Ua4.a.1.1.{. ill Iii lilt 111 lit lii Ill Il I 3.74' Shaffer ,,. 135/8SM III III III ill iii III I!I I!I I!I Ili CIW-U _ Variable 27/8-5 4.67' _ • rf 13 5/8-5000 _- -I �= Blind Rams Ili Iii Ill III Iii Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses �. Ill ICI III III III _ 2.00' 51111 1[4. - - I f1 I .�' iii lit Ill iii Iii III 1►I III III III Riser,13 5/8 5M FE X 13 5/8 5M API 413 hub 13.70' i s' .., _, -. ... 'a".., ,.6 . • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION '" "ry a ,. REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon 0 Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other ❑ Performed: Alter Casing ❑ ' Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Qperat. Shutdown❑ Stimulate - Other El Re -enter Suspended WOO 1 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development IS Exploratory ❑ 170-007 • I 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20211 -00 — 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 . Trading Bay Unit / K -30 - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . McArthur River Field / Middle Kenai G Oil, West Foreland Oil, Hemlock Oil Pools 11. Present Well Condition Summary: Total Depth measured 12,600 feet Plugs measured N/A feet true vertical 10,191 feet Junk measured N/A feet Effective Depth measured 12,543 feet Packer measured 11,750 feet true vertical 10,139 feet true vertical 9,423' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 360' 24" 396' 396' Surface 2,151' 13 -3/8" 2,187' 2,024' 3,090 psi 1,540 psi Intermediate Production 12,037' 9 -5/8" 12,074' 9,713' 6,870 psi 4,750 psi Liner 1,359' 7" 12,575' 10,168' 7,240 psi 5,410 psi Perforation depth Measured depth 10,802' - 12,480' feet SCANNED APR 1 9 2 O 1 3 True Vertical depth 8,644' - 10,082' feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 9,745' (MD) 7,821' (TVD) Packers and SSSV (type, measured and true vertical depth) 7" E -line Packer 11,750' (MD) 9,423' (TVD) SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Pumped 4500 gallons (107 bbls) 15% Hydrochloric acid bullheading into formation. Pumped 81 bbls FIW for displacement, Shut -in well for 6 hour soak. Brought well back on to production. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 50 35 855 55 50 Subsequent to operation: 45 35 1520 80 85 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: „ Oil El 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: 313 -087 Contact Ted Kramer Email tkramer @hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer / Signature / // 7� Phone 907- 777 -8420 Date 3/18/2013 Form 10-404 Revised 10/2012 R8 DMS MAR 19 2013 f j // q./ y , Submit Original Only • • Hilcorp Alaska, LLC Hi!cog),11a„ka. Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date K -30 50- 733 - 20211 -00 170 -007 2/24/2013 2/25/2013 Daily Operations: 02/24/13 - Sunday Fly to platform, Complete Permit to Work, Rig -up injection pump, sent NPF to TBay, Pressure Test passed, mixed 206 bbls Preflush, Begin pumping FIW down tubing. Returns routed to separator Casing Full - Returns at Separator, total 326 bbls pumped, Started pumping 150 bbls of Preflush, Finished pumping 150 bbls and closed 9 5/8 casing bullheading the remaining 56 bbls of Preflush, Pumped 4500 gallons (107 bbls) 15% Hydrochloric Acid bullheading into formation, Pumped 81 bbls FIW for displacement, Shut -in Well for 6 hour Soak 02/25/13 - Monday Complete 6 hour acid soak, Complete Permit to Work, Issues with one tote of SCW -4004, Pulled fluid from top of tote and finished mixing Scale Inhibitor pill, Pumped the 157 bbl Scale Inhibitor Pill, Pumped 1400 bbl FIW at a 2.5 BPM Rate then S/I well for 12 hours Sent NPFF to Tbay • • 1 King Salmon Platform SCHEMATIC Well K -30 Last Completed 5 -27 -2011 Hilcorp Alaska, LLC RKB: 100' AMSL KB -THF: 33.76' KB Casing and Tubing Detail z NNW Wt/ Cement/ Size Type Grade TOP BTM CONN / ID Other . 24" Conductor 94/ H40 36.4 396' Welded/ 19" Driven 24" @ 396' i ;y 13 -3/8" Surface 61/ K55 36.4 2187 BTC/ 12.515" 9 -5/8" Intermediate 47/ N80 36.4 10092' BTC/ 8.681" "+ 9 -5/8" Intermediate 47/ P110 10092 12074' BTC / 8.681" 7" Liner 29/L80 11216 12575 BTC-KC/ ti Tubing 4 -1/2" Prod Tubing 12.6/ L80 Surf 1707 Hy SrCIC563 260 Joints (New) A IL 4 -1/2" Prod Tubing 12.6/ L80 1707' 9745' Hydril 503 50 Joints (New) 13.3/8" @ 2161' Jewelry Details # (RKB) Length (Drift) OD Item 33.8' 1707' ID 1 3.958" FMC Hanger Type "H ", 4 -1/2" IBT Top and BTM X -Over — (4 -1/2" IBT P x 4 -1/2" Hydril 503 P) I 3.883 4.5' 4 -1/2" 180, Hydril 503 Tubing 2784' 4574' 5758' 8.98' 3.833" 7.063' 4 -1/2" GLM #7, IBT w/ Hydril 563 Pups 8.97' 3.833" 7.063' 4 -1/2" GLM #6, IBT w/ Hydril 563 Pups 8.98' 3.833" 7.063' 4 -1/2" GLM #5, IBT w/ Hydril 563 Pups 6926' 8.97' 3.833" 7.063' 4 -1/2" GLM #4, IBT w/ Hydril 563 Pups 7683' 8.77' 3.833" 7.063' 4 -1/2" GLM #3, IBT w/ Hydril 563 Pups 8359' 8.98' 3.833" 7.063" 4 -1/2" GLM #2, IBT w/ Hydril 563 Pups I 9057' 8.98' 3.833" 7.063" 4 -1/2" GLM #1, IBT w/ Hydril 563 Pups 9750' 4.33' 3.813" 3.810" 4 -1/2" SSD Sliding Sleeve TOC: 9600' 9798' 1.22' 3.725" 3.725" 4 -1/2" "XN" Profile Nipple 9851' 1.45' 3.830" 5.220" X -over to ESP Equipment 9852' 120.39' ND 5.650" Centralift ESP: Motor, Pump and Assembly 9911' ND 5.630" Centralift ESP: Pump Intake I 9973' ND 8.00" Phoenix & w/ 4 Anodes Bull nose Assy 11,750' 3.9 6.184" E -Line set Packer Perforation Data *; - ZONE TOP BTM SPF AMT Condition 6-06 DST 10802' 10830' 4.5 28 4/70, Sqz'd after DST 6-1 10865' 10895' 24.5 30 4/70,7/78, 3/88, 11/90, 2/02 G -2 10920' 10945' 24.5 25 4/70,7/78, 3/88, 11/90, 2/02 0 - 6 G -2 10955' 10945' 24.5 39 4/70,7/78, 3/88, 11/90, 2/02 6-3 11004' 11050' 29.5 46 4/70,7/78, 3/88, 11/90,2/02,9/07 0 2, 3 G-4 11056' 11130' 24.5 74 4/70, 7/78, 3/88, 11/90, 2/02, 9/07 . 6-5 11195' 11224' 24.5 29 4/70, 7/78, 3/88, 11/90, 2/02 TOL: 11216' G - 4 6-5 11232' 11268' 24.5 36 4/70, 7/78, 2/02 Isolation Squeeze G - HB -1 11422' 11454' 11 32 'Feb 2002, 9/07 11985 . 9 @ 11327' HB -2 11477' 11572' 5 95 Sept '07 1 HB -3 11586' 11627' 5 41 Sept '07 HB - 16-3 11636' 11702' 11 24 'Feb 2002, 9/07 HB-4 11660' 11720' 11 42 'Feb 2002, 9/07 HB - HB-4 11700' 11790' 6 20 'Feb 2002 HB HB -5 11780' 11820' 6 10 'Feb 2002 PKR: 11,750' 18 -5 11799' 11930' 6 21 'Feb 2002 H B - 5, 6, 7 HB -6 11880' 11975' 6 50 'Feb 2002 11985-11986 ya , Squeeze Isolation S . HB -7 11960' 11975' 6 15 'Feb 2002 8 WF - 3,4,5 WF -3 12005' 12070' 20.5 65 4/70, 2/79, 11 /80, 3/88, 11/90 WF -6, 7 WF-4 12082' 10105' 20.5 23 4/70, 2/79, 11 /80, 3/88, 11/90 ien,,,,p WF-4 12144' 12190' 12.5 46 4/70, 3/88 TD = 12600' PBTD = 12543' WF-4 12200' 12245' 16.5 45 4/70, 2/79, 11/80, 3/88, 11/90 WF -5 12250' 12350' 8.5 100 4/70,3/88 WF -6 12360' 12413' 8.5 53 4/70, 2/79, 11/80, 3/88, 11/90 Directional Data: WF -7 12468' 12480' 4.5 12 'April 1970 max = 42.5° at 6237' Updated by: JLL 02/15/13 OF 7,11,_ • • I % %s . THE STATE Alaska Oil and Gas (. ��► ��� OJl 1Ll SKA - _ Conservation Commission GOVERNOR SEAN PARNELL 0 333 West Seventh Avenue ALAS Anchorage, Alaska 99501 -3572 Main: 907.279.1 433 Fax: 907.276.7542 1 q � Ted Kramer NHE° BAR Sr. Operations Engineer Q °° Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G, West Foreland, and Hemlock Oil Pool, Trading Bay Unit K -30 Sundry Number: 313 -087 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this day of February, 2013. Encl. • III RECEIVED � 013 STATE OF ALASKA 0-i L z2 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1. Type of Request: Abandon Cl Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend El Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown CI Re-enter Susp. Well CI A c. cLtimulate El Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development J . 170 -007' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20211 -00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay Unit / K -30 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0017594 - McArthur River Field / Middle Kenai G Oil, West Foreland Oil, Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): . 12,600 10,191 ' 12,543 10,139 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 360' 24" 396' 396' Surface 2,151' 13 -3/8" 2,187' 2,024' 3,090 psi 1,540 psi Intermediate Production 12,037' 9 -5/8" 12,074' 9,713' 6,870 psi 4,750 psi Liner 1,359' 7" 12,575' 10,168' 7,240 psi 5,410 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 010,802' - 12,480' 8,644' - 10,082' 4 -1/2" 12.6# / L -80 9,745' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): 7" E -line Packer / SSSV N/A Packer 11,750' (MD) 7,821' (ND) / SSSV - N/A 12. Attachments: Description Summary of Proposal El , 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/28/2013 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 tkramerta7.hilcorp.com Printed Name Tedd Kramer Title Sr. Operations Engineer � Signature ; ( `� �� " Phone 907 777 -8420 Date 2/18/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �) —^ Yvl 3.7 Plug Integrity ❑ BOP Test CI Mechanical Integrity Test CI Location Clearance ❑ Other: RBDMS FEB 252O13 Y-k Spacing Exception Required? Yes ❑ No lid Subsequent Form Required: l b _ YQ Lit APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2. _z a _is ubmit Form and ‘k° \N ') ()Tlt:14 etiso/ GL Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,�'�� • • Well Work Plan Well: K -30 Hilcorp Alaska, Lb Date: 02/19/2013 Well Name: K -30 API Number: 50- 733 - 20110 -00 Current Status: ESP Lifted Producer Leg: Leg 1, NE Corner Slot #2 Estimated Start Date: February 25, 2013 Rig: N/A Reg. Approval Req'd? February 19, 2013 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 170 -007 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: Current Bottom Hole Pressure: 1,007 psi at the Phoenix Gauge (8,000' TVD) Maximum Expected BHP: 3,102 psi @ 8,000' TVD from 12 -2 -2012 Well shut in. Max. Allowable Surface Pressure: 2,000 psi pump pressure limit setting. Well Summary The K -30 is an oil well producer which is currently on ESP artificial lift. Total fluid production from this well decreased from 1,900 BTFPD on 4/20/2012 to 252 BTFPD on 1/1/2013. This decrease is believed to have been caused by scale formation in the well bore and perforation tunnels. On February 4 2013, an acid soak was performed in attempt to dissolve this scale. The well responded to the treatment and produced fluid increased post job to 948 BTFD on 2/13/13. Well Objective Hilcorp believes that the February 4 2013 helped the well but that near well bore scale is still impeding inflow into the wellbore. Hilcorp plans to pump a second acid soak down the production tubing but this time pump it into the formation as well. This acid will be followed by a scale squeeze into the formation to clean up additional scale and protect the well from future scale formation. Procedure: 1. MIRU pumping equipment. 2. Shut down ESP. 3. Pressure test surface lines to 2,000 psi. 4. Mix chemicals and pump in the following sequence: • • Well Work Plan Well: K -30 Hilcorp Alaska, LL Date: 02/19/2013 a. Open back side, pump FIW down tubing until returns are received up the annulus. b. Pump 150 bbls. of pre -flush. c. Close the 9 -5/8" casing return line and pump 56 bbls. of preflush into the formation. d. Pump 4,500 gals. Of 15% HCL bull heading into formation followed by 81 bbls. of FIW for displacement. e. Shut down pump and let acid soak for 6 hours. f. Mix and pump 157 bbl scale inhibitor pill followed by 1,400 bbls. FIW overflush. 5. Shut in well for 12 hours. 6. RD Pumping equipment. 7. Return well to production. Attachments: 1. As -built Schematic + • 0 II King Salmon Platform SCHEMATIC Well K -30 Last Completed 5 -27 -2011 Hilcorp Alaska, LLC RKB: 100' AMSL ■ KB -THF: 33.75' KB Casing and Tubing Detail Size Type G W t d e TOP BTM CONN / ID Cement Other / 24" Conductor 94/ H40 36.4 396' Welded/ 19" Driven 24" @ 398 13 -3/8" Surface 61/ K55 36.4 2187 BTC/ 12.515" 9 -5/8" Intermediate 47/ N80 36.4 11216 10092' BTC/ 8.681" + 9 -5/8" Intermediate 47/ P110 10092 12074' BTC/ 8.681" 7" Liner 29/ L80 12575 6.184 " / Tubing 4 -1/2" Prod Tubing 12.6/ 180 Surf 1707 Hy SrCC 563 260 Joints (New) 4 -1/2" Prod Tubing 12.6/ 180 1707' 9745' Hydril 503 50 Joints (New) 13- 318" @ 2151' I Depth Jewelry Details # (RKB) Length (Drift) 00 Item I 33.8' 1 3.958" FMC Hanger Type "H ", 4 -1/2" IBT Top and BTM X -Over — (4 -1/2" IBT P x 4 -1/2" Hydril 503 P) 1707' 3.883 4.5 "" 4 -1/2" L80, Hydril 503 Tubing II 2784' 8.98' 3.833" 7.063' 4 -1/2" GLM #7, IBT w/ Hydril 563 Pups 4574' 8.97' 3.833" 7.063' 4 -1/2" GLM #6, IBT w/ Hydril 563 Pups 5758' 8.98' 3.833" 7.063' 4 -1/2" GLM #5, IBT w/ Hydril 563 Pups 6926' 8.97' 3.833" 7.063' 4 -1/2" GLM #4, IBT w/ Hydril 563 Pups 7683' 8.77' 3.833" 7.063' 4 -1/2" GLM #3, IBT w/ Hydril 563 Pups 8359' 8.98' 3.833" 7.063" 4 -1/2" GLM #2, IBT w/ Hydril 563 Pups 9057' 8.98' 3.833" 7.063" 4 -1/2" GLM #1, IBT w/ Hydril 563 Pups 9750' 4.33' 3.813" 3.810" 4 -1/2" SSD Sliding Sleeve TOO: 9600' I 9798' 1.22' 3.725" 3.725" 4 -1/2" "XN" Profile Nipple I 9851' 1.45' 3.830" 5.220" X -over to ESP Equipment 9852' 120.39' ND 5.650" Centralift ESP: Motor, Pump and Assembly 9911' ND 5.630" Centralift ESP: Pump Intake 9973' ND 8.00" Phoenix & w/ 4 Anodes Bull nose Assy 11,750' 3.9 6.184" E -Line set Packer X4 Perforation Data ir ZONE TOP BTM SPF AMT Condition G -06 DST 10802' 10830' 4.5 28 4/70, Sqz'd after DST .�� 0-1 10865' 10895' 24.5 30 4/70,7/78, 3/88, 11/90, 2/02 0-2 10920' 10945' 24.5 25 4/70,7/78, 3/88, 11/90, 2/02 0 - 6 0-2 10955' 10945' 24.5 39 4/70, 7/78, 3/88, 11/90, 2/02 6-3 11004' 11050' 29.5 46 4/70, 7/78, 3/88, 11/90, 2/02, 9/07 r G - 2, 3 6-4 11056' 11130' 24.5 74 4/70, 7/78, 3/88, 11/90, 2/02, 9/07 ?. .. 6-5 11195' 11224' 24.5 29 4/70, 7/78, 3/88, 11/90, 2/02 TOL: 11216' G - 4 6-5 11232' 11268' 24.5 36 4/70, 7/78, 2/02 Isolation Squeeze °w G - HB -1 11.422' 11454' 11 32 'Feb 2002, 9/07 11985.11986 ^� 9-5/8" ig 11327' HB -2 11477' 11572' 5 95 Sept'07 3 H8 - 1/07 HB -3 11586' 11627' 5 41 Sept '07 L I HB - 2 FIB-3 11636' 11702' 11 24 'Feb 2002, 9/07 HB-4 11660' 11720' 11. 42 'Feb 2002, 9/07 AV. HB HB-4 11700' 11790' 6 20 'Feb 2002 HB HB -5 11780' 11820' 6 10 'Feb 2002 PKR: 11,750' HB -5 11799' 11930' 6 21 'Feb2002 Isolation Squeeze � ' HB 6, 7 HB -6 11880' 11975' 6 50 'Feb 2002 11985 .tit ..i HB -7 11960' 11975' 6 15 'Feb 2002 VW - 3,4,5 WF -3 12005' 12070' 20.5 65 4/70, 2/79, 11/80, 3/88, 11/90 s WF - 7 WF-4 12082' 10105' 20.5 23 4/70, 2/79, 11 /80, 3/88, 11/90 ;,ir WF-4 12144' 12190' 12.5 46 4/70, 3/88 TD = 12600' PBTD - 12543' WF-4 12200' 12245' 16.5 45 4/70, 2/79, 11/80, 3/88, 11/90 WF -5 12250' 12350' 8.5 100 4/70, 3/88 WF -6 12360' 12413' 8.5 53 4/70, 2/79, 11/80, 3/88, 11/90 Directional Data: WF -7 12468' 12480' 4.5 12 'April 1970 max = 42.5 at 6237' Updated by: .ILL 02/15/13 • • SEAN PARNELL, GOVERNOR smIRE ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 August 31, 2011 PHONE (907) 279 -1433 g FAX (907) 276 -7542 Mr. Chris Myers Field Superintendent Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519 RE: No -Flow Verification Trading Bay Unit K -30 McArthur River Field . F I + PTD 1700070}!;; Dear Mr. Myers: On July 6, 2011 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a "no flow test" of Trading Bay Unit K-30 located on the King Salmon Platform in Cook Inlet. The well is operated by Union Oil Company of California (Union). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail -safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. Union recently completed a workover on Trading Bay Unit K -30 to replace the downhole electric submersible pump. The AOGCC Inspector confirmed that Union verified no obstruction exists in the wellbore. Trading Bay Unit K -30 was monitored 3 hours for flow by opening it to atmosphere through flow measurement equipment with suitable range and accuracy. During the flow monitoring period, the maximum gas flow rate measured on the calibrated flow meter was 190 standard cubic feet per hour. Total liquid production was less than 1 gallon. The subsurface safety valve must be returned to service if Trading Bay Unit K -30 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, j a,tit(0, b James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Re E3 1 2 i DATE: July 6, 2011 P.I. Supervisor I FROM: Jeff Jones SUBJECT: No -Flow Test Petroleum Inspector Unocal / King Salmon PLT K -30 .x t 1 P $`, .1 ! ? i PTD- 1700070 - Trading Bay Unit July 6, 2011: I traveled to Unocal's King Salmon Platform in Cook Inlet to witness a No -Flow Test on well K -30. On my arrival on the platform I met with Unocal Lead Operator Wayne Johnson and we discussed the operational details of the test. Mr. Johnson indicated that the well pressure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Unocal representative Greg McGahan performed the test today in a safe and proficient manner. Well K -30 has an electric submersible pump (ESP) installed and was lined up from the tree top swab valve through an Armor -Flow model # 3461 -03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test and as the data below indicates, well K -30 meets the AOGCC requirements for a No -Flow status determination. Summary: I witnessed a successful No -Flow Test on Unocal's Trading Bay Unit well K -30 on the King Salmon Platform. Well No -Flow Test Data Operator: Union Oil Co. Operator Rep: Greg McGahan/Wayne Johnson AOGCC Rep: Jeff Jones Field /Unit/Pad TBU / King Salmon PLT Well: K -30 Time, Well Flow Comments Gas Liquid 8:00 180 scfh < 1 cup Start Test 8:30 190 scfh < 1 cup 9:00 190 scfh < 1 cup 9:30 180 scfh < 1 cup 10:00 180 scfh < 1 cup 10:30 180 scfh < 1 cup 11:00 180 scfh < 1 gallon during entire test ' End Test Produced to open top container through a new Armor -Flow meter model #3461- 03T0 -13 ser. # 112377 Total liquid produced: less than 1 gallon. - This well has an ESP (electric submersible pump) installed. Attachments: none RJF 09/19/02 Page 1 of 1 2011 -0706 No- Flow_TBU_K -30 jj.xls STATE OF ALASKA 41-71?-oil ALASKAWAND GAS CONSERVATION COMMISSIOW REPORT OF SUNDRY WELL OPERATIONS 1. Abandon 11 Repair Well U Plug Perforations U Stimulate Lf Other U ESP Repair ' Alter Casing ❑ Pull Tubing 0 / Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 170 -007 ' 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20211 -00 .-. 0 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 (King Salmon Platform) - Trading Bay Unit K -30 9. Field /Pool(s): McArthur River Field / Middle Kenai G Oil, Hemlock Oil, West Foreland Oil Pools 10. Present Well Condition Summary: Total Depth measured 12,600 feet Plugs measured N/A feet true vertical 10,191 feet Junk measured N/A feet Effective Depth measured 12,543 feet Packer measured 11,750 feet true vertical 10,139 feet true vertical 9,422' feet Casing Length Size MD TVD Burst Collapse Structural 'Vet 064 l Conductor 360' -24' 396' 395' Surface 2,151' 13 -3/8" 2,187' 2,024' 3,090psi 1,540psi Intermediate Production 12,037' 9 -5/8" 12,074' 9,713' 6,870psi 4,750psi Liner 1,359' 7" 12,575' 10,168' 7,240psi 5,410psi Perforation depth Measured depth See Schematic X10 JUN True Vertical depth See Schematic UN a 1 e Tubing (size, grade, measured and true vertical depth) 4 -1/2" / 12.6 #, L -80 9,745' MD 7,821' Packers and SSSV (type, measured and true vertical depth) 7" E -line Packer / N/A RECEIVED 11,750' MD ( 9,422' TVD) / N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): AN el 6 11i i N/A Treatment descriptions including volumes used and final pressure: N/A iltiaska Oil rrtiA Cfttts. G' Ii mission 12. Representative Daily Average Production or Injection Data ti {-r.I' Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 336 194 4888 50psi 60psi Subsequent to operation: 142 88 2358 . 55psi 60psi 13. Attachments: N/A 14. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 ., Service ❑ Stratigraphic0 Daily Report of Well Operations Y 15. Well Status after work: Oil 0 -. Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number r N/A if C.O. Exempt: 311 -104 Contact Jack Newell 263 -7832 Printed Name Timothy C. Brandenburg a Title Drilling Manager Signature - C7 ' ~ -"' Phone 276 -7600 Date 6/6/2011 L r Form 10 -404 Revised 10/2010 1113DAIS lig og Submit Original Only Chevron • • 1%0 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) K -30 TRADING BAY UNIT K -30 ADL0017594 5073320211 AR4431 33.76 125.00 dens Primary Job Type Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig 5/3/2011 5/27/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number K -30 507332021100 1700070 Daily Operations 4/21/2011 00:00 - 4/22/2011 00:00 Operations Summary Mobilize personnel & equipment. 4/22/2011 00:00 - 4/23/2011 00:00 Operations Summary Mobilize equipment. 4/23/2011 00:00 - 4/24/2011 00:00 Operations Summary Mobilize equipment. 4/30/2011 00:00 - 5/1/2011 00:00 Operations Summary Mobilize equipment from Grayling Platform to King Salmon Platform. 5/1/2011 00:00 - 5/2/2011 00:00 Operations Summary Mobilize equipment from Grayling Platform to King Salmon Platform. 5/2/2011 00:00 - 5/3/2011 00:00 Operations Summary Mobilize equipment from Grayling Platform to King Salmon Platform. 5/3/2011 00:00 - 5/4/2011 00:00 Operations Summary Mobilize equipment from Grayling Platform to King Salmon Platform. RU equipment & CUDD HWO unit. 5/4/2011 00:00 - 5/5/2011 00:00 Operations Summary RU equipment & CUDD HWO unit. 5/5/2011 00:00 - 5/6/2011 00:00 Operations Summary RU equipment & CUDD HWO unit. RU Closing unit for BOPE, prepare BOP equipment for RU to well. 5/6/2011 00:00 - 5/7/2011 00:00 Operations Summary RU E -line, Pressure test lubricator 250PSI low /3500PSI high. RIH w/ 1- 11/16" tubing punch and punch tubing from 10,136- 10,147' RKB SLM. RD E -line. 5/7/2011 00:00 - 5/8/2011 00:00 Operations Summary Circulate well with 3% KCL, ND Tree, AOGCC witnessed test waiver recieved from Bob Noble, AOGCC 5/7/2011. 5/8/2011 00:00 - 5/9/2011 00:00 Operations Summary NU BOP, PU bell nipple - install on stack, function test all BOP rams and valves, install two -way check, start BOP test with 4" work string DP. 5/9/2011 00:00 - 5/10/2011 00:00 Operations Summary Test BOP and all safety valves using 4" DP - 250 PSI Lw/ 3500 PSI High, test annular to 250 PSI Low/ 2500 PSI High, chart all tests, RD 4" test — equipment and RU 4 -1/2" test equipment same pressures as 4" testing - chart all testing, perform closing unit test, draw down 3000 PSI - 1600 PSI, build 200 PSI in 19 secs, full pressure in 100 seconds - all ok - RD testing equipment - pull two way check, RU ESP pulling equipment. 5/10/2011 00:00 - 5/11/2011 00:00 Operations Summary Pull hanger off seat, losses increased, mix & pump salt pill, losses decreased, begin pulling 4 -1/2" ESP completion from 10,326' to 8,656', losses decreased. 5/11/2011 00:00 - 5/12/2011 00:00 Operations Summary Continue to pull out of hole with ESP completion, after 180 joints (5400') pulled from well shut down due to weather conditions, continue to monitor well. 5/12/2011 00:00 - 5/13/2011 00:00 Operations Summary Continue to pull completion from well. 5/13/2011 00:00 - 5/14/2011 00:00 Operations Summary Continue to pull ESP completion from well, LD ESP. 5/14/2011 00:00 - 5/15/2011 00:00 Operations Summary Rig down ESP pulling equipment, prepare BHA for 9 -5/8" clean out run, PU and RIH with same. 5/15/2011 00:00 - 5/16/2011 00:00 Operations Summary Continue to PU BHA assembly and run in well. Chevron • • 1%0 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) K -30 TRADING BAY UNIT K -30 ADL0017594 5073320211 AR4431 33.76 125.00 Daily Operatt9ns .. 5/16/2011 00:00 - 5/17/2011 00:00 Operations Summary Continue to RIH with 9 -5/8" clean out assembly, saw no tight spots until 10,955' MD, could not go further, circulate viscous sweep, POH to change BHA assembly. Waiver by Jim Regg, AOGCC received at 11:30 hours 5 -16 -2011 to allow for performing BOP test after assembly pulled from well. 5/17/2011 00:00 - 5/18/2011 00:00 Operations Summary Finish pulling 9 -5/8" clean out assembly from well, Start AOGCC (Bob Noble) witnessed BOP test using 4" test joint, test test all assemblies and functions, swap over to 4 -1/2: test joint testing same as with 4" test joint. Pressure test annular to 250 PSI low /2500 PSI high. Pressure test BOP upper, lower and blind rams to 250 PSI low /3500 PSI high. Good test. 5/18/2011 00:00 - 5/19/2011 00:00 Operations Summary Perfom rig maintenance, PU 7" liner clean out assembly and RIH to depth of 4442' MD. 5/19/2011 00:00 - 5/20/2011 00:00 Operations Summary Tagged up at 10,955' MD, Sand, Wash and clean out well to 11,098' MD. Monitor fluid losses. 5/20/2011 00:00 - 5/21/2011 00:00 Operations Summary Continue to wash down cleaning well bore of sand, cleaned to a depth of 11,360', loose sand found, no gravel. Monitor fluid losses. 5/21/2011 00:00 - 5/22/2011 00:00 Operations Summary Continue to wash and clean out well bore of sand, no pebbles or gravel, at 11,784' tagged solid on packer, wash and clean, pull above packer and circulate viscous sweep, Start to pull out of hole. 5/22/2011 00:00 - 5/23/2011 00:00 Operations Summary Continue to pull out of well bore with work string, monitor well for static fluid losses, Finish POOH. 5/23/2011 00:00 - 5/24/2011 00:00 Operations Summary LD BHA, MU 4 -1/2" ESP equipment, PU Motor assembly and run in well bore. Monitor fluid losses. 5/24/2011 00:00 - 5/25/2011 00:00 Operations Summary Continue RIH with 4 -1/2" ESP completion w/ gaslift mandrels. 5/25/2011 00:00 - 5/26/2011 00:00 Operations Summary RIH with 4 -1/2" 12.75# L -80 ESP completion w/ gaslift mandrels and land at 9,973' with intake at 9,911'. 5/26/2011 00:00 - 5/27/2011 00:00 Operations Summary ND BOPE, NU tree, and test same to 250psi low /5,000psi high. Rig down and begin move to K- 13RD2. Turn well over to production. Start ESP. evro King Salmon Platform K -3ORD Well K -30 4.4"■.../.. ast Completed 5 Wellbore Schematic 5 -27 -2011 vim -27-2011 RKB: 100' AMSL KB -THF: 33.76' KB Casing and Tubing Detail :4" @ 396 Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 24" Conductor 94/ H40 36.40 396' Welded/ 19" Driven 13 -3/8" Surface 61/ K55 36.40 2187 BTC/ 12.515" 9 -5/8" Intermediate 47/ N80 36.40 10092' BTC/ 8.681" 9 -5/8" Intermediate 47/ P110 10092 12074' BTC/ 8.681" 7" Liner 29/ L80 11216 12575 BTC -KC/ 6.184" A Tubing 3/a °° @ z161' 4 -1/2" Prod Tubing 12.6/ L80 Surf 1707 Hydril 563 SCC 260 Joints (New) 4 -1/2" Prod Tubing _ 12.6/ L80 1707' 9745' Hydril 503 50 Joints (New) 5 Production Completion # Depth (RKB) Length ID (Drift) OD Item 33.8' 1 3.958" FMC Hanger Type "H ", 4 -1/2" IBT Top and BTM X -Over— (4 -1/2" IBT P x 4 -1/2" Hydril 503 P) a 1707' 3.883 4.5 4 -1/2" L80, Hydril 503 Tubing 2784' 8.98' 3.833" 7.063' 4 -1/2" GLM #7, IBT w/ Hydril 563 Pups 4574' 8.97' 3.833" 7.063' 4 -1/2" GLM #6, IBT w/ Hydril 563 Pups 11 5758' 8.98' 3.833" 7.063' 4 -1/2" GLM #5, IBT w/ Hydril 563 Pups 6926' 8.97' 3.833" 7.063' 4 -1/2" GLM#4, IBT w/ Hydril 563 Pups 7683' 8.77' 3.833" 7.063' 4 -1/2" GLM #3, IBT w/ Hydril 563 Pups 8359' 8.98' 3.833" 7.063" 4 -1/2" GLM #2, IBT w/ Hydril 563 Pups TOC:9600' 9057' 8.98' 3.833" 7.063' 4 -1/2" GLM #1, IBT w/ Hydril 563 Pups D 9750' 4.33' 3.813" 3.810" 4 -1/2" SSD Sliding Sleeve 9798' 1.22' 3.725" 3.725" 4 -1/2" "XN" Profile Nipple 1 9851' 1.45' 3.830" 5.220" X -over to ESP Equipment 9852' 120.39' ND 5.650" Centralift ESP: Motor, Pump and Assembly 9911' ND 5.630" Centralift ESP: Pump Intake I_ _ 9973' ND 8.00" Phoenix & w/ 4 Anodes Bull nose Assy 11,750' 3.900 6.184" E -Line set Packer . / Perforation Data ZONE TOP BTM SPF AMT Condition G -06 DST 10802' 10830' 4.5 28 4/70, Sqz'd after DST 0-6 G -1 10865' 10895' 24.5 30 4/70, 7/78, 3/88, 11/90, 2/02 G -2 10920' 10945' 24.5 25 4/70, 7/78, 3/88, 11/90, 2/02 G-1, 2, 3 G -2 10955' 10945' 24.5 39 4/70, 7/78, 3/88, 11/90, 2/02 TOL: 11216' G -3, 4 0-3 11004' 11050' 29.5 46 4/70, 7/78, 3/88, 11 /90, 2/02, 9/07 Isolation Squeeze 1 G -5 G -4 11056' 11130' 24.5 74 4/70, 7/78, 3/88, 11/90, 2/02, 9/07 1198511986 9-5/8" @ 11327' G -5 11195' 11224' 24.5 29 4/70, 7/78, 3/88, 11/90, 2/02 HB -1/G7 0-5 11232' 11268' 24.5 36 4/70, 7/78, 2/02 HB -1 11422' 11454' 11 32 'Feb 2002, 9/07 VI H8 -2 HB -2 11477' 11572' 5 95 Sept'07 1 HB -3 11586' 11627' 5 41 Sept'07 4_ HB -3 HB -3 11636' 11702' 11 24 'Feb 2002, 9/07 r' HB-4 HB -4 11660' 11720' 11 42 'Feb 2002, 9/07 PKR: 11,750' !- . HB -4 11700' 11790' 6 20 'Feb 2002 Isolation Squeeze :t. H8 5, 6, 7 HB -5 11780' 11820' 6 10 'Feb 2002 11985 -11986 ":''�' HB -5 11799' 11930' 6 21 'Feb2002 WF -3,4,5 HB-6 11880' 11975' 6 50 'Feb 2002 WF -6, 7 HB -7 11960' 11975' 6 15 'Feb 2002 j'.1 ' ...y;;j' WF -3 12005' 12070' 20.5 65 4/70, 2/79, 11/80, 3/88, 11/90 TD = 12600' PBTD = 12543' WF-4 12082' 10105' 20.5 23 4/70, 2/79, 11/80, 3/88, 11/90 WF-4 12144' 12190' 12.5 46 4/70, 3/88 WF-4 12200' 12245' 16.5 45 4/70, 2/79, 11/80, 3/88, 11/90 WF -5 12250' 12350' 8.5 100 4/70, 3/88 WF-6 12360' 12413' 8.5 53 4/70, 2/79, 11/80, 3/88, 11/90 Directional Data: WF-7 12468' 12480' 4.5 12 'April 1970 max = 42.5° at 6237' WBD K -30 05- 27- 11.docx Updated by JRN 06 -01 -2011 • • Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) ( !J �� T6 K - � (��) �� � 17c`7 _ �7 Sent: Tuesday, May 31, 2011 11:18 AM I To: 'Martin, J. Hal' Subject: RE: K -30RD SSV Test and No -Flow Test Deal in SVS test to be done in conjunction with no flow test is acceptable Dealying conjunction p Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 i 907 - 793 -1236 U �N `- 1 `ZU I t From: Martin, J. Hal [mailto:Hal.Martin @chevron.com] Sent: Sunday, May 29, 2011 6:17 PM To: Regg, James B (DOA) Cc: Johnson, Chris W; Njaa, Dale A; Greenstein, Larry P; DOA AOGCC Prudhoe Bay Subject: FW: K -30RD SSV Test and No -Flow Test Jim, The purpose of this e-mail is to make you aware of our well production status and to ask permission to conduct the SSV and no -flow tests on the well at the same time to minimize our shut -ins, and to communicate with you so that compliance is maintained. Unfortunately, the well's behavior and the fact that it is a long holiday weekend are making it more difficult for us to be as timely as we would like. I left a message on your office phone today and also called and spoke with Lou Grimaldi to make him aware of our situation and request. King Salmon Well K -30RD (PTD 170 -007) was worked over and turned on Friday, 5/27. During the course of the workover, we clean out soft solids (sand, iron sulfide and barium sulfate) fill from the well from 10955' (middle of G -Zone Bench 2 perfs) to 11784' (below Hemlock Bench 4 perfs). This type of solids fill was unexpected and although we proceeded with the ESP install, gave us some concern about how the well would produce. During the workover, we lost about 2450 Bbls FIW w/ 3% KCL (8.6 ppg according to drilling). After our turn -on on Friday AM, the well produced very erratically for a day or two before settling down. The well we have today is different from the well we had before losing the ESP about a year ago - currently about half the rate and half the PI. We are being as careful as we can to not upset the well any further and let it continue to settle out. I know that you waived the SSV test to Chris Johnson. My understanding, though, is that an actual test of the SSV needs to happen within 48 hours of the well becoming stable - which entails a shut -in. After talking w/ Lou, I had Chris Johnson on the King e-mail me the information about what type of SSV function test the King performed (see below). Because this is an ESP completion with no packer and no sub surface safety valve and we cleaned out the well across some of the existing perforations, we also need to conduct a no -flow test on the well - also requiring a shut -in. 5/31/2011 • Page 2 of 2 • Please review the information above and below and let me know if we can delay the SSV test until we arrange to have the no -flow conducted on the well. As I mentioned above, I am asking permission to have the tests conducted during the same shut -in period. Also, let me know if you need other information. I will call you Tuesday late morning if I have not heard back from you before then. Thanx, Hal From: Johnson, Chris W Sent: Sunday, May 29, 2011 5:17 PM To: Martin, J. Hal Subject: K -30 Hal, On 5/26/2011 we function tested K -30's high pilot, low pilot and Surface Safety Valve. First we tested the high pilot and it shut the SSV at 350 psi, then we tested the low pilot and it shut the SSV at 35 psi. After we checked the pilots we pressured up between the master valve and the SSV, we pressured it up to 960 psi and did not lose any pressure over a 5 minute period. Chris Johnson Lead Operator King Salmon Platform 907 - 776 -6690 5/31/2011 • Page 1 of 1 Regg, James B (DOA) • From: Purugganan,Abraham [ABRAHAMP @chevron.com] 1- &-{ K--3o Sent: Monday, May 23, 2011 9:19 PM ! To: DOA AOGCC Prudhoe Bay ` \ 'f�L 7 I Cc: Hammons Jr, Darrell James; Bonnett, Nigel (Nigel.Bonnett); Brandenburg, Tim C; Sunderland, Sloan [Swift Technical Services]; Brumley, Rick D. [Nabors] Subject: AOGCC H2s Alarm notification Importance: High This Message is sent in Behalf of Chevron Drilling Superintendent, Darrell, Hammons Date May 23, 2011 Time of BOPE Use 0910 hours Well/Location/PTD Number 4.N Trading Bay Unit K -30 /King Salmon Platform /700 -070 �` ; Rig Name CUDD #136 Operator Contact Abraham Purugganan, Drill Site Manager Cell 907 230 7262 Darrell, Hammons, Drilling Superintendent Office 263 -7632 Cell 907 -382 -4225 Operations Summary, including events leading up to BOPE use While preparing to Pick up Electronic submersible pump. A H2s alarm was set off in the well head room. the highest reading noted was 25 PPM. The blinds were already in the closed position while preparing to pick up ESP. The well was previously taking 1.5 BPH loss rate. Crew verified the well was shut in and proceeded to muster area. The Production team Dawned SCBA and Checked for ✓ H2s with hand held Multi meter. The hand held meter read 0 PPM H2s. All clear was given and the Tech. checked sensor for failure, accuracy, and compliance. Sensor was found to be within calibration and compliance with no evidence of sensor failure. System was put back in to service. 5/26/2011 • • SlinifE OFF ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager O 0 Union Oil Company of California l 1 P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU K -30 Sundry Number: 311 -104 Dear Mr. Brandenburg: APR 0 8 ZO h 4 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of April, 2011. Encl. • • Chevron Timothy C Brandenburg Union Oil Company of California 4110 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com March 28, 2011 RECEIVED APR 0 ?- Commissioner 4tf�1M3SI0iP Alaska Oil & Gas Conservation Commission 8 ���` 333 W. 7th Avenue, Suite 100 Anonrage Anchorage, Alaska 99501 -3572 Re: King Salmon Platform PTD: 170 -007 K -30 ESP Repair, Application for Sundry Approval Dear Commissioner Enclosed is an Application for Sundry Approval (Form 10 -403) for the above referenced well. The outlined workover is to pull the ESP, perform acid work, and install new ESP. The location of the SSV is currently "adjacent to the vertical run" on the production tree of well K -30. Union Oil Company requests a variance to 20 AAC 25.265 (c) (1), requiring that the SSV must be located in i the vertical run of the tree. Per 20 AAC 25.285 the choke an ill lines are to be 3" in nominal diameter if MASP is greater than l` 3000PSI. The MASP expected is OBI Union Oil Company requests a variance to utilize 2" nominal ID choke and kill lines on this work er. If you have any questions pertaining to this variance, please contact Jack R Newell 907 - 263 -7832. c. Timothy C. Brandenburg Drilling Manager Enclosure Cc: Well File Union Oil Company of California / A Chevron Company w4k- I 2ot1 /1,A 4111Lf STATE OF ALASKA OCC t a! 4} 0 t Mil ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS & Cons. Commission 20 AAC 25.280 cnorage 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool El Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing El • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El • Alter Casing ❑ Other: Esp Repair El 2. Operator Name: Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Development Ei , Exploratory ❑ 170 -007 • 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ❑ Service ❑ 6. API Number: 50- 733 - 20211 -00 • 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 111 No 0 TRADING BAY UNIT K -30 9. Property Designation (Lease Number): 10. Field / Pool(s): • McArthur River Field/ Middle Kenai G Oil, Hemlock Oil, and West Foreland Oil Pools ADL0017594 (King Salmon Platform) 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): 12,600' • 10,191' • 12,543' 10,139' N/A N/A / Casing Length Size MD / TVD Burst Collapse Structural Conductor 360' 24" 396' 395' Surface 2,151' 13 -3/8" 2,187' 2,024' 3,090psi 1,540psi Production 12,037' 9 -5/8" 12,074 9,713' 6,870psi 4,750psi Liner 1,359' 7" 12,575' 10,168' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4 -1/2" 12.6# L -80 10,309' See Schematic See Schematic Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A and N/A N/A and N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 15- Apr -11 Commencing Operations: Oil El Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned El Commission Representative: N/A GSTOR El SPLUG ❑ 17. 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 C Phone 276-7600 Date 3/28/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\ `I t34 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ i es* recs..- koPE to Woo pt! an,►a.wla.r rob tm 2500 )s-k. Other: Ktvt;Ka. t to 20 AA-c- L5. 2 - G5 (off C! at fer e- $$( p I �,e- e- w�t� �e. ► � � p rov , NAr saA 2 AAA to 0 > 25'. (k) 1 a l t n.a -t e✓tc«.tt. lo (1E gS t,perv Subsequent Form Required: 10 — f r 0 T APPROVED BY Approved by: • / COMMISSIONER THE COMMISSION Date: 5 RBDMS APB 0,8 2011 n RIGINAL p Form 10-403 Revised 1/2010 V Submit in Duplicate • • Chevron Trading Bay Unit K -30 1 %Oa 01 3 -28 -2011 Objective: • Pull and replace ESP completion. Current BHP: 3967psi @ 9353' TVD 8.2 PPG EMW Max BHP: ,psi @ 9353' TVD 8.2 PPG EMW (Based on previous actual Phoenix Reading) MASP: 031 p+si (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) 7 30S 3 V-4 Procedure ummary: 1. MIRU HWO unit (rig). 2. RU Wireline. Pressure test lubricator 250psi low /3100 psi high. 3. RIH w/ GR to clear tubing to +/- 10,300' MD. 4. PU RIH 4 -1/2" CAT standing valve and place in XN profile at 10,298' MD. 5. Shift sliding sleeve @ 10,253' MD or punch holes in tubing © ±10,245' MD. 6. RD Wireline. 7. Circulate wellbore with 3% KCI -FIW (filtered inlet water). 8. Spot sized salt pill as necessary. 9. ND tree. NU and test BOPE. Pressure test 250psi Low/ 3500psi High, Annular 250psi Low/ 2500psi High / 10. Recover 4 -1/2" completion and ESP assembly. 11. Run 9 -5/8" scraper BHA to the top of 7" liner at 11,216'. Circulate hole clean. / 12. Run 7" Cleanout BHA to the top of WL set packer @ 11,750' MD. 13. Pickle work string with 10 Barrels 12.5% HCL to end of tubing — reverse out. 14. Perform 60 barrels 7.5% HCL Calcium Carbonate scale treatment. 15. Soak 4 Hours — reverse scale treatment fluid from well bore. 16. Spot sized salt pill as necessary. 17. RIH 4 -1/2" 12.6# L -80 ESP and GLM completion w/ pump intake set at depth +/- 10,532'. 18. ND BOPE. NU and test tree. Pressure test 250 PSI Low/ 5000 PSI High 19. Secure and turn well over to production. 20. Rig down and release HWO unit (rig). 03/28/2011 AC III K - Permit 8. Dria: no -0w CURREN Salmon Platform Per Pea a seriaw ADL 17594 �'` Field: Trading Bay Unit API #. 50- 733 - 20211 -00 - RIGINAL RIG Leg: 1 Well Classificaton: Producer ELEVATIONS Slot#: 2 Total Depth: 12,600' Surface Location: PBTD: 12,543' 687' N 8 78' W fr SE nr Sec17 Tubing: 4 -% ", 12.6#, N -80, BTC T9N,R13W,SM 33.75' Prod Pkrs: 9 -5/8" Otis "WD" Wfreline Set Pkr ' Well Status: SI 7" Otis "WD" Wireline Set Pkr Operator: Chevron Ownership: Chevron/PE L I - BHP Spud Date: 1/23/70 3:30 PM Other: Rednlled April 1970; WO July 1978; VVO March 1988; CT CO Sept 1998; CT TCP March 2002 r--- Converted to ESP March 2002 BHT: 3967 orate Description Weight Grade Conn ID Length Top Btm TOC Mrs r.,� Conductor 24 " Weld 360' 36.40' 396' Driven 84.0 hrs Suface 133/8" 61.0# K -55 BTC 12.515" 2,151' 36.40' 2,187' Surf 364.0 hrs Production 9 5/8" 47.0# N -80 BTC 8.681" 10,056' 36.40' 10,092' 9 60. 568' 20 hrs III rZ! Production 9 5/8" 47.0# P -110 BTC 8.681" 1,981' 10,092' 12,074' 1 j 2,187' Ai III' Liner 7 " 29.0# N -80 8rd 6 260' 11 11 11,740' 43.0 hrs Liner 7 29.0# P -110 8rd 6.184" 1,099' 11,476' 12,575' 2,750' - _ om' . Tubing 4 1/2" 12.6# L -80 IBTC 3.958" 33.75' 10,309' o ♦ Description Depth Length ID OD �' ■ WH FMC ge - v pro 38' ra. port (w 4 p Mh orr capillary line) - 36.4' 1.00' 3.958" . _ y, 3 Rene type 'BP V proBb -One NPT parwh Continuous ator port d 2174 minj Min 10.4 1 ? ass IBT top Bottom. 1 m 1 4 - 1/2" SFO - 2 GLM w/ RK Latch 2,684' 9.80' 3.958" a = r1� 1 4 -1/2° SFO -2 GLM w/ RK Latch 4,311' 9.85' 3.958" 9,600' TOC - 4 -1/2" SFO-2 GLM w/ RK Latch 5,755' 9.82' 3.958" 1 4 -1/2° SFO-2 GLM w/ RK Latch 7,054' 9.79' 3.958" 4 -1/2° SFO -2 GLM w/ RK Latch 7,808' 9.80' 3.958" 4-1/2" SFO -2 GLM w/ RK Latch 8,443' 9.79' 3.958" 4-1/2" SFO -2 GLM w/ RK Latch 9,077' 9.80' 3.958" Pup Joint, 4-1/2" IBT BxP 10,246' 6.16' 3.958" 4.500" i t - " � 2 HES 4 -t4" SSD Sliding Sleeve (Shift Down to Open) 10,253' 4.20' 3.813" 5.625" I I 11 Pup Joint, 4 -1/2" IBT BxP 10,257' 3.91' 3.958" 4.500" E Pup Joint, 4 -1/2° IBT BxP 10,292' 6.07' 3.958" 4.500" ' ,IIIM Q 3 HES 4 - "XN" Profile Nipple w/ 3.813" profile 10,298' 114' 3.725" 4.500" C 4 Crossover 4-W IBT Box x 3 -%" New VAM Pin 10,309' 0.93' 3.000" 5.188" 5 Pup Joint /2" New VAM BxP (Handling pup) 10,310' 5.73' 2.992" 3.500" J 6 "Y " -T 9.2# MJ Double Box w /Cable Gip 10,316' 1.40' NA 7 REDA SP 64 Stage 538 S6000N Pump & 660 hp Tandem Motor) 10,317' 134.73' NA 7.250" Phoe uge 10,449' 1.84' NA 4.500" 8 2 -%" By -Pass Tube w/ WLEG @ 10461' 10,317' 143.40' 1.995" 2.750" 10,802' ° - , = I A 7" Otis WD wireline set perm packer (set 3/88) 11,750' 10,830' c- B Camco "D" Nipple (WLEG & Nipple possibly fell to btm in 2002) - _ II 11_ WLEG C FISH(s) Misc GLV equipment 11,216' TOL si ■ ;;Z•...-... .. . Top Btm 11,327' TOW Zone Top Btm Amt SPF 'VD TVD Date - G-Zone - C G -06 DST 10,802' 10,830' 28 4.5 8,643' 8,665' 4/70, Sqz'd after DST 0= G -1 10,865' 10,895' 30 24.5 8,691' 8,714' 4/70, 7/78, 3188, 11/90, 2/02 G -2 10,920' 10,945' 25 24.5 8,733' 8,753' 4/70, 7/78, 3/88, 11/90, 2/02 G -2 10,955' 10,994' 39 24.5 8,761' 8,791' 4/70, 7/78, 3/88, 11/90, 2/02 iiic ��� G -3 11,004' 11,050' 46 29.5 8,799' 8,835' 4/70, 7/78, 3/88, 11/90, 2/02, 9/07 LJ G -4 11,056' 11,130' 74 24.5 8,840' 8,898' 4/70, 7/78, 3/88, 11/90, 2/02, 9/07 _ 7 .... ' , - G -5 11,195' 11,224' 29 24.5 8,949' 8,972' 4/70, 7178, 3/88, 11/90, 2/02 Al ¢ G -5 11,232' 11,268' 38 24.5 8,978' 9,007' 4/70, 7/78, 2/02 Ic Hemlock Cmt Sqz 11,385' 11,386' 1 6 April 1970 HB -1 11,422' 11,454' 32 11 9,133' 9,160' Feb 2002, 9/07 HB -2 11,477' 11,572' 95 5 9,180' 9,624' Sept'07 Ir e= HB -3 11,586' 11,627' 41 5 9,276' 9,312' Sept'07 HB -3 11,636' 11,660' 24 11 9,320' 9,342' Feb 2002, 9/07 HB-4 11,660' 11,702' 42 11 9,342' 9,379' Feb 2002, 9/07 './ HB -4 11,700' 11,720' 20 6 9,378' 9,395' Feb 2002 HB-5 11,780' 11,790' 10 6 9,449' 9,458' Feb 2002 HB-5 11,799' 11,820' 21 6 9,466' 9,485' Feb 2002 HB-6 11,880' 11,930' 50 6 9,539' 9,583' Feb 2002 HB -7 11,960' 11,975' 15 6 9,610' 9,624' Feb 2002 CmtSqz 11,985' 11,986' 1 6 April1970 West Forlands VVF-3 12,005' 12,070' 65 20.5 9,651' 9,709' 4/70, 2/79, 11/80, 3/88, 11/90 WF -4 12,082' 12,105' 23 20.5 9,720' 9,741' 4/70, 2/79, 11/80, 3/88, 11/90 WF -4 12,144' 12,190' 48 12.5 9,776' 9,818' 4/70, 3/88 VVF-4 12,200' 12,245' 45 16.5 9,827' 9,867' 4/70, 2/79, 11/80, 3/88, 11/90 VVF -5 12,250' 12,350' 100 8.5 9,872' 9,963' 4170, 3/88 WF-6 12,360' 12,413' 53 8.5 9,972' 10,020' 4/70, 2/79, 11/80, 3/88, 11/90 0 M 0 - 7 12,468' 12,480' 1 12 4.5 10,070' 10,081' April1970 Current Schematic as of 9/13/07 I (Prepared By: Steve Tyler I 0 e hevro K-30 Well K-30 `, .._. �� , �..:.Ml 4*`*■/'° P ropose d W e ll bore Schematic Upd a Completed e 01 � 002 RKB: 100' AMSL KB -THF: 33.76' KB j ` 1 Casing and Tubing Detail /4" @ 396' ' Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 24" Conductor 94/ H40 36.40 396' Welded/ 19" Driven ' 13 -3/8" Surface 61/ K55 36.40 2187 BTC/ 12.515" 9 -5/8" Intermediate 47/ N80 36.40 10092' BTC/ 8.681" 9 -5/8" Intermediate 47/ P110 10092 12074' BTC/ 8.681" 7" Liner 29/ L80 11216 12575 BTC -KC/ 6.184" Z. ti Tubing 4 -1/2" I Prod Tubing I 12.6/ L80 I 33.75 I ±10410 I Hydril 563/ I From CVX Stock/ New - 3/8 2161' NOTE: 4 -1/2" IBT Tubing to be sent to Tuboscope for inspection and put in stock. 0 Production String Jewelry Detail 0 # Depth (RKB) Length ID (Drift) OD Item 6 4 3 g, FMC Hanger Type "H ", 4 -1/2" IBT Top and BTM X - Over - (4 - 1/2" IBT P x 4 - 1/2" Hydril 503 P) I 3.883 5.200" 4 -1/2" L80, Hydril 563 Tubing ±2751' ±10' 3.833" 6.141" 4 -1/2" GLM, IBT 3.833" 5.200" 4 -1/2" L80, Hydril 563 Tubing ±4565' ±10' 3.833" 6.141" 4 -1/2" GLM, IBT 3.833" 5.200" 4 -1/2" L80, Hydril 563 Tubing ±5747' 10' 3.833" 6.141" 4 -1/2" GLM, IBT 3.833" 5.200" 4 -1/2" L80, Hydril 563 Tubing TOO 9600' ±6878' ±10' 3.833" 6.141" 4 -1/2" GLM, IBT 3.833" 5.200" 4 -1/2" L80, Hydril 563 Tubing ±7633' ±10' 3.833" 6.141" 4 -1/2" GLM, IBT 3.833" 5.200" 4 -1/2" L80, Hydril 563 Tubing ±8317 ±10' 3.833" 6.141" 4 -1/2" GLM, IBT 3.833" 5.200" 4 -1/2" L80, Hydril 563 Tubing ±9019' ±10' 3.833" 6.141" 4 -1/2" GLM, IBT 3.833" 5.200" 4 -1/2" L80, Hydril 563 Tubing ±9718' 3.833" 6.141" 4 -1/2" GLM, IBT ±10370' 3.813" 4 -1/2" SSD Sliding Sleeve ±10390' 3.725" 4 -1/2" "XN" Profile Nipple X -over to ESP E ui ment 0-6 110532 - ND ND Centralift ESP: Pum Intake I 1,2,3 TOL: 1121 4 Perforation Data 5 ZONE TOP BTM SPF AMT Condition &1 /G7 G -06 DST 10802' 10830 45 28 4/70, Sgid after DST G -1 10865' 10895 245 30 4/70, 7/78, 3/88, 11/90, 2/02 -2 G -2 10920' 10945' 245 25 4/70, 7/78, 3/88, 11/90, 2/02 • -3 G -2 10955' 10945' 245 39 4/70, 7/78, 3/88, 11/90, 2/02 G -3 11004' 11050' 29.5 46 4/70, 7/78, 3/88, 11/90, 2/02, 9/07 -4 G -4 11056' 11130' 24.5 74 4/70, 7/78, 3/88, 11/90, 2/02, 9/07 PKR: 11750' G -5 11195' 11224' 24.5 29 4/70 7/78, 3/88, 11/90, 2/02 -5, 6, 7 G -5 11232' 11268' 245 36 4/70, 7/78, 2/02 -3,4,5 HB -1 11422' 11454' 11 32 'Feb 2002, 9/07 HB -2 11477' 11572' 5 95 Sept'07 F 6, 7 HB -3 11586' 11627' 5 41 Sept'07 ♦ `` ' HB -3 11636' 11702' 11 24 'Feb 2002, 9/07 TD = 12600' PBTD = 12543' HB -4 11660' 11720' 11 42 'Feb 2002, 9/07 HB -4 11700' 11790' 6 20 'Feb 2002 HB -5 11780' 11820' 6 10 'Feb 2002 HB -5 11799' 11930' 6 21 'Feb 2002 HB-6 11880' 11975' 6 50 'Feb 2002 Directional Data: HB -7 11960' 11975' 6 15 'Feb 2002 WF -3 12005' 12070' 20.5 65 4/70, 2/79, 11/80, 3/88, 11/90 max = 2.25° at 7,083' WF-4 12082' 10105' 20.5 23 4/70, 2/79, 11/80, 3/88, 11/90 WF-4 12144' 12190' 12.5 46 4/70, 3/88 WF-4 12200' 12245' 16.5 45 4/70, 2/79, 11/80, 3/88, 11/90 WF -5 12250' 12350' 8.5 100 4/70, 3/88 WF-6 12360' 12413' 8.5 53 4/70, 2/79, 11/80, 3/88, 11/90 WF -7 12468' 12480' 4.5 12 'April 1970 WBD K -30 02 -22 -11 Proposed.docx Updated by JRN 03 -14 -2011 • King Salmon Platform BOP Stackup 03/14/2011 %IP King Salmon 2011 ESP Workovers BOP Drawing K-1RD2, K- 13RD2, K -30, K -25 7 4.54' BOP based on Cudd rental Hydril stack drawing 13 5/8" 5000 al; mica. I t 10I 11111I ZU 4.67' - n , , , k - . g * - ,., .....,_ ., itri I _ Ill n1 n1 n1 u1 .- All choke and kill line III III III '!' III valves 2'1/16.SM w/ ). :lion: Iii..).. I I unibolt end connections 2.00' , ii, ,i, ii, 111 ' III III 111 III III 2.83' aIIIMIBO Iii 111 Ill Iti iii ' 701 III 111 III III III Drill deck Riser 13 5/8 5M FE X 13 5/8 5M API Hub 12.98' � , mu I11 u 4 I II I' :.. ' 5.70' '' • 1. 1� r f f L� 4 11. L.,►1' : 1I ,' / 4 f ........""-- - IL _iiin m% 6_..4. I. El Chevron ~.~ Francisco Castro Technical Assistant January 3, 2008 To: AOGCC Mahnken, Christine R 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 ~ ~ ~ . ~ r~ Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ~~~5~~'~ JAN ~ 2~i18 -, - -- ~--~ ~ ~ I I I NOTE=S ~I ~ WELL i LOG TYPE i ~ I i, SCALE ~ LAG DATE ~ I~~TEP.VP.L L~GGEG ~ RU~d B- ~ ~ # ~ LIf~iE ~ FILM -LAS, CD ~ P~~, --- ~ DLIS I ULTRASONIC K-30RD CORROSION LOG USIT/GR/CCL 5" 27-Au -07 150 - 11110 3 1 1 PDS RESERVOIR K-30RD SATURATION LOG RST/PRES/TEMPlGR/CCL 5" 29-Au -07 6500 - 10960 2 1 1 PDS TUBING CONVEYED GUN CORRELATION K-30RD PRESSlTEMP/GR/CCL/RS T-C 5" 7-Se -07 10450 - 10850 1 1 1 PDS l~0.0~~ ~~ ~{_ so i5~a (o r~a~- r~~a~ s Please acknowledge receipt by signing and returning one copy of ttrisasmit~a~q~ t. 907 263 7828. ~~, ,~ ~_ Received ay: /y Date: r l/~! , .;~,~5 ;, . . Page 1 of 1 Maunder, Thomas E (DOA) From: Tyler, Steve L [tylers/@chevron.com] Sent: Tuesday, October 23, 2007 5:23 PM To: Maunder, Thomas E (DOA) Subject: RE: TBU K-30 (170-007) Embarrassing discovery of utilizing Barite in our 3% KCI brine, to mix dry jobs prior to tripping pipe. When found we had a total of ±10,000# of Barite in our system. Decided to change over to a "Cleaner fluid" prior to perforating. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) Sent: Tuesday, October 23,200712:41 PM To: Tyler, Steve L SUbject: TBU K-30 (170-007) Steve, I am reviewing the operations report for the recent workover on this well. On September 5, operations were suspended due to "contaminated mud", Could you provide some further information regarding this? Thanks in advance, Tom Maunder, PE AOGCC tjGANNED NOV 0 1 2007 ,.... &.~<..:..,....__~.,._ ," "~'''~'_''_'''''~''"'''.'';''''t.; 1 0/24/2007 . STATE OF ALASKA .. ALASKA OIL AND GAS CONSERVATION COMMì!!fON REPORT OF SUNDRY WELL OPERATIONS tU:'vt:1 V t:.LJ OCT 2 2 2007 Alaska Oil & Gas Cons. Commission Anchorage 1. Operations Abandon U Repair Well lj Plug Perforations U Stimulate U Other L::J ESP CO Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 . Re-enter Suspended Well 0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Union Oil Company of California Development 0 ~ Exploratory 0 170-007 3. Address: PO Box 196247, Anchorage, AK, 99519-6247 Stratigraphic 0 Service 0 6. API Number: 50-733-20211-00 " 7. KB Elevation (ft): 9. Well Name and Number: 100' AMSL'" K-30 A 8. pr~eSignatioy 1:.21.07 10. Field/Pool(s): Mid K~C)¡,I ADL 1 4 r759 McArthur River Field, Hemlock oIL-) W rcq-C..k. D/ I 11. Present Well Condition Summary: Ao .2. 'S Total Depth measured 12,600' . feet Plugs (measured) true vertical 10,191' feet Junk (measured) Effective Depth measured 12,454' < feet true vertical 10,057' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 360' 24 " 396' 395' Surface 2,151' 13 3/8" 2,187' 2,024' 1,540 psi Production 12,037' 9518" 12,074' 9,713' 4,760 psi Liner 1,359' 7 " 12,575' 10,168' 5,410 psi Perforation depth: Measured depth: See Attachment True Vertical depth: See Attachment Tubing: (size, grade, and measured depth) 4-%" L-80 10,309' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft 0 CT 2 4 Z007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 20 10 Subsequent to operation: 519 3890 ... 6211 70 90 ~ 14. Attachments: 15. Well Class after work: Exploratory 0 Development 0 --I' Service 0 Copies of Logs and Surveys Run Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 307-166 Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Title Drilling Manager .--, /2 ~ Signature L Phone 907263-7657 Date 10/15/2007 ~ /o~Z.:~.'o 7 i!..;-- c:>7 Form 10-404 Revised 04/2006 0 RIG I N A L ~ \Db,\.{ ..J'. ~~~It Onglnal Only ,~IEI'~?Þ7 . . I OIL Depth I TVD Depth Zone I Top I Btm I Top Btm Amt I Gun Size I SPF Phase Date G-Zone G-06 DST 10,802' 10,830' 8,643' 8,665' 28 4.5 4/70, Sqz'd after DST G-1 10,865' 10,895' 8,691' 8,714' 30 24.5 4/70, 7/78, 3/88, 11/90, 2/02 G-2 10,920' 10,945' 8,733' 8,753' 25 24.5 4/70, 7/78, 3/88, 11/90, 2/02 G-2 10,955' 10,994' 8,761' 8,791' 39 24.5 4/70, 7/78, 3/88, 11/90, 2/02 G-3 11,018' 11,050' 8,810' 8,835' 32 24.5 4/70, 7/78, 3/88, 11/90, 2/02 G-4 11,065' 11,130' 8,847' 8,898' 65 24.5 4/70, 7/78, 3/88, 11/90, 2/02 G-5 11,195' 11,224' 8,949' 8,972' 29 24.5 4/70, 7/78, 3/88, 11/90, 2/02 G-5 11,232' 11,268' 8,978' 9,007' 36 24.5 4/70, 7/78, 2/02 Hemlock emt Sqz 11,385' 11,386' 9,102' 9,102' 1 6 Apríl1970 HB-1 11,412' 11,440' 9,124' 9,148' 28 6 Feb 2002 HB-4 11,636' 11,660' 9,320' 9,342' 24 6 Feb 2002 HB-4 11,671' 11,690' 9.352' 9,369' 19 6 Feb 2002 HB-4 11,700' 11,720' 9,378' 9,395' 20 6 Feb 2002 HB-5 11,780' 11,790' 9,449' 9,458' 10 6 Feb 2002 HB-5 11,799' 11,820' 9,466' 9,485' 21 6 Feb 2002 HB·6 11,880' 11,930' 9,539' 9,583' 50 6 Feb 2002 HB·7 11,960' 11,975' 9,610' 9,624' 15 6 Feb 2002 emt Sqz 11,985' 11,986' 9,633' 9,634' 1 6 Apríl1970 West Forlands WF·3 12,005' 12,070' 9,651' 9,709' 65 20.5 4/70, 2/79, 11/80, 3/88, 11/90 WF-4 12,082' 12,105' 9,720' 9,741' 23 20.5 4/70, 2/79, 11/80, 3/88, 11/90 WF-4 12,144' 12,190' 9,776' 9,818' 46 12.5 4/70, 3/88 WF-4 12,200' 12,245' 9,827' 9,867' 45 16.5 4/70, 2/79, 11/80, 3/88, 11/90 WF-5 12,250' 12,350' 9,872' 9,963' 100 8.5 4/70, 3/88 WF-6 12,360' 12,413' 9,972' 10,020' 53 8.5 4/70, 2/79, 11/80, 3/88, 11/90 WF-7 12,468' 12,480' 10,070' 10,081' 12 4.5 Apríl1970 Existing Perforations Added Perforations I OIL Depth TVD Depth Zone I Top I Btm I Top Btm Amt Gun Size I SPF I Phase I Date G-Zone G-3 I 11,023' I 11,043' 8,814' 8,830' 20 45/8" I 5 1 60 19/8/2007 G-4 I 11,075' I 11,120' 1 8,855' 8,890' 45 45/8" I 5 I 60 19/8/2007 Hemlock HB-1 11.440' 11,472' 9,148' 9,176' 32 45/8" 5 60 9/8/2007 HB-2 11,495' 11,590' 9,196' 9,280' 95 45/8" 5 60 9/8/2007 HB-3 11,605' 11,636' 9,293' 9,320' 31 45/8" 5 60 9/8/2007 HB-3 11,636' 11,646' 9,320' 9,329' 10 45/8" 5 60 9/8/2007 HB-3 11,660' 11,671' 9,342' 9,352' 11 45/8" 5 60 9/8/2007 HB-4 11,671' 11,690' 9,352' 9,369' 19 45/8" 5 60 9/8/2007 HB·4 11,690' 11,700' 9,369' 9,378' 10 45/8" 5 60 9/8/2007 HB-4 11,700' 11,720' 9,378' 9,395' 20 45/8" 5 60 9/8/2007 . Chevron - Alaska SWW Daily Operations Summary Well Name K-30 Primary Job Type Recompletion Jobs PmnaryJobType - Recom pletion Field Name I MCARTHUR API/UWI 1507332021100 \. Lease/Serial ,ADL0017594 Primary Wellbore Affected i Main Hole IOr;9 KS Elev (ltKS) IWater Depth (It) 100.0 - --. ··_·~IJOb Cate9ory- ìAFENo.~mObjec¡¡Ve--- Recomplete I R7013 Ipull ESP. Mill Out PKR. Clean well out. Replace \ESP IÄ~~~;~~a;7 ¡End Dat"-rÖCErlgineer Daily Operations 8/5/200700:00 - 8/6/2007 00:00 Operatl6riSSummary - -- - ----- _~_~_m_ m_ ---- Mobe/Skid HWR from JS:.12Rt:>Jo K-30RD.lnstall BPV..!'JD tre~ Clean/chase9.Jift threads_ on hngr~U BOPE.~_ 8/6/200700:00 - 8/7/2007 00:00 ÓperationsSummary- - - -- -. -- Continue mobe HWR over K-30RD -'- .-----....----.....-.-. --'--,--- -_.-._._~----~-- --- ....-. ..- ___ ____.,' .___'. _____ .....__.__ .._ u___.,__'_ .__.__....__.______ DSM Comment: Called AOGCC NS @ 11:10. Told to call Mr. Regg. Spoke to Jim Regg at 11:15. Chuck Scheve called back at 14:00 hrs. Will advise ----,-----_._--_.._-_.__.._-----_.._..__.._._-----_._~._..._--_.._----_..._------_._---~,----_._- 8/7/200700:00 - 8/8/2007 00:00 OperationsSummary - - - - -- - - - - -- - Continue Mobe HWR. Conduct BOPE test. --..'-----.. ---.---....---. ---- - ---._-- -- --' --- ----'-- ----' ---- ',-- --- 8/8/200700:00 - 8/9/2007 00:00 OperationSSummar:y------------.-.-m-- --..- ---~- ____._m______~_ Finished BOPE test. Circulate 800 bbls down tbg to production. Recovered only slight trace of oil. Monitor well. Losses at 1 bph. PUMU Land jt. BO LDS. Pull hngr to window. Pulling 4-1/2" tbg LD same. 8/9/200700:00 - 8/10/2007 00:00 operations Summary·-- -.-- --.- - .-- ..--. Continue pulling out hole laying down tbg & GLM's. -" ..--- -'--- - ---"-----" ._- ._----_...._--.--~ ---..----. .-.' .--- ______n_ ____ -.-.-......-- __ ___ .__. _.___.._.._nn__.___ -~_..._- --.--.-.-----.-.-.-.--.-.."---.------ ___._ __._ .__.. ..__m .____._.....__ _._ .__..__n ____ _._..__ ----.-..--..--.-..-.---..---- Losses @ about 1 bbl per hr. - .__.·___.._____n.._____..__.·._ ___ ..._ --.,--..-- -.'.--- --...--- .---. .--.---- --- --' .-.. ----.. .'-'- ---- -- ...--.. --" -..---- ..---.. .---..--.-----.....-..------.--...--- 8/10/200700:00 - 8/1112007 00:00 . ...... ............. .___ ____ OperationsSummary------·---·----·-------·-m-- -----.-.~.- - LD ESP motor & Pump. Motor full of brass. Seals full of water. Recovered (324) jts of 4-1/2" tbg, (172) Cannon Clamps, (20) Super Bands, (4) Protectorlizers, (10.66') of Flat Guard. Power Wash work basket. Worked boat. Install Wear Ring. Comments: . Found a burn in a cable blowout about 2 to 3 feet above MLE splice. First two reels out of hole looked ok and checked good. Last reel out had heavy corrosion on the armor. All three pumps were locked. Top pump packed with sand. Middle pump has two inch hole in housing about half way down. Seal was wet except for bottom chamber had discolored oil. Motor checked wet and had water and lots of brass in the bottom. LlH: (27) Super Bands (2) Protectolizer doors Unknown amount of Flat Guard. Approximatly +/- 80' ----------~---,_._~-------_.._~_._._....__._-_._-,----_.._-_...__.._-_.._._.__..,---_..._---_..__._-'_.-_.~ 8/11/200700:00 - 8/12/200700:00 Opèrations Summary ---- --.------.----- .----.---..----- ------. ------ ----. --- ---- ._- -------- ------.---- --- ---- ____..____n.______ PUMl.J...C~nou.!.!3HA.B'I_I. :Jickingup ~.______ ____ _ __ _ ____ __ ______~_ 8/12/200700:00 - 8/13/2007 00:00 Operations Summary ~0f1!i.nue~~ij:leanout ~A while pickin~p.E"'---Wash down w/ reverse basket from' (),4~~'t~JO,546'~B~OOf_jstan9ing back DP.~_ ~ 8/13/200700:00 - 8/14/2007 00:00 Operations Summa-,y----- Cont POOH. Clean string magnet. Not much recovery. Clean reverse basket. Recover 45' to 50' of wadded flat guard (28.5#), 13 flat guard buckles, 15 super bands and large chunks of scale. PUMU same BHA (left out string magnet. RIH on DP. -------.-.-------...---.-.---.---.--- 8/14/2007..Q0:00.-JIf15/20()L00:00___ .. __ _ ... .._ ___ _ _ __ ____ ~_~ Operations Summary .- - - . - - -. --- - Continue RIH w/ Reverse Basket BHA. Drop ball. Circulate @ 11 bpm. Work pipe down to 10,548'. Circulation pressure increased by 600 psi. (indiating basket is full). POOH. DSM Comments: Contacted AOGCC on Slope 09:05 8/14/07 for BOP test on 8/15/07, Contacted Jim Regg w/AOGCC 09:10 8/14/07 concerning BOP test on 8/15/07. He waived witness of BOP Test on 8/15/07. _._--_..._----_._--_.._--.----~----- _._-_.__.._-----_._-_.._._-._.__..__._--~-- ___..______._. _.._._____._______....________________._...____.___ ._'.__ __...__..___.._._.________ - ___..____.._.___..n..._______..__.n________.._ 8/15/200700:00 - 8/16/2007 00:00 OperationsSummary-·------·-·-·---·----·~--·-·----·-·---_..-..-~. Continue TOH. LD BHA. Recovered 12" of metal and some scale. RIH 10 stnds. Test BOPE. --.----.--.-....-.- -- -----..--.-.---.-----.....------..--- ----...--.---.-----------------..---. --------.- ----.-.--.----...---..-.----- Chevron - Alaska SWW Daily Operations Summary Well Name K-30 I Field Name . MCARTHUR API/UWI 507332021100 I Lease/Serial ADL0017594 Orig KS Elev (ltKS) Water Depth (It) 100.0 Daily Operations 8/16/200700:00 - 8/17/2007 00:00 Operations-SÙmmary- ----- ---- ---- -- PUMU P~m~HA.RIH tagp~@ 10,547'.Mill pkr (3~rsl£'ush same down hole "1£!'()OH w/ pkr mi~ 8/17/200700:00 - 8/18/2007 00:00 OperationsSlImmary- --- ---- Pumped sweep aroun~ix/pumpdry pill. POOH periodically stopping~lean slip dies"~_~:)gH:~slinger s..jars:__ _ ______ 8/18/200700:00 - 8/19/2007 00:00 OperationsSummary---- --- -- ---- ----- LD Pkr Milling AsSJ.: PUMI..J.sp~ar.~H.£ng~~ pkrfisl1._@!..O,56!~ Ja-,,-onE~r fis.l1..!or4 hrs,r-.¡o_Joy. Release spear. F'0()~ 8/19/200700:00.. 8/20/2007 00:00 óperaÏions~:;_ummar:y----·--------- ~-----,---------------------~------.----,--------~---------~-~.~-_._- Contirl[jeF'0f:i_",,/ sEea-,"-as~"Y': LD same." Found sp~a.r.wél~missing ~4" x 6-1/4"sectionCJ!.9rapp~: RIH withpkrmill as~y \Nith_mill extension. __ 8/20/200700:00 - 8/21/2007 00:00 OperatìonsSummary-~--~----- ____""_"____~m~________ ----- ----- "-------- ~ntil"l.u.e_!'f:i vv¿Ykr_l1lil'-as~.Y':T~ up onpkr ~J.0,~~'.~II 0I'lJ>krto! 7 hrs. ~ ________ _____ ~~~~~~~:u~~~~~ ~?2/2007 OO:OL_~ --- ----~------- QC\\ Continue to mill on pkr additional 7 hrs. Pkr fell free. RI tag pkr @ 10,600'. Milled on pkr an additional 3 hrs. No further movement%w/ mill assy. -----... .._--- ----.---- ...--- -'_._- -"- ---.._.~.._..- -_._..~--- DSM Comments: Contacted AOGCC on Slope 08:30 hrs on Aug 21,2007 for test on 8/22/07, Contacted John Crisp who waved witness. Jim Regg w/AOGCC called and also wavied witness for the BOP test ___~___ - - ___ - - - ____..__."._.,,_.._'_______._____.___n___._ _._---------~- 8/22/2007 00:00 .. 8/23/2007 00:00 Operations-Summary-m--- -------- ________m -------- --- ---- ------ ------.----- -------------- Continue to POOH w/ pkr mill BHA. LD same. Junk baskets were full of metal shavings f/ pkr. Magnets had good retention of cuttings. NORM less than 20 units. Packer mill showed signs of wear. Conduct BOP test. Fluid loss of 14 bbls over last 24hrs. --~-,--------------------._---------------------,------------------- 8/23/2007 00:00 - 8/24/2007 00:00 C)"peraÜ()ns Summar:y------------ ----------- ____n ------------ ---- --- ------ Finished BOPE test. PUMU ITCO Spear and fishing BHA. RIH latch fish @ 10,611 '. POOH. __________ __n_______,,__ Zero fluid losses for last 24 hrs. _.._----~-------,--------------------------------------,-----------._- --------,-------------------------~ 8/24/200700:00.. 8/25/2007 00:00 operations Sumr11ary-- --- Ensure spear was latched onto fish. POOH. HawkJaw broke while handling DC's. Worked to fix same. Fluid Loses = about 1 bbl per hr. __ ______________n___ _________________________n__________________ ____ _____ _______________ ___ 8/25/2007 00:00 .. 8/26/2007 00:00 OperationsSumma¡:y"---------"------~--"- ""-"------"- Fixed HawkJaw. Finished handling DC's. LD fish (pkr remnants & tail pipe assy -43'). PUMU 8-1/2" mill. RIH. Fluid loss @ 1 bph ---------------- 8/26/2007 00:00 .. 8/27/2007 00:00 Operations sumrriary---------------------n---- -- -- ----- ---- --------------------- ---------------------- RIH. Tag @ 10,602' dpm w/ 10k down. Wash & ream from 10,602' to 11,259'. Found tight spots 10,602' to 10,629'; 10,640'; 10,707'. Fine sand over shakers during cleanout. Pump high visc sweep. CBU. POOH. Fluid loss during cleanout = 11.1 bph (111 bbls total) Static fluid loss @ 4 bph. --------- -------- ---------- -----~-- _._-_.._._--------_._---~-_._-~-~- ._---,,-----------------~----------------- ------------,_._~_._---~~-- 8/27/200700:00.. 8/28/2007 00:00 -Operations Summary ------~--- ~ ---- ----- POOH W/~Junk Baskets & Magnets. Add Csg Scraper &2'!'i:~_____ 8/28/200700:00.. 8/29/2007 00:00 OperationsSur11mary--- ----- --~ ---- - u_ ---- -------- -- --- _~n___ ---- ----- Continue TI H to 11,198'. Tagged up w/ 10K Dn. Stage pumps up to 10 bpm - 1750 psi. Wash & ream down from 11,174' to liner top (11,259' DPM). CBU 2x @ 11 bpm - 2000 psi. No gas, excessive solids or hyrdocarbons observed @ BU. POOH. ------ ---- ----,,~-- --~- DSM Comments: AOGCC notified on Aug 28 @ 10:18 hrs. Received extension till Midnight Aug 30 for BOP test to start. Talked to Lou Grimaldi -------,------ -----------------,----- -------------------------,------------------ --------- --------- ----,-----_._--------------------- ~----.__.~- , . Chevron - Alaska SWW Daily Operations Summary Well Name K-30 I' Field Name MCARTHUR APIIUWI .507332021100 Lease/Serial IADL0017594 ,Orig KS Elev (ItKS) Water Depth (It) 100.0 Daily Operations 8/29/2007 00:00 - 8/30/2007 00:00 QperaÙonsSIJmmary------ ---- ____n'__________ ---- Cont POOH w/ 9-5/8" scrapper assy. RU Eline. RIH w/ GR/Junk Basket to TOL. POOH. LD GR/Junk Basket. Switch to AFE #R7028 DSM Comments: AOGCC notified on Aug 29 @ 0900 hrs. Left message on recorder as per Mr. Lou Grimaldi request. Mr Grimaldi called back @ 1330 hrs & waived the BOP inspector for an on site inspector. 8/30/200700:00 - 8/31/2007 00:00 Operfüions·-·Sumrña¡:y---------------------- --------------------------,----,---~ Finished RST Log. PUMU USIT. RI Log from 11,110' to surface. RD Eline. Conduct BOPE Test. Last 24 hrs = Zero Fluid Loss --_...~----_.-._-----_._---,_._---_._--"-- DSM Comments: AOGCC notifed on Aug 30 @ 1020 hrs for test today. Mr Grimaldi is aware of time & date. Talked to Jim Regg at 1600 hrs. -,----------------,'._-------,---,--,--_.,----------_.-._- -----_._-._-----_.~--_._..__._-,...~._-" 8/31/200700:00 - 9/1/2007 00:00 OperationSS-ummaiy-- ---- -~ -- --- --- Finish BOPE test. LD test plug. PU 6" mill & DC's. RIH Wash from 11,253' to 11,569'. __·-00__--- ___'_·N'______,_ Zero Fluid Loss in last 24 hrs. --- --.--,.-'- ----- ---.---"'----'-"--- -'" -- ....---. ..--- ____ _____.u .._____.__n_ --- ---------,---------",.- 9/1/200700:00-9/2/200700:00 . ... . . . .. ........ ~___~___ Operations Summary----- - -~-~-- ~-- -- - - -- - - --- - -.---- FinishPOOH w/ DC's. LD Test plug. Install WB. RIH w/ 6" mill. Cleaned out 7" liner f/ 11,259' U 11,823' DPM (7" pkr). Pumped a 50 bbl high vis sweep. CBU. POOH. Zero fluid losses last 24 hrs. --------,.__.._.__.._._---~-_._--_._--~-_..._- ---_._..._._--...~---_._._---_._.__._-_._---------~.- 9/2/200700:00 - 9/3/2007 00:00 Operations Summary- . - - -- .-- - Finish POOH. w/ BHA # 9. PU String Mill w/ 10' ext & 3-7/8" mill. RIH U top of 7" pkr @ 11,823' DPM. CO to 11,833' DPM. Pump hi vis sweep. CBU. --------..-. .---. --.-----. ...-- _._____.·_...n____.·..._ 15bbls of fluid loss over last 24 hrs. __.._ ___. .___ ._..__ ...___....____n .__ __ .n___··...__·.___· _____ ---.- -.--.. ..---.. -- --- ...--.........-..-... ----.... .--- -----..---- 9/3/200700:00 - 9/4/200700:00. .. .. . ... ......... .... .. .... . .~__ Operationsšumma-,=y-------~-----------~·-------- - --------~ POOH w/ String Mill (BHA # 10). PUMU HES RTTS tool. RIH U 2955'. Set RTTS. Tested 9-5/8" Csg f/ 2955' to surface to 2600 psi for 30 min. Unset RTTS. POOH. Loss 15bbls of fluid over last 24 hrs. -.---------.--.-----..----- -.-----....---------.--.---.---..----.------ 9/4/2007 00:00 - 9/5/2007 00:00 Operations Summary-- --- -- -- .------- - .----. --- POOH w/ RTTS pkr. LD same. PUMU 4-5/8" 5 spf TCP guns. RIH. ___.... .___... _._n ...__ --" --.- --- ..---.--...----...--..-"-------.- ---.--',.- Zero Fluid Loss last 24 hrs. _...___._..___.._._____..._. .__._____..._._ _...___ ._____ _____.. .____ ______. .___,_ ..n__ __....___..___. ._.... ..__. _..______._..___ ___._" ___..__._".__ ------....------- 9/5/2007 00:00 . 9/6/2007 00:00 Operations Summary ..--------....----.---- ______.____.____.._._..__.___.._~·_e RIH w/ Perf guns to 11,718'. RU Eline. RIH w/ GR. Log RA to correlate gun on depth. Suspend perforating operations due to contaminated mud. RD Eline. PU and position circulation port @ 10,500'. Clear & Prep drill decks for handling contaminated mud. Last 24hrs lost 4 bbls. -----_._-------~~-_.._----_..__.__._.._----.__.._._....._._---------_._~_.- 9/6/200700:00 - 9/7/2007 00:00 Operations-Summary ------..--------- ----.---.--.------- ____.n______ Continue arranging decks to make room for iso tanks to handle contaminated mud. -----... -.-.-----...----- __..____ ____... ._..______._...______n___·_ Fluid Loss last 24hrs = 3 bbls --..------..--.--.-.--...- ---..----.--.---.--. .---.-..----.....-----.---.----.....----- -----. ----.-..--..-..------.---.---.---.....----.----.---...-------.-- '", .f Chevron - Alaska SWW Daily Operations Summary Well Name K-30 I Field Name , MCARTHUR IAPI/UWI 507332021100 ¡ Lease/Serial ! ADL0017594 Ori9 KB Elev (ltKB) IWater Depth (It) 100.0 Daily Operations 9/7/200700:00 - 9/8/2007 00:00 Operabor,SSummàry - - ---- -- - - - -------- --- --- Continue displacing contaminated fluid from well w/ 3% KCUFIW. RIH 6 stands. RU Eline. RI w/ RST. Log RA tag. Correlate same on depth. Last 24 hrs lost Zero bbls of fluid. __._.__m.._ - _._.___ .n_.m_ n_. ..____._____ ___._.___ ____ _m_ n__._ ...__. .____m. ..__ __mo. . .____.. .._______ ._..__ _.... _.___.n ____ ....___.. .____....__.___._.___ m____·.._________ 9/8/200700:00 - 9/9/2007 00:00 Operations summäry-----------n---.- -----,-----.------------ _________.__________.m__._"'_m._.__.._ Confirm top shot depth. Drop bar @ 0310 hrs. Guns Fired @ 0315 hrs. Perf G zone & Hemlock. Monitor well. Loss 1.5 bbls in 1/2 hr. PU 6 stands. CBU. Monitor well. POOH. Last 24 hrs lost 29 bbls --------- -------- - --- ----------------------- ---- 9/9/200700:00 - 9/10/2007 00:00 operatlOils sumniary·--·--------·-- --- ·._____..___._.·__n .---- -- ..__..m____ Continue POOH w/ TCP guns. Monitor well. LD TCP guns. Conduct BOPE Test. RU ESP running equipment. Last 24 hrs lost 15 bbls of fluid. _. __·____._._m_._._·___._....__..___.._..._m_.__.....__._..____...._____..____.____ .___...._._. .__. __._.___..'___m ___.. __ ____.._._.__.n._.'_n_..__.__m ___.___. .__ __._____,________n.._..__".__.__ 9/10/200700:00 - 9/11/2007 00:00 Operations Summary Spot ESP running equipment and spoolers. PU/MU ESP motors, Pumps, By-pass tubes and "Y" Block. RIH with ESP completion, cable, chemical line bundle and GLM's. _. _____ .____. ___m____·_· ___.n______·______· n___·__..,,______ ______._____m___·.·_______.__.__.________._____.~_~_____., ---~ Zero fluid loss last 24hrs. ____,_..__._.___n_______,__.____ ___m_" _. __.n__. __m_.. .__n.__.___... .___.. ___., _.__._ ._ _... ..__"..____..___·______n____..__....___·.______· ___.....__..___________ -- ..---..---'-- 9/11/200700:00 - 9/12/2007 00:00 Operations Summary ------~------------------------------------ ~_H'^'/~S~ BH~._'~allir1~GLM~a~J)e!GL ~esign, m~~able e~ery_1~00',,- __ ____ _ __ _ .__ _ ______ _ ____ 9/12/200700:00 - 9/13/2007 00:00 Operations Summary~------------------------------------------- Continue RIH w/ ESP/GL completion. MU Tbg hngr. Last 24hrs lost 2 bbls, ----------------_._------~-----_.-..._--_._.__._-._._----_...._-_.._-_..._._-_._~--_._-~-- 9/13/200700:00 - 9/14/2007 00:00 OperationsSunimary--- --- -------- -- -- --- ---- - -- ------- -- ------- ------ Finish MU of tbg hngr. Make penetrator splice and install Chem injection lines @ hngr. Conduct electrical test. Land tubing @ 0425 hrs. Install BPV. ND BOPE. NUTree. Test Same. Clean pits. Prep for rig skid to K-19. - _·__·_·__..._...._______...._.n.._____.__...__...____._._.._..____ __._ __m 9/22/200700:00·9/15/200700:00 Oper8tlOns Summary ---------------- --- -------------- ----.------~--.---- No Operations. Added Cost for ESP_~9uipmen~________________________ ___ ._.__ ________m_ ..___ _....____n __"..________....n__.._n.______._._______..·___ .__ -...----.-.-.- Surface Location: 687' N & 78' Wfr SE cr Sec17 T9N.R13W,SM API#: Well Classificaton: Total Depth: PBTD: Tubing: Prod Pkrs: Producer Well Status: Operator: BHP: SI Chevron 12,600' 12,543' 4-%".12.6#. N-80, BTC 9-5/8" Otis "WD" Wireline Set Pkr 7" Otis "WD" Wireline Set Pkr Ownership: Chevron/PE Spud Date: 1/23/703:30 PM Other: Redrilled April 1970; WO July 1978; WO March 1988; CT CO Sept 1998; CT TCP March 2002 Converted to ESP March 2002 396' Conductor 24 Suface 133/8" 61.0# K-55 12.515" Production 95/8" 47.0# N-80 8.681" Production 95/8" 47.0# P-110 8.681" 2,181' Liner 7 29.0# N-80 6.184" Liner 7 29.0# P-110 6.184" 2,750' 41/2" 12.6# L-80 IBTC 3.958" 33.75' 9,600' TOC 11.321' TOW 2 Depth Lenoth ID 00 FMC Hanger ~ 2 EACH 3/8" NPT Continuous chern. inj port (with pass through 1/4" capillary line) 36.4' 1.00' 3.958" 3.980 type "H" BPV profile ~ One penetrator port 2.274 Mín 1.0. 41/2" 18T top & Bottom. 4-1/2" SFO-2 GLM wI RK Latch 2,684' 9.80' 3.958"1 4-1/2" SFO-2 GLM wI RK Latch 4,311' ::: ¡¡ - 4-1/2" SFO-2 GLM wI RK Latch 5,755' - 4-1/2" SFO-2 GLM wI RK Latch 7,054' 9.79' - 4-1/2" 81'0-2 GLM wI RK Latch 7,808' 9.80' 4-1/2" 81'0-2 GLM wI RK Latch 8,443' 9.79' i 3.958" 4-1/2" SFO-2 GLM wI RK Latch 9,071' ~ Pup Joint, 4-1/2" IBT BxP 10,246' 3.958" 4.500" HES 4-Ÿ2" SSD Sliding Sleeve (Shift Down to Open) 10,253' 4.20' 5.625" Pup Joint, 4-1/2" IBT BxP 10,251' 3.91' Pup Joint, 4-1/2" IBT BxP 10,292' 6.01' 3.958" 4.500" HES 4-Ÿ2" "XN" Profile Nipple wI 3.813" profile 1 0,298' ~ I 4.500" Crossover 4-Ÿ2" IBT Box x 3-%" New VAM Pin 10,309' 0.93' 5.188" Pup Joint 3-1/2" New VAM BxP (Handling pup) 10,310' 2.992" 3.500" "Y"-Tool 9.2# PMJ Double Box w/Cable clip 10,316' 1.40' NA REDA ESP (164 Stage CR-CT 538/540 Pump & 330 hp Tandem Motor) 10,311' 134.73' NA 7.250" Phoenix gauge 10,449 1.84' NA 4.500" 2-0/." By-Pass Tube wI WLEG @ 10461' 10, 143.40' 1.995" 2.750" 7" Otis WD wireline set perm packer (set 3/88) 11.750' Cameo "0" Nipple (WLEG & Nipple possibly fell to btm in 2002) WLEG Zone Top Btm Gun Size SPF Phase Date G·Zone G-06 DST 10,802' 10,830' 28 4.5 4/70, Sqz'd after CST G-1 10,865' 10,895' 30 24.5 4/70, 7/78, 3/88, 11/90, 2/02 G-2 10,920' 10.945' 25 24.5 4/70,7/78,3/88,11/90,2/02 G-2 10,955' 10,994' 39 24.5 4/70, 7/78, 3/88, H 1"""1"" G-3 11,004' 11.050' 46 29.5 4/70,7/78,3/88,11/90,2/02,9/07 G-4 11.056' 11,130' 74 24.5 4/70, 7178, 3/88, 11/90, 2/02, 9/07 G-5 11,195' 11,224' 29 24.5 4/70,7/78,3/88,11190,2/02 G-5 11,232' 11.268' 36 24.5 4/70, 7/78, 2/02 Hemlock Cmt Sqz 11~11,386' 1 6 IE HB-1 11, 11,454' 32 11 7 HB-2 11,471' 1Æ 5 HB-3 11,586' 11 5 '07 HB-3 11,636' 11,660' 24 11 2002, 9/07 HB-4 11,660' 11,702' 42 11 Feb 2002, 9/07 HB-4 11,700' 11.720' 20 6 Feb 2002 HB-5 11.780' 11,790' 10 6 Feb 2002 HB-5 11,799' 11.820' 21 6 Feb 2002 HB·6 11,880' 11,930' 50 6 Feb 2002 HB-7 11.960' 11,975' 15 6 Cmt Sqz 11,985' 11.986' 1 6 April 1970 West Forlands WF-3 12,005' 12,070' 65 20.5 4/70,2/79,11/80,3/88,11/90 WF-4 12,082' 12,105' 23 20.5 4/70,2/79,11/80,<3/88,11/90 WF-4 12,144' 12,190' 46 12.5 4/70, 3/88 WF-4 12,200' 12.245' 45 165 4/70,2/79,11/80, 311!8, 11/90 WF·5 12.250' 12,350' 100 8.5 4/70, 3/88 WF-6 12,360' 12,413' 53 8.5 4/70,2/79,11/80,3/88,11/90 WF-7 12,468' 12,480' 12 45 April 1970 WH 3 4 5 6 7 8 A B C Current Schematic as of 9/13/07 Prepared By: Steve Tyler r1 L__J October 16, 2007 N1r. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99~ 19 SARAhO PAUfU, GOI/ER~OR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 276-7542 ~~~ ~~~ RE: No-Flow Verification Trading Bay Unit K-30, PTD 170-007 Dear Mr. Myers: On .October 12, 2007 an AOGCC Petroleum Inspector witnessed a "no flow test" at __ __ - Unocal's King Salmon platform, Trading Bay Unit Well K-30. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated an initial flow of 600 standard cubic feet per hour, quickly falling to an immeasurable rate while open to atmosphere. well pressure built to approximately 1 psi during the shut-in monitoring period. Subsequent flow tests confirmed the first flow and shut-in results, with well pressures falling to less than 1 psi and gas rate rapidly falling to immeasurable flow. No liquid hydrocarbons were present at surface. The subsurface safety valve may be removed from service in Well K-30 based on this no- flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper Working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon platform. Sincerely, Cathv . Foerster Commissioner cc: Bob Fleckenstein MEMORANDUM TO: Jim Regg (P.l. Supervisor) Petroleum Engineer }~ ~~ r ~~r ~~~~~Y~~, N~~ S 2007 FROM: Lou Grimaldi ~~^~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 12, 2007 SUBJECT: No Flow test TBU K-30 `~ King Salmon Platform Trading Bay Field PTD 1700070 I witnessed a No-Flow test on Chevron's well TBU K-30 aboard the King Salmon platform. The test went well with no fluid produced to surface and the gas flow so low as to be immeasurable. A new 60 psi gauge with 1 psi increments and a Erdco `~ flow meter with a span of 180 scf to 1800 scf were used. i ran ashut-in and b{eed sequence three times with similar results (as noted below). The well appears to meet no-flow criteria. Timr Prasc~ ira (Heil Fln~ro Rata (crfl Comments 0840 <1 600 Flowin to atmos here, o en casin vent valve. Flow at 600 scf 0845 <1 <180 whis er Fiowin to atmos here. Shut-in well. 0900 <1 SI Shut-in for build u . 0905 <1 SI Shut-in for build u . 0935 <1 SI Shut-in for build u . 1020 <1 1100 0 en well to atmos here 1021 <1 800 Flowin to atmos here. 1022 <1 300 Flowin to atmos here. 1023 <1 <180 whis er Flowin to atmos here. 1030 <1 <180 whis er Flowin to atmos here. 1045 <1 <180 whis er Flowin to atmos here. Shut-in welt. 1145 <1 850 Shut-in for build u . O en to atmos here. 1146 <1 250 Flowin to atmos here. 1147 1 <180 Fiowin to atmos here. 1150 <1 <180 whis er Fiowin to atmos here. 1155 <1 <180 whis er Flowin to atmos here. 1200 <1 <180 whis er Fiowin to atmos here. Shut-in well. 1300 <1 600 Shut-in for build u . O en to atmos here. 1301 <1 <180 Flowin to atmos here. 1315 <1 <180 whis er Fiowin to atmos here. 1330 0 <180 whis er Flowin to atmos here. Conclude test. Pagel of 1 No Fiow TBU K-30 10-12-07 LG.xis 10/15/2007 . . Page 1 ofL Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, September 04,20073:16 PM fr ~"1VV\ C\ J~ To: 'Tyler, Steve l' Cc: Buster, Larry W; Brandenburg, Tim C; Nienhaus, Doug R; Harness, Evan Subject: RE: K-30RD Completion Reference Sundry# 307-166 \'\0--0°1 Steve, Nice to have some good news for a change on workovers. I think you were overdue! It appears that you have satisfactorily verified the condition of the 9-5/8" production casing. Good luck with the completion. Tom Maunder, PE AOGCC ._----~----_._--~-- From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Tuesday, September 04,20072:28 PM To: Maunder, Thomas E (DOA) Cc: Buster, Larry W; Brandenburg, Tim C; Nienhaus, Doug R; Harness, Evan Subject: K-30RD Completion Reference Sundry# 307-166 Tom Over the weekend we cleaned out TOl @ 11,216'. Ran a RST log from 10,960 to 6470'. Ran a USIT log from TOl to Surface. Pressure tested 9-%" csg from 2955' to 2600 psi for 30 min. SCANNED SEP 0 7 2007 Analysis of the USIT log indicates our production csg to be in unexpectedly good shape. We followed up with a pressure test to ensure the PC could contain a GO-6 gas influx, if in the event the GO-6 sand cmt sqz gives up. At this time our plan is to run the ESP completion without the ESP pkr as per the attached proposed diagram. Please let me know if you have any questions or concerns. Thanks. Drilling Engineer, Adviser Union Oil Company of California tlOffice: (907) 263-7649 ItCell: (907) 350-6295 9/4/2007 9,568' TOC - 11,327' TOW . . Page 1 of 5 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 23, 200711:52 AM To: 'Tyler, Steve L' Cc: Nienhaus, Doug R; Harness, Evan; Buster, Larry W; KRAMER, TED E; Brandenburg, Tim C Subject: RE: K-30¢ESP WO Sundry #307-166 Procedure Variance \~a-ro\ Steve, We discussed this information yesterday. Adding the casing tests is prudent. I will place a copy of this message in the file. Nothing further is needed. Tom Maunder, PE AOGCC From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Wednesday, August 22,20075:56 PM To: Maunder, Thomas E (DOA) Cc: Nienhaus, Doug R; Harness, Evan; Buster, Larry W; KRAMER, TED E; Brandenburg, Tim C Subject: K-30RD ESP WO Sundry #307-166 Procedure Variance Tom Chevron is proposing the following procedural changes to our K-30RD ESP WO Sundry # 307-166 (Changes are italic in bold red) K-30RD Workover, Basic Plan of Operations 1. Blow down and prepare K-30RO for operations. 2. MIRU Cudd HWOU over K-30RD. 3. Install and test BOPE to 250/3000psi per AOGCC regulations. 4. TOOH with failed ESP completion. 5. PU DP. Mill over and recover abandoned 9 5/8" packer. 6. Clean out wellbore. 7. MIRU ELU. Run USIT & RST logs. 8. Run/set RTTS pkr. Pressure test 9-%" csg to 1000 psi. 9. Add / Reperforate Hemlock and G sands via TCP. 10. Run new "Y" Block ESP completion below ESP pkr. Pressure test pkr to 1,000 psi. 11. NO BOP's, NU tree and test. 12. ROMO Cudd HWOU. SCANNeD AUG 2 8 2007 The changes are to mitigate a low probable failure of the GO-6 gas sand cmt squeeze (10,802'-10,830'), during ESP production of the G & Hemlock oil sands. Attached is a proposed schematic. Please contact me if there are any questions that I can assist you with. 8/28/2007 9,568' Toe 10,570' 10,794' '" '" '" '" <DO - 11,216' TOL 11,327' TOW . 'IT@1f.. ~ f[1HE@n @ ~[V1IÂ1 U llÙ U: liD if LJ:\J LL tf~l Q:~ .~ lrÙ . AI~SIiA OIL A1Q) GAS CONSERVATION COMMISSION / SARAH PAUN. GOVERNOR I / / ¡ 333 W 7th AVENUE, SUITE 100 . .. ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 Timothy Brandenburg UNOCAL PO Box 196247 Anchorage, AK 99519-6247 s{;ANNED JUN 0 7 2001 Re: McArthur River Field, Hemlock Oil Pool, K-30RD Sundry Number: 307-166 vQ1 \ 1{)-' Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ day of June, 2007 Enc!. p~ 6/' ,,11 ~Tì;J~~1LASKA . kro' RECE\VED ALAS OIL AND GAS CONSERVATION COM ON (c.ø MAY 1 7 2007 APPLICATION FOR SUNDRY APPROVALS . C Commission 20 MC 25.280 .. _IIA nil ß GAS ons. 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0" ''''''''''Waiver ~nc"oraQe Other 0 Alter casing 0 Repairwell 0. Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 ( Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ;?1Þ.l>1 Union Oil Company of California Development 0 Exploratory 0 ~ 171>-&>07 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 196247, Anchorage, AK, 99519-6247 50-733-20211-00 , 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 0 No 0 K-30RD - 9. Property Designation:,¡ A.'lÞÞ7 10. KB Elevation (ft): 11. Field/Pool(s): ADL'j)Hf(- /1S"1 1 00' AMSL / McArthur River Field, Hemlock / 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,600 9,867' 12,545 10,152 Casing Length Size MD TVD Burst Collapse Structural Conductor 366 24" 396 396 Surface 2157 13 3/8" 2187 2012 3,090 1,540 Intermediate Production 11293 95/8" 11327 9,043 6,870 4,760 Liner 1382 7" 11216-12598 8953-10201 7,240 5,410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10802-12480 8628-10076 41/2" N-80 10,220 Packers and SSSV Type: NA Packers and SSSV MD (ft): NA Otis 9 5/8 WD, Otis 7" WD 9 5/8 pkr @ 10,500, 7" @ 11750 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 6/15/2007 16. Well Status after proposed work: , Commencing Operations: Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Rose, 907-263-7637 Printed Name Timothy Brandenburg Title Drilling Manager Signature --7 -> e-,Ó Phon Date S; - It¡ - õ--::¡- ¿ - -;7 c1' ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (g(ý)-- /I,/Il Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ~oaOI(<'-\ 'ßOi? \-<:,,~. \}..:>..,".J.=~=~=Y o.aJs~~a \J """"'\{ <J.<s,,,,,, ~~'\> ~C'~~~'X>~~Ù~" ~~~\c.~~c::,.-\ ~~\,.)\~ ~\\"\'" ð~(tfè\:..s.. O\-- ~<L \,\~ ~\.0Ç-"- ~~ ~~C\-'t:)~ Subsequent Form Required: \r\Ü~ , ~MMISSIONER APPROVED BY Date:6-1-ðr Approved by: THE COMMISSION Form 10-403 Revised 06/2006 t]/kCJß1 N Submit in ~Plicate ~ Ç;'-. ~-,D'" AL . . Chevron ., Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com RECEIVED MAY 1 7 Z007 May 11, 2007 Alaska Oil & Gas Cons. Commission Anchorage Commissioner Alaska Oil & Gas Conservation Commission 333 W. ¡th Avenue Anchorage, Alaska 99501 Re: King Salmon Platform, Well K-30RD, PTD 70-0007-0, API 50-733-20211-00 Dear Commissioner, Chevron intends to work over the above referenced well to recover a failed ESP, remove an abandoned packer, add perforations and reinstall a new ESP completion. /Please see the attached documents for additional information. Please review and approve the Application for Sundry Approvals at your earliest convenience. Please contact Jim Rose at 907-263-7637 if you have any questions. Sincerely, ---z~ C.þ Timothy C. Brandenburg Drilling Manager ;7 Attachment: BOP Sketch Choke Manifold Sketch K-30 ESP WO, Basic Plan of Operations Current Well Sketch Form 10-403 in duplicate Cc: File Union Oil Company of California I A Chevron Company Page 1 of 1 A 21/16" 5M HCR Valve B 21/16" 5M Manual gate valve C :2 1/16" 5M Manual gate Kill line D 21/16" 5M Manual gate Kill line E 3 118" 5M Target Tee F 21/16" 5M Target Tee G 13 5/8" 5M x 13 5/S" 5M # 13 Hub 5/12/2007 Top of drill deck JAR K-30R 3 1/8" 5000 PSI Choke Manifold 2" to Production Separator or Gas Buster Bypass to Vent 3" 5M National Ball Valves þ 2", 5M, Flanged, Hose From Choke Line Side of Drilling Spool . . Chevron 11:I King Salmon Platform Well K-30RD ESP Replacement Workover 2007 K-30RD Workover, Basic Plan of Operations 1 . Blow down and prepare K-30RD for operations. 2. MIRU Cudd HWOU over K-30RD. 3. Install and test BOPE to 2S0/3000psi per AOGCC regulations. 4. TOOH with failed ESP completion. 5. PU DP. Mill over and recover abandoned 9 5/8" packer. 6. Clean out well bore. 7. MIRU ELU. Run RST log. / 8. Add I Reperforate Hemlock and G sands via TCP. 9. Run new "Y" Block ESP completion. 1 O. ND BOP's, NU tree and test. 11. RDMO Cudd HWOU. .. 2,187' AND DETAIL SIZE WT GRADE CONN m TOP BTM. 13-3/8" 61.0 K-55 12.515 34' 2187 9-5/8" 47 N-80 & P-110 BTC/LTC 8.681 34' 11,327 T' Liner 26,29 N-80 & P-110 BTC 6.184 11,216 12,578 Tubin2: 4-112" 12.6 N-80 BTC 3.958 35 10,230' DETAIL 12" X 4-112" OCT type "UH-TC-IA" Butt TbgHngr 1. 2607 4802 5999 6880 7582 8126 8669 9181 10,220' 3 10,230' 4. 10342' 4 5. 10,500' 6. ¡ 1750' 10,500' 5 11,216' 11,327' 11,750' 7" WD Pkr tail possibly fell off during perf job 2/02. LAST TAG @ 12,375' w/2.70' GR on 4/26/94 4-112" SFO-2 GLM wi RK Latch 4-112" SFO-2 GLM wI RK Latch 4-112" SFO-2 GLM wI RK Latch 4-112" SFO-2 GLM wI RK Latch 4-112" SFO-2 GLM wI RK Latch 4-1/2" SFO-2 GLM wi RK Latch 4-112" SFO-2 GLM wi RK Latch 4-112" SFO-2 GLM wi RK Latch Pup Joint 4-112" x 10' Centrilift ESP (213 Stage GC6100 Pump & 418 hp KMH Motor) Phoenix gauge 9-5/8" Otis WD wireline set perm packer (set 3/88) 7" Otis WD wireline set perm packer (set 3/88) 3.958" 3.958 .~ 'ATION nATA TOP JIT.M. ZONE SPF DATE 10802 10830 GO-6 4 4/70 Saueezed DST 10865 10895 G-l 6-18 4/70, 7/78, 3/88, 11190, 2/02 Existing 10920 10945 G-2 6-18 4/70, 7/78, 3/88, 1lI90, 2/02 Existing 10955 10994 G-2 6-18 4/70, 7/78, 3/88, 11190, 2/02 Existing 11018 11050 G-3 6-18 4/70, 7/78, 3/88, 11190, 2/02 Existing 11065 11130 G-4 6-18 4/70, 7/78, 3/88, 11/90, 2102 Existing 11195 11224 G-5 6-18 4/70,7/78,3/88, 11/90,2/02 Existing 11232 11268 G-5 8 4/70, 7/78, 2/02 Existing 11385 11385 N/A 4 4/70 Saz Perfs 11412 11440 HB-l 6 2/02 CT TCP'd 11636 11660 HB-4 6 2/02 CT TCP'd 11671 11690 HB-4 6 2/02 CT TCP'd 11700 11720 HB-4 6 2/02 CT TCP'd 11780 11790 HB-5 6 2102 CT TCP'd 11799 11820 HB-5 6 2/02 CT TCP'd 11880 11930 HB-6 6 2/02 CT TCP'd 11960 11975 HB-7 6 2/02 CT TCP'd 11985 11985 N/A 4 4/70 SqZ Perfs 12005 12070 WF-3 4-20 4/70,2/79, 11180,3/88, 11190 Existing 12082 12105 WF-4 8-16 4/70,2/79, 11180,3/88, 11190 Existing 12144 12190 WF-4 4-12 4/70, 3/88 Existing 12200 12245 WF-4 4-16 4/70, 2/79, 11180,3/88, 11190 Existing 12250 12350 WF-5 4-12 4/70, 3/88 Existing 12360 12413 WF-6 4-20 4/70, 2/79, 11180, 3/88, 11190 Existing 12468 12480 WF-7 4 4/70 Existing PBTD::: 12,552' TD::: 12,600' MAX HOLE ANGLE::: 43.750 @ 3943' , C:\Documents and Settings\roseji\Desktop\K30RD\K-30rd Actual Dwg 3-13-02 Rev1.doc REVISED: 5/1l/07 BY: JAR K-30RD Perforated interval . . Steve please see the attached spread sheet identifying the perforating planned in the K-30RD well. If you have any questions, please let me know. Jim Content-Description: K-30RD Perfs.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 5/25/2007 4:46 PM . . K-30RD ESP WO 2007 Perf Intervals, DIL G-3: 11023' - 11043' MD REPERF (20') G-4: 11075' - 11120' MD REPERF (45') HK2: 11495' -11590' MD NEW (95') HK3: 11605' -11636' MD NEW (31') HK3: 11636'-11646'MD REPERF(10') HK4: 11660' - 11671' MD NEW (11') HK4: 11671' - 11690' MD REPERF (19') HK4: 11690' -11700' MD NEW (10') HK4: 11700' - 11720' MD REPERF (20') e e ,,1 / ,; 1 ¡ / I I AItASIiA OILAlQ) GAS ! CONSERVATION COMMISSION / FRANK H. MURKOWSKI, GOVERNOR / 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 \10/001 Re: McArthur River Field, Hemlock Oil Pool, K-19 Sundry Number: 306-194 . '~'fi ¡"- f" ."fA \\'I~"t~ "" ::2ì"~ ",,'" ~. Ii ?Njtj .,-- ,-;:::-:-..... Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thiS~ day of June, 2006 Encl. Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB toTubing Head = 33.75' 8. Property Designation: King Salmon Platform/Cook Inlet 11. 1. Type of Request: Total Depth MD (ft): 12,600 . Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): See Attached Schematic Packers and SSSV Type: {)Tj 6/' 9/k J:Kl::lA:'1 V t:.LJ STATE OF ALASKA ALAe OIL AND GAS CONSERVATION COMMeO . (¡¡{~UN 0 5 2006 APPLICATION FOR SUNDRY APPROVAIsti Oil & G C C " 20 MC 25.280 as ons. ornmtsslon Abandon Suspend Repair well D Pull Tubing 0 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Other .¡ Stimulate D Time Extension D Run Replacement Re-enter Suspended Well D ESP 5. Permit to Drill Number: Development 0 Stratigraphic D Exploratory D 70-0007-0 ,70D07c> -i~ .ò"" Service D 6. API Number: 50-733-20211-00 ~ 9. Well Name and Number: Total Depth TVD (ft): 10,203' Length McArthur River Field/Hemlock, G Sands, West Foreland PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,543' 10,152' n/a 12,375' Size MD TVD Burst Collapse 2,157' 11 ,297' 13-3/8" 9-5/8" 2,012' 9,043' 3,090 psi 6,870 psi 1,540 psi 4,750 psi 2,187' 11 ,327' 1,382' 10,201 ' Tubing Grade: 8,160 psi 7,020 psi Tubing MD (ft): L-80 10,546' 9-5/8"@ 10,500', 7" @ 11,750' 7" 12,598' Tubing Size: Perforation Depth TVD (ft): See Attached Schematic 9-5/8" & 7" Otis WD Perm Packer 4-1/2" Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry W. Buster 263-7853 Printed Name Timothy C. Brandenburg Title Drilling Manager 13. Well Class after proposed work: Exploratory D Development 0- 15. Well Status after proposed work: 7/1/2006 Oil 0 Gas D Plugged D WAG D GINJ D WINJ D WDSPL .¡ Service D Abandoned D D Date: Signature . Phone 907-276-7600 Date COMMISSION USE ONLY ,-z-~ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test ..~ Mechanical Integrity Test D Location Clearance D O\,~h"'t--~\"Q~~ ""..' (U~.~Q\.Ä ¡.-~\)roC! ~'-~\a~ ~S\ ~..cy\)\\tÛ ~ '"\ -\-\.,. '\ ú'.. ''-\ 9 0- 'i <> c-Ç ~~~ ~ Other: ~OOO ~Š, ~t)V ~S-\ 0.. ~ 1>\0. ESY \..~,\Lo~~, Subsequent Form Required: ~O \..... Approved by: APPROVED BY THE COMMISSION Date: RBDMS BFL JUN 1 3 2006 Form 10-403 Revised 07/2005 '1'7 chevron === e e King Salmon Platform Well K-30RD ESP Workover OBJECTIVE: Pull the existing ESP assembly. Recover existing 9-5/8" and 7" production packers. Clean-out . the casing as required. Run replacement ESP assembly. PROCEDURE SUMMARY: 1. Shut off gas lift gas and bleed pressure off annulus. 2. Rill and punch holes in tubing just above the ESP. 3. Circulate well with 3% KCL in Filtered Inlet Water. 4. Set BPV and N/D tree on Well K-30RD. N/U BOPE and CUDD HWOU. Test 13-5/8" BOPE (see attached diagram) to 250/3,000 psi. 5. Circulate well with 3% KCL in Filtered Inlet Water and pump sized salt LCM pill if required. 6. POH w/ existing completion. 7. M/U packer recovery assembly. Rill and recover 9-5/8" production packer. 8. MIU packer recovery assembly. RIH and recover 7" production packer. 9. Make clean-out run into the 7" casing if required. 10. Spot LCM pill if required and POOH. 11. RJU and run ESP assembly on 4-1/2" tubing c/w gas lift mandrels to +/- 10,600'. 12. Install BPV. RID CUDD HWOU. N/D BOPE. N/U and Test Tree. AOGCC K-30RD ESP WO Summary 10fl May 26, 2006 2,187 T~ Liner BTC/LTC BTC 11,327 12,578 12.6 N-80 3.958 10,230' BTC 35 12" X 4-1/2" OCT type "UH- TC-IA" Butt Tog Hnge 1. 2607 4802 5999 6880 7582 8126 8669 9181 10,220' 3 10,230' 4. 10342' 4 5. 10,500' 6. 11750' 10,500' 5 11,216' 11,327' 11,750' 7" WD Pkr tail possibly fell off during perf job 2/02. LAST TAG @ 12,375' w/2.70" GR on 4/26/94 4-l/2" SFO-2 GLM w/ RK Latch 4-112" SFO-2 GLM w/ RK Latch 4-1/2" SFO-2 GLM w/ RK Latch 4-1/2" SFO-2 GLM w/ RK Latch 4-1/2" SFO-2 GLM w/ RK Latch 4-1/2" SFO-2 GLM w/ RK Latch 4"1/2" SFO-2 GLM w/ RK Latch 4-1/2" SFO-2 GLM w/ RK Latch Pup Joint 4-1/2" x 10' CentriJift ESP (2 I 3 Stage GC6 I 00 Pump & 4 18 hp KMH Motor Phoenix gauge 9-5/8" Otis WD wireIine set perm packer (set3/88) T' OtisWD wireIine set perm packer (set 3/88) 3.958" 3.958 TOP BTM ZONE DATE 10802 10830 GO-6 4/70 SQueezedDST 10865 10895 G-l 4/70,7178,3/88, 1 l/90, 2/02 Existing 10920 10945 G-2 6-18 4/70,7/78,3/88, 11/90,2/02 Existing 10955 10994 G-2 6-18 4/70,7/78,3/88, 11/90,2/02 Existing 11018 11050 G-3 6-18 4/70,7/78,3/88, 11/90,2/02 Existing II 065 11130 G-4 6-18 4/70, 7/78,3/88, lJ/90, 2/02 Existing II 195 Jl224 G-5 *8 4/70, 7/78, 3/88, 11/90, 2/02 Existing 11232 11268 G-5 4/70,7/78,2/02 Existing 11385 11385 N/A 4/70 5Qz Peds 11412 11440 HB-l I 6 2/02 2T TCP'd 11636 11660 HB-4 6 2/02 2T TCP'd 11671 11690 HB-4 6 2/02 CT TCP'd 11700 11120 HB-4 6 2/02 ·1 ~t'(J 11780 11790 HB-5 6 2/02 CT TCP'd 11799 11820 HB-5 6 2/02 CT TCP'd 11880 11930 HB-6 6 2/02 .1 ..,1" (J 11960 11975 HB-7 6 2/02 CT IU:'"( 11985 11985 N/A 4 4/70 SqZ Perfs 12005 12070 WI'-3 4-20 4/70,2/79, 11/80,3/88, l1!90 Existing 12082 12105 WI'-4 8-16 4/70,2/79, Il!80, 3/88, Il!90 Existing 12144 12190 WF-4 4-12 4/70, 3/88 Existing 12200 12245 WI'-4 4-16 4/70, 2/79, 11180, 3/88, 11/90 Existing 12250 12350 WF-5 4-12 4/70, 3/88 Existing 12360 12413 WI'-6 4-20 4/70,2/79, 11/80,3/88,11190 Existing 12468 12480 WI'-7 4 4/70 Existing PSTD = 12,543' TD = 12,600' O:\DRiI~~i!]~1K.4î'1.g~a@l~-30\K30RD _ESPWO_AFE _ XXXXXX\Program\K-30rd Actual Dwg 3"] 3-02 Rev] .doc REVISED: 5/1/06 BY: JHM 61.0 K-55 47 N-80 & P-110 BTC/LTC 7" Liner 26,29 N-80 & P-II0 BTC 2,187 12.6 N-80 BTC 3.958 10,600' 1 3 4 11,216' 11,327' 7" WD Pkr tail possibly fell off during perf job 2/02. LAST TAG @ 12,375' w/2.70" GR on 4/26/94 PBTD = 12,543' TD = 12,600' MAX HOLE ANGLE = 43.75° @ 3943' , x 4-112" OCT type "UH·TC-1A" Butt TbgHngr 2. 3. 4. TBD TBD TBD TBD TBD TBD TBD TBD 10,450 10,500 10,600 4-1/2" SFO-2 GLM wi RK Latch 4-1/2" SFO-2 GLM wi RK Latch 4-1/2" SFO-2 GLM wi RK Latch 4-1/2" SFO-2 GLM wi RK Latch 4-1/2" SFO-2 GLM wi RK Latch 4-1/2" SFO-2 GLM wi RKtatch 4-112" SFO-2 GLM wi RK Latch 4-112" SFO-2 GLM wi RK Latch XN Nipple Centrilift ESP Phoenix gauge T.O.P BTI\'I ZONE PI? nATIi: 10802 10830 GO-6 4/70 S""PP7",APlQ,., 10865 10895 G-1 6-18 4/70, 7/78, 3/88, 11/90,2/02 Existing 10920 10945 G-2 6-18 4/70,7/78,3/88, 11/90,2/02 Existing 10955 10994 G-2 6-18 4/70, 7/78,3/88, 11/90,2/02 Existing 11018 11050 G-3 6-18 4/70, 7/78, 3/158, 11/90,2/02 Existing I 11065 11130 G-4 Existing I 11195 11224 G-5 6- ¡ 8. 0, 7/78, 3/88, 11/90, 2102 Existing I 11232 11268 G-5 8 0,7/78,2/02 Existing ~ 11385 N/A 4 0 S< : Pens 11412 11440 HB-I 6 2 1L1"'0 11636 11660 HB-4 6 I\..-t" 0 11671 11690 HB-4 6 TCP'd 11700 11 720 HB-4 6 .1\,01' µ 11780 11790 HB-5 6 ·l\,oYO 11799 11820 HB-5 6 CT TCP'd 11880 11930 HB-6 6 2/02 "- 'u 11960 11975 HB-7 6 2/02 \,0 \,01 U 11985 11985 N/A 4 4/70 SQZ ~erfs 12005 12070 WF-3 4-20 4/70,2/79, 11/80,3/88, 11/90 Exist :íng 12082 m05 WF-4 8-16 4/70,2/79, 11/80,3/88, 11190 Exist :ing 12144 12190 WF-4 4-12 4/70, 3/88 Existing 12200 12245 WF-4 4-16 4/70,2/79, 11/80,3/88, 11/90 Existing 12250 12350 WF-5 4-12 4/70, 3/88 Existing 12360 12413 WF-6 ~ 4/70,2/79, 11/80,3/88, 11/90 ExistiTI!! 12468 12480 WF-7 4/70 Existing · Test Pressure: 250/3000 psi 3 1/1ô"5M x 41/1S"SMDSA TOp Deçk A 41/16" 5M Foster HCR Valve B 41/16" 5M Manual gate valve C 31/16" 5M Manual gate Kill line D 31/16" 5M Manual gate Kill line GralockHub 55" 34" 27" ¡ 14" 10.90' 12.67' MEMORAND('uM TO: Randy Ruedrich, Commissioner THRU' Regg/Maunder, ~. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission ~ DATE: August 20, 2003 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector No-Flow Test Unocal King Salmon, K-30 Trading Bay Unit PTD 170 0070 NON-CONFIDENTIAL Wednesday, Au_qust 20, 2003: I witnessed a No-Flow verifiCation on the King Salmon Platform platform, well #K-30 in the McArthur River field. Following is a timeline and well status during test. 0710 Well flowing to atmosphere at less than 1 psi & less than180 scf, no fluid. 0715 Shut-in well. 0815 SITP 1 psi, open well to gas flow gauge, initial flow @ 1700 scl down to <180 scl in 2 minutes. 0820 Shut-in well @ 0 psi 0916 SITP 1 psi, open well, initial flow @ 1700 scl down to <180 scf in 1 minute. 0921 Shut-in well @ 0 psi 1040 SITP 2 psi, Open to atmosphere. Flow initially 1800 scl, down to <180 scl in 2 minutes 1045 Shut-in well @ 0 psi. 1245 Shut-in @ 3 psi. Open to Flow meter, initial flow @ 1800 scl down to < 180 scl in 3 minutes. Down to whisper in 5 minutes total. Observe for 15 minutes in this state. 1305 Ended test, turn well over to production. Note: The gauge used to check flow was incapable of measuring below 180 scf or above 2000 scf. 100-psi gauge used to check tubing pressure. Zero flow indicated by hose in bucket. This well exhibited inability to flow to surface unassisted and I recommend it be granted No- Flow status. I explained to Dave Condon (Platform Lead Operator) that any cleanout, perforating or other stimulation would require another No-Flow test. SUMMARY: I witnessed No-Flow verification on UNOCAL's King Salmon platform well #K-30 in the McArthur River field. NON-CONFIDENTIAL CC; Dwight Johnson (Unocal), (platform) SCANNED SEF 0 8 200'3 2003-0820_NooFlow_TBU_K-30_lg.doc ~l~k OILANDGAS CONSI~RYATIO~ COMMISSIO~ / i / :: .., Dwight Johnson Field Superintendent Unocal 260 Caviar Street Kenai, Alaska 99611 August 21, 2003 FRANK H. MURKOWSKI, GOVERI~IOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: No-Flow Verifications McArthur River Unit Well K- 13RD2, PTD 201-046 Well K-30, PTD 170-007 Dear Mr. Johnson: On August 20, 2003, AOGCC Petroleum Inspector Lou Grimaldi witnessed "no flow tests" on Unocal's McArthur River Unit, King Salmon Platform, Wells K-13RD2 and K- 30. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy. Both wells produced short duration, low volume gas that quickly diminished; the sustained gas rates were less than APl leakage criteria for subsurface safety valves (900 SCF per hour). No liquid hydrocarbons were produced to surface during the tests. Based on the results of these no-flow tests, subsurface safety valves may be removed from service in Wells K-13RD2 and K-30. These wells must continue to be equipped with fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow, maintained in proper working condition, and tested as required in 20 AAC 25.265. If for any reason either well becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. Please retain a copy of this letter on the King Salmon platform. Sincerely James B. Regg [ I Petroleum Inspection Supervisor cc: Bob Fleckenstein STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 100' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit/ P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: McArthur River Field 4. Location of well at surface 8. Well number King Salmon Platform - Leg #1, Slot #2, 678' FSL, 78' FEL, Sec 17, T9N, R13W, SM K-30 At top of productive interval 9. Permit number/approval number 1081' FSL, 1634' FEL, Sec 21, T9N, R13W, SM 70-0007-0 At effective depth 10. APl number 322' FSL, 1364' FEL, SEC 21, T9N, R13W, SM 50- 733-20211-00 At total depth 11. Field/Pool 301' FSL, 1359' FEL, SEC 21, T9N, R13W, SM McArthur River Field / Hemlock 12. Present well condition summary Total depth: measu red 12600' feet Plugs (measu red) true vertical 10203' feet Effective depth: measu red 12545' feet Junk (measu red) 12427' - 12545' true vertical 10152' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 366' 24" Pile Driven 396' 396' Surface 2157' 13-%" 1490 sx Class G 2187' 2012' Intermediate Production 11297' 9-%" 1000 sx Class G 11327' (window) 9043' Liner 1382' 7" 225 sx Class G 11216'- 12598' 8953'- 10201' Perforation depth: measured See Attached Sheet true vertical See Attached Sheet Tubing (size, grade, and measured depth) RECEIVED 4-1/2", 12.6#, L-80 @ 10,230' Packers and SSSV (type and measured depth) 118' long ESP @ 10,230', Otis 9-%" pkr set @ 10500', Otis 7" pkr set @ 11750' .. lJ lt~.l 13. Stimulation or cement squeeze summary Naska Oil & Gas Cons. C0mm ss o Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 206 BOPD 320 Mcfpd 1954 BWPD 1100 psi 80 psi Subsequent to operation 300 BOPD 390 Mcfpd 2300 BWPD 70 psi 50 psi 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: ~ ~ SUBMIT IN DUPLICATE Form 10-404 Rev 061/~5/88 0 R I Gl ~! ~ t K-30RD Perforations Zone GO-6 G-1 G_2~ G-2L G-3 G-4 G-5 G-5 Top 10,802' 10,865' 10,920' 10,955' 11,018' 11,065' 11,195' 11,232' MD Btm Amount 10,830' 28' 10,895' 30' 10,945' 25' 10,994' 39' 11,050' 32' 11,130' 65' 11,224' 29' 11,268' 36' Top 8,628' 8,676' 8,718' 8,743' 8,789' 8,823' 8,936' 8,966' TVD Btm 8,649' 8,699' 8,736' 8,772' 8,812' 8,870' 8,960' 8,995' Amount 21' 23' 18' 29' 23' 47' 24' 29' HB-1 HB-4 HB-5 HB-6 HB-7 11,412' 11,440' 28' 11,636' 11,660' 24' 11,671' 11,690' 19' 11,700' 11,720' 20' 11,780' 11,790' 1 O' 11,799' 11,820' 21' 11,880' 11,930' 50' 11,960' 11,975' 15' 9,124' 9,320' 9,352' 9,378' 9,449' 9,466' 9,539' 9,610' 9,148' 9,342' 9,369' 9,395' 9,458' 9,485' 9,583' 9,624' 24' 22' 17' 17' 9' 19' 44' 14' WF-2 WF-3 WF-4 WF-4 WF-4 thru 6 WF-7 Basal WF 12,005' 12,082' 12,144' 12,200' 12,250' 12,468' 12,500' 12,070' 65' 12,105' 23' 12,190' 46' 12,245' 45' 12,413' 163' 12,480' 12' 12,545' 45' 9,644' 9,714' 9,77O' 9,820' 9,866' 10,065' 10,094' 9,703' 9,734' 9,811' 9,861' 10,015' 10,076' 10,203' 59' 20' 41' 41' 149' 11' 109' 1'fading Bay [nit King SMm(m PLatform Well # K-30RD Actaal Campletion 3/t 3/02 RKB to TBG Head = 33.75' Tree connection: 10,500' 11,216' 11,327' 4 11,750' Pkr tail fei off during per~ job 2/02 PBTD = 12,543' TD = 12,600' MAX HOLE ANGLE = 43.75° @ 3943' ESP Cable N-80 1 0SOLBC 5KV 90 FI3 185 GAl ~,/(2) 0375" 5;5; I 611' X [ FUBES-GAL-R 2361" .[ 3375 I 2607 5999~] 4-1/2" SFO-2 GLM w: RK t~tch 6880 ] ~ 4-1/2" SPO 2 GLM w' RK ~ttch 8126 ! [ 4 I/2"SFG-2GLM x;/ RK Lalch I 4-1/? SFO-2 GLM w RK Latch 4d/2" SFO--2 GLM RK latch Pup Joint 4 1,2" x 10' Centrilit't ESP Pump & Motol BIIA Length=l I822' Otis WD 55/8" ~ir¢line set perm packer PERFORATION DATA 11652 K-30rd Actual Dwg 3-13-02 REVISED: 5,"31,,'02 'l~t:3r. I~d~fl~14,1q:/Ot IT,/I I~lil[kLff~JliCal.y VV(:IIVt:~I ti,Fi &tj J'ti"l,V &V.&q,,~d'! i'~lll~l vgUil~'l! VV'~II Subject: Re: Request for Temporary Waiver of 20 AAC 25.265, King Salmon Well K-301~B Date: Thu, 07 Mar 2002 10:33:41 -0900 From' Tom Maunder <tom_maunder@admin.state.ak. us> TO: "Bowen, Jerry -Alaska" <jbowen@unocai.com> \ ~ ~ --[~)(~ ~ CC: "Martinez, Steve" <smartinez@unocal.com> Jerry, Your request is appropriate. It is likely that the well performance will decline to allow the well to meet the no-flow criteria. The performed test shows that the well will not produce liquid. In the final surface hook up, a surface safety valve in concert with the pump electrical shutdown will be employed which will ensure that the production can be halted should the need arise. Your plan is acceptable. Good luck with the workover. Tom Maunder, PE AOGCC "Bowen, Jerry -Alaska" wrote: Tom; With reference to our telephone discussion this morning, Unocal respectfully requests a temporary waiver of Regulation 20 AAC 25.265 for King Salmon Well K-30~. As you are aware, AOGCC representative Jeff Jones witnessed our No-Flow Test attempt on March 4, 2002. After being bled down for approximately one day, the subject well continued to bleed wet gas at a reported rate of 1200 SCF/hr, which is more than the maximum allowable rate of 900 SCF/hr. The well has stabilized and is still bleeding gas at approximately the same rate almost two days after it was first shut-in. Well K-3ORD produced from the G-Zone and West Foreland since it was first completed in 1988. Perforations were added in the Hemlock Benches 1, 4, 5, 6 & 7 in early February 2002 (AOGCC 10-403 approval #302-039). Apparently we were fortunate in that the Hemlock reservoir was not yet completely watered out in the vicinity of well K-3ORD, and the oil cut on gas lift has ranged from 20% to 27% since adding the Hemlock perforations (the well tests results vary from test to test). Immediately prior to shutting the well in two days ago, the well produced approximately 3300 BFD with 660 to 900 BOPD on gas lift. The well is located relatively high on the structure, and is surrounded by other Hemlock producers (please refer to attached structure map). The nearest Hemlock producer, well K-17, is located approximately 500' away. It produces with a 96% watercut, and it passed a No.Fiow test on 11/13/01. Although the well has a higher oilcut than nearby wells, the well's flowrate is almost Iow enough to pass the No-Flow Test at this time. The oilcut is expected to decrease relatively quickly based on similar expe#ences with other TBU wells, once ESP production is initiated. We are confident that well K-3OR~ will pass the No-Flow test after the reservoir is drawn down by ESP production at a rate of 5000+ BFPD, and after I of 2 3/7/02 10:34 AM Re: Reqtest for Temporary Wah~er of 20 > the water-cut has increased ~u the more typical 90% range. Unocal would > prefer to perform a No-Flow Test at the first convenient opportunity (i.e. > whenever we have a platform shutdown, an electrical problem, etc.), if > necessary, we will agree to shut down the ESP and conduct a No-Flow test > after a specified period of production time. Please advise if additional information is required or if additional discussion is warranted. Thanks. Jerry F. Bowen, P,E. Sr. Advising Drilling Engineer Office: g07.263.7640 Cell: 907-360-2490 Home: 907.688.2278 Fax: 907-263-7884 < <K3ORD_HKT. jpg> > Name: K3ORD_HKT. jpg K3ORD_HKT. jpg Type: JPEG Image (image/jpeg) Encoding: base64 Tom Maunder <tom maunderC'~admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 3/7/02 10:34 AM K-,30R[: ?, ? I ? / I ? 27-Jan-02 6-Feb-02 7-Feb-02 8-Feb-02 King K-30RD Daily Report of Operations b 6 to Feb. 12, 2002 & March 8 to March 13, 2002 Off load CT equipment from boat. CT equipment released to Phillips. Backload CT equipment on boat. Off load CT equip, from boat, spot coil equipment. RU CT equip. Function test BOP equip. Continue RU of CT equip. PU/MU Dummy gun/Memory BHA. RIH to 10,574'. Unable to work CT pass. POOH LD Memory tool. RIH w/Dummy Gun BHA. RIH to 10,581'. Pushed through w/5-6k down weight. Set down @ 11,171'. Worked through. RI to 12,000'. POOH. PU/MU Memory logging tool. RIH to 12,000'. POOH. PU/MU TCP gun. RIH. correct depth @ flag. 9-Feb-02 10-Feb-02 On depth @ 11,862'. Drop ball. Fire gun w/well on gaslift. POOH LD TCP gun #1. PU/MU TCP gun #2. RIH looking to No-Go in XO below pkr @ 11,750'. RI to 12,176' w/o setting down in pkr. POOH. LD TCP guns. PU/MU Memory Logging tools. RIH logging to 11,820'. flag CT @ 10,800'. POOH. LD memory logging tools. PU TCP Gun #2. RIH past flag @ 10800'. PU to flag. Made correction. RIH then PU to top shot depth @ 11617'. Drop ball fire guns. POOH. LD perf guns. PU/MU TCP Gun #3. RIH to flag @ 10800' correct depth. RI & PU to top shot depth @ 11178'. Drop ball, fire guns. POOH. LD TCP guns. 11-Feb-02 Work on closing SSSV. PU/MU Memory logging tools. RIH logging to 11000'. POOH to SSSV. Wash across SSSV. POOH. LD memory tools. PU TCP Gun #4. RIH made depth corrections. Place top shot @ 10856'. Drop ball. Fire guns. POOH. 12-Feb-02 8-Mar-02 9-Mar-02 POOH. LD TCP Gun #4. RD Coil. Turned well over to production. Release coil. RU pump lines to' K-30 tree. Pump 120 bbls of 3% KCI/FIW down tbg. Pump 55 bbls down annulus. RD pump lines. RU APRS. RIH w/tbg punch gun. Perf tbg f/1076' to 10478'. POOH. RD APRS. RU pump 684 bbls down tbg, take return up annulus. RD lines. ND tree. NU & test BOPE. 10-Mar-02 Finished BOPE test. Pump 14 bbls down tbg. Pulled BPV. MU land jt. Pull tbg hngr free. Worked seals out of pkr. LD tbg hngr. Trip out LD 4-1/2" tbg. 11-Mar-02 Finished POOH & LD 4-1/2" completion string. Tested blind rams. RU ESP running equip. PU ESP BHA. Fill "V" door w/4-1/2" pipe. 12-Mar-02 PU 4-1/2" tubing & RIH w/ESP BHA. 13-Mar-02 Continue RIH w/ESP completion on 4-1/2" tbg. MU tbg hngr. Made splice. RI land hngr w/top of ESP @ 10,230'. ND BOPE. NU tree test to 5k psi. NU wing valves. Release rig. 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: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate': X Other: Convert to ESP 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Alaska Development: X 100' above MSLfeet 3. Address Exploratory: 7. Unit or Property name PO Box 196247 Stratigraphic: Trading Bay Unit Anchroage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number King Salmon Platform - Leg #1, Slot #2, 678' FSL, 78' FEL, Sec 17, T9N, R13W, SM K-30RD At top of productive interval ~). Permit number 1081' FSL, 1634' FEL, Sec 21, T9N, R13W, SM _ 70-0007-0 At effective depth 10. APl number 322' FSL, 1364' FEL, SEC 21, T9N, R13W, SM 50- 733-20211-00 At total depth 11. Field/Pool 301' FSL, 1359' FEL, SEC 21, T9N, R13W, SM McArthur River Field 12. Present well condition summary Total depth: measu red 12600' feet Plugs (measu red) true vertical 10203' feet Effective depth: measured 12545' feet Junk (measured) 12427' - 12545' true vertical 10152' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 366' 24" Pile Driven 396' 396' Surface 2157' 13-%" 1490 sx Class G 2187' 2012' Intermediate Production 11297' 9-%" 1000 sx Class G 11327' (window) 9043' Liner 1382' 7" 225 sx Class G 11216'- 12598' 8953' - 10201' Perforation depth: measured .See Attached SheetRECEIVED true vertical See Attached Sheet Tubing (size, grade, and measured depth)JAN :Z 5 Z00 4-1/2", 12.6#/ft, L-80 @ 10546' Packers and SSSV (type and measured depth) Alaska 0il & Gas Cons. C0mmJssi0n 1 - Otis 9-%" set @ 10500', 1 - Otis 7" set @ 11750', I - Camco TRDP-1A SSSV @ 297' Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: ,,, 14. ~'n~ated date for commencing operation 15. Status of well classification as; ~/25/2,002 16, If~posal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: 17. I hereb~v,E~ify that tl~ forC~g~ ~g~ is true and correct to the best of my knc~4vledge. I . Signs '~¢Ajl .~/~/,~Y~v/~~ A Title: //~/4~/.~//,/¢/,,~ ~///~/ Date/""~¢""~.2 .... · ," v' ..... FOR COI~'S/¢'S'~; 0~F__//ON[.Y Conditions of approval: Notify Commission so representative may witness/ ~ I Approval No. Plug integrity.__ BOP Test Location clearance.--rI ~)'~'~ ~q Mechanical Integrity Test Subsequent form required 10- L~O Approved by order of the Commissioner ~-~a~l!t."e~,~..~, Commissioner Date K-30RD Perforations Zone GO-6 G-1 G-2 G-2L G-3 G-4 G-5 G-5 MD Top Btm Amount 10,802' 10,830' 28' 10,865' 10,895' 30' 10,920' 10,945' 25' 10,955' 10,994' 39' 11,018' 11,050' 32' 11,065' 11,130' 65' 11,195' 11,224' 29' 11,232' 11,268' 36' Top 8,628' 8,676' 8,718' 8,743' 8,789' 8,823' 8,936' 8,966' TVD Btm 8,649' 8,699' 8,736' 8,772' 8,812' 8,870' 8,960' 8,995' Amount 21' 23' 18' 29' 23' 47' 24' 29' WF-2 WF-3 WF-4 WF-4 WF-4 thru 6 WF-7 Basal WF 12,005' 12,082' 12,144' 12,200' 12,250' 12,468' 12,500' 12,070' 12,105' 12,190' 12 245' 12,413' 12,480' 12,545' 65' 23' 46' 45' 163' 12' 45' 9,644' 9,714' 9,770' 9,82O' 9,866' 10,065' 10,094' 9,703' 9,734' 9,811' 9,861' 10,015' 10,076' 10,203' 59' 20' 41' 41' 149' 11' 109' Summary of Proposed Well Operations Well TBU K-30RD I RU 1-%" Coil Tubing unit. / 2 Perforate the following intervals with coil conveyed TCP guns. Run # Zone Top Btm Amount SPF G-1 10,865' 10,895' 30' 6 G-2 10,920' 10,945' 25' 6 4 G-2 10,955' 10,994' 39' 6 G-3 11,01 8' 11,050' 32' 6 G-4 11,065' 11,130' 65' 6 G-5 11,195' 11,224' 29' 6 G-5 11,232' 11,268' 36' 6 3 HB-1 11,412' 11,440' 28' 6 HB-4 11,636' 11,660' 24' 6 11,671' 11,690' 19' 6 2 11,700' 11,720' 20' 6 HB-5 11,780' 11,790' 10' 6 11,799' 11,820' 21' 6 HB-6 11,880' 11,930' 50' 6 I HB-7 11,960' 11,975' 15' 6 RD Coil Unit. Production test well. MIRU Rig. v/ Pull/Retrieve 4-Y2" tubin,~ and completion jewelry. RI w/ESP completion on new 4-~" tubing. Land tbg hng. Move rig. RKB to TBG Hanger = 33.75' TAG top of packer ~ 11,720' CTM w/3 70' mill on CT on 9/t7/98 LAST FILL TAG Q? t2.375' w/2 70" GR on 4/26/94 Possible casing damage 10,644'. Tradb~ay Unit King Salmon Platform Well # K-30RD Proposed Completion 1/14/02 PBTD = 12,543' TD = 12,600' MAX HOLE ANGLE = 43° K-30rd Prop Sc[mLDOC SIZE WT 13-3/8" 6I 9-5/8" 47 7" 26 Tubing: 4-t/2" 3-1/2" NO, 1. 2. 3. CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM K-55 BTC 34' 2187' PI 10/N80 BTC 34' 11327' P110N-80 LTC 11216' 12578' 12.6 L-80 BTC-NKK 34' 10546' Isolation Packer 8rd I 1750' I I 177' Depth JEWELRY DETAIL 34 4-t/2" FMC Tubing Hanger w/4-1/2" top and bottom BTC thread Camco TRDP- 1A SSSV nipple (ID: 3.813") Camco MMG 4-1/2" GLMs w/R-20 vlv~/RKlatch GLM #1 GLM #2 GLM #3 GLM/14 GLM #5 GLM #6 GLM #7 GLM #8 297' 2884' 5396' 71/5' 8279' 9089' 9620' 9992' 10284' 10802 10830 GO-6 4 4/70 Squeezed DST 10865 10895 G-I 6-18 4/70 Existing (t b~ ~c ? f d1 10920 10945 G~2 6~ 18 4/70 Existing (~ 10955 10994 G-2 6-18 4/70 Existing 0o be I1018 11050 G-3 6-18 4/70 Existing <t~ I I065 I 1130 G-4 6-18 4/70 Existing (to 11195 I 1224 G-5 6-18 4/70 Existing (~o 11232 11268 G-5 8 4/70 Existing (~ I 1385 11385 N/A 4 4/70 Sqz Pe~ 11412 11440 HB-1 6 P ? 3sod 1 t636 11660 HBo4 6 P -~l?(~d 11670 11690 HB-4 6 Prop(~ ( i pe~i~ 11700 11720 lIB-4 6 P oposc ! perfk 11780 11790 HB-5 6 P c~p~ ,,cd I 1800 I 1820 HB-5 6 P ~p ~.e ~ 11985 I 1985 N/A 4 4/70 Sqz 12005 12070 WF-2 4-20 4/70 Existing 12082 12105 WF-3 8-16 4/70 Existing 12 t 44 12190 WF-4 4-12 4/70 Existing 12200 12245 WF-4 4-16 4/70 Existing 12250 12413 WF-4-6 4-20 Existing 12468 12480 WF-7 4 ~xisting 12500 12545 Basal WF4 Existing 12545 12552 Basal WF4 T under pB/'I~EVISED: 01/17/02 DRA~ BY: JFB 4. t0450'+/- Centrilift 380 hp 562 series ESP,/,~0 cable w/2x3/8" chemical injection lines 5. 10500' Otis WD 9-5/8" wireline set perm packer 6. 10534' Camco DB-6 nipple, ID 3.75" 7. 10546' Otis WLEG, 4-1/2" tubing tail 8. 11750' Otis 7" WD wireline set isolation packer 9. 11764' Camco D nipple, ID 2.75" 10. 11777' WLEG, 3-1/2" tubing tail PERFORATION DATA TOP BTM ZONE SPFDATE COMMENTS King Salmon Ptat£orm Well # K-30RD Current Completion 3/15/88 RKB to TBG Hanger = 33.75' TAG top of packer (c( l 1,720' CTM w/3 70" mill on CT on 9/17/98 Possible casing damage I0,644' 10 LAST FILL TAG bi; I2,375' w/2 70" GR on 4/26/94 PBTD 12,543' TD= 12,600' MAX HOLE ANGLE = 43° K-30rd Sclnn 3q5-88.DOC SIZE WT t3-3/8" 61 9-5/8" 47 7" 26 Tubing: 4-1/2" 12.6 3-1/2" NO~ CASING AND TUBING DETAIL G~DE CONN TOP BOTTOM K-55 BTC 34' 2187' Pll0/NS0 BTC 34' 11327' PI10N-80 LTC 11216' 12578' L-80 BTC-NKK 34' Isolation Packer 8rd 11750' JEWELRY DETAIL __~ep!h Item 34 297' 10546' 11177' 2884' 5396' 7115' 8279' 9089' 9620' 9992' 10284' 4, 10498' 5. 10500' 6. 10534' 7. 10546' 8. 11750' 9. 11764' 10. 11777' TOP BTM ZONE 4-1/2" FMC Tubing Hanger w/d- 1/2" top and bottom BTC thread Camco TRDP-1A SSSV nipple (ID 3.813") Camco MMG 4-t/2" GLMs w/R-20 vlv/RKlatch GLM #I GLM #2 GLM #3 GLM #4 GLM #5 GLM #6 GLM #7 GI.M #8 Otis Seal assy, 19.23'~ 1.08' locator k l' spaceout Otis WD 9-5/8' wireline set perm packer Camco DB-6 nipple, ID 3.75" Otis WLEG, 4-1/2" tubing tail Otis 7" WD wire/ine set isolation packer Camco D nipple, ID 2.75' WLEG, 3-1/2" tabing tail PERFORATION DATA SPF DATE COMMENTS 10802 10830 GO-6 4 4/70 Squeezed DST 10865 10895 G-1 6-18 4/70 Existing 10920 10945 G-2 6-18 4/70 Existing 10955 10994 G-2 6-18 4/70 Existing 11018 11050 G-3 648 4/70 Ex/sting 1 t065 I1130 G-4 6-18 4/70 Existing 11195 11224 G-5 6-18 4/70 Existing 11232 11268 G-5 8 4/70 Existing 1t385 11385 N/A 4 4/70 SqzPerfs 11985 11985 N/A 4 4/70 Sqz Perle, 12005 12070 WF-2 4~20 4/70 Existing 12082 12105 WF-3 8-16 4/70 Existing 12144 12190 WF-4 4-12 4/70 Existing 12200 12245 WF-4 4-16 4/70 Existing 12250 12413 WF-4-6 4-20 Existing 12468 12480 WF-7 4 Existing 12500 12545 Basal WF 4 Existing 12545 12552 BasalWF 4 7' under PBTD REVISED: 01/17/02 DRAW2',I BY: TAB UNOCAL ) P. O. Box 196247 Anchorage, Ak 99519.6247 907-276-7600 907-263-7884 fax October 29, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Attn: Re: Mr. Blair Wondzell King Salmon Platform Well K-4RD APl # 50-133-20075-01 Well K-30RD APl #50-733-20211-00 Report of Coil Tubing Cleanouts Mr. Wondzell: This letter is to inform you of recent coil tubing operations on King Salmon K-4RD and K-30RD. On 9/16/98, coil tubing was utilized to mill out scale from inside the 4-1/2" production tubing on K-30RD. Production had declined recently on K-30RD and the suspected problem was severe scale restriction in the tubing. Scale was milled from 10,000' to the tubing tail at 10,555'. However, a relatively fast penetration rate of 10-30 ft/min indicated the scale build-up was not severe. The well has been placed back on gas- lifted production with no appreciable increase in production. On 9/22/98, a "Fas-Drill" tubing bddge plug was ddlled out of the tubing tail on K-4RD injection well. The plug had been set in the tubing tail to allow a pressure test to demonstrate casing integrity in this well which has known tubing leaks. (An eadier correspondence dated 9/3/98 documented the pressure test and AOGCC approval was granted 9/8/98 to resume injection) After the plug was ddlled out with coil tubing, the well was placed on injection. If there are any questions or you require further information on these two operations, please contact me at 263-7677 or Tim Billingsley at 263-7659. Drilling Manager Unocal Alaska K-4RD Well File K-3ORD Well File RECEIVED Alaska Oil & ~,~ Cons. Commission Anchorage RUG-22-97 FR! 15:57 UNOORL R~ET GR~ G~P NO, 9072637874 F, U4/U4 ~rg,cedure for. MIT on.Shut-in. Graylinn Injector G-28 1. Record daily tubing, casing, and outer casing pressures for a consecutive ten day period. Casing Pressure Outer Casing Pressure . Date Tubing Pressure ....... 7" ......... 9-5/8, .... !3-318''. 7/1/97 630 600 193 210 7/2/97 630 600 193 210 7/3/97 630 600 193 210 · . . 7/4/97 600' 600 196 210 7/5/97 600 600 196 210 . . 7/.6/97 ..,. 600 ..............60.0 .............1.96 210 7/7/97 600 600 196 210 7/8/97 600 600 194 210 7/9/97 600 600 194 205 . 7(10/97 ~-_ 6_0..0_ ... ............ 600 ..... 194 ...... 205..~ 1. Type of Request: Operation Shutdown Pull tubing ., 2. Name of Operator UNOCAL Corporati on (ARCO Alaska. Inc. is sub-operator) 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 678' FSL, 78' FEL, Sec. 17, TgN, R13W, SM At top of productive interval 1081' FSL, 1634' FEL, Sec. 21, TgN, R13W, SM At effective depth 322' FSL, 1364' FEL, Sec. 21, TgN, R I3W, SM At total depth 301' FSL~ 1359' FEL~ Sec. 21~ TgN~ R I3W~ SM 12. Present well condition summary Total Depth: !~ STATE Of ALASKA · ' AL^oKA OIL AND GAS CONSERVATION COMMISSION O ¢ ~ G 1 N REPORT OF SUNDRY ELL OPERATIONS Stimulate Plugging Perforate ~ Pull tubin9 Other 6. Datum elevation (DF or KB) Alter casing __ Repair well 5. Type of Well: Development ._~ Exploratory I Stratigraphic __ Service RKB 100' above biSL feet 7. Unit or Property name Trading] Bay Unit 8. Well number K-~ol~r (~-~o~ ,~r~. 9. Permit number/approval number measured 12600' feet true vertical 10203' feet O. APl number 50-1 33-2021 ! ~l 1. Field/Pool McArthur River 'G' and West Foreland Plugs (measured) None Effective depth: measured 12545' feet true vertical 10152' feet Junk (measured) 12427'- 12545' Casing Length Size Cemented Measured depth Structural Conductor 366' 24" Pile Driven 396' Surface 2157' 13-3/8" 1490 sx Class G 2187' Intermediate Production 11297' 9-5/8" 1000 SX Class G 11327' (window) Liner 1382' 7" 225 SX Class G I 1216'- 12598' Truevertlcaldepth 396' 2012' 9043' 8953'- 10201' 13. Perforation depth: measured See attached sheet true vertical See Attached sheet Tubing (size, grade, and measured depth) 4-1/2", 12.6#/ft, L-80 @ 10546' Packers and SSSV (type and measured depth) 1-Otis 9-5/8" set @ 10500'~ 1-Otis 7" set @11750'~ 1-Camco SSSV @ 297' Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure RECEIVED 14. Reoresentative Daily Averaoe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 795 1088 656 1150 100 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil . X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ , ~,~:~' Title 1111 396 625 11 lO 110 16. Status of well classification as: Suspended Service ... Trading Bay Well K-30RD Unit Exlstin~ Perforationa -- G-Zone Perforation Data 10802-10830' 10865-10895' 10920-10945' 10955-10994' 11018-11050' 11065-11130' 11194-11224' 11232-11268' 8628-8649' 8676-8699' 8718-8736' 8743-8772' 8789-8812' 8823-8870' 8935-8960' 8966-8995' West MD 12005-12070 12082-12105' 12144-12190' 12200-12245' 12250-12413' 12468-12480' 12500-12545' Foreland Perforation TVD 9644-9703' 9714-9734' 9770-9811' 9820-9861' 9866-10015' 10065-10076' 10094-10203' Data _NOU-25~'90 08:52 ID:~'-'q SALMON 'ARCO Alaska, Inc. Gubeidla~ of Allaflti¢~ Richfield ComlN~y WELL REMARKS TEL NO:9072E"~91 ~370 P02 WELL SERVICE REPORT IFIELD · DISTRICT- STATE OPERATION AT REPORT TIME IDAY,~. , IDATE _ I , _//. ;_~0 - 17:00 /7:00 '- Il:E) /~:5'0 21: oo .. Z! : ~D . CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. ~_~iOIIm/Of Atlanllo RIrJ~fl$1d COmpaq/ ~-$0 ,~ ' i~'= WELL SERVICE FIE,p.O, FIq JOPERATION AT REPOI~r¥1~---E , 0'/: ~o' 09:0~ . ,mm ..... ~ '+~, - NOU-2~-'~90 ~8:51 ID:.~'~G SALMON ARCO Alaska, Inc. ~uba~ll&ry of Ail-nile Ri~.flel<:l Company TEL N0:9072 ~91 ~370 PO1 WELL SERVICE REPORT FIELD' DISTRICT. STATE tOPERATION AT REPORT TIME IDAYS i DATE lg:30 - _l~:f'O F-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION 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 _ Pull tubing _ Variance _ Perforate ~X Other _ 2. Name of Operator 5. Type of Well' 6. Datum elevation (DF or KB) UNOCAL Corporation Development X .(ARCO Alaska, Inc, is sub-operator) Exploratory _ RKB 100' Above MSL feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Trading Bay Unit 4. Location of well at surface 8. Well number 678' FSL, 78' FEL, Sec. 17, T9N, R13W, SM K-30RD (44-21) At top of productive interval 9. Permit number 1081' FSL, 1634' FEL, Sec.21, T9N, R13W, SM At effective depth 10. APl number 322' FSL, 1364' FEL, Sec. 21, TgN, R13W, SM 50-133-2021 1-00 At total depth 11. Field/Pool Mc Arthur River "G" 301' FSL, 1359' FEL, Sec.21, TgN, R13W, SM & West Foreland _ .~ .~ o 12. Present well condition summary ,~/~3~,~.,~..~,~~.~.. Total Depth: measured 1 2600' feet Plugs (measured) None true vertical 10203' feet Effective depth: measured 12545' feet Junk (measured) 12427-12545' true vertical 10152' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 366' 24" Pile Driven 3 96' 39 6' Surface 21 5 7' 1 3- 3 / 8" 1490 sx Class G 21 8 7' 2 01 2' Intermediate Production 11 297' 9- 5/8" 1000 sx Class G 11327'(window) 9043' Liner 1382' 7" 225 sx Class G 11216'-12598' 8953'-10201' Perforation depth: measured true verticalSee attached sheet R E · See attached sheet Tubing (size, grade, and measured depth 2 4-1/2", 12.6#/ft, L-80'@10546' Packers and SSSV (type and measured depth) Cons. ornmis 1-Otis 9-5/8" set @ 10500',l-Otis 7" set @11750', 1-Camco SSSV @ 297' ,~'~lJ JJ,~Jll~l 13. Attachments Description summary of proposal _ Detailed operation program X BOP sKe~cn 14. Estimated date for commencing operation 15. Status of well classification as: October, 1990 Oil ~( Gas __ Suspended __ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereb/5~ertify th~.the f,or-.~oing is true and correct to the best of my knowledge. Signed Title Cook Inlet RegionaFEncjr. Date FOR COMMISSION USE ONLY , Conditions of approval: Notify Commission so representative may witness IApprov,~l~lo. ~,~., Plug integrity_ BOP Test_ Location clearance__ I 7u-' Mechanical Integrity Test_ Subsequent form require 10-¥0~'! Original Slgned By David W. Johnston ,Approved by the order of the ,Commission Commissioner Date [0 Form 10-403 Rev 5/03/89 SUBMIT IN1 711~'~TRIP . TE Approved Copy rned Trading Bay Unit Well K-30RD Existim3 Perforations -- G-Zone Perforation Data MD 10802-10830' 10865-10895' 10920-10945' 10955-10994' 11018-11050' 11065-11130' I 1195-11224' 11232-11268' TVD 8628-8649' 8676-8699' 8718-8736' 8743-8772' 8789-8812' 8823-8870' 8936-8960' 8966-8995' West Foreland Perforation Data MD 12005-12070 12082-12105' 12144-12190' 12200-12245' 12250-12413' 12468-12480' 12500-12545' TVD 9644-9703' 9714-9734' 9770-9811' 9820-9861' 9866-10015' 10065-10076' 10094-10203' SUMMARY OF PROPOSED WELL OPERATIONS WELL TBU K-1RD (October, 1990) 1. RU E-line unit. 2. Perforate the following intervals under draw-down conditions: Run No. Zone Interval (MD-CET) Interval (MD-DILl I WF-5 I 2364-1 2394 12360-12390 2 WF-2 I 21 59-1 21 89 12155-12185 3 WF-0 I 2034-1 2064 12030-12060 4 G-5 I I 198-1 1218 11194-11214 5 G-'4 I 1084-11 I 14 11080-11110 6 G-3 11024-11054 11020-11050 7 G-2L 10959-10989 10955-10985 8 G-2 I 0924-1 0949 10920-10945 9 G-1 I 0869-1 0899 10865-10895 30 30 30 20 30 30 30 25 30 255 ,.gPF Note: . Lubricator will be pressure tested to 2500 psig prior to each run. RD E-line unit and lubricator. 'EIVED OCT ' 990 · aSka Oil & Gas Cons, Anchorag~ E-Line-BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual"Rams Swab Valve Double Master Valves Wellhead Unocat North Ame~ Oil & Gas Division P.O. Box 1 g0247 Ancnarnge. AIss~ gg5 TeteDnone ~90~ 276-7800 Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Leaps" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, a~~U~ sh ' GRegional Drilling Manager GSB/lew KING SALMON PLATFORM FROM SE CORNER SEC. 17, .TgN, R13W CONDUCTOR LEG ~1: LEG #2: 9 l0 ll 12 13 14 15 16 LEG #3: 17 18 19 20 21 22 23 24 Leg #4' 25 26 27 28 29 30 31 32 "Y" COOR. "X" COOR. WELL #' FNL 2,511,762 2,511,761 2,511,764 2,511,768 2,511,772 2,511,773 2,511,770 2,511,766 2,511,690 2,511,686 2,511,684 2,511,687 2,511,691 2,511,695 2,511,696 2,511,694 2,511,689 2,511,723 2,511,721 2,511,724 2,511,728 2,511,732 2,511,733 2,511,731 2,511,726 2,511,799 2,511,798 2,511,801 2,511,805 2,511,809 2,511,810 2,511,807 2,511,803 213,819 213,815 213,811 213,810 213,812 213,817 213,821 213,822 213,768 213,772 213,768 213,763 213,762 213,765 213,769 213,776 213,774 213,712 213,708 213,703 213,702 213,705 213,709 213,713 213,714 213,760 213,756 213,752 213,751 213,753 213,758 213,762 213,763 K-21 & RD 688 74 K-30 687 78 K-18 690 82 K-17. 694 83 K-23 (23-19) 698 81 K-19 699 76 K-22 & RD 696 72 K-20 692 71 FWL K-15 & RD 611 121 K-9 610 126 K-4 & RD 613 130 K-11 617 131 K-13 & RD 621 128 K-2 & RD 622 124 K-7 & RD- 619 120 K-5 615 1!9 K-8 725 133 · K-1 & RD 724 135 K-10 &'RD 727 141 K-16 731 142 K-12 & RD 735 140 K-6 & 24 736 135 K-3 & RD 729 130 STATE Of ALASKA ALA~/"~. OIL AND GAS CONSERVATION COM, JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other 2. Name of Operator UNOCAL (ARCO Alaska. Inc. is ~ub-oDerator) 3. Address P.O. Box 190247~ Anchorage~ AK 99519 4. Location of well at surface Leg 1, Conductor 2 678' FSL, 78' FEL, Sec.17, TgN, R13W, SM At top of productive interval 1081' FSL, 1634' FEL, Sec.21, TgN, R13W, SM At effective depth 322' FSL, 1364' FEL, Sec.21, TgN, R13W, SM At total depth 301' FSL~ 1359' FEL~ Sec.21~ TgN~ R13W, SM 11. Present well condition summary Total depth: measured 12600'MD true vertical 10203'TVD Stimulate [] Plugging [] PerforateX] Pull tubing WORKOVER 5. Datum elevation (DF or KB) RKB 100~ 6. Unit or Property name Trading Ba.y Unit 7. Well number K-30 (44-21) 8. Approval number 7-q?cl g. APl number 50-- l~-?n?ll 10. Pool McArthur River "G" & We~l; For~] and feet Plugs (measured) None feet Feet Effective depth: measured 12545'MD feet Junk (measured) None true vertical 10152'TVD feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 366' 24" Pile driven 396'MD. 396'TVD Surface 2157' 13-3/8" 1490 sx Class G 2187'MD 2012'TVD Production 11297' 9-5/8" 1000 sx Class G l1327'MD(window) 9043'TVD Liner 1382' 7" 225 sx Class G 11216'-12598'MD 8953'-10201'TVD Perforation depth: measured See attached sheet true vertical See attached sheet RECEII/ED Tubing (size, grade and measured depth) · 4-1/2", L-80 tbg w/tail ~ 10546'. Tailpipe assembly f/11750'-l1777,.~las~a Oil & Gas £bns..< .... Packers and SSSV (type and measured depth) WD pkr ~ 10500~ & 11750~ (WLM)~ TRDP-1A-SSSV (~ 297~ 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production orlniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 340 274 344 1220 1028 461 744 960 Tubing Pressure 120 3.34 14. Attachments (Workover Wel 1 History) Daily Report ,of Well Operations I~ Copies of Logs and Surveys Run [] 1 lr~5~f~thereby~,~,~ certify that the foregoing is true and correct to the best of my knowledge s, ned ,,t,e Engineer Form 10-404 R~'v. 12-1-85 R.D. Roberts (Dani) SW03/64 Date 4/28/88 Submit in Duplicate REPORT OF SUNDRY WELL OPERATIONS TRADING BAY UNIT K-30 Item 11: Perforati on Depths MD TVD Perforated w/6 spf, 120° phasing 10865' -10895' 10920'-10945' 10955' -10994' 11018'-11050' 11065'-11130' 8677' -8700' 8720'-8739' 8747' -8778' 8797' -8822' 8834' -8886' Perforated w/5 spf 11195'-11224' 8937'-8961' Original perforation 11232'-11268' 8968'-8997' Perforated w/4 spf, 90° phasing 12005'-12070' 12082'-12105' 12144'-12190' 12200'-12245' 12250'-12413' 12468'-12480' 9616'-9676' 9686'-9706' 9740'-9779' 9787'-9826' 9830'-9968' 10014'-10024' SWO3/64a 3/24/88 ARCO Oilan~.GalCompan~ ~)~ -. Wall H[t~tb~. Initial, Report - Daily Instructions: Prepare and submit the "Initial Rel~O~t" on the first Wednesday aftel ; well la spudded or workover operations are Itl'ted. IWell no, Daily work prior to sPudding should be summarized on the form giving inclusive dates only. District I County~ parish or borough I Ste ARco A~a.-~a, ~no~.. I ~NA~ BOROUGH , t~< TRADING BAY UNIT I iLease or Unit iTitlel ] WORKOVER Field Auth. or W,O. no. AD6102 K-30RD API: 50-133-20211 Operator IARCO W.l. ARCO [ 10.0000 Spudded or w,O.AcCEPTbegun [Date 02/24/88 IHOur 1900 HRS IPrlor status if a w.o. Complete record for each day repo~ed KING SALMON Date and depth as of 8:00 a.m. 02/25/88 ( TD:12600 PB: SUPV:HP 02/26/88 ( TD:12600 SUPV:HP 02/27/88 ( TD:12600 PB: SUPV:HP 02/28/88 ( TD:12600 PB: SUPV:HP 02/29/88 ( TD:12600 PB: SUPV:HP 03/01/88 ( TD:12600 PB: SUPV:HP 03/02/88 ( TD:12600 PB: SUPV:HP 03/03/88 ( TD:12600 PB: SUPV:HP The above is correct NU BOPE MW: 8.7 FIW SKID RIG FROM K-23 TO K-30. ACCEPT RIG @ 1900 HRS 2/24/88. CUT TUBING @ 10780' . SET BPV. ND TREE. NU BOPE. DAILY:S45,684 CUM:$45,684 ETD:S45,684 EFC:$1,256,000 CIRC. BOTTOMS UP MW: 8.7 FIW FINISHED NU BOPE & TESTED TO 3000 PSI. FILLED ANNULUS. PERFORATED SHORT STRING @ 10641'-10643'. CIRC. CRUDE OUT OF ANNULUS. RU DUAL TUBING EQUIP. UNSEAT HANGER & ATTEMPTED TO PULL PACKER LOOSE. CIRCULATE BOTTOMS UP. DAILY:S15,097 CUM:$60,781 ETD:S60,781 EFC:$1,256,000 POOH LD TBG MW: 8.7 FIW CIRC. PULL ON TBG. REACH MAX PULL. CUT BOTH STRINGS JUST ABOVE PKR. PULL HANGER TO FLOOR. LD SAME. CIRC AND COND HOLE. POOH LD TBG. DAILY:S48,973 CUM:$109,754 ETD:S109,754 EFC:$1,256,000 LD TUBING STRING MW: 8.7 FIW POOH. LD DUAL TUBING STRING. DAILY:S13,600 CUM:$123,354 ETD:S123,354 EFC:$1,256,000 LD 9-5/8" RETRIEVABLE PKR MW: 8.7 FIW FIN LD TBG. CHANGE RAMS AND TEST BOPE. RIH. LATCH 9-5/8" RET PKR. POOH. LD SAME. DAILY:S20,302 CUM:$143,656 ETD:S143,656 EFC:$1,256,000 PULL FISH ~ 2 MW: 8.7 FIW LD FISH ~ 1. RIH. ATTEMPT TO RETRIEVE FISH ~ 2. GRAPPLE SLIPPED OFF. CBU. POOH. RIH W/ UNDERSIZE GRAPPLE. LATCH AND PULL FISH FREE FROM PKR. PULL UP. ATTEMPT TO CIRC. DAILY:S17,496 CUM:$161,152 ETD:S161,152 EFC:$1,256,000 CIRC HOLE CLEAN MW: 8.7 FIW PULL 2 STANDS. CIRC OUT GAS BUBBLE. TOH. LD FISH. PUT FTA ~ 3. TIH. BURN OVER 7" PKR AT 11310'. CIRC HI VIS SWEEP. DAILY:S14,292 CUM:$175,444 ETD:S175,449 EFC:$1,255,995 TIH MW: 8.7 FIW TOH. DID NOT RECOVER PKR. PU SPEAR. TIH TAG BOTTOM AT 12380'. TOH. LD FISH. MU BIT AND SCRAPER. DA!LYr$!J.~00 p p ,~'/ar d distribution, For form re aratto see Procedures Ma(lJlal, Section 10, Drilling, Pages 86 a~d 87. AR3B-459-1-D Number all as they are daily well history forms consecutively prepared for each well. ARCO Oil a~. Gas Company '~ Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ali drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lltlerim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO Alaska, Inc. ICounty or Parish ]Stat1 KENAI BOROUGH Lease or Unit K-30RD TRADING BAY UNIT IWell no. Date and depth as of 8:00 a.m. 03/04/88 ( TD:12600 PB: SUPV:ML 03/05/88 ( 1 TD:12600 PB: SUPV:ML 03/06/88 ( 1 TD:12600 PB: SUPV:ML 03/07/88 ( 1: TD:12600 PB: SUPV:ML 03/08/88 ( 1 TD:12600 PB:12515 SUPV:ML 03/09/88 TD:12600 PB:12515 SUPV:ML 03/10/88 (1.') TD: 12600 PB:12545 SUPV: HP The above is correct Signature DAILY. $ 77, ~, "~'~ate ! For form preparation an~/distribuuon see Procedures Manuay ~ection 10, Drilling, Pages 86 and~8'7 Complete record for each day while drilling or workover in progress KING SALMON MU BHA MW: 8.7 FIW RIH. TAG TOL AT 11213'. CIRC BTMS UP. TOH. LD BHA. CHANGE OUT 7" SPACER SPOOL. MU 9-5/8" RTTS. RIH. SET RTTS AT 10775'. TEST 9-5/8" CSG TO 2500 PSI F/ 30 MIN. TOH. LD RTTS. DAILY:S32,568 CUM:$221,612 ETD:S221,612 EFC:$1,256,000 WASHING OVER FISH MW: 8.7 FIW/KCL PU 6" BIT. TIH. CLEANED OUT FILL F/12380'-TOP OF FISH @ 12419'. CIRC. BOTTOMS UP. TOH. PU OS. TIH. TAGGED FISH @ 12425'. WASHED OVER FISH. DAILY:S13,822 CUM:$235,434 ETD:S235,489 EFC:$1,255,945 TOH MW: 8.7 FIW/KCL TAGGED TOP OF FISH @ 12425'. WASHED OVER FISH TO 12448'. TOH. RECOVERED CCL/FH/TS (2.20'). CHANGED OUT SHOE. TIH. TAGGED TOP OF FISH @ 12427'. WORKOVER OVER SAME, BURN OVER FISH F/12448'=12451'. TOH. DAILY:S13,600 CUM:$249,034 ETD:S249,034 EFC:$1,256,000 REV. CIRC. HOLE CLEAN MW: 8.7 FIW/KCL FINISHED TOH. LD FTA #6. PU FTA #7. TIH. WORKED OVER FISH. CATCH SAME. TOH & LD FISH. MU CLEAN OUT ASSEMBLY. TIH. CLEANED OUT 7" LINER F/12451'- 12515'. RU. REVERSE CIRC. HOLE CLEAN. DAILY:S26,136 CUM:$275,170 ETD:S275,170 EFC:$1,256;000 PREP TO PU-GUNS MW: 8.7 FIW/KCL REVERSE CIRC HOLE CLEAN WITH FIW. DISPLACE HOLE WITH CLEAN 3% KCL FIW. TOOH. CUT 90' OF DRILLING LINE. FINISH TOOH. RU LOGGER. RUN GR/CCL/CET FROM 12506- 11206' TOL. POOH. RESET CET TOOL FOR 9 5/8" CASING. RIH. RUN GR/CCL/CET FROM 11206-8638'. ACST CALIPER LOG TO 100'. RD LOGGERS. PREP TO PU GUNS. DAILY:S19,820 CUM:$294,990 ETD:S294,990 EFC:$1,256,000 TOH PREP TO LD GUNS ON DP MW: 8.7 FIW/KCL RD SOS. PU BAKER PERF ASSY. TIH. RU SOS TIE-IN WITH (3/7/88 CET). POSITION GUNS. SET PACKER. PERF W/4 SPF, 90 DEGREE PHASE FROM 12(005-070,082-105,144-190,200-245,250-275,280-350, 360-413)'. REVS OUT OIL AND GAS. TOH. PREP TO LD GUNS. DAILY:S15,879 CUM:$310,869 ETD:S310,924 EFC:$1,255,945 MU OTIS J-SLOT PLUG ON DP MW: 8..7 FIW/KCL LD PER ASSEMBLY. RIH WITH BIT AND SCRAPPER. WASH AND REAM 12515-12543'. CIRCULATE HI VIS SWEEP. POOH. RU SOS. MAKE JB/GR RUN. RIH WITH WD PACKER. SET @ 11750'. RD SOS. PU OTIS J-$LOY PLUG ON DP. CU~;$Bgg,412rTitlo~TD,$3S$,412 ,3-36-ds~' AS~3ClATE ENGINI~R AR3B-459-2-B lNumber all daily we1 history forms consecutively as they are prepared for each well, ARCO Oil and Gas Company Daily Well History--lnterin Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on 'Iht®rite" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO Alaska, Inc. TRADING BAY UNIT rcounty or ~,arish jstet~ KENAI BOROUGH Iweu Lease or Unit no. K-30RD Date and depth as of 8:00 a.m. 03/11/88 ( TD:12600 PB:12545 SUPV:HP 03/12/88 ( TD:12600 PB:12545 SUPV:HP 03/13/88 ( TD:12600 PB:12545 SUPV:HP 03/14/88 ( TD:12600 PB:12545 SUPV:HP 03/15/88 ( TD:12600 PB:12545 SUPV:HP 2)) Complete record for each day while drilling or workover in progress KING SALMON 03/16/88 (2.) TD:12600 PB:12545 SUPV:HP POOH WITH 7" UNFIRED GUNS MW: 8.7 FIW/KCL RIH AND SET J-SLOT PLUG. DUMP SAND. POOH. MU 7" GUNS. RIH. RUN CORRELATION LOG. UNABLE TO ADJUST GUNS. POOH WITH GUNS. DAILY:S32,991 CUM:$421,403 ETD:S421,403 EFC:$1,256,000 POOH WITH TCG MW: 8.7 FIW/KCL POOH LD TUBING. WIRELINE PERF 11195'-11213'. PU AND MU BAKER 7" TCG. RIH. CORRELATE. FIRE GUNS. FLOW WELL 30 MINUTES. CIRCULATE. POOH WITH TCG. (PERF'D WITH 4 SPF) DAILY:S14,989 CUM:$436,392 ETD:S436,392 EFC:$1,256,000 PREP TO POOH WITH J-PLUG MW: 8.7 FIW/KCL FINISH POOH. PERF F/11130'-11065', 11050'-t1018', 10994'-10955', 10945'-10920', 10895'-10865'. 6 SPF, 120 P~ASE. LD TCG. RIH W/ 8-1/2" BIT & SCRAPER. CBU. POH. RIH W/OTIS PLUG REVERSING TOOL. RE~ DAILY:S88,485 CUM:$524,877 ETD:S524,877 EFC:$1,256,000 POOH LDDP MW: 8.7 FIW/KCL POOH WITH OTIS J-PLUG ON DP. WIRELINE SET OTIS 9-5/8" PACKER AND TAILPIPE @ 10500'. CBU. POOH LDDP. DAILY:S103,395 CUM:$628,272 ETD:S628,272 EFC:$1,256,000 ATTEMPT TO PULL STANDING MW: 8.7 FIW/KCL FINISHED POH & LDDP. CHANGED RAMS TO 4-1/2" & TESTED. RAN 261 JTS 4-1/2", 12.6#, L-80, TBG W/SSSV @ 297', TAIL @ 10546', TAILPIPE @ 11777' SPACED OUT & LANDED. PKRS 10500" & 11750'. STANDING VALVE. TESTED TBG & CONTROL LINES. PULLING STANDING VALVE DAILY:S13,800 CUM:$642,072 ETD:S642,072 EFC:$1,256,000 WAIT ON SL CREWS & TOOLS MW: 8.7 FIW/KCL ATTEMPTED TO PULL STANDING VALVE. FISHED WITH WIRELINE. WAITING ON SLICKLINE CREW RELIEF & TOOLS. DAILY:S154,259 CUM:$796,331 ETD:S796,331 EFC~$1,256,000 The above is correct Signature For form preparation an,d~ distribu ~on see Procedures Manual(.~ect~on 10. Drilling, Pages 86 and 87 AR3B-459-2-B Date JTitle A880CIATE ENGINEER I N umber all daily well history forms consecutively as Ihey are prepared for each well. ARCO Oil.a,,d Gas_ Company ~aily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and-representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Aecountlng cost center code District I St ate~ ARCO Alaska, Inc. Field TRADING BAY UNIT Auth. or W.O. no. ~61o2 Operator ~CO I County or Parish KENAI BOROUGH Lease or Unit Title . K-30RD IWail no. Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 03/17/88 ( TD:12600 PB:12545 SUPV:ML A.R,Co. W,I, 10.0000 Date 02/24/88 Complete record for eac~ day reported KING SALMON lotal number of wells (active or inactive) on thisj Dst center prior to plugging and ~ bandonment of this well J our I Prior status if a W.O, i 1900 HRS I MOVING RIG TO K-11 MW: 8.7 FIW/KCL MU WL FISHING TOOLS. RIH WITH SL UNIT. RECOVER FISH. RD SL UNIT. RU SOS. ATTEMPT TO RETRIEVE STANDING VALVE. NO GOOD. RD SOS. ND BOPE. NU AND TEST TREE TO 5000 PSI. RELEASE RIG @ 0000 3/17/88. RD. PREP TO MOVE RIG TO K-11. DAILY:S19,120 CUM:$815,451 ETD:S815,451 EFC:$1,256,000 Old TD I New TD PB Depth Released rig I Date Kind of rig Classifications (oil, gas, etc.) Producing method Potential test data IType completion (single, dual, etc.) Official reser'voir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % ~OR Gravity Allowable EffeCtive date corrected · The above is correct Signature , ITitle For form preparatioF/~nd distribution, see Procedures Mail/al, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are pre, pared for each well. DIvlIio~ ol AtlantlcRIclflle~eCe,ae,m~ ~ - ' .,/"-~ STATE OF ALASKA AL~ ~A elL'AND GAS CONSERVATION CO,. ,llSSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] R~i'enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing~ Amend order [] Perforate/~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) .UNOCAL (ARCO Alaska~ Inc. is sub-operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg 1, Conductor 2 678' FSL, 78' FEL, Sec.17, T9N, R13W, SM At tOp of productive interval 1081' FSL, 163,4' FEL, Sec.21, TgN, R13,W, SM At effective depth 322' FSL, 1364' FEL, Sec.21, TgN, R13,W, SM At total depth 3,01' FSL, 13,59' FEL, Sec.21, TgN, R!3,W, SM RKB 100' 6. Uniter Property name Trading Bay Unit 7. Wellnumber K-3,0 (44-21) 8. Permit number 70-7 9. APl number 50-- 133,-20211 10. Pool McArthur River "G" & West Forel and feet 11. Present well condition summary Total depth: measured 1 2600 ' MD feet true vertical 10203, ' TVD feet Effective depth: measured 1 2545 ' MD true vertical 10152'TVD Casing Length Size Conductor 3,66 ' 24" Surface 21 57 ' 13-3/8" P roducti on I 1297 ' 9-5/8" Li net 1 382 7" Plugs (measured) None feet feet Junk (measured) None Cemented Measured depth True Vertical depth Pile driven 396'MD 396'TVD 1490 sx Class G 2187'MD 2012'TVD 1000 sx Class G 11327'MD(window) 9043,'TVD · ~ ~--~L ! VE ~,~~ Perforation depth: measured true vertical See attac She Tubing (size, grade and measured depth) Lo Packers and SSSV (type and measured depth) ~ 11308', 1-Otis SSSV ~ 251' (she See attached sheet Alaska Oil & Gas Cons. Commission h e d s h e e t Anchorage rt string - 3-1/2" 9 2#/ft U-80 ~ 10757' ng string - 3,-1/2" 9 2#/ft N-80 @ 113,79' 1-Baker 9-5/8" dual A-5 ~ 10683,', l-Baker 7" F-1 rt string), 1-Otis SSSV @ 288' (long string) 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for comme'ncing operation December 14, 1987 14. If proposal was verbally approved . Name,~f approver Date approved 15. I ~'re~y~ certif,~,~/t the foregoing is true and correct to the best of my knowledge Signed~~~,~ ~.(44i1~/L Title As soci ~te Enai neer Conditions of approval ~ mm~ i I Co 'ss'on Use On y ( T.! R ) .c; A '~ / 1 7 Notify commission so representative may witness I AP~r°Va'l No. [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned .~ Approved by Form 10-403 Rev 12-1-85 Date//,---,,2.['-~ 4~O'7 ORIGINAL SIGNED BY l_Ol~NIF c, 8MITtt Commissioner the commission Date Submit in triplicate TRADING BAY UNIT K-30 APPLICATION FOR SUNDRY APPROVALS Block #11: Perforation Depths Short string: MD TVD 10876 -10888 10926 -10944 10956 -10988 11024 -11036 11040 -11046 11078 -11120 11202 -11224 11232 -11268 Long string: 12008 12021 12032 12055 12082 12156 12173 12208 12230 12258 12468 -12014 -12026 -12040 -12068 -12105 -12166 -12184 -12212 -12242 -12408 -12480 8685 -8694 8723 -8737 8747 -8772 8800 -8810 8813 -8818 8843 -8877 8941 -8959 8967 -8995 9663 9675 9685 9706 9730 9796 9812 9845 -9669 -9680 -9692 -9717 -9751 -9805 -9822 -9848 I 9865 -9876' 9890'-10026' 10082'-10093' RECEIVED iJOv 2 :: ~:~>/ Alaska Oil & Gas Cons. Commissior~ Anchomge SA3/17a 11/9/87 K-30 RD Workover Procedu?-% Objective Remove existing dual 3½" completion assembly, perforate production zones, run new 4½" completion with isolation packer, and put on production. This will be a single commingled producer. Procedure 1. Prior to RU over K-30, kill well with filtered 3% KC1 inlet water (long and short tubing strings and annulus). Monitor pressures to be sure well is dead. RU slickline and pull valves from lowest GLM's in both strings. 2. MI RU over TBU K-30, leg #1. 3. Circulate well as required to be sure both tubing strings and annulus are dead. 4. ND tree. 5. NU & test BOPE. 6. Unset dual Baker packer and unsting from lower F-1 permanent packer. Circulate bottoms up and POOH & LD 3½" tubing and jewelry. 7. PU 8½" bit and 9-5/8" 47# casing scraper and clean out to top of liner @ 11,216'. POOH. 8. PU mill and packer plucker, mill over and recover Baker Model "F-i" permanent packer set at 11,308' MD inside 7" 29# liner. 9. PU 6" bit and 7" 29# casing scraper and cleanout to PBTD @ 12545'. 10. PU RTTS & RIH. Set 50' above top perforations and pressure test the 9-5/8" casing to 2500 psi. Isolate any casing leaks and perform remedial work as required. Clean out to PBTD if required. 11. PU TCG perforating assembly and RIH with specified underbalance conditions. Perforate both West Foreland/G. Zone intervals at the same time and flow 'well as directed by well site engineer. 12. PU 6" bit and 7" 29# casing scraper and make clean-out run to PBTD. 13. RU electric line. Make 6.000' GR/JB run to 1~,~'. RIH & set permanent isolation packer at 11,300'. RIH and set permanent packer at 10,700'±. RD electric line. 14. RIH with 4½" Completion Assembly. Space out so that locator is 1' above permanent packer at 10,700'. Land tubing string. Run in lock down screws. 15. Pressure test annulus to 2000 psi for 30 minutes. Test tubing and SSSV. 16. Pull landing joint. Install BPV. ND stack. NU FMC 4-1/16" 5000 psi tree. Pull B?V. Install t est plug. Test tree to 250 and 5000 psi. Test packoff to 5000 psi. Pull tree test plug. R~C~/vE0 17. Move rig and release well to Production. SR/200 ih wuJ. pno~n ] AHCO ALASKA, INC cAsm --~ ~ : ~ TRADI~ BAY UNIT ~ o~, ,7, 200 ~ ~ J .~A~ ALASKA 171 ' O~ ~~~N D'~L ~ 2187' ~1,327' 12508' I~ ~1/ ' ~~~"~='"~ ' ' I / / ~. ~ ~.~ ~ ~c ~..~ ~.4~ t 1 ~ -~ .... i i , t - I ~o~il ~m ~ o.M ~ ~c I ' 2309.08~ ~S0.44 I O 211 I I ~ ' !~° f' Il ~m.m~o.~ 11 ~S I / ~G. ~1~ o. ~ ~ / ~81NG, ~1~ 9. --~ I 7~ ~.C,~,~KS~ ..S,i 7SSS.4, ~ ~ T~81,~. ~/~ 0.~ ~-K 8TO ~ 733.33, 7581.0o ~ ~ 8 ~. CA~ ~1/2' KB~ 6.51 0 ~ 0 ~ m TUB'NG. 3'1/2' 9.~ "'~ BTC 617.79 8301.83 ~ /~ 9 GLO* CAM~ ~1/2' KB~ 6.67 8010.62 ~ ! / 11 GLM, CA~ ~1/2' KB~ 6.62 98'7.29 / / J ~81NG, ~1/2' 9.~ N'~ BTC ' 392.56 0863.01 6 62 10246 / / ~ 12 GLM, cA~ ~1/2" KB~ = · ' - I~ TUBING, ~1/2" g.~ N-~ BTC 354.60 10253.09 I 13 GLM, C~ ~1/2' KB~ _ 6.54 10607.60 -- / ~ p~ER, BAKERg.~F A.SHYDDUAL~ 10.68~10682.8~ ~ ~/~ ' TUBING 3'1/2" 9.2~ N-~ BTC : 30.21 10603.53i 2~ ' ' ' ~1/ ,s '~N.~.o,,~ ,.3~ ~~~ 16 ~R~B 1.42 10755.90 ~ / "1 ] ~ ' P~e 1 ~ 2 (~e A~A~ ~ ~ L~ ~R~ DATA) Cons. Commiss;~~ I A",c9,.c I ,,~.1.. K-30 pu,l. coMPLiTIO" Oil',mr i , i I La'Dm ~om~r (H~Z~mER ELEVATm~m~ $4.40 fl'OPS) ii i i ~. $1~ t~ K ~G - - 285.40 34.40 i i i 2 ~. ~ ~ V~ 2.a8 287.80 ii i1~ i i ~. ~1~ OJ ~ ~C 2~O.JS 200.18 17 ~ ~ ~1~ ~ 8.6S ~8~S.43 , i i i t i i iii 10 GLM. ~ ~q;~ ~ e~SO 5S80.2S i tt ii ti i mmv. ~ o~ ~ ~c ~ ~ss,7s smo4.Ts i i ~0 ~ ~ ~/~ ~ 0.14 0720.48 ii i i ~ i lU i ~. ~1~ 0~ ~-,~ 846.07 0787.0f i i ii 21 GLM, ~ ~1~ ~ 8.~ 768~.00 i i i ~ffi~. ~1~ O~ ~ ~C 716.88 7688.60 , ~Bl~. 3-1~ g~ ~ ~C 617.08 8550.60 i ii TUMS, ~,~ 0~ ~ ~c '" ,'/.d 24 ~LM, ~ ~11~ ~ ' ' ~.S~ "g446.~1 r it i iii ,u8.~. 3-~ o.2, ~ ~c 428.2. 25 GLM, CA~ ~-1/~ K8~ ........ 6.S1 O8~O.gO , , , TUBI~. 3-~/~ g.2g N-~ BTC 388.47 0807.50 i i i 28 GLM. CA~ 3-1/~ KB~ tl.51 10275.97 27 GLM, CA~O 3-1/~ KBUG 6.52 10640.11 i i ,,i i i i i TUBI~, 3-1/2' 9.2~ N-80 BTC 33.7~ 1 1 4 PACKER, BAKER ~ A-S HYD DUAL 12.60 10680.42 i 2g PACKER.~ER~:~ ~ (1.00) 11308.49 ,. , ,,, i ,i TUBI~, 3-1/2' 9.2~ N-80 BTC 62.11 11315.34 ;1 ~~ .86 11377,48 32 ~ ~(~~ ~R~ ~)l 1.10 11378.34 ii ii iiii BO~ ~ T~i~ TAIL 11379.44 , , , ,, i , i i i i i i ii , , i il iii ,,, ,,, , ,, ,, ~ , , , P~GE 2 ~ 2 !_3,,-5/8" 3000, PS!,,,BOP STACK ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 1. FMC TYPE Iil UNIHEAD 2.13-5/8' 5000 PSI HUB X 3000 PSI FLANGE ADAPTER 3.13-5/8' - ;3000 PSI DRILLING SPOOL 4. 13-5/8' - 3000 PSI BLIND RAMS 5.13-5/8' - 3000 PSi PiPE RAMS 6.13-5/8' - 3000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR P~FIE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIMF, THEN CLOSE ALL UNrl~ SIMULTANEOUSLY AND RECORD THE TIME AND PRESSU~ REMAINING AFTER ALL UNITS ARE CLOSED WiTH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECOND~ CLOSING TIME AND 1200 PSI REMAINING PRESSURF_ BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL 2. CHECK THAT ALL H{:X.D-EX:~/~I SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.; CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PR.m/ENTER AND CLOSE TOP SET OF PIPE RAM~. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PS1 UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAIVL BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSi FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12, TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLET1E BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage JG NOVEMBER 9, 1987 (FOR TBU WELLS) unocal Oil & Gas Divisior'~ Unocal Corporation R O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Environmental Group Alaska District July 18, 1986 Ms. Elaine Oohnson AK. Oil & Gas Conservation Comm. 3001 Rorcupine Drive Anchorage, Alaska 99501 Dear Ns. Oohnson: Listed below is the information you recently requested on the status of the following wells: Hemlock zone shut in, not abandoned. The well is still producing from the Granite Roint Sands. TBS A-10 & A-16 Sundry notice to abandon A-10 & A-16 submitted Narch, 1984. .The abandonment was never performed. TBS A-23 A-23S shut in since September, 1983. A-23L has just been shut in. This well is not abandoned. G-23RD, G-33 & G-34 Dual string producer. Hiddle Kenai "G" shut in Harch, 1984. K-21RD Dual string producer shut in July, 1983. The well is not abandoned. 'K-30 Dual string producer, Hiddle Kenai shut in July, 1982. The well is not abandoned. If you have any further questions, give me a call. Very truly yours, Candace Lockwood P.,ECEIYED 00280 Alaska O~l & Gas Cons. C0mmisslo. Anchorage '' ' ".' {" "-../.'-~--*;SUbseque~t Reports" ln'l~upHca[e · ' STATE O.¢~"¢I-ASKA " ' - 0IL AND GAS CONSERVATION COMMI~EE SUNDRY NOTICES AND REPORTS 0N WELLS {Do not u~ this fo~ for pro~os~ts to drill or to deepen U;e "APPLICATION FOR PERMIT~' for ~ch ,,, o,~ ~ ~As ~ . WELL~ WELL OTHER ' 2. NAMEOF OPERATOR . - Union Oil C'o' of california*---'' 3. ADDRESS OF OPERATOR . . · '. 909 W. Ninth Ave'.",. Anchorage, AK 99502'- :. ~o LOcATI(~N OF-WELL ' -. - : .' <-:.--. At. surf~.e 68,7" N &' 78 ' ' W; 'F~.-.S.E ' Corne~ . - ' .,---:-.- Sec. 17,' T9N.;'.RI3W,-.SM ' .. . - ... .... ..... ~" .... ' -I- ~ ~- _ . . - .-. ¢~; . .. .. ... ;, '.~! NUMERICAL CODE 50-133-202-10 6. LE~$E DES.IGNATIONAND SERIAL NO. ' ADL 17594 . ._ 7. IF INDIAN, ALLOt )'EEORTRIBE NAtvlE .. UNIT, FAR.~I OR LEASE NAMEr Tradinq BaY_Unit WELL, N~ K-30L 10~- FIELD AND POOL, OR _WIti1DCAT McArthur River ,G & West-fore- lands ]1,, SEC.., T.. R., M., (BOTTOM HOLE OBJECTIVE) Sec 21, T9N, Ri'3W,.'sM-. _ · _. 'tp'_ i;~RMIT Nb. . . · ;<¥'; z~. - Check .Ap~opriate Box TO lndicats-Nature of Notice, R. epo_.r~or~~ : ;':'..:' _ .- _. ' ' NOTICE OF II~ION'TO: '-::.,_. ..... TE3T WATER SHUTOFF ~ _ PULL OR ALTER CA~.ING -' FRACTURE TRE~T ~ I~/IULTIPLE COMPLET~ :' ' SHOOT OR ACIDIZE ~BA~=O~* · ' - ~1~ ' ~' ,.: ' 'CHANG~ ~N -REPAIR WELL S (Other) ~ ..... ,,, ..... DBCRIBE PRO~SEO OR COMPL~B OPERATIO~,(CI~rly ~ate ~11 pe~lnet detail~ and ~ive p~f~inent da[=~, in¢l~in~ elUmated date of Aa~in~ any proposed The following intervals were 1 and·2, I980-: WAT~RFR~C~U. E ~R EP^, R,NG WELL SHOOTING OR ACD~ING ! ! ABANDONMENT* (Othe,) Reper foration {~OTE: Repo~ re~l~ of mult~le completion on Well Com~le[lon or Recomptetion Reoo~ and LO9 form,) 1-2008" - 12014' DIL 12021' - 12026' DIL 12032 '~- 1.2040' -DIL 12084" - t2104' DIL 12230' - 12240' DIL 12365' - ~'~' ' u. --- ~, 0.7 DIL reperforated on October 31, November · : ,2 * ARCO Oil and Gas Company, Suboperator 'Alaska 0il & Gas Cons. Commission :," Anchorage .... ...- - : . hereby certtb~that .tilre~ foregoing l$ true and correct ED .......... TITLE -D I S T R I C T ENGINEER DATE 1 2/30/80 (This space for State office use) APPROVED' BY ......... CONDITIONS-OF APPROVAL, IF'ANY-: TITLE DATE - - ,, See Instructions On Reverse Side REV. 1-10-73 "Subsequent i~eports" in IJul~mt~.~[o STATE Ot~"'~ILAS KA OIL AND GAS CONSEr, v'ATION COMMITTEE =., , SUNDRY NOTICES AND REPORTS ON WELLS {Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) oil D--I CAS !--I WELL~ W EL~u OTHER 2. NAME OF OPERATOR . Union Oil 'Co. of California* ADDRESS OF OPERATOR .. 909 W. Ninth Ave. ,' Anchora~, ~laska LOCATION OF WELL At surface 687' N & 78' W Fr-SE Corner Sec 17, T9N, R13W, 'SM . .. '99'502 "'., 13. ELEVATIONS (Show whether DF, ET, GE, etc.) 100 ~ 14. 3'EST WATER SHU.T-OFF FRACTURE TREAT SHOOT OR ACIDIZI~ REPAIR WELL ' (Other) Reper forage Check Appropriate Box To Indicate Nature of Notice, Re : · NOTICE OF INTENTION TO.' MULTIPLE COMPL~E ' . ABANDON* ; '- CHANGE PLANS ~PI NUMERICAL CODE 50-133-20211 . '- 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN. ALLOTTEE OR TRIBE NAME 8. UNIT, FAR,'Vt OR LEASE HAME Trading Bay 'Unit 9. WELL NO. 10. FIELD AND POOL. OR WILDCAT . McArthur Riv~_r "G" [1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) . Sec 21, T9N, R13W, SM PERMIT NO. 70-7 )o~, or Other Data - -"" SUBSEQUENT REPORT OF: · WATER SHUT-OFF REPAi RING WELL . FRACTURE TREATMENT . ALTER lNG CASING · SHOOTING O R AC ID Iai NG ABANDONMENT* _ (Other) - (NOTE.- Report results of multiple completion on Welt Completion or Recompletion Report and Log form.) ~5. DESCRIBE PROPOSED OR COMPL~-TED'OPERATIONS (Clearly state all pertinent details, and 9ire pertinent dates, includ~ng estimated date of ~tartin0 any proposed work. 'We propose to reperforate ~he follOWing West Forel'~nd '.inte~als: · 12008-120i4 DIL 12021-1'2026 DiL 12032-1204'0.:. DIL 12084~12104. DIL .... 12230-12240 DIL. ' ' "123~5-12410 DIL .. : ... ; :. , ~ - . _. .. . .. -. . *ARc~ Oil and Gas Comp.any,--Suboperat°r .. . . · · ., . 16. I hereby certify that the foregoing is true and correct --C. ff. case · TITLE District 'Engineer DATE - ,9/16/8Q (This space for State o~use) ~. ,~h. , . . . - _ ° . _ . . . . - ~e Instructions On Reve'~e Side DATE - · -' - ' ' Submlt"lntention~" in Triplicate Form 10-403 & "Subsequent Reports" In Duplicate REV.~l-lO-73 . /...~, - - . , . ... , . ' STATE'O~ ,LASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen APl NUMERICAL CODE 50-133-20211 . 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 1. '. OIL WELL Use ,'APPLICATION FOR PERMIT--" for such proposals.) GAS n OTHER WELl.. NAME OF OPERATOR Union Oil-Co. of Ca_!iforpiaw 3. ADDRESS OF OPERATOR 909 W. Ninth. Ave. ,' Anchora~e, Alaska 4~ LOCATION OF WELL . .. 99'502 At surface · 687' N & 78' W Fr' SE Corner Sec 17, T9N, Ri3w, 'SM 13. ELEVATIONS (Show whether DF, ET, GR, etc.) - . '- 100 [,Gl ~ 1~ Check Appropriate Box To Indicate Nature of. NotiCe~' Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AClDIZ[ REPAIR WELL (Other) _ Reper forate MULTIPLE COMPLETE ' . ABANDON* CHANGE PLANS , 7. IF INDIAN, ALLO~i''I'EE OR TRIBE NAME UNIT, FARM OR /FASE NAME · Trading Bay-Unit 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT - - 1)-. SEC.~T., R., M.~ (BOTrOM HOLE OBJECTIVE) Sec 21, T9N, R13W, SM 12. PERMIT NO. 70-7 ~ort, or Other Data SUBSEQUENT REPORT WATER SHUT-OFF ~ REPAIRING WELL . FRACTURE TREATMENT _ /%L.TERING CASING · SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well ComPletion or RecomPletion Report and Log form.) [5. DESCRIBE PROPOSED OR COMPLETED'OPERATIONS (Clearly state all pertinent details, and 9lye pertinent date% includ~ng estimated ~rate of ~ ~ . starting any proposed work. 'We propose to reperforate the follOWing West Forel'~nd .interVals: · 12008-12014 DIL 12021-I2026 DiL ~ 12032'12040. DIL . . 12084~12104. DIL .- : 12230-12240 DIL. 123~5-124!0 DIL · .. .. .. . .. *ARCO Oil and Gas Comp-any, 'Suboperator hereby certify that the foregoing is true and correct TITLE_ District 'Engineer DATE, 9/],6/80 '(This space for State of.~. ~se) · . . _ DATE. - See Instructions On Reverse Side July 16, 1980 Production Foreman King Salmon Platform ARCO Oil and Gas Company P. O. Box 1400 Kenai, Alaska 99611 Ref: Attn: No-Flow Test of Well K-30,~King Salmon Platform. D~n Gann: Please refer to our letter of July 7, 1980 concerning the no-flow test on Well K-3. The correct well is K~8~.~ Please change your data to shc~ that we agree that Well K-3q is not capable of unassisted flow; therefore, you may remove the downhole safety valve~ frcm this well. please void our letter of July 7 regarding a no-flow test on Well K-3. Sincerely Lonnie C. Smith Commissioner July 7, 1980 Production Foreman King Salmon Platfonn ABED Oil and Gas ~ P. O. Box 1400 Kenai, Alaska 99611 Bef~ -f ~ have reviewed th~ test data 4f Well~.ob~_a~ned c~ June,2S, 1980 and partially observed by Petroleum ,Ins~ ~ld H -awkins. ~ agree that this well is not capable of ur~_ssisted f!cw; th~-efore, you may remuve the I.'(.-m P--7 SUBMIT IN DU}.. CATE* STATE OF ALASKA (S~e other st ructions on O1[ AND GAS CONSERVATION COmmITTEE ..... .~ WELL COMPLETION OR REfOMPLETION REPORT AND LOG* la. TYPE OF WELL: oII, ] ~ GAS ~ WELL ~ WELL ~ DRY ~ Other b. TYPE OF COMPLE~ON: WELL 2. NAME OF OPERATOR ,Union Oil Company of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 9950-1 · 4. LOC~TION OF WELL (Report location clearly and in accordance with any State requirements)* At su~ace 678'N & 78'W from SE cr, Sec 17, T9N-R13W, SM A~ to. prod4~n~r~a~ rei:)orted be,ow & 3646'E from NW cr Sec 21, T9N-R13W, SM At total depth 4974'5 & 3919'E from NW cr Sec 21, T9N-R13W, SM 50-133-20211] Trading Ba~ McArthur R~ver 70-7 13. D~TE uegan i ~ ~ , , I 7/lfl/7R i :~ . I 7/31/7R ! lO0 RKB . ~ ~: - ' D 9 G ' D & ~D , ~ ~LT~LE CO~L., 21. ' I .... cx~[,g TOOLS '~'~ '"~.~ ' :~' ..... ~ ~ ' ~ [NQne ~DUCI~Ib-!N~VAL(S). OF ~I~'dOM~IO~--TOP, BOSOM, NAME (~ AND ~)* ]23. WAS DIRE~ONAL SURVEY MADE :]0,876' (8685' TVD) --]],268 (3996' TV9) McArthuc River "~" Sand ~No ]2,008' (9648' TV~) -~]2,480 (]0,076' TVD) West Fore]and Sand t 24. Tt'PE ELECTRIC AND OTHER LOGS RUN None 25, CASI~C; SIZE 13-3/8" 9-5/8" i iiii CASING RECORD (Report all strings set in well) I WEIGHT, LB/FT. GRA. DE~ DEPTH SET (,iV~D) I HOLE SI~1 CF_ahIY~NTING RECOILD M/IOUNT PULLED 61# ]K-55 ] '2127"' ! 18" I Existing 47# P'I 12036' Exi sti . 26. LINER I~CO~----~ [ ~. //--- .TUBING RECO,~E) , [ ! Existin Ehor [ ]0,756 .I]0,6 , ~8 PERYO~AT~ONS OP~ TO PRODUG]I~O~ (interval size and numb~P-~ ~." ' ACID, ]],024-]],036; ]],040-13,046; 33,078-3]~]20 ~ 11,202-11,223; 11,232'1q,268; Total 179 l 4 csg gun with 4/SpF . [ ' ' -. P~ODUCTION ~':~8/3/78~'~ ~,-~o~-~,o~ }'Gas . L 5 ft [ P~oduc~ n~ DATE OF TEST,[~HOURS TES,TEID. ' [: lcnoxg SIZE tTI~ST Pk:tL!OD]'~-ROD'N''" FO,~, ,IoI~BDL' ]Gz%~CF' l WA'I~BBL. ~ GAS-OIL R.kTIO " ~ tc" WA'i'~BBL. IOIL GRAVITY-~I (CO~.) ~%V, ~TBING ]CAS~G PRESSURE ~CAL~T~ OI~BBL. GA~C~. I [ -'- 31.D~SPOSm'IONOF~S (Sold, used f~r ~uel, vented, e .) [TEST wITNESSED BY 32. LIST OF ATTACHMENTS 33. I hereby cer~ that the for_egoln~, and attached information is complete and correct as determined from all'available records ITL~ DIST. DRILLING SUPI-. ~,T~ ~78 *(See Instructions and Spaces I:or Additional Data on Reverse Side) INSIRUCTIONS General: This form is de:igned for submitting a complete and correct well completion report end log on all types of lands and lea~es in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spa~es on this form and in any attachments. Items :20, and 22:: If thi,, well is completed for separate production from more than one interval zone (mulliple completion), se state in item 20, and in item 22 show the producing int6rval, or intervals, top(s), bottom(s) and name (s) (if any) for only 1he interval reported in item 30. Submit a separate report (pa0e) on this form, adequately identified, for each additional interval to be separately produce.J, show- ing the ac~ditional data pertinent to such interval. It~n'~6: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing ard the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). '"34. SUMM'ARY' OF' F.ORMATION TESTS INCLUDIN(; INTERVAL TESTED, PH~URE DATA ¢ ~OV~I~' OF OIL. GAS, 35. G~GIC MARK~ WA~ AND MUD ~A~ MEAS, D~{ r~ V~T. . . ~v. ~-,-zo STATE ~ ALASKA SUSMrr ~ D~. LICAT~: ~-API'NU~IER/CAL ~'ODE OIL AND GAS CONSERVATION CO~I~EE ~ , ...................... 50-133-20211 " MONTHLY REPORT O'F DRILLING ~ '~s~ ~s:~o~ ..' ..... AND WORKOVER OPERATIONS AD~ Z75~4 .................... . / ~ r ..... Union Oil Company of California * Trading Bay Unit ,, 909 WDSt Ninth Avenue, .Anchorage~ Alaska 99501 T~U K-30 (4~-21) ~ 30~OL _McArthur River "G ~~re] 678' N, 78' W fr SE cr, Sec 17, T9N, R13W, SM C~FE~: Sec 21, T9N, R12W,F~M ,, " ..... ' ~"~ '~ ~ 117 · ,, . ,,, . ,., ,, ,, . ,, 13. REI~ORT TOTAL DEPTIq AT ]~ND OF MONTH. CHA~NGES IN HOLE SIZE, CASING A~ C~NG JO~S INCLUDING DEP~ SET ~ VOL~ USED. P~O~TIONS. ~TS ~ ~S~L~ FISHI~rG JO~ J~K ~ HO~ AND SIDE-~C~D HO~ ~D ~Y O~R SIGNIFIC~¢T ~~ ~ HO~ ~ITIONS Report of Operations for the Month of July 1978: Moved rig over location on July 10, 1978. Killed well by bullheading in with Dril-S pill. Lubricated annulus with 8.8 ppg Dril-S workover fluid. Nippled down tree and nippled up BOP. Tested BOP and manifold on July 12, 1978. Unlatched short string out of packer and pulled out of hole. Ran free point and jet cut long string at 11,818'. POH with long string and upper packer. Changed to 5" drill pipe rams and tested BOP on July 16. Ran wash pipe and washover shoe and worked to top of lower packer at 11,867'. Ran overshot and recovered lower packer. Ran 8-1/2" bit and 9-5/8" casing scraper to top of liner at 11,216'. Ran 6" bit and 7" casing scraper, washed fill to 12545'. Lost one cone off 6" bit. Circulated hole clean and spudded Dril-S pill in liner. Re-perforated with 4" casing gun at various intervals from 11,268' to 10,876'. Made gauge ring run to PBD. Made two attempts to set B~' BD-1 packer on wireline without success. Ran Baker F-1 packer on drill pipe and set same at 11345'. Packer did not test. Milled out and retrieved packer. Ran and set second Baker F-1 packer at 11,310', and tested same at 500 psi. Spotted Dril-S pill from packer up to 10,610'. Displaced hole above 10,690' with 9# filtered inlet water. Changed to dual 3-1/2" rams and tested BOP on July 24. Ran dual 3-1/2" completion tubing with hydraulic packer, gaslift valves and surface control safety valves. Pulled up to change out crushed 1/4" control line. Ran back in hole and unable to work long string tail pipe past top of liner. While working tubing, both strings broke at the surface and fell 23' below the rotary table. Engaged both strings with overshots and pulled out of hole. Installed guide nose on tail pipe of long string and re-ran both strings with new dual packer. Landed tubing, set packer with 3000 psi. Nippled do~ BOP and nippled up Christmas Tree. Tested tree, tubing hanger Dlv~0~ flange and safety valve control line to 5000 psi. Installed production flow lines and release rig on July 31, 1978, Completion strings are as sho~ in th~ ~tt~nh~ ~nh~m~tic. , .... ; il 1, , 11 . 14. J he~b~t~ ~t the forego~ ~ t~e ~ ~ ,~//~_~ ~/~_~- - =~ ~._ n~_.~.,t ~,~ 8112/78 otl and gas coniervat(on commi~ee bythe 15~ of the suec~ding mn~, ~le~ otherwise directed. * Atlantic Richfield Company is sub-operator. * Atl~nticRichfieldCompany l'Subject. File IPage No. IDate e '?~, dss" Ip~SyS ' Subml t "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use ,,APPLICATION FOR PERMIT--" for such proposals.) 1. Ow~LLL[--~WELLGAS D OTHER NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 909 West Ninth Avenue, Anchorage, AK 99501 4, LOCATION OF WELL Atsurface 678'N 78' W fr SE er, Sec 17, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 100' RKB MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) Workover 5. APl NUMERICAL CODE 50-133-20211 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBU K-30 (44-21) 10. FIELD AND POOL, OR WILDCAT McArthur River "G" & West Foreland 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 21, T9N, ~13W, SM 12. PERMIT NO. )oft, or Other Data SUBSEQUENT REPORT OF: .MULTIPLE COMPLETE FRACTURE TREATMENT' ALTERING CASING ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* CHANG E PLANS (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Present Status: The well is presently completed as a dual completion producing by gas lift from the "G" zone (10,876' - 11,268' MD') and the West Foreland Formation (12,008' - 12,480' MD). Proposed Program: We proposed to kill the well with Dril-S Pill and workover fluid. Install 3000 psi BOPE w/dual rams and Hydril. Retrieve the existing completion assemblies and clean the well. Reperforate "G" zone, run dual completion string with gas lift assemblies and reperforate West Foreland Formation 'through tubing. A production profile survey will be run throughout the West Foreland Formation. The work will commence on or about July 1, 1978. JUN 2 3 1978 * Atlantic Richfield Company is Sub-operator I hereby cer~')that the foregoing is true and correct · R. Cal 1 '_ .ar .... (This s~ace for State office use) Dist. Drlg, Superintendent., DATE 6/23/78 APPROVEDBV ,~.O. ,,~_,e,..-....,~.~.~"'~'""~,*"%' TITLE:,, PETI{DLEUM ENGZNEER CONDITIONS OF APPROVAL, IF ANY~r See Instructions On Reverse Side DATE JUNE 26. 1978 Approved union Union Oil and Gas D~sion' Western Region Union Oil Company ,.. California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 279-7681 lc. ~o~:!.~,,~,, l~m~F Il 13 ENG I: J. uly 9, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 [ 4 ENrT, ] 5 '~N,3 i .... I3 o,~ot. _. I r~sv I i D,~,~T i .... I SEC CONFER: FILE: RE: TBUS K-30 (44-21) Dear Mr. Marshall: Enclosed for your approval are three (3) copies of the Sundry Notice and Reports on Wells for the above captioned well Very truly yours, District Drlg. Supt. sk Encl. (3) cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Phillips Petroleum · Skelly Oil Co. Standard Oil Co. of Calif. DIVISION OF OIL AND OAS ANCHORAOE Form 10-403 REV. 1-1C~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports, in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL i i OTHER 2. NAME OF OPERATOR *Union 0il Company of California 3. ADDRESS OF OPERATOR 909 W. Ninth Avenue, Anchorage, AK 99501 4. LOCATION OF WELL 5. APl NUMERICAL CODE 50-133-20211 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBU K-30 (44-21) 10. FIELD AND POOL, OR WILDCAT c Art~oreRiver "G" & est ur land At surface 687' N & 78'W fr SE er Sec 17, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 100' RKB ~Ove M~Lw 14. CheCk Appropriate Box To Indicate Nature of Notice, Re Sec 21, T9N, R13W, 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Improve PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Lift SUBSEQUENT REPORT OF: WATER SHUT-OFF F'~ REPAIRING WELL FRACTURE TREATMENTF~ ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Present Status: - The well is presently completed as a dual completion DreduCing by gas lift from the "G" zone (10,876-11,268') and the Westforeland Zone (12,008-12,480'). Proposed Program.: We propose to kill the well with 9 PPg workover fluid. Install 3000 psi BOPE w/double rams & Hydril. Pull the existing completion assembly. o i " " ~n le t~e ~ ": .... ~t~_n.~d Zo,,.n.~ by running a single 3-1/2" gas lift completion assembly. Run a production profile. Reperforate through tubing, based on the production profile. The work will commence about July. 21, 197~ ~ ~ ~ ~ ~ ~~ ,t;I! 0 :~ ',~,'~,'~ *Atlantic Richfield Company - Sub-operator -- 16. I hereby c~ti~ tha~he ~goln? is true and correct SIGNE ,1:3~/.~'1~' ~~ 2 TITLE DIVISION OF OIL AND GAS ANCHORAGE Dist. Drlg. Supt. DATE · 7/9/75 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Document Transmittal Union Oil Company of Ca' . union To From Harry Kugler G. H. Laughbaum, Jr. Transmitti ag the fo l I owl ng: Date At At 6-16-70 NO. State of Alaska Division of Oil & Gas Anchorage District lea. Sepia and Blueline 2" DIL TBU K-SO (Orig. Ho[e) lea. Sepia and Blueline 2" DIL TBU K-SO [Re trill) . ,. 2 Directional Surveys TBU G-$6 __ PLEASE ACKNOWLEDGE AND RETUR~ SIG~NEI3 COPY TO: Union Oil Coml~any 2805 Denali Street Anchorage, Alaska 9950~ ATTN' Rochelle Carlton Form 369 (Rev 12/67) Form P--7 STATE OF ALASKA SUBMIT IN DUPIICAT~;* ( See other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE riI I ~T---- i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* I I WELL WELl, DRY Other b. TYPE OF COMPLETION: WELL OVER EN BACK gESVR. Other 2. NAME OF 0PERATOP. *Union Oil Company of California 3. ADDRESS OF OPERATOR 2805 Denali Street, Anchoraoe, Alaska 99509 4. LOCATION OF WELL -(Report location clearly a~'d in accordance with any StSte requirements)* at,u~ace 687' N & 78' W fr SE cr Sec. 17. T9N,'R13W, SM At top prod. interval reported below · 4191'S & 3646' E fr NW cr Sec. 21, T9N, R13W, SM At total depth 5. API NUM.F.R/C..~J.~ CODE ADL 1 7594 8. UNIT,FA.R_Ni OR LEASE Al'A/ViE Tradino 2ay lJnit 9. WELL 1~O, 1<-30 (44-21 ~ ('UDDer Comple4 lO. F~ on ~nArthl]r IRi vor o~Iv~) Sec. 21, T9N, R13W, SM 12. PI~:U'ViIT ~O. 4974' S & 3919' E fr NW cr Sec. 21 T9N, R13W, SM 70-7 13' DATE SPUDDED 114' DATE T'D' RE~CI-LED 115' DATE COiViP' SUSP' ~ A~D' i15' ELEVATIONS (DF' RKB' RT' GR' 'ETC)' 17' ~LW' C'ASINGHEAD 1-2',3-70" , :1, 4~14-70 :' I 4 27-70 ! 1oo' v,a ' 18. TOT'%~L.,DE[PTH~ iVLD & TV.D~19. PLUG ~CK MD & ~D~. ~ ~LT~LE CO~L., · [ 21. INTERVALS "DRILLED BY '-.. .,. :[~" :' .,' ;L. . [ DEPt. / ~OW~Y* { ROTARY TOOLS ] CABLE TOOLS 12600'~ '(lOl::.86:~VD} 12552' (lO047'VD/! 2 1 ., .... : ,: ..,.. ',' SURVEY ~&DE 108:76": {8685 ':' VD) - 11268' (8996'VD) McArthur River "G" Sand Yes ,,~ , , . ,~ . 24.( ~E~C'TmC ~D 0~ LOGS RUN 'D!L., !'$dhic ,..an].(/. SNP.' ___ ~.:.;.. ...... ~ ..... . .... .;::,. CA. Sm~ SlZ'~/ ' :'"'~V~iGHT" LB/FT. I GRA, DEI DEPTH SET, (M.D) ..... -'-318 :,,~ !: :':'"',~q :ill#ITt,,: K-55 2187 ~a., ~ ' '~' ~ ~co~ , .;,~ ~ ~.':' TO? (~D)' BOTTOM (MD) SACKS C~T* ~.8. ~ . · . See..: R'e ye .. CASING RECORD (Report all strings set in well) HOLE SIZE 18" 12-1/4" (Interval, size and number) :,~, i ...... ~,.,~':t '~,,:~ .,;,,~' '.,,,?'~ .... !"'~ '}"!:q ' " m::,'.-~ i: ,.::, 6 ',i ?:: :! .> .~ ,,. J' ~"' '"i' ""~' ! i CEAiENTIi~G RECOi~D / A/VIOUNT k°ULLED .t000. s× "fl" Noat , 27. TUB~G ~O0~ S~E~ (~D) SIZE DEP~ SET (~D) PACK~ SET (MD) 29. ACID, SHOT, F~CTLrHE, CF_~ViE. AIT SQUEEZE, ETC. ~x -,C'lass "G" z,, w/1.O0 sx :Class "G" - Liner z w/275",'SkC~ass "G" .'~'ATE FIRST ~I%ODUCTION [ 'FRODUCT10'N METHO'D (Flowh~.g, gas lift, pumpiag--size and type of pump) [WELL STATUS (Producing or ii' .... 7. '" ,.. '.'i .... ' . :-.,4-~9~-70 .'- [' FlOwltl_Q ,,, l, Prnd~,ninn DAT]~ 01t,' TZS,14.t /IHou'Rs TESTED · ICI-ICe'RE SiZE [PROD'N FOR O~BEL. GAS--1V~CF. WATER,--BBL. [G~k'S-OIL r4/LTIO ..., .. , ' "'" """" ' I I zone ._5,~--70 '. . ,.,t~.4 ..... ~ 7nn~i I ' J' 2041 . ~ss.. .... , ..:~ .~ . ~,-.ou, ~ ,I 27 ' '.. ,, 'Tq',' "' ']?'."~'0- ]" ~ ~ 2041 ~ 738.8 ~ ,(. '~'-* L:. '..-' .' ~'as(l l::.i ft. :an~ ffl:are ' Dick Smi th :[-32. LIS'T QF ATTACHMENTS e'l',q~ ~_i~'gtorV :.~;d Directinn~l S~rvov '~,..82. I herebs ~6~r$~y,,.fh~t the ~ore~ofn~ and at~ebe~ fn~6rm~tfon fB complete an~ correct ~ determfneO ~rom ~llFav~flable records ~t:t"a]~ti c Ri chfiel ~.~6mp'6mp~J~~(~ ~erator ], '~ - ~' '~S,~dm.,tru¥~., ~.a S~c,, Jor Additio.al Data on Reverse INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repor! end log on all types of lands.? and leases' in Alaska. ~;.~; Item: 16: Indi~ca'te which elevation is used as reference (where not otherwise' shown) for depth measure- ments given in ether spaces on this form and in any attachments. Items'~20, and 22::'.lf.?his well is completed for separate production from more than one interval zone (multiple comPletion)-,' so state in item 20, and in item 22 show the prcJucing interval, or intervals, 'top(s), bottom(s) an"d 'name (s) (if' any) for only the interval reported in item 30. Submit a separate report (page) on this f0?rn, ~'dequatel~;':identified, for each additional inte~ val' .to be seperately produced, show- ing the adlditional :.datn pertinent to such interval. .r Item26: "Sacks cement,,: Attached supplemental records for this well shoulci show the details of' any mul- ... tiple stage cementjng'::'anct the location of the cementing tool. ., .. Item 28: Submit.a separate completion report on this form for each interval to be separately produced. (See instruction for.items 20 and 22 above). '~ '~'i ' ~'" .... 34. SUMMARY O!~ I~ORMATION TESTS INCLU'DIN(I IN'~.'ERVkl.. TESTED, PRE.~URE DATA AN~ RECO~]EZRIES OF OIL, GA~, '-' ........... ' . 35. G~OLOGIC ,. ,. . WATER AND MUD 11268 11232. ;. ,,-,' - . .: ~^s. 11224-11.~0~2 ........ ' , - 11120-11078 · 11046-11040 ~op Middle ~enai 10876' 11036-11024 "O" 10988_10956 10944-10926 :":~ ' · 10888-10876 . ~a. cor~ ~^T^. ^TTACU ~mE~ ~scan, mo~s ot~ ~,o~oa¥. Po,OmT¥. raAeTt~. ^~'PAm, m,T D~'S .. ^,D D~'r~cn'm~ s. OWS O~' om. ~s OR W*~m~. NON~ i i ii i i ,.DST ~11: Shot 4 1/2" H/F 10802-10830' (28'). Ran Halliburton csg tst tools w/1200.: WC. Set pkr @ 10788. Opn tools f/IF @ 12:12 pm 4/18. Took 5 min IF. 1 hr ISI. Opnd tool @ 1:17 pm f/2-hr flow test. Had 2800 psi @ surf in 30 min. Had GTS @ rate of 5.8MM cuft/day w/slight tr of liquid, SI f/2-hr SI period @ 3:17 PM. Closed tstr @ 5:17 pm. Bksctld DP. Re¢ approx 20-bbls wtr w/slight oil stain. PO. Inside IH 4592 IF 969 ISI 3643 Flow 3595 FSI 3800 FItS 4545. Top OS IH 4590 IF 1026 ISI 3590 Flow 3562 FSI 3748 FHS 4543. ,, Btm OS IH 4620, IF 1034 I.SI 3656 Flow 360'8 FSI 3811 FHS 4620. IN~TIIUCTIONS: Prepere and submit the FINAL REPORT on the first Wednesday efter ellowable hal been sesigned or -ell ia Plals,i, Abandoned. or Sold. FINAL REPORT should be submitted also when operations are suspended for an indefinite or appre¢,abie 'length of time. On ,orkovera when an official test is not required upon completion, report completion ~nd repreaentatsv, te,t date in blocks provided. The FINAL REPORT lorn nay be used for reportin$ the entire operation if spate is evsilsble. DAILY WELL HISTORY - FINAL REPORT District Alaska County or Parish Kenai Borough State Alaska Fiel~ G-Zone, West Foreland Zone Lease or Unit TBUK-30 Well No.ua-21 Auth. or W.O. No. 19-7230 Title Drill TBUK-30 (#44-21) Operator Atlantic Richfield Company Spudded or W.O. Begun .qpudded Date 1-23-70 TABCO'S W.I. Prior Status Hour 3:30 PMif a W.O. -0- Date & Depth as of 8:00 A.M. 4-28-70 4-29-70 Complete Record for Each Day Reported Testing -Clnd up "G" Zone. Tstd 723 BO, 127 BW, 15% BSgW in '(24-hr rate) API Gray 33.5, Tbg press 140, Csg press 0. West Forelands Zone SI until "G" Zone clns up g is tstd. Productidn tests for 4-29-70 after 24-hr data completed on G- Zone. Producing - "G" Zone 24-hfs flowing 2068 BF, 2041 BO, 27 BW, 1.3% BSgW GOR 362, API Gr. 33.3. West Foreland Zone 18-hfs flowing 1242 BF, 1217 BO, 25 BW, 2.0% RS&W, GOR 180, API Gr 31.5. FINAL REPORT. Old TD New TD ,, t~-:600" PB Depth Rotary Released Rig Classifications (Oil, Gas, etc.) 4-27-70 Date 3:00 AM Kind of Rig Type Completion Oil (Single, Dual, etc.) Dual Producing Method Flowing Official Reservoir Name(s) McArthur River G-Zone ':Jest FePeland Potential Test Data: WELL NO, DATE RESERVOIR PRODUCING INTERVAL OIL OR TEST TIME PRODUCTION GAS ' OIL ON TEST GAS PElt , 44-21 4-29-70 McArthur Rvr. G-ZOne 10,876-11,258 Oil 24-hr 2,041 738. West Foreland Zone 12,008-12,4~0 Oil 18-hr 1,217 219 b'.CF ..... 18-hfs GRAVITY.. PUMP SIZE. SPM X LENGTll CllOKE SIZE T. P. C. P. WATER % GOR ALLOWABLE EFFECTIYE CORRECTED .. 75 0 1.3% 362 33.3 .... 100 0 2.0% 180 31.5 .... Distribution: ]'he Above is Correct: Orig.: i)rilli,,g Sect ion - l)allas cc:- l)istrict Office Engi.eering I)ivisio,s . (720) Co- ()~'ne r ( .~ ) As Ai,|~roi,r i at.e llegio.al Office, %,'11 Il.cord File PAGE NOs..=_.~d,~==(NIIklllfll AI.I, DAII.Y ~1(I.I. III.~'I'~)IIY I'~qlM5 ¢'¢)NSt~('IITIVFI.Y AS 'I'III.iY Alii-, I'ltll'Alltll I.()11 t~AIII ~11.1.. ! .. · ., INSTfllYCTIONS: This form ia used during drilling or ,orkover operations. If testing, corinR, or~ perfoestinff, sho- formation name in describing work performed. Number all drill stem teats aequentzally. Attach deacriptnon of all cores. Work per- formed by Producing Section w~ll be reported on "INTEiIIM" sheets until final completion. Ileport official or representatsve teat on "FINAl." form. (1)Submit "INTERIM" sheets -hen f~lled out but not less frequently than every 30 days. or (2)on Wedneaca of the week in whzch oil string ia set. Submit weekly for workovera and following setting of oil string until completion. District Alaska DAILY WELL HISTORY - INTERIH County or Parish Kenai Borough . State Alaska Field G-Zone: West Foreland Zone Lease or Unit TBUK-30 Well no.-,=- Date'& Depth at 8:00 A.M. 4-24-70 TD 12600 ' 4-27-70 TD 12600' Complete Record for each Day While Drilling or Workover in Progress PBD 12552' -Rng tbg - MW 76#, Vis 47, WL 11, Oil 4% Perfd 4 1/2" hpf 12272-12268, 12266-12258, 12242-12230, 12212-12208, 12184-12173,12166-12156, 12105-t2092'. 12087-12082, 12068-12055, 12040-12034, 12025-12021, 12014-12008, 11268211232, 11224-11202, 11120-11078, 11046-110G0, 11036-11024, 10988-10956, 10944~10926, 10888-10876. Chngd pipe rams & pulled wear bushing, Ran 3-1/2" tbg w~Guiberson 9-5/8" pkr, Otis 7" pkr g Otis CS Mandrels, 104 its now in hole. PBD 12552' - Ran 3-1/2" 9.60# N'80 Buttress Dual tbg strings to top of lnr @ 11216'. Could not get tbg tail to go inside lnr. Pulled tbg strings. Welded 6" O.D. centering lugs ontbg tail g below pkr. Reran 3-1/2" long tbg string. Tail g Pkr went in lnr OK. Long tbg string - 382 its 3-1/2" 9.6C~ N-80 Buttress w/sp clearance coUpling (11765') landed @ 11940', 7" Otis RH-1 pkr @ 11867', 9-5/8" Guiberson RH-2 pkr @ 10711' w/12 3-1/2" Otis CX mandrels @ 3846, 4810, 5830, 6770, 7510, ~041, 8606, 8893, 9269, 9677, 10671. 3-1/2" CCi, X-0 sly @ 11833'. 3-1/2" Otis X-nipple @ 11904'. Guiberson Shear sub @ 11940'. 3-1/2" ball vlv @ 438'. ~an short tbg string. Landed tbg. Short tbg string - 344 its 3-1/2" 9.60# N-%0 Buttress sp clearance coupling tbg (10629') Landed @ 10~13' w/12 3-1/2" Otis CX mandrels @ 2777, 3832, 4796, 5816, 6747, 7492, 802~ 8584, 8869, 9242, 9652, 10643. Otis "G" nipple @ 10754'. Landed tbg into 9-5/8" pkr w/5000#. 3-1/2" Otis ball vlv @ 405'. Removed BOPE. Installed OCT dual 3-1/2" X-mas tree. Tstd tree w/5000 psi OK. Displ mud w/diesel oil 900 bbls w/Hallibumton pmps. Set 7" pkr w/1000 psi. Set 9-5/8" ~kr w/2003 psi, shea~ out shear sub w/4000 psi. Tstd both pkrs w/1000 psi OK. Rig..Relaased @ 3:00 A.M. 4-27-79· __ The Above is Correct: 1.1. LV 4, lq70 S ! (;N A'I'IlllE / _11J_'~gt~ick_flz~J_ll.in~." ' '" T ! T I.E PA(;E No ...... ,=} _{NI~MP, I':II AI.I. DAII.Y WI'.I.I. IIIN*I*OIIY Iq)liMN (R)N.~I<(:IJ'flVEI.Y AN I*IIEY Alii-: I'IIi:I'AIII'I) ii)Il I':A(H ~H,I.. ) I)AI'E PIIINTI-:D IN II..%.A. -... .]1~-459-2 INSTllUCTIONS: This form is used during drilling or .orkover operations. If testing, coring, or perforating, sho, ~me in describing work performed. Number nil drill stem tests sequentially. Attach descrtpt~on of all cores. Work formed by Producing Section will be reported on "INTEIIIM" sheets until final completion, lleport official or representatsve tent on "FINAL" form. {l)Submit "INTEBIM" sheets when filled out but not less frequently than every 30 days, or of the week in which oil string is set. Submit weekly for ,orkovers and following setting of oil string until completsoa. DAILY WELL HISTORY - INTERIH District Alaska County or Parish Kenai Borough State Alaska Field G-Zone, West Foreland Zone Lease or Unit TBUK-30 Well No :--- Date & Depth at 8:00 A.M. 4-20-70 TD 12600' ~-21-70 TD12600' 4-22-70 TD 12600' ~-23-70 TD 12600' Complete Record for each Day While Drilling or Workover in Pro~ress PBD 12552' - CO amt - MW 75#, Vis 49, WL 10, Oil 5% Ran D/A. Shot 4 1/2" holes @ 11385'. Ran 7" Halliburton E-Z drill rtnr. Set @ 11335'. Pmpd 12-cuft/min @ 2900 psi. Sqzd holes @ 11385'. Mixed 100 sxs Class "G" cmt treated w/l% D-31 & 0.3% BJR-5, 100 tuft wtr ahead. Disp w/20 cult wtr & 928 cult mud. Closed tool & sqzd 85 sxs cmt to fmtn in 2 stages. Final press 4000 psi. CIP @ 1:30 P.M. 4-17-70. Bksctld DP - no cmt rets. POH. Ran 9-5/8, Baker Retv cmtr to 11104'. Pmpd into lrw lap 16-cuft/min @ 2200 psi. Sqzd lnr lap. Mxd 150 sxs Class "G" cmt t~eated w/l% D-31 & 0.3% BJR-5. 200 cult wtr ahead. Displ w/60 cuft wtr & 632 cult mud. Closed tools. Sqzd to lap 125 sxs cmt in 3 stages. Max press 4000 psi. CIP @ 12:35 A.M. 4-18-70. Held press f/20 min. Rlsd tool. Bksctld DP cln - no cmt rets. Ran D/A. Shot 4 1/2" H/F 10802-10830' (28'). POH w/D/A guns. DST #1 10802-10830'. Ran Halliburton csg tst tools w/1200' WC. Set pkr @ 10788'. Opn tools f/IF @ 12:12 P.M. 4-18-70. Took 5-min IF. 1_ h~ ISI. Opnd tool @ 1:17 P.M. f/2-hr flow tst. Had 2800 psi @ Surf in 30-min. Had GTS @ rate of 5.8MM cult/day w/slight trace of liguid. SI f/2-hr SI period @ 3:17 P.M. Closed tstr @ 5:17 P.M. Bksctld DP. Rec approx 20-bbls wtr w/slight oil stain. POH. Inside - IH 4592 IF 969 ISI 3643 Flow 3595 FSI 3800 FHS 4545. Top OS - IH 4590 IF 1026 ISI 3590 Flow 3562 FSI 3748 FHS 4543. Btm OS - IH 4620, IF 1034 ISI 3656 Flow 3608 FSI 3811 FHS 4620. Ran 8-1/2" bit S 9-5/8" csg sept to top of cmt plug @ 11109'. Circ& cond gas cut mud. POH. Ran 9-5/8" Baker Retv sqz tool. Set @ 10690'. Fmtn b~oke dn @ 3200 psi @ 16 cult/ min.. Sqz perfs 10802-10830'. Mxd 200 sxs Class "G" treated w/l% D-31 & 0.3% BJR-5. Preced w/200 tuft wtr. Disp w/40 cuft wt~ & 636 cult mud. Closed tools. Sqzd away 175 sxs w/3200 max press. No bld up. Clea~ed perfs. Mixed 100 sxs Class "G" w/l% D-31 & 0.3% BJR-5. Preced cmt w/100 cuft wtr. Disp w/ 300 cult wtr & 800 tuft mud. Closed tools. Sqzd away 75 sxs cmt w/max press 4000 psi. CIP @ 6:15 P.M. 4-19-70. Held 1500 psi in annulus du~ing sqz to tst 915/8'' csg. Rlsd tools. Bksctld DP cln - no cmt rets. POH. Stood cmtd 12-hfs out of hole. Ran 8-1/2" bit g 9-5/8" csg sept. Top of cmt @ 10691' (ha~d). PG12552' - POH - MW 76#, Vis 60, WL 10, Oil 5%. DO hard cmt 10691-10871.' Circ& cond mud. Ran 9-5/8" Baker Retrv cmtr to 10700'. Press tstd shot holes 10802-10830' w/3500 psi. Held 30-min OK. POH. Ran 8-1/2" bit & 9-5/8" csg scpr. DO hard cmt 11109-11216'. Circ& cond mud. PBD 12552' -Circ - MW 76#, Vis 50, WL 11, Oil 5%. Ran 6" bit &'ink sub. DO E-Z drl retnr @ 11330'. CO cmt 11330-11q45'. RI to 11935', DO E-Z drl retnr & hrd cmt 11935-12025'. RI to baffle cl~ @ 12552'. Circ 1-1/2 hrs. POH. Ran 6" bit & 7" csg scrpr to 12552'. Circ off btm, prepg spot 200 bbls Invermul mud. PBD 12552' - ?erfg - MW 75#, Vis 50. Spotted 200 bbls 72# Invermul mud @ 12552-10500'. POH. LD DP & DCs. Ran DA. Perfd q 1/2" holes/ft w/csg guns 12q80-12q68'. 12408-12362' 123q5-12268' in progress. Chgd perfg WL unit after line stranded. Tile Above is Correct: ~ · / ) ., .' . · · S ! (;NA'I'IIIIE / / TI TI.E PAGE N(). ~_=__(NIIUIIEII AI.I, DAII.Y W[:l.I. IIIN'I'()IIY ['IJlIUS C(~NNI.'.I:II'I'IVI:I.Y AS TIII.:Y Alit'. I'III.:I'AIII.:I) t'(ill YA('II ltl.l.. ) April 23, 1'370 DATE I'lllN'll':i) IN II,S,A, %: ]1l-4.',9.2 I.' ~' . IN~TflUCTIONS: This form is used during drilling or workover operations. Xf test~n8, coring, or perforsting, show form,t:o: n-~'me In describing work performed. Number all drill stem tests sequentially. Attach description of sll cores. Work per- formed by Produc:ng Section will be reported on "INTEfllM" sheets until finnl completion, lleport official or representatz,e test on "FINAl." form. (1} Submit "INTEI{IM" sheets when filled out but not less frequently than every 30 days. or (2} on wedaes=~- of the week in wh:ch oil string is set. Submit weekly for workovers and following setting of oil string until completion. DALLY WELL HISTORY - INTERIM District Alaska County or Parish Kenai Borough State Alaska Field G-Zone: West Foreland Zone Lease or Unit TBUK-30 We 1 1 No Date & Depth at 8:00 A.M. 4-9-70 11570' 4-10-70 11756' 4-13-70 12386' ~-14-70 12600' ~-15-70 12600' \ 4-16-70 12600' 4-17-70 TD 12600' Complete Record for each Day While Drilling or Workover in Progress (116') MW 76#, Vis 42, WL 7, Oil 7% - Drlg Trpd. PU 40-its HWDP. Rmd 11526-11550'. Drld 11454-11570'. Survey: 11550' 27°30' 9247.43 VD S23E S5236.42 E3880.09 (186') MW 75#, Vis 45, WL 6.0, Oil 6% - Drlg Drld 11570-11756'. Survey: 11657' 27© 9342.77 S19E S5282.35 E3895.91. (630') MW 76#, Vis 46, WL 6, Oil 4% - Drlg Drld 11756-12386'. Survey: 12226' 25© 9856.08 S16E S5516.88 E3968.17 (2t4') MW 76~, Vis 51, WL 6.4, 0il 6% - POH Drld 12386-12600'. Survey: 12526' 24© 10130.13 S13E S5635.76 E3995.62 (0') MW 76#, Vis 49, WL 6.8, Oil 9% - POH Ran Sch DIL 12564-11334' (two runs). Ran 8-1/2" bit. Measured in hole CK. Clnd brdg @ 12570' $ ran to 12600'. Circ g cond. POH. LD HWDP, Monel & steel DC. 7" lnr cmtd @ 12598' top @ 11216'. Ran 260' (6-its) 7" 29# N-80, 8 rd LT&C w/turned couplgs & 1099' (27-its) 7"'26# P-110 8-rd LT&C w/couplgs as lnr w/TIW fill-Up shoe & baffle tlr (bfl tlr @ 12552') g TIW Hydril Hngr & Tie Back Sly. Top of sly @ 11216'. Ran cmt on 32-its cmt lnr @ 12598' w/225 sx Class "G" w/l% D-31 g 0.3 BJR-5. Started mixing @ 6:40 AM 4-15-70. Mix time 10-min. Preflushed w/100 tuft wtr. Displ cmt w/56 cult H20 g 1365 cult mud. BmPd plug. Had good circ thruout. CIP ~ 7:20 AM 4-15-70. Float held OK. PBD 12552' (0') - GIH - MW 76#, Vis 48, WL 6.8, Oil 5.5%. POH w/10-stds $ backscUttled DP - Clean - no cmt. POH. PU 48-its 3-1/2" DP g stood in derrick. Ran 8-1/w" bit g 9-5/8" csg scpr w/DP rbrs on ea jr. Ran to top of lnr @ 11216'. No cmt. Circ 1-hr & POH. PU 6" bit g 7" csg scpr. PBD 12552' - MW 76#, Vis 49, WL 6.8, Oil 5% GIH Ran 6" bit g 7" csg scpr to 12552'. Circ 2-hrs. POH. Ran D/A Gamma Ray-Neutron w/tlr lctr 12545-10600'. Ran D/A CBL w/tlr lctr 12545-10600'. Ran D/A. Shot 4 1/2" holes @ 11985'. Ran 7" Halliburton E-Z drill rtnr. Set @ 11935'. Hole took fluid @ 3600 psi @ 10 cult/min. Mixed 100 sxs Class "G" w/l% D-31 g 0.3% BJR-5 rtdr w/67 tuft H20. Put 100 cuft wtr ahead. Dspl w/20 tuft wtr & 917 cuft mud. Closed tools. Sqzd 109 cuft cm. __ fmtn. Had slow build up to 4000 psi. Max press ~000 psi. CIP @ 2:05 A.M. 4-17-70. PO of tool. Bkscuttled DP cln. No cmt rets. POH. Ran D/A perfr. PA(;E No. 7 IqtlNlEI} iN U.h.A. The Above is Correct: · , ! ) ~ / ; /~'- , / . ( / , , S ! ¢;N A'I'IIIIE 1'1 TIE (NIq~IIFII AI.I. IIAII.Y WEI.I. III.%'I'(UIY }'l)llMh (])Nhl:I:IJTIVI.:I.Y AS TIII.:Y Alii.: I'III.:I'AIOI! I.(UI I:A('II ~1.1.1., ) · Al'mi ] 23, i '"- I}AI'E INSTIIUCTIONS: This form is used during drilling or workover operations. If testing, coring, or perforating, aho- format:on name in describing work perfor-med. Number all drill stem tests sequentially. Attach descr:ptton of all cores, Work per- formed by Producing Section will be reported on "INTEIIIM" sheets unttl final completion. [leport official or repreaentatave tent on "FINAL" form. (1)Submit "INTEBIM" sheets when filled out but not less frequently than every 30 days, or {2)on ~ednes=s of the week in whach oil string is set. Submit weekly for vorkovera and following setting of oil string until completion. DAILY ~ELL HISTORY - INTERIH Alaska Kenai Borough District County or Parish ~State Alaska Field G-Zone: West Foreland Zone Lease or Unit TBUK-30 We 11 No.g~-£ Date & Depth at 8:00 A.M. 3-30-70 (Con 3-31-70 TD 13196 ' N-l-70 TD 13196 ' ~-2-70 TD 13196 ' ~-3-70 TD 13196 ' ~-6-70 TD 13196 ' ~-7-70 TD 13196 ' ~-8-70 TD 13196 ' Complete Record for each Day While Drilling or Workover in Progress 'd) POH. Ran WO shoe #7. 8-1/8" scallop rotated 1-1/2 hfs before mill would start cut. Milld over fish 11520-11523'. Held fire drill 11:00 NM 3-29-70. ~ MW 81#, Vis ~1, WL 8, Oil 9% -~Circ @ 11505' Milled over fish 11523-11527'. Started in hole w/mill #8. Received orders to plug fish g re-dPill~ POH. Ran 8-1/2" & 9-5/8" csg scraper to top of fish @ 11515'. ! POH - MW 80#, Vis 52, WL 8.g, Oil 6%. Circ g cond mud w/bit g scraper. POH. LD 105 its 5" DP. (Had cmt ring on inside wall.) Ran 9-5/8" Baker cast iron Model "K" cmt retainer. PU 101 its 5" DP. Set Model "K" cmt retaineP 11509'. Tstd 5" DP w/g000 psi OK. Released f~m retainem. Tstd 9-5/8" csg w/1000 psi OK. Set into' - Model "K" retainer @ 11509'. Press below retainer w/~000 psi for 10 min-0K. Released press. PU 11~79'. Cond mud, raised vis to 52 sec. Atmpt unplug #2 section mill - MW 80#, Vis 68, WL 8.0, Oil 6%. POH w/Baker setting tool. Ran 8-1/q" section mill. Cut 9-5/8" csg @ 11327-113~7' in 6-h~s. Circ for trip g-hfs to CO steel in hole. POH. Ran sharp section mill. Opnd mill. Mill plugging. POH - Revers circ OK in atmpt to unplug section mill but plugged when circ dn DP. Could not break plug loose. POH. Had plug in 60th std w/steel shavings'g cmt. Had steel shavings on top of mill. Ran mill #3. Rabbited DP. DC was plugged w/steel shavings. Broke Circ ea 20 stands. Milled 9-5/8" csg 113~7-11351 in 2-1/2 h~s. Mill cutrs cut off. Circ 2-hrs. (MW 81, Vis 57, WL 8.0, Oil 6%) WOC - MW 82#, Vis 58, WL 6.6, Oil 8%. POH w/#3 sctn mill. RIH w/#~ mill. Broke circ ea 2g stds to prevent plug. On btm 12N ~-g-70. Milled 11351-11367' @ g:30 PM q-~-70. Circ g cond mud g hole. Circ out steel cutgs. POH. LD SM. Ran 15" Grant blade-type under rm~ on 8-1/2" Pilot bit. Opnd 12-1/g" hole to 15" 11327-11339'. Broke blades. POH. Re-d~sd UR. RIH. Broke circ ea 2~-stds. OH 11339-113~'. Made connctn. Could not make UR cut. POH. 2-blades broken. Re-drsd UR. RIH. Broke circ ea 2~ stds. OH 113gq-11367'. POH. UR OK. RIH w/OE 5" DP. Washed 11367-11509'. Plugged 11509-11180+ w/5" OE DP @ 1150~' mixed w/130 sxs Class "G" cmt treated w/l% D-31 & 0.3% BJR retarder & 23 sxs (20%) 20-g0 sand. Used 85 cuft fresh wtr. Preceded cmt w/100 tuft wtr. Displaced cmt 15 cult wtr g 1100 tuft mud. CIP @ 11:10 AM ~-5-70. Pulled 10 stds. Backscuttled DP clean. POH. Stndg cmtd. Changed Sand line. Orienting - MW 76#, Vis ~5, WL 11, Oil 8%. WOC 3-hrs. Ran 8-1/2" bit. Found top of cmt @ 11155'. CO hard cmt 11155- 11327'. Cond mud. POH. Ran Dyna-dril #q. STl1327', Depth Today 11~5~' (127') - Drilling - b~ 76#, Vis q5, WL 9.6, Oil 7%. Oriented DD'g surveyed. Tripd & chngd BHA. PU HWDP. No direct on survey due to mag. interference from csg. Survey: 11~5~' 31030'. 6 PAGE N(). PIIINIEI1 IN II..%.A. The Above is Correct: / ,~./' · . · / /^ S I (;N A'I'I I Il E / · T I TI.Fi __(NIIMI',I':I', AI.I. I)AII.Y '~:1.1. III.";TI~IIY FOIIM,~ CE()NSI.:I'II'I'I¥1<I,Y A.~ 'I'II}:Y Alff: I'lff:l'Alll*l! I*{~1! }A(II ~tl.I.. ) I}ATE Ill- 4f, q. 2 12'~' INSTRUCTIONS: This form is used during drilling or workover operations. Xf teasing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work per- formed by Producing Section will be reported on "INTERIM" sheets until final completion. Beport official or representati,e test on "FINAl." form. (1) Submit "INTEI?IM" sheets when filled out but not [ess frequently than every 30 days, or (2) on Wednesday of the week in whzch oil string is set. Submit.weekly for workovers and following setting of oil string until completion. DAILY WELL HISTORY - INTERIH District Alaska . County or Parish Kenai Borough State Alaska Field G-Zone, West Foreland Zone Lease or Unit TBUK-30 Well No.q4-2! Date & Depth at 8:00 A.M. 3-23-70 TD 13196 ' 3-2~-70 TD 13196 3-25-70 TD 13196 ' 3-26-70 TD 13196 ' 3-30-70 TD 13196' Complete Record for each Day While Drilling or Workover in Progress MW 93#, Vis q8. Fishing. Cond gas cut mud to 92# rrm 70#. POH g swab cut swollen 6-1/2" $ lip cut. Ran 6" bit to ck lnr cond. Ran to baffle clr@ 1315q'. Lnr OK. Had very little gas cut mud off btm g started POH. DIL assy, 6" bit, bit sub 3 q-3/q" DC, q2 its 3-1/2" DP (1331') g 5" DP. Cond mud @ 106q2'. Ran 7" RTTS sqz tool g circ sub on 1331.8q' of 3-1/2" DP (13.3#/ft) g 106q8.8~' of 5" (19.5#/ft) DP.-Set RTTS tool @ 11985'. Circ 7" ln~ w/950 psi. Circ g cond gas cut mud for 15 min. Pmp in 50 cf w-tr. Mix 600 sx Class "G" premixd w/l%-D-31 disp cmt w/lO61 cf mud. Pmp press startd to rise when cmt startd a~ound shoe of lrnp approx 700 cf mud disp. Press increasd f~om 500 psi - 3500 psi while disp1 700- 1060 cf g went to q500 psi. Bled 20 cf. Could not rels RTTS tool. Could not rels'frm tool w/sfty sub. Startd mixg @ 12:05 PM 3-21-70 ..... Mix time 30 min. CIP @ l:q0 PM 3-21-70. BO 5" X 3-1/2". CO g circ DP clean w/approx 50 cf cmt rets. POH g recov~d 5" DP & 5" X 3-1/2" CO. Top of fish @ 106q2'. Ran 8-1/2" bit to 106q2'. Csg cln. POH. Made up Tri State outside cutr on 7-5/8" wash pipe. Ran 8-1/8" cutr on 317' of 7-5/8" WP. Over fish to 10961'. Cut 3-1/2" CP here g POH. Rec 319' of 3-1/2" DP. Top of fish @ 10961'. Re-ran cutr on 317' WP. Got over fish to 11279'. Atmptd cut but POH w/no recv~y. Ctms on tool bmoken. MW g2#, Vis q4, WL 6, Oil 9% - Fishing Redressed Tri-State outside cut~. Ran cutr on 317' 7-5/8" WP Jars ~ B-sub' to 11278'. Atmpt cut @ 11278', no cut. Shea~d dogs g cutrs. POH. Had 1/2 gal cmt pamticles on top of dogs (f~ 5" DP). Redressed Tri- State outside curt. RIH on 317' X 7-5/8" WP jams ~ B-sub to 112q8'. Cimc WP dragging GIH 11150-112~8'. Atmpt cut @ 11248'. No cut. Shear cutm $ dogs. POH. Acts as if some loose rubrs fouling cutms. MW 90#, Vis q4, WL 5.6, Oil 9% - Fishing POH w/8-1/8" Tmi-State cutr. Ran 8-1/8" Tri-State WO shoe to 10950'. Circ 1-1/2 hrs. Rotated &circ over fish @ 11283'. POH. Ran 8-1/8" T~i-State oUtside curt. Went over 10 its to 11277'. Could not cut. PU to 112q5' g made cut. POH. Top of fish @ 112q5'. MW 93#, Vis ~q - Fishing Finished POH w/8-1/8" Tri-State outside curt. Rec 9 its 3-1/2" DP. Re-man 8-1/8" cutr to 11445'. Set dn on solid material. PU to 11q36'. Atmpt cut. POH. Had DP ruhr in catcher dogs. Re-ran 8-1/8" cutr to 11~75'. Set dn on solid material. PU to 11q68'. Atmpt cut. POH. Had DP ruhr in catcher dogs. RIH w/8-1/8" WO shoe. MW 81#, Vis 40, WL 7.8, Oil 6% - Fishing 'Ran 8-1/8" Tri-State WO shoe. CO g milld to 11q92'. POH. Ran 8-1/8" Tri-State outside cutr to 11~0~'. Made cut @ llq0~'. POH w/fish. Rec 5-its (158.75') 3-1/2" DP. Ran WO shoe. WO on 10 its 7-5/8" wash pipe. Milld 11~9q-11513'. POH w/WO shoe #3. Rec 3-its 3-1/2" DP wedged in WP. Top of fish @ 11510'. Ran WO shoe #~. WO fish 11513-11520'. POH. Ran WO shoe #5. Rmd 11517-11520'. POH w/#5. Rec 5' fish. Top of fish @ 11515'. Ran 8-1/8" scallop WO shoe #6. Rmd 11517-11520'. Would not cut. Nil. The Above is Correct: April, 1, 1970 S ! (;NA'I'IIIII.: / /' l)i:~tri¢;t~ lh'J ]_ l.i I~,, ',h~l~-:r'v i :;or' 1'1 TI.I.: I)AI'E (NIIMIII':II Al.I. DAII.Y Wl.:l.I. IIl.%l'OlIY I-'l~lIM:~ I:iiN.~:i:II'I'IVI.'I.Y A5 'I'III';Y Alii.: I'lll<l'Al~llI tl~ll I'A{'II Wtl.I., ) .IN~TIUICTION~: This form ia used during drilling or workover operations, If testing, coring, or perforating, show formstnon name in describing work performed, Number all drill stem testa sequentially, Attach description of all cores, Work per- [ormed by Producing ~ect~on will be reported on "INTERIM" sheets until final completion. Report official or representative tent on "FINAL" form, (l)Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2)on Wednes~as Of the week in which oil string ia set, Submit weekly for ~orkovera and (o~lowing setting of oil string until completion. DALLY WELL HISTORY = INTERIM District Alas~ka County or Parish Kenai Borough State Alaska Field C--Zone, West. Fore!~-d Zon~ Lease or Unit We 11 No4"-,=- Date & Depth at 8:00 A.M. 3-10-70 1260~ ' 3-11-70 12750 ' 3-12-70 12883 ' 3-13-70 12992 ' 3-16-70 TD 13196~ 3-17-70 TD 13196 ' 3-18-70 13196 ' TD 3-19-70 13196 ' 3-20-70 TD 13196 ' Complete Record for each Day While Drilling or Workover in Progress (150') MW 78#, Vis 51, WL 4.8- Drlg Drld 12455-12605'. Survey: 12549' 33°15' 10093.48 S18E S5738.12 E4053.61 (145') MW 78#, Vis 50, WL 5 - Drlg Drld 12605-12750' · (128') MW 78#-, Vis 55, WL 5, Oil 5%- Drlg Drld 12750-12883' · Survey: 12828' 29°15' 10336,91 S13E S5870.95 E4084.28 (109') MW 78#, Vis 54, WL 5, Oil 4% - Drlg Drld 8-1/2" hole 12883-12992'. Survey: 12987' 29o30' 10475.30 S10E S5948.66 E4097.87 (204') MW 95#, Vis 62, WL 4.4, Oil 8%- POH Drld 12992-13039'. Had gas cut mud rets. Had 1800 units on mud logger readgs. Increasd mud wt 79#-81#. Had gas cut mud 42#. Increasd mud to 84#, gas cut ret 42#-43#. Increasd wt to 85#. Circ 3-hrs w/rets of 47-1/2#. Increasd wt to 88# w/rets of 42-47#. Increasd wt to 90# w/47 rets. Increasd wt to 94# w/rets of 72#. Circ w/95# mud. No increas in pit volumes. Used 1500 sxs Bariod. Circ mud ~ 13049'. 95# GI, circ mud levld out ~ 92# in & out. No gas. Made l0 stand wiper run. Circ btms up w/2200 units gas & 42# gas cut mud 25-min. Raised mud to 95# while drlg ahead. No further gas cut mud. Drld 13049-13196TD. Ran Schl'DIL frm 13173'. Ran FDC G/R 13173-12905'. Sonde stuck. Wkd free in 15-min. Survey: 13196' 30°45' 10643.34 S9E S6047.11 E4103.28 MW 95#, Vis 58, WL 4.4, Oil 8% - Logging Re-ran FDC-GR. Ran BHC, SNP, HDT. Re-ran SNP (caliper on 1st run did not work) fr 13176-12036'. (FDC-GR 13176-11786' ) MW 93#, Vis 52, WL 5.0, Oil 8%- Pulling DP. Ran 8-1/2" bit to 13!96'. Cond hole Made 10 std wiper run. Circ btms up w/min of gas cut mud. Ran 31-Jts (1264') 7" 26# P-110 8-rd cig w/ turned couplgs as lnr w/Brown float shoe & stop clr w/30 centrlzrs. Ran 4-stds DP. Un-"J'd" from runng tools & drop to btm. POH. LD swab cups. RIH w/Brown runng tool, top @ 11943'. Could not "J"into lnr. Cond gas- cut mud. P0H - Ran Bowen 7" csg spear to top of lnr. Could not latch into top 4" of lnr. Circ & cond mud. POH. Re-ran 7" csg spear on 30' X 4-3/4" DC. RI to top of lnr. Circ gas & oil cut mud. RI lnr. Took hold of lnr. Jarrd on lnr 6-hrs w/max 450#. Could not Jar lnr free. Cond mud - Ran 7" Guiberson down cup packoff tool. Could not work inside lnr. Reversd circd trying to collapse pkr cups. Would not go in lnr. Circd gas cut mud. Had rets of 70#. Cond to 95#. (holding 100 psi on annulus while circ up light mud. ) ]'he Above is Correct: PAGE NO. )l PIIIN1EI} IN II.,~.A. IN~TBU£TIONS: This form is used during drilling or .orkover operations. If testing, coring, or perforating, show formation name an describing -ork performed, Number mil drill stem teats sequentially. Attach descrlptnon of all cures. Work per- formed by Producing Section ~lll be reported on "INTERIM" sheets until final completion, il. port official or representative test on "FINAL" form. (1) Submit "INTEi{IM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesd.v of the -eek in ,hich oil string is set. Submit weekly for ~orkovers and following setting of oil string until completion. DAILY WELL HISTORY - INTERIM District ^~,.~ County or Parish Kenai Borough State Field. G-Zone West Foreland Z~n~ Lease or Unit TBUK-3Q Well No.hL.-2l Date & Depth at 8:00 A.M. 2-24-70 2-25-70 11585 ' 2-26-70 11658' 2-27-70 11722 ' 3-2-70 11967' 3-3-7O 11995 ' 3-4-7o 12020 ' 3-5-70 12150 ' 3-6-7O 12150 ' 3-9-70 12150 ' Complete Record for each Day While Drilling or Workover in Progress (435') MW 76#, Vis 65, WL 5.2, Oil 4%- Drlg Dir drld 12-1/4" hole 11070-11505'. Survey: 11494' 35°15' TVD9191.4~ S19E S5224.63 E3866.43. (80') MW 76#, Vis 52, WL 4.8, Oi~ 4%-Orlg Dir drld 12-1/4" hole 11505-11585'. (73') MW 76#,.Vis 42, WL 5.2, Oil 4%- Drlg Tstd BOPE w/5000 psi & Hydril w/3000 psi. Dir drld 12-1/4" hole 11585-11658'. ~' (64') MW 76#, Vis 46, WL 5.4· - Trpg for new bit. POH Looking for washout Hit tite spots ~ 10500' 7531' 6144' 5782' · · , , ~ · (235') MW 75#, Vis 50, WL 5.2, O~l 5% - Drlg .Dir drld 12-1/~" hole 11722-11967'. (28') MW 75#, Vis 50, WL 5.2, Oil 5%- Logging Drld 12-1/4" hole 11967-11995'. Circ & cond mud. Ran Schl DIL 11995-2187'. Now pulling density log. (25') MW 75, Vis 54, WL 5·0, Oil 5%- Drlg 1/2-hr rea~ed 11960-11995'. 17-hrs logging w/Schl. Ran sonic log & SNP log 11995-9000'. Ran SWS log 11335-9275'. (1BO') MW 76#, Vis 57, WL 4.8, Oil 4.5% - Circ mud. Drld 12020-12150'. (0') Rng 9-5/8" csg. Circ & cond mud. Pulld tite 12020-11930'. Max pull 400000#. Wkd tite spot free. LD DA. Pulld wear bushing. Cut DL. Chngd to 9-5/8" pipe r_am.~. (0') MW 77#, Vis 52, WL 5.4, Oil ~% 9-5/8" cs5 cmtd ~ 12076'. Ran 305 jts 9-5/8" csg as follows: 48 jts 9-5/8" (1981.30') 47# P-111 & 257 jts 9-5/8" (10055.83') 47# N-80 Buttress csg landed ~ 12076.23'. Used Baker diff float shoe (12076') & diff FC (11989'). Used 26 B & W Turbolater centrizr on btm. 26 jts & 16 centrlzrs ~ 200' intervals, cmt w/lO00 sxs Class "G" cmt treated w/l% D-31. Preceded .cmt w/100 cuft wtr, displcd cmt w/50 cuft wtr & 5029 cu ft mud w/rig pmp ~ 70 cu ft/min. Bmpd plug w/2000 psi. CIP ~ 3:15 PM 3-6-70. Installd 9-5/8" pack-off· Chngd to 5" pipe rams Made up 8-1/2" bit, 8-1/w" 6 pt Rmr, 8-1/2" stab, 6" x 25' Monel DC. 8-1/2" stab, 6" x 18' Monel, 8-1/2" stab, 6-1/h" x 61' DC, 8-1/2" stab, S-O, B-S, 40 jts HWDP. RIH rubbering 2nd singles of DP. 3-8-70- 12280' (130') -MW 77#, Vis 50, WL 5.2, Oil 4% Found top of cmt ~ 11933'. Tstd csg w/1500 psi from 11933'. DO FC & shoe ~ 12076'. Tstd csg shoe w/1000 psi ~ ~2129'. }{eld 0K. Drld 8-1/2" hole 12150-12280'. 3-9-70- 12255' (175') - MW 78#, Vis 52, WL 5.2, Oil 3.5%. Drld 12280-12255'. Survey: 12336' 31o30' 9915.35 S19E S5627.04 E4017.53. The Above is Correct: __' ~ : . _/ ' S 1 (;N ATIIIIE / / / ---JJi~k~:i~: [~Drilling ..i]upervizor. T I TI.t: (NI~MII}:I{ AI.I. I)AII.Y WEI.I. II!,~'1'()11¥ F'()IIMN (:()Nhl.(Jl'l'lVl].Y A.'/ 'I'III.iY Alit: I'III:I'AIII. I) F()II I':A(ll ~1'1,1.. ) M:treh ]-7, 1070 IIATI': PRINTED IN II..'i.A. ~' .111-459.2 12/,,7 INSTRUCTIONS: This form ia used during drilling or workover operations. If test ag. coring, or perforating, show formation ~ame in describing work performed. Number &Il drill stem tests sequentially. At nth description of all cores. Work per- forned by Producing Section will be reported on "INTEBIM" sheets until final completion. Beport official or representative teat on "FINAL" form. (1) Submit "INTEI{IM" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesda- of the ,eek in ,hich oil string is set. Submit weekly for workovera and following setting of oil string until completion. \ DALLY WELL HISTORY - INTERIM · District Al~-~k~ County or Parish _ Field G-Zone~ West Foreland Zone Lea s e or Un i t TBUK- 20 State We 11 NJ4~-~- Date & Depth at 8:00 A.M. 2-5-70 7005 ' 2-6-7o 7~15' 2-9-70 8220 ' 2-10-70 8575 ' 2-11-70 8905' 2-12-7o 9205 ' 2-13-70 2-16-7o 10328' 2-17-70 10476 ' 2-18-70 10679 ' 2-19-70 10 890 ' 2-20-70 11070 ' Complete Record for each Day While Drilling or Workover in Progress (595') MW 72#, Vis 46, WL 8.6. Drlg Dir drld 12-1/4" hole 6410-7005'. Survey: 6964' 37o45' VD5621.52 S30E S2723.00 E2641.09. (410') MW 73#, Vis 53, WL 8. Drlg Dir drld 12-1/4" hole 7005-7415'. Survey: 7393' 37° VD5962'88 S28E S2953.51 E2765.31. (805') MW 73#, Vis 54, WL 9, Oil 3% Drlg Dir drld 12-1/4" hole 7415-8220'. Survey: 8110' 36° VD6537.36 S29E S3332.21 E2966.13. (355') MW 73#, Vis 47, WL 8, Oil 4% D~lg Dir drld 12-1/4" hole 8220-8575'. Tstd CSO & pipe rams w/5000 psi, Hydril w/3000 psi-OK. Survey: 8297' 37°30' VD6685.72 S31E S3429.79 E3024.76. (330') POH MW 73#, Vis 49, WL 8.2 Oil 3% Dir drld 12-1/4" hole 8575-8905' Survey: 8672' 39°15' VD6976.12 ~28E S5639.27 E3136.15. (30o') MW 72,#, Vis 50, WL 7.6, Oil 4% Drlg Dir drld 12-1/4" hole 8905-9205' SurveY: 9197' 37°15' VD7391.33 ~28E S3920.25 E3292.26. (315') MW 75#, Vis 49, WL 7, Oil 4% Drlg Dir drld 12-1/4" hole 9205-9520'~. (808') POH MW 75#, Vis 50, WL 7.6, Oil 3% Dir drld 12-1/4" hole 9520-10328' Survey: 10135' 37°45' VD8125.49 ~24E S4449.94 E3538.10. (148') GIH MW 74#, Vis 51, WL 4.8 Oil 4% Dir drld 12-1/4" hole 10328-10476'. Tstd Hydril w/3000 psi. Tstd CSO w/4500 psi & pipe rams w/3500 psi. Tst plug rubbers failed. Survey: 10476' 39045' VD8390.31 S23E S4647.64 E3622.01. (203') POH MW 74#, Vis 49, WL 5, Oil 3% Dir drld 12-1/4" hole 10476-10679'. Survey: 10679' ~0°15' VD8545.2~ S24E S4767.47 E3675.36. (211') MW 74#', Vis 50, WL 5.5, 0il 3% Drlg Dir drld 12-1/4" hole 10679-10890'. (180') MW 74#, Vis 53, WL 5.2, Oil 4% Drlg Dir drld 12-1/4" hole 10890-11070'. Made 15 stand wiper run-OK. Survey: 10913' 39045' TVD8725.10 S25E S4903.06 E3738.59. The Above is Correct: INST~UCTIONS: Prepare and submit the INITIAl. IU:POltT on the first Wednesday after a -ell ia spudded or ,orkover operations ,re started. Daily -ork prior to spudding should be summarized on the Jorm giving inclusive dates only. DAILY WELL HISTORY-INITIAL REPORT District Alaska County or Parish Kenai Borough State Lease or Unit TBUK-30 Title Drill TBUK-30 (#hh-21) Field G-Zone, .We.~t ~r~.~,'l~n_a Zone Auth. or W.O. No._ 19-7230 Alaska Well No.hh-2: Operator' Spudded or W.O. Begu, Atlantic Richfield Company Spudded Date 1-23-70 .TARCO'S W.I Prior. Status Hour 3:30 PMi£ a W. O. -0- Date & Depth as of 8:00 A.M. 1-26-70 1-27-70 2250 ' 1-28-70 2250 ' 1-29-70 2250 ' 1-30-70 2492' \ 2-2-70 5290' 2-3-70 5930' 2-4-70 6410' 1-26-70 2250 ' Complete Record for each Day Reported (Bottom of page) FIRST REPORT (0') MW 74#, Vis 44, W1 12.5 Prepg to run 13-3/8" csg Spudded ~ 3:30 PM 1-23-70 Opened 12-1/4" hole to 18" hole 521-2225'. (0') WOC 13-3/8" cs~ ~ 2187'. Ran 53 its (2041.84') 61#, K55, Buttress csg w/il B&W Centralizers ~ 200' intervals w/Baker guide shoe & diff clr (shoe ~ 2187', clr ~ 2108.92') w/Oct unihead ~ 36.40. Lnded csg ~ 2187.28'. Baker loc btm 6 jts. Circ while repairing cmtg unit 11-1/2 hrs. PI 100 cuft wtr, mixed 1090 sx Class "G" cmt mixed w/lO% Gel & 400 sx Class "G" Neat cmt, displaced w/50 cuft wtr & mud w/rig DmDs. Bmpd plug w/1500 psi. CIP ~ 7:30 AM 1-28-70. ~ood cmt retUrns. Standing cmtd. (0') GIH to DO cmt Instld BOPE, changed Hydril bag. Tstd rams to 3000 psi, Hydril to 1500 psi (to retst to 5000 & 3000). GIH w/12-1/~" bit to DO cmt & tst cmt job. . ~(242') MW 72#, Vis 46, WL 14 Making up Junk bskt DO cmt 2106-2188'. CO to 2250'. Drld 2250-2492'. POH. Left 3 cones in hole. Survey: 2357' 40°~5' 2130.81 S46E S422.14 E658.31 Survey: 2492' ~0°45' 2233.08 S45E S484.46 E720.63. (2798') Drlg Ran Sperry Sun Gyro multi-shot survey. Ran globe ink bskt. Drld 11-3/4" hole 2492-2495-1/2'. Recov 2 cones & 3 spindles & 7" unidentified object. Reran junk bskt. Drld 2495-1/2-2499', no recov. Dir drld 2499- 5290' Survey: 5206' 40030' 4283.53 S43E S1804.26 E1965.69. (640') MW 73#, Vis 52, WL 9.5 Drlg Dir drld 12-1/4" hole 5290-5930'. Survey: 5831' 41°45' ~757.83 S37E S2114.h3 E2228.28. (h80') MW 72#, Vis 47, WL 10 Drlg Drld 12-1/4" hole 5930-6410'. Held safety meeting & fire drill. Survey: 6417' 42o15' VD5189.67 S36E S2432.2~ E2h65.13. (2250') Drlg MW 71#, Vis 50, WL 12. First Drld 18" hole 355-450'. Directionally drid i2--±/q-' hole 450-2250'. OH to 18" 450-522' . c ! o Survey: 22~0 40 2049 S52E N373.62 E608.07. ~ tribut ion: )rig.: Drilling Section- I)all:,s cc:- I)istrict Ot'fice l'h, gineeri,g l)ivisio,, - (720) Co-Owner(s) - As Al~l,rOpr~at.e Ilegion. l Offico, W,.II Ih.c~,,'d File 1'he Above is Correct.: ~ i llb' A'I'IIIII': 1'i 11.1:: (' / . .- .(.l,~-' ,, DATE ,- · ( "'D.I g_t.r.i ?..t_,_. l~r_i 1-1 ing ..:)tU.,,?~:¥1:; ur .... ~'; NI")......,..~(NIiMItF'II Al.I. I)AII.Y ~1':1,1, IIl.",,'l'(~llY F(,li.M.', (:()N.'.,I.:('UI'IVH,'i' AS 'IIII(Y ALU.: I'IIII'AI(II) t()ll I'A(:II ~FI.I,. ) INSTRUCTION~: Thio form is used during drilling or workover operations. If testing, coring., or perforating, show formation name in describing work performed. Number all drill stem testa sequentially. Attach description of all cores. Work per- formed by Producing Section .ill be reported on "INTERIM" sheets until final completion. Beport official or representative test on "FINAL.' form. (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. .Submit weekly for workovers and following setting of oil string until completion. District Field DALLY WELL HISTORY - INTERIM South Alaska County or Parish Cook~ Inlet ~State Lease or Unit TBUK-30 #44-21 Alaska Well No. Date & Depth at 8:00 A.M. 4-28-70 4-29-70 5-1-70 3-10~71 3-16-71 Complete Record for each Day While Drilling..or Workover in Progress PRODUCTION Testing - Clnd up "G" Zone. Tstd 723 BO, 127 BW, 15% BS&W in (24 hr rate) API Gray 33.5, Tbg press 140, Csg press 0. West Fore~ands Zone SI until "G" Zone clns up g is tstd. PRODUCTION Testing. Well still cleaning up "G" Zone 14-1/2 hrs. 1040 BF, 983 BO, 57 BW. 24-hr rates: 1720 BF 1630 BO 90 BW.. West Foreland Zone 7 hrs. 318 BF, 305 BO, 13 BW. 24-hr. rates: 1090 BF, 1045 BO, 45 BW. PRODUCTION . 4-29 - ProduCing. "G" Zone 24 hfs flowing 2068 BF, 2041 BO, 27 BW, 1.3% BS&W, GOR 362, API Gr. 33.3. West Foreland Zone 18 hfs flowng 1242 BF, 1217 BO, 25 BW, 2.0% BS&W, GOR 180, API Gr 81.5. FINAL REPORT PRODUCTION . (Short String) - RU North Star. Ran 24-hr BHP tst. Well SI @ 9:00 PM 3-9-71. PRODUCTION Short String,- SI 3-9-71. POH w/BHP Survey @ 9:00 PM 3-10-71. RD. Mvd over K-30L. Long String - 3-11-71 - RU North Star. Ran 24 hr BHP build-up survey. Made flowing gradient stops GIH & static gradient stops POH. RD North Star 3-12-71. 3-12-71 - RU Otis. POHw/BV. Ran new style BV. Could not opn BV. Pulled same. Reran BV - could not opn. Pulled same. Ran new style BV. Set in 3-1/2" Otis BV nipple @ 438'. Tstd. Held press. RD Otis. 3-15-71 - RU Otis. POH w/BV. Ran rebuilt new style 3-1/2"'BV. Set in BV nipple @ 438'. Tstd 3 times OK. RD Otis. The Above is Correct: S I GNATIIllE DATE PAGE__ TANGENT[AL METHED ATLANTI£ RICHFIELD CO K-30 44-2! WELL CONPLETION PREPARED BY SCS 3-16-70 MEASUREC D DEPTH ANG E V_I A T I 0 LE DIRECTION N TOTAL COORDINATES C L 0 S U R E S _SUB SEA LATITUDE DEPARTURE DISTANCE ANGLE TVD DOG LEG SECTIOI SEYERZTY D[STANCI ORIGIN LOCATED 11~ 0 15 139 0 15' 164 0 15' ~g O ?]4 0 _ 264 0 10~ 289 0 15 31~ 0 15' ~ 339 0 15~ 364 0 15' 400 ~ 45' 500 I 45 600 4 700 8 15' 8~0 _900 15 0 !000 !t 45' !!00 18 45' !~00 20 45~ !300 22 15~ !4~0 ~4 0 1~00 1600 ?8 30' 1700 30 30s 1800 B2 45 !900 35 2000 37 45 0.007 39.00 113.99 138.99 163.99 188.99 21~.99 263.99 288.99 313.99 338.99 263.99 ~99.99 499.94 _T¥D = -60.qq 13.99 38.99 6'3.99 88.99 113.99 163.99 0.007 LATITUDE = 71.27, DEPARTURE = 46.93 71.27N 46.93E 85.33 N' 33.36E . 0-000 71.16N 46'61F 85.07 N 33.22E 0.333 71.14N 46,51E 84,99 N 33.17E 0.087 71-03N 46.50E 84,90 N 33.20E 1,161 7t.14N 46.47E 84.97 N 33.15E 1.975 71.12N 46.51E 84'98 N 33.18E 1.237 71.12N 4~.54~ 85.00 N 33.20E 0.t83 71.15N 46;61E . 85-06 N 33.22E 0,364 -32,61 -32.6~ -32.71 -32,6, -32.7. -32,7 -32.6 -32,6 188,99 213.99 238.99 263.99 281.99 ._ 299'99 399.94 71,05N 46:.65E 85.00 N 33.28E 71.14N__ 46.71E_ 85,11N 33.29E 71.24N 46.76E 85.22 N 33.28E 71.35N 46'77E 85.31N:33.24E 71.58N 46.73E 85.~'9 N 33.14E 71.74N _ 46.56E 85.53 N 32'98E ~9.47N ~8,6IE 84.:79 N:34-97E 63.55N 53'-7~E 83.24 N 40,22E 1.211 -32.5 1,757 -32,6 0.174 -32,6 0.295 -32,7 2.877 -32'9 2.575 ~ 2.498 -~0.1 2,7~0 .-22.3 698'60 598,60 796,23 696.23 892.82 792.82 1083.27 983.27 !176,79 !076.7~ 126q.34 1!69.34 1360.6g 1~60-69 1450.3R 1538.26 1624.43 1524.43 1708.53 1608.53 1790.45 1690.45 1869.51 1769.51 1945.R4 1845'86 . 52,89N 63'36E 82,53 N..50:.t4E 36.07N _ 76'9~E 85'~1N 64~89E 1'7.45N . 94-96E 96,55 N 79.58E 3.27S 114'98E I15-02 S 88-36E 25,605 138.i0E 140,45' $ '79,~9E 51.095 162.TIE 170.54 ~S, 72'56E 78.32S 189,01E __ 204'~0 S 1~7.58S 217.27E 242.44 5 63':65E 1'38'86S 248-:~4~ 284.70 S 172,605 282.28E 330'87 S,58-55E 208.48S 318.17E 380,3~ S 56:.76E 2~6.7~S 356.42E 433.49 S.55.30E 287,2~S 396'98E 490.03 S 54.IOE 332~38.73E _.550.2~ S.52'8~ 379.32S 482.80E 613.99 S 51'84E 3o751 -8,1 4.282 13.3 2,765 38.9 1.750 67'2 2,090 98.7 2'110 133.6 1-500 170'~ 1.750 211.~ 2.289 2.250 2-000 351-~ 2.250 2.250 460.~ ___2.994 _ :521.1 2-499 585..~ lO 9 6 {' ' ~ T R E £ T T ~ N A L S U R V E Y PAGE 2 ~ TANRFNTIAL NFTHOD ATLANTI£ RICHFIFLD CO K-30 44-21 NELL CONPLETION PREPARED BY SCS 3-16-70 NEASURED C F DEPTH ANGLE I A T I D N DIRECTION TCTAL COORDINATES C L 0 S U R E TVD SUB SEA LATITUDE DEPARTURE DISTANCE ANGLE O~G LEG' SECTIOI SEVERITY DISTANC! ( ( ( ( ( (( ( 2170 4] 2?50 40 ~357 40 45* 2492 40 45* ~670 41 15~ ?885 42 !5' 31q5 4~ 3865 41 30* 4085 40 4~75 40 4478 4~ 4~70 40~0~ 4725 40 ~014 ~0 30' ~20~ 40 30 5423 ~0 O' ~&12 40 O' 5831 41 ~083 43 30' ~237 42 30 6417 42 15~ aaR4 3q O' 6964 37 4~, 7~03 37 7~9~ 3'7 769M 37 45* S 44E S 46E S 45E S 47E R 47F S &TF S47E S 48F S 47E S 47E S 47E S 47F S 45E S 4SE S 43E S43E S S 37E S 37E S 37F S S ~OE S 30E S 29E S 28E S 26E 1998.67 1898.67 2059-95 195q-q5 2141.01 2041.01 2243.28 2143.2'8 2377.11 2277.11 2536.26 2436.26 2760.19 2660.19 2924.80 2824.80 3092.09 299'2.09 3255.36 3~55.36 3422.65 3322:.65 3491.09 3391.09 3600.23 3500.23 3722-~ ~622'35 3792.30 3692.30 3910.1'7 3810.17 4129.92 4029.92 4275.92' 4175.92 4442'15 4342.15 458~.94 4486.94 4750.32 4650-32 4933.12 4833-12 5046'66 4946;.66 5!79.~0 5079.90 53:87.40 5287.40 5506.79 5406.79 5608.79 ~'798.40 ~698.40 5950.14' ' 58~0.14 6188.93 6088.93 412.36S 514.70E 448.08S 551.69E 496.60S 601.93E 558.91S 664.25E 638.95S 750-08E 737.54S 855.80E 883.74S 1012.58E 98q.35S 1125.83E 1092.98S 1236.97E 118,9.645. 1344.32E I287.085 1448.81E 1326.95S 1491.56E t389.965 1559.13E 1460.465 1634'74E 1502.715 1676'995 1573.89S 1748-17E ~&48.46S 1817.7'I~ :1710,135 1877.26E 1801'33S 1962.30E 1903.345 2057.43:E 1995.035 2137.13E 2111'49S 2224'89E 2250-03S 2329.2'9E 2333:.125 2391.90E 2431,035 2463,04E 2573.53S 2552.0:8E 2653.58S 2598'30E 2721.98S 2637'79E 2849.23S 2708.33E 2950.19S 2762-01E 3116'37S 284:3-06E 659.51S 51.29E 710.73 S 50-91E . 780,34 S 50.47E 868.11S 4~'9:2E 985-33 S 49.57E 1129.77 S 49.24E 1344-00 S 48.88E 1498.77 S 48~69E 1650.67 S 48.53E 1795.11S 48.49E 1937.95 S 48.38E 1996.38 S 48.34E 2088.75~ S 48.28E 2192-11 S'48-22E 225I'76 S 48.~3E 2352'28 S 48-00E 2453-88 S 47-79E 2539.42 S 47'66E 2663.72' S 47.44E 2802,81S 47'22E 2923'61 S:46'96E 3067 '34 S 46o~9E 3238'55 S. 45.99E 33:41:.35 S 45-7!E 3460.70 S 45-37E ~ 3624.3'8 S 44'!76E 37~3-85'S 44,!39E 3790'40 S 44'ZOE 393'1.05 S~:43'54E 404t'33 S, 43.1~E 4218,38 S 42.37E 1.418 630.21 2.048 680.6: 0.700 748.9' 0-483 835-5: 0.:788 949,9~ 0.465 1090.'9; 0-483 1299.9' 0.22I 1450.9! 0.442 1599.0' 0e460 1739.3~ 0.543 1878.6' 0.000 t935,6i 0.174 2025o7! 0.000 2126'5~ 1.'434:. 2185.2, 0-000 22:84.1; 0.8;27 23:84-8' 0:,492 : 2469.3, 0.338 2592.5i 0.230 2730.3" ,0*680 21851.0; 1'437 2996,6' 0.694! 3169.9: :0-649 3273.8' 0-399 339~'81 1.559 3562.71 1'166 ~0-000 3733.61 :0-276 3878.5; 0.413 3992'2~ 0.472 4175-:~ 8 ,,,.% 6 5 ~ D ! R E C T T_ ~ N A I S U R V E Y PAGE TANGFNTIAL METHCD ATLANTIC RICHFIELD C0 K-30 44-21 WELL"COMPLETION PREPARED. BY.SCS 3-16-70 MEASURED D E V I A T I ~ DEPTH ANGLE DIRECTION TCTAL COORDINA'TES C L O S U R E S DOG LEG TVD SUB SEA LATITUDE DEPARTURE DISTANCE ANGLE SEVERITY D SECTIOi ISTANCJ 7760 7862 a i o 8297 8672 890'S q~iRq 9811 10135 10328 10679 {hq13 ~2~62 12987 !~!0~ 35 30' S 30E 6241.85 ]5 95' S 3GE 6324.63 36 15' S 29E 6524.63 37 30m S 31E 6672.98 39 15m S 28E 6963.38 38 15m S 30E 7146.36 32 15' S 28E 7378.79 ~q Om S 25E 768~.43 38 30' S 26E 7857.17 37 45~ S 24F 8113.35 38 30~ S 23E 8264.40 39 45' S 23~ 8378.19 40 15' S 24E 8533.12 39 4~t R 25F 871~.03 37 45t $ 23E 8g09.12 36 30e S 23E 9017.64 35 !5' S !qE q!79-34 30 30' S 2I[ 9754.01 31 30, S lgE g903.27 33.1~ S 1SE 10081.40 29 1.5' S 13F !0324-22 29 30~ S 10E 10463'21 30 4~' S 7E !056&.~4 ' ~0 45* S 9E 10642.82 6141.85 314g.065 2861.93E 4255.26 S 42.26E -5o044 6224.63 3200.67S 2891.73E 4313.51S 42.09E 0.245 6424.63 3328.93S' 2962'82E 4456.4? S 41'66E 0.311 6572.98 3426.51S 302.1.45E 4568.38 $ 41,40E 0,926 6863.38 3636.00S 3132.84E 479g.50 S 40.74E 0.881 7046.36 3760.92S 3204.gTE 4941'.29 S 40o43E 0.687 7278.79 3916.98S 3287.94E 5114.03 S 40.01E 0.54I 7583.4~ 4140.56S 3392.20E 5352.69 S 3g.3~E 0.649 775'7.17 4264.77S 3452.78E .5487.26 $ 38.99E 0'360 8013.35 4445.98S ~3533.46E 5679-09 S 38,47E 0,445 8164.40 4556.57S 3580.41E 5794.97.S 38.~5E 0-503 8278.]9 4643'69S. 3617'-38E 5886.37 S~37.91E 0'844 8433.12 4763.51S 3670.73E 6013.76' S 37.6IE 0.4101 8&13.03 4899-12R 3733.97E 615'g'87YS;BT-31E 0-348 880g.12 5038'88S 1.3793.29E'' 6307'09~ S 36'97E 0.951 8917.64 5112~80S 3824,67E 0.925 9654.91 5532-36S 3~83.~7E 682'1.27 S:35,72E 0.72~ 9803.27 .,5623.33S ~012'97E 6~8'38 S:35-51E 0'825 ' 9981.40 .5734,.40S 4049-06E 0.859 !0224-82 5867.23S 4079'.73E7146.2~ S34'81E 1.707 10363.2I 5944.33S 4093.32E 7217'37 S 34'55E :0'938 10666,~ 6005-2~S 41'00,80E 7271.821S 34-32E 1,1630 10542'82 6050,18S 4107-92E : 7312'9:8 S 34'17E 1.148 4212,9i 4272.3~ 4418,4~ 4532.0~ 47'67,9! 4g11.8; 5087.5, 5331.0 54:67o8~ .5663.1i 5780.91 5873°8 6002'9 6150.6' 6299.5 6378.3 6488~6 68:18-7 6g06'5 '7018-6 7145.7 7217.2 ~'72.71.8 ~7312..9 CLOSURE 7312'98 S 34-II' E 12 10 3 . D I R E C T :[ fl N A L !NTERP~LATF{'3 vALUES FOR' EVEN 100 S U R .V E Y' PAGE FEET DF SUB SEA DEPTH ATLANTIC RICHFIELD CC K-30 44-2[ WELL COMPLETION PREPARED. BY SCS 3-16-70 TANGENTIAL METHOD MFASURED DEPTH TOTAL CODRDINATES ND-TVD VERTICAL TVD SUB SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION ¢ ¢ ¢ 400 701 907 1012 !444 15~6 !677 ?040 2177 -~30~ 24~5 2701 ~836 2g73 31~2 ~87 200.00 100.00 300.00 200.00 400.00 300.00 500.00 400.00 60C.G0 500-00 700.00 600.00 ~00.00 7flO.O0 900.00 ' 800.00 1CO0.O0 900.00 llO0.OO 1000-00 1~00.00 1100.00 1700.00 1200-00 1400-00 1~00.00 1500.00 1400.00 1600.00 1500.00 !700-0o !600-00 1800.00 1700.00 lqO0.O0 1~00.00 2'000'00 1900.00 7!00.00 ~000-00 2200.00 2100.00 2~OO.OO 2200-00 24.00-08 2300-00 2500.00 2400.00 2~00.00 2500-00 2700.00 2600.00 2800-0'0 2700-00 2900.00 2800-00 300O.OO 2900.00 3100.00 3000.00 71.1~N 7!.09N 71.74N 69.47N 63.51N -57. -88. -1~I- -157 -198 -292 -350 -41~ ~6.49E 46.~8E a6.56E 48.61E ~3.79E ~aN 77.6RF 90N 96.46E 96S 117.76E 16S 142.50E 925 169.30F 14S 198.49E 2g~ 230.gTE .90S 267.59E .BlS 307.99E '70S 402.02E .lBS ~515.50E -532..'54S 637-87E -592 R3S ' 700-62E -653.{3S' -715.08S -779.1&S :-844'44S -909'~8S -1035'93S -109~'66S 765.28F 900.43E :970-44E 1039.97E l108.'?7E 1175.79E 1242'16E 0 0 0 0 0 0 0 0 0 1 4 3 '2' 3 12 5 18 6 25 7 34 44 56 72 90 112 140 172 203 267 301 336 412 450 : 487 523 558 lO 12 16 18 ~2 28 32 31 32 32 3.4 37 37 36 35 4 T ! 13 N A ! ~ U R V E Y PAGE 2 FOR EVEN 1_00 FEET OF ~UB SEA DEPTH ATLANTIC RICHFIELD CO K-30 44-2! NELL COMPLETION PREPARED BY SCS 3-16-70 TANGENTIAL ME'THOD MEASURED DEPTH TOTAL COORDINATES MD-TVD VERTICAL TVD SUB SEA LATITUDE DEPARTURE DI'FFERENCE CORRECTION 12 11 ~7ql 3924 6055 41R7 4318 ~44~ 47~2 4843 497~ 54gg 576~ 5899 6037 a30q 6443 6700 682~ T079 7~05 7~?0 ..... 7456 7587 3200.00 3100.00 -1156.86S 1307.91E 591 33 3300.00 3200.00 -1215.645 1372.19E 624 3400.00 3300.00 -1273.895 1434.'66E 655 31 3500.00 3400.00 -!3~2.09S 14g?.O7E 687 32 3600.00 3500.00 -138q.82~ 1558-99E 718 31 270~,00 3600,00 -!.447.565 1620.g0E 749 31 3800.00 3700-00 -1507,~6g 1681.6~E 7AO ~go0.O0 3800.00 -1567.755 1742.03E 812 52 4000.00 3900.00 -1630.005 1800.49E 843 31 4100-00 4000.00 -1691'745 1859.50E 875 32 4200.00 4100.00 -175~.905 1918.07F 906 '~1 4300.00 4200-00 -181&.10S 1976'08E 93? 31 44~a.00: 430~.~0 -1~??.479' ~33.3~E 968 31 4500.00 4400.00 -1939-97S 2089.27E 999 31 4~00.00 4500.00 -2004-~4S 2144'14E 1030. 4.7n0,00 4&~O,O0 -2075 625 2!'97,8:&E !064 34 4800.00 4700-00 -2149.14S 2253o26E 1099 4900 O0 4800.00 -2~.24'92S 2310-37E __ 1137 38 MO00.O0 4900.~0 -2298-q7S 236&.ITE 1174 37 5~00.60 5000+00 -~7~.~1~ 2420.~8E '1209 5200.00 5100.00 -2444-83~ 2471.66F 12'43 5~0e.00 5200+~0 -75!~.~05 ~q14-~7E 1272 29 5.400.00 5300.00 -2.5~!,975 2556'96,:~ 1300 28 5500.0:0 5400.00 -2649..035 2595'67E 1~26 26 5600.00 5500.00 -271~-08S 2&'34-3SE 1:3::~3 27 5700.00 5600.00 -2783.19S 267[.72E 1379! 26 5800.00 5700.00 -2850.29S 2708-89E 1405 26 5900.00 5800.00 -291&.83S 27,44'27E 1430 25 6000.00 5900.00 -2984-89S 2778-93E 1456 26 6100.00 6000-00 -3054'48S 2812.87E 1482 26 3 D ! R E Il. T ! O N A L $ U R V E Y INTERP~!I=/tTFB VALUES FaR EVEN 1OO FEET GF $U8 ~SEA' DEPTH. PAGE ATLANTIC RICHFIELD CO K-30 44-2! WELL COMPLETION PREPARED BY SCS 3-16-70 TANGENT'IAL HETHOD MFASIJRED DEPTH TOTAL COORDINATES HD-TVD VERTICAL TVD SUB SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION 77nq 7R32 7955 8~79 8719 8A46 8~72 9098 q724 9482 q61. O 9738 9865 10246 !0370 11023 !!!4q 1!774 1!3q7 12 6?0O.00 6100.00 -312~.21S 2847o00E 1509 27 6300.00 6200.00 -3185.315 2882.86E 1532 23 6400.00 6300.00 -3249.00S 2918.52E 1555 23 6500.00 6400.00 -3313.1~S 2954.07E 1579 24 6600.00 6500.00 -3~78.50S 2qg2.6iF 1605 26 6700.00 6600-00 -34'45-99S 3031.81E 1632 27 6900.00 6800.00 -3590.27S ~108.53F ~690 29 7000.00 6900.00 -3661.00S 3147o27E 1719 29 7100.00 7000.00 -3729.27S 3186.69E 1746 27 7200.00 7100.00 -3796.935 3224.11E ~772 26 7300.00 7~00.00 -3864.075 3259.81E 1798 7400.00 7300..00 -3g3~-54~ 3295.20E 1824 26 7500.00 '7400.00 -4005.93S ~29-42E %853 7600.00 ?~00.00 -4079'32S' ~6~o6~E %a82 77~0~00 7600,~0 -4!5~405 3~97.98E 1910 28 7800.00 7700.100 -4223°895 3%32,85E 1938 28 7900.00 7800.00 -4295.06S 3466.27E 1965 27 8~oo.oo 79oo-oo -4365.8os 3497o76E 1992 27 8ldn.dO RO00-O0 -4436.535 ~529.26E 2018 26 8200.00 8100-00 -4509.42S ~560.39E 2046 8300,00 82o0-00. -458~,83S 3591'98E 2074. 8400.00 8300.00 -4660.55S 3624.89E 2%05 31 ~5oo.oo 8400,00 -47~7.:89~ 3659.33E 2136 '31 RAO0.O0 : ~500.00 -4812.92~ ~694-24E 2166 87:00-00 8600-00 -4889.'29S ~729.39E 2196 30 RSO0*O0 8700.00 -6961.105 3760-28E 2223 27 RqO0.00 8800.00 -503:2,38S 3790.53E 22~9 26 gO00.O0 8900.00 -5100.78S 3819.57E 2274 25 9100.00 9000.00 -5167-835 ~843:.62E 2297 9 ?l 4 B 1'_ R E £ T ! ~ N A L_ g U R V E Y !NTERPt"11 ATEI3 VA! UE_$ F~R ~VFN 1OO FEET 'I3F RUB SEA DEPTH PAGE ATLANTIC R[CHFTELD CO K-30 44~2! NELL COMPLETION PREPARED BY SCS 3-[6-70 TANGENTIAL METHOD EASURED EPTH TOTAL COORDINATES MD-TVD VERTICAL TVD SUB SEA LATITUDE DEPARTURE ' O[FFERENCE CORRECTION 11518 11634 11750 11866 llgR2 12098 I?PI~ 12332 12~52 12570 12685 12800 13030 13146 q200.O0 9100.00 -5232.21g 3866.23E 2318 21 9300.00 9200.00 -5287.20S 3887.34E 2334 16 9400.00 9300.00 -5342.19S 3908.45E ~50 16 9500.00 9400.00 -5397.18S 3929.56F 2366 16 9600.00 9500.00 -5452.18g 3950.67E 2382 16 9700.00 9600-00 -5507.17S 397t.78E 2398 16 qgO0.O0 9800.00 -5621.'43S 4012.32F 2432 10000°00 9900.00 -5683.645 4032.57E 2452 20 10100.00 10000.00 -574~.555 4051.41E 2470 18 10200.00 10100.00 -5799.118 4064..00E 2~85 10300.00 10200.00 -5853.68S 4076.60E 2500 10400.00, 10~00.00 -SqOq.llg i08?.llE 2514 14 10500.00 10400.00 -5966.06S 4~95.99E 253:0 16 10600.00 10500.00 -6025.01S 4103.93E 2546: 16 5 D I R E C T I .O N A L INTERPOLATED VALUES FOR EVEN 1000 5 U RV'EY FEET OF MEASURED DEPTH PAGE 1 ATLANTIC RICHFIELD CO K-30 44-21 NELL COMPLETION PREPARED BY"SCS 3-16-70 TANGENTIAL METHOD MEASURED ( DEPTH TOTAL COORDINATES MD-TVD VERTICAL TVD SUB SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION 1000 2000 3000 4000 5000 6000 8000 0000 10000 llOOO 12000 l~OO ~RPT1 gR8 1869 2619 3358 4119 4872 6435 7221 8006 8781 9615 10474 .58 888.58 -3.275 114.98E II 11 .51 1769.51 -332.07S 438.73E 130 llg .33 2519.33 -791.785 gl3.g6E 380 250 .02 3258.02 -1249.435 1408.44E 641 261 .28 4019.28 -1703.595 1870.94E 880 239 .91 4772.91 -2204.405 2294.gOE 1127 247 .35 5~37.3~ -2741.155 2648.41E 1362 235 .92 6335.92 -3272.045 2931.'29E 1564 202 .98 7121.98 -3811.69S 3231.96E 1778 214 .6I 7906.61 -4370.48S 3499.85E lgg~ 215 .82 8681.82 -4948.15S 3754.78E 2218 225 -32 9515.32 -5460.60S 3953.91E '2384 166 .38 10374.38 -5950.93S 4094.13E 2~25 12 9 OR ! G ! N LOC !, 14 0 15 1_59 0 15 164 0 15 ! 89 0 15 214 0 28_q 0 1,5 3],4 0 15 339 0 ].5 364 0 15 38 Z 0 45 400 0 500 ! 45 600 4. 30 7OO 800 12 30 _q 00 1 '5 0 1000 16 4.5 1100 18 1200 20 4-5 1300 22 15 )~400 24 O: ~600 !700 30 BO 1800 32 45 !gO0 '35 O 2000 37 4.5 2!00 40 15 0~0'0: TVD = !13.gg !3~g9 7! !'BR+gg '38+99 71 188,99 88,99 7! 213.99 !!3,89 7! 3'38.99 238~g9 7! 363,98 263,99 7! 38!,99 28!~qq 7! 399 gg 299~99 7! 5~9:63 4.99:63 63 698.60 598.60 52 7q6~23 Rq2+S~ 7q2+R2 !7 988 58 888.58 3 108-5~27 98~27 1176='79 1076~79 51 126.9.34 1169.34 78 !360~69 !260+69 !07 !450,'38 1538,26 !43R+26 !77 1624.4'3 !524.4~ !708.53 1608,53 ?46 !8.6q.5! 1769.5! '~32 1945,84 !845.84 379 TIIDF = .27N -14N ,O3N -!4N .12N .05N -!4N -~4N -'~SN .'74N ,47N ~55N .89N .45N ~27S ~OqS ~2S ~48S .74S .2gS .fl7g 71.277 DEPARTURE = 46.9~F 85.3~ N 3B.B6F 46'61ff 85-07 N 46.51E 84.99 N 33.17E 46.50~ 84.90 N' BB.20~ 46.47E · 84.97 N 33.15E 46.5~E 84.~8 N 33.!8E 46,6!F 85-06 N 46!'65E 85,00 N 33.28E 46.71E 85.1I N 33.29E 46.76F 85.)2 N BB.28E 46.77E 85.31N 4A.7~F R~.4q N ~.14F 46.5&~ 85=53 53,75E 83-24 N 40-2~E 63.36E 82.53 N 50.14E 76.98E 85,01. N 64.89~ 138.10~ 140.45 !6~,7~ !70-54 217-27F ~42.44 PSR.PSF 330.87 S 58.55E ~lS.l?E 380.39 S 56.76E '356.42E 433.49 396.98E 490.03S 54-10E 4BS.73E 550.24 S 52.87E 46.93 0-000 0.087 1'1.61 1'975 1.237 0,364 1'2::11 1'757 0-174. 0.295 2-R'77 2'575 ~.750 ~.751 _ 4.282 2.765 2.090 1.500 2-250 2-000 2.250 2.250 ~-994 ?.4gq g ~ 6 ~ 4 T SURVEY TANC~F:kJTI'Bi ~F~TI-i~D K--~ RFORI'_II LFG 2 CRNI~ 2_ WFL[ l".l"]l~.Pl FTI'QN PRFPARFD BY ~I".S 04/14/70 MEASURED D E V I A T ! 0 N DEPTH ANGLE O!RECT!ON TVD SUB SEA TGTAI C~f]RD!N~T~S C L O S lJ R F L,~T 1'_ TUDE DFP~RTIJRF ~!ST~N£F ANGI DDG LEG SEC'T!Ot~ SFVFR'I TY DISTANCf 2170 41 O' S 44E 2~57 40 45' 24q2 40 45' § 45F 2670 41 15' ~!25 43 45' S 47E 3647 42 15' $ 47F ~865 4! 30, S 48F 4085 4~ 30' S 47F 4175 4.0 30' $ 47E 4318 40 15' $ 47~ 4478 40 !5! ~ 4l'7~ z,-570 40 30' S 45E 4725 40 30' S 455 4882 40 30' S 43E 50!4 40 BO' S 44~ ~5206 4.0 30' $ 43E -- 54~ 40 ~' .5612 40 O' $ 41~ 583! 4! 45' $ '3'7~ 6083 43 30' S 37E 623'7 '42 30' $ 37~ 6417 42 1.5' .S 6835 37 45' S 30E 6964 37 45' S 305 ~ 37 30' S 2gE ~393 37 O' S 7695 57 45' 1998.67 1898,67 ~flSq.q5 !959.95 2141.0! 2041.01 2B77.11 ~77.!! 253a~26 243a,26 2760.19 26A0.19 3255.36 3155.36 ~432.65 B522.65 3~00.25 ~500 ~3 39120.!7 38!0.!7 4029~55 39Z9,55 4129.92 4029.92 4275.92 4!75.92 4586~94 448.6.94 4750.3~ 4650.32 4933=!2 4833.!2 5046.66 4946.66 5179.90 507g.Q0 538.7~40 5287.40 5506.79 5406.79 5608.79 5508.79 412-36S 514.70E 496.60~ 60].93E 558.91S 664.25~ 6~8-95~ 750.08E 757-545 855.80~ 88'B-74~ !fl!2-58F 10g2.98S 1236.97E 1189.64S 1344.32E 1287.08S _1448.81~ 1326.95~ 1491.56E !389-965_ '!559.13~ !50~.7!S !676.99~ 157~-89~ !748.17~ 1648,465 1817.715 1710.13S 1877.26E 659.51 S 51.29E 710.73 S 50.glE 780.34 S 50.47E 868.11 S 49.92E 985.3~ S 49.57E 112g.77 S 49.24E 14qR.77 K 4R-AqF 1650.67 S 48.53E 1795.11 S 48.495 1937.95 S 48.38E 1996.38 S 48.34E 2088.75 S 48.28E 2192.11 2251.76 S 48.1BE 2352.28 S 48.00F 2453.88 S 47.795 2539.42 S 47'66E !~0!.335 _!96~.3~F 2663.72 $ 47.44~ 190:~.~4g 2057.4~F !995.03S 2!37.!~F 2!!!_-495 2224 2250.03S ?,329.2~E 2333,1~S 2391,.90E 2853.58S 27~1,98S ~637-'79E 2950.!9S 3!16.'37S 2RO2.gl. R 47.22F 3067.B4 S 46.49F 37!3-85 $ 44.BqE 3790.4~ S 44-!~E 3931,05 S 43-54~ 4G4'1.33 S 43-11E 4218-38 $ 42,37E 1.418 633.7; 2.048 684.2~ 0.700 752.8, 0.483 839.6~ 0.788 954.5~ 0.465 1096.1( 0.2~1 14~7.K' 0.442 1606.3{ 0.460 1747.11 0.543 1887.0~ 0.000 1944.2' 0.174 2034.7; 1.434 2:194.8( 0.827 2305.0~ 0.492 2479.7~ 0~338 ~603.3i !-437 B008.1: 0.~49 3285.~ 1.559 3574-2~ !.166 3666.3, 0.000 3744.g~ 0.276 3889.67 0.413 4003.0' 0.472 4!85,5 lO 6 D ! R E C T ! 0 N ~. [ S U R V E ¥ PAC. F TaNGENT!aL METHOD g-~q RF~RTI L I_FG ~ C. flNI3 2 WFII C{']MPLFTTtqN · PRF:PARFD BY .~C~ 04/14/70 ME.~SIJRED D E V ! ~ DEPTH ANGLE D!R T I 0 N T~TAI CI'IfIRDINATFS C L a S U R E ECT! n_N TVP, SUB SEA, I. ATITHBE DEPARTURE DISTANCE ANGLE BaG LEG SEVERITY SECTIOr DISTANCI 7760 35 30' 7862 35 45' 8110 36 15' 8297 37 30' 8672 39 15' 8905 38 15, 9197 37 15, 9589 39 O' 9811 38 30' ~0!35 37 45' 10328 38 30' 10476 39 45' 10679 40 15' 10913 39 45' 1'!161 37 45' S 30~ 624!.85 6141.85 B~4g.06~ 2861.9BF 4255.26 S 26E 7857:17 7757:!7 4264.775 ~45~.78~ 5487.26 S 24F 8!13.35 R0!3~35 4445.98S 35BB.46E 5679.09 S 2B~ 8378.19 8278.19 S 245 8533.12 8433.12 4763.5!5 3870.73E 60!3.76 S 23E 8909,12 8809,12 5038,88S g7q~.2gE MD = ]11296 TVD = 90!7,64: LAT!TUD~E = -5121~2 S 235 9042;'55 8942:.55 5129:77S 3831,87E S 23F 91(}4,12 g004~2 5165.87S 3847.20E S 23E 9150,16 9050,1.6 5]~1,85S '3858~27E S 23E ~2~5~2 ~13~32 52~2~5S S l'9E 9330:66 9.2'30=66 5278.58S S 18E 96!4 67 Q514,67 54!0~3~S ~934.1~E S 16E 9843:97 9743.97 5513.!1=S PLUGGED BACK :11327 36 30' 11400 32 30' 11454 31 30' 11550 27 30' 11657 27 O' !!97~ 26 O' 12226 25 O' 12526 24 O' . !2600 23 30' ¸Tn_ g 42.26E 5.044 4223.1, ' S 42.0q~ 0.245 4282.51 S 4!.66E 0.311 4428.2~ S 41.40E 0.926 4541.81 S 40.74E 0.681 4777.1~ S 40~4BE 0~687 4920.8~ $ gS.qgF 0-360 5475.B1 S 38.47E 0.445 5669.9, S 38-!5E 0.503 5787.3t S B7.gIE 0.844 5879.8! S 37.61E 0.401 6008.51 6307.0q S '36.97E 0-951 DEPARTURE = ~824.67 6B04. !~ 6402,95 $ 36.75E 0~000 6400,6! 6441-05 S 36'67E 5.479 6438.91 6689.49 S 36.02E 0.346 6688.8~ 6902.77 S 35-32E 0.5!3'l 6902.'7~ CLOSURE 6929_-67 $ 35- 13' E 12 10 9 ~ 6 ~ 4 ~ 3 D ! R E C T ! 0 N A L S U R V E Y P.at__.E 1.. I_NTERPOL4TED V4LUES FOR EVEN 100 FEET OF $1JB SEA _I~FPTH K-3n REOR!LL LFG 2 CONO ? WELL CONPLFT!ON PRFPARED BY SCS 04/14/70 TANGENTIAL METHOD MEASURED ~EPTN TOTAL CQORnTNATFg MD-TVD VFRTICAL TVO StIR SE~ IATiTU~F ~EPARTURE DIFFERENCE CORRECTION ¢ ¢ ¢ ( ¢ ( 300 400 500 600 701 804 907 1118 1334 144.4 1556 1672 1790 1912 2040 2!7~ 2303 2435 2567 2701 2836 2973 3112 3250 3387 3523 3658 2nn,nn 10n,00 7!,!3N 46.49F 0 0 400,00 300,00 7!,74N 4fi.56~ 0 O 500.00 400,00 69.47N 48.6!E 0 0 600,00 500,00 63,5!N 53,7qF 0 O 700,00 600,00 52,65N 63,55E '! 1 800.00 700.00 35,34N 77,6RF 4 lO00.00 q00.00 -5-g6~ 117.76E 12 5 l!O0.00 !00O,O0 -qO.!6S !42.50F 18 ]~O0,oO l~O0.no -57,g?S !ag,~OF 25 7 1300.00 !?OO.O0 -88.!45 !qS,49F 34 l~n0,00 !~00,00 -!2!,2gS 2~n q'7~ 44 150n. O0 1400,00 -'!57,90S ~67 5g'F 56 12 1600,0~ ~50o~00 -~g8,3!S 307,ggE 72 16 !700,00 1600=00 -242=85S 352,54E go 18 lfl~o0.o0 t700.00 -~92.'70S 402.02F 112 22 lg00,00 1800.00 -350.g4S 456.~3E !4.0 28 2100,00 2000-00 -472,05S 576.5!E 203 31 2200..00 2!~.00 -532,54S 637 8'7F 235 32 2300,00 2200,00 '-592 8~'S 700,62E 267 32 2400,00 :2300.00 -653,!3S 765.28E 301 34 2500'00 2400,00 -7!5,08S 83!,72E 336 35 2600.00 2500,00 --779.165 qOO,4'~E 3'73 37 2700.00' 2600,00 -844 44S 970.4.4E 4!2 39 2800.00 2700-00 -909,28S 1039 gTE 450 38 2900.00 28(30,00 -97B.445 !108.7'7F 48'7 37 3000.00 2900.00 -1035,9'35 !!75.7qg 523 3100.00 3000,00 -!097'6.6S !242.!6~ 558 11 8 3 !N'TERPOL.~TED VALUES FOR EVEN !00 FEET OF gUR gFA r'JFPTH K-30 RFDRILL LEG 2 CnND 2 WFLt £QMPLETTON PREPARED BY'SCS 04/14/70 TANGENTEAL METHOD :~EASURED nEPTH TOTAL CnORDTN~TFS MD-TVD VERTICAl TVD SIIB SEA t_~TITUOF DEPARTURE DIFFERENCE CORRECTION 12 392q 3300~00 3200 4055 3400~00 3BO0 4187 3500.00 '3400 4318 3600~00 3500 4449 3700.00 3600 4580 3800:00 3700 4712 3900:00 3800 4843 4000,00 ~gO0 4975 4100.00 4000 5106 4~00~00 4!00 · 5237 4300~00 4200 5499 4500=00 4400 56~0 4600.00 4500 5764 4700:00 4600 58~9 4800.0Q 4700 6037 ~900=00 ~800 6309 5!00~00 5000 6572 5300:00 5200 6700 5~00,00 5300 6826 5500.00 5400 7079 5700.00 5600 7205 5800.00 5700 ~456 600~,00 5gO0 7582 6!00~00 6000 -!I~A=~AS }~o7=qlF 59'1 -!2!5.64S !37~.!9E 624 -!27~,8qS 1434.66F 655 -1332.095 !4~7~07F 687 -!38q.82S !S58,qqE 7!8 -!447.:56S !620,90E 749 . -!507=~65 !68! 63E 780 -1.567,75S !742,03E 812 32 -!aql.74.$ !85q.50E 875 B2 -!753.q0S lq!B.OTF 906 -!8!6.!0S !qT&.OBE 93'7 -!877,.475 ~033~3~F qaa --!qBq.q7$ '~q,27F 999 B'I -2004,34S 2!44.!4E 1.030 -2075~625 2!97.86~ 1064 -2!49.14E 2253.26E 1099 35 -?298-q7g 2~a~-17E 1,174 37 -2372=3!S 24~0.~8[ l:2Oq -25!3,50S 25!4,57:E 1272 29 -258!,97S 2556,q6F !~0~ 28 -2649,09S .2595,675 1326 -27!~,~8S 2a~4.'BSF ]~5~ ,27 -2850,29S 270.8,89E 14e5 26 -2g!6,R~S 2744..27F 1.4~0 25 -?984 895 ~778 q3E 1456 26 10 9 4 T D I R E C T ! 0 N .a L S IJ R V E Y PAGE !NTERPOLATE_P.', V~LIJES FOR EVEN 100 FEET OF SUB SEA DEPTH K-BO RFDR!LL ~FG 2 C~ND 2 WEll C~MPIFT!ON PREPARED BY SCS 04/14/70 TANGENTIAL METHO0 NEASURED nFPTH TOTAL COORDINATES ND-TVD VERTI[AI TVD St_IR %FA LATTTUDE DEP~RTURF DIFFERENCE CORRECTION ¢ ¢( ¢ ¢ ¢ ¢ ¢ (. 12 ,, I 1 77~q 7832 8079 8205 8332 8461 8590 87!q 8846 8972 9098 9~_~ 9353 9~82 9610 9738 9865 10118 10246 10374 10505 106_%6 10766 10896 !!023 11149 1139:5 1151O 6300,00 6200~00 -3!85,31S 28~?,STF !5~2 6400.0fl 6~00,00 -3249,00S 2918.52E 1555 23 6500.00 6400.00 -33!3.!BS ?954~07F 1579 24 6600.00 6500.00 -3378.50$ 2992.61E 16o5 26 6700=00 6600=00 -3445.995 30BI.81E 1637 27 7c00-00 69o0.00 '-~66!.00S ~147.~7~F 1719 29 7~00.00 7000.00 -~7~9.~75 ~!86.69~ 1746 ' 27 7~00=00 7!00.00 -3796.935 32~4.11~ ]772 26 7500+00 7400,00 -4005,9~S ~29.42F !853 29 '7700:00 7600:00 -4!52=40S 3397:98E 1910 28 7800.00 7700.00 -4223.89S 3432.85E 1938 28 7900.00 7800,00 -4795.06S 34~6+~7F 1965 27 8!00~00 8000:00 -4436=53S 3529.265 20!8 8300:00 82,00=00 -4583.8'35 359!=9~ ~074 28 8400~00' 8~00.0:0 -4660~555 3624.89~ 7!05 8500~00 8400.00 < -4'737':'8:95 '3659.33E ~!B6 8900.00 ~800~00 -50~R$ ~790.5~ 224,9 9!00,00 qO00,O0 -5!63,4~5 384~!'7E 229~ 4~ 9200.00 9!00.00 --5215.'72S 3868,36E 2~'1~ !5 lo 6 P, I R E C T I n_ N A L S U R V E Y !NTERPOLa'TEO VALUES FOR EVEN 100 FEET OF SUB SEA DEPTH PAGE K-30 REDR!LL LEG 2 CGND 2 WF!L C~)~PLFTIC'-N PREPARED BY SCS 04/14/'70 TANGENTIAL METHOD N~E~SURED TnTAL £nDRDIN~TES MD-TVD VER'TICAL TVD SIIB SFA LATITUDE DEPARTURE DIFFERENCE CORRECTION !!62B 11845 11957 ~Z067 121'77 1~B06 9300-00 q~on~o0 -~2A3~A!S ~SRA-P'7F 9400~00 9300~00 -5310.74S BgO]~!E 9600.00 9500=00 -5403.52S 393!.95E ~57 1.2 9700:00 9600=00 -5448~575 9800:00 9700.00 -5493,39S 3957,98E 2377 10 9900:00 9800:00 -5537:4!$ !OOO0:O0 9900=00 -5580,795 12 11 8 ~ 4 (' ~ _F:PTHm. 3000 4000 6000 7000 _ ooo 9ooO !OOOO 12000 !! 12 TnTAL £nnRDIN~TES MD-TVD VFRTICAI TVD StIB SEA LATITUDE OEPARTURE DIFFERENCE CORRECTION 4872.9! 477~.91 -2204.40S 2~q4.qOF ))2'? 247 6435.q2 a33~,92 -3272.045 293].~gF 1564 202 727).98 7121.98 -~R1!.69S B2B'l.g6F 1778 214 8781-82 RaSl-R2 -494R,155 2754.7RF 2218 225. 9639.!4 q53q~:!~ -542!~2qS 3937.~1, F 2360 142 Wt~ PT ! , i i it! ;--I 'F'r '' Form. No. P---4 REV. 9-30-6"; ,- STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REiPORT OF ~DRILLING AND WORKOVER OPERATIONS W~.LL WELL OTHER 2. NA/VIE OF OPEI~TOR * Union Oil Company of California 3,ADDRESS OF OPERATOR 2805 Denali Street, Anchorage, Alaska 99'503 4. LOCATION OF WELL 687' N & 78' W fr SE cr Sec 17, T9N, R13W, S.M. SUBMIT IN DEPLICATE T. IF INDIAN, ALOTikE OR TRIBE NASIE :ikE ,, - 8. UNIT,FAi~M OR LEASE N.~ME Trading Bay Unit g. %VELL LN'O. K'30 (44-21) 10. FIELD AND POOL, OR WILDCAT McArthur River "G" & ., 11. S~C., T., R., ~., (BO~O~ HO~ sec 21, Tgl~, R13W, SM 12, PERMIT NO, , T0-7 13. REPORT TOTAL DEPTH AT END OF MONTH, CHJ~GES IN HOLE SI~E, CASING AND CE!VIENTING JOBS INCLUDING DEPTH SET AiNrD VOLUiVIES USED, PERFORATIONS, TESTS A_ND RESULTS, FISHING JOBS, JUNK IN HOLE A.ND SIDE-TtL~CKED HOLE AND ANY OTHER SIGNIFICANT CI-LAJq~ES IN HOL~ CONDITIONS. April, 1970 Milled over fish ~ 11523-11527'. Received orders to plug fish and redrill hole. Ran 8-1/2" bit & 9-5/8" casing scraper to top of fish ~ 11515'. Circulated and Conditioned mud and ran 9-5/8" cement retainer, set same ~ 11509'. Tested drill ~ipe w/4000#, tested 9-5/8" casing w/1000# OK. Tested below retainer with 4000# ten minUtes OK. Conditioned mud and raised viscosity to 52 seconds. Ran 8-1/2" section mill and cut 9-5/8" casing 11327-11367'. Ran 15" under reamer and opened 12-1/4" section in 9-5/8" casing to 15" 11327-11367'. Set cement plug w/130 sacks Class "G" w/retarder, 20% sand, 11509' to +11180'. Dressed off top of plug and directionally drilled through window in 9-5/8" casing. Side- tracked hole to 12600'. Survey ~ 12526' 24° VD 10130.13' S13E S5635.76 E3995.62. Ran Dual Induction Log 12564-11334'. Cemented 7" liner 12598-11216'~w/125 sacks retarded Class "G" cement. Cleaned out to float collar in 7" liner and ran cement bond log. Perforated four 1/2" holes at 11985'. Set cement retainer at 11935' and squeezed perforations Shot four 1/2" hole at 11385'. Ran cement retainer and set at 11335'. Squeezed perforations. Ran 9-5/8" retrievable cementing tool and set at 11104' and squeezed liner lap. Perforated four 1/2" holes per foot 10802-10830 and ran DST #1 over same perforations. Had gas to surface in thirty minutes at 2800 psi with rate of 5.8MM cuff per.day with slight trace of liquid. Ran 8-1/2" bit and 9-5/8" casing scraper to 11109'. Circulated and conditioned gas cut mud. Ran 9-5/8" retrievable squeeze tool and set at 10690' and squeezed perforations 10802-10830' with 275 sacks Class "G" cement. Held 1500# on annulus during squeeze to test 9-5/8" casing OK. Drilled hard cement 10691-10871' and tested perforations 10802-10830' with 3500 psi OK. Cleaned out hole with bits to 12552 and spotted 200 barrels Invermul mud on bottom 12552-10500'. Selectively perforated four 1/2" holes per foot 12480-10876'. Ran completion assembly. Removed BOPE. Installed dual tree & tested with 5000#. Displaced mud with diesel oil. Set 7" hydraulic packer and 9-5/8" hydraulic packer and tested with 1000# OK. Released rig 3:00 A. M. 4-27-70. Final Report 4-27-70. .. ~i.i' : . L-~ *Atlantic Richfield-Sub-Operator. S~G~rSD _il~ I~ i I/J,JJ,,/J,~JV TITLE Dist. Drl~, Sunt. nAu.'r: 5/12/70 ,. [JJL .II{~/'i'~II~v. J ~ - ' . ,,. NOTE R~or[ on t~i~ form is/~quired for each calendar month, regardless of the statu~ of operation% and must ~ filed in duplicate with the Division of Mines & Miner~l~ by the 15th of the succeeding month, unless othe~ise directed, Form No. 1:--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF ~DRILLING AND WORKOVER OPERATIONS O,L IX! G,. [] WELL WELL OTHER NAME OF OP~,ATOR * Union Oil Company of California 2805 Denali Street, Anchorage, Alaska 99503 4. LO'CATION O,F 687' N & 78' W fr SE cr Sec. 17, T9N, R13W, S.M. SUBMIT IN DEPLICATE 7. IF INDIAN, ALO-I 1~:~. OR TRIBE NAME 8. U'NIT,F.~q~M OR LEASE Tradin9 Bay Unit K-30 (44-21) 10. ~J~DAAi~j~Lj~Ij~D~.~[JII and West Foreland 11, SEC., T., R., A{., ~BO~FOM HOL~E OBJECTIVE) Sec. 21, T9N, R13W, SM 12. PEP~IT NO. 70-7 13. REPORT TOTAL DEl~TH AT END OF MONTH, CI-IA.NGES IN HOLE SI~E, CASING AND CElVIENTING'JOBS INCLUDING DEPTH SET ~ VOLLrNIES USED, PERFORATIONS, TESTS AiW'D RESULTS. FISHING JOBS. JLrNK ~ HOLE A.ND SIDE-T]~ACK~ HOLE AND ANY OTHER SIGNIFICANT CH3kN~ES IN HOL]~ CONDITIONS. Report for March 1970 Directionally drilled 12-1/2" hole 11825' - 11995' Ran DIL Log 11995' - 2187', Density, 'Sonic & SNP Logs 11995' - 9000' Took SWS 11335'- 9275' Drilled 12-1/4" hole 11995' - 12150' 9-5/8" Csg cmtd @ 1203~'. Ran 305 j:tS. 9-5/8" Csg as-follows' 48 its 9-5/8" (1981.30') 47# P-111 & 257 its 9-5/8" (10055.83') 47# N-80 buttress csg landed @ 12036' Used Baker Diff Float Shoe (12036') & Diff FC (11949'). Used 26 B & W ~urbolater"centrlzr on BTM. 26 its & 16 centralizers @ 200' intervals, cmt w/lO00 sxs Class "G" cmt treated w/l% D-31. Preceded cmt w/lO0 cuft wtr. Displcd cmt w/50 cu ft wtr & 5029 cu ft mud w/rig pump @ 70 cu ft/min. Bmpd plug w/2000 psi. CIP @ 3:15 PM 3-6-70. Installed 9-5/8 pack-off. Chngd to 5" pipe rams. Made up 8-1/2" bit. .Found top of cmt @ 11933'T. Tstd csg w/l$O0 psi from 11933' DO FC & Shoe @'1.2036'..std csg shoe w/lO00 psi @ 12129'. ~eld OK. Drld 8-1/2" hole 12150'13196' Increased mud wt to 95# @ 13039. Had gas~cuireturns of 42#. ' ~an DIL, FDC-GR. BHC, Sonic, SNP & HDT. Fr 13176' - 12036' (FDC-GR 13176' - 11786'). Ran 31 its (1.264') 7" 26# P-1IO 8-RD Gsg w/turned couplgs as lnr w/Brown float Shoe & stop clr w/30 centralizers. Ran 4-stds dp. Un-"J'd" from running toolS & drop to BTM. RIH w/Brown running tool, top @ 11943'. Could not "J" into lnr. POH ~ Ran Bowen 7" csg spear to top of lnr. Could not latch into top 4" of lnr. POH. Re-ran 7" csg spear on 30' x 4-3/4" DC. Ri to top of lnr. Took hold of lnr, jarred on lnr 6-hrs w/max 450M#. Could not jar lnr free. Ran 7" Guiberson down cup pack off tool. Could not work inside lnr. Reversed circd trying to collapse p'kr cups. Would not go in lnr. Ran 6" bit to ck lnr cond. Ran to baffle clr @ 13154'. Lnr OK. * Atlantic Richfield C~,mpany Sub-Operator ~ I~ /'~1/ , s,a~n ._ 'fi _t ~~ ~ , % ~ ~ IfA'a "[ ~Y; NOTE~R~po~ on [his form with the Division of Mi~es & MindrB ~/~/~o required for each calendar month, regardless of the status of operations, anO must lis by the 1Sth of the succeeding me nth, unless othe~ise directed. Atlantic Richfield Wel 1 No. K-30 (44-21) Page 2 Ran 7" RTTS Sqz tool & circ sub on 1331.84' of 3-1/2" DP (13.3# ft) & 10648.84' of 5" (19.5# ft) DP. Set RTTS tool @ 11985' Circ 7" lnr w/950 psi. Pmp in 50 CF wtr. Mix 600 sx Class "G" premixed w/l% D-31 Disp cmt w/lO61 CF mud. Pmp press started to rise when cmt started around shoe of lnr approx 700 CF mud displ. Press increased from 500 psi - 3500 psi while displ 700-1060 CF & went to 4500 psi. Bled 20 CF. Could not rels RTTS tool. Could not rels frm tool w/sfty sub. Started mxg @ 12:05 PM 3-21-70. Mix time 30 rain, CIP @ 1:40 PM 3-21-70. Backed out 5" x 3-1/2". CO & cir DP clean w/approx 50 CF cmt rets. Top ~of fish @ 10642'. Ran 8-1/2" bit to 10642' Csg cln. POH. Made up tri State outside cutr on 7-5/8" wash pipe. Ran 8-i/8" cutr on 317' of 7-5/8 WP. Over fish to 10961'. Cut 3-1/2" DP. Rec. 319' of 3-1/2" DP. Re-ran cutr on 317' WP. Att,d cut @ 11248' no cut. Ran 8-1/8" wO shoe to 10950' rotated & circ over fish @ 11,283'. POH. Ran 8-1/8" outside cutr. Made cut @ 11245'. Ran 8-1/8' outside cutr to ?404'. Made cut @ 11404'.,, POH w/fish. Rec 5-its (158.75') 3-1/2 DP. Ran wO shoe. Wo on 10 its 7-5/8 wash pipe milled 11494' - 11513'. POH w/wo shoe #3. Rec. 3-its 3-1/2". DP wedged in WP. Top of fish @ 11510' ,Ran wo shoe #4 wo fish 11513' - 11520'. POH. Ran wo shoe #5. Brad 11~17 - 11520'. POH w/#5. Rec 5' fish. Top of.fish @ 11515'. Ran 8-1/8" sc,a, llop wo shoe #6 Pmd 11517' - 11520'. Would not cut. POH. Ran wo shoe #7 8-1/8 scallop rotated 1-1/2 Hrs before mill would start cut. Milld over fish 11520' - 11523'. Last day March 30. Form REV. 9-30-67 SUbmit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIONi CO,MMII-I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PER.MIT~" for such proposals.) 1, oil ~X GAS Q WELL WELL OTHER 2. NAME OF OPERATOR *Un~on 0ilCompany of California 3[ ADDRESS OF OPERATOR 2805 Denali Street,Anchorage, Alaska 99503 4. LOCATION. O,F WELL At surface 687' N & 78' W fr SE er Sec 17, T9N, R13W,~ SM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 100 KB '5.' API N~CAL CODE OK(~~~~-- 50'133'20211 KLV 6. LEASE DESIGNATION AND SEROX ~:~ REL ~ ADL 17594 -- 14. 7, IF INDIAN, ALLO'i"r~ OR TRIBE _N~ANIE , 8. UNIT, FA-RA~ OR LEASE NAME : TradinM Bay Unit 9; w~.',L NO. · ~ '~,30 (44-21) · McArthur River 'G' and West Ot~I~,CTIVE) .~ Sec 21, T9N, R13W, SM · : 'I ~70-7 ¢~eck A~roMr]~e Sox ?~ NOTICE OF INTENTION TO: SURS~QUI~NT REPOaT OF: FRACTURE TREATMENT FRACTURE TREAT MULTIPLE COMPLETE ALTERING CASING SHOOT OR ACIDIZE -- ABANDON* SHOOTING_~)R ACIDIZING ABANDONMEN'T* REPAIR WELL ~ CHANGE PLANS (Other) ' (NOT/": Report results of multiple completion on Well (O~her) CompJetton or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Present'Condition: ~T.D. 13196' DD 9-5/8" 47# P-110 & N-80 cemented at 12036' 7" 26# P-110 liner at 13196, Top ~ 11943' While cementing liner in place, had early set of cement While displacing, cemented in liner, cementing tool and 458' of 3-1/2" 13.3# drill pipe. It is not practical to recover fish. Top of fish ~ 11515' Leaving all Zones behind cemented pipe. We Propose: 1. Set retainer at 11510', squeeze top of fish. 2. Mill window 11326-11366. Re-drill hole to 12640'+. 3. Complete well w/liner, block squeezing base & top of Hemlock Zone and liner lap. ' 4. Run dual 3-1/2" tubing strings for "G" & West.Foreland production. Proposed Bottom Ho~a Location 1550' W & 225'N fr SE cr Sec 21, TgN, R13W, *Atlantic Richfield Company, Sub-Operator. · 16. ! hereby certify ~a/lth. f r~lt. tru. ,nd cor,.~t SIG~D ~ (This space f~ti~e o~ u~) / ~ APPROVED Be ~~~ CONDITIONS OF~APPROVAL~ IF TITLE District Drilling Supv. DATE ANCHORAQI~ March 31, 1970 -iL See instructions On Reverse Sid~ Approved Copy Returned ~v Form No. P--4 REV. 9-30-6'; STATE O,F ALASKA SUBMIT IN DEPLICATK O~h AND GAS CONSERVATION COMMITTEE A'~ONT'HLY REPORT O!F ~DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Union 0il Company of California AD~'kESS OF OPE/~ATOR 2805 Denali Street, Anchorage~ Alaska LOCATION O'F WELL 687' N & 78'W fr SE cr Sec 17, T9N, R13W, SM RECEIVED HLB TRM ~. APZ NmVmmc.~., cone OKG 50-133-20211 KLV ........ 6. LEASE DESIGNATION AND REL ADT. 17594 T. IF INDIAN, A~t i~ OR TRIBE NA~IE FLLE 8. UTqlT,FA/~M OR LEASE N.~ME Trading Bay Unit 9. WELL NO. K-30 (44-21) 10..~'I~;I.,D AND POOL, OR WILDCAT "G" & West Forelands I1. SEC., T., R., M., /BOTTOM HOLE OBJECTIVE) Sec 21, T9N, R13W, SM 12. PgR.MIT N'O. 70-7 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN N([~I~ SIZe, ~-A§'ING AND C~VIENTING JOBS INCLUDING DEPTH Dlv'lo~O~4 ~! .... i~_, ~ qD GA5 Report for February,..197.0 Ran Gyro-Multi-Shot survey 2187-0'. Ran junk basket. Drld 2492-2499'. Recovered 2 cones, 3 spindles. Directionally drilled 12-¼" hole 2499-11825' Survey: 11494' 35015' S19E S5217.77 VD9180.46 E3857.25. *Atlantic Richfield Company Sub-Operator 14. I hereby certify he for~ true .and coffee% NOT~Report o~ this for s required for each calendar month, regardless of the status of operation~, a.O must ~e fileO in duplicat~ with the Division of Mines & Minerals by the 15th of the succeeding menth, unless othe~ise directed. Form No. P--4 RE%r. 9-30-6T STATE OF ALASKA SUBMIT IN DEPLICATE ~s. API N~EmCAL CODE O~L AND GAS CONSER:VATION COMMITTEE MONTHLY REPORT O'F 'DRILLING AND WORKOVER OPERATIONS 2. NAME OF OP~TOR Union 0il Company of California 3, ~DDRESS OF OPE~k~TOR ' ' 2805 Denali Street, Anchorage, Alaska 4. LOCATION O,F W~T.T. 687'N & 78'W fr SE cr Sec 17, T9N, R13W, SM KLV 50-133-20211 HWk: /~ .... ADL 1759~ 7. IF INDIAN, ALO'I"/EE OR TR _N'A.%IE 8. U'NIT,FAR~M OR LEASE NAAIE Trading Bay Unit 9. %¥ELL NO. ~o, tiEreD POOL, Da wmoc~zr II. SEC., T., R., M., (BOSOM HO~ O~) Sec 21, T9N. R13W; SM 12. P~:LIVXIT NO. 7Ft-7 13, REPORT TOTAL DEPTH AT END OF MON'rH, CHA/~GES IN HOLE SI~E, CASING AND CKMENT~NG J~)BS INCLUDING DEPTH SET ~ VOLU/Vi~ USED, PF-J{FOP~ATIONS, T~F--STS ~ P~ESULTS, FISHING JOP. S, J~K ~ HO~ ~D SIDE-~CK~ HOLE A~ ~Y O~R SIGNIFIC~T ~~ ~ HO~ ~ITIONS. REport for,,,,, February, 1970 Ran Gyro Multi-Shot survey 2187-0'. Ran Junk basket. Dr'ld 2~92-2499'. Recovered 2 cones, 3 spindles. Directionally drilled 12-1/4" hole 2~99~11825' Survey: 11~94' 35015' SI9E VD9180.~6 S5217.77 E3857.25. 'RECEIVED 2 3 1970 DIVISION O~ OIL. AND OAS ANC. MOJLA~I hereby eerti£y tha~" the/~r.e~tn~:~ true and ~ ..... ~~-- . -- ~~T~ ~:.~il~~DA..., March 19 19Y0 .. NOT~--Re~r~, this form is required fOr each calendar month, regardless of the status of operations, and must ~ filed in duplkate with the Divisio f Mines & Minerals by the 15th of the succeeding me nth, unless othe~ise directed. Form No. 1:--4 p~---~r. 9-30-67 STATE O,F ALASKA OiL AND GAS CONSERVATION COMMITTEE MONTHLy REPORT OF 'DRILLING AND WORKOVER OPERATIONS 2. NAlVlE OF OPEP. ATOR * Union Oil COmpany of California 3. ADDRESS OF OPERATOR 2805 Denali Street, Anchorage, Alaska 4. LOCATION O'F WELL 687'N & 78'W fr SE cr Sec 17, T9N, R13W, SM SUBMIT IN DEPLICATE AP1 NUAIERICAL CODE 50-133-20211 ADL 17594 7. IF INDIAN, ALOTTEE OR TI~BENAAIE 8. U~'IT,FA~M OR LEASE NA_RIE Trading Bay Unit 9. WELL .'N'O. K-30 (44-21) 10. FIEI~ AND POOL, OR WILDCAT "G" and "West Fore]and" "11. SEC., T., R., M., (BO~I'OM HOI~E Sec 21, T9N, R13W, SM 12. PERMIT NO. 70-7 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA_NGES IN HOLE SIZE, CASING A1N1-D CEMENTING JOBS INCLUDING DEl:TH .SET A/ND VOLI/M-ES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JLrNK IH HOLE AND SIDE-TRACKED HOLE AD ANY OTI-I2ER SIGNIFICANT CliAH~ES IN HOL]~ CONDITIONS. January, 1970 Spudded @ 3:30 p..m? 1-23-70. Drld 18" hole 355-450. Directionally drld 12-1/4" hole 450-2250. Opened 12-1/4'~-hole to 18" hole 450-2225. 13-3/8" csg @ 2.187'. Ran 53 jts (2041 84') 61#, K-55 Buttress csg w~/)l centralizers 020b'"'interval~~~w/guide shoe & diff, Jlr (shoe @ 2187' clr@ 2108.=~ ). Landed csg @ .2187.-28' Baker Loc btm 6 its. Cmtd csg w/lO90 sxs Class "G" cmt mixed w/lO% gel followed w/400 sxs Class ',G" Neat cmt. Displaced water & mud. Bumped plug w/1500 psi. CIP @ 7:30 a.m. 1-28-70. Good cmt returns. Instld' BOPE, changed Hydrill bag. Tstd rams to 3000 psi, Hydrill to 1500 psi. Ran 12-1/4" bit. DO cmt 2106-2188. CO to 2250, drld 2250-2492. POH. Left 3 cones in hole. Ran Gyro multi-shot survey. Ran junk basket. Drld 11-3/4" hole 2492-2495-1/2'. Recovered 2 cones & 3 spindles & 7" unidenti- fied object. Re-ran junk basket. Drld 2495-1/2 - 2499'. No recovery. Directionally drld 12-1/4" hole 2499- 4443. *Atlantic Richfield Company Sub-Operator m 14. I hereby SIGNED _ _~ with the Division of I a I, .£. I certiil~ ~, the ,o[e~, , /~D ~,~/ ,e and correct ~1 f/ I v, ~ is required for NOfE{Lt:eport ~n this forr~[ each calendar month, regardless of the ~tatu~ of operations, anO must be filed in duplicate ' erals by the lSth of the succeeding month, unless otherwise directed. ALASKA OIL AND ~ CONSERVATION COMMITTEE ~anuary 21, 1970 Mr. ilobert T. Anderson U~on Oil Company of California 2805 E~nalt Street Anch~age, AlaSka 99503 K-3G (44-21) Union Oil Co. of Calif., operator Dear Sir: ~losed is the approved application for permit to drill the abo~ referenced well, on or about January 21, 1970, from the ~ng Salmon platform. Well samples and ~e chips will not be required. A dMectionat survey .is required. Fach electric tog 0 :sepia and pint filed pursuant to AS 31.05.030 and the applicable regulations shaU i~tude the c~ration file and the ~chanical zero. ~.siUons of~ log traces, both before and after the log pan. Each ~ shah show aH format data including (I) type of fluid in the hole, (2.) changes in mud type and additional samples, (3)scale cha~es, (4) equipment data .and (5) equipment 'used. In the event of suspension or abandonment Iflease noti~ ~l.$ office, adequately in advance so that we may have a witness present. Very ~Iy yours, Enclosure Homer L. Burrell C~~an cc.: Department of Labor w/,o encl.. De~tment of Fish &' Game w/o encl. SUBMIT IN TRIP]II~-, (Other lnstructlonk- reverse side) STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE' APPLICATION FOR PERMIT TO DRILL~, DEEPEN,, OR PLUG BACK la. TYP~ OF WORK DRILL ~] DEEPEN I-] PLUG BACK b. TYP]~ o~ W~LL WELL OTHER ZONE ZONE 2. NAME OF OPEP~TOR * Union Oil Company of California 3.ADDRESS (3~F OPEI:L~TOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL At surface 687'N & 781W from SE corner Sec. 17, TgN, R13W, S.M. . ^t proposed prod. zone Top West Foreland- 687'N & l153'W'from SE corner Sec 21 TgN,R13W SM Top "G"-12~0'N 1700~W fr_ SE cor. Sec.21 * , ! · , 13. DISTANCE IN MILES AND DIRECTION F.~OM NEAREST TOWN OR POST OFFICE* TgN, R13W, SM 24 mi les NW of Kenai 50-133-20211 6. I.~SE DI~IGNA~ION A_NrD S~RIAL NO. ADC 1 7594 ~f~,~;,~-,.-~,'%:!¢ ?. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT{FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. K-30 (44-21) 10. FIELD AND POO~, OR WIIi~AT . McArtbur ~ve;r ' G ana West I-oreIana 11. SEC., T,, R,, M., (BOTTOM HOLE OtLIECTIVE) Sec. 21, TgN, R13W, S.M. 14. BOND INFORMATION: TYPE S ta tew i de Surety and/or No, Federa 1 DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 180I 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL D~ILLING, COMPLETED, OR APPLIED FOR, FT. 1 , 2'00 I f rom K-9 Insurance Co. //8011-34-40 t18. NO. OF ACRES IN LEASE 5,.1'10 19. PROPOSED DEI:~I~I · 13~200~ DD 10,675' VD ~mo,,~t $100,000. 17. NO. ACRES ASSIGNED TO THiS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, GR. etc.) 22. APPROX. DATE WORK WILL START* 100' KB 1-20-70 23. PROPOSED CASING AND CEMEN'rING PROGRAM SIZE OF HOLE SIZE OF 18,, ~ 13_3/~,,- 61~ J 2,200 2,200 sxs ~;//~ ~o~ ' 12-1/4" ~-5/8" 47~ ~ P & N 12.:OOO 1.OOO sxs ~;/I~ ,~o,' 8-1/2,, 7I, liner 29~ , N 1~]200 200 sxs ~;tl~ /~o , , , , , J, , . , , Logging Program at 12,000' and TD. BOPE: 5000 psi double Shaffer gate and Hydril. Bottom Hole Location: 180~N & 820'W from SE corner Sec. 21 TgN, R13W, S ~:~.....-~.,. * Atlantic Richfield Company, sub-operator JAi 1,5 "".. . ~ue v~l dept. Gl~e Blo~ preventer p~ram. j [] Y~S , DIRECTIONAL SURVEY REQUIRED YES ri NO ^P~ov~.- /_/__~ .~.Chairman,.. .... "' *~ Inmu~ions ~ Reve~ Side 24. I hereby certify ~oins ls~g~,~e and~orrec~ S!G1NJ~'~'~~//~~/~--~¢~'~'' DA~. January 14, 1970 (T~is space fo~ S~te office u~) ;- C ' ONS OF ~P~V~, IF A~: SAMPL~ AND CORE CHIPS H.~~ / tOTHIIR A.P.I. ~CAL CODI~ District Land Manager See Transmittal Letter A~.~OVA~ OA~ January 21, 19 70 DAT~ January 21, 1970 R 13W 1'7 ARCO NG SALMON PLATFORM K-16 K-6 ARCO MCARTHUR RIVER 13 9 K-II UNION- MARATHON ADE-17594 \ \ \ \ \ \ \ \ TMD 10,30C \ /TVD ~ Prop. T/WF \ TMDII,900' \ TVD 9680' · Prop. BH TMD 13,2.00' TVD 10,675' ATLANTICRICHFIELD ADL- 18772 JAH UNION WELL LOCATION MAP ARCO SUB-OPERATOR TRADING BAY STATE (44-21) 0 2000 SCALE ~ I "= 2ood ~Li '' - i 1 K -$0 NOV. 5, 1969 . Company Union Oil Co. of Calif. 1. Is well to be located in a defined pool ................. ~V~K Do statewide rulcs apply ...... 3. Is a registered survey plat attached 4 Is well located proper distance from property iiF~e ........... ~: ~ Is well located proper distance from other wells .......... ~:~_~ 6. Is sufficient undedicated acreage available in this pool ........ ~/~c 7. Is well to be deviated ......................... ~_~ ..... e Is operator the only affected party ................... _~-¢_,~ ......... 9. Can pemit be approved before ten-day wait ............... ~.~ _ 10. Does operator have a bond in force ................... 11, Is conductor string provided ...................... 12, ]~. enough cement used to circulate on conductor and surf~ce ~J,, ~ill cement tie in surface and intermediate or production strings t4, Will cement cover all possible productive horizons 15, Will surface casing cover all fresh water zones ........... ~ 16. Will surface csg, internal burst equal .5 psi/Ft, 1.o nex'L string .... ~ 17. Will all,casing give adequate safety in collapse and tension ...... 18~ l)o~:: i:;OPE have sufficient pre~s~'rc' ratine! ......... ~ Add1 t:i, onal Requ i 'i'~'~'~ents·
