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Home My WebLink About174-021 STATE OF ALASKA RECEIVED AL A OIL AND GAS CONSERVATION COMM ION NOV 1 REPORT OF SUNDRY WELL OPERATIONSAOGC 2017 1.Operations Abandon U Plug Perforations LI Fracture Stimulate U Pull TubingU U Operations s utdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing LI Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ElRe-enter Susp Well ❑ Other:Repair Rods-Recover/Replace PumpEl Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC lorato❑ment Develo 0 Exploratory p ry ❑ 174-021 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-133-10103-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996 Soldotna Creek Unit(SCU)12A-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 10,880 feet Plugs measured 10,588&10,697 feet true vertical 10,878 feet Junk measured ±10,586 feet 10,136; 10,583; Effective Depth measured 10,798 feet Packer measured 10,651; 10,691 feet true vertical 10,796 feet true vertical 10,134; 10,581; feet 10,649;10,689 Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.4#/L-80 8,211'MD 8,209'TVD Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#L-80&N-80 10,748'MD 10,746'TVD Baker FH/Baker FH/ 10,136'MD; 10,583'MD; 10,134'TVD;10,581'TVD; Packers and SSSV(type,measured and true vertical depth) Baker FH/Baker D;N/A 10,651'MD; 10,691'MD 10,649'TVD;10,689'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A SCANNED Jai 1 1 2018 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 140 170 Subsequent to operation: 26 171 192 125 130 14.Attachments(required per 20 PAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data Cl 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: 317-337&317-456 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerna.hilcom.com v,, Authorized Signature: Date: �'//p O/! 7 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 j/./y./7�,, 17, 711S / L-42°," 'I 4 2017 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-04 Moncla 401 50-133-10103-01 174-021 8/11/17 10/3/17 Daily Operations: 08/11/2017 - Friday Held PJSM and discussed daily ops. SITP 200psi, hooked up blow down tank to tbg and bled off to Opsi. Laid 75' x 75' containment, spotted beam and rig. Raised derrick and anchored guidelines. Split block to 2 line. PU rod handling tools. Removed horse head, BO/LD stuffing box and polish rod. MU 1' rod and stripped over rod stripping head and MU same. PU on rod string weight at 22K and seen pump stroke, PU 6K over and started jarring on rod pump. Continued jarring on pump and moved pump up hole 8' after 1.5hrs of jarring. MIRU vac truck, tried pumping down tbg with no luck. RD vac truck. MIRU Pollard pump truck and pumped 52 bbls of 130deg water down the casing-csg on vac. Made several attempts to jar pump free with no luck. Swap valves to pump down tbg. Started pumping down tbg after 1 bbl pump away tbg pressured up to 700psi. SD pump and monitored a slow leak of 50psi after 5 mins. Bled off tbg. LD rod stripper head and PU/MU polish rod and stuffing box. SD to let the hot water set over night. SDFN. 08/12/2017-Saturday Held PJSM and discussed daily activities. SITP Opsi, BO/LD stuffing box and polish rod. PU 1 1" sucker rod. Continued jarring on pump with rod string pu weight @ 20K. Pulling 10K over to jar.Jarred for 2hrs with no movement. Discussed w/engineer and decide to try a blind back at the pump. PJSM, PU on 6K over on rod string, made 6 turns to the left, held and worked torque down. Made 4 more turns to the left and held torque with pipe wrench and secured with cat line. SO rod string f/6k and caught rod string w/brake at 3k over string weight for 10 mins trying to work torque down and break bottom connection w/no luck. Check tongue on pipe wrench and only got 1 turn back. Continued trying to work torque down w/no luck. Looks like the rod pump is spinning while working torque down hole. Cont trying to free up rod string with no luck. PU/MU polish rod and stuffing box. Secured polish rod with rod clamps. SDFN. 08/13/2017 -Sunday Held PJSM. Cleared rig floor and RD, RDMO Moncla 401, built containment on the side of the 12-04 pad and parked Moncla 401. Sealed in containment. 09/21/2017-Thursday MONCLA 401 crew starts to arrive. Hold safety meeting and Permit to work. Fire equipment and back up to well. RU 401. Latch up to rod. Moncla crew secure split block to main block. Wanted to pull with main block to ensure weight is as accurate as possible. Hanging weight of block is 12k on weight indicator. Block should weight 8k. 12k was used as our tare weight. Rod string weights 22k. 50K is our weak link on rod elevators. 56k is our max pull weight indicator. Pull up to 52k 6 times rods not moving. Slack off. Add Rod to string. RIH and tap down on pump 3 times until elevators slack off. PU hold at 55k on weight indicator. Rod weight dropped to 30k. Start pulling rods and laying down first 3. Start pulling triples and rack in rig. Weight still pulling 10-15k heavy. Feel like we are dragging something up. Peak vac truck on location with 30 bbls of water and PAO77. Not able to pump down hole. Pulled 15 triples. Split blocks so we can pull faster. Continue to pull rods. Pulled 15 weight bars out, 7 weight bars remain in hole.Threads on pin end of#15 weight bar look good. Previous attempt to back off rods must have had some stored torque. When we slacked off and pulled up on string rod finished spinning off. Rod threads were not damaged. Weatherford tool hand gathering overshots and oil jars for the AM. Pollard slick line will be out in the am for a drift and tag. Location secure. • • Hilcorp Alaska,p LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-04 Moncla 401 50-133-10103-01 174-021 8/11/17 10/3/17 Qarl C►l` 4!p;!s �` ;:„,,7:311 4 09/22/2017-G Friday Hold safety meeting. Moncla 401 fired rig and prepared for Pollard SL. Pollard SL on location with .125" line. RU make up Rope socket, 10' stem, Knuckle joint, oil jars, spangs, 1.85" LIB. (all tools 1.5" OD except the LIB). RIH Tag TOF @ 9897'. POOH to surface to check LIB.Tagged up. Pop off. LIB shows perfect circular marks of a rod box end. No sand/paraffin or debris on SL tools. Rig down pollard SL. Weatherford tool hand on location. Inspect tools, sucker rod to 1" MT x over 1.95" OD. Nominal ID of 2.375" tubing is 1.995".Tool OD isn't to drift size.Tool hand sent back to shop to have machinist turn down x over to 1.85" OD.Tool hand back on location. Make up BHA as follows: 3/4" SRx 1"MT(1.85" OD), jar accelerators 1" MT box x 1" MT pin, (1.82" OD), Oil Jars 1" MT box by pin (1.82". 78"overshot). RIH with Rod fishing string. Swapped out 15 1 1/4" weight bars for 15 1" EL rods. Set down on fish 9868'. 30' higher than slick line depth. 10k string weight down.Attempt to latch series 10 overshot. PU weight bouncing all over the place. Same trend as prior run when pulling rod string.Attempts to latch.44k max pull seen on weight indicator 9k over string weight and block weight. Attempted to pull to break over weight plus 5k to watch for jars to fire. No luck seeing jars fire. I don't believe we are on fish.Attempt to rotate sucker rod assembly while slacking off weight. No luck seeing over pull. Start pulling rods. Shut down for night. 09/23/2017-Saturday Hold safety meeting. Sign Permit to work. Continue Tripping OOH with rods to check for fish.At surface with Overshot. No fish. Edges of overshot guide dinged up. Grapple has no wear marks. Never made it over fishing neck. Pollard SL en-route to Swanson.JSA and PTW with Pollard SL. RU Pollard SL. RIH with 1.84" LIB sit down weight @ 8240' RKB. Make several attempts to pass various speeds. No luck. Looks like sitting down at 2 7/8"x 2 3/8" crossover. POOH. At surface. RIH with 1.75" DD bailer. Set down @ 8240'. Make several attempts. POOH to surface. No debris in bailer. RIH with 2 3/8" GU adaptor w/GS w/2.8" bait sub w/Weatherford 1.85" series 10 overshot w/cut lip guide. Not able to pass tubing x over at 8240'. POOH. Install knuckle joint between weight bars. RIH with same. Sit down at 9890' KB. OOH weight prior to latching 700 lbs. PU to 1200 lbs. Look to be latched. PU 1350 lb jar lick,free. POOH at surface. Fished out rod collar box x box. Previous fishing attempt rig tried to back off rods. Rod collar was hanging on by 2 threads. Stripped rod collar from rod. Collar fished OOH. RIH with same. 9891' KB. Sit down. PU to 1200 lbs. Spang down 4 times to ensure overshot full engaged. PU to 1800 lbs and hit jars.Took 4 hits to shear up pin on GS. OOH with sheared GU. Left baite sub and GS Spear in hole latched to fish. OOH. Rig down SL. Baited fish left in hole. 1.85" OD x 1.84' Series 10 overshot, 1.80" OD x .6' X over, 1.85" GS box x .86'. Pollard SL unit parked on bull rail. RIH with Weatherford fishing assembly(GS spear 1.8" OD, x over 1.7" OD, X over 1.7" OD, Oil Jars 1.81" OD,jar slinger 1.81" OD, x over 1.85" OD,Total length 18.74'. RIH with rods. With 1 triple rod in derrick tie split block into full block for accurate weight. Slack off rod weight of 22k on fish. Pu to 40k. Look to be latched. RIH slack off rod weight additional 4 times to ensure overshot fully engaged. Pu to 54k on weight indicator. Block 12k, string 22k, 20K over pull. Jars fired. RIH reset jars. PU to 60k let jars fire. Repeat 3 more times. On jar lick#5 holding 60k or 26k over pull jars fired. Weight broke back to 30k. PU pulling free. Rih to slack off. Stroked pump and fluid seen at surface. PU and no over pull. Well is not on a vac.Trip OOH to inspect BHA. Weakest link on fishing BHA would be GS spear dogs. Either we broke dogs, pulled overshot off Fish, or pump and rods are coming OOH. 3 rods pulled. Secure well.SDFN. • • � Hilcorp Alaska, LLC 124, 44,4 Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-04 Moncla 401 50-133-10103-01 174-021 8/11/17 10/3/17 Daily Operations: 09/24/2017-Sunday PTW. Hold safety meeting. Fire rig. POOH from previous days fishing run.At surface, No rods attached to GS. 1.85" GS spear has missing dog. Spear lasted 5 jar licks at 26k over string weight. Dog measures 3.23" long x .5" width. No room for lost dog to get on outside of baited GS box fishing profile. More than likely fell into bottom of GS box on baited sub. Called town to discuss. Pollard en-route with another GS spear. Wait for pollard to arrive. Crews cleaning up location. Make up G spear(G wiz, Non shearable). Same fishing BHA as previous day. RIH with rods. Stack weight. Pu 10k over. Latched into GS fishing profile. PU to 40K on weight gauge. 6K over. Couldn't feel jars hit. RIH reset jars. PU to 45K. Couldn't see jars fire. RIH reset. PU to 52k.Jars fired. Good jar lick. Continue and perform 17 jar licks with up weights from 52-54K. Last jar lick weight dropped back to 25k. RIH and pick up. Not able to over pull. Well did not go on vac. Looks like we lost the ability to latch. POOH to surface. At surface. Break down Weatherford fishing BHA. Pollard SL GS spear. Left half the GS spear in hole. 6" long 1.375" OD fishing OD. SDFN. 09/28/2017 -Thursday PTW. Hold safety meeting. Pull pit liner. Spot in carrier. Rig up Moncla 401. Start pulling rods from 8,200'. Rig support spotting Moncla skids. Rods OOH. Rig up Moncla skids. Build BOPE. Flow cross, HCR valves. Total safety, wellhead tech dispatched for AM callout. 24 BOPE test witness notification sent. 09/29/2017 - Friday PTW. Hold safety meeting. Finish rigging up Moncla 401. NOS install BPV. RU hydraulic hoses. Kelly hoses, RU pressure control equipment. 7-1/16" x over to 11". 11" mud cross with manual 2-1/16" valve and 2-1/16" HCR on flow/kill line. MU 11" combi BOPE dressed with 2-3/8" to 3-1/2" flex rams and blind rams. Shoot fluid level with echo meter on IA. 645' 24 hr BOPE test witness notification sent 9/28/17 @ 15:16 hrs. Witness waived by Jim Regg 9/29/17 @ 10:35 am. Test BOPE to required pressure as per sundry 250/3,000 psi (2,500 annular). 1 FP noted. Blind rams bled down. Cycled rams and retested. BOPE test complete. Shut down rig. Bleed down IA pressure. Pressure bleed down. Pump 45 bbls of produced water down backside. Shut down pump. Check for flow. Well is on a vac. Locations secure. Pollard E-line will be on location in the AM to perform tubing punch. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-04 Moncla 401 50-133-10103-01 174-021 8/11/17 10/3/17 Daily Operations: 09/30/2017 -Saturday PTW. Hold safety meeting. Bleed down IA . RU PESI E-line unit. RIH with tubing punch. 1-3/8" rope socket, 1-11/16" weight bars 5' x 2, 1-9/16" firing head and tubing punch. BHA length 16.5'. Tagged at 2-7/8" x 2.375" x over @ 8,218' . Made multiple attempts to enter 2.375" tubing. No luck. POOH to surface. Remove 1 x 5' 1-11/16" weight bar. RIH. Not able to pass x over at 8,218'. BHA length 11.5'. RIH. Stack weight not able to pass x over at 8,218' RKB. POOH to surface, @ surface install knuckle joint between 1 x 5' weight bar and firing head. 12.5' BHA length. State Rep Brian Bixby on site for rig inspection. RIH. Not able to pass x over at 8,218'. Multiple attempts. No luck. Called town. Permission to shoot above x over. Log strip to ensure not shooting on collar. 8,218' pop holes in tubing. IA started blowing air. Looks like we have communication. POOH to surface. Rig back E-line and PESI standby to punch 2.375" tubing once all the 2-7/8" is pulled. State Rep off location . RU 2.375"joint to lift hanger. Pick out of wellhead bowl. Rotate pipe and slack off through hanger. Weight should read 62K. (Tubing was set with 17K tension from tubing anchor to surface hanger.) Slacked off and weight was 43K. Good indication tubing anchor has failed. Rig up 1502 on TIW valve and pump 10 bbls of produced water to clean oil from inside tubing string.Trip 2-7/8" tubing OOH. Rack back in derrick. Pulling doubles. Pulled 131 doubles and 1 single (9,920') . At the 2.375" tubing. Lay down one 2.375" tubing. Tubing below x over had tubing punch holes in it. Secure tubing in BOPE. Install TIW valve. RIH with tubing punch, set down on top of fish inside 2.375" @ 1,611'. Log strip to ensure we are not punching on collar. Tagged 1,611'. Shot tubing punch. Tubing on vacuum. POOH with E-line. At surface. Secure well. Install TIW valves. Manually lock BOPE rams. Location secure. Crews off location. SDFN. 10/01/2017-Sunday Hold safety meeting. PTW. Pump 10 bbls down tubing and 10 down IA. Start pulling 2.375" tubing OOH. All pipe OOH. Break down mud joints. Pump stuck inside tubing joint. Packed off with sand. Pollard GS spear, Weatherford series 10 overshot recovered from wellbore. RIG up Pollard SL. with 4" drift/Junk basket. RIH. No issues drifting liner. Tagged top of packer at 10,200' SLMD. POOH to surface. At surface. Metal bank, stainless steel in junk basket. Rig down Pollard. RIH with completion. 125 stands of tubing ran. Lock down BOPE. SDFN. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-04 Moncla 401 50-133-10103-01 174-021 8/11/17 10/3/17 Daily Operations: 10/02/2017- Monday Permit to work. Safety meeting. Discuss job scope with crews. RIH with remaining stands of 2-7/8" tubing. Ran new tubing anchor. RIH WT 52K. PU WT 54K. Marked 42" on pipe. Calculated stretch to obtain 17K for tension in hanger. Set tubing anchor. PU land in surface hanger. 42" gave us 14K over pull or stretch when landed. Pollard SL on location. Hold safety meeting. Discuss plan forward. RU Pollard slick line with circulation valve/ pack off plug. RIH with tubing scratcher for the 2.375" completion. No issues getting to bottom. Make two trips from 2.375" to bottom. POOH to surface. RIH with pack off plug to test tubing completion. Tag @ 10,070' RKB. Spang down on pack off plug to set. Fill tubing and pressure up to 1,500 psi. Pressure not holding. Repeat pressure test 3 times. No luck holding 1,500 psi. Lost 10-20 psi per second. Bleed pressure down . Attempt to spang down on plug to obtain a better set. Pressure up to 1,500 psi. Leaking faster. Good indication leak is at the plug. Attempt to pull plug out. Pollard trying to equalize plug. POOH . At surface. No plug recovered. RIH with different JDC overshot. Latched up. Pull plug from 10,070' and dragged it to 9,870' and POOH. Looks like we lost plug and sheared release pins. At surface. No plug attached. Re-pin and run IH with JDC. Latched up and attempt to pull plug OOH. Plug at surface. Secure TIW valve and shut down location. Location secure. SDFN. 10/03/2017-Tuesday PTW. Hold safety meeting. Set BPV. Rig down 11" BOPE stack. Make up rod completion wellhead. Pressure test seals . RU rig floor and rod equipment. Pu new pump. Test at surface. RIH with rod completion. Set pump and space out 30" off bottom of pump. Install Lufkin polished rod in bridle. Secure location. SDFN. • • • Soldotna Creek Unit Well SCU 12A-04 II ACTUAL SCHEMATIC PTD p174 021 letion n:3/10/14 Flacon.4iUa4,.LLC API: 50-133-10103-00 CASING DETAIL RKB= 14.83' Size Wt Grade Conn ID Top Btm A 22" 29' 1 13 3/8" 54.5# J-55 - 12.615" Surface 2,024' "° 7" 29# N-80 6.184" Surface 324' ( 7" 26# N-80 6.276" 324' 1,087' 6 ' 22 7" 23# N-80 6.366" 1,087' 4,857' 7" 26# N-80 6.276" 4,857' 6,704' 7" 29# P-110 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' 13-3/8" TUBING DETAIL 2 Fair Cmt 2-7/8" 6.4# L-80 TC-II 2.441" Surface 8,211' 2-3/8" 4.6# L-80 TC-II 1.995" 8,211' 9,979' - Good Cmt 2 3/8" 4.6# N-80 IBT 1.995" 10,520' 10,748' 3 JEWELRY DETAIL '. 4 C - 7„ No. Depth ID OD Item 1 18' - - Tubing Hanger,Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp D 2 4,011' 2.441" 5.000" 2-7/8"Depth Indicator Sub e 5 -- 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8"Crossover 4 8,397' 4.151" 5.000" Simplex Liner Hanger(Burns) E5 9,981' 1.930" 4.000" Tubing Anchor(New 9/30/17;Shear set to 35K) X41 6 10,056' 1.785" 2.375" Seating Nipple ty i 7 10,057' 1.995" 2.375" Slotted Flow Sub v 6 8 10,061' 1.995" 2.375" 2 joints 2-3/8"tubing,EUE 8RD(Gas Anchor) 7 9 10,126' - 2.500" Bull Plug F I 10 10,136' 1.991" - Packer,Permanent,Baker Mod."D"2-7/8" 8 11 10,188' 1.875" 2.70" HES'X'Nipple G 9 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint,Brown"CC",Bottom half/Pin up 14 10,583' - - Packer,Retrievable,Baker Mod."FH"5"x2-3/8" 10 X F<'„ 15 10,588' 1.875" - "S"Nipple,(Position No.2)w/PS plug installed(11-15-87) 11 x 16 10,647' 2.0" 3.094" Safety Joint,Brown"CC" 12 .--a 17 10,648' 1.875" - Otis"XA"Sliding Sleeve G2 18 10,651' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" H 1 19 10,657' 2.0" 3.094" Safety Joint,Brown"CC" 20 10,691' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" H2 21 10,697' 1.791" - "N"Nipple,w/PN plug installed(11-12-87) = H3 22 10,748' 1.995" - WLEG 13 — = UH8 ..- ROD DETAIL Tubing Pen # *= MH8 No. Depth Length OD Item 10,570'-10,575' A 4' 26' 1-1/2" Polished Rod,15'in well 14 B 30' 16' 1" 1"x 6',2'EL Pony Rods 15 S LH8 46' 2,575' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) 2,621' 3,500' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) 16 _ H9 6,121' 3,350' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(Used) C 9,471' 550' 1-1/4" 1-1/4"x 25'K Bars(weight bars) 17 %A D 10,021' 2.5' 1" 2"x 30"Stabilizer Bar w/%"Pins 18 E 10,023' 25' 1-1/2" 1-1/2"x 25'Insert Pump,RHBC Pump w/PA Ring 19 80 PA Ring,Sand Seal,2"x 1-1/2"x 24"x 24-1/2"x 25' RHBC Possible leak . UH10 F 10,048' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom 10,655'-10,675' G 10,052' 1.0' 1.250" Welded coupling to bull plug—No Gauges 20 �rr X N/�fl Tubing Perf 21 10,735'-10,745' l LH10 22 5„ TD=10880'•ETD=10,798' MAX HOLE ANGLE=14deg Downhole Revised: 11-03-17 Updated by DMA 11-03-17 • • Soldotna Creek Unit Well SCU 12A-04 ACTUAL SCHEMATIC Connp174021letion an:3/10/14 PTD Nilson)Alaska.LLC API: 50-133-10103-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8"Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8"Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8",HC,0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8",HC,60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8",HC,60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8"Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Revised: 11-03-17 Updated by DMA 11-03-17 • • ti` o i) In 12 a a a a a a a Cl. a a a a a a Cl- a a a a a • `c-) r> v °? 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C L a) co 0 C 0 a) L cn C u. o m mC m C'° o Z I� > N p 0 E O , O O w a) u- m > 0 �' - 1- m 12 N �I O 0 a m 2 O cLa .-Cr) 0 > ? m W a) o aCi 0 E rn 0 Cm m 2 cca ,_as� a) 3J w Q a caj) C a) ` 0 cNa a) >�, o J N > T u ° d o o = Q E of a) Wa) (1 ,/� m � Q LL } C E CO M O — C a L 0 C a) v, L L U N a a) o O o r- o U Q C9 N N voi Y a) C L m N m aoi 0 .c r Z ii = a) m 5 (XO V) cL° a a) Z m O U) 0 MS ai') • N Q I- w ; E a) cam E Y a) �- >, L a) L C L Q LL 3 "O O) Q cn L o v) Q O cn -p ,� L J O .2' o a) u) - O 7 a) a) m CO C a) 'C N O 'C ca >,= o 0 p 0E0 a EL_ 2aco0 ¢ 0QI- _YLi0 0 = Y ma Y C c) a) SD- L U) v/ m Q 1 O U O N CO a) LO O �, L L ¢ o- C m aaa0aa faaaaa00Z0- as as E Q 0 E cocti a) co Nr o ••c o o L 0) Y 0 U fn V ca a) a)N > Z m a)OmmQ , c) < LI U) -I 0)wCro Q. u) C o1-- C0 N = w CO (/)a 2 2 1 co 5 O co m .r a a) 0 a) a — L co cn v co o 0 = F- O)a cn H co U 0 . ra il' a) N N o C a) H a) > -0 o a) O .Q T2 Et w LU Z Z Q C O O 0) 0) m C — a) a) m _ (A Q— O Y O -J 2 o a C C ca rrLY C Y a) C a) > l rn g Z o o a) U Q 0 — a Y Y c 0 -o Y 0 Yo J rnw C C = 3 c w Si) U- 0 rn rn Q a) Q o o C Q.5 0 - s — a3 U m �a o o a a) 0 a) Eb o SO � � ¢ dm � cnUYF- = 2L� 0it0 a � •mpg 7 • • "\\\I%%y.,, THE STATE Alaska Oil and Gas �� ALA sKA Conservati®n Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson WI Q 2Q1� Operations Manager �� Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 12A-04 Permit to Drill Number: 174-021 Sundry Number: 317-456 Dear Mr. Helgeson: 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, Hollis S. French Chair DATED this 2-1 day of September, 2017. RBDMS LL UL i" - 3 2017 • • • RECEIVED STATE OF ALASKA SEP 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate El Repair Well 0 Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill El Perforate New Pool El Re-enter Susp Well El Alter Casing El Other. Recover/Replace Rod Pump(Z 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory El Development 0. 174-021 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-133-10103-01 • 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes El No El Soldotna Creek Unit(SCU)12A-04 • 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 • Swanson River Field/Hemlock Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,880 ,, 10,878 ' 10,798 10,796 0 psi 10,126, 10,588&10,697 ±10,586 Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,284-10,581 10,283-10,580 2-7/8"&2-3/8" 6.4#L-80/4.6#L-80&N-80 8,211&10,748 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packers(x4)See Schematic&SSSV:N/A Packers(x4)See Schematic&SSSV:N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch 0 Exploratory El Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/29/2017 OIL 0 . WINJ El WDSPL ❑ Suspended El 16.Verbal Approval: Date: el/2.51/7 GAS ❑ WAG El GSTOR 1:1 SPLUG El Representative: C'```► S h ,.,,r ti.._ GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing 4 true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramernhilcorp.com Contact Phone: 777-8420 Authorized Signature: ea/fi % f.ci Date: "051V COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 I 7-4/5(o Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other. X- 3000r . (2,:-..;r ' r-;f- ( Z 3 0c) p; 4,,,,,v,„) Post Initial Injection MIT Req'd? Yes ❑ No ❑ l3 7 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / r 0� RBDMS t L UI,,I _ 3 Lu i ' APPROVED BY Approved by: 0 -- COMMISSIONER THE COMMISSION Date: r ?$ I i1 Sy.,("ON(Ci '4 ?-21-17 .,-;.: 47 14'7 ,,,.&:: , ...._ Submit Form and Form 10-403 Revised 4/2017 a li a i or 12 months from the date of approval. Attachments in Duplicate in • • Well Prognosis Well: SCU 12A-04 Hilcorp Alaska,LL Date:9/25/2017 Well Name: SCU 12A-04 API Number: 50-133-10103-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: September 29th, 2017 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 174-021 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907)777-8354 (0) (907)903-0341 (C) AFE Number: 1752669 Current Bottom Hole Pressure: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD) Maximum Expected BHP: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of -''----, 10,500' MD) Max.Allowable Surface Pressure: 500 pi Surface pressure when testing tubing and rods (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft)will balance reservoir pressure at 7,175 ft. TVD Brief Well Summary Soldotna Creek 12A-04 was drilled as a sidetrack of SCU 12-04 in 1974 due to parted tubing and bad casing in the original wellbore. In 1975 the completion was pulled to re-perforate the original Hemlock perforations in the Hemlock H-8, H-9, and H-10 benches. Thru-tubing perfs were added in 1988 to access zones isolated between packers.A 1995 workover changed the upper part of the completion and perforated the Tyonek G2 zone.Thru-tubing perfs were added in 1998 that added the Hemlock H-1, H-2, and H-3 benches. A 2009 workover pulled the tubing due to an obstruction in the tubing and perforations were added to the H4/H5,the Tyonek G2 was re-perforated, and a new completion was ran into the well. The well was converted to rod pump in July 2013. The tubing anchor was reset in March 2014. Parted rods were repaired in early May 2014 and April 2015. In July 2017 the rod pump fouled and an attempt to pull the rods in September to change the pump found the pump to be stuck in the hole. Rods were unthreaded to 9,845'. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump. • Pump is stuck in the well. Rods removed down to 9,845'. `�/ • Wellbore maximum deviation below sidetrack is less than 14 degrees. OBJECTIVE OF WORKOVER Pull tubing and recover stuck rod pump. Run tubing, replacement pump and rods back in the well. • WO Rig Procedure-continue from Sundry#317-337: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. MIRU Moncla #401 WO Rig. 3. Set BPV. • • Well Prognosis Well: SCU 12A-04 Hilcorp Alaska,LLt Date:9/25/2017 4. NU BOPE and test to 250psi low/3.QQQp,si high (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24hrs in advance to witness, be ready to test when/if inspector arrives. b. Using 11" BOPE. 5. RIH with Slick line and punch tubing @ 9,845' (+/-)to avoid pulling a wet string. 6. Pull tubing hanger free, unseat tubing anchor and POOH w/tubing. 7. Rack back tubing string (2-7/8"TC-IIx 2-3/8"TC-II). a. Inspect tubing for holes/worn joints. b. Inspect tubing anchor for damage/wear. 8. If tubing anchor is damaged, PU new tubing anchor. 9. RIH existing 2-7/8"TC-IIx 2-3/8"TC-II L-80 tubing. a. Set depth indicator sub at same depth, approx.4,000'. 10. Set tubing anchor and land existing Seaboard tubing hanger. 11. Set TWC, ND BOPE, NU tree and test. Pull TWC. 12. NU Rod stripper. 13. PU new 1-1/2" rod pump, RIH with existing 1-1/4" sinker bars and existing tapered EL rod string (3/4", 7/8" and 1"), space out the rods, install polish rod. 14. ND rod stripper, install surface equipment onto well and test to 500 psi. 15. Rig up Lufkin pumping unit head and connect bridle to polished rod. 16. RD Moncla#401. 17. Return to production with same surface safety system as previously installed. 18. Replace IA x OA pressure gauge if removed (7" x 13-3/8"). Attachments: 1. Schematic—Current/Proposed (Same) 2. Well Head Diagram—Current/Proposed (Same) 3. BOPE Diagram 4. Rig Flow/Circulating Diagram 5. RWO Change Form Soldotna Creek Unit Well SCU 12A-04 • iii ACTUAL SCHEMATIC PTD:p174021Ran:3/10/14 Hilcoro Alaska.LLC API: 50-133-10103-00 RCASING DETAIL KB= 14.83' Size Wt Grade Conn ID Top Btm A 1 22" - - - 29' 13-3/8" 54.5# J-55 - 12.615" Surface 2,024' 7" 29# N-80 - 6.184" Surface 324' 7" 26# N-80 - 6.276" 324' 1,087' B 22" 7" 23# N-80 - 6.366" 1,087' 4,857' r; 7" 26# N-80 - 6.276" 4,857' 6,704' 7" 29# P-110 - 6.184" 6,704' 8,597' -- 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' 13-3/8" TUBING DETAIL 2 Fair Cmt 2-7/8" 6.4# L-80 TC-II 2.441" Surface 8,211' .,AV 2-3/8" 4.6# L-80 TC II 1.995" 8,211' 9,979' /� NJ1 Good Cmt 2-3/8" 4.6# N-80 IBT 1.995" 10,520' 10,748' P C 4 JEWELRY DETAIL No. Depth ID OD Item '� 7 1 18' - - Tubing Hanger,Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp D 4 061 2 4,011' 2.441" 5.000" 2-7/8"Depth Indicator Sub SUSPECTED ROD 7A�- '..,t 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8"Crossover PART NEAR PUMP �✓` 4 8,397' 4.151" 5.000" Simplex Liner Hanger(Burns) E 1 5 9,981' 1.930" 4.000" Tubing Anchor(New 3/11/14;Shear set to 35k) 1...'l 6 10,056' 1.785" 2.375" Seating Nipple 7 10,057' 1.995" 2.375" Slotted Flow Sub 6 8 10,061' 1.995" 2.375" 2 joints 2-3/8"tubing,EUE 8RD(Gas Anchor) L. 7 9 10,126' - 2.500" Bull Plug F �, 10 10,136' 1.991" - Packer,Permanent,Baker Mod."D"2-7/8" El 8 11 10,188' 1.875" 2.70" HES'X'Nipple G 9 ' 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint,Brown"CC",Bottom half/Pin up . r 14 10,583' - - Packer,Retrievable,Baker Mod."FH"5"x2-3/8" 10 ►.1 15 10,588' 1.875" - "S"Nipple,(Position No.2)w/PS plug installed(11-15-87) 11 16 10,647' 2.0" 3.094" Safety Joint,Brown"CC" 12 F..' 17 10,648' 1.875" - Otis"XA"Sliding Sleeve , G2 18 10,651' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" 19 10,657' 2.0" 3.094" Safety Joint,Brown"CC" ::r 2H 1 20 10,691' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" V H2 21 10,697' 1.791" - "N"Nipple,w/PN plug installed(11-12-87) 47 H3 22 10,748' 1.995" - WLEG 13 — F 477, UH8 ROD DETAIL Tubing Perf r) MH8 No. Depth Length OD Item 10,570'-10,575' 0' *# A 4' 26' 1-1/2" Polished Rod,15'in well 14 x I>< B 30' 16' 1" 1"x 6',2'EL Pony Rods 15 S ,` 46' 2,575' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) LH8 2,621' 3,500' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) 16 6,121' 3,350' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(Used) H9 C 9,471' 550' 1-1/4" 1-1/4"x 25'K Bars(weight bars) 17XA D 10,021' 2.5' 1" 2"x 30"Stabilizer Bar w/%"Pins 18 E 10,023' 25' 1-1/2" 1-1/2"x 25'Insert Pump,RHBC Pump w/PA Ring 19 80 PA Ring,Sand Seal,2"x 1-1/2"x 24"x 24-1/2"x 25' < RHBC Possible leak . UH 10 F 10,048' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom 10,655'-10,675' • G 10,052' 1.0' 1.250" Welded coupling bull plug g to p g—No Gauges 20 X IX..' N r Tubing Perf 21 o. t} ,;';-,, 10,735'-10,745' LH10 22 L I,,, 5„ TD=10,880';ETD=10,798' MAX HOLE ANGLE=14deg Downhole Revised:7/21/17 Updated by CAH 07-21-17 . WSoldotna Creek Unit ell SCU 12A-04 . m ACTUAL SCHEMATICCompletion 174-021 Hamra PTD Hilcora Alaska.LLC API: 50-133-10103-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8"Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8"Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8",HC,0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8",HC,60 deg. 12/11/1998 H3 10,451'. 10,459' 10,450' 10,458' 8' 6 2-1/8",HC,60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8"Millineum TCP 8/17/2009 UI-18 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Revised:7/21/17 Updated by CAH 07-21-17 0 • , El[ Swanson River SCU 12A-04 Ifilrorp tla•ka,LIA. 05/29/2013 Swanson River Tubing hanger,Seaboard, SCU12A-04 ECO tension,7 1/16 5M X 2 133/8X7X27/8 7/8EUElift and susp,w/2% type H BPV,3/8 control line, 5"slickneck,left to release, right to engage Full stainless steel for chemical injection Special Cross,2 9/16 5M FE X 2 7/8 EUE 8rd w/2-2 1/16 5M SSO , Valve,wing,WKM-M,2 1/16 o j. o !b- 5M FE,HWO,DD trim O. 0 a 24.00" rn T-r en crc Adapter,Seaboard,7 1/16 5M FE X 2 9/16 5M w/5"PP seal pocket,%control line Grade Level 1) exit,alloy material 11.1) Tubing head,Seaboard S-8, 13 5/8 3M X 7 1/16 5M,w/ . ,1,5, .`"1 i,, 2-2 1/16 5M SSO,BG bottom O ° nil : prep / �� .f�; ; t - _ , _ flip_ ii2 ill ' : ----4r a Casing head, Shaffer KD, 135/83MX 133/8 SOW, III I-1 w/2-2" LPO, 7" KD slips o/- , I 1 ''„ Valve,WKM-M 2"LPO and packoff assy in head ooJo f 6 • HILCORP ALASKA 11" 5M BOPE 11" 5M HYDRIL GK ANNULAR 47-7/8"TALL, FLANGE TO FLANGE 11" 5M CAMERON TYPE U DOUBLE GATE BOP pot DRESSED W/VARIABLE RAMS IN TOP ° DRESSED W/BLIND RAMS IN BOTTOM ' lib 54-1/2"TALL, FLANGE TO FLANGE 11" 5M DRILLING SPOOL ® W/2-1/16" &4-1/16"5M OUTLETS jaift R' 24"TALL, FLANGE TO FLANGE ' 127"TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: -8.08 gallon open chamber volume -9.81 gallon close chamber volume GATE STYLE BOP SPECS: -3.4 gallons to open per gate -3.5 gallons to close per gate -7.3:1 closing ratio -2.5:1 opening ratio • 0 (2 ® Z§§ , § $ -I k o z o § q § « z \ ,. k § #� g t § )§ , � ^ � r- °o ., — 0 | j | ii \k .. 2 ) ; S § (\ ) `� C` tilr � iiiiiitio/ 1 § _ i�0.1a��»■ � \~ V' :f 9,1 P. ~ I-- )---+ , �kk \ P ----i< )§ • C • n0 / 2 A 0 / 7Cn ? • \ a) CD 0 / Q -. q 5 E = o ® 0 CD i ■ O = % * = R g g co R . = 0 � - a) - / / q co P E C 7 D 11, \ § * o "0 CD 0 2n) D m "0 % f = 0 CD x§ \ M m / O / a ■ _ - --i; \ § C. CD 0. 2 -oA) Q CD 0 cD (0 a 0 a ¥ ) / � 2 _ > n f ■ Q / C CO CO / m / / ƒ Cl) n // .13 - / a 6 0 _ CD cp \ 0 Q. O CD C / CDZ $3 % �22 qE a) 2I & DO « « % w f' q / / C _ / 8 /�� / k F co » / CDa • D $ % K = = Ee k 7 2 7 ro ■ ao 2 2 ] D 0 § 220 7R �cu //kA) — n o am * 2 o.Q _) & ° a) z $ - a. • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, September 28, 2017 2:54 PM To: Ted Kramer Cc: Donna Ambruz;Juanita Lovett Subject: RE: SCU 12A-04 AOGCC 10-403 Submitted 2017-09-25.pdf PTD 174-021, Sundry# 317-337 (to pull Rods and change pump) Ted, You have verbal approval to proceed with RWO to pull the tubing(using BOPE) and rod pump as outlined in the sundry application (new sundry#317-456) that you attached. Post this email on site with Rig 401 to document the approval... BOPE test pressure is 3000 psi (annular at 2500 psi). '/� �}_ Regards, c Guy Schwartz Sr. Petroleum Engineer /-1,r1-1 1 AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Ted Kramer[mailto:tkramer@hilcorp.com] Sent:Tuesday,September 26,2017 7:27 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Donna Ambruz<dambruz@hilcorp.com>;Juanita Lovett<jlovett@hilcorp.com> Subject:SCU 12A-04 AOGCC 10-403 Submitted 2017-09-25.pdf PTD 174-021,Sundry#317-337(to pull Rods and change pump) Guy, Attached is a Sundry application to pull the tubing on the SCU 12A-04. This Sundry was sent over Yesterday afternoon. Hilcorp is asking for an expedited approval on this Sundry in order to complete this work before the rig crew leaves the field. Ideally,we would like to be back on this well by this Friday. The SCU 12A-04 was rigged up on in Sundry#317-337 to change a fouled pump. In the course of attempting to unseat the pump the rods backed off. An overshot tool used to capture the rods failed while latched onto the rods and there is not room to get over the tool. Therefore the only option to recover the pump is to pull the tubing. This Sundry application is for pulling the tubing, recovering/replacing the pump and running the completion back as is. This is a no flow well. No perforations are to be added. Simple pull and run. Any help you can provide to get back on this well before the crews leave would be appreciated. 1 • Sincerely, Ted Kramer Sr.Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 2 . OF r • • g ‘, 11 ��sA THE STATE Alaska Oil and Gas Of/\ /�1ZS Conservation Commission 1`1 333 West Seventh Avenue I. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson SCANNED AUG 1 >' 2017 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Soldotna Creek Unit, Hemlock Oil Pool, SCU 12A-04 Permit to Drill Number: 174-021 Sundry Number: 317-337 Dear Mr. Helgeson: 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, daik Hollis S. French c l- Chair DATED this 1 day of August, 2017. RBDMS (,'.-AUG - 9 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION it J( 2 1 2017 APPLICATION FOR SUNDRY APPROVALS Dc" 4)"!,i 20 AAC 25.280 G Cd" 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well D• Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Repair Rods Q • 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q• 174-021 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage Alaska 99503 50-133-10103-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Soldotna Creek Unit(SCU)12A-04, 9. Property Designation(Lease Number): 10. Field/Pool(s): FEDA028996 • Swanson River/Hemlock Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,880' • 10,878' • 10,798' 10,796' 500 psi 10,588'&10,697' ±10,586' Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130P si Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340P si Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 2-7/8" Tubing Grade:6.4#/L-80, Tubing MD(ft): 8,211' See Attached Schematic See Attached Schematic 2-3/8" 4.6#/L-80&N-80 10,748' Packers and SSSV Type: Baker FH/ Packers and SSSV MD(ft)and TVD(ft): 10,136'MD/10,134'TVD; Baker FH/Baker FH/Baker D;N/A 10,583'MD/10,581'TVD; 10,651'MD/10,649'TVD; 10,691'MD/10,689'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 0 Stratigraphic ❑ Development Q Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: August 4,2017 OIL Q • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramert hilcora.com � ' Contact Phone: 777-8420 Authorized Signature: if.:/-.1"1,17 : .1 �!✓� Date: 7/z i)(7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1?- 33'7 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 1:1No 0 RBDMS Lv__gUG - 9 2017 Spacing Exception Required? Yes 0 No d Subsequent Form Required: j © - Li 01 I APPROVED BY �` Approved by: COMMISSIONER THE COMMISSION Date: J '' I( q \� RAIFGeI < ^6,V, 'Form 10-403 Revised 4/2017 O 4cArJivalid for 12 months m the date of approval. Attachments in Dplicate 7<2.'f./•-2, • Well Prognosis Well: SCU 12A-04 Hiicorp Alaska,LL: Date:7/21/17 Well Name: SCU 12A-04 API Number: 50-133-10103-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: 8/4/17 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 174-021 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354(0) (907) 903-0341 (M) AFE Number: Current Bottom Hole Pressure: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD) Maximum Expected BHP: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD Max Predicted Surface Pressure: — 500 psi (Pressure from pressure testing pump and rods to 500 psi.) Brief Well Summary Soldotna Creek 12A-04 was drilled as a sidetrack of SCU 12-04 in 1974 due to parted tubing and bad casing in the original wellbore. In 1975 the completion was pulled to re-perforate the original Hemlock perforations in the Hemlock H-8, H-9, and H-10 benches.Thru-tubing perfs were added in 1988 to access zones isolated between packers. A 1995 workover changed the upper part of the completion and perforated the Tyonek G2 zone.Thru-tubing perfs were added in 1998 that added the Hemlock H-1, H-2, and H-3 benches.A 2009 workover pulled the tubing due to an obstruction in the tubing and perforations were added to the H4/H5,the Tyonek G2 was re-perforated, and a new completion was ran into the well.The well was converted to rod pump in July 2013.The tubing anchor was reset in March 2014. Parted rods were repaired in early May 2014 and April 2015. In July 2017 a rod appears to be broken. The purpose of this work/sundry is to repair parted rods for this Lufkin Rod Pump well. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect rods parted). • Wellbore maximum deviation below sidetrack is less than 14 degrees. Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer) on casing. 2. MIRU Moncla #401 WO Rig.✓ 3. Rig down Lufkin pumping unit head. Nipple up rod stripper head. 4. LD polish rod and pull EL rods. Rack back the rods in basket. 5. PU overshot. 6. RIH and fish out remainng rod string and pump. LD pump. 7. LD and inspect pump and dip tube. 8. PU existing dip tube and new 1-1/2" rod pump, replace and RIH with existing tapered rod string (sinker bars, 3/4", 7/8" and 1), space out the rods, install polish rod. 9. Space out the rods, install existing polish rod. 10. ND rod stripper, install surface equipment onto well and test to 1,500 psi. • • Well Prognosis Well: SCU 12A-04 IIilcorp Alaska,LL. Date:7/21/17 11. Rig up Lufkin pumping unit head and connect bridle to polished rod. 12. RD Moncla#401 WO Rig. 13. Return to production with same surface safety system as previously installed. Attachments: 1. Actual Schematic • Soldotna Creek Unit . H 0 • Well SCU 12A-04 ACTUAL SCHEMATIC PTD p174-021 letion n:3/10/14 Hikers Alaska.LiA. API: 50-133-10103-00 RCASING DETAIL KB= 14.83' Size Wt Grade Conn ID Top Btm 1S ; A s 1 22" - - - 29' 13-3/8" 54.5# J-55 - 12.615" Surface 2,024' 7" 29# N-80 - 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' B 22 7" 23# N-80 - 6.366" 1,087' 4,857' 7" 26# N-80 - 6.276" 4,857' 6,704' 7" 29# P-110 - 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' 13-3/8" TUBING DETAIL 2 Fair Cmt 2-7/8" 6.4# L-80 TC-II 2.441" Surface 8,211' 2-3/8" 4.6# L-80 TC-II 1.995" 8,211' 9,979' Good Cmt 2-3/8" 4.6# N-80 IBT 1.995" 10,520' 10,748' 3 JEWELRY DETAIL 4 C . .. 7„ No. Depth ID OD Item 1 18' Tubing Hanger,Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp D * 2 4,011' 2.441" 5.000" 2-7/8"Depth Indicator Sub 1.995" 2.875" 5 3 8,211' 2-7/8"x2-3/8"Crossover SUSPECTED ROD PART NEAR PUMP4 8,397' 4.151" 5.000" Simplex Liner Hanger(Burns) E III 5 9,981' 1.930" 4.000" Tubing Anchor(New 3/11/14;Shear set to 35k) 6 10,056' 1.785" 2.375" Seating Nipple 7 10,057' 1.995" 2.375" Slotted Flow Sub 6 8 10,061' 1.995" 2.375" 2 joints 2-3/8"tubing,EUE 8RD(Gas Anchor) 7 9 10,126' - 2.500" Bull Plug F 10 10,136' 1.991" - Packer,Permanent,Baker Mod."D"2-7/8" 8 11 10,188' 1.875" 2.70" HES'X'Nipple d G 9 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint,Brown"CC",Bottom half/Pin up . 14 10,583' - - Packer,Retrievable,Baker Mod."FH"5"x2-3/8" 10 ',►� , 15 10,588' 1.875" - "S"Nipple,(Position No.2)w/PS plug installed(11-15-87) 11 x _i 16 10,647' 2.0" 3.094" Safety Joint,Brown"CC" 12 r—‘ ' 17 10,648' 1.875" - Otis"XA"Sliding Sleeve ^)= G2 18 10,651' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" H1 19 10,657' 2.0" 3.094" Safety Joint,Brown"CC" 20 10,691' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" H2 21 10,697' 1.791" - "N"Nipple,w/PN plug installed(11-12-87) 22 10,748' 1.995" - WLEG H3 13 UH8 ROD DETAIL Tubing Perf _. MH8 No. Depth Length OD Item 10,570'40,575' A 4' 26' 1-1/2" Polished Rod,15'in well 14 v B 30' 16' 1" 1"x 6',2'EL Pony Rods 15 s 46' 2,575' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New5/28/14) Ti---- LH8 2,621' 3,500' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) 16 H9 6,121' 3,350' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(used) C 9,471' 550' 1-1/4" 1-1/4"x 25'K Bars(weight bars) 17 XAD 10,021' 2.5' 1" 2"x 30"Stabilizer Bar w/%"Pins 18 4i E 10,023' 25' 1-1/2" 1-1/2"x 25'Insert Pump,RHBC Pump w/PA Ring 19 �� "` • 80 PA Ring,Sand Seal,2"x 1-1/2"x 24"x 24-1/2"x 25' RHBC Possible leak —_► UH10 F 10,048' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom 10,655'40,675' G 10,052' 1.0' 1.250" Welded coupling to bull plug—No Gauges 20 X ' Tubing Perf 21 10,735'-10,745' LH 10 22 5" TD=10,880';ETD=10,798' MAX HOLE ANGLE=14deg Downhole Revised:7/21/17 Updated by CAH 07-21-17 Soldotna Creek Unit .. H H . ` Well SCU 12A-04 ACTUAL SCHEMATIC pRan:3/10/14 PTD174021 Hileora Alaska.LLC API: 50-133-10103-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8"Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8"Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8",HC,0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8",HC,60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8",HC,60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8"Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UI-110 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Revised:7/21/17 Updated by CAH 07-21-17 STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COM, SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate LI Pull Tubing U Operations shutdown U I Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑, Re-enter Susp Well ❑ Other: Rod Pump Repair❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 174-021 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10103-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996 Soldotna Creek Unit(SCU)12A-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 10,880 feet Plugs measured 10,588&10,697 f E .°V£D true vertical 10,878 feet Junk measured ±10,586 feet 10,136; 10,583; ,IU L 0 S 2015 Effective Depth measured 10,798 feet Packer measured 10,651; 10,691 feet true vertical 10,796 feet true vertical 10,134; 10,581; feet , OGCC 10,649; 10,689 Casing Length Size MD ND Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.4#/L-80 8,211'MD 8,209'ND Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#L-80&N-80 10,748'MD 10,746'ND Baker FH/Baker FH/ 10,136'MD; 10,583'MD; 10,134'TVD;10,581'TVD, Packers and SSSV(type,measured and true vertical depth) Baker FH/Baker D;N/A 10,651'MD; 10,691'MD 10,649'TVD;10,689'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A SCANNED ,!()L , A %ijjc 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 145 160 Subsequent to operation: 51 14 218 145 150 14.Attachments(required per 20 AAc 25 070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exemp: 315-285 Contact Joe Kaiser Email jkaiserc. hilcoro.com Printed Name J e Kaiser Title Operations Engineer Signature ---...-..---7( - Phone 907-777-8897 Date 7Ni 5- RBDMS JUL - 9 1015 orm 1004 Revis 5/2015 i_., 7 3 Submi o•ginal Only 7A3//c" Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 12A-04 50-133-10103-01 174-021 6/17/15 6/18/15 Daily Operations: 06/17/2015-Wednesday Hold safety meeting with MONCLA. Discuss job procedures and safety hazards. Review well prognosis as per Sundry 315-285. Confirmed tubing bleed down. No pressure on tubing. Remove Lukfin Horse head lay down. RU Moncla rig. Latched up to polish rod. Pick up to 32K. Pick pump off seat. 35K to remove pump from seat. Normal OOH weight 18K. Check tubing pressure. Pull and lay down polished rod with stuffing box attached. Continue to pull rods OOH. Lay down weight bar. Pump confirmed at surface. Unscrew pump from dip tube. Perform function test of pump by compressing pump piston. Pump compressed and no fluid noticed. Lay down pump. Inspect dip tube. TIW valve installed on tree. All valves confirmed closed. Wel!site secure. Crews off location. 06/18/2015 -Thursday Hold safety meeting and discuss job procedures. Open TIW valve and bleed down gas. 10 minutes bleed down to zero. Remove TIW and install rod packoffs. PU new rod. Set in 5 gallon bucket and stroke rod piston. Fill bucket wtih 5 more gallons of water. Stroke pump. Pump confirmed working correctly. Install exisiting dip tube below rod. RIH with pump and associated rods/weight bars. Set pump into profie. Pick up and stack weight 3 times. Look for movement of polished rod. Pump set. Screw down packoff/wiper assembly. Measure distance from rod clam to top of sucker rod threads. Rig down clamp. Vac truck on location to fill tubing. Rig up vac truck. 30K weight of rods on up stroke. Fill tubing. Calculated volume is 50 bbls. Fill tubing with produced fluid. 45 bbls loaded. Gauge in vac truck stopped dropping. Close in vac truck line. Stroked pump 10 times before pressure on gauge. Pressure test tubing to 1,500 psi for 15 minutes. No leakoff. Pump confirmed working. Set clamp for space out. Install horse head and center on polished rod. Start rigging down MONCLA 401. Location secure. Soldotna Creek Unit Well SCU 12A-04 . 11 ACTUAL SCHEMATIC Co p174 O21letion an:3/10/14 Hikorp Alaska.LL(. API: 50-133-10103-00 CASING DETAIL RKB= 14.83' Size Wt Grade Conn ID Top Btm A 1 t 22 29' 13-3/8" 54.5# 1-55 12.615" Surface 2,024' 7" 29# N-80 - 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' B L— 22 7" 23# N-80 6.366" 1,087' 4,857' t 7" 26# N-80 - 6.276" 4,857' 6,704' 7" 29# P-110 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' 13-3/8" TUBING DETAIL 2 Fair Cmt 2-7/8" 6.4# L-80 TC-II 2.441" Surface 8,211' Good Cmt I 2-3/8" 4.6# L-80 TC-II 1.995" 8,211' 9,979' 2-3/8" 4.6# N-80 IBT 1.995" 10,520' 10,74.8' 3 t JEWELRY DETAIL j 4 No. Depth ID OD Item C I 7 1 18' TuHanger, e2-7/8 IBT lift x 2-7/8 IBT D I 2 4,011' 2.441" 5.000" 2-7bing/8"Depth IndicatorSSub susp _ 5 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8"Crossover 4 , 8,397' 4.151" 5.000" Simplex Liner Hanger(Burns) E 5 9,981' 1.930" 4.000" Tubing Anchor(New 3/11/14;Shear set to 35k) Y 1! I 11& 6 10,056' 1.785" 2.375" Seating Nipple •=• 7 10,057' 1.995" 2.375" Slotted Flow Sub 6 8 10,061' 1.995" 2.375" 2 joints 2-3/8"tubing,EUE 8RD(Gas Anchor) 7 9 10,126' 2.500" Bull Plug F 4 10 10,136' 1.991" - Packer,Permanent,Baker Mod."D"2-7/8" kg 8 , 11 10,188' 1.875" 2.70" HES'X'Nipple G 9 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint,Brown"CC",Bottom half/Pin up 14 10,583' - - Packer,Retrievable,Baker Mod."FH"5"x2-3/8" 10 —1 ►� I 15 10,588' 1.875" - "5"Nipple,(Position No.2)w/PS plug installed(11-15-87) 11 © 1R 16 10,647' 2.0" 3.094" Safety Joint,Brown"CC" 12 i 17 10,648' 1.875" - Otis"XA"Sliding Sleeve t,,, G2 18 10,651' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" As H1 19 10,657' 2.0" 3.094" Safety Joint,Brown"CC" 20 10,691' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" H2 21 _10,697' 1.791" - "N"Nipple,w/PN plug installed(11-12-87) ii' 22 10,748' 1.995" - WLEG `r. H3 ri 13 ® y UH8 ROD DETAIL yI Tubing Perf MH8 No. Depth Length OD Item 10,570'-10,575' * A 4' 26' 1-1/2" Polished Rod,15'in well 14 2 Fro B 30' 16' 1" 1"x 6',2'EL Pony Rods 46' 2,575' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) 15 1H82,621' 3,500' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) 16 H9 6,121' 3,350' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(used) 17 C 9,471' 550' 1-1/4" 1-1/4"x 25'K Bars(weight bars) s D 10,021' 2.5' 1" 2"x 30"Stabilizer Bar w/s/"Pins 18 'I1 4 a E 10,023' 25' 1-1/2" 1-1/2"x 25'Insert Pump,RHBC Pump w/PA Ring 19 (NEW 3/11/14) 80 PA Ring,Sand Seal,2"x 1-1/2"x 24"x 24-1/2"x 25' Possible leak ..., UH10 RHBC 10,655'-10,675' y-1 F 10,048' 20 1.315" Dip Tube,bottom 1'ported,bull plug on bottom Of G 10,052' 1.0' 1.250" Welded coupling to bull plug—No Gauges 20 / rir Tubing Perf 21 ', 10,735'-10,745' 'i. LH10 22 r. L. 5„ TD=10,880';ETD=10,798' MAX HOLE ANGLE=14deg Downhole Revised:5/28/14 Updated by DMA 07-06-15 Soldotna Creek Unit Well SCU 12A-04 r H ACTUAL SCHEMATIC PTD:mp1 tion Ran:3/10/14 Hilcoro Alaska.LLC API: 50-133-10103-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8"Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8"Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8",HC,0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8",HC,60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8",HC,60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8"Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 _ Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Revised:5/28/14 Updated by DMA 07-06-15 (,<\OF j��sTHE STATE Alaska Oil and Gas •' — � ofA AS}(J\ Conservation Commission 111 333 West Seventh Avenue }= / GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 ��ALAS'" Fax: 907.276 7542 www.aogcc alaska gov Joe Kaiser ,CANNED MAYZ095 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 12A-04 Sundry Number: 315-285 Dear Mr. Kaiser: 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, P Cathy . Foerster Chair 4- DATED this �2 day of May, 2015 Encl. `14i`: 4:i'V . STATE OF ALASKA MAY 11 LU) • ALASKA OIL AND GAS CONSERVATION COMMISSION 1375 t Z() 'Z-I /5, APPLICATION FOR SUNDRY APPROVALS /AOG CC, 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ 644, Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other. Rod Pump Repair E. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Q . 174-021 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-133-10103-01 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes ❑ No 2Soldotna Creek Unit(SCU)12A-04 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996' Swanson River/Hemlock Oil • 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): 10,880 ' 10,878 ' 10,798' . 10,796 ' 10,588'&10,697' ±10,586' Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22" 29' 29 . Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi i 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 2-7/8" Tubing Grade:6.4#/L-80, Tubing MD(ft): 8,211 See Attached Schematic See Attached Schematic 2-3/8" 4.6#/L-80&N-80 10,748 Packers and SSSV Type: Baker FH/ Packers and SSSV MD(ft)and TVD(ft): 10,136'MD/10,134'TVD; Baker FH/Baker FH/Baker D;N/A 10,583'MD/10,581'TVD;10,651'MD/10,649'TVD;10,691'MD/10,689'TVD;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑., Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 05/24/15 Commencing Operations: OIL ❑� ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Kaiser Email jkaiSeraJliICOrD.COM Printed NameJooe Kaiser Title Operations Engineer SignatureI Phone 907-777-8393 Date 57,7/7U/5 COMMISSION USE ONLY Conditions of app al: Notify Commission so that a representative may witness Sundry Number: 16 Plug Integrity ❑ BOP Test , i Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 14 Subsequent Form Required: / 0'"y c`I APPROVED BY � Approved by P•20.644.....__0#47COMMISSIONER THE COMMISSION Date: SI,/��l� S '/51/5- okRiGikkkvb Submit Form and Forrn 10-403 R ised 5/2015 for 12 months from the date of approval. Attachment in Duplicate RBDMS MAY 1 2 2015 --1 ,- .,- ..bk c77/-/-c-- Well Prognosis . Well: SCU 12A-04 Hilcorp Alaska,LL Date:5/11/2015 Well Name: SCU 12A-04 API Number: 50-133-10103-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: May 24th, 2015 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 174-021 First Call Engineer: Joe Kaiser (907)777-8393 (0) (907)952-8897 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD) Maximum Expected BHP: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD) Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 7,175 ft. TVD. Brief Well Summary Soldotna Creek 12A-04 was drilled as a sidetrack of SCU 12-04 in 1974 due to parted tubing and bad casing in the original wellbore. In 1975 the completion was pulled to re-perforate the original Hemlock perforations in the Hemlock H-8, H-9, and H-10 benches.Thru-tubing perfs were added in 1988 to access zones isolated between packers.A 1995 workover changed the upper part of the completion and perforated the Tyonek G2 zone.Thru-tubing perfs were added in 1998 that added the Hemlock H-1, H-2, and H-3 benches.A 2009 workover pulled the tubing due to an obstruction in the tubing and perforations were added to the H4/H5,the Tyonek G2 was re-perforated,and a new completion was ran into the well.The well was converted to rod pump in Ju112013.The tubing anchor was reset in March 2014. Parted rods were repaired in early May 2014, with the rod pump and string being re-run. On April 19th, 2015,the well was shut in due to a suspected rod part near the pump. i The purpose of this work/sundry is to repair parted rods for this Lufkin Rod Pump well. Notes Regarding Wellbore Condition i • Well is currently not producing on rod pump(suspect rods parted). • Wellbore maximum deviation below sidetrack is less than 14 degrees. (� cr� Workover Rig Procedure: O x�4 1. Blow-down any pressure on the well and shoot fluid level(echometer)on casing. 2. MIRU Moncla#401 WO Rig. 3. Rig down Lufkin pumping unit head. Nipple up rod stripper ead. 4. LD polish rod and pull EL rods. Rack back the rods in asket. 5. PU overshot. 6. RIH and fish out remainng rod string and pump. LD pump. 7. LD and inspect pump and dip tube. II Well Prognosis Well: SCU 12A-04 Hilcorp Alaska,LL Date:5/11/2015 8. PU existing dip tube and new 1-1/2" rod pump, replace and RIH with existing tapered rod string (sinker bars, 3/4", 7/8" and 1),space out the rods, install polish rod. 9. Space out the rods, install existing polish rod. 10. ND rod stripper, install surface equipment onto well and test to 1,500 psi. 11. Rig up Lufkin pumping unit head and connect bridle to polished rod. 12. RD Moncla#401 WO Rig. 13. Return to production with same surface safety system as previously installed. Attachments: 1. Actual Schematic Soldotna Creek Unit Well SCU 12A-04 ACTUAL SCHEMATIC PTD p174-021 letion n:3/10/14 Hamra Alaska.LL(: API: 50-133-10103-00 CASING DETAIL RKB= 14.83' Size Wt Grade Conn ID Top Btm A 1 22" - - - 29' 13-3/8" 54.5# 1-55 12.615" Surface 2,024' 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' B 22" 7" 23# N-80 6.366" 1,087' 4,857' 7" 26# N-80 6.276" 4,857' 6,704' 7" 29# P-110 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' 13-3/8" TUBING DETAIL 2 Fair Cmt 2-7/8" 6.4# L-80 TC-II 2.441" Surface 8,211' Good Cmt i2-3/8" 4.6# L-80 N-80 TC II 1.995" 8,211' 9,979' 4.6# IBT 1.995" 10,520' 10,748' 3!1 2-3/8" ` 4 JEWELRY DETAIL C T No. Depth ID OD Item D 1 18' Tubing Hanger,Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp E 5 2 4,011' 2.441" 5.000" 2-7/8"Depth Indicator Sub SUSPECTED ROD 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8"Crossover PART NEAR PUMP4 8,397' 4.151" 5.000" Simplex Liner Hanger(Burns) E Ij 5 9,981' 1.930" 4.000" Tubing Anchor(New 3/11/14;Shear set to 35k) rla A 6 10,056' 1.785" 2.375" Seating Nipple 0, 7 _ 10,057' 1.995" 2.375" Slotted Flow Sub I ! 6 8 _10,061' 1.995" 2.375" 2 joints 2-3/8"tubing,EUE 8RD(Gas Anchor) 7 9 _10,126' 2.500" Bull Plug F a 10 10,136' 1.991" - Packer,Permanent,Baker Mod."0"2-7/8" Id 8 ° 11 10,188' 1.875" 2.70" HES'X'Nipple G 9 t 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint,Brown"CC",Bottom half/Pin up 14 10,583' - - Packer,Retrievable,Baker Mod."FH"5"x2-3/8" 10 1 15 10,588' 1.875" - "S"Nipple,(Position No.2)w/PS plug installed(11-15-87) 11 © g 16 10,647' 2.0" 3.094" Safety Joint,Brown"CC" 12 -- 17 10,648' 1.875" - Otis"XA"Sliding Sleeve G2 18 10,651' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" .may 19 _10,657' 2.0" 3.094" Safety Joint,Brown"CC" it H1 20 10,691' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" ill H2it 21 10,697' 1.791" "N"Nipple,w/PN plug installed(11-12-87) 22 10,748' 1.995" WLEG I H3 t1 13 r ! UH8 ROD DETAIL Tubing Perf * MH8 No. Depth Length OD Item 10,570'-10,575' • ..4 A 4' 26' 1-1/2" Polished Rod,15'in well 14 M 0 g B _ 30' 16' 1" 1"x 6',2'EL Pony Rods 15 © 46' 2,575' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) f�±w, LH8 2,621' 3,500' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(New 5/28/14) 16 H9 41 6,1213, 350' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(Used) C 9,471' 550' 1-1/4" 1-1/4"x 25'K Bars(weight bars) 17 D _ 10,021' 2.5' 1" 2"x 30"Stabilizer Bar w/s/"Pins 18 r 4,r 1 E 10,023' 25' 1-1/2" 1-1/2"x 25'Insert Pump,RHBC Pump w/PA Ring (NEW 3/11/14) i9 80 PA Ring,Sand Seal,2"x 1-1/2"x 24"x 24-1/2"x 25' Possible leak _� UH10 RHBC 10,655'-10,675' i+� F 10,048' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom + G 10,052' 1.0' 1.250" Welded coupling to bull plug—No Gauges 20 / R Nit Tubing Perf 21 E 10,735'-10,745' i LH10 22 r T a a te' t. 5,, TD=10,880';ETD=10,798' MAX HOLE ANGLE=14deg Downhole Revised:5/28/14 Updated by STP 6/17/14 Soldotna Creek Unit 0, Well SCU 12A-04 ACTUAL SCHEMATIC p 174-021 letion n:3/10/14 PTD Hilrnro Alaska.LLC API: 50-133-10103-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8"Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,323' _ 10,349' 10,322' 10,348' 26' 6 3-1/8"Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8",HC,0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8",HC,60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8",HC,60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8"Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' _ 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' _ 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Revised:5/28/14 Updated by STP 6/17/14 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 7T Repair Well Plug Perforations Ll Perforate Other Rod Pump Repair Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate -Other ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Stratigraphic ❑ Exploratory ❑ Service ❑ 174-021 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 50-133-10103-01 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028996 Soldotna Creek Unit (SCU) 12A-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River / Hemlock Oil 11. Present Well Condition Summary:` Total Depth measured 10,880 feet Plugs measured 10,588&10,697 feei� Cjpl vim° true vertical 10,878 feet Junk measured ±10,586 feet r c 10,136; 10,583; ,l UN 1 7 2014 Effective Depth measured 10,798 feet Packer measured 10,651; 10,691 feet true vertical 10,796 feet true vertical 10,134; 10,581; feet AOGC 10,649; 10,689 Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.4# / L-80 8,211' MD 8,209' TVD Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.6# L-80 & N-80 10,748' MD 10,746' TVD Baker FH/Baker FH/ 10,136'MD; 10,583' MD; 10,1347VD, 10,5817VD; Packers and SSSV (type, measured and true vertical depth) Baker FH/Baker D; N/A 10,651' MD; 10,691'MD 10,649'TVD; 10,689'TVD N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 200 180 Subsequent to operation: 71 61 145 180 160 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory. ❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ 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: 314-325 Contact Stan Porhola Email sporhola(ahilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date 6,k Form 10-404 Revised 10/2012 N��/� / 7't -C MEMS JUN 18 2C`:. Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 12A-04 50-133-10103-01 1 174-021 5/27/14 1 5/28/14 Daily Operations: 05/27/2014 -Tuesday MIRU, remove horsehead, L/D polish rod and ponies. POOH, 36 1" rods, find rod box parted between #36 and 37 rod, P/U overshot with spiral grapel. RIH, engage fish, latch up work rods, unseat pump. POOH to top of fish. Flush rods with 30 bbls hot FSW. Resume POOH, L/D all 1"" and 7/8" rods, stand back 3/4" rods, inspect pump and find sand seal on top damaged, replace with new pump. RIH with new pump and old dip tube less memory gauge. RIH with 3/4" rods and retorque all connections, replace 2 damaged 3/4" rods. 05/28/2014 - Wednesday Continue in hole. P/U 7/8" rods. RIH with 1" rods. Rod string: 1 - gas anchor 20', 1 XO, 1 - 1.50" x 25' insert pump, 1 - stabilizer bar, 22 - 1-1/4" weight bars 134 - 3/4" EL rods new 140 -7/8" EL rods new 103 - 1" rods 1 - 6' x 1" y " g pony, 1-2 x 1 pony, 1 - 1.50" x 26' polish rod, get spacing. P/U polish rod, P/U ponies, seat pump, load tubing, jug test to 800 psi - test good. Run unit, set rod rotator, get horse head straight. RD, load all equipment, clean location. Demobe rig to Susan Dionne #8. B C D 11 22" —13-3/8- 2 13-3/8"2 Fair Cmt 3 Good Cmt 4 7" 5 RESET 6 7 F 8 A9 10 11 12 13 Tubing Perf _ 10,570'-10,575' 14 15 16 17 18 19 Possible leak _ 10,655'-10,675' 20 Tubing Perf 21 10,735'-10,745' 22 G2 H1 H2 H3 UH8 MI -18 LH8 H9 UH10 LH 10 5„ TD = 10,880'; ETD = 10,798' MAX HOLE ANGLE = 14deg Downhole Revised: 5/28/14 Depth Soldotna Creek Unit OD Item 1 18' Well SCU 12A-04 - - 2 ACTUAL SCHEMATIC Comletion n: 3/10/14 p 54.5# J-55 12.615" Surface PTD: 174 021 7" Niloora Alae4a, LLC N-80 API: 50-133-10103-00 Surface 324' CASING DETAIL 26# N-80 RKB = 14.83' 324' Size Wt Grade Conn ID Top Btm N-80 6.366" 1,087' 4,857' A 26# 1 HI 4,857' 22" 7" 29# P-110 6.184" 6,704' 8,597' B C D 11 22" —13-3/8- 2 13-3/8"2 Fair Cmt 3 Good Cmt 4 7" 5 RESET 6 7 F 8 A9 10 11 12 13 Tubing Perf _ 10,570'-10,575' 14 15 16 17 18 19 Possible leak _ 10,655'-10,675' 20 Tubing Perf 21 10,735'-10,745' 22 G2 H1 H2 H3 UH8 MI -18 LH8 H9 UH10 LH 10 5„ TD = 10,880'; ETD = 10,798' MAX HOLE ANGLE = 14deg Downhole Revised: 5/28/14 TUBING DETAIL 2-7/8" 6.4# L-80 TC -II 2.441" Surface 8,211' 2-3/8" 4.6# L-80 TC -II 1.995" 8,211' 9,979' 2-3/8" 4.6# N-80 IBT 1.995" 10,520' 10,748' JEWELRY DETAIL No. Depth ID OD Item 1 18' - - - 2 29' 13-3/8" 54.5# J-55 12.615" Surface 2,024' 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' 7" 23# N-80 6.366" 1,087' 4,857' 7" 26# N-80 6.276" 4,857' 6,704' 7" 29# P-110 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' TUBING DETAIL 2-7/8" 6.4# L-80 TC -II 2.441" Surface 8,211' 2-3/8" 4.6# L-80 TC -II 1.995" 8,211' 9,979' 2-3/8" 4.6# N-80 IBT 1.995" 10,520' 10,748' JEWELRY DETAIL No. Depth ID OD Item 1 18' - - Tubing Hanger, Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp 2 4,011' 2.441" 5.000" 2-7/8" Depth Indicator Sub 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8" Crossover 4 8,397' 4.151" 5.000" Simplex Liner Hanger (Burns) 5 9,981' 1.930" 4.000" Tubing Anchor (New 3/11/14; Shear set to 35k) 6 10,056' 1.785" 2.375" Seating Nipple 7 10,057' 1.995" 2.375" Slotted Flow Sub 8 10,061' 1.995" 2.375" 2 joints 2-3/8" tubing, EUE 8RD (Gas Anchor) 9 10,126' - 2.500" Bull Plug 10 10,136' 1.991" - Packer, Permanent, Baker Mod. "D" 2-7/8" 11 10,188' 1.875" 2.70" HES'X' Nipple 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint, Brown "CC", Bottom half/Pin up 14 10,583' - - Packer, Retrievable, Baker Mod. "FH" 5"x2-3/8" 15 10,588' 1.875" - "S" Nipple, (Position No. 2) w/ PS plug installed (11-15-87) 16 10,647' 2.0" 3.094" Safety Joint, Brown "CC" 17 10,648' 1.875" - Otis "XA" Sliding Sleeve 18 10,651' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 19 10,657' 2.0" 3.094" Safety Joint, Brown "CC" 20 10,691' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 21 10,697' 1.791" "N" Nipple, w/ PN plug installed (11-12-87) 22 10,748' 1.995" WLEG ROD DETAIL No. Depth Length OD Item A 4' 26' 1-1/2" Polished Rod, 15' in well B 30' 16' 1" 1" x 6', 2' EL Pony Rods 46' 2,575' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod (new 5/28/14) 2,621' 3,500' 7/8" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod (New 5/28/14) 6,121' 3,350' 3/4" 3/4" x 25' EL Sucker rods w/ 4 XL guides per rod (used) C 9,471' 550' 1-1/4" 1-1/4" x 25' K Bars (weight bars) D 10,021' 2.5' 1" 2" x 30" Stabilizer Bar w/ YV Pins E 10,023' 25' 1-1/2" 1-1/2" x 25' Insert Pump, RHBC Pump w/ PA Ring (NEW 3/11/14) 80 PA Ring, Sand Seal, 2" x 1-1/2" x 24" x 24-1/2" x 25' RHBC F 10,048' 20' 1.315" Dip Tube, bottom 1' ported, bull plug on bottom G 10,052' 1.0' 1.250" Welded coupling to bull plug– No Gauges Updated by STP 6/17/14 Soldotna Creek Unit Well SCU 12A-04 I'm ACTUAL SCHEMATIC PTD Completion 174 0 tan: 3/10/14 daeara Alaska. LLC API: 50-133-10103-00 PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8" Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8" Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8", HC, 0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8", HC, 60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8", HC, 60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8" Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH 10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH 10 10,720' 10,745' 10,719' 1 10,744' 25' 4 Isolated by PS Plug Downhole Revised: 5/28/14 Updated by STP 6/17/14 ar ' Nl\ T B V uAtl r, ._ l t _ J -. C -1.:4 ;, _-� 333 `^J< Sevenli-, P ve ue . )l'-tii «%' - -- ' <.nVT i oR " 4 �AR\I:LI. An�.ho ice, Alaska 99501-3572 � •h, 74P vain 279 5(5 Stan Porhola � Operations Engineer 1 � Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field/Hemlock Oil Pool, Soldotna Creek Unit 12A-04 Sundry Number: 314-325 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, V / 1-77',7-eVt -- Cathy P oerster Chair G DATED this/.1- day of May, 2014. Encl. SCANNED JUL 1 6 2014 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,i I s 5I2-z"" �� APPLICATION FOR SUNDRY APPROVALS V 20 AAC 25.280 AA GCC 1.Type of Request: Abandon❑ Plug for Redrii ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Atter Casing❑ Other. Rod Pump Repair E • 2.Operator Name: r. Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development El . 174-021 , 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10103-01• 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B • Sddotna Creek Unit(SCU)12A-04 - Will planned perforations require a spacing exception? Yes ❑ No 0❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 Swanson River/Hemlock Oil , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,880 4 10,878 • 10,798 10,796 10,588'&10,697' ±10,586 Casing Length Size MD ND Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade:6.4#/L-80, Tubing MD(It): See Attached Schematic See Attached Schematic 2-7/8"x2-3/8" 4.61E/L-80&N-80 10,119' Packers and SSSV Type: Baker FH/Baker FH/Baker FH/Baker D Packers and SSSV MD(t)and ND(ft): 10,691/10,651/10,583/10,136 MD No SSSV No SSSV 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic❑ Development n Service n 14.Estimated Date for 15.Well Status after proread work: Commencing Operations: 05/24/14 Oil ❑Q . Gas 0 WDSPL ❑ Suspended p 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 Stan Porhda Phone: 907-777-8412 Email soorholaOhilcorD.cortl Printed NameStan Porhola Title Operations Engineer Signature l; Phone 907-777-8412Date s /1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '7" `L(_ 32_5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: /L --y L,-7 APPROVED BY Approved by: f )(ix,44,..____ COMMISSIONER THE COMMISSION Date: 5_ 22 - `f �, S2Pt1 \ � V� Submit Form and Ri3Fo1§0-40471e1, Il ,� i App v p i i i r 2 months from the date of approval. Attachm is in Duplicate • Cr .15‘/744.....- b 5'21. 74i Well Prognosis • Well: SCU 12A-04 Hilcon)Alaska,LL) Date:5/19/2014 Well Name: SCU 12A-04 API Number: 50-133-10103-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: May 24th, 2014 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 174-021 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: - 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD) Maximum Expected BHP: - 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD) Max. Allowable Surface Pressure: -0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 7,175 ft. TVD. Brief Well Summary Soldotna Creek 12A-04 was drilled as a sidetrack of SCU 12-04 in 1974 due to parted tubing and bad casing in the original wellbore. In 1975 the completion was pulled to re-perforate the original Hemlock perforations in the Hemlock H-8, H-9, and H-10 benches.Thru-tubing perfs were added in 1988 to access zones isolated between packers.A 1995 workover changed the upper part of the completion and perforated the Tyonek G2 zone.Thru-tubing perfs were added in 1998 that added the Hemlock H-1, H-2, and H-3 benches.A 2009 workover pulled the tubing due to an obstruction in the tubing and perforations were added to the H4/H5,the Tyonek G2 was re-perforated, and a new completion was ran into the well.The well was converted to rod ePump in July 2013.The tubing anchor was reset in March 2014. Parted rods were repaired in early May 2014, with the rod pump and string being re-run. —� The purpose of this work/sundry is to repair parted rods for this Lufkin Rod Pump well. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect rods parted). • Wellbore maximum deviation below sidetrack is less than 14 degrees. Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. MIRU Moncla#401 WO Rig. 3. Rig down Lufkin pumping unit head. Nipple up rod stripper head. 4. LD polish rod and pull EL rods. Rack back the rods in basket. 5. LD and inspect pump and dip tube and all pulled rods. 6. PU existing dip tube and existing 1-1/2"rod pump, replace and RIH with new tapered rod string (sinker bars, 3/4", 7/8" and 1),space out the rods, install polish rod. 7. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 8. Rig up Lufkin pumping unit head and connect bridle to polished rod. Well Prognosis Well: SCU 12A-04 Hilcarp Alaska,LL Date:5/19/2014 9. RD Moncla#401 WO Rig. 10. Return to production with same surface safety system as previously installed. 11. Replace IA x OA pressure gauge if removed (7"x 13-3/8"). Attachments: 1. Actual Schematic Soldotna Creek Unit Well SCU 12A-04 .. ii ACTUAL SCH E MATI C pn:3/10/14 PTD: 174 021 Htleoru ctc API: 50-133-10103-00 SUSPECTED ROD PART AT+/-2,000' CASING DETAIL RKB= 14.83' Size Wt Grade Conn ID Top Btm A i122" 29' 13-3/8" 54.5# J-55 12.615" Surface 2,024' • 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' Bt,.. 1 [ 22 7" 23# N-80 - - 6.366" 1,087' 4,857' 7" 26# N-80 - 6.276" 4,857' 6,704' 7" 29# P-110 _ - 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' 13 3/8" TUBING DETAIL 2 Fair Cmt 2-7/8" 6.4# L-80 TC-II 2.441" Surface 8,211' 9' l x Good Cmt 2-3/8" 4.6# N-80 Butt 1.995" 10,52V 710,748' 3 t , 4 JEWELRY DETAIL C 7, No. Depth ID OD Item D 1 18' - - Tubing Hanger,Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp 2 4,011' 2.441" 5.000" 2-7/8"Depth Indicator Sub VI 5 RESET 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8"Crossover ! i 4 8,397' 4.151" 5.000" Simplex Liner Hanger(Burns) E I 5 9,981' 1.930" 4.000" Tubing Anchor(New 3/11/14;Shear set to 35k) a ?:a 6 10,056' 1.785" 2.375" Seating Nipple •_• ;ik.,1 7 10,057' 1.995" 2.375" Slotted Flow Sub 1 6 V 8 10,061' 1.995". 2.375" 2 joints 2-3/8"tubing,EUE 8RD(Gas Anchor) 7 9 10,126' 2.500" Bull Plug F a 10 10,136' 1.991" - Packer,Permanent,Baker Mod."D"2-7/8" 8 #fit 11 10,188' 1.875" 2.70" HES'X'Nipple G 1 9 i 12 10,220' 1.997" 3.50" WLEG y 13 10,520' 2.0" _ 3.094" Safety Joint,Brown"CC",Bottom half/Pin up 14 10,583' - - Packer,Retrievable,Baker Mod."FH"5"x2-3/8" 10 1 15 10,588' 1.875" - "S"Nipple,(Position No.2)w/PS plug installed(11-15-87) 11 © 4 16 10,647' 2.0" 3.094" Safety Joint,Brown"CC" 12 17 10,648' _ 1.875" - Otis"XA"Sliding Sleeve G2 18 10,651' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" '.:' 19 10,657' 2.0" 3.094" Safety Joint,Brown"CC" •!t H1 20 10,691' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" H2 21 10,697' 1.791" - "N"Nipple,w/PN plug installed(11-12-87) }t. 22 10,748' 1.995" - WLEG H3 Y4 13 UH8 ROD DETAIL V. Tubing Perf 111 A MH8 No. Depth Length OD Item 10,570'-10,575' A 4' 26' 1-1/2" Polished Rod,15'in well 14 / r/ B 30' 16' 1" 1"x 6',4',2',4'EL Pony Rods r 46' 2,565' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod 15 I =w LH8 2,621' 3,500' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod 16 H9 6,121' 3,350' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod 17 -I C 9,471', 550' 1-1/4" 1-1/4"x 25'K Bars(weight bars) D 10,021' 2.5' 1" 2"x 30"Stabilizer Bar w/'A"Pins 18 4 tE 10,023' 25' 1-1/2" 1-1/2"x 25'Insert Pump,RHBC Pump w/PA Ring 19 (NEW 3/11/14) 80 PA Ring,Sand Seal,2"x 1-1/2"x 24"x 24-1/2"x 25' Possible leak UH10 RHBC 10,655'-10,675' {y F 10,048' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom G 10,052' 3.5' 1.688" 1-1/4"Memory Gauge(welded coupling to bull plug) 20 / �'' Tubing Perf 21 p .- 10,735'-10,745' i ++. LH10 22 - t; 5" TD=10,880';ETD=10,798' MAX HOLE ANGLE=14deg Downhole Revised:5/17/14 Updated by STP 5/19/14 Soldotna Creek Unit Well SCU 12A-04 • H ACTUAL SCHEMATIC pan:3/10/14 PTD: 1740 1 Hllcora Alaska.LLC API: 50-13340103-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8"El,90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8"Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8"E1,90 deg. r, 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8"Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8",HC,0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8",HC,60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8",HC,60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8"Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Revised:5/17/14 Updated by STP 5/19/14 Davies, Stephen F (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Wednesday, May 21, 2014 12:45 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA); Ferguson,Victoria L (DOA); Bettis, Patricia K DO Subject: RE: Rush Sundry Applications for SCU 41A-08 (194-085) and SCU 2A-0 (174-021) - Explanations Needed Steve, The urgency on the sundries for SCU 41A-08 (194-095)and SCU 12A-04 (174-021)was based on recent Rod Failures of these wells and the anticipated availability of a workover rig to pull the rods from these wells. We have since seen a delay in the availability of the rig and anticipate the workover rig to be available on Friday, May 23rd at the earliest. It was anticipated that these sundries would have short reviews due to the nature of the work (pulling/running sucker rods). Guy Schwartz said he is looking into requests such as these not requiring sundry approval in the future.The 7 rod pump wells at Swanson River create a unique aspect where when we have failed rods,we can move onto these wells quickly if the workover rig is available, as opposed to other operations. We are continuing to strive to get scopes of work out as soon as possible, anticipating future needs such as when a well is perforated and comes back non-productive. In this case, our sundry applications will anticipate this step and address future work in the original sundry,thus reducing the short turnaround or verbal approval requests being made from our office. Stan • From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, May 21, 2014 12:27 PM To: Stan Porhola Cc: Schwartz, Guy L (DOA); Ferguson, Victoria L(DOA); Bettis, Patricia K (DOA) Subject: Rush Sundry Applications for SCU 41A-08 (194-085) and SCU 12A-04 (174-021) - Explanations Needed Stan, At noon today, May 215t, I received two Applications for Sundry Approvals for SCU 41A-08 (194-095)and SCU 12A-04 (174-021) with "Rush" notes attached to them. The estimated dates for commencing the requested operations are May 22nd and May 24th, respectively. There is no explanation of why urgency is needed. For these two Sundry Applications, please explain in detail what led to the need for short notice. I'll hold these two applications until the requested explanations arrive via email. I'm going to repeat the text of an email sent last week by Guy Schwartz to Daniel Taylor, with minor modifications: AOGCC's guidelines, below, were published in last month's AADE bulletin. Please adhere to this standard. Submitting sundries 3-4 days before work is expected to start is not acceptable. Verbal Approvals for Sundries: 1 Verbal approvals should be rare. In order for the Commission to properly vet the incoming sundries two weeks of notice are required. When well work does come up unexpectedly and there is no way to avoid requesting verbal approval the following steps should be taken: 1) Call the staff AOGCC engineer that will be handling the request and explain the situation. 2) Follow up with an email requesting verbal approval with an outline of the scope of work and steps to be taken for the required well work. Include as much detail as possible. (always include the well name and permit to drill number in the email subject line!!!) 3) The email must include information outlining the reason that the sundry request is verbal. Explain in detail what led to the need for short notice such as unexpected pressures, last minute rig changes, ESP failure, etc. 4) Post the email authorizing the verbal approval on the well site. 5) Submit a 10-403 as soon as possible. Include a copy of the verbal approval email in the sundry application. Please let me know if you have any questions. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon H Repair Well 11 Plug Perforations L. I Perforate Other Replace Rod Pump Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development 0 Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 174-021 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 - 50-133-10103-01 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028996 r , Soldotna Creek Unit (SCU) 12A-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River/ Hemlock'n'r In 11. Present Well Condition Summary: Total Depth measured . 10,880 feet Plugs measured 10,588 & 10,697 feet MAY 2 0 2014 true vertical 10,878 feet Junk measured ±10,586 feet 10,136; 10,583; AQGCC Effective Depth measured 10,798 feet Packer measured 10,651; 10,691 feet true vertical 10,796 feet true vertical 10,134; 10,581; feet 10,649; 10,689 Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.4# / L-80 8,211' MD 8,209' TVD Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.6# L-80 & N-80 10,748' MD 10,746' TVD Baker FH/Baker FH/ 10,136'MD; 10,583' MD; 10,1347VD; 10,581'TVD; Packers and SSSV (type, measured and true vertical depth) Baker FH/Baker D; N/A 10,651' MD; 10,691'MD 10,6497VD; 10,689'TVD N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A RBDM8F& MAY 2 0 2014 _7 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 150 180 Subsequent to operation: 128 37 92 150 150 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Explorator/ ❑ Development Ow Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil t 0 Gas ❑ WDSPL ❑ GSTOR ❑ 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: 314-051 Contact Stan Porhola Email Sporhola(a)hilCorp.conl Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date S Form 10-404 Revised 10/2012 � �/�//� Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 12A-04 50-133-10103-01 174-021 4/27/14 1 5/2/14 Daily Operations: 04/27/2014 -Sunday Mob rig from D&D yard to SCU 12A-4, stage equipment and carrier. 04/28/2014 - Monday Finish load out equipment in D&D yard. Set in generator, doghouse, parts house. Raise derrick, set berms around rig and generator house. Raise derrick. Remove bridal line from polish rod. 04/29/2014 -Tuesday Install berms hook up gas detectors while bleeding off annulus. Hook up power to office trailers. Lay down polish rod and 40 1" rods, found rod box parted. Inspect rods. Make up overshot trip in hole. Work overshot over fish. Pulled 20K on rods. Rod weight calculates to be 25K. Overshot pulled loose 4 times. POOH with rods. Found that grapple and guide had pulled off overshot. Shut in well. 04/30/2014 - Wednesday Switching out rod tongs and bleed down well. RIH with 2-5/16" series 10 over shot with 2" spiral grapple. Slip over fish pulled 26K over overshot slipped off. POOH with overshot. Swelled and split. Hold school for handling rods, wait on fishing tools, service rig. Make up overshot, RIH with 14 stds 1" rods. Latch fish, POOH, Lay down overshot, recovered fish. RIH, screw into fish. Rod pump pulled free with 3K overpull. String wt 24K. POOH. 05/01/2014 - Thursday Bleed off well, continue to pull rods. Lay down rod pump. Break off dip tube and weld on XO. Clean out dip tube. Make up dip tube to rod pump. RIH. 05/02/2014 - Friday Bleed off well. RIH with sucker rods, break and retorque connections. Hook up vac truck and put 35 MIS. Lease water down tubing. Space out rod pump, stroke pump to pressure tubing, pressure went up to 75 psi. Hook up vac truck fill tubing, strike pump, build pressure to 650 psi. Hold 5 min. Space out poilsh rod and install bridal. MOB to SCU 12A-03. Soldotna Creek Unit Well SCU 12A-04 ACTUAL SCHEMATIC PTD:pletion 174 021 n: 3/10/14 Hilcura Alaska. LLf, API: 50-133-10103-00 CASING DETAIL RKB = 14.83' 22" — 13-3/8" Fair Cmt Good Cmt 4 7" 5 RESET Tubing Perf _ 10,570'-10,575' 14 15 16 17 18 19 Possible leak _ 10,655'-10,675' 20 Tubing Perf 21 10,735'-10,745' 22 5„ TD = 10,880'; ETD = 10,798' MAX HOLE ANGLE = 14deg Downhole Revised: 5/02/14 Size Wt Grade Conn ID Top Btm 22" - - Tubing Hanger, Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp 2 29' 13-3/8" 54.5# J-55 12.615" Surface 2,024' 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' 7" 23# N-80 6.366" 1,087' 4,857' 7" 26# N-80 6.276" 4,857' 6,704' 7" 29# P-110 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' TUBING DETAIL 2-7/8" 6.4# L-80 TC -II 2.441" Surface 8,211' 2-3/8" 4.6# L-80 TC -II 1.995" 8,211' 9,979' 2-3/8" 4.6# N-80 Butt 1.995" 10,520' 10,748' JEWELRY DETAIL No. Depth ID OD Item 1 18' - - Tubing Hanger, Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp 2 4,011' 2.441" 5.000" 2-7/8" Depth Indicator Sub 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8" Crossover 4 8,397' 4.151" 5.000" Simplex Liner Hanger (Burns) 5 9,981' 1.930" 4.000" 1 Tubing Anchor (New 3/11/14; Shear set to 35k) 6 10,056' 1.785" 2.375" Seating Nipple 7 10,057' 1.995" 2.375" Slotted Flow Sub 8 10,061' 1.995" 2.375" 2 joints 2-3/8" tubing, ELIE 8RD (Gas Anchor) 9 10,126' - 2.500" Bull Plug 10 10,136' 1.991" - Packer, Permanent, Baker Mod. "D" 2-7/8" 11 10,188' 1.875" 2.70" HES'X' Nipple 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint, Brown "CC", Bottom half/Pin up 14 10,583' - - Packer, Retrievable, Baker Mod."FH" 5"x2-3/8" 15 10,588' 1.875" - "S" Nipple, (Position No. 2) w/ PS plug installed (11-15-87) 16 10,647' 2.0" 3.094" Safety Joint, Brown "CC" 17 10,648' 1.875" - Otis "XA" Sliding Sleeve 18 10,651' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 19 10,657' 2.0" 3.094" Safety Joint, Brown "CC" 20 10,691' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 21 10,697' 1.791" "N" Nipple, w/ PN plug installed (11-12-87) 22 10,748' 1.995" WLEG ROD DETAIL No. Depth Length OD Item A 4' 26' 1-1/2" Polished Rod, 15' in well B 30' 16' 1" 1" x 6', 4', 2', 4' EL Pony Rods 46' 2,565' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod 2,621' 3,500' 7/8" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod 6,121' 3,350' 1 3/4" 3/4" x 25' EL Sucker rods w/ 4 XL guides per rod C 9,471' 550' 1-1/4" 1-1/4" x 25' K Bars (weight bars) D 10,021' 2.5' 1" 2" x 30" Stabilizer Bar w/ %" Pins E 10,023' 25' 1-1/2" 1-1/2" x 25' Insert Pump, RHBC Pump w/ PA Ring (NEW 3/11/14) 80 PA Ring, Sand Seal, 2" x 1-1/2" x 24" x 24-1/2" x 25' RHBC F 10,048' 20' 1.315" Dip Tube, bottom 1' ported, bull plug on bottom G 10,052' 3.5' 1.688" 1 1-1/4" Memory Gauge (welded coupling to bull plug) Updated by STP 5/19/14 Soldotna Creek Unit Well SCU 12A-04 ACTUAL SCHEMATIC PTD:pletion 174-021 n: 3/10/14 Hileru AleHka. LLC API: 50-133-10103-00 PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8" Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8" Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8", HC, 0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8", HC, 60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8", HC, 60 deg. 12/11/1998 1-14/1-15 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8" Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MI -18 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH 10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' i 10,744' 25' 4 Isolated by PS Plug Downhole Revised: 5/02/14 Updated by STP 5/19/14 CE STATE OF ALASKA ALA—..A OIL AND GAS CONSERVATION COMMISSION ,1I yr'', j 1 ?'1;1,1 REPORT OF SUNDRY WELL OPERATIONS ,, AO(�- 1'GC, 1.Operations Abandon U Repair Well Li Plug Perforations U Perforate U Other-Ed Rod Pump Repair Performed: Alter Casing ❑ Pull Tubing❑, Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other p Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ i 174-021 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 . 50-133-10103-01 7.Property Designation(Lease Number): 8.Well Name and Number: . FEDA028996 . Soldotna Creek Unit(SCU)12A-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured % 10,880 feet Plugs measured 10,588&10,697 feet true vertical 10,878 feet Junk measured ±10,586 feet 10,136; 10,583; Effective Depth measured , 10,798 feet Packer measured 10,651;10,691 feet true vertical 10,796 feet true vertical 10,134; 10,581; feet 10,649;10,689 Casing Length Size MD ND Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,1401psi 10,490 psi Perforation depth Measured depth See Attached Schematic SCANNED MAY vy @ 201 4 True Vertical depth See Attached Schematic ISG 2-7/8" 6.4#/L-80 8,211'MD 8,209'ND Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#L-80&N-80 10,748'MD 10,746'ND Baker FH/Baker FH/ 10,136'MD;10,583'MD; 10,134'TVD;10,581'ND; Packers and SSSV(type,measured and true vertical depth) Baker FH/Baker D;N/A 10,651'MD;10,691'MD 10,649'TVD;10,689'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A RBDM MAY 15 2014 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 150 180 Subsequent to operation: 94 60 101 170 150 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil • Q Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-073 Contact Stan Porhola Email sporhola((l7.hilcoro.com Printed Name Stan Porhola Title Operations Engineer Signature ,.N.,,, in(,+, ..e_J Phone 907-777-8412 Date t- - /0// (- ,,,/ S -2Zi ( Form 10-404 Revised 10/2012 S/ Al Submit Original Only Soldotna Creek Unit Well SCU 12A-04 ACTUAL SCH EMATIC PTD p174 021 letion n:3/10/14 Hibor)Alaska.LLC API: 50-133-10103-00 CASING DETAIL RKB= 14.83' Size Wt Grade Conn ID Top Btm t. 22" - - - 29' A _ 1 13-3/8" 54.5# J-55• 12.615" Surface 2,024' 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' B 22 7" 23# N-80 - 6.366" 1,087' 4,857' 7" 26# N-80 - _ 6.276" 4,857' 6,704' 7" _ 29# P-110 - 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' 13-3/8" TUBING DETAIL mom 2 Fair Cmt 2-7/8" 6.4# L-80 TC-Il 2.441" Surface 8,211' 2-3/8" 4.6# L-80 TC-II 1.995" 8,211' 9,979' — Good Cmt 2-3/8" 4.6# N-80 Butt _ 1.995" 10,520' 10,748' C 7 3 JEWELRY DETAIL 13. B 4 C _ . . 7" No. Depth ID OD Item D — 1 _ 18' - - Tubing Hanger,Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp 2 4,011' 2.441" 5.000" 2-7/8"Depth Indicator Sub lit SAW 5 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8"Crossover 4 8,397' 4.151" 5.000" Simplex Liner Hanger(Burns) E 5 9,981' 1.930" 4.000" Tubing Anchor New 3/11/14;Shear set to 35k) 6 10,056' 1.785" 2.375" Seating Nipple 7 10,057' 1.995" 2.375" Slotted Flow Sub 6 8 10,061' 1.995" 2.375" 2 joints 2-3/8"tubing,EUE 8RD(Gas Anchor) J 7 9 10,126' 2.500" Bull Plug F t 10 10,136' 1.991" - Packer,Permanent,Baker Mod."D"2-7/8" 8 11 10,188' 1.875" 2.70" HES'X'Nipple �9 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint,Brown"CC",Bottom half/Pin up 14 10,583' - - Packer,Retrievable,Baker Mod."FH"5"x2-3/8" 10 , 15 10,588' 1.875" - "5"Nipple,(Position No.2)w/PS plug installed(11-15-87) 11 I© 16 10,647' 2.0" 3.094" Safety Joint,Brown"CC" imi 12 — G�' 17 10,648' 1.875" - Otis"XA"Sliding Sleeve T G2 18 10,651' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" --"- H1 19 10,657' 2.0" 3.094" Safety Joint,Brown"CC" 20 10,691' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" '' H2 21 _10,697' 1.791" - "N"Nipple,w/PN plug installed(11-12-87) r 22 10,748' 1.995" - WLEG .i H3 13 = "1. to UH8 ROD DETAIL Tubing Perf jo MH8 No. Depth Length OD Item 10,570'-10,575' . A 4' 26' 1-1/2" Polished Rod,15'in well 14 B 30' 16' 1" 1"x 6',4',2',4'EL Pony Rods 15 46' 2,565' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod Ts— LH8 2,621' 3,500' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod 16H9 6,121' 3,350' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod � ' C 9,471' 550' 1-1/4" 1-1/4"x 25'K Bars(weight bars) 17 xn D 10,021' __2.5' 1" 2"x 30"Stabilizer Bar w/''A"Pins 18 " ' '" E 10,023' 25' 1-1/2" 1-1/2"x 25'Insert Pump,RHBC Pump w/PA Ring 19Alli •*, (NEW 3/11/14) --r. 80 PA Ring,Sand Seal,2"x 1-1/2"x 24"x 24-1/2"x 25' Possible leakUH10 RHBC 10,655'40,675' ; F 10,048' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom r. 20 / -* Tubing Perf 21 10,735'-10,745' 1, LH 10 22 6. L 5„ TD=10,880';ETD=10,798' MAX HOLE ANGLE=14deg Down hole Revised:3/11/14 Updated by STP 4/10/14 Soldotna Creek Unit Well SCU 12A-04 via ACTUAL SCH EMATIC pn:3/10/14 PTD: 174 021 Hi!cora Alaska,LLC API: 50-133-10103-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8"Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8"Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8",HC,0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8",HC,60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8",HC,60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8"Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Revised:3/11/14 Updated by STP 4/10/14 • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 12A-04 50-133-10103-01 174-021 3/6/14 3/11/14 Daily Operations: 03/06/2014-Thursday Laid contaiment and MIRU WOR and Equipment. Sealed in contaiment and stood derrick up. The hydraulics and air would not work on rig. Waited for parts from Moncla Shop. Changed out the hydraulic pump but could not get the Shuttle Valve to work that supplies air to the back of the rig. 03/07/2014- Friday Worked on repairs for rig. They replaced clutch handle, hydraulic pump, shuttle valve and fittings. We bypassed the shuttle and made the rig operational. Scopped derrick out and secured the guidelines. RD the Horsehead. RU the rig floor. 03/08/2014-Saturday Backed out stuffing box, LD polish rod. Prepped rig to pull rods. Pumped 10 gals of diesel and 10 bbls of lease water. TOOH w/Rod completion. The pull rod section of the pump parted where it threads into the plunger. LD the pull rods and sent pictures to town and Weatherford. MIRU SL, and Kelly hose to WL pump in sub. TIH w/1.75"TBG Hole Finder. Tag at 10,015' SLM. Set tool and primed rig pump. Pumped 12 bbls of lease water down to and pressured up to 1,500psi. Tested ok. POOH and RDMO SL. Set a BPV and ND PT and NU BOP's. 03/09/2014-Sunday Prep for BOPE test. Tested BOPE,Valves 250-3000psi, Rams 250-3000psi, Annular 250-3000psi. Witnessed by Lou Grimaldi, AOGCC. 2 FP on the Kill Line Hose. Performed Koomey Draw Down test with no failures. SICP 150psi. Hooked up Kelly hose to csg valve. Bleed down csg to rig pit. MU 2-7/8" pulling jts. PU on hanger to string weight and pulled hanger__The tbg anchor was not set. LD hanger and tbg was wet. MIRU EL. RIH w/1-11/16" tbg punch and CCL and tagged top of pump at 10,000'. PU 2' and punched holes in tbg. Waited for tbg to equalize and POOH. 03/10/2014- Monday TOOH 16 stand. Drug anchor up hole through the 5" liner. We had to pump water and rotate while TOOH. TOOH w/completion string. LD tbg anchor(damaged on top section of anchor), seat nipple with pump and cleaned out gas anchor. TIH w/completion w/BHA. Gas anchor, slotted sub, seat nipple, 1 jt 2-3/8" 8rd, 8.12" 2-3/8" 8rd pup, 1 jt 2-3/8" 8rd and tbg anchor. MU tbg hanger and landing jt. Landed hanger and secured lock down pins. Un-J out of hanger and spaced out 42". Set tbg anchor and J back into hanger. Landed with 16,000k in tension. LD landing jt. Set BPV and ND BOP's. NU PT and pulled BPV. 03/11/2014-Tuesday TIH wkew_1-1/2" pump and rods, MU a 2"_pony rod, rod bop's,stuffing box andpolished rod. Seated pump and spaced out 40" of bottom. MU a Kelly hose to the wing valve. Pumped 30bbls and pressured up to 200psi. SD pump. Started stroking rod pump with rig and pressured up on tbg to 700psi. Test ok. Bled off pressure. PU horsehead and bridal. Connected polish with rotator and load cell. Hookup the flowline to the tbg and csg. RDMO WOR and associated equipment. Production kicked off pumping unit at 22:00. THE STATE Stan Porhola GOVERNOR SEAN PARNELL Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 12A-04 Sundry Number: 314-073 Dear Mr. Porhola: LCL 4 �k iR G 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 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, eP. oerster Chair DATED this -0 day February, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 0 6 2014 �s 2(/ 9I- It 9- AOG CC 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing [] Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing ❑ Other: Rod Pump Repair ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 174-021 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 50-133-10103-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 1236 Will planned perforations require a spacing exception? Yes F-1❑ No Soldotna Creek Unit (SCU) 12A-04 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028996 Swanson River I Hemlock Oil 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): 10,880 - 10,878 10,798 10,796 10,588'& 10,69T ±10,586 Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22° 29' 29 Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8"x2-3/8" 6.4#/L-80 & 4.6#/N-80 10,119' Packers and SSSV Type: Baker FH/Baker FH/Baker FH/ Baker D Packers and SSSV MD (t) and TVD (ft): 10,691/10,651/10,583/10,136 MD No SSSV No SSSV 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ✓ Exploratory Stratigraphici I Development ✓ Service 14. Estimated Date for 15. Well Status after propsed work: Commencing Operations: 02/20/14 Oil ❑✓ Gas ❑ WI NJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Cortact Stan Porhola Phone: 907-777-8412 Email s orhola hilcor .com Printed Name Stan Porhola Title Operations Engineer CG Signatures Phone 907-777-8412 Date ab / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3kL4 - o -7 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ffiblA MAY 10 2014 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /10 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z 3 Form 10-403 Revise 0/2012 Ap4RII&I4412 months from the date of approval. Submit Form and Attachments in Duplicate llilcorp Alaska, LL, Well Prognosis Well: SCU 12A-04 Date: 2/06/2014 Well Name: SCU 12A-04 API Number: 50-133-10103-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: February 20`h, 2014 Rig: Moncla 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 174-021 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summa 1,280 psi @ 10,500' TVD 1,280 psi @ 10,500' TVD 0 psi (Static survey May 2013 mid pert of 10,500' MD) (Static survey May 2013 mid pert of 10,500' MD) (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 7,175 ft. TVD. Soldotna Creek 12A-04 was drilled as a sidetrack of SCU 12-04 in 1974 due to parted tubing and bad casing in the original wellbore. In 1975 the completion was pulled to re -perforate the original Hemlock perforations in the Hemlock H-8, H-9, and H-10 benches. Thru-tubing perfs were added in 1988 to access zones isolated between packers. A 1995 workover changed the upper part of the completion and perforated the Tyonek G2 zone. Thru-tubing perfs were added in 1998 that added the Hemlock H-1, H-2, and H-3 benches. A 2009 workover pulled the tubing due to an obstruction in the tubing and perforations were added to the H4/H5, the Tyonek G2 was re -perforated, and a new completion was ran into the well. The well was converted to rod pump in July 2013. A review of the recent Dynacards indicates the tubing anchor may not be set. if` Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect worn out pump or leaving standing valve). • Wellbore maximum deviation below sidetrack is less than 14 degrees. OBJECTIVE OF WORKOVER Pull and replace the downhole rod pump. Reset the tubing anchor. . WO Rig Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing. 2. MIRU Moncla #405 WO Rig. 3. Rig down Lufkin pumping unit head. Nipple up rod stripper head. - 4. Nipple up rod stripper head. 5. POOH polish rod and POOH EL rods. Rack back in rod baskets. 6. LD pump, investigate pump damage. 7. RU slickline, run press/temp survey down to 10,100'. POOH. 8. Drop standing valve to test tubing. Test tubing to 2,000 psi. Hilcorp Alaska, LL' Well Prognosis Well: SCU 12A-04 Date: 2/06/2014 a. If tubing tests good, re -run pump and rods. b. If tubing does not test good, plan to pull tubing. 9. RIH slickline, pull standing valve. 10. Set BPV. ND rod stripper head and tree. 11. NU BOPE and test to 250psi low/3,OOOpsi high (hold each valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24hrs in advance to witness, be ready to test when/if inspector arrives. b. Using 7-1/16" ROPE. 12. Pull tubing hanger free, unseat tubing anchor and POOH w/ tubing. 13. Rack back tubing string (2-7/8" TC -II x 2-3/8" TC -II). a. Inspect tubing for holes/worn joints. b. Inspect tubing anchor for damage/wear. 14. If tubing anchor is damaged, PU new tubing anchor. 15. RIH existing 2-7/8" TC -ll x 2-3/8" TC -II L-80 tubing. a. Set depth indicator sub at same depth, approx. 4,000'. 16. Set tubing anchor and land existing Seaboard tubing hanger. 17. Set TWC, ND ROPE, NU tree and test. Pull TWC. 18. NU Rod stripper. 19. PU 1-1/2" rod pump, RIH with existing 1-1/4" sinker bars and existing tapered EL rod string (3/4", 7/8" and 1"), space out the rods, install polish rod. 20. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 21. Rig up Lufkin pumping unit head and connect bridle to polished rod. 22. RD Moncla #405. 23. Return to production with same surface safety system as previously installed. 24. Replace IA x OA pressure gauge if removed (7" x 13-3/8"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Diagram Soldotna Creek Unit Well SCU 12A-04 Comletion j ACTUAL SCHEMATIC PTD: p 174-021 n: 7/31/2013 Hilroru Alae4a, LLC API: 50-133-10103-00 CASING DETAIL RKB = 14.83' Size Wt Grade Conn ID Top Btm A 1 22" 29' B C D Worn Out Pump 10 11 12 13 Tubing Perf _ 10,570'-10,575' 14 15 16 17 18 19 Possible leak _ 10,655'-10,675' 20 Tubing Pen` 21 10,735'-10,745' 22 2 3 6 7 8 9 22" 13-3/8" Fair Cmt Good Cmt 4 7" 5 G2 H1 H2 H3 UH8 MI -18 LH8 H9 UH10 LH10 5„ TD = 10,880'; ETD = 10,798' MAX HOLE ANGLE = 14deg Downhole Revised: 01/13/14 TUBING DETAIL 2-3/8" 4.6# N-80 I Butt 1.995" 10,520'_ 10,748' JEWELRY DETAIL No. Depth ID OD Item 1 18' - - - 2 13-3/8" 54.5# J-55 12.615" Surface 2,024' 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' 7" 23# N-80 6.366" 1,087' 4,857' 7" 26# N-80 6.276" 4,857' 6,704' 7" 29# P-110 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 1 10,880' TUBING DETAIL 2-3/8" 4.6# N-80 I Butt 1.995" 10,520'_ 10,748' JEWELRY DETAIL No. Depth ID OD Item 1 18' - - Tubing Hanger, Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp 2 4,011' 2.441" 5.000" 2-7/8" Depth Indicator Sub 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8" Crossover 4 8,397' 4.151" 5.000" Simplex Liner Hanger (Burns) 5 10,013' 1.930" 4.000" Tubing Anchor 6 10,048' 1.785" 2.375" Seating Nipple 7 10,049' 1.995" 2.375" Slotted Flow Sub 8 10,053' 1.995" 2.375" 2 joints 2-3/8" tubing, EUE 8RD (Gas Anchor) 9 10,118' - 2.500" Bull Plug 10 10,136' 1.991" - Packer, Permanent, Baker Mod. "D" 2-7/8" 11 10,188' 1.875" 2.70" HES'X' Nipple 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint, Brown "CC", Bottom half/Pin up 14 10,583' - - Packer, Retrievable, Baker Mod. "FH" 5"x2-3/8" 15 10,588' 1.875" - "S" Nipple, (Position No. 2) w/ PS plug installed (11-15-87) 16 10,647' 2.0" 3.094" Safety Joint, Brown "CC" 17 10,648' 1.875" - Otis "XA" Sliding Sleeve 18 10,651' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 19 10,657' 2.0" 3.094" Safety Joint, Brown "CC" 20 10,691' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 21 10,697' 1.791" "N" Nipple, w/ PN plug installed (11-12-87) 22 10,748' 1.995" WLEG ROD DETAIL No. Depth Length OD Item A 4' 26' 1-1/2" Polished Rod, 15' in well B 30' 16' 1" 1" x 6', 4', 2', 4' EL Pony Rods 46' 2,565' i" 1" x 25' EL Sucker rods w/ 4 XL guides per rod 2,621' 3,500' 7/8" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod 6,121' 1 3,350' 3/4" 1 3/4" x 25' EL Sucker rods w/ 4 XL guides per rod C 9,471' 550' 1-1/4" 1-1/4" x 25' K Bars (weight bars) D 10,021' 2.5' 1" 2" x 30" Stabilizer Bar w/ %" Pins E 10,023' 25' 1-1/2" 1-1/2" x 25' Insert Pump, RHBC Pump w/ PA Ring 80 PA Ring, Sand Seal, 2" x 1-1/2" x 24" x 24-1/2" x 25' RHBC F 10,048' 20' 1.315" Dip Tube, bottom 1' ported, bull plug on bottom Updated by STP 01/17/14 Soldotna Creek Unit Well SCU 12A-04 ACTUAL SCHEMATIC PTD:pletion 174 021an:7/31/2013 Hilrura Alaska. LLC API: 50-133-10103-00 PERFORATION HISTORY (DII-) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8" Millineum TO 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8" Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8", HC, 0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8", HC, 60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8", HC, 60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8" Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH 10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH 10 10,720' 10,745' 10,719' 1 10,744' 25' 4 Isolated by PS Plug Downhole Revised: 01/13/14 Updated by STP 01/17/14 Soldotna Creek Unit Well SCU 12A-04 PROPOSED SCHEMATIC PTD•osed 174021pletion Hilcoru Alaska. LLC API: 50-133-10103-00 CASING DETAIL RKB = 14.83' Size Wt Grade Conn ID Top Btm 22" 29' A s 1 B D E 10 11 12 13 Tubing Perf _ 10,570'-10,575' 14 15 16 17 18 19 Possible leak _ 10,655'-10,675' 20 Tubing Perf 21 10,735'-10,745' 22 22" —13-3/8- 2 Fair Cmt2-7, 2-3, 3 Good Cmt - 2-3, 4 7" 5 RESET 6 7 8 9 G2 H1 H2 H3 UH8 MH8 LH8 H9 UH10 LH 10 5„ TO =10,880'; ETD =10,798' MAX HOLE ANGLE = 14deg Downhole Proposed TUBING DETAIL 6.4# 1 L-80 I TC -II t 2.441" Surface 8,211' 4.6# L-80 TC -II 1.995" 8,211' 10,119' 4.6# N-80 Butt 1.995" 10,520' 10,748' JEWELRY DETAIL No. Depth ID OD Item 1 13-3/8" - 54.5# - J-55 - 12.615" Surface 2,024' 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' 7" 23# N-80 6.366" 1,087' 4,857' 7" 26# N-80 6.276" 4,857' 6,704' 7" 29# P-110 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' —13-3/8- 2 Fair Cmt2-7, 2-3, 3 Good Cmt - 2-3, 4 7" 5 RESET 6 7 8 9 G2 H1 H2 H3 UH8 MH8 LH8 H9 UH10 LH 10 5„ TO =10,880'; ETD =10,798' MAX HOLE ANGLE = 14deg Downhole Proposed TUBING DETAIL 6.4# 1 L-80 I TC -II t 2.441" Surface 8,211' 4.6# L-80 TC -II 1.995" 8,211' 10,119' 4.6# N-80 Butt 1.995" 10,520' 10,748' JEWELRY DETAIL No. Depth ID OD Item 1 18' - - Tubing Hanger, Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp 2 4,011' 2.441" 5.000" 2-7/8" Depth Indicator Sub 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8" Crossover 4 8,397' 4.151" 5.000" Simplex Liner Hanger (Burns) 5 10,013' 1.930" 4.000" Tubing Anchor (NEW OR REFURBISHED) 6 10,048' 1.785" 2.375" Seating Nipple 7 10,049' 1.995" 2.375" Slotted Flow Sub 8 10,053' 1.995" 2.375" 2 joints 2-3/8" tubing, EUE 8RD (Gas Anchor) 9 10,118' - 2.500" Bull Plug 10 10,136' 1.991" - Packer, Permanent, Baker Mod. "D" 2-7/8" 11 10,188' 1.875" 2.70" HES'X' Nipple 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint, Brown "CC", Bottom half/Pin up 14 10,583' - - Packer, Retrievable, Baker Mod. "FH" 5"x2-3/8" 15 10,588' 1.875" - "S" Nipple, (Position No. 2) w/ PS plug installed (31-15-87) 16 10,647' 2.0" 3.094" Safety Joint, Brown "CC" 17 10,648' 1.875" - Otis "XA" Sliding Sleeve 18 10,651' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 19 10,657' 2.0" 3.094" Safety Joint, Brown "CC" 20 10,691' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 21 10,697' 1.791" "N" Nipple, w/ PN plug installed (11-12-87) 22 10,748' 1.995" WLEG ROD DETAIL No. Depth Length OD Item A 4' 26' 1-1/2" Polished Rod, 15' in well B 30' 16' 1" 1" x 6', 4', 2', 4' EL Pony Rods 46' 2,565' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod 2,621' 3,500' 7/8" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod 6,121' 3,350' 1 3/4" 3/4" x 25' EL Sucker rods w/ 4 XL guides per rod C 9,471' 550' 1-1/4" 1-1/4" x 25' K Bars (weight bars) D 10,021' 2.5' 1" 2" x 30" Stabilizer Bar w/ %" Pins E 10,023' 25' 1-1/2" 1-1/2" x 25' Insert Pump, RHBC Pump w/ PA Ring (NEW) 80 PA Ring, Sand Seal, 2" x 1-1/2" x 24" x 24-1/2" x 25' RHBC F 10,048' 20' 1.315" Dip Tube, bottom 1' ported, bull plug on bottom Updated by STP 02/06/14 Soldotna Creek Unit Well SCU 12A-04 PROPOSED SCHEMATIC PTD:osed 174021 Completion Hilcoro AlaNka. LLf. API: 50-133-10103-00 PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8" Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8" Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8", HC, 0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8", HC, 60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 1 6 2-1/811, HC, 60 deg. 12/11/1998 1-14/1-15 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8" Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MI -18 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug 1,11-110 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH 10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH 10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Proposed Updated by STP 02/06/14 Hilrnrp :Vn.k:�. LLf. Swanson River 2014 Moncla Rig 405 Knight Oil Tools BOP 2 3/8 3 Yz variable 2 1/16 10M Kill Valves Manual and HCR 7 1/16 5000 Blind 2 1/16 1 O Choke Valves Manual and HCR CAMERON • 71/165000 • 2 1/16 10M Kill Valves Manual and HCR 7 1/16 5000 Blind 2 1/16 1 O Choke Valves Manual and HCR STATE ! ) rp�tt f- 1 s_ d E .L _ :_._��. z t J'.L.\,2: �_ ptt- f 333 vh'esi Seventh Avenue "%'` C C;VI:R OR ` ;1 N p:1I. f;i.l. Ancnc ace, Alaska 99501 3572 .2i '&. u �uw-a1R G�Ii �n' c :< satitIED MAY 1 6 2014 Stan Porhola /ie 0.2-4Operations Engineer I/ ` Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99504 Re: Swanson River Field, Hemlock Oil Pool, SCU 12A-04 Sundry Number: 314-051 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P'71144"--- Cathy P oerster Chair DATED this /=--/day of January, 2014. Encl. i ``� L� RECEIVED STATE OF ALASKA N. ALASKA OIL AND GAS CONSERVATION COMMISSION JAN Z2 � 01 1, 2014, I APPLICATION FOR SUNDRY APPROVALS ��CC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowl❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other: Replace Rod Pump Q • 2.Operator Name: r. Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑✓ 174-021 / 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10103-01- 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)12A-04 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 Swanson River/Hemlock Oil - 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): 10,880 ' 10,878 • 10,798 10,796 10,588'&10,697' ±10,586' Casing Length Size MD 7VD Burst Collapse Structural • Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade:6.4#/L-80, Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8"x2-3/8" 4.6f+t/L-80&N-80 10,119' Packers and SSSV Type: Baker FH/Baker FH/Baker FH/Baker D Packers and SSSV MD(t)and TVD(ft): 10,691/10,651/10,583/10,136 MD No SSSV No SSSV 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: 01/28/14 Commencing Operations: Oil ❑✓ • 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 Stan Porhola Phone: 907-777-8412 Email soorholatthiIcorD.com Printed Name Stan Porhola Title Operations Engineer Signature Ilk /"K/._____. Phone 907-777-8412 Date I 2/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: l 1-14) 1 Plug Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMSCIAIMAY ii 9 2014 Spacing Exception Required? Yes ❑ No IA Subsequent Form Required: 16_4 o'- APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date: 9-/4_ Submit Form and �' Form 10-403(Revised 10/2012) Approve I It�l I I r�r1 rlths from the atf-'27- i l' ze of approval. Attachm nts in Duplicate �� Well Prognosis Well: SCU 12A-04 Hilcorn Alaska,LLC Date: 1/21/2014 Well Name: SCU 12A-04 API Number: 50-133-10103-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: January 28th, 2014 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 174-021 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD) Maximum Expected BHP: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid pert of 10,500' MD) Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 7,175 ft. TVD. Brief Well Summary Soldotna Creek 12A-04 was drilled as a sidetrack of SCU 12-04 in 1974 due to parted tubing and bad casing in the original wellbore. In 1975 the completion was pulled to re-perforate the original Hemlock perforations in the Hemlock H-8, H-9, and H-10 benches.Thru-tubing perfs were added in 1988 to access zones isolated between packers.A 1995 workover changed the upper part of the completion and perforated the Tyonek G2 zone.Thru-tubing perfs were added in 1998 that added the Hemlock H-1, H-2, and H-3 benches.A 2009 workover pulled the tubing due to an obstruction in the tubing and perforations were added to the H4/H5,the Tyonek G2 was re-perforated, and a new completion was ran into the well.The well was converted to rod pump in July 2013. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect worn out pump or leaking standing valve). • Wellbore maximum deviation below sidetrack is less than 14 degrees. OBJECTIVE OF WORKOVER Pull and replace the downhole rod pump. Workover Rig Procedure: ✓1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. MIRU Moncla#405 WO Rig. 3. Rig down Lufkin pumping unit head. Nipple up rod stripper head. 4. LD polish rod and pull EL rods. Rack back the rods in basket. 5. LD and inspect pump and dip tube and all pulled rods. 6. PU existing dip tube and new 1-1/2"rod pump, replace and RIH with existing tapered rod string (sinker bars, 3/4",7/8" and 1),space out the rods, install polish rod. 7. ND rod stripper, install surface equipment onto well and test to 3,000 psi. II Well Prognosis Well: SCU 12A-04 Hilcory Alaska,LLC Date:1/21/2014 8. Rig up Lufkin pumping unit head and connect bridle to polished rod. 9. RD Moncla#405 WO Rig. 10. Return to production with same surface safety system as previously installed. 11. Replace IA x OA pressure gauge if removed (7"x 13-3/8"). Attachments: 1. Actual Schematic Soldotna Creek Unit Well SCU 12A-04 - • ti ACTUAL SCHEMATIC PTD p174 021 letion n:7/31/2013 Meant,Alaska,LIC API: 50-133-10103-00 CASING DETAIL RKB= 14.83' Size Wt Grade Conn ID Top Btm A 1 22" - - 29' 13-3/8" 54.5# J-55 12.615" Surface 2,024' 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' B 22" 7" 23# N-80 - 6.366" 1,087' 4,857' 7" 26# N-80 - 6.276" 4,857' 6,704' 7" 29# P-110 - 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' 13-3/8" TUBING DETAIL Ef! 2 Fair Cmt 2-7/8" 6.4# L-80 TC-ll 2.441" Surface 8,211' TC 0 ■ ' Good Cmt 2-3/8" 4.6# N 80 Butt 1.995" 0 520' 10,748' 3 JEWELRY DETAIL � 4 No. Depth ID OD Item 1.995" LC 1 18' - - Tubing Hanger,Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp D 2 4,011' 2.441" 5.000 2-7/8"Depth Indicator Sub 5 UNSET! 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8"Crossover 4 8,397' 4.151" 5.000" Simplex Liner Hanger(Burns) I5 10,013' 1.930" 4.000" Tubing Anchor(***UNSET***) E i 6 10,048' 1.785" 2.375" Seating Nipple 7 10,049' 1.995" 2.375" Slotted Flow Sub 6 8 10,053' 1.995" 2.375" 2 joints 2-3/8"tubing,EUE 8RD(Gas Anchor) 7 9 10,118' 2.500" Bull Plug joints 10 10,136' 1.991" - Packer,Permanent,Baker Mod."D"2-7/8" ki8 VI 11 10,188' 1.875" 2.70" HES'X'Nipple 9 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint,Brown"CC",Bottom half/Pin up 14 10,583' - - Packer,Retrievable,Baker Mod."FH"5"x2-3/8" 10 �� ►�� .4 15 10,588' 1.875" - "5"Nipple,(Position No.2)w/PS plug installed(11-15-87) 11 LI 1 16 10,647' 2.0" 3.094" Safety Joint,Brown"CC" 12 17 10,648' 1.875" - Otis"XA"Sliding Sleeve ►a G2 18 10,651' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" ;1.' H1 19 10,657' 2.0" 3.094" Safety Joint,Brown"CC" 20 10,691' - - Packer,Retrievable,Baker Mod."FH"5"x 2-3/8" ,;di H2 21 10,697' 1.791" - "N"Nipple,w/PN plug installed(11-12-87) llo 22 10,748' 1.995" - WLEG H3 13 — I'll .41 UH8 ROD DETAIL Tubing Perf • -; MH8 No. Depth Length OD Item 10,570'-10,575' A 4' 26' 1-1/2" Polished Rod,15'in well 14 2 0 1 B 30' 16' 1" 1"x 6',4',2',4'EL Pony Rods 15 © LH8 46' 2,565' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod a 2,621' 3,500' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod y1. 16 6,121' 3,350' 3/4" 3/4" „ H9 x 25'EL Sucker rods w/4 XL guides per rod C 9,471' 550' 1-1/4” 1-1/4 x 25'K Bars(weight bars) 17 D 10,021' 2.5' 1" 2"x 30"Stabilizer Bar w/'"Pins 18 '4 '4 E 10,023' 25' 1-1/2" 1-1/2"x 25'Insert Pump,RHBC Pump w/PA Ring 19 80 PA Ring,Sand Seal,2"x 1-1/2"x 24"x 24-1/2"x 25' RHBC Possible leak --1.. UH10 F 10,048' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom 10,655'-10,675' 20 2 ►moi, "" Tubing Perf 21 c 10,735'-10,745' a LH 10 22 -' i - 4: 5„ TD=10,880';ETD=10,798' MAX HOLE ANGLE=14deg Downhole Revised:07/31/13 Updated by STP 08/15/13 Soldotna Creek Unit r Well SCU 12A-04Conn letion 7/31/2013 SCHEMATIC PTD: 174-021 Hikora Alaska.LLC API: 50-133-10103-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' _ 10,313' 10,283' 10,312' 29' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8"Millineum TCP 8/17/2009 G2 10,324' 10,350' _ 10,323' 10,349' 26' 12 2-1/8"EJ,90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8"Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8",HC,0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8",HC,60 deg. 12/11/1998 _H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8",HC,60 deg. 12/11/1998 H4/H5 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8"Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 _ 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Downhole Revised:07/31/13 Updated by STP 08/15/13 THE STATE GOVERNOR SEAN PARNELL January 14, 2014 CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7009 2250 0004 3911 3545 Mr. Luke Saugier N. Kenai Asset Team Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Re: Defeated Safety Valve System Missing Annulus Valves SN Swanson River Field Dear Mr. Saugier: Aiacka. s01 -U a,nd Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 On December 9, 2013 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector accompanied by Hilcorp Alaska LLC (Hilcorp) representatives performed safety valve system inspections at well sites within the Swanson River Field, Soldotna Creek Unit (SCU). Two wells equipped with rod pumps — namely SCU 12A-04 (PTD 1740210) and SCU 41A-08 (PTD 1940850) — were found to have the controller in bypass mode, preventing the pump from tripping (i.e., the low pressure actuating device was found defeated). Also during the AOGCC inspections, SCU 24A-09 (PTD 1750220) was observed to be without a pressure gauge to monitor the outer annulus. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system and failure to equip wells with the required pressure gauges. Each is a violation of State regulations. Please note that this is a second notice regarding SCU wells with defeated surface safety systems and a missing OA pressure gauge. The AOGCC Inspector's report indicates that the controllers were placed back in service for SCU 12A-04 and SCU 41A-08 and both subsequently passed the required tests (tripping the pump offline at a pressure in compliance with AOGCC regulation). Hilcorp is reminded that 20 AAC 25.265 requires a completed well to be equipped with a functional safety valve system. By letter dated September 24, 2013 AOGCC approved a variance for all Swanson River Unit wells that are equipped with rod pumps allowing them to operate with an alternate surface safety system; in lieu of a surface safety valve, approval was granted for the use of "functionally equivalent components that are common to rod pump wells that automatically terminate production from the well" as provided by 20 AAC 25.265(o)(1). Notice of Violation — Swanson River Field January 14, 2014 Page 2 of 3 AOGCC recognizes there may be legitimate operating reasons for defeating a well safety valve system. Paragraph (m) of 20 AAC 25.265 establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was no tag observed on either well that would indicate an inoperable safety system for the rod pump wells. Regulation 20 AAC 25.200(c) requires wellhead equipment to include appropriate gauges and valves installed in the tubing, casing -tubing (inner) annulus, and casing -casing (outer) annuli. AOGCC records indicate SCU 24A-09 was worked over to replace the tubing and perforate with work completed and production commencing in February 2013. The reason for delaying the installation of required pressure monitoring equipment is unclear. Hilcorp is directed to accomplish the following actions within 14 days of receipt of this letter: - install an appropriate outer annulus pressure gauge on SCU 24A-09; - provide AOGCC with an explanation of how these non -compliances happened and what has been or will be done in the future to prevent recurrence at Hilcorp-operated well sites in Alaska. The AOGCC reserves the right to pursue enforcement action in connection with the defeated surface safety systems on SCU 12A-04 and SCU 41A-08 and the missing outer annulus pressure gauge on SCU 41A-09 as provided by 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, CathyP. oerster Chair, C mmissioner Attachment cc: P. Brooks AOGCC Inspectors Notice of Violation — Swanson River Field January 14, 2014 Page 3 of 3 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further tie as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. THE STATE Alaska Oil and Gas ofALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 September 23, 2013 Mr. Chad Helgeson Operations Manager, North Kenai Area Hilcorp Alaska, LLC -• P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Soldotna Creek Unit 12A-04 WAS PTD 1740210 Dear Mr. Helgeson: On August 9, 2013 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Soldotna Creek Unit 12A-04. The well is operated by Hilcorp Alaska, LLC (Hilcorp), completed as an artificially -lifted producer that relies on a rod pump system to bring production to surface. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to the well and for flow to surface. The well was being produced upon arrival by the AOGCC Inspector for the no -flow tests; it was immediately shut in and well pressures bled before opening up to for the flow monitoring period. The Inspector observed a series of flow periods and shut-ins during which time no liquid production was observed and gas production — measured through the no -flow meter — was at rates less than 900 standard cubic feet per hour. Soldotna Creek Unit 12A-04 meets the AOGCC requirements for a no -flow status determination. Hilcorp requested a safety valve system variance for its rod pump wells located in the Swanson River Field (Swanson River Unit and Soldotna Creek Unit) by letter dated December 31, 2012. In lieu of a surface safety valve (as required by 20 AAC 25.265), Hilcorp requests AOGCC consider an alternate configuration for well control equipment supported by the approved no flow status. The AOGCC decision regarding a required surface safety valve for Soldotna Creek Unit 12A-04 will be addressed in response to Hilcorp's variance request. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 11A-11".14, ' W'1:4P Al1G 2 7 2013 1. Operations Abandon Repair Well LJ Plug Perforations LJ Perforate LJ Other : Run Rod Pump Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Completion Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development ❑✓ Exploratory ❑ 5. Permit to Drill Number: 174-021 Stratigraphic ❑ Service ❑ 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99504 50-133-10103-01 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028996 Soldotna Creek Unit (SCU) 12A-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 10,880 feet Plugs measured 10,588 & 10,697 feet true vertical 10,878 feet Junk measured ±10,586 feet 10,136; 10,583; Effective Depth measured 10,798 feet Packer measured 10,651; 10,691 feet true vertical 10,796 feet true vertical 10,134; 10,581; feet 10,649; 10,689 Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 4.6# / L-80 10,220' MD 10,218' TVD Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.6# L-80 & N-80 10,520'-10,748' MD 10,518'-10,746' TVD Baker FH/Baker FH/ 10,136'MD; 10,583' MD; 10,134'TVD; 10,581'TVD; Packers and SSSV (type, measured and true vertical depth) Baker FH/Baker D; N/A 10,651' MD; 10,691'MD 10,649'TVD; 10,689'TVD N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A SCANNED SEP 2 4 2013 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 36 66 8 1 800 280 Subsequent to operation: 30 206 135 180 148 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: GSTOR ❑ WINJ Oil El Gas LJ WDSPL ❑ 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: 313-347 Contact Stan Porhola Email S orholalp7_hllcorp.com Printed Name Stan Porhola Title Operations Engineer Signature l Phone 907-777-8412 Date � T�� 13 Form 10-404 Revised 10/2012 l �lj/I-1�'13 RBDMS SEP - 4 2 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 12A-04 50-133-10103-01 174-021 7/26/13 1 7/31/13 Daily Operations: 07/26/2013 - Friday Install power system for pumping unit. 07/27/2013 -Saturday Completing electrical work on the unit. MIRU WOR and equipment, laid containment and seals. Pumped 280bbls of PW to fill well. Circulated well clean. SI tbg and pressured up to 1,500psi and charted for 30mins. Set BPV and ND PT. NU BOPS. MIRU SL, RIH w/2" JDC and latched prong at 10,130'wlm. POOH w/prong. RIH w/same and latched px plug. POOH w/plug. RDMO SL. Secure well and SDFN. 07/28/2013 -Sunday Waited for 3 hrs to hear from the AOGCC for the okay to start BOP testing. Tested BOPE (witness waived by Lou Grimaldi, AOGCC), annular 250-1500psi, valves 250-3,000psi, rams 250-3,000psi. Charted for 10mins. Function tested Koomey unit and gas detection. Prepped rig to pull pipe. PU on pulling jt and released hanger weighing 49k. Did not see seal assembly pull free with weight indicator. L/D tbg hanger. TOOH w/30 stands of 2-7/8" 6.4# TC -II connection and .25"control line. Secured well and SDFN. 07/29/2013 - Monday Continued TOOH w/60 stands of 2-7/8" 6.4# TC -II and .25" control line. With the tbg string weighing 18k we PU 7" RTTS and TIH to 60'. Set RTTS and tested to 1,500psi for 15 mins. RD rig floor and ND BOP stack Installed new tbg head and accessories. NU BOP stack and shell tested o 3,000psi for 5 mins. RU rig floor and prep rig to pull pipe. Secured well and SDFN. 07/30/2013 -Tuesday Continue TOOH w/ completions, 256 jts of 2-7/8" TC -II, 56 jts of 2-3/8" TC -II, 9 GLM, chemical injection mandrel, XD sliding sleeve, seal assmbly and 8,252' of .25" control line. PU a bull plug, 2 jts of 2-3/8" EUE, slotted sub, seat nipple, 1 jt of 2-3/8" EUE, 5" tbg anchor and XO 2-3/8" TC -II box x 2-3/8" EUE pin. TIH w/BHA and 56 jts of 2-3/8" TC -II, XO 2-7/8" TC -II box x 2- 3/8" TC -II pin, 261 jts of 2-7/8" TC -II, 1.88' 2-7/8" TC -II pup jt, XO 2-7/8" IBT box x 2-7/8" TC -II pin and a tbg hanger (2-7/8" IBT box x box). Landed tbg hanger. Turn 1/4" to right and drop thru parent bowl. Pipe weight at 46k. Set tbg anchor @ 10,012', PU 3-1/2' and landed hanger thru parent bowl with pipe weight at 63k. Tbg hanger set at 17k in tension. MIRU SL, RIH w/1.75" hole finder plug. Tag seat nipple at 10,058'. PU 10 and set the plug. RU pump, pumped 40 bbls and pressured up on tbg to 1,000psi. Held for 15 mins. Bled pressure to 0 psi. Released plug and POOH. RDMO SL. Installed a BPV. Secured well and SDFN. 07/31/2013 - Wednesday RD rig floor. ND BOPs and NU PT. Pulled BPV and tested PT. RU floor and prepped rig to run rods. TIH w/ 25'x 1-1/2" sand seal pump, 30" x 1" stabilizer rod, 22 1.25" K bars, 134 3/4" EL rods, 140 7/8" EL rods, 103 1" EL rods, 6', 4', 2', 4' pony rods and 26' polish rod. Installed stuffing box, landed pump and tested to 500psi. Spaced out pump 24" of bottom. Set rod clamps and stacked out rod. Secured well and SDFN. Soldotna Creek Unit Well SCU 12A-04 Completion Ran: 7/31/2013 ,V -,ACTUAL SCHEMATIC PTD: 174-021 Hilcoru Alneka. I,Lf. API: 50-133-10103-00 CASING DETAIL RKB = 14.83' Size Wt Grade Conn ID Top Btm AM 1 22" 29' 13 Tubing Perf _ 10,570'-10,575' 14 15 16 17 18 19 Possible leak _ 10,655'-10,675' 20 Tubing Perf 21 10,735'-10,745' 22 22" " 13-3/8" Fair Cmt Good Cmt 4 7" 5 UNSET!' G2 H1 H2 H3 UH8 MH8 LH8 H9 UH10 LH10 5„ TD = 10,880'; ETD = 10,798' MAX HOLE ANGLE = 14deg Downhole Revised: 07/31/13 TUBING DETAIL F 2-3/8" 1 4.6# I N-80 Butt _ 1 1.995" 1 10,520'1_ 10,748_ J JEWELRY DETAIL No. Depth ID OD Item 1 13-3/8" 54.5# - J-55 - 12.615" Surface 2,024' 7" 29# N-80 6.184" Surface 324' 7" 26# N-80 6.276" 324' 1,087' 7" 23# N-80 6.366" 1,087' 4,857' 7" 26# N-80 6.276" 4,857' 6,704' 7" 29# P-110 6.184" 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,397' 10,880' TUBING DETAIL F 2-3/8" 1 4.6# I N-80 Butt _ 1 1.995" 1 10,520'1_ 10,748_ J JEWELRY DETAIL No. Depth ID OD Item 1 18' - - Tubing Hanger, Seaboard 2-7/8 IBT lift x 2-7/8 IBT susp 2 4,011' 2.441" 5.000" 2-7/8" Depth Indicator Sub 3 8,211' 1.995" 2.875" 2-7/8"x2-3/8" Crossover 4 8,397' 4.151" 5.000" Simplex Liner Hanger (Burns) 5 10,013' 1.930" 4.000" Tubing Anchor (***UNSET***) 6 10,048' 1.785" 2.375" Seating Nipple 7 10,049' 1.995" 2.375" Slotted Flow Sub 8 10,053' 1.995" 2.375" 2 joints 2-3/8" tubing, EUE 8RD (Gas Anchor) 9 10,118' - 2.500" Bull Plug 10 10,136' 1.991" - Packer, Permanent, Baker Mod. "D" 2-7/8" 11 10,188' 1.875" 2.70" HES'X' Nipple 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint, Brown "CC", Bottom half/Pin up 14 10,583' - - Packer, Retrievable, Baker Mod."FH" 5"x2-3/8" 15 10,588' 1.875" - "S" Nipple, (Position No. 2) w/ PS plug installed (11-15-87) 16 10,647' 2.0" 3.094" Safety Joint, Brown "CC" 17 10,648' 1.875" - Otis "XA" Sliding Sleeve 18 10,651' - - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 19 10,657' 2.0" 3.094" Safety Joint, Brown "CC" 20 10,691' - Packer, Retrievable, Baker Mod. "FH" 5"x 2-3/8" 21 10,697' 1.791" "N" Nipple, w/ PN plug installed (11-12-87) 22 10,748' 1.995" WLEG Rnn nFTAII No. Depth Length OD Item A 4' 26' 1-1/2" Polished Rod, 15' in well B 30' 16' 1" 1" x 6', 4', 2', 4' EL Pony Rods 46' 2,565' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod 2,621' 3,500' 7/8" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod 6,121' 3,350' 3/4" 3/4" x 25' EL Sucker rods w/ 4 XL guides per rod C 9,471' 550' 1-1/4" 1-1/4" x 25' K Bars (weight bars) D 10,021' 2.5' 1" 2" x 30" Stabilizer Bar w/ %" Pins E 10,023' 25' 1-1/2" 1-1/2" x 25' Insert Pump, RHBC Pump w/ PA Ring 80 PA Ring, Sand Seal, 2" x 1-1/2" x 24" x 24-1/2" x 25' RHBC F 10,048' 20' 1.315" Dip Tube, bottom 1' ported, bull plug on bottom Updated by STP 08/15/13 Soldotna Creek Unit Well SCU 12A-04 Comletionr ACTUAL SCHEMATIC PTD: p174021an: 7/31/2013 xa�"� nlea�a, LLC API: 50-133-10103-00 PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3-1/8" Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2-1/8" E1, 90 deg. 6/9-7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3-1/8" Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2-1/8", HC, 0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2-1/8", HC, 60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2-1/8", HC, 60 deg. 12/11/1998 1-14/1-15 10,452' 10,503' 10,451' 10,502' 51' 6 3-1/8" Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MI -18 10,561' 10,581' 10,560' 10,580'V23'4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605'Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646'Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686'Isolated by PS Plug LH 10 10,697' 10,710' 10,696' 10,709'Isolated by PS Plug LH 10 10,720' 10,745' 10,719' 10,744'Isolated by PS Plug Downhole Revised: 07/31/13 Updated by STP 08/15/13 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -(6 12-31(3 DATE: August 09, 2013 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Verification Petroleum Inspector Hilcorp Alaska LLC SCU 12A-04 PTD #1740210 satee LL iu1`` Soldotna Creek Unit Friday, August 09, 2013: I witnessed the No-Flow test on Hilcorp's Soldotna Creek Unit 12A-04 in the Swanson River field. This test was performed today in conjunction with routine SVS and another No Flow test on SCU 12A-03. The well numbers are deceiving as the two wells are a few miles from each other and definitely not on the same pad. Marty Guth (Instrument Tech) and Micah Robertson (Production Operator) performed the tests today. The flow rates were read on a new, factory calibrated, Erdco, Armor- Flo resistance style gas flow meter, range of 150 scf-1500 scf and a 30 psi test gage w/0.1 psi increments having a current calibration. The well is lifted by a reciprocating rod pump driven by one of the new Lufkin - beam style jacks that Hilcorp has brought to the Swanson Field. The well was being lifted when I arrived with approximately 150 psi on the tubing and 130 psi on the annulus. The annulus was in communication with the tubing. I had Chris Walgenburg (Field Lead) turn the pump drive off and start bleeding the tubing/annulus to an open top tank that was staged next to the well. I moved on to the other well needing a no-flow test and allowed this well to be bled to the tank while I was gone. When I returned I lined the tubing/annulus up to the flow meter and observed a 1:45 hour flow period that was somewhat stable at 500 scf/hour at 0.7 psi. I felt . this may have been the inflow from the formation and decided to shut the well in for buildup and allow the well to stabilize. After 3 hours shut-in the well was "blown down" to the open top tank for exactly five minutes at which time the flow was routed through the flow meter. The flow and pressure were below measurable range with flow being a bare whisper. I observed this condition for one hour at which time I released the well to be put back into production. The well exhibited proper parameters for a no-flow status. The following table contains the steps, pressures and flow rates observed. 2013-0809_No-Flow_SCU_12A-04_lg.docx 1 of 3 . • • Time Notes Pressure Flow Rate 11:15 Flowing Through Meter <0.1 11:25 Flowing Through Meter 0.1 11:30 Flowing Through Meter 1 11:35 Flowing Through Meter 1 11:40 Flowing Through Meter 1 g Through Meter 0.9 - Flowin Throu 11:45 g 11:50 Flowing Through Meter 0.8 11:55 Flowing Through Meter 0.7 12:00 Flowing Through Meter 0.7 12:05 Flowing Through Meter 0.7 13:00 Flowing Through Meter/Shut-in for buildup 0.6/0.8 - --- 13:45 Shut In for Buildup 1.4 --- 14:00 Shut In for Buildup 1.6 --- 14:15 Shut In for Buildup 1.8 --- 15:15 Shut In for Buildup 2.6 " --- 16:55 Shut In for Buildup/Open to Tank 5 minutes 4.0 --- 17:00 Flowing Through Meter 0 Whisper 17:15 Flowing Through Meter 0 Whisper 17:30 Flowing Through Meter 0 Whisper 18:00 Flowing Through Meter 0 Whisper ' Attachments: 2 photos Non-Confidential 201 3-0809_No-Flow_SCU_12A-04_lg.docx 2 of 3 r • • • No Flow Test— SCU 12A-04 (PTD 1740210) Photos by AOGCC Inspector L. Grimaldi 9/9/2013 s n• �y +� Silto -� l '` Reciprocating Rod v� Pump Unit—Lufkin• Beam-style Jack ``A — .. We 'Tve --tea a^ • _ ,.... ^ • .�t No Flow Test va :,. ¢ t, Equipment .;,....:- ,,,''•' ..\ 0.0e* \ **10:'"): . ii,!Ill;itirr----- il ' (c,--..!.._.:77,-......)41 , r:, . 201 3-0 809_No-F low_S CU_12 A-04_lg.docx 3 of 3 ` • • �w I I /j 4∎ THE STATE k Oil and Gas "..3.-.•--- '��s ® f Conservation Commission _ ALAS G OVERNOR SEAN PARNELL 333 West Seventh Avenue = O Q. Anchorage, Alaska 99501 -3572 ALA SCANNED JUL r t � Main: 907.279.1433 2Q 3 Fax: 907.276.7542 Stan Porhola Operations Engineer /�� ©� r Hilcorp Alaska, LLC j /7" f- r 3 800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 12A -04 Sundry Number: 313 -347 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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. S' • _: - d i ( t�0 an 'o ssione DATED this Y day of July, 2013. Encl. • �� . f ' i, �� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20AAC25.280 '' ;s '{ 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wei❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tube ° Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Wel El Stimulate ❑ After CasinE Other Run Rod Pump Completion el 2. Operator Name: 4. Current Well Class: 5. Permit to Ord Number. Hilcorp Alaska, LLC 021 ° Exploratory ❑ Development p ° 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number Anchorage, Alaska 99503 50 ° 7. If perforating: 8. Wet Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C0123A ° Soldofie Creek Unit (SCU) 12A - 04 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028996 Swanson River / Hemlock Od • 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): 10,880 ° 10,878 , 10,798 10,796 10,588' & 10,697' ±10,586' Casing Length Size MD TVD Burst Collapse Structural Conductor 29, 22' 29' 29' Surface 2,024' 13 - 3/8" 2,024' 2.024 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 6.4#/L -80, Tubing MD (ft): See Attached Schematic See Attached Schematic 2 - 7/8 "x2 - 3/8" 4.6#/L -80 & N-80 10,220' Packers and SSSV Type: Baker FH /Baker FH /Baker FH/ Baker D Packers and SSSV MD (t) and TVD (ft): 10,691/10,651/10,583 /10,136 MD No SSSV No SSSV 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development Fr Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 07/12/13 Oil Ei ° 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 Stan Particle Phone: 907 - 777-8412 Email spQola©hjlcorp.cofJ Printed Name Stan � P l orrhhhola Title Operations Engineer f / Signature s . >v / / / / ", ' ' Phone 907 - 777-8412 Date / D l 1 7 ? COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 34 1 Plug Integrity ❑ BOP Test Lm Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3 - 136 P �s *- ot�a psi: c; ' t RBDMS JUL - 3 ': Spacing Exception Required? Yes ❑ No C Subse. ent Form Required: / 6- Yo 1 APPROVED BY �� Approved by: go ,. % MISSIONER THE COMMISSION Date: i ` Z � Submit Form and t° Form 10 -403 (Revised 10/2012) A: IC i li t* 1fal�l `" L Lr 1S- mtonths from the d of approval. Attachments in uplicate / V • • Well Prognosis Well: SCU 12A-04 Hilcorp Alaska, LL Date: 7/01/2013 Well Name: SCU 12A -04 API Number: 50- 133 - 10103 -01 Current Status: Gas Lifted Oil Well Leg: N/A Estimated Start Date: July 12, 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 174 -021 First Call Engineer: Stan Porhola (907) 777 -8412 (0) (907) 331 -8228 (M) Second Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) AFE Number: 1321712 Current Bottom Hole Pressure: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid perf of 10,500' MD) Maximum Expected BHP: — 1,280 psi @ 10,500' TVD (Static survey May 2013 mid pert of 10,500' MD) Max. Allowable Surface Pressure: — 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi /ft) will balance reservoir pressure at 7,175 ft. TVD. Brief Well Summary Soldotna Creek 12A -04 was drilled as a sidetrack of SCU 12 -04 in 1974 due to parted tubing and bad casing in the original wellbore. In 1975 the completion was pulled to re- perforate the original Hemlock perforations in the Hemlock H -8, H -9, and H -10 benches. Thru- tubing perfs were added in 1988 to access zones isolated between packers. A 1995 workover changed the upper part of the completion and perforated the Tyonek G2 zone. Thru- tubing perfs were added in 1998 that added the Hemlock H -1, H -2, and H -3 benches. A 2009 workover pulled the tubing due to an obstruction in the tubing and perforations were added to the H4 /H5, the Tyonek G2 was re- perforated, and a new completion was ran into the well. Notes Regarding Wellbore Condition • Well is currently producing on gaslift at 30 BOPD and 10 BWPD. r' • Wellbore maximum deviation below sidetrack is less than 14 degrees. OBJECTIVE OF WORKOVER Pull current gas lift completion and convert the well to rod pump artificial lift. Work -Over Rig Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. MIRU Williams 405 WO Rig. 3. Pump produced water (8.5 ppg) down tubing and annulus. 4. Set TWC or test plug in Shaffer tubing hanger, ND tree, NU BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high (hold each valve and test for 10 -min). Record accumulator pre- charge pressures and chart tests. a. Notify AOGCC 24hrs in advance to witness, be ready to test when /if inspector arrives b. Notify BLM 48 hrs in advance of BOP test -/ 5. Remove TWC, shoot fluid level (echometer) on casing and tubing. • • Well Prognosis Well: SCU 12A -04 Hilcorp Alaska, LL Date: 7/01/2013 6. Pump produced water (8.5 ppg) down tubing and annulus. 7. Pull tubing hanger free and tubing out of seal assembly of Model "D" packer. 8. Rack back tubing string (2 -7/8" and 2 -3/8" TC -II tubing). LD jewelry. 9. PU 7" retrievable bridge plug and set at.§' using existing 2 -7/8" TC -II L -80 tubing, POOH. 10. Test plug to 1,500 psi. 1°1 pDO pr ..) 6 / SC) o psi. /.? 11. ND BOPE. ND Shaffer tubing head. C� �� ;� A 12. NU new Seaboard tubing head. Test tubing head to 5,000 psi. D_ 13. NU BOPE and shell test to 250 psi low /3,000 psi high (test all flanges that were separated). 14. Unseat retrievable bridge plug. Monitor well for 15 mins. 15. POOH and LD retrievable bridge plug. 16. RIH w/ existing 2 -7/8" TC -II L -80 tubing and 2 -3/8" TC -II L -80 tubing with the following BHA. (bull plug, 60ft of blank 2 -3/8" 8rd EUE tubing, slotted flow sub, cup type pump seating nipple (approx. 10,029'), 2 -3/8" 8rd EUE tubing, Weatherford tu anchor (approx. 9,970'), and depth indicator sub (approx. 4,0001. 17. Land new Seaboard tubing hanger with tubing in tension (approx. 15,000 #'s). 18. Set TWC, ND BOPE, NU flow cross and test. 19. NU Rod stripper. 20. PU 20ft dip tube, new 1.50" rod pump, RIH with tapered rod string (3/4 ", 7/8" and 1 "), Inspect rods and guides (4 rods per guide), land the pump, space out the rods, install polish rod. 21. ND rod stripper. 22. RD Williams #405. P" J Lock • Te d °i 23. Rig up new Lufkin pumping unit, couple, and remove LOTOon motor. 4_67 24. Return to production. 25. Notify AOGCC to conduct a no flow test on the well after it has flowed for 5 days and stable production. A c6cc c .,,; :ALsr -e.4 S7/S Attachments: 1. As -built Schematic 2. As -built Wellhead 3. Proposed Schematic 4. Proposed Wellhead 5. BOP Schematic • • • Well SCU 12A 04 Soldotna Creek Unit ti ACTUAL SCHEMATIC Actual 174 -021 Completion: 08/21/09 PTD Nikon, Alaska, LLC API: 50- 133 - 10103 -00 CASING DETAIL RKB = 14.83' Size Wt Grade Conn ID Top Btm 1 " 22" - - - 29 ' I 13 -3/8" 54.5# 29# J -55 N -80 N -80 12.615" Surface 2,024' - 2 7" 6.184" Surface 324' 7" 26# 6.276" 324' 1,087' 22" 7" 23# N -80 6.366" 1,087' 4,857' 7" 26# N -80 - 6.276" 4,857' 6,704' 7" 29# P -110 6.184" 6,704' 8,597' 5" 18# N -80 EL, LT &C,Butt 4.151" 8,397' 10,880' POI 13-3/8" TUBING DETAIL 2 -7/8" 6.4# L -80 TC -II 2.441" Surface 8,209' 2 -3/8" 4.6# L -80 TC -II 1.995" 8,209' 10,220' Fair Cmt 2 -3/8" 4.6# N -80 Butt 1.995" 10,520' 10,748' JEWELRY DETAIL I No. Depth ID OD Item 1 16' 2.485" Tubing Hanger, Shaffer -AJO 7x2 -7/8 BTC lift x 2 -7/8 TC -2 cusp 2 2,488' 2.347" 4.75/4.0" 2 -7/8" SFO -1 GLM w/ BK -2 latch & TRO 1,367 I 3,980' 2.347" 4.75/4.0" 2 -7/8" SFO -1 GLM w/ BK -2 latch & TRO 1,351 y.1 5,200' 2.347" 4.75/4.0" 2 -7/8" SFO -1 GLM w/ BK -2 latch & TRO 1,337 ood Cmt 6,292' 2.347" 4.75/4.0" 2 -7/8" SFO -1 GLM w/ BK -2 latch & TRO 1,325 7,289' 2.347" 4.75/4.0" 2 -7/8" SFO -1 GLM w/ BK -2 latch & TRO 1,314 3 8,192' 2.347" 4.75/4.0" 2 -7/8" SFO -1 GLM w/ BK -2 latch & TRO 1,346 3 8,209' 1.983" 3.211" 2- 7/8 "x2 -3/8" Crossover 4 A5 ' 7" 4 8,252' 1.901" 3.875/2.9" 2 -3/8" BST GLMAX-1 Chemical Injection Mandrel 5 8,397' 4.151" 5.0" Simplex Liner Hanger (Burns) a r 6 6 8,887' 1.901" 3.875/2.9" 2 -3/8" BST GLMAX -1 SC GLM w/ BK -2 latch & TRO 1,337 ""' 9,561' 1.901" 3.875/2.9" 2 -3/8" BST GLMAX -1 SC GLM w/ BK -2 latch & TRO 1,331 10,035' 1.901" 3.875/2.9" 2 -3/8" BST GLMAX -1 SC GLM w/ BK -2 latch & Orifice valve 7 10,120' 1.875" 3.250" HES XD Sliding Sleeve 78 141 ►�i 8 10,136' 1.991" - Packer, Permanent, Baker Mod. "D" 2 -7/8" 9 © 9 10,188' 1.875" 2.70" HES 'X' Nipple 10 - fi 10 10,220' 1.997" 3.50" WLEG G2 11 10,520' 2.0" 3.094" Safety Joint, Brown "CC ", Bottom half /Pin up J 12 10,583' - - Packer, Retrievable, Baker Mod. "FH" 5 "x2 -3/8" ° H1 .;,' 13 10,588' 1.875" - "S" Nipple, (Position No. 2) w/ PS plug installed (11- 15 -87) H2 14 10,647' 2.0" 3.094" Safety Joint, Brown "CC" ... 15 10,648' 1.875" - Otis "XA" Sliding Sleeve , , H3 16 10,651' - - Packer, Retrievable, Baker Mod. "FH" 5 "x 2 -3/8" 11 ,. UH8 17 10,657' 2.0" 3.094" Safety Joint, Brown "CC" 18 10,691' - - Packer, Retrievable, Baker Mod. "FH" 5 "x 2 -3/8" Tubing Perf _, w ;, MH8 19 10,697' 1.791" - "N" Nipple, w/ PN plug installed (11- 12 -87) 10,570'-10,575' ' ' 20 10,748' 1.995" - WLEG 12 © A PERFORATION HISTORY (DIL) 13 . LH8 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date 4 G2 10,284' 10,313' 10,283' 10,312' 29' 12 2 -1/8" EJ, 90 deg. 6/9- 7/20/95 14 H9 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3 -1/8" Millineum TCP 8/17/2009 15 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2 -1/8" EJ, 90 deg. 6/9- 7/20/95 0 _ '33 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3 -1/8" Millineum TCP 8/17/2009 16 I 4 e, H1 10,391' 10,399' 10,390' 10,398' 8' 6 2 -1/8 ", HC, 0 deg. 12/11/1998 17 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2 -1/8 ", HC, 60 deg. 12/11/1998 ite Possible leak - H3 10,451' 10,459' 10,450' 10,458' 8' 6 2 -1/8 ", HC, 60 deg. 12/11/1998 UH10 10,655'- 10,675' #A H4 /H5 10,452' 10,503' 10,451' 10,502' 51' 6 3 -1/8" Millineum TCP 8/17/2009 + UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus '�" MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus 18 2 0/5 LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug © gr H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug Tubing 0 19 UH10 10,657' 10,687' 10,656' 10,686' 30' 4 Isolated by PS Plug 10,735' - 10,,7 745' LH 10 20 l LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug - LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug 5 „ TD = 10,880'; ETD = 10,798' MAX HOLE ANGLE = 14deg Downhole updated: 08 -21 -09 Updated by STP 07 -01 -13 • • • Soldotna Creek Unit Well SCU 12A -04 PROPOSED SCHEMATIC PTD Hilcora Alaska. LLC API: 50- 133 - 10103 -00 CASING DETAIL RKB = 14.83' Size Wt Grade Conn ID Top Btm L � 22" - 29 ' - 13-3/8" 54.5# 1-55 12.615" Surface 2,024' 7" 29# N -80 6.184" Surface 324' 7" 26# N -80 - 6.276" 324' 1,087' '� 22 7" 23# N -80 6.366" 1,087' 4,857' 7" 26# N -80 6.276" 4,857' 6,704' 7" 29# P -110 6.184" 6,704' 8,597' 5" 18# N -80 EL,LT &C,Butt 4.151" 8,397' 10,880' 13 3/8" TUBING DETAIL Fair Cmt 2-7/8" 6.4# L -80 TC -II 2.441" Surface 8,209' 1 2 - 3/8" 4.6# L -80 TC II 1.995" 8,209' 10,220' Good Cmt 2 3/8" 4.6# N -80 Butt 1.995" 10,520' 10,748' ■ 4 JEWELRY DETAIL A No. Depth ID OD Item 7 1 16' - Tubing Hanger, Seaboard 2 -7/8 EUE lift x 2 - 7/8 EUE susp it , 2 4,000' 2.441" 5.000" 2 -7/8" DepthlndicatorSub 3 8,200' 1.995" 2.875" 2 - 7/8 "x2 - 3/8" Crossover T 4 8,397' 4.151" 5.0" Simplex Liner Hanger (Burns) F_ 5 10,000' 1.995" 4.151" Tubing Anchor 6 10,059' 1.800" 2.375" Seating Nipple 7 10,060' 1.995" 2.375" Slotted Flow Sub 8 10,070' 1.995" 2.375" 2 joints 2 - 3/8" tubing, EUE 8RD (Gas Anchor) - 9 10,130' - 2.500" Bull Plug 10 10,136' 1.991" - Packer, Permanent, Baker Mod. "D" 2 -7/8" r 11 10,188' 1.875" 2.70" HES 'X' Nipple 12 10,220' 1.997" 3.50" WLEG 13 10,520' 2.0" 3.094" Safety Joint, Brown "CC ", Bottom half /Pin up 14 10,583' - - Packer, Retrievable, Baker Mod. "FH" 5 "x2 -3/8" 10 Mi1 'rt,`'� 15 10,588' 1.875" - "5" Nipple, (Position No. 2) w/ PS plug installed (11- 15 -87) 11 © 16 10,647' 2.0" 3.094" Safety Joint, Brown "CC" 12 = 17 10,648' 1.875" - Otis "XA" Sliding Sleeve G2 18 10,651' - - Packer, Retrievable, Baker Mod. "FH" 5 "x 2 -3/8" H1 19 10,657' 2.0" 3.094" Safety Joint, Brown "CC" 20 10,691' - - Packer, Retrievable, Baker Mod. "FH" 5 "x 2 - 3/8" H2 21 10,697' 1.791" - "N" Nipple, w/ PN plug installed (11- 12 -87) H3 22 10,748' 1.995" - WLEG 13 w UH8 ROD DETAIL Tubing Perf MH8 No. Depth Length OD Item ► 10,570'- 10,575' A 5' 26' 1 -1/2" Polished Rod, 21' in well 14 2 B 31' 8' 1" 1" x 8' EL Pony Rod 15 © 39' 2,565' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod L H8 2,604' 3,500' 7/8" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod 16 ` H9 6,104' 3,350' 3/4" 3/4" x 25' EL Sucker rods w/ 4 XL guides per rod C 9,454' 550' 1 -1/4" 1 -1/4" x 25' K Bars (weight bars) 17 XA D 10,004' 30' 1" 2" x 30' Stabilizer Bar w/ 3" Pins 18 ,'." E 10,034' 25' 1 -1/2" 1 -1/2" x 25' Insert Pump, RHBC Pump w/ PA Ring 19 80 PA Ring, Sand Seal, 2" x 1 -1/2" x 24" x 24 - 1/2" x 25' RHBC Possible leak L UH 10 F 10,059' 20' 1.315" Dip Tube, bottom 1' ported, bull plug on bottom 10,655' - 10,675' 20 / M Tubing Perf 21 ► c — 10,735'- 10,745' — i t LH10 22 4 5 " TD = 10,880'; ETD = 10,798' MAX HOLE ANGLE = 14deg Proposed Completion Updated by STP 07 -01 -13 • Soldotna Creek Unit • Well SCU 12A-04 PROPOSED SCHEMATIC Proposed Completion PTD:174021 Hilcora Alaska, LLC API: 50-133-10103-00 i PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G2 10,284' 10,313' 10,283' 10,312' 29' 12 2 -1/8" EJ, 90 deg. 6/9- 7/20/95 G2 10,284' 10,311' 10,283' 10,310' 27' 6 3 -1/8" Millineum TCP 8/17/2009 G2 10,324' 10,350' 10,323' 10,349' 26' 12 2 -1/8" EJ, 90 deg. 6/9- 7/20/95 G2 10,323' 10,349' 10,322' 10,348' 26' 6 3 -1/8" Millineum TCP 8/17/2009 H1 10,391' 10,399' 10,390' 10,398' 8' 6 2 -1 8" HC, 0 deg. 12/11/1998 H2 10,419' 10,443' 10,418' 10,442' 24' 6 2 -1/8 ", HC, 60 deg. 12/11/1998 H3 10,451' 10,459' 10,450' 10,458' 8' 6 2 -1/8 ", HC, 60 deg. 12/11/1998 H4 /H5 10,452' 10,503' 10,451' 10,502' 51' 6 3 -1/8" Millineum TCP 8/17/2009 UH8 10,534' 10,552' 10,533' 10,551' 18' 4 Opened in annulus MH8 10,561' 10,581' 10,560' 10,580' 20' 4 Opened in annulus LH8 10,590' 10,606' 10,589' 10,605' 16' 4 Isolated by PS Plug H9 10,624' 10,647' 10,623' 10,646' 23' 4 Isolated by PS Plug UH10 10,657' 10,687' 10,656' 10,686' _ 30' 4 Isolated by PS Plug LH10 10,697' 10,710' 10,696' 10,709' 13' 4 Isolated by PS Plug LH10 10,720' 10,745' 10,719' 10,744' 25' 4 Isolated by PS Plug Proposed Completion Updated by STP 07 -01 -13 .. II • • .,.. River CURRENT WELLHEAD DRAWING SSwanson wanson 04 11 05/29/2013 Swanson River Tubing hanger, Shaffer T55- SCU12A-04 AJO, 7 X 2 7/8 IBT lift and 133/8X7X27/8 2 7/8 TC-2 susp, w/ 2 %" type H BPV profile, 3/8 control line 6 % Extended neck BHTA, Bowen, 3 1/8 5M FE X 3" Bowen Union . 111 LI Valve swab, WKM -M — 3 1/8 5M FE, HWO, AA _00 0 Valve wing, WKM -M - i 3 1/8 5M FE, HWO, AA 004 Valve wing, WKM -M irA6 o 2 9/16 5M FE, HWO, AA d, :Cc o , lc" • o,I 0_ o a 0 0 6 0 ' ^ • ' • • Valve upper master, a 0 WKM -M, 3 1/8 5M FE, .. c O$` HWO, AA . ^ a Valve lower master, O . WKM -M 3 1/8 5M FE, it � • # Adapter, Shaffer -AJO, HWO, AA 60 71 /165MstddX 29/16 °" 5M, w/ 1 -'h control line exit 6' /d' seal pocket Tubing head, Shaffer '71 T55 LI, 13 5/8 3M X -up m_ Ground Level 71/165Mw/2- 21/165M tL 1, 3 SSO, 7" Type 1 secondary . seal in head _ : Valve, VG -200, 2 1/16 5M 1 041 �I ■�11t X911 FE, HWO, Rockwell Plug Valve „ 1 14 s Casing head, Shaffer KD, a 13 5/8 3M X 13 3/8 SOW, N1 — T N I w/ 2- 2" LPO, 7" KD slips ® Valve, WKM - 2" LPO and packoff assy in head o illi 1 l ©C)o 11 -iv 0 • • ..13 Swanson River I PROPOSED WELLHEAD DRAWING SCU 12A -04 05/29/2013 11,1- %I.,4.,.1.14 Swanson River Tubing hanger, Seaboard, SCU12A -04 ECO tension, 7 1/16 5M X 2 13 3/8 X 7 X 2 7/8 7 /8 EUE lift and susp,w /2% type H BPV, 3/8 control line, 5" slickneck, left to release, right to engage Full stainless steel for chemical injection Special Cross, 2 9/16 5M FE X 2 7/8 EUE 8rd w/ 2- 2 1/16 5M SSO _ G ;' Valve, wing, WKM -M, 2 1/16 '' t E _ E 5M FE, HWO, DD trim ono >o] - - Ir°°1I 24.00" i i." ii Adapter, Seaboard, 7 1/16 _,∎•• _ llfl 5M FE X2 9/16 5M w/ 5" PP = '��_ seal pocket, %2 control line Grade Level -SIN , Ilia exit, alloy material III 1 1!1 Tubing head, Seaboard S -8, 13 5/8 3M X 7 1/16 5M, w/ "" "' 2 2 1/16 5M SSO, BG bottom i prep � 0 Iii �lil - iima Casing head, Shaffer KD, IF 111 � 1 13 5/8 3M X 13 3/8 SOW, Valve, WKM M 2" LPO w/ 2- 2" LPO, 7" KD slips O and packoff assy in head IN II IIIIIIN to % � I o ; i l if • „ fir Swanson River 2013 Williams Rig 405 Knight Oil Tools BOP Hd�nrp . tl i.L.i. 1.1 1 O O 111111 °111 111 III 111 Ii•i 1 2.57' Shaffer 71/16 5000 lit, 111 111 111 111 111 III I11 lil 1.1 _ 2 3/8 -3 % variable _ - CAMERON 3.68' 4-11 • Blind 7 1/16 I 5000 111114 ,= 111 111 111 111 111 Choke and Kill valves are 2 1/16 10M I!1 [VIII 111 111 . v41110 r!.,tel 1.56' M' 4 ' 71/16 5000 N ' ` ' " 111 I l 1 =111 111 Itl 1 � �� • �� 4ie STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMMI~N ~~~5cs" ; ~/~49 _. ~ II~IL'il'E` REPORT OF SUNDRY WELL OPERATIONS _ 4~~2.~tooy 1. Operations Abandon Repair Wetl Ptug Perforations Stimulate Other ~ Run 2-3/8"x2-7/8" Performed: Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extension^ Completion Change Approved Program ^ Operat. Shutdown ^ Perforate ^~ Re-enter Suspended Well^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ^ 174-021 ~ 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ 6. API Number: / 50-133-10103-01 ~~ 8. Property Designation (Lease Number): 9. Well Name and Number: FEDA028996 [Swanson River Unit] ~ Soldotna CK Unit (SCU) 12A-04 10. Field/Poo!(s): Swanson River Field / Hemlock Oil Pool / 11. Present Well Condition Summary: Total Depth measured 10,880 ~ feet Plugs (measured) 10,588 & 10,697 feet true vertical 10,878 feet Junk (measured) 10,586' (+/-) feet Effective Depth measured 10,798 feet Packer (measured) 10,136 feet true vertical 10,796 feet (true vertical) 10,134 feet Casing Length Size MD ND Burst Coilapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,878' 10,140 psi 10,490 psi ^~~~ifi~~~~ ~.. _ ~ f a.-! ~ . Perforation depth: Measured depth: See Attached Schemati c "' ''~+ True Vertical depth: See Attached Schematic 6.4# L-80, 10,220' & 10,218' & Tubing (size, grade, measured and true vertical depth): 2-7/8"x2-3/8" 4.6# L-80 & N-80 10,5 '-10,748' 10,518'-10,746' 0,13 , 10,583', 10,134', 10,581', Packers and SSSV (type, measured and true vertical depth): Baker DB &(3) Baker FH Retr Pakers / N/A 1, 51', & 10,691' 10,649', & 10,689' ~ Pu r @ ~~,13~ ' (nnD) (n/~) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 690 psi 2,045 psi Subsequent to operation: 9 255 39 680 psi 120 psi 14. Attachments: 15. Well Class after work: Copies of ~ogs and Surveys Run N/A Exploratory^ Development Q Service^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry NumbQr or N/A if C.O. Exempt: 309-220 / Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenburg Title Drilling Manager n ~ Signature C. ;~ - Phone 276-7600 Date 9/15/2009 Form 10-404 Revised 7/2009 ~~$~ ~;^~ ~~.. ' t F 4~, Submit Ori inal Onl , `. ~ F ~? c ~~0~ 9 Y ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 12A-04 SOLDOTNA CK UNIT 12A-04 FEDA028996 5013310103 QA5245 201.00 .. ,;,.~ .~,:m. .. ~ , ,_ ~ ~. <. . ~` ;- ~ ~ .. ~~~s~ ~ ~:.. ~~ x~ti~ , .. , ~:. ,m x ~ ri . z.,.:. ~t~w. ~ ~ , _ ~ , , 5 : Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion - Reconfigure Major Rig 7/28/2009 8/22/2009 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SCU 12A-04 5013310103-01 1740210 . ~~;,.. ..t ~~ , ;x ,.. , . ~.. ~ ~ ,~ ~ u ;. r. ~ n.. 7'/28/2009 00:00 - 7/2912009 00:00 -, Operations Summary Move in and berm up equipment, RU same, bleed flow line and remove pipeing around well head. Build 550 Bbis of 3% KCL and 50 Bbls of sized salt pill. Test hard line 250 low / 3,000 psi high and kill weli. Notice given to AOGCC & BLM of upcoming BOP test. 7129/200~ ;00~:00 - ~/341~~=04.~~ ~ '' ` ~~ Operations Summary Finish bullheading fluid and monitor well (650 psi). Reverse circulate holding 400 psi on tubing, pump a total of 392 Bbls, ending pressures 650 tu 250 casing. Lubricate and bleed 3% KCL and finish weli kili. Set BPV, ND tree, NU BOPE, pull BPV install two way check, test BOPE 250 low 50 si high. (test witness waived by AOGCC Jim Regg on 07-28-09) r~~~~~ ~~ai~ ~ ~~~~rzooa ~~t~ ~~~~ .~ .w . 3~ Operations Summary ' Complete BOPE test, pull two way. MU landing joint and ROLDS (run out lock down screws), puli hanger and release packer with 116K straight pull. Circulate hole volume @ 2BPM, then check for flow (none). POOH with production tubing - full recovery to WLEG @ 8,429'. Install wear bushing, MU 7" csg scraper assy & RIH with same. ~v 7/31/2008 00:00 - 8/1/2009 D0:00 ~ Operations Summary Con't RIH with 7" scraper assy. tag 5" liner top @ 8,402' DPM. POOH with 7" scraper assy. MU 5" clean out BHA (4.125 junk and string mill) RIH and tag fill @ 10,453'. 8/1/2009 00:00 - 8i2/~bQ!$ t~1~:00 Operations Summary Clean out fill to 10,479', CBU, POOH with 5" clean out assy. Service rig. MU 5" RTTS packer and RIH w/ same to 10,138', set packer and test 5" liner and 7" casing to 2,500 psi for 30 minutes (chart record same) good test, POOH w/ RTTS assy. ~8~~~tl~OQ:4 - 8l312QQ9 OO,Q ~ ~ ~ ~ ~ '~7~= ~,~ :,<~ ~_ t . Operations Summary BO & LD RTfS BHA. PU/MU junk basket BHA and RIH w/ same to 10,478'. Rotate and work junk basket from 10,474' - 10,478' unable to make any further progress. POOH with junk basket (wet) ~~otts ao:oa _- sr~2oos ~:oo~ ~ ~ ~ ~t ~ ~ ~~~. ~ Operations Summary OOH with junk basket assy. Recoverd KOBE fish and basket was packed with scale and metal debris. BO same. PU/MU 1-1/4" Hydril tbg 28' & boot basket, RIH with same to 10,478', rotate, circulate and clean out fill and junk to 10,506' +- 1' bites working pipe. POOH and hang @ 10,096', cont to pump, rotate & work pipe while POOH. Tight spots @ 9,749', 9,624', 9,436', 9,124' - 8,936'. POOH from top of 5" liner. 8/4/2009 04.E10 - $lSf24~~`~:6Ef `~~ ~ ~ ~ ~~ ~~~ ~ Operations Summary POOH with 1-1/4" stinger assy. Recovered 3#'s of junk iron from boot basket. PU/MU reverse circulation junk basket & RIH with same, tag @ 10,493' and wash to 10,494', POOH, recovered 1 small piece of rubber and 1 piece of inetal. MIRU APRS, PU/MU standard tool string w/ CCL, RIH with same, unable to get deeper than 10,494', POOH & RDMOL APRS ,~ ~ {~Q~tt0:Q0-~ 816l2009 OOAO~ ' " ~ ~ , _ ~ ~ ~ . ~. ,.,._ Operations Summary PU/MU 1-1/4" stinger, RIH with same to 10,494' and wash to 10,515', circ high vis sweep (recover 1 gai perf debris) POOH with stinger assy - difficult getting out of the 5" liner, work pipe through midnight. Notice given to BLM & AOGCC of upcoming BOP test. 818i200$~ Q0:00 - 817120Q9 04:00 ~'; "'a~; ;~ ~~ ~ ~ `t~-. ~ .,:~., ' ~`,~~ Operations Summary POOH with stinger assy & lay down same. Recover 2 pounds of gun debris from boot basket. PU/MU open ended 2-7/8" x 3-1/2" work string; RIH with same. Tag @ 10,502' and reverse circulate to 10,510' unable to work deeper. Pump 2 high vis sweeps and POOH. debris plugged surface lines while circulating OOH. shut down and clear lines / pump c and forth to clear up. Recovered +- 6 gal of gun d~bris. POOH. lead in collar showed signs of hitting the scoop head. TEST BOPE 250pis low / 500 si high (witness waived by AOGCC Jim Regg) l , F; ~ ~ ~ ~ .~r~ t.~,. ~: ~-; 8/772b09 oO:OQ « 8f81Z009 00.00 ~ ~ ` A, t ~,. ~ ~ ~~ * ' ~ Operations Summary Complete BOPE test. MU 1-1/4" stinger and RIH to lower 2-3/8" completion @ 10,510'. Clean out same to 10,524' (refusal) CBU w/ high vis pill & POOH ~~#~ ~, ~- ~~ -~~ ~~ S/812009 OOcOQ - 8J9I2009 00:00' ; . ~ ;`! , ~, ~.~~ - Operations Summary Con't POOH with stinger assy, BO & LD same. MIRU APRS wireline w/ CCL, magnet, wt bars. RIH and log lower completion to ensure enough room for cut. unable to positively identify correct depth. RD APRS wireline / MIRU Pollard wireline, RIH w/ standard 1-1/2" tool string & 1.8" swege to 10,536'. POOH. RD Potlard wireline, RU APRS wirelineRlH w/ 2.25" swege and tag scoop head @ 10,524'. POOH. RIH with APRS wireline to reconfirm depths, flag line @ 10,524', log inconclusive, POOH / Chevron Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (fl) SCU 12A-04 SOLDOTNA CK UNIT 12A-04 FEDA028996 5013310103 QA5245 201.00 ~ `~,' ~ x ~ ~ ~ ~.k ~. ~ . . ~F . , , ~ _~ , ~ . ~ . ~.. ~s 81912009 OEC:01~ = 8ki0%2b09 00:00 Operetions Summary POOH & RD APRS wireline, Wait on spear from California. MU 2" spear and RIH on work string to engage and release the scoop head and 150 series overshot. ~X'kt~~`~ ~~ ~1$ QO:t~d - $lt~112009 t~0t0a ° ~ ~~ z . . ~ z ~ ~ t~ t1 ~r~,~.~., Operations Summary PU power swivel, spear fish @ 10,510' pull 15K fire jars and begin to rotate slow w/500 - 900 ft/#'s of torque. Popped free had extra weight, POOH. Left lower 1.5' of spear on the hole. MU 1-1/4" stinger and RIH with same to push fish down hole. Unable to push fish past 10,512.5', CBU & POOH with stinger ~ x,~., svi ~ ~ ~ , r,. 8H 1/2009 00:00 - 8/7 2/2009 00:00 Operetions Summary POOH w/ 1-1/4" stinger assy. MIRU APRS wireleine, RIH w/jet cutter and cut tubing @ 10,519.5' POOH. PUMU spear assy, RIH and recover scoop head (OAL 1.21'), service rig while waiting on hydraulic disconnect. 8/12/2009 00:00 - 8/13/2009 00:00 ~ Operetions Summary PUMU 4-1/8" overshot and fishing string, RIH w/2-7/8" x 3-1/2" work string, dress top of fish and engage same, Rotate fish free & POOH with same.. Recovered Bowen 150 series over shot and twisted off spear from previous run. 8l13/2009 OOc00 - 8/14/20Q9 OOt00 ~ Operations Summary PUMU 3-1/2" cut lip guide and RIH with same. Reverse circulate and wash over tubing stub to top of XA sliding sleeve @ 10,531' CBU 2x's. MIRU Pollard wire line & RIH w/ 2" JDC to recover prong. (no recovery). Run various tools with out success. RDMOL Pollard wireline. Notice given to BLM & AOGCC of upcoming BOP test. 8/14f~U09 00.00 - 8/15/2009 OOAO ~ ~ /~ ~~~ ~ ~~ ~ ~_;;`~ ~ ~ / Operations Summary " RDMOL Slick line, CBU reversing, POOH. Test BOPE 250psi lo i high, Bob Noble w/AOGCC waived witness of BOP test. PUMU 4-1/8 overshot and fishing BHA, RIH with same to 10,517', engage fis a egin jarring operations ~ ~ k K•- 8/15/2009 ~00:00 - 8/16/2009 OO:OQ~ ~ ~ ~ ~ ~ ~ `~~ ~~` ~ ° ` ~ ` 4 ...:' . , s . ...o-A v Operations Summary Con't jarring on fish. Attempt to rotate and release CC safety joint, kept releasing from fish, re-engage fish and continue jarring. Packer released and well went on vaccuum / POOH with fish. 100 Bbls to keep hole full, losing 60-80 BPH. Brake out top packer assembly and PUMU 4-1/8" overshot w/fishing BHA & RIH with same ~,. ~ ~ ~ ~ 8lt$I2009~ OQ:00 - 8/17/20 9~Oq:OQ ~ ~ ~~x~ ~ ~ .~. ~ ! ~, ~ -, rt Operations Summary RIH w/ overshot assy. Pump sized salt pill. Engage fish @ 10,543' (3' deep) work jars and torque, came free w/ 5k drag, POOH. No recovery, grappie broken w/3" piece left in the hole, MU new overshot assy and RIH with same. ~ 8/17120Q& E1Q:00`- $!18/2009 OOsO(~ ` s .. Operations Summary Engage fish and begin jarring and torquing operations, no recovery, overshot kept releasing from the fish. POOH with work string and lay down same. PJSM on picking up TCP guns. 8/1812009 00:00' - 8r1912009 OOc00 ;; ,yr ; . Operations Summary PUMU 3-1/8" 6spf TCP guns and RIH with same. Tie in guns and place bottom shot 10,503' drop bar and fire guns. Perforated H4/H5 from 10,503'-10,452' and G2 from 10,349'-10,323' & 10,311'-10,284'. POOH with spent TCP guns filiing hole 40-45 BPH. OOH and lay down TCP BHA all shots fired. Hole losses decreased 1.8 BPH. ,, ; ~~, ~.. 8/19! Q09 00:00 - $/20/2009 00:00 ' ° Operations Summary POOH and lay down perforation guns (all shots fired). PUMU Baker Model DB production packer and tail pipe assy. RIH and set top of packer @ 10,136' w/ WLEG @ 10,220' Pressure test casing to 2500 psi for 30 minutes (good) release from packer and POOH (losses 9 BPH) 8/2012009 00:00 - 8/21/2009 00:00 ~ ' ~~_~~` ,~ ~..~ ~ .~.. _ Operetions Summary POOH w/ packer setting string / PUMU 2-3/8" 4.6# L-80x 2-7/8" 6.4# L-80 gas lift completion w/chem. inj. mandrel and RIH with same 8/21/2009 00:00 - 8/22/2009 00:00 Operations Summary Displace annulus w/3% KCL / space out and land seals w/7.5' of travel up and down. Install two way check, ND BOPE NU tree test same 250 low 5000 high, pull two way check. RD Key energy rig # 3 and move to 21A-34 Chevron ~ RKB = 14' 1 2 a S son River We SCU 12A-04 Current Completion as of 8/21/09 CASING AND TUBING DETAIL S17.E WT GRADE CONN ID TOP BTNI. 22° - - - 29' 13-3/8" 54.5# J-55 - 12.615" Surface 2,024' 7" 29# N-80 - 6.184" Surface 324' 7" 26# N-80 - 6.276" 324' 1,087' 22~~ 7" 23# N-80 - 6366° 1,087' 4,85T T' 26# N-80 - 6.276° 4,857' 6,704' T' 29# P-110 - 6.184° 6,704' 8,597' 5" 18# N-80 EL,LT&C,Butt 4.151" 8,39T 10,880' r Tubing 13-3/38" Z"~~8 6.4# L-80 TC2 2.441" Surface 8,209' 2-3/8" 4.6# L80 TC2 1.995" 8,209' 10,220' , 2-3/8° 4.6# N-80 Butt 1.995" 10,520' 10,748' Fair Cmt Cmt 3 4 5 6 7 8 9 10 11 Tubing Perf 10,570'-10,575' 12 13 14 15 16 17 Possible leak 10,655'-10,675' 18 Tubing Perf ~ 9 10,735'-I0,745' 20 ~» G2 H1 H2 H3 UH8 MH8 LH8 H9 UH10 LH10 JEWELRY DETA[L NO. Death ID OD Item 1 I6' 2.485" Tubing Hanger, Shaffer-AJO 7x2-7/S BTC IiR x 2-7/8 TC-2 susp 2 2,488' 2347" 4.75/4.0 2-7/8" SFO-1 GLM w/ BK-2 latch & TRO 1,367 3,980' 234T' 4.75/4.0 2-7/8" SFO-1 GLM w/ BK-2latch & TRO 1,351 5,200' 2.347" 4.75/4.0 2-7/8" SFO-1 GLM w/ BK-2 latch & TRO 1,337 6,292' 234T' 4.75/4.0 2-7/8° SFO-l GLM w/ BK-2 latch & TRO 1,325 7,289' 2347" 4.75/4.0 2-7/8° SFO-1 GLM w/ BK-2 latch & TRO 1,314 8,192' 234T' 4.75/4.0 2-7/8" SFO-1 GLM w/ BK-2 latch & TRO 1,346 3 8,209' 1.983" 3211" 2-7/8"x2-3/8" Crossover 4 8,252' 1.901" 3.875/29 2-3/8" BST GLMAX-1 Chemical Injection Mandrel 5 8,39T 4.151" 5.0" Simplex Liner Hanger (Bums) 6 8,88T 1.901" 3.875/2.9 2-3/8" BST GLMAX-1 SC GLM w/ BK-2 latch & TRO 1,337 9,561' 1.901" 3.875/2.9 2-3/8" BST GLMAX-1 SC GLM w/ BK-2 latch & TRO 1,331 10,035' I.901" 3.875/2.9 2-3/8" BST GLMAX-I SC GLM w/ BK-2 latch & Oriface valve 7 ]0,120' 1.875" 3.250" HES XD Sliding Sleeve 8 10,136' 1.991" - Packer, Revievable, Baker Mod. "FH" 2-7/8" 9 10,188' 1.875° 2.70" HES `X' Nipple 10 10,220' 1.997" 3.50" WLEG I 1 10,520' 2.0" 3.094" Safety Joint, Brown "CC", Bottom half/Pin up 12 10,583' - - Packer, Retrievable, Baker Mod. "FH" 5"x2-3/8" 13 10,588' 1.875" - "S" Nipple, (Position No. 2) ~~~/ PS plug installed (11-15-87) 14 10,64T 2.0° 3.094" Safety Joint, Brown "CC" 15 10,648' L875 - Otis "XA" Sliding Sleeve 16 I Q651' - - Packer, Retrievable, Baker Mod. "FH° 5"x 2-3/8" 17 10,65T 2.0" 3.094° Safety Joint, Brown "CC" 18 10,691' - - Packer, Retrievable, Baker Mod. "FH"5"x 2-3/8~~ 19 ]0,697' 1.791„ _ "N„ Nipple, ~~~/ PN plug installed (1 I-12-87) 20 10,748' 1.995° WLEG PERFORATION HISTORY DIL nterva ccum. Date Zone To Btm Amt s f Comments 6/9-7/20/95 G2 10,284' 10,313' 29' 12 2-1/8" EJ, 90 deg 8/17l2009 G2 1Q284' 10,311' 27' 6 3-1/8" Millineum TCP 6/9-7l20/95 G2 1Q324' 10,350' 26' 12 2-1/8" EJ, 90 deg 8/17/2009 G2 10,323' 10,349' 26' 6 3-1/8" Millinaun TCP 12/11/1998 H1 10,391' 1Q399' 8' 6 2-1/8", HC, 0 deg. 12/11/1998 H2 10,419' IQ443' 24' 6 2-1/8", HC, 60 deg. 12/11/1998 H3 10,451' 10,459' 8' 6 2-1/8", HC, 60 deg. 8/17/2009 H4/HS 1Q452' 10,503' S1' 6 3-1/8" Millineum TCP UHS 10,534' 10,552' 18' 4 Opened in ~nulus MI-~ 10,561' 10,581' 20' 4 Opened in annulus LH8 1Q590' 1Q606' 16' 4 Isolated by PS Plug H9 IQ624' 10,647' 23' 4 Isolated by PS Plug iJH10 1Q657' 10,687' 30' 4 Isolated by PS Plug LH 10 10,697' 10,710' 13' 4 Isolated by PS Plug LH10 IQ720' 1Q745' 25' 4 Isolated by PS Plug ~ 5~~ ETD = 10,798', TD = 10,880' MAX HOLE ANGLE = 14deg ~CU 12A-04 Schematic 9-14-09.doc DRAWN BY: CVK REVISED: 9/14/09 ~ ~7~ ~ Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 ~ Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com I ~ " ~ ~ ~~CE1~/E[~ July 27, 2009 ~ `~ Commissioner ~~ ~UL 2 $ ?Q~1~ Alaska Oil & Gas Conservation Commission f'~Iaska t~il & Gas Cans. ~.~mmissi~n 333 W. 7'" Avenue q~~~~~;~~e Anchorage, Alaska 99501 Re: Swanson River Workover Program Update For SCU 12A-04 - Sundry # 309-220 Dear Commissioner, Attached please find updated BOPE and choke diagrams, as well as the updated workover summary for SCU 12A-04 that has been approved by Sundry 309-220. UOCC appreciates your consideration of this proposal and looks forward to discussing any questions with the proposed configuration as needed. Please let us know if we can provide any further information by contacting myself at 263- 7657 or Evan Harness at 263-7932. Sincerely, ~ C ~ . ~ ~; . , ~~~~t~ ~R' ~= "~ ~t ~C~~'~. Timothy ~andenburg ~, ~; ~ Drilling Manager Attachments: Summary of Swanson River Workover Program BOPE diagram Choke diagram Union Oil Company of California / A Chevron Company Chevron . ~ ~ ~ Summarv of Kev Enerqv Riq #3 Specifics SCU 12A-04 Workover The SCU 12A-04 workover is to pull the existing completion, fish and cleanout to the base of the Hemlock (or as deep as possible) and run a new completion. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Confiauration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft- 9/16" sand line. Derrick The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Shaffer Single gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram and blind ram Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 140 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Fourteen 11 gallon accumulators with four 11 Gallon Nitrogen Bottles for backup. 210 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Key Energy Rig #3 Specs (SCU 12A 04).doc 7/27/09 Chevron • • ~ ~ Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-flex hose with a Unibolt/Hub-flanged connectors. Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically operated HCR valve that is attached to the mud cross with co-flex hose with a Unibolt/Hub-flanged connectors. Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SCU 12A 04).doc 7/27/09 ~~~ ~ BO• iagram ~ SCU 12A-04 Workover ~ 07/27/2009 ~nnular preventer, 7 1/16 5M Flar 2.58' I haffer Chasovoy 7 1/16 5 Pipe Ram 7.16' ~.Q~' stdd X 7 1/~6 5M stdd I hafferChasovoy 7 1/is 5 Pipe Ram stdd X 7 1 5M stdd 1.75' • Blind Ram Mud Cross, 7 1/16 5M FE X 7 1/16 5M FE w/ 2 1/16 5M X 3 1/8 5M EFO Kill line 2 1/16 5M Choke line 2 1/16 5M 1.83' Unibolt - ~ HCR Unibolt DSA 3 1/8 5M X 2 1/16 5M ~ ~ SCU 12A-04 rrom ~noKe 1", 5M, Unibolt, Hose F-rom C:hoke Line Line Side of Drilling Spool ~ • - , ,:` 0 r an' ` ~ ^ d R x ~ ~ ~ t~'i , ti ~ S ~ ~e r 4 o-F 4 . b ~ I " ~ F °-~ °! ~ F ' ` ~ ~~ ~ ~ ~~ ~ ~~ E y GOVERNOR q SARAH PALIN & ~ y r ~ 5 ~ ~ ~ ~ ~' ~ ~ t a ~' ~~" " ° `~~' @ '~ ` ~ ~ ~~ ~ , ~, ~ ~ m ... _ h n . ~ ~ ~ ~ A~S~~ ~~ L~`D li~S 333 W. 7th AVENUE, SUITE 100 ~" COI~TSER'QATIOI~T COMMl~~'IISSIOI~T ~ ANCHORAGE,ALASKA 99501-3539 f PHONE (907) 279-1433 ' FAX (907) 276-7542 Mr. 'I~mothy C. Brandenburg Drilling Manager Union Oil Company of California ~~ P.O. Box 196247 ~ ~ ~ ~ Anchorage, Alaska 99519 Re: Swanson River, Hemlock Oil, Soldotna CK Unit (SCU) 12A-04 Sundry Number: 309-220 Dear Mr. Brandenburg: {~~ d~~~~~ ~ U~- ~`~ ~~~~~ 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 C~mmission 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 ne~ wor~ng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. 7~ Chair DATED this / day of July, 2009 Encl. - ~/~ kJ ' STATE OF ALASKA ~~.°~~~~~~ '~~~ -O~ i~ ALAS~OIL AND GAS CONSERVATION COMM~ON ~ 6 /~ .,~t~N 2 ~ 200~ 4J~A- APPLICATION FOR SUNDRY APPROVALS o~7 .o~~~,o~~ 2o,4ac 25.280 ~1as~a ~iI ~ Ga~ ~~?~~. ~~~~,~i~~cn~~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ~ Wa @F~ ~'~~~ Other^~ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Run 2-3/8"x2-7/8" Change approved program^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ completion 2. Operator Name: 4. Current Well Class: 5. Permit to Driil Number: Union Oil Company of California Development ~ Exploratory ~ 174-021 - 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10103-01 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Soldotna CK Unit (SCU) 12A-04 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028996 (Swanson River UnitJ ~ 15' Swanson River / Hemlock Oil ' 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10,880 10,842 10,459 10,430 N/A 10,459' (+/-) (fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 22" 29' 29' Surface 2,024' 13-3/8" 2,024' 2,024' 2,730 psi 1,130 psi Intermediate Production 8,597' 7" 8,597' 8,596' 3,830 psi 6,340 psi Liner 2,483' 5" 10,880' 10,880' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" & 2-3/8" ~ 6.4# L-80 & 4.6# N-80 8,430' & 10,500'-10,748' Packers and SSSV Type: Packers and SSSV MD (ft): (5) Baker Mod Retrievable Packers / N/A 8,319', 10,515', 10,583', 10,651' & 10,691' / N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP e~ch Q Exploratory ^ Development Q- Service ^ 15. Estimated Date for 7/28/`L009 ~ 16. Well Status after proposed work: Commencing Operations: ~ Oil Q- Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL Q Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Nigel Bonnett 263-7853 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 6/23/2009 ~ ' _ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: QC~ Z2~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other. ~e/ ~'/~1~~ 2S.2j~s ~j. t ~- ' ~-f 1~e.yx ° ~ ~, e g o i~~ ~ ~ v'e , , c , 5~~ Subsequent Form Required: ~ p- r.~o ~, APPROVED BY ~ ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: 7 [~~~ ~- ~ ~ g Form 10-403 Revised 0 ~~' ~~ ~~~~ g~ ~~~~~ Submit in Duplicate k~ _ Chevron ~ ~ 7 RKB = 15' ~ 1 2 • S~7,E • Swanson River Well SCU 12A-4 Actual Completion 6/4/95 CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. - - - 29' 54.5 J-55 - 12.615 Surface 2,024' 29 N-80 - 6.184 Surface 324' 26 N-80 - 6.276 324' 1,08T 23 N-80 - 6366 1,087' 4,85T 26 N-80 - 6.276 4,857' 6,704' 29 P-110 - 6.184 6,704' 8,59T 18 N-80 EL,LT&C,Butt 4.151 8,39T 10,880' 6.4 L-80 Butt 2.441 15' 8,430' 4.6 N-AO 1.995 10.500 10.748' 22„ 13-3/8" ~>, ~„ 22~~ 7>, ~„ ~„ 5" Tubing 13-3/38" 2"~~8" 2-3/R" Fair Cmt Tagged ~ Obstruction ~ at 8,099' / 3-4-09 Good Cm~ 3 ~ 4 x ~» 5 ~ G2 • H1 2.3"x t o" H2 Kobe SV „ - H3 6 'J XA w/ PX plug & prong 8 9 0 ~-~ w/CaC03 on cop/ t o,s t 2' 1 Tubing P E U H 8 er » 10,570'- 10,575' I1 ,~ - , MH8 2 S 1 LH8 13 - H9 14 , xn I S +~ 16 ~~ UH10 Tubing ~ ~ Perf j $ ~ 10,735'- to,745' 19 ' LH10 JEWELRY DETAIL NO. De th ID OD Item 1 15' - - Tubing Hanger, 2-7/8", Purchased from DSR, P/N: 421758 2 2,244' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2", 05321-000-2400 3,648' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 4,616' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 5,298' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 5,918' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 6,503' 2343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 7,088' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x l-1/2" 7,674' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 8,260' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 3 8,319' 2.416 5.983 Packer, Retrievable, Baker Mod. "FH" 2-7/8" - 4 8,397' 2.313 3.500 Nipple, `X', 2.313 LD. 5 8,429' 2.441 3.700 WLEG 6 10,493' 2.000 - Scoophead Guide Assembly w/ 4 sxCaCo3 7 10,497' 2.000 3.973 Overshot, Bowen Series 150 8 10,512' - - Sliding Sleeve, Otis "XA", 2-3/8" W/ "PX" Plug, 3'CaCo3 on top 9 10,515' - - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 10 10,520' - - Safety Joint, Brown "CC", 2-3/8" I l 10,583' - - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 12 10,588' - - Nipple, "S" (Position No. 2), 2-3/8" 13 10,647' - - Safety Joint, Brown "CC", 2-3/8" 14 10,648' - - Sliding Sleeve, Otis "XA", 2-3/8" 15 10,651' - - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 16 10,657' - - Safety Joint, Brown "CC", 2-3/8" 17 10,691' - - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 18 10,697' - - Nipple, "M" or "D" 19 10,748' - - WLEG PERFORATION HISTORY DIL Interval Accum. Da te Zone To Btm Amt s f Comments 6/9-7/20/95 G2 10 284' 10 313' 29' 12 2-1/8" E.T 90 de . 6/9-7/20/95 G2 10 324' 10 350' 26' 12 2-1/8" EJ 90 de 12J11/98 H1 10 391' 10 399' 8' 6 2-1/8" HC 0 de . l2/11/98 H2 10 419' 10 443' 24' 6 2-1/8" HC 60 de 1?J11/98 H3 10 451' 10 459' 8' 6 2-1/8" HC 60 de UH8 10 534' 10 552' 18' 4 Isolated b PX Plu MH8 10 561' 10 581' 20' 4 Isolated b PX Plu LH8 10 590' 10 606' 16' 4 Isolated b PX Plu H9 10 624' 10 647' 23' 4 Isolated b PX Plu [JH10 10 657' 10 687' 30' 4 Isolated b PX Plu LH10 10,697' 10 710' 13' 4 Isolated by PX Plug LE { 10 10.720' 10.745' 25' 4 Isolated bv PX Plue ; 5~~ ETD = 10,798', TD = 10,880' SCU 12A-04 Schematic Rev l.doc MAX HOLE ANGLE = 14deg? DRAWN BY: tcb REVISED: 12/21/98 Chevron • • Swanson River ~ Well SCU 12A-4 _ ~ PROPOSED Comp. / CASING AND TUBING DETAIL SIZE WT GRADF, CONN ID TOP BTM. 22" - - - 29' 13-3/8" 54.5 J-55 - 12.615 Surface 2,024' 7" 29 N-80 - 6.184 Surface 324' 7" 26 N-80 - 6276 324' 1,08T 7" 23 N-80 - 6.366 1,087' 4,857' 7" 26 N-80 - 6.276 4,857' 6,704' 7" 29 P-110 - 6.184 6,704' 8,597' 5" l8 N-80 EL,LT&C,Butt 4.151 8,39T 1Q880' Tubing 2-7/8" 6.4 L-80 TGII 2.441 15' 8,320' 2-3/8" 4.6 N-80 TC-1I 1.995 8,320' 10,180' JEWELRY DETAIL NO. De th ID OD Item 1 15' 2.441 - Tubing Hanger, 2-7l8", Purchased from DSR, P/N: 421758 2 +2,244' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" +3,648' 2343 5.500 GLM, Camco, MMG, 2-7/8" x I-1/2" +4,616' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x l-I/2" +5,298' 2343 5.500 GLM, Camco, MMG, 2-7/8" x I-I/2" +5,918' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/Y' +6,503' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x l-I/2" +7,088' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-U2" +7,674' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 3 +8,320' 1.995 2.875 X-Over 2-7/8" TCI[ x 2-3/8" TCII 4 +8,750' 1.995 3.805 GLM, Special Clearance 2-3/8" +9,184' 1.995 3.805 GLM, Special Clearance 2-3/8" +9,616' 1.995 3.805 GLM, Special Cleazance 2-3/8" +1Q050' 1.995 3.805 GLM, Special Clearance 2-3/8" 5 +10,070' 1.995 3.805 Chemical injection mandrel 6 +1Q080' 1.98 4.125 Packer, Retrievable, Baker Mod. "FH" 2-3/8" 7 +10,120' 1.875 Nipple, `X' g +I0,180' 1.995 WLEG PERFORAT[ON HISTORY DIL nterva ccum. Date Zone Top Btm Amt spf Comments 6/9-7/20/95 G2 10,284' 10,313' 29' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,324' 10,350' 26' l2 2-1/8" EJ, 90 deg. 12/11/1998 Hl 10,391' 10,399' 8' 6 2-1/8", HC, 0 deg. 12/1 U1998 H2 10,419' 10,443' 24' 6 2-1/8", HC, 60 deg. l2/11/1998 H3 10,451' 10,459' 8' 6 2-1/8", HC, 60 deg. UH8 10,534' 10,552' 18' 4 MH8 10,561' 10,581' 20' 4 LH8 10,590' 10,606' 16' 4 H9 10,624' 10,647' 23' 4 UH10 10,657' 10,687' 30' 4 LH10 10,697' 10,710' 13' 4 LH10 10,720' 10,745' 25' 4 __ ~ - -- - _ i ETD = 10,798', TD = 10,880' MAX HOLE ANGLE = 14deg? DRAWN BY: MQ REVISED: 6/10/09 Chevron * ~ Soldotna Creek Unit Well # SCU 12A-04 ~ 6/23/09 OBJECTIVE: • Pu112-7/8" tubing completion, retrieve fish and scoophead, fish 2-3/8" completion string, recomplete G2 to H10 bench if possible. PROCEDURE SUMMARY: 1 MURU. ND Tree, NLJ BOP. Test BOPE 250psi low/3,OOOpsi high. ~'" 2 RU & pu112-7/8"tubing to shear FH packer, straight pull. POOH and lay down tubing. / Contingency: (If packer does not shear) a. RU and RIH, cut off 2-7/8" tubing above tubing obstruction at +/- 8,099' RKB and POOH w/ same. b. Fish packer, POOH 3 Fish out Kobe valve w/ reverse basket, POOH 4 Clean out reentry joint (scoophead), POOH ~ 5 Clean out CaC03 in 2-3/8" tubing to prong & PX plug at 10,512' RKB & retrieve same, POOH 6 Cut off 2-3/8" tubing at +/-10,502' RKB. 7 MU Fishing BHA, RIH w/spear and catch scoophead guide, POOH MU Fishing BHA, RIH w/overshot, catch stub, pull to shear packers (rotate to release 8 CC safety joint if packer(s) do not shear), POOH. Evaluate recovered tubing/packer fish. 9 If Required, RIH w/overshot, catch stub, pull to shear packer (rotate to release CC safety joint if necessary to release), POOH w/ packer @ 10,583' RKB. ~ 10 If Required, RIH w/overshot, catch stub, pull to shear packer (rotate to release CC safety joint if necessary to release), POOH w/ packer @ 10,651' RKB. 11 If Required, RIH w/overshot, catch stub, pull to shear packer (rotate to release CC safety joint if necessary to release), POOH w/ packer @ 10,691' RKB. ' 12 Clean out fill at TD if required and hole conditions allow. 13 ~H with TCP or wireline guns (depending on zonal recovery) and reperforate zones G-2 to LH-10 if possible, POOH. 14 Recomplete well w/ 2-7/8" x 2-3/8" tubing & 5" FH packer to be set at +/- 10,080' / RKB completion. 15 ND BOP, NU Tree. SCU 12A-04 REVISED BY: CVK 6-23-09 Che1-rOn ~ Swa• n River ~ 2009 Workover Program ~ 06/24/2009 Annular preventer, Shaffer, 7 1/16 5M '" Flanged 2.58' Double gate, Shaffer Chasovoy 7 1/16 5M stdd X 7 1/16 5M ~ stdd ~ 1.75' ~ Mud Cross, 7 1/16 5M s O FE X 7 1/16 5M FE w/ 2 /16 5M X 3 1/8 5M EFO Kill line 2 1/16 5M Choke line 2 1/16 5M o° o° o° 0 0 o QQ 1.83' °o °o ~ °o' ~t ~ I 1502 union 1502 Union ~ DSA ~ 3 1/$5M X 2 1/16 5M Hose ' ,~~t Jy ay~ ~ ~° ~ Chevron ~ Timothy C Brandenburg Drilling Manager ~ Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com :~~~~~~~~~~~ June 23, 2009 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Swanson River Workover Program Variance Request Dear Commissioner, JUN ~ ~ '.l.()i~y ;~1~$n~ S3~I SJf t7t~v~ ~~.~a?~. i `~3'ai?)'Al~.°aif~!;~ a4n~h~r~~~ UOCC is requesting a variance of 20 AAC 25.285 (c) (9) and (10) for well service work in the Swanson River Field. UOCC is preparing to perform well intervention work with a"well servicing unit" provided by Key Energy. Key Energy is mobilizing the workover unit here from the Rocky Mountain area. After reviewing the BOPE rig up and equipment as used in UOCC's last Swanson River workover campaign in 2004, we feel that the proposed system is fit for purpose in well control capabilities and mobility to other BOPE configurations for this well service work. As in this same configuration successfully used in 2004, UOCC is asking for a variance ~ of the kill line and choke line configuration and the choke manifold equipment requirements. We consider the application of this and all BOP configurations to be a well bore specific concern and do not intend or desire to consider this as an area wide or unilaterally applied configuration. UOCC appreciates your consideration of this proposal and looks forward to meeting with you to discuss any questions with the proposed configuration. Attached is a brief description of the wells to be worked on, the calculated maximum anticipated surface pressure (MASP), and the proposed BOP configuration and schematic. Please let us know if we can provide any further information by contacting myself at 263- 7657 or Evan Harness at 263-7932. Sincerely, ` ~ ~/ ~ Timot y . Brandenburg Drilling Manager Union Oil Company of California / A Chevron Company ~ ~ Chevron ~ ~ Summarv of Swanson River Workover Pros~ram Well Work Inventorv 1 ea. Gas Re-completions (Tyonek) Plan is to change the tubing string in a gas storage well from 2- 3/8" to 3-1/2" tubing to increase deliverability. (KGSF #1) 3 ea. Oil Re-cgmpletions (Hemlock Oil) Plan is to recomplete Hemlock with optimized gas lift designs. (SCU 12A-04, SRU 21A-34, SRU 21-27) 1 ea. Rod Pump Repair / Re-completion (Hemlock Oil) Plan to retrieve rods, pull and replace tubing and change out pump. (SCU 33-33) Additional potential for several wells to P&A Hemlock horizons. Reservoir The planned recompletion of the gas storage well will be after the storage well is "full", with a maximum BHP of 3300 psi @ 6,388' TVD (Tyonek). Fully evacuated, the MASP would be as follows: 3300 psi BHP -(6,388' ND x.1 psi/ft Gas Gradient) = 2,661 psi MASP. ~ The highest BHP of the oil wells to be worked on at this time is 3120 psi @ 10,994' TVD (Hemlock) which is equivalent to a.272 psi/ft gradient. Fully evacuated, the MASP would be as follows: 3120 psi BHP -(10,994' ND x.1 psi/ft Gas Gradient) = 2,020psi MASP. ~ A 3,000 psi BOPE configuration is sufficient for all planned well work. Proposed Confiauration BOP's Annular, 5M 7-1/16" Hydril or 11" Shaffer Double gate, 5M, 7-1/16" Hydril or 11" Shaffer Mud Cross, 7-1/16" and 11" (optional based on BOP height) Accumulator 140 gallon KOOMEY Accumulator System. 5 functions with manual bypass and remote panel. Fourteen 11 gallon accumulators with four 11 Gallon Nitrogen Bottles for backup. 210 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. Pump The pump is a National JWS-400 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2", 5000 psi Iron or 2", 5000 psi hoses with integral Fig 1502 Unions. ~ Chevron ~ ~ ~ Kill Line Valves The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16", 5M valves attached to either the mud cross or the tubing spool annulus valve. Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16" 5M valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke Line The choke line will consist of 5,000 psi hoses with integral Fig 1502 Unions. Choke Manifold The choke manifold is 3-1/8", 5M with ~nro,~anual chokes and five valves. There are two valves upstream of each choke. ~- Choke Return Line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with integral Fig 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster A free standing gas buster will be placed adjacent to the mud pits. Gas Detection We are proposing that a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a single gas LEL monitor and a single H2S monitor be placed at the shale shaker (if used). PVT We are proposing to work with-out a PVT system as the circulation system on this workover rig, as is standard practice in this type of well service work. SCU 12A-04 Pressure Monitorin~date Maunder, Thomas E (DOA) From: Sent: To: Cc: Maunder, Thomas E (DOA) Wednesday, May 20, 2009 1024 AM 'Winslow, Paul M' a~~ ~ ~ 'Whitacre, Dave S'; 'Greenstein, Larry P;'Myers, Chris S'; 'Bonnett, Nigel (Nigel.Bonnett)'; 'Tyler, Steve L'; 'Eastham, Kevin (KEastham)'; Regg, James B(DOA) Subject: RE: SCU 12A-04 Pressure Monitoring Update Paul, Thanks for providing the information. I concur with you assessment. We will look for your continued information as injection into the storage reservoir continues. Call or message with any questions. Tom Maunder, PE AOGCC From: Winslow, Paul M [mailto:PWinslow@chevron.com] Sent: Wednesday, May 20, 2009 9:33 AM ~... ~-... -"'~~~' °.". To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Whitacre, Dave S; Greenstein, Larry P; Myers, Chris S; Bonnett, Nigel (Nigel.Bonnett); Tyler, Steve L; Eastham, Kevin (KEastham) Subject: SCU 12A-04 Pressure Monitoring Update ~ ~, ~ ~~~; :u ~ ~~ ~ ~ ~00~ Tom & Jim, Attached is the update spreadsheet showing the pressure measurements from the SCU 12A-04 wellbore. Over the past two weeks (since the last update given to the AOGCC on 5/4/09), the tubing pressure has stabilized at -2,031 psig. Note that the pressure climbed as high as 2,034 psig (on 5/14/09) and has been ever so slowly dropping over the past six days. Over this same -two week period (since 5/4/09), CVX has continued to inject gas into the 77-3 storage reservoir (via both the SCU 42-05X and 42-05Y wellbores). Approximately 414 MMcf of gas has been injected into the 77-3 reservoir since the pressure has stabilized in the SCU 12A-04 well (since 5/4/09), and a total of 534 MMcf of gas has been injected since storage resumed on 4/22/09. Once again, it does not appear that the 77-3 storage resevoir is in communication with the SCU 12A-04 wellbore. We will be continuing to fill the 77-3 reservoir over the coming months and will continue to monitor the SCU 12A-04 wellbore. If you have any questions or concerns, please give me a cali. Paul «SCU 12A-4 Monitoring 5-20-09.x1s» Paul Winslow Petroleum Engineer Advisor Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907-263-7629 Cel I: 907-382-3813 Fax 907-263-7828 pwinslow@chevron.com c~r--~~ ~~ ~' ~~v • Page 1 of 1 ----~~• 1.~ `\ ~- ~ ~c -- ~ _. 11 /19/2009 ~i+~ ~ A7A n~ 2200 2000 1800 1600 1400 •N 1200 a a 3 iooo soo 600 400 200 0 ~\~\~Op~ ~~~0~~ ^~\~0~~ ~~\~0~~ `L~ `L `L~ ~\~\~0~0 ~~~0~0 ~~\~0~~ ~~ ^~~ • • Date ~~\~0~~ ~~~0~~ ~~\~0~~ ~\~0~~ ~~\~0~~ ~O\~0~~ ~~\~0~0 ~\~0~~ ~~\~00~ ~~\~0~~ ~~ \ \ ~~~ ~~ ~~ \ ~~~ ~~ ~~ SCU 12A-04 Pressure Monitorin~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, May 04, 2009 2:40 PM To: 'Winslow, Paul M'; Regg, James B(DOA) Cc: 'Whitacre, Dave S'; 'Greenstein, Larry P'; 'Myers, Chris S'; 'Tyler, Steve L'; 'Bonnett, Nigel (Nigel.Bonnett);'Eastham, Kevin (KEastham)' Subject: RE: SCU 12A-04 Pressure Monitoring Paul, Thanks for providing the information. I concur with you assessment. We will look for your continued information as injection into the storage reservoir continues. Call or message with any questions. Tom Maunder, PE AOGCC From: Winslow, Paul M [mailto:PWinslow@chevron.com] Sent: Monday, May 04, 2009 1:30 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Whitacre, Dave S; Greenstein, Larry P; Myers, Chris S; Tyler, Steve L; Bonnett, Nigel (Nigel.Bonnett); Eastham, Kevin (KEastham) Subject: SCU 12A-04 Pressure Monitoring Tom & Jim, Attached is a spreadsheet showing the latest pressure measurements from the SCU 12A-04 wellbore. Note that since resuming injection into the 77-3 gas storage reservoir (on 4/22/09), the SCU 12A-04 casing pressures have remained stable and the tubing pressure stayed on the same trend. Over the past couple of days, the tubing pressure has started to flatten out and was at 2,027 psig this morning. Assuming no fluid in the tubing (as a conservative estimate), this WHP would equate to a SI BHP (at the 77-3 reservoir datum of 7,787' TVD) of -2,420 psia. Material balance on the 77-3 reservoir would suggest an average reservoir pressure of -2,010 psia as of this morning. Thus it appears that the pressure in the SCU 12A-04 well is at least 400 psi higher than the 77-3 reservoir. We will be continuing to fill the 77-3 reservoir over the coming weeks and months and will continue to monitor the SCU wellbore. If you have any questions or concerns, please give me a call. Paui «SCU 12A-4 Monitoring 5-4-09.xis» Paul Winslow Petroleum Engineer Advisor Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907-263-7629 Cell: 907-382-3813 Fax 907-263-7828 pwinslow@chevron.com 11 /19/2009 SCU 12A-04 S 04 SITP CU 12A - Pressure Monitoring = 2,027 psig (on 5/4/09) 2200 2000 1800 1600 1400 . °-~ 1200 y a a 1000 ~ 800 600 400 200 0 O~ O°' O°~ O°~ O°' O°~ o°' o°' O°' O°' O°~ O°~ O~' O°' O°' O°~ O°' ~O ~O ~O ,y0 ~O ~O ~O ~O ~O ~O ,LO ~O ~O ~O ~O ~O ~O ~~~ ~ °~~ ` ~~j~ `l' ~°~ `~~ ~~ °~~ ` ~~ ~`l' ~°~~ ` ` ~ ~°~ ~~ ~~ 1~ ~p`~ `L ry rL\~ rL\ l, `~ ,~\~ , ~\ L p p, ~\~ ~\ l, ~\ ~ ~\ ` c,\~' ~ ~\ c~\~' Date ~ +Tubing Pressure ~ -~ Production Casing Pressure ~ Surface Casing Pressure SCU 12A-04 SITP = 1,802 psig (on 4/22/09) 77-3 Reservoir Pressure: ---- _ -1,867 psia (as of 4/21 /09) (before Injection resumed) 010 psia (as of 5/4/09) _ -2 , ~~MNh 4/22/09 - Resume Injection into 77-3 Reservoir *ti........,.,..+~.~,.~..,~~ _ i • SCU 12A-04 Update 4-20-09 ~ ~ Page 1 of~`~{ .~ Maunder, Thomas E (DOA) From: Winslow, Paul M [PWinslow@chevron.com] Sent: Wednesday, April 22, 2009 9:22 AM To: Maunder, Thomas E (DOA) Cc: Whitacre, Dave S; Myers, Chris S; Eastham, Kevin (KEastham); Merle, Greg L; Page, Donald A; Tyler, Steve L; Bonnett, Nigel (Nigel.Bonnett); Regg, James B(DOA); Greenstein, Larry P Subject: RE: SCU 12A-04 (174-021) Update 4-20-09 Tom, Thank you for your quick response to our request to resume injection into the 77-3 reservoir. In response to your requests/questions below: 1. In addition to the monthly monitoring report that Mr. Greenstein sends to the AOGCC (which will continue to include the SCU 12A-04 well), I will try to send you bi-monthly updates on the monitoring of the SCU 12A-04 welibore (at least initially), as we resume injection into the 77-3 reservoir. If anything out of the ordinary happens, the AOGCC will be notified immediately. 2. Christine Mahnken located a copy of the 9-5/8" bond log from SCU 12-04, in your off-site storage. I thought that she had shown you the log either before or after she had it sent out to be scanned for our files. If you still need a copy, we should be able to print another copy and send it over to you. 3. After reviewing the 77-3 reservoir well penetrations in the vicinity/fault block of the 77-3 storage operation; we have concluded that three (3) additional wells need to be added to the monthly monitoring list. Mr. Greenstein will add SCU 33-05, SCU 314-04, and SCU 13-04 to the list of monitored wells that are reported to the AOGCC. All other non P&A'd wells are already on the monitoring list. Please note that even though these three welis have not been reported monthly to the State, they have been monitored by Chevron, as are all shut-in and producing wells in the Swanson River Field. If you have any other questions regarding the SCU 12A-04 or 77-3 storage reservoir, please drop me a note or give me a call. Paul Winslow Chevron N American Exploration 8~ Production MidContinent / ka Business Unit 3800 Centerpoint Dr., ite 100, Anchorage, AK 99503 Tel: 907-263-7629 Cel I: 907-382-3813 Fax 907-263-7828 pwinslow@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.g Sent: Tuesday, April 21, 2009 11:40 AM To: Winslow, Paul M Cc: Whitacre, Dave S; Myers, Chris S; Eastham, Kevin (KEastham); Merle, Greg L; Bonnett, Nigel (Nigel.Bonnett); Regg, James B(DOA) 11 /19/2009 Donald A; Tyler, Steve ~• ._ SCU 12A-04 Update 4-20-09 . ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 21, 2009 11:40 AM To: 'Winslow, Paul M' Cc: 'Whitacre, Dave S'; 'Myers, Chris S;'Eastham, Kevin (KEastham)'; 'Merle, Greg L'; 'Page, Donald A'; 'Tyler, Steve L'; 'Bonnett, Nigel (Nigel.Bonnett)'; Regg, James B(DOA) Subject: RE: SCU 12A-04 (174-021) Update 4-20-09 Attachments: AOGCC_77_3_SCtJ42-05XY_Mar2009.ppt Paul, et al, Jim and I have examined the available information provided by Chevron over the past few months regarding possible subsurface communication to the 77-3 gas storage reservoir via SCU 12A-04. It appears that it has been demonstrated that the tubing and production casing have pressure integrity and the gas analyses demonstrate that the gas from SCU 12A-04 is different from the gas being stored in the 77-3 reservoir. On the basis of the information supplied and your stated forward monitoring plans it is ACCEPTABLE to resume qas storaqe injection into the 77-3 reservoir.~ V11e will look forward to reviewing the monitoring information. We do have a couple of requests/questions ... ~ 1. Will the SCU 12A-04 information be provided in the normal monthly monitoring report or under separate cover? 2. Was a copy of the 9-5/8" bond log from SCU 12-04 (161-101) ever located? 3. A plan view of wells proximate to the 77-23 reservoir was provided by Mr. Eastman on March 4(copy attached). There are a number of wells that appear to be in the 77-3 polygon that are not presently on the monthly monitoring list provided by Mr. Greenstein. Please confirm that all wells penetrating the 77-3 reservoir are on the monthly monitoring list. Call or message with any questions. Tom Maunder, PE AOGCC om: Winslow, Paul M [mailto:PWinslow@chevron.com] Sen Monday, April 20, 2009 3:20 PM To: Mau r, Thomas E(DOA); Regg, James 6(DOA) Cc: Whitacre, ve S; Myers, Chris S; Eastham, Kevin (KEastham); Merle, Greg L; Page, Donald A; Tyler, Steve L; Bonnett, Nigel ~ el.Bonnett) Subject: SCU 12A-04 date 4-20-09 Tom & Jim, Since our last status report on 4-2-09, SCU has remained shut-in and there has been no injection into the 77-3 reservoir (via SCU 42-OSX and SC 2-OSY). Tubing and casing pressure readings (for SCU 12A-04) have been recorded every six hours du this time. The attached spreadsheet shows the pressure readings since SCU 12A-04 was shut-in, in additi to the pressures back to early February, when the pressure increase was brought to your attention. Note that on 4/2/09, the tubing and casing strings were completely blinde ff from one another. The plot of the pressure data indicates that there is mechanical integrity between t wo strings of pipe. The casing pressure has stabilized at approximately 915 psig, whereas the tubing press continues to cliinb and is currently at 1,747 psig. Why the tubing and casing pressures were tracking prio this blind-off operation (and aren't now), has yet to be fully explained. 11 /19/2009 LEGEND: Blue Line/Numbers = Section Line/Numbers. Green Lines = Well Paths Purple Lines = 77-3 storage reservoir fault polygons. Gray Lines/Numbers = top of 77-3 reservoir Structure Contours Red Well Names located SW of BHL. Red + signs indicate location of wellbore intersection with top of 77-3 sand. Negative number to SE of red + sign is 77-3 sand depth in TVDSS. Black + signs indicate wellbore Surface Hole Location S7, ' - SCU 32-05 ~ ' -78J0 ~\ 1 ~ SCU 32Q-0~ 5 ~ ` \ \~~ \\ \\\ \~\ • SCU 92R-05 ;~ SCU 92-BSRO(/ ~ SCU 92-9,:i r ~ / ~~U9~~-~-~5~g~689 SCU 42-~57~,' '_769] ~ ~ ' -7597 ~ -'7~98 , ', ~ ' SCU 928-0SP8. ~ , i ~ ~~_ J: 1! ' i SLU 33-05 ~ -~--' ~ ~~ ~ z,~-~ 7n~5G SL~t~9~~=~~ -7655 ~,~--i' '~' E -~' '~~-~ - 7F9 B7 ' \~ ~ -7695 ~ ~CU 29R-05 f ,~ - -- _ !~~ P 05 ; ..\ \ ~ ``\~ scu 39-es ,\ ,` .; -7431 + SCU 12A-04 ~ SCU 12-04 ~ 79 ~ ~ + C BHL SCU ~1-04P8 +' BHL 4 ~ SCU 22-04 • ~ ~ SCU 323-04 1 4 -7312 N • I s~~ a,9-~~ _;~sz 0.2 5 mi \. _ ~~ ~ ~ SCU 12A-04 Update 4-20-09 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Winslow, Paul M [PWinslow@chevron.com] Sent: Monday, April 20, 2009 3:20 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Whitacre, Dave S; Myers, Chris S; Eastham, Kevin (KEastham); Merle, Greg L; Page, Donald A; Tyler, Steve L; Bonnett, Nigel (Nigel.Bonnett) Subject: SCU 12A-04 Update 4-20-09 Attachments: SCU 12A-4 Monitoring 4-20-09.x1s Tom & Jim, Since our last status report on 4-2-09, SCU 12A has remained shut-in and there has been no injection into the 77-3 reservoir (via SCU 42-OSX and SCU 42-OSY). Tubing and casing pressure readings (for SCU 12A-04) have been recorded every six hours during this time. The attached spreadsheet shows the pressure readings since SCU 12A-04 was shut-in, in addition to the pressures back to early February, when the pressure increase was brought to your attention. Note that on 4/2/09, the tubing and casing strings were completely blinded off from one another. The plot of the pressure data indicates that there is mechanical integrity between the two strings of pipe. The casing pressure has stabilized at approximately 915 psig, whereas the tubing pressure continues to climb and is currently at 1,747 psig. Why the tubing and casing pressures were tracking prior to this blind-off operation (and aren't now), has yet to be fully explained. Plan forward: Chevron would like permission from the AOGCC to resume injection into the Tyonek 77-3 reservoir, via the SCU 42-OSX & SCU 42-OSY wellbores. During this injection, Chevron proposes to leave SCU 12A-04 shut-in and will continue monitoring the well with six hour readings on the tubing and casing. Note that with the warmer temperatures and thus lower demand for produced gas, Chevron will be forced to shut-in gas production (from Swanson River Field, Grayling gas sand, etc.) if we are not allowed to inject into the 77-3 storage reservoir. If you have any questions with this update, or would like to discuss our proposal, please give rne a call at your earliest convenience. Paul «SCU 12A-4 Monitoring 4-20-09.x1s» Paul Winslow Petroleum Engineer Advisor Chevron North American Exploration 8~ Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907-263-7629 Cel I: 907-382-3813 Fax 907-263-7828 pwinslow@chevron.com /~0 ~ s ~ ~~ ~ ~~ J ~~ 11/19/2009 ~~~ ~'~ 2000 1800 1600 1400 1200 rn .N ~ 1000 a x ~ 800 600 400 200 0 SCU 12A-04 Pressure Monitoring ~ Tubing Pressure -•- Production Casing Pressure + Surface Casing Pressure ~ \~\~o~~ ~~~0~~ ~~\~o~~ ~\~0~0 \~\~0~0 `L ~,\ ~y\ ~,\`L `~ \`l'~~~ \`l'~~~ \~'~~~ \`L~~~ \`L~~~ \`L~~~ \`L~~~ \`L~~~ ~~~~ ~~~~ ~~~~ ~\~ ~`\~ D~~~~ D~~~~ ~~~~ Date • ~ lo/ e Cly ,' ADO Oh lie l°c�,r,a�' pf %4Q A' 7-4 y- �� a/ 6 /f OTGyes AOS 74� �6 /eCv vo/'or� %f Cif l�fPrPk� ' �y% fi ceo t� -7d, d� ce(llpP 6� arm � to � �C. Ci/'e t� tloN.� Q�xfi✓reis�h Gi G((��P✓ N Ol Eol rql`oAetl- 0r tkc QS IQ_ q (�oUv; aye r 4,',s r—e-tl � � tot,, Maavl�&% SCU 12A-04 Monitoring Update • • Page 1 of 2 Maunder, Thomas E (DOA) From: Winslow, Paul M [PWinslow@chevron.com] Sent: Thursday, April 02, 2009 3:51 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Tyler, Steve L; Myers, Chris S; Whitacre, Dave S; Eastham, Kevin (KEastham); Brandenburg, Tim C; Merle, Greg L; Greenstein, Larry P Subject: SCU 12A-04 Monitoring Update Attachments: Gas Storage Gas Analyses Summaries 3-19-09.xis; SCU 12A-04 Gas Analyses Mar-09.pdf Tom & Jim, I just wanted to give you an update on the SCU 12A-04 monitoring. After seeing the tubing and casing pressure increases in the 12A-04 well (back in February), we have been monitoring the well daily. After the last time we spoke with you, we attempted to run a gauge ring to the bottom of the tubing, but could only get to 8,100' MD. We then ran a pressure/temperature log to 8,078' MD. Neither the static nor dynamic pass of the pressure/temperature log showed any indications of fluid movement behind pipe. We then opened the well up to flow through the tubing and have monitored both the tubing and production casing for the last couple of weeks. During this time, the well flowed gas at about 35 Mcf/d. Three (3) gas samples were taken, all of which show significantly heavier gas (less methane and more propanes, butanes, etc.) than any of the storage gas. I've attached a scan of the three gas analyses. I've also attached a spreadsheet of historic gas analyses from our storage operations (KGSF #1 (prod. & inj.), KGSF #7A, SCU 42-05X, SCU 42A-05, & SCU 4213-05). It's interesting to note that the injected and produced gas back in the 2001 timeframe is very close in composition to the current samples taken from SCU 12A-04 (-93% methane, 1.8% ethane, 1.7% propane, 0.8% butanes(i & n), etc.). In 2001, we were blowing down the Hemlock pressure - maintenance gas, which was the snake up of what was being put into storage. In contrast, the gas going into (& out of) storage in the past —4 years has been predominantly Tyonek, Beluga, & Sterling gas, which has a much lighter composition (-98% methane, 0.2% propane, 0.2% butanes, etc.). Based upon these gas analyses, we do not believe that the gas coming from the SCU 12A-04 well is storage gas (coming from the 77-3 storage reservoirs). It is our opinion that the gas in the SCU 12A-04 well is Hemlock/G zone gas, which is most likely migrating up the wellbore past one or more isolation packers. Fluid levels were shot within the past couple of days, on both the tubing and annulus. The annulus showed a fluid level of 7,777' MD, which is —100' below the second lowest gas -lift mandrel. The fluid level in the tubing wasn't clear (from the echo meter), so a pressure/temperature gauge was run. This pressure/temperature log showed a fluid level inside the tubing at 6,116' MD. Plan forward: The SCU 12A-04 well is currently shut-in, and we are going to blind off the tree from the flowline and also blind off the tubing from the production casing. We are installing electronic gauges on both the tubing and production casing and will be recording pressures every 6 hours. The idea is to monitor both the tubing and casing and see where the pressures level off at. It is then our hopes to get AOGCC permission to resume injection into SCU 42-05X & SCU 42-05Y, and see if the pressure in SCU 12A- 04 change. AA-k� 5 r-� SrGC VC' -'k �i "-_V LC C, L� r� �i �-o - � 11/19/2009 1 SCU 12A-04 Monitoring Update ~ ~ Page 2 of 2 Note that we have not injected any gas into 77-3 storage reservoir (SCU 42-OSX & SCU 42-OSY) since notifying the AOGCC of the elevated pressures in SCU 12A-04. We have however produced a minor amount of gas from 77-3 storage, in meeting our gas contracts. If you have any questions with this update, please give me a call. «Gas Storage Gas Analyses Summaries 3-19-09.x1s» «SCU 12A-04 Gas Analyses Mar-09.pdf» Pau/ Winslow Petroleum Engineer Advisor Chevron North American Exploration 8~ Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907-263-7629 Cel I: 907-382-3813 Fax 907-263-7828 pwinslow@chevron.com 11 /19/2009 Date Report Name Meter Meter # Created SRU : 3/19/2009 Gas Analysis KGSF-1 1569 Date Btu (btu/n3) Gravity C02 (%) N2 (%j Meth (%) Eth (%) Prop (%) IBut (%) NBut (%) NeoPent (%) IPent (%) NPent (%) C6+ (%) 5/14/200713:06 1014.69 0.571 0.262 1.06 97.9 0.26 0.21 0.06 0.11 0 0.032 0.039 0.064 1/16/2007 17:00 1014.49 0.571 0.249 1.18 97.68 0.35 0.2 0.09 0.14 0 0.028 0.031 0.043 11 /27/2006 14:11 1017.51 0.574 0.272 1.19 97.6 0.35 0.18 0.07 0.11 0 0.024 0.031 0.169 5/15/200612:20 1021.46 0.574 0.213 1.09 97.3 0.73 0.23 0.15 0.19 0 0.029 0.026 0.045 9/19/200514:39 1025.35 0.578 0.199 1.2 96.45 1.49 0.27 0.14 0.18 0 0.023 0.022 0.03 6/20/200516:07 1006.98 0.56 0.197 0.62 99.06 0.12 0 0 0 0 0 0 0 4/12/200516:55 1025.92 0.577 0.181 1.15 96.89 0.96 0.34 0.14 0.2 0 0.04 0.037 0.065 3/15/200519:21 1014.58 0.569 0.181 1.07 97.75 0.64 0.16 0.07 0.09 0 0.013 0 0.042 11/16/200413:43 1010.45 0.558 0.13 0.36 99.45 0.03 0.01 0 0 0 0 0 0.015 3/29/200412:33 1030.56 0.586 0.234 1.64 95.38 1.61 0.56 0.19 0.26 0 0.044 0.041 0.04 1/19/200413:36 1016.11 0.564 0.17 0.53 99.01 0.06 0.01 0 0.01 0 0 0.016 0.182 6/9/200313:18 1036.46 0.59 0.317 1.46 95.43 1.19 0.98 0.19 0.27 0 0.054 0.051 0.062 3/10/200316:08 1054.6 0.6 0.223 1.46 94.35 1.64 1.42 0.27 0.39 0 0.079 0.075 0.085 12/18/200214:42 1071.33 0.61 0.193 1.48 93.37 1.96 1.71 0.39 0.56 0 0.117 0.107 0.114 12/11/200117:52 1066.17 0.608 0.182 1.56 93.51 1.93 1.73 0.32 0.44 0 0.102 0.096 0.12 12/11 /2001 15:37 1066.54 0.608 0.184 1.57 93.46 1.94 1.75 0.32 0.45 0 0.1 0.099 0.119 ~ ~ Date Repo~t Name Meter Meter # Created SRU : KGSF #1 3/19/2009 Gas Analysis Inj. 1581 Date Btu (btu/ft3) Gravity C02 (%) N2 (%) Meth (%) Eth (%) Prop (%) IBut (%) NBut (%) NeoPent (%) IPent (%) NPent (%) C6+ (%) 8/20/200713:42 1022.65 0.574 0.197 1 97.34 0.85 0.19 0.12 0.17 0 0.024 0.034 0.06 6/19/200712:51 1018.42 0.574 0.239 1.18 97.46 0.45 024 0.12 0.18 0 0.033 0.041 0.052 4/12/200711:09 1012.5 0.568 0.263 0.99 98.14 0.22 0.15 0.05 0.09 0 0.026 0.033 0.044 1/16/2007 12:36 1019.63 0.575 0.265 1.19 97.45 0.32 0.3 0.1 0.18 0 0.056 0.068 0.071 9/19/200615:21 1017.94 0.569 0.212 0.79 98.21 0.25 0.24 0.07 0.12 0 0.032 0.037 0.046 7/5/2006 6:44 1018.38 0.574 0.212 1.27 96.63 1.53 0.15 0.08 0.1 0 0 0 0.019 4/5/2006 17:51 1031.66 0.581 0.217 1. ~ 3 96.64 0.94 0.36 0.22 0.32 0 0.064 0.058 0.055 9/19/200512:38 1021.85 0.576 0.193 1.22 96.74 1.3 0.2 0.13 0.16 0 0.021 0.019 0.026 6/20/200514:14 1031.96 0.583 0.194 1.33 96.38 0.97 0.43 0.15 0.27 0 0.075 0.081 0.116 4/12/200514:05 1014.44 0.574 0.187 1.51 97.1 0.63 0.21 0.13 0.17 0 0.021 0.02 0.031 12/13/200416:41 1017.78 0.572 0.202 1.09 97.64 0.49 0.21 0.11 0.16 0 0.032 0.034 0.04 9/20/200416:04 1021.04 0.572 0.203 0.92 97.57 0.72 0.22 0.12 0.18 0 0.016 0.027 0.03 6/21/200416:39 1034.96 0.586 0.218 1.34 95.76 1.53 0.54 0.17 0.24 0 0.062 0.064 0.083 3/29/200414:36 1042.01 0.592 0.217 1.46 95.13 1.63 0.78 0.23 0.32 0 0.081 0.078 0.074 1/19/200413:13 1121.76 0.641 0.215 1.28 92.55 1.72 1.12 0.44 0.87 0 0.486 0.575 0.738 10/2/200314:12 1041.76 0.592 0.229 1.54 95.07 1.59 0.78 0.21 0.31 0 0.079 0.079 0.118 9/10/200212:51 1048.31 0.596 0.196 1.52 94.45 2.01 1 0.27 0.37 0 0.067 0.059 0.054 6/11/200216:07 1054.54 0.6 0.199 1.49 94.25 1.96 1.17 0.28 0.4 0 0.086 0.085 0.095 3/14/200218:20 1054.67 0.599 0.191 1.47 94.36 1.88 1.1 0.3 0.41 0 0.085 0.079 0.118 1/2/2002 18:55 1085.86 0.619 0.188 1.46 92.83 1.98 1.73 0.57 0.76 0 0.154 0.142 0.185 9/11/200116:22 1086.96 0.619 0.183 1.41 92.49 2.22 2.23 0.42 0.65 0 0.142 0.139 0.126 9/11/200114:45 1059.9 0.604 0.179 1.57 93.79 1.87 1.64 0.3 0.4 0 0.088 0.079 0.074 6/21/200115:28 1066.82 0.608 0.183 1.6 93.39 1.95 1.77 0.33 0.46 0 0.105 0.1 0.104 6/21 /2001 13:05 1066.96 0.609 0.183 1.6 93.37 1.96 1.78 0.33 0.46 0 0.105 0.099 0.104 ~ ~ ~ Date Report Name Meter Meter # Created SRU : KGSF-7 3/19/200 Gas Analysis Prod 1589 9 Date Btu (btu/ft3) Gravity C02 (%) N2 (%) Meth (°/a) Eth (%) Prop (%) IBut (%) NBut (%) NeoPent (%) IPent (%) NPent (°/a) C6+ (°/a) 5/14/200710:29 1014.72 0.571 0.263 1.06 97.89 0.27 0.22 0.06 0.11 0 0.032 0.04 0.052 2/26/200713:45 1016.01 0.571 0.243 1.09 97.81 0.3 0.21 0.08 0.14 0 0.037 0.041 0.057 11/27/200614:53 1023.54 0.577 0248 1.14 97.44 0.31 0.31 0.09 0.17 0 0.061 0.068 0.156 5/15/200610:44 1025.17 0.577 0214 1.09 97.06 0.82 0.28 0.18 0.25 0 0.043 0.034 0.031 11/14/200513:39 1018.63 0.572 0.199 1.06 97.37 0.9 0.2 0.09 0.12 0 0.018 0.013 0.035 9/12/200511:41 1015.08 0.57 0.202 1.06 97.5 0.93 0.14 0.06 0.07 0 0 0 0.032 3/15/200519:40 1033.27 0.583 0.19 1.22 96.2 1.31 0.48 0.16 0.23 0 0.055 0.056 0.092 1/31 /2005 13:22 1009.18 0.565 0,217 0.94 98.35 0.3 0.08 0.04 0.06 0 0 0 0.018 1/31 /2005 12:39 1008.6 0.565 0.228 0.97 98.31 0.3 0.08 0.03 0.05 0 0 0 0.018 \ J LJ Date Report Name Meter Meter # Created SRU : 3/19/2009 Gas Analysis 42x-5 1598 Date Btu (btu/ft3) Gravity C02 (°/a) N2 (%) Meth (%) Eth (%) Prop (%) IBut (%) NBut (%) NeoPent (%) IPent (%) NPent (%) C6+ (%) 1l16/200715:43 1016.98 0.573 0.245 1.17 97.61 0.34 0.23 0.09 0.16 0 0.041 0.044 0.067 8/2/200612:23 1014.59 0.576 0.278 1.56 97.07 0.4 0.28 0.09 0.16 0 0.038 0.048 0.081 8/2/200611:16 1012.96 0.576 0.278 1.7 96.94 0.4 0.27 0.09 0.16 0 0.044 0.044 0.075 8/2/200610:59 1012.44 0.576 0.274 1.72 96.94 0.39 0.27 0.09 0.15 0 0.039 0.043 0.076 8/2/200610:42 1017 0.577 0284 1.51 97.05 0.4 028 0.1 0.17 0 0.046 0.057 0.107 8/2/200610:11 1015.5 0.576 0.281 1.53 97.08 0.39 0.28 0.1 0.16 0 0.042 0.053 0.085 \J C~ Date Report Name Meter Meter # Created SRU : 3/19/2009 Gas Anal sis 42A-5 1586 Date Btu btu/ft3 Gravit C02 % N2 %) Meth % Eth % Prop °/a IBut °/a NBut % NeoPent °/a IPent % NPent % C6+ % 11 /3/2005 15:52 1008.33 0.562 0.174 0.79 98.75 0.16 0.07 0.02 0 0 0 0 0.021 5/3/200516:43 1008.19 0.562 0.149 0.84 98.73 0.16 0.07 0.02 0 0 0 0 0.026 1/31 /2005 13:40 1007.17 0.563 0.21 0.84 98.66 0.19 0.07 0.02 0 0 0 0 0.013 11/16/200413:19 1008.79 0.562 0.153 0.77 98.81 0.16 0.07 0.02 0 0 0 0 0.029 11/16/200413:01 1008.87 0.563 0.209 0.78 98.68 0.2 0.08 0.02 0 0 0 0 0.029 11 /2/2004 18:24 1007.84 0.562 0.205 0.78 98.72 0.19 0.07 0.02 0 0 0 0 0.012 8/2/200416:55 1007.5 0.562 0.194 0.81 98.71 0.19 0.07 0.02 0 0 0 0 0.007 i ~ Date Report Name Meter Meter # Created SRU : Productio 3/19/200 Gas Analysis n 1597 9 Date Btu (btulft3) Gravity C02 (%) N2 (°/a) Meth (%) Eth (%) Prop (%) IBut (%) NBut (%) NeoPent (%) IPent (%) NPent (%) C6+ (%) 4/5/200611:25 1023.48 0.58 0.257 1.43 96.57 0.83 0.35 0.16 0.25 0 0.05 0.049 0.053 12/20/200511:58 1022.12 0.575 0.321 0.96 97.19 0.85 0.3 0.12 0.17 0 0.024 0.027 0.036 ~ ~ # 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T?r'i:; ~~'` .~,~~~ 1057.0 ~tu/~F _ ~6 . 5i?9 lbc: /100C3C~' 46 . g361 yk3m/? f~~OC:~' = _r~9.~1 :'"'.341 ^~? ~~s Cf 1G54 .4 $~u/~..r Aug.20 Ofi 0$ : 07 ~?i: 3.4-~~ . ~.v. Cr+ l~m/GaI 5.5425C, ~.n~ C6+ P~c~l.~~1~.. 92.0~. "! ~.. lr~../ '~~ i . ,- 4~ /+y~ ., r+ 11. ,.e1 ~ 4 I t ~C.a=~ ~ ,~ { ^ • • Cl~andl~r Engineering ~o. i~ade~ 292,r~92G B3'i.T Analyzer ~'=; 4fi tine: ~3ar.23 ~~ 11:54 ~.'@S~ ~ : $ ~a17.~J1"at1L9:'t #; 5 LoCation ~do. :254~ StGr-dar~!~ zy A~a?ysis Satudat~d/t~e~ ~r~alysa.s t°~iale°~ ~~i~* k.Den. ~ GPM** f=~c1.e~ B'I°tJ~ R.Den. * *`yuh~r_e 93.3~~ 945.2.~ ^u.5i?2 -- Q2.74A 92$.7E Q.508i ~a±°h~,ae 1. ~? ~ 32 . 6v J. Jl~l 0.4~1i 1. 806 32 . 0.~ 0. OI87 = z:t~;^~r~~ ~, .':°~2 44 .19 0. t~267 0. 4824 1. ~'22 43 .42 fl. 0262 i-F:::~G~.e 0.353 11.52 O.GO^3 0.125b 0.3~i? 11.32 fl.OG7~ ~.-'3~:.~~:~? 0_ d 2t? 2' . 00 0. 0104 Q.1539 tI . 511 ? 6.7fl {3 . t7I~3 i-P~z~~ta?~e 0.1? I 5.~6 0.~433 U. 048C 0.129 5.17 0. Ot~32 n-Pen*~ne 0.''.?:? ~.s2 (?.0~3~ 0.0479 fl.13{7 5.?.?. O,OCt32 { C6+ ) tl . 2i~ ~ ~ . C~ ~ . C;[??3 ~ . ~98? 0 . 22~ I.1.43 (7 . G074 '~~.^ista~e ~.OC~:3 i .4~ fl.~OC~ -- 1.74~ ~'.86 fl.t31t}B li.~tx'uQ~r~ ~ 1.~~`~ Q.O~ O.~J15Q __ 1r523 ~.OQ fl,(~1a~7 { C!~2 ) 0.125 G~ .~Q u. OC~19 -- ~i . 32s 0. QO 0. t?G29 zae~~, ~.ao , ov ~c~~ .-; a. ss~a z. 4~~~ * . ~T~'!.~rYr~~t~d ~~r ^~:~~essi~~Iit;r at ~".OR & ~4.730PSIA. ** : Lir~,:id L'o~uwe renorted at 60.OF. S~~n~arc~/~rp "nalysis Satura~edJWet P_na].yszs '=:~1~.~ A~ass = I.7 . i a 1 I7 ."7t}? It~l~.t~ v~ L'ensi'~s' = 0.~124 Q. 61~6 Cc~r.sgres~ibili~v ~~.ct~?" = 0.9975 0.9S7S Cr~ss he~* ir~g Va1t:e = 22945 . Btui lb 22557 . Btu/1 b Groas ;:ea~~r~ valve = 1075.3 Bt~1CF Abso~.t~te Gas DE'ris1t,' ~~~b~~ Tnde~: Un~aara;~lizcd Tctal : Last Calibrated s.*~ ~h C6+ Last i."~a~.~` ~ : Gs ='~ 'r`+ ~'I'*V;`vF 5Co! 1057.6 Btu/CF = ~~.8654 1bmJ1000CF 46,8845 lbm!IOflOCF = 1351.45 93 , 79E; Calgas cf 1(354,0 Btu/CF ~ug.2Q 0$ 08;07 a:S1-9Q. i.8, C6-~ 1'.b:'1/G11 5.64250, ~I2d C6+ M~1.FaTt. 92.Ot?. ~~ ? ~ t - ~, l ~ /, ,A '~;? .rL.~ rN ~~_r~ ~ f ~/ ~,! ! t f~' "t ~{~, ~' i • Chandl.e~' E~.g~.neering Co . '~tedel 292/2920 BTL; AnaZyzer Te~C tim~~: N:ar.3~ L'~ 12:49 Ta~'t # : 5 Cal~.bratiar_ # : 5 liocation NQ. :2~40 S~an3ard/;~ry Ana?ysis Mole~ BT[a* R.Den.* GPM** ?~i~C3~~r~ie 94.523 9~6.92 0.5236 -- ~'~hare 1.54~ 27.~6 {~.01~1 0.4137 '.-'~7Fane 1. , 27' 32 . L~~ 0. 0194 ~. 3499 ~-Butane 4.233 7.60 0.~+047 0.0763 n-~ut~ne 0.320 3.0.~7 U.4064 L.1009 i-Pentan~ 0.~47 1.90 0.(3a12 0.017~ n-Pentan~ 0.t~55 2.~3 U.0014 0.0201. ( C~+ } 0.1!J9 5.52 Q.0035 f3.G468 ?~!oisture o.oc~ o.oe a.oooo -- ~s:~.~z~o~en ~..~~~ o.o~ o.oi~~. __ f ~'~2 } 0.124 O.C10 0.001~ -- ~~~~:~a~e~.o~~~ ~~~~~~5 i+~C~le$ 3'I'L~ R.Den_* 92.878 :4~.27 +~.5144 1.52: 26.98 0.03.58 ~..~~~ ~i.~~ o.o~.~o p. 229 i.47 0. t?Q~6 0.315 1Q.2~ Q.U0~3 0.047 1.87 ~.G022 ~.Q55 2.19 0.~014 0. 20? 5.~2 0. O(334 1.7~t~ {3.88 4.03.0~ 1.738 O.OQ 0.0168 o.a.2~ n.oc o.ooia Ideal 100,00 1fl~4.1 0.5951 1.0251 *: L+p1ZC.'OT~r~G`~e~ for compressibility at 60.OF & 14.73DPSIA. ~** : Liaui.d Vollam~ re~~rted at 60. OF. S~andard/I~ry P.nalysis SatuxatedJWet Analysis a~9t~1~~ M~.ss = 37.235 17.~~9 Relative D~nsiLy = 0.596?, 0.5967 Cc*.n~ressibility ~`actr~r = 0.9978 0.99?7 ~=~ass H~aci.ng Value - 2~937. Btu/lb 2~~39. BCullb sross Heating Value = '046.5 Btu/CF .Absolu~e Gas I~ensity ~.obbe Index ~Tnnorm~.2ized Total. : Last Calibrated with C5t La~t Up3ate: GP~ ~'S+ I3TU/CF SC6'. 1Q29.3 Btu/CF = 45.5243 1bmf1000CF 45,66~9 ].bm/~ppO~F` = Z333.02 ~2.095 Calga~ o~' 1054.0 Btu/CF Aug.20 C8 48:07 226I-90. ~.8, C6+ 3bm/Gal 5.64250, and C6+ Mol.Wt. 92.00. { .~. rs +:r ' ~ { 1 l• _' "L ~ ~ ,.~, ~ - f , I~~ ' ' ,_g r- %-- ~ Maunder, Thomas E (DOA) ~ Page 1 of 3 From: Maunder, Thomas E (DOA) Sent: Thursday, Aprii 02, 2009 11:00 AM To: Myers, Chris S Subject: RE: SCU 12A-04 Weekend Survey work Hi Chris, No, I have not received any reply. Tom Maunder, PE AOGCC From: Myers, Chris S [mailto:myersc@chevron.com] Sent: Thursday, April 02, 2009 10:57 AM To: Maunder, Thomas E (DOA) Subjed: RE SCU 12A-04 Weekend Survey work Did you get a response back on the request? Chris S. Myers Operations Superintendent MidContinent/Alaska SBU Chevron North America Exploration a~d Production Co. 3800 Centerpoint Dr. suite ]00 Anchorage, Alaska 99503 Tel 907 263 7654 Fax 907 263 7847 Mobile 907 398 9955 myersc@chevmn.com _ _.._ .__ . _ _ _. ___ __ _ _ _ _ _ _ _ __ . _. _. __ _ . From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, April 02, 2009 8:46 AM To: Tyler, Steve L; Winslow, Paul M Cc: Bonnett, Nigel (Nigel.Bonnett); Brandenburg, Tim C; Myers, Chris S; Merle, Greg L; Eastham, Kevin (KEastham); Whitacre, Dave 5; Kanyer, Christopher V; Harness, Evan; Regg, James B (DOA); Bush, Robert E; Walgenbach, Christopher Subject: RE: SCU 12A-04 Weekend Survey work Steve- et al Belov; is the message from Larry regardiag the monthly report of operating pressures for wells In an near the 77-3 _clorage projecl. Ne include5 some comments regarding gas sampling and ana!ysis for 12A-04. Laok at my f!e on the matter, I show the last information I have received was March 9. I have also included that message text Would you or Paul please provide an uFdate on 12A-04 and include the gas analysis information? Thanks in advance. Cail or message with any questions. Tom Maunder,PE ' AOGCC Hi Jim & Tom.. Here is March's monthly report for the wells requiri~g pressure monitoring near !he SRF Tyonek 77-3 Sand Storage reservoir The pievious three menth data window has been ~tiidened to a six month window this report to better cisualize a welfs response to a secondary mechanical integnty fai(ure. The 12A-4 weil saga continues. Gas samples have been cotlected aver time that all show the same thing. The gas in the casing ane tubing ls assureofy Hemlock~G-Zone In origin. Thls gas is appreciably different than the gas put into ihe storage welL The casing pressures probably result from a Isaky chec~k valve In the o~~ifce valve that may or may not seat correctly at times. More v,~ork will follow to further document the pressures. Some ef the daily pressures are sti!I being missed on 22-4, agaln ~a~e are attempting to get all the readlnqs entered into the database. There has been fairiy heavy use of the storage wells thi~ Iast month again, but almost no injection, and a~l pressures are resp~nding as expected. All tr;e rest of the wells appear to have pressures for the month that don't ~how any indications of a response due to the gas storage operations. Botton~ line, Ihe pressures remain in expected ranges for ~hese ~a~elis. Larry _ ___ _ . __ _._ _ .___.._ _ ..._.. __.._ _._. __. _ _ _____ --- - -- __ From: Tyler, $teve L [mailto:tylersl@chevron.com] Sent: Monday, March 09, 2009 1:00 PM To: Maunder, Thomas E (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett); Brandenburg, Tim C; Myers, Chris S; Merle, Greg L; Winslow, Paul M; Eastham, Kevin (KEastham); Whitacre, Dave S; Kanyer, Christopher V; Harness Evan; Reqg, James B(DOA); Bush, Robert E; Walqenbach, Christopher Subject: SCU 12A-04 Weekend Survey work Current Pressures this AM are: Tb9 @ 1740 psi Csg @ 480 psi Tom Finished running our static & dynamic temp/pressure gauges. (composite data attached) No conclusion other than we appear to have tbg integrity. Fonvard Pfan • Open tbg to production for one week. Capture two samples. One within couple days and one at the end of the flow period. • Anaryze gas samples to determined methane amounL 11/19/2009 2009 March's SRF Tyonek 77~nd Storage Well Monitoring Report ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinip@chevron.com] Sent: Thursday, April 02, 2009 8:06 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Ayer, Phil M; Winslow, Paul M Subject: 2009 March's SRF Tyonek 77-3 Sand Storage Well Monitoring Report Attachments: Master Well List TIO Report 2009 04 01.x1s Hi Jim & Tom, Here is March's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77-3 Sand Storage reservoir. The previous three month data window has been widened to a six month window this report to better visualize a well's response to a secondary mechanical integrity failure. The 12A-4 well saga continues. Gas samples have been collected over time that all show the same thing. The gas in the casing and tubing is assuredly Hemlock/G-Zone in origin. This gas is appreciably different than the gas put into the storage well. The casing pressures probably result from a leaky check valve in the orifice valve that may or may not seat correctly at times. More work wiii follow to further document the pressures. Some of the daily pressures are still being missed on 22-4, again we are attempting to get all the readings entered into the database. There has been fairly heavy use of the storage wells this last month again, but almost no injection, and all pressures are responding as expected. All the rest of the wells appear to have pressures for the month that don't show any indications of a response due to the gas storage operations. Bottom line, the pressures remain in expected ranges for these wells. Larry «Master Well List TIO Report 2009 04 01.x1s» 11 / 19/2009 ~ ~ Page 1 of ~, ~ Maunder, Thomas E (DOA) From: Tyler, Steve L [lyiersl@chevron.com] ~ Sent: Monday, March 09, 2009 1:00 PM To: Maunder, Thomas E (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett); Brandenburg, Tim C; Myers, Chris S; Merle, Greg L; Winsiow, Paul M; Eastham, Kevin (KEastham); Whitacre, Dave S; Kanyer, Christopher V; Harness, Evan; Regg, James B(DOA); Bush, Robert E; Walgenbach, Christopher Subject: SCU 12A-04 Weekend Survey work Attachments: image006.gif; image005.gif; SCU 12A-4 Static Survey 3-07-09.zip CurreM Pressures thls AM are: Tbg @ 1740 psi Csg @ 480 psi Tam Finished running our static & dynamic templpressure gauges. (composite data attached) No condusion other than we appear to have tbg integrity. Forv/ard Plan • Open tbg to production for one week. Capture two samples. One within couple days and one at the end of the fiow period. . Analyze gas samples to determined methane amount. M Alaska Wellbore Maintenance Team Leader "' ! Cbevron North America Exp{oration and Production . MidcontinenUAlaska SBU { ~ 909 W. 9th Avenue ~ Anchorage, AK 995013322 /- 'a'Office: (907)263-7649 ~;-- ~CeIL (907) 350-6295 '~Home: (907) 696-1837 QFax: (866)244-1439 - ~ ~'~ ~- ~-- ~ =.^~~Email: tylersl@chevron.com 11 /19/2009 Dil Co. ~ Well: ~ SCU 12A-4 ~ Field: ~ S~ ~J~~ ~~*~~ ~`~ ~~~~~5 ~~~~~ pressure (psia) ~ 1750 1800 1850 1900 1950 2000 2050 2100 0 1000 2000 , 3000 ~ +'~.~ 4000 ~ d ~ ~ L ~ a ~ d ~ 5000 ~ 6000' ~ 7000 ~ ~ 8000 ~ 9000 30 ~ 2150 2200 2250 2300 2350 ~, Pressure-Temperature Profile 1. Going in hole to 8062' RKB 2. Overlay 3-6 static and bleeding casing ; ~ ~ ~ ~. ' . h ~ ~ ~ 40 50 60 70 80 90 100 110 120 130 140 Te m ne ratur~lD~a~F~-_-. Pressure - Perfs ~ Mandrel tbg - 5" 7" 13-3/8" 3-6 Psia Temperature 3-6 Tem 150 ~ • Maunder, Thomas E (DOA) From: Tyler, Steve L [tylersl@chevron.com] Sent: Friday, March 06, 2009 9:34 AM To: Maunder, Thomas E(DOA); Winslow, Paul M; Regg, James B(DOA) Cc: Williamson, Mary J(DNR); Saltmarsh, Arthur C(DOA); Whitacre, Dave S; Page, Donald A; Myers, Chris S; Brandenburg, Tim C; Eastham, Kevin (KEastham); Greenstein, Larry P; Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett); Merle, Greg L; Harness, Evan Subject: RE: 12A-04 (174-021) pressure plot 3-2-09.x1s Attachments: SCU 12A-4.doc ~~ SCU 12A-4.doc (60 KB) Tom We have been looking for a copy of this CBL and as of yet have not been successful in being able to locate this. we are still looking. Operation Update Attached Forward Plan 1. Continue to brush and flush tbg to gain slickline access. 2. Run static memory temp/pressure survey to ETD. 3. Run dynamic (flowing gas from tbg x csg annulus at -lmmcfpd) memory temp/pressure survey to ETD. 4. Capture Gas Sample for analysis. -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 04, 2009 8:42 AM To: Winslow, Paul M; Regg, James B(DOA) Cc: Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A; Myers, Chris S; Brandenburg, Tim C; Eastham, Kevin (KEastham); Greenstein, Larry P Subject: RE: 12A-04 (174-021) pressure plot 3-2-09.x1s Thanks Paul. As I have reviewed the available files over here, I have not been able to find a copy of the 9-5/8" bond log from the 9-5/8" casing of 12-04 (161-001). If that old log is available, a copy of the portion from ~ 8700' (below the milled section) to ~300' above the 77-3 sand would be appreciated. Thanks in advance. Tom Maunder, PE AOGCC -•----Original Message----- From: low, Paul M [mailto:PWinslow@chevron.com] Sent: Tuesda , rch 03, 2009 3:49 PM To: Maunder, Thoma OA); Regg, James B(DOA) Cc: Williamson, Mary J( • Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A; Myers, Chris S; denburg, Tim C; Eastham, Kevin (KEastham); Greenstein, Larry P Subject: RE: 12A-04 pressure plot 3-2-09.x1s Tom & Jim, Just wanted to give you a heads up that we are planning to make a 1.25"\ gauge ring run down the SCU 12A-04 tubing tomorrow, followed by a temperature~ri (assuming the GR run is successful). Hopefully this survey will give us an indicatio s to where the pressure is coming from (i.e. gas movement behind pipe, through the casing, possibly from below the lower plug, etc.). We will keep you appraised as to the results. ~ Chevron ~ ~ SCU 12A-4 C~ 3/4/09 - In preparation of running a temp survey, a 1.5 GR was run to 1,563'. Couldn't get any deeper due to paraffin. - Decision made to call out Hot Oil Truck. - Tubing pressure - 1740# Casing 1740#. - Starting pumping 160 degree crude down tubing @.45 BPM and 1800# tubing pressure. - 10 bbls away tubing at 1500# Casing at 1740# - Start W/L in hole while pumping. - 30 bbls away and tubing up to 2000#. S.D pumping. Tubing bled off to 1500#. Continue pumping the last 10 bbls away. - Tubing 1740# Cas 1740# - W/L falling slowly to 2,389', fell thru to 8,099'. Sat down and couldn't make any hole. Very sticky. Over pull of 800#. Appears to be asphalteens. - Decision made to pump 10 bbls xylene and chase with crude to spot at 8,100'. 3/5/09 - Tubing 1750# Casing 1750# - Pumped 10 bbls xylene with triplex pump. - Rig up HOT and starting chasing with crude. Pressure increased to 2500# on tubing and 1800# on casing at 10 bbls. Shut-down pumping and let pressure bleed off. - RIH with S-line brush to 8,050'. Worked brush to 8,099'. Couldn't make any more hole. - Attempt to run 1.50 bailer. Had trouble getting in hole due to pressure and icing on line. C/O to 1.50 toolstring for more weight. Bled tubing pressure down to 1680# from 2000#. Casing at 1800#. - Ran L50 TS and L50 DD bailer to 7,925'. Couldn't work any deeper. - Appears tubing is corkscrewed. A 1.25 TS will make it down to 8,100', but a 1.50 will only go to 7,925'. No spang action, just a straight pull when pulling up. - End of job - Tbg-1700# Cas- 1760. - Casing didn't appear to track tubing during pumping and bleeding. There was a slight pressure change, probably thermal. - Plan forward is to run temp survey tomorrow down to app. 8,100'. 2009 February's SRF Tyonek ~ Sand Storage Well Monitoring Repo~ Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Thursday, March 05, 2009 12:56 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Ayer, Phil M; Winslow, Paul M Subject: 2009 February's SRF Tyonek 77-3 Sand Storage Well Monitoring Report Attachments: Master Well List 2009 03 02.x1s Hi Jim & Tom, Page 1 of 1 Here is February's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77-3 Sand Storage reservoir. The 12A-4 well was shut-in in January and the shut-in tubing pressure climbed appreciably. Attempting to flow the well resulted u-tubing gas. The next shut-in period showed the tubing and casing pressures climbing timed coincidentally with injection into the 42-5X storage well. Attempting to enter the well for diagnostic survey work showed lots of asphaltenes in tubing causing blockages. Pressure increase may have resulted from preemptive xylene soakings that opened channels in tubing to blocked-in hemlock pressures. More investigations will follow to examine pressure concerns. Some of the daily pressures were missed on 22-4, this has been rectified and daily readings have been reinstated. There has been very heavy use of the storage wells this last month again, including some injection, and all pressures are responding as expected. All the rest of the wells appear to have pressures for the month that don't show any indications of a response due to the gas storage operations. Bottom line, the pressures remain in expected ranges for these wells. Larry «Master Well List 2009 03 02.x1s» ~~c,~ eT~..S~`J~ r~ \C~`~ C 11/19/2009 • • Page ] of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 04, 2009 5:33 PM To: Winslow, Paul M Cc: Bonnett, Nigel (Nigei.Bonnett); Regg, James B(DOA); Saltmarsh, Arthur C(DOA); Williamson, Mary J (DOA) Subject: Swanson Storage Situation Importance: High Paul, This confirms our conversation of a few moments ago. You had advised me when you notified me of the elevated pressures on SCU 12A-04 that it was SI but that gas was stitl being produced from the storage reservoir. What went unsaid at that time, but you confirmed in our conversation was that there is no intent to inject additional gas into the storage reservoir until the situation and mechanism of the communication to 12A-04 is understood and mitigated. You are correct; there should be no gas injection into the storage reservoir until further authorized by the Commission. Keep us advised of the gauge ring and temperature survey outcome. Call or message with any questions. Tom Maunder, PE AOGCC 1 U19/2009 ~ • Maunder, Thomas E (DOA) From: Williamson, Mary J (DOA) Sent: Wednesday, March 04, 2009 2:33 PM To: Saltmarsh, Arthur C(DOA); Maunder, Thomas E(DOA); Regg, James B(DOA) Subject: FW: 12A-04 (174-021) pressure plot 3-2-09.x1s Attachments: AOGCC_77_3_SCU42-05XY_Mar2009.ppt ~~ AOGCC_77_3_SCU 12-05XY Mar2009... Has Art been reviewing this? I would think we need a better subsurface look, and you might find this in the confidential files. As noted in the proposed storage regs, the following is what we had been talking about requiring for application. I can't remember how much we actually made them do. (7) geological and geophysical data and assessments of any regional tectonic activity, regional or local fault zones, and structural, stratigraphic, and lithologic characteristics, focusing on the proposed subsurface gas storage interval, adjacent confining intervals, and producing or potentially productive oil, gas or freshwater- bearing horizons, including (A) an isopach, net pore volume map, and hydrocarbon pore volume map of the proposed gas storage reservoir; (B) isopach maps of the upper and lower confining intervals for the proposed gas storage reservoir; (C) structure maps of the top and base of the proposed gas storage reservoir; (D) map or illustration showing all faults, structural spill points or stratigraphic anomalies controlling the isolation of storage gas; and (E) and structural and stratigraphic cross-sections that describe the geologic conditions at the proposed gas storage reservoir; -----Original Message----- From: Eastham, Kevin (KEastham) [mailto:KEastham@chevron.com] Sent: Wednesday, March 04, 2009 1:19 PM To: Maunder, Thomas E(DOA); Winslow, Paul M; Regg, James B(DOA) Cc: Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A; Myers, Chris S; Brandenburg, Tim C; Greenstein, Larry P Subject: RE: 12A-04 (174-021) pressure plot 3-2-09.x1s Tom & Jim, Attached is a map with the 42-05X & Y wells and the location of 77-3 penetrations in the same fault block as the X& Y wells. If you have any questions or need the map at a different scale, please let me know. Kevin KEVIN EASTHAM Geologist Chevron North America E&P Cook Inlet Asset Development 3800 Centerpoint Drive #13114 Anchorage, AK 99503 Tel. 907.263.7959 keasthamCchevron.com -----Original Message----- ~ ~ Maunder, Thomas E (DOA) From: Eastham, Kevin (KEastham) [KEastham@chevron.com] Sent: Wednesday, March 04, 2009 1:19 PM To: Maunder, Thomas E(DOA); Winslow, Paul M; Regg, James B(DOA) Cc: Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A; Myers, Chris S; Brandenburg, Tim C; Greenstein, Larry P Subject: RE: 12A-04 (174-021 } pressure plot 3-2-09.x1s Attachments: AOGCC_77_3_SCU42-05XY_Mar2009.ppt L~~ AOGCC_77_3_SCU 12-05XY Mar2009... Tom & Jim, Attached is a map with the 42-05X & same fault block as the X& Y wells. different scale, please let me know. Kevin KEVIN EASTHAM Geologist Chevron North America E&P Cook Inlet Asset Development 3800 Centerpoint Drive #13114 Anchorage, AK 99503 Tel. 907.263.7959 keastham@chevron.com Y wells and the location of 77-3 penetrations in the If you have any questions or need the map at a -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 04, 2009 8:42 AM To: Winslow, Paul M; Regg, James B(DOA) Cc: Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A; Myers, Chris S; Brandenburg, Tim C; Eastham, Kevin (KEastham); Greenstein, Larry P Subject: RE: 12A-04 (174-021) pressure plot 3-2-09.x1s Thanks Paul. As I have reviewed the available files over here, I have not been able to find a copy of the 9-5/8" bond log from the 9-5/8" casing of 12-04 (161-001). If that old log is available, a copy of the portion from ~ 8700' (below the milled section) to ~300' above the 77-3 sand would be appreciated. Thanks in advance. Tom Maunder, PE AOGCC -----Original Message--- - From: Winslow, Paul M [mailta:PWinslow@chevron.com] Sent: Tuesday, March 03, 2009 3:49 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A; Myers, Chris S; Brandenburg, Tim C; Eastham, Kevin (KEastham); Greenstein, Larry P Subject: RE: 12A-04 pressure plot 3-2-09.x1s Tom & Jim, Just wanted to give you a heads up that we are planning to make a 1.25" LEGEND: Blue Line/Numbers = Section Line/Numbers. Green Lines = Well Paths Purple Lines = 77-3 storage reservoir fault polygons. Gray Lines/Numbers = top of 77-3 reservoir Structure Contours Red Well Names located SW of BHL. Red + signs indicate location of wellbore intersection with top of 77-3 sand. Negative number to SE of red + sign is 77-3 sand depth in TVDSS. Black + siqns indicate wellbore Surface Hole Location f.7~ ' ~ ~ SCU 32-05 ~ ~ 1 _ -7870 `\ \~ a SCU 32R-85 5 . SCU 92R-85 ,~ SCU 92-05R0;; ~ SCU 92-05 ~ ~ ~ j ~ / 1 CU u4 S~CU94$-ysk;~63~~609 i SCU 42-~SY, ~_~607 ~ . 1, ' -7597 -7648 ( BHL BHL ~ SCU 928-05P6` j' \ \ ~ \ ~ . ,' ... +-T- E 7 ~ SCU 33-05 -- ~,L _ -~ \~ -~+-•~.~,~'~~13 84 \ ~ ~~ \\ S1~~~9~~=~J -7655 ~, ~ ~ ~ ~, \ \\~ ~.\\\ i _ _ ,.~;~ ~ \~6 ~.~*' ~.--- ---~~ - ~87 ' \ J -7695 i''5CU 29R-05 \`,~ /~ ~ .~ _. \~~~~. ~ ~ a5 ~ ; ~ scu 39-es - ` '=~` ~ x -7431 SCU 12A-04 ~ + SCU 12-04 `~ ~q ~ 6 } S~U ~2-B4PB~ • 4 SCU 22-04 ~ r . (, / 1 SCU 323-04 -~312 N . ~' sc~ ~~9-~~ _ -;~~ 0.25 mi ~ • ~ Maunder, Thomas E (DOA) From: Bonnett, Nigel (Nigel.Bonnett) [Nigel.Bonnett@chevron.com] Sent: Wednesday, March 04, 2009 10:59 AM To: Maunder, Thomas E (DOA) Subject: RE: Storage Well Subsurface Communication Tom, Yes, I noticed that. ~ Page 1 of 2 13.2 ppg Flex-Stone design yield is 1.43 ft3/sx. I have no sx quantities. Job appeared to be designed as 125 bbl single slurry. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 04, 2009 10:35 AM To: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: Storage Well Subsurface Communication Nigel, Do you have the yields or sack count for the Iead and tail? The sack count is combined on the 407 and the volumes do not match what was submitted in the permit application. Tom Maunder, PE AOGCC From: Bonnett, Nigel (Nigel.Bonnett) [mailto:Nigel.Bonnett@chevron.com] Sent: Wednesday, March 04, 2009 10:32 AM To: Maunder, Thomas E (DOA) Cc: Winslow, Paul M; Regg, James B(DOA); Walsh, Chantal [Petrotechnical); Tyler, Steve L; Kanyer, Christopher V Subject: RE: Storage Well Subsurface Communication Morning Tom, Reviewing our Daily Drilling reports, I can advise that the cementing of the 7" casing on SCU well 42-05X, was carried out by pumping 30 bbls of 13.0 ppg lead slurry, followed by 145 bbls of "Flex-stone" 13.2 ppg slurry. No losses reported during cementing, but plug was not bumped after displacing with 309.5 bbls, which included half shoetrack capacity. A USIT log showed TOC at 3910 ft MD - planned TOC had been 4000 ft MD. Cement inside 7" casing was found at 7995 ft and cleaned out to 8047 ft. Shoe at 8130 ft MD. Regards, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 03, 2009 1:44 PM To: Bonnett, Nigel (Nigel.Bonnett) Cc: Winslow, Paul M; Regg, )ames B(DOA); Walsh, Chantal [Petrotechnical] Subject: Storage Well Subsurface Communication Nigel, 11/19/2009 • ~ Page 2 of 2 In the course of reviewing well file information for the welis in the vicinity of SCU 12A-04 (174-021), I have need of greater detail regarding the 7" cementing operations for SCU 42-05X (206-074). A brief narrative summarizing the operation was provided as an attachment to 10-407 completion report, however it lacks sufficient detail to allow me to reconcile the cementing information provided in the permit apptication with what was actually pumped. Thanks in advance for the assistance. I look forward to your reply. Tom Maunder, PE AOGCC 11 / 19/2009 • ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 04, 2009 8:42 AM To: Winslow, Paul M; Regg, James B(DOA) Cc: Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A; Myers, Chris S; Brandenburg, Tim C; Eastham, Kevin (KEastham); Greenstein, Larry P Subject: RE: 12A-04 (174-021) pressure plot 3-2-09.x1s Thanks Paul. As I have reviewed the available files over here, I have not been able to find a copy of the 9-5/8" bond log from the 9-5/8" casing of 12-04 (161-001). If that old log is available, a copy of the portion from ~ 8700' (below the milled section) to ~300' above the 77-3 sand would be appreciated. Thanks in advance. Tom Maunder, PE AOGCC -----Original Message----- From: Winslow, Paul M [mailto:PWinslow@chevron.com] Sent: Tuesday, March 03, 2009 3:49 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A; Myers, Chris S; Brandenburg, Tim C; Eastham, Kevin (KEastham); Greenstein, Larry P Subject: RE: 12A-04 pressure plot 3-2-09.x1s Tom & Jim, Just wanted to give you a heads up that we are planning to make a 1.25" gauge ring run down the SCU 12A-04 tubing tomorrow, followed by a temperature survey (assuming the GR run is successful). Hopefully this survey will give us an indication as to where the pressure is coming from (i.e. gas movement behind pipe, through the casing, possibly from below the lower plug, etc.). We will keep you appraised as to the results. Regarding your request for an updated map, Kevin Eastham (Geologist working SRF) is currently working on it and will relay it to you when complete. Regards, Paul Paul Winslow Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907-263-7629 Cell: 907-382-3813 Fax 907-263-7828 pwinslowCchevron.com -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 03, 2009 9:51 AM To: Winslow, Paul M Cc: Regg, James B(DOA); Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA); Tyler, Steve L; Whitacre, Dave S; Page, Donald A Subject: RE: 12A-04 pressure plot 3-2-09.x1s Thanks Paul. We had problems with our email system yesterday. One item that we request as the communication is researched is an updated plan view of the well locations that penetrate the storage reservoir. In the SI06 file there is such a map, however it is fairly small scale and does not have 42-05X and 42-05Y "spotted". Thanks in advance. ~ Tom Maunder, PE AOGCC ~ -----Original Message----- From: Winslow, Paul M [mailto:PWinslow@chevron.com] Sent: Tuesday, March 03, 2009 6:51 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B(bOA}; Williamson, Mary J(DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 12A-04 pressure plot 3-2-09.x1s Tom, This is the note that I sent last night. I'm not sure why it didn't get sent correctly. Tom, I'm currently gathering information from the field (both crews) regarding diagnostics that have been run and will get back to you and Jim. We haven't done much (if any) slickline work in 12A-04, in past 2.5 to 3 years. The last slickline work appears to have been in 2006 and we reportedly had issues getting the slickline to bottom (possible cork-screwed tubing). Let us dig a little deeper and we'l1 get back to you. Paul Paul Winslow Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907-263-7629 Cell: 907-382-3813 Fax 907-263-7828 pwinslow@chevron.com -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.govj Sent: Monday, March 02, 2009 3:06 PM To: Winslow, Paul M Cc: Whitacre, Dave S; Page, Donald A; Tyler, Steve L; Regg, James B(DOA); Williamson, Mary J(DOA); Saltmarsh, Arthur C(DOA) Subject: RE: 12A-04 pressure plot 3-2-09.x1s Paul, et al, I acknowledge receipt of your message and phone call. I have forwarded your message to Jim Regg who manages the underground injection program. In our discussion you indicated that 42-05X is currently producing. Would you provide the operations detail of any diagnostic testing or other work that has been accomplished on 12A-04 or 42-05X and what further activities might be planned? It would appear that for the January cycle the well had tubing integrity however the near equalization of tubing and IA pressures in February would indicate that tubing integrity no longer exists. Has there been slickline work accomplished in 12A-04? We will get back to you. Please be sure to copy Jim Regg and myself on any reply. Tom Maunder, PE AOGCC -----Original Message----- From: Winslow, Paul M [mailto:PWinslow@chevron.com] Sent: Monday, March 02, 2009 2:44 PM To: Maunder, Thomas E (DOA) Cc: Whitacre, Dave S; Page, Donald A; Tyler, Steve L Subject: 12A-04 pressure plot 3-2-09.x1s «12A-04 pressure plot 3-2-09.x1s» Tom, Attached is a spreadsheet of tubing and casing pressures for SCU 12A-04 and one of our gas 2 ~ ~ storage wells SCU 42-05X. The tubing and casing pressures on SCU 12A-04 (174-021) would indicate communication between the wells. Note that the 42-05X (206-074) & 42-05Y (207-082) wells are completed in the Tyonek 77-3 reservoir and the SCU 12A-04 is completed in the Hemlock and G-zone. When we injected into 42-05X on both ~Jan. 13th and ~Feb. 12th, we see a sharp pressure rise in the 12A-04 tubing (& casing in Feb.). Note that SCU 12A-04 is shut-in and we have verified that we have isolation from any gas- lift pressure. Please give me a call to discuss this. Paul Winslow Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907-263-7629 Cell: 907-382-3813 Fax 907-263-7828 pwinslowCchevron.com 3 ~ ~ Plot Pressure & Rate vs Time - Well SCU 12A-04 1800 1600 i ~ 7" 13 3/8" ~ 1400 ~Tubing 1200 1000 y ~ w N d a aoo soo i ~ i aoo ~ ~ ~ 200 ~ ~ A ; ~_ ~ f ~0 N a0 a0 W a0 a0 m W a0 aD m aD m~O c0 c0 ~ ~D ~O a0 ~ c0 eD N aD N c0 N aD ~ o~ oJ N m W c0 N eD [O O~ O~ O~ O~ O~ O~ O~ O~ O~ O~ O> rn rn O~ O> O~ O~ O~ rn rn O~ O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O (h ~D O~ (V u~'~ aO ~ d I~ O c`~ ~D m N N~ ~ V 1~ O(~ N~ ~ V ~ O Ni ~O O~ l~ ~~ ~ O 1~ O t") tD O~ V!~ O M~D m N~~ fh <D O~ N~ W~ V N O O O ~ ~ ~ N N N t+l O O O ~.- ~ N N N M O O O•- ~- N N N N O O O ~ ~ ~ N N N(V O O O ~ ~ ~ ~ N N(V ["J O O O ~ ~ ~ N N N O ~~~ m m Q> Q> m O> O~ O O O O O O O O O O ~ ~~~ ~ N N N N N cV N N N N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O ~ ~ ~ ~.- ~ ~ ~ ~.- .- ~ ~ ~.- ~ ~ ~ ~.- ~ ~ ~ ~ ~,-. .- ~ ~ ~ 13 3l8" : Tubing 110~ 174G 110~ 1730 1t0 172U 1~Oi 1720 110; 1700 ~in'~ 1680 110! 1680 1~Oj 1680 01 1660 110; 1640 110 1640 110' 1640 1'0~~~ 1640 1'0 1640 110 1540 110 1460 110 1180 110, 900 110 580 108 1640 108 1450 108 1160 110 8S0 110 550 120 150 120 140 110 140 110 150 110 150 110 15G 110 1660 11C 1660 110 16,50 110 16(i0 110 1660 110 1650 TIO Report Data Sheet SCU 12A-04 GAS LIFT Permit # 1740210 API # 50-133-10103-01 09/03/2008 to 03/02/2009 11/19/2009 3:12 PM - TIO Reports 7e.xls J J Dolan 12A-04 pressure plot 3-2-09 (5).xls SCU 12A-04 Plot Pressure & Rate vs Time - V1'ell SCU 42-OSX aooo ._ _.o.. _.. _ 18000 3500 - 16000 ~ ~„ ~~9 5/8" 3000 ~Tubing 14000 ~Vol ~Vol 2500 12000 ~ 100 ~0 ~ y 2000 i a~ ` o ~ a 8000 1500 6000 1000 4000 500 2000 0 0 ao m m m m o~ ao m m ao m m m w m w ao w w w ao m m co m m ro m m o~ m m m ao m m m oo m ro rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn m rn rn rn rn a~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M t0 O~ N~ a0 ~ O 1~ O M t0 O~ N N a0 ~~ I~ O N ~~ ~ a!~ O M i0 O~ N N aD ~ Q 1~ O C"~ i0 O~ ~ O 1~ O t") ~O O~ (~ N a0 ~ M~O O~ N N W e- V I~ N ' O O O ~ ~ ~ N N N C l O O O ~•- ~ N(V N<+J O O O ~ ~ N N(V N O O O ~ ~ ~ N N N N O O O ~ ~ N N N M O O O ~ ~ ~ N N N O O~ O~ O~ O~ Q~ O~ 01 01 O~ O) O O O O O O O O O O r' `\ ~ N N N N(V N(V N(V (V ~ ~` ~ •- N N(~ N N N N N N M O O O O O O O O O O ~~- ~ ~ ~~- ~- •- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O O O O O O O O O O O O O O O O O O O O O Date 7" 9 518" HRS O N Tubing Vol Vol TIO Report 03/01 /09 300 0 2'{ 1II15 1 Ci12 8; H 02/28/09 300 0 2'• 1841 30~J2 Data Sheet 02/27/09 280 0 1:> 7829 3933 02/26/09 280 0 n 1751 156F ~~~ 02/25/09 280 0 ~ 1743 G _ $CU 42-OSX 02/24/09 260 0 17 1709 G -. 02/23/09 280 0 2w 1615 22 ~ 02~22~09 2so o ~z ~7~5 r. _._ STORAGE WELL 02/21/09 260 0 0 1775 8 ~y 02/20/09~ 260 0 6 1799 3153 0 02/19/09 260 0 24 2188 9356 o Permit # 2060740 02/18/09 280 0 24 1963 9371 n 02/17/09 270 0 2, 1915 8993 0 02/16/09 2~0 0 2~ 2084 i~sas o API # 50-133-20561-00 02l15/09 240 0 2~ 2275 14348 0 02/14/09 240 0 2~ 2146 8764 0 02/13/09 260 0 12 1484 1844 0 09103/2008 to 03102/2009 02112I09 280 0 h 1395 1 C ~~ ~ 02/11/09 280 0 18 1055 1 5327 02/10/09 280 0 24 1054 0 7261 02/09/09 280 0 24 1110 0 7379 02/08/09 260 0 24 1109 Q 8174 02/07/09 280 0 10 1684 2165 02/06!09 280 0 G 1538 0 A 02/OS/09 280 0 2~ 1133 7~~17 02/04/09 2S0 0 24 1118 s~ur,~l 02/03/09 280 0 24 1164 0 52Gi 02/02/09 280 0 24 1230 0 10006 02/01/09 280 0 ?4 1262 0 1016~ 01/31/09 280 0 2~ 1564 0 611f; 01/30l09 2S0 0 24 1735 0 a8~~s 01/29/09 2S0 0 24 1775 0 ape ~: O1/28/09 280 0 24 1721 15 ~,St~a 01/27/09 280 0 24 1706 1 7~~n 01/2610~ 280 0 6 1~78 3 ~:~t~~' 01/25/O~J, 280 0 4 17&0 14,67 ~749 11/19I2009 3:13 PM - TIO Reports 7e.xls J J Dolan 12A-04 pressure plot 3-2-09 (5).xls SCU 42-05X ,'"" STATE OF ALASKA '-" ALASKA OiL AND GAS CONSERVATION CO~v~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 201' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotna Creek Unit 4. Location of well at surface 8. Well number 2,130' South and 690' East of NE Corner, Sec. 4, T7N, R9W, SM $CU 12A-4 At top of productive interval 9. Permit number Same 74-21/95-121 At effective depth 10. APl number Same 50- 133-10103-01 At total depth 11. Field/Pool ~ '7,,~t OO Same Swnason River Field / Tyonek / Hemlock 12. Present well condition summary Total depth: measured 10,880' feet Plugs (measured) true vertical 10,880' feet Effective depth: measured 10,798' feet Junk (measured) true vertical 10,798' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 29' 22" Yes 37' 37' Surface 2,024' 13-3/8" 1,875 sx 2,024' 2,024' Intermediate Production 8,597' 7" 2,300 sx 8,597' 8,597' Liner 2,483' 5" 500 sx 8,397'-10,880' 8,397'-10,880' Perforation depth: measured 10,284'-10,313'; 10,324'-10,350'; 10,391'-10,399'; 10,419'-10,443'; 10,451'-10,459' Isolated · 10,552'-10,534';10,570'-10,575'; 10,581'-10,561'; 10,590'-10,606'; 10,624'-10,647'; 10,657'-10,687'; 10697'-10,710'; 10,720'-10,745' true vertical Same Tubing (size, grade, and measured depth) 2-7/8", 6.4#, L-80, 8,430' 2-3/8", N-80, 10,493'-10,748' Packers and SSSV (type and measured depth) Baker 7" FH Packer @ 8,319'; Baker 5" FH @ 10,515'; Baker FH @ 10,583'; Baker FH @ 10,652'; Baker FH @ 10,692' 13. Stimulation or cement squeeze summary N/A INn~/~rvals treated (measured)ORIGINAL .. Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11/19~98 12 120 0 950 160 Subsequent to operation 12/3/98 77 2,911 3 450 300 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: D r' ~' L,~ ii '~ j~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: I~ [. ~., L ! ~ I::)£C 29 199 ~"/~' ~ _ Alaska Oil & Gas Cons. Co Anchorage Signed:/~-'~ 7~,o,,~/~L~)~-c~ar'/so~.ban Williamson Title: Ddlling Manager Date: ~,~5 Z:~'~-_~ '~__~ D nmissi~: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ELECTRIC LINE JOB RECORD Well: 12A-4 Facility: Swanson River Field: Swanson River APl No: 50-133-10103-01 AFE No: 133685 Service Co: Schlumberger Service Co. Rep: Ray Ambrose Unocal Witness: Shane Hauck Date Completed: 12/11/98 COMMENTS Set dn on tbg stub or fill @ 10459' So was unable to perforate H4 or H5 UPDATE RECORD Document I Date Well History: Wellbore Diagram: Sundry (AOGCC): Sundry (BLM): BenchI .T°P I BottomI H3 10,451 10,459 H2 10,419 10,443 H1 10,391 10,399 Total: INTERVALS PERFORATED (DIL) Feet II SPF I Phase I 8 6 60 24 6 60 8 6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 40 Gun Type 2-1/8" hollow carrier 2-1/8" hollow carrier 2-1/8" hollow carrier INTERVALS LOGGED Top Bottom Type of Log Reason 9,350 10,459 CCL Tie-in WELL TEST DATA Before After Date: Date: 'Gross: Gross: Oil: Oil: Gas (P): Gas (P): Water: Water: Tbg. psi Tbg. psi Csg. Psi Csg. Psi Cut %: #DIV/0! Cut %: #DIV/0! ELJOBREC.XLS Fill tagged at: Size gauge run: Fish left in hole? No E-line cost: $13,357 UNOCAL Fill Tagged 10,459' ELM 12/11/98 6 7 8 Tubing ~0 Perf. 10,570'- 10,575' 11 12 13 14 15 16 Tubing Perf 17 10,735'- 18 10,745' 19 12A-4 Act Draw.doc G2 HI H2 H3 UH8 MH8 LH8 H9 UH10 LH10 ~', Swanson River Well SCU 12A-4 Actual Completion 6/4/95 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 22" - - 29' 13-3/8" 54.5 J-55 12.615 Surface 2,024' 7" 29 N-80 6.184 Surface 324' 7" 26 N-80 6.276 324' 1,087' 7" 23 N-80 6.366 1,087' 4,857' 7" 26 N-80 6.276 4,857' 6,704' 7" 29 P-110 6.184 6,704' 8,597' 5" 18 N-80 EL,LT&C,Butt 4.151 8,397' 10,880' Tubing 2-7/8" 6.4 L-80 Butt 2.441 15' 8,430' 2-3/8" 4.6 N-80 1.995 10,500' 10,748' JEWELRY DETAIL NO. Depth ID OD Item 1 15' - Tubing Hanger, 2-7/8", Purchased from DSR, P/N: 421758 2 2,244' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2", 05321-000-2400 3,648' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 4,616' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 5,298' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 5,918' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 6,503' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 7,088' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 7,674' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 8,260' 2.343 5.500 GLM, Camco, MMG, 2-7/8" x 1-1/2" 3 8,319' 2.416 5.983 Packer, Retrievable, Baker Mod. "FH" 2-7/8" 4 8,397' 2.313 3.500 Nipple, 'X', 2.313 I.D. 5 8,429' 2.441 3.700 WLEG 6 10,493' 2.000 Scoophead Guide Assembly w/4 sx CaCo3 7 10,497' 2.000 3.973 Overshot, Bowen Series 150 8 10,512' - Sliding Sleeve, Otis "XA", 2-3/8" W/"PX" Plug, 3'CaCo3 on top 9 10,515' - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 10 10,520' - - Safety Joint, Brown "CC", 2-3/8" 11 10,583' - - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 12 10,588' - Nipple, "S" (Position No. 2), 2-3/8" 13 10,647' - - Safety Joint, Brown "CC", 2-3/8" 14 10,648' - - Sliding Sleeve, Otis "XA", 2-3/8" 15 10,651' - - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 16 10,657' - - Safety Joint, Brown "CC", 2-3/8" 17 10,691' - - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 18 10,697' - - Nipple, "M" or "D" 19 10~748' - - WLEG PERFORATION HISTORY (DIL) Interval Accum. Date Zone Top Btm Amt spf Comments 6/9-7/20/95 G2 10,284' 10,313' 29' 12 2-1/8" EJ, 90 deg. 6/9-7/20/95 G2 10,324' 10,350' 26' 12 2-1/8" RI, 90 deg. 12/11/98 H1 10,391' 10,399' 8' 6 2-1/8", HC, 0 deg. 12/11/98 H2 10,419' 10,443' 24' 6 2-1/8", HC, 60 deg. 12/11/98 H3 10,451' 10,459' 8' 6 2-1/8", HC, 60 deg. UH8 10,534' 10,552' 18' 4 Isolated by PX Plug MH8 10,561' 10,581' 20' 4 Isolated by PX Plug LH8 10,590' 10,606' 16' 4 Isolated by PX Plug H9 10,624' 10,647' 23' 4 Isolated by PX Plug UH10 10,657' 10,687' 30' 4 Isolated by PX Plug LH10 10,697' 10,710' 13' 4 Isolated by PX Plug LH10 10,720' 10,745' 25' 4 Isolated by PX Plug ETD = 10,798', TD = 10,880' MAX HOLE ANGLE = 14deg? DRAWN BY: tcb REVISED: 12/21/98 STATE OF ALASKA ~ AL~ t OIL AND GAS CONSERVATION COMk ,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging _ _ Pull tubing _ _ Alter casing__ Repair well _ _ 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 Perforate X Pull tubing X_ OtherX_ J5. Type of Well: Development X_ Exploratory __ Stratigraphic__ Service __ 4. Location of well at surface 2130' South and 690' East of NE Corner, Section 4, '[TN, R9W At top of productive interval Same as above At effective depth Same as above At total depth Same as above 6. Datum elevation (DF or KB) RKB=201 (GL=186 KB=15) 7. Unit or Property name Soldotna Creek Unit feet 8. Well number SCU 12A-4 9. Permit number/approval number 74 -21/95-121 10. APl number 50-133-10103-01 11. Field/Pool Swanson River-Tyonek/Hemlock 12. 13. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 29' Surface 2024' Intermediate P roductio n 10,984' Liner 2483' Perforation depth: 10,880' feet 10,880' feet 10,798' feet 10,798' feet Plugs (measured) Junk (measured) Size Cemented 22" Yes 13-3/8" 1875 sx 7" 2300 sx 5" 500 sx SEP 12 199,5 Nas~ 0~1 & Gas Cons, Co. mndsslo, r~ Measured depth: ~ldi~0ra~lue'vertical depth 37" ' z/.~?~: Same 2024' '~'~,/?/O~me 10,984' Same 8397'- 1 ~80' Same measured 10,284'-10,313'; 10,324'-10,350'; 10552'-10534'; 10581'-10561'; 10590'-10606' 10,624'-10,647'; 10657'-10687'; 10697'-10710'; 10720'-10745'; 10570'-10575' true vertical Same as above Tubing (size, grade, and measured depth) 2-7/8", 6.4, #L-80, 8430' 2-3/8", N-80, 10,493'-10,748' Packers and SSSV (type and measured depth) Baker 7" FH pkr @ 8319'; Baker 5" FH @ 10515', Baker FH @ 10,583', Baker FH @ 10,652', Baker FH @ 10692' Stimulation or cement squeeze summary Intervals treated (measured) None Treatment description including volumes used and final pressure None 14. Prior to well operation Subsequent to operation Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 90 18,674 10 1750 1400 119 56 4 700 450 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x_ Gas __ Suspended _ _ Service 17' I hereby certify that the fO~r~/~ngI .i(~ie~n~ to the best °f mY kn°wledge. Signed G. Russell Schmidt,~~~itle Drilling Manager Form 10-404 Rev 06/15/88 Date 09/05/95 SUBMIT IN DUPLICATE uornp~etea:/iCl/ Lost Workover Ff S~nson r~,,,er Fid AP! No.: ~0-!~-!(~1~'~- I 0,0- 32L0' 7" OD 29,00!/~t N-80 PROD CSCs 324.0- ~0~7.0' rOD 26.00~lft f~-80 ~ ~ 1087.0- 4857.0' 7"OD 2;~.~/ft It-80 PROD CSC 4857.0- 6704.0' 7" OD 26.~/lt N40 PFIOD 0% 6.7~,0 - 8597.0'. T'OD 29,~/fi P-IlO .PROD T I ~ 0.0 - 84302' 2.875" OD ~.4~/ft LdO Buttress ~ 10468,0- 10749,0' 2.,.t75" OD i,~" ID 4,30i/fl N-80 ll~ 105t0.0- I0,6t2.0' fi~ r'?.C',,'~.,,,,.,,,, fill On top ,~, ''~ P× plug I0515.0 - 10515.0' RBTN. P.(ER Baker lO~.O- 1I~t~ I~B ~ 4Hff, 18' ~o~,o- ~o57~,~ P~m ~I~ n~, ~.o-~or~.o' P~rS ~, 4mr, {~2.0 - 10~2.0' EI~. ,P,~K[R ~er B Pkr {0720,0 - 10~45.0' ~FS Ltt-10, 10692.0-10692.0' RUt~. ~ER P.,oker FH, Pkr BID: t01~ uompte[eo:// bdSt Work, over f"" ~' b~Oll,SO~ lqlvcr ,rl~lO APl No.: 5,0-!35-!0!05-01 0.0 - 29.0' 2?'® C~ 0.0- 2024.0' 15 5/8"00 ~.50iflt J-55 SURF CSG 2024.0 - 2024.0' S~ 1087.0 - 4~7.0' 7" OD 23.~/It N-80 P~B CSG ,.,,,,-.,.,,P,~O,, 57.0 - r7;u,, ?, 0';] g.~/ff N40 ~ n r~ ~97.0 - ~7,C~ SHOE IVO'lg 5298.2 55!8.,7' '::':" - ,~,~, OD 2,34Y iD GASUFT rAVE !6: ~co ~ 5918.8:59.59.4' 55" OD 2.~3" D OASDFT ~ '~ i5, Cqmco ~ 1.5" 8260.2- ozoz,~,'~°°'" 5,? On ..... 2.~4y ~. GA$UFI' ~gT,0 8.~&2' 2]U" ID N~tE "X" 842.6 - 84JO. Z 2.q1" tD EBRY ~I~ ~ ~t En[~ Gu~ PERIS t:;-2, ~2,~, 90 DL:'C §]9 & 7120J95 F~' r" !1 ~wonson xlver AP! No.:x """"'"" ": I~15.0 - 10515,0' R~.t. P,~f~ Boker FH !~.0 - I058~1.0~ R[t'I~. P,~ER B~ker fH Pkr t~.t,0 - I~5~.t7 R~'L PE~<FR P, ake. r FI.'t ~r ~.~z.u t~.0 R~L P~KB--R Boker Pd Pkr !0i~!0.0 - !~.0' ~Brl' ,PL~ KB ELEY: !~68.0 - 10749,0' 2,575" OD !.995" tD 4,$0~/l! N-~3 !~ 10493.2 - 10497.3' 3,875" OD ~62" iD REEN'IRY J~ 3-7/8" 104975 - 10505.7' 5.975" OD 2" iD ~ ~F Bek~ 3-6/i6" tD5~2.0 - ]05!2.0' ~"PX" Pb9 !~59.0 - I06~.0' BL~[ J0~ 10657.0 - 10687.0' ?Ei~ ~-10, ~:T, · 1~7.0-10710'.0' PEI:ES I}H0, ,tt~, !13~3~.0 - t074gfl BAST JOINT IOT/O,O = 10745.0' P[RB L!'t-lo, 41'ttT, 25' I0749.0 - t07~9.0' RE~ JONT I SCU !~,-4 S~enson River field AP! No.: 50-155-!0!0;]-0! 10497,3- 10503.? 3.97Y OD 2" ID ON OFF Baker 3-15/I¢ Ove~l SEP 12 1995 Gas Cons, Anchorailm 10583.0 - 105~.¢ ~V. PACi~ kler Ft-t Pit l~.O - l~.~ ~ ~ Otis S ~o~ {2 10591.0 - 10647,0' i062" OD ~T J~ '1 SWANSON RIVER SCU 12A-4 DAY 1 (05/25/95) 22" @ 29' 13-3/8" @ 2,024' 7" @ 10,969' 5" @ 10,880' SUMMARY: 5116/95 - 5/19/95 - PREP & KILL WELL. 5/25/95 - CHECK TBG SLIGHT VAC. CHECK ANN SLIGHT VAC. CUT OFF FLOWLINE & BLIND FLANGE SAME. DAY 2-5 (05/26-29/95) MIRU AWS RIG #5 ON TURNKEY MOB. ACCEPT RIG @ 18:00 5/27/95. TBG & ANNULUS ON VACUUM. CHANGE OUT ANNULUS PLUG VALVE. ND TREE NU BOP. TEST BOPE 250 & 5000 PSI W/JOE RUSSELL (BLM) @ WITNESS. HAD LEAK IN #1 PIT. FIX#1 PIT. RIH W/LANDING JT. ATTEMPT PULL HGR. PULL 80%. WOULD NOT RELEASE. PRESSURE UP TBG TO 300 PSI. HGR CAME LOOSE. POOH W/2-7/8" TBG CHECKING FOR NORM. TBG IN GOOD SHAPE. DAY 7 (05/31/95) 22" @ 29' 13-3/8" @ 2,024' 7" @ 10,969' 5" @ 10,880' SUMMARY: CONT RIH W/BHA #1. P/U KELLY & PUPS. WASH OVER FISH & DRESS INSIDE & OUT OF TBG STUB. TOF @ 10,515'. PUMP XANVIS SWEEP. POOH & PU BHA #2. (SCOOPHEAD ASSEMBLY). DAY 8 (06/01/95) 22" @ 29' 13-3/8" @ 2,024' 7" @ 10,969' 5' @ o,88o' RIH W/SCOOPHEAD GUIDE & INSTALL. PUMP HI-VIS SWEEP. DUMP CACO3 ON TOP OF GUIDE (4SX). POOH LD 2-7/8" TBG. DAY 9-10 (06/02-03/95) 22" @ 29' 13-3/8" @ 2,024' 7" @ 10,969' 5" @ '~o,88o' RELEASE RIG 6/3/95 @ 11:00 HRS. POOH & LD BHA # & 2-7/8" WORK STRING. PULL WEAR BUSHING. PU NEW 2-7/8" BUH. TBG. TEST STANDING VALVE TO 2500~ OK. RIH W/2-718" TBG. LAND HANGER. CIRC. INHIBITOR SET PKR. TEST TBG TO 4000 PSI. TEST CSG TO 3000 PSI. SET BPV. ND BOP. NU TREE & TEST. RELEASE RIG 6/3/95 @ 11:00 HRS. BEGIN MOVE TO SCU 321-9. DAY 11-12 (06~04-05/95) 22" @ 29' 13-3~8" @ 2,024' 7" @ 10,969' 5" @ ~0,880' COMPLETE RIG MOVE. RU SLICKLINE UNIT. RIH & RETRIEVE STANDING VALVE FROM X-NIPPLE. POOH. RD SLICKLINE UNIT. DAY 13 (06/06195) 22" @ 29' 13-3/8" @ 2,024' 7" @ 10,969' 5" @ '~0,880' SPOT TANKS. HAUL DIESEL FOR COILED TUBING SWAP-OVER. DAY 14 (06/07/95) 22" @ 29' 13-3/8" @ 2,024' 7" @ 10,969' 5- @ ~o,88o' MIRU ARCTIC RECOIL CTU. COMPLETE BOP CHECK LIST. MU 1.5" CTG, BYPASS TOOL & WASH NO77LE. RIH W/BHA & 1.5" CT. TAG @ 10,528' CTM. PU 5' & PUMP 87 BBLS OF DIESEL. TAKE LEASE WATER RETURNS TO PRODUCTION. POOH. RD MO. DAY 15 (06/09/95) 22" @ 29' 13-3/8" @ 2,024' 7" @ 10,969' 5" @ 10,880' D.C. $ 16,500 CUM: $ 287,062 AFE: $ 485,000 AFE #752512 W/OVER RECOMPLETE TO TYONEK G-2 TIME REQUIRED: 6 DAYS RU SCHLUMBERGER WLU. RIH WI2-118" ENERJET, GP,/CCL. PULL TIE-IN STRIP. PERFORATE TYONEK G-2 @ 10,324'-10,350' & 10,284'- 10,313'. POOH. RD SWLS. TURN WELL OVER TO PRODUCTION. DAY 16 (06/10/95) 22" @ 29' 13-3/8" @ 2,024' 7" @ 10,969' 5' @ ~0,880' INITIAL TBG PRESSURE = 1100 PSI AFTER PERFORATING. WELL UNLOADED DIESEL. WELL WAS SLUGGING. TBG = 0 PSI UNOFFICIAL FLOW RATE = 182 BOPD (FLUCTUATING). DAY 17 (07/20/95) RU SCHLUMBERGER WLU. NU LUB. AND TEST. OK. RIH AND PERFORATE TYONEK @ 10320'-10346. POOH. RIH WITH PERF GUNS AND PERFORATE TYONEK @ 10281'-10309'. TURN WELL OVER TO PRODUCTION. (2-1/8" ENERJET 6 SPF 90 DEG PHASING) STATE OF ALASKA . ._.ASKA OIL AND GAS CONSERVATION C(- .iVlISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ _ Suspend __ Operal~ons shutdown __ Re-enter suspended well__ Alter oasing__ Repair well __ Plugging ~ Time extension __ Stimulate __ Change approved program Pull tubing X_ Variance Perforate X_ Other X_ 2. Name of Operator 5. Type of Well: 6. Datum elevaUon (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) F_xpk)rato,/__ 210 KB feet 3. Address StraUgraph~= __ 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 service~ Soldotna Creek Unit 4. Location of well at surface 8. Well number 2130' South & 690' East of NE Corner of Sec. 4, T7N, RSW SCU 12A-4 At top of productive interval 9. Permit number Same as above At effective depth ~10. APl number Same as above 50-133-10103-01 At total depth 11. Field/Pool Same as above Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10,880' feet Plugs (measured) 10,798' true vertical 10,880' feet .. ~ I~IKt / Effective depth: measured 10,798' feet Junk (measured) ~-~: i-'~ [ ~.~' '~ /''~ L.. true vertical 10,798' feet casing Length Size Cemented Measured depth True vertical depth Structural Conductor 29' 22" Yes 37' Same Surface 2024' 13-3/8' 1875 sx 2024' Same Intermediate Production 10,984' 7" 2300 sx 10,984' Same Liner 2,483' 5" 500 sx 8397'- 10880' Same Perforation depth: measured 10552'- 10534', 10581 '- 10561 ', 10590'- 106061~10624'- 10647' 10657'- 10687', 10697'- 10710', 10720'- 10745', 10570'- 10575' RECEIVED true vertical Same as above Tubing (size, grade, and measured depth) 2-7/8", N-SO, 8320'J U N 2 ?- 1995 2-3/8", N-80, 8320'- 10,748' Packers and SSSV (type and measured depth) Baker FH 10,515', Baker FH, 10,583', Baker FH,Alaska 0il & Gas Cons. Commissio 10652'; Baker FH, 10,692' Anch0rc ',~ 13. Attachments Description summary of proposal x _ Detailed operations program_ _ BOP sketch _ _ 14. Estimated date for commencing operation 15. Status of well classification as: 5/16/95 16. If proposal was verbally approved Oil x _ Gas __ Suspended __ 5/11/95 Name of approver Blair Wonzell Date approved Service 17. I here~rt~ ~"~t th.,e~re,~o~ is true and correct to the best of my knowledge. Signed ~l~u[~~~'l~d~~ Title Drilling Manager Date 06/15/95 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Appr~?.~°'; Plug Integrity _ BOP Test_ ~ Location clearance _ Mechanical Integrity Test._ Subsequent form required 10- ,~0 ~__Approved Copy Original Signed By Returned Approved by the order of the Commission David W. Johnston ~,. ?..,1,,,: ? ~ ~'Commissioner -~- Date ~_,~. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE $CU 12A-4 1/2 Preliminary Procedure 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 26 27 29 30 31 32 33 34 36 37 38 39 40 41 42 43 44 45 Prepare Location RU Slicklinc Unit R/H and make GR rum Set PX plug in to~ XA sleeve ~ 10512' Pressure test plug and tubing to 1500 psi w/lease water. Dump Bail CaCo3 on top of plug RIH and pull bottom gas li~ valve (~ 8308' Kill well by circulating lease water through _I3LM ~ 8308'. POOH and RD OTIS RU APR$ using Otis SL unit and RIH. Pressure up TBG to 3000 psi. Cut tubing @ 10,467' w/1-1 1/16' chemical cutter. POOH and RD APR$ ' Circulate well through cut and verify well is deaeL Test Casing and liner lap to 3000 psi. Install two-way checl~ MIRU .*l~sk~_ Well Service RIG :5. Turnkey Mob. NU BOPE Test BOPE MU landing JT RIH w/landing JT and engage TBG HGR. PU and check to see if TBG is cut Circulate well and verify well is dead. POOH w/completion. LD 2-3/8" TBG. Install wear bushing. Check TBG for Norm MU CSG Scraper and dressing tool. RIH w/2-7/8" TBG and tandem CSG scrapers to 10,490' Tag TBG stub dress offTBG stub and scrape casing POOH w/dressing tool and CSG scrapers. PU WL skirt/~de RIH w/Guide on 2-7/8" TBG Install wireline entry guide. POOH and LD 2-7/8" TBG PU new 2-7/8" TBG. ~ RIH w/retrievable PKR and TBG. Space out and land TBG hanger Spot Packer Fluid Pressure up on tubing (standing valve in place) and set ~ Set BPV ND BOPE Test tree De-MOB rig #$. NU flowlines and gas liR line. If'l~bing is not cut, make another cut AT 10,477'. RECEIVED JUN 22 1S95 Naska Oil & Gas Cons. Commission Anchor~' .'? CTCSTEST. XLS 5/18/95 SCU 12A-4 2/2 46 47 48 49 50 51 52 53 54 55 56 57 58 RU Ods SL Unit RII-I and Pull standing valve RDOfis RU CTU RIH wt Coil Displace Lease water w/diesel. POOH w/diesel RD CTU RU wirclinc Unit RII-I wl peffo~g guns Make correlation nm. Pcrfora~ Tyonck G-2 (~ 10297'-10312' & 10324'-10350' POOH and RD wirclinc trail CTCSTEST.XLS 5/18/95 /-" Arco Alaska Inc,- Swanson; ver F'eld ~JJ- SCU 12A-4 APl#: 133-10103-01 Well Type:Proclucer Spud Date: 5/25/74 Completion Date: 7/6/74 Last Workover: 4/22/75 Original RKB: 17' Hanger Type: Shaffer Hanger' Shaffer Top of Hemlock:10,390'MDMax, Hole Angle: ° , Angle @Hemlock' ° All Depths are RKB MD to Top of Equipment. ,4 8597' Win(Iow ! 8637' LH8 H9 UH10 LHIO 1 11 3 12 13 4 14 5 15 16 6 17 18 7 O3 o~ 19 8 2o 21 23 24 9 IC] to, s-t~r 11 13 /o ~03 15 17 18 ~ ~,6~- 19 Jewelry 1 2303' 2 4151' 3 5580' 4 6695' 5 7526' 6 8042' 7' 8308' 8 8321' 9 10.512' 10 10.515' 10,521' 10 .522' 10.583' 10,589' 10,591' 10.647' 10.649' 10.652' 10.657' 10.659' 10.692' 10.697' 10~98' 10,749" Camco MMA GLM Camco MMA GLM Camco MMA GLM Camco MMA GLM Camco MMA GLM Camco MMA GLM Camco MMA GLM X-Over 2 3/8" x 2 7/8' Offs 'XA"'sleeve Baker "FH* Packer Brown "CC' Safety Jt. 3 Blast Joints (61.023 3.062' OD 18 # Baker "FH" Pkr. Offs "S" Nipple Position #2 4 Blast Joints (66.233 3.062" OD Brown "CC" Safety Jr. Offs *XA' Sleeve 18 · Baker "FH" Pkr. Brown "CC" Safety Jt. 3 Blast Joints (337 3.062" OD 18~ Baker "FH" Packer Offs "N" cx Cam,":o *D" Nipple 3 Blast Joints (,50.303 3.062" OD Baker Out Sub Casing and Tubing Size Weight Grade Top 22' 0 13-3/8' 54.5~ J-55 0 7' 29~ N-80 0 7' 26~ N-80 324' 7" 23~ N-80 1087' 7' 26# N-80 4857' 7" 29~ P- 110 6704' 5" 18~' N-80 8397' 2 -7/8' 6.5~ N-80 0 2-3/8' 4.3# N-80 8308' Perforation Data ~ Zone ET. SPF 10.534'-10,552' . UH8 18' 4 -- 10,561'-10.581' ' MH8 20' 4 10,590'- 10,606' LH8 16' 4 10,624'. 10,647' 1-19 23' 4 104~57'-10,687' UH10 30' 4 10~97"-10,710' LH10 13' 4 10,720"-10,745" LH10 25' 4 Bottom Description 29' Strucl~e Casing 2024' Surface Casing 324' Procluction Casing' 1087' 4857' 6704' 10.969' 10,880' Liner 8308' Tubing 10,749' Tubing Comments Perf. tubing 10.570'-575' Perf. tubing 10.735'-745' 24 P BTD = TD = 10,798' 10,880' Well SCU12A-4 8y: JLB ! 1/8/8g ' / I~ Completed'. 7/6//e ~ ~ ~' ina t Los[ Worbver: 4/zd75 Proposed SCU 12A-4 S~anson River Field APl No.: 50-1 -~''' ~,~-10105-01 Top of Hemlock: 'lO,$gO Fi. MI) bqle @ Hemlock: 113eqs. Hanger: Shaffer 97.0' 7" OD 29.00t/fi P-IlO PROD i, bO ~ro,,.,~h Windo~ 8597.0 - 8597.0' SHOE tOilWell KB [LEV: 17' PBED: 1(184(1' rD: 10880' 0.0-8450.0' 2.87? OD 6.50t/f[ N-80 TBG ~.a!7.0 - ~c,~u.u PACKER 8420.0 - 8421.0' NIPPLE "X" 8450.0 - 84Eg' REENTRY JOINT Re-Ent~ Guide RECEIVEL,, ,/UN 2 2 1~95 ,,a~ska U~l & Gas Cork~, CollilTl/ss~on Allchorg. ;~ · 10287.0 - 10312.0" PERFS G-2, 4HPF, 25', PROPOSED 10324.0 - 10350.0' PEFS 6-2, 4HPF, 26', PROBED 1~67.0 - 104~.0' LOCATOR JOINT Re-EnIw Oude 10512.0- 10512.0' PLUG "PX" Plug 10512.0 - 10512.0' SLE~E Otis ~ 1~15.0 - 10515.0' R~RV. PACKER Baker FH 1~21.0 - 10521.0' JOINT Brown CC Softy Jt 1~22.0 - IOM.O' ~.062" OD BMST JOINT 105~4.0 - 10552.0' PERB UH-8, 4HPF, 18' iitGItiAL ~ n n ~ 6 0 :-. ~c,~p~.%%~ ~~°''~ ~ a~"'~.~-'- L9 weLLS ~t ,~"" . nit ....... weLlS SoL~O~' ' ~ Apron,at' ~ ~o ~.dica~' Natu,' ~6. ,~1C. o'~.~°~ ~: ~ . .o · , ,,,,, ,,,,~,, ~ ~,,~, ~o... ~ ~ o~,,~ '" _. ~ -~dO~~t AS a~'~_.~ save a t~ RECEIVED DEC ,,;3 1 1991 SRU 23-22 ~ 12A4 ~ ~14 SKU ~15 5RU ~27 ~ l~ ~ 1~9 SKU ~15 5gU 212-27 ~ 21A4 ~U 2~'9 5RU 211A5 5RU 331-27 ~U ~9 SKU 4lA-IS 5RU ~28 ~ ~A4 ~U l~ 5gU 43A-i5 SKU 43-2~ ~ ~5 5RU 1~22 5RU 2~33 5RU 32-33~ Alaska Oil & Gas Cons. Commissiol ,dotna cree~-~s°n RY. · ,High GOR wells that may be pro~uced~. · See Ind,uc~o"' on Reverie S~de AttaChment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A :i:~:~:i:E:;:~:;:~:i:~:~:i:~:;:;:~:i:i:i:~:~:i:i:~:;:;:E:i:!::.:;:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::E:~:i:i:E:i:;:;:~:~:~:~:~:~:~:;:~:i:~:~:;:;:~:i:i:i:i:i:i:~:i:i:~:i:!:!:~:i:i:i:~:i:~:~:i:i:!:i:;:~:~:;:i:i:E:;:!:;:i:i:i:~:~:~:~:i:~:~:!:~:i:~:i:i:!:i:i:i:~:~:i:i:;:~:i:.::~:!:i:~: SCU 12A-4 SRU 212-10 SCU 13-4 SRU 211-15 SCU 21A-4 SRU 23-15 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 SRU 32-33WD · SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 9 Wellg 3 Wells Shut-in Wells until the Field Blowdown · Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned i:i:~:i:i:~:~:~:i:~:!:~:~:~:~:~:~:~:i:~:.::~:~:~:i:~:~:~:~:i:i:i:i:~:~:~:~:~:~:!:i:~:i:i:i:!:~:~:~:~:~:i:~:i:i:~:i:i:~:i:~:~:~:~:i:~:~:i:~:~:~:~:i:i:~:i:~:~:!:~:~:~:~:i:~:~:~:~:!:~:~:~:~:~:~:i:i:i:~:~:i:!:!:i:!:~:i:!:!:~:i:~:i:i:i:i:!:i:i:i:i:i:~:i:~:i:i:~:i..i..?~:i:i.i:i:!..??~..i:~.i.i SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For. Temporarily Abandonment Sundry 12/27/91. Attachment 2 RECEIVED Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) Alaska Oil & Gas Cons. Commission Anchorage Added to 1992 Temporarily Abandoned Status: · SCu 23B-3 & · SCU 21-8: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. · SCU 12A-4: High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU 21-15 & · SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED Alaska Oil & 6as Gons. oommissio~' Anchoraae ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry. Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected to be shut-in for a period of at least 30 days during 1992. Severa1 information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: . rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only ' abandonment. RECEIVED DEC 3 1 1991 Alaska Oil & Gas Cons. Commission Anchorage Mr. J. A. Dy gas Page 2 December 27, 1991 Shut-in wells until field blowdown, including: 4~ Hemlock prodUcers, and wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last year's TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4107. Sincerely, J. C. Winn Acting Regional Engineer JTZ:jlg:0025 Attachment CC: L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation R£CE V£D Alaska 0ii 8, 6as Cons. ARCO Alaska, Inc. · Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 David S. Joiner Engineering Manager Cook Inlet/New Ventures January 25, 1988 Mr. C. V. Chatterton Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached is a Report of~Well Operations for the recent perforating job that took place on Welli~l~~ This well was successfully perforated on 1/13/88 with a 5 foot 1-11/16" Enerjet gun between 10,575' RKB and 10,570' RKB. Unfortunately, the perforating gun was stuck in the well while it was being pulled out of the hole. Fishing operations were conducted for almost a week, but the gun could not be retrieved from the well. The top of the perforating gun in now located at 10,556' RKB. On 1/18/88, SCU 12A-4 was returned to production. The initial tests on this well indicated a flow rate of 185 BOPD with a GOR of 28,000 SCF/STB and a FTP of 2000 psi. We plan to keep this well on production as long as the producing GOR allows. Sincerely, D. S. Joiner DSJ:JWR:ch:0004 Attachn~nt RECEIV'E:D JAN Alaska Oil & Gas Cons. Commlsslo~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~'-" ALA .A OIL AND GAS CONSERVATION COI~.. ,iSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [Z Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface 2130' South & 690' East of NE corner of Sec. 4, T7N, Rgw, At total depth ·35' North & 370' West of SL 5. Datum elevation (DF or KB) 210 ' KB Feet 6. Unit or Property name Swanson River Unit- 7. Well number SCU 12A-4 8. Approval number 7-929 9. APl number 50-- 133-10103-01 10. Pool Swanson River-Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth See attached schematic True Vertical depth true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of mY knowledge ~7~. /' ~ ~ ~-~7i Signed _~ ,~ Form 10-404 Rev. 12-1-85 Title M~r., Cook Inlet Engineering Date //~'7/~J:~1' Submit in~'uupl~cat~~ , · ' - ~ ~. I~. 6.~ ~ 8~ ~ ~. 8xT.t~, · · ' ~ JU. ~. 6.~ ~ h x~ Tm. ~.~, . - 8,~8). ~ ~ ~~- ~.TJ, · 8 ~- ~, I ~. ~ &.~ ~ ~ x~ Tm. ~S).n, - B,~O. SZ' ~" z ~Z. ---~ U'~' . . ' 16)Y ' . · I ' · ~A~I *ZW ..... , ~m.o'. k ' ~ mn ~ m. ~.~P m ~.~, !""' I ., · ..__.. ._ . ... ~.r,~. =..o. ,: ICASfNG ~ TUBING D[TAIL f.O. ~,~, I SECTION 4 ~ T ~,R;9 W. ARCO Alaska, Im Post Office =~ux 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 David S. Joiner Engineering Manager Cook Inlet / New Ventures December 2, 1987 Mr. C. V. Chatterton Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are two Applications for Sundry Approval to perforate the tubing in Wells SCU 12A-4 and Well SCU 44-4. The lower zone of Well 44-4 cannot be opened to production without perforating the tubing due to sand fill and a solid obstruction at 10,812'. The obstruction at 10,812' is impassible with a coiled tubing unit. It is proposed that the tubing be perforated at 10,778' with five feet of 1SPF, 1-11/16" perforating guns. The upper zone in Well 12A-4 is isolated behind tubing. It is proposed that the tubing in this well be perforated at 10,575' with five feet of 1SPF, 1-11/16" hollow carrier perforating guns. By perforating the tubing in this well we will be able to test a zone that has been shut-in for 13 years. With your approval, we would like to expedite this work within the next several days. If you have any questions, please contact Tom Wellman at 263-4304. D. S. Joiner DSJ:JWR:ch:0003 Attachments CC: J. A. Dygas U. S. Bureau of Land Management.(For Information Only) RECEIYEI) DEC 0 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALA:SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate [~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office BOx 100360 Anchorage, Alaska 99510 4. Location of wellatsurface 2130' South & 690' East of N.E. Corner of Sec.4, T7N, Rgw, 5. Datum elevation(DF or KB) 210' KB 6. UnitorPropertyname Swanson River Unit 7. Well number SGU 12A-4 feet /)~X~X~~M(~Xv)~Xi~:Ik'~×~X At total depth 35' SB&M North & 370' West of S.L. 8. Permit number 9. APl number 50-- 133-10103-01 10. Pool ~;wanson River - Hem-rock 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented See Attached Schematic Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Measured depth True Vertical depth 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch Well Schematic 13. Estimated date for commencing operation 12/~/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ /.,C)~~... /~ .Z:,~ _,.:l~~_Title Mgr., Cook I n let Eng i neet i nq Commission Use Only Conditions of approval ORIGINAL SIGNED BY Approved by Form 10-403 Rev 12~-"~ Date Notify commission so representative may witness I Approval No. ~ .~ [] Plug integrity [] BOP.Test [] Location clearancel Approve(I (Jopy ,,.:, ~.;~,,~ '~:aa ~~ Return~ by order of Commissioner the commission Date Submit in triplicate,~, .78* · ~,20).0~ ~ mA ~ · . ' . ST Jm. ;l" 6.~ ~ ~.~-~ Tm. ' / ' ~.~'6.~~8~~TM, / · ~ %~ - ~" . p~ o.~' . . ' t ~ ~" ~ ' -.· .' ~t[tl~t~ · ,¥',: ~%~: · ~~A~o0~II~ 6e~v ~ l :.o..,. , ~,~, ~.-~.~. o~ ~.=, ToP er 1.D. CASING & TUBING DETAIL SECTION 4 ?. ? N.,R;gw. ARCO Alaska, h Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907263 4724 David S. Joiner Engineering Manager Cook Inlet/New Ventures November 20, 1987 Joseph A. DYgas, Branch Chief United States Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Joseph: Attached is a Sundry Notice of Intent to perforate the robing in Well SCU This operation was discussed with A. Seidlitz on November 20, 1987 and apProval was received. The proposed perforations will enable us to test a zone in this well that has been shut-in for almost 15 years. We plan to use 1-11/16" hollow carrier perforating guns and shoot five shots at 1 SPF. If you have any questions, please contact me at 263-4724. Sincerely, D. S. JoinerX DSJ:JWR:ch:0002 Attachment cc: C.V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission (For Info Only) RECEIVED. '~l~a 0il & Gas Cons. Cnmmissl0" Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfie/dCompany Form 3160--5 (November 1983) (Formerly 9--331) ITED STATES (Other Inetruc,..ae on DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT suNDRy NOTICES AND REPORTS ON WELLS (Do not ufa this form tot proposals to drUl or to deepen or pluw back to a difbreut reservoir. Use "AFPLICATION FOR PERMIT--" for sueb propamlL) ARCO_Alaska, In~. ADDUa8 O~ OPUA~B Post Office Box 100360 Anchorage, AK 99507 LOCATION Or U't-LL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface SL: BHL: 14. PigRMIT NO. 2130' South & 690' East of NE corner of Sec. 4, T7N, R9W, SB & M 35' North & 370' West of SL. JI$. B~VA~OSS (8~w whether u~ ~, ~ eta.) 210' KB Form approved. 13~get Bureau No, 1004-0135 Expires. August 31, 1985 LeaSe OaamNATmW AND en~L wo. A-028997 UMIT AGtBBMBMT NA~B So ldotna Creek So ldotna Creek waLL ~o. SCU 12A-4 10. r~ AND POOL, OR WIL~AT Swanson River - Hemlock II. $~., ~ B., M., OB Bag. AMD Sec. 4~ T?N~ Rgw. SB g M 13. eo~w~z om KenaiJ Alaska 10, Check AplarOl~iOte Box To Indicate Nature al Notice, Report, or Other Dole NOTICB OP %NTBNTION TO: FRACTURg TREAT MULT/FLg COMPLETE SHOOT OB ACIDL~B ABANDON° SEPSIS WEL~ CHANGZ PLANS (Other) (Nc,rs: Report results ~ multf~Io eompleUon on Well Completion or Recorapleuon Report and Log form.) i?. O~SCRX~E t'ROPOSEO sa CO.~PLETEO OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of startinw an. 7 propose~ work. If well is dlr~ction&lly drilled, give subsurface locations and measured and true vertical deptk8 for nil matt, leers alid neat to this work.) * ARCO Alaska, Inc. requests permission to perforate the 2-3/8" tubing at 10,575' KB with five feet of 1SPF, 1-11/16" hollow carrier perforating guns. Perforating the tubing will allow the upper H8 to be tested and possibly returned to production. This zone is currently isolated between packers without any sleeves to open it to production. RECEIVED ~,~d u 2 5 1.987 Alaska Oil & Gas Cons. Commission Anchorage 18. I hereby certify that the forewoing Is true and correct Mgr., Cook In let Enqineer i ngl>~,rj ////~'~///H~? (This space for Federal or 8tats sates uae) APPROVED BY CONDITIONS OF APPROVAL~ IF ~: TITLI~ DA~ *See Inductions on Revme Side Title 18 U.$.C. Section 1001, makes it a crime for any person kfloveiflgly and willfully to make to any department or agency of the United States any false, ~ictitious or fraudulent statements or representations as to any matter within its jurisdiction. ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 !2t5 Cook Inlet/New Ventures Engineering November 6, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management P. O. Box 230071 AnchOrage, Alaska 99523 Dear Joseph, Attached is a Sundry Notice of Intent to pedorate the tubing in Well SCU 12A-4. The proposed perforations will enable us to test a zone in this well that has been shut in for almost 15 years. We plan to use 1-11/16" hollow carrier perforating guns and shoot five shots at 1 SPF. If you have any questions, please contact me at 263-4724. Sincerely, D. S. Joiner Manager, Cook Inlet Engineering DSJ:JWR:ch:O001 Attachment CC: C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission (For Info Only) t ECEiIfEO NOV ~ ~ ~. A!as!<a Oil & Gas Cons. CornrnissiOl~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfietdCompany Form 3160--5 (November 1983) (Formerly 9--331) ,NITED STATES SUBMIT (Other tustr~ DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drUI or to deepen or plug back to R diei'erent reservoir. Use "APPLICATION FOR PERMIT--" for such Form approved. l:ludget Bureau No. 1004--0135 Expires_ August 31, 1985 fi*. LEAIN DEIIG~ATION AND IBIIAL A-028997 INDIAN, ALLOTTEE ON TRIBE NAME 1. 7, OMIT AGIBRMIINT NAMm Of L WE~L ~ GA,wELL I--] OTaE, So Ids*aa Creek 2. NAMB OF OPERATOR ARCO Alaska Inc. ADDIgE8 O11' OPERATOR P.O. Box 100360 AnChoraqe, AK 99507 LOCATION OF WELl, (Report location clearly and in accordance with any State requirementL· See also 8pace 17 below.) At surface 2130' South & 690' East of NE corner of Sec. 4, T7N, R9W, SB & M 35' North & 370' West of SL. SL: ItS. BmV~TIONS (Show whether DF. rt. a~ ets.) 210' KB 14. BHL: PERMIT NO. 8. PimM OB LEAIJB NAMm So ldotona Creek 9. WELL NO. SCU 12A-4 10. PIBLD AND POOL, OI WILDCAT Swanson River-Hemlock 11. SBa., T., B., M** ON BLE. AMD IUItVBY OB ABRA Sec. 4, T7N, R9W, SB & M 12. COUNTY oN ets,mai 18. ~,TN Kenai[Alaska 16, Check Approtmate Box To .indicate Nature of Notice, Report, or O~er I)ata N(YTI~B OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT oR ACIDrY-B ABANDONs REPAIR WELL CtIANGE PLANS (Other) WATER RHUT-OrP ~ itBPAIRIIlO WELL ~ PRACTURB TIBATMENT ALTBBilIG CA~INO 8HOOTING OR ACIDIIBINO ABANDONMBMT· (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 17. 0~:.~CR[U~: I'ROPOSKD OR CO.MPLETKD OPERATIONE. (Clear'l? state ali pertinent details, and give pertinent dates, la.cluding estimated date of starting any proposed work. If well ia directionally drilled, give subsurface loc~tiuns and measnred and true vertical aepths for all markers and Sones perti- nent to this work.) * ~3v, ARCO Alaska Inc. request permission to perforate the z§ Tubing ~ 10,681' KB with 11,, . five feet of 1SPF, 1-~6 Hollow Carrier perforationg guns. Perforating the tub~w~ will allow the upper HIO to be tested and possibly returned to production. This zone is currently isolated between packers without any sleeves to open it to production. ~ RECEIVED NOV / ^lask~ Oil & Gas Cons. Commission Manager Cook I n let Engineer ' ng:o,~'~l /f//Z//7 (This space for Federal or State omee u~e) APPROVED BY CONDITIONS OF APPROVAL, LU* ANY: TITLE DATE *See Inslnmfions on Revmse Side Title 18 U.S.C~ Section 100l, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. TABLE I Wel 1 s under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future Uti 1 i ty 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 ARCo Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, A1 aska 99523 Dear Joseph: Attached is a Sundry NOtice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during Our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categorieS: 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in- inefficient production 4. Shut in - save for blowdown Wells in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundr. y Notice request, please contact me at 263-4299. Sincerely, o H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB: JWR: ch: 0006 Attachment cc: C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission ARCO Alaska. Inc is a Subs,diary of At!anl~cR~chfieldComparly Form 3160--5 (November 1983) (Formerly 9--331) UNITED STATES sum, IT m Telrr,.c,~. (Other tustrneUouo au DEPARTMENT OF THE INTERIOR verseMda) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drUI or to de~pon or plug beck to · different reservoir. U~e "APPLICATION -FOR PERMIT--*' for such propo~lt) GAn ~ OTHRI Soldotn~ 2. NAMR or OPERATOR ARCO Alaska, Inc. ADDRESS OF OPIRATOR P. O. Box 100360 · Anchoraeo~. AK 99510-0360 4. LOCATION or WEr. L (Report location clearly and i~ a~cordsnce with any State requirements.· See also space 17 below.) At sqr~aee Soldotna Creek Unit - 15 Swanson River Unit - 22 wells 14. PERMIT NO. J16. ELBVATIOIqS (Show whet~er Dr, ~ mt, ~.) Form approved. Budget Bureau No. 1004--0135 Expires, August 31, 1985 §. Lfiem DBmIONAWON Arid inuL CreeklSwanson River Unit lien Git LIAll NAMD O. W~rJ_- 10. fflDLD AND POOL) OR WILDCAT Swanson River Field 11. ~** ~., L, M., Oil BL~. ~ ~UltVm! GU AADA 12. cooN,, o, ,ie,,nJ 18. ~-TR Kenai J Alaska Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 8FIOOT OB ACIDIZD ABANDONe SHOOTING OR ACIDIBIN· ABAN~NMBMT° REPAIR WELL CHANGE PLAN8 (Other) (N~B: Re.ri remul~ of mMtlplo ~mpleflon on W~ (Other) Tomporarily abandon _~. Completion or R~mpletion Re.ri and ~g fan.) DgSCRIU~ I'ROPOa8D OR COMPLETED OPERATION8 (Clen,*17 state all pertlne.t detalia, and ~lve pertinent dateL Ineludl~ proposed work. If w~! b di~tJon~y driH~, five s~e l~tions and mensur~ and true vertl~ depth for ~1 markers and Mn~ ~rfl- neat ~ ~is wor~) ' As described in the attached memo, ~C0 Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SCU12A-4 SCU 13-9 SRU 34-10 SCU 13-4 SCU12A-10 SRU 14-15 SCU323-4 SCU343-33 SRU 21-15 SCU43A-4 SCU 14-34 SRU 31-15 SCU 24-5 SCU 14-3 SRU 432-15 SCU 33-5 SCU23B-3 SRU 34-15 SCU341-8 SCU 34-4 SRU41A-15 SCU21A-4 SRU43A-15 SRU312-22 SRU 21-22 SRU 23-22 SRU 22-23WD SRU212-27 SRU314-27 SRU 23-27 SRU331-27 SRU 34-28 SRU14A-33 SRU 24-33 SRU 12-34 SRU 21-34 18. ! hereby cert~f~at the foregoing tF/~'ae and correct sx r~'. . ...- TITLE Regional Engineer DATa (This space for Federal or State office u~e) APPROVED BY CONDITION8 OF APPROVAl,, I~ ALii: TITLE DAT~ *See Inslmctions on Revme Side Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, £ictit~ous or fraudulent statements or representations as to any matter within its jurisdiction. COMPLETION REPORT - REMEDIAL STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS. INC., OPERATIONS , . ~AREA: Swanson River .Piel~ i Kenai Peninsula '- Cook Inlet Area' Alaska .~ROPERTY: Soldotna Creek Unit WELL NO: SCU 12A-4 LOCATION AT SURFACE: o [LOCATION AT DEPTH: -. EAND OFFICE: Anchorage' LEASE NO: A-028997 API NO: 50-133-10103-01 2130' South and 690' East from Northeast Corner Section 4, T7N, R9W, Seward B & M. · 35' North and 370.' ~.West from surface. ~ii ELEVATION: 201' K.B. K.B. is 1'5' from g~'ound surface. .. ~. M. McKinley / Area Engineer DRI..]J,ED' BY: Nabobs Rig #5 DATE COMMENCED DRILLING: 12:01 AM, April 13, 1975 · . -. · DATIg COMPLETED: 10:00 PM, April 22, 1975 DATE OF INITIAL I:'RODUCTION: TOTAL DEPTH: 10,808' SU~RY PLUGS: 10,840'-10,808' EFFECTIVE DEPT}I: 10,840' CASING: 22" cemented at 29'' 13 3/8" cemented at 2,024' 7~· cememted at 8,397'. LINER: 5" cemented at 10,880' COMPLETION REPORT - REDRILL STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS. INC., OPERATIONS !AREA: Swanson River Field .... Kenai Peninsula .Cook Inlet Ar~a, Alaska 'b LAND OFFICE: Anchorage · PROPERTY: Soldotna Creek Unit LEASE NO: A-028997 - · . " WELL NO: i2A-4 " ' 'API NO: 50-133-10103-01 LOCATION AT SURFACE: 2130' South and 690' East from Northeast Corner Section 4, T7N, R9W, Seward B & M. - ... - LOCATION AT DEPTH: 35' North and-370"-West 'from surface. ELEVATION: 201' k.B. , ~//~//~?~ K.B. it 15' from ground DATE: '/BY:. · / surface. R.M. McKinle~ , Area Engineer DRILLED BY: Kenai Drilling Co~pany, Rig #2 : DATE COMMENCED DRILLING: 10.- 30' .AM, ..May 25, 1974 DATE COMPLETED ~ '" 9: 00 PM, July 6, 1974 DATE OF INITIAL PRODUCTION: July 6, 1974 S~ARY TOTAL DEPTH: 10,880 ' EFFECTIVE DEPTH: 10,840 ' CASING: 22" cemented-at- 29' .....- ~ ~ '~-. - "' 13 3/8" cemented at 2,024' ~-c . ."~7" cemented at 10,969' (milled 8,597'-8,637') PLUGS: 10,840'-10,880' cement , LINER: 5" cemented at 10,880' Top at 8,397' · · JUNK $.T, 7" casing'from 8,637.' to 1~,969' (2,332') · 9.b 19/5 DIYISiON OF 0]1, AND .' , -, \ - . ,. ,""~ -~ .. . .~. ".....,." ~ " COMPLETION REPORT - REMEDIAL STANDARD OIL COHPANY OF CALIFORNIA, WESTERN OPERATIONS. INC., OPERATIONS . " AREA: swansonRi ver Field' Kenai Periinsu1a Cook In~et Area, Alaska. LAND OFFICE: Anchorage' PROPERTY: , so1àotna Creek Unit LEASE NO: A-028997 WELL NO: API NO: 50-133-10103-01 SCu12A-4 LOCATION AT StJØACE: 2130' South and 690' East from Northeast Corner Section 4, T7N, R9W, Seward B & M. , LOCATION AT DEPTH: 35' liorth and 370:*-.West, from surface. ELEVATION: 2018 K.B. K.B. is 15' from gmound surface.' . "\ DATE: 9Þpr ~ BY: £Þ Ø/P. j; Area Engineer - - . DRI}.LED BY: Nabors Rig #5 DATE COMMENCED DltILLING: 12:01 AM, April 13, 1975 ....-t°,,",.' -.. ..-:" , DATE COMPLETED: > lO:OOPM, April 22, 1975 DATE OF INITIAL PRODUCTION: SUMMARY TOTAL DEPTH:" 10,1,808' PLUGS: 10,840'-10,808' . ...:.;. J''''' 1... ' _. EFFECTIVE DEPTH: 10,840' . ...' :;-~, CASING: 22" cemented at 29' - . 13 3/8- cemented at 2,024' 11! cemenbed at 8,397'. ~. ." ~ LINER.: 5" cemented at 10,S80' ..¡Æ Œ~Œ H W fE ~ ".,'. . SE P '2 ó 1975 DIVISIO~ OF OfL AND GAS . ¿tJm:)ii'ì.N~t~~ . . ~ - . . ,-,..', .~~ '~ ,,'~ -'.f .- .~~ '. ~~~~ ¡.kJ " , Perforations: !, i Logs: --~ ~ 1st Rework - four 0.4" jetho1es per foot at: 10,745'-10,720' 10,710'-10,697' 10,687'-10,657' 10,647'-10,624' 10,606'-10,590' 10,581'-10,561' 10,552'-10,534' 2nd Rework -two 0.5" jet holes per foot at: 10,720'-10,745' Go-Inte%nationai Perforating Collar Log 10,842'-10,200' Go-Internationa1 Neutron Collar Log 8,200'-10,746' ~ ~ '! A~ril 13, 1975 -Comenced operations at 12:01 AM. Killed well with 74 pcf~ mud. Installed Cosasco plug in donut and tested to 5,000 psi, ok. Removed x-mas tree. April 14, 1975 Installed Class III 10" 5,000 psi BOPE. Tested, ok. Pulled cosasco plug. Pulled out tubing, broke off at cc joint at 10,550.8'.. Recovered FH packer. A~ril 15-9, 1975 ~ecovered 29.26' of fish. Engaged fish at 10,544' and pulled out, Engaged fish at 10,604' and pulled out'30.16'. Engaged fish at 10,634' and pulled out 76.52'. Engaged fish at 10,710' and lost it. Engaged fish at 10,709' and pulled out 24.35'. Engaged fish at 10,733' and pulled out 38.40'. April 20, 197'5 Ran Go-International Perforating Collar Log from 10,842'-10,200'. Perforated 5" liner with 2 je.t holes per foot, from 10,720'-10,745'. : jApril 21, 1975 ~ Ran Go-International Neutron Collar Log 8,200'-10,746'. Ran 2 7/8" tubing to 8,320' and 2 3/8" t~bing down to 10,748'. Tested tubing hanger 2,500 psi, ok. See tubing detail. .April 22, 1975 ~moved BOPE. Installed x-mas tree and tested to 5,000 psi, ok. Displaced mud with lease crude. Closed sleeves at 10,514' and 10,650'. Pressure set packers at 10,517', 10,585', 10,653' and 10,693', ok. Rig released at 10:00 PM. J. W. Wilson .' i .. J KB ~o "I'U,DiNO HANOgR ~L7.OO* ~BIEG ltAN.J£R . . · 8397' ' ] 86~7' WINDOW IN 7." ; · · · , 10,512.47 ~ OTIS "XA" SLE.-UVE . ' .' ' 10,~15..35_~'~ 2~" BAKER m PACK~ 10534' 10,5~.~0 ~ ~ "CC" SAF~Y JT. ' / ~ IO552' IO561'. - l°S8~' ]: ' . , ~'KERB~'r JTS. 3.~2" OD ~ 10,5~.~8 ~ OP~ "S" NIPPY, Position ~2 10~7~ _ n ~C~691.~S ' s. ' . · ~ .~: _ ~ ~ x 5 ,18~ BAKgR FH PACKER ~,~e~?" ~ .u,oyi.~ ~ OT~ "N" or ~CO "D" NIPP~ ~o,,o'. .j' · ' ~ ~m ~ ~. ~.~, og TOP T.D. 10,880' · . -' '" 73 5TS. 2;" 4.3~ EUE §rd N-80 TBOo 2A-4 .70' 2278.81' 12.78' 1~16.71' 12.79' 1102.47' 12.81' 817.93' 5o2.6h' 12.73' 253.21' 13.05' 1.10' 2190.5~ ' 2.88' 1.hl' 61.O2' 1.5h' 66.23' 1.hO' 2.~7' 1.3~' %0.30' CASING & SECTION TUBING DETAIL 4 T. ? N.,R~9 W. z,"o~-m So. P-4 · STATE ¢~ ALASKA SUBMIT IN DI.~LICA"~ - OIL AND GAS CONSERVATION CO~i~E~ ......... '...... 50-133~ I. 1 lNG 'F '~. MONTHLY REPORT OF DRILLING AND WORKOV.ER OPERATIONS. A-O2899G ~.' ~ o~ OP~Toa .. 8. ~'ZT,~ O~ Standawd Oil Cnmnnn~ ~ California. WOT Soldo~a Creek ~-~.. .... , 3. ADDRESS OF OP~TOR ....... ' 9. " P.- O. Box 7-839. ~ehorn~a. Ala~ qq~10 . SCU 4.' ~CA~ON OF W~ lO. F~ ~D P~L. OR WIL~ ~ '~:':' - 2130' Sou~ ~d 690' East of N.W. comer of Sec~on 4; T-7N, R-9W. _. , ..... ,,, ,,, ,,, ,~ i . , .,, , ,.. , ,, ,t , , , ,~, , ,, ,. . , - , . .,. , . , REPORT TOTAL DEPTH AT END OF MON'rH, CHANGES IN HOLE SIZE, CASING AND C~WIENTING JOBS INCLUDING DEPTH SET A/~q) VOLUlVII~ USED. PEP,~OP,-ATIONS. TESTS AND RESULTS. FISH/NG JOB~. JUNK IN HOLE AND SIDE-TP,.ACKED HOLE A~N~) ANY OTI-I:F_,~ SIGNIFICANT CHANGES IN HOLF.. CONDITIONS. May 1974 Moved in rig to well SCU 12A-4. Circulated well full of 80 PCF mud. Installed and tested 10" - 5,000# BOPE. Recovered tubing leaving 22' of fishing tools and 129' of tubing fish including model F packer in hole from 10541 - 10,685'. Bridged 7" casing from 10,054' to 10,556' with 91 sacks of class "G" cement. Milled window in 7" casing from 8597' to 8618'. This constitutes notice of abandonment of original well-bore, prior to redrilling the well under another designation. P,. M. McKinlev~~~___ Area En,ineer DA~ NOTE--Report off this form is required for 'each calendar month, rqardless of the status of operations, and must ~ filed in dupli~te with the Division ~ Mines & Mi~rals* by the [Sth of the succeeding month, unless othe~ise diff~ed. Perforations: Original- five 1/2" holes at 10,339' four 1/2" jet holes per foot at: 10,343'-10,371' 10,383'-10,397' 10,418'-10,430' 10,~439'-10,475' 10,482'-10,496' 10,504'-10,579' 10,589'-10,605' 10,622'-10,701' *Note none of the original perforations are any longer open. Rework - four ~0.4" jet holes per foot at: 10,745'-10,720' 10,710'-10,697' 10,687'-10,657' 10,647'-10,624' 10,606'-10,590' 10,581'-10,561' 10,552'-10,534' Logs: Schlumberger Dual Induction Laterolog Borehole Compensated with Caliper Gamma Ray Formation Density & Oom~ensated Neutron Log Dresser Atlas Cement Bond Log Variable Density Log Neutron Collar Log Neutron Collar Log 8,592'-10,869' 8,592'-10,868' 10,868'- 9,000' 8,340'-10,816' 1! --5 II 2 "- 5" 5" Initial Production: Method: flowing Oil b/d: 1,338 Water b/d: 370 Gas mcf/d: 5,372 GOR cf/b: 4,014 July 6, 1974 May 25, 197.4. comnenced operations at 10.:30 AM. Killed well with 80# mud. Installed ,Cosasco backpressure valve. Removed x-mas tree. '~ May...26, 1974 Installed 10" 5,000 psi BOPE. Tested to 5,000 psi, ok. Removed Cosasco plug. ~nlanded tubing. Circulated and conditioned mud. Pulled top two Baker l~ackers. Freed Brown packer. Circulated and conditioned mud. Hole taking fluid. 75 pcf mud .May 27, ~974 Mixed a~ conditioned new mud. Pulled "production assembly, left 10" of Brown l~acker, 1 joint 2 7/8" tUbing, 1 nipple, 1 joint of 2 7/8" tubing, MM mandrel, 1 joint 2 7/8" tubing,-"D" nipple, stop and seal assembly, -~' -2 joints of 2 7/8" tubing, 4~ perforated pup joint. Total fish length is 183 ' . 75 pcf mud May 28, 1974 Recovere~ 33' of fish. Recovered 21.8' fish. 128.2' fish left in hole. 75 pcf mud ; '~¥ 29,~1974 Recovered 4' of fish, 124' fish left. Top at 10,561'. 75 pcf mud May 30, 1974 Mixed 91 sacks "G" cement. Preceded cement with 40 cu. ft. water and dis- placed with 5 cu. fto Water and 414 cu. ft. mud. Pulled down to 9,973'. Dowsqueezed 100 ft. Reversed out at 9,973'. Pulled up to 9,880'. Increased mud weight from 74 to 96 pcf. ~MaY 31,, 1974 Ran Tristate section mill. Started cutting out at 8,597'. Milled 7" section 8,597'-8,615'. 18' in 9 1/2 hrs. June 1, 1974 Milled 7' ~section from 8,615'-8,637'. 19' in 10 1/2 hrs. 96.5 pcf mud 96 pcf mud J~une 2, 1974 Baker lockomatic opened 12" from 8,597'-8,637'. Added Hi-¥iscosity loss- ~circulation material. Circulated and conditioned mud. Lowered viscosity .. from 130 to 57. Plugged 12" hole and 7" casing from 8,639'-8,197' through 3 1/2" drillpipe hung at 8,639'. Mixed 114 cu.ft. "G" cement made into 125# slurry. Cement preceded with 42 cu.fto Water and equalized with 6 cu. ft. Water and 335 cu. ft. mud. Pulled up to 8,113' and reversed out -trace of Water. 96 pcf mud 'June 3, 1974 Cleaned out cement stringers from 8,117'-8,127'. Slid to 8,468'. Drilled out cement fromm S,468'-8,601. : . '96 pcf mud June 41, 1974 Drille~ with 6" Dlrna-drill and steering tool from 8,601'-8,639'. 96 pcf mud June 5, 1'974 An~le building set-up 6" bit: Reamed from 8,601' -8,639 ' Drilled from 8,639'-8,670'~ Reamed from 8,639'-8,670' Drilled from 8,670'-8,680' 96 pcf mud June 6, 1974 Drilled 6" hole 8,680'-8,793 ' 'J%me 7, 1974 Drilled 6" hole 8,793'-8,888 (113') (95 ' ) 96 pcf mud 96 pcf mud June 8, 1974 Drilled 6" hole 8,888'-8,985 ' (97') 96 pcf mud June 9, 1974 Ran Dyna-drilI with 2 degree bent sub. · 8,985 '-9,004 ' Dyna-drilled (19 ' ) 6" hole June 10, 1974 Dyna-drilled 6" hole. Reamed from 8,985 ' -9,059 '. 9,~04 '-9,059 ' (55') June 11, 1974 Drilled 6" hole 9,059 '- 9,181' [122') June 12, 1974 Drilled 6" hole 9,181'-9,292' June 13, 1974 Drilled 6" hole 9 ;292 '-9,420' (111') (128') ': 95 pcf mud 96 pcf mud 96 pcf mud 96 pcf mud 96 pcf mud 'June 14; 1974 Drilled 6" hole 9,420 '-9,520' (100') 96 pcf mud June 15, 1974 Drilled 6" hole 9,52.0'-9,649' (129 ' ) 96 pcf mud 'June '16, 1974 · Drilled 6" hole 9,649'-9,767' (118') 96 pcf mud _June 17, 1974 Drilled 6" hole 9,767'-9,841' (74") 96 pcf mud June .1.8, 1974 Drilled 6" hole 9,841'-9,966 June 19, 1974 Drilled 6" hole 9,966 ' -10,125 (125 ' ) (159 ' ) 96 pcf mud 96 pcf mud June 20, 1974 Drilled 6" hole 10,125'-10,280 June 21, 1974 Drilled 6" hole 10,280'-10,414' (155') (134 ' ) 96 pcf mud 95 pcf mud June 22, 1974 Drilled 6" hole 10,414'-10,483'. D=illed from10,483'-10,493'. June 23, 1974 Drilled 6" hole 10,493'-10,495' Reamed from 10,465'-10,495'. Drilled .from 10,495'-10,543'. -June 24, 1974 Drilled 6" hole 10,543 '-10,631 ' Pipe stuck 7% hrs. (79 ' ) Reamed from 10,280'-10,483' 96 pcf mud Conditioned mud, added diesel and bit lube. (50') 96 pcf mud (88') 96 pcf mud June 25 { 197~4 Drilled 6" hole 10,631 '-10,753 ' (122') 96 pcf mud gun.e 26~1974 Drilled 6" hole 10,753'-10,804.' (51') 96 pcf mud june 2~, 1974. Drilled 6" hole .10,804 '-10,880' I Conditioned mud for logging. (76') '? 96 pcf mud June 28, 1974 Ran Schlumberger Dual Induction Laterolog from 8,592'-10,869'. Reamed from 10,830'-10,875'. Circulated and conditioned mud. June 29, 1974 Ran Schlumberger Borehole Compensated Sonic and Caliper Log from 8,592'- 10,868'. Ran Schlumberger Gamma Ray FDC and CNL logs from 10,868'-9,000'. Circulated and conditioned mud for 5" iiner. 96 pcf mud June 30, 19.74 Ran 5" 18# N-80 liner and set on bottom. Liner froze on bottom at 10,880', top at 8,397'. Cemented 5" liner around shoe with 500 sacks of "G" cement mixed 125# slurry. Displaced with 598 cu. ft. of mud. Pulled dry to 8,060' and reversed circulated with 658 cu.ft, of mud. Backscuttled out cement. Full circulation through job. Ran Saraband 9,000'-10,860' 96 pcf mud Ju~.y 1, 1974 Located top of cement at 8,045'. Drilled out cement with 6" bit from 8,045'-8,397'. Ran in hole to 10,835'. Conditioned mud for Cement Bond Log. 95 pcf mud July 2, 1974 Dresser Atlas ran Cement Bond Log, Variable Density Log, and Neutron Collar LOg from 8,340'-10,816'. Decreased mud weight from 88 to 73 pcf. Dresser Atlas perforated 5" casing four 0.4" jet holes per foot. Intervals: 10,552'-10,534' 10,-581'-10,561' 10,590'-10,606' 10,624'-10,647' 10,657'-10,687' 10,697'-10,710' 10,720'-10,745' July 4, 1974 Began running tubing. July 5, 1974 Ran Dresser Atlas Neutron Collar Log to set packers. .Jul~ 6, 1974 Landed 2 7/8" tubing down to 8,307.77' mandrel and x-over 2 3/8" tubing down to 10,745'. Installed Cosasco plug. Removed class III BOPE. Installed x-mas tree and tested to 5,000 psi, ok. Removed plug, displaced mud with lease crude. Closed XA sleeves at 10,512', 10,583', 10,648'. Flowed well. Rig released at 9:00 PM. J. W. Wilson t ' ' ' YUBZEO ]tANGEE · 71 J~3. 2-? & PUPS 6.~# EOF, 8rd N-80 22.7~o~1' · - - ~ C~CO K~A ~NDi~EL ~.~' / . ' ~ ~. ~'" ~.~tt sos 8rd-N;80 TBO. .' ~ a~s, 2~,, 6.~t ~u~ 8~.N-80 T~. ~h~6.7~' C~~ ~A ~DIiiL " ' ~CO ~t F~NDR~ " · ' 12.81' - . ':' '"' 26 JTS. 2~" 6.~ EUE' 8~ N-80 T~. 817.93" C~CO ~ ~ND~L 13.0%' ' ' ~ ~ ~. $,, 6.~ s~ ~CO ~A MAND~L. ~ 12.73' 8.~rs. ~,, 6.~ sus 8r~ N-~O T~. 8,307.77~ C~CO ~A. M~NDR~ 13.05' " ' 8,320.82 ~2~$" x 2~' . X-O~R 1.10' . . ,... · ~.'. t-~7 .. . . ~7;' '. ' · "~ ~ ~s. 2? ~.~ ~us ~ N-OD TBo. 2~0.~, WINDOW IN~" I 10,512.47 % OTIS "XA" SLEEVE " . ' · 2.88' 10,515.35_~-~ 2{" BAKER ,~ PACKER ~.45' 10534' 10~5~,60 ~ ~ "CC" SAF~Y dT. ' 1,41l ~ 10552' ~o56~' '. . ' ~ ~KER B~'~ JTS. 3.~2" OD 61.02' ~!O58f. 10,583'23 ~ 2?' x ~W606' 10,588.68 ~ O~IS "S" NIPPY, Position ~/2 · ... 1.~' ~.wsz4. ~' '. 4 ~ B~T JTS..3.~2" OD ~.23' ( ~o647"- 10,647.45 ~ BR~'N "CC" SAFE~ JT. 10,651.72 ~ OTIS XA S ~ "CC" SAFgTY JT. ' ~o687' ' ~,~ 10,,697.~ .~ OTIS "a" or ~lCO "D" NIPP~ ~o~,o' ~ 3 ~m ~r ~. 3.~' on ~o.3o~ ',o,,,. 2 A - TOP of* PLUG U 10,798' . CASING 8, TUBING DETAIL T.D. 10,880, SECTION 4 T. 3' N.,R',9 W. ~-4 -1'5 Perforations: 1st Rework - four 0.4" jet 10,745'-10,720' 10,710'-10,697' 10,687'-10,657' 10,647'-10,624' holes per foot at: 10,606'-10,590' 10,581'-10,561' 10,552'-10,534' 2nd Rework - two 0.5" jet holes per foot at: 10,720' -10,745 ' Logs: Go-International Perforating COllar Log 10,842'-10,200' Go-International Neutron Collar Log 8,200'-10,746' April 13, 1975 -Commenced operations at 12:01 AM- Killed well with 74 pcf' mud. Installed Cosasco plug in donut and tested to 5,000 psi, ok. Removed x-mas tree. A~ril 14, 1975 Installed Class III 10" 5,000 psi BOPE. Tested, ok. Pulled cosasco plug. Pulled out tubing, broke off at cc joint at 10,550.8'.. Recovered FH packer. April 15-9, 1975 Recovered 29.26' of fish. Engaged fish at 10,544' and pulled out, Engaged fish at 10,604' and pulled out'30.16'. Engaged fish at 10,634' and pulled out 76.52'. Engaged fish at 10,710' and lost it. Engaged fish at 10,709' and pulled out 24.35'. Engaged fish at 10,733' and pulled out 38.40'. April 20, 1975 Ran Go-International Perforating Collar Log from 10,842 '-10,200'. Perforated 5" liner with 2 jet holes per foot, from 10,720'-10,745'. : April 21, 1975 Ran Go-International Neutron Collar Log 8,200'-10,746'. Ran 2 7/8" tubing to 8,320' and 2 3/8" t~zbing down to 10,748'. Tested tubing hanger 2,500 psi,. ok. See tubing detail. April 22, 1975 Removed BOPE. Installed x-mas tree and tested to 5,000 psi, ok. Displaced mud with lease crude. Closed sleeves at 10,514' and 10,650'. Pressure set packers at 10,517', 10,585', 10,653' and 10,693', ok. Rig released at 10:00 PM. J. W. Wilson I J I i ~L~V. 201' 'B TU [I]l~O ItANJI".R · · '/1 Jrs. 2-[" & PuPs · · .. 2,303. O~;- CAMCO ~ F~NDREL ' . " 'fl~ J~,~ ~"' 6.5// EUE 8rd-NLSO T~. ' ''" / ' ' " 4%JTS. 2]" 6.~UE 8~.N-80T~. ' . ] ' 3% JTS. ~" 6.~ EUE 8rd..N-80 T~. ' ~ ' !'"' · ' "" ~6 4TS. ~¢" 6.5,f EUS 8~ N-~O T~. 7,526.~ c~co ~A ~ND~L '" /' ' _oo 8,O41.83~ C~CO ~A HANDEL. . 8,307.77 ~ C~CO ~A N&NDHEL 8,3JO.82 ~ 2~" x 2!,, X-O~R · _ . 8397' ' · 8597 WINDOW IN . 8657' 17,00' -. ' "73 ~TS. 2;" 4o3~ EUE 8~d N-80 TBO. 10,512.147 OTIS "XA" SLEEVE - ' ' io,5i5.35 2~', BAKER ~q{ PACKER . 10,~20.80 ~OWN "CC" SAFETY JT.. · . ' ) BAKER BLASt JTS. 3.~2" OD 10,583-23 2!" x 5" 18~ B~ER ~ PACER . 10,588.68 O~IS "S" NIPPy, · 4 ~ B~T JTS. 3.~2" OD 10,647.45 BR~N "CC" SA~ JT. 10,6~.85 OTIS "XA" ~VE ~o,6~.~2 2%" x 5" 1K~' ~K~ FH 10,65~.17 BE~ "CC" S~ETY JT. ~0,69~.~5 ~,, x 5,' .~8~ B~KHH FH ~AC~S~ 10,69~.~ OTIS "N" or ~CO "D" NIPP~ . ' ) ~ B~T J~. 3.~' OD 10,~48.90 ~K~ ~T SUB. 2 T.D. 10,880' 13.O5' ~34.50' 12.78' 1$16.71' 12.79' 1102.47' 12.81' 817.93' i3.o5' 502.64' 12.73' 253.2~' 13.O5' 1.10' 2.88' 1.41' 61.O2' · . 1.5~' 66.23' 1.40' 2.~J?' 1.36' 33.00' 50.30' CASING & SECTION TUBING DETAIL 4 T. 7 N.,R~9'W. TRANSMITTAL A ACKNOWLEDGEMENT OF RECEIPT OF ERIAL - (ALASKA) ,_ . Mr. 'r. FL Marshall TO: ~-i 8late of Alaska · ,~ D{vlslon of Oil & Gas - DEPT. :--! 3001 Porcupine Drive ~ Anchorage. Alaska 99504 PLACE: j ~*~E, (/~/~,~.CG /97,~~ FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. · COMPANY' WELL HISTORY LOG ~,~ ~ ...... ,5'0~ ,4 / ~ ~ ) . - ......... ~e~t~~ 2" 5" I I 0/C o I< o RECEIVED BY REMARKS O//N OTHER SIDE, THIS SHE'ET Ol Z2"~ 29' 2,401.60' 3,73§.98' 4,696.70' 5,463.07 -- 6,042.37 ~ 6,495.8~ -- 6,792.21 6,994° 74 .... 8,~2%.68' 8597' 10,520.74' 2~fd, 10,523.60' 10,529.00* 2~e" ,, . [o,55o. 5o~ ~,, -10,553.66' 10,559.~' ~ 2[" 10,578.44 ' 10,579.84' 10,582.69' 10,588.13' ~ 10,~O9.92' "~ LANDING MANDREL TO K.Bo DO-NUT '"~ ' '5 PUP JTS. 2~"'N~.O (.65',2.06',8.O3',10.09,) 75 JTS. 2~' N-80 8rd EUE TUBING 2~J' CAMCO MMA MANDREL 42 JTS. 2)s" N-80 8rd EUE TUBING 2~e" CAMCO ~A MANDREL 30 JTS. 2~e" N-80 8rd EUE TUBING ~}~' CAMCO MMA MANDP~L 24 JTS. 2~" N-80 8rd EUE TUBING 2~,, CAMCO MMA MANDREL 18 JTS. 2~," N-80 8rd EUE TUBING 2~, CA, C0 ~A ]34 JTS. 2}~' N-80 8rd EUE TUBING 2%" C~CO ~ ~D~L 9 JTS. 2~a" N-80 8rd RUE TUBING 2%" C~CO ~ ~ND~L . 6 JTS. 2PJ' ~80 8rd EOE TUBING 2%" C~CO ~ ~ND~L 42 JTS. 2}~' ~80 8rd EUE TUBING 75 JTS. ~%" N-80 8rd EUE TUBING OTIS "XA" SLEEVE x 5~' 23~ BAKER "FH" PACKER OTIS "S" NIPPLE, Position #6 2~',~'. BLAST JT. (3.062" OD ) BR~WN "CC" JOINT OTIS "XA" SLEEVE · x 5~" 23.~ BAKER "FH" PACKER OTIS "S" NIPPLE, Position #5 2~, BLAST JT. (3.062" OD) =- 2_~' BROWN "CC" JOINT . ~- ~"OTIS "XA" SLEEVE . ~- 27J' x 5~' BAKER "FH" PACKER ~- 2~" OTIS "S" NIPPLE, Posi%ion #4 ~'~" B~$? ~T.. (3,067' .OD) '...~- 2~a" BROWN "CC" JOINT 17. CO ' .50' 26.0~' 12.78' 132~.~O' 12.6~' 9~ ~. c~ ' 13. o5 ' 753.32' 12, ?& ' 12.6~ ' ~.o2' 2~3.35' 13.~' .67' 2194.39 ' 5.~o' 1.52 ' 18.~8 ' 1.~O' 2.84' 5.40' '1.~0, 17.88' 1.~O' 2.85' 5.4~" 1.52' 18.86, 1.40' 2,~5 ' -4 10,612.77'-_ ~ 2?J'C~IS "XA" SLE~V~ .' ' . lo,6r~,:~o, .. ........ ~ ~ 2~, ~ ~, ~ ,,m,, ~AC~ . 27~' OT~ "S" NIPPY, P~ition ~3 2 2~" B~T JTS. (3.Oa2" OD) lO,64a.~, 10,694.39'- ~ 2~ x ~ B~EE ~ PACKER ~o,7[~.oo, ~ 2}o" OTIo "N" NIPP~ ~ MZ;' ~ ~rS. (3.O~" OD) 10,743.90 BAKER SHE~ SUB .... " 'R_. -.C '" .IP_ .A. ~o~8~o, r.o. 5.~3 ' 1.50, 24.90, 1.39 ' 2.06' 5.~' 1.~3' 28.92, 1.40, 2.86, 5.41, 1.50, 13 ~ 23 5 2.~8, 5.39' 1.62' 25.91' _ CASING 8 TUBING DETAIL $~¢TION 4 T.? N., R.~W. Sg. 9 -9-74 i _il t i i t i T?JCi~.ff TTAL A,,'iD ACKN?,--.vk-i)CT.flq..,,T OF RECE1 PT OF MATEII~)~i ' ~ ..~,...: :. .. :. ; .. . . . .. I OLLO,.,IaG IS A LIST OF ~TERI~ ENCLOSED HEREWITH. .~ " CttECK AND [~VISE I~DiEDIATELY. ~ PLEASE --- -~:"~¢~5~~~~.. '~ >'~' ' ~~~~-~.~~~'z~:""~ "' ' ''~ '~'"' '''~' ""'" '""" '~" ~:'~' .~_'-% '.. . ' . ' ... · ...' ' .-'. · .~ . ' . . ~. ~.._ Received and checked by:~~.~....~. Date ',~/9 /~,'~ TRANSMITTAL AND ACKNOI.~ED~GMENT OF RECEIPT O~ MATERIAL- (ALASKA) . .'" :' THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREWITH. PLEASE '. . - CHECK AND gl)VISE IMbtEDIATELY. j . - DIVISION OF 'OIL AND (;AS ANCHORAGE Remarks: SUBMIT IN DUPLICATE* STATE OF ALASKA · ~: rGc T ;,,ri.,, ,,;1 OIL AND GAS CONSERVATION COMMITTEE WELL (OMPLEIION OR RE{OMPLETION REPORT AND LOG * ~ ELl. ~ WELl. ~ DRY b. TYPE 0F COMPLETION: 1% EI ! ~ ~%'ER ~ EN ~ D.~CK ~ES%'R. Other iRI'GINAL Standard Oil Company of California, WOI ADI,KES.q OF OPERATO~ P.O. Box 7-839, Anchorage, Alaska 99510 4 I.OC:TI,')N OF WEI.L (Report location clea,'lll a?d in accordance l~'ith CZ~ll/ State rcquircrnentz)*t_ Z:'.,.~ ,'/ xt~um~ce 2130' South and 690'East f c~' ,'- ~-- rom Nor th~&ot. i~,0~ ~rod. Sg~0r~be~.~r°j'' Sec. 4; T7N, R9W, Seward B&M 30' North and 300' West from surface At total depth . 35' North and 370' West from surface 5. APt .NUNLILI',.ICAL COt3k; 50-133-10103-01 Four %" hole 10534'-10552 10561'-10581 10590'-10606 10624'-10647 30. - PiIODUCTION- " ' ] · [PnoD':v FO.~ J TE~ 7/9/74 3 [ 54/64" FLOgV, TUEING CASU~G PRESSURE JCALCU~T~ OIbBBL. r~0 0 }24-HOU~ RATE . - ~ 1338 Injected back into Field ..... 32.-Llsx' OF &X~ACtIMENTS . DATE FIRST P£:ODUCTION 7/6/74 per foot 10657'-10687' 10697'-10710' 10720'-10745' SIZ~I ~ TOP (AID, EOTTOAI (5ID; SACi{.S CEMENT' 5" [ 8397' 10880' 500 28. PERFORAilONS OPE~N TO PRODUC'i~ION (interval, size and number) C/~,SI~4C. SIZE %VEiGHT. LB FT. GR.~Dg DEPTH SET (~m; H~E"~ CEklLNTING I{ECOi~ 1 /,2.[CUNT PULLED 22" 29 ,, ' 13-3/8" ''54.5'~ J-55 20~'4; .... 18 5/8[' 1875 sacks cement None 7" 23 , 26 , &29 _ ~ , ~r, 8q, P-110 .... 10~59':_. _12~.[ 2300 sacks cement None , I 'i I 1J. L)A. TE ~I'UDDED 14. DATE T.D. ~.,A. CI4ED 15. DATE COMP SUSP OR ABAND. 16. 5/25/74 6/27/74 7/6/74 201' KB , lg I',3T.AL DE?CH. 21. INTERVALS DRH. LED BY 1.0842' TV 0835 MD10798'T 0-10880 ,_ "'~. P~ODUCING TN~RVAL(S), OF ~IS COJ1P~TIO.N--TOP, BO~ObI, NA~IE (MD AND svnv~Y ~aDZ . Top 10534' MD 10494. ' TVD [ Yes Bottom 10745' MD 10700' TVB. Hemlock ........ 24.TYPE ELECIillC AND OT}[~ LOGS RUN ...., ...... ~ . ~ . , ,. , . ,, ., . CASING RECORD (Report ail strings set in weld i 27. TUBING HELD[AD $C_:iiF_.~ ,51D, ] SIZE:see ..Atti I)EF'TH SET ¢5:D' iiPA'CI;'EN SF'T (?'IDIchad ..... tubin; 'de. ts. il. ACID. Si.CT. Fii~%Z'I CI:~, C-q .iEN'F SQU'-EZ". ETC. IN%ERVAL (.MD; [ A?,iOUNr AND I-~!.ND O!,' ?,IA1E.--'.iAL USED PIIODUCTION MEI!{OD ~Flowii~o% ~'.a3 lift, p;mptng--size and type of pump, Flowing O1L--}3DL. GA S--M C-"P. 5372 ~ 1%; ELL 5'I'A rUM i Producing or .{ P~oducing G;X~--AICF. %V.'JI'EIq.--BP.L. ] GAS-OIL II.%TIO 671.5 [ 46.3 {, 4014 !&'ATER--EBL. [ OIL Gt{AVITY-YkPI (CORIL) { 370 1 J/EST 33. I hereby certify that the foregoing and attached inf,,rmatiou is complete and correct as. ~'~}e~'~'lned' frot~ ~all-available recUrd.~ j i brea SIGNED' __ ' TITLE ~,n~neer DATE IEI--~-VA. TION$ iL)F, IiKI3, t~'i', Git, gl'C;' j17. ~.~v. CA$1NGIIE.a~D 186~ 9. WE. LL NO. SCU 12A-4 10. I-'i;.'-LJ.) A,ND POOL, O11 WILDCA. T Swanson River 11. SEC., T., R., 5I. tI$OTTO31 iiOL~: OB./IgCTIVE/ Sec. 4; T-7N, R-9W 12. PEIt.XlIT 74--21 A-028997 IS. UNIT,FAI~I OR' LK,I~P; NAME Soldotna Creek *; L1.'...\.,,I-: DYL~;G ,N ,%'Flt):,; :',..% D ~EI~[AL iNSTtt, UCTiONS General: This form is designed fOr submilting a complete and correct well completion report end leg on all types of lan:is and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- meats given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prcduction 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) and name (s) (if any) for only the interval rel)orted in item 30. Submit a separate report (page) on this form, adequately identified, for each additional inte, val to be separately' produced, show· ing the ack.titional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoul::l show the details of any mul-' tjple stage cementing and 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). 3,~. GIDOLOGIC i ,11 ,1 i i iii i ii / i , H1 10388 ' 10361 ' ~ 1. ' H2 10418' 10390' i H3 10450' 10421' , . I H5 10480' 10451' , ' ~8 10s34, 1050_ ) -- 11. i i i _J ,,~ ^~ x,~'r~c~'m, s,,,~w~ oP o,t,. c,^s o,~ w^~'~,. H 10 10657 ' 10623 ' - I II -; i ~ . Il . I I Il , . . i ifil ltl , 11 . ,, · · . . · . · . REPORT OF SUB-SUP, FAt]E DIRECTIOFJAL SURVEY STA!,TDAI~D OIL Oli' CALIFORNIA CO]T, PANY WELL ~,:SCU 12A-~.~ WELL NAME RIVER UN'IT FIEI,D LOCATION AL6?~F-D3 ~OB ~UMBER . SINGI,E o,tOT ..... TYPE SURVEY .?.2-74- DA'rE AUG .S 0 i9'/'4 DI¥iSIgN 07 0ii, A~']D CAS THIS IS A RECO[~D n ,.,F A SUB-SURFACE SURVEY 0F YOUR WELL We have retained a copy of your su,'vey repo~t in our files for your conve..ionce; howaw.~r, shouid you so desire, alt col'.,ics of the survey report will be forwarded ~.o you on writt~:n request. All surveys are kept in a locked-file and are held in stri(:~est confidence. AdcJitional copies of yr;ur survey report can t]~ reade from the original by any blueprint company. .. "' :,:,"b, 0~''' " "'-' ' . .-,.. C o ,...r CAL.,'. FOqi'.:'r,x ~ ','/0 ~ '-', r:.'-" '"" £D ~v zv -- -.T'IC' '~i;~...:~~ :.~m,,T RV:,.. -.. GREAT '"" .': ~ J ¢ ;,-,'~' ",~,~". ~i_ ,F'- '"/'AT [ 0"'; "~C1'. F" Dc''~., L ! iX/~ 'r I "% 2; "'"rrz'I'-".'=T-'.'OD- ~)F ~.v.,~'""~LJTAT~C,;%' :.~v ..... =o :¢., L~h:,DS~-.'"v, .... ~ ..... ............................................. ...................... ; ,--.,, .............. . ......................... . ,' .......... ............ ' ................................................ R:C''~n'OF SURV~:'v ~/" iL E .... ~" :' ':-' ..... "'; """ ...... ' " " ............. ._ : ..... .. ................................................. T~ L.~E ...... ....... -' 2 ,-'.-4 E L E C T iR 0 ?,~ i C "C Ot'::o u T E ~k _ TOTAL " '~1 ~j il,,,.;,.., 0, i(: '::', · 2. l · C C. 7i I ,4-2 i.71 2 ,, 16 :.,.', l ~. .- ~. L . D ': ! . ":'6 C L'O S .. -- .' tt ...... · './~, S u 3',: .-.: ~ ~ ":.:' i, '-'; 2. . ...... 2 '~ 9 ;-~.., .5'2. 5 · ~ ...... ~ .... ~ .*,~ ..... ~ ~ ......... .., 30 ..... 27v .91 ~57,,~.:-1 S 3 C .... iS Zg~9',gO 2 7 g' F.,., C,O $ ......,,~' ~30 ....... .., ,.., ,, .- c,: · "';3 .... 2 ~ .-.' :.'.," ~;':.."""",., ' o" .~ ..... .,~--. ?,;: ....... ,~ 1 ...z, e. o c, C ...... ~. .... ....... '. 99r. ,,c~0 .... ' ' - -' "' -'" - .., , -" '" C: ~ '~ ; "'"' ~-~':~.:)(~ .~..?';~..,, S 7' ....... ,"- ..... ~ ....... '~. 3 ~'-.;. 9 O. .... .S 1 '7 ~':, · 9 C .., -.- 7:,---~,~ .... ~&$,.~,~ . .:,,.'.:.,... . ? ..... C.- '~ ~ ..... .R 5 c: z, 3 5 -. ~ g .:... ; o- ~-.,: . ~ ~ .. :-: .... n-'~.-5. -'-:4F.gV0 ~ ....... P"~ ,;::.:9 ' .. , .-,:: .v: ;,~.,, ~ ~ ...... .~ .-.o...-'.... :., ,...c? .... . '"'"'3, L'5 ...... ,s.O..';9,.:_-, .:c..'J~-, .. $ S 5' W i '/, .3 6 w .... i (: o l i · . U q £ S 5 ',; :l ............................................ qECO'.~:~ ' CF S U.'~t" ;Z Y ' ............... A'LZ' CALC~jLAT,T, ON-S PERFOR,',"t~:'D c~Y ~ B ,~ ELEC~'~'''''' ...... ~ r,~.~ ~ C ................... ~ ~ ...... .... i .......... ~ ........ "~;q~FT'"V'E~'Ti'C~l. :-, .,_ ............. S~" ~;~l;.=T TOTAL COORDI~NAT~8 <'."A ~"S L~ ..... i;:_."-~ T~"' ................................. SEA D ~ ~ ~C' "' ................................... : DI:~. T A,'~ C :.' - ........ ~ ...... ;~ ....................... D~ S' ......... . ............... ........ ........ 1- ..... 0-'-~49;~'c'2'. - · ..... 52°;),S3... ..... ~'< .... 36 'vr 5.r~,,~., ;~'~ " ..... a"45" ~qq.~2 5~9F.62' N' 25 W ........ 6,21 ~,' ..... " ....... _n ....... ~"'n:ae,~O-,. .., 'bAcn,...,6,",~ N ~.,, ~'".. 7.69 ~x:, 75.2c-,. ,. "~,. '-- ' .... "~ ....... c~e 56 ......... 5c ........... '"1'2 E" .... ~ :~.02 ~'~ ..... 5~ ~9~ .... l"A'5 .....5 g~.~" 609F~/,5 - F~ 2D E ...... 17,90 ,"" ?'" 3 "('2~,~2 ~.~e~,42 .... "' ?6 ~ ~' 05 ',~ 2~' ~F, ~,' .. . ...... · . ,, .,. ,.. ~., ~ . : ..... ~ 15,~,59C.,:7. 639~:.,77 ..... ,,'~,O., ,--= 27.t.~.,, · ~'1 ~':', .tS '.,' ........ !'"45'?'6&=~. ..,22 '"Cag[~,22' N' ~2 [ ....... 3n..~... ' ~ ',~ ~6.a~.... ,,,. '" ~""~'~- _, -' 6~99.~6' fif;9~-....16. ;,"22 E':'- ' ~".~.q,?. ..~v. .~4.72 ~,'.' ,,~.'",.~ 6[g~.09 ~',le ;- .... ~" " ~: ',' ' '~"~= ..... ..... ~"g~'- ,0~ .... 70g~.O~,. ..... .'~"~3 E ..... .. ,'+~,O~:. "~ '" ";..g~ ~... !'16 ..... 7-g9.02' 7!9g,~2 i'i 46 ~' z,~,57 ~ t~.. 7~?.~,., . ' ,.. 4~., ... ,,~:~. .. . .. .'~, . ,. .... 2'5 .. .~. ..... .........~ C.~,,".- =',;'-~ 7=~7,91.,." ,";' l~ -~ '~'5'""~ .~; ,-~ , ..... -- ....................... . ............ , ,..... ................ , ............ .... ..... . , ..... ~ ..... . ....... ~ ..... .,.., .... , .......................... . ......................... , ,. ....... i ,.· ~., . i"; i:; I ,5 aC' ~ .~-I .p ': ., - "' ':'! 4.2 iff · . .'. 7 "' -'~- :'.': ':, ' . " -~+ ~:'. i ~' · .~'/. ,.~. .,.~ ~ .,, .. ,:~ -~ /". :.'".:~ :..2 ~, ~-~ · . ~:.. I '~' "' ": '~ 'i 'i '? ' .': I 5 · 9 o, .,,, ,o, . · ,.. .... ~ ; .; ~. ,';, [..~, ... -~ ~. ,'., -:., ,'. - . 1 F r.-:-T,. ,--? ,,-., OTHER ~.ATA .. -- ; ~~ ~ · .... "2A!L"?~:- VE~T. ~CAL S~..: :',~-tx/~., ' - Vr TTC~, ......... . ...................... .. ..... . _ '. ....... ~ 1 ..................... ~ '- e . ........ · .c~ .............~ ..... ~¢9'~.. ..... ~7 0 ........ ' : ........... ..... __..., ....... ~,~ .......... ~_ . ~. .... , -.--.-( ' ~3~'~ ~ t, I C"'C ~ " -- C: i ........... 4 4 C' i · -', 2,3 :) ......... ~, ~.i'a ................... ' .........-~' r~' ~ ~ ~ & ~ ................... ~ (; ~ r,~.. ~ t ~ ~ ~"~ .... 47C,~ '" 4VC1. aSO~, ,.- · '0 0 "'4eOf .................... ~C!.' -'4600, " 0 ........... "' ........ . .............. . ~ . . .; '. ~ ~ ,", . ....... 55 "" ~ ............... ~ '~'~ I, ..... . O · ....... 5 ~ '''~ ''~ () ......... ..... -:-;,,.. · ..~J' ..... '~ ~., ~:.. . . ~ rl .,, ........ ... :o[ ...... 5*'J~. ...... * 55~'~- ...................... ~ '2: ........... '.5 ? ~; [ ...........~[, 5600 . . . ~ ~ I"~ ~ g'l .................. =-;0!." 57C, r':. "'0 ........... (. · ~l 600!, 9gCO, .... ....... ~ ..................... ~'~9~ (:I~' "' "'2 " 62< ' ~ "7~I , g.. ...... ,' . ~ ,, ~ .., E~'~ ' ' A~ ~ .... ~ .... ........... f,~,O2. .......... ; ........6rC!. .... · 6~gS, ', ~' r' ~; . &~r. ............ L; ' ": ' ' ' '" ~.V:;2 ........ 6~'01- · r'5'~'~,., . ! '' {;" .............~ ~- ,"'., 2. .......... .... 6 ~ C, 'i. {, .~z ~' C, . I · . ~-.. 2 .................... ~.. ,....e.o" ~ , 671)(~. ~ ' '~ ..................... ,".. ...... " 7r'~2.-,:., .... ?OC1. ~..O,.", .... i '?" 0 ., ;.~ ,~.,~,, .......... ~*'' -770.~ ..... ~'~ .... ' ' ""'~ ................. -' ' ~'~'~ ..... ....... . .,..., .. ........ T C T ~ L i TOTAL ....... D ' ........ · . 17 9 .'-:', · 2 7 ~-: .6',. 37{.: '; ~ 7797. c: '? ;., 4. F £' :'. T -" 14 2O .3.5 · ,29 S :' ,, !9 ~:, '., ',,;.':' ¢.' ,.~ ,ia. S iv,r`'` · 3. g a.,, :.., :-. ", '~ · ?~, f',,: 1:4. - i7 ", 2", ,45 ;',:" iV~i"..,, ... HORIZONTAL VI,-ZW ....... " SC'ALE I''= .500' STA~'iDARD OIL COMPANY,OF CALIFORNIA - . , . scu ~-4 . '--- ." · , ._ -. ...... .... .t .......... i 2 4 0 0 - SCALE !":'.'i.300' · S'F/:'-,i.I'.'A!,..'~') O!L CO!dr .:\:.;Y CF 3200 3500 4000 44OO 4800 5200 5600 6C00 6400 680O 7200 7600 8000 8400 8800 92OO 9600 i0,000 ~ ! O, Fh3,) 1, TVD: !0,B42' TMD = I0,880' ~v. 9-3o-6: STATE OF ALASKA S~BMrr IN D~PL~CA~E . : ' B. API NUMER/CAL CODE C. ENG/ sas s0-z -z0z z-z0 JONT'HLY REPORT OF DRILLING , AND WORKOVER OPERATIONS A-028996 ~LL ~ZLL St~dard 0il Company of California, W0I ~ Sold0tna Creek --i-~-'~o~-"1 t P. 0. Box 7-839, ~chorage, ~aska 99510 SCU 12A-4 ' ~ n~T I , 4. LOCA~ON O~ ~ 1~. ~T~T.~ ~D P~L. O~ %VILDI~I .... 2130' South ~d 690' East of N.W. corner of Section 4; Sw~so~ ~ver iiI. SEC., T., T-7N, R-9W o~~ r F1L5~ ~ec. 4; T-7N, R-9W .... ~. P~IT 74-21 ]3. REPORT TOTAL DEP~/4 AT END OF MONTt{, CIiA/~GES IN HOLE SIZE, CASING A_N-D C~EN'I'ING JOBS INCLUDING DEPTH SET ~ VOLLrNIES USED, PEI{FORATIONS, TESTS ~ I~ESULTS, FlSttING JOB~. JLrIqK L~ HOLE ~D SIDE-TI~ACK~ HOLE AD A/~y O~/4ER SIGNIFICANT CIiAN~ES IN HOL~ CONDITIONS. June, 1974 Milled window in 7" casing 8618' to 8637'. Bridged 21" hole and'.7" casing from 8601' to 8639' with 114 cu. ft. of class "G" cement. Drilled 6" hole 8601 - 10,080' Ran Dual Induction lateral log, compensated sonic - caliper log, and compensated neutron formation density - gamma log. Cemented 2483' of 5" liner at 10880', top at 8397', with 500 sacks of class "G" cement. JLIL 1 ': i~74 t4. ! hereby certify ttmt the foregoing is true SIG1N-ED ~'~ l~.lq C[~1~ ~.~' DA'z'~I NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be file~ in duplicatt with the Division of Mines & Minerals by the 15th of the succeeding month, unless othen~tise directed. z~orm No. ~'--4 lC. (~'EOL ~V. 9-~7 STATE OF A~KA SgB~ ~ D~L[C~ ~. A~I N~SmC~ CODE OIL AND GAS CONSERVATION,, CO~I~EE ,,. 50-~33-~0~2~-~0 --[ MONTHLY REPORT OF DRILLING ~. ~ o~s~b,,~os ,~-~ s =~ ~e~N~.., AND WORKOVER OPERATIONS A-028996 ' '[--'~"'F,~x , , ,, ~',~ "' ~ P 0. BOX 7-839 ~chor~: A]a~ qq~ln SOU 12A-~ '~. LOCA~ON O~ W~ - ~ ~0. F~ ~ND P~L,' OR WZL] ~Ck~ u~r~ Sw~son ~ver I SEC 2130'-South ~d 690' East of N.W. co~er of Section 4; u, ssc..r..R..~.. T- 7N, R-9W. o~~ sec. ...... 12, P~IT NO. , , 13. RE~OI{T TOTAL DEI~/"rt AT E/~D OF MONTH, CliA~NGES IN HOLE SIZE, CASING A_N-D CElVlENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED, PEI{FOi{ATIObTS. TESTS ~ I~ESULTS. FISHING JOB~, JIFHK IN HOLE A_ND SIDE-TI~ACIiED HOLE ANT) A~qY O~TER SIGNIFICA/qT CIiA/~-GES IN HOL~ CONDITIONS. May 1974 Moved in rig to well SCU 12A-4. Circulated well full of 80 PCF mud. Installed and tested 10" - 5,000# BOPE. Recovered tubing leaving 22' of fishing tools and 129' of tubing fish including model F packer in hole from 10541 - 10,685'. Bridged 7" casing from 10,054' to 10,556' with 91 sacks of class "G" cement. Milled window in 7" casing from 8597' to 8618'. JUN 974 sxGwsn R. ,..}4. -McKinlev./7~~~'~z'///- Area Enainee.r DATI~ , NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed, Form P'3 S~abrn~t "Intentions" ill Trtplioate ' ~V. 9-~9 ~ "Su~quent ~epo~s" ~ Dupli~te STALE OF A~KA ~..~ N~c~ CO~E ."'2 OIL AND GAS CONSERVATION CO~IHE~ S~-~33-~0~03-01 sUNny NOTICES AND REPORTS ~ W~ A.028997 (Do not ~se this fo~ for proposals ~ di'iH or to deeDen Use "~CA~ON'FOR ~'E~k~~' ~or sucn-~o~o~a~:) J 5 ENG ...... o~ ~ ~,s ~ OT.~ ~LL ~LL =. NAtal OF OPZ~TOg ~. UN[%Fa~ OR g~S~ ~a~E I 3 GEOg'[ Standard Oil C~pany of Califomia~ WOI Soldotna Creek P. O. ~x 7-839, ~chorage, Alaska 99510 SCU.12A-4 [ 'SEC . ~-i 4. LOC~TION OF W~L 10. F~ ~D P~L, OE WI~CA ?'CONFEr: ~t~u~c~ 2130' S ~d 690' East from ~ corner Swanson ~ver FIkE: of Sec 4; T-7N, R-9W SB~ n. S~C..O~[vmT.. ~., ~.. (SO~m ~O~ SEC 4; T-7N, R-gw ( 201 ' KB ] 74-21 Check Appropriate Box To In~ica~ Niat'ure of N~ti'ce, Report, or Other NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT [ ] MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS iOther) SUBSEQUENT REPORT OF : WATER EHUT-OFF REPAIRING WELL .- FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING ABANDONMEIC, TS (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 an)' proposed work. Per telephone conversation 5/30/74 - H. Hamilton (DOG) & T. Biery (SOCO) revised ab~don- ment program approved verbally. Status: Tubing has been recovered to 10561' MD (near base of HB sand). Bad casing located in interval 10447-10557'. Unable to washover fish because of bad casing~;le}ft 20 feet of wash pipe in hole. Propose abondonment of well from presen~:'~th as follows: 1. Equalize cement plug from top of fish to 10189'. Downsqueeze at least 100 lineal feet of cement. 2' Locate top of cement. ~ '~[' ~ ~ ~.~4'-"~ with step No. If cement is below 10289' 10 of original prggram. · re cement. AND GAS (This space for State office use), CONDITIONS OF~'~PP~¥AL, iF ANY: DATE 5/ 31 /74 ,_~, See Instructions On Reverse Side DATE Approved Copy Returned Form REV. 9-30-6 9 Smbrnit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATIO'N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or .to. d, ecp,e.n use "APPLICATION'FO~{ P'EPJViiT--" 'for such proposals.) 1. WELL WELL OTHER 2. NAME OF oPERATOR Standard Oil Company of California, WOI 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 2130' South & 690' East from NW Corner Proj. Sec. 4, T.7N, R. 9W, SBa'vi DIR 'J 50-133-10103-01 A-028997 '-'--~-~-~-~-(~"~ ,.~ '~.IF INDIAI~, ALLOTTEE OR TRIBE NA ~SE NAME . Soldo~na C~eek 10. ~ ~D POOL, O~ WI~T : ~ver Sw on 11. SEC., T., R., M., (B~M HO~ O~E~IVE) Sec. 4; T-7N, R-9W ~~o. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 201" KB (KB is 15' above ground) 14. Check Appropriate Box To Indicate N, ature of NOtice, Re ~ort, or Other Data ' s~UBBEQUENT REPORT OF: NOTICE OF INTENTION TO: r '] lJ REPAIRING WELL TEST WATER SHUT-OFF i FRACTURE TREAT MULTIPLE COMPI,ETE FRACTURE TREATMENT --i ALTERING CASING ABANDON MEI~Ts SHOOT OR AClDIZE ABANDONS SHOOTING On ACIDIZINO REPAIR WELL CHANOE PLAYS (Other) (NOTE: Report results of multipls completion on Well tOther~ , , Completion or Reeompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. A. The proposed bottom hole location is changed from 350' Southwest to 350' due West of existing location. B. It is proposed to cement approximately 2600' of 5" 18# & 15# ~-80 liner in 6" hole. SIGNED TITLE Area Engineer CONDITIONS OF APPROVAL, IF i~: / See Instructions On Reverse Side DATE 5/29/74 Approved Copy , Returned, P. o. ~ '7~ - ~nchel~ge. Ai~ ~10 ~ Sir: Enclosed ts~ appllca~l for pemtt to dr111 the above referenced ell, it a-~ .~ h-~ detem at. a locatton tn Sectten 4, Tewnshtp 7N, k/ell ~les, core chtps, and a mud log are ~t required. A directional sur- vey ~ required. ~~ to eessatlon of dr1111ng operations a registered · su~ pla t ~-required, ~ ~vers tn Alaska and t~etr drat~ systems have been classtt'ted as tlmporteot ~ ~ ~~ o~.algratton of anadremous ffsh. Opet&ttons tn these, areas are sab..~t~.t to AS .16.50.870 and the .regulations promulgated ~here- uader (Tttle 5. Alaska Admlfllstrattve Code.). Prtor to coamenctng operations you nay ~ con.ted b~ the Habltat Coordtnator*s offtce, Department of Ftsh :~lals~tlve Code.,-~ter 70)~ ~ by the Federal Hater Pollutt -~, as ame~,,~ ~or-~-t~ c~ng operations you may be c..onTted by a represeUtattv, ~ the Department of Eqvtrewaental Conservation Very//truly Home~ L. ~il Alask& 0tl an~ G&s Conservatten Cematttee Enclosure cc: Department of Ftsh a~ Game, Habttat Sectton w/o eno1. Depart:meat ef Envlroamatal Conservation w/o encl. Oepartmen_' t of ~-Laber, Supervisor, Labor La~ Compliance OlvlSton wte eriC1. STATE OF ALASKA . , .. OIL.AND .GAS.CONSERVATION COMMITTEE' · - . .. .. PERMIT TO DRILL (DR . DEEPEN -.""- ' [:3 . b. TYPZ OF WELL W~LL O~HZ~ ZON su~."'.,. ~,PI .~ (or,; mstructions ..verse side) 2. NAME OF OPI/~.ATOR ' Standard 0il'Company of California, W0I iL ADDRIg&~ ~ OPERATOR P. 0. Box 7-839, Anchorage,-Alaska 99510 · .-O¢^TION oF WELL 2130' South arid. 6~K)'" East- from:Northeast corner At surface of-proj Sec 41 '~T 'TN~' R"<JW, .Seward At prol~sed prOd. zone ~ -. Approximately 350' .South,/est_ of-surface 13. I~ISTANCE 1N MILES AND DIRECTION FROM .NEAREST TOWN OR POST OFFICE' ApproXimately 16.5: miles., from 'Kenai BOND INFOR-MAT-I0. N: Typ~ation,,~de S.re~.,, a~d/o~ ~o. SL 6205.86'2 .... DISTANCE FROM PROPOSED' LOCATION TO NEAHEST -PROPERTY OR LEASE LINE. FT. IAt~o to nearest drip. unit, ii any)~ ' t 16. NO. OF ACR~ IN LEASE 1120 i~.P~OPOS~-,-i 11000' · $. A.P.I. # 50-133-10103-01 18. DISTANCE FROM PROPOSED LOCA'I'iON* TO NEAHEST WELL DRILLING. COMPLETIKD, OR APPLIED FOR. FT. 6. LEASE DESIGNATION A2FD SERIAL NO. A- 028996 ?. IF ~INDIAN. ,AJ.J.~D'~-r{~li; OR TRIBE NA2J~E $. UNIT~FARM OI-I LEA~E N.~,ME Soldotna Creek 9. WELL NO. SCU 12A-4 10 FIELD AND POOL. OR WILDCAT Swanson River Il. SEC.. T.. R.. M,. (BOTTOM HOLE OBJECTIVE~ 3ection ~; T-7N, R-gw A~o--, $150,000 NO. ACRES ASSIGNED TO THiS WELL 20. ROTARY OR CABLE TOOLS Rot~.r¥ ELEVATIONS (Show whether DF, RT. CH. etc.) 22. APPBOX. DATE WORK WILL START*' _~/lqlT~ 201' K.B. PROPOSED CASING AND CEMENTING PROGRAM SiZE O'F HCLE[' .sIzE-o~SINO ~'E~qHT PER rOOT GRANDE SET'rING DEPTH 4uantit¥ of cement ' ~ existin~ 10 S~ 12-4 . ', ' ... . '-i ! ..... ~ ~ .... ' -. --~ . ' ' ' ' -- " ' t,. , . ,,/ We propose as per attached program. MAY 9 I974 DIVISION OF OIL C-AS 4NCfi~RAII, e." " 1'~ ABO%~ SPA~ D~IBE ~OPOSD PR~R.~: If p~t is to dee~n 'give~ on present p~u~ive zone a~'~ pro~m~ new pro'duO,ye zone. Ii ~1'~i Is W drll~ 'or a~n dwec%ionaily, give Pertinent ~b~' on sgbsu~a~ ~t~ ~d meas~d and ~ue ve~ical depC-~x~ Gi%~-biSwou[ p~eve~ter program. 24. i here~y c~r~:.~ that :he ForegoLug'l_~Trde arl/t Correc~ [] v~ { SEE TRANSMITTAL LETTER 5/20/74 · - Field:' Swanson River Proper.ty an0 Well: -~ ~- "i: -:~' "'-- " Surface Location: 2130':~ South and 690." East of the NW corner of Section 4; ~T7N,. R9W, SB&M. -?0tal .Depth: 10,974' Plu~: 10,969' - 10,929' ' ' - ..... 'Effective DePth,: 10,782' top of fish (see below) on 9-29-69 ~ !: -- ' Casing: 22" cemented at 29' '" - · . .-....:.. . 7" cemented at 10,969' as follows: Next.18 Joints - - 339.50' -1102.81' 26#, N-80, BT Next .88' Joints ":- 1102.81' - 4872.33' 23#, N-80, BT ' -6718.96' 26#, N-80, BT . , Next. 43 Joints - - 4872.33" - ' Bottom 103 Joints " 6718.96' - 10984.01' 29#, P-110, L8R · ' -- :Note: 'Top joint cut off 14.35', leaving, shoe at 10,969.66' ' - 262 , ,E .log .depth. 13' marker joint _1.0~,249' 10.,.. ' Perforations: per foot . 5 - 1/2" holes at 10,339' (WSO) 4 - 1/2" holes as follows: 10,343' - 10,371'; 10,383' - 10,397'; 10,418' - 10,430'; 10,439'- 10,475'; 10,482' - 10,496'; 10,504'-10,579'-, 10,589' - 10,605,;-and 10,622' - 10,701'. The interval 10,664' - 10,679' was reperforated with 4 - 1/2" holes Junk: .Fish in hole as follows: (top) 2 3/8" tubing pup 4' long, 2 3/8" "D" nipple 1' long, and 2 3/8" tubing joint 16' long. The tubing pup joint looking up parted in the pin area. Top of the fish is 10,782' or lower. Fish left in hole in 1969 and is below present tubing shoe. Tubing Detail: Per attached detail. Present ?-~echanical Condi'~.!?~_~_- Tubing is parted and offset at +_10,56i', wir~line depth. Impression block gave picture of 2 7/8" collar looking uF- fron below the part. Description of tubing below the part is on thc attached detail. Due to inaccuracy with wireliue measurements, it is unclear if part is above or below Camco ~'¢k'.I Mandrel at 10,567'. HAY 9 I974 " i~ W ~ Proposal ell ~rations PRO 316-1 RewOrk Program Blowout Prevention: Considerations: - 1, Potential Problems ~. Gas · Gas mgy be .encountered after Packers are released, while fishing, cleaning out the 7" casing prior to abandonment and while ' '~ ~ - redrilling.- Care must be exercised at all times not to swab the well during trips or when pulling prOduction equipment. This well is high gas-oil ratio, and gas entries will most probably . - occur within the Hemlock Zone. Hemlock formation pressure could be near 5000 psig. The programmed mud weight of 74 psig prior tO'redrilting the' well will overbalance the potential reservoir pressure:of. 5000 psig by 300 psig'~ .. . -'~"~' B, wa'ter~ Entries ' - - - _..~/-_ ' . ,. Extreme caution must ben-exercised while redrilling this well. A ~ mudweight of~96-98 pcf is required to overbalance potential , .. :. ~ high pressure entries while redrilling the'~ell above the Hemlock. - This well was originally drilled with 96-98 pcf mud without · problems. .. . - _" ' .'. 'C. Lost Circulation The programmedmud weight of 96-98 pcf is the lowest which can be used to.maintain an adequate pressure overbalance on the interval above the Hemlock. Howe'~r, because of lower forma- tion pressure in the Hemlock, lost circulation could occur. While drilling well SCU 42-5 in the Hemlock No. 8 sand with 96-98 pcf mud, lost circulation did in fact occur. As a result, it was necessary to redrill a portion - of 42-5. - . :'~ D.' Precautions Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods and care should be exercised a~ all times ~y every crew member. The hole must be kept full at all times. 3. ~4aximum Possible Surface Pressure: 4000 psig 4. Blowout Prevention Eauit~ment M, Y 9 I974 A. As per "Operating Instructions D-17." B. Class III, ]0" - 5000 psig for all work. Datum: _'~.ke all mea.~.urc.,en..s from a point 15' above ground level, the original K.B. elevation for SCU 12-4. Proposal for Well Operations PRO 316-1 Rework Program '~ ' . .. 1. Prior t° rigging up,~ pull CEV'~ from mandrels at 10,354' and 10,435'. Check casing, casing annulus for pressure.. · · 2. Move.in.rig and mix 74-76 pcf mud. 3.~ Kill well by.disPlacing mud down the tubing out the mandrel at 10,354' _ and.up the tubing-casing annulus. Install Cosasco back pressure valve, and remove the xmas tree. -. 5, Nipple up 10" - 5000 psig BOPE ~ncluding 5000 psig blow and kill ' ..... ~ lines. 'Refer to attached BOPE detail. Pressure test all BOPE and -~'"~ ~ ~ ~-'~'-'' manifolds to 5000 psig per "Operating Instructions D-17." Remove .... .~ Cosasco Plug. . 6.- - Release. packers at~10,396' and 10,496' and pull production equipment ' ' from above parted tubing at 10,561'· Examine production equipment for damage .and notedepth of damaged tubing. Pull tubing slowly to ~i.i. ~ '~..' '-' .'~ mi~mize~any swabbing. 7. 'Recover ~tubing an~ mill ower and ~rauover .Baker model "F" packer at --" 10,613', Clean.out to below the bottom perforation at 10,701'. .. 8. Equalize cement plug in stages, 'if necessary, from effective depth to 10,189' or above. Downsqueeze 100 lineal feet of cement. 9. Run bit and locate the top of the cement plug. If plug is below 10,289', recem~ent. Division of Oil and Gas add USGS to witness the location and hardness of the final plug. - 10. Pressure test the 7" casing to 3000 psig (rig pumps) for 15 minutes. . 11. Condition mud to 96-98 pcf. 12. Mill a 40'. window in the 7" 29# P-110 casing from 8600' to 8640' , , · Casing collars are located at 8566', 8610', and 8654'. 13. Plug the 40' window and 7" casing with'densified Class "G" cement (126,129 pcf). Top of plug is to be +150' above the top of the window. Do~nsqueeze, leaving top of plug +50' above top of window. 14. Drill out cem~ent plug to 2' below top of window. · 15. Sidetrack original hole and directionally redrill 6" hole to a total depth of 11,000'. A directional plat will' be furnished, but .target. is the Hcmlock NO. 9 sand deviated 350' from present bottom hole MAY 9 'i974 " Proposal ~or Well operations PRO 316-1 · - Rework Program ~ Note:-Continually moniter mudsystemfor either high pressure fluid 'k:·-/~kl?- entries-or iostcirculation. Lo.st circulation is most apt to occur below.the top. of the. Hemlock at 10,340'. 16' AtT.D.,-condition mud.,for logs.·-~ Obtain a 1/2 gallon sample of dril- - ling fluid'before pulling out of the hole. :'~17'-. RunSChlUmberger Dual Induction Laterolog with SP, Micro'log, BHC :-- Sonic with SP, and~Compensated Neutron - Density Log ~from T.D. to ~ the 7"casing.~ Have dipmeter on location. '~A. Use linear scale for 2" DIL and logar~thm±c scale for 5" DIL. B. Use + 10 MV'SP scale and 0-50 ohm-meters for the linear DIL. '18i .Cement'apprOximatelY'2600' of 5" liner at total depth with sufficient .... Class "G" cement premixedwith 3/4% CFR-2 to obtain returns above top - ' - of liner. EqUip liner with 5" x ~", 29~ Burns liner hanger grooved for cementing. Allow for 200' of liner lap. ~.' A. Run-float collar and float shoe. Float collar is to be one ..' joint above shoe. B. :Liner ·detail to be ,provided at a later date. . . ~9.'~ Clean out cement to float collar. 20. Run variable density Cement bond - neutron - collar log from effective - depth to above top of-liner hanger. 21. Pressure test 7" casing, 5" x 7" lap and 5" liner to 3000 psig for 15 minutes. 22. 'Condition mud weight to 74-76 pcf. '. 23. Jet perforate selected Hemlock sand intervals for production. 24. Run tandem 5" casing scrapers and scrape the entire 5" liner. 25. Run-and hydrotest to 5000 psig 2 7/8" x 2 3/8" tubing, gas lift mandrels, and completion jewelry. A d~tailed completion program will be provided after T.D. logs have been run. 26. Remove BOPE and install xmas tree. Pressure test tree to 5000 psig. Displace.drilling fluid down the annulus and up the tubing with lease crude oil. 27. Set production packers and release rig. .Place well on production as directed. 9 I974 W. R. Tinker Iit SWANSON RIVER FIELD DRILLING FLUID PROGRAM REWORK -~" ...... ~-~ .... BAsic DRILLING FLUID SYSTEM Medium treated~Lignosulfonate mud. IN 7" AND 5" Weight - Pcf Viscosity- sec/qt.~, API Fl'aid l./oss - cc, /LPI Plastic. viscosity - CPS Yield point - Lb/100 ft2 Gel ~ Lb/100 ft2_ 10 min Calcium '-. PPM Solids content- % Vol 'OPTIMUM DRILLING FLUID PROPERTIES 74 '. 76 ' 43 - .47 .4 - 7 10- 14 8 - 12 0- 5 9.5 50 ma~. 6 10 WHILE REDRILLING 96- 98 43 - 47 ~ - 10 See 4 20- 30 8 - 12 10 max. 8.5 - 10 50 max. 10- 18 . 1. Limit dry jobs t° '20 'sacks of barite or as directed by Drilling .. - . Foreman. 2. Maintain adequate Supply 6f barite and LCM on location. · ' 3. During milling and redrilling operations continually monitor . (on 24-hour basis) mud system for evidence of high pressure water entry. BE PREPARED TO SHUT h~ELL IN AND RAISE WEIGHT. . . 4. Maintain fluid loss~'between 4'-and 7 cc below the top of the PROPOSAL FOR WELL OPERATIONS PRO 316-1 REWORK PROGRAM Field: Swanson River Property and Well: ~CU 12 4 Surface Location: 2130' South and 690' East of the NW corner of Section 4; T7N, R9W, SB&M. Total Depth: 10,974' Plugs: 10,969' - 10,929' Effective Depth: 10,782'.top of fish (see below) on 9-29-69 Casin~: 22" cemented at 29' 13 3/8" cemented at 2024' . . 7" cemented at 10,969' as follows: Depth Top 8 Joints Next 18 Joints Next 88 Joints Next 43 Joints Bottom 103'Joints 0 - 339.50' 339.50' - 1102.81' 1102.81' - 4872.33' 4872.33' - 6718.96' 6718.96' - 10984.01' 29#, N-80, BT 26#, N-80, BT 23#, N-80, BT 26#, N-80, BT 29#, P-110, L8R N°te: T°P j°int cut °fl 14'35'' leaving sh°e at 10'9~6~'~ E' r 13 ma ker joint 10,249' - 10,262', E .log depth. Perforations: MAY 9 I974 5 - 1/2" holes at 10,339' (~SO) 4 - 1/2" holes as follows: 10,343' - 10,371'; 10,383' - 10,397'; 10,418' - 10,430'; 10,439' - 10,475'; 10,482' - 10,496'; 10,504' - 10,579'; 10,589' - 10,605'; and 10,622' - 10,701'. The interval 10,664' - 10,679' was reperforated with 4 - 1/2" holes per foot. Junk: Fish in hole as follows: (top) 2 3/8" tubing pup 4' long, 2 3/8" "D" nipple 1' long, and 2 3/8" tubing joint 16' long. The tubing pup joint looking up parted in the pin area. Top of the fish is 10,782' or lower. Fish left in hole in 1969 and is below present tubing shoe. Tubing Detail: Per attached detail. Present Mechanical Condition: Tubing is parted and offset at +10,561', wireline depth. Impression block gave picture of 2 7/8" collar looking up fron below the part. Description of tubing below the part is on the attached detail. Due to inaccuracy with wireline measurements, it is unclear if part is above or below Camco ~M Mandrel at 10,567'. Proposal for Well ~3erations PRO 316-1 Rework Program Blowout Prevention Considerations: 1. Potential problems A. Gas -- Gas mgy be encountered after packers are released, while fishing, cleaning out the 7" casing prior to abandonment and while redrilling. Care must be exercised at all times not to swab the well during trips or when pulling production equipment. This well is high gas-oil ratio, and gas entries will most probably occur within the Hemlock Zone. Hemlock formation pressure could be near 5000 psig. The programmed mud weight of 74 psig prior to redr±lling the well will overbalance the potential reservoir pressure of 5000 psig by 300 psig. B. Water Entries Extreme caution must be exercised while redrilling this well. A mud weight of 96-98 pcf is required to overbalance potential high pressure entries while redrilling the well above the Hemlock. This well was originally drilled with 96-98 pcf mud without problems. C. Lost Circulation The programmed mud weight of 96-98 pcf is the lowest which can be used to maintain an adequate pressure overbalance on the interval above the Hemlock. However, because of lower forma- tion pressure in the Hemlock, lost circulation could occur. While drilling well SCU 42-5 in the Hemlock No. 8 sand with 96-98 pcf mud, lost circulation did in fact occur. As a result, it was necessary to redrill a portion of 42-5. D. Precautions Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods and care should be exercised a~ all times ~y every crew member. The hole must be kept full at all times. . 2. Maximum Anticipated Formation Pressure: 5000 psig in the Hemlock 3. Maximum Possible Surface Pressure: 4000 psig 4. Blowout Prevention EqUipment A. As per "Operating Instructions D-17." B. Class III, 10" - 5000 psig for all work. Datum: Take all measurements from a point 15' original K.B. elevation for SCU 12-4. above g~n~ l~v~ ,~ t~e ~ MAY 9 I974 Proposal for Well Operations PRO 316-1 Rework Program PROGRAM 1. Prior to rigging up, pull CEV's from mandrels at 10,354' and 10,435'. Check casing-casing annulus for pressure. · 2. Move in rig and mix 74-76 pcf mud. 3. Kill well by displacing mud down the tubing out the mandrel at 10,354' and up the tubing-casing annulus. 4. Install Cosasco back pressure valve and remove the xmas tree. · . 5. Nipple up 10" - 5000 psig BOPE including 5000 psig blow and kill lines. Refer to attached BOPE detail. Pressure test all BOPE and manifolds to 5000 psig per "Operating Instructions D-17." Remove Cosasco plug. 6. Release packers at 10,396' and 10,496' and pull production equipment from above parted tubing at 10,561'. Examine production equipment for damage and note depth of damaged tubing. Pull tubing slowly to minimize any swabbing. 7. Recover-tubing and mill. over and recover Baker model "F" packer at 10,613'. Clean out to below the bottom perforation at 10,701'. 8. Equalize cement plug in stages, if necessary, from effective depth to 10,189' or above. Downsqueeze 100 lineal feet of cement. 9. Run bit and locate the top of the cement plug. If plug is below 10,289', recem~ent. Division of Oil and Gas and USGS to witness the location and hardness of the final plug. 10. Pressure test the 7" casing to 3000 psig (rig pumps) for 15 minutes. 11. Condition mud to 96-98 pcf. 12. Mill a 40' window in the 7", 29#, P-110 casing from 8600' to 8640'. Casing collars are located at 8566', 8610', and 8654'. 13. Plug the 40' window and 7" casing with densified Class "G" cement (126-129 pcf). Top of plug is to be +150' above the top of the window. Downsqueeze, leaving top of plug +50' above top of window. 14. Drill out cement plug to 2' below top of window. 15. .Sidetrack original hole and directionally redrill 6" hole to a total depth of 11,000'. A directional plat will be furnished, but target is the Hemlock No. 9 sand deviated 350' from present bottom hole location along a S45°W course. MAY 9 I974 · Proposal for Well Operations PRO 316-1 Rework Program Note: Continually moniter mud. system for either high pressure fluid entries or lost circulation. Lost circulation is most apt to occur below the top of the Hemlock at 10,340'. 16. At T.D., condition mud for logs. Obtain a 1/2 gallon sample of dril- ling fluid'before pulling out of the hole. 17. Run Schlumberger Dual Induction Laterolog with SP, Microlog, BHC Sonic with. SP, and Compensated Neutron - Density Log from T.D. to the 7" casing. Have dipmeter on location. A. Use linear scale for 2" DIL and logarithmic scale for 5" DIL. · B. Use + 10 MV SP scale and 0-50 ohm-meters for the linear DIL. 18. Cement 'approximately 2600' of 5" liner at total depth with sufficient CZass "G" cement premixed with 3/4% CFR-2 to obtain returns above top of liner. Equip· liner with 5" x 7", 29~ Burns liner hanger· grooved for cementing. Allow for 200' of liner lap. A. Run float collar and float shoe. Float collar is to be one joint above shoe. B. Liner detail to be provided at a later date. 19. Clean out cement to float collar. 20. Run variable density cement bond - neutron - collar log from effective depth to above top of liner hanger. 21. .Pressure test 7" casing, 5" x 7" lap and 5" liner to 3000 psig for 15 minutes. 22. Condition mud weight to 74-76 pcf. 23. Jet perforate selected Hemlock sand intervals for production. 24. Run tandem 5" casing scrapers and scrape the entire 5" liner. 25. Run and hydrotest to 5000 psig 2 7/8" x 2 3/8" tubing, gas lift mandrels, and completion jewelry. A detailed completion program will be provided after T.D. logs have been run. 26. Remove BOPE and install xmas tree. Pressure test tree to 5000 psig. Displace drilling fluid down the annulus and up the tubing with lease crude oil. 27. Set production packers and release rig. directed. 'Place wel~n~r~d~ti~ ~ ~ 9 'i§74 W. R. Tinker III B ¥[$t0N OF OIL AND GAS DRILLING FLUID PROGRAM REWORK SCU 12-4 SWANSON RIVER FIELD BASIC DRILLING FLUID SYSTEM Medium treated Lignosulfonate mud. OPTIMUM DRILLING FLUID PROPERTIES PROPERTY Weight - pcf Viscosity - sec/qt., API Fluid Doss - cc, API Plastic viscos±ty - CPS Yield point - Lb/100 ft2 Gel - Lb/100 ft2 - 10 min pH Calcium - PPM Solids content - % Vol IN 7" AND 5" WHILE REDRILLING 74 - 76 96 -98 43 - 47 43 - 47 4 - 7 7 - 10 See 4 10 - 14 20 - 3Q 8 - 12 8 - 12 0 - 5 10 max. 9.5 8.5 - 10 50 max. 50 max. 6 - 10 10 - 18 1. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 2. Maintain adequate supply 6f ~arite and LCM on location. 3. During milling and redrilling operations continually monitor (on 24-hour basis) mud system for evidence of high pressure water entry. BE PREPARED TO SHUT WELL IN AND RAISE WEIGHT. 4. Maintain fluid loss between 4 and 7 cc below the top of the Hemlock. MAY 9 974 Lease & Well No. ~C~4 CHECK LIST FOR NEW WELL PERMITS yes No Remarks 1. Is well to be located in a defined pool ................. ~' e · Do statewide rules apply ........................ Is a registered survey plat attached. . . . . . . Is well located proper distance from property line ~'.i~i 16. Will surface csg. internal burst equa.1 .5 psi/ft, to next string .... !/~'~ 17. Will all casing give adequate safety in collapse and tension ...... ~ ts well located proper' distance from other wells ............ 6. Is sufficient undedicated acreage available in this pool ........ _ , 7.~ Is well to be deviated ......................... '8 Is operator the only affected party ~ ~ · · · · · · · · · · · · i 9. Can pem~it be approved before ten-day wait ...... ~ ........ l0 Does op~, ator have a bond in force . ill. IEs conduc~.or string provided ..................... · i~.12, Is enough c. eme~t used to circulate on conductor and surface 14, W~ll cement: cover a.ll possible productive horizons ............ " Will surface casing cover all fresh water zones ............ 18, Does BOP[ have sufficient pressure rating ...... - .........