belmont island removal and field revitalization · belmont island removal and field revitalization...
TRANSCRIPT
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OUTLINE
• Belmont Background and History• New Contracts• Belmont Development Plan• Drilling Results -1st Well• Drilling Challenges and Solutions• Redevelopment – Upper, Lower Zones• Belmont Redevelopment Recap• Overview and Opportunities
California State Lands Commission Prevention First 2006Belmont Island Removal and Field Revitalization
Aerial View during Island Removal Activity
Los Angeles
LBU
Belmont
Belmont Island Removal and Field Revitalization
• Located 8,100 feet offshore Seal Beach, CA in 42 feet of water depth
• Construction completed in 1962
• Oil production ceased 1995. 28 million barrels of oil and 24 billion cubic feet of natural gas. The State $40M revenue and the operation grossed over $240M
• All wells abandoned by 1996
• Complete removal of the platform structure was accomplished in 2002.
Belmont Island Background/History
Belmont Island Removal Activities• Wells Plugged and Abandoned• Cut and Prepare Well Conductors• Decommission Electrical Cable• Decommission Pipelines• Remove South Span and South Tower• Remove Caisson Deck and Wall Structures• Remove Hydrocarbon-Impacted Fill, Well Conductors and Wooden
Piles• Remove East Wharf• Remove Boat Landing• Remove Strut Supports- West Face• Remove North Wharf• Remove Caisson and Rip-Rap• Debris Recovery
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1947 1957 1967 1977 1987 1997 2007
BPD Oil
Injection
Water
Producers
Injectors
Belmont Upper (Ranger) Performance
Oil Prod: 789 BOPDWater Prod: 4150 BWPDWater cut: 84 %WOR: 5Water Inj: 2843 BWIPDProducers: 3Injectors: 2
Pipeline restricted
Storm destroyed island
Waterflood
Belmont Contracts
Three Contracts• Oil and Gas Lease Between OLBI and State of California
• Facilities Agreement Between OLBI and City of Long Beach
• Pass-Through Agreement Between OLBI and City of Long Beach
Key Terms• State receives 17.9% royalty
• City of Long Beach receives 2.5% “Pass-thru”
Belmont Offshore Redevelopment
-2500 -3000 -3500
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IslandChaffee
MontereyIsland
EstherIslandEastern Boundary
of the Long BeachUnit
State PRC 186
State 3095(Operated by DCOR)
City of Seal Beach
Extent of Ranger OilColumn
One Mile
3-D View of Long Beach Unit & Belmont Offshore Field Wellpaths
Pier J
Grissom White
Chaffee
Belmont
Freeman
ISLAND CHAFFEE
Island ChaffeeSpill Prevention Equipment and Containment
Equipment Type Quantity
• Oil boom (30” Expandi 3000) 1000 ft• Oil boom (16” foam filled) 900 ft• Anchors 4• Crew and tug boats available on call• Vacuum Truck 1• Sorbent pads 75 bales• Sorbent blankets 15 rolls• Sorbent drums (55 gal) 25
• 12” curb height• 54” cellar walls• 7 cellars – 23,000 barrel capacity
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Phase 1 Producer
Phase 2 Producer
Phase 2 Injector
Existing LBU Injector
Original Belmont Development Plan
Drill in low WOR area
Offset good rate wells
Peripheral injection
C332A
C-332rd1 Open Hole Log (M1 Sand)
RESISTIVITY
POROSITYGAMMA RAY
Flow Unit Boundary
2 Oil Columns with Partial Sweep at Base
C-332rd1First Producer • ‘Standard LBU vertical’ (50o)
redrilled OHGP completion (7”intermediate casing & 3-1/2” WWS)
• 73o sail section for 4300’• 500’ completion interval• Running casing was difficult• Initial oil rate 450 bopd• Reservoir pressure higher than
expected• Repressurization after 10 years• Higher rates, recoveries, fewer
wells needed
Drilling Challenges
• Must deal with anti-collision (LBU & P&A’d Belmont wells)• Maintain high penetration rates & drill high quality hole• Minimize tripping for bits & logging tools• Overcome torque & drag effects on drilling/running casing
– Long reach, high angle sail sections (almost 5000’ to the near lease line, 8000’ to the far lease line)
– Slide drilling is required in horizontal completion intervals & to drop angle at the end of the injectors
– Casing must get to bottom• Geological interpretation is critical
More difficult with directional survey depth uncertainty
Drilling Solutions
• Anti-collision Issues, Geological Interpretation:– Generated Belmont directional survey data base
from scratch• Drilling Performance (ROP, Minimizing Roundtrips):
– Used a steerable 5 blade Smith PDC bit, Top drive on 4th well and wells after
– Drilled surface shoe with directional assy & LWD built angle
– Used KCl/gelite mud (clay swelling) & high circ rate
Drilling Solutions (cont’d)• Torque and drag effects while drilling:
– Chose wellheads that allowed two dimensional well plans to be drilled, when targets allowed
– Modeled with torque & drag software– Set surface casing through the build section– Maximized rotational drilling– Adjusted BHL’s to minimize “late turns”
• Torque and drag effects while running casing: – Spotted lube pills prior to running casing– Stopped and circulated when running casing– Drilled larger hole in two wells (9-7/8” vs. 8-3/4”)
Belmont Field: Top M1 Structure Current Status
C-332A
C-232
C-237I
C-234I
C-230IC-301
C-247
Possible injector
C-236 Drilling
Redrillinjector
C-332A
SW NE
SW
NE
LOCATOR MAP: Structure Top M1
Plan for Sub-Horizontal Wells C-301st1, C247st1
Change of Plans (horizontal producers)Upper Zone Cross-Section showing three M1 sand lobes
C-301st1 & C-247st1Horizontal Producers
• Drilling horizontal OHGP producers has allowed:– longer completion intervals (1000’ to 1300’)– production from all three M1 sand lobes– oil rates to be accelerated– fewer wells to be drilled
• These are ‘Standard LBU horizontal’ new OHGP completions (7”intermediate casing & 3-1/2” wire wrapped screens)
• Completion angles are 82o to 85o
• Landing these horizontals was difficult because they needed to be ‘turned’ into the structure
• C-301st1 drilled fast, but had 3 tool failures & OH sidetrack • C-247st1 had great drilling performance, in spite of sidetrack• Oil rates were 300 bopd (C-301st1) & 800 bopd (C-247st1)
C-332rd1, C-301st1, C-247st1 Wellpaths
C-332rd1
C-301st1
C-247st1
MTS-116P&A’d
MTS-122P&A’d
MTS-114P&A’d
C-230I, C-234I, C-237IWater Injection Wells
• All are down dip water injectors on the far side of the lease • All have high angle sail sections (C-237I had 6300’ at > 70o)• All are long reach (C-237I had a 2.6:1 ratio of md/tvd)• Drilled “two dimensional” well plans from optimal wellheads• Decided to drill 9-7/8” hole in C-237I to decrease risk• Excellent drilling performance
Two Dimensional Well Plans
C-234I C-230IC-237I
Lower Zone (UP Ford) Drilling Status
• The Lower Zone producers will be completed as cased hole frac & fracpack completions
• Wells C-238 and C-354 were drilled and completed into the Lower Zone in June 2006
• Two injection wells are planned for this year
• Phase II and III Development to proceed and be evaluated based on results from first two producers and injectors.
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-5400
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C-239C-239
C-318C-318AC-318B
C-323
C-323IA
C-326C-326
C-339C-339A
C-357I
C-358C-403
403A403A
C-410B
C-440
-441441S
C-442
43IA
C-444C-444IS
C-447
C-448
MTS-13
MTS-14
MTS-15
MTS-16
MTS-17
MTS-18
MTS-19MTS-19
MTS-2
MTS-20
MTS-21
MTS-23
MTS-25OH
MTS-26
MTS-27
MTS-27A
MTS-28
MTS-29
MTS-3
MTS-4
MTS-6
MTS-7
MTS-9
4247000 4248000 4249000 4250000 4251000 4252000
4247000 4248000 4249000 4250000 4251000 4252000
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40100004011000
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[ft]
[ft]
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1:10732
Country
Block
License
Model name
Horizon name
Contour inc
User name
Date
SignatureCopy of UPF fault edit
50
morsem
01/23/2006
MJ MORSE
Map
UP Ford Belmont Area (AK1 Level)
MTS-24
MTS-5
MTS-10
MTS-22MTS-8
MTS-11
C-431IA C-354
C-238
CUFBELI1
CUFBELI2
Key
Last 6 active wells
Phase II
Phase III
Phase I
Belmont Drilling Program
230$1.13374’7554’July-06NOHGPUpperC-232
380$2.16378'9054'June -06NCH4FLowerC-354
90$2.06281'8978'June -06NCH4FLowerC-238
inj$1.03530'9153'July-06NCHSIUpperC-237I
inj$1.13490'8590'Feb-06NCHSIUpperC-234I
inj$0.93490'8114'Dec-05NCHSIUpperC-230I
800$1.13238'7583'Nov-05NOHGPHUpperC-247st1
300$1.23171'8060'Sep-05NOHGPHUpperC-301st1
450$1.53333'7365'Jun-05ROHWGPUpperC-332A
IPbopd
ActualCost, $M
TDtvd
TDmd
Compl.Date
WellTypeZone
WellNumber
Belmont Redevelopment Recap
• Six producing wells and three injection wells• Oil production is 240 MBO in less than 1 year• Current Oil Rate 1456 BOPD for August 2006 • Drilling performance is improving
– Best performance drilling production hole (1249 fpd)– Beat estimate by 7.5 drilling rig days (4 days < target)
• C-301st1 is longest horizontal from Islands (8060’ md)• Actual costs are 4% below estimate. Average drilling
rig time is 3.5 days below estimate (without C-332rd1)
Overview• Recovery of substantial oil reserves left behind• Oil Island and associated facilities removed• Oil spill risk minimized by transferring operation to state
of the art facility• Increased revenues to the State and City of Long Beach
Opportunities
•Develop unrecovered reserves using existing infrastructure•Develop new areas from existing offshore infrastructure or sites based onshore
Acknowledgements
• Belmont’s success is a team effort. The team includes:– Oxy Long Beach Inc. (OLBI) and Thums
Drilling Engineers, Reservoir Engineers, Geologists, and Drill Site Managers
– California State Lands Commission– Long Beach Gas and Oil Department– Ensign Drilling Crews– Inteq Planners and Directional Drillers – MI Drilling Fluids
Questions?
[email protected] (562) 590-5266