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Collaborating Authors
Summerland Field
The history of California's oil business is long and checkered. The first Californian well was drilled in 1865 in Humboldt County (Am. The state's first gusher arrived in 1876 in the Pico Canyon oil field located north of Los Angeles and launched a statewide industry (Figure 1A) (oilindependents.org). The early success led to a drilling rush, which spawned supporting industries such as pipeline construction (California's first was built in 1877) and crude oil refining (California's first refinery opened in 1880) (AOGHS, 2019). Following the initial oil discovery in California, Edward L. Doheny struck the massive Los Angeles oilfield in 1892, only 35 miles south of the Pico Canyon (Figure 1B) (oilindependents.org,
- Geology > Geological Subdiscipline (0.70)
- Geology > Rock Type > Sedimentary Rock (0.51)
- Geology > Petroleum Play Type > Unconventional Play (0.48)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- South America > Brazil > Parnaiba Basin > Block PN-T-68 > California Field (0.99)
- North America > United States > California > Santa Barbara Basin > Summerland Field (0.99)
- North America > United States > California > Pico Canyon Field (0.99)
- (8 more...)
Lack of adequate policies and hotly debated topic. This with the drilling of wells from piers set off and techniques for abandonment and decommissioning most recently involved the central California coast. Many of these decommissioning during that time is creating four offshore platforms, a pier, and an wells were drilled before regulations concerning a problem even today because of the island in state waters. It also involved the drilling and abandonment were as potential for oil to leak from improperly abandonment of more than 23 subsea comprehensive as they are today. The first plugged wells and because of debris left wells and associated debris off the Santa offshore field in the United States was at on the ocean floor.
Abstract Pacific Operators Offshore Inc. (POOI) as the operator of 3 leases within the Carpinteria field participated in two projects with the DOE that supported the planning and implementation of the Offshore Carpinteria Field redevelopment. The first was the Advanced Reservoir Management (ARM) Project, which used 3-D modeling and simulation to better identify target intervals for redevelopment. During the ARM project a 19 well workover program was initiated. The ARM project directly supported the second undertaking, a Class III field demonstration project. This included 6 redrills: 2 vertical pilots and 4 horizontal wells. Reservoir characterization efforts included extensive petrophysical and geologic work to thoroughly map and correlate the productive intervals and identify targets, which contained oil bypassed by the natural water drive. Drilling and completion accomplishments include the use of a modified workover rig (240,000 lb. mast) to drill the slimhole wells from 7" casing, and produce the non-gravel packed wells with rod driven production systems. Only 19% of the estimated 521 million bbl original oil in place have been produced (98 million bbl) field wide. The analysis of the Carpinteria field and successful pilot 6 well drilling project has led to an extensive redevelopment plan. The initial results of the redevelopment program have been encouraging, with an additional production of 300,000 BOE. The tentative redevelopment plans include 18 to 27 horizontal wells, 5 to 9 vertical redrills, 20 to 30 workovers, a pilot waterflood, and possibly a full field waterflood project. Introduction Field redevelopment has inherent advantages that can make very profitable additional investment in a previously developed field. Facilities are in place that have already been capitalized by the original development operation. These original facilities are normally oversized for the current production rates from a mature oilfield, and easily can be modified to handle additional oil and gas production. Numerous wells have been drilled in the field, establishing an open hole and production database that allows a much more refined understanding of the field geology and production characteristics. New technology can be applied to the field that may not have existed when the field's initial development was undertaken. Horizontal drilling, geosteering, and polymer mud systems are a few of the giant strides forward that have been made in drilling technology. Progressive cavity pump (PCP) technology can be successfully mated to slimhole electrical submersible motors, or rod driven from the surface to achieve acceptable production rates in sandy environments. This paper addresses how this new technology can be applied to redevelopment opportunities in a mature field. The Carpinteria Offshore field is such a redevelopment opportunity that has seen a successful application of new technology. The field was nearing its economic operating limit when the redevelopment pilot project was initiated in 1997. The redevelopment project was based on the premise that the fixed operating costs offshore were high, but the variable costs of additional production would be relatively low. This paper discusses in depth the geologic modeling and interpretation that led to the decision to go forward with a redevelopment operation using slimhole horizontal redrills from existing producers. The drilling program is outlined and the results compared to expectations are presented. The sand control options are outlined and the application of rod driven PCP and rod pump technology to successfully produce the wells is covered.
- Geology > Structural Geology > Fault (0.48)
- Geology > Geological Subdiscipline > Stratigraphy (0.47)
- Geology > Rock Type (0.47)
- Geology > Sedimentary Geology > Depositional Environment (0.46)
- North America > United States > California > Ventura Basin > Pico Formation (0.99)
- North America > United States > California > Santa Barbara Basin > Summerland Field (0.99)
- North America > United States > California > Carpinteria Field (0.99)
- (3 more...)
The biggest challenge involved finding a of it made them legendary.
- North America > United States > Texas > Anadarko Basin (0.99)
- North America > United States > Oklahoma > Anadarko Basin (0.99)
- North America > United States > Kansas > Anadarko Basin (0.99)
- (2 more...)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Equipment (1.00)
- Well Drilling > Drill Bits (1.00)
- (4 more...)
Abstract Sockeye Field, discovered in 1970, lies offshore California in the Santa Barbara Channel. The decision to develop the field was made in 1983 based on 1979–83 exploration drilling. Platform Gail was installed in 1987 and development drilling commenced in June 1988. Currently there are eleven development wells with plans for two more (two duals and eleven single completions). This project has taken 20 years to reach the development stage since the lease sale in 1968. This long time span was partly due to permitting delays encountered in offshore California projects and a Santa Barbara Channel drilling moratorium in the 1970's. The field produces from five reservoirs; Middle and Upper Sespe Sands, Lower and Upper Topanga Sands, and the Monterey Formation. Sespe Sands are fluvial channel deposits with individual sand bodies with limited areal extents. The Middle Sespe produces dry sweet gas and the Upper Sespe produces dry sweet gas and the Upper Sespe produces sweet 29 degrees API gravity oil. The produces sweet 29 degrees API gravity oil. The Topanga Sands were deposited in a near shore environment and are more continuous in nature. Lower Topanga Sands contain sweet oil whereas Upper Topanga Sands test a low gravity 18 degrees API sour oil. The Monterey Formation is composed of thin beds of cherts, porcellanites, siliceous shales, mudstones, and dolostones. The fractured Lower Monterey produces heavy sour oil, similar to that of the Upper Topanga. To minimize risk, delineation wells were drilled early in the development program to ensure that reserves warranted additional investment in wells and facilities. Nine wells were completed during the first phase of the drilling program. Gas production from these wells was projected to exceed the capacity of the Carpinteria Gas Plant. The drilling rig was put on standby to evaluate various facilities modifications to handle production. At the conclusion of the evaluation, drilling was resumed with plans to drill four more wells. Reservoir information was obtained through an integrated program of formation evaluation, core analysis, production logging and build-up and interference testing. Introduction Sockeye Field is located about six miles north of Anacapa Island and nine miles west of Oxnard (Figure 1) on OCS leases 204,205,208 and 209. This paper describes the detailed history of the field from 1968 when these leases were acquired to the present development stage. Included are present development stage. Included are the exploratory drilling phases, the development drilling phases, the production response and the facilities constraints on production. The reservoir evaluation production. The reservoir evaluation program, which includes pressure testing, program, which includes pressure testing, production logging, rock and fluid analysis production logging, rock and fluid analysis and simulation, is also detailed. GEOLOGY Structure The Sockeye structure is a broad NW-SE trending doubly plunging anticline. Maps 1 and 2 show the structure at the M4 marker and the Sespe unconformity. P. 305
- Geology > Sedimentary Geology > Depositional Environment (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.89)
- North America > United States > California > Ventura Basin > Sockeye Field (0.99)
- North America > United States > California > Ventura Basin > Pico Formation (0.99)
- North America > United States > California > Sespe Formation (0.99)
- (5 more...)
Abstract This paper presents a historical overview of platform design and construction offshore California. platform design and construction offshore California. Twenty-two platforms and seven islands have been installed since the first island was installed offshore Seal Beach in 1948. Seismic design requirements, steeply sloping ocean bottoms, limited availability of heavy derrick barge equipment and unusual producing requirements resulted in a number of producing requirements resulted in a number of innovative platform designs. The first platform was installed offshore California in 1958. This structure, platform Hazel, was also the world's first gravity platform. Platform Hilda was the first tilt-up structure. Platform Hondo, in 850 feet of water, was fabricated in two sections and these were joined underwater after they were launched. Platform Emmy is one of the few platforms that were equipped with pumping units for platforms that were equipped with pumping units for artificial lift. The paper describes the design considerations involved with these platforms as well as the fabrication and installation methods employed. Introduction When researching background material for this paper it was somewhat surprising to find that very paper it was somewhat surprising to find that very little had been published about the early California offshore platforms. In fact, not a single paper could be found describing the design or the construction of platforms Hazel and Hilda (Chevron) or Emmy (Aminoil). platforms Hazel and Hilda (Chevron) or Emmy (Aminoil). Yet these were unique platforms and eminently successful. Why was so little publicity given in the technical journals about these platforms? Part of the reason is that the offshore California activity was always far overshadowed by the Gulf of Mexico and later the North Sea activity. California offshore activity has been sporadic at best. Whereas a hundred or more platforms are installed in the Gulf of Mexico every year, the most active year offshore California (1981) saw the installation of only three platforms. As a result nothing similar to the highly developed and competitive Gulf of Mexico offshore fabrication and construction industry could develop or support itself on the West Coast. A further reason for the difference in platform development between the Gulf of Mexico and California is because of geographic differences. The ocean bottom offshore California slopes quite steeply away from the coast. Accordingly, there is only a narrow band along the coast where relatively inexpensive shallow water platforms can be used. In the Gulf of Mexico, the ocean bottom slopes very gently and the available shallow water area is a multiple of that offshore California. Additionally, platforms offshore California need to be designed for earthquakes which impose quite different load conditions than Gulf of Mexico hurricanes. P. 321
- North America > United States > California > Santa Barbara Basin > Summerland Field (0.99)
- North America > United States > California > Los Angeles Basin > Huntington Beach Field (0.99)
- North America > United States > California > Beta Field (0.99)
- (2 more...)
Summary Besides small amounts of suspended oil, oilfieldproduced water after conventional treatment cancontain dissolved organic and ammonium compounds that may preclude its discharge into the oceanbecause of environmental protection regulations.Two field pilot studies in southern California established the technical feasibility and cost ofremoving these dissolved compounds by biologicaloxidation in a biodisk. Effluent from the two pilot plants complied with all requirements of Californialaw. Introduction Despite the lack of documented adverse effects fromnormal petroleum operations, environmentalprotection regulations have been adopted that limitthe offshore discharge of produced water. The WaterQuality Control Plan for the Ocean Waters ofCalifornia (CWQCP), adopted in 1972 andamended in 1978, regulates all domestic andindustrial wastewaters discharged within California's3-mile (5.5-km) zone. The CWQCP includes effluentlimits on oil and grease, dissolved phenols, dissolvedammonium compounds, and toxicity to marine life.U.S. guidelines proposed in 1975 for the onshore petroleum industry by the Environmental ProtectionAgency would require"zero pollutant discharge"inside the 3-mile (5.5-km) zone by 1983. Previous publications have reported thecompositions of oilfield produced waters. Workdone by Chevron shows that typical produced watersfrom the U.S. west coast and the Gulf of Mexico, after oil removal by gravity separation and/orflotation, have compositions ranging from 20 000 to135 000 g/m3 TDS, 45 to 130 g/m3 ammonia (as N), and 0.1 to 3.0 g/m3 phenols (as C6H5OH). Conventionaloilfield water-separation processes are notdesigned to remove these dissolved compounds, andother treatment processes are needed where disposalrestrictions on such compounds exist. Biological oxidation uses harmless bacteria, algae, fungi, and protozoa to convert dissolved organic andammonium compounds into water plus CO2 andnitrates/nitrites, respectively. A field pilot studyof an aerated lagoon conducted at Carpinteria, CA, demonstrated the feasibility of biological oxidationfor removing dissolved compounds such as ammoniaand phenols from produced waters. This paperdescribes two field pilot studies conducted insouthern California that demonstrated, for the firsttime, the feasibility of another biological oxidationtreatment process - the rotating biological surface(biodisk). JPT P. 1136^
- North America > United States > California (1.00)
- Europe > United Kingdom > North Sea > Central North Sea (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.70)
- North America > United States > California > Santa Barbara Basin > Summerland Field (0.89)
- North America > United States > California > Carpinteria Field (0.89)
JPT Forum Articles are limited to 1,500 words including 250 words for each table and figure, or a maximum of two pages in JPT. A Forum article may present preliminary results or conclusions of an investigation that the present preliminary results or conclusions of an investigation that the author wishes to publish before completing a full study; it may impart general technical information that does not warrant publication as a full-length paper. All Forum articles are subject to approval by an editorial committee. Letters to the editor are published under Dialogue, and may cover technical or nontechnical topics. SPE-AIME reserves the right to edit letters for style and content. Introduction Despite the lack of documented adverse effects, environmental protection regulations severely restrict the offshore discharge of oilfield-produced waters. The California Ocean Plan (COP), adopted in 1972, regulates all domestic and industrial wastewaters discharged within California's 3-mile (4.8-km) zone. The 1972 COP includes strict limits on oil and grease, dissolved phenols and ammonium compounds, and toxicity to phenols and ammonium compounds, and toxicity to marine life. Federal guidelines proposed in 1975 for the offshore petroleum industry by the U.S. Environmental Protection Agency would require "zero pollutant Protection Agency would require "zero pollutant discharge" inside the 3-mile (4.8-km) zone by 1983.Besides small amounts of suspended oil, oilfield produced waters can contain dissolved organics (e.g., produced waters can contain dissolved organics (e.g., organic acids and phenols) and ammonium compounds that conventional oilfield gravity-separation and flotation processes are not designed to remove. Other processes are not designed to remove. Other water-treatment processes may be needed to remove such dissolved compounds and to allow ocean discharge of produced water to continue as an alternative to produced water to continue as an alternative to underground injection. Biological oxidation processes appear suitable for this application.The aerated lagoon is one of the most common biological oxidation processes. It is used widely for treating municipal wastewater and process water from oil refineries and chemical plants. The process is cost-competitive when sufficient land is available and is fairly resistant to sudden changes in feedwater characteristics. Water-retention times range from a few days to more than a month, and water depths range from 6 to 15 ft (2 to 5 m)Aerators are used to supply oxygen to the bacteria and may induce enough mixing in the lagoon to keep a significant portion of the bacteria in suspension. These bacteria then are carried out of the lagoon and contribute to suspended solids in the effluent. Therefore, clarification of lagoon effluent may be required to comply with suspended-solids limits.This paper describes a 19-month field pilot study conducted in southern California that demonstrated for the first time the feasibility of the aerated lagoon for biotreating oilfield-produced water. Description of Pilot Plant The two-stage pilot lagoon (Fig. 1) consisted of two 500-bbl (80-m3), plastic-lined steel tanks in series, each filled with 375 bbl (60 m3) fluid. Stage 1 was primarily for oxidizing suspended oil and dissolved organic compounds; Stage 2 was for oxidizing dissolved ammonium compounds. Each stage was aerated by a variable-speed, "egg-beater" type of mixer. Feedwater flowed continuously to the pilot plant, with each stage independently controlling the water-retention time.Feedwater to the lagoon was a mixture of produced waters from the Carpinteria and Summerland state leases after oil removal by induced-air flotation. The total dissolved solids (TDS) content of the mixture was 20,000 g/m3 . About 10 g of Na3PO4 (as P) was added per cubic meter of feedwater, to ensure adequate (though per cubic meter of feedwater, to ensure adequate (though not necessarily optimum) phosphorus for microbial growth. JPT P. 241
- North America > United States > California (1.00)
- Europe > United Kingdom > North Sea > Central North Sea (0.25)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.90)
- Government > Regional Government > North America Government > United States Government (0.87)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.75)
- North America > United States > California > Santa Barbara Basin > Summerland Field (0.89)
- North America > United States > California > Carpinteria Field (0.89)
ABSTRACT T The importance of the Offshore Province in supplying a significant part of today's energy needs and an increasingly significant part of tomorrow's needs is unquestioned. The greatest uncertainty, however, is just how much of our future supply will come from the offshore areas and, from a total national viewpoint, what is the best way to develop and utilize the potential when balanced against all other alternatives. The evolution, present status and near term status of offshore drilling and production technology is reviewed and summarized. The application of this technology to the development of the petroleum potential of the continental margins (0 to 2500 meters) of the USA is discussed and illustrated. Some effects of hopefully accelerated offshore leasing are examined. N The purpose of this paper is to help provide the answers to at least a part of these questions by summarizing quantitatively the industry's existing capability to provide offshore drilling and producing systems. In doing so it will be instructive to show the evolution of the various segments of offshore drilling and producing technology and to show how we got to where we are today. Without attempting to quantify the tremendous efforts, either in terms of manpower or dollars, I will show where technology stands as of today and where it will very likely be in the next four or five years more or less under existing momentum. I will also discuss how this technology is related to the total potential of the continental margins of the U.S.A. The development of future technology will depend a great deal on the consistent progressive application of today's technology as well as the overall assessment of the rewards and benefits to be achieved by advancing the technology. Remember that technology is not only the acquisition and possession of scientific knowledge but more than that, it is the application of scientific knowledge. Let me bring this point home. I am not aware of any field of scientific endeavor which has even possessed or purported to possess the "final" answer to a particular problem before attempting a solution. There have always been uncertainties and there always will be; but, the uncertainties diminish by orders of magnitude as soon as someone accomplishes the "feat". Then everyone jumps on the bandwagon and says, "I knew it could be done!" Ladies and Gentlemen, the Petroleum Industry, and more particularly the offshore segment of that industry, is no different in this regard from any other field of scientific endeavor. Categorical guarantees just are not in the cards. The real question and often times the most significant problem then is what is the best possible assessment of the realities of a potential course of action; in other words, "Which experts should one believe?" And let's face it, this is no small task because the issues are complex and interwoven and the experts are numerous
- North America > United States > Alaska (0.29)
- North America > United States > California (0.29)
- Europe > United Kingdom > North Sea (0.28)
- North America > United States > Louisiana (0.28)
- North America > United States > California > Santa Barbara Basin > Summerland Field (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Block 211/29 > Brent Field (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 21/10 > Forties Field > Forties Formation (0.99)
- (5 more...)
The existence of petroleum in California has been known for many years. Fromtime immemorial the California Indians used this mineral, in the form ofasphaltum, for various purposes. In the early history of the State the Catholicfathers utilized it for the roofing their missions and other buildings. It is said that in 1855 or 1856 Andreas Pico distilled petroleum on a smallscale for the San Fernando Mission. He obtained his crude oil from Pico canon, near Newhall, in Los Angeles county; and he was probably the first refiner of petroleum in this State. In 1856 a company commenced work at the La Brea ranch, in Los Angeles county, and tried to refine the crude oil. In 1857 an attemptwas made to produce illuminating-oil from crude petroleum at Carpentaria, inSanta Barbara county; and there are records of similar attempts in otherlocalities previous to 1860; but none of them were successful. The first scientific report on petroleum in California was made by Prof. B.Silliman, who published his researches in 1865. He spoke favorably of thepossibility of obtaining petroleum in remunerative quantities in this State, and gave the results of his experiments in the Fractional distillation ofCalifornia petroleum. The next decade was marked by a considerable oil-excitement in California; anda great many companies were formed for the purpose of petroleum-mining and fordistilling crude oil. In most instances these companies did not meet with success; but it must beremembered that the pioneer oil-miners did not have the drilling-machinery ofthe present day, and that they possessed a very limited knowledge concerningthe geological conditions pertaining to the occurrence ofpetroleum-deposits. The pioneer distillers appear to have expected that by the fractionaldistillation of California petroleum they would obtain similar products tothose resulting from the fractional distillation of the petroleum found in theEastern States; but they were disappointed. It is not surprising that, i11 the course of years, the smaller operators became merged in larger concerns. In1887, when the State Mining Bureau made a reconnaissance of thepetroleum-industry of California, the only companies actually engaged inpetroleum-mining were: The Pacific Coast Oil Co. in Pico canon and the PuenteOil Co. in the Puente hills, Los Angeles county; the Hardison and Stewart OilCo., subsequently incorporated as the Union Oil Co., of Ventura county; andMcPherson &Co., operating in Moody Gulch, in Santa Clara county. AIME 029–53
- Geology > Rock Type > Sedimentary Rock (0.47)
- Geology > Mineral (0.35)
- North America > United States > California > Santa Barbara Basin > Summerland Field (0.99)
- North America > United States > California > Salinas Basin > Coalinga Field (0.99)
- North America > United States > California > Los Angeles Basin > Los Angeles Field (0.99)
- (3 more...)